Source: http://federal.elaws.us/fr/5/11/2018/2018-09305
Timestamp: 2019-08-18 21:47:58
Document Index: 560339762

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2018-09305. Oil and Gas and Sulfur Operations in the Outer Continental Shelf-Blowout Preventer Systems and Well Control Revisions, Federal Register
Home » 2018 Issues » 83 FR (05/11/2018) » 2018-09305. Oil and Gas and Sulfur Operations in the Outer Continental Shelf-Blowout Preventer Systems and Well Control Revisions
2018-09305. Oil and Gas and Sulfur Operations in the Outer Continental Shelf-Blowout Preventer Systems and Well Control Revisions
Start Preamble Start Printed Page 22128
The Bureau of Safety and Environmental Enforcement (BSEE) is proposing to revise existing regulations for well control and blowout preventer systems. This proposed rule would revise requirements for well design, well control, casing, cementing, real-time monitoring (RTM), and subsea containment. These revisions modify regulations pertaining to offshore oil and gas drilling, completions, workovers, and decommissioning in accordance with Executive and Secretary of the Interior's Orders to ensure safety and environmental protection, while correcting errors and reducing certain unnecessary regulatory burdens imposed under the existing regulations. Accordingly, after thoroughly reexamining the original Blowout Preventer Systems and Well Control final rule (WCR), experiences from the implementation process, and BSEE policy, BSEE proposes to amend, revise, or remove current regulatory provisions that create unnecessary burdens on stakeholders while ensuring safety and environmental protection. The proposed regulations would also address various issues and errors that were identified during the implementation of the recent rulemaking on these issues.
You may submit comments on the rulemaking by any of the following methods. Please use the Regulation Identifier Number (RIN) 1014-AA39 as an identifier in your message. See also Public Availability of Comments under Procedural Matters.
The American Petroleum Institute (API) provides free online public access to view read only copies of its key industry standards, including a broad range of technical standards. All API standards that are safety-related and that are incorporated into Federal regulations are available to the public for free viewing online in the Incorporation by Reference Reading Room on API's website at: http://publications.api.org.[1] In addition to the free online availability of these standards for viewing on API's website, hardcopies and printable versions are available for purchase from API. The API website address to purchase standards is: http://www.api.org/​publications-standards-and-statistics/​publications/​government-cited-safety-documents.
The International Organization for Standardization (ISO) creates documents that provide requirements, specifications/government-cited-safety documents. ISO creates documents that provide requirements, specifications, guidelines or characteristics that can be used consistently to ensure that materials, products, processes and services are fit for their purposes. All ISO International Standards are available at the ISO Store for purchase, https://www.iso.org/​store.html.
Send comments on the information collection in this rule to: Interior Desk Officer 1014-0028, Office of Management and Budget; 202-395-5806 (fax); email: oira_submission@omb.eop.gov. Please send a copy to BSEE.
Public Availability of Comments—Before including your address, phone number, email 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. In order for BSEE to withhold from disclosure your personal identifying information, you must identify any information contained in the submittal of your comments that, if released, would constitute a clearly unwarranted invasion of your personal privacy. You must also briefly describe any possible harmful consequence(s) of the disclosure of information, such as embarrassment, injury, or other harm. 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.
For technical questions contact Fred Brink, GOMR District Operations Support, (504) 736-2400, or by email: OMM_DFO_DOS@bsee.gov; for procedural questions contact Kirk Malstrom, Regulations and Standards Branch, (202) 258-1518, or by email: regs@bsee.gov.
Although the WCR addressed a significant number of issues that were identified during the analysis of the Deepwater Horizon incident, BSEE recognized that BOP equipment and systems continue to improve technologically and well control processes also evolve. Therefore, since the WCR became effective in 2016, BSEE has continued to engage with the offshore oil and gas industry, Standards Development Organizations (SDOs), and other stakeholders. During the course of these engagements, BSEE identified issues and stakeholders expressed a Start Printed Page 22129variety of concerns regarding the implementation of the WCR. For instance, oil and natural gas operators raised concerns about certain regulatory provisions that impose undue burdens on their industry, but do not significantly enhance worker safety or environmental protection (e.g., how RTM is monitored and utilized onshore, a strictly enforced 0.5ppg drilling margin, having requirements inconsistent with API Standard 53—an American National Standards Institute (ANSI) accredited, voluntary consensus standards development organization, and delays waiting for certain BSEE approvals during cementing operations). Other stakeholders suggested that certain regulatory requirements do not properly account for advances or limitations in technology and processes. Further, BSEE received numerous questions regarding the proper interpretation and application of provisions viewed to be unclear or ambiguous, requiring BSEE to provide substantial informal guidance regarding the terms of the WCR.
In keeping with the Executive and Secretary's Orders, BSEE undertook a review of the 2016 Well Control Final Rule with a view toward the policy direction of encouraging energy exploration and production on the OCS and reducing unnecessary regulatory burdens while ensuring that any such activity is safe and environmentally responsible. BSEE carefully analyzed all 342 provisions of the 2016 Well Control Final Rule, and determined that only 59 of those provisions—or less than 18% of the 2016 Rule—were appropriate for revision. In the process, BSEE compared each of the proposed changes to the 424 recommendations arising from 26 separate reports from 14 different organizations developed in the wake of and response to the Deepwater Horizon disaster, and determined that none of the proposed changes ignores or contradicts any of those recommendations, or would alter any provision of the 2016 Well Control Final Rule in a way that would make the result inconsistent with those recommendations. Further, nothing in this proposed rule would alter any elements of other rules promulgated since Deepwater Horizon, including the Drilling Safety Rule (Oct. 2010), SEMS I (Oct. 2010), and SEMS II (April 2013). BSEE's review has been thorough, careful, and tailored to the task of reducing unnecessary regulatory burdens while ensuring that OCS activity is safe and environmentally responsible.
B. Purpose and Summary of the Rulemaking
C. Summary of Documents Incorporated by Reference
D. New Executive and Secretary's Orders
II. Section-by-Section Discussion of Proposed Changes
III. Additional Comments Solicited
A. BOP Testing Frequency
To carry out its responsibilities, BSEE regulates offshore oil and gas operations to enhance the safety of exploration for and development of oil and gas on the OCS, to ensure that those operations protect the environment, and to implement advancements in technology. BSEE also conducts onsite inspections to assure compliance with regulations, lease terms, and approved plans and permits. Detailed information concerning BSEE's regulations and guidance to the offshore oil and gas industry may be found on BSEE's website at: http://www.bsee.gov/​Regulations-and-Guidance/​index.
BSEE's regulatory program covers a wide range of facilities and activities, including drilling, completion, workover, production, pipeline, and decommissioning operations. Drilling, completion, workover, and decommissioning operations are types of well operations that offshore operators [2] perform throughout the OCS. These well operations are the primary focus of this rulemaking.
This proposed rule would amend and update certain provision of the Blowout Preventer Systems and Well Control regulations and update the regulations to better implement BSEE policy. This proposed rule would fortify the Administration's position towards facilitating energy dominance leading to increased domestic oil and gas production, and reduce unnecessary burdens on stakeholders while ensuring safety and environmental protection. Since 2010, BSEE has promulgated many rulemakings (e.g., Safety and Environmental Management Systems (SEMS) I and II, the final safety measures rule, and the production safety systems final rule) to improve worker safety and environmental protection. Additionally, on April 29, 2016, BSEE published a final rule to consolidate into one part the equipment and operational requirements that were found in various parts of BSEE's regulations pertaining to well control for offshore oil and gas drilling, completions, workovers, and decommissioning (81 FR 25888). That final rule addressed issues relating to Start Printed Page 22130BOP and well-control requirements. More specifically, the final rule incorporated industry standards; adopted reforms to well design, well control, casing, cementing, real-time well monitoring, and subsea containment requirements; and implemented many of the recommendations resulting from various investigations of the Deepwater Horizon incident. Most of the provisions of that rulemaking became effective on July 28, 2016.
Since the time the Blowout Preventer Systems and Well Control regulations took effect, oil and natural gas operators have raised various concerns, and BSEE has identified issues during the implementation of the recent rulemaking. The concerns and issues involve certain regulatory provisions that impose undue burdens on oil and natural gas operators, but do not significantly enhance worker safety or environmental protection. BSEE understands the concerns that have been raised, but BSEE also fully recognizes that the BOP and other well-control requirements are critical components in ensuring safety and environmental protection. After thoroughly reexamining the Blowout Preventer Systems and Well Control regulations, BSEE has identified those provisions that can be amended, revised, or removed to reduce significant burdens on oil and natural gas operators on the OCS while ensuring safety and environmental protection. In keeping with the Executive and Secretary's Orders, BSEE undertook a review of the 2016 Well Control Final Rule with a view toward the policy direction of encouraging energy exploration and production on the OCS and reducing unnecessary regulatory burdens while ensuring that any such activity is safe and environmentally responsible. BSEE carefully analyzed all 342 provisions of the 2016 Well Control Final Rule, and determined that only 59 of those provisions—or less than 18% of the 2016 Rule—were appropriate for revision. In the process, BSEE compared each of the proposed changes to the 424 recommendations arising from 26 separate reports from 14 different organizations developed in the wake of and response to the Deepwater Horizon disaster, and determined that none of the proposed changes ignores or contradicts any of those recommendations, or would alter any provision of the 2016 Well Control Final Rule in a way that would make the result inconsistent with those recommendations. Further, nothing in this proposed rule would alter any elements of other rules promulgated since Deepwater Horizon, including the Drilling Safety Rule (Oct. 2010), SEMS I (Oct. 2010), and SEMS II (April 2013). BSEE's review has been thorough, careful, and tailored to the task of reducing unnecessary regulatory burdens while ensuring that OCS activity is safe and environmentally responsible.
API Standard 53—Blowout Prevention Equipment Systems for Drilling Wells
API Recommended Practice 17H—Remotely Operated Tools and Interfaces on Subsea Production Systems
ISO ISO/IEC 17021-1—Conformity Assessment—Requirements for Bodies Providing Audit and Certification of Management Systems
The proposed rule would incorporate this standard into the regulations by Start Printed Page 22131reference for the first time, for purposes of the quality management system certification requirements of section 250.730(d). This standard contains principles and requirements for the competence, consistency, and impartiality of bodies providing audit and certification of all types of management systems. It provides generic requirements for such bodies performing audit and certification in the fields of quality, the environment, and other types of management systems. Incorporation of this standard would provide clarity and consistency surrounding the critical qualifications of entities responsible for certifying quality management systems for the manufacture of BOP stacks.
When a copyrighted publication is incorporated by reference into BSEE regulations, BSEE is obligated to observe and protect that copyright. BSEE provides members of the public with website addresses where these standards may be accessed for viewing—sometimes for free and sometimes for a fee. Standards development organizations decide whether to charge a fee. One such organization, the American Petroleum Institute (API), provides free online public access to view read only copies of its key industry standards, including a broad range of technical standards. All API standards that are safety-related and that are incorporated into Federal regulations are available to the public for free viewing online in the Incorporation by Reference Reading Room on API's website at: http://publications.api.org.[3] In addition to the free online availability of these standards for viewing on API's website, hardcopies and printable versions are available for purchase from API. The API website address to purchase standards is: http://www.api.org/​publications-standards-and-statistics/​publications/​government-cited-safety-documents.
BSEE is also considering potential, technical (non-substantive) revisions to § 250.198 for the purposes of reorganizing and revising that section to make it clearer, more user-friendly, and more consistent with the Office of the Federal Register's (OFR) recommendations for incorporations by reference in Federal regulations. BSEE will continue to consult with OFR regarding its suggestions for specific organizational and language changes to § 250.198 and expects to address such technical revisions in a final rule as soon as possible. BSEE does not anticipate that those potential revisions would have any substantive impact on the proposed incorporations by reference of industry standards discussed in this rule.
On March 28, 2017, the President issued Executive Order (E.O.) 13783—Promoting Energy Independence and Economic Growth (82 FR 16093). The E.O. directed Federal agencies to review all existing regulations and other agency actions and, ultimately, to suspend, revise, or rescind any such regulations or actions that unnecessarily burden the development of domestic energy resources beyond the degree necessary to protect the public interest or otherwise comply with the law.
On April 28, 2017, the President issued E.O. 13795—Implementing an America-First Offshore Energy Strategy (82 FR 20815), which directed the Secretary to review the WCR for consistency with the policy set forth in section 2 of E.O. 13795, and to “publish for notice and comment a proposed rule revising that rule, if appropriate and as consistent with law.” To further implement E.O. 13795, the Secretary issued Secretary's Order No. 3350 on May 1, 2017, directing BSEE to review the WCR for consistency with E.O. 13795, including preparation of a report “providing recommendations on whether to suspend, revise, or rescind the rule” in response to concerns raised by stakeholders that the WCR “unnecessarily include[s] prescriptive measures that are not needed to ensure safe and responsible development of our OCS resources.”
Implementation of the Original WCR—BSEE Questions and Answers (Q's and A's)
The Department promulgated the original “Blowout Preventer Systems and Well Control” final rule (WCR) in April 2016. Subsequently, during the implementation of the revised regulations, BSEE received numerous questions from stakeholders seeking clarification and guidance concerning the WCR's provisions. The questions covered a vast array of issues and spanned multiple subparts of the regulations.
BSEE reviewed each question it received and decided whether the question presented an issue that was appropriate for Bureau guidance. To the extent a question required guidance or clarification, BSEE provided a response to clarify any potentially confusing language. In addition to deciding on the appropriateness of a question for guidance, BSEE determined whether a question posed was of sufficient public interest to merit broader publication of a response. After finalizing regulatory Start Printed Page 22132guidance in response to a stakeholder's question, BSEE typically publishes both the question and BSEE's answer on its web page. The information, which reflects BSEE's guidance of the current regulations, may be found at: https://www.bsee.gov/​guidance-and-regulations/​regulations/​well-control-rule. BSEE has posted approximately 100 responses on the web page.
Additionally, there were eight presentations made at the forum. These presentations are available at https://www.bsee.gov/​guidance-and-regulations/​regulations/​well-control-rule/​public%20forum.
BSEE would revise paragraph (h)(63), which incorporates API Standard 53, Blowout Prevention Equipment Systems for Drilling Wells, Fourth Edition, November 2012, to add a new cross reference to § 250.734. The changes to this paragraph are administrative and merely reflect substantive changes made to § 250.734, addressed further at the corresponding location in the section-by-section discussion.
BSEE would revise paragraph (h)(78), which incorporates API Standard 65—Part 2, Isolating Potential Flow Zones During Well Construction; Second Edition, December 2010, to add a new cross reference to § 250.420(a)(6). The changes to this paragraph are administrative. For discussion of the effects on the regulatory requirements of incorporating this document, refer to § 250.420(a)(6).
BSEE would also revise paragraph (h)(94) to update the incorporation of API RP 17H to the second edition. The changes to this paragraph are administrative. For discussion of the effects on the regulatory requirements of incorporating this document, refer to § 250.734(a)(4). BSEE has reviewed the differences between the first and second editions of API RP 17H. The API RP 17H second edition was mostly rearranged to clarify and consolidate similar topics covered in the first edition. The second edition now includes the following sections: Subsea intervention concepts, subsea intervention systems design recommendations, ROV interfaces, materials, subsea markings, and validation and verification. These sections are mostly a reorganization of the content of the first edition with minor changes to the design recommendations. The most significant change from the first edition to the second edition was the addition of the Type D connection to the ROV interface section. The Type D connection is intended for large bore, high circulation capabilities and is limited to the maximum rated pressure of 5,000 psi. This Type D connection allows the ROV hot stab to meet the API Standard 53 closing timing requirements, which API RP 17H first edition did not accomplish.
BSEE would add new paragraph (m)(2) for the International Organization for Standardization (ISO) 17021 to update the erroneous standard incorporated in the original WCR. For discussion of the effects on the regulatory requirements of incorporating this document, refer to § 250.730(d) and the associated section-by-section discussion.
This rulemaking would revise paragraph (p) by clarifying the free standing hybrid riser (FSHR) requirements and removing the requirement for certification of the tether system and connection accessories by an approved classification society or equivalent. Based on BSEE experience during the implementation of the original WCR, these revisions to paragraph (p) would clarify the focus of the requirements for FSHR systems that involve a buoyancy air can suspended from the top of the riser, regardless of the manner of connection, to avoid confusion over whether a specific component type would be considered `critical' or not. The requirements in existing § 250.292(p)(2) and (p)(3) would be removed because the detailed information specified on the FSHR design, fabrication, installation, and load cases is already required by the relevant portions of the platform verification program (PVP) in § 250.910(b), and in §§ 250.1002(b)(5) and 250.1007(a)(4)(ii). This would reduce the burden on operators by eliminating the requirement to submit the same or very similar information on an FSHR system through more than one regulatory permitting process. Section 250.292 paragraphs (p)(4) and (p)(5) would be redesignated as § 250.292 paragraphs (p)(2) and (p)(3), and their language would be revised to align with the clarification in paragraph (p). The requirements in § 250.292(p)(6) would be removed altogether, because they are duplicative of the certification that any permanent pipeline riser installation and its tensioning systems will undergo via the Certified Verification Agent (CVA) requirements of § 250.911, in connection with the PVP.
What must my description of well drilling design criteria address? (§ 250.413)
This rulemaking would add in paragraph (g) a parenthetical clarification of “surface and downhole” after “proposed drilling fluid weights”, to ensure the operator includes the weight of the drilling fluid in both places. This clarifies the information the operator has previously been required to provide, without adding a new burden, and improves the safety of the drilling operation by ensuring the drilling fluid weight is fully evaluated and appropriate for the estimated bottom hole pressures.
What must my drilling prognosis include? (§ 250.414)
This proposed rule would revise paragraph (c)(3) of this section to add Start Printed Page 22133the words “and analogous” before “well behavior observations” and “, if available” at the end of paragraph (c)(3) of this section. This minor wording change would ensure that operators use available data from wells with similar conditions as the well being drilled when determining the pore pressure and fracture gradient to ensure accuracy and safety when establishing the drilling margin. BSEE is specifically soliciting comments about the effectiveness of the use of related analogous data and how the pore pressure and fracture gradient are determined without related analogous data. Please provide reasons for your position.
The purpose of the drilling margin is to ensure that the drilling fluid weight used allows for some variability in the pore pressure and fracture gradient, ensuring the safety of drilling operations. In 2011, the National Academy of Engineering and National Research Council of the National Academies recommended that “[d]uring drilling, rig personnel should maintain a reasonable margin of safety between the equivalent circulating density and the density that will cause wellbore fracturing.” Macondo Well Deepwater Horizon Blowout—Lessons for Improving Offshore Drilling Safety (NAE Report), Recommendation 2.2 (p. 43). The NAE Report stated further that “until a reasonable standard is established, industry should design the ECD [equivalent circulating density] so that the difference between the ECD and the fracture mud weight is a minimum of 0.5 ppg . . . Additional evaluations and analyses should be performed to establish an appropriate standard for this margin of safety.” Id. The Department's 2011 joint investigation team report (DOI JIT Report) regarding the causes of the April 20, 2010, Macondo Well blowout recommended that BSEE define the term “safe drilling margin(s)” and that such a definition should “encompass pore pressure, fracture gradient and mud weight.” The Bureau of Ocean Energy Management, Regulation and Enforcement Report Regarding the Causes of the April 20, 2010, Macondo Well Blowout (DOI JIT Report), Recommendation 3 (p. 202). Thus, the NAE Report and the DOI JIT Report recommended additional evaluations, analyses, and definition of what a safe drilling margin is. In the 2016 final well control rule preamble, BSEE cited this JIT Report recommendation and the bureau's prior typical reliance on a minimum of 0.5 ppg below the lower casing shoe pressure integrity test or the lowest estimated fracture gradient as an appropriate safe drilling margin and as the basis for including this as the default requirement in the current section 250.414(c). 81 FR 25888, 25894 (April 29, 2016). Section 250.414(c) also allows for using an equivalent downhole mud weight, provided that the operator submitted adequate documentation justifying the use of an alternative equivalent downhole mud weight.
Blowout Preventer Systems and Well Control Rule.—The Committees encourage the Bureau to evaluate information learned from additional stakeholder input and ongoing technical conversations to inform implementation of this rule. To the extent additional information warrants revisions to the rule that require public notice and comment, the Bureau is encouraged to follow that process to ensure that offshore operations promote safety and protect the environment in a technically feasible manner.
For these reasons, BSEE is requesting comment and further statistical analysis from stakeholders about whether the 0.5 ppg drilling margin in this proposed rule should be revised or removed. BSEE solicits comments on alternatives to the current set 0.5 ppg drilling margin. Specifically, BSEE requests comment on replacing it with a more performance-based standard under which the approved safe drilling margin is established on a case-by-case basis for each well, based on data and analysis particular to that well, through the permitting process. BSEE also requests comment on potentially providing for a different drilling margin or multiple drilling margins that are specific to the conditions in which the wells are drilled, such as if the well is drilled in deep water or shallow water. BSEE further requests comment on whether removal of a specific reference to a 0.5 ppg standard from the regulation may be appropriate. For example, the standard establishes a prescriptive margin without an in-depth analysis of appropriate margins for potential hole sections, which must take into account factors, such as cutting loads, equivalent downhole mud weight, and fluid temperatures and pressures. Further, enforcing a prescriptive minimum margin can force operators to encroach on pore pressure, which might result in unintended kicks. These types of considerations may suggest that a more case-by-case approach toward the establishment of appropriate safe drilling margins for particular wells through the permitting process would be preferable. Consequently, BSEE specifically solicits comments regarding the potential removal of the specific reference to a 0.5 ppg drilling margin from § 250.414(c) and its replacement with a more performance based, case-by-case standard for the establishment of appropriate safe drilling margins through the well permitting process.
BSEE also requests comment on the criteria that BSEE could use to apply alternative approaches, such as an operator demonstrating that a well is a development well as opposed to an exploratory well. To utilize this alternative option, the rulemaking could specify what documentation operators would need to submit with the APD in order to provide adequate justification. BSEE requests comment on what supplemental data would provide an adequate level of justification for deviating from the 0.5 ppg drilling margin under identified circumstances, such as requiring the submission of Start Printed Page 22134offset well data, analog data, seismic data, and decision modeling.
BSEE also requests comment on whether there are situations where drilling can continue prior to receiving alternative safe drilling margin approval from BSEE. BSEE requests comment on (1) whether there are situations where, despite not being able to maintain the approved safe drilling margin, an operator's continued drilling with an alternative drilling margin creates little risk; (2) the criteria that BSEE should use to define those situations and the available alternative drilling margins; and (3) what level of follow-up reporting (e.g. submitting a follow-up notice to BSEE within a specified time frame) would be appropriate. Such an approach could provide assurance that an operator, with the appropriate level of justification, could continue to drill as real time data is evaluated, and would largely be designed to add more clarity to the existing option(s) provided by § 250.414(c)(2). This would provide a proactive approach to managing risk and ensuring safe operations, while also providing increased investment certainty for the regulated community.
In addition, BSEE could add the words “and analogous” before “well behavior observations” and “, if available” at the end of paragraph (c)(3) of this section. This minor wording change could ensure that operators use available data from wells with similar conditions as the well being drilled when determining the pore pressure and fracture gradient to ensure accuracy and safety when establishing the drilling margin. BSEE is specifically soliciting comments about the effectiveness of the use of related analogous data and how the pore pressure and fracture gradient are determined without related analogous data. Please provide reasons for your position.
What well casing and cementing requirements must I meet? (§ 250.420)
What are the casing and cementing requirements by type of casing string? (§ 250.421)
What are the requirements for casing and liner installation? (§ 250.423)
This rulemaking would revise paragraphs (a) and (b) by removing the words “and cementing” after “upon successfully installing”. Revisions to this section are necessary because there are many situations in the design of the casing or liner string running tool where the latching or lock down mechanism is automatically engaged upon installing the string. BSEE has received many alternate procedure requests to accommodate these situations since publication of the original WCR. This change would not impact safety because BSEE is still requiring these mechanisms to be engaged upon successful installation of the casing or liner. The proposed change would allow more flexibility on an operational case-by-case basis in determining the appropriate time to engage these mechanisms and would also reduce the number of alternate procedure requests submitted to BSEE for approval.
What must I do in certain cementing and casing situations? (§ 250.428)
BSEE is proposing to revise paragraph (c) to include the term “unplanned” when describing the lost returns that provide indications of an inadequate cement job. This revision would minimize the number of unnecessary revised permits submitted to BSEE for approval. Current cementing practices utilize improved well modelling to identify and account for zones that may have anticipated losses. It is unnecessary to submit a revised APD to address lost returns for a well cementing program that has been designed for those occurrences. Any unexpected losses would require locating top of cement and determining whether the cement job is adequate.
Paragraph (d) would be revised to clarify that, if there is an inadequate cement job, operators are required to comply with § 250.428(c)(1). The original WCR did not address this provision, however based upon BSEE experience this revision would help assess the overall cement job to allow for improved planning of remedial actions.
Based upon BSEE experience with the implementation of the original WCR, BSEE has determined that allowing the professional engineer (PE) to certify the remedial cementing actions in the contingency plan within the original permit would help streamline the Start Printed Page 22135permitting process and reduce delays to remedial actions without compromising safety. The proposed revision to this paragraph would eliminate the requirement for a PE certification for any changes to the well program so long as the changes were already approved in the permit. This would result in less rig down time waiting for PE certifications before beginning initial remedial actions. In conjunction with the approval of the remedial actions BSEE requires a PE certification for any changes to the well program. These proposed revisions would minimize the number of revised permits submitted to BSEE for approval, reducing burdens on operators and BSEE.
What are the diverter actuation and testing requirements? (§ 250.433)
What are the requirements for directional and inclination surveys? (§ 250.461)
What are the source control, containment, and collocated equipment requirements? (§ 250.462)
Paragraph (b) of this section would be revised to clarify that the source control and containment equipment (SCCE) to which operators need to have access is based on the determinations regarding source control and containment capabilities required in § 250.462(a), and that the identified list of equipment represents examples of the types of SCCE that may be determined appropriate rather than universal requirements. Based upon BSEE experience with the implementation of the original WCR, this revision would help ensure that appropriate SCCE is available for the specific corresponding well rather than requiring every possible type of SCCE regardless of the well-specific determinations.
Paragraph (e)(1)(ii) would be revised to remove “a BSEE approved verification organization” and replace it with “an independent third party” that meets the requirements of § 250.732(b). For a discussion on the changes from a BAVO to an independent third party, see the section-by-section discussion of § 250.732.
Tubing and Wellhead Equipment (§ 250.518)
This rulemaking would revise paragraph (e)(1) by clarifying that only permanently installed packers or bridge plugs that are qualified as mechanical barriers are required to comply with ANSI/API Spec. 11D1. Based upon BSEE experience with the implementation of the original WCR, including questions BSEE received from operators, this revision would codify BSEE's policy to ensure that the required mechanical barriers in a well are held to a higher standard than other common packers or bridge plugs used for various other well-specific conditions and completions design. Furthermore, BSEE is aware that certain packers and bridge plugs cannot meet the specifications of ANSI/API Spec. 11D1. BSEE does not expect these revisions to reduce safety. The proposed change would ensure that the packers and bridge plugs utilized as required mechanical barriers are ANSI/API Spec. 11D1 compliant, while eliminating the need for packers and plugs used for other, non-critical, purposes to meet the standard.
What are the requirements for casing pressure management? (§ 250. 519)
How do I manage the thermal effects caused by initial production on a newly completed or recompleted well? (§ 250.522)
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)
BSEE would make minimal revisions to this section to update incorrect citations. These revisions are Start Printed Page 22136administrative in nature and ensure that the appropriate citations are correctly cross referenced.
What if my casing pressure request is denied? (§ 250.530)
Definitions (§ 250.601)
This rulemaking would revise the definition of routine operations in this section to make it consistent with the definition of routine operations in § 250.105 by adding paragraph (m) “acid treatments.” The original WCR did not address this provision, however based upon BSEE experience, this revision is necessary to help minimize confusion about the definition of routine operations.
Coiled tubing and snubbing operations (§ 250.616)
This section would be removed and reserved. The content of this section would be moved to proposed § 250.750, with minor revisions discussed in connection with that provision. These revisions would help BSEE eliminate inconsistencies between similar requirements throughout different BSEE subparts by consolidating those requirements into Subpart G which is applicable to drilling, completions, workovers, and decommissioning operations.
Tubing and wellhead equipment (§ 250.619)
This rulemaking would revise paragraph (e)(1) by clarifying that only permanently installed packers or bridge plugs that are qualified as mechanical barriers are required to comply with ANSI/API Spec. 11D1. This revision would codify BSEE's policy developed since the WCR, to ensure that the required mechanical barriers in a well are held to a higher standard than other common packers or bridge plugs used for various well specific conditions and completions design. Furthermore, BSEE is aware that certain packers and bridge plugs cannot meet the specifications of ANSI/API Spec. 11D1. BSEE would also add that operators must have two independent barriers, one being mechanical, in the exposed center wellbore prior to removing the tree or well control equipment. This addition would codify existing BSEE policy and add into the workover regulations in Subpart F requirements about mechanical barriers similar to those already found in § 250.720(a). This addition would help ensure the well is properly secured before removal of the tree or well control equipment.
What rig unit movements must I report? (§ 250.712)
When and how must I secure a well? (§ 250.720)
BSEE proposes to revise paragraph (a)(1) to add an impending National Weather Service-named tropical storm or hurricane to the list of example events that would interrupt operations and require notification. Furthermore, BSEE also proposes to add new paragraph (a)(3) to include provisions for testing the applicable BOP or lower marine riser package (LMRP) upon relatch according to § 250.734 paragraphs (b)(2) or (b)(3), respectively, and obtaining BSEE approval before resuming operations. Based upon BSEE experience with the implementation of the original WCR and longstanding policy, these revisions would codify the BSEE storm policy reflected in longstanding guidance and provide clarity for testing when an operator has returned to the location and relatched the BOP or LMRP. These tests help confirm that the BOP or LMRP is properly functional prior to resuming operations after being unlatched due to a storm or other interruption.
This rulemaking would also add new paragraph (d) requiring equipment and capabilities for well intervention. This addition would specify that equipment used solely for well intervention must be readily available for use, maintained in accordance with applicable original equipment manufacturer (OEM) recommendations, and available for inspection by BSEE upon request. BSEE would add this paragraph to ensure that when intervention is necessary on a well, the applicable tools (such as the tree interface tools) are available and ready for their intended use. BSEE is aware of recent instances where intervention was necessary on a particular subsea tree, and the tree-specific unique interface tools were not available to perform the work on that well, delaying the operations.
What are the requirements for prolonged operations in a well? (§ 250.722)
BSEE is proposing to revise the prolonged operations well casing reporting requirements in paragraph (a)(2) of this section to clarify that District Manager approval is not required to resume operations if a successful pressure test was conducted as already approved in the applicable permit. BSEE would also clarify that the successful pressure test results must be documented in the Well Activity Report (WAR). The original WCR did not address the issue of District Manager approval, however based upon BSEE experience, these revisions would minimize the amount of unnecessary rig operational time waiting for separate BSEE approval of the successful pressure test where BSEE has already approved the relevant testing and streamline BSEE approval of associated operations. These revisions would be applicable only if the actions are appropriately planned for and already approved in the associated permit. The pressure tests are conducted to help verify casing integrity. BSEE would also make a minor revision to this paragraph to provide that the calculations are used to “indicate” not “show” that the well's integrity is above the minimum safety factors. This change is necessary because the calculations do not guarantee or “show” integrity; they are used as a way to help determine well integrity. Using the word “indicate” removes the definitive statement or assumption that the calculations demonstrate well integrity. BSEE does not expect these revisions to decrease safety because, by approving the test pressure described in the APD, BSEE has determined that any test that successfully meets the pre-approved test pressure for that casing design is sufficient. Therefore, requiring an additional, subsequent approval of the test results before operations may be resumed is redundant and unnecessary and does not improve safety. BSEE will Start Printed Page 22137be notified of the test results through the reporting requirements of the WAR.
What additional safety measures must I take when I conduct operations on a platform that has producing wells or has other hydrocarbon flow? (§ 250.723)
This rulemaking would revise this section by removing the phrase “or lift boat.” This revision would mostly impact paragraph (c)(3) which requires a shut-in of all producible wells located in the affected wellbay when a lift boat moves within 500 feet of the platform until the lift boat is secured in place and ready to begin operations. Removing the references to lift boats from these requirements would minimize the number of unnecessary well shut-ins and delayed production. Since the original WCR, BSEE reevaluated the lift boat activities, and determined that the vast majority of lift boats used on the OCS are relatively small when compared to the size of a mobile offshore drilling unit (MODU) and would not have the same operational impacts and potential risks as a MODU. BSEE is considering the effects of the size of lift boats for potential future rulemakings, and may gather additional information and provide guidance on a case-by-case basis for any lift boats comparable in size to a MODU.
What are the real-time monitoring requirements? (§ 250.724)
What are the general requirements for BOP systems and system components? (§ 250.730)
BSEE proposes to revise paragraph (a) by removing “excluding casing shear” and replacing “at all times” with “in the event of flow due to a kick.” Based upon BSEE experience with the implementation of the original WCR, BSEE is removing the phrase “excluding casing shear” because it is not necessary in this context. The requirements of this sentence are applicable to the entire BOP system, including the casing shear. BSEE expects the BOP system as a whole to be capable of closing and sealing the wellbore. BSEE also proposes to clarify that the BOP system must be able to close and seal the wellbore in the event of flow due to a kick. BSEE would make this change to codify BSEE guidance on the original WCR posted on the BSEE website at https://www.bsee.gov/​guidance-and-regulations/​regulations/​well-control-rule. BSEE understands mechanical and operational design limits of equipment and expects operators to ensure ram closure time and sealing integrity before exceeding those operational and mechanical limits.
Paragraph (b) would be revised to clarify that BSEE expects the use of “applicable” OEM recommendations for the design, fabrication, maintenance, and repair of BOP systems, as well as personnel training in their use. The proposed revision to include “applicable” is necessary because some OEMs may not have specific recommendations for every item required by this paragraph. BSEE expects operators to follow OEM recommendations to the extent relevant recommendations exist.
BSEE proposes to add new paragraph (c)(4) to explain that BSEE may designate a third party to collect failure data and reports on behalf of BSEE, and failure data and reports must be sent to the designated third party. The changes regarding submittal of the reports to BSEE or designated third party would codify BSEE guidance on the original WCR posted on the BSEE website at https://www.bsee.gov/​guidance-and-regulations/​regulations/​well-control-rule.
BSEE is currently using www.SafeOCS.gov as the designated third party. Reporting instructions are on the SafeOCS website at: www.SafeOCS.gov. Reports submitted through www.SafeOCS.gov are collected and analyzed by the Bureau of Transportation Statistics (BTS) and protected from release under the Confidential Information Protection and Statistical Efficiency Act (CIPSEA), which permits BTS to confidentially Start Printed Page 22138handle and store reported information.[4] Information submitted under this statute also is protected from release to other government agencies, Freedom of Information Act (FOIA) requests, and certain records requests.
BSEE also proposes to revise paragraph (d) by removing the reference to an incorrect document incorporated by reference and replacing it with the correct document incorporated by reference. The original WCR requires that BOP stacks must be manufactured pursuant to a quality management system certified by an entity that meets the requirements of ISO 17011. The correct reference is ISO 17021. This was an error in the original WCR, and BSEE would make this correction in keeping with the WCR guidance posted on the BSEE website at https://www.bsee.gov/​guidance-and-regulations/​regulations/​well-control-rule
What information must I submit for BOP systems and system components? (§ 250.731)
This rulemaking would revise the information submitted to BSEE pursuant to paragraph (a)(5) by replacing “to achieve an effective seal of each ram BOP” with “to close each ram BOP.” This revision would affect information submitted to BSEE and, based upon BSEE experience with the implementation of the original WCR, would more accurately reflect the control system and regulator control setting requirements of API Standard 53. BSEE does not expect these revisions to decrease safety. BSEE has determined that these revisions would be adequate to meet the API Standard 53 requirements for control systems to ensure that each ram BOP can be effectively sealed, as the original WCR language intended.
This section would also be revised by removing the BAVO verification requirements in existing paragraphs (d) and (f). The BAVO verifications required by existing paragraphs (d)(1) and (d)(3) were redundant to the verifications required by paragraph (c); however, the verifications required by current paragraph (d)(2) are still necessary and BSEE therefore proposes to add them to revised paragraph (c). BSEE proposes to remove paragraph (f) because the Report that is the subject of that paragraph is proposed for elimination in connection with proposed revisions to § 250.732(d) (see section-by-section discussion of that provision for further explanation). The independent third party verifications under paragraph (c) help ensure that the BOP is fit for service at each specific well. BSEE proposes to revise this section by replacing references to a BAVO with references to an independent third party that meets the requirements of § 250.732(b). For a discussion of the proposed shift from BAVOs to independent third parties, see the section-by-section discussion of § 250.732.
What are the independent third party requirements for BOP systems and system components? (§ 250.732)
This proposed rule would remove the requirements to verify that testing was performed on the outermost edges of the shearing blades of the shear ram positioning mechanism, found in current paragraph (b)(1)(iv). This would align the verification requirements with BSEE's proposal to remove the centering mechanism required in existing § 250.734(a)(16) that is the subject of this verification (see section-by-section discussion of § 250.734 for discussion of those changes). BSEE does not expect this revision to decrease safety since it simply aligns this testing requirement with the proposed change to § 250.734(a)(16). As explained in connection with that proposed change, BSEE believes that, since newer shearing blades can center pipe, it is unnecessary to require a pipe centering mechanism. In addition, the shear rams are capable of shearing along the entire blade surface area without specifically requiring testing on the outermost edges. BSEE also proposes to remove from existing paragraph (b)(1)(i) a vestigial reference to a compliance deadline that has already passed. This is merely an administrative revision.
BSEE also proposes to make a minor revision to paragraph (c) to update an incorrect citation—the referenced definition of High Pressure High Temperature (HPHT) environments is found in § 250.804(b) rather than § 250.807(b), as stated in the current regulations. This revision is administrative in nature and ensures Start Printed Page 22139that the appropriate citations are correctly cross referenced.
With the removal of the BAVO references, BSEE is also proposing to remove the mechanical integrity assessment (MIA) report requirements from paragraph (d). This MIA report was a function of the BAVO. Based on discussions regarding the MIA report after publication of the original WCR, BSEE determined that the information contained within the MIA report was redundant with the BOP equipment capability verifications required by § 250.731. The independent third party verifications in § 250.731 help ensure that the BOP systems have the appropriate capabilities and are fit for service for a specific well and location.
What are the requirements for a surface BOP stack? (§ 250.733)
New paragraph (e) would be added to clarify the minimum surface BOP system requirements for well-completion, workover, and decommissioning operations where estimated well pressures are low. The provisions in this proposed paragraph were inadvertently removed from the regulations through the original WCR and are consolidated from §§ 250.516, 250.616, and 250.1706 of the regulations as they existed before the original WCR. BSEE is proposing minor revisions to the original language to conform to the applicable operations covered under revised Subpart G and to update cross-referenced citations. When BSEE developed the original WCR, it attempted to consolidate all of the BOP requirements from Subparts D, E, F, and Q, but in doing so inadvertently removed the requirements of this paragraph. The provisions in this paragraph would provide flexibility to utilize appropriate configurations and capabilities for surface BOP stacks where estimated well pressures are low (e.g., an end of life well).
What are the requirements for a subsea BOP system? (§ 250.734)
BSEE proposes to revise paragraph (a)(1)(ii) by clarifying that a “combination of the” shear rams must be capable of shearing all the items specified in the paragraph. This revision would better align the functionality of the BOP system with API Standard 53 and proposed § 250.730(a). Based upon BSEE experience with the implementation of the original WCR, BSEE is aware that certain casing shears still have difficulty shearing electric-, wire-, or slick-line, while certain blind shear rams have difficulties shearing larger casing sizes. This proposed revision would provide the operators flexibility for how they utilize the BOP system and components for operations while still ensuring all critical shearing capabilities. This would not impact safety because BSEE would still require the capability to shear at any point along the tubular body of any drill pipe (excluding tool joints, bottom-hole tools, and bottom hole assemblies such as heavy-weight pipe or collars), workstring, tubing and associated exterior control lines, appropriate area for the liner or casing landing string, shear sub on subsea test tree, and any electric-, wire-, slick-line in the hole. BSEE expects the operators to better evaluate how the BOP system, including both shear rams, would function together to comply with the required shearing capabilities. The proposed rule would also revise paragraph (a)(1)(ii) by removing references to extended times for compliance with certain shearing requirements under the original WCR, which BSEE anticipates will have run and no longer warrant reference in the regulations by the time a final rule is promulgated.
This rulemaking would revise the accumulator requirements in paragraph (a)(3) to better align with API Standard 53. BSEE would remove the reference to the subsea location of the accumulator capacity. BSEE understands that the accumulator system works together with the surface and subsea accumulator capacity to achieve full functionality, and BSEE determined that it was unnecessary to specifically identify only subsea requirements when the entire system is covered within API Standard 53. BSEE does not expect these revisions to reduce safety. The requirements to operate the key components of the BOP subsea will remain the same. This revision helps reduce the non-critical accumulator capacity on the BOP stack subsea, but would not affect safety of the critical components. Adding subsea accumulator bottles increases weight and size, which could have a negative impact on the stability and functionality of existing facilities by exceeding the operational or mechanical design limits of the wellhead and BOP systems.
Paragraph (a)(3)(ii) would be revised to clarify that the accumulator capacity must have the capability to perform the ROV functions within the required times outlined in API Standard 53 with ROVs or flying leads. Based upon BSEE experience with the implementation of the original WCR, BSEE is proposing to Start Printed Page 22140revise this paragraph not only to better align with API Standard 53, but also to account for the technological advancements in ROV capabilities and ROV standardization to meet the appropriate BOP closing times via an ROV. Many of these advancements have taken place after publication of the original WCR. BSEE is aware of operators currently using high flow rate ROVs to meet the BOP component closing times of API Standard 53.
Paragraph (a)(3)(iii) would be revised by removing the mention of “dedicated” bottles and allowing bottles to be shared among emergency and secondary control system functions to secure the wellbore. This revision would further align the accumulator capacity requirements with API Standard 53 and account for the appropriate number of accumulator bottles on the subsea BOP stack. This revision would increase operator flexibility to utilize the appropriate accumulator capacity to perform the necessary emergency functions. Through the implementation of the original WCR, BSEE was able to better evaluate the effects of the original WCR accumulator requirements impacting subsea BOP space and weight limitations. This revision would help ensure that the regulatory requirements do not exceed the operational or mechanical design limits of the wellhead and BOP systems, and would help minimize risks associated with approaching those design limits.
This rulemaking would revise paragraph (a)(4) by removing the term “opening” and adding reference to the ROV function response times outlined in API Standard 53. After publication of the original WCR, the API Standard 53 committee clarified the definition of “operate” critical functions to include “close” only and not to include “open.” Removal of the ROV open function would limit the ability for well intervention after the well has already been secured; however, it would not affect or decrease the ability for the ROV to close the required components for well control purposes. During a well control event, the most critical functions would be to close the BOP components and seal the well. This revision would minimize the required number of equipment alterations to the subsea ROV panel and associated control systems and improve consistency with similar requirements in API Standard 53. The open function on the ROV panel may also be unnecessary due to technological advancements in well intervention capabilities once the well has already been secured. This paragraph would also be revised by requiring the ROV to function the appropriate BOP component within the required response time outlined in API Standard 53. BSEE is proposing to revise this paragraph not only to better align with API Standard 53, but also to account for the recent technological advancements in ROV capabilities and ROV standardization to meet the appropriate BOP closing times via an ROV. BSEE is aware that operators currently use high flow rate ROVs to meet the BOP component closing times of API Standard 53.
BSEE would also update the incorporated reference to API RP 17H to a newer edition in § 250.198(h)(94). There is a conflict between the API RP 17H first edition referenced in the original WCR and the API Standard 53 ROV requirements. The second edition of API RP 17H eliminates the conflict between the first edition and API Standard 53. BSEE would incorporate by reference the second edition of API RP 17H to ensure the appropriate methods are utilized to comply with the API Standard 53 ROV closure timeframes of 45 seconds. One of the main differences between the first edition and second edition of this recommended practice is that the second edition includes provisions on high flow Type D 17H hot stabs.
This rulemaking would also revise paragraph (a)(6)(iv) by clarifying that the autoshear/deadman functions must close at a minimum two shear rams in sequence, not every emergency function. Closing two shear rams in sequence may not be advantageous for certain emergency disconnect system (EDS) functions. Depending upon the rig operations, operators develop different EDS modes that would function different BOP components at appropriate times. The selection of the EDS mode and the specific sequencing of emergency functions should be developed by the operator based on safety considerations and an operational risk assessment. BSEE would make this change to codify BSEE guidance on the original WCR posted on the BSEE website at https://www.bsee.gov/​guidance-and-regulations/​regulations/​well-control-rule.
BSEE would revise paragraph (a)(16) by removing references to the centering mechanism and the ability to mitigate compression of the pipe between the shear rams in paragraphs (i) and (ii), respectively. Based upon BSEE experience with the implementation of the original WCR and increased interactions with OEMs of shearing components, BSEE would remove these paragraphs based upon a better understanding of the technological advancements of available shearing capabilities to accomplish the same goals outlined in these paragraphs. Many of the shear ram designs have improved the shearing capabilities to help ensure the shearing is conducted on the appropriate shearing area of the shear blades. This is commonly done by shaping the shear ram cutting blades in a “V” or “W” pattern to help center the pipe as it shears, as well as to increase the blade face surface area to ensure there are no areas that cannot shear the pipe in the well. BSEE is also proposing to remove paragraphs (a)(6)(v) and (a)(6)(vi) based upon a better understanding of the third party verifications and documentation of the shearing requirements as outlined in current § 250.732(b). BSEE does not expect these revisions to decrease safety because these newer designed shear rams are off the shelf available components that can be swapped with current components. BSEE believes that operators will continue to substitute new components for old ones to comply with the still-required increased shearing capability provisions of the original WCR. BSEE is aware of many technological advancements in shearing ram designs and capabilities. BSEE expects the shear rams to shear pipe or wire in any position within the wellbore; however, BSEE is specifically soliciting comments about the effectiveness of requiring shear rams to center pipe or wire while shearing, or requiring shear rams to have the capability to shear any pipe or wire in the hole without a separate centering mechanism. Another option BSEE is considering is retaining the centering mechanism requirements, but expressly providing that the shear rams with these capabilities satisfy the requirements. Please provide reasons for your position and any applicable associated data.
This rulemaking would revise paragraph (b)(1) by replacing the BAVO references with references to an independent third party. For a discussion of the general shift from BAVOs to independent third parties, see the section-by-section discussion of § 250.732.
BSEE would also revise paragraph (b)(2), redesignate existing paragraph (b)(3) as (b)(4), and add new paragraph (b)(3) to include provisions for testing the applicable BOP or LMRP upon relatch to the well. The original WCR did not address this provision, however based upon BSEE experience, these revisions would codify longstanding BSEE policy and provide clarity for testing when an operator has returned to the location and relatched the BOP or LMRP to the well. These tests help confirm that the BOP or LMRP is Start Printed Page 22141properly functional prior to resuming operations after being removed.
What associated systems and related equipment must all BOP systems include? (§ 250.735)
This proposed rule would revise paragraph (a) by clarifying that the accumulator system must have the fluid volume capacity and appropriate pre-charge pressures in accordance with API Standard 53. BSEE would revise this section to provide consistency with the API Standard 53 and conform to the other proposed accumulator system revisions in § 250.734. This revision would not materially alter the requirements of this section, which are already based upon API Standard 53. An accumulator system is necessary to provide the fluid and pressure to operate desired BOP functions. API Standard 53 outlines the pre-charge pressure calculations in Annex C and additional requirements for the accumulator system pressures in the drawdown tests.
What are the requirements for choke manifolds, kelly-type valves inside BOPs, and drill string safety valves? (§ 250.736)
What are the BOP system testing requirements? (§ 250.737)
In this proposed rule, BSEE would also revise paragraphs (d)(2) and (d)(3) by removing the requirement to submit test results to BSEE where BSEE is unable to witness testing. Based upon BSEE experience with the implementation of the original WCR, these revisions would significantly reduce the number of submittals to BSEE and minimize the associated burden for BSEE to review those submittals. If BSEE is unable to witness the testing, BSEE still has access to the testing documentation upon request in accordance with §§ 250.740, 250.741, and 250.746.
Paragraph (d)(3)(iv) would be revised by removing “test and[.]” BSEE would remove this term to minimize confusion regarding verification and testing. In this instance, verification of closure qualifies as testing the ROV functions. The purpose of the stump test is to help ensure the BOP components and control systems can function properly before being utilized on a well.
Paragraph (d)(4)(i) would be revised to clarify that the initial subsea BOP test on the sea floor would need to “begin” within 30 days of the stump test. BSEE receives many questions about the timing of the initial subsea test and, as written, the regulation was ambiguous regarding exactly what needed to occur within the 30 days. Based upon its experience with the implementation of the original WCR, BSEE proposes this revision to clarify that the testing has to begin within 30 days. BSEE wants to ensure that the time between the stump testing and the initial subsea test is minimal to help ensure that all of the BOP components can properly function upon installation on the well.
BSEE would revise paragraph (d)(5) by clarifying the alternating testing schedules of control stations and pods. These revisions would ensure that operators develop a testing schedule that allows for alternating testing between the control stations, and also between the pods for subsea BOPs. The intended result of alternating the testing is to ensure that each control station, and each pod for subsea, can properly function all required BOP components. Based on BSEE experience during the implementation of the original WCR, Start Printed Page 22142BSEE has concluded that these revisions would help ensure BOP functionality while not inadvertently requiring unnecessarily duplicative testing. This revision would save rig operational time by reducing the number of unnecessary duplicate tests, and minimize the risk associated with wear of the BOP components functioned during testing.
What must I do in certain situations involving BOP equipment or systems? (§ 250.738)
This rulemaking would revise paragraphs (b), (i), (m), and (o) by replacing the references to BAVOs with references to an independent third party throughout. For a discussion of the proposed shift from BAVOs to independent third parties, see the section-by-section discussion of § 250.732.
Paragraph (m) would be revised to replace the term “well-control equipment” with “circulating or ancillary equipment.” This revision would eliminate confusion arising from the use of conflicting terms that may have different meanings throughout the regulations.
What are the BOP maintenance and inspection requirements? (§ 250.739)
BSEE proposes to revise paragraph (b) by replacing “complete breakdown and detailed physical inspection” with a “major, detailed inspection,” identifying examples of well control system components, replacing references to the BAVO with references to an independent third party, and replacing the requirement to have a BAVO present during each inspection with a requirement for an independent third party to review inspection results.
Replacing “complete breakdown and detailed physical inspection” with a “major, detailed inspection” would correct the industry misconception, prevalent since the promulgation of the original WCR, that each component must be dismantled to its smallest possible part. This was never the intent behind this provision of the WCR, and these revisions would clarify BSEE's positions on the WCR requirement and resolve perceived ambiguities, without substantively altering the inspection requirement. BSEE would make this change to codify BSEE guidance on the original WCR posted on the BSEE website at https://www.bsee.gov/​guidance-and-regulations/​regulations/​well-control-rule. BSEE also proposes to add references to examples of the well control system components requiring inspection to clarify the general reference in the original WCR.
For a discussion of the proposed shift from BAVOs to independent third parties, see the section-by-section discussion of § 250.732.
BSEE would also remove the requirement for the BAVO to be present during each inspection and replace it with a requirement that an independent third party review the inspections results. BSEE expects the independent third party to review the documentation of the inspections to help ensure that the appropriate entities accurately and appropriately complete the activities. These reports would also help facilitate other required verifications that the BOP is fit for service, such as those required by § 250.731. These revisions would ease the original WCR logistical and economic burdens of having the BAVO onsite at all times during all inspections.
What are the coiled tubing and snubbing requirements? (§ 250.750)
The content of this proposed section was moved from current §§ 250.616 and 250.1706. This section would consolidate some of the minimum BOP system component requirements for coiled tubing and snubbing operations. BSEE is proposing minor revisions to the original language to conform to the applicable operations covered under Subpart G. BSEE is also proposing to add paragraph (d) to conform snubbing unit testing with updated requirements.
Coiled Tubing Testing Requirements (§ 250.751)
BSEE proposes to add this section to codify current BSEE policy regarding the coiled tubing testing and recording requirements. This addition would a reintroduce similar provisions that were inadvertently removed in the original WCR, consolidating elements from §§ 250.617 and 250.1707 of the regulations as they existed before the original WCR. Both sections are currently reserved. BSEE is proposing revisions to the original language to conform to the applicable requirements of Subpart G. For example, BSEE would not include in this section the provisions regarding testing of the coiled tubing connector, because the proposal would require that operators “must test the coiled tubing unit in accordance with § 250.737 paragraphs (a), (b), (c), (d)(9), and (d)(10)”. Section 250.737 requires testing of the system when installed and provides testing criteria. Identifying the connector testing in this section is not necessary because it is already covered by the testing requirements of § 250.737.
What are the general requirements for decommissioning? (§ 250.1703)
This rulemaking would revise paragraph (b) to clarify that only packers or bridge plugs used as mechanical barriers are required to comply with ANSI/API Spec. 11D1. Based upon BSEE experience with the Start Printed Page 22143implementation of the original WCR, this revision would codify BSEE's policy to ensure that the required mechanical barriers in a well are held to a higher standard than other common packers or bridge plugs used for various well specific conditions and completions design. Furthermore, BSEE is aware that certain packers and bridge plugs cannot meet the specifications of ANSI/API Spec. 11D1. This revision would minimize the number of alternate equipment requests submitted to BSEE. BSEE would also add that operators must have two independent barriers, one being mechanical, in the exposed center wellbore (e.g., this could be the tubing or casing depending on the well configuration) prior to removing the tree or well control equipment. This addition would codify BSEE policy and align the well decommissioning requirements with similar requirements from §§ 250.720(a) and 250.1712(g). This addition would help ensure the well is properly secured before removal of the tree or well control equipment.
What decommissioning applications and reports must I submit and when must I submit them? (§ 250.1704)
Coiled Tubing and Snubbing Operations (§ 250.1706)
This section would be removed and reserved. The content of this section would be moved to proposed § 250.750. These revisions would help BSEE eliminate inconsistencies between similar requirements throughout different BSEE subparts by consolidating those requirements into Subpart G, which is applicable to drilling, completions, workovers, and decommissioning operations.
Must I notify BSEE before I begin well plugging operations? (§ 250.1713)
This section would be removed and reserved. Based upon BSEE experience with the implementation of the original WCR, BSEE determined that the submittal of the information required by this section is redundant with similar rig movement notification information required under § 250.712.
To what depth must I remove wellheads and casings? (§ 250.1716)
If I install a subsea protective device, what requirements must I meet? (§ 250.1722)
Executive Order 13563 reaffirms the principles of E.O. 12866 while calling for improvements in the Nation's regulatory system to promote predictability, to reduce uncertainty, and to use the best, most innovative, and least burdensome tools for achieving regulatory ends. The E.O. directs agencies to consider regulatory approaches that reduce burdens and maintain flexibility and freedom of choice for the public where these Start Printed Page 22144approaches are relevant, feasible, and consistent with regulatory objectives. Executive Order 13563 emphasizes further that regulations must be based on the best available science and that the rulemaking process must allow for public participation and an open exchange of ideas. We have developed this rule in a manner consistent with these requirements.
Executive Order 13771 requires Federal agencies to take proactive measures to reduce the costs associated with complying with Federal regulations. This proposed rule is expected to be an E.O. 13771 deregulatory action. Details on the estimated cost savings of this proposed rule can be found in the rule's economic analysis. The cost savings for the regulatory clarifications, reduction in paperwork burdens, adoption of industry standards, and migration to performance-based standards for select provisions constitute an E.O. 13771 deregulatory action. BSEE also finds that the reduced regulated entity compliance burden would not increase the safety or environmental risks for offshore drilling operations.
This rulemaking proposes to revise regulatory provisions in 30 CFR part 250, subparts D, E, F, G, and Q. BSEE has reassessed a number of the provisions in the original (1014-AA11) WCR rulemaking and proposes to rewrite some provisions as performance-based standards rather than prescriptive requirements. Other proposed revisions would reduce or eliminate parts of the paperwork burden, while providing the same levels of safety and environmental protection. BSEE sought the best available data and information to analyze the economic impact of the proposed changes. The Initial RIA (IRIA) for this rulemaking can be found in the https://www.regulations.gov/​ docket (Docket ID: BSEE-2018-0002). The IRIA indicates that the estimated overall cost savings to the industry over the next 10 years would exceed $900 million in nominal dollars.
(1.) Underestimating the cost for revising permits or reporting certain operations to the District Manager (§§ 250.428 and 250.722), and
(2.) Underestimating both the number of subsea BOPs that would require modifications and the cost of those modifications under the 1014-AA11 regulations (§ 250.734).
The proposed revisions to existing ram and accumulator requirements for subsea BOPs (§ 250.734) represent the single largest cost savings provision in this proposed rule, yielding cost savings of $690 million (nominal$). The proposed changes to § 250.734 would better align the shear ram provisions with API Standard 53, revise the accumulator capacity requirements for subsea BOP stacks, and redefine shearing requirements.
The proposed § 250.734 amendments would better define the BOP components functionality requirements, revise the requirements for ROV capability and functionality, and amend accumulator capacity requirements for subsea BOP stacks. This revision to the accumulator requirements would increase operator flexibility to utilize the appropriate accumulator capacity to perform the necessary emergency functions. Through the implementation of the original WCR, BSEE was able to better evaluate the effects of the original WCR accumulator requirements on subsea BOP space and weight limitations. After reevaluating the API 53 standards, BSEE agrees that certain prescriptive requirements in the current regulations are unnecessary and the proposed regulatory text revisions would align BSEE regulations with the performance standards in API Standard 53. The proposed § 250.734 revisions would also remove the prescriptive requirement that EDS emergency functions must close at a minimum two shear rams in sequence. This would allow the operator to select the appropriate EDS emergency function shearing sequence for the circumstances and would adopt the performance standard that the BOP system must be able to seal the wellbore. Furthermore, the accumulator capacity required in API 53 is sufficient to actuate the BOP ram functions necessary to seal the well. This performance standard meets the intent of the 1014-AA11 well control rule without the prescriptive and unnecessarily burdensome requirements. The alignment of the accumulator volume requirements with industry standards would also provide additional safety benefits. The weight of the combined BOP and accumulator bottle package required by the original rule would be reduced with these proposed revisions. This reduction would avoid increased strain on rig handling systems and potentially avoid modifications on some rigs to accommodate the additional space and BOP handling requirements.
The proposed § 250.737 paragraph (d)(5) amendments would allow the operator to alternate tests between the two control stations rather than testing from both control stations on each test. Testing from both control stations on a weekly basis has been proven to wear the BOP components out at a faster rate than was expected when the original WCR was written. The proposed rule would return the regulations to pre-1014-AA11 regulatory language in order to prevent the additional wear and tear on the BOP components. This change would align BSEE regulations with the industry testing standards.
As defined by the Small Business Administration (SBA), a small entity is one that is “independently owned and operated and which is not dominant in its field of operation.” What characterizes a small business varies from industry to industry in order to properly reflect industry size differences. This proposed rule would affect lease operators that are conducting OCS drilling or well operations. BSEE's analysis shows this could include about 69 companies with active drilling or well operations. Of the 69 companies, 21 (30 percent) are large and 48 (70 percent) are small. Entities that would operate under this proposed rule are classified primarily under North American Industry Classification System (NAICS) codes 211120 (Crude Petroleum Extraction), 211130 (Natural Gas Extraction), and 213111 (Drilling Oil and Gas Wells). The proposed rule would indirectly impact OCS drilling companies that are the regulated entities classified under NAICS code 21311 and this analysis focuses on the OCS oil and gas lessees and operators. For NAICS codes 211120, SBA defines a small company as having fewer than 1,251 employees.
BSEE considers that a rule will have an impact on a “substantial number of small entities” when the total number of small entities impacted by the rule is equal to or exceeds 10 percent of the relevant universe of small entities in a given industry. BSEE's analysis shows that there are 48 small companies with active operations on the OCS, and all of these companies could be impacted by the proposed rule if conducting drilling or well operations. Therefore, BSEE expects that the proposed rule would affect a substantial number of small entities.
This proposed rule is a deregulatory action; however, BSEE has evaluated possible costs and benefits and has estimated that there is an overall associated cost savings. BSEE has estimated the annualized cost savings by regulatory provision and then allocated those savings to small or large entities based on drilling/well activity (circa October, 2017; activity breakouts can be found in the IRFA). The proposed changes to §§ 250.423, 250.734, and 250.737 paragraph (d)(5) would only apply to subsea BOPs and would yield cost savings that sum to $70,250,336. All remaining proposed changes would apply to all well operations or subsea/surface BOPs, and would yield cost savings that sum to $24,367,256. Using the share of small and large companies subject to each suite of provisions, we estimate that small companies would realize 15 percent of the cost savings from this rulemaking and large companies 85 percent. The allocation is displayed in the following table.
a. Would have a positive economic effect on the economy of $100 million or more. The cost savings will not materially affect the economy nationally or in any local area.
b. Would not cause a major increase in costs or prices for consumers; individual industries; Federal, State, Tribal, or local governments; or regions of the nation. This proposed rule would have positive effects on OCS operators and is not anticipated to negatively impact oil, gas, and sulfur production or the cost of fuels for consumers.
BSEE complies with the National Technology Transfer and Advancement Act (NTTAA) (15 U.S.C. 3701 et seq.) requirement that an agency “use standards developed or adopted by voluntary consensus standards bodies rather than government-unique standards, except where inconsistent with applicable law or otherwise impractical.” (OMB Circular A-119 at p. 13). BSEE also complies with the OFR regulations governing incorporation by reference. (See, 1 CFR part 51.) Those regulations also specify the process for updating an incorporated standard at § 51.11(a), and BSEE complies with those requirements, including seeking approval by OFR for a change to a standard incorporated by reference in a final rule.
This proposed rule contains collections of information that will be submitted to OMB for review and approval under the PRA, 44 U.S.C. 3501 et seq. As part of its continuing effort to reduce paperwork and burdens on respondents, BSEE invites the public and other Federal agencies to comment on any aspect of the reporting and recordkeeping burden. If you wish to comment on the information collection (IC) aspects of this proposed rule, you may send your comments directly to OMB and send a copy of your comments to the Regulations and Standards Branch (see the ADDRESSES section of this proposed rule). Please reference 30 CFR part 250, subpart G, Blowout Preventer Systems and Well Control, 1014-0028, in your comments. To see a Start Printed Page 22147copy of the information collection request submitted to OMB, go to http://www.reginfo.gov (select Information Collection Review, Currently Under Review); or you may obtain a copy of the supporting statement for the new collection of information by contacting the Bureau's Information Collection Clearance Officer at (703) 787-1607.
This proposed rule affects Applications for Permits to Drill (1014-0025, expiration 4/30/20); Applications for Permits to Modify (1014-0026, expiration 7/31/20); Subpart B (1014-0024, expiration 11/30/18); Subpart D (1014-0018, expiration 3/31/2021); Subpart E, (1014-0004, expiration 1/31/20); Subpart G (1014-0028, expiration 07/31/19); and Subpart Q, (1014-0010, expiration 1/31/20).
APD—Proposed § 250.428 removes the requirement to resubmit an application for permit to drill (APD) in the event of planned mud losses, or remedial actions for inadequate cement jobs, if these circumstances are addressed in the original approved APD. Reductions will be shown during the renewal process (see Section by Section Discussion above).
Subpart A—§ 250.423 proposes rewording the requirement in a manner that would reduce the number of alternative procedure or equipment requests under § 250.141. Reductions will be shown during the renewal process (see Section by Section Discussion above).
Subpart B—§ 250.292(p) proposes to require less information to be submitted in the DWOP. Reductions will be shown during the renewal process (see Section by Section Discussion above).
Subpart D—§ 250.462(e)(1) would add Independent Third Party costs increasing the non-hour cost burdens by $16,000 (see Section by Section Discussion above).
§ 250.720(a)(3) would be new and would require operators to request and receive District Manager approval before resuming operations after unlatching the BOP or LMRP, and would add 13 burden hours (see Section by Section Discussion above).
§ 250.731 would add Independent Third Party costs, increasing the non-hour cost burdens by $31,000 (see Section by Section Discussion above).
§ 250.732(a) would add Independent Third Party costs, increasing the non-hour cost burdens by $765,000 (see Section by Section Discussion above).
§ 250.732(d) would eliminate the requirement to request and submit for approval all relevant information to become a BAVO. This would decrease the hour burden by 700 hours (see Section by Section Discussion above).
§ 250.737(d)(5) would be new and proposes to allow for alternating tests between two control stations; adding 25 burden hours (see Section by Section Discussion above).
§ 250.751 would be new and proposes to include the coiled tubing testing and recording requirements that were inadvertently removed in the original Well Control Rule; adding 3,630 burden hours (see Section by Section Discussion above).
BSEE has prepared a draft environmental assessment (EA) to determine whether this proposed rule would have a significant impact on the quality of the human environment under the National Environmental Policy Act of 1969 (NEPA) (42 U.S.C. 4321 et seq.). If the final EA supports the issuance of a Finding of No Significant Impact for the rule, the preparation of an environmental impact statement pursuant to the NEPA would not be required. A copy of the draft EA can be viewed at www.regulations.gov (use the keyword/ID “BSEE-2018-0002”).
This proposed rule is not a significant energy action under the definition in E.O. 13211. Although the rule is a significant regulatory action under E.O. 12866, it is not likely to have a significant adverse effect on the supply, distribution, or use of energy. A Statement of Energy Effects is not required.Start Printed Page 22148
Before including your address, phone number, email 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. In order for BSEE to withhold from disclosure your personal identifying information, you must identify any information contained in the submittal of your comments that, if released, would constitute a clearly unwarranted invasion of your personal privacy. You must also briefly describe any possible harmful consequence(s) of the disclosure of information, such as embarrassment, injury, or other harm. 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.
Outer Continental Shelf—mineral resources
Outer Continental Shelf—rights-of-way
2. Amend § 250.198 by revising paragraphs (h)(63), (h)(78), and (h)(94), and adding new paragraph (m)(2), to read as follows:
(63) API Standard 53, Blowout Prevention Equipment Systems for Drilling Wells, Fourth Edition, November 2012, incorporated by reference at §§ 250.730, 250.734, 250.735, 250.737, and 250.739;
(78) API Standard 65—Part 2, Isolating Potential Flow Zones During Well Construction; Second Edition, December 2010; incorporated by reference at §§ 250.415(f) and 250.420(a)(6);
(94) API Recommended Practice 17H, Remotely Operated Tool and Interfaces on Subsea Production Systems, Second Edition, June 2013, Errata January 2014, incorporated by reference at § 250.734(a)(4);
(2) ISO/IEC 17021-1—Conformity assessment—Requirements for bodies providing audit and certification of management systems—Part 1, First Edition, June 2015, incorporated by reference at § 250.730(d).
3. Amend § 250.292 by revising paragraph (p) to read as follows:
4. Amend § 250.413 by revising paragraph (g) to read as follows:
What must my description of well drilling design criteria address?
5. Amend § 250.414 by revising paragraph (c)(3) to read as follows:
What must my drilling prognosis include?
6. Amend § 250.420 by revising paragraph (a)(6) to read as follows:
(6) Provide adequate centralization consistent with the guidelines of API Standard 65—Part 2 (as incorporated by reference in § 250.198); and
7. Amend § 250.421 by revising paragraphs (c), (d), (e), and (f) to read as follows:
8. Amend § 250.423 by revising paragraphs (a) and (b) to read as follows:
What are the requirements for casing and liner installation?
(a) You must ensure that the latching mechanisms or lock down mechanisms are engaged upon successfully installing the casing string. If there is an indication of an inadequate cement job, you must comply with § 250.428(c).
(b) If you run a liner that has a latching mechanism or lock down mechanism, you must ensure that the latching mechanisms or lock down mechanisms are engaged upon successfully installing the liner. If there is an indication of an inadequate cement job, you must comply with § 250.428(c).
9. Amend § 250.428 by revising paragraphs (c) and (d) to read as follows:
What must I do in certain cementing and casing situations?
10. Amend § 250.433 by revising paragraph (b) to read as follows:
What are the diverter actuation and testing requirements?
11. Amend § 250.461 by revising paragraph (b) to read as follows:
12. Amend § 250.462 by revising paragraphs (b) introductory text, (e)(1)(ii), (e)(3), and (e)(4) to read as follows:
What are the source control, containment, and collocated equipment requirements?
13. Amend § 250.518 by revising paragraph (e)(1) to read as follows:
(1) All permanently installed packers and bridge plugs qualified as mechanical barriers must comply with ANSI/API Spec. 11D1 (as incorporated by reference in § 250.198);
14. Revise § 250.519 to read as follows:
Once you install your wellhead, you must meet the casing pressure management requirements of API RP 90 (as incorporated by reference in § 250.198) and the requirements of §§ 250.519 through 250.531. 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.
15. Revise § 250.522 to read as follows:
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 §§ 250.521 and 250.523.
16. Amend § 250.525 by revising paragraph (d) to read as follows:
(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 § 250.522;
17. Revise § 250.526 to read as follows:
Within 14 days after you perform a casing diagnostic test requiring action under § 250.525:
18. Amend § 250.530 by revising paragraph (b) to read as follows:
(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 § 250.523(e).
19. Amend § 250.601 by adding paragraph (m) to the definition of “routine operations” to read as follows:
20. Remove and reserve § 250.616.
21. Amend § 250.619 by revising paragraph (e)(1) to read as follows:
§ 250.619
(1) All permanently installed packers and bridge plugs qualified as mechanical barriers must comply with ANSI/API Spec. 11D1 (as incorporated by reference in § 250.198). You must have two independent barriers, one being mechanical, in the exposed center wellbore prior to removing the tree and/or well control equipment;
22. Amend § 250.712 by adding paragraphs (g) and (h) to read as follows:
§ 250.712
What rig unit movements must I report?
23. Amend § 250.720 by revising paragraph (a)(1) and adding paragraphs (a)(3) and (d) to read as follows:
§ 250.720
(i) Upon relatch of the BOP, you must test according to § 250.734(b)(2), or
(ii) Upon relatch of the LMRP, you must test according to § 250.734(b)(3); and
24. Amend § 250.722 by revising paragraph (a)(2) to read as follows:
§ 250.722
What are the requirements for prolonged operations in a well?
25. Amend § 250.723 by revising the introductory text and paragraph (c)(3) to read as follows:
§ 250.723
What additional safety measures must I take when I conduct operations on a platform that has producing wells or has other hydrocarbon flow?
26. Revise § 250.724 to read as follows:
§ 250.724
What are the real-time monitoring requirements?
(2) A description of how your real-time monitoring data will be transmitted during operations, how the data will be labeled and monitored by qualified personnel, and how the data will be stored as required in §§ 250.740 and 250.741;
27. Revise § 250.730 to read as follows:
§ 250.730
(1) The BOP requirements of API Standard 53 (incorporated by reference in § 250.198) and the requirements of §§ 250.733 through 250.739. If there is a conflict between API Standard 53 and the requirements of this subpart, you must follow the requirements of this subpart.
(2) The provisions of the following industry standards (all incorporated by reference in § 250.198) that apply to BOP systems:
(c) You must follow the failure reporting procedures contained in API Standard 53, (incorporated by reference in § 250.198), and:
(d) If you plan to use a BOP stack manufactured after the effective date of this regulation, you must use one manufactured pursuant to an ANSI/API Spec. Q1 (as incorporated by reference in § 250.198) quality management system. Such quality management system must be certified by an entity that meets the requirements of ISO/IEC 17021-1 (as incorporated by reference in § 250.198).
28. Amend § 250.731 by:
a. Removing paragraphs (d) and (f);
b. Redesignating existing paragraph (e) as (d); and
c. Revising paragraphs (a)(5) and (c) to read as follows:
§ 250.731
What information must I submit for BOP systems and system components?
29. Revise § 250.732 and the section heading to read as follows:
§ 250.732
What are the independent third party requirements for BOP systems and system components?
(b) The independent third-party must be a technical classification society, or a licensed professional engineering firm, or a registered professional engineer capable of providing the required certifications and verifications.Start Printed Page 22155
(c) For wells in an HPHT environment, as defined by § 250.804(b), you must submit verification by an independent third party that the independent third party conducted a comprehensive review of the BOP system and related equipment you propose to use. You must provide the independent third party access to any facility associated with the BOP system or related equipment during the review process. You must submit the verifications required by this paragraph (c) to the appropriate District Manager and Regional Supervisor before you begin any operations in an HPHT environment with the proposed equipment.
30. Amend § 250.733 by:
a. Revising paragraphs (a)(1) and (b)(1); and
§ 250.733
(1) For BOPs installed after April 29, 2021, follow the BOP requirements in § 250.734(a)(1).
(e) Additional requirements for surface BOP systems used in well-completion, workover, and decommissioning operations.
31. Amend § 250.734 by:
a. Removing paragraphs (a)(6)(v) and (vi); and
b. Revising paragraphs (a)(1)(ii), (a)(3), (a)(4), (a)(6)(iv), (a)(16), and (b) to read as follows:
§ 250.734
What are the requirements for a subsea BOP system?
(2) Upon relatch of the BOP, perform an initial subsea BOP test in accordance with § 250.737(d)(4), including deadman in accordance with § 250.737(d)(12)(vi). If repairs take longer than 30 days, once the BOP is on deck, you must test in accordance with the requirements of § 250.737;
(i) Pressure test riser connector/gasket in accordance with § 250.737(b) and (c);
(ii) Pressure test choke and kill stabs at LMRP/BOP interface in accordance with § 250.737(b) and (c);
(v) Deadman test with pressure test in accordance with § 250.737(d)(12)(vi).
32. Amend § 250.735 by revising paragraph (a) to read as follows:
§ 250.735
What associated systems and related equipment must all BOP systems include?
(a) An accumulator system (as specified in API Standard 53, and incorporated by reference in § 250.198). Your accumulator system must have the fluid volume capacity and appropriate pre-charge pressures in accordance with API Standard 53. If you supply the accumulator regulators by rig air and do not have a secondary source of pneumatic supply, you must equip the regulators with manual overrides or other devices to ensure capability of hydraulic operations if rig air is lost;
33. Amend § 250.736 by revising paragraph (d)(5) to read as follows:
§ 250.736
What are the requirements for choke manifolds, kelly-type valves inside BOPs, and drill string safety valves?
34. Amend § 250.737 by:
a. Removing paragraph (d)(4)(vi),
b. Adding paragraph (d)(13), and
c. Revising paragraphs (b) introductory text, (b)(2), (d)(2)(ii), (d)(3)(iii), (d)(3)(iv), (d)(3)(v), (d)(4)(i), (d)(4)(iii), (d)(4)(v), (d)(5), (d)(12)(iv) and (d)(12)(vi) to read as follows:
§ 250.737
What are the BOP system testing requirements?
35. Amend § 250.738 by revising paragraphs (b)(4), (f), (i), (m), and (o) to read as follows:
§ 250.738
What must I do in certain situations involving BOP equipment or systems?
36. Amend § 250.739 by revising paragraph (b) introductory text to read as follows:
§ 250.739
What are the BOP maintenance and inspection requirements?
37. Add § 250.750 and undesignated center heading to read as follows:
§ 250.750
What are the coiled tubing and snubbing requirements?
(d) Test the snubbing unit in accordance with § 250.737(a), (b), and (c).
38. Add § 250.751 to read as follows:
§ 250.751
Coiled tubing testing requirements.
Coiled tubing tests. You must test the coiled tubing unit in accordance with § 250.737(a), (b), (c), (d)(9), and (d)(10). You must successfully pressure test the dual check valves to the rated working pressure of the connector, the rated working pressure of the dual check valve, expected surface pressure, or the collapse pressure of the coiled tubing, whichever is less. The test interval for coiled tubing operations must include a 10 minute high-pressure test for the coiled tubing string.
39. Amend § 250.1703 by revising paragraph (b) to read as follows:
(b) Permanently plug all wells. Packers and bridge plugs used as qualified mechanical barriers must comply with ANSI/API Spec. 11D1 (as incorporated by reference in § 250.198). You must have two independent barriers, one being mechanical, in the exposed center wellbore prior to removing the tree and/or well control equipment;
40. Amend § 250.1704 by adding paragraph (g)(4) and revising paragraph (h)(2) to read as follows:
What decommissioning applications and reports must I submit and when must I submit them?
41. Remove and reserve § 250.1706:
§ 250.1706
42. Remove and reserve § 250.1713:
43. Amend § 250.1716 by revising paragraph (b)(3) to read as follows:
44. Amend § 250.1722 by revising paragraph (d) introductory text to read as follows:
1. To view these standards online, go to the API publications website at: http://publications.api.org. You must then log-in or create a new account, accept API's “Terms and Conditions,” click on the “Browse Documents” button, and then select the applicable category (e.g., “Exploration and Production”) for the standard(s) you wish to review.
2. BSEE's regulations at 30 CFR part 250 generally apply to “a lessee, the owner or holder of operating rights, a designated operator or agent of the lessee(s) . . . ,” covered by the definition of “you” in § 250.105. For convenience, this preamble will refer to all of the regulated entities as “operators” unless otherwise indicated.
3. To view these standards online, go to the API publications website at: http://publications.api.org. You must then log-in or create a new account, accept API's “Terms and Conditions,” click on the “Browse Documents” button, and then select the applicable category (e.g., “Exploration and Production”) for the standard(s) you wish to review.
4. OMB defines BTS as one of 14 CIPSEA statistical agencies; BSEE is not a CIPSEA statistical agency. (“Implementation Guidance for [CIPSEA]”); 72 FR 33362 at 33368 (June 15, 2007).
[FR Doc. 2018-09305 Filed 5-10-18; 8:45 am]
22128-22162 (35 pages)
Docket ID: BSEE-2018-0002, 189E1700D2 ET1SF0000.PSB000 EEEE500000
1014-AA39
250.198,250.292,250.413,250.414,250.420,250.421,250.423,250.428,250.433,250.461,250.462,250.518,250.519,250.522,250.525,250.526,250.530,250.601,250.616,250.619,250.712,250.720,250.722,250.723,250.724,250.730,250.731,250.732,250.733,250.734,250.735,250.736,250.737,250.738,250.739,250.750,250.751,250.1703,250.1704,250.1706,250.1713,250.1716,250.1722
Administrative practice and procedure, Continental shelf, Environmental impact statements, Environmental protection, Oil and gas exploration, Penalties, Reporting and recordkeeping requirements, Sulfur
2018-09305.pdf
» AA39 IRIA
» AA39 Draft Environmental Assessment
CFR: (43)
30 CFR 250.198
30 CFR 250.292
30 CFR 250.413
30 CFR 250.414
30 CFR 250.420