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Home My WebLink AboutO 045 e e Image Project Order File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. o Q LI- 5" Order File Identifier Organizing (done) o Two-sided III \111111111\ IIIII o Rescan Needed 11\ IIII111I11111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: 0 Diskettes, No. ~reYSCale Items: \ ~ 0 Other, Norrype: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: DateIJ~JG7 o Other:: BY: ~ /s/ vV\f Project Proofing 1111111111111111111 Mr ~p BY: ~ Date '1:;'/07 /s/ Scanning Preparation BY: x 30 = + = TOTAL PAGES (Count does not include cover sheet) /s/ Date: Production Scanning Stage 1 Page Count from Scanned File: ~ LJ:- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date: / /d-./07 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 11///11111111111111 NO /s/ VV\ P NO BY: Maria Date: /s/ /1111111111I11 "'II Scanning is complete at this point unless rescanning is required. ReScanned ""1111111111 "III BY: Maria Date: /s/ Comments about this file: Quality Checked /11/1111111I1111111 10/6/2005 Orders File Cover Page. doc 1. July 26, 2006 July 28, 2006 July 28, 2006 2. 3. 4. August 31, 2006 5. October 9, 2006 6. November 6, 2006 7. November 15, 2006 8. November 28, 2006 9. December 4, 2006 . . Other 45 Permit to Drill and BOPE Regulations Proposed Regulations Notice of Hearing, distribution list File opening memo to AGO Juneau Transcript of Hearing Entire package mailed to the AGO in Juneau Affidavit of Jody Colombie Final Regulations Order Certifying the changes to regulations of AOGCC Changes made by the Lt. Governor's Office . . Notice of Adopted Changes to Regulations On August 31, 2006 the Alaska Oil and Gas Conservation Commission adopted regulation changes in Title 20 of the Alaska Administrative Code, Chapter 25 dealing with Permit to Drill requirements and blowout prevention equipment requirements. The affected regulations are 20 AAC 25.005(c)(4)(A), 20 AAC 25.035(e)(1), 20 AAC 25.035(e)(2), 20 AAC 25.035(e)(4), 20 AAC 25.035(e)(10), 20 AAC 25.036(c)(1), 20 AAC 25.036(c)(2), 20 AAC 25.036(c)(4)(H), 20 AAC 25.036(d), 20 AAC 25.280(b), 20 AAC 25.285(c)(2), 20 AAC 25.285(c)(3), 20 AAC 25.285(c)(9)(A), 20 AAC 25.285(c)(10), 20 AAC 25.285(f), 20 AAC 25.286(d)(1), 20 AAC 25.286(d)(3), 20 AAC 25.286(e). The regulation changes were reviewed and approved by the Department of Law, signed and filed by the Lieutenant Governor on November 28, 2006, and will go into effect on December 28, 2006. The new regulations will be printed in Register 180, January 2007 of the Alaska Administrative Code. For further information or to obtain a copy of the amended regulations, contact Jody Colombie, Alaska Oil and Gas Conservation Commission, at (907) 793-1221, fax (907) 276-7542, or e-mail JodyColombie@admin.state.ak.us. Register ~ . 200 MISCELLANEOUS B'ARDS 20 AAC 25.005(c)(4)(A) is amended to read: (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a pressure e:radient to surface of 0.1 psi per foot of true vertical depth. unless the commission approves a different pressure e:radient that provides a more accurate means of determinine: the maximum potential surface pressure [METHANE GRADIENT]; (Eff. 4/13/80, Register 74; am 4/2/86, Register 97; am 11/7/99, Register 152; am 6/4/2000, Register 154; am 1/5/2006, Register 177; am~~~ Register---.-J Authority: AS 31.05.030 AS 31.05.090 20 AAC 25.035(e)(l) is amended to read: (l) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 3.000 psi or less [REQUIRING A BOP STACK LESS THAN API 5K], BOPE must have 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) or 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 (B) for an operation. other than a casine: or liner operation. with a maximum potential surface pressure of e:reater than 3.000 psi [REQUIRING A BOP 1 Register -' . 200 . MISCELLANEOUS BOARDS STACK EQUAL TO OR GREATER THAN API 5K], BOPE must have at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe !!! [,] tubing [, OR CASING] 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; (C) for a casine: or liner operation with a maximum potential surface pressure of e:reater than 3.000 psi. BOPE must have at least four preventers. includine: (0 one equipped with pipe rams that fit the size of the drill pipe or tubine: beine: used. except that pipe rams need not be sized to BRAs and drill collars; (m one equipped with pipe rams that fit the size of casine: or liner beine: used; (iü) 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; 20 AAC 25.035(e)(2) is amended to read: (2) in coiled tubing unit operations, the well control equipment must include 2 Register _, . 200 . MISCELLANEOUS BOARDS (A) for an operation with a maximum Dotential surface Dressure of 5.000 Dsi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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, tubing, liner, or casing 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 tubing, liner, or casing being used, except that pipe rams need not be sized to BHAs and drill collars; and (B) for an operation. other than a casine: or liner oDeration. with a maximum Dotential surface Dressure of e:reater than 5.000 Dsi [REQUIRING A BOP STACK GREATER THAN API 5K], (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, tubing, liner, or casing 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 3 Register _, . 200 . MISCELLANEOUS BOARDS (iv) at least two preventers equipped with pipe rams that fit the size oftubing[, LINER, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; (C) for a casine: or liner oDeration with a maximum Dotential surface Dressure of e:reater than 5.000 Dsi. (i) BOPE rams Drovidine: for DiDe. SliD. curtine:. and blindine: oDerations on the coiled tubine: in service: (ii) two him Dressure Dack-otTs. striDDers. or annular tvDe Dreventers: (ill) if Dressure deDlovment of tools. tubine:. liner. or casine: is Dlanned. a riser or lubricator sized to the BHA and Drovidine: for Dressure intee:ritv from the BOPE rams to the him Dressure Dack-otT. striDDer. or annular tvDe Dreventer: (iv) at least one Dreventer eauiDDed with DiDe rams that fit the size of the tubine: beine: used. exceDt that DiDe rams need not be sized to BHAs and drill collars: and (v) at least one Dreventer eauiDDed with DiDe rams that fit the size of casine: or liner beine: used. 20 AAC 25. 035(e)(4)(F) is amended to read: (F) 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: 4 Register _, . 200 . MISCELLANEOUS BOARDS (i) 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 e:reater than 3.000 psi [REQUIRED BOP IS RATED EQUAL TO OR GREATER THAN API 5K], the nominal diameter of the choke outlets must be at least three inches; (ii) each valve must be sized at least equal to the required size of the outlet to which it is attached; (iii) the outer valve on the choke side must be a remotely controlled hydraulic valve; (iv) the inner valve on both the choke and kill sides may not normally be used for opening or closing on flowing fluid; 20 AAC 25. 035(e)(4)(H) is amended to read: (H) a choke manifold equipped with (i) 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 e:reater than 3.000 psi [REQUIRES A BOP STACK EQUAL TO OR GREATER THAN API 5K]; (ii) a line at least two inches in nominal diameter downstream of each choke; (iii) 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 [REQUIRING A BOP STACK LESS THAN API 5K], or at least two 5 Register _, . 200 . MISCELLANEOUS BOARDS full-opening valves for an operation with a maximum potential surface pressure of 2reater than 3.000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K]; and (iv) a bypass line, at least the diameter of the choke line, with at least one full-opening valve for an operation with a maximum potential surface pressure of 3.000 psi or less [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full-opening valves for an operation with a maximum potential surface pressure of 2reater than 3.000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K]; 20 AAC 25.035(e)(10) is amended to read: (l0) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non- compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; however, the commission will require that the BOPE be function pressure-tested weekly, if the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance; (B) when installed, repaired, or changed on an exploratory or stratigraphic test well and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required 6 Register _, . 200 e MISCELLANEOUS BOARDS working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (C) if any BOP [SEALING RAM TYPE] equipment components have [HAS] been used for well control or other equivalent purpose. or when routine use of the equipment may have compromised its effectiveness. the components used [IT] must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (D) BOP ram and annular components except blind rams must be function-tested weekly, and all BOP ram and annular components must be function- tested after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing of blind rams must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; (E) for each BOPE test durine: drilline: and completion operations. variable bore rams must be function pressure-tested to the required pressure on the smallest outside diameter (OD) and lare:est outside diameter (OD) tubulars that may be used durine: that test cYcle. except that variable bore rams need not be tested on BHAs and drill collars: (F) after installine: casine: rams in the BOP stack. the ram bonnets must be tested to the required pressure before runnine: casine:: 7 Register _, . 200 e MISCELLANEOUS BOARDS illl. BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1), and must be provided to the commission. in a format approved bv the commission. within fIVe days after completine: the test; .an [(F)] at least 24 hours notice of each BOPE function pressure test must be provided to the commission so that a commission representative can witness the test; (EfT. 4/13/80, Register 74; am 2/22/81, Register 77; am 4/2/86, Register 97; am 11/7/99, Register 152; am 10/24/2004, Register 172; am~~-, Register ~ Authority: AS 31.05.030 20 AAC 25.036(c)(1) is amended to read: (1) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], BOPE must have 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; [AND] (B) for an operation other than a casine: or liner operation. with a maximum potential surface pressure of e:reater than 5.000 psi [REQUIRING A BOP 8 Register _, . 200 . MISCELLANEOUS BOARDS STACK GREATER THAN API 5K], BOPE must have at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe !!! [,] tubing[, OR CASING] being used, except that pipe rams need not be sized to BRAs 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 casine: or liner operation with a maximum potential surface pressure of !!reater than 5.000 psi. ROPE must have at least four preventers. includine: (i) one equipped with pipe rams that fit the size of the drill pipe or tubin!! bein!! used. except that pipe rams need not be sized to RHAs and drill collars; (Ü) one equipped with pipe rams that fit the size of casin!! or liner bein!! used; (iÜ) one with blind rams. except that a subsea BOPE assemblv must have blind/shear rams in place of blind rams; and (iv) one annular type; 20 AAC 25.036(c)(2) is amended to read: (2) in coiled tubing unit operations, the well control equipment must include 9 Register _, . 200 . MISCELLANEOUS BOARDS (A) for a.."'1 operation with a maximum Dotential surface Dressure of 5.000 Dsi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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, tubing, liner, or casing 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; [AND] (B) for an operation. other than a casinlf or liner oDeration with a maximum Dotential surface Dressure of Ifreater than 5.000 Dsi [REQUIRING A BOP STACK GREATER THAN API 5K], (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, tubing, liner, or casing 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 10 Register _, . 200 . MISCELLANEOUS BOARDS (iv) at least two preventers 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; and (C) for a casine: or liner operation with a maximum potential surface pressure of e:reater than 5.000 psi. (i) BOPE rams providine: for pipe. slip. cuffine:. and blindine: operations on the coiled tobine: in service: (ü) two him pressure pack-offs. strippers. or annular tvpe preventers: Wi) if pressure deployment of tools. tobine:. liner. or casine: is planned. a riser or lubricator sized to the BHA and providine: for pressure intee:ritv from the BOPE rams to the hie:h pressure oack-off. stripper. or annular type preventer: (iv) at least one preventer equipped with pipe rams that fit the size of the tobine: beine: 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 casine: or liner beine: used: 20 AAC 25.036(c)(4)(H) is amended to read: (H) for conventional open loop fluid process drilling operations, a choke manifold equipped with 11 Register _, 2' MISCELLANEOUS BLs (i) two or more adjustable chokes, one of which must be hydraulic and remotely controlled from near the driller's or operator's station if the operation has a maximum notential suñace nressure of 2J'eater than 3.000 nsi [REQUIRES A BOP STACK EQUAL TO OR GREATER THAN API 5K]; (ii) a line at least two inches in nominal diameter downstream of each choke; (iii) immediately upstream of each choke, at least one full-opening valve for an operation with a maximum notential surface nressure of 5.000 nsi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], or at least two full-opening valves for an operation with a maximum notential suñace nressure of e:reater than 5.000 nsi [REQUIRING A BOP STACK GREATER THAN API 5K]; and (iv) a bypass line at least two inches in nominal diameter with at least one full-opening valve immediately upstream of each choke for an operation with a maximum notential suñace nressure of 5.000 nsi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], or with at least two full- opening valves immediately upstream of each choke for an operation with a maximum potential suñace pressure of e:reater than 5.000 psi [REQUIRING A BOP STACK GREATER THAN API 5K]; 20 AAC 25.036(d) is amended to read: (d) A BOPE assembly must be tested as follows: 12 Register _, . 200 . MISCELLANEOUS BOARDS (1) when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; however, the commission will require that the BOPE be function pressure-tested weekly, if the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance; (2) when installed, repaired, or changed on an exploratory or stratigraphic test well and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (3) other well control equipment must be pressure-tested to the maximum potential wellhead pressure after each installation of the well control equipment and before wellbore entry, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (4) ifanv BOP [SEALING RAM TYPE] equipment components have [HAS] been used for well control or other equivalent purpose. or when routine use of the equipment may have compromised its effectiveness. the components used [IT] must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; 13 Register _, . 200 . MISCELLANEOUS BOARDS (5) BOP ram and annular components except blind rams must be function-tested weekly, and all BOP ram and annular components must be function-tested after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing of blind rams must be performed as soon as possible after the workstring is pulled out of the well and the [BHA] clears the BOP; (6) for each DOPE test durin!! drillin2 and completion operations. variable bore rams must be function pressure-tested to the required pressure on the smallest outside diameter (OD) and lar!!est outside (OD) tubulars that mav be used durin!! that test cvcle. except that variable bore rams need not be tested on DRAs and drill collars; ill DOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1). and must be provided to the commission. in a format approved by the commission. within five days after completin!! the test; 00 [(7)] at least 24 hours notice of each DOPE function pressure test must be provided to the commission so that a representative of the commission can witness the test. (Eff. 11/7/99, Register 152; am 10/24/2004, Register 172; am ___-L-~ _, Register ~ Authority: AS 31.05.030 20 AAC 25.280(b) is amended to read: (b) The Application for Sundry Approvals must set out (1) the current condition of the well; (2) a copy of the proposed program for well work; 14 Register _, . MISCELLANEOUS BLs (3) unless already on file with the commission, a diagram and description of the well control equipment to be used, including if applicable a list of the blowout prevention equipment (BOPE) with specifications; (4) the maximum downhole pressure that may be encountered. criteria used to determine it. and the maximum potential suñace pressure based on a pressure e:radient to suñace of 0.1 psi per foot of true vertical depth. unless the commission approves a different pressure ~radient that provides a more accurate means of determinin!! the maximum potential suñace pressure. such as usin!! a stabilized shut-in tobin!! pressure: œ a description of any wellbore fluid to be used for primary well control; and œ [(5)] the current bottom-hole pressure, or, if data setting out the actual pressure are not available, an estimate of the current bottom-hole pressure. (Eff. 4/2/86, Register 97; am 11/7/99, Register 152; am~~--, Register ) Authority: AS 31.05.030 20 AAC 25.285(c)(2) is amended to read: (2) in rotary drilling rig operations, (A) for an operation with a maximum potential suñace pressure of 3.000 psi or less [REQUIRING A BOP STACK LESS THAT API 5K], at least three preventers,including (i) one equipped with pipe rams that fit the size of drill pipe, tubing, !i!!£!: or casing being used, except that pipe rams need not be sized to bottom-hole assemblies (BHAs) and drill collars; 15 Register _, . 200 . MISCELLANEOUS BOARDS (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] (B) for an operation. other than a casine: or liner operation. with a maximum potential surface pressure of e:reater than 3.000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K], at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe !!! [,] tubing[, OR CASING] 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 casine: or liner operation. with a maximum potential surface pressure of e:reater than 3.000 psi. at least four preventers. includine: (i) one equipped with pipe rams that fit the size of the drill pipe or tubine: beine: used. except that pipe rams need not be sized to BHAs and drill collars: (m one equipped with pipe rams that fit the size of casine: or liner beine: used: (Ui) one with blind rams. except that a subsea BOPE assemblv must have blind/shear rams in place of blind rams: and (iv) one annular type: 16 Register _, t MISCELLANEOUS B'ARDS 20 AAC 25.285(c)(3) is amended to read: (3) in coiled tubing unit operations, (A) for an operation with a maximum potential suñace pressure of 5.000 psi or less [REQillRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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 BRA 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 BRAs and drill collars; [AND] (B) for an operation. other than a casin2 or liner operation. with a maximum potentia) suñace pressure of ~eater than 5.000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], (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 BRA and providing for pressure integrity from the BOPE rams to the high pressure pack-off, stripper, or annular type preventer; and 17 Register _, . 200 . MISCELLANEOUS BOARDS (iv) at least two preventers 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; and (C) for a casine: or liner operation with a maximum potential surface pressure of e:reater than 5.000 psi. (i) BOPE rams providine: for pipe. slip. cuffine:. and blindine: operations on the coiled tobine: in service: (ii) two him pressure pack-offs. strippers. or annular tvpe preventers: (ÏÜ) ü pressure deplovment of tools is planned. a riser or lubricator sized to the BRA and providine: for pressure intee:ritv from the BOPE rams to the hie:h pressure pack-off. stripper. or annular tvpe preventer: (iv) at least one preventer eQuipped with ~ipe rams that fit the size of the tubine: beine: used. except that pipe rams need not be sized to BRAs and drill collars: and (v) at least one preventer eQuipped with pipe rams that fit the size of casine: or liner beine: used: 20 AAC 25.285(c)(9)(A) is amended to read: (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: 18 Register --' , MISCELLANEOUS B'ARDS (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 suñace pressure of 2reater than 3.000 psi [REQUIRED BOP IS RATED EQUAL TO OR GREATER THAN API 5K], 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 20 AAC 25.285(c)(10) is amended to read: (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 of2reater than 3.000 psi [REQUIRES A BOP STACK EQUAL TO OR GREATER THAN API 5K]; (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 [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full-opening 19 Register _, . 200 . MISCELLANEOUS BOARDS valves for an operation with a maximum potential surface pressure of 2reater than 3.000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K]; 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 [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full-opening valves for an operation with a maximum potential surface pressure of 2reater than 3.000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K]. 20 AAC 25.285(f) is amended to read: (f) The BOPE must be tested as follows: (1) when installed, repaired, or changed, and at least once a week thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which the BOPE may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (2) if any BOP [SEALING RAM TYPE] equipment components have [HAS] been used for well control or other equivalent purpose. or when routine use of the equipment may have compromised its effectiveness, the components used [IT] must be function pressure-tested before the next wellbore entry, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 Register _, . 200 . MISCELLANEOUS BOARDS 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which that equipment may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; (4) for each BOPE test durine: drilline: and completion operations. variable bore rams must be function pressure-tested to the required pressure on the smallest outside diameter (OD) and lare:est outside diameter (OD) tubulars that may be used durine: that test cvcle. except that variable bore rams need not be tested on BRAs and drill collars; (5) after installine: casine: rams in the BOP stack. the ram bonnets must be tested to the required pressure before runnine: casine:; (6) BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1). and must be provided to the commission. in a format approved by the commission. within five days after completine: the test; í1l. [(5)] at least 24 hours notice of each DOPE function pressure test must be provided so that a representative of the commission can witness the test,;, (8) the operator shall report to the commission within 24 hours any instance of DOPE use to prevent the flow of fluids from a well. (Eff. 4/2/86, Register 97; am 11/7/99, Register 152; am---1---1_, Register ~ Authority: AS 31.05.030 21 Register ~ . 200 . MISCELLANEOUS BOARDS 20 AAC 25.286(d)(2) is amended to read: (2) in rotary drilling rig operations, (A) for an operation with a maximum potential suñace pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], 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; and (B) for an operation. other than a casine: or liner operation. with a maximum potential suñace pressure of e:reater than 5.000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe or[,] tubing[, OR CASING] 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; (C) for a casine: or liner operation with a maximum potential suñace pressure of e:reater than 5.000 psi. at least four preventers. includine: 22 Register --' e 200 . MISCELLANEOUS BOARDS (i) one equipped with pipe rams that fit the size of the drill pipe or tubine: beine: used. except that pipe rams need not be sized to BRAs and drill collars: (ii) one equipped with pipe rams that fit the size of casine: or liner beine: used: (üi) one with blind rams. except that a subsea BOPE assemblv must have blind/shear rams in place of blind rams: and (iv) . one annular type: 20 AAC 25.286(d)(3) is amended to read: (3) in coiled tubing unit operations, (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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; and (iii) if pressure deployment of tools is planned, a riser or lubricator sized to the BRA and providing for pressure integrity ftom the BOPE rams to the high pressure pack-off, stripper, or annular type preventer; and (B) for an operation with a maximum ~otential surface pressure of e:reater than 5.000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], 23 Register _, . 200_ . MISCELLANEOUS BOARDS (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; and (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; 20 AAC 25.286(e) is amended to read: (e) The operator shall test the BOPE assembly as follows: (1) at least once a week, and after each [USE,] repair, [OR] change, or use for well control or other equivalent purpose. or when routine use of the equipment mav have compromised its effectiveness. BOP equipment [BOPE PIPE AND BLIND RAMS] must be function pressure-tested, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which they may be subjected, except that the annular type preventer need not be tested to more than 50 percent of its rated working pressure; (2) after each installation of BOPE or other well control equipment, the equipment must be pressure-tested, before wellbore entry, to the maximum potential wellhead pressure to which it may be subjected, except that when testing against the annular type preventer, pressure testing need not exceed 50 percent of the rated working pressure of the annular type preventer; 24 Register _, . 200_ . MISCELLANEOUS BOARDS (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing must be performed as soon as possible after the workstring is pulled out of the well and the BRA clears the BOP; (4) after each well installation of the BOPE, the BOPE hydraulic connections to the rams must be visually verified before wellbore entry,¡ (5) for each BOPE test durine: drilline: and completion operations. variable bore rams must be function pressure-tested to the required pressure on the smallest outside diameter (OD) and lare:est outside diameter (OD) tubulars that may be used durine: that test cycle. except that variable bore rams need not be tested on BHAs and drill collars: (6) BOPE test results must be recorded as part of the daüv record required by 20 AAC 25.070(1). and must be provided to the commission. in a format approved by the commission. within five days after completine: the test: (7) at least 24 hours notice of each DOPE function pressure test must be -provided so that a representative of the commission can witness the test: (8) the operator shall report to the commission within 24 hours any instance of BOPE use to prevent the flow of fluids from a well. (Eff. 11/7/99, Register 152; am~~_, Register ~ Authority: AS 31.05.030 25 Amended Regulations . . Subject: Amended Regulations From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Thu, 28 Dec 2006 09:51:53 -0900 To: undisclosed-recipients:; BCC: Christine Hansen <c.hansen@iogcc.state.ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, stanekj <stanekj@unoca1.com>, ecolaw <ecolaw@trustees.org>, trmjr 1 <trmjr l@aol.com>, jdarlington <jdarlington@forestoi1.com>, nelson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <markdalton@hdrinc.com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P. Worcester" <markp.worcester@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv@dnr.state.ak.us>, tjr <tjr@dnr.state.ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <Mike1.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <PlattJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.f.fullmer@conocophillips.com>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank.alford@exxonmobil.com>, Mark Kovac <yesno1@gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>,jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>,jah <jah@dnr.state.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark _ hanley@anadarko.com>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz <jwkatz@sso.org>, tablerk <tablerk@unoca1.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kenai.ak.us>, Jim White <jimwhite@satx.rr.com>, "John S. Haworth" <john.s.haworth@exxonmobi1.com>, marty <marty@rkindustrial.com>, ghammons <ghammons@ao1.com>, rmclean <rmclean@pobox.alaska.net>, mkm7200 <mkm7200@aol.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr.state.ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks <kristin_dirks@dnr.state.ak.us>, Kaynell Zeman <kjzeman@marathonoil.com>, John Tower <John.Tower@eia.doe.gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe <lambes@unocal.com>, jack newell <jacknewell@acsalaska.net>, James Scherr <james.scherr@mms.gov>, n1617@conocophillips.com, Tim Lawlor <Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs <Jerry.C.Dethlefs@conocophillips.com>, crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>, Jon Goltz <Jon.Goltz@conocophillips.com>, Roger Belman <roger.belman@conocophillips.com>, Mindy Lewis <mlewis@brenalaw.com>, Kari Moriarty <moriarty@aoga.org>, Patty Alfaro <palfaro@yahoo.com>, Jeff <smetankaj@unocal.com>, Gary Rogers <gary Jogers@revenue.state.ak.us>, Arthur Copoulos <Arthur_Copoulos@dnr.state.ak.us>, Ken <ken@secorp-inc.com>, Steve Lambert <salambert@unocal.com>, Joe Nicks <news@radiokenai.com>, Jerry McCutcheon <susitnahydronow@yahoo.com>, Bill Walker <bill-wwa@ak.net>, Iris Matthews <Iris_Matthews@legis.state.ak.us>, Paul Decker <paul_decker@dnr.state.ak.us>, Aleutians East Borough 10f2 12/28/200610:06 AM Amended Regulations . . <admin@aleutianseast.org>, Marquerite kremer <marguerite_kremer@dnr.state.ak.us>, Mike Mason <mike@kbbi.org>, Garland Robinson <gbrobinson@marathonoil.com>, Cammy Taylor <Camille_Tay10r@law.state.ak.us>, Winton GAubert <winton_aubert@admin.state.ak.us>, Thomas E Maunder <tom_maunder@admin.state.ak.us>, Stephen F Davies <steve_davies@admin.state.ak.us>, Keith Wiles <kwiles@marathonoil.com>, Deanna Gamble <dgamble@kakivik.com>, James B Regg <jimJegg@admin.state.ak.us>, Catherine P Foerster <cathy_foerster@admin.state.ak.us>, Bob <Bob@fairweather.com>, gregory micallef <micallef@clearwire.net>, Laura Silliphant <laura _ silliphant@dnr.state.ak.us>, David Steingreaber <david.e.steingreaber@exxonmobil.com>, akpratts@acsalaska.net, Robert Campbell <Robert.Campbell@reuters.com>, Steve Moothart <steve_moothart@dnr.state.ak.us>, Anna Raff <anna.raff@dowjones.com>, Cliff Posey <cliff@posey.org>, Paul Bloom <paul_bloom@m1.com>, Meghan Powell <Meghan.Powell@asrcenergy.com>, Temple Davidson <temple_davidson@dnr.state.ak.us>, Walter Featherly <WFeatherly@PattonBoggs.com>, Tricia Waggoner <twaggoner@nrginc.com>, Mike Stockinger <Mike.Stockinger@anadarko.com>, , John Spain <jps@stateside.com> This serves as a notification that the Alaska Oil and Gas Conservation has adopted regulation changes in Title 20 of the Administrative Code, Chapter 25 dealing with Permit to Drill and Blowout Prevention Equipment requirements. These adopted regulations can be found on our website at aogcc.alaska.gov. If you have any questions, please feel free e-mail or call me at 907-793-1221. Jody Colombie, Special Assistant to the Commission Jody Colombie <iody colombie(a¿admin.state.ak.us> Special Staff Assistant Alaska Oil and Gas Conservation Commission Department of Administration 20f2 12/28/200610:06 AM #q · Office of the Attorney General Oil, Gas & Mining Section 1031 W. 4th Avenue, Suite 200 Anchorage, AK 99501-1994 Phone: (907) 269-5255 Fax: (907) 279·8644 Fax Transmission The information contained in this fax is confidential and/or privileged. This fax is intended to be reviewed initially by only the individual named below. If the reader of this transmittal page is not the intended recipient or a representative of the intended recipient, you are hereby notified that any review, dissemination or copying of this fax or the information contained herein is prohibited. If you have received this fax in error, please immediately notify the sender by telephone and return this fax to the sender at the above address. Thank you. To: Jn~ From: ~ Fax#: 21~ -1Yf~ Date: /')-{ tJ ( 0 (. ,~ Subject: J'\l~ f\~ Message: Pages: , including cover sheet ~0vLL-~~ ~~+k- L\-. Gtevt~ ~. .--'" If you do not receive all the pages or have any problems with this fax, lease call for assistance at 907) 269-5255. I:\FORMS\FAX - CONFIDENTIAL.DOC.DOC 12/04/2006 11:52 FAX 9072798644 ATIORNEY GENERAL'S OFF 141001 ********************* *** TX REPORT *** ********************* TRANSMISSION OK TX/RX NO RECIPIENT ADDRESS DESTINATION ID ST. TIME TIME USE PAGES SENT RESULT 2917 2767542 12/04 11: 51 00'54 5 OK Office of the Attorney General Oil, Gas & Mining Section 1031 W. 4th Avenue, Suite 200 Anchorage. AK 99501-1994 Phone: (907) 269·5255 Fax: (907) 279·8644 Fax Transmission The information contained in this fax is confidential and/or privileged. This fax is intended to be reviewed initially by only the individual named·below. If the reader of this transmittal page is not the intended recipient or a representative of the intended recipien~ you are hereby notified that any review, dissemination or copying of this fax or the information contained herein is prohibited. If you have received this fax in e"or, please immediately notify the sender by telephone and return this fax to the sender at the above address. Thank you. To: .Jn~ From: ~. Subject: J)t~ j\1~ Message: Fax#: 2-"1 ~ - 1s1-;;t Date: /,./ tJ (/) '" ~ . including cover sheet Pages: ~ IÀ.A..<- ~ ~ ~; +k- Lt. Gtøv·~ ~. Register , -- MISCELLANEOUS .DS (B) when installed, repaired, or changed on an exploratory or stratigraphic test well and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (C) if any BOP [SEALING RAM TYPE] equipment components have [HAS] been used for well control or other equivalent purpose, or when routine use of must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (D) BOP ram and annular components except blind rams must be function-tested weekly, and all BOP ram and annular components must be function- tested after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing of blind rams must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; (E) ~cdf- 'i17F' be used durin A :;A CJr , t2. 7/'2.00" 7 Register _, -- MISCELLANEOUS .RDS specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (5) BOP ram and annular components except blind rams must be function-tested weekly, and all BOP ram and annular components must be function-tested after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing of bl' d rams must be performed as soon as possible ßI-\A .(, after the workstring is pulled out of the well ;-theE~clears the BOP; 1\ ;.( cðï (6) for each BOPE test during drilling and completion operations, variable "/ï..7fwo(. ~- ~ . . I_ . ---- . ;; ~ ev-tside dlo.W\C-C~ bore rams must be function ressure tested to the re uired ressure on the sma est D ~s\kd-¡~~4 .4 t· ~ r ~and larest D tubulars that ma be used durin that test c '-<71 .1- " 1I/1.7/1.ooL -. J rams need not be tested on BHAs and drill collars; ~~ JI /7..7/z.o0 (" m BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1), and must be provided to the commission, in a format approved by the "Iv> '" ",\4 þ{ '" <'\d.-u- Ii VI -c. commission, within five days after completing the test; ...., ~(7)] at least 24 hours notice of each BOPE function pressure test must be provided to the commission so that a representative of the commission can witness the test. iT' ,f l' /\' \'- Hi~tgr~(¥ff. 11/7/99, Register 152; am 10/24/2004, Register 172; am_/_/_, Register ~ Authority: AS 31.05.030 Yea. d pr '<f-- 20 AAC 25.280(b) is amended to a@d-a R']U'1"Rl'RgU : (b) The Application for Sundry Approvals must set out Ii Register _, -- MISCELLANEOUS .RDS (2) if any BOP [SEALING RAM TYPE] equipment components hav~HAS] been used for well control or other equivalent purpose. or when routine use of the equipment may have compromised its effectiveness, the components used [IT] must be function pressure-tested before the next wellbore entry, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, ifthat application is not required, to the maximum potential surface pressure to which that equipment may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that ifthe workstring is continuously in the well, function-testing must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; r 0ICðfr , 1"2.'7/ùM. /0-- - rams need not be tested on BHAs and drill collars; a:... ~flter installing casing rams in the BOP stack. the ram bonnets must be r~ tested to the required pressure before running casing; ~ BOPE test results must be recorded as part of the daily record required by 20 - AAC 25.070(1). and must be provided to the commission. in a format approved by the commission. within five days after completing the test; ffi[(5)] at least 24 hours notice of each BOPE function pressure test must be .}, , ¡ß. provided so that a representative of the commission can witness the test;if' 02./ Register _, -- MISCELLANEOUS .DS (2) after each installation ofBOPE or other well control equipment, the equipment must be pressure-tested, before wellbore entry, to the maximum potential wellhead pressure to which it may be subjected, except that when testing against the annular type preventer, pressure testing need not exceed 50 percent of the rated working pressure of the annular type preventer; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; (4) after each well installation of the BOPE, the BOPE hydraulic connections to the rams must be visually verified before wellbore entry.i~ ~Ldr '1/l7/~o, (5) for each HOPE test durin!! drillin!! and completion operations. variable bore ra'::-must be function res~~sted to the re Ulred ~S!<tti.~I(;lfl'l.e.te.~ t and lar est OD_ tubulars that ma be used durin that test c ~Cdr ..(- Jlj"17jw;I'.. rams need not be tested on HRAs and drill collars; (6) BOPE test results must be recorded as part ofthe daily record required d(d0 1'/27/200' by 20 AAC 25.0700). and must be provided to the commission. in a format approved by the commission. within five days after completin!! the test; (7) at least 24 hours notice of each HOPE function pressure test must be provided so that a representative of the commission can witness the test; (8) the operator shall report to the commission within 24 hours any instance rf.., .......bølJ Q( lìn(. of BOPE use to prevent the flow of fluids from a well. .,,11.«(" .... :25 ~8 12/18/2006 17:55 907465~1 LT GOV SEAN PAR~ PAGE 02 ORDER CERTIFYING THE CHANGES TO REGUL \. TIONS OF ALASKA OIL AND GAS CONSERVATION COMMISSION The attached 26 pages )f regulations, dealing with Permit to Drill requirements and blowout prevention equipment ur der 20 AAC 25 are hereby certified to be a correct copy of the regulation changes that the Alask l Oil and Gas Conservation Commission adopted at its September 27, 2006 meeting, under tJ: e authority of AS 31.05.030 and 31.05.040 and after compliance with the Administrative ProcedlU'e Act (AS 44.62), specifically including notíce under AS 44.62.190 and 44.62.200 and opportu llty for public corrunent under AS 44.62.210. This action is not exp~~ ~ted to require an increased appropriation. On the record, in consi ::lering public comments, the Alaska Oil and Gas Conservation Commission paid spec lal attention to the cost to private persons of the regulatory action being taken. The regulation change; described in this order take effect on the 30th day after they have been filed by the lieutenant :;ovemor, as provided in AS 44.62.180. DATE: Octobe; . 9. 2006 Anch Jrage ~t~ C y P. Foerster Commissioner FILING CERTIFICATION I, Loren Leman, Lieut mant Governor for the State of Alaska~ certify that on ~~, 28 . . 2006 at II: r¡ ~., I filed the attached regulations according to the provisions of AS 44.6 !.040 - 44.62.120. ~ -&. ~ .' Lie:utenant Governor Ei:fective: ~ rJJ.u-.;;g , dð'O{' .. Rcgister~ lKl4~ *1 . . MEMORANDUM State of Alaska Department of Law To: John K. Norman, Chair Date: November 15,2006 Oil & Gas Conservation Commission Dept. of Administration File No.: 993-07-0029 Tel. No.: 465-3600 4J-A-.lrw.-LJ;::~' ~ From: Deborah E. Behr Chief Assistant Attorney General and Regulations Attorney Legislation and Regulations Section Re: Alaska Oil and Gas Conservation Commission Regulations Re: Permit to Drill Requirements and Blowout Prevention Equipment (20 AAC 25) Under AS 44.62.060, we have reviewed the Alaska Oil and Gas Conservation Commission's adoption, amendment, and repeal of these regulations and approve the changes for filing by the lieutenant governor. A duplicate original of this memorandum is being furnished the lieutenant governor, along with the 26 pages of regulations and the related documents. You might wish to contact the lieutenant governor's office to confirm the filing date and effective date of the attached regulation changes. The July 26, 2006 public notice and the October 9, 2006 certification order both state that this action is not expected to require an increased appropriation. Therefore, a fiscal note under AS 44.62.195 is not required. In accordance with AS 44.62.125(b)(6), some corrections have been made in the regulations, as shown on the attached copy. DEB:pvp cc w/enc.: Kevin Brooks, Regulations Contact Dept. of Administration Cammy Taylor, Assistant Attorney General Anchorage . . MEMORANDUM State of Alaska Department of Law To: Hon. Loren Leman Lt. Governor Date: November 15, 2006 File No.: 993-07-0029 ~¿'~ From: Deborah E. Behr Chief Assistant Attorney General and Regulations Attorney Legislation and Regulations Section Tel. No.: 465-3600 Re: Alaska Oil and Gas Conservation Commission Regulations Re: Permit to Drill Requirements and Blowout Prevention Equipment (20 AAC 25) We have reviewed the attached regulations from the Alaska Oil and Gas Conservation Commission (AOGCC). A duplicate of this memorandum is being furnished to Chair John K. Norman, along with a copy ofthe regulations. The Department of Law has reviewed the attached regulations against the statutory standards of the Administrative Procedure Act. Based upon our review, we find no legal problems. This memorandum and the attached duplicate memorandum dated November 15, 2006 constitute the written statement of approval under AS 44.62.060(b) and (c) that authorizes your office to file the attached regulations. The regulation changes were adopted by the AOGCC after the close of the public comment period. The regulations concern permit to drill requirements and blowout prevention equipment. The certification order for the regulations states that this action is not expected to require an increased appropriation. Therefore, a fiscal note under AS 44.62.195 is not required. We have made technical corrections to conform the regulations with the drafting manual under AS 44.62.060 and 44.62.125. The corrections are shown on the attached copy of the regulations. DEB:pvp cc: John K. Norman, Chair Oil & Gas Conservation Commission Dept. of Administration /~ . Register _, '0 MISCELLANEOUS lARDS E:-- 20 AAC 25.005(c)(4)(A) is amended to read: (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a pressure gradient to surface of 0.1 psi per foot of true vertical depth. unless the commission approves a different pressure gradient that provides a more accurate means of determinin the maximum otential surface '1 t l' 1'. 1" (Eff. 4/13/80, Register 74; am 4/2/86, Register 97; am 11/7/99, Register 152; am 6/4/2000, Register 154; am 1/5/2006, Register 177; am _/ ~ _, Register ~ Authority: AS 31.05.030 AS 31.05.090 ç- 20 AAC 25.035(e)(1) is amended to read: (1) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 3.000 psi or less [REQUIRING A BOP STACK LESS THAN API 5K], BOPE must have 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) or 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 J ~. Register _, t MISCELLANEOUS 'ARDS (B) for an operation, other than a casine: or liner operation. with a maximum potential surface pressure of e:reater than 3.000 psiJREQUIRlNG A BOP STACK EQUAL TO OR GREATER THAN API 5K], BOPE must have at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe ..¡ Q![,] tubing [, OR CASING] 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; (C) for a casine: or liner operation with a maximum potential surface pressure of e:reater than 3.000 psi, BOPE must have at least four preventers, includine: (n one equipped with pipe rams that fit the size of the drill pipe or tobine: beine: used. except that pipe rams need not be sized to BHAs and drill collars; (in one equipped with pipe rams that fit the size of casine: or liner bein2 used; (Hi) one with blind rams. except that a subsea BOPE assembly must have blind/she·ar rams in place of blind rams; and (iv) one annular type; <. 20 AAC 25.035(e)(2) is amended to read: c2 ~ Register _, I MISCELLANEOUS 'ARDS (2) in coiled tubing unit operations, the well control equipment must include (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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, tubing, liner, or casing 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 tubing, liner, or casing being used, except that pipe rams need not be sized to BHAs and drill collars; and (B) for an operation. other than a casin~ or liner operation. with a maximum potential surface pressure of ~reater than 5.000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], (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, tubing, liner, or casing is planned, a riser or lubricator sized to the BHA and providing for pressure 3 Register _, to MISCELLANEOUS 'ARDS 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 oftubing[, LINER, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; (C) for a casine or liner operation with a maximum potential surface pressure of ereater than 5.000 psi. (i) BOPE rams providine for pipe. slip. cuttine. and blindine operations on the coiled tubine in service; (m two hieh pressure pack-offs. strippers. or annular type preventers; (Hi) if pressure deplovment of tools. tubine. liner. or casine is planned. a riser or lubricator sized to the BRA and providine for pressure inteeritv from the BOPE rams to the hieh pressure pack-off. stripper. or annular tvpe preventer; (iv) at least one preventer equipped with pipe rams that fit the size of the tubine beine 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 casine or liner beine used. ) <E-- 20 AAC 25. 035(e)(4)(F) is amended to read: '-/- Register _, I MISCELLANEOUS 'ARDS (F) 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: (i) 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 2reater than 3.000 psi [REQUIRED BOP IS RATED EQUAL TO OR GREATER THAN API 5K], the nominal diameter of the choke outlets must be at least three inches; (ii) each valve must be sized at least equal to the required size of the outlet to which it is attached; (iii) the outer valve on the choke side must be a remotely controlled hydraulic valve; (iv) the inner valve on both the choke and kill sides may not normally be used for opening or closing on flowing fluid; <E:--20 AAC 25. 035(e)(4)(H) is amended to read: (H) a choke manifold equipped with (i) 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 10,,1"'\ -- maximum potential surface pressure of 2reater than 3.000 psi [REQUIRES A BOP STACK EQUAL TO OR GREATER THAN API 5K]; (ii) a line at least two inches in nominal diameter downstream of each choke; s- Register _, . 200 MISCELLANEOUS 'ARDS (iii) 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 [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full-opening valves for an operation with a maximum potential surface pressure of I!reater than 3,000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K]; and (iv) a bypass line, at least the diameter of the choke line, with at least one full-opening valve for an operation with a maximum potential surface pressure of 3,000 psi or less [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full-opening valves for an operation with a maximum potential surface pressure of I!reater than 3.000 ps\[REQUIRlNG A BOP STACK EQUAL TO OR GREATER THAN API 5K]; ~ 20 AAC 25.035(e)(10) is amended to read: (10) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non- compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; however, the commission will require that the BOPE be function pressure-tested weekly, if the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance; ~ Register _, t MISCELLANEOUS 'ARDS (B) when installed, repaired, or changed on an exploratory or stratigraphic test well and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (C) if any BOP [SEALING RAM TYPE] equipment components have [HAS] been used for well control or other equivalent purpose. or when routine use of must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (D) BOP ram and annular components except blind rams must be function-tested weekly, and all BOP ram and annular components must be function- tested after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing of blind rams must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; (E) for each BOPE test durinf! drillinf! and completion operations. variable bore rams must be function pressure tested to the required pressure on the smallest outside diameter (OD) and larf!est OD tubulars that may be used durinf! 7 Register _, . 200 MISCELLANEOUS 'ARDS that test cycle. except that variable bore rams need not be tested on BRAs and drill collars; (F) after installin£! casin£! rams in the BOP stack. the ram bonnets must be tested to the required pressure before runnin£! casin£!ø , í!!l. BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1), and must be provided to the commission. in a format approved bv the commission. within five days after completin£! the test; (H) [(F)] at least 24 hours notice of each BOPE function pressure test must be provided to the commission so that a commission representative can witness the test; l' f IÎ' Iì' (Hfstory;ÍEff. 4/13/80, Register 74; am 2/22/81, Règister 77; am 4/2/86, Register 97; am 11/7/99, Register 152; am 10/24/2004, Register 172; am _I _I _, Register ~ Authority: AS 31.05.030 <: 20 AAC 25.036(c)(1) is amended to read: (1) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], BOPE must have 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; <1 Register _, . 200 MISCELLANEOUS !ARDS (ii) one with blind rams, except that a subsea BOPE assembly must have blind/shear rams in place of blind rams; and AroJD (iii) one annular type; ~ J (B) for an operation other than a casinl! or liner operation, with a maximum potential surface pressure of I!reater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], BOPE must have at least four preventers, including (i) two equipped with pipe rams that fit the size ofthe drill pipe o~,] tubing[, OR CASING] 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; ~ Y' Ò, (C) for a casinl! or liner operation with a maximum potential surface pressure of I!reater than 5,000 psi, BOPE must have at least four preventers, includinl! (n one equipped with pipe rams that fit the size of the drill pipe or tubinl! beinl! used, except that pipe rams need not be sized to BHAs and drill collars; (m one equipped with pipe rams that fit the size of casinl! or liner beinl! used; (iii) one with blind rams, except that a subsea BOPE assembly must have blind/shear rams in place of blind rams; and 9 Register _, . 200 MISCELLANEOUS lARDS (iv) one annular type; ~o AAC 25.036(c)(2) is amended to read: (2) in coiled tubing unit operations, the well control equipment must include (A) for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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, tubing, liner, or casing 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 MP sized to BHAs and drill collars;~.J (B) for an operation, other than a casill!! or liner operation with a maximum potential surface pressure of greater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], (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; /0 Register , . 200 MISCELLANEOUS 'ARDS (iii) if pressure deployment of tools, tubing, liner, or casing 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[, LINER, OR CASING] being used, except that pipe rams need not ,.. be sized to BHAs and drill collars;QJ'\ d - (C) for a casine: or liner operation with a maximum potential surface pressure of e:reater than 5.000 psi. (i) BOPE rams urovidine: for pipe. slip. cuttine:. and blindine: operations on the coiled tubine: in service: (ii) two hie:h pressure pack-offs. strippers. or annular type preventers: (iii) if pressure deployment of tools. robine:. liner. or casine: is planned. a riser or lubricator sized to the BHA and providine: for pressure intee:ritv from the BOPE rams to the hie:h pressure pack-off. stripper. or annular type preventer: (iv) at least one preventer equipped with pipe rams that fit the size of the tubine: beine: 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 casine: or liner beine: used: ) I Register _, I MISCELLANEOUS .ARDS <:::f-- 20 AAC 25.036(c)(4)(H) is amended to read: (H) for conventional open loop fluid process drilling operations, a choke manifold equipped with (i) two or more adjustable chokes, one of which must be hydraulic and remotely controlled from near the driller's or operator's station if the operation has a maximum potential surface pressure of e:reater than 3.000 psi [REQUIRES A BOP STACK EQUAL TO OR GREATER THAN API 5K]; (ii) a line at least two inches in nominal diameter downstream of each choke; (iii) immediately upstream of each choke, at least one full-opening valve for an operation with a maximum potential surface pressure of 5.000 psi or less, [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], \( or at least two full-opening valves for an operation with a maximum potential surface pressure of e:reater than 5.000 psi [REQUIRING A BOP STACK I( GREATER THAN API 5K]; and (iv) a bypass line at least two inches in nominal diameter with at least one full-opening valve immediately upstream of each choke for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], or with at least two full- opening valves immediately upstream of each choke for an operation with a maximum potential surface pressure of e:reater than 5.000 psi~REQUIRING A BOP STACK GREATER THAN API 5K]; 12 Register _, . 200 MISCELLANEOUS ARDS ~ 20 AAC 25.036(d) is amended to read: (d) A BOPE assembly must be tested as follows: (1) when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; however, the commission will require that the BOPE be function pressure-tested weekly, if the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance; (2) when installed, repaired, or changed on an exploratory or stratigraphic test well and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (3) other well control equipment must be pressure-tested to the maximum potential wellhead pressure after each installation of the well control equipment and before wellbore entry, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (4) if any BOP [SEALING RAM TYPE] equipment components hav~AS] been used for well control or other equivalent purpose, or when routine use of the equipment may have compromised its effectiveness, the components used [IT] must be function pressure-tested, before the next wellbore entry, to the required working pressure /) Register _, . 200 . MISCELLANEOUS BOARDS specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (5) BOP ram and annular components except blind rams must be function-tested weekly, and all BOP ram and annular components must be function-tested after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing of blind rams must be performed as soon as possible ßHA after the workstring is pulled out of the well and the ~ clears the BOP; (6) for each BOPE test durinl! drillinl! and completion operations. variable ov-+ .s i cleo d i C:l1IYH~...1t: v- bore rams must be function ressure tested to the re uired ressure on the sma est D and larl!est OD tubulars that may be used durinl! that test cycle. except that variable bore rams need not be tested on BHAs and drill collars~ ill BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1). and must be provided to the commission. in a format approved by the '")u> 10 ,p\4 ." ... M'CK Ii VI 'Co commission. within five days after completinl! the test~ ...., ~(7)] at least 24 hours notice of each BOPE function pressure test must be provided to the commission so that a representative of the commission can witness the test. 0' ,t t /\' \- HijìtQf)9.~ff. 11/7/99, Register 152; am 10/24/2004, Register 172; am~_/_, Register ~ Authority: AS 31.05.030 Ye OL d ~ 'f-- 20 AAC 25.280(b) is amended to add::a :SBW pfJl'Rg : (b) The Application for Sundry Approvals must set out 11 Register _, . 200 MISCELLANEOUS BIRDS (1) the current condition of the well; (2) a copy of the proposed program for well work; (3) unless already on file with the commission, a diagram and description ofthe well control equipment to be used, including if applicable a list of the blowout prevention equipment (BOPE) with specifications; (4) the maximum downhole pressure that may be encountered, criteria used to determine it, an~ximum potential surface pressure based on a pressure eradient to 1\ surface of 0.1 psi per foot of true vertical dept~unless the commission approves a different pressure eradient that provides a more accurate means of determinine the maximum potential surface pressure, such as usine a stabilized shut-in tubine pressure. .J æ a description of any wellbore fluid to be used for primary well control; and .Œì [(5)] the current bottom-hole pressure, or, if data setting out the actual pressure are not available, an estimate of the current bottom-hole pressure. l' 1" l' l' ~ ~&'£f.~4/2/86, Register 97; am 11/7/99, Register 152; am~~_, Register ) Authority: AS 31.05.030 ~ 20 AAC 25.285(c)(2) is amended to read: (2) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 3,000 psi or less [REQUIRING A BOP STACK LESS THAT API 5K], at least three preventers, including }5 Register _, e 200 MISCELLANEOUS !tRDS (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 casine; or liner operation. with a maximum STACK EQUAL TO OR GREATER THAN API 5K], at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe o~,] tubing[, OR CASING] 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; tÎ.Y'I '^ - (C) for a casine; or liner operation. with a maximum potential surface pressure of e;reater than 3.000 psi. at least four preventers. includine; (i) one equipped with pipe rams that fit the size of the drill pipe or tubine; beine; 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 casine; or liner beine; used; /(:; Register _, e 200 . MISCELLANEOUS BOARDS (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; ~20 AAC 25.285(c)(3) is amended to read: (3) in coiled tubing unit operations, (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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 ANi> to BHAs and drill collars;§rl J (B) for an operation. other than a casing or liner operation. with a maximum potential surface pressure of greater than 5.000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], (i) BOPE rams providing for pipe, slip, cutting, and blinding operations on the coiled tubing in service; 1/ Register _, . 200 MISCELLANEOUS ARDS (ii) two high pressure pack-offs, strippers, or annular type preventers; (iii) if pressure deployment of tools is planned, a riser or no bolJ o(vl\ð.(...VIi'l-! lubricator sized to the BHA ~Jt 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[, LINER, OR CASING] being used, except that pipe rams need ^ not be sized to BRAs and drill collars; ct.Y' cf (C) for a casin2 or liner operation with a maximum potential surface pressure of 2reater than 5.000 psi. (0 BOPE rams providin2 for pipe. slip. cuttin2. and blindin2 operations on the coiled tubin2 in service; (ii) two hi2h 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 providin2 for pressure inte2rity from the BOPE rams to the hi2h pressure pack-off. stripper. or annular type preventer; (iv) at least one preventer equipped with pipe rams that fit the size of the tubin2 bein2 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 casin2 or liner bein2 used; )$> Register _, . 200 MISCELLANEOUS ~RDS <:;-- 20 AAC 25.285(c)(9)(A) is amended to read: (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 e;reater than 3,000 psi~(REQUIRED BOP IS RATED EQUAL TO OR GREATER THAN API 5K], 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 ~20 AAC 25.285(c)(10) is amended to read: (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 e;reater than 3,000 psi fEQUIRES A BOP STACK EQUAL TO OR GREATER THAN API 5K]; I~ Register _, e 200 MISCELLANEOUS ARDS (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 [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full-opening valves for an operation with a maximum potential surface pressure of e;reater than 3.000 psi~REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K]; 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 lest[REQUlRlNG A BOP STACK LESS THAN API 5K], or at least two full-opening valves for an operation with a maximum potential surface pressure of e;reater than 3.000 ps~REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K]. ~ 20 AAC 25.285(f) is amended to read: ~ (f) The BOPE must be tested as follows: (1) when installed, repaired, or changed, and at least once a week thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which the BOPE may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; ~o Register _' . 200 MISCELLANEOUS ARDS (2) if any BOP [SEALING RAM TYPE] equipment components hav\:HAS] been used for well control or other equivalent purpose. or when routine use of the equipment may have compromised its effectiveness, the components used [IT] must be function pressure-tested before the next wellbore entry, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which that equipment may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines ftom the BOPE, except that if the workstring is continuously in the well, function-testing must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; and lareest OD tubulars that may be used durine that test cycle. except that variable bore rams need not be tested on BHAs and drill collars: ~ mflter installine casine rams in the BOP stack. the ram bonnets must be l~ tested to the required pressure before runnine casine; .Œl. BOPE test results must be recorded as part of the daily record required by 20 - AAC 25.070(1). and must be provided to the commission. in a format approved by the commission. within five days after completine the test: ffi[(5)] at least 24 hours notice of each BOPE function pressure test must be ~)o ~ LÌ> provided so that a representative of the commission can witness the test;~ 02./ Register _, . 200 MISCELLANEOUS ARDS Œl the operator shall report to the commission within 24 hours any instance --- J. ^" 10.1 ð oc.¡"¿'(.o(lirl(. of BOPE use to prevent the flow of fluids from a well. N ~t f /' ~(Eff. 4/2/86, Register 97; am 11/7/99, Register 152; am_/_/_, Register ~ Authority: AS 31.05.030 ~ 20 AAC 25.286(d)(2) is amended to read: (2) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], 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; and (B) for an operation. other than a casin~ or liner operation. with a maximum potential surface pressure of ~reater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe or[,] tubing[, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; ),:2. Register _, . 200 MISCELLANEOUS .ARDS (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; (C) for a casine or liner operation with a maximum potential surface pressure of ereater than 5,000 psi, at least four preventers, includine (i) one equipped with pipe rams that fit the size of the drill pipe or tubine beine 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 casine or liner beine 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; <:-- 20 AAC 25.286(d)(3) is amended to read: (3) in coiled tubing unit operations, (A) for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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; and ,)3 Register _, . 200 MISCELLANEOUS ARDS (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 (B) for an operation with a maximum potential surface pressure of greater than 5.000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], (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; and (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; < 20 AAC 25 .286( e) is amended to read: (e) The operator shall test the BOPE assembly as follows: (1) at least once a week, and after each [USE,] repair, [OR] change, or use for well control or other equivalent purpose. or when routine use of the equipment may have ~ compromised its effectiveness. BOP!ÉfeqUipmentrIPE AND BLIND RAMS] must be function pressure-tested, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which they may be subjected, except that the annular type preventer need not be tested to more than 50 percent of its rated working pressure; J.+ Register _, . 200 . MISCELLANEOUS BOARDS (2) after each installation of BOPE or other well control equipment, the equipment must be pressure-tested, before wellbore entry, to the maximum potential wellhead pressure to which it may be subjected, except that when testing against the annular type preventer, pressure testing need not exceed 50 percent of the rated working pressure of the annular type preventer; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing must be perfonned as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; (4) after each well installation of the BOPE, the BOPE hydraulic connections to the rams must be visually verified before wellbore entry.iif (5) for each BOPE test durin!! drillin!! and completion operations. variable bore rams must be function pressure tested to the required pressure on the smallest OD and lar!!est OD tubulars that may be used durin!! that test cycle. except that variable bore rams need not be tested on BHAs and drill collars: (6) BOPE test results must be recorded as part of the daily record required by 20 AAC 25.0700). and must be provided to the commission. in a format approved by the commission. within five days after completin!! the test; (7) at least 24 hours notice of each BOPE function pressure test must be provided so that a representative of the commission can witness the test: (8) the operator shall report to the commission within 24 hours any instance rf., ~b.,¡J qf "'nC- of BOPE use to prevent the flow of fluids from a well. .,./('" ... :25 . Register , . 200 MISCELLANEOUS ARDS ~ff. 11/7/99, Register 152; am~_/_, Register-.--J Authority: AS 31.05.030 ~(p 4t./P . . STATE OF ALASKA ) ) ss. ) THIRD JUDICIAL DISTRICT AFFIDAVIT OF NOTICE OF PROPOSED ADOPTION OF REGULATIONS AND FURNISHING OF ADDITIONAL INFORMATION I, Jody J. Colombie, Special Staff Assistant, of Alaska Oil and Gas Conservation Commission, being sworn, state the following: As required by AS 44.62.190, notice of the proposed adoption of changes to 20 AAC 25, Permit to Drill Requirements and Blowout Prevention Equipment Requirements has been given by being (I) published in a newspaper or trade publication; (2) furnished to interested persons; (3) furnished to appropriate state officials; (4) furnished to the Department of Law, along with a copy of the proposed regulations; (5) electronically transmitted to incumbent State of Alaska legislators; (6) furnished to the Legislative Affairs Agency, Legislative Library; (7) posted on the Alaska Online Public Notice System as required by AS 44.62.175(a)(1) and (b) and 44.62.l90(a)(l); (8) furnished electronically, along with a copy of the proposed regulations, to the Legislative Affairs Agency, the chair of the House and Senate Resources Committee, House Special Committee on Oil and Gas, and the Administrative Regulation Review Committee, and the legislative council. As required by AS 44.62.l90( d), additional regulations notice information regarding the proposed adoption of the regulation changes described above has been furnished to interested persons and those in (5) and (6) of the list above. The additional regulations notice information also has been posted on the Alaska Online Public Notice System. DATE: \ \, G 0 U Anchorage, Alaska ~r~~C~~N'~ Jo J. olom~ J Special Staff Assistant SUBSCRIBED AND SWORt'\[ TO before me this ~ day of \ìo'leVYìß~ ( , d-.DOIo. /-~~~ / /Notary Publ1c.-ir{and for the '.,.../ State of Alaska / My commission expires: // ) / I /6 b . , , *5 . . MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERV A TION COMMISSION TO: Regulations Attorney Legislation/Regulation Section Department of Law DA TE: October 9, 2006 FROM: a¡¡¡ ¡/~~ Cathy P ~oerster Regulations Contact Department of Administration SUBJECT: Request for Legal Review of Regulations Project on dealing with the method of determining a well's maximum potential surface pressure and blowout prevention equipment 993-07 -0029 20 AAC 25.005 - .286 Weare requesting legal review and approval of the attached final regulations on changes to the method of detennining a well's maximum potential surface pressure and blowout prevention equipment, which were adopted by Alaska Oil and Gas Conservation Commission. Enclosed are the following documents: I. the original and one copy of the final regulations for the Department of Law's use; 2. the original of the signed and dated certification order; 3. the original of the public notice; 4. the original of the additional regulations notice information form distributed with the notice; ). the original of the publishers' affidavit of publication; 6. the original of the affidavit of notice; 7. affidavit of oral hearing 8. affidavit of commission action; 9. excerpt from unapproved minutes from the September 27,2006 meeting; We have worked with Assistant Attorney General Cammy Taylor on this project. Upon completion of your review, pleas forward the regulations to the lieutenant governor for filing. Register _, .0_ MISCELLANEOU.ARDS \/ ~_ _~ i _ ~ a _ 20 AAC 25.005(c)(4)(A) is amended to read: (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a pressure gradient to surface of 0.1 psi per foot of true vertical depth, unless the commission approves a different pressure gradient that provides a more accurate means of determining the maximum potential surface pressure [METHANE GRADIENT]; (Eff. 4/13/80, Register 74; am 4/2/86, Register 97; am 11/7/99, Register 152; am 6/4/2000, Register 154; am 1/5/2006, Register 177; am _I_I _, Register~ Authority: AS 31.05.030 AS 31.05.090 20 AAC 25.035(e)(1) is amended to read: (1) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 3,000 psi or less [REQUIRING A BOP STACK LESS THAN API 5K], BOPE must have 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) or drill collars; (ii) one with blind rams, except that a subsea BOPE assembly must have blindlshear rams in place of blind rams; and (iii) one annular type; and / Register _, .0_ MISCELLANEOU.ARDS (B) for an operation, other than a casine: or liner operation, with a maximum potential surface pressure of e:reater than 3,000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K], BOPE must have at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe Q![,] tubing [, OR CASING] 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; (C) for a casine: or liner operation with a maximum potential surface pressure of e:reater than 3,000 psi, BOPE must have at least four preventers, includine: (n one equipped with pipe rams that fit the size of the drill pipe or tubine: beine: used, except that pipe rams need not be sized to BRAs and drill collars; (in one equipped with pipe rams that fit the size of casine: or liner beine: used; (iin one with blind rams, except that a subsea DOPE assembly must have blind/shear rams in place of blind rams; and (iv) one annular type; 20 AAC 25.035(e)(2) is amended to read: ¿ Register _, .0_ MISCELLANEOU.ARDS (2) in coiled tubing unit operations, the well control equipment must include (A) for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5KJ, (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, tubing, liner, or casing 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 tubing, liner, or casing being used, except that pipe rams need not be sized to BHAs and drill collars; and (B) for an operation, other than a casin2 or liner operation, with a maximum potential surface pressure of 2reater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5KJ, (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, tubing, liner, or casing is planned, a riser or lubricator sized to the BHA and providing for pressure 3 Register _, .0_ MISCELLANEOU.ARDS integrity from the BOPE rams to the high pressure pack-off, stripper, or annular type preventer; and (iv) at least two pre venters equipped with pipe rams that fit the size oftubing[, LINER, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; (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; (in two high pressure pack-offs, strippers, or annular type preventers; (iii) if pressure deplovment of tools, tubing, liner, or casing is planned, a riser or lubricator sized to the BRA 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 bein2 used, except that pipe rams need not be sized to BRAs and drill collars; and (v) at least one preventer equipped with pipe rams that fit the size of casing or liner being used. 20 AAC 25. 035(e)(4)(F) is amended to read: Lj Register _' .0_ MISCELLANEOU.ARDS (F) 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: (i) the outlets must be at least two inches in nominal diameter, except that for rotary drilling rig operations, if the operation bas a maximum potential surface pressure of g:reater than 3,000 psi [REQUIRED BOP IS RATED EQUAL TO OR GREATER THAN API 5K], the nominal diameter of the choke outlets must be at least three inches; (ii) each valve must be sized at least equal to the required size of the outlet to which it is attached; (iii) the outer valve on the choke side must be a remotely controlled hydraulic valve; (iv) the inner valve on both the choke and kill sides may not normally be used for opening or closing on flowing fluid; 20 AAC 25. 035(e)(4)(H) is amended to read: (H) a choke manifold equipped with (i) 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 2:reater than 3,000 psi [REQUIRES A BOP STACK EQUAL TO OR GREATER THAN API 5K]; (ii) a line at least two inches in nominal diameter downstream of each choke; 5" Register _, .0_ MISCELLANEOUaARDS (iii) 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 [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full-opening valves for an operation with a maximum potential surface pressure of greater than 3,000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K]; and (iv) a bypass line, at least the diameter of the choke line, with at least one full-opening valve for an operation with a maximum potential surface pressure of 3,000 psi or less [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full-opening valves for an operation with a maximum potential surface pressure of e:reater than 3,000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K]; 20 AAC 25.035(e)(10) is amended to read: (10) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non- compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; however, the commission will require that the BOPE be function pressure-tested weekly, if the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance; ~ Register _, .0 MISCELLANEOU&ARDS (B) when installed, repaired, or changed on an exploratory or stratigraphic test well and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type pre venter need not be tested to more than 50 percent of its rated working pressure; (C) if any BOP [SEALING RAM TYPE] equipment components have [HAS] been used for well control or other equivalent purpose, or when routine use of the equipment may have compromised its effectiveness, the components used [IT] must be function pressure-tested, before the next well bore entry, to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type pre venter need not be tested to more than 50 percent of its rated working pressure; (D) BOP ram and annular components except blind rams must be function-tested weekly, and all BOP ram and annular components must be function- tested after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing of blind rams must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; (E) for each BOPE test durine; drilline; and completion operations, variable bore rams must be function pressure tested to the required pressure on the smallest outside diameter (OD) and lare;est OD tubulars that may be used durine; 7 Register _, .0 MISCELLANEOUaARDS that test cycle. except that variable bore rams need not be tested on BHAs and drill collars; (F) after installing casing rams in the BOP stack. the ram bonnets must be tested to the required pressure before running casing. íQì. BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1), and must be provided to the commission. in a format approved by the commission. within five days after completing the test; an [(F)] at least 24 hours notice of each BOPE function pressure test must be provided to the commission so that a commission representative can witness the test; History: Eff. 4/13/80, Register 74; am 2/22/81, Register 77; am 4/2/86, Register 97; am 11/7/99, Register 152; am 10/24/2004, Register 172; am_/_/_, Register ~ Authority: AS 31.05.030 20 AAC 25.036(c)(l) is amended to read: (1) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], BOPE must have 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; g Register _, .0_ MISCELLANEOUaARDS (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 (B) for an operation other than a casine or liner operation, with a maximum potential surface pressure of ereater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], BOPE must have at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe Q!:[,] tubing[, OR CASING] 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; (C) for a casine or liner operation with a maximum potential surface pressure of ereater than 5,000 psi, HOPE must have at least four preventers, includine (i) one equipped with pipe rams that fit the size of the drill pipe or tubine beine used, except that pipe rams need not be sized to HHAs and drill collars; (in one equipped with pipe rams that fit the size of casine or liner beine used; (iii) one with blind rams, except that a subsea HOPE assembly must have blind/shear rams in place of blind rams; and q Register _, .0 MISCELLANEouAARDS (iv) one annular type; 20 AAC 25.036(c)(2) is amended to read: (2) in coiled tubing unit operations, the well control equipment must include (A) for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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, tubing, liner, or casing 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 pre venter; and (iv) at least one pre venter 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; and (B) for an operation, other than a casin2 or liner operation with a maximum potential surface pressure of 2reater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], (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; /0 Register , .0 MISCELLANEouAARDS (iii) if pressure deployment of tools, tubing, liner, or casing 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[, LINER, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; (C) for a casin2 or liner operation with a maximum potential surface pressure of 2reater than 5.000 psi. (n BOPE rams providine for pipe. slip. cuttine. and blindine operations on the coiled tubin2 in service; (in two hieh pressure pack-offs. strippers. or annular type preventers; (iii) if pressure deplovment of tools. tubin2. liner. or casin2 is planned. a riser or lubricator sized to the BRA and providin2 for pressure inteerity from the BOPE rams to the hieh pressure pack-off. stripper. or annular type preventer; (iv) at least one preventer equipped with pipe rams that fit the size of the tubine beine used. except that pipe rams need not be sized to BRAs and drill collars; and (v) at least one preventer equipped with pipe rams that fit the size of casine or liner bein2 used; II Register _, .0 MISCELLANEOUaARDS 20 AAC 25.036(c)(4)(H) is amended to read: (H) for conventional open loop fluid process driIling operations, a choke manifold equipped with (i) two or more adjustable chokes, one of which must be hydraulic and remotely controlled from near the driller's or operator's station if the operation has a maximum potential surface pressure of greater than 3,000 psi [REQUIRES A BOP STACK EQUAL TO OR GREATER THAN API 5K]; (ii) a line at least two inches in nominal diameter downstream of each choke; (iii) immediately upstream of each choke, at least one full-opening valve for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], or at least two full-opening valves for an operation with a maximum potential surface pressure of greater than 5,000 psi [REQUIRING A BOP STACK GREA TER THAN API 5K]; and (iv) a bypass line at least two inches in nominal diameter with at least one full-opening valve immediately upstream of each choke for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], or with at least two full- opening valves immediately upstream of each choke for an operation with a maximum potential surface pressure of greater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K]; /z Register _, .0 MISCELLANEOUaARDS 20 AAC 25.036(d) is amended to read: (d) A BOPE assembly must be tested as follows: (1) when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; however, the commission will require that the BOPE be function pressure-tested weekly, if the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance; (2) when installed, repaired, or changed on an exploratory or stratigraphic test well and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (3) other well control equipment must be pressure-tested to the maximum potential wellhead pressure after each installation of the well control equipment and before well bore entry, except that an annular type pre v enter need not be tested to more than 50 percent of its rated working pressure; (4) if any BOP [SEALING RAM TYPE] equipment components have rHAS] been used for well control or other equivalent purpose, or when routine use of the equipment may have compromised its effectiveness, the components used [IT] must be function pressure-tested, before the next well bore entry, to the required working pressure /3 Register _, .0 MISCELLANEOUaARDS specified in the approved Permit to Drill, using a non-compressible t1uid, except that an annular type pre venter need not be tested to more than 50 percent of its rated working pressure; (5) BOP ram and annular components except blind rams must be function-tested weekly, and all BOP ram and annular components must be function-tested after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing of blind rams must be performed as soon as possible after the workstring is pulled out of the well and the BRA clears the BOP; (6) for each BOPE test durin2: drillin2: and completion operations, variable bore rams must be function pressure tested to the required pressure on the smallest OD and lar2:est OD tubulars that may be used durin2: that test cycle, except that variable bore rams need not be tested on BHAs and drill collars; ill BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1), and must be provided to the commission. in a format approved by the commission, within five days after completin2: the test; ~[(7)] at least 24 hours notice of each BOPE function pressure test must be provided to the commission so that a representative of the commission can witness the test. History: Eff. 11/7/99, Register 152; am 10/24/2004, Register 172; am~_/_, Register -----.J Authority: AS 31.05.030 20 AAC 25 .280(b) is amended to add a new paragraph: (b) The Application for Sundry Approvals must set out 14 Register _, . MISCELLANEOUSeARDS (1) the current condition of the well; (2) a copy of the proposed program for well work; (3) unless already on file with the commission, a diagram and description of the well control equipment to be used, including if applicable a list of the blowout prevention equipment (BOPE) with specifications; (4) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a pressure 2:radient to surface of 0.1 psi per foot of true vertical depth unless the commission approves a different pressure 2:radient that provides a more accurate means of determinin2: the maximum potential surface pressure, such as usin2: a stabilized shut-in tubin2: pressure. æ a description of any wellbore fluid to be used for primary well control; and œ [(5)] the current bottom-hole pressure, or, if data setting out the actual pressure are not available, an estimate of the current bottom-hole pressure. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152; am_/_/_, Register_) Authority: AS 31.05.030 20 AAC 25.285(c)(2) is amended to read: (2) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 3,000 psi or less [REQUIRING A BOP STACK LESS THAT API 5K], at least three preventers, including JS Register _, .0 MISCELLANEOU.ARDS (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; and (B) for an operation, other than a casin2 or liner operation, with a maximum potential surface pressure of 2reater than 3,000 psi [REQUIRING A BOP ST ACK EQUAL TO OR GREATER THAN API 5K], at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe Q!:[,] tubing[, OR CASING] being used, except that pipe rams need not be sized to BRAs 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; (C) for a casin2 or liner operation, with a maximum potential surface pressure of 2reater than 3,000 psi, at least four preventers, includin2 (i) one equipped with pipe rams that fit the size of the drill pipe or tubin2 bein2 used, except that pipe rams need not be sized to BHAs and drill collars; (in one equipped with pipe rams that fit the size of casin2 or liner bein2 used; /0 Register _, .0_ MISCELLANEOU.ARDS (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; 20 AAC 25.285(c)(3) is amended to read: (3) in coiled tubing unit operations, (A) for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5KJ, (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; and (B) for an operation, other than a casin2 or liner operation, with a maximum potential surface pressure of 2reater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], (i) BOPE rams providing for pipe, slip, cutting, and blinding operations on the coiled tubing in service; r7 I I Register _, .0 MISCELLANEouAARDS (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[, LINER, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; (C) for a casing or liner operation with a maximum potential surface pressure of greater than 5,000 psi, (i) HOPE rams providing for pipe, slip, cutting, and blinding operations on the coiled tubing in service; (in two high pressure pack-offs, strippers, or annular type preventers; (iin if pressure deployment of tools is planned, a riser or lubricator sized to the HHA and providing for pressure integrity from the HOPE 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 HHAs and drill collars; and (v) at least one preventer equipped with pipe rams that fit the size of casing or liner being used; iX lu Register _, .0_ MISCELLANEOU.ARDS 20 AAC 25.285(c)(9)(A) is amended to read: (9) a kill line and a choke line each connected to a flanged or hub bed 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 e;reater than 3.000 psi [REQUIRED BOP IS RATED EQUAL TO OR GREATER THAN API 5K], 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 20 AAC 25.285(c)(lO) is amended to read: (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 e;reater than 3.000 psi [REQUIRES A BOP STACK EQUAL TO OR GREATER THAN API 5K]; /'1' (.; Register _, .0_ MISCELLANEOUaARDS (B) a line at least two inches in nominal diameter downstream of each choke; (C) immediately upstream of each choke, at least one tùll-opening valve for an operation with a maximum potential surface pressure of 3,000 psi or less [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full-opening valves for an operation with a maximum potential surface pressure of 2reater than 3,000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K]; and CD) 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 [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full-opening valves for an operation with a maximum potential surface pressure of 2reater than 3,000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K]. 20 AAC 25.285(f) is amended to read: Cf) The BOPE must be tested as follows: (1) when installed, repaired, or changed, and at least once a week thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested, using a non-compressible fluid, to the required working pressure specitìed in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which the BOPE may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure: ~o Register _, .0_ MISCELLANEOU&ARDS (2) if any BOP [SEALING RAM TYPE] equipment components have rHAS] been used for well control or other equivalent purpose, or when routine use of the equipment may have compromised its effectiveness, the components used [IT] must be function pressure-tested before the next wellbore entry, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which that equipment may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; (4) for each BOPE test durine drilIine and completion operations, variable bore rams must be function pressure tested to the required pressure on the smallest OD and lareest 00 tubulars that may be used durine that test cvcle. except that variable bore rams need not be tested on BHAs and drill collars; @l After instaIIine casine rams in the BOP stack. the ram bonnets must be tested to the required pressure before runnine casine. í.2l. BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1), and must be provided to the commission, in a format approved by the commission, within five days after completine the test; ill [(5)] at least 24 hours notice of each BOPE function pressure test must be provided so that a representative of the commission can witness the test;[.] ~ / (;I-- Register _, .0 MISCELLANEOU.ARDS Œl. the operator shall report to the commission within 24 hours any instance of BOPE use to prevent the flow of fluids from a well. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152; am_/_/_, Register _) Authority: AS 31.05.030 20 AAC 25.286(d)(2) is amended to read: (2) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], 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; and (B) for an operation, other than a casing or liner operation, with a maximum potential surface pressure of greater than 5,000 psi [REQUIRING A BOP ST ACK GREATER THAN API 5K], at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe or[,] tubing[, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars: aJ Register _, .0_ MISCELLANEOU.ARDS (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; (C) for a casing or liner operation with a maximum potential surface pressure of greater than 5,000 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; (in 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; 20 AAC 25.286(d)(3) is amended to read: (3) in coiled tubing unit operations, (A) for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5KJ, (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; and ,a3 Register ~, .0_ MISCELLANEOUaARDS (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 (B) for an operation with a maximum potential surface pressure of greater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], (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; and (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; 20 AAC 25.286(e) is amended to read: (e) The operator shall test the BOPE assembly as follows: (1) at least once a week, and after each [USE,] repair, [OR] change, or use for well control or other equivalent purpose, or when routine use of the equipment may have compromised its effectiveness, BOP[E] equipment [PIPE AND BLIND RAMS] must be function pressure-tested, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which they may be subjected, except that the annular type preventer need not be tested to more than 50 percent of its rated working pressure; dL/ Register _, .0_ MISCELLANEOU.ARDS (2) after each installation of BOPE or other well control equipment, the equipment must be pressure-tested, before well bore entry, to the maximum potential wellhead pressure to which it may be subjected, except that when testing against the annular type preventer, pressure testing need not exceed 50 percent of the rated working pressure of the annular type preventer; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; (4) after each well installation of the BOPE, the BOPE hydraulic connections to the rams must be visually verified before wellbore entrYi[.] (5) for each BOPE test durin~ drillin~ and completion operations, variable bore rams must be function pressure tested to the required pressure on the smallest OD and lar~est OD tubulars that may be used durin~ that test cycle, except that variable bore rams need not be tested on BHAs and drill collars; (6) BOPE test results must be recorded as part of the daily record required bv 20 AAC 25.0700), and must be provided to the commission, in a format approved by the commission, within five days after completin~ the test; (7) at least 24 hours notice of each BOPE function pressure test must be provided so that a representative of the commission can witness the test; (8) the operator shall report to the commission within 24 hours any instance of BOPE use to prevent the flow of fluids from a well. (J5 Register _, .0_ MISCELLANEOU.ARDS History: Eft. 11/7/99, Register 152; am_/_/_, Register----> Authority: AS 31.05.030 tjG Register _, .0_ l'vIISCELLANEOLJWARDS 20 AAC 25.005(c)(4)(A) is amended to read: (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a pressure eradient to surface of 0.1 psi per foot of true vertical depth, unless the commission approves a different pressure eradient that provides a more accurate means of determinin!! the maximum potential surface pressure [METHANE GRADIENT]; (Eff. 4/lJi80, Register 74; am 4/2/86, Register 97; am 11/7/99, Register 152; am 6/4/2000, Register 154; am 115/2006, Register 177; am _ _/_, Register~ Authority: AS 31.05.030 AS 31.05.090 20 AAC 25.035(e)(l) is amended to read: (1) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 3,000 psi or less [REQUIRING A BOP STACK LESS THAN API 5K], BOPE must have at least three preventers, including (i) one equipped with pipe rams that tìt the size of drill pipe, tubing, liner or casing being used, except that pipe rams need not be sized to bottom-hole assemblies (BHAs) or drill collars: (Íi) 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 / Register _, .0_ MISCELLANEOU.ARDS (B) for an operation, other than a casin2 or liner operation, with a maximum potential surface pressure of 2reater than 3,000 psi [REQUIRING A BOP STACK EQUAL TO OR GREA TER THAN API 5K]. BOPE must have at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe !U:[,J tubing [, OR CASING] 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; (C) for a casin2 or liner operation with a maximum potential surface pressure of 2reater than 3,000 psi, BOPE must have at least four preventers, incIudin2 (i) one equipped with pipe rams that fit the size of the drill pipe or tubin2 bein2 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 casin2 or liner bein2 used; (iin one with blind rams, except that a subsea BOPE assemblv must have blind/shear rams in place of blind rams; and (iv) one annular type; 20 AAC 25.035(e)(2) is amended to read: ¿ Register , ~ - .0_ rvIISCE LLANEO U.ARDS (2) in coiled tubing unit operations, the "veIl control equipment must include (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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; (iíi) if pressure deployment of tools, tubing, liner, or casing 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 tubing, liner, or casing being used, except that pipe rams need not be sized to BHAs and drill collars; and (B) for an operation. other than a casin2 or liner operation. with a maximum potential surface pressure of 2reater than 5.000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], (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. tubing, liner, or casing is planned, a riser or lubricator sized to the BHA and providing for pressure 3 Register _, .0_ MISCELLANEOU.ARDS 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 oftubing[, LINER, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; (C) for a casin!?; or liner operation with a maximum potential surface pressure of !?;reater than 5,000 psi, (i) HOPE rams providin!?; for pipe, slip, cuttin!?;, and blindin!?; operations on the coiled tubin!?; in service; (in two hi!?;h pressure pack-offs, strippers, or annular type preventers; Wi) if pressure deplovment of tools, tubing, liner, or casing is planned, a riser or lubricator sized to the HHA and providing for pressure integrity from the HOPE rams to the hi!?;h pressure pack-off, stripper, or annular type preventer; (iv) at least one preventer equipped with pipe rams that fit the size of the tubing bein!?; used, except that pipe rams need not be sized to HHAs and drill collars; and (v) at least one preventer equipped with pipe rams that fit the size of casing or liner being used. 20 AAC 25. 035(e)(4)(F) is amended to read: Lj Register ~, .0_ .'vffSCELLANEOU.ARDS (F) a kill line and a choke line each connected to a flanged or hub bed outlet on a drilling spool or on the BOP body with two full-opening valves on each outlet conforming to the fo!!mving specifications: (i) 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 e;reater than 3,000 psi [REQUIRED BOP IS RA. TED EQUAL TO OR GREATER THAN API 5K], the nominal diameter of the choke outlets must be at least three inches; (ii) each valve must be sized at least equal to the required size of the outlet to which it is attached: (iii) the outer valve on the choke side must be a remotely controlled hydraulic valve; (iv) the inner valve on both the choke and kill sides may not normally be used for opening or closing on flowing fluid; 20 AAC 25. 03 5( e )(4 )(H) is amended to read: (H) a choke manitàld equipped with (i) 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 e;reater than 3,000 psi [REQUIRES A BOP STACK EQUAL TO OR GREATER THAN API 5K]; (ii) a line at least two inches in nominal diameter downstream of each choke: .5' Register ~, .0_ \;fISCELLANEOUeARDS (iii) 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 [REQUIRING A BOP STACK LESS THAN API 5K], or at least t\VO full-opening valves for an operation with a maximum potential surface pressure of 2reater than 3,000 psi [REQUIRNG A BOP STACK EQUAL TO OR GREATER THAN API 5K]; and (i v) a bypass line, at least the diameter of the choke line, \vith at least one full-opening valve for an operation with a maximum potential surface pressure of 3,000 psi or less [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full-opening valves for an operation with a maximum potential surface pressure of 2reater than 3,000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K]: 20 AAC 25.035(e)(1O) is amended to read: (10) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non- compressible tluid, except that an annular type preventer need not be tested to more than 50 percent of its rated \vorking pressure; however, the commission will require that the BOPE be function pressure-tested weekly, if the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance; Co Register _, .0_ MISCELLANEOU.ARDS (B) when installed, repaired, or changed on an exploratory or stratigraphic test well and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (C) if any BOP [SEALING RAM TYPE] equipment components have [HAS) been used for well control or other equivalent purpose, or when routine use of the equipment mav have compromised its effectiveness, the components used [IT] must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using a non-compressible Duid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (D) BOP ram and annular components except blind rams must be function-tested weekly, and all BOP ram and annular components must be tùnction- tested after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing of blind rams must be performed as soon as possible after the 'vvorkstring is pulled out of the well and the BHA clears the BOP; (E) for each BOPE test during drilling and completion operations, variable bore rams must be function pressure tested to the required pressure on the smallest outside diameter (OD) and largest OD tubulars that may be used during ~ Register _, .- MISCELLANEOUeARDS that test cycle, except that variable bore rams need not be tested on BHAs and drill collars; (F) after installin2 casin2 rams in the BOP stack, the ram bonnets must be tested to the required pressure before runnin2 casin2. llil. BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1), and must be provided to the commission, in a format approved bv the commission, within five days after completin2 the test; an [(F)] at least 24 hours notice of each BOPE function pressure test must be provided to the commission so that a commission representative can witness the test; History: Eff. 4/13/80, Register 74: am 2/22/81, Register 77; am 4/2/86, Register 97: am 117/99, Register 152; am 10/24/2004, Register 172; am _/_ _, Register ~ Authority: AS 31.05.030 20 AAC 25.036(c)(1) is amended to read: (1) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], BOPE must have 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: ."'ì ¡ ¡ X (j Register~, _~_ MISC ELLANEO UeARDS (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 (B) for an operation other than a casing or liner operation, with a maximum potential surface pressure of I!reater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], BOPE must have at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe Q![,] tubing[, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; (ii) one \vith blind rams, except that a subsea BOPE assembly must have blind/shear rams in place of blind rams; and (iii) one annular type; (C) for a casing or liner operation with a maximum potential surface pressure of I!reater than 5,000 psi, BOPE must have at least four preventers, including (i) one equipped with pipe rams that fit the size of the drill pipe or tubinl! being used, except that pipe rams need not be sized to BHAs and drill collars; (in 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 assemblv must have blind/shear rams in place of blind rams; and q Register _, .0_ MISCELLA.\JEOU.ARDS (iv) one annular type; 20 AAC 25.036(c)(2) is amended to read: (2) in coiled tubing unit operations, the well control equipment must include (A) for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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, tubing, liner, or casing is planned, a riser or lubricator sized to the BHA and providing tàr 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; and (B) for an operation, other than a casine or liner operation with a maximum potential surface pressure of ereater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], (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; /0 Register _, . MISCELLANEOUS.ARDS (iii) if pressure deployment of tools, tubing, liner, or casing 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 pre venters equipped with pipe rams that tIt the size of the tubing(, LINER, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; (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 deplovment of tools, tubing, liner, or casing is planned, a riser or lubricator sized to the BHA and providing for pressure integrity from the ROPE 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; II Register _, .0 MISCELLANEOU.ARDS 20 AAC 25.036(c)(4)(H) is amended to read: (H) for conventional open loop fluid process drilling operations, a choke manifold equipped with (i) two or more adjustable chokes, one of which must be hydraulic and remotely controlled from near the driller's or operator's station if the operation has a maximum potential surface pressure of greater than 3,000 psi [REQUIRES A BOP STACK EQUAL TO OR GREATER THAN API 5K]; (ii) a line at least two inches in nominal diameter downstream of each choke: (iii) immediately upstream of each choke, at least one full-opening val ve for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], or at least two full-opening valves for an operation with a maximum potential surface pressure of greater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K]; and (iv) a bypass line at least two inches in nominal diameter with at least one full-opening valve immediately upstream of each choke for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIR[\iG A BOP STACK EQUAL TO OR LESS THAN API 5K], or with at least two full- opening valves immediately upstream of each choke for an operation with a maximum potential surface pressure of greater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K]: /z Register_. .- MISCELLANEOU.ARDS 20 AAC 25.036(d) is amended to read: (d) A BOPE assembly must be tested as follows: (1) when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to DrilL using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; however, the commission will require that the BOPE be function pressure-tested weekly, if the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance; (2) when installed, repaired, or changed on an exploratory or stratigraphic test well and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated \-vorking pressure; (3) other well control equipment must be pressure-tested to the maximum potential wellhead pressure after each installation of the well control equipment and before wellbore entry, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (4) if!!!y BOP [SEALING RA.~l TYPE] equipment components have fHAS] been used for well control or other equivalent purpose, or when routine use of the equipment may have compromised its effectiveness, the components used [IT] must be function pressure-tested, before the next \vellbore entry, to the required working pressure j/ ,J Register _. . MISCELLANEOUS eA.RDS specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated vvorking pressure; (5) BOP ram and annular components except blind rams must be function-tested weekly, and all BOP ram and annular components must be function-tested after an action that disconnects the hydraulic system lines trom the BOPE, except that if the workstring is continuously in the well, function-testing of blind rams must be performed as soon as possible after the workstring is pulled out of the well and the BRA clears the BOP; (6) for each BOrE test durin!! drillin!! and completion operations, variable bore rams must be function pressure tested to the required pressure on the smallest OD and lar!!est OD tubulars that mav be used durin!! that test cvcle, except that variable bore rams need not be tested on BHAs and drill collars; ill BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1), and must be provided to the commission, in a format approved bv the commission, within five days after completin!! the test; .@.L[(7)] at least 24 hours notice of each BOPE function pressure test must be provided to the commission so that a representative of the commission can witness the test. History: Eff. 11/7/99, Register 152; am 10/24/2004, Register 172: am_/ _ _, Register Authority: AS 31.05.030 20 AAC 25.280(b) is amended to add a ne"v paragraph: (b) The Application for Sundry Approvals must set out 14 Register _, . rvfISCELLANEOUS.ARDS (l) the current condition of the we!!; (2) a copy of the proposed program for we!! work; (3) unless already on file with the commission, a diagram and description of the well control equipment to be used, including if applicable a list of the blowout prevention equipment (BOPE) with specifications; (4) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a pressure eradient to surface of 0.1 psi per foot oftrue vertical depth unless the commission approves a different pressure eradient that provides a more accurate means of determinine the maximum potential surface pressure, such as usine a stabilized shut-in tubine pressure. ill a description of any we!!bore fluid to be used for primary well control; and @ [(5)] the current bottom-hole pressure, or, if data setting out the actual pressure are not available, an estimate of the current bottom-hole pressure. History: Eff. 4/2/86, Register 97; am 1117/99, Register 152: am_/_/_, Register_) Authority: AS 31.05.030 20 AAC 25.285(c)(2) is amended to read: (2) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 3,000 psi or less [REQUIRING A BOP STACK LESS THAT API 5K], at least three preventers, including IC¡ J...J Register _, . l\ifISCELLANEOUS .A.RDS (i) one equipped \vith 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; and (B) for an operation, other than a casin2: or liner operation, with a maximum potential surface pressure of 2:reater than 3,000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K], at least four preventers, including (i) t\VO equipped with pipe rams that fit the size of the drill pipe or[,] tubing[, OR CASING] 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; (C) for a casin2: or liner operation, with a maximum potential surface pressure of 2:reater than 3,000 psi, at least four preventers, includinf! (i) one equipped with pipe rams that fit the size of the drill pipe or tubinf! beinf! used, except that pipe rams need not be sized to BHAs and drill collars; (in one equipped with pipe rams that fit the size of casinf! or liner beinf! used; Jlo I Register _, . MISCELLANEOU.ARDS (iii) one with blind rams, except that a subsea BOrE assemblv must have blind/shear rams in place of blind rams; and (iv) one annular tvpe; 20 AAC 25.285(c)(3) is amended to read: (3) in coiled tubing unit operations, (A) for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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 pre venter; (Ìii) 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; and (B) for an operation, other than a casine or liner operation, with a maximum potential surface pressure of ereater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], (Ì) BOPE rams providing for pipe, slip, cutting, and blinding operations on the coiled tubing in service: ;/1 ¡ . f I , ! Register _, . MISCELLANEOUSeARDS (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-otl, stripper, or annular type preventer; and (iv) at least two preventers 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; (C) for a casin2 or liner operation with a maximum potential surface pressure of 2reater than 5,000 psi, (i) HOPE rams providin2 for pipe, slip, cuttin2, and blindin2 operations on the coiled tubin2 in service; (in two hi2h pressure pack-offs, strippers, or annular type preventers; (iii) if pressure deployment of tools is planned, a riser or lubricator sized to the HHA and providin2 for pressure inte2rity from the HOPE rams to the hi2h pressure pack-off, stripper, or annular type preventer; (iv) at least one preventer equipped with pipe rams that fit the size of the tubin2 bein2 used, except that pipe rams need not be sized to HHAs and drill collars; and (v) at least one preventer equipped with pipe rams that fit the size of casin2 or liner bein2 used; ,,/ J' \.". 1\ ,{j Register .- MISCELLANEOUS .RDS 20 AAC 25.285(c)(9)(A) is amended to read: (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 ereater than 3,000 psi [REQUIRED BOP IS RATED EQUAL TO OR GREA TER THAN API 5 K], 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 20 AAC 25 .285( c)(1 0) is amended to read: (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 ereater than 3,000 psi [REQUIRES A BOP STACK EQUAL TO OR GREATER THAN API 5K]; ; /"\ /~! Register _, . MISCELLANEOUSeARDS (B) a line at least two inches in nominal diameter dO\vnstream of each choke: (C) immediately upstream of each choke, at least one fu[[-opening valve for an operation with a maximum potential surface pressure of 3,000 psi or less [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full-opening valves for an operation with a maximum potential surface pressure of 2:reater than 3,000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K]; and (D) a bypass line, at least tvvo 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 [REQUIRING A BOP STACK LESS THAN API 5K], or at least tvvo full-opening valves for an operation with a maximum potential surface pressure of 2:reater than 3,000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K]. 20 AAC 25.285(f) is amended to read: (D The BOPE must be tested as follows: (I) when installed, repaired, or changed, and at least once a week thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which the BOPE may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated vvorking pressure: ~{7 Register _, . MISCELLANEOUS.ARDS (2) if any BOP [SEALING R.AM TYPE] equipment components have rHAS] been used for well control or other equivalent purpose, or when routine use of the equipment may have compromised its effectiveness, the components used [IT] must be function pressure-tested before the next wellbore entry, using a non-compressible tluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surtàce pressure to which that equipment may be subjected. except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the \vorkstring is continuously in the well, function-testing must be performed as soon as possible after the \vorkstring is pulled out of the well and the BHA clears the BOP; (4) for each BOPE test durine drilline and completion operations, variable bore rams must be function pressure tested to the required pressure on the smallest OD and lareest OD tubulars that may be used durine that test cycle, except that variable bore rams need not be tested on BHAs and drill collars; (5) After installine casine rams in the BOP stack, the ram bonnets must be tested to the required pressure before runnine casine. ill.. BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1), and must be provided to the commission, in a format approved by the commission, within five days after completine the test; ill.. [(5)] at least 24 hours notice of each BOPE function pressure test must be provided so that a representative of the commission can witness the test:[.] /"', I ¡ í ..~ Register . :vrISCELLANEO US.ARDS ŒL the operator shall report to the commission within 24 hours anv instance of HOPE use to prevent the flow of fluids from a well. History: Eff. 4/2/86, Register 97; am II T99, Register 152; am_ _ _' Register _) Authority: AS 31.05.030 20 AAC 25.286(d)(2) is amended to read: (2) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], 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 \vith blind rams, except that a subsea BOPE assembly must have blind/shear rams in place of blind rams; and (iii) one annular type; and (B) for an operation, other than a casill1! or liner operation, with a maximum potential surface pressure of greater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe or[,J tubing[, OR CASING J being used, except that pipe rams need not be sized to BHAs and drill collars; 1) :/)~ Register . MISCELLANEOUS.ARDS (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; (C) for a casin2 or liner operation with a maximum potential surface pressure of 2reater than 5,000 psi, at least four preventers, includin2 (i) one equipped with pipe rams that fit the size of the drill pipe or tubin2 bein2 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 casin2 or liner bein2 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; 20 AAC 25 .286( d)(3) is amended to read: (3) in coiled tubing unit operations, (A) for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (i) BOPE rams pro\'iding for pipe, slip, cutting, and blinding operations on the coiled tubing in service: (ii) a high pressure pack-off stripper, or annular type preventer: and --., 'Î / I) .~ .--..1 Register . c.. _ . MfSCELLANEOU.ARDS (Ìii) 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 (B) for an operation with a maximum potential surface pressure of 2;reater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5KJ, (i) BOPE rams providing for pipe, slip, cutting, and blinding operations on the coiled tubing in service; (ii) tvvo high pressure pack-offs, strippers, or annular type preventers; and (Ìii) 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 pre venter: 20 AAC 25.286(e) is amended to read: (e) The operator shall test the BOPE assembly as follows: (1) at least once a \veek, and after each [USE,] repair, [OR] change, or use for well control or other equivalent purpose, or when routine use of the equipment may have compromised its effectiveness, BOP[E] equipment [PIPE AND BLIND RAMS] must be function pressure-tested, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surtàce pressure to \vhich they may be subjected. except that the annular type preventer need not be tested to more than 50 percent of its rated \\larking pressure; è~~ Reaister to __. . ~nSCELLA;\[EOUS .RDS (2) after each installation of BOPE or other well control equipment the equipment must be pressure-tested, before weIIbore entry, to the maximum potential weIIhead pressure to which it may be subjected, except that when testing against the annular type pre venter, pressure testing need not exceed 50 percent of the rated working pressure of the annular type preventer; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the \vell, function-testing must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP: (4) after each \vell installation of the BOPE, the BOPE hydraulic connections to the rams must be visually veritìed before weIIbore entry.;lJ (5) for each BOPE test during drillinl! and completion operations, variable bore rams must be function pressure tested to the required pressure on the smallest OD and larl!est OD tubulars that mav be used during that test cycle, except that variable bore rams need not be tested on BHAs and drill collars; (6) BOPE test results must be recorded as part of the dailv record required by 20 AAC 25.070(1), and must be provided to the commission, in a format approved bv the commission, within five davs after completing the test; (7) at least 24 hours notice of each BOPE function pressure test must be provided so that a representative of the commission can witness the test; (8) the operator shall report to the commission within 24 hours anv instance of BOPE use to prevent the flow of fluids from a well. /ì-- cr) ~ Register _, . MISCELLANEOUS e'\RDS History: Eff. ] [17/99, Register 152; am_ _ _, Register ~ Authority: AS 3] .05.030 /\ lo I r eX . . . ORDER CERTIFYING THE CHANGES TO REGULATIONS OF ALASKA OIL AND GAS CONSERVATION COMMISSION The attached 26 pages of regulations, dealing with Permit to Drill requirements and blowout prevention equipment under 20 AAC 25 are hereby certified to be a correct copy of the regulation changes that the Alaska Oil and Gas Conservation Commission adopted at its September 27, 2006 meeting, under the authority of AS 31.05.030 and 31.05.040 and after compliance with the Administrative Procedure Act (AS 44.62), specifically including notice under AS 44.62.190 and 44.62.200 and opportunity for public comment under AS 44.62.210. This action is not expected to require an increased appropriation. On the record, in considering public comments, the Alaska Oil and Gas Conservation Commission paid special attention to the cost to private persons of the regulatory action being taken. The regulation changes described in this order take effect on the 30th day after they have been filed by the lieutenant governor, as provided in AS 44.62.180. DATE: October 9,2006 Anchorage t~f~ C y P. Foerster Commissioner FILING CERTIFICATION I, Loren Leman, Lieutenant Governor for the State of Alaska, certify that on ,2006 at provisions of AS 44.62.040 - 44.62.120. .m., I filed the attached regulations according to the Lieutenant Governor Effective: Register: . . STATE OF ALASKA NOTICE OF PROPOSED CHANGES IN THE REGULATIONS OF THE ALASKA OIL AND GAS CONSERVATION COMMISSION The Alaska Oil and Gas Conservation Commission ("AOGCC") proposes to adopt regulation changes in Title 20, Chapter 25, of the Alaska Administrative Code, dealing with Penn it to Drill requirements and blowout prevention equipment requirements including the following: The method of determining a well's maximum potential surface pressure is precisely specified in 20 AAC 25.005(c)(4)(A); and Blowout prevention equipment requirements are clarified in 20 AAC 25.035(e)(I), 20 AAC 25.035(e)(2), 20 AAC 25.035(e)(I0), 20 AAC 25.036(c)(I), 20 AAC 25.036(c)(2), 20 AAC 25.036(d), 20 AAC 25.285(c)(2), 20 AAC 25.285(c)(3), 20 AAC 25.285(t), 20 AAC 25.286(d)(I), 20 AAC 25.286(d)(3), 20 AAC 25.286(e) You may comment on the proposed regulation changes, including the potential costs to private persons of complying with the proposed changes, by writing to AOGCC, 333 W. th Avenue, Suite 100, Anchorage, AK 99501. The comments must be received no later than 4:30 p.m. on September 8, 2006. Oral or written comments may be submitted at a hearing to be held on August 31,2006 at 333 W. th A venue, Suite 100, Anchorage, AK 99501. The hearing will begin at 9:00 a.m. and might be extended to accommodate those present before 9:30 a.m. who did not have an opportunity to comment. If you are a person with a disability who may need a special accommodation in order to participate in the process, please contact Jody Colombie at 793-1221 by 4:00 p.m., August 18, 2006 to ensure that any necessary accommodations can be provided. For a copy of the proposed regulation changes, contact Jody Colombie at AOGCC, 333 W. th A venue, Suite 100, Anchorage, Alaska 99501, or by telephoning the AOGCC at 907-793-1221, or on the AOGCC website at: http://www .aogcc.alaska. gov. After the public comment period ends, the AOGCC will either adopt this or another proposal dealing with the same subject, without further notice, or decide to take no action on it. The language of the final regulations may be different from that of the proposed regulations. YOU SHOULD COMMENT DURING THE TIME ALLOWED IF YOUR INTEREST COULD BE AFFECTED. Written comments received are public records and are subject to public inspection. S 3 1.05.030. pected to require an increased Statutory Authority: AS 31.05.030. Statutes Being Implemented, Interpreted, or Fiscal Information: The proposed regulati appropriation. Date: July 26, 2006 Published: July 28. 2006 AO-02714001 . . ADDITIONAL REGULA TrONS NOTICE INFORMATION (AS 44.62. 1 90(d)) 1. Adopting agency: Alaska Oil and Gas Conservation Commission. 2. General subject of regulations: Permit to Drill requirements and blowout prevention equipment requirements. 3. Citation of regulations: 20 AAC 25.005(c)(4)(A), 20 AAC 25.035(e)(1), 20 AAC 25.035(e)(2), 20 AAC 25.035(e)(10), 20 AAC 25.036(c)(1), 20 AAC 25.036(c)(2), 20 AAC 25.036(d), 20 AAC 25.285(c)(2), 20 AAC 25.285(c)(3), 20 AAC 25.285(t), 20 AAC 25.286(d)(1), 20 AAC 25.286(d)(3), 20 AAC 25.286(e) 4. Reason for the proposed action: clarification of the subject regulatory requirements. 5. Program category and BRU affected: Alaska Oil and Gas Conservation Commission. 6. Cost of implementation to the state agency: zero. 7. The name of the contact person for the regulations John K. Norman, Alaska Oil and Gas Conservation Commission, 333 W. th Avenue, Suite 100, Anchorage, AK 99501, (907) 279-1433. 8. 9. Date: 10. Prepared by: 4tnchOrage Daily News Affidavit of Publication . lOO! Northway Drive. Anchorage. AK 99508 PRICE OTHER OTHER OTHER OTHER OTHER GRAND AD# DATE PO ACCOUNT PER DAY CHARGES CHARGES #2 CHARGES #3 CHARGES #4 CHARGES #5 TOTAL 889675 07/28/2006 002714001 STOF0330 5270.18 $270.18 $0.00 $0.00 $0.00 $0.00 $0.00 $270.18 STATE OF ALASKA THIRD JUDICIAL DISTRICT Christine Clark, being first duly sworn on oath deposes and says that she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individua~¡ /~.. / .//'i~ /7' 5i~~v!dl/fYJL(I:'~' , // \,..._y_/ci''- Subscribep and sworn to me before this date: '-'1 II ì' ~'" f". ' d ¡¡'~ "I. J..uO!¡; '/ Nota~y Public in and for the State of Alaska, Third Division. Anchorage, Alaska ¡'~~ t (l (({ (f If I: YA.þ.....l"r: , ..... .v~~'l " --;;p .,,~~ N O,.ARþ·.t. ~ /" . ~ ..... /.;.... "" -'~ ..-" ~- , ... -... '- ' ,1:tI" "C . ~ := : ru8\.\ ",,' $....., ~:i·.úI ....~ ~:<fl.::::: - ~:A. .r¡¡,;,"F.!V~ ~. ;-'!~Œ 1\"':" ,:,,,,' ~ .'. . :..b,-'" ;;;.... .... .~'1' ;,.''''./' @;~. '1\\ . J}).nm\ì STATE OF ALASKA NOTICE OF PROPOSED CHANGES IN THE REGULATIONS OF THE ALASKA OIL AND GAS CONSERVATION COMMISSION The Alaska Oil and Gas Conservation Cammission ("AOGCC") proposes. to adopt regulation changes in Title 20, Chapter 25, of the Alaska Administrative Cade, dealing with Permit to Drill requir~ments and blowout prevention equipment requirement s including the follo\/,!lng: The method of determining a well's maximum potential surface pressure is preciselY specified in 20 AAC 25.005(c)(4)(A); and Blowout prevention equipment requirements are clarified In 20 AAC 25.035(e)(1), 20 AAC 25.035(e)(2h 20 AAC 25.035(e)(10), 20 AAC 25.036(c)(1), 20 AÄC 25.036(c)(2), 20 AAC 25.036(dh 20 AAC 25.285(c)(2), 20 AAC 25.285(c)(3), 20 AAC 25.285(f), 20 AAC 25.286(d)(l), 20 AAC 25.286(d)(3), 20 AAC 25.286(e) You may comment on the praþosedregulatiOO changes, including the )()t~tntial costs to private persons of complying with the proposed changes, bY writIng to AOGCC, 333 W. 7th Avenue, Suite 100, Anchorage, AK 99501. The comments must be received no later than 4:30 p.m. on September 8, 2006. Oral or written comments may be submitted at 0 hearing to be held on Augu!'t 31. 2006 at 333 W. 7th Avenue, Suite 100, Anchorage, AK 99501. The hearing "'1111 begin at 9:00 a.m. and might be extended to accommodate those present be- fore 9:30 a.m. who did not hove an opportunity to comment. If yau ore a person with 0 disability who may need a special ac~ommodation in order to participate In the process, please contact Jody ColombIe at 793-1221 bY 4:00p.m., August 18,2006 to ensure that any necessary accommodatIOns con be provided. For a copy of the prap()sed regulation changes, contact Jody Colombie at AOGCC, 333W. 7th Avenue, Suite 100, Anchorage, Ala.ska 99501. or bY telephon- ing the AOGCC at 907-793-1221. or on the AOGCC webslte at: http://www;aa9cc.a laska. gav. After the public comment period ends, the AOGCC will either adapt this or ,!n- other proposal dealing with thesamesubiect, without further notice, or decide to take no action on it. The language of the final regulations may be different from thot of the proposed regulations.. YOU SHOULD COMMENT DURING. THE TIME ALLOWED IF YOUR INTEREST COULD. BE AFFECTED. Writ- ten comments received ore public records and are sublect to public inspectIOn. Statutory Authority: AS 31.05.030; AS 31.05.040. . . Statutes Being Implemented, Interpreted, or Made SpecIfIc: AS 31.05.030. Fiscal Information: The proposed regulation changes are not expected to require an increased appropriation. Dote: July 26, 2006 Isf: John K. Norman, Chairman Alaska Oil and Gas Conservation Commission AO# 02714001 Published: JulY 28, 2006 . . SI A IE OF ALASKA. ) ) ss. ) THIRD JUDICIAL DISTRICT AFFIDA VIr OF NOTICE OF PROPOSED ADOPTION OF REGULATIONS AND FURNISHING OF ADDITIONAL INFORMATION I, Jody J. Colombie, Special Staff Assistant, of Alaska Oil and Gas Conservation Commission, being sworn, state the following: As required by AS 44.62.190, notice of the proposed adoption of changes to 20 AAC 25, Permit to Drill Requirements and Blowout Prevention Equipment Requirements has been given by being (I) published in a newspaper or trade publication; (2) furnished to interested persons [as shown on the attached list]; (3) furnished to appropriate state officials; (4) furnished to the Department of Law, along with a copy of the proposed regulations; (5) electronically transmitted to incumbent State of Alaska legislators; (6) furnished to the Legislative Affairs Agency, Legislative Library; (7) posted on the Alaska Online Public Notice System as required by AS 44.62.1 75(a)(1) and (b) and 44.62.190(a)( I); (8) furnished electronically, along with a copy of the proposed regulations, to the Legislative Affairs Agency, the chair of the House and Senate Resources Committee, House Special Committee on Oil and Gas, and the Administrative Regulation Review Committee, and the legislative council. As required by AS 44.62.190( d), additional regulations notice information regarding the proposed adoption of the regulation changes described above has been furnished to interested persons [as shown on the attached list] and those in (5) and (6) of the list above. The additional regulations notice information also has been posted on the Alaska Online Public Notice System. DATE: /0/9106 AnclSorage, Alaska SUBSCRIBED AND SWORN TO before me this C¡~day of OC~ f1¡~ ( ,'}.,OC~ ~;~na1ø:?~ State of Alaska / My commission expires: 1/ /1/ IDb· t I . . STATE OF ALASKA ) ) ss. ) THIRD JUDICIAL DISTRICT AFFIDA VII OF ORAL HEARING I, Jody 1. Colombie, Special Staff Assistant of the Alaska Oil and Gas Conservation Commission, being sworn, state the following: On August 31,2006, at 9:00 a.m., 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501, a public hearing presided over by John K. Norman, Chairman, was held in accordance with AS 44.62.210 for the purpose of taking testimony in connection with the adoption of changes to . 20 AAC 25.005(c)(4)(A), 20 AAC 25.035(e)(1), 20 AAC 25.035(e)(2), 20 AAC 25.035(e)(4), 20 AAC 25.035(e)(lO), 20 AAC 25.036(c)(1), 20 AAC 25.036(c)(2), 20 AAC 25.036(c)(4)(H), 20 AAC 25.036(d), 20 AAC 25.280(b), 20 AAC 25.285(c)(2), 20 AAC 25.285(c)(3), 20 AAC 25.285(c)(9)(A), 20 AAC 25.285(c)(10), 20 AAC 25.285(f), 20 AAC 25.286(d)(1), 20 AAC 25.286(d)(3), 20 AAC 25.286(e). DATE: October 9, 2006 Anchorage SUBSCRIBED AND SWORN TO before me this 9th day of October, 2006. . . ALASKA OIL AND GAS CONSERVATION COMMISSION MEETING September 27, 2006 Excerpt From Unapproved l'vfinutes Commissioner Cathy P. Foerster moved and Commissioner Daniel T. Seamount, Jr. seconded the following motion: "I move to adopt the amendments, specifically to 20 AAC 25.005(c)(4)(A), 20 AAC 25.035(e)(l), 20 AAC 25.035(e)(2), 20 AAC 25.035(e)(4), 20 AAC 25.035(e)(lO), 20 AAC 25.036(c)(l), 20 AAC 25.036(c)(2), 20 AAC 25.036(c)(4)(H), 20 AAC 25.036(d), 20 AAC 25.280(b), 20 AAC 25.285(c)(2), 20 AAC 25.285(c)(3), 20 AAC 25.285(c)(9)(A), 20 AAC 25.285(c)(lO), 20 AAC 25.285(f), 20 AAC 25.286(d)(l), 20 AAC 25.286(d)(3), 20 AAC 25 .286( e), all of which pertain generally to the same subject as written in the September 27th draft of regulations." The motion carried unanimously. . . STATE OF ALASKA ) ) ss. ) THIRD JUDICIAL DISTRICT AFFIDAVIT OF COMMISSION ACTION I, Jody 1. Colombie, Special Staff Assistant for the Alaska Oil and Gas Conservation Commission, being duly sworn, state the following: The attached motion dealing with the method of determining a well's maximum potential surface pressure and blowout prevention equipment regulation changes was passed by the Alaska Oil and Gas Conservation Commission during its September 27, 2006 meeting. Date: October 9,2006 Anchorage SUBSCRIBED AND SWORN TO before me this 9th day of October 2006. -r7 ¿P ~ ot Public in and for the State of Alaska My commission expires: 11111/06. :#=4 · · · 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 . . 1 ALASKA OIL AND GAS CONSERVATION COMMISSION 2 Before Commissioners: John K. Norman, Chairman Daniel T. Seamount Cathy Foerster 3 4 Proposed Changes to Blow Out Prevention Equipment Regulations 5 6 ALASKA OIL and GAS CONSERVATION COMMISSION Anchorage, Alaska 7 8 August 31, 2006 9:00 o'clock a.m. 9 PUBLIC HEARING BEFORE: John K. Norman, Chairman Cathy Foerster, Commissioner R & R C 0 U R T R E P 0 R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 · · · . . 1 PRO C E E DIN G S 2 Tape 1 3 0015 4 (On record - 9:00 a.m.) 5 CHAIRMAN NORMAN: Good morning. This is a hearing before 6 the Alaska Oil and Gas Conservation Commission being held on 7 the morning of Thursday, September 30th -- correction, 8 September 31st [sic] at the hour of 9:00 o'clock a.m. The 9 purpose of the hearing is to receive comments on the proposed 11 out prevention equipment, more specifically to the regulations 10 amendments to the Commission's regulations pertaining to blow 12 found in 20 AAC 25.005 and forward. I will not read each of 13 the specific amendments because they will be addressed in the 14 15 course of these proceedings. 16 the Commission. To my left is Commissioner Cathy Foerster, the I'll first introduce myself, I'm John Norman, Chairman of 17 Engineering Commissioner. Commissioner Dan Seamount is unable 18 to be with us today, but we do have a quorum present and can 19 proceed with this hearing. 20 In compliance with the Americans with Disabilities Act, if 21 any persons have any special needs for accommodations to enable 22 them to participate in this hearing or provide testimony, 23 please, see the Commission's Special Assistant, Jody Columbie, 24 and she will assist you. Ms. Columbie is in the back of the 25 room, would you, please, hold your hand up, please, for R & R C 0 U R T R E P 0 R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 2 · · · . . 1 identification? Thank you. 2 Before we get into the testimony I'll remind everyone to, 3 please, first identify yourself, your company affiliation if 4 any, and your name clearly for the record. Also be sure to 5 speak into the microphone so that those in the rear of the room 6 can hear you. And also a transcript is being made of these proceedings and it will be important that the court reporter also be able to have clear testimony to prepare that record. 7 8 9 Notice of this hearing was published on July 28, 2006, in 10 the Anchorage Daily News. Any persons desiring to see a copy 11 of that notice can see the Commission's Special Assistant and 12 that will be provided to you. 13 This hearing is proceeding in accordance with the general 14 15 hearing regulations applicable to this Commission and those 16 Alaska Administrative Code. regulations are specifically found at 20 AAC 25.540 of the 17 We have a sign up sheet and if there are any persons who 18 wish to testify that have not signed up, we would appreciate 19 you doing so. 20 I'll pause now and see if Commissioner Foerster has 21 anything to add before we go forward? 22 23 COMMISSIONER FOERSTER: No. CHAIRMAN NORMAN: Then we will first hear briefly from the 24 Commission's staff concerning the regulations. Dr. Aubert? 25 DR. AUBERT: Thank you. For the record my name is Winton R & R C 0 U R T R E P 0 R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 3 · · · . . 1 Aubert, spelled W-i-n-t-o-n, last name A-u-b-e-r-t, and I'm on 2 the Commission staff. 3 Before the Commission today are proposed changes to Title 4 20, Chapter 25 of the Alaska Administrative Code which I'll 5 henceforth refer to either as Commission regulations or as 6 AOGCC regulations. Also since a number of proposed changes 7 today concern blowout prevention equipment I will refer to 8 that equipment occasionally as BOP or BOPE or BOP equipment. 9 Our first proposed change is to Section 005 of the 11 change to the method by which a well's maximum anticipated 10 Commission regulations. We're proposing a straight forward 12 surface pressure is calculated. 13 Our next series of changes are to Sections 035, 036, 285 14 15 and 286 of the Commission regulations. Current AOGCC regulations in these sections express blowout prevention 17 Petroleum Institute or API pressure ratings of individual BOP 16 equipment configurations in terms of required American 18 components. Our proposed changes will express required blow 20 maximum potential surface pressure on which the equipment is 19 out prevention equipment configurations in terms of a well's 21 installed. 22 We also propose amendments to Section 035, 036, 285 and 23 286 of the Commission regulations to one, clarify testing after 24 use requirements of BOP equipment; second, to specify a time 25 limit on reporting of BOP test results; and third, to codify an R & R C 0 U R T R E P 0 R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 4 · · · . . 1 area on which current regulations are silent, namely required 2 testing of variable bore ram BOP equipment. 3 To conclude, we believe the present proposed changes to 4 the Commission regs will reduce regulatory ambiguity and 5 variations in interpretation, will reduce instances of 6 regulatory noncompliance, will reduce the numbers of regulatory 7 waivers and variances the Commission issues and will improve 8 time utilization of Commission staff and Commission inspectors. 10 change the regulatory burden on Alaska's petroleum industry. 9 We also believe that the proposed changes do not appreciably 11 12 13 14 CHAIRMAN NORMAN: Thank you, Dr. Aubert. DR. AUBERT: Thank you. CHAIRMAN NORMAN: Commissioner Foerster? 15 increase, do they do anything to decrease the regulatory COMMISSIONER FOERSTER: You said they don't appreciably 16 burden? 17 18 19 DR. AUBERT: They do not. COMMISSIONER FOERSTER: Okay. CHAIRMAN NORMAN: Thank you. And if you would remain 20 available in case there are questions. 21 We have several persons testifying and I'm not sure if 22 you've simply indicate you're here or if you wish to testify. 23 So I will ask persons that wish to testify to, please, come 24 forward and -- yes, Ms. Moriarty? 25 MS. MORIARTY: Good morning. My name is Kara Moriarty, R & R C 0 U R T R E P 0 R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 5 · · · . . 1 I'm the External Affairs Manager for the Alaska Oil and Gas 2 Association. AOGA is a private, non-profit trade association 3 whose member companies represent the majority of oil and gas 4 exploration, production, transportation, refining and marketing 5 in Alaska. 6 AOGA has reviewed the draft AOGCC regulation changes and 7 we appreciate the opportunity to provide testimony and comment 8 today. AOGA commends the Commission in its efforts to provide 10 We support the proposed regulation changes and would offer 9 clarity and consistency to existing regulation. 11 minor clarifications and additions. Ilm going to give the 12 Commissioners our packet of information now and then I'm going 13 to ask Jerome Eggemeyer from ConocoPhilips Alaska and Harry 14 15 16 Engel from B.P. to walk through the minor suggested clarifications and additions that we would like to propose. CHAIRMAN NORMAN: Let the record reflect that a copy has 17 been provided to both Commissioners and also a copy to the 18 court reporter and this copy will be affixed to the transcript 19 of this meeting. 20 Mr. Engel or Mr. Eggemeyer, which one of you wants to go 21 first? 22 MR. ENGEL: Good morning, Commissioners Norman and 23 Foerster. My name is Harry Engel. For the record, the last 24 name is spelled E-n-g-e-l. I am a staff engineer for B.P. 25 Exploration here in Anchorage and B.P. is a member of AOGA. R & R C 0 U R T R E P 0 R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 6 · · · . . 1 I also want to echo the comments made by Kara a few 2 minutes ago regarding the effort by the AOGCC to modify these 3 regulations. We do also agree that the effort provides clarity 4 and consistency across Alaska with respect to BOP requirements 5 in our industry. 6 Kara has provided a list of our comments, I can go through 7 them with you in detail if you'd like and we'll start with the 8 first recommendation in Section 25.005(c) (4) (a). We'd like to 9 add a minor suggest -- a minor recommendation referring to the 10 words, an equally effective means of determining. We'd 11 recommend changing that to read, a more accurate means of 12 determining the surface pressure. We think that would 13 strengthen the regulation. 14 15 The next comment is in regard to wording related to 16 regulations there are sections in there where this remains requiring a stack of less than API 5K. Throughout the 17 unchanged and we would like to recommend that for consistency 18 purposes that the language that's used which is, with a maximum 19 potential surface pressure of 3,000 PSI which is used in the 20 regulations, be used throughout the proposed regulations for 21 consistency purposes. And we've identified the areas in which 22 we feel that may be appropriate in the revised regulation. 23 The next comment we have is in regards to Section 24 25.035(e) (10) (c). And we suggest that the proposed language, 25 if BOP equipment has been used, be clarified to state, if any R & R C 0 U R T R E paR T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 7 · · · 10 . . 1 BOP equipment components have been used. We feel this will add some clarity into what component of the BOP equipment will be 3 required in that section of the regulation. 2 4 The next comment is in relationship to the requirement for 5 submitting test results to the Commission within two days which 6 is the proposed amendment to the regulation. We would like to 7 recommend that we change that to within a five day period to 8 allow for weekend and holiday periods throughout the year and allow us time to submit the reports in a timely manner without being in noncompliance of the proposed regulation. 9 11 And I'll ask Jerome to address the next comment related to 12 the addition of a subsequent regulation we'd like to propose to 13 the Commission. 14 15 MR. EGGEMEYER: For the record, I'm Jerome Eggemeyer, last 16 m-e, employee for ConocoPhilips, Engineering Team Lead in the name's spelled, E-g-g-e-m-e-y-e-r, first name Jerome, J-e-r-o- 17 Drilling and Wells group. And I will address a couple other 18 items with regard to the proposed regulation. 19 20 have two suggested additions to the regulation. One addition We have two suggested additions to the regulation. We 21 would affect regulation -- Notice for Revision in the set of 22 revisions in 20 AAC 25.035. We would suggest that a new 23 subsection is inserted between (10) (e) and (10(f) and that 24 would address testing of the ram bonnets after installing 25 casing rams into the stack before casing is run. R & R C 0 U R T R E P 0 R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 8 · · · 10 11 12 13 14 15 . . 1 CHAIRMAN NORMAN: Mr. Eggemeyer, so I can -- let's see, 2 are you -- you're referring -- I'm looking at your handout and 3 it's numbered at the bottom, so you're referring right now to 4 page to 5, the subsection (f), is that -- is that what you're 5 mentioning? 6 MR. EGGEMEYER: Page 5, item (f)..... 7 CHAIRMAN NORMAN: Item (f). Okay. I'm with you. 8 MR. EGGEMEYER: .... . about a third of the way down on the 9 page. CHAIRMAN NORMAN: Yes, I'm with you. MR. EGGEMEYER: Yes. CHAIRMAN NORMAN: Thank you. MR. EGGEMEYER: And so that particular addition would say that after installing casing rams in the BOP stack the ram 16 the casing. And this would just offer a clarification on that bonnets must be tested to the required pressure before running 17 for -- for consistency and continuity. This is also consistent 18 with language, I believe, used by the MMS which is one resource 19 we used to see how this was addressed in other places. 20 Additionally, the -- another item -- other proposed 21 addition to -- is to insert a new subsection 20 AAC 22 25.280(b) (6), to add a requirement to the Sundry notice 23 application addressing the maximum surface pressure 24 calculation. And on the handout that is towards the back, page 25 9, I believe. Okay. We suggest that the Commission apply the R & R C 0 U R T R E P 0 R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 9 · · · . . 1 surface pressure calculation concept articulated in the 2 proposed revision, 25.05(c) (4) (a) [sic] to work over operations 3 with additional wording to indicate that using stabilized shut- 4 in tubing pressure may be -- may provide an alternative way 5 that is acceptable to the Commission for determining the 6 maximum potential surface pressure for proposed work over 7 operations. Our suggested language is included in the handout 8 which I think you're looking at there. 9 And if this suggested addition to the regulations does not 10 fit within the scope of the proposed revisions then that would 12 could be considered on a future revision. So depending on 11 -- that has been publicly noticed so far, then that change 13 order of business of how we can address that. 14 But that actually is a fairly important component just to 15 add clarity for the work over sector. Otherwise we often end 16 up falling back to the drilling rig to get guidance for that. 17 18 understand it, that revision will be included in a future COMMISSIONER FOERSTER: Mr. Eggemeyer, the way I 19 revision to the regulations and we appreciate your comment and 20 it will be addressed. 21 22 23 MR. EGGEMEYER: Okay. Great. Thank you. CHAIRMAN NORMAN: Okay. Anything further? MR. ENGEL: Yes, Commissioner Norman, I want to just 24 clarify that we do have in our package this morning a reference 25 of the MMS regulations referring to testing casing rams after R & R C 0 U R T R E paR T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 10 · · · . . 1 installation and before running casing as an amendment. And 2 it's MMS regulation 30CFR Part 250, Subpart D, Oil and Gas 3 Drilling Operations and it's Section .451, and it's attached 4 for your reference in our package. 5 CHAIRMAN NORMAN: Yes, I think -- I see we have it right 6 here. 7 MR. EGGEMEYER: Thank you. 8 CHAIRMAN NORMAN: Commissioner Foerster, any further 10 the testimony of these two witnesses that you feel would 9 questions of the witnesses? Dr. Aubert, was anything said in 11 require some clarification? If there is, I'd ask that you come 12 forward. If not, why I just want to give you the opportunity 13 if they have any questions? 14 15 DR. AUBERT: No, but I would like to thank the AOGA 16 which are very germane as usual. representatives for their -- for their comments and suggestions 17 18 have only one question and that relates to the opinion of the CHAIRMAN NORMAN: Okay. The record will reflect that. I 19 Commission that this will not add to the regulatory burden on 20 industry and included in that is added cost to industry. Is 21 that your opinion of these regulations if they're adopted that 22 they will not increase the costs or regulatory burden on the 23 industry? 24 MR. ENGEL: Yes, Commissioner, I agree with that statement 25 that we don't see any additional burden to industry in regards R & R C 0 U R T R E P 0 R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 11 · · · . . 1 to the regulation. 2 MR. EGGEMEYER: I would agree with that statement and 3 actually I think it is a benefit because it offers clarity and 4 less administration, less administervia (ph) I'll call it, in 5 understanding what the best solution is whenever there is lack 6 of clarity. 7 CHAIRMAN NORMAN: Yes. All right. Well, we thank you 8 very much for taking your time to come in and offer comments on 10 effort between the Commission and industry and the goal, of 9 these regulations and this is an example of a good cooperative 11 course, is to have a very safe and well-functioning oil 12 industry operating in the state of Alaska. 13 So again we thank all of you and thank you, Ms. Moriarty. 14 15 Do you have anything now to finish your testimony? Okay. 16 awake, the audience has pointed out that when we started the COMMISSIONER FOERSTER: I do. To prove to us that they're 17 hearing we said that the date today was September 31st, but 18 it's August 31st. 19 CHAIRMAN NORMAN: Thank you for that correction. We'll 20 excuse you, gentlemen, and ask you to remain. 21 And I'll just ask generally now if there are any other 22 persons present who wish to offer any comments on these 23 regulations? Okay. The Chair sees no one asking to be 24 recognized. 25 The regulations have been duly noticed, a quorum of R & R C 0 U R T R E P 0 R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 12 · · · . . 1 Commissioners is present to receive the testimony. And so we 2 will now take your comments into consideration as well as any 3 other information and then in due course there will be a 4 subsequent hearing at which the Commission will vote formally 5 to adopt these regulations. They will then be sent to Juneau 6 to be filed with the Lieutenant Governor. And then following 7 that there will be a new effective date and they'll become part 8 of the regulations assuming that they are adopted. 9 COMMISSIONER FOERSTER: Can I move to adopt -- to adjourn 10 the meeting, please? 11 CHAIRMAN NORMAN: It's been moved and without objection we 12 are adjourned. 13 (Recessed - 9:25 a.m.) 14 15 16 17 18 19 20 21 22 23 24 25 0512 R & R C 0 U R T R E P 0 R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 13 · · · . . 1 C E R T I F I CAT E 2 UNITED STATES OF AMERICA ) ) ss. STATE OF ALASKA ) 3 4 I, Rebecca Nelms, Notary Public in and for the State of Alaska, residing at Anchorage, Alaska, and Reporter for R & R 5 Court Reporters, Inc., do hereby certify: 6 THAT the annexed and foregoing Public Hearing Regarding Proposed Changes to Blow Out Prevention Equipment Regulations 7 was taken by Lynn Hall on the 31st day of August, 2006, commencing at the hour of 9:00 a.m., at the Alaska Oil and Gas 8 Conservation Commission, Anchorage, Alaska; 9 THAT this Hearing Transcript, as heretofore annexed, is a true and correct transcription of the proceedings taken and 10 transcribed by Lynn Hall; 12 11 IN WITNESS WHEREOF, I have hereunto set my hand and affixed my seal this 1st day of September 2006. 13 14 15 16 17 18 19 20 21 22 23 24 25 ~~~..c.~ Notary Public in and for Alaska My Commission Expires: 10/10/06 R & R C 0 U R T R E P 0 R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 . . STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Permits and Equipment Regulations Hearing August 31, 2006 at 9:00 am NAME - AFFILIATION ADDRESS/PHONE NUMBER TESTIFY (Yes or No) ~RINT)Ðù~f1 J!.c.y 11 W1~¡"(l.yf¡ j Ie f' t:) ~ ~ £~~ e vvt-e-j .r¿J' ÇbC( ~c¡(~ é)/7~, - 1'-1 ß , 2. ¿,.s- - to 4 q YÉ3'" Vi.c; *S · Alaska Oil and Gas Isociation A0GA 121 W. Fireweed Lane, Suite 207 Anchorage, Alaska 99503-2035 Phone: (907)272-1481 Fax: (907)279-8114 Email: brady@aoga.org Judith Brady, Executive Director August 30, 2006 Commissioner John Norman Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501-3539 Re: AOGA Comments on AOGCC Permit to Drill/BOPE ReQulation ChanQes DearCommissioner Norman: The Alaska Oil & Gas Association (AOGA) is a private non-profit trade association. Its member companies represent the majority of oil and gas exploration, production, transportation, refining and marketing activities in Alaska. AOGA has reviewed the draft Alaska Oil and Gas Conservation Commission (AOGCC) regulation changes and appreciates the opportunity to provide comment and testimony. AOGA commends the AOGCC in its efforts to provide clarity and consistency to existing regulations. We support the proposed regulation changes, and would offer minor clarifications and additions. FoUowing is a brief description of the changes we suggest, and the specific changes are shown in the attached redline document. 1. In the new language proposed for 20 AAC 25.005(c)(4)(A), line 5, we suggest revising the words "an equally effective means of determining. . ." to read "a more accurate means of determining. . ,II 2. In the existing regulations, there are a couple of places where the wording "requiring a stack less than API 5k" remains unchanged by the proposed regulation revisions. Based on the consistent use of the phrase "with a maximum potential surface pressure of 3,000 psi or less" in the revised regulations, we suggest that all such references to the API 5k stack be revised to use the new proposed language. The regulations that would require additional changes to the new wording are at 20 AAC 25.035(e)(4)(H)(iii) and (iv) and 20 AAC 25.285(c)(10)(C) and (D). August 31, 2006 Page 2 . . 3. In the proposed revision to 20MC 25.035(e)(10)(C), we suggest that the proposed language "if BOP equipment has been used. . ." be clarified to "if any BOP equipment components have been used. . ." 4. We propose changing the requirement of submitting BOPE test results to the Commission from "within two days" to "within five days." We believe that this timeframe is an acceptable timeframe for what is normally a non-urgent submission and allows for weekends and holidays without putting a party in non-compliance. This time requirement is found in proposed revised regulations 20 MC 25.035(e)(10)(F), 20 MC 25.036(d)(7), 20 MC 25.285(f)(5), and 20 MC 25.286(e)(6). We have two suggested additions to the proposed regulations. One addition would affect a regulation noticed for revision in this set of revisions. In 20 MC 25.035(e)(10), we suggest that a new subsection be inserted between (10)(E) and (10)(F), which would address testing the ram bonnets after installing casing rams, before running casing. The U.S. Minerals Management Service includes a similar requirement in its OCS regulations, a copy of which is attached to these comments. Suggested language is included in the attached redlined document. The other proposed addition is to insert a new subsection, 20 MC 25.280(b)(6), to add a requirement to the Sundry Notice application addressing the maximum surface pressure calculation. We suggest that the Commission apply the surface pressure calculation concept articulated in the proposed revision to 20 MC 25.005(c)(4)(A) to workover operations, with additional wording to indicate that using a stabilized shut-in tubing pressure may provide an alternative way that is acceptable to the Commission for determining the maximum potential surface pressure for proposed workover operations. Suggested language is included in the attached redlined document. If this suggested addition to the regulations does not fit within the scope of the proposed revisions that have been publicly noticed for change at this time, we ask that this addition be considered for inclusion in a future revision of the Commission regulations. Thank you for the opportunity to provide comment and testimony on these proposed revisions to the Commission's regulations. Sincerely, Enclosures (2) [red line; MMS reg] Register --' -200 MISCELLANEOt BOARDS 20 AAC 25.005(c)(4)(A) is amended to read: (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a pressure s:radient to suñace of 0.1 psi per foot of tme vertical de..th. unless the commission aporoves a different pressure 2radient that provides aft eq8ftBv dJedÎVe more ¡tCl'urate meaDS of determinin2 the maximum ootential suñace pressure [METHANE GRADIENT]; / (Eft: 4/13/80, Register 74; am 4/2186, Register 97; am 1117/99, Register 152; am 6/412000, Register 154; am 1/5/2006, Register 177; am ---1---1--> Register.---J Authority: AS 31.05.030 AS 31.05.090 20 AAC 25.035(e)(1) is amended to read: (1) in rotary drilling rig operations, (A) for an operation with a maximum QC)tential suñace pressure of3..ooo psi or less [REQUIRING A BOP STACK LESS THAN API 5K], BOPE must have 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 (8RAs) or 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 (8) for an operation. other than a casin~ or liner operation.. with a muimum POtential suñace pressure of 2reater than 3.000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K], BOPE must have at least four preventers, including (i) two equipped with pipe rams that fit the size of the drin pipe !.!: tubing [OR CASING] being used, except that pipe rams need not be sized to BHAsand 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; 1 Register ---> -200 MISCELLANEO'BOARDS (C) for a casine or üner operation with a maximum pOtential sudate pressure of ereater than 3.000 osi. DOPE must have at least four preventers.indudinJ (n one e{Juipped with pipe rams that fit the size of the driB pine or tobin, beÎDe used. except that pine rams need not be sized to DHAsaad drill eolian; (ü) oae equipped with Dine rams that fit the size of casine or üner heine used: (ill) oae with blind rams.. ex~t that as.Mea BOPE assemblv must have blind/shear nuBS m ølate of bliød rams: and (iv) oneauDular tvøe: 20 MC 25.035(eX2) is amended to read: (2) in coiled tubing unit operations, the well control equipment must include (A) for an operation with a maximum pOtential sudace pressure of 5.000 osi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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, tubing, liner, or casing is planned, a riser or lubricator sized to the BHA and providing for pressure integrity trom 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 tubing, liner, or casing being used, except that pipe rams need not be sized to BRAs and drill coUars;and (B) for an operation. other than a casine or liner operation. with a ...xi.... DOteøtial s.riace press.re of ereater than 5.000 øsi [REQUIRING A BOP STACK GREATER THAN API5K], 2 Register ---' ·200 MISCELLANEOI BOARDS (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; (iü) if pressure deployment of tools. tubing, liner. or casing is planned, a riser or lubricator sized to the BHA and providing for pressure integrity «om 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 tubing[. LINER OR CASING] being used, except that pipe rams need not be sized to BRAs and drillcoUars; (c) for a cuin!! or liner operation with a maximum ootential soda" oressure of ereater than 5.000 osi. (n BOPE rams orovidillf! for oipe.. sliD. atttiD~..d blindiB!! oøeratioDs OR tile œiIed tub~ in ~ (ü) two 11_ oressure oack-offs. striopers. or annular type oreventen; (üi) if oressure deøIoYIDeRt of tools. tubiu.Iioer. or cuin!! is ~ a riser or lubricator sized to die BBAalld onwidin!! for uressure iatet!1'ÍtY from the BOPE ~s to the IIn onssure .-ck-off.. MODer.. or aanular t\1Je oreventer; (iv)at least ORe ,reveRter ea..... with OM raDII that fit the size of tile tRbiB~ IteiMo ..... e:s:œøt that. nuBS Deed DOt be sized to BBAs aDd drill collars; aDd (v) at least ORe preveDtereauipøed with pipe nuns that fit the .size of casiaS! or liner heia!! used. 20 AAC 25.()35(e)(4} is amended to ..ead: (4) a BOPE assembly must include (H) a choke manifold equipped with (iii) immediately upstream of each choke, at least one full- opening valve for an operation with a maximum I>otential 3 Register ----7 ·200 MISCELLANEOI BOARDS slIrfafe pressure of 3.000 psi or less [REQUIRING A BOP STACK LESS THAN API 5K], or at least two fuU-opening valves for an operation requiring a BOP stack equal to or greater than API 5K; and (iv) a bypass line, at least the diameter of the choke line, with at least one full-opening valve for an operation with a maximum notentÎaJ surf~lce [H'eSSure of 3,000 psi or less [REQUIRING A BOP STACK LESS THAN API SK], or at least two ful1-opening valves for an operation requiring a BOP stack equal to or greater than API 5K; 20 AAC 25.03S(e)(IO) is amended to read: (10) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; however, the commission will require that the BOPE be function pressure-tested weekly, if the commission determines that a weeldy BOPE pressure test interval is indicated by a particular drilling rig's BOPE perfonnance; (8) when installed, repaired, orcbanged on an exploratory or stratigraphic test well and at least once a week: thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; ! (C) if'lliY_BOP [SEALING RAM TYPE] equipmen(çç'J}lPS~Der!!l? ha}'..çs been used for well control or other equivalent purpose. or when routine use of the eouipment may have com,romised its effectiveness. the eouiøment [IT] must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (D) BOP ram and annular components except blind rams must be function-tested weeldy, and all BOP ram and annular components must be 4 Register ~ ·200 NUSCELLANEOttBOARDS function-tested after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing of blind rams must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; (E) for each DOPE test durine: drilline: and comoletion ooerations. variable bore rams must be function oressure tested to the reQuired oressure on the smallest outside diameter (OD) and lare:est OD tubulal'S that mav be used durine: that test cvcle. exceot that variable bore rams need not be tested on DBAs and drill collars: (F) After installin2 casin2 rams in the BOP stack. the ram bonnets must be tested to the reQuired pressure before runnin2 casim!. / fF.)(G) BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1), and must be rovided to th commission in a format a roved b the commission within days after comoletin2 the test: fG}(H) [(F)] at least 24 hours notice of each BOPE function pressure test must be provided to the commission so that a commission representative can witness the test; History: Eff 4/13/80, Register 74; am 2/22/81, Register 77; am 4/2/86, Register 97; am 11/7/99, Register 152; am 10/24/2004, Register 172; am-1-1----, Register ~ Authority: AS 31.05.030 20 AAC 25.036(c)(1) is amended to read: (1) in rotary drilling rig operations, (A) for an operation with a maximum potential surface oressure of 5.000 osi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], BOPE must have 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; and 5 Register ---' ·200 MISCELLANEOI BOARDS (B) for an operation other than a casin2 or liner ooeration. with a maximum ootential suñace pressure of ~reater than 5.000 osi [REQUIRING A BOP STACK GREATER THAN API 5K], BOPE must have at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe or[,] tubing[, OR CASING] being used, except that pipe rams need not be sized to BRAs 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; (C) for a casin2 or liner operation with a maximum ootential suñace oressure of 2reater than 5.000 osi. BOPE must have at least four oreventers. includin2 (n one eauiooed with pioe rams that fit the size of the drill pioe or tubin2 bein2 used. exceot that oipe rams need not be sized to BRAs and drm collars: em one eauiooed with pioe rams that fit the size of casin2 or liner bein2 used: (iii) one with blind rams. exceot that a subsea BOPE assemblv must have blind/shear rams in place of blind rams: and (iv) one annular tvoe: 20 AAC 25.036(c)(2) is amended to read: include (2) in coiled tubing unit operations, the well control equipment must (A) for an operation with a maximum potential suñace Dressure of 5.000 osi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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; 6 Register ----J ·200 MISCELLANEOI BOARDS (iii) if pressure deployment of tools, tubing, liner, or casing 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; and (B) for an operation. other than a casing or liner operation with a maximum ootential suñace oressure of 2reater than 5.000 osi [REQUIRING A BOP STACK GREATER THAN API 5K], (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, tubing, liner, or casing 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[, LINER, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; (C) for a casin2 or liner ooeration with a maximum ootential suñace oressure of 2reater than 5.000 osi. {n DOPE rams orovidin2 for oioe. SliD. cuttin2. and blindin2 ooerations on the coiled tubin2 in service: (m two hip pressure oack~otTs. striDDen. or annular tvoe oreventers: eiii) if oressure deolovment of tools. tubin2. liner. or casin2 i. olanned. a riser or lubricator sized to the DRA and providin2 for oressure inteJri1y from the BOPE rams to the hi2h oressure oack-otT. striooer. or annular tvoe oreventer: (iv) at least one oreventer eauiooed with oioe rams that fit the size of the tubin~ bein~ used. exceot that oipe rams need not be sized to BRAs and drill collars: and 7 Register ----J . ZOO MISCELLANEOI BOARDS (v) at least one preventer eQuipped with pipe rams that fit the size of casine or liner beine used: ZO AAC Z5.036(d) is amended to read: (d) A BOPE assembly must be tested as follows: (1) when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; however, the commission will require that the BOPE be function pressure-tested weekly, if the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance; (Z) when installed, repaired, or changed on an exploratory or stratigraphic test well and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non- compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (3) other well control equipment must be pressure-tested to the maximum potential wellhead pressure after each installation of the well control equipment and before well bore entry, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (4) if BOP [SEALING RAM TYPE] equipment has been used for well control or other eQuivalent purpose. or when routine use of the equipment mav have compromised its effectiveness. the eQuipment [IT] must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (5) BOP ram and annular components except blind rams must be function- tested weekly, and all BOP ram and annular components must be function-tested after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing of blind rams must be performed as soon as possible after the workstring is pulled out of the well and the BRA clears the BOP; (6) for each BOPE test durine driUine and completion operations. variable bore rams must be function pressure tested to the reQuired pressure 8 Register ---' .200_ MISCELLANE+OARDS on tbe smallest on and laœest on tubulars tbat may be used durin!! tbat test cvcle. except tbat variable bore rams need not be tested on BRAs and drill collars; ill DOPE test results must be recorded as part of the daily record required by 20 AAC 25. 070( 1 ). and must be provided to the commission. in a format approved bv tbe commission. within· -1 days after completin!! the test; Œì.[(7)] at least 24 hours notice of each BOPE function pressure test must be provided to the commission so that a representative of the commission can witness the test. History: Eff 11/7/99, Register 152; am 10/24/2004, Register 172; am-.-f _/--> Register ---.J Autbority: AS 31.05.030 (b) The Application for Sundry Approval must set out 20 AAC 25.285(c)(2) is amended to read: (2) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 3.000 psi or less [REQUIRING A BOP STACK LESS THAT API 5K], 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 9 Register ~ ·200 MISCELLANEOI BOARDS (iii) one annular type; and (B) for an operation. other than a casin2 or liner oDeration. with a maximum Dotential sudace Dressure of ¥reater than 3.000 Dsi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API SK], at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe su:[,] tubing[, OR CASING] 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; (C) for a casin2 or liner oDeration. with a maximum Dotential surface Dressure of 2reater than 3.000 Dsi. at least four Dreventers. includin2 (0 one eauiDDed with DiDe rams that fit the size of the drill DiDe or tubin2 bein2 used. exceDt that DiDe rams need not be sized to BRAs and drill collars: (ii) one eauiD~ed with DiDe rams that fit the size of casin2 or liner bein2 used: (iii) one with blind rams. exceDt that a subsea BOPE assemblv must have blind/shear rams in Dlace of blind rams: and (iv) one annular tvDe: 20 AAC 25.285(c)(3) is amended to read: (3) in coiled tubing unit operations, (A) for an operation with a maximum potential sudace Dressure of 5.000 Dsi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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; 10 Register ~ ·200 MISCELLANEO' BOARDS (ìiì) if pressure deployment of tools is planned, a riser or lubricator sized to the BHA and providing for pressure integrity ftom 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 BRAs and drill collars; and (B) for an operation. other than a casine or liner otJeration. with a maximum ootential suñace oressure of ereater than 5.000 osi [REQUIRING A BOP STACK GREATER THAN API SK], (i) BOPE rams providing for pipe, slip, cutting, and blinding operations on the coiled tubing in service; (ii) two high pressure pack-off's, 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[, LINER, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; (C) for a casine or liner ooeration with a maximum potential suñace oressure of 3reater than 5.000 psi. (n DOPE rams orovidine for oioe. slip. cuttinJ. and blindine ooerations on the coiled tubin3 in service: (ii) two hieh oressure oack-otTs. striooen. or annular tv{)e oreventers: (iii) if oressure deolovment of tools is olanned. a riser or lubricator sized to the BRA and orovidine for oressure inteeritv from the DOPE rams to the hieh oressure oack-otT. striooer. or annular tvoe oreventer: (iv) at least one oreventer eauiooed with pioe rams that fit the size of the tubine beine used. exceot that oioe rams need not be sized to DRAs and drill collars: and 11 Register --' ·200 MISCELLANEOI BOARDS tv) at least one preventer equipped with pipe rams that fit the size of casine or liner beine used: 20 AAC 25.285(c)(10) is amended to read: (10) a choke manifold equipped with (C) immediately upstream of each choke, at least one full-opening for an operation with a maximum potential surface pressure of 3.000 psi or less [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full-opening valves for an operation requiring a BOP stack equal to or greater than API 5K; 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 [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full opening valves for an operation requiring a BOP stack equal to or greater than API 5K. 20 AAC 25.285(f) is amended to read: (f) The BOPE must be tested as follows: (1 ) when installed, repaired, or changed, and at least once a week thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which the BOPE may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (2) if BOP [SEALING RAM TYPE] equipment has been used for well control or other equivalent purpose. or when routine use of the equipment may have compromised its effectiveness, the equipment [IT] must be function pressure-tested before the next wellbore entry, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which that equipment may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing 12 Register ~ ·200 MISCELLANEO' BOARDS must be perfonned as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; (4) for each DOPE test durin!! drillin!! and comDletion oDerations. variable bore rams must be function ~ressure tested to the required Dressure on the smallest 0» and lal'2est 0» tubulars that may be used durin!! that test cycle. except that variable bore rams need not be tested on DRAs and drill collars: œ DOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1). and must be Drovided to the commission. in a format apDroved by the commission. within five tw&-davs after completin2 the test: í!l.[(5)] at least 24 hours notice of each DOPE function pressure test must be provided so that a representative of the commission can witness the test;[.] ill the ODerator shall reDO" to the commission within 24 hours any instance of BOPE use to Drevent the flow of fluids from a well. History: Eff 4/2/86, Register 97; am 11/7/99, Register 152; am ~ ~ ~ Register ~ Authority: AS 31.05.030 20 AAC 25.286(d)(1) is amended to read: (1) at least one positive seal manual or hydraulic valve or blind ram flanged to the wellhead or tree; (2) in rotary drilling rig operations, (A) for an operation with a maximum potential suñace Dressure of 5.000 Dsi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], 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 (BRAs) 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 (B) for an operation. other than a casin!! or liner oDeration. with a maximum Dotential surface Dressure of !!reater than 5.000 Dsi 13 Register -' ·200 MISCELLANEOI BOARDS [REQUIRING A BOP STACK GREATER THAN API 5K], at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe or[,] tubing[, OR CASING] being used, except that pipe rams need not be sized to BRAs 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; (C) for a casin2 or liner operation with a maximum potential surface pressure of 2reater than 5.000 psi. at least four preventen. includin2 (0 one eauipped with pipe rams that fit the size of the drill pipe or tubin2 bein2 used. except that pipe rams need not be sized to BRAs and drill collars: (ii) one eauipped with pipe rams that fit the size of c~sin2 or liner bein2 used: (iii) one with blind rams. except that a subsea BOPE assemblv must have blind/shear rams in place of blind rams: and (iv) one annular type: 20 AAC 25.286(d)(3) is amended to read: (3) in coiled tubing unit operations, (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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; and iii) if pressure deployment of tools is planned, a riser or lubricator sized to the BRA and providing for pressure integrity 14 Register -' ·200 MISCELLANEOI BOARDS ITom the BOPE rams to the high pressure pack-off, stripper, or annular type preventer; and (B) for an operation with a maximum potential surface pressure of greater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], (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; and (iii) if pressure deployment of tools is planned, a riser or lubricator sized to the BRA and providing for pressure integrity ITom the BOPE rams to the high pressure pack-off, stripper, or annular type preventer; 20 AAC 25.286(e) is amended to read: (e) The operator shall test the BOPE assembly as follows: (1) at least once a week, and after each [USE,] repair, [OR] change, or use for well control or other equivalent ourpose. or when routine use of the eQuioment may have comoromised its effectiveness. BOP[E] equioment [PIPE AND BLIND RAMS] must be function pressure-tested, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which they may be subjected, except that the annular type preventer need not be tested to more than 50 percent of its rated working pressure; (2) after each installation ofBOPE or other well control equipment, the equipment must be pressure-tested, before wellbore entry, to the maximum potential wellhead pressure to which it may be subjected, except that when testing against the annular type preventer, pressure testing need not exceed 50 percent of the rated working pressure of the annular type preventer; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines ITom the BOPE, except that if the workstring is continuously in the well, function-testing must be performed as soon as possible after the workstring is pulled out of the well and the BRA clears the BOP; (4) after each well installation of the BOPE, the BOPE hydraulic connections to the rams must be visually verified before wellbore entry;[.] 15 Register ----' ·200 MISCELLANEOI BOARDS (5) for each DOPE test durine drilline and comDletion oDerations. variable bore rams must be function oressure tested to the required pre~sure on the smallest OD and lan!est OD tubulars that mav be used durine that test cycle. exceot that variable bore rams need not be tested on DBAs and drill collars: (6) DOPE test results must be recorded as part of the daily record required bv 20 AAC 25.070(1). and must be orovided to the commission. in a format aooroved bv the commission. within five twe-days after comoletine the test: (7) at least 24 hours notice of each DOPE function oressure test must be orovided so that a representative of the commission can witness the test: (8) the ooerator shall reoort to the commission within 24 hours any instance of BOPE use to ~revent the flow of fluids from a well. History: Eff 11/7/99, Register 152; am--.!--.! ----' Register --..--J Authority: AS 31.05.030 16 . . MMS regulation reference related to testing ram bonnets after installing casing rams. MMS Regulations 30CFR Part 250 Subpart D Oil & Gas Drilling Operations Sec. 250.451 What must I do in certain situations involving BOP equipment or systems? The table in this section describes actions that lessees must take when certain situations occur with BOP systems during drilling activities. ----------------------------------------------------------- If you e?counter the following situation: Then you must... ----------------------------------------------------------- (f) Install casing rams in a BOP stack....Test the ram bonnets before running casing. Register ----y ~oo MISCELLANEOulOARDS -,- ~ 20 AAC 25.005(c)(4)(A) is amended to read: (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a pressure 2radient to surface of 0.1 psi per foot of true vertical depth. unless the commission approves a different pressure 2radient that provides aft equallY eff-eetive ' .'. means of determinin2 the maximum potential surface pressure [11ETHANE GRADIENT]; (Eff 4/13/80, Register 74; am 4/2/86, Register 97; am 11/7/99, Register 152; am 6/412000, Register 154; am 1/5/2006, Register 177; am_/_/_, Register--.-J Authority: AS 31.05.030 AS 31.05.090 20 AAC 25.035(e)(1) is amended to read: (1) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 3.000 psi or less [REQUIRING A BOP STACK LESS THAN API 5K], BOPE must have 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 (BRAs) or 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 (B) for an operation. other than a casin2 or liner operation. with a maximum potential surface pressure of 2reater than 3.000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K], BOPE must have at least four preventers, including (i) two equipped with pipe rams that fit the size of the driB pipe ill: tubing [OR CASING] being used, except that pipe rams need not be sized to BRAs 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; Register _, ~oo MISCELLANEOulOARDS (C) for a casin2 or liner operation with a maximum potential surface pressure of 2reater than 3.000 psi. DOPE must have at least four Dreventers. including (i) one eauipped with piDe rams that fit the size of the drill pipe or tubin2 bein2 used. except that pipe rams need not be sized to BRAs and drill collars; (in one eauipped with pipe rams that fit the size of casin2 or liner being used; (iii) one with blind rams. except that a subsea BOPE assemblv must have blind/shear rams in place of blind rams; and (iv) one annular tyDe; 20 AAC 25.035(e)(2) is amended to read: (2) in coiled tubing unit operations, the well control equipment must include (A) for an operation with a maximum Dotential surface pressure of 5.000 Dsi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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, tubing, liner, or casing is planned, a riser or lubricator sized to the BHA and providing for pressure integrity ITom 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 tubing, liner, or casing being used, except that pipe rams need not be sized to BHAs and drill collars; and (B) for an operation. other than a casin2 or liner oDeration. with a maximum potential surface Dressure of 2reater than 5.000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], 2 Register ----------y ~oo MISCELLANEoutOARDS (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, tubing, liner, or casing is planned, a riser or lubricator sized to the BHA and providing for pressure integrity ITom 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 tubing[, LINER, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; (C) for a casin2 or liner operation with a maximum potential surface pressure of 2reater than 5.000 psi. in DOPE rams providin2 for pipe. slip. cuttiD!!. and blindin2 operations on the coiled tubin2 in service: (ii) two hi2h pressure pack-offs. strippers. or annular type preventers: (iii) if pressure deplovment of tools. tubin2. liner. or casin2 is planned. a riser or lubricator sized to the BRA and providin2 for pressure inte2rity from the BOPE rams to the hi2h pressure pack-off. stripper. or annular type preventer: (iv) at least one preventer equipped with pipe rams that fit the size of the tubin2 bein2 used. except that pipe rams need not be sized to BRAs and drill collars: and (v) at least one preventer equipped with pipe rams that fit the size of casin2 or liner bein2 used. (4) a BOPE assembly must include (H) a choke manifold equipped with (iii) immediately upstream of each choke, at least one fi.1ll- opening valve for an operation 3 Register -----' _00 MISCELLANEOulOARDS [REQUIRING A BOP ST ACK LESS THAN API 5K], or at least two full-opening valves for an operation requiring a BOP stack equal to or greater than API 5K; and (iv) a bypass line, at least the diameter of the choke line, with at least one full-opening valve for an operation [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full-opening valves for an operation requiring a BOP stack equal to or greater than API 5K; 20 AAC 25.035(e)(1O) is amended to read: (10) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; however, the commission will require that the BOPE be function pressure-tested weekly, if the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance; (B) when installed, repaired, or changed on an exploratory or stratigraphic test well and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (C) if BOP [SEALING RAM TYPE] equipment ha oS been used for well control or other equivalent purpose. or when routine use of the equipment may have compromised its effectiveness. the equipment [IT] must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (D) BOP ram and annular components except blind rams must be function-tested weekly, and all BOP ram and annular components must be 4 Register ---y ~oo MISCELLANEOUttOARDS function-tested after an action that disconnects the hydraulic system lines rrom the BOPE, except that if the workstring is continuously in the well, function~testing of blind rams must be performed as soon as possible after the workstring is pu]]ed out of the we]] and tbe BRA clears tbe BOP; (E) for each DOPE test durint! drillint! and completion operations. variable bore rams must be function pressure tested to the required pressure on the smallest outside diameter (0)>) and laNest 0» tubulars that may be used durint! that test cvcle. except that variable bore rams need not be tested on BRAs and drill collars; æ BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1), and must be provided to the commission. in a format approved bv the commission. within twi)-p days after completint! the test; flli·· [(F)) at least 24 hours notice of each BOPE :fi.mction pressure test must be provided to the commission so that a commission representative can witness the test; History: Eff 4/13/80, Register 74; am 2/22/81, Register 77; am 4/2/86, Register 97; am 1117/99, Register 152; am 10/24/2004, Register 172; am_/_/_, Register----.--J Authority: AS 31.05.030 20 AAC 25.036(c)(1) is amended to read: (1) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], BOPE must have 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; and 5 Register --y _00 MIS CELLANEOU.OARDS (B) for an operation other than a casint! or liner operation. with a maximum potential surface pressure of t!reater than 5.000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], BOPE must have at least four preventers, including (i) two equipped with pipe rams that tit the size of the drill pipe or[,] tubing[, OR CASING] being used, except that pipe rams need not be sized to BRAs 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; (C) for a casint! or liner operation with a maximum potential surface pressure of t!reater than 5.000 psi. BOPE must have at least four preventers. includint! (n one eQuipped with pipe rams that fit the size of the drill pipe or tubint! beint! used. except that pipe rams need not be sized to BRAs and drill collars; em one eQuipped with pipe rams that fit the size of casint! or liner beint! used; (iii) one with blind rams. exceot that a subsea ROPE assemblv must have blind/shear rams in place of blind rams; and (iv) one annular tvpe: 20 AAC 25.036(c)(2) is amended to read: include (2) in coiled tubing unit operations, the well control equipment must (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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; 6 .. Register ----y _00 MISCELLANEOulOARDS (iii) if pressure deployment of tools, tubing, liner, or casing 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 BRAs and drill collars; and (B) for an operation. other than a casine or liner operation with a maximum potential surface pressure of ereater than 5.000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], (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, tubing, liner, or casing is planned, a riser or lubricator sized to the BRA 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[, LINER, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; (C) for a casine or liner operation with a maximum potential surface pressure of ereater than 5.000 psi. (i) BOPE rams providine. for DiDe. sliD. cuttine.. and blindine. oDerations on the coiled tubine in service: (ii) two hieh pressure pack-offs. striPDen. or annular type preventers: (iii) if pressure deplovment of tools. tubine. liner. or casine. is planned. a riser or lubricator sized to the BRA and providine for pressure intee.rity from tbe BOPE rams to tbe hie.h pressure pack-off. stripper. or annular type preventer: (iv) at least one preventer eqUiDPed with DiDe rams that fit the size of the tubine. beine. used. except that pipe rams need not be sized to BRAs and drill collars: and 7 Register ---y _00 MIS CELLANEoutOARDS (v) at least one preventer equipped with pipe rams that fit the size of casin!! or liner bein!! used: 20 AAC 25.036(d) is amended to read: (d) A BOPE assembly must be tested as follows: (1) when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; however, the commission will require that the BOPE be function pressure-tested weekly, if the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance; (2) when installed, repaired, or changed on an exploratory or stratigraphic test well and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non- compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (3) other well control equipment must be pressure-tested to the maximum potential wellhead pressure after each installation of the well control equipment and before wel1bore entry, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (4) if BOP [SEALING RAM TYPE] equipment has been used for well control or other equivalent purpose. or when routine use of the equipment may have compromised its effectiveness. the equipment [IT] must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (5) BOP ram and annular components except blind rams must be functÎon- tested weekly, and all BOP ram and annular components must be function-tested after an action that disconnects the hydraulic system lines fÌ"om the BOPE, except that if the workstring is continuously in the well, function-testing of blind rams must be performed as soon as possible after the workstring is pulled out of the wel1 and the BRA clears the BOP; (6) for each BOPE test durin!! drillins: and completion operations. variable bore rams must be function pressure tested to the required pressure 8 Register ---' '0 MISCELLANEOU.OARDS on tbe smallest 0» and la~est 0» tubulaJ'S tbat may be used durin!! tbat test cycle.. exceot that variable bore rams need not be tested on BRAs and drill collars: ill BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1). and must be provided to tbe commission. in a format approved by the commission. within 4 days after completin!! the test: !n,[(7)] at least 24 hours notice of each BOPE function pressure test must be provided to the commission so that a representative of the commission can witness the test. History: EfT 11/7/99, Register 152; am 10/24/2004, Register 172; am~~---, Register ~ Autbority: AS 31.05.030 (b) The Application for Sundry Approval must set out 20 AAC 25.285(c)(2) is amended to read: (2) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 3.000 psi or less [REQUIRING A BOP STACK LESS THAT API SKI, 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 9 Register ----' ~oo MISCELLANEOUttOARDS (iii) one annular type; and (B) for an operation. other than a casin2 or liner operation. with a maximum potential surface pressure of 2reater than 3.000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API SK], at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe m:[,] tubing[, OR CASING] being used, except that pipe rams need not be sized to BRAs 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; (C) for a casin2 or liner operation. with a maximum potential suñace pressure of 2reater than 3.000 psi. at least four preventers. includin2 (n one equipped with pipe rams that fit the size of the drill pipe or tubin2 bein2 used. except that pipe rams need not be sized to BRAs and drill collars: (m one equipped with pipe rams that fit the size of casin2 or liner bein2 used: (iii) one with blind rams. except that a subsea BOPE assemblv must have blind/shear rams in place of blind rams: and (iv) one annular type: 20 AAC 25.285(c)(3) is amended to read: (3) in coiled tubing unit operations, (A) for an operation with a maximum potential suñace pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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; 10 Register _, _00 MIS CELLANEOulOARDS (iii) if pressure deployment of tools is planned, a riser or lubricator sized to the BHA and providing for pressure integrity ftom 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; and (B) for an operation. other than a casim~ or liner operation. with a maximum potential surface pressure of !!:reater than 5.000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], (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 ftom 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(, LINER, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; (C) for a casin!!: or liner operation with a maximum potential surface pressure of ~reater than 5.000 psi. (i) BOPE rams providin!!: for pipe. slip. cuttin2. and blindin!!: operations on the coiled tubin!!: in service: (ii) two hi!!:h pressure pack-ofTs. strippers. or annular type preventers: (iii) if pressure deployment of tools is planned. a riser or lubricator sized to the BBA and providin!!: for pressure inteIDity from tbe BOPE rams to the hi!!:h nressure nack-otT. stripper. or annular type preventer: (iv) at least one preventer equipped with pipe rams that fit the size of the tubin!!: bein!!: used. exce~t that {)ipe rams need not be sized to BRAs and drill collars; and 11 Register _, .00 MISCELLANEOulOARDS (v) at least one preventer equipped with pipe rams that fit the size of casinS! or liner beinS! used; (10) a choke manifold equipped with (C) immediately upstream of each choke, at least one fhl1-opening tor an operation [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full-opening valves for an operation requiring a BOP stack equal to or greater than API 5K; and (D) a bypass line, at least two inches in nominal diameter, with at least one full-opening valve for an operation [REQUIRING A BOP STACK LESS THAN API 5K], or at least two full opening valves for an operation requiring a BOP stack equal to or greater than API 5K. 20 AAC 25.285(f) is amended to read: (f) The BOPE must be tested as follows: (1) when installed, repaired, or changed, and at least once a week thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which the BOPE may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (2) if BOP [SEALING RAM TYPE] equipment has been used for well control or other equivalent purpose. or when routine use of the equipment may have compromised its effectiveness, the equipment [IT] must be function pressure-tested before the next well bore entry, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 MC 25.280 or, if that application is not required, to the maximum potential surface pressure to which that equipment may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing 12 Register ~ _00 MISCELLANEOulOARDS must be performed as soon as possible after the work string is pulled out of the well and the BHA clears the BOP; (4) for each BOPE test durin2 driUin~ and completion operations. variable bore rams must be function pressure tested to the reauired pressure on the smallest OD and lar;est OD tubulars that may be used durin2 that test cycle. except that variable bore rams need not be tested on BRAs and drill collars; æ BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1). and must be provided to the commission. in a format approved by the commission. within .. ...... twtHIays after completin2 the test; í§l.[(5)] at least 24 hours notice of each BOPE function pressure test must be provided so that a representative of the commission can witness the test;[.] ill the onerator shall report to the commission within 24 hours any instance of BOPE use to prevent the flow of fluids from a well. History: Eff 4/2/86, Register 97; am 11/7/99, Register 152; am~~~ Register --.J Authority: AS 31.05.030 20 AAC 25.286(d)(I) is amended to read: (1) at least one positive seal manual or hydraulic valve or blind ram flanged to the wellhead or tree; (2) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], 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; and (B) for an operation. other than a casin2 or liner operation. with a maximum potential surface pressure of 2reater than 5.000 psi 13 , . Register ~ _00 MISCELLANEOulOARDS [REQUIRING A BOP STACK GREATER THAN API 5K], at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe or[,] tubing[, OR CASING] being used, except that pipe rams need not be sized to BRAs 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; (C) for a casine: or liner operation with a maximum potential suñace pressure of e:reater than 5.000 psi. at least four preventers. includine: (i) one eauipped with pipe rams that fit the size of the drill pipe or tubine: bein~ used. except that pipe rams need not be sized to BRAs and drill collars; (ii) one eauipped with pipe rams that fit the size of casin~ or liner beine: used; (iii) one with blind rams. except that a subsea DOPE assemblv must have blind/shear rams in place of blind rams; and (iv) one annular type; 20 AAC 25.286(d)(3) is amended to read: (3) in coiled tubing unit operations, (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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; and iii) if pressure deployment of tools is planned, a riser or lubricator sized to the BRA and providing for pressure integrity 14 Register ---' _00 MISCELLANEOulOARDS / ~ from the BOPE rams to the high pressure pack-ofT, stripper, or annular type pre venter; and (B) for an operation with a maximum potential surface pressure of greater than 5,000 psi [REQUJRING A BOP STACK GREATER THAN API 5K], (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; and (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-ofT, stripper, or annular type preventer; 20 AAC 25.286(e) is amended to read: ( e) The operator shall test the BOPE assembly as follows: (1) at least once a week, and after each [USE,] repair, [OR] change, or use for well control or other equivalent purpose. or when routine use of the e9uioment may have compromised its effectiveness. BOP[E] equipment [PIPE AND BLIND RAMS] must be function pressure-tested, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which they may be subjected, except that the annular type preventer need not be tested to more than 50 percent of its rated working pressure; (2) after each installation ofBOPE or other well control equipment, the equipment must be pressure-tested, before well bore entry, to the maximum potential wellhead pressure to which it may be subjected, except that when testing against the annular type preventer, pressure testing need not exceed 50 percent of the rated working pressure of the annular type preventer; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; (4) after each well installation of the BOPE, the BOPE hydraulic connections to the rams must be visually verified before wellbore entry;[.] 15 Register _, _00 MISCELLANEouttOARDS ~ . (5) for each BOPE test durin!! drillin!! and completion operations. variable bore rams must be function pressure tested to the reauired pressure on the smallest on and lal1!est on tubulars that may be used durin!! that test cvcle. except that variable bore rams need not be tested on BRAs and drill collars: (6) BOPE test results must be recorded as part of the daily record reauired by 20 AAC 25.0700). and must be provided to the commission. in a format approved by the commission. within! . tw6-days after comvletin~ the test: (7) at least 24 hours notice of each BOPE function pressure test must be provided so that a representative of the commission can witness the test: (8) the operator shaU report to the commission within 24 hours any instance of DOPE use to prevent the flow of fluids from a well. History: Eff. 1117/99, Register 152; am~~--, Register ~ Authority: AS 31.05.030 16 . . MMS regulation reference related to testing ram bonnets after installing casing rams. MMS Regulations 30CFR Part 250 Subpart D Oil & Gas Drilling Operations Sec. 250.451 What must I do in certain situations involving BOP equipment or systems? The table in this section describes actions that lessees must take when certain situations occur with BOP systems during drilling activities. ----------------------------------------------------------- If you encounter the following situation: Then you must... ------------------------------------------~---------------- (f) Install casing rams in a BOP stack.. ..Test the ram bonnets before running casing. [Fwd: Tomorrow's Public Hearing] . " Subject: [Fwd: Tomorrow's Public Hearing] From: John Norman <john_norman@admin.state.ak.us> Date: Tue, 29 Aug 2006 16:29:38 ~0800 To: Jödy J Còlpmhi¢ <jodyjcolombie@admin.state.ak.ûs> -------- Original Message -------- Subject:Tomorrow's Public Hearing Date:Tue, 29 Aug 2006 13:15:36 -0800 From:Kara Moriarty <moriarty(G}aoga.org> Reply- T o:moriarty(G}aoga.org Organization:Alaska Oil & Gas Association To:'John Norman' <john norman(G}admin.state.ak.us>, 'Dan Seamount' <dan seamount(G}admin.state.ak.us>, 'Cathy Foerster' <cathy foerster(G}admin.state.ak. us> TO: AOGCC Commissioners I will be unable to attend your monthly meeting tomorrow due to a conflict here at our office. I did want to let you know that AOGA will be providing supporting comments and testimony at the hearing on August 31 in regards to the proposed regulation changes. We appreciate the Commission's efforts in providing clarity to these regulations. We will be offering additional minor edits and suggestions for your consideration, and we will review these suggestions in testimony and in writing. Industry folks have discussed these proposed minor edits and suggestions with AOGCC staff. I look forward to seeing you all on Thursday. Kara Kara Moriarty External Affairs Manager Alaska Oil & Gas Association 121 W. Fireweed Lane, #207 Anchorage, AK 99503 (907) 272-1481 Cell: (907) 441-5272 Fax: (907)279-8114 moriarty(G}aoga.org John K. Norman <John Norman(G}admin.state.us> Chairman Alaska Oil & Gas Conservation Commission 1 of 1 8/30/2006 8:32 AM *3 . . . MEMORANDUM State of Alaska Department of Law To: John K.Norman, Chair Alaska Oil and Gas Conservation Commission Dept. of Administration Date: July 28, 2006 File No.: 993-07-0029 Tel. No.: 465-3600 "om' ~~9£~ Chief Assistant Attordey Deneral and Regulations Attorney Legislation and Regulations Section Re: Regulations File Opening Re: AOGCC: Permits and Equipment (20 AAC 25.005 - .286) We have received your memorandum of July 26, 2006 regarding this project, along with a copy of the proposed regulations and related documents. The project has been assigned to Assistant Attorney General Cammy Taylor, phone number 269-5100. Our department's file number for this project is 993-07-0029. This file number should be used on any further correspondence pertaining to this project. DEB:pvp cc: Kevin Brooks, Regulations Contact Dept. of Administration Lauren Yocom, AAC Coordinator Lt. Governor's Office Larry Ostrovsky, Supervising Attorney Oil, Gas and Mining Section Cammy Taylor, Assistant Attorney General Anchorage . MEMORANDUM . STATE OF ALASKA ALASKA OIL AND GAS CONSERV A TION COMMISSION TO: Deborah E. Behr Assistant Attorney General And Regulations Attorney Legislation and Regulations Section FROM: DATE: July 26, 2006 SUBJECT: File-opening request for Regulations Project on Permit to Drill Requirements and Blowout Prevention Equipment Requirements 20 AAC 25.005(c)(4)(A) 20 AAC 25.035(e)(1) 20 AAC 25.035(e)(2) 20 AAC 25.035(e)(10), 20 AAC 25.036(c)(1), 20 AAC 25.036(c)(2), 20 AAC 25.036(d), 20 AAC 25.285(c)(2) 20 AAC 25.285(c)(3) 20 AAC 25.285(f) 20 AAC 25 .286( d)(1) 20 AAC 25.286(d)(3) 20 AAC 25.286(e) We are requesting that you open a new file for a regulations project regarding changes in Title 20, Chapter 25, of the Alaska Administrative Code, dealing with Permit to Drill requirements and blowout prevention equipment requirements for the Alaska Oil and Gas Conservation Commission. Enclosed is a copy of the public notice, Additional Regulations Notice Information, and a draft of the regulation. Please assign Assistant Attorney General Cammy Taylor to this project. Our contact person for the project is Jody Colombie at 793-1221. :#;1. STATE OF ALASKA e NOTICE TO PUBLISHER e ADVERTISING ORDER NO. ADVERTISING ORDER INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE AO-02714001 F AOGCC AGENCY CONTACT DATE OF A.O. R 333 W 7th Ave, Ste 100 o Anchorage, AK 99501 M Jod Colombie PHONE Jul 26 2006 PCN ~ Anchorage Daily News PO box 149001 Anchorage, AK 99514 July 28, 2006 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Advertisement to be published was e-mailed Type of Advertisement Legal!:8J D Display Classified DOther (Specify) SEE ATTACHED SEND IN AOGCC, 333 W. 7th Ave., Suite 100 AnchoraQ"e. AK 99';01 AMOUNT DATE REF TYPE 1 VEN 2 ARD 3 4 02910 ¡::It..! 4Mf'lIIt..!T <:::v .r.r. Pf:M Ir. 4r.r.T ¡::v NMR DIST LlQ 05 02140100 73451 2 3 4 REQUISITIO DIVISION APPROVAL: I 02-902 (Rev. 3/94) pUblisher/olal Copies: Department Fiscal, Department,IeiVing AO.FRM STATE OF ALASKA ADVERTISING ORDER NOTICE TO PUBLISHER ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO.. CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COpy OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE AO-02714001 R o M AOGCC 333 West ih Avenue. Suite 100 AnrJ,orJ:luP AK QQ"Ol 907-793-1221 AGENCY CONTACT DATE OF A.O. T o Anchorage Daily News PO box 149001 Anchorage, AK 99514 July 28, 2006 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Account # STOF0330 United states of America AFFIDAVIT OF PUBLICATION REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COpy OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. division. Before me, the undersigned, a notary public this day personally appeared who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2005, and thereafter for _ consecutive days, the last publication appearing on the _ day of , 2005, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This _ day of 2005, Notary public for state of My commission expires [Fwd: Re: Public Notice] . . Subject: [Fwd: Re: Public Notice] From: Ceresa Tolley <ceresa_tolley@admin.state.ak.us> Date: Thu, 27 Jul 2006 15 :49: 19 -0800 -------- Original Message -------- Subject:Re: Public Notice Date:Thu, 27 Jul 2006 11 :30:00 -0800 From:Ads, Legal <legalads~adn.com> To:Ceresa Tolley <ceresa tolley~admin.state.ak.us> Hello Ceresa: Following is the confirmation information on your legal notice. Please review and let me know if you have any questions or need additional information. Account Number: STOF 0330 Legal Ad Number: 889675 Publication Date(s): July 28, 2006 Your Reference Number: 02714001 Cost of Legal Notice: $270.18 Thank You, Kim Kirby Anchorage Daily News Legal Classified Representative E-Mail: legalads@adn.com Phone: (907) 257-4296 Fax: (907) 279-8170 On 7/26/06 4:09 PM, "Ceresa Tolley" <ceres a tolley@actmin.state.ak.us> wrote: > Please publish on 7/28/06. > > Jody Colombie 1 of 1 7/27/20063:49 PM Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 . David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 . Mona Dickens Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Ivan Gillian 9649 Musket Bell Cr.#5 Anchorage, AK 99507 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 James Gibbs PO Box 1597 Soldotna, AK 99669 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 North Slope Borough PO Box 69 Barrow, AK 99723 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 Iv OW ~i ~1.~Þ· Public Notice . . Please publish on 7/28/06. Jody Colombie Ceresa Tolley <ceresa tolley(â¿admin.state.ak.us> Staff Assistant 907-793-1238 Alaska Oil & Gas Conservation Commission Department of Administration Content-Type: applicationlmsword Content-Encoding: base64 to Drill, DOPE Content-Type: applicationlmsword Content-Encoding: base64 1 of 1 7/26/2006 4: 11 PM Public Notice, Additional Regulation Notice Information and Amend... e e >, "MarkP. ,w , mjnelson >, "Randy L. Skillern" ssberg" s>, Ken adiokenai.com> , lof3 7/26/20062:15 PM Public Notice, Additional Regulation Notice Infonnation and Amend... . e e Jerry McCutc <Iris Matthe <rob.g.dragruch@e kremer <m Mason <m" <Camille Maunder Keith Wi <jim~r >, Hollis 20f3 7/26/20062:15 PM Public Notice, Additional Regulation Notice Infonnation and Amend... e e <representa . <represe <senator Tom An <repr <sen Jody Colombie <iody colombie~admin.state.ak.us> Special Staff Assistant 907-793-] 221 Alaska Oil and Gas Conservation Commission Department of Administration 30f3 7/26/20062:15 PM . . Copy of Notice and Additional Regulations Notice Information was mailed to the following on July 26, 2006. Scott N ordstrand Commissioner D~partment of Administration PO Box 110200 Juneau, AK 99811 Legislative Reference Library Legislative Affairs Agency State Capitol Juneau, AK 99801 Mail Stop: 3101 Senator Tom Wagoner, Chair Resources 145 Main St Lp Ste 226 Kenai AK 99611 Rep Vic Kohring, Chair House Special Committee on Oil and Gas 600 E Railroad Ave Wasilla AK 99654 Rep Tom Anderson, Chair Administrative Regulation Review 716 W 4th Ave Ste 610 Anchorage AK 99501-2133 Rep Pete Kott, Chair Legislative Council State Capitol Rm 3 Juneau AK 99801-1182 File Opening Memo, Copy of Notice, Additional Regulations Notice Information, draft regulation was mailed to the following on July 26, 2006. Debra Behr Assistant Attorney General Department of Law PO Box 110300 Juneau, AK 99811 Address Book . . 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Display Name: Bill Stoltze representative bill stoltze@leqis.state.ak.us Card for Bruce Weyhrauch Display Name: Bruce Weyhrauch representative bruce weyhrauch@leqis.state.ak.us Card for peggy wilson Display Name: peggy wilson representative peqqy wilson@legis.state.ak.us Card for Donny Olson Display Name: Donny Olson senator donny olson@leqis.state.ak.us Card for Ralph Seekins Display Name: Ralph Seekins senator ralph seekins@leqis.state.ak.us Card for Tom Anderson Display Name: Tom Anderson representative tom anderson@leqis.state.ak.us Card for Ethan Berkowitz Display Name: Ethan Berkowitz representative ethan berkowitz@leqis.state.ak.us Card for Fred Dyson 7 of 10 7/18/2006 11 :46 AM Address Book . . Display Name: Fred Dyson senator fred dyson@lec¡is,state.ak,us Phone Work: (907)465-2199 Fax: (907)465-4587 Work Senator Legislative Affairs Juneau, AK Card for Bert K Stedman Display Name: Bert K Stedman senator bert stedman@lec¡is,state,ak.us Phone Work: (907)465-3873 Fax: (907)465-3922 Work Senator Legislative Affairs Juneau, AK Card for rep~ay_ramras rep jay ramras@leqis,state.ak,us Card for rep~ay_ramras rep jay ramras@leqis,state.ak,us Card for Albert Kookesh Display Name: Albert Kookesh representative albert kookesh@lec¡is.state,ak.us Card for senator_charlie_huggins senator charlie huqc¡ins@leqis.state.ak.us Card for rep~im_elkins rep jim elkins@leqis,state.ak,us 8 of 10 7/18/2006 11 :46 AM Address Book . . Card for rep_berta_gardner reD berta qardner@leqis.state.ak.us Card for rep_mike_kelly reD mike kelly@legis.state.ak.us Card for rep_mark_neuman reD mark neuman@legis.state.ak.us --- Card for rep_gabrielle_ledoux reD gabrielle ledoux@legis.state.ak.us ---.---- Card for senator _charlie_huggins senator charlie huggins@legis.state.ak.us Card for senator _albert_kookesh senator. albert kookesh@legis.state.ak.us Card for Donny Olson Display Name: Donny Olson senator donny olson@legis.state.ak.us --- Card for Ralph Seekins Display Name: Ralph Seekins senator ralDh seekins@legis.state.ak.us Card for representativeJim_elkins 9 of 10 7/18/2006 11:46 AM Address Book . . representative jim elkins@leqis.state.ak.us Card for representative_berta_gardner representative berta qardner@leqis.state.ak.us Card for representative_mike_kelly representative mike kelly@leqis.state.ak.us Card for representative_gabrielle_ledoux representative qabrielle ledoux@leqis.state.ak.us Card for representative_mark_neuman representative mark neuman@legis.state.ak.us Card for representative_kurt_olson representative kurt olson@leqis.state.ak.us Card for representative-iay_ramras representative jay ramras@leqis.state.ak.us Card for representative_woodie_salmon representative woodie salmon@leqis.state.ak.us ----- 10 of 10 7/18/2006 11 :46 AM ~1 Register _, 200 MrSCELLANEOU~ úOARDS 20 AAC 25.005(c)(4)(A) is amended to read: (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a pressure gradient to surface of 0.1 psi per foot of true vertical depth, unless the commission approves a different pressure gradient that provides an equally effective means of determining the maximum potential surface pressure [METHANE GRADIENT]; (EtI. 4/13/80, Register 74; am 4/2/86, Register 97; am 11/7/99, Register 152; am 6/4/2000, Register 154; am 1/5/2006, Register 177; am _/ _/ _, Register---.J Authority: AS 31.05.030 AS 31.05.090 20 25.035(e)(1) is amended to read: (1) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 3,000 psi or less [REQUIRING BOP STACK LESS THAN API SK], BOPE must have 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) or drill collars; (ii) one with blind rams, except that a subsea BOPE assembly must have blind/shear rams in place of blind rams; and (iÜ) one annular type; and (B) for an operation, other than a casing or liner operation, with a maximum potential surface pressure of greater than 3,000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K], BOPE must have at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe or tubing [OR CASING] 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; Register _, ~OO MISCELLANEouloARDS (C) for a casin2: or liner operation with a maximum potential surface pressure of 2:reater than 3.000 psi. BOPE must have at least four preventers. includin2: (i) one equipped with pipe rams that fit the size of the drill pipe or tubin2: bein2: 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 casin2: or liner bein2: 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; 20 AAC 25.035(e)(2) is amended to read: (2) in coiled tubing unit operations, the well control equipment must include (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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, tubing, liner, or casing 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 tubing, liner, or casing being used, except that pipe rams need not be sized to BHAs and drill collars; and (B) for an operation. other than a casin2: or liner operation. with a maximum potential surface pressure of 2:reater than 5.000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], 2 Register _, _00 MISCELLANEouloARDS (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, tubing, liner, or casing 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 oftubing[, LINER, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; (C) for a casine: or liner operation with a maximum potential surface pressure of e:reater than 5.000 psi. (i) HOPE rams providine: for pipe. slip. cuttine:. and blindine: operations on the coiled tubine: in service; (m two hie:h pressure pack-offs. strippers. or annular type preventers; (im if pressure deployment of tools. tubine:. liner. or casine: is planned. a riser or lubricator sized to the HHA and providine: for pressure intee:rity from the HOPE rams to the hie:h pressure pack-off. stripper. or annular type preventer; (iv) at least one preventer equipped with pipe rams that fit the size of the tubine: beine: 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 casine: or liner beine: used. 20 AAC 25.035(e)(10) is amended to read: (10) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 3 Register , _00 MISCELLANEOU.OARDS percent of its rated working pressure; however, the commission will require that the BOPE be function pressure-tested weekly, ifthe commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance; (B) when installed, repaired, or changed on an exploratory or stratigraphic test well and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (C) if BOP [SEALING RAM TYPE] equipment has been used for well control or other equivalent purpose. or when routine use of the equipment may have compromised its effectiveness. the equipment [IT] must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (D) BOP ram and annular components except blind rams must be function-tested weekly, and all BOP ram and annular components must be function-tested after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing of blind rams must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; (E) for each BOPE test durine: drilline: and completion operations. variable bore rams must be function pressure tested to the required pressure on the smallest outside diameter (OD) and lare:est OD tubulars that may be used durine: that test cycle. except that variable bore rams need not be tested on BHAs and drill collars; Œ:l BOPE test results must be recorded as part ofthe daily record required by 20 AAC 25.070(1), and must be provided to the commission. in a format approved by the commission. within two days after completine: the test; !ill [(F)] at least 24 hours notice of each BOPE function pressure test must be provided to the commission so that a commission representative can witness the test; History: Eff. 4/13/80, Register 74; am 2/22/81, Register 77; am 4/2/86, Register 97; am 11/7/99, Register 152; am 10/24/2004, Register 172; am~_/_, Register ~ 4 Register , _00 MISCELLANEOU.OARDS Authority: AS 31.05.030 20 AAC 25.036(c)(1) is amended to read: (1) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], BOPE must have 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; and (B) for an operation other than a casin2 or liner operation. with a maximum potential surface pressure of 2reater than 5.000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], BOPE must have at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe or[,] tubing[, OR CASING] 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; (C) for a casin2 or liner operation with a maximum potential surface pressure of 2reater than 5.000 psi. BOPE must have at least four preventers. includin2 (i) one equipped with pipe rams that fit the size of the drill pipe or tubin2 bein2 used. except that pipe rams need not be sized to BRAs and drill collars: (m one equipped with pipe rams that fit the size of casin2 or liner bein2 used; (im one with blind rams. except that a subsea BOPE assembly must have blind/shear rams in place of blind rams; and 5 Register _, _00 MISCELLANEOU.OARDS (iv) one annular type; 20 AAC 25.036(c)(2) is amended to read: include (2) in coiled tubing unit operations, the well control equipment must (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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, tubing, liner, or casing 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; and (B) for an operation. other than a casin~ or liner operation with a maximum potential surface pressure of ~reater than 5.000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], (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, tubing, liner, or casing 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[, LINER, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; 6 Register _, ttoo MISCELLANEOU.OARDS (C) for a casinl! or liner operation with a maximum potential surface pressure of e:reater than 5.000 psi. (i) DOPE rams providine: for pipe. slip. cuttine:. and blindine: operations on the coiled tubine: in service; (ii) two hie:h pressure pack-offs. strippers. or annular tvpe preventers; (iii) if pressure deployment of tools. tubine:. liner. or casine: is planned. a riser or lubricator sized to the DHA and providine: for pressure intee:ritv from the DOPE rams to the hie:h pressure pack-off. stripper. or annular tvpe preventer; (iv) at least one preventer eauipped with pipe rams that fit the size of the tubine: beine: used. except that pipe rams need not be sized to DHAs and drill collars; and (v) at least one preventer eauipped with pipe rams that fit the size of casine: or liner beine: used; 20 AAC 25.036(d) is amended to read: (d) A BOPE assembly must be tested as follows: (1) when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; however, the commission will require that the BOPE be function pressure-tested weekly, if the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance; (2) when installed, repaired, or changed on an exploratory or stratigraphic test well and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non- compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (3) other well control equipment must be pressure-tested to the maximum potential wellhead pressure after each installation of the well control equipment and before wellbore entry, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; 7 Register , ~oo MISCELLANEOU.OARDS (4) if BOP [SEALING RAM TYPE] equipment has been used for well control or other equivalent purpose. or when routine use of the equipment may have compromised its effectiveness. the equipment [IT] must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (5) BOP ram and annular components except blind rams must be function- tested weekly, and all BOP ram and annular components must be function-tested after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing of blind rams must be performed as soon as possible after the workstring is pulled out of the well and the BRA clears the BOP; (6) for each DOPE test durin2 drillin2 and completion operations. variable bore rams must be function pressure tested to the required pressure on the smallest OD and lar2est OD tubulars that may be used durin2 that test cycle. except that variable bore rams need not be tested on DHAs and drill collars; ill DOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1). and must be provided to the commission. in a format approved by the commission. within 2 days after completin2 the test; Œl.[(7)] at least 24 hours notice of each BOPE function pressure test must be provided to the commission so that a representative of the commission can witness the test. History: Eff. 11/7/99, Register 152; am 10/24/2004, Register 172; am_/_/_, Register ~ Authority: AS 31.05.030 20 AAC 25.285(c)(2) is amended to read: (2) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 3.000 psi or less [REQUIRING A BOP STACK LESS THAT API 5K], at least three preventers, including 8 Register _, _00 MISCELLANEOU.OARDS (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; and (B) for an operation. other than a casine: or liner operation. with a maximum potential surface pressure of e:reater than 3.000 psi [REQUIRING A BOP STACK EQUAL TO OR GREATER THAN API 5K], at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe or[,] tubing[, OR CASING] 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; (C) for a casine: or liner operation. with a maximum potential surface pressure of e:reater than 3.000 psi. at least four preventers. includine: (i) one equipped with pipe rams that fit the size of the drill pipe or tubine: beine: used. except that pipe rams need not be sized to BRAs and drill collars: (m one equipped with pipe rams that fit the size of casine: or liner beine: 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: 20 AAC 25.285(c)(3) is amended to read: (3) in coiled tubing unit operations, 9 Register _, ~oo MISCELLANEOulOARDS (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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 ofthe tubing, liner, or casing being used, except that pipe rams need not be sized to BHAs and drill collars; and (B) for an operation. other than a casine: or liner operation. with a maximum potential surface pressure of e:reater than 5.000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], (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[, LINER, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; (C) for a casine: or liner operation with a maximum potential surface pressure of e:reater than 5.000 psi. (i) BOPE rams providine: for pipe. slip. cuttine:. and blindine: operations on the coiled tubine: in service; (ii) two hie:h pressure pack-offs. strippers. or annular type preventers; 10 Register _, _00 MIS CELLANEOU'OARD S (iii) if pressure deployment of tools is planned. a riser or lubricator sized to the BHA and providin2 for pressure inte2ritv from the BOPE rams to the hi2h pressure pack-off. stripper. or annular type preventer; (iv) at least one preventer equipped with pipe rams that fit the size of the tubin2 bein2 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 casin2 or liner bein2 used; 20 AAC 25.285(f) is amended to read: (f) The BOPE must be tested as follows: (1) when installed, repaired, or changed, and at least once a week thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which the BOPE may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (2) if BOP [SEALING RAM TYPE] equipment has been used for well control or other equivalent purpose. or when routine use of the equipment may have compromised its effectiveness, the equipment [IT] must be function pressure-tested before the next wellbore entry, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which that equipment may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; (4) for each BOPE test durin2 drillin2 and completion operations. variable bore rams must be function pressure tested to the required pressure on the smallest OD and lar2est OD tubulars that may be used durin2 that test cycle. except that variable bore rams need not be tested on BHAs and drill collars; 11 Register , ~oo MISCELLANEouloARDS ill BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1), and must be provided to the commission, in a format approved bv the commission, within two days after completine: the test; ~[(5)] at least 24 hours notice of each BOPE function pressure test must be provided so that a representative of the commission can witness the test; [.] ill the operator shall report to the commission within 24 hours any instance of BOPE use to prevent the flow of fluids from a well. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152; am _1_1_, Register -> Authority: AS 31.05.030 20.AAC 25.286(d)(1) is amended to read: (1) at least one positive seal manual or hydraulic valve or blind ram flanged to the wellhead or tree; (2) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 5,000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], 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; and (B) for an operation, other than a casine: or liner operation, with a maximum potential surface pressure of e:reater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe or[,] tubing[, OR CASING] being used, except that pipe rams need not be sized to BHAs and drill collars; 12 Register _, _00 MISCELLANEouloARDS (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; (C) for a casine: or liner operation with a maximum potential surface pressure of e:reater than 5.000 psi. at least four preventers. includine: (i) one equipped with pipe rams that fit the size of the drill pipe or tubine: beine: used. except that pipe rams need not be sized to BHAs and drill collars; (in one equipped with pipe rams that fit the size of casine: or liner beine: used; (iii) one with blind rams. except that a subsea BOPE assemblv must have blind/shear rams in place of blind rams; and (iv) one annular type; 20 AAC 25.286(d)(3) is amended to read: (3) in coiled tubing unit operations, (A) for an operation with a maximum potential surface pressure of 5.000 psi or less [REQUIRING A BOP STACK EQUAL TO OR LESS THAN API 5K], (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; and 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 (B) for an operation with a maximum potential surface pressure of greater than 5,000 psi [REQUIRING A BOP STACK GREATER THAN API 5K], 13 Register , ~oo MISCELLANEOultOARDS (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; and (iií) 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; 20 AAC 25.286(e) is amended to read: ( e) The operator shall test the BOPE assembly as follows: (1) at least once a week, and after each [USE,] repair, [OR] change, or use for well control or other equivalent purpose. or when routine use of the equipment may have compromised its effectiveness. BOP[E] equipment [PIPE AND BLIND RAMS] must be function pressure-tested, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which they may be subjected, except that the annular type preventer need not be tested to more than 50 percent of its rated working pressure; (2) after each installation of BOPE or other well control equipment, the equipment must be pressure-tested, before well bore entry, to the maximum potential wellhead pressure to which it may be subjected, except that when testing against the annular type preventer, pressure testing need not exceed 50 percent of the rated working pressure of the annular type preventer; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function-testing must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; (4) after each well installation of the BOPE, the BOPE hydraulic connections to the rams must be visually verified before well bore entry;[.] (5) for each BOPE test durin2 drillin2 and completion operations. variable bore rams must be function pressure tested to the required pressure on the smallest OD and lar2est OD tubulars that may be used durin2 that test cycle. except that variable bore rams need not be tested on BRAs and drill collars; 14 Register _, ~oo MISCELLANEouloARDS (6) DOPE test results must be recorded as part of the daily record required by 20 AAC 25.0700). and must be provided to the commission. in a format approved by the commission. within two days after completing the test; (7) at least 24 hours notice of each DOPE function pressure test must be provided so that a representative of the commission can witness the test; (8) the operator shall report to the commission within 24 hours any instance of DOPE use to prevent the flow of fluids from a well. History: Eff. 11/7/99, Register 152; am~_/_, Register ~ Authority: AS 31.05.030 15