Alaska Administrative Code › Title 20 - Miscellaneous Boards and Commissions › Chapter 25 - Alaska Oil and Gas Conservation Commission › Article 3 - Production Practices › 20 AAC 25.285 - Secondary well control for tubing workover operations: blowout prevention equipment requirements

Current through May 31, 2024
(a) This section applies to workover operations
				performed with the tree removed. These operations are also subject to the
				requirements of
				20 AAC 25.527.
(b) The rated working pressure of the BOPE and
				other well control equipment must exceed the maximum potential surface pressure
				to which it may be subjected. If an approved Application for Sundry Approvals
				(Form 10-403) is required under
				20 AAC 25.280, the commission will specify in that approved
				application the working pressure that the equipment must be rated to meet or
				exceed. However, the rated working pressure of the annular type preventer need
				not exceed 5,000 psi.
(c) Well
				control equipment must include
(1) at least one
				positive seal manual or hydraulic valve or BOPE blind ram and one set of BOPE
				pipe rams flanged to the wellhead;
(2) in rotary drilling rig operations,
(A) for an operation with a maximum potential
				surface pressure of 3,000 psi or less, at least three preventers, including
(i) one equipped with pipe rams that fit the
				size of drill pipe, tubing, liner or casing being used, except that pipe rams
				need not be sized to bottom-hole assemblies (BHAs) and drill collars;
(ii) one with blind rams, except that a subsea
				BOPE assembly must have blind/shear rams in place of blind rams; and
(iii) one annular type;
(B) for an operation, other than a casing or
				liner operation, with a maximum potential surface pressure of greater than 3,000
				psi, at least four preventers, including
(i)
				two equipped with pipe rams that fit the size of the drill pipe or tubing being
				used, except that pipe rams need not be sized to BHAs and drill
				collars;
(ii) one with blind rams,
				except that a subsea BOPE assembly must have blind/shear rams in place of blind
				rams; and
(iii) one annular type;
				and
(C) for a casing or
				liner operation, with a maximum potential surface pressure of greater than 3,000
				psi, at least four preventers, including
(i)
				one equipped with pipe rams that fit the size of the drill pipe or tubing being
				used, except that pipe rams need not be sized to BHAS and drill
				collars;
(ii) one equipped with pipe
				rams that fit the size of casing or liner being used;
(iii) one with blind rams, except that a subsea
				BOPE assembly must have blind/shear rams in place of blind rams; and
(iv) one annular type;
(3) in coiled tubing unit
				operations,
(A) for an operation with a maximum
				potential surface pressure of 5,000 psi or less,
(i) BOPE rams providing for pipe, slip,
				cutting, and blinding operations on the coiled tubing in service;
(ii) a high pressure pack-off, stripper, or
				annular type preventer;
(iii) if
				pressure deployment of tools is planned, a riser or lubricator sized to the BHA
				and providing for pressure integrity from the BOPE rams to the high pressure
				pack-off, stripper, or annular type preventer; and
(iv) at least one preventer equipped with pipe
				rams that fit the size of the tubing, liner, or casing being used, except that
				pipe rams need not be sized to BHAs and drill collars;
(B) for an operation, other than a casing or
				liner operation, with a maximum potential surface pressure of greater than 5,000
				psi,
(i) BOPE rams providing for pipe, slip,
				cutting, and blinding operations on the coiled tubing in service;
(ii) two high pressure pack-offs, strippers, or
				annular type preventers;
(iii) if
				pressure deployment of tools is planned, a riser or lubricator sized to the BHA
				and providing for pressure integrity from the BOPE rams to the high pressure
				pack-off, stripper, or annular type preventer; and
(iv) at least two preventers equipped with pipe
				rams that fit the size of the tubing used, except that pipe rams need not be
				sized to BHAs and drill collars; and
(C) for a casing or liner operation with a
				maximum potential surface pressure of greater than 5,000 psi,
(i) BOPE rams providing for pipe, slip,
				cutting, and blinding operations on the coiled tubing in service;
(ii) two high pressure pack-offs, strippers, or
				annular type preventers;
(iii) if
				pressure deployment of tools is planned, a riser or lubricator sized to the BHA
				and providing for pressure integrity from the BOPE rams to the high pressure
				pack-off, stripper, or annular type preventer;
(iv) at least one preventer equipped with pipe
				rams that fit the size of the tubing being used, except that pipe rams need not
				be sized to BHAs and drill collars; and
(v) at least one preventer equipped with pipe
				rams that fit the size of casing or liner being used;
(4) if a tapered string is used,
				either an additional set of rams for each size of pipe being run or a variable
				ram, except if small diameter tubulars are used to perform a clean-out operation
				through a production packer or to clean out a liner where the casing has been top
				set;
(5) locking devices on the
				ram-type preventers;
(6) in rotary
				drilling rig operations, one complete set of operable remote BOPE controls on or
				near the driller's station, in addition to controls on the accumulator
				system;
(7) in coiled tubing
				operations, one complete set of operable remote BOPE controls on or near the
				operator's station and, if these controls are not in close proximity to the
				drilling platform floor, a second annular type preventer closing control located
				on the drilling platform floor;
(8) a
				hydraulic actuating system with
(A) sufficient
				accumulator capacity to supply 150 percent of the volume necessary to close all
				BOPs, except blind rams, while maintaining a minimum pressure of 200 psi above
				the required precharge pressure when all BOPs, except blind rams, are closed and
				all power sources are shut off; and
(B) an accumulator pump system consisting of
				two or more pumps with independent primary and secondary power sources and an
				accumulator backup system having sufficient capacity to close all BOPs and to
				hold them closed;
(9) a
				kill line and a choke line each connected to a flanged or hubbed outlet on a
				drilling spool or on the BOP body with two full-opening valves on each outlet,
				conforming to the following specifications:
(A)
				the outlets must be at least two inches in nominal diameter, except that for
				rotary drilling rig operations, if the operation has a maximum potential surface
				pressure of greater than 3,000 psi, the nominal diameter of the choke outlets
				must be at least three inches;
(B)
				each valve must be sized at least equal to the required size of the outlet to
				which it is attached;
(C) the outer
				valve on the choke side must be a remotely controlled hydraulic valve;
(D) the inner valve on both the choke and kill
				sides may not normally be used for opening or closing on flowing fluid;
				and
(10) a choke manifold
				equipped with
(A) two or more adjustable chokes,
				one of which must be hydraulic and remotely controlled from near the driller's
				station if the operation has a maximum potential surface pressure of greater than
				3,000 psi;
(B) a line at least two
				inches in nominal diameter downstream of each choke;
(C) immediately upstream of each choke, at
				least one full-opening valve for an operation with a maximum potential surface
				pressure of 3,000 psi or less, or at least two full-opening valves for an
				operation with a maximum potential surface pressure of greater than 3,000 psi;
				and
(D) a bypass line, at least two
				inches in nominal diameter, with at least one full-opening valve for an operation
				with a maximum potential surface pressure of 3,000 psi or less, or at least two
				full-opening valves for an operation with a maximum potential surface pressure of
				greater than 3,000 psi.