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Image Project Order File Cover Page XNVZE 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 dt.lring a special rescan activity or are viewable by direct inspection of the file. ~~~ Order File Identifier Organizing (done) ^ Two-sided III IIiIII II III II III Rescan Needed III II I ^ I IIIIIIII IIII RESCAN DIGITAL DATA OVERSIZED (Scannable) ^ Golor Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by ^ Poor Quality Originals: a Large Scanner ^ Other: OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ 3 O /s! Project Proofing III IIIIII VIII II III BY: Maria Date: ~ ~ /s/ Scanning Preparation x 30 = + =TOTAL PAGES BY: Maria 5" ~ ~ Date: (Count does not include cover sheet) /s/ Production Scanning III IIIIII VIII II III Stage 1 Page Count from Scanned File: d ~ (Count does include cover sheet) Page Count Ma tches Number in Scanning Preparation: ~YES NO BY: Maria Date: ~ 3 /O _ /s/ Stage 7 If NO in stage 1 , page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II iI II I IIII ((III ReScanned III IIiIIIIIIII VIII BY: Maria Date: fs/ Comments about this file: Quality Checked I II ( I'III III IIII III 10/6/2005 Orders File Cover Page.doc ~ ~ INDEX OTHER ORDER NO. 28 Regulations on Blowout Prevention 20 AAC 25.035 and 20 AAC 25.036 1. - ------------ Draft copies of the regulation BOPE 2. April 16, 2004 File opening to Dept of Law 3. April 16, 2004 Notice of Hearing, Affidavit of publication, a-mail Distribution list, bulk mailing 4. Apri120, 2004 Approved File Opening from AGO 5. April 22, 2004 Notice of Hearing, Affidavit of publication, a-mail Distribution list, bulk mailing 6. June 8, 2004 Transcript 7. June 8, 2004 Sign In Sheet 8. June 8, 2004 E-mail from Jim Regg to file 9. June 16, 2004 Public Meeting Minutes Adopting Regulation 10. June 16, 2004 6/16/04 version of proposed regulation 11. June 18, 2004 Notice of Hearing, Affidavit of publication, a-mail Distribution list, bulk mailing 12. August 12, 2004 Public Meeting Minutes 8/11/04 13. August 19, 2004 Regulation Package submitted to AGO 14. July 14, 2004 Proposed revisions to the final regulation 15. Background information and analysis 16. September 24, 2004 e-mail re: effective date 17. October 25, 2004 Final Regulations from the AGO Juneau 18. October 25, 2004 Post Hearing Notice Other Order 28 11/10/2004 11:32 9074655400 LT GOV LOREN LEMAN PAGE 01 ~~F, ~~~~ ~ -.='~ ::'='~~ -~j, State Capital ~ '";~.~• • ,Juneau, Alaska 99581 ~`,'~• wt' `-'^~ s~o vuar rr~A~e, sul~~ imo . Agcharage. Alaska 99501 907•.269,460 269.0263rast 907.465.3520 465-540ornx www.H,govstare,ak.us rr_Governor@$ovstate.ak.us Lieutenant Gov~rno~r .Loren Lerman. MEMQi~ANDUM ., ~ . bAT~,: ~ Octob~ ~r~7, 2Q04 TO:Mike °f ibbles, Regufations C©ntact ~ .~ Depar9 went of. Administration • .. . FROM: Robe.ri Pearson k.~ ~ ~ ' Admra ~strativeCode Coordinator . S.UBJEGT: Parma gent ~ilin.g. of FteguFetion(s) RE:. ~ ~ Alaska Oil and.'Gas Comm.; i3lowout Pre'venttin Equipn:aent (20 AAC ~ ~25) ~ ~ ... ~.. C7ate re,grtlation .s.igi -Ed by L7.eutenant Governor (or designee) ~ Sep: 24, 2t}0~~ ~ . Date Regulation :eft eCtivrE , Oct: 24r -2004. i Attorney General ~~ le No. , ~ ~ ~ ~ . . ' 3-0~4;~0.;159 . 99 Regulation wil! be .I printed in ~ ~ Register1 f 72, January.2005 , ••, .'ATTACHMSNTS~ 1. Signed Ado:ptia i QrderlCertifi.cation of Compliance ~ X ~. ' 2. Designee's Cer° ~ificate if applicable X 'cc:, S. J~. Jordan, CSapr . ofi Law 11/16/2604 11:32 9674655460 LT GOV LOREN LEMAN PAGE 02 ORDER CERTIFYING TFIE CHAI`1CxES TO REG'UI. ~1TIONS Ol, TIC ALASKA OIL AND GAS CONSERVATION GOMMISSION The attached three sages of regulations, dealing with blowouts preveution equipment under 20 AAC 25, are hereb+ certified to be a correct copy of the regulation changes that the Alaska Oil and Gras Conserirat on Commissiaa~ adopted at its August l 1,' 2004 public meeting, under the authority of AS :? 1.05.034, and after compliance with the Administrative Procedure Act (AS 44.62), specifi, ally including notice under ,AS 44.62.190 sad 44.62.200 and opportunity for public comment nn~s ex AS 44.62.210. This action is zlot ea pealed to require an increased appzopriation: Although no public ~omrnents were received, the .Alaska Oil sad Gas Conservation Caznmission paid spacial attentit n to the cost to private persons of the regulatory action being taken. The regulation cha~_ ges described. in this order take effect on the30th day ex they have been filed, by the lieutena nt governor, as provided in AS 44.62.180. a DATE: Auk ;ust 11, 2004 ,Ar.~ ;horage, Alaska t FILING C'fiRTIFiCATION I, __ . 7 u, Lieutenant Go~ver~xo or the State of Alaska, certify that om. s ~ ~ , 200 ~ at 2'~.na., I filed the attached regulations according to the provisions of AS 44.52.040 - 14.62.120. Lieutenant Governor ~~ Effective: 0 ~; T'• 2 `~~ 2.~o y Register: ~ ~ ,~, ~ ~^~ ~~' 11/10/2004 11:32 9074655400 LT GOV LOREN LEMAN L1EU'tENANT GOVERNOR S~'A.'>t'~ OF AY,ASS~i, FOR I~ELEI:-ATION OF LIEU'~ENANY GOVERNOR'S AUTHORITY PAGE 03 1, LOREN LEI11fAN, LIEUTENANT GOVERN01~ O1= THE STATE OF ALASKA, as authorized icy AS 44.9 9.25, designate the following state offici2~l .to serve as temporary cus~ ~adisn of the state seal and as the officer to p®rforrn the Administrative I~r~>'cedure Act filing functions and the authenticating . functions of the lieutenant governor during such time as t act as governor, am absent from t ie State, or am otherwise unavailable at the state capit2~l. to perform these fuu ~ctfons~ Annette KrE. itzer, Chi®f-of-Staff, Office of the Lieutertiant Governor •, IN TESTIMOMf WHEREOC=, !have set my hand and a#flxed hereto the Seal of the State of Alaska, at Juneau, the Capitol, Tht~ ............. `~...,.,..... y . A.D. Zo.Q.,~..".,........ ~. LiEUTE:NAhIT OOyERIVpR P.O. F! ~z i'to0t5 Juneau, Ataaka 99871-0016 Phone (907 465.31620 Fsz ( daer;54O0 11/10/2004 11:32 9074655400 Register l?~, `~i rJ•. _2005 LT GOV L~REN LEMAN i '1VIYSCELLAN,EOUS BOARDS 20 A,AC 25.035(e)(10) ~i ~ repealed and readopted and a newv paragraph is added to read: (10) the k3QF>~ must be tested as follows: PAGE 04 (A) when i :tstalled, repaired, or changed on a development or sexvice well andeso-~i~ ~ ~1 ' at time intervals not to exceed each days thereafter, BOpE, including kelIy vah~ ;s, emergency valves, and choke manifolds, must be function pressure~tested to the required workin ;pressure specified in the approved Permit to Dri11, using anon-eornpressible fluid, except that an annular c reverter need not be tested to moxe than S0 percent of its rate goweve~ -~. c,orkwussion +.vill rec~u r2 -t~c~ tY~ FQPE b2 functian ptessr~re,-~~s}ed w¢~2kle~, if `Hv+- corarKisSion wor 'ng pressure; d~1'¢.r-v~ln.e..s }ham" a. w¢~kV~ a~3Ffc. pres5t-r2 i-¢.5i^ i~~arvcJ is inJdiea~ecl by d.. po~ri~it~lar' atr7ltin~C hg's FsOPE pe.rfc+rrKanca.; (B) when : nstalled, xepaired, or changed an an exploratory or stratigraphic test we11 and at least once a week tl: wreafter, BOl~'E, including kelly valves, emergency valves, and choke rnanifolds, must be fiuiction pr~ .sure-tested 1io the required working pressure speci.~ed in the approved Pez~mit to Dri11, using a nonmc~ impressible fluid, except that an annular type preventer xxeed not be tested to more than 50 percent of i~ s rated working pressure; (C) if BQ:I 'sealing ram type equipx,~ent has been used, it rnust be fuxACtion pressure-tested, before the next wet: bare entry, to tk~e required working pressure specified in the approved Pexmtit to Drill, using a nort-c impressible fluid, except thafi an annular type preventer need not be tested to more than 50 percent of ;i s rated working pressure; ~~,} (D) $aP i ~rr~ and annular components blind rains must be function,-tested weekly, and all BO'' ram and. annular components must be functioxa-tested after an action that disconnects Uae hyd -colic system lines fxozn the BOPE, except that if the workstring is earttirtuously in the we11, functio1 -testing of blind ra;nns rnust be performed as soon as possible after the workstring is pulled out of the Ne11 and the $HA clears the BOF'; ()) B0~'~: test results must be recorded as part of the daily record required by 20 AAC zs.o~o(1); (F) at leasa ; 2,4 hours notice: of each $QFE function pressure test must be provided to the 11/10/2004 11:32 9074655400 LT GOV LOREN LEMAN PAGE 05 Register P~ TA nl_. ?00 ~ MISCELLANEOUS BOARDS commission so that f comtxiission representative can witness the test; (11) the opexat~ •r shall xeport to the comn'~ission within 24 hours any instance of BOpE use to prevent the flow of fluid ~ from a well. (Eff. 4/13/$0, Register ;r 1; any 2/22181, xegister 77; am 4/2/86, Register 97; am 11/7/99, Register 152; am Ic9' l 2~ 120 , R~;;ister l~ ~~ how~.ver, i'#~ c,o~u.wussian will rect„y}r¢. 'nc~~' ~~4~ bz f'unci'ian ~r¢~5urer~'e.s'r¢.d ~wee.l<It~, +F }'ha. contir+tis5idn Authority: AS 31!.5.030 c~zir~-rmin~s ~h~' ~ ~~k1~'$~P~ pr¢ssur~¢, -k~ea~' in~'~rval is inc~~Cor¢.d- by o~ ~r~'iGU1a.r c~illin~ rig`s $oPE ~2.rfors:v.a~nC.1t.~ _~ 20 AAC 25.036(d) is xe; -ealed axad readopted and a new subsection is added to read: (d) A BOPE assert b1y must be tested as follows: (1) when insta led, repaired, or changed on a development or service well andp-es~t' u IH .B9P~.pet~~~~at ~ ime intet'vals not to ~xeeed each days thezeafter,130PE, including kelly valves, emergency vale ;s, and choke manifolds, must be function pressure-tested to the required working pressure specified inn. the approved Permit to Drill, using a noza-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (2) when inst: fled, repaired, or changed on an exploratory or stratigraphic test well and at least once a week thereafter, BOPS, including ke11y valves, emergency valves, a»d choke manifolds, must be functio:r~ pressure-testes . to the required working pressure speeif•zed in the approved Permit to Drill, using a non-compressible flu.: d, except that an annular type preventer need not be tested to more than 50 percent of its rated working prti ssure; (3) other well control equipment must be pressure-tested to the maximum potential wellhead pressure after each ins-t ~1lation of the well control equipzxtent and before wellbore entry, except that an annulax type preventer Zeed not be tested to more than. 50 percent of its rated working pressure; (A~) it' BOP se ding xam type equipment has been used, it must be fimctionpressare-tested, before the next wellbore entr, , to the required working pressure specified in the approved Permit to Aril/, using a non-compressible flair ,except that an annular type preventer need not be tested to more than 50 percent 2 11/10/2004 11:32 9074655400 Register 1? ~-, . ~~ ^f '-, ?00 ~ LT GOV LOREN LEMAN M)CSCELLANEOUS BOARDS PAGE 06 of its xated working press ore; zxcszp} (5) BOP ram ax d annular components ~ blind rams must be function-bested weekly, and all BOP ram and ant ular components must be fuxwction~tested aftex an action that disconnects the hydraulic system 1i;nes f~ nn the BOPS, except that if the workstring is continuously in the well, function- testing oFblind rams mu ~t be performed as soon as possible after the worl~string is pulled out of the well and the BHA clears the ] 3aP; (6) test results oust be recorded as part of the daily record required by 20 AAC 25.070(1}; (7} at least 241 yours notice of each fiction pxessure test must be provided to the coxtunission so that a representative of t ie commission can witness the test. (g) The operator sl al1 report to the catnrnission within 24 !lours any instance of BOPE use to prevent the flow of fluids from ~ Well_ (11ff 11!7199, Register 152; am ~!z ~~/ 2m o ,Register 7 ~..~ Authority; AS 31.' X5.030 3 X18 • • Amended Regulations Dealing with Blowout Prevention Equipment The Alaska Oil and Gas Conservation Commission has amended its regulations dealing with blowout prevention equipment ("BOPE"), 20 AAC 25.035 and 20 AAAC 25.036. The amendments increase the maximum testing interval from seven days to 14 days, make other changes in the timing requirements for BOPE testing, and add reporting provisions relating to the use of BOPE. The Lieutenant Governor signed and filed the regulation changes on September 24, 2004, with an effective date of October 24, 2004. For further information or to obtain a copy of the amended regulations, contact Jody Colombie at (907) 793-1221, fax (907) 276-7542, or e-mail Jody Colombie ,admin.state.ak.us. Post Hearing Notice Subject: Post Hearing Notice From: Jody Colombie <jody colombie@admin.state.ak.us> Date: Mon, 25 Oct 2004 10:44:34 -0800 "To: unelisclo~sed-recipients:; BCC'.: Robert E Mintz <robert mintzlal<tw.state.ak.us-~~. Christine Hansen c.hanscn ce,iogec.sta[e.ok.us>, "~errie FIubble ~ -hubhletl!ubh.c~~m-~, S~,nclra Sttwi~~an <StewmaSDt~r.F3P.com ~, Scou ~ Cammy ~I'a~~lor <staylc~rrcr alaska.net= , stanckj stanckj«~ur~o~~tl.com . eeolaw ecola~~~~u; rustees.org= , roserags~iale °'roseragsdalc~u:gci.net--. trmjrl ~lrmjrl ~,cr;a~l.com>, Jbr~ddle <jbricjdlci~i~n~arathun~~il.c~~m=~•_ rockhill ~~-r~~ckhillyda~~ga.~~r~~%, shanc~~ --shane~~~~t~,evergreennas.com>, j~l~~rlirlgt~m =jdarlin~~t~n«i torest~~il.c;vrn~, n~ls~~n =:keelson!c~i,petrolei~mnc~~~s.com%, :;hodd~ ~clx~d~ly(~r usibclli.com~. Mark llaltoti mark.dalton~rhdrinc.e.om->, Shannon Donnelly <-Shannon.donnell~~~~conoco~hillips.eom , "Mark P. ~~'orcestrr" <mark.~~.w~or~ester@eQnocophillips.cum=>, "Jerry C. Dethlefs,~ -~crrv~.e.Beth]~fs~u;eono~ohhillips.cr~m ~~, I3oh <hobl~u.inlctkcci~er.urb:~~, wdv ~_~«1v~ dtu~.sta~e.~~.u~-~, tjr ~tjr~<<~inr.state.ak.us= , bhritch <bbrit~:h~u alaska.net->, mjnelson <mjnelson@purvingertz.com>, C"harks O'Donnell ~~ charles.u'donnell~~ veco.com ~>, "Randy L. Skillern" <SkilleRL@BP.eom>, "Deborah J. Jones" ~-JonesD6@BP.com=, "Paul G. Hyatt" <hyattpg@BP.com>, "Steven R. Rossberg" <RossbeRS~i BP.com ~, Leis ~=lois@inletkeeher.org~=. Dan Bross kuacnews@kuac.or~~=>, Gordon Pos~aisil <PoShisGlct BP.com=~, "Francis S. Sommer" <Sommerl~S~u:BP.com>, Mikel Schultz <Mikel.SchulV(""~i,E3Y.~om>. "Vick W. Glover" <GhwerN~~ ~ci;BP.cum>,'DarylJ. f:leC,i~in" ~'KleppiDC~uBP.ce>m>, "Janet D. Platt" -=PlattJD~BP.com~~. "Rosanne M. Jacobsen" ~JacobsRMiu~BP.c©m>, ddonkel ~'~lclonkel(~;efl.rr.com=~; Collins ~9uunt <eollins mount~revenue.state.ak.us->_ mcka~ "mc~.ay~~rgci.net~ . Barbara F Fullmer "harhara.t:lullmer@con~eophillips.com~, hocastwf <t~ocastwl~u;hp.com:>, Charles Barker ~~ harker~~r;usgs.gov>, doug_schul~~e ~~~ dougschultzc(c~xtoencrg~.com: ~, I Iank .11fi~rd ~~-hank.alf~rd@.exxonmobiLcom-~ . !~1ark ILI~VaC ~yesnol :fir gci.net =. gspfofl' <gsploti~~laurorapo~~~cr.com>, Gregg i~adv <~,regg.na~v~u;shell.co~n- ~, Frcri Stec~c <Fred.steccri~i statc.s~l.us =. r~:rott~ ~-_rcrott~~~<<'ch2m.com- . jejones ~ ;jejones~~aurorapower.~;om>, rlapa <dapaC~ralaska.net=~-, iro~lerick ~_jroderick~u.gri.net-~. evanc~~ e~anc_v c~seal-tite.net>, "James M. Ruud" ~ j;tines.nl.n~ud@conc~cophillips.c~~n~- ,Brit Lively =map<ilatikai~~~a1{.net>, lab jah~~i dnr.state.akus>, Kurt F. Olson ~_kurt_ olsonCIegis.state.akus=, buy>n~,jc ~=huonoje<«hh.cu~r~=>, Mark Hanley markhanl~~~cr;anadark~~.com:=-, lor~r~_Ieman <loren_leman~go~~.state.ak.us>, Julie. Houle <julie_h©ulcr~i;dnr.state.ak.us>, J~~hn ~~ Katz <jwkatz(~lsso.org>, Suaan J f-till -suian hill c~dec.state.ak.us=°, tablerk ~~to[~lcrk~r~utiocal.c~~m ~, Br~~d~ ~"-bradv~u;ao~~a.or~=', Brian Hai-clock <beh~~dnr.statc.ak.us=. hpopp ~~.hh~~hp~u;liorough.kcnai.ak.us=. Jim While. <jit»tit hittrresat~.rr.eom-=. "J~hn S. Halvorth" <_john.s.haworth~~i.c~ronmohil.com ~, mart_v <mart~~c~~rkindustrial.com-. ghammon5 ° ghammons~u~aol.coin -, rmclcan <rn~clean'~c polios.alaska.nct?, mkm72~lU ~ _mkm7~(~O~~laol.com-~, Brian Gillcshic <ifbmg~uaa.alaska.edu- , Davie L Boelens ~ dboelrns~a,.aur~>rapower.cr~m=, ~Icxid L~urkce <TDURKEE~c1K1~~iG.ccn~ ~~, Gary Schultz ~gary schulti!«::dnr.statc.ak.us>, Way7~e Ranvier <RANGIER(uj~etro-canada.ca-~,~Bill Miller <Bill !~lill~rr'u~ti~alaska.coir~>. Bra~Idr~n Ga~~non <bgagnon ct;br~nalaw.com.. Paul ~Vinslo~~~ ~pmwinsl~,~~~~u-l~~r~stc,il.c~~~1~-=.Garry Carron <catrongr~uhE~.com>; Sharmainc Cohcland =copelasv(uh~~.com>, ,Kristin Dirks <kristin_dirk~rci-dnr.statc.ak.us->. havnell Lenlall `-kjzeman~~i>,marat.hunoil.com~>, John ~I~owcr <John.To~~e~ r~i;cia.doe.go~ >, Bill Fo~~ lcr ~ Bi11 Fowler a anadarko.COM=~. Vaughn 5~~artz vaughnswartz@rbccm.coin ~_ Scott Cransvvick ~~-scutt.cransw~iek<<r~mms.gov>, Brad McKim mckimbs@BP.com> 1 of 2 10/25/2004 10:44 AM Post Hearing Notice Content-Type: application/msword post_hearing_notice_.doc Content-Encoding: base64 _ __ 2 of 2 10/25/2004 10:44 AM 20 AAC 25 r • Subject: 20 AAC 25 From: Jody Colombie <Jody_colombie@admin.state.ak.us> Date: Mon, 25 Oct 2004 09:43:42 -0800 To: ~~n~isclosed-recipients:; BCC: Angela Webb <an~i~ ~wehh~cr.a~lmin.statt.~zk.us.-. Cynthia ~3 R-1civer <brcn lnciver~r admin.statc.ak.us> Please post --- _._._ --. i Content-Type: application/msword post_hearing_notice.doc Content-Encoding: base64 1 of 1 10/25/2004 10:44 AM x$17 10/25/2004 10:00 FAK 9072798644 ~. ATTORNEY GENERAL'S OFF ~ AOGCC ' • QfFice~ of the Attorney General OiI, Gas & MFning Section 1031 W. 4th Avenue, Suite 200 Anchorage, AK 98501-1994 _ Phone: (9Q7) 269-5255 Fax: (907) 27g-as4a Fax Transmiiss~on r~ool/005 The information contained in fhls fax is confidential and/or privileged. this fax !s intended #o be revlowed initially by only the individual named below. If the reader of this transmittal page is no# the intended recipient or a rQpresentafive of the intended recipient you are hereby noff5®d thaf any review, dfssennination or copying of this fax or ifie information contained herein is prohibifed. ~tf you have recei~ned Phis fax in e-rar, pisses immediately nofity ~e senderby telephone and re[um fhis fax fa the sender of the above address. Thank you. To: From: Subject: Message: Fax #: ~Cr,~C' C ~~C ~ ' ~1 ~i \ 1'~ Date: ~, ~ f Pages: i If you da not receive atl the pages or have any this fax, please call for assistance of (DOT} inGuding cover sheet ,, ~ ~_ ,. Taal -.. a*M'~;-~N, '~ ~4,1N'y a; :,}dA~ ' ~. '` . , Stems with 5255, 10/25/2004 10:00 FAQ 9072798644 ATTORNEY GENERAL'S OFF } AOGCC I~j002/005 .~ • ~ 1 . ME]MOFtANaULTM State f Alaska rtment of Law to: rbha K. Norman, Chair aATE: September 1 , 2004 Alaska Oil and Gas Conservation Commission File No,: 993.04"0159. TELEPHONE NO,: 465-3600 FROM: Steven C. Weaver sue,~ecr: Regulations :blowout preven- Agsistant Attorney General tion equipm t (HOPE) (20 AAC T~.egislation/Regulations Section--Juneau 25.235(e)(10 (11); 20 AAC . 25.236(d), ( ) under AS 44.b2.060, we have reviewer the attached regulations ges by the Alaska Oil and .Gas Conservation Coz~amission, and approve the changes for ffi" by the lieutenant governop. I have revi.ewcd this project under a specific delegation dated eptember I4, 2004 from thr Regulations Attorney. A duplicate original of this memorandum i being fiu~ished to the lieutenant governor, along with the three pages of regulations and the rel ed documents. you might wish to contact the lieutenant governor's office to effective date of the attached regulation changes. The Tune 18, 2004 public notice amd the August 11, 2004 certi that this ~ action is not expected to require an increased appropriation. under A$ 44.62.195 is not required. I>a a~ccardance with AS 44.62.125(b)(6), some corrections have regulatioins, as shown on the attached. copy. sew a wlone: [Gavin Ssool~, Lleputy Cozrmrissionar Bc Regulations Comet Deparm~ent of AdtmtnisLratiou Robot $. Mintz Aaaistapt At6oraay Gea~etsl oil, Qss & Mining SeCrlon--Pmctitorage the Sling date and order both state re, a fiscal note made in the 10/25/2004 10:00 FAX 9072798644 ltegistet ~, 200 5 ATTORNEY GENERAL'S OFF -~ AOGCC • MISCLLLANL~OUS HOARDS ~joo3/o05 20 AAA 25.035(e}(10) is repealed and readopted and a new paragraph is added to (10) the BOPS must be tested as follows; (A) when installed, repaired, or changed on a devaelopment or s+~G~~~~lat time intervals not to exceed each ly days tea ' ~aaP>;, 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 non-compressible fluid, except that an annular reverter need not be tested to more than 50 ercent of its to howeve., ~ GpwtwomSlCn will ui~Q i'Fta!' iiv. 8bt'!" 6¢, func+ion pregsure•+~z5#ed- w It~y, if -H+,e. carKwc+ission war ~ $ press det~rr~itie,s +hat cs. urea-kid paPr~ pressure tEai' int va.1 is i.~dlc~a}ed. by a.. gnrticulo~r aLrill~'^~~ry9's ROPE rfoPnaq~c~z~ ($) when installed, repaired, or c~ianged on an exploratory or strati hie test well and at least once a week therea#ler, BOFE, including kelly valves, emergency valves, ~nd choke manifolds, must be function pressure-tested to the required working pressure specified in toe approved Permit to Drill, using a non~ompressible fluid, except that an amtular type preventer nee~3 not be tested to more than 50 percent of its rated working pressure; (G") if BQP sealing ram type equipment has been used, it must be function pressuratested, befdre the next wellbore entry, to the required working pressure specified in th approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer ne not be tested to morn thaa~ SO percent of its rated working pressure; ~P} (D) HOP ram and annular components blind rams must fimctior~-tested weeldy, and all BOP ram and annular components must be function~tested a an action that disc~ects the hydraulic system lines from the BOPI~, except that if the works~ring is continuously in the well, function-testing of blind rams must be performed as soon as possib~ after the workstring is pulled out of the well and the HA:A clears the BOP; (E) 130PE test a~esults must be recorded as part of the daily record required by 20 AAC 25.OI~0(1); (F) at least 24 hours notice of each HOPE function prossure test must ~-c provided to the 1 10/25/2004 10:00 FAX 9072798644 ATTORNEY GENERAL'S OFF -~ AOGCC - -Register 200 JTri MISCELLANEOUS BOARDS commission so that a commission representative can witness the test; (11) the operator shall report to the commission within 24 hours any prevent the flow of fluids from a well. (Eff. 4/y 3/80, Register 74; am 2122/81, register 77; am 4/2/86, Register 97; am 11 / / ,Register ^~ ~ ~ ho waves, tha. ce ~wti ss io n {~ Funt.'Fic~n ~rtSSUrc-tc,Si Authority: AS 31 05,030 ~~¢r~;,,QS ~,ai- ci u-eckl~ is inc~ieci}~2.d ~' a pesri'icu 4erfar~w.av, e~~ 20 AAC 25:036(d) is repealed and readopted and a new subsection is added to rep (d) A BOFE assembly must be tested as follows: (1) when installed, repaired, or changed an a development or service ~' ly ~Al?Frp~Forssa~eeJat time intervals not to exceed each days thereafter, (~j 004/005 of BOFE use to Register I52; am U rp~,ulr¢, thc~!' t1vr.'BCPE ~ we.akl~. , if iiu. torKn~~ssian $O~PE laressurt. -hest ~ni•¢rv0.~ drilli.,9 fi~',5 $4PE including kelly valves, emergency valves, and choke rnanifolds, must be fanctian pressure tested ~ the required working pressure specified in the approved Permit to Thill, using a non~ornpressible fluid, ~xcept that an aruaular type preyventer need not be tested to more than 50 percent of its rated working (2) when installed, repaired, or changed on an exploratory or stratigraphid test well and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and cho manifolds, must be function pressure-tested to the required working pressure speoifaed in the approved ea~ni,t to Drill, using anon-compressible fluid, except that an annular type prev+enter need not be tested more than 50 percent of its rated working pressure; (3) other well control equipment must be pressure-tested to the pressure after each iraBtallation of the well control equipment and before wellbare annular type prevcnter need not be tested to more than 50 percent of its rated (4) if BOP sealing ram type ecluapment lass been used, it must be function the xaexti wellbare entry, to the required workirsg pressure specified in the approved non-compressible fluid, except that an annular type preventer need not be tested to tential wellhead y, except that an pressure; :ssuretested, before nrrit to lar'ill, using a ire than 50 gereent 2 10/25/2004 10:00 FAX 9072798644 . ' ._ ,Register 200 ~ ATTORNEY GENERAL'S OFF -~ AOGCC MISCELLANEOUS 13OA~DS of its rated working pressure; axcAp+ (5) BOP ram and annular components blind rams must be fu and all BOP r'am and annular eomponent8 must be functiontested after an action t] hydraulib system lines from the BOPS, except that if the workstring is continuousl testing of blind rams must be performed as soon as possible after the workstring is and the BHA clears the BOP; (6) test results must be reoorded as part of the daily record required by 20 ('~ at least 24 hours notice of each function pressure test must be provide that a npresenffitive of the commission can wiirless the test, (,~) ' The operator 511311 repOTt to t~C CQ1TlguB9I0Il withm 24 hours wily 121St&I1CC the flow of fluids from a well, (Eff, 11/7/99, Register 15Z; am / / Authority: AS 31.05.030 ~ 005/005 .ion tested weekly, ~t disconnect$ the in the well, function- idled out of the well #AC 25.070{1); to the commission so ,'I3UYlr use to prevent Register _~ 3 ..x.16 [Fwd: Re: AOGCC Regulations] Subject: [Fwd: Re: AOGCC Regulations] From: John Norman <johnnorman@admin.state.ak.us> Date: Fri, 24 Sep 2004 17:44:41 -0800 To: Jody J Colombie <jody_colombie@admin.state.ak.us> for the file -------- Original Message -------- Subject:Re: AOGCC Regulations Date:Fri, 24 Sep 2004 15:37:32 -0800 From:Robert Pearson <robert pearson~a,gov.state.ak.us> Organization:Alaska Office of the Lieutenant Governor To:Robert Pearson <robert pearson(a,gov.state.ak.us> CC:John K Norman <john norman(uadmin.state.ak.us>, Kevin A Brooks <kevin brooksnaadmin.state.ak.us>, Steven C Weaver <steve weaver cr,law.state.ak.us>, Barbara A Jordan <bj jordan(a,law.state.ak.us> References:<4154AC09.1060009(cr~,gov. state. ak.us> Correction: effective date is Oct. 24, 2004. Apologies for the error!/Robert Robert Pearson wrote: The Lieutenant Governor today, Sep. 24, 2004 filed regulations from the Alaska Oil and Gas Conservation Commission re: Blowout prevention equipment (BOPE) (20 AAC 25; AG file no. 993-04-0159), effective Oct. 25, 2004, will be published in Register 172, Jan. 2005. Hard copy will follow./Robert __ __._ !'; John K. Norman <John Norman(a~admin.state.us> Commissioner Alaska Oil & Gas Conservation Commission 1 of 1 9/28/2004 11:40 AM ~.9 5 ~ ~ Review of Historical Blowout Prevention Equipment Tests Alaska Oil and Gas Conservation Commission May 2004 Introduction and Back r Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") regulation) requires blowout prevention equipment to be function pressure tested when installed, repaired or changed, and at least once per week thereafter. Operators in Alaska have approached the Commission in the past with the idea of extending the BOPE testing interval to 14 days based on industry studies, equipment performance, and regulatory initiatives in other areas of the U.S. and world. Specifically noted regulatory agencies with longer than 7 day testing intervals for BOPE are the Minerals Management Service (14-day interval), the Bureau of Land Management (30- day interval), and Norwegian Petroleum Safety Authority (14-day interval).2,3,a In the most recent case, MMS funded a comparative study to determine "if within fourteen day test interval will provide the same amount of safety as within seven day test interval." The results indicated no statistical difference in BOPE performance between the two test frequencies.5 Despite some industry interest in the longer test cycle for drilling in Alaska, no specific Alaska BOPE test performance data has been presented to date and no concerted effort was undertaken to revise the Commission's regulations. A 2004 initiative by the Commission investigated the idea of 14-day BOPE test frequency for development well drilling within the Prudhoe Bay and Lisburne fields. Two conservation orders (CO 516 and 517) were issued for the Prudhoe Bay and Lisburne Oil Pools. The bases for these orders were: high level of geologic control allowing the accurate prediction of subsurface pressures; few wells that will flow naturally (under-pressured oil pools); large kick tolerance based on drilling practice; and the lack of well control events. The Commission further decided' to investigate extending the 14-day BOPE testing cycle to the remainder of development drilling on land within the State of Alaska in March 2004. A proposed change to Commission's statewide regulations was published for comment in Apri12004. Scope of Review An evaluation of historical BOPE test data was deemed necessary to support the decision to change 20 AAC 25 regarding BOPE test frequency. The Commission examined all BOPE test records for years 2001-04 (through Apri130, 2004). Commission inspectors witness a sufficient number of BOPE tests statewide to confirm that the test data is reasonably representative of actual BOPE operating performance. All BOPE test results have been submitted to the Commission in a consistent Microsoft Excel workbook format during this time interval, facilitating a quality assurance review before conducting any data compilation. Statistical information was developed including the number of components tested, number of failures, identification of critical component failures, and failure rates (total and critical components). ' 20 AAC 25.035(e)(10); 20 AAC 25.036(d) a 30 CFR 250.447(b) s 43 CFR 4160 a Norwegian Petroleum Safety Authority Regulations, Chapter II, Section 48 5 "Reliability of Blowout Preventers Tested Under Fourteen and Seven Day Time Intervals"; Tetrahedron, Inc.; December 1996; MMS Technology Assessment and Research Project # 253 Review of Historical BOPl~sts May 2004 Review Results 2001 2002 2003 2004 Totals BOPE Tests 686 598 592 177 2053 Components Tested 17150 14950 14800 4425 51325 # Failed; All 396 324 260 127 1107 Components Failure Rate; All 2,31% 2.17% 1.76% 2.87% 2.16% Components # Failed; Critical g 1 49 67 21 218 Components Failure Rate; Critical Components 0.47% 0.33% 0.45% 0.47% 0.42% 17i ~cu ~Si nn ~' N ~~ ~-n ~~ The review results demonstrate the high degree of reliability of BOPE as used in Alaska, with a 'Z failure rate of critical components less than one-half of one percent. The critical components as listed above were chosen based on well control consequence severity in the event of component attention to reventative failure One ossible reason for the low failure rate is an on oin . p g g p ~ maintenance, Commission oversight, and the limited number of rigs and BOPE system owners .. used for drilling in Alaska (allowing for equipment standardization and performance data sharing among the rigs). The Commission notes'that whenever failures have been identified in any of the critical components, repairs or component replacement have occurred in most instances during the test or shortly afterthe test failure, demonstrating a real commitment to the high level of equipment reliability and performance. While there is no equivalent review of BOPE test data for earlier years, the Commission believes the 2001-04 results are indicative of improvements to equipment (design, materials, manufacturing, etc.) and practice compared to when regulatory requirements originally established the 7-day testing cycle. Drilling efficiency has improved such that frequent operational trips to change equipment, perform surveys, etc. are no longer routine, allowing for ' increased on-bottom drilling time. Many well control events can be attributed to swabbing or , surging a well during an operational trip. Fewer trips represent an increased level of safety (reduction in potential for inducing a well control event) when considered in conjunction with equipment reliability/performance and BOPE redundancy. Operator requests to delay BOPE tests have become routine in recent years. Most are attributable to improved drilling efficiency and the request represents a desire to avoid a premature trip for the sole purpose of testing. Regulatory extensions have been granted by the Commission on a case-by-case basis and represent an increasing administrative burden to track and verify operator compliance. ° BOPS tests through Apri130, 2004 ~ Approximately 25 individual components are tested during each BOPE system test $ Critical components are: annular preventer, pipe rams (all), blind or blind-shear rams, and accumulator system 2 Review of Historical BOPl~sts • May 2004 In the context of this review, it is important to note that the Commission has not proposed any changes to the configuration of the BOPE. An additional consideration not considered in the calculation of critical failure rate is the level of redundancy within a BOPE system, particularly regarding the critical components of the stack. Each BOPE system is composed of multiple sets of devices capable of closing an uncontrolled flow, redundant controls, numerous paths for routing returning wellbore fluids, and operational monitoring that provides early warning of a potential well control event. All this is in addition to the primary means of well control: the drilling fluid that is required to provide for an overbalance of downhole pressure while drilling. The Commission would be remiss to not recognize there is a significant cost savings to industry associated with less frequent testing. Test results during the 3+ years evaluated indicate each BOPE test, not considering trip time, will typically take 4-8 hours to complete.9 Conclusion and Recommendation Performance information presented in this review shows a very low failure rate for equipment without any consideration being given to redundancy within the BOPE system. In addition to performance, there are regulatory, safety, and economic reasons that favorably support the Commission's proposal to revise the BOPE pressure-testing interval during development drilling10 and completion activities. As noted in the Conservation Orders for PBU and Lisburne Oil Pools, there is also a high level of geologic control associated with development drilling in Alaska. Adopting a 14-day maximum interval :between BOPE tests would be consistent with other major regulatory jurisdictions such as MMS, BLM, and Norway's PSA, and more restrictive than published industry recommended practicer r without compromising safety. Specific recommendations: - 20 AAC 25.035(e)(10) and .036(d) should be revised to allow a maximum 14-day BOPE pressure test interval for development drilling and completion activities; - All other rig related operations, including exploration drilling and workovers, should retain the 7-day test interval as currently stated in the Commission's regulations; - There should be no need for extensions to the 14-day interval. The operator should justify any request for an extension beyond the proposed 14-day interval in writing, and Commission approval should be rare; - Regulations should retain provisions for reverting to 7 day testing; possible reasons include poor performance, first test(s) after a rig has been stacked, unique operating circumstances - Function testing of BOPE should continue on a 7 day cycle; this is consistent with other regulatory jurisdictions; - The Commission should continue to track BOPE test results and compare against the 3+ years of baseline data. 9 AOGCC; Conservation Order 516 10 The break between exploratory and development drilling is interpretive and solely at the Commission's discretion. " API RP 53 - "Recommended Practices for Blowout Prevention Equipment Systems for Drilling Wells"; 3rd Edition, March 1997; this standard establishes weekly function testing and pressure testing at intervals not to exceed 21 days. 3 Appendix BOP Test Failures: 2001 through April 30, 2004 BOP Performance: 2001 Failures File Name Date Field/Unit Well PTD Ri Witnessed? # Components ~" Critical Component Failures g Failed ~ ANN ~ PR ~ BR .A000rv1 2001 BOPE Tests 1/1/2001 Kenai 31-7 200-138 Inlet GD1 N 2 1 1/2/2001 PBU 4-41A 200-195 Nabors CDR1 N 1 1/3/2001 PBU Z-101 200-162 Nabors 7ES N 1 1 1/4/2001 MPU E-24A 200-186 Nabors 22E N 1 1/4/2001 PBU K-12A 200-207 Nabors 3S N 2 1/5/2001 KRU 1D-37 200-204 Nabors 16E Scheve 2 1/6/2001 KRU 2N-314 200-193 Nabors 19E Scheve 1 1/10/2001 PBU 4-41A 200-195 Nabors CDR1 N 2 2 1/11/2001 MGS A-14LN2 200-131 Inlet XTOA N 1 1/13/2001 MPU E-24A 200-187 Nabors 22E Crisp 1 1/13/2001 TBU M-32RD 199-097 Nabors 51 Jones 5 1 1 1/15/2001 PBU C-33A 200-202 Nabors CDR1 N 3 1/16/2001 Redoubt 1 200-165 Nabors 429 Grimaldi 5 1/17/2001 PBU S-104 200-196 Nabors 9ES Crisp 2 1/19/2001 MGS A14-01 200-131 InIetXTOA N 2 1/21/2001 Niakuk NK-43 201-001 Doyon 14 Spaulding 5 1 1/21/2001 MPU E-24A 200-187 Nabors 22E N 1 1/22/2001 PBU C-33A 200-202 Nabors CDR1 Grimaldi 3 1 1/23/2001 Alpine CD1-NQ1 200-215 Doyon 19 N 2 1/23/2001 Kenai 42-7 199-025 Inlet GD1 N 1 1/25/2001 TBU K-15RD 179-034 Nabors 58 Crisp 2 1/26/2001 MGS A14-01 200-131 Inlet XTOA Jones 4 1/26/2001 MPU F-81 200-066 Nabors 4ES Scheve 2 1/31/2001 MPU F-05 199-074 Nabors 4ES N 2 2/1/2001 Kenai 42-7 199-024 Inlet GD1 Jones 4 1 2/6/2001 Palm 1 201-005 Nabors 19E Spaulding 1 2/8/2001 Northstar NS-27 201-027 Nabors 33E Spaulding 1 2/11/2001 PBU NGI-04 175-069 Nabors 9ES Jones 2 2/14/2001 Alpine CD1-21 201-006 Doyon 19 Operator 1 2/14/2001 Palm 1 201-005 Nabors 19E Operator 1 2/14/2001 PBU P-206 200-159 Nabors 7ES Grimaldi 1 2/15/2001 PBU 16-06A 201-008 Nabors 3S Scheve 4 1 2/18/2001 WMRU 7 200-201 Nabors 160 Operator 1 1 2/21/2001 Alpine CD1-21 201-006 Doyon 19 Operator 1 2/22/2001 Endicott 2-28A 201-018 Doyon 15 Operator 3 1 2/23/2001 KRU 1J-08 201-024 Nabors 16E Crisp 1 2/26/2001 Kenai 24-6 200-188 Inlet GD1 Jones 2 2/27/2001 Northstar NS-27 201-027 Nabors 33E Crisp 4 3/4/2001 Redoubt 2 201-031 Nabors 429 Operator 1 3/6/2001 KRU 1 L-09 190-034 Nordic 3 Operator 1 3/7/2001 Nigliq 1 201-036 Doyon 19 Jones 4 3/8/2001 Kenai 24-6 200-188 Inlet GD1 Grimaldi 1 1 3/10/2001 Niakuk NK-12B 201-015 Doyon 14 Scheve 1 3/11/2001 Trail Blazer A 201-013 Nabors 22E Scheve 3 • Page 1 of 5 File Name I Date I Field/Unit I Well I PTD I Ri I Witnessed? # Components Critical Component Failures g I Failed ANN PR BR ACCUM BOPE Tests 3/11/2001 PBU E-07A 201-034 Nabors CDR1 Grimaldi 2 3/12/2001 Palm 1A 201-040 Nabors 19E Operator ' ' 1 1 3/13/2001 WMRU 7 201-042 Nabors 160 Crisp 1 3/14/2004 KRU 1 L-11 190-045 Nordic 3 Operator 1 1 3/17/2001 Trail Blazer A 201-013 Nabors 22E Crisp 4 3/18/2001 PBU E-07A 201-034 Nabors CDR1 Operator 1 3/19/2001 TBU K-1RD 201-009 Nabors 58 Jones 2 3/24/2001 MPU F-33A 201-062 Nordic 1 Jones 1 3/26/2001 PBU E-07A 201-034 Nabors CDR1 Operator 1 3/28/2001 Nigliq 1 201-061 Doyon 19 Operator 1 3/29/2001 Moose's Tooth C 201-049 Doyon 141 Scheve 1 3/29/2001 MPU H-086 201-047 Nabors 3S Operator 1 1 3/31/2001 Trail Blazer E1 201-035 Nabors 22E Scheve 1 4/1/2001 Northstar NS-29 201-041 Nabors 33E Grimaldi 3 1 4/3/2001 MGS A32-11 R 193-092 Inlet 9086 Grimaldi 1 4/3/2001 Beaver Ck BC-10 200-192 Inlet GD1 Jones 2 4/4/2001 Redoubt 2 201-031 Nabors 429 Jones 1 4/7/2001 MPU L-06 190-010 Nabors 4ES Operator 2 4/8/2001 Lookout 1 201-003 Nabors 14E Spaulding 6 4/9/2001 PBU F-03 201-053 Nabors CDR1 Operator 1 1 4/10/2001 MGS C23-23 168-030 Inlet XTOC Grimaldi 3 4/12/2001 MPU F-73 200-198 Nordic 3 Operator 1 4/13/2001 Lookout 1 201-003 Nabors 14E Operator 1 4/15/2001 KRU 1J-14 200-200 Nabors 16E Spaulding i 1 4/15/2001 PBU F-03 201-053 Nabors CDR1 Operator 1 1 4/19/2001 Northstar NS-29 201-041 Nabors 33E Operator 1 1 4/20/2001 Lookout 1 201-003 Nabors 14E Operator 3 4/22/2001 MPU E-30A 201-011 Nabors 3S Scheve 2 1 4/23/2001 KRU 2A-15 185-146 Nordic 3 Operator 1 4/25/2001 Endicott 3-15 187-094 Doyon 15 Operator 2 4/27/2001 Alpine CD1-14 201-038 Doyon 19 Crisp 2 5/4/2001 MPU J-01A 190-095 Nabors 4ES Jones 1 5/9/2001 Kenai 24-5 182-098 In-et GD1 Crisp 1 5/21/2001 KRU 2P-438 201-082 Doyon 141 Crisp 1 5/24/2001 Alpine CD2-42 201-067 Doyon 19 Jones 1 5/26/2001 Kenai 24-5 182-098 Inlet GD1 Operator 2 5/27/2001 MPU J-18 197-220 Nabors 4ES Operator 1 5/30/2001 MGS A23-01 201-073 Inlet XTOA Crisp 4 1 6/2/2001 KRU 1C-133 201-077 Nabors 245 Scheve 4 1 6/2/2001 Northstar NS-29 201-041 Nabors 33E Operator 1 1 6/2/2001 PBU 02-21 201-099 Nabors 3S Operator 1 6/4/2001 KRU 3K-20 201-088 Nabors 16E Scheve 1 6/9/2001 MPU C-41 201-078 Nabors 22E Crisp 5 6/9/2001 Northstar NS-27 201-027 Nabors 33E Operator 1 1 6/11/2001 Redoubt 2 201-031 Nabors 429 Operator 1 6/12/2001 KRU 1C-121 201-080 Nabors 245 Operator 1 Page 2 of 5 ~J File Name ~ Date ~ FieldlUnit ~ Well 2001 BOPE Tests PTD Rig 6/12/2001 PBU L-01 201-072 Nabors 9E5 6/19/2001 Redoubt 2 201-031 Nabors 429 6/23/2001 PBU K-10A 201-058 Nabors 3S 6/26/2001 PBU K-33 196-202 Nabors 4ES 6/30/2001 MPU I-04A 201-092 Nabors 3S 7/1/2001 Falls Ck 1 160-042 Inlet GD1 7/2/2001 Redoubt D1 201-085 Nabors 429 7/2/2001 KRU 3K-19 201-108 Nordic 3 7/5/2001 PBU Y-15A 201-089 Nabors CDR1 7/8/2001 Northstar NS-27 201-027 Nabors 33E 7/10/2001 PBU 12-29 184-032 Doyon 16 7/10/2001 Redoubt D1 201-085 Nabors 429 7/11/2001 KRU 1C-111 201-121 Nabors 245 7/13/2001 TBU K-18RD 201-117 Nabors 58 7/15/2001 FCU 1 160-042 Inlet GD1 7/16/2001 PBU S-107 201-113 Doyon 14 7/16/2001 Alpine CD2-33 201-120 Doyon 19 - 7/19/2001 MPU C-24 201-094 Nabors 22E 7/19/2001 KRU 1C-123 201-084 Nabors 245 7/24/2001 TBU M-25 187-086 Nabors 51 7/25/2001 MPU F-86 201-087 Nabors 27E 7/26/2001 KRU 1 R-22A 199-049 Nordic 3 7/27/2001 MGS A23-01 201-073 Inlet XTOA 7/29/2001 MGS A23-01 201-073 Inlet XTOA 8/1/2001 PBU S-107 201-113 Doyon 14 8/1/2001 KRU 2N-304 201-130 Nabors 16E 8/7/2001 KRU 2N-304 201-130 Nabors 16E 8/8/2001 SCU 13-34 171-021 H & R Drilling 9 8/9/2001 TBU K-18RD 201-117 Nabors 58 8/11/2001 PBU 04-09 176-030 Doyon 16 8/13/2001 SCU 32-8 100-266 H & R Drilling 9 8/15/2001 FCU 1 201-155 Inlet GD1 8/18/2001 MPU G-14 201-133 Nabors 27E 8/18/2001 PBU 01-04A 201-152 Nabors 3S 8/18/2001 MPU L-11 193-013 Nabors 4ES 8/19/2001 TBU M-14RD 201-171 Nabors 51 8/20/2001 KRU 2K-28 201-154 Nordic 3 8/22/2001 KRU 2N-348 201-142 Nabors 16E 8/25/2001 Kenai 21-6 165-006 Inlet GD1 8/28/2001 PBU 04-13 178-031 Doyon 16 8/31/2001 Kenai 14-32L 182-015 Dowe119086 8/31/2001 PBU Y-02A 201-173 Nabors CDR1 9/1/2001 MPU G-14L1 201-134 Nabors 27E 9/5/2001 MPU L-35A 201-109 Nabors 27E 9/7/2001 TBU K-24RD2 201-141 Nabors 58 9/7/2001 PBU Y-02A 201-173 Nabors CDR1 Page 3 of 5 Witnessed? Operator Scheve Grimaldi Operator Operator Operator Crisp Jones Jones Jones Grimaldi Operator Crisp Grimaldi Operator Scheve Grimaldi Crisp Jones Crisp Operator Grimaldi Operator Operator Operator Scheve Operator Operator Grimaldi Operator Grimaldi Operator Operator Jones Grimaldi Jones Operator Jones Operator Grimaldi Operator Operator Operator Operator Operator Failed 1 1 2 1 I 8 1 6 1 3 8 2 1 2 2 2 1 1 2 4 3 1 1 2 3 1 3 1 1 3 2 2 1 2 2 2 4 2 7 2 2 1 1 1 2 1 Critical Component Failures ANN PR BR ACCUPdI __ 1 1 1 1 1 2 1 2 1 1 1 1 1 1 l 2 1 • 1 1 1 Fil Name D t Fi ld/U it W ll PTD Ri d? Wit # Components ,, Critical Component Failures e a e e n e g nesse Failed ANN PR BR ACC 3OPE Tests 9/10/2001 MPU L-35A 201-109 Nabors 27E Jones 2 9/11/2001 MPU I-11L1 201-138 Nabors22E Jones 4 9/13/2001 Alpine CD2-39 201-160 Doyon 19 Operator 2 1 9/14/2001 KRU 1C-102L1 201-172 Nabors 245 Operator 1 1 9/17/2001 PBU N-20A 196-184 Doyon 16 "' Operator 1 9/18/2001 MPU L-35A 201-109 Nabors 27E Operator 1 9/22/2001 PBU 15-36A 201-162 Nabors 3S. Operator 1 1 9/23/2001 KRU 1C-102 201-161 Nabors 245 Spaulding 6 9/25/2001 KRU 2N-350 201-175 Nabors 16E Operator 1, 1 9/25/2001 MPU L-35A 201-109 Nabors 27E Operator 1 9/27/2001 MPU I-11L1 201-138 Nabors22E Operator 2 10/1/2001 PBU C-24 201-094 Nabors 4ES Operator 1 10/2/2001 Grassim Oskolkoff 2 201-096 Inlet GD1 Jones 1 1 10/4/2001 TBU M-12 201-176 Nabors 51 Operator 1 1 10/5/2001 KRU 1C-131 201-185 Nabors 245 Operator 1 10/6/2001 MPU F-78 195-144 Nabors 4ES Scheve 1 10/14/2001 TBU M-12 201-176 Nabors 51 Spaulding 1 10/15/2001 KRU 1C-125 201-199 Nabors 245 Operator 1 10/17/2001 PBU 05-28 201-195 Nordic 1 Grimaldi 1 10/19/2001 KRU 2P-420 201-182 Doyon 141. Grimaldi 2 1 10/19/2001 Grassim Oskolkoff 2 201-096 Inlet GD1 Operator 2 1 10/22/2001 MGS A11-01 166-029 InIetXTOA Operator 2 10/23/2001 PBU W-21A 201-111 Nabors 9ES Jones 1 10/24/2001 KRU 2T-39 201-183 Nabors 16E Jones 4 1 1 10/24/2001 PBU Y-176 201-179 Nabors 3S Operator 1 10/27/2001 KRU 2P-420 201-182 Doyon 1.41 Operator 1 10/27/2001 PBU A-02 171-031 Doyon 16 Operator 1 1 10/30/2001 KRU 1C-109 201-203 Nabors 245 Scheve 2 11/1/2001 MPU I-12 201-163 Nabors 22E Crisp 2 1 11/6/2001 Grassim Oskolkoff 2 201-096 Inlet GD1 Operator 2 1 11/6/2001 KRU 1C-109L1 201-204 Nabors 245 Operator 2 11/6/2001 TBU A-09RD 181-036 Nabors 56 Jones 4 1 11/7/2001 PBU K-056 201-206 Nabors 2ES Crisp 4 11/7/2001 PBU M-13A 201-165 Nabors 3S Operator 2 1 1 11/8/2001 PBU K-05B 201-206 Nabors 2ES Jones 7 1 11/12/2001 KRU 2P-415 201-131 Doyon 141 Operator 1 11/14/2001 PBU E-103 201-200 Doyon 14 Operator 1 11/15/2001 PBU M-13A 201-165 Nabors 3S Operator 1 1 11/17/2001 Northstar NS-13 201-088 Nabors 33E Scheve 4 1 11/19/2001 PBU U-156 201-197 Nabors 35 Operator 1 11/22/2001 Kenai 24-5RD 201-144 Inlet GD1 Jones 2 1 11/22/2001 Hansen 1 201-157 Nabors 273 Spaulding 2 11!23/2001 KRU 1R-35 201-210 Nabors 245 Operator 4 1 11/23/2001 TBU A-15RD 201-189 Nabors 56 Operator 1 1 11/24/2001 PBU Y-24 186-113 Doyon 46 Grimaldi 1 1 11/24/2001 MGS A11-01 166-029 InletXTOA, Jones 2 I• ~ • Page 4 of 5 File Name Date Field/Unit Well PTD Ri Wit d? # Components Critical Component Failures g nesse Failed ANN PR 6R ACCUM 2001 BOPE Tests 11/25/2001 PBU 14-40A 201-135 Nordic 1 Crisp 3 1 11/29/2001 KRU 2P-415 201-131 Doyon 141 Spaulding 2 12/1/2001 MPU F-90 201-211 - Nabors ~7E Operator 1 12/1/2001 MPU I-11L1 201-137 Nabors4ES Jones 2 12/7/2001 KRU 1C-135 201-220 Nordic 3 Scheve 1 12/7/2001 PBU 05-12A 201-180 Nordic 1 Operator 1 1 12/9/2001 PBU 15-36A 201-162 Nabors 3S Operator 1 12/12/2001 Susan Dionne 1 RD 185-208 Inlet GD1 Operator 4 1 2 12/13/2001 TBU A-15RD 201-189 Nabors 56 Operator 1 12/15/2001 KRU 1C-135 201-220 Nordic 3 ~ Operator 1 12/16/2001 PBU 13-17 182-026 Doyon 16 _ Crisp 1 ~ 12/17/2001 KRU 3N-19 201-225 Nabors 16E Crisp 4 12/20/2001 Alpine CD2-34 201-191. Doyon 19 Operator 1 12/21/2001 TBU A-15RD 201-189 Nabors 56 Operator 1 12/21/2001 PBU F-09A 201-198 Nordic 1 Operator 1 1 12/21/2001 KRU 1 D-141 200-16 Nordic 3 Operator 1 12/22/2001 NNA 1 201-215 H& R Drilling 9 Grimaldi 6 12/27/2001 Alpine CD2-34 201-191 Doyon 19 Operator 1 12/27/2001 Hansen 1 201-157 Nabors 273 Operator 1 12/28/2001 TBU A-15RD 201-189 Nabors 56 O erator 1 Failure Totals - 2001 396 20 36 15 10 2001 Summa Tests 686 Components Tested (~25/test) 17150 Critical Components Failed 81 Critical Component Failure Rate 0.004723 All Componet Failure Rate 0.0230904 Page 5 of 5 0.47% 2.31 File Name BOP Performance: 2002 Failures Date I FieldlUnit I Well I PTD I Rig I Witnessed? I # C Failed 1/5/2002 PBU K-056 201-206 Nabors 3S Operator 3 1!9/2002 NNA 1 201-215 H& R Drilling 9 Operator 1 1/12/2002 Northstar NS-14 201-118 Nabors 33E Jones 2 1/13/2002 PBU 13-20 182-009 Doyon 16 Jones 5 1/13/2002 Hansen 1 201-157 Nabors 273 Grimaldi 1 1/14/2002 Kenai 43-6RD 201-231 Inlet GD1 Operator 3 1/15/2002 Alpine CD2-26 201-232 Doyon 19 Operator 1 1/16/2002 NNA 1 201-215 H& R Drilling 9 Operator 1 1/17/2002 PBU 05-26A 201-221 Nabors 2ES Operator 1 1/23/2002 Cirque 3 201-244 Doyon 141 Scheve 1 1/23/2002 Alpine CD2-49 201-249 Doyon 19 Operator 1 1/23/2002 Northstar NS-14 201-118 Nabors 33E Operator 1 1/25/2002 NNA 1 201-215 H& R Drilling 9 Jones 3 1/25/2002 MPU S-15 201-245 Nabors 27E Crisp 2 1/29/2002 Redoubt 4 201-194 Nabors 429 Operator 1 2/2!2002 NNA 1 201-215 H& R Drilling 9 Operator 1 2/8/2002 Alpine CD2-17 202-015 Doyon 19 Operator 2 2/11/2002 Hansen 1 201-157 Nabors 273 Crisp 2 2/16/2002 Redoubt 4 201-194 Nabors 429 Operator 1 2/18/2002 Northstar NS-08 201-021 Nabors 33E Operator 3 2!19/2002 KRU 2P-422 201-246 Nabors 19E Crisp 23 2/21/2002 PBU S-17C 202-007 Nabors 3S Jones 5 2/21/2002 TBU K-1RD2 201-009 Nabors 58 Scheve 2 2/24/2002 PBU 15-29A 202-016 Nordic 1 Spaulding 1 2/24/2002 KRU 2P-451 202-008 Nordic 3 Operator 1 2/27/2002 TBU K-12RD 178-057 Nabors 58 Operator 1 2/28/2002 Hunter A 202-013 Nabors 16E Operator 2 3/1/2002 TBU K-12RD 178-057 Nabors 58 Operator 1 3/2/2002 PBU Z-39 200-208 Doyon 14 Scheve 2 3/9/2002 KRU 2P-441 202-017 Nordic 3 Operator 1 3/10/2002 MPU H-07A 202-028 Nabors 27E Crisp 2 3/10/2002 TBU K-30RD 170-007 Nabors 58 Operator 2 3/11/2002 KBU 23X-06 184-109 Inlet GD1 Operator 3 3/14/2002 PBU Y-37A 202-046 Nabors 3S Operator 2 3/15/2002 Griner 1 202-041 H& R Drilling 9 Grimaldi 2 3/15/2002 Hunter A 202-013 Nabors 16e Operator 2 3/16/2002 KRU 2P-441 202-011 Nordic 3 Spaulding 1 3/18/2002 Grizzly 1 202-040 Nabors 19E Spaulding 6 3/18/2002 Northstar NS-15 202-054 Nabors 33E Jones 2 3/18/2002 PBU L-102 202-036 Nabors 9ES Jones 1 Page 1 of 5 Critical Component Failures ANN PR BR ~ ACCUM 2 1 1 1, i~ File Name Date Field/Unit Well PTD Ri Witnessed? # Components ~ Critical Comporer~t Failures g Failed ~ ANN PR BR 3/19/2002 Altamura 1 202-010 Nabors 14 Spaulding 3 3/21/2002 Nanuq 5 202-042 Doyon 19 Scheve 4 3/22/2002 KTU 32-7H 202-043 Inlet GD1 Operator 1 3/26/2002 TBU K-17 173-001 Nabors 58 - Operator 2 3/28/2002 Altamura 1 202-010 Nabors 14 Operator 1 3/28/2002 MPU E-13B 202-044 Nabors 27E Operator 1 1 3/28/2002 PBU Y-37A 202-046 Nabors 3S Operator 1 4/2/2002 PBU W-10A 202-059 Nabors 3S Operator 1 1 4/5/2002 Heavenly 1 202-060 Doyon 141 Jones 4 4/8/2002 PBU L-119 202-064 Nabors 9ES Operator 1 4/9/2002 KRU 3H-16A 200-022 Nordic 1 Jones 4 1 4/10/2002 KTU 32-7H 202-043 Inlet GD1 Operator 1 4/12/2002 TBU G-7 168-061 Nabors 55 Grimaldi 3 4/17/2002 KTU 32-7H 202-043 Inlet GD1 Operator 1 4/17/2002 TBU G-29 192-052 Nabors 55 Operator 1 1 4/18/2002 PBU J-11A 196-104 Doyon 16 Grimaldi 1 1 4/22/2002 Northstar NS-07 202-077 Nabors 33E Operator 1 4/22/2002 Redoubt 5 202-083 Nabors 429. Jones 1 1 4/24/2002 TBU G-29RD 192-052 Inlet GD1 Grimaldi 1 4/24/2002 MGS C32-23LW 202-034 Inlet XTOC Jones 1 4/27/2002 KRU 2P-427 202-018 Nordic 3 Operator 1 5/3/2002 KRU 3M-29A 202-084 Nordic 1 Operator 1 5/4/2002 KRU 2P-427 202-018 Nordic 3 Operator 2 5/5/2002 MGS C34-23 167-051 Inlet XTOC Crisp 2 5/6/2002 Redoubt 4 201-194 Nabors 429. Operator 1 1 5/7!2002 Northstar NS-07 202-077. Nabors 33E Grimaldi 1 5/9/2002 PBU C-09A 202-094 Nabors 3S Operator 1 1 5/11/2002 PBU W-08A 202-090 Doyon 14 Grimaldi 1 5/12/2002 KRU 1 D-117 197-237 Nabors 245 Grimaldi 2 1 5/13/2002 Redoubt 4 201-194 Nabors 429 Operator 1 5!1712002 PBU X-35L1 202-078 Nabors 3S Operator 1 5/17/2002 PBU V-102 202-033 Nabors 9ES Operator 1 5/18/2002 PBU F-04A 202-100 Nordic 1 Crisp 3 5/20/2002 Redoubt 4 201-194 Nabors 429 Jones 1 5/23/2002 Northstar NS-06 202-101 Nabors 33E Operator 2 5/25/2002 MPU F-66A 196-162 Nabors 4ES Operator 1 1 5/29/2002 Redoubt 4 201-194 Dowell 9436 Jones 2 5/31/2002 Alpine CD2-48 202-108 Doyon 19 Operator 1 5/31/2002 MPU E-08 191-050 Nabors 4ES Crisp 1 6/1/2002 Northstar NS-06 202-101 Nabors 33E Operator 2 6/1/2002 TBU G-12RD3 202-055 Nabors 54 Operator 1 6/3/2002 PBU L-109 201-201 Nabors 9ES Operator 1 M • ~~i 1 Page 2 of 5 File Name I Date I Field/Unit ~ Well I PTD I Rig I Witnessed? I "' "`""'""" Failed 2002 BOPE Tests 6/8/2002 PBU L-109 201-201 Nabors 9ES Operator 1 6/9/2002 Susan Dionne 3 202-070 Inlet GD1 Grimaldi 1 6/10/2002 PBU PSI-06 202-079 Nabors 27E Jones 4 6/14/2002 Redoubt 5 202-083 Nabors 429 Operator 1 6/15/2002 PBU 15-31A 202-102 Nordic 1 Operator 1 6/18/2002 PBU PSI-06 202-079 Nabors 27E Operator 1 6/21/2002 Northstar NS-12 202-110 Nabors 33E Crisp 1 6/22/2002 PBU S-113 202-120 Doyon 14 Grimaldi 4 6/22/2002 PBU L-108 202-109 Nabors 9ES Operator 1 6/23/2002 SRU KGSF 2 202-119 Nabors 129 Scheve 4 6/24/2002 PBU G-106 202-117 Nordic 1 Operator 1 6/26/2002 PBU D-08A 202-123 Nabors 2ES Operator 1 7/2/2002 KRU 1C-104 202-061 Nabors 245 Jones 5 7/4/2002 Alpine CD2-23 202-134 Doyon 19 Operator 1 7/10/2002 SRU KGSF 2 202-119 Nabors 129 Operator 1 7/11/2002 KRU 1C-104 202-061 Nabors 245 Operator 1 7/16/2002 PBU PSI-01 202-145 Nabors 27E Operator 1 7/18/2002 TBU A-29RD 202-004 Nabors 56 Operator 1 7/19/2002 KRU 1 C-104L1 202-062 Nabors 245 Operator 1 7/24/2002 Wolf Lake 1 184-201 Inlet GD1 Operator 5 7/25/2002 PBU 07-28AL1 202-106 Nordic 1 Scheve 1 7/25/2002 Alpine CD2-41 202-126 Doyon 19 Operator 1 7/26/2002 PBU S-112 202-135 Doyon 14 Scheve 1 7/29/2002 NCU 2 166-038 Aurora WS 1 Spaulding 7/30/2002 KRU 1C-117 201-121 Nabors 245 Operator 1 8/8/2002 PBU 18-186 202-121 Nordic 1 Operator 1 8/10/2002 Redoubt 5 202-083 Nabors 429 Operator 1 8/12/2002 MPU S-31 202-014 Doyon 141 Jones 1 8/13/2002 Wolf Lake 1 202-088 Inlet GD1 Scheve 2 8/20/2002 Wolf Lake 1 202-088 Inlet GD1 Operator 1 8/27/2002 Alpine CD2-38 202-171 Doyon 19 Operator 3 8/28/2002 NCU 2 166-038 Aurora WS 1 Scheve 5 8/29/2002 Northstar NS-17 202-169 Nabors 33E Operator 1 8/29/2002 PBU E-09B 202-161 Nordic 1 Grimaldi 3 9/3/2002 Alpine CD2-38 202-171 Doyon 19 Jones 2 9/3/2002 Northstar NS-17 202-169 Nabors 33E Operator 1 9/5/2002 Wolf Lake 2 198-142 Inlet GD1 Operator 2 9/13/2002 Northstar NS-17 202-169 Nabors 33E Operator 1 9/15/2002 SCU 43B-08 190-152 Nabors 26S Operator 1 9/15/2002 PBU A-22 182-018 Nabors 2ES Crisp 1 9/16/2002 PBU A-22 182-018 Nabors 2ES Crisp 1 9/17/2002 PBU S-114 202-175 Doyon 14 Operator 1 ANN I PR 1 1 1 t Failures _ BR ACCUM 1 I • 1 1 • Page 3 of 5 File Name Date Field/Unit Well PTD Ri Witnessed? #Components `Critical Co g Failed ANN PR 2002 BOPE Tests 9/18/2002 NCU 1A 202-162 Aurora Gas LLC 1 Operator 1 1 9/18/2002 Alpine CD2-44 202-165 Doyon 19 Operator 1 9/19/2002 SRU 21 B-16 185-255 Nabors 26S Operator 1 9/20/2002 KBU 41-7X 202-025 Inlet GD1 Grimaldi 2 9/25/2002 NCIU B-2 197-210 BJ Grimaldi 1 9/26/2002 Alpine CD2-29 202-148 Doyon 19 Operator 1 9/28/2002 KBU 41-7X 202-025 Inlet GD1 Operator 1 10/1/2002 PBU W-38A 202-191 Doyon 14 Scheve 1 1 10/2/2002 Alpine CD2-29 202-148 Doyon 19 Operator 1 10/7/2002 PBU J-206 202-170 Nordic 2 Crisp 2 1 10/8/2002 PBU W-38A 202-191 Doyon 14 Operator 1 10/10/2002 Alpine CD2-13 202-203 Doyon 19 Operator 1 10/11/2002 Kenai 14-6 174-050 Inlet GD1 Operator 2 10/11/2002 MPU I-02 190-091 Nabors 4ES Jones 4 10/14/2002 PBU W-38A 202-191 Doyon 14 Operator 1 10/16/2002 Alpine CD2-13 202-203 Doyon 19 Operator 1 10/18/2002 MGS C13-13LN 202-213 Inlet XTOC Grimaldi 2 10/24/2002 Alpine CD2-13 202-203 Doyon 19 Operator 1 10/26/2002 PBU V-109 202-202 Nabors 9ES Grimaldi 1 10/28/2002 TBU K-12RD 178-057 Cudd 131 Jones 3 10/31/2002 PBU V-109 202-202 Nabors 9ES Jones 2 11/1/2002 PBU W-32A 202-209 Doyon 14 Operator 1 11/1/2002 Northstar NS-19 202-207 Nabors 33E Jones 1 11/7/2002 PBU V-109 202-202 Nabors 9ES Operator 1 11/8!2002 Northstar NS-19 202-207 Nabors 33E Operator 1 11/9/2002 TBU M-29 191-027 Nabors 51 Crisp 1 11/9/2002 PBU J-27A 202-200 Nordic 1 Operator 1 11/11/2002 MPU I-02 190-091 Nabors 4ES Jones 4 11/12/2002 Redoubt 2 201-031 Nabors 429 Operator 1 1 11/15/2002 KRU 3S-07 202-187 Nabors 7ES Crisp 2 11/16/2002 PBU W-32A 202-209 Doyon 44 Crisp 1 11/16/2002 TBU M-28 190-019 Nabors 51 Operator 1 11/16/2002 PBU J-016 202-201 Nordic 1 Operator 1 11/22/2002 PBU W-15A 202-151 Nordic 2 Jones 5 11/25/2002 PBU 14-08AL1 202-210 Nordic 1 Operator 1 11/26/2002 Northstar NS-22 202-223 Nabors 33E Operator 1 11/27/2002 MGS C13-13LN 202-213 InIetXTOC Operator 2 11/28/2002 Granite Pt 50 192-041 Cudd 131 Grimaldi 4 1 2 11/28/2002 PBU W-37A 202-149 Nordic 2 Operator 3 12/3/2002 MGS C13-13LN 202-213 Inlet XTOC Operator 2 12/3/2002 PBU K-20 202-224 Nordic 1 Operator 1 12/4/2002. Redoubt 3 201-064 Nabors 429 Jones 1 t raiiures BR ACCUM 1 1 Page 4 of 5 File Name Date Field/Unit Well PTD Rig Witnessed? # Components Critical Component Failures Failed ANN PR BR ACCUM 2002 BOPE Tests 12/6/2002 PBU W-32A 202-209 Nordic 2 Operator 3 12/8/2002 KRU 3S-09 202-205 Nabors 7ES Operator 1 12/9/2002 PBU 18-05A 202-219 Nabors 2ES Operator 1 1 12/10/2002 PBU W-32A 202-209 Nordic 2 Operator 3 12/15/2002 TBU G-15RD 198-099 Nabors 54 Grimaldi 1 12/17/2002 PBU M-09B 202-220 Nordic 2 Operator 1 12/18/2002 KRU 1C-22 202-222 Doyon 141 Scheve 3 1 1 12/18/2002 Sterling 41-15 198-041 BJ 170 Grimaldi 1 12/18/2002 KRU 1 C-22 202-222 Doyon 141 Scheve 3 12/25/2002 PBU L-02 201-207 Doyon 14 Operator 1 12/27/2002 Redoubt 6 202-228 Nabors 429 O erator 1 Failure Totals - 2002 324 7 17 15 10 2002 Summary Tests 5gg Components Tested (~25/test) 14950 Critical Components Failed 49 Critical Component Failure Rate 0.0032776 All Componet Failure Rate 0.0216722 0.33% 2.17% r ~ LJ Page 5 of 5 BOP Performance: 2003 Failures File Name I Date I 2003 BOPE Tests Field/Unit I Well I PTD I Rig I Witnessed? I # Components L Failed ~ Critical Component Failures ANN PR BR AGGUM 1/3/2003 PBU L-112 202-229 Doyon 14 Jones 3 1 1 1/6/2003 PBU K-3178 201-156 Nordic 2 Operator 1 1/7/2003 MPU J-06 194-095 Nabors 4ES Jones 1 1/8/2003 Alpine CD2-35A 202-244 Doyon 19 Jones 4 1/15/2003 MPU E-09B 194-132 Nabors 4ES Operator 1 1/15/2003 PBU K-3178 201-156 Nordic 2 Operator 1 1/17/2003 Northstar NS-22 202-223 Nabors 33E Crisp 2 1 1/25/2003 MPU S-19A 202-233 Doyon 14 Operator 2 1/26/2003 DIU 4-10A 202-238 Doyon 15 Spaulding 4 1/26/2003 PBU 15-30A 202-089 Nordic 2 Operator 1 1 1/29/2003 Northstar NS-O6 202-101 Nabors 33E Operator 2 1 1/31/2003 Alpine CD2-08 202-250 Doyon 19 Operator 1 1/31/2003 PBU F-06 171-012 Nabors 4ES Scheve 1 2/2/2003 TBU D-17RD 181-023 Nabors 77 Crisp 2 2/3/2003 KRU 3S-16 203-007 Nabors 7ES Operator 1 2/6/2003 PBU 15-38A 203-016 Nordic 1 Operator 1 1 2/8/2003 Abalone 1 202-129 Inlet 1 Crisp 2 2/8/2003 PBU 07-296 202-239 Nordic 2 Jones 2 2/9/2003 Northstar NS-O6 202-101 Nabors 33E Operator 1 2/9/2003 TBU D-17RD 181-023 Nabors 77 Operator 1 2/12/2003 PBU 15-48A 203-005 Nordic 1 Operator 1 2/13/2003 Alpine CD2-36 203-014 Doyon 19 Operator 1 2/15/2003 Abalone 1 202-129 Inlet GD1 Operator 3 1 2/21/2003 TBU D-47 191-011 Nabors 77 Operator 1 2/24/2003 DIU 3-17E 202-247 Doyon 15 Scheve 1 3/2/2003 KRU 3S-08 203-022 Nabors 7ES Crisp 2 3/3/2003 PBU L-121 203-013 Nabors 9ES Crisp 1 3/3/2003 PBU W-19AL1 202-235 Nordic 1 Operator 1 1 3/4/2003 Abalone 1 202-129 Inlet GD1 Operator 1 3/7/2003 MPU S-12 203-023 Doyon 14 Operator 1 3/13/2003 BCU 6 181-150 Inlet GD1 Operator 1 3/13/2003 KRU 2B-03A 203-009 Nordic 2 Operator 1 3/17/2003 Puviaq 1 202-248 Nabors 16E Operator 1 3/17/2003 PBU PM2-54A 203-010 Nordic 1 Operator 1 1 3/19/2003 DIU 2-28A 203-006 Doyon 15 Grimaldi 4 2 3/19/2003 Hansen 1A 203-004 Nabors 273 Jones 1 3/21/2003 BCU 6 181-150 Inlet GD1 Spaulding 1 3/22/2003 Natchiq 1 202-227 Nordic 3 Crisp 4 1 1 3/26/2003 Kustatan 1 20-153 Inlet CC1 Jones 4 1 3/28/2003 PBU E-01A 203-033 Nordic 1 Jones 2 1 3/30/2003 KRU 2T-218 203-017 Doyon 19 Jones 4 1 3/31/2003 KRU 3S-21 203-031 Nabors 7ES Operator 9 4/1/2003 KRU 3S-21 203-031 Nabors 7ES Operator 1 i Page 1 of 4 File Name I Date I Field/Unit I Well I PTD I Rig I Witnessed? # Components Critical Coi~~ponent Failures Failed ANN PR BR ACCUM 2003 BOPE Tests 4/5/2003 WMRU D1 192-156 Inlet CC1 Operator 3 4/11/2003 KRU 1C-178 203-041 Doyon 141 Crisp 2 4/11/2003 KRU 3S-23 203-045 Nabors 7ES Grimaldi 1 4!13/2003 BCU 11 203-025 Inlet GD1 Operator 1 4/16/2003 DIU 3-256 203-021 Doyon 15 Operator 1 4/20/2003 PBU W-23A 203-056 Nabors 9ES Operator 1 4/21/2003 PBU 13-13A 203-036 Nabors 2ES Jones 2 1 4/22/2003 Alpine CD2-51 202-249 Doyon 19 Operator 1 4/22/2003 Redoubt 3 201-064 Nabors 429 Crisp 2 4/28/2003 Northstar NS-23 203-050 Nabors 33E Operator 2 2 4/29/2003 KRU 3S-17 203-015 Nabors 7ES Operator 1 4/30/2003 MPU S-04 203-052 Doyon 14 Operator 1 5/7/2003 PBU V-202 203-077 Nabors 9ES Spaulding 1 1 5/13/2003 Northstar NS-20 202-188 Nabors 33E Jones 2 5/13/2003 PBU 18-146 203-063 Nordic 1 Jones 2 1 5/14/2003 MPU K-37 196-076 Nabors 4ES Crisp 1 5/17/2003 PBU 02-05A 203-082 Nordic 1 Operator 1 5/21/2003 SRU KGSF 3 203-074 Nabors 129 Jones 8 1 1 5/25/2003 BCU 3RD 203-044 Inlet GD1 Operator 2 2 5/29/2003 MPU L-01A 203-064 Nordic 2 Spaulding _ 3 1 5/31/2003 PBU C-16A 203-084 Nabors 2ES Spaulding 2 6/2/2003 KBU 43-7X 203-066 Inlet GD1 Operator 1 6/7/2003 MPU S-10 203-067 Doyon 14 Operator 1 1 6/8/2003 Redoubt 4A 203-081 Nabors 429 Operator 1 6/16/2003 MPU C-26L1 203-076 Nordic 2 Operator 1 6/17/2003 KRU 1C-172 203-096 Doyon 141 Spaulding 3 1 6/18/2003 Happy Valley 1 203-072 Nabors 129 Grimaldi 4 1 6/19/2003 KBU 14X-6 181-092 Inlet GD1 Operator 1 6/19!2003 Redoubt 4A 203-081 Nabors 429 Jones 2 1 6/22/2003 NCIU A-10 169-088 Kuukpik 5 Crisp 5 6/24/2003 MPU C-26L1 203-076 Nordic 2 Operator 1 1 6/26/2003 PBU 14-32 183-133 Nabors 4ES Grimaldi 1 1 6/28/2003 PBU V-117 203-090 Nabors 9ES Grimaldi 1 6/29/2003 NCIU A-10 169-088 Kuukpik 5 Operator 2 6/30/2003 Alpine CD2-20 202-249 Doyon 19 Scheve 1 6/30/2003 PBU 15-07G 203-097 Nabors 2ES Operator 1 7/2/2003 Happy Valley 1 203-072 Nabors 129 Operator 1 7/9/2003 PBU W-16L1 203-100 Nordic 1 Jones 5 1 7/13/2003 Redoubt 4A 203-081 Nabors 429 Operator 1 7/15/2003 NCIU A-10A 169-088 Kuukpik 5 Operator 1 1 7/16/2003 Happy Valley 2 203-113 Nabors 129 Operator 1 7/18/2003 MPU S-06 203-109 Doyon 14 Scheve 2 7/27/2003 KRU 1A-08 178-040 Nabors 3S Grimaldi 3 1 7/31/2003 Alpine CD2-40 203-126 Doyon 19 Operator 1 8/6/2003 Kustatan 1 200-153 Inlet GC1 Grimaldi 2 1 `J Page 2 of 4 File Name I Date I Field/Unit 2003 BOPE Tests ui~ni~nn~ nice r 8/14/2003 NCU 8/15/2003 Sterling 8/15/2003 Alpine 8/16/2003 KRU 8/18/2003 Sterling 8/18/2003 NCIU 8/20/2003 Alpine 8/20/2003 PBU 8/24/2003 KRU 8/25/2003 SRU 8/26/2003 KRU 8/26/2003 PBU 8/26/2003 PBU 8/27/2003 NCIU 8/28/2003 PBU 8/30/2003 PBU 9/4/2003 PBU 9/6/2003 KRU 9/6/2003 PBU 9/10/2003 PBU 9/11/2003 MPU 9/15/2003 NCU 9/21/2003 PBU 9/24/2003 Alpine 9/28/2003 Redoubt 9/29/2003 PBU 10/4/2003 PBU 10/5/2003 NCIU 10/6!2003 Moquawkie 10/7/2003 Northstar 10/12/2003 CLU 10/17/2003 PBU 10/23/2003 PBU 10/24/2003 Kasilof South 10/25/2003 PBU 10/26/2003 PBU 10/27!2003 Northstar 10/28/2003 KRU 11/2/2003 Kasilof South 11/3/2003 PBU 11/12/2003 TBU 11/13/2003 PBU 11/14/2003 BCU 11/14/2003 PBU Well I PTD I Rig I Witnessed? ~ "I VIII~JVII Failed 3 167-007 Aurora WS 1 Jones 9 3 167-007 Aurora WS 1 Jones 4 41-15 198-041 Inlet GD1 Operator 2 CD2-40 203-126 Doyon 19 Grimaldi 1 3J-19 196-148 Nabors 3S Operator 2 41-15 198-041 Inlet GD1 Operator 1 A-10A 203-075 Kuukpik 5 Operator 1 CD2-40 203-126 Doyon 19 Operator 1 15-28A 203-124 Nordic 1 Operator 1 16-101L1 203-134 Doyon 141 Jones 2 12-15 160-022 Schlumberger 2 Operator 2 2U-08 185-021 Nabors 3S Operator 1 Z-26 189-052 Nabors 4ES Jones 2 W-205 203-116 Nabors 9ES Jones 2 A-10A 203-075 Kuukpik 5 Operator 1 F-15A 203-137 Nordic 1 Scheve 2 L1-15A 203-120 Nordic 2 Scheve 4 F-15A 203-137 Nordic 1 Operator a 2U-10 185-039 Nabors 3S Crisp 3 L1-15A 203-120 Nordic 2 Operator 1 F-06A 203-149 Nabors 2ES Grimaldi 2 S-35 203-143 Doyon 14 Jones ~ 9 202-208 Aurora WS 1 Operator 2 G-12B 203-141 Nordic 1 Operator ~ CD2-55 203-118 Doyon 19 Operator 1 7 203-150 Nabors 429 Jones 1 G-126 203-141 Nordic 1 Operator 2 Q-076 203-157 Nabors 2ES Operator 1 B-3 198-058 Kuukpik.5 Operator 1 1 203-069 Aurora WS 1 Operator NS-29 201-041 Nabors 33E .Jones 3 1 RD 203-129 Inlet GD1 Operator 2 07-146 203-142 Nordic 1 Crisp 1 S-102L1 203-156 Nordic 1 Operator 1 1 202-256 Nabors 273 Operator 1 W-400 203-165 Doyon 141 Operator 1 07-336 203-112 Nordic 2 Jones 3 NS-29 201-041 Nabors .33E Operator 1 1 D-110A 200-039 Nabors 3S Jones 4 1 202-256 Nabors 273 Grimaldi 1 A-24 182-070 Nabors 4ES Operator 1 M-16RD 203-182 Nabors 51 Operator 1 13-30A 203-180 Nabors 2ES Jones 3 13 203-138 Inlet GD1 Operator 1 H-04 203-161 Nordic 1 Operator 1 Critical Core ~+~ent F ANN ~ FR~ BR ~ ,a000i 3 1 1 1 1 1 1 1 --1- 1 1 1 1 t 1 1 • C~ Page 3 of 4 File Name Date Field/Unit Well PTD Rig Witnessed? # Components Critical Co~~iponent Failures Failed ANIJ PR eR A~;CUM 2003 BOPE Tests 11/21/2003 PBU H-04 203-161 Nordic 1 Operator 1 ' 1 11/21/2003 Northstar NS-25 203-166 Nabors 33E Crisp 2 11/22/2003 Iliamna 1 203-172 Pelican Hill 7 Operator 2 1 11/22/2003 Alpine CD2-07 203-187 Doyon 19 Operator 2 1 11/25/2003 Northstar NS-27 201-027 Nabors 33E Operator 1 1 11/27/2003 PBU S-276 203-168 Nabors 2ES Operator 1 1 11/28/2003 PBU Z-100 203-171 Nabors 7ES Crisp 3 2 12/10/2003 PBU K-19AL1 203-190 Nordic 1 Operator 1 1 12/17/2003 PBU W-01A 203-176 Nordic 2 Crisp 1 12/18/2003 KBU 33-6X 203-183 Nabors 129 Operator 1 12/20/2003 PBU 02-37L1 203-098 Nordic 1 Operator 1 1 12/29/2003 KBU 33-6X 203-183 Nabors 129 Operator 1 12/31/2003 PBU 15-33B 203-194 Nordic 1 Jones 3 1 12/31/2003 KRU 2P-424 203-203 Do on 141 O erator 1 Failure Totals - 2003 260 3 26 18 20 2003 Summa Tests 5g2 Components Tested (-25/test) 14800 Critical Components Failed 67 Critical Component Failure Rate 0.004527 All Componet Failure Rate 0.0175676 0.45% 1.76% Page 4 of 4 File Name BOP Performance: 2004 Failures valid thru: 4f30/200~ Date Field/Unit Well PTD Ri Witnessed? # Components Critical Component Fail~rres g Failed ANN PR BR ACCUM 1/4/2004 PBU L-210 203-199 Nabors 9ES Grimaldi 2 1/5/2004 PBU 15-04A 203-114 Nordic 2 Operator 1 1/6/2004 CLU 7 203-191 Inlet GD1 Operator 1 1/6/2004 Kasilof South 1 202-256 Nabors 273 Operator 1 1/8/2004 PBU L2-14 187-102 Nabors 2ES Jones 1 1/12/2004 PBU 05-41A 203-170 Nordic 1 Operator 1 1/13/2004 Kasilof South 1 202-256 Nabors 273 Grimaldi 1 1/13/2004 PBU Z-30A 203-219 Nabors 7ES Spaulding 1 1/13/2004 PBU 15-04A 203-114 Nordic 2 Operator 1 1/19/2004 PBU L2-14A 203-214 Nordic 2 Operator 1 1/21/2004 PBU 05-41A 203-170 Nordic 1 Operator 1 1/24/2004 Redoubt 1 200-165 Cudd 131 Jones 13 1 2 1/26/2004 Alpine CD1-23 203-225 Doyon 19 Scheve 5 2 1/26/2004 PBU 01-17B 204-012 Nordic 1 Operator 1 1 1/28/2004 Hot Ice 1 203-026 DynaTec 6 Crisp 5 1/28/2004 CLU 8 204-005 Inlet GD1 Jones 2 1/30/2004 MPU G-16L1 203-211 Doyon 14 Operator 1 2/2/2004 Redoubt 1 200-165 Cudd 131 Operator 7 2/3/2004 KRU 3F-19A 204-016 Nordic 3 Crisp 1 2/11!2004 Redoubt 1 200-165 Cudd 131 Operator 1 2/11/2004 Niakuk NK-12C 203-055 Nordic 1 Operator 1 2/12/2004 PBU 17-07A 204-011 Nabors 7ES Jones 4 2/13/2004 PBU A-28 182-150 Nabors 4ES Jones 3 2/13/2004 Happy Valley 5 204-007 Kuukpik 5 Grimaldi 3 1 1 2/14/2004 KRU 2P-449 204-026 Doyon 141 Operator 2 2/15/2004 KRU 3F-19A 204-016 Nordic 3 Scheve 3 i - 2/18/2004 Niakuk NK-12C 203-055 Nordic 1 Operator 1 2/21/2004 Redoubt 1 200-165 Cudd 131 Grimaldi 4 2/21/2004 PBU 01-19A 202-022 Nabors 4ES Operator 1 1 2/25/2004 Nikaitchuq 1 204-018 Nabors 27E Spaulding 2 2/26/2004 Happy Valley 3 203-022 Kuukpik 5 Grimaldi 2 2 2/27/2004 Paxton 1 204-010 Nabors 129 Operator 1 2/27/2004 PBU A-38L2 203-184 Nordic 1 Operator 4 1 2/28/2004 DIU 03-17F 203-216 Nordic 2 Operator 1 2/29/2004 Redoubt 1 200-165 Cudd.131 Operator 1 3/10/2004 Redoubt 7 203-150 Cudd 131 Operator 8 3/11/2004 DIU 03-17F 203-216 Nordic 2 Operator 1 3/11/2004 Placer 1 204-014 ~ Nordic 3 Grimaldi 2 3/13/2004 Happy Valley 3 203-022 Kuukpik 5 Operator 2 3/18/2004 Redoubt 7 203-150 Cudd 131 Scheve 1 i Page 1 of 2 File Name Date Field/Unit Well PTD Rig Witnessed? # Components Critical'Component Failures Failed ANN PR BR ACCUM 2004 BOPE Tests 3/18/2004 Nikaitchuq 2 204-038 Nabors 27E Crisp 2 3/21/2004 PBU 03-07A 204-043 Nabors 2ES Jones 2 1 3/22/2004 KBU 33-6 199-024 Inlet GD1 Operator 1 3/24/2004 Nikaitchuq 2 204-038 Nabors 27E Operator 1 3/26/2004 MPU C-43 204-039 Doyon 14 Scheve 2 3/29/2004 Spark 4 204-008 Doyon 19 Operator 3 4/1/2004 PBU L-201 204-046 Nabors 9ES Crisp 2 4/4/2004 KRU 1 E-119 204-031 Doyon 141 Operator 1 4/5/2004 DIU 1-65A 203-212 Nordic 2 Scheve 2 4/9/2004 MGS C43-14 188-132 XTOC Operator 1 4/9/2004 KRU 2P-443 204-032 Nordic 3 Jones 3 1 4/10/2004 Happy Valley 6 204-044 Kuukpik 5 Operator 2 4/13/2004 PBU L-201 L1 204-047 Nabors 9ES Operator 1 4/18/2004 Alpine CD1-46 204-024 Doyon 19 Operator 2 1 4/18/2004 Kenai 31-7X 200-148 Inlet GD1 Grimaldi 1 4/21/2004 PBU L-201 L2 204-048 Nabors 9ES Operator 1 4/21/2004 PBU 14-06A 204-036 Nordic 2 Grimaldi 2 1 1' 4/23!2004 KRU 1 L-09 190-034 Nabors 3S Grimaldi 2 4/29/2004 PBU 14-06A 204-036 Nordic 2 Operator 1 1 Failure Totals - 2004 127 5 7 3 6 valid thru~ dl:i(7C2€~{7d 2004 Summary Tests 177 Components Tested (~25/test) 4425 Critical Com onents Failed 21 Critical Component Failure Rate 0.0047458 All Componet Failure Rate 0.000452 0.47% • 0.05% Page 2 of 2 BOPE Failure Rates: 2001-2004 2001 2002 2003 2004"` BOPE Tests 686 598 592 177 Components Tested (25/test) 17150 14950 14800 4425 All Components Failed 396 324 260 127 All Components Failure Rate 2.31 % 2.17% 1.76% 2.87% Critical Components Failed 81 49 67 21 Annular 20 7 3 5 Pipe Rams 36 17 26 7 Blind Rams 15 15 18 3 Accumulator 10 10 20 6 Critical Com onent Failure Rate 0.47% 0.33% 0.45% 0.47% " 2004 Failure Rates Valid Through: 4f3012004 Totals 2053 51325 1107 2.16% 218 35 86 51 46 0.42% .._ BP-AMOCO EXPLORATION, ALASKA Historical Blowout Study North Slope, Alaska Prepared by Anchorage, Alaska June, 2000 ~ ~ Historical Blowout Study North Slope, Alaska Table of Contents Introduction Purpose and Scope of Study ........................................... 1 Research Methods and Sources .................................. .. 1 Defuution of Blowout ...................................................... 3 Incidents Documented ................................................... . .. 3 Geographical Characterization ........................:...:................ 3 Table: Incident Summary ................................................... 4 Blowout Narratives Simpson Core Test # 16 .... ~-~;~: ~ . ~'.~:: ;.... ~~:3~- ~: ~~ . ...... 5 Simpson Core Test #26 ..... :~.~.~ :-.1 x.4c..... < < ~:~.::: ~ l....`>.:~ .......... 6 Gubik #2 ......~C:t.~:::.~~. ~,. ... ~' ~:` ~ `°'.1 ice-: ~ l ................ ..... 7 CPF 1-23 ...................... . ......... ............................... 11 Cirque # 1 ....... -' ~ ~:~ . ............ ~'~ : ..:.~~` .................... . . 1-53/Q-20 .......Ic4.-~. ~ , ? . ..............~~j~w.: ~i'.--~,.............. ... 13 Well Control Incident Narratives Alaska State A-1 ...... :.:~, : ~. ~,': ~....:~'~'.~~ ..`:~ ~ ~:°::~~ .......... 14 _,. Tunalik Test Well #1 ..::-......~.~ ................:..°~.' ~.: ~`~.......... 15 ~~ * ~ PBU 15-21 .......... ~ ~:'.:- ~.~,4.~ s .......... ~- ...:.. '` ~ : `~': ~ .......... 16 Challenge Island # 1 ~.: :,- .:: ~ . . ................:. `. ' ..: ~............. 17 KRU 1H-15 ......... ..~.......~:.~£~ .. ......... ... `~ ..:...........:.. 19 =. KRU 3F-19 ...........~~~~~ : ~.t~:~ ..................:: ~:~.`:`"_`~...----...... 19 Sources 20 ~ ~ Alaska North Slope Historical Blowout Study Purpose and Scope of Study BP-Amoco Exploration (Alaska), Inc. contracted Fairweather E&P Services, Inc. to perform an exhaustive review and documentation of all historical loss-of- control well incidents that have occurred to date on the North Slope of Alaska. The scope of the study includes documentation of known well control incidents, a search of all available sources of information that may reveal poorly documented or forgotten North Slope well control incidents .and documentation of them. Although the primary subject of this study is blowouts, other serious well control incidents that did not ultimately result in blowouts are discussed. It is important to be aware of these non-blowout incidents, as they are the root subjects of much anecdotal evidence prevalent among people within and outside of the industry in Alaska. -This study does not attempt to document in detail everything .that happened during each blowout or well control incident. If such detailed knowledge is needed on any particular event, the information source list contained in this report will steer the researcher to sources of detailed information. Research Methods and Sources This study uses as it's starting point the results of C.R. Mallary's 1998. study, "A Review of Alaska North Slope Blowouts, 1974-1997" for BP Exploration (Alaska), Inc. Mallary's study covers recent, well-documented blowouts, but was limited in scope to relatively recent times and to wells that suffered catastrophic blowouts. In the preparation of the current report, there was no additional research performed on 5 of the 7 wells cited in Mallary's study and the narratives included here are substantially unchanged from his. Mallary touched on the CPFl-23 and Challenge Island # 1 blowouts, but did not detail them, as research on .those incidents was ongoing when his report was issued. These 2 wells were researched for this report and are expanded upon here. Tracking down information on undocumented well control problems for this study began with conducting interviews with various people within or associated with the drilling industry on the North Slope. Many are no longer active in the industry, but served as excellent sources of information. These interviews yielded clues to additional sources as well as names and approximate dates of candidate wells that were then further researched in the archives of Operators and State and Federal agencies. 1 ~ r We are confident that all of the North Slope blowouts that have occurred are documented here. The Alaska Oil and gas Conservation Commission maintains an internal documentation of blowouts in Alaska and, while neither we nor Mallary were permitted to examine that documentation, the AOGCC has assured us that we have overlooked no North Slope blowouts of which they are aware. Further, ' all: published reports on wells drilled by and for Federal agencies on the North Slope were reviewed and interviews were conducted with Federal agency personnel and private contractors involved with the wells. All of the troublesome wells referenced in the reports or referred to in interviews were researched and the ones found to be real and significant are included in this study. Finally, many people who are known to have been involved in and. knowledgeable about the Alaskan oil .industry were interviewed on the subject of memorable troublesome wells and all of the wells they referenced were investigated. Our research was halted when all new information sources consistently referenced the same wells already investigated and no new incidents were being brought to light. Sufficient overlaps and repeats of information exist as well as lack of further evidence in the various archives examined and interviews conducted that we are confident there are no blowouts or serious well control incidents left un- addressed in this study. A comprehensive list of sources is listed at the end of this study and all incident narratives reference the appropriate listed sources. Documentation of well control .incidents in the historical record prior to 1970, when the industry became firmly established on the North Slope, is very sketchy.. The only. formal documentation is contained in general reports by and for government agencies summarizing large, multi-well exploration programs that emphasized geological findings rather than operational details. Researchers will find little more in those reports than what is offered in the narratives in this report. These early events also suffer the disadvantage of having occurred so long ago that there are few people left to provide even anecdotal evidence. Nevertheless, the search performed through published reports on wells drilled prior to 1970 leaves us confident. that there were no wells left un-examined and no serious incidents left unidentified here. Recent well control incidents present the opposite problem. They are documented in so much detail and by so many parties that discerning what actually occurred and what the causes were sometimes becomes a challenge. The narratives presented here summarize the events but do not attempt to detail causes as post- event analyses by operators, individuals and agencies often conflict as to the causes. Detailed documentation of these events can be found by consulting the sources cited at the end of this report. 2 ~ ~ Definition of Blowout It became necessary early in the research phase to provide interviewees and agencies with a strict definition of "blowout" in order to focus the search. The definition we provided and which we use in referring to blowouts in this study is: Blowout: An uncontrolled flow at the surface of liquids and/or gas from. the wellbore resulting from human error and/or equipment failure. This definition resulted in downgrading the subjects of much dramatic anecdotal evidence- from "blowout" to "well control incident". Several "blowouts" recalled in interviews turned out to be kicks that necessitated lengthy and difficult operations to bring the well back under control but did not meet the definition of blowout as given above. Incidents Documented The table on Page 4 lists the blowouts and well control incidents identified and discussed in this report. The list of blowouts is complete. However, the well control incidents, or "kicks", listed are only those that entailed a greater amount of time and/or effort than usual to retain control of the well. It is not within the scope of this study to identify every historical kick that was routinely encountered and circulated out. As will be seen in the narratives for Simpson Core Tests # 16 and #26, it could be .questionable that they be called blowouts. They technically meet the definition of blowout given above, but the flows to surface were un-spectacular and could not have been avoided in that there were no casings or BOPE available to prevent them. Geographic Characterization The types and timing of North Slope well control incidents divide themselves into three geographical areas. The Eastern North Slope around the Pt. Thomson/ Flaxman Island area has a history of pressure problems at depths around 12,000'. Several large kicks have been encountered, of which Exxon's Alaska State A-1 (documented in this report) is typical, but there have been no blowouts. The blowouts on the Western North Slope all occurred during early U.S. Navy exploration of Naval Petroleum Reserve No, 4 (now called NPRA) and resulted from poor drilling practices used long ago. The Central North Slope contains all of the developed and developing North Slope oilfields. 3 BLOWOUTS Well Year Field/Area O eration at Time Influx Fluid O erator Simpson Core Test #16 1949 NPRA, Cape Simpson Drilling (exploratory) Gas U.S. Navy Simpson Core Test #26 1950 NPRA, Cape. Simpson Drilling (exploratory) Oil' U.S. Navy Gubik #2 1951 Near Umiat, Western N. Slope Drilling (exploratory) Gas U.S. Navy Kavik #1 1969 Canning R., Eastern N. Slope Drilling (exploratory) Gas Pan American Petroleum Corp. NGI-7 * 1976 Prudhoe Bay Field Workover (development) Gas ARCO Alaska, Inc. CPF 1 23 * 1979 Kuparuk River Field Drilling (disposal well) .Gas ARCO Alaska, Inc. F-20 * 1986 Prudhoe Bay Field Drilling (development) Gas BP Exploration (Alaska), Inc. J-23 * 1987 Prudhoe Bay Field Completion (development Gas BP Exploration (Alaska), Inc. Cirque #1 * 1992 Colville R., Central N. Slope Drilling (exploratory) Gas ARCO Alaska, Inc. .1-53/Q-20 * 1994 Endicott Field Drillin develo ment) Gas BP Exploration (Alaska), Inc. .~ KICKS Well Year Field/Area Ty a of Well Influx Fluid O erator Alaska State A-1 1975 Flaxman Is., Eastern N. Slope Drilling (exploratory) Gas Exxon Tunalik Test Well #1 1978 NPRA, Icy Cape Drilling (exploratory) Gas U.S. Geological Survey 15-21 1980 Prudhoe Bay Field Drilling (development) Gas ARCO Alaska, Ina Challenge Island #1 * 1981 Pt. Thomson, Eastern N. Slope Drilling (exploratory) Gas w/minor oil Sohio Alaska Petroleum Co. LS-36 1989 Lisburne Field Drilling (development) Gas ARCO Alaska, Inc. 1H-15 1993 Kuparuk River Field Drilling (development) Unknown ARCO Alaska, Inc. 3F-19 1996 Ku aruk River Field Drillin develo ment) Unknown ARCO Alaska, Inc. * Incident previously identified in Mallary study (1998) BLOWOUT NAl~;R.ATIVES Simpson Core Test #16 Simpson Core Test #26 Gubik #2 Kavik #1 NGI-7 CPF1-23 F-20 J-23 .Cirque #1 1-53/Q-20 SIMPSON CORE TEST # 16 U.S. NAVY The history of Simpson Core Test # 16, spudded on August 24, 1949, is extremely sketchy.. This well, located near Simpson Lagoon on the Western North Slope, experienced a gas blowout, and produced gas for more than a year afterward.. No casing was set in the well. On August 31, 1949, .while drilling at a depth of 800' gas came to surface and accidentally caught fire. 600 gallons of water were pumped into the well in an attempt to kill it, but the gas blew out most of it back out. The rig was then moved off of the well. Melting of surficial ice and sloughing around the hole created afunnel-shaped cavity approximately 25' in diameter. The fire went out by itself on September 2, though gas continued to flow. Water was left in the hole to freeze, but the gas continued to flow for more than a year. A photo shows gas bubbling out of the crater after the rig had been hauled off. There is no evidence in the photo of a wellhead, casing or remaining rig equipment. Sources: 2, 20, 22 5 SIMPSON CORE TEST # 26 U.S. NAVY The Simpson Core Test # 26 was spudded on August 13, 1950 neaz Simpson Lagoon on the Western North Slope. The operator was drilling ahead at 306' when oil began to flow from the well. No casing or conductor had been set. Oil filled the mud pit and covered the area around the rig with about a foot of fluffy gas cut oil. The mud in the drill pipe became partly frozen and fairly lazge ice crystals were observed in the oil. The oil flow decreased as the hole continued to freeze. The operator reamed the frozen hole to 295' and circulated 12.7 ppg mud. This killed the well for approximately an hour, but it .then began to flow again. Reports indicate that drilling was shut down for 7 days while cementing equipment was installed and rig engine repairs were made. It is assumed the well continued to flow oil during this period. Upon resumption of operations, 14.2 ppg mud was circulated into the well but the well continued to flow some gas-cut mud. The pump had difficulty circulating the gas- and oil-cut mud and, as circulation decreased, the hole froze up again. After reaming the frozen hole, drilling operations recommenced. While drilling at 509', the well again flowed oil to the surface, but was stopped with the pumping of 12.0 .ppg mud into the hole. Drilling continued to 895' during which time the drill pipe twisted off twice. The well froze again during the second fishing operation and ice was reamed from the surface to 350' to enable setting casing. Fresh water was used for reaming and oil continued to flow from the well. At 350', "heavy mud" (density unknown) was circulated into the well. No heavy mud returned, but the oil flow ceased. 8-5/8" casing was run to 350' and cemented. The well was then drilled to 1,171' TD with no further well control incidents. Sources: 20, 22 6 i ~ GUBIK # 2 U.S. DEPARTMENT OF THE NAVY The Gubik #2 well was spudded in on Sept. 11, 1951 on the Western North Slope, northeast of Umiat. With the well at 120', surface casing was run consisting of 101' of 16 '/2", 471b., slip joint welded casing. The top 40' was jacketed with. 23" casing. The casing was cemented to surface with 100 sacks of Cal-Seal. At 810',. intermediate casing was run consisting of 34 joints of 11 3/4", 47 lb, 8 round casing.- The casing was cemented with 8 bbls of 15 percent by weight salt brine, 40 bbls of diesel oil, and 200 sacks of Hi-Early cement. On December 5, with the well at 4,620' the hole was plugged back with cement from 2300' - 2200' approximately. The operator started out of the hole intending to run in with a 10-5/8" bit to dress off the cement to 2200'. With three stands of drill pipe still in the slips, the well started to flow mud and immediately went out of control An attempt was made to close the pipe rams around the drill pipe, but mud and gas continued blowing .out at an undiminished rate. It was later found that the blowing wellbore fluids had lifted. the pipe out of the slips and dropped it into the hole. Gas continued to flow and, after an estimated five minutes, the well ignited and the .rig collapsed three or four minutes later. The well .sanded up in a few hours, but enough gas, thought to originate in a shallower sand, continued to escape from the casing to maintain a flame 4' to 6' high. Two days after the original blowout, the well again blew out with .volume and force about the same as the first time, but it again sanded up within a few hours and continued to burn with a flame about 4' or 5' high. Wreckage was cut away with a torch before extinguishing the blaze in order to remove the Shaffer gates, which were still usable. After the blaze was extinguished with carbon dioxide, the hole was filled with water above the bridge and allowed to freeze. The 204 bbls of water required to fill the well indicated the bridge was at approximately 1,800'. It was impossible to set plugs between the various gas sands logged above 1,800'; therefore, there is only a bridge of sand or fill to prevent the movement of high- pressure gas from the 1,800' sand upward to any of the various shallower permeable sands beginning at 1,134'. The well was abandoned on December 14, 1951 with the following wellhead equipment in place: from the bottom up, starting at the cellar floor, there is an 11 3/a" landing base, 11 3/a" landing spool, adapter flange, 10 3/a" x 3" swedge, and a 3" plug valve. The only zone in this well that showed by formation test to have high pressure, large volume gas was between 1,810' and 1,858'. This zone was also the only one on the resistivity log about which there .could be no question of the content being oil or gas. Sources: 2, 4, 14, 15, 18, 23, 27 g KAVIK # 1 PAN AMERICAN PETROLEUM CORP. On March 17; 1969 there was a blowout and fire at the Kavik # 1, located on the Eastern North Slope next to the Canning River. Five days after the incident, two members of the AOGCC flew to the location and interviewed various people about what had happened. The information was written in a memo to the Alaska Oil and Gas Conservation Commission's (AOGCC) well file and dated March 27, 1969. It is this report, supplemented by interviews with.- people present at the time that serve as the sources for the following account. With 13-3/8" casing set at approximately 3,000', drilling was underway at approximately 4,300'. The operator had encountered a gas stringer at 4,100' as well as a lost circulation zone while drilling 12-'/a" hole. The operator was pulling out of the hole and had reached the BHA when gas pressure under the drill collazs in the rotary table blew .the drill collars out of the hole and through the crown. A witness on the rig floor saw a rock strike a piece of steel, which caused a spark that set the gas on fire inside the derrick. All flame was confined to the inside of the derrick. As soon as .the well blew out, the Operator's Representative closed the annular preventer, thinking the collars were still in the hole, however the fire continued to bum. An off-duty driller saw what was happening, ran under the floor and closed the blind rams. This immediately extinguished the fire. The fire had burned for approximately 2 to 2-1/2 minutes prior to being extinguished. The fire resulted in injury to the derrick man. He was on the monkey boards and was wearing heavy clothing and an azctic facemask, but no gloves. When the well blew out, mud and rocks were blown up through the derrick covering the derrick man in mud. The flame from the fire coming up through the derrick was quite hot. As he started down the ladder, he found the steel too hot to hold on to. He climbed back to the monkey boazds and slid down the dead line of the drilling cable, holding on with his haze hands. The drop was approximately 90'. The fire had been extinguished by the time he had returned to the monkey boards and crewmen had attempted to convince him that there was no more danger, but he was very excited and frightened and wanted to get down the fastest way possible. He suffered serious bums to his hands, but no other serious bums to the rest of his body. 9 The rig was under repair for approximately two weeks after the incident. A snubbing unit was brought in to kill the well, and later drilling resumed without further incident. None of the information sources could offer more than speculation as to the cause of .the blowout. Sources: 14,18 NGI-7 ARCO Alaska, Inc. In 1976, while completing Prudhoe Bay gas injector NGI-7 with a drilling rig, a leak path developed at the bottom of the 7" production liner. With three joints of a 7" circulating string in the hole, the well started to unload diesel completion fluid. The blind rams were closed on a strong gas flow but the rams failed 20 minutes later. The annulaz preventer was closed, but the rig crew had been unable to stab a safety valve on the 7" and .the well blew out dry gas and condensate through the circulating string. Well control was eventually regained by plugging the flow with a hydrate plug and performing a top kill via the lubricate-and-bleed method. Source: 16 io ~ • CPF1-23 ARCO ALASKA, INC. CPF1-23 was spudded on 8/23/79 as a water injection well near the Kuparuk Base Camp. The 12-1/4" surface hole had been drilled to a depth of 2,~4' and the drill string .was being brought out of the hole in preparation for running surface pipe. Seven stands (651') of HWDP and 6 drill collars (184') and bit were still in the hole when the well started to unload. The two 6" diverter valves were opened and the diverter was closed. An AOGCC representative reported the well blew 9.3 to 9.6 ppg drilling mud and gravel out of the well bore and through the diverter. Approximately nine hours later the well was still blowing gas with 6 to A0 psi on the diverter lines. Two attempts to pump mud through a 4" port below the 6" diverter line outlets were moderately successful. 125 bbls of 15.0 lb/gal was pumped down the annulus with approximately 35 to 50 bbls staying in the well bore and the remaining being blown out through the diverter by the gas. In a second attempt approximately one hour later, 508 bbls of 14.5 lb/gal mud were. pumped down the annulus. Half of the mud stayed in ,the well bore while the other half was blown out through the diverter. The gas pressure on the diverter lines had diminished to 3 - 4 psi. Gas pressure on the diverter lines declined 0.5 to 1 psi over the next 24 hrs. Very weak gas bubbling was observed in the cellar around the outside of the conductor. A circulating head and Schlumberger wire line preventers with 1-'/4" ram blocks were rigged up on top of the 5" drill pipe. 1-'/4" tubing was run into the drill pipe while circulating 140 degree, 14.5 lb/gal mud to clean out frozen material. The mud was then displaced out of the drill pipe with a 50/50 mixture of glycol and water. The 1 '/4" tubing was pulled out of the drill pipe and laid down. Circulation down the drill pipe was established, but after 10 - 12 bbls were pumped the jets in the bit plugged. The hole was filled through the annulus with 13 8 bbls of mud and stood full with no signs of gas. Schlumberger was rigged up and the drill collars were perforated at 650'. The well was circulated with mud and the remainder of the BHA was pulled out and laid down. Anew BHA was picked up and run in the hole. The hole was reamed to 1,704' where circulation was lost. The hole was displaced with lighter mud and returns were regained. After washing and reaming to 2250', logs were run and 10 3/a" surface casing was set. No other well control problems were encountered while drilling the well. Sources: 14, 27 li ~ ~ F-20 BP Exploration (Alaska), Inc. In 1986, an intersection of Prudhoe Bay ,Well F-9 by Well F-20 caused a subsurface blowout and gas percolation in well cellars. Communication between the two wells occurred when the drill string in F-9 wore a hole through the surface casing and production tubing. The incident was controlled with cement plugs in F-9 and a top kill in F-20. Source: 16 J-23 BP Exploration (Alaska}, Inc. Well J-23 was being completed in the Prudhoe Bay Field in 1987 when an annular gas flow occurred. Gas percolated up through the well cellar under the rig. The gas source was determined to be the Seabee Formation. The flow path was believed to be up the 9-S/8" intermediate casing annulus (the cement top was below the hydrocarbon-bearing Seabee Fm.) to the 13-3/8" surface casing, and then up the outside of the 13-3/8" to the cellar. Remedial cement work was performed which successfully shut off the gas flow. Source: 16 Cirque # 1 ARCO Alaska, Inc. Cirque # 1 was an exploration well spudded during the winter of 1992 on the Central North Slope southwest of the Kuparuk River Field. A conductor and diverter had been set and, while tripping out of the hole to run surface casing, a gas kick was .swabbed in. The well kicked out all the drilling mud and the diverter was closed as the crew abandoned the rig. Dry gas flowed from the well at a high rate, but there'~vas na fre or exploai+e~:`Attempts were made to kill the well using the rig equipment on location, but the lines had all frozen when the rig was: shut down upon the well blowing out. A relief well was spudded and was nearing TD when a top kill, possibly aided by the blowing well bridging itself off was successfully achieved. Source: 16 12 • 1-53/Q-20 BP Exploration (Alaska), Inc. Well 1-53 was drilled in 1994 in the Endicott Field. During intermediate hole drilling operations, a 33 bbl gas kick was taken from the Kekituk Reservoir. After shutting the well in, gas broached to the surface in the cellar of well 1-53 and adjacent wells, Flow from the well was sent to the process plant while a dynamic kill was designed and successfully implemented. Source: 16 13 WELL CONTROL INCIDENT NA1~.RATIVES Alaska State. A-1 Tunalik Test Well #1 PBU 15-21 Challenge Island #1 L5-36 KRU 1H-15 KRU 3F-19 ALASKA STATE A-1 EXXON Alaska State A-1 was spudded on March 15, 1975 on Flaxman Island on the Eastern North Slope. On June 6, 1975, with 13-3/8" casing cemented at 3,378', the .operator was coring at 12,463' when an abnormal pressure zone was encountered. The 11.4 ppg mud was. gas cut and the well was .shut in with SICP 430 and SIDPP 200. The mud weight was raised to 12.0 ppg and the well was killed through the core barrel. A temperature log was run to ensure no subsurface flow between zones. After working the circulating mud weight up to 13.3 ppg, 135 bbls of 19.0 ppg mud was spotted at the bottom of the well with 185 bbls of 17.0 ppg mud spotted above that in order to stabilize the well sufficiently to allow wireline logging. After successfully logging the open hole, another 235 bbl, 20.0 ppg pill was spotted in the well and the hole above the pill conditioned with 13.3 ppg mud in preparation for n~nning 9-5/8" casing. Circulation was lost, but then regained after pumping LCM. 16.5 and 15.0 ppg mud was spotted on bottom and the well conditioned at the casing shoe with 12.8 ppg mud. There. followed 2 weeks of attempting to balance circulating with kill weight mud and solve lost circulation problems. Forty-four days after experiencing the first gas kick, 9-518" casing was finally run and cemented at 11,076' in spite of consistent oil-and-gas .cut mud. Additional abnormal pressures were encountered while drilling 8-1/2" hole. Varying mud weights were used until a 7" liner was set at TD. Source: 14 14 ~ ~ TUNALIK TEST WELL # 1 U.S. GEOLOGICAL SURVEY The Tunalik Test Well # 1 was drilled from November 9, 1978 to January 7, 1980 on the Western North Slope near Icy Cape. Several kicks and drilling breaks were experienced in this well prior to running 13-3/8" casing, but the most significant well control problem occurred while drillingl2-1/4" hole at a depth of 12,557'. On 4/9/79, with 13-3/8" casing set at 8,298', the operator was drilling ahead at 12,557' with 13.5 ppg mud in the hole and stopped to check for flow. The well was flowing, so the operator recorded drill pipe and casing pressures, increased the mud weight to 14.5 ppg and circulated it into the well. The well continued to flow, so the operator raised the mud weight to 14.8 ppg, but started experiencing lost circulation while pumping it. The rate and pressure down the drill pipe were decreased and full returns were regained. However, .the mud came back cut in weight. For the next 53 days the operator alternated varying kill mud weights with pumping rates and pressures in attempting to kill the well while experiencing varying degrees of lost circulation. Finally, on 5/29/79 a cement plug was spotted from 12,557' to 12,357' and 12,385' of 9 3/4" casing was successfully run on 6/5/79. No other significant well control problems occurred after the 9 3/a" casing was set and cemented. Sources: 4, 8, 10 15 ~ ~ D.S. 15-21 ARCO ALASKA, INC. Prudhoe Bay Unit Well 15-21 experienced a kick that is not particularly notable among others that have been circulated out of North Slope wells. It is significant enough to be included here because: 1) it kicked while cunning casing and, 2) there are numerous anecdotal references to it among people interviewed about historical North Slope well control problems. Well 15-21 was spudded on 10/6/80 on Prudhoe Bay Unit Drillsite 15. 9-5/8" casing had been set at 10,838' and 8-1/2" hole drilled to 11,860'. The operator was rnnning approximately 1,400' of 7" liner on drill pipe and the liner shoe was at 9,920' when the well began to kick. The well was shut with the annular preventer around the drill pipe and pressures taken. The well was killed with 11.3 ppg mud, then the BOPS were opened. While the hole was being conditioned with 11.3 ppg kill-weight mud, the well kicked again with the mud weight being cut to 10.6 ppg.. The mud weight was increased to 11.5 ppg and the well killed again with minor mud losses to the hole being experienced. LCM was pumped to cure the lost circulation problem and the. liner was run to TD and cemented. There were no further well control problems experienced in this well. Sources: 9, 13, 14, 27 16 • • CHALLENGE ISLAND #1 SOHIO ALASKA. PETROLEUM CO. The Challenge Island # 1 well was drilled on the Eastern North Slope from Challenge Island, northwest of Point Thomson. On February 1, 1981, with 9-5/8" casing set at 10,393', the operator was drilling ahead at 13,587' with 15.4 ppg mud when circulation was lost. Pumping LCM and lowering the mud weight to 15.0 ppg resulted in temporary and sporadic relief from lost circulation, but allowed the well to flow. Flow increased while mixing mud to 15.0 ppg and circulating bottoms up from the 9-5/8" casing shoe. The well was shut in with 900 psi SICP and 900 psi SIDPP. Annulus returns contained an oiUwater ratio of 6.5/100. 15.4 ppg mud was mixed and pumped as quickly as possible. However, well control efforts extended over a period of 5 days, hampered by difficulties in handling the gas-cut mud at the surface, inability to pump down the annulus and a plugged choke. Pressure-related line failures and BOP stack leaks at the surface began to occur as the casing pressure climbed erratically upward. Finally, with the SICP at 5,500 psi, the SIDPP at 450 psi, the annulus packed off and the BOPs leaking, the operator decided to abandon the well. With the bit at 10,266', the drill pipe was perforated and the well cemented via the perforations. Three weeks were spent abandoning the well, complicated by continuing well control problems, fishing operations and lost circulation. Sources: 1, 6 i~ • L5-36 ARCO ALASKA, INC. On April 10, 1989, while drilling ahead in the Lisburne Field at 11,849', circulation was lost and the drill string became stuck. Jarring operations commenced while attempting to keep the hole filled on the backside.. A total of 600 bbls of 9.8 ppg mud was lost. Partial returns were eventually regained. The pipe was freed and the well started to flow. The well was shut in and 9.6 ppg mud was circulated through the choke. The initial shut in pressures were SICP 275, SIDPP 0, with gas back to surface. Over the following 72 hours attempts were made to kill the well with gas being vented through the choke and gas buster, but the operator was unable to regain control with mud. Finally, the drill pipe was perforated and the well killed by pumping cement through the perforations. This required three attempts. Data obtained through research is unclear on whether this well was abandoned or sidetracked. Sources: 14, 27 is i • 3F-19 ARCO ALASKA, INC. Well 3F-19 was being drilled in the Kuparuk River Field on June 26, 1996 when the well kicked at 7901' with 10.7 ppg/mud in the hole. Three days were spent " gradually weighting up the mud to 12.6 ppg and circulating until the well was killed. .Once the well was killed, a short trip was conducted, the remaining 300' of hole was drilled, and 7" casing was run without further incident. Sources: 27 1H-15 ARCO ALASKA, INC. Well 1H-15 was being drilled in the Kuparuk River Field on January 17, 1993 when, at 9,711', the driller noticed a pit increase. The well was shut in with SIDPP 400, SICP 800. Three days were spent gradually weighting up the mud to 12.0 ppg and circulating until the well was killed and drilling resumed. Sources: 27 19 ~ ~ INFORMATION SOURCES ._. • SOURCES 1) BP-Amoco Library, Challenge Island #1 well files 2) Baggett, David, Pers. Comm., President, Quadco Inc. • 3) Bixby, William, Pers. Comm., Tool Pusher, Nabors Alaska Drilling Co. 4) Brewer, Max C., Pers. Comm., U.S.G.S. Geologist, retired 5) Brockway, Randy, Pers. Comm., former U.S.G.S. Geologist 6) Driskill, Larry, Pers. Comm., former Drilling Superintendent, BPXA 7) Gardner, Robert, Pers. Comm., President, Fairweather E & P Services, Inc. 8) Heim, Dink, Pers. Comm., Consulting Drilling Supervisor 9) Henley, Chazlie, Pers. Comm., Tool Pusher, Nabors Alaska Drilling Co. 10) Hewitt, S. L., History of Drilling .Operations, Tunalik Test Well No. 1, Husky Oil NPR Operations, Inc., June 1983 11) Hicks, Randy, Pers. Comm., Vice President of Operations, Quadco Inc. 12) Keener, Jack, Pers. Comm., former Tool Pusher, Brinkerhoff Drilling Co. 13) Larkin, Richazd, Pers. Comm., Tool Pusher, Nabors Alaska Drilling Co. 14) Library, Alaska Oil and Gas Conservation Commission (AOGCC), Well Files, et al, 3001 Porcupine Road, Anchorage, Alaska 15) Lowe, David, Pers. Comm., Consulting Mechanical Engineer 16) Mallary, C. R., A Review Of Alaska North Slope Blowouts, 1974-1997, June 1998 17) Mallary, C. R., Pers. Comm., Senior Drilling Engineer, BPXA 18) Mangus, Marvin, Pers. Comm., U.S.G.S. Geologist, retired 20 • • 19) Mead, Robert, Pers. Comm., Former Drilling Superintendent, Husky Oil Co. and Alaska United Drilling Inc. 20) Reed, John C., Geological Survey Professional Paper 301, Exploration Of Naval Petroleum Reserve No. 4 and Adjacent Areas, Northern Alaska, 1944- 53, Part 1, History of the Exploration, United States Government Printing .Office, Washington: 1958 21) Reeder, John, Pers. Comm., U.S.G.S. employee 22) Robinson, Florence M., Geological Survey Professional Paper 305-L, Core Tests, Simpson Area, Alaska, Exploration Of Naval Petroleum Reserve No. 4 and Adjacent Areas, Northern Alaska, 1944-53, Part 5, Subsurface Geology And Engineering Data, United States Government Printing Office, Washington: 1964 23) Robinson, Florence M., Geological Survey Professional Paper 305-C, Test Wells, Gubik Area, Alaska, Exploration Of Naval Petroleum Reserve No. 4 and Adjacent Areas, Northern Alaska, 1944-53, Part 5, Subsurface Geology And Engineering Data, United States Government Frinting Office, Washington: 1958 24) Roderick, Jack, Pers. Comm., Oil Industry Historian & Author 25) Schindler, John F., The Second Exploration, 1975-82, National Petroleum Reserve In Alaska, Husky Oil NPR Operations, Inc. August, 1983 26) Wester, Don, Pers. Comm., Consulting Drilling Supervisor 27) Wondzell, Blair, Pers. Comm., Sr. Petroleum Engineer, AOGCC 21 X14 09/14/2004 11:45 FAX 9072798644 ATTORNEY GENERAL'S OFF ~ AOGCC • OfFice of the Attorney General Oii, Gas & Mining Section 1031 W. 4th Avenue, Suite 200 Anchorage, AK 99501-1994 Phone: (907) 269.5255 Fax; {9'07) 279-8644 Fay Transmission The Information contained in Phis fax is confidential and/or prnileged. This fax Is Intended to be reviewed initially by only the Individual named below. If the reader of this transmlt~l page is not the infended recipient or a rapre~sentatlve of the intended recipien>y you a~ hereby notr~ed that any review, dlsseralnatlon or copying o/ #~ls fax or the information contained herein is prohibited. ~If you have received this fax !,n error, please immediately notl~i the sender by telephone and return this fax to the .sender at th®above address. Thank you. To: ~ dom. V~ .p ~/ Fax #: ~' ~ ~ h~ ~~ From: ~~ ' ~'\ ~~~ ~ Date: I Subject: ~ V ~ ~ ~ ~ • :. 4 Message: 4I1~ ~~ ~a` ~ ~o~~ y~o ~~ ..~ Pages; _ ~ _ _~~ including cover sh®et , ~ ~~ ~d~~ ~f .f `; r~oo1/005 .f ',.`~ If you do not receive aN the pages or have arty problems with this fax lease cal! for assistance at SOT 269-5255. ~/ ~~e QK F ~~V ~~ S~.A CEP ~. ~ X004 ~ ~~ 09/14/2004 11:45 FAX 9072798644 ATTORNEY GENERAL'S OFF ~ AOGCC 0 002/005 08/14/04 lOt5b FA% 807'486 ~ Ll4SA & LEGS/RE~GS •OIL~GAS/D~1rNII3G f~j0~01 STATE Q1F ALASKA, b~p~/#,RTM~ENT OF LAVY LEGISLATION /REGULATIONS sECTlON DImand Gourt Building, 6'th Floor P.O. Box 11 Q300; Juneau, A1~aska 9981'1-0300 TEL: (907) 465-3600 ~ FAX: (907) 465-2520 GONl=1pENTIA~. FACSI'M1LE 1'liE INFOF#MNTIbN CONTAINEb IN THIS FAX IS CONFIDENTIAL ANbIt7R pRIVCLEGED. THIS FAX f5 INTENDED TO BE REVIBW~ INRIALLY BY QNLY rHl: INbIVIDiAL NAMED BELOW. Ii= THE FCEADER OF THIS TRANSMITTAL. 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Jvl'd2in, Legal Texk Editor ^ Deborah E. 6ehl•, Leglslatlon A1:4omey ^ Kevln Massing, Legal Text Editor S#ev@ Weaver, Asst, Attorney General ^ Pat VanPvol, Law Offiae Assistant TaTAL NUMBER fOp RAGES ~ (fn'cludes this covQrshset).~ Rg; ~a~C~ c+2gwlai'idns re c '13UP~ (~9a-oy~ raa59 CCI'ri1179r1tS: eda}~a arm ~' 'hark@d~, far review bG- uec. rx/i~ '1'k-Q. c.fipi-i; ~ celaca3'¢r~ -F~.~ taxi- on cueakl~ -i~x'~'S f4~ ~W'C. v„ do-Y~.1apr~e~' pr service. wP.~ls -No e~voie~ con~uaia~ ra.bma} - - -~ wl,iah cJaus~~*- phreR.s.~''~'~in~ iti^~Prvc.JS ._. ~Rr~eesf'L'~' -~o~fie~. 'Picuse. lei's !~•oe... iF -~sc ~.s~s cst14 e~..o~k; ~~ ~ do,~n ~' LI F~~^~ka--(ina7 a,~my~ -~`t$~.-work , ~h.Q.til~s if you have any problems recalving thla fsx, please call: fat Yak„~?„r~~i (_$07148S,3~R~0. pnxSrtTSxe l9lal~o0d1 09/14/2004 11:45 FAR 9072798644 09/14/04 10:66 FA% 907 496 R.ogistcr 200 ATTORNEY GENERAL'S OFF ~ AOGCC Lr;<SA 8c LEGS/KEGS .OIL, GAS/MINING MISCEi T.ANROUS BOARDS a0 AAIC 25.035(e)(10) is repealed and readopted end a new paragraph is added to read: ~ ooa/oo5 ~ 002 (10) the BODE must be tested as follows: (A.) when installed, repaired, or changed on a development or service well and~rless ' ~ time intervals not to exceed eaoh .1!i days thereafter, BOPS, including lorlly valves, cmergmtcy valves, and cholc$ xxattifolds, must be fuxtetion lsressure~tested to the required working pressure 8pcci~ied in the approved Permit to Drill, using a n~an-compressible flutid, axca~t that an annular a oreventer need not be tested tp more than 50 percent of its ted ~v~•; far.. ccn~MnSssian w111 uirQ ilaal~ i'4~.~ 84P~ ~ ~vnc~ion ~pr~,sSayr~-~e.s}~ wa~tkls~, if 't!~ tontnaiss7on .•.__.,,•~'-- w~'lciri es d,etr~rrwl+-,a..s i~!'oo'r a, we~kl~ ~Prv pressure •M+~B+' ini~.rvaS is lnc~.fea~tel. by ~.. ar+Tcc+lar otrillln nod's BOPS r~Oar~nncrs;, (B) whim installed, zepaired, or changed on an exploratory or stratigraphic test well end at least once a week thereafter, BOP>?, including kelly valves, emergency valves, and choko manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that a». annular type preventer need not be tested to more them SO percent of ita rated worlang pressure; (C) if BO>s sealing ram type equipment hoe boon 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 anon-compressible fluid, accept that azt atxttular type preventtr need not be tested to more than 50 percent of its rated working pressure; t (D) BOP ram and annular components blind rams must be function-tested weakly, and all BOP ram and annular components must be fiuiction•tiested after an action that disaotineats the hydraulic system lines from the BOPl3, except that ifthe warks~lzing is continuously in iltc well, function-testing of blind rams must be performed as soar as possible atlteer the vvr~rkstring is pulled out of the `well and the BHA clears the HOP; (13) BOpE tort results must be recorded as part of the daily record required by 2U AAC 25.070(1); (F) at least 24 hours notice of eaoh BOPE function pressurt test must be provided to the 09/14/2004 11:45 FAX 9072798644 ATTORNEY GENERAL'S OFF -~ AOGCC 0 004/005 09/14/OQ 10:55 FAX 907 465 ~ J.&SA & LEGS/1tEiG5 ~IL,GAS/MINING I~JO'OS Register _ 200 5 MI3CELLANEOU3 BOARDS cornxdi.BBion 80 that a G4rT)IriS8810n represent$tive can witness the test; (1 I) the operator slYall repoErt to the commission within 24 hours any instance of SOPS use to prevenlt the flow of fluids from s well. . (Efi 4Y13180, Register 74; am Z!22J81, register 77; am 4/2/86, Register 97; am 1 l/7/9~9, Register 152; am ~_ / /. , Register _, ~ ~ow~v~r, 'Fl'ixcn~itruus5ipn will f~„vlrR. 'rko} ~kiz.'~rOP~ be. ~uhcffQr+ 'Pres;~r~.~~'e.5i'aat 4+.+ea.]Glc~, ilr i~h+~ C.arn~rtissian Authority: A$ 3l.OS,030 a(,~~erMic~¢a ii~~ 0. WP.~lclc~ ~Cx?~ ~res~Ur~.• hest 1n4'erval is inr~~~QCR ~' c~ fart;wlar d.rillin~ ri9'~' ~oF<r der frprtta~- cn r,~ 20 AAC 25.036(d) is repealed and readopted and a new subsection is added to read: (d) A ROPE assembly must be tested as follows: (1) when installed, repaired, or changed on a development or service well artdl'~°~ t~ ;$61Fer~ee~~at time intervals not to exceed each days therea#ler, BODE, including kelly valves, emergency valves, and choke manifolds, must be fut~tiati pressure-tested to the required working pressure specified im the approved Permit to Drill, using anon-compressible fluid, except that an annular typo pre'venter need sot be tested to more than 50 percent ofita rated working pressure; (2) when installed, repaired, or changed ors an exploratory or atratigraphic test well and at least once a roveck thereafter, 90PE, 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 noa~ampressible fluid, except that an a7mular type prevents[ need not be tested to more'than SO percent of its rued working pressure; (3) otlYer wall cantrol equipment must be pressare-tested to the maximum potential wellhead presatue after each installation of she well control equipment and before wellbare entry, except that an snmular type prevents[ need not be tested to more than 50 percent of its rated working pressure; (4) if BOP sealing ram type equipment has been usctl, it must be function preasuxe-tested, before the next wel]bore entry, to the required working pressure specified in the approved Perrrlit to Dri11, using a non-ooittpressible #luid, ~CCept that an annular type prevents[ need not be tested to more than 50 percent 2 09/14/2004 11:45 FAX 9072795644 ATTORNEY GENERAL'S OFF ~ AOGCC f~j005/003 09/14/04 10:56 FA7C 807 466 2~ L&SA & LEGS/KEGS ~IL,GAS/MINING ~J004 Register 200 S 1~sc~lrr.Alvlraus ~aoAl~s pf its rated wvrldag pressure; m,ccup} (S) B~QP ram anti annular componcnta blind rams inuet be function-tested weekly, and a11!BOF ram and annular eomporsents must be function tcxtcd after an cation that discrnmects the hgdrauflic system lines from tha BOPS, except that if fbe workstring is oontinuously in the well, function,- testing,ofblind rams must be performed as sooa as possible after the workstrizrg is pulled out of the well and t]u BHA cle8rs the 130P; (~ teat results must be recorded as part of the daily record required by 20 AAC 25.070(1); (7) at least 24 hours notice of each furiatian pressure test must be provided to the commission so that a repreecntative of the commiasipr4 can witness the test. (~J 'Tlae operator shall report to the comrmssion within 24 hours any instance oi'EOPE use to prevent th+e flow of fluids from a well. (Eff; 11/7/99, Register 152; am / / .Register _) Authority; AS 31.OS.030 3 X13 MEMORANDUM r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Regulations Attorney Legislation/Regulation Section Department of Law FROM DATE: August 11, 2004 SUBJECT: Request for Legal Review Of Regulations Project on blowout prevention, 20 AAC 25.035 and 20 AAC 25.036 We are requesting legal review and approval of the attached final regulations on Blowout Prevention Equipment, which were adopted by Alaska Oil and Gas Conservation Commission. Enclosed are the following documents: 1. the original and one copy of the final regulations for the Department of Law's use; 2. the original of the signed and dated adoption document; 3. the original of the public notice; 4. the original of the additional regulations notice information form distributed with the notice; 5. the original of the publishers' affidavit of publication; 6. the original of the affidavit of notice; 7. affidavit of commission action; 8. excerpt from unapproved minutes from the August 11, 2004 meeting; We have worked with Assistant Attorney General Robert E. Mintz on this project. Department of Administration Register 2~ MISCELLANEOUS BOAR 20 AAC 25.035(e)(10) is repealed and readopted and a new paragraph is added to read: (10) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a development or service well and, unless the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to exceed each fourteen 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 anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (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 anon-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, it must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-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 exclusive of 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) BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1); (F) at least 24 hours notice of each BOPE function pressure test must be provided to the Register 20~ MISCELLANEOUS BOAR commission so that a commission representative can witness the test; (11) 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. 4/13/80, Register 74; am 2/22/81, register 77; am 4/2/86, Register 97; am 11./7/99, Register 152; am / / ,Register ) Authority: AS 31.05.030 20 AAC 25.036(d) is repealed and readopted and a new subsection is added to read: (d) A BOPE assembly must be tested as follows: (1) when installed, repaired, or changed on a development or service well and, unless the commission determines that a weekly BOPE_pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to exceed each fourteen 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 anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (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 BOP sealing ram type equipment has been 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 Register 20~ of its rated working pressure; MISCELLANEOUS BOAR (5) BOP ram and annular components exclusive of 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) test results must be recorded as part of the daily record required by 20 AAC 25.070(1); (7) at least 24 hours notice of each function pressure test must be provided to the commission so that a representative of the commission can witness the test. (g) 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. 1 ]./7/99, Register 152; am / / ,Register ) Authority: AS 31.05.030 3 Register 20~ MISCELLANEOUS BOAR 20 AAC 25.035(e)(10) is repealed and readopted and a new paragraph is added to read: (10) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a development or service well and, unless the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to exceed each fourteen 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 anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (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 anon-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, it must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-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 exclusive of 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) BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1); (F) at least 24 hours notice of each BOPE function pressure test must be provided to the Register 20~ MISCELLANEOUS BOAR commission so that a commission representative can witness the test; (11) 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. 4/13/80, Register 74; am 2/22/81, register 77; am 4/2/86, Register 97; am 11/7/99, Register 152; am / / ,Register ~ Authority: AS 31.05.030 20 AAC 25.036(d) is repealed and readopted and a new subsection is added to read: (d) A BOPE assembly must be tested as follows: (1) when installed, repaired, or changed on a development or service well and, unless the commission determines that a weekly BOPE_pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to exceed each fourteen 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 anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (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 BOP sealing ram type equipment has been 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 2 Register 2~ of its rated working pressure; MISCELLANEOUSBOA~ (5) BOP ram and annular components exclusive of 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) test results must be recorded as part of the daily record required by 20 AAC 25.070(1); (7) at least 24 hours notice of each function pressure test must be provided to the commission so that a representative of the commission can witness the test. (g) 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 3 • • ORDER CERTIFYING THE CHANGES TO REGULATIONS OF THE ALASKA OIL AND GAS CONSERVATION COMMISSION The attached three pages of regulations, dealing with 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 August 11, 2004 public meeting, under the authority of AS 31.05.030, 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. Although no public comments were received, 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 filed by the lieutenant governor, as provided in AS 44.62.180. DATE: August 11, 2004. Anchorage, Alaska FILING CERTIFICATION they have been I, ,Lieutenant Governor for the State of Alaska; certify that on 2004 at .m., I filed the attached regulations according to the provisions of AS 44.62.040 - 44.62.120. 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 blowout prevention equipment, including the following: 20 AAC 25.035 and 25.036 are proposed to be amended to change the time intervals for testing blowout prevention equipment, change the types of tests required for blowout prevention equipment, and add a requirement. that use of blowout prevention equipment to prevent fluid flow from a well be reported to the AOGCC. 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. 7"' Avenue, Suite 100,. Anchorage, AK 99501. The comments must be received no later than 4:30 p.m. on July 19, 2004. If you are a person with a disability who may need a special accommodation, auxiliary aid or service, or alternative communication format in order to participate in the process on the proposed regulation, please contact Jody Colombie at (907) 793-1221 by 4:00 p.m., June 15, 2004, to ensure that any necessary accommodations can be provided. Copies of the proposed regulation changes may be obtained from the AOGCC office, 333 W. 7th Avenue, 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 fmal regulations may be different from that of the proposed regulations. YOU SHOULD COMMENT DURING THE T1ME ALLOWED IF YOUR INTEREST COULD BE AFFECTED. Written comments received are public records and are subject to public inspection. Statutory Authority: AS 31.05.030. Statutes Being Implemented, Interpreted, or Made Specific: AS 31.05.030. Fiscal Information: The proposed regulation ch ge a of expected to require an increased appropriation. ~~ ~ Date: June 17.2004 Jo K. Norman, Chair laska Oil and Gas Coi Published: June 18, 2004 AO-02414043 • • ADDITIONAL REGULATIONS NOTICE INFORMATION (AS 44.62.190(d)) 1. Adopting agency: Alaska Oil and Gas Conservation Commission 2. General subject of regulations: blowout prevention equipment. 3. Citation of regulations: 20 AAC 25.035 and 25.036. 4. Reason for the proposed action: updating regulatory requirements in light of experience and information. 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. 7th Avenue, Suite 100, Anchorage, AK 99501, (907) 279-1433. 8. The originof the proposed a~ona staff. 9. Date: June ~'1, 10. Prepared by: ~(/(/ J an, Chair Alaska Oil and Gas Conservation Commission (907)279-1433 Anchorage Daily News Affidavit of Publication 1001 Northway Drive, Anchorage, AK 99508 AD# DATE PO ACCOUNT 200569 06/18/2004 02414043 STOF0330 STATE OF ALASKA THIRD JUDICIAL DISTRICT 6/ls/zoo4 PRICE OTHER OTHER OTHER OTHER OTHER GRAND PER DAY CHARGES CHARGES #2 CHARGES #3 CHARGES #4 CHARGES #5 ~' TAI- $195.64 $195.64 $0.00 $0.00 $0.00 $0.00 $0.00 $195.64 Teresita Peralta, 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 individuals. Signed ~" ~J Subscribed and sworn to me before this date: Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska ~ MY COMMISSION tee, ~ ~r°k ~~® A = ,~°'~ :~ ~; f, ~ _., ~ ~3 ~, ~, ~ -~ ~- ~ .,,, ~, ~ d~ r%:~a 1'a~i ~'~~>stiJ111 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 Administra- tive Code, dealing with blowout prevention equip- ment, including The following: 20 AAC 25.035 and 25.036 are Proposed to be amended to change the time intervals for testing blowout prevention equipment, change the types of tests required for blowout prevention equipment, and add a requirement That use of blowout prevention equipment to prevent fluid flow from a well be reported to the AOGCC. You may comment on the proposed regulation changes, including the potential costs to prfvaTe persons of complying with The Proposed changes, by writing to AOGCC, 333 W. 7th Avenue, Suite 100, Anchorage, AK 99501. The comments must be re- ceived no later than 4:30 p.m. on July 19, 2004. If you are a person with a disability who maY need a special accommodation, auxiliary aid or service; or alternative communication format in ordQr~ to participate in the process on the proposed regula- tion, please contact Jodv Colombie at (947)-793-1221 by 4:00 p.m., June 15, 2004, to ensure that any nec- essary accommodations can be Provided. Copies of the proposed regulation changes may be obtained from the AOGCC office, 333 W. 7th Av- enue, Anchorage, Alaska 99501, or by Telephoning The AOGCC aT 907-793-1221, br on the AOGCC web- site at: hitp://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.IN- TEREST COULD BE AFFECTED. Written com- ments received are public records and are subject to public inspection. Statutory Authority: AS 31.05.030. Statutes Being Implemented, Interpreted, or Made Specific: AS 31.05.030. Fiscal Information: The Proposed regulation changes are not expected to require an increased aPprOprlQYfan. Date: June 17, 2004 /s/: John K. Norman, Chair Alaska Oil and Gas Conservation Commission AO-02414043 Publish: June 18, 2004 • • 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 Title 20, Chapter 25 of the Alaska Administrative Code, dealing with blowout prevention equipment, has been given by being (1) 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 44.62.175(a)(1) and (b) and 44.62.190(a)(1). 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: July 28, 2004 Anchorage, Alaska O~~ od J. n e Special Staff Assistant SUBSCRIBED AND SWORN TO before me this 28th day of July, 2004. N ry Public in and for the State of Alaska My commission expires: / / ~r~~e.~~' ~/•~~y Citgo Petroleum Corporation Mary Jones David McCaleb PO Box 3758 XTO Energy, Inc. IHS Energy Group Tulsa, OK 74136 Cartography GEPS 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102-6298 Houston, TX 77056 Kelly Valadez Robert Gravely George Vaught, Jr. Tesoro Refining and Marketing Co. 7681 South Kit Carson Drive PO Box 13557 Supply & Distribution Littleton, CO 80122 Denver, CO 80201-3557 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Richard Neahring John Levorsen Hodgden Oil Company NRG Associates 200 North 3rd Street, #1202 408 18th Street President Boise, ID 83702 Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Kay Munger Samuel Van Vactor Michael Parks Munger Oil Information Service, Inc Economic Insight Inc. Marple's Business Newsletter PO Box 45738 3004 SW First Ave. 117 West Mercer St, Ste 200 Los Angeles, CA 90045-0738 Portland, OR 97201 Seattle, WA 98119-3960 Mark Wedman Schlumberger David Cusato Halliburton Drilling and Measurements 200 West 34th PMB 411 6900 Arctic Blvd. 3940 Arctic Blvd., Ste 300 Anchorage, AK 99503 Anchorage, AK 99502 Anchorage, AK 99503 Baker Oil Tools Ciri Jill Schneider 4730 Business Park Blvd., #44 Land Department US Geological Survey Anchorage, AK 99503 PO Box 93330 4200 University Dr. Anchorage, AK 99503 Anchorage, AK 99508 Gordon Severson Jack Hakkila Darwin Waldsmith 3201 Westmar Cr. PO Box 190083 PO Box 39309 Anchorage, AK 99508-4336 Anchorage, AK 99519 Ninilchick, AK 99639 James Gibbs Kenai National Wildlife Refuge Penny Vadla PO Box 1597 Refuge Manager 399 West Riverview Avenue Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-7714 Soldotna, AK 99669-2139 Richard Wagner Cliff Burglin Bernie Karl PO Box 60868 PO Box 70131 K&K Recycling Inc. Fairbanks, AK 99706 Fairbanks, AK 99707 PO Box 58055 Fairbanks, AK 99711 Williams Thomas North Slope Borough Arctic Slope Regional Corporation PO Box 69 Land Department Barrow, AK 99723 PO Box 129 Barrow, AK 99723 Regulations: Blow Out Prevention Equipmet~ • Subject: Regulations: Blow Out Prevention Equipment From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Thu, 17 Jun 2004 10:55:28 -0800 To: undisclosed-recipients:; BCC: ConBunde <senator_con_bunde@legis.state.ak.us>, ;~ohn Cowdery <senator~john_cowdery@legis.state.ak.us>, Bettye J Davis<senator bettye_davis a,legis.state.ak.us>, Johnny Ellis JR <senator~johnny elks@legis.state.ak.us>, Kim S Elton <senator_kim_elton@legis.state.ak.us>, Hollis French <senator_hollis_french@legis.state.ak.us>, Lyda N Green <senator lyda_green c~legis.state.ak.us>, Gretchen G Guess <senator_gretchen_guessClegis.state.ak.us>, Lyman F Hoffman <senator Lyman_hoffmau@legis.state.ak.us>, Georgianna Lincoln <senator georgianna Lincoln@legis.statc.ak.us>, Scott Ogan <senator_scott ogan@Iegis.state.ak.us>, senator_ben_stevens <senator_ben_stevens@legis.state.ak.us>, senator gary_stevens ~senator_gary_stevens@legis.state.ak.us>, , senator_gene_then•iault senator gene_therriault@legis.state.ak.us>, senator tho~nas wagoner <senator 'thomas_wagoner cr le~isatate.ak.us>, senator_gary_wilken <senator.. gary_wilken@legis.state.ak.us>, mike. chenault <representative_mike_chenault@legis.state.ak.us>, sharon cissna <representative Sharon_cissna@legis.state.ak.us>, John Coghill. <representative~jolul_coghill@legis.state.ak.us>, harry Crawford <representative_harry Crawford@legis.statc.ak.us>, eric croft representative_eric_croft@legis.state.ak.us>, nancy dahlstrom <representative_nancy_dahlstrom c~legis.state.ak.us>, richard foster representative richard foster~a legis.state.ak.us>, Les gaga representative_les_garaClegis.state.ak.us>, Carl Gatto <representative_carl_gatto@legis.state.ak.us>, max gruenberg <representative_max_gruenberg@legis.state.ak.us>, david guttenbei°g <representative_david_guttenberg@legis.state.ak.us>, John Har7is representativejohn_harris@legis.state.ak.us>, mike hawker <representative_mike_hawker@legis.statc.ak.us>, cheryll heinze <repre~entati~e_cheryll_heinze@legis.state.ak.us>, Jim Holm ~representative~jim _holm@legis.state.ak.us>, reggie joule <representative_reggie~joule@legis.state.ak.us>, mary kapsner <representative_mary kapsner~a legis.state.ak.us>, Beth Kerttula representative_beth_kerttula@legis.state.ak.us>, vic kohring <representative_vic_kohring@legis.state.ak.us>, Albert Kookesh representative_albeit_kookesh@legis.state.ak.us>, pete kott represcntative~ete_kott@Legis.state.ak.us>, l3ob Lynn <representative_bob_lynn@legis.state.ak.us>, Beverly Masek <representative_beverly masek@legis.state.ak.us>, lesil mcguire <representative_lesil_mcguire@legis.state.ak.us>, kevin meyer representative_kevin_meyer~legis.state.ak.us>, earl morgan representative_earl_morgan@legis.state.ak.us>, earl mows <representative_carl_rnoses@legis.state.ak.us>, ~dan ogg <representative_dan_ogg@legis.state.ak.us>, norman rokeberg <representative~nortnan rokeberg a legis.state.ak.us>, ralph samuels representative ralph_samuels@legis.state.ak.us>, p~ulseaton ~representative~aul_seaton~legis.state.ak.us>, Bi11 Stoltze 1 of 3 Regulations: Blow Out Prevention Equipme~ representative `bill.. stoltze@legis.state.akus>, Bruce Weyhrauch <representative Bruce weyhrauch@legis.state.ak.us>, Bill .Williams... <representative_bill~williams@legis.state.ak.us>, peggy wilsorr <representative~eggy Wilson r~legis.state.ak.us>, Kelly Wolf <representative kelly_wolf@legis.state.ak.us>, Donny Olson <senator Bonny Olson@legis.state.ak.us>, Ralph Seekns <senator ralph_seekins@legis.state.ak.us>, Tom Anderson <representative_tom_anderson@legis.state.ak.us%, Ethan Berkowitz <representative_ethan_berkowitz~legisatate.ak.us>, hugh fate <representative_hugh_fate@legis.state.ak.us>, Fred Dyson <senator fi•ed_dyson c~legis.state.ak.us>, Bert K Stedman <senator bert_stedman a legis.state.ak.us>, Nick Stepovich <representative_nick_stepovich@legis.state.ak.us>, Robert E Mintz <robert_mintz@law.state.ak.us>, Christine Hansen <c.hansen@iogec.state.ok.us>, Ten•ie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, Scott & Cammy Taylor <staylor a~alaska.net>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw~trustees.org>, roseragsdale <roseragsdale c~gci.net>, trmjrl <trmjrl @aol.com>, jbriddle <jbriddle@marathonoil.com?, rockhill <rockhill~a~aoga.org>, shaneg <shaneg@evergreengas.com~, jdarlington <jdarliugton~forestoil.com>, nelson <nelson cr gci.net=, eboddy <cboddy@usibelli.eom>, Mark Dalton <mark.dalton@hdrinc.com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P. Worcester" <mark.p.Worcester@conoeophillips.com>, "Jerry C. Dethlefs" <ferry.c.dethlefs@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv~dnr.state.ak.us>, tjr <tjr@dnr.state.ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@pu~-vingertz.com>, Charles O'Donnell <eharles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Jeanne H. Dickey" <DickeyJH@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Paul G. Hyatt" <hyattpg@BP.com~, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois Qois ~inletkeeper.org>, "Joseph F. Kirchner" <Ku-chnJF@BP.com>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS~;u BP.com>, Mikel Schulta <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE r~BP.com>, "Janet D. Platt" <PlattJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel coctLr~-.com>,Collins Mount <collirls_mount@reveriue.state.ak.us>, mckay <mckay@gci.net>, BarbaraF Fullmer ~barbara.f.fullmer ~zconocophillips.com>, bocastwf <bocastwf@bp.com>, Charles F3arker <barker@usgs.gov>, doug~schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank.alford@exxonmobil.com>, Mark Kovac <yesnol @gci.net>, gspfoff <gspfoff c~aurorapower.com>, Gregg Nady <gregg.nady c~shell.com>,Fred Steece <fred.steece u~state.sd.us>, rcrotty <rcrotty cOch2m.com>, jejones <ejones@aurorapower.com>, dapa <dapa@alaska.net>, jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. Ruud" <janles.m.ruud@conocophillips.com>, Brit Lively <mapalaska@,ak.net>, fah <jah@dnr.state.ak.us>, Kurt E Olson <kurt~olson@legis.statc.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, Loren Leman <loren_leman@gov.state.ak.us>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz <jwkatz@sso.org>, Suzan J Hill <suzan hill@decatate.ak.us>, tablerk <tablerk@unocaLcom>, 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@exxonmobil.com>, marty <marty@rkindustrial.com>, ghammons <ghammons@aol.com>, t7nclean <rinclean~a pobox.alaska.net>, James Scherr <james.scherr@mms.gov>, 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>, Bill Miller 2 of3 6/17/2004 1059 AM Regulations: Blow Out Prevention Equipmert` <BiII~Mille~@xtoalaskacom>,BrandonGagnon <bgagnon~brenalaw.com>, Raymond Matiashowski ,)"R <rymond_matiashowski@admin.state.ak.us> ~ Content-T e: a ltcation/msword 3rd revision re ulation.doc i yp ~~ g Content-Encodin base64 I ~ I g' `~ Content-Type: application/msword BODE second notice.doc ~ i, Content-Encoding: base64 __ _ _ __ Content-Type: application/msword Second Additional Regulation Notice.doc , Content-Encoding base64 -__- ~ ~ • STATE OF ALASKA ) ss. THIRD JUDICIAL DISTRICT ) AFFIDAVIT OF COMMISSION ACTION I, John K. Norman, Chair of the Alaska Oil and Gas Conservation Commission, being duly sworn, state the following: The attached motion dealing with blowout prevention equipment was passed by the Alaska Oil and Gas Conservation Commission during the August 11, 2004 meeting. Date: August 11, 2004 Anchorage, Alaska SUBSCRIBED AND SWORN TO before me this 11th day of August, 2004.. N P i in or the State of Alaska My commission expires: 11/11/06 ~ • ALASKA OIL AND GAS CONSERVATION COMMISSION MEETING Augustl 1, 2004 Excerpt From Unapproved Minutes Commissioner Daniel Seamount moved and Chair John K. Norman seconded the following motion: "I move to adopt the changes to 20 AAC 25.035 and 20 AAC 25.036, dealing with blowout prevention equipment, as written in the August 1 1, 2004 draft regulations." The motion carried unanimously. X12 Alaska Oil and Gas Conservation Commission August 11, 2004 at 9:00 am -Public Meeting Minutes Attendees John Norman Chairman Daniel T. Seamount, Jr. Commissioner Jody Colombie Special Staff Assistant Linda Berg Administrative Manager Winton Aubert Sr. Petroleum Engineer Steve Davies Sr. Petroleum Geologist Howard Okland Geologist Assistant Helen Warman Administrative Clerk II Theresa Rockhill AOGA Harry En el BP Ex loration (Alaska), Inc. Jerome Eggeme er ConocoPhillips (Alaska), Inc. Erin Kamm Bo Scout 1. Approve minutes Approve minutes from July 7, 2004 Norman: Minutes July 7, 2004 Seamount: Motion to approve minutes of July 7, 2004 Norman: Seconded Norman: Minutes July 7, 2004 approved Approve minutes from July 14, 2004 Norman: Minutes July 14, 2004 Seamount: Motion to approve minutes of July 14, 2004 Norman: Seconded Norman: Minutes July 14, 2004 approved Approve minutes from July 21, 2004 Norman: Minutes July 21, 2004, quorum not present Seamount: Approve minutes of July 21, 2004 Approve minutes from August 6, 2004 1 N Norman: Minutes August 6, 2004, Commissioner Seamount absent and quorum not present Norman: Approves August 6, 2004 2. Staff member team activity presentations Seamount: Team Reporting. Aubert: .:East Team Report. Reporting for the East Team. There wire 3 permits F, t to drill and 2 sundry applications approved this week. Davies: West Team Report. There were 3 permits to drill and 1 sundry application approved. West team is also working on 2 spacing exceptions, 1 conservation order, 1 enhanced recovery and 1 aquifer exemption 3. Schedule of Costs and Fees for Documents Well History Files on CD's and printed copies of maps color and oversized Norman: Explains the background and reasons for the schedule of the additional fees. Discussion. Effective today the new cost schedule will go into effect and will be posted on the website. This action is pursuant to 6 AAC 96.360 that authorizes agencies to adopt a public schedule of fees. Chairman reads into the record the new fee schedule. Seamount: Commends Ms. Warman and others who came up with the idea and who worked on the effort. Comments. Norman: Chairman asks if anyone in attendance has any comments? Attendees: There were no comments. Norman: Appropriate to formally approve the proposed schedule of costs dated August 11, 2004. Seamount: Motion to approve new fee schedule. Norman: Second. Is there any opposition? Hearing none this cost schedule will become effective immediately. 4. Well Work Operations and Reporting Requirements Norman: Gives background of reasons for the Task Force. Tom Maunder has been the lead in this effort. Commission would like to get this work completed by the end of the month. After finalizing the report, the Commission will amend Conservation Orders as necessary to eliminate reporting and if there are suggested changes to the regulations the Commission will also review those. 2 L ~ J Seamount: Asked Ms. Rockhill how the Task Force was coming along. Rockhill/AOGA: Spoke to Tom Maunder two days ago and he indicated that he was hoping to get it finalized by Thursday. 5. Adoution of BOPE Regulations Norman: Lead by Dr. Winton Aubert and Staff at the Commission. They looked at the particular regulations for testing blowout prevention equipment. Based upon the staff report we have prepared an amended regulation. Aubert: Summarizes the changes in the proposed regulation. Changing the test frequency on development and service class wells from seven days to fourteen days. The other change Commission has proposed is that whenever blowout prevention equipment is used to prevent flow of fluids it must be reported to the Commission. Agency reviewed other regulations from other jurisdictions. There have been actual statistics from Alaska and it turns out the failure. rate during tests was very low. Changing the test interval from seven to fourteen days in general will not compromise safety. Discussion. Norman: There have been no additional comments in the last thirty days. Have e-mailed notice to members of the legislature of the proposed changes. It has been published to solicit any further comments. Asks Special Assistant if there had been any additional comments? Colombie: There have been no additional comments. Norman: We are required to take note before voting on any regulatory change, of the cost to private persons of the regulatory action being taken. In this case there will be no additional costs to anyone. We have been told that there will be savings in the millions of dollars based on the fact that the number of blowout prevention equipment tests, as to these wells, will be cut in half. The version of the regulations being adopted is dated August 11, 2004. As a Commission we will vote today to make this change and then the regulatory change package will be submitted to Juneau and entered into the register. In the interim period the Commission will grant waivers upon request to extend the test interval for blowout prevention equipment. We are now ready for the formal vote on 20 AAC 25.035(e)(10) as reflected in the draft dated August 11, 2004. Are there any comments from the audience? No one has asked to comment on the proposed regulation. 3 M N Seamount: Move to approve the regulation change. Norman: Second. Without opposition the motion is approved. Norman: 20 AAC 25.036(d) regulation is repealed and readopted and a new subsection is added. Norman: Vote on the new 20 AAC 25.036(d) as set forth in the August 11, 2004 draft. Seamount: Moves to approve the change. Norman: Second. Without opposition the motion is approved. ltockhill~AOGA: Commends the Commission for taking the initiative to make these changes. I .know the operators have wanted .this change for a number of years. 6. Review of Re~ulatory Cost Change for Fiscal Year 2005. Norman: Fiscal year 2005 began on July 1, 2004. See AS 31.05.093. Gives background of how the Regulated Well Regulatory Cost Charge is calculated. For the record I will review the current charge and the procedure the agency follows to send notifications to the operators. Charges are apportioned according to the volume of fluid produced and injected and that will be based upon estimates initially, followed with atrue-up of the actual amount as soon as actual figures are made available. The total amount of the budget for FY 2005 is $4,136,300.00. There is an additional capital appropriation of $260,000.00 which makes for a total appropriation of approximately 4.4 million dollars. Expect federal receipts of $126,000 from the administration of the underground injection control program under the Federal Safety Drinking Water Act. The estimated permit fee receipts will be approximately $20,000. We estimate savings from last year in the amount of $830,000.00, which will carry forward as a credit against this year's budget. Therefore our estimate for the total AOGCC Regulatory Cost Charge for FY 2005 is $3,420,300. It takes approximately 1 cent per barrel of oil to operate the AOGCC. The estimated FY 2005 cost assessment by operator is as follows: 4 M N Company Total Estimated Assessment 2005 Aurora Gas LLC $ 284.56 BP Exploration. (Alaska), Inc. $2,710,504.36 ConocoPhillips (Alaska), Inc. $ 606,221,72 Evergreen resources (Alaska) $ 107.82 Forest Oil Corporations $ 5,288.56 Marathon Oil Company $ 11,132.30 North Slope Borough $ 315.91 Phillips Petroleum Company $ 6,865.33 Pioneer Natural Resources $ 5.12 Union oil Company of California $ 74,177.58 XTO Energy Inc. (Cross Timbers) $ 5,396.74 Norman: The assessment notice for one quarter of the above amounts will be sent this week. Amounts invoiced will be due 30 days from receipt. Seamount: Comments. Commissioner Palin and I many months ago evaluated how this agency operated how we could cut costs. We came up with a plan that included the elimination of a few positions. We had a large DOE grant last year that helped offset costs as well. Norman: In response to questions from operators, comments on the Commission operation as a whole and states that. he does not foresee any radical changes in his recommendations to the Governor. EngeUBPXA: Industry feels that the AOGCC is not overstaffed and that the agency is responsive to the needs of the industry. Commends the Commission on doing a great job of changing the BOPE regulation and the resulting cost savings to industry. Seamount: Motion to approve the estimated Regulatory Cost Charge schedule for FY 2005. Norman: Seconded. Without opposition the motion is approved. New Business: 1. Granting Permits to Drill before Spacing Exceptions Orders are Approved Seamount: The Commissioners have determined that we should not be granting permits to drill before spacing exceptions are approved. 5 M N Norman: Issuance of Drilling permits before approval of Spacing Exceptions will not be granted routinely. They will be granted only in rare and compelling circumstances. Norman: If there is no further business do I have a motion to adjourn? Seamount: Moves to adjourn. Norman: /bonded. They're being no further business; the meeting is ad' urned at 10:15 am. d Date 6 X11 STATE OF ALASKA ~ NOTICE TO PUBLISHER ~ ADVERTISING ORDER NO. ADVERTISING ORDER INVO UST BE IN TRIPLIC( TE SHOWING ADVERTI; ING ORDER RTIFIED AFFIDA~~T OF PUBLICATION PART2 OF THIS FORM WITH ATTACHEV COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE /~ 0.02414043 A SEE BOTTOM FOR INVOICE ADDRESS F R AOGCC 333 W 7th Ave, Ste 100 AGENCY CONTACT Jod Colombie DATE OF A.O. June 17 2004 ° M Anchorage, AK 99501 PHONE PcN DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News P O Box 149001 Anchorage, AK 99514 June 18, 2004 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: STOF0330 Advertisement to be published was e-mailed Type of Advertisement X Legal ^ Display ^ Classified ^Other (Specify) SEE ATTACHED SEND INVOICE IN TRIPLICATE TO AOGCC, 333 W. 7th Ave., Suite 100 Anchora e AK 99501 PAGE 1 OF 2 PAGES TOTAL OF ALL PAGES$ REF TYPE NUMBER AMOUNT DATE COMMENTS 1 VEN z ARD 02910 3 4 FIN AMOUNT SY CC PGM LC ACCT FY NMR oisr iw 1 04 02140100 73540 2 3 4 REQUISITIONED BY• DIVISION APPROVAL: 3 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM STATE OF ALASKA ADVERTISING ~ NOTICE TO PUBLISHER ~ INVO UST BE IN TRIPLICATE SHOWING ADVERTISING ORDER N ., CERTIFIED ADVERTISING ORDER NO. A ORDER AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE 0.02414043 !1 SEE BOTTOM FOR INVOICE ADDRESS F AQU`C''C'' AGENCY CONTACT DATE OF A.O. R 333 West 7th Avenue Suite 100 ° , Anchorage, AK 99501 PHONE PCN M 907-793-1221 DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News June 18 2004 , P O Box 149001 Anchora e AK 99514 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS g , ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: AFFIDAVIT OF PUBLICATION United states of America REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. division. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. Before me, the undersi ned, a nota g ry public this day personally appeared ATTACH PROOF OF PUBLICATION HERE. who, being first duly swom, 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 2004, and thereafter for consecutive days, the last publication appearing on the day of .2004, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and swom to before me This _ day of 2004, Notary public for state of i My commission expires '~, 02-901 (Rev. 3/94) AO.FRM Page 2 PUBLISHER RE: Notice Subject: RE: Notice From: legaiads <legaiads@adn.com> Date: Thu, 17 Jun 2004 12:01:34 -0800 To: Jody Colombie ~jody_colombiela,admin.state.ak.us Hi Jody: Following is the confirmation information on your legal notice. Please let me know if you have any questions or need additional information. Account Number: STOF 0330 Legal Ad Number: 200569 Publication Date(s): June 18, 2004 Your Reference or PO#: 02414043 Cost of Legal Notice: $195.64 Additional Charges Web Lank: E-Mail Link: Bolding: Total Cost to Place Legal Notice: $195.64 Ad Will Appear on the web, www.adn.com: Ad Will Not Appear on the web, www.adn.com: ~~Y Thank You, Kim Kirby Anchorage Daily News Legal Classified Representative E-Mail: legaiads@adn.com Phone: (907) 257296 Fax: (907) 279-8170 From: Jody Colombie Sent: Thursday, June 17, 2004 10:56 AM To: legaiads Subject: Notice «File: ROPE second notice.doc»«File: Second Additional Regulation Notice.doc» Please publish the attached tomorrow. Jody 1 of 1 6/17/2004 1:16 PM Regulation Subject: Regulation From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Thu, 17 Jun 2004 10:58:55 -0800 To: ~yntllia B Mciver <bren mciver(u),admin.state.ak.us> Please publish on the website. Content-Type: application/msword 3rd revision_regulation.doc' ` - 'Content-Encoding: base64 __ _ Content-Type: application/msword BOPE second notice doc Content-Encoding: base64 __ _ _ _ _ _ . f Content-Type: application/msword Second Additional Regulation Notice.doc , Content-Encoding: base64 1 of 1 6/17/2004 10:59 AM Notice Subject: Notice From: Jody Colombie <jody colombie@admin.state.ak.us> Date: Thu, 17 Jun 2004 10:58:07 -0800 To: undisclosed-recipients:; BCC: Angela Webb <angie webb(c.admin.siate.ak.us> Please publish on-line. Content-Type: application/msword BOPE second notice doc ; Content-Encoding: base64 'Content-Type: application/msword Second Additional Regulation Notice.doc ;Content-Encoding• base64 1 of 1 6/17/2004 10:59 AM Notice Subject: Notice From: Jody Colombie <Jody_colombie@admin.state.ak.us> Date: Thu, 17 Jun 2004 10:56:31 -0800 To: Legal. Ads Anchorage Daily Nees <legalads@adn.com> Please publis ~ the attached tomorrow. Jody __ __ _ _ _ "Content-Type: application/msword BOPE second notice.doc! is Content-Encoding: base64 __ 'j Content-Type: application/msword Second Additional Regulation Notice.doc Content-Encoding: base64 1 of 1 6/17/2004 10:59 AM Ad Order Subject: Ad Order From: Jody Colombie <Jody_colombie@admin.state.ak.us> Date: Thu, 17 Jun 2004 11:20:26 -0800 To: Legal Ads Anchorage Deily I~e~~~s <leg~~~.ds@adn.com> Attached is the Ad Order for the Notice and Attachment for the blowout prevention equipment. ~~ _ ~ Content-Type: application/msword Ad Order form.doc i ,; Content-Encoding: base64 1 of 1 6/17/2004 11:20 AM Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Schlumberger Drilling and Measurements 3940 Arctic Blvd., Ste 300 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 North Slope Borough PO Box 69 Barrow, AK 99723 David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 Regulations: Blow Out Prevention Equipmen~ Subject: Regulations: Blow Out Prevention Equipment From: Jody Colombie <jody colombie@admin.state.ak.us> Date: Thu, 17 Jun 2004 10:55:28 -0800 To: undisclosed-recipients., . BCC: Con Bunde <--senatorcon bunde~u`I~~is.state.ak.us>-, .Cohn Co~~dery <senator_johncowdery~'legis.state.alc,us==, Bettye J Davis <senator bettvc davisl~~legis.state.ak.us>, 3ohnny Ellis .1R <-senator~ohnny_cllis(ci~legis.state.ak.u~:=, Kim S Elton ~senator_kim_eltotl u<~legisatate.ak.u~>, Hollis French <senator_hollis freni;h(i~lrgis.state.ak.us>, Lyda N Green senator lyda_grecn(~ile~is.statc.al~us%. Gretchen G Guess <senator_gcetchen ~ess(ttlegis.state.akus%, Ly~rnan F Hoffman <senatorlvman_ hoffmatt(ulegis.statc.ak.us=>, Gcorgianna Lincoln ~senatorgeorgiannalincoln(ci;legis.state.ak.u5>, Scott Dian <senatocscott_ ogan~u~~legis.statc.ak.us>, senator_benstevens <senatorbenstevens(a;lcgi5.state.al+.us=, senator _gat~~ Stevens <senator_guystcvens(~i%legis.state.ak.u5>, , senatorgene therr~iault <senator_gene_therriault(cllegis.state.ak us%, senator_thornaswagoner <senator_thomas_w~agoner(~iJlegis.statc.ak.us>; senator_gar~°_wilken ~senator_gary_wilken(ulegis.state,ak.us>, mike chenault <representative_mike_chenaultla~le~is.state.ak.us>, sharon cissna <representative_sharoncissna(c~~legis.statc.ak u~-,John Coghill representative. jolul_coghill@1e~is.state.ak.us%, har7y Crawford <representativeharry crawtord«i~legis.state.ak.us%, eric croft <representative_eric_croft~cr.-le.gi.s.state.ak.us~, nanev dahlstrom -~represcntative_nancy_dahlstrom~r~egis.state.ak.us>, richacd fustei~ representativerichacdloster(u~le~is.state.ak.us~=, les gaga <representativeles__gara(cl-legis.statc.ak us=>, C'arl Uatto <representative_earl_gatto~u~legis.state.ak.us~, may gr'uc;nberg ~representative_ma~_ gruenberg(u;legis.state.ak.us%, david Guttenberg <represeutati~-edavid_euttenberg(ilegis.statc.ak.us=>, Jahn Har7-is <representative,john_har-rrs~a:;lcgis.state.ak.uti=~, mike hawker °=r-epresentative_mikeh~~,~ kerrci,le~is.state.~k.us?, cheryll heinl.~ ~~~representative ehcryll_hein~e(a;,legisstate.ak.us>, Jim Haln1 <representative~imholml~Llegis.state.ak.us~>. reggie joule ~representative_reggie joule(ulegis.state.ak.us-=,mart' kapsncr representativc_mary_ kapsner(u?legis.statc.ak.us -, Beth Kerttula ~representative,beth_kcrttula~u;;legis.state.ak.us>, vie kohring representativevic_kola•ing(ci:legis.statc.ak.us=~, Albert Kookesh <representative _alber-tkookesh(ci~le~is.state.ak.irs'=, Pete kott <representative;pete_kott(~i~legis.state.ak.us>, Bob Lynn ~r~presentativz_bab_lyTinlccaegis.state.ak.us=~, Bevcrly:'~lasek <represe.ntative_bevcrly_masek(ci;legis.state.~ik.us-=, ]csil mc~trirc <representative_lesilmcguire(a;legis.statc.ak.us=>, kevin mcy~r <representative_kevin_mever~~legis.statc.ak.us?~, crrrl morgan ~representative_carl_morganna legis.state.ak.us>, earl muses representative_earl_moses<oJ.legis.state.ak.us=-, dan o~g <represent~rtive_ dan_ ogg~r egis.state.ak u5=>, no~-man rokeherg ~cepresentativc_norman _rokeberg~cL;legis.state.ak.us=•, ralph Samuels ~~representativeralph_samuels(ci!legis.slate.ak.us>, pain sexton <representative~~aul_seatonr~i.legis.st~~te.ak.tts=~, Bill Stolbc 1 of 3 6/17/2004 10:59 AM Regulations: Blow Out Prevention Equipment representative_hillstoltzelalegi .state.ak.us%. Bruce Weyhrauch <represent~rtive_bcuccweyhrauch(a;~ ebisatate.ah.us%, Bill Williams <representative_billwilliams<<i legis.state,ak.us=, Peggy ~~-ikon • representative~eggy _~~ ilson(ci~lecis.state.al:.us=>, Kelly ~'~'olf <"representative_kelly ~~olf aile~is.state.ak.u5~=, Donny Olson <senator_donnyolson~ulegis.state.ak.us=.Ralph Seekins <=senator_ralph _se~kins~~z'legis.state.ak.us%, Tom Anderson <:representative_tom_anderson(~i:aegis.statc.ak.us=, Ethan Berkowitz. <~~representativeethan_berko~~itz(ci~legis.st~itc.ak.us~%, hugh fate <representative_hugh_fate(«%1egi5.state.ak.us~, Fred Dyson <senatorti-eddyson~u;~,legis.state.ak.us-=, Bert K Stedman ~senator_bertstedm~tn~-legis.statc.ak.us>, 1~i~k Step~~~~ich °~representative_nickstepovich(cijlegis.statc.ak.us~, Robert E Mintr 'robea-t miniz(ci;la~a~.state.ak.us>, Chr7stine Hansen <-c.hansen(~iiogcc.state.ok.us>, Terrie I-bubble •~-hubhletl@bp.cr~m~~, Sondra Stewm~n~ <_Ste«~maSD(r~SP.com>. Scott & Cammy Taylor ~staylor(ci~ilaska.net= , st~n~eki <stanekj(uunocaLcom-->, ecolaw <ecol~i~~~ci.trustces.or~', roseragsdale ~-roscra~sdal~lu~~,t~c.i.ntt>. trmjrl >~trmjrl(cuaol.cum>, jbriddle <jbriddlc~~r~marathonoil.cc~m>, mckhill <rockhill(u;aoga.org>, 5hane~~ ~shane~(cZ?evergreengas.com=>, jdarlington <-jdarlingtonr~forestoil.com>, nelson <nelson<«gci.net>, cboddv ~cbc>ddy ~~~usibelli.com ~, Mark Dalton ~niark.dalton!~i:~hdrinc.com~.=, Sh~ulnon Donnelly <sha~~non.donne-lIy(czconocophillips.e~m>, "Mark P. Worcester,. <mark.p.Worcester(ci~conocophillips.eom=~, "Jerry C. Dethlcfs" ~jerry.c.dcthlei~(u%conocophillips.eom:=~, Bob <bob(~i~inletkeeper org>, wdv <~~~d~ «i,:dnr.state.aku~~, tjr <-tjr(c~dnr.state.ak.us=-, bbritch -=-bbritch(u;alaska.net%. n~jnelson <nljnelson~ci;prrrvingertz.com:>. Charles O'Donnell <charles.o'donnell{l!veco.com>, "Randy L. Skillern" <SkillcRL(uBY.com>, "Jeanne H. Dickey" <DickeyJH@$P.com%, "Deborah J. Jones" <JoneSDfi~ruBP.com=~, "Paul G. Hyatt" ~hyattpgl~iBP.com>, °Stcvcn R Rossberg" <RossbeRS(ci,~BP.corn= -, Lois ~lois<<i~~inletkeeper.org>, "Joseph F. Kirchner" ~~-KircluiJ~~~a;.BP•com= ,Gordon Puspisil <Pospr~G(c~_BP.com>, "Francis S. Sommer" <:SommerFS(ct'~BP.com~=, >Vlikel Schultz <-Mikel.Schultz(c~BP.com?, `'Nick W. Glover" <GloverNW(u~,BP.a~m==, "Daryl J. kle~pin" <'KleppiDE(~i!BP.com>, "Janet D. Platt" ~_Platt<ID~a:;BP.eom= , "Rosanne M. _l<rcc~bsen" ~JacobsRM(~~.BP.com~=, ddonkel<ddonkel ~r cfl.rr.com>. Collins Ulount <collinsmount(~i?,revenue.state.ak.usr, mckay <mckay(ci.!.gci.net=~, B~trbar~a F Fullmer =barbara.f.fullmer(a::conocophillips.co7n>, bocast~~ f <=bocastwf(~ bp.com>. Charles Barker <barker(ci~,usgs.gov>, doug _schultze <doug_s~hultzt(uYtoenergy.cum~%, Hank Alti~rd hank.alford(~i;e~xonmobil.com%, ~~lark E~ovac <yesno 1 ~u;gci.net= . gspl-off <gspfoff(~z',aurorapower.com>. Gregg Nady <gregg.nady(%shclLcom=-. Fred Stecce <fred.steece~a?state.sd.us=>, rcrotty <rcrutty(~!ch2m.eom=, jejones ~.jejonc~;ciaurorapo~~~c;r.com%., dapa <dapa~ci%alaska.net>, jrodc,r ick <jroderi~klci~gci.net>, eyan~y ~~eyancy<<r: cal-tite.uet= , ",lames M. Ruud" <jarnes.m.ruud(a.;conocophil~ips.com=, Brit Lively <mapalaska(uak.net%, jah ~~jah(a;dnr.state.ak.us>, hurt E Olson <kurt_olson~i~~legis.state.ak.us=-, buono,je ~=buonoje(ubp.corn=. Mark Hanley <mark hanley(u?anadarko.com>, loren_~eman <lorenleman(~l~gov.state.ak.u5=, Julie Houle ~'juke__houle~a;:dnr.state.ak.us=%. John W Katz <jwkatl~cc-sso.org=,, Suzan J Hill ~suz~u~_hill~~odec.state.ak.us>, tablerk <tahlerk(~unoeaLcom>. Brady <hradv(uaoga.org%, Brian Havelock <heh(«%drTr.statt.ak.us>, bpopp <bpopp ~l?borough.kenai.ak.us>, Jim White. <jimw~hrteicl~,satx.rr,conl>, "John S. Ha~~orth" ~~john.s.haworfh~ci,exYOntnobil.con>>. mar•ty <mart}(cirkindustz~al.com>, glzasnmons <ghazz~mons~ci?aol.com=>, r7nclean <rn~cleanl~i.pobo~.alaska.net>, James Scherr rjames.scherrr.mms.gov?; rnkm7?OU ~~ mkm7?U(11uaol.com=>, Brian Gillespie ~ itbmg(a uaa.alaska.cdu-~, David L Boclcns <dboe~l~ns(ii;aurorapower.com%, Todd Durkee ~TDURKEE(u;K?~1G.com==, Gary Schultz -'nary schultz(c~;dnr.state.ak.us>, Wayne Railcier <RANGER(u;petro-canada.ea= , Bill Miller 2 of 3 6/17/2004 10:59 AM Regulations: Blow Out Prevention Equipment. • <Bill_Miller(~uxtoalaska.com~, Brandon Gagnon -~='bga~noii~a;brenala«~.com=%. Ray~tn~~nd Matiashowski JR <ra~~nond_matiashow-ski(~~ad~nin.state.ak.us? Content-Type: application%msword '3rd_revision_regulation.doc Content-Encoding: baseb~ ___ Content-Type: application,`ms~i~ocd BOPE second notice.doc Content-Encoding: base64 Content-Type: application%ms~word Second Additional Regulation Notice.doc Content-Encoding: base6~ __ 3 of 3 6/17/2004 10:59 AM ~~,~F,,j.~_. -ah ~~i,,,, Deborah Behr Assis~ant Attorney General Legislation & Regulations Section Department of Law PO B x 110300 June~u AK 99811 Alaska Oil and Gas Cc~n~er~ ati~~n Commission ~.3 ~~~est 7"~ _~,~enue. Suite 1011 Anchoi•aQe..~K 9901 Legislative Affairs Agency Legislative Reference Library State Capitol Room 3 Juneau AK 99801 ~o • ARDS ~ ~ ,~ ~v~~ Register , 200_ MISCELLANEOUS BO ,~ // // 20 AAC 25.035(e)(10) is repealed and readopted and a new paragraph is added to read: (10) the BOPE must be tested as follows: ~~~~ (A) when installed, repaired, or changed on a well classified as "development" or 7' ~~ °~ rv 1 is indicated service and, unless the commission determmes that a weekly BOPE pressure test mte a by a particular drilling rig's BOPE performance, at time intervals not to exceed each fourteen days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be 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; (B) when installed, repaired, or changed on a well classified as "exploratory" or "stratigraphic test" and at least once a-week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon-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, it must be 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 exclusive of blind rams must be function-tested weekly 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; blind rams must be function-tested at least every thirty days; (E) BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1); Register , 200_ • MISCELLANEOUS BOARDS (F) at least 24 hours prior notice. of each BOPE pressure test shall be provided to the commission so that a commission representative can witness the test; (11) instances of BOPE use to prevent the flow. of fluids from a well must be reported to the commission within 24 hours of use. (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 / ,Register ~ Authority: AS 31.05.030 20 AAC 25.036 (d) is repealed and readopted and a new subsection is added to read: (d) A BOPS assembly must be tested as follows: (1) when installed, repaired, or changed on a well classified as "development" or "service" J and. unless the commission determines that a weekly BOPE pressure test interval is indicated by a 1 ~'~ particular drilling rig's BOPE performance, at time intervals not to exceed each fourteen days. thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested to the required ~- working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested. to more than 50 percent of its rated working pressure; (2) when installed, repaired, or changed on a well classified as "exploratory" or "stratigraphic test" and at least once a week thereafter, BOPE, including emergency valves, and choke manifolds, must be pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon-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 BOP sealing ram type equipment has been used, it must be pressure-tested, before the-next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using a non- 2 Register , 200_ ~ MISCELLANEOUS BOARDS 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 exclusive of blind rams 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 shall be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; blind rams must be function-tested at least every thirty days; (6) test results shall be recorded as part of the daily record required by 20 AAC 25.070(1); (7) at least 24 hours prior notice of each function press e.~e shall be provided to the commission so that a representative of the commission can witness the test. (g) Instances of BOPE use to prevent the flow of fluids from a well must be reported to the commission within 24 hours of such use. (Eff. 11/7/99, Register 152; am / / ,Register -) Authority: AS 31.05.030 3 • ~ June 16, 2004 at 9:05 am -Public Meeting ATTENDEES John K. Norman Chair Daniel Seamount Commissioner Jody Colombie Special Staff Assistant Winton Aubert Senior Petroleum Engineer Steve Davies Senior Petroleum Geologist Linda Berg Administrative Manager Rob Mintz Assistant Attorney General Agenda: Old Business 1. Approve Minutes of June 2, 2004 meeting 2. Staff member team activity presentations 3. Adoption of BOPE Regulation 1. Approve minutes from June 2.2004 Norman: Minutes June 2, 2004 Seamount: Motion to approve minutes of June 2, 2004 Norman: Seconded Norman: Minutes June 2, 2004 approved 2. Staff team activity reports Seamount: Team Reporting. Seamount: East Team Report. Aubert: There were 4 permits to drill and 2 sundry applications approved this week. Seamount: West Team Report. Davies: There were 6 permits to drill and 4 sundry applications approved this week. Hearing last week on Envirotech's application for an Aquifer Exception order relating to the North Foreland Field. The record on this application is open until June 25, 2004. The Commission requested additional information from the applicant. 3. Blow Out Prevention Equipment Regulations Norman: Blow Out Prevention Regulation Hearing. The hearing was on June 8, 2004. Commission staff testified. Chair gives brief explanation of proposed regulation. Staff study has shown that safety will not be compromised by increasing required interval between BOPE tests. Changing the test intervals from 7 to 14 days will also be a cost savings to the operators and private individuals in the millions of dollars. It usually takes a minimum of 4 hours per rig to perform a BOPE test. • • Aubert: The operators at Prudhoe Bay estimate a .5 a million dollar saving per rig. One- fourth of the rigs in Alaska are located on the North Slope. Seamount: Notes that the purpose in changing this regulation is to increase efficiency and to minimize the risk to personnel doing the test. Norman: Any further discussion with respect to the adoption? None. Voting: Seamount -Yes. Norman -Yes. 4. Geological Materials Center Seamount: As a reminder we were going to submit support letters from industry to Senator Stevens for the support of funding for the Alaska Geological Material Center. We should add this to next week's agenda and invite AOGA to attend. Commissioner requests Special Assistant to do this. 5. Flags Berg: The flags have been purchased and installed. 6. Panic Button Berg: Has contacted Guardian Security and they will submit a price quote for installation. 7. Processing of Permits to Drill and Sundry Applications Colombie: I will be processing these for a couple of weeks so that Linda Laasch can get caught up with her j ob duties. Norman: If there is no further business do I have a motion to adjourn? Seamount: Moves to adjourn. Norman: Seconded. They're being no further business; the meeting is adjourned 9:40 am Approved by Chair John K. No •man Date 2 ~~ about:blank • • Thank you Jim. We will ~ spy c~€ i~ t ~ t~ ~+ _ ` ~ - ~~~ . James Regg wrote: There is one other reporting obligation that is new in the proposed regulation that I did not mention this morning -- instances of BOPE use to prevent the flow of fluids from a well must be reported to the Commission within 24 hours. Jim Regg AOGCC Petroleum Engineer I of 1 6/8/2004 9:45 AM ~ 7 ~ • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BLOW OUT PREVENTION EQUIPMENT REGULATION HEARING June 8, 2004 9:00 am NAME -AFFILIATION ADDRESS/PHONE NUMBER TESTIFY (Yes or No) (PL,E~ASE PRINT) ~j~/~= / rc~~~-~ ~~ ~ z ~ ~ ,.~ ~Ilearing_Sign-In ~~ • 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 ALASKA OIL AND GAS CONSERVATION COMMISSION PUBLIC HEARING In Re: ) Proposed Regulations ) Blowout Prevention Equipment. ) TRANSCRIPT OF PROCEEDINGS Anchorage, Alaska June 8, 2004 9:02 o'clock a.m. COMMISSIONERS: JOHN NORMAN, Chairperson DAN SEAMOUNT ~C ~~~ ~ ~Q~~ ~ask~ 0~1 ~ ~~~ Cony. C~m~nissiQ~' A~~~r~~e METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 • 2 3 4' ~i 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 i• TABLE OF CONTENTS OPENING REMARKS BY CHAIRPERSON NORMAN Page 3 TESTIMONY JAMES REGG Page 5 END OF PROCEEDINGS Page 13 METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 i • '~ 1 P R O C E E D I N G S 2 (On record 9:02 a.m.) 3 CHAIRMAN NORMAN: This hearing is called to 4 order. This is a hearing before the Alaska Oil and Gas 5 Conservation Commission. The date is Tuesday, June 8, 2004. 6 The time is approximately 9:03 a.m. The location is at the 7 Commission's offices at 333 West Seventh Avenue, Anchorage, 8 Alaska. Present is myself, Chairman of the Commission, John 9 Norman. Also present is Commissioner Dan Seamount. A quorum 10 is present, and we will proceed with the meeting. Laura 11 Ferro -- am I pronouncing that right? 12 COURT REPORTER: Yes, sir. 13 CHAIRMAN NORMAN: Of Metro Court Reporting is h b t di 14 jec ngs. T e su here to provide a transcript of the procee 15 of today's hearing is the interval for testing blowout 16 prevention equipment. It is by definition a very important 17 subject. It concerns safety. It also concerns sound 18 practice, and it's something that the Commission is very 19 concerned about. We do not want to require testing of blowout 20 prevention equipment at unnecessarily frequent intervals. At 21 the same time, the Commission must be absolutely satisfied 22 that safety and other good oil field practice will not be 23 compromised. 24 The subject today is adoption of a regulatory change 25 in Title 20 of Chapter 25 of the Alaska Administrative Code METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 3 1 dealing with blowout prevention equipment. Specifically, the 2 proposed amendment will amend two sections of the Alaska 3 Administrative Code. These are respectively 20 AAC 25.035 and 4 20 AAC 25.036. Copies of the specific amendments proposed 5 have been available and will be made a part of the record. 6 They will also be discussed specifically later in this 7 hearing. 8 Essentially, what is proposed is that the regulations 9 and the two sections referenced will be amended to change the 10 required test time interval between testing of blowout 11 prevention equipment from 7 days to 14 days in the specific 12 instances that will be identified and are identified in the 13 proposed regulation. Notice of this hearing was published on i i 14 on ss April 22, 2004, in the Anchorage Daily News. The Comm 15 has received no written comments. As earlier indicated, this 16 hearing is being recorded, and there will be a transcript made 17 of it. Anyone wishing a copy of the transcript later may 18 obtain that. Likewise, if there's anyone in the audience that 19 wishes to testify, we do have a sign-in sheet and would ask 20 that you sign in so that we can identify you for the record. 21 Initially, testifying for the Commission will be Mr. 22 Jim Regg, a petroleum engineer. Would you swear in Mr. Regg, 23 please? 24 COURT REPORTER: Mr. Regg, raise your right 25 hand, please. METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 4 1 (Oath administered) 2 MR. REGG: I do. 3 COURT REPORTER: Thank you. State your full 4 name for the record. 5 MR. REGG: James Regg. 6 COURT REPORTER: Thank you. 7 CHAIRMAN NORMAN: Mr. Regg, could you first 8 begin by stating your position and your qualifications? 9 MR. REGG: Yes, sir. I joined the Commission 10 in 2002 as a staff petroleum engineer. I currently supervise 11 five petroleum inspectors here. I have a Bachelor of Science 12 Degree in Petroleum and Natural Gas Engineering from 13 Pennsylvania State University. ik 14 e on. COURT REPORTER: Please clip the m 15 MR. REGG: Is that better? A Bachelor of 16 Science Degree in Petroleum and Natural Gas Engineering from 17 Pennsylvania State University, and a companion Bachelor of 18 Arts Degree in Math and Natural Sciences from Edinboro State 19 University. My work experience spans 20 years in both Alaska 20 and the Gulf of Mexico evaluating technical issues associated 21 with oil industry operations from a regulatory perspective. 22 Those areas include drilling production, problem well 23 initiatives, and alternate compliance findings. I was part of 24 an MMS industry reliability study that investigated blowout 25 prevention testing, and specifically focusing on a 14-day METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 5 1 versus 7-day test cycle. And in 2001, I was recognized by the 2 National Society of Professional Engineers as MMS Engineer of 3 the Year. 4 CHAIRMAN NORMAN: Thank you, Mr. Regg. 5 Commissioner Seamount, do you have any questions concerning 6 the qualifications of the witness? 7 COMMISSIONER SEAMOUNT: I have no questions 8 about his outstanding qualifications. 9 CHAIRMAN NORMAN: Good. Mr. Regg, then could 10 you proceed in your own manner in whatever order you wish to 11 discuss the background research that has been done by you and 12 others at the Commission staff to establish a baseline of 13 information upon which we might consider a change in the d 14 ays? regulatory test interval from 7 to 14 15 MR. REGG: Thank you. The purpose of my 16 remarks this morning are to present the results of a blowout 17 prevention equipment performance review performed by the 18 Commission. I want to introduce the results into the record, 19 and a copy of that report has been provided to you this 20 morning. Some background before I get into the actual 21 results. 22 CHAIRMAN NORMAN: Mr. Regg, if I could pause 23 for a moment just for the record again. I have before me the 24 document entitled Review of Historical BOPS Tests, dated May 25 of 2004. And it consists of three primary pages, and then an METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 6 • 1 appendix. And the appendix consists of it looks like about 10 2 pages rough- -- approximately. And this will be officially 3 made a part of the record upon conclusion of your testimony. 4 MR. REGG: Okay. The background to begin, 5 current regulations require function and pressure testing of 6 blowout prevention equipment when installed, repaired, or 7 changed, and at least once per week thereafter. In the past, 8 operators have approached the Commission about changing the 9 test cycle from 7 days to 14 days citing other regulatory 10 jurisdictions such as the Minerals Management Service, the 11 Bureau of Land Management, Norway's Petroleum Safety 12 Administration as examples where longer test cycles have been 13 allowed. In those past discussions there's been no h i d i 14 e on, an t ss performance data presented to the Comm 15 Commission took no action. 16 In early 2004, the Commission on its own initiative 17 investigated a 14-day blowout prevention equipment test cycle 18 for the Prudhoe Bay and Lisburne Oil Pools. The results of 19 that investigation were Conservation Orders 516 and 517, 20 respectively. The decision to allow 14-day BOP testing in 21 those two pools for development well drilling only was based 22 on the high degree of geologic control, under-pressure pools, 23 the large kick tolerance provided by the drilling practice, 24 and the lack of well control events. Subsequent to that 25 effort, the Commission has proposed to look at the 14-day BOP METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 7 • 1 test frequencies on a state-wide basis. That takes us to this 2 point. As part of that effort, we decided that a review of 3 historical BOP performance would be useful. 4 I next want to talk about the scope of our review. 5 I'll present results, and them I'll make some concluding 6 remarks. The test results that we investigated are from 2001 7 through April 30 of 2004. The data set includes both 8 operator-witnessed and commission-witnessed BOP tests. The 9 Commission has witnessed approximately 22 percent of the 10 blowout prevention equipment tests during this review 11 timeframe. We believe the test data is representative of 12 actual BOP operating performance. 13 Test results are routinely submitted to the Commission lik l d f i i h 14 y errors e ata or n a standard format. We rev ew t ose 15 and omissions including dates, well names, descriptions of the 16 failures, and actual counts of the failures. The effort was 17 designed to develop statistical information from tests. We 18 looked at the number of components tested, the number of 19 failures of all components, the .number of failures of critical 20 components, and then the respective failure rates. Critical 21 components were chosen based on the severity of consequences 22 should the component fail during a well control event. 23 Included in that were annular precentors, the pipe rams, blind 24 rams, and the accumulator system. 25 I next want to draw your attention to page two in the METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 8 • 1 report. There's a table that summarizes the statistical 2 results of our review. We present the results for each year. 3 And I want to focus you towards the far right column under 4 Totals. Note that the failure rate for all components is 2.16 5 percent, and for those critical components is 0.42 percent. 6 The failure rates statistics demonstrate a high degree of 7 reliability of BOP equipment. Further reducing the 8 significance of failure statistics are the redundancy within 9 the BOP equipment, the multiple devices capable of shutting 10 off an uncontrolled flow, the redundant controls, mobile paths 11 for returning fluids, operational monitoring, and, of course, 12 the primary means of well control, the drilling fluid. 13 In our review we were not able to locate any t i i 14 pment tes on equ equivalent review of Alaska blowout prevent 15 data for earlier years to compare our results against. There 16 have been other studies of BOP performance but they're not 17 directly comparable to this review. But those results have -- 18 excuse me, those results have concluded that there is no 19 statistical difference between 14-day and 7-day test 20 intervals. The low rate of failure is reasonable given 21 equipment and operational improvements that occurred since 22 regulations established a BOP test interval and ongoing 23 equipment maintenance practices. 24 In addition to the technical and performance arguments 25 relative to the changing the test interval, there are METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 9 1 administrative issues and economic considerations. These are 2 beyond the scope of this review but are acknowledged in the 3 report. 4 Our report does make several specific recommendations 5 based on blowout prevention equipment performance review, 6 which I will defer discussing at this time. And I am willing 7 to address any questions you have about our review. Thank 8 you. 9 CHAIRMAN NORMAN: Thank you, Mr. Regg, for 10 your work on this and your testimony. Commissioner Seamount, 11 do you have questions? 12 EAMOUNT: Mr. Re this looks COMMISSIONER S gg, 13 like an outstanding study. I just had maybe only one i h 14 s a very ere question. The table on page two shows that t 15 high degree of reliability, especially in the critical 16 components. Now these are totals from all BOP tests, is that 17 correct? 18 MR. REGG: That's correct. 19 COMMISSIONER SEAMOUNT: Were you able to split 20 out the timing between -- I mean sometimes an extension will 21 be given on a test, and there are some tests in Alaska that -- 22 where the interval is 14 days or longer. Did you go so far as 23 to look at those tests and see if there's any difference 24 between -- in reliability between those and those that were 25 stuck to the regulatory 7-day interval? METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 10 i • 1 MR. REGG: One of our initial goals in doing 2 the statistical review was to capture the time interval 3 between tests so that we could do that. Unfortunately, we 4 don't have good enough data to make a specific statistical 5 presentation of that. We can make a statement that it appears 6 when there are extensions granted, they typically extend a BOP 7 test from 7 days out to about 10 or 11 days. If you look at 8 the other BOP studies that have been done, and I'll reference 9 specifically the one done by the Minerals Management Service, 10 they actually did look at a statistical difference between 7- 11 day BOP testing and 14-day. And they put two different -- 12 they took a set of drilling operations and put those on the 13 different test cycles so they could actually determine that. t f B diff 14 rom erence. u And they found there was no statistical 15 our data we cannot do that at this point in time. 16 COMMISSIONER SEAMOUNT: Okay. Thank you, Mr. 17 Regg. I have no further questions. 18 CHAIRMAN NORMAN: Mr. Regg, the table at the 19 top of page two, the statistical table of the BOP tests and 20 results that is spread between 2001 and 2004, what was the 21 distribution of those wells tested? More specifically, is 22 that representative of the entire State of Alaska or is it 23 concentrated in one area and one operator? 24 MR. REGG: The results are statewide, all BOP 25 tests in the State of Alaska, but as you're aware, the METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 11 • i• i• 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 preponderance of work on the North Slope so the numbers would be skewed toward operations there. CHAIRMAN NORMAN: On the North Slope does it include though a random distribution of fields such as Alpine and Kuparuk and others outside the immediate Prudhoe Bay area? MR. REGG: Yeah. Our data includes all BOP tests done in all fields in the State of Alaska during that time frame. CHAIRMAN NORMAN: And the age of the wells tested, there's a good statistical distribution of the age of the wells tested as well? MR. REGG: We didn't look at the age of the wells in our consideration. CHAIRMAN NORMAN: Would the age of the wells have a bearing upon the reliability of the blowout prevention equipment? MR. REGG: I don't believe so. It's unique to the blowout prevention equipment itself, the rig and the operation. CHAIRMAN NORMAN: The proposed regulation, in addition to going from 7 days to 14 days, there are some other changes in here. Could you briefly mention the other changes that are addressed in the regulation if you have that before you? MR. REGG: Yes. One of the changes is that METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 12 • 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 ~~ `.__.~ the regulations right now require a 7-day function and pressure test. The proposed regulation would continue to require a function test weekly, but would also -- would extend the pressure test requirement to 14 days. The requirement is also for development drilling only, which would exclude all exploratory work. I believe that's the extent of the changes that we've proposed. CHAIRMAN NORMAN: Yes. Thank you. Commissioner Seamount, anything further? COMMISSIONER SEAMOUNT: Is there a change in reporting requirements? MR. REGG: There's not a change in the reporting requirements. We would still expect all BOP tests to be reported to the Commission. It will be critical that we do get all reports since -- as well as the notification about a pending BOP test so the Commission has the opportunity to witness those. COMMISSIONER SEAMOUNT: That's all I have, Mr. Chairman. CHAIRMAN NORMAN: Okay. Mr. Regg, again, I want to add to Commissioner Seamount's thanks to you for overseeing this study and to all the rest of the staff that worked on it, and others that cooperated and participated in putting it together. Let's see, are there any other persons present today that wish to offer any testimony on this? Okay. METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 13 ., .~ • • 1 2 3, 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 • Hearing none, and Commissioner Seamount, with your permission, I'd like to leave the record open in case a comment might come in the mail even though we had a cut-off. I'd like to leave the record open until close of business this Friday, and then we will consider the record finally closed, and the Commissioners will then take action on the proposed regulation. COMMISSIONER SEAMOUNT: That sounds very appropriate. CHAIRMAN NORMAN: As earlier indicated, these proceedings will be transcribed, and interested parties may obtain a copy of the proceedings. Attached to a copy of the proceedings will be the written study that has been referred to by Mr Regg. If there's no further business before the Commission, we will adjourn at 9:22 a.m. (Off record 9:22 a.m.) * * * END OF PROCEEDINGS METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Ataska 99501 (907) 276-3876 14 • 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 I 20 21 22 23 24 25 i• C E R T I F I C A T E SUPERIOR COURT STATE OF ALASKA ss. I, Jerri Young, Notary Public in and for the State of Alaska, do hereby certify: THAT the annexed and foregoing pages numbered 2 through 14 contain a full, true and correct transcript of the Public Hearing before the Alaska Oil and Gas Conservation Commission, taken by Laura Ferro and transcribed by me: THAT the Transcript has been prepared at the request of the Alaska Oil and Gas Conservation Commission, 333 West Seventh Avenue, Anchorage, Alaska. DATED at Anchorage, Alaska this 15th day of June, 2004. SIGNED AND CERTIFIED TO BY: Jer Young No `ry in a for A ska My Commission Expires: 11/03/07 METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 15 ~5 STATE OF ALASKA ~ NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING ORDER INVO UST BE IN TRIPLIC( TE SHOWING ADVERTI) ING ORDER RTIFIED AFFIDAVIT OF PUBLICATION PART2 OF THIS FORM WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE /~ 0.02414030 A SEE 80TTOM FOR INVOICE ADDRESS F R AQCjCC 333 W 7th Ave, Ste 100 AGENCY CONTACT Jod Colombie DATE OF A.O. Aril 20 2004 ° M Anchorage, AK 99501 PHONE PCN DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News P O Box 149001 Anchorage, AK 99514 April 22, 2004 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: STOF0330 Advertisement to be published was e-mailed Type of Advertisement X Legal ^ Display ^ Classified ^Other (Specify) SEE ATTACHED SEND INVOICE IN TRIPLICATE TO AOGCC, 333 W. 7th Ave., Suite 100 Anchora e AK 99501 PAGE 1 OF 2 PAGES TOTAL OF ALL PAGES$ REF TYPE NUMBER AMOUNT DATE COMMENTS 1 VEN s A>to 02910 3 4 FIN AMOUNT SY CC PGM LC ACCT FY NMR DIST LID ~ 04 02140100 73540 2 3 4 l REQUISITIONED BY: ' '; 4 "`.. DIVISION APPROVAL: 4 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM STATE OF ALASKA ~ NOTICE TO PUBLISHER ~ ADVERTISING ORDER NO. ADVERTISING INV UST BE IN TRIPLICATE SHOWING ADVE TISING ORDER ERTIFIED j AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM WITH ATTACHED COPY OF p 0.02414030 A ORDER ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE SEE 80TTOM FOR INVOICE ADDRESS ~ AOGCC AGENCY CONTACT DATE OF A.O. R 333 West 7th Avenue, Suite 100 ° Anchorage, AK 99501 PHONE P N M 907-793-1221 DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News Apri122 2004 , P O Box 149001 Anchora e AK 99514 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS g , ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: AFFIDAVIT OF PUBLICATION United states of America REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. division. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. Before me, the undersigned, a notary public this day personally appeared ATTACH PROOF OF PUBLICATION HERE. 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 2004, and thereafter for consecutive days, the last publication appearing on the day of .2004, 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 2004, Notary public for state of My commission expires 02-901 (Rev. 3/94) AO.FRM Page 2 PUBLISHER • i STATE OF ALASKA SUPPLEMENTAL 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 blowout prevention equipment. This is a SUPPLEMENTAL NOTICE adding to the NOTICE OF PROPOSED CHANGES dated April 16, 2004 concerning these proposed regulations revisions. Except as provided in this supplemental notice, the contents in the AOGCC's notice of April 16, 2004 are incorporated by reference. This supplemental notice is being issued because the AOGCC has changed the date for the oral hearing and has extended the period for receiving written comments. You may comment on the proposed regulation changes, including the potential costs to private persons of complying with the proposed changes, by submitting written comments to the Alaska Oil and Gas Conservation Commission, 333 W. 7th Avenue, Suite 100, Anchorage, AK 99501. The comments must be received no later than 4:30 p.m. on June 8, 2004. Oral or written comments also may be submitted at a hearing to be held on June 8, 2004, at the AOGCC offices, 333 W. 7th Avenue, Suite 100, Anchorage, Alaska. The hearing will begin at 9:00 a.m. and might be extended from day to day if necessary 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, auxiliary aid or service, or alternative communication format in order to participate in the process on the proposed regulation, please contact Jody Colombie at (907) 793-1221 by 4:00 p.m., June 1, 2004, to ensure that any necessary accommodations can be provided. Statutory Authority: AS 31.05.030 Statutes Being Implemented, Inter Fiscal Information: The nronose~ appropriation. Date: Apri120, 2004 or a ,~ ec c: AS 31.05.030 y~h es e t,~expected to require an increased K. Aiafinan, Chair Alaska Oil and Gas Conservation Commission Published: Apri122, 2004 AO-02414030 ADDITIONAL REGULATIONS NOTICE INFORMATION (AS 44.62.190(d)) 1. Adopting agency: Alaska Oil and Gas Conservation Commission. 2. General subject of regulations: blowout prevention equipment. 3. Citation of regulations: 20 AAC 25.035 and 25.036. 4. Reason for the proposed action: updating regulatory requirements in light of experience and information. 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. 7th Avenue, Suite 100, Anchorage, AK 99501, (907) 279-1433. 8. The origin of the proposed action: 9. Date: Aprill 10. Prepared by: Alasl~il and Gas Conservation Commission (907) 279-1433 ~nchorage Daily News • Affidavit of Publication 1001 Northway Drive, Anchorage, AK 99508 AD# DATE PO ACCOUNT 134188 04/22/2004 02414030 STOF0330 STATE OF ALASKA THIRD JUDICIAL DISTRICT 4/23/200 PRICE OTHER OTHER OTHER OTHER OTHER GRAND PER DAY CHARGES CHARGES #2 CHARGES #3 CHARGES #4 CHARGES #5 TOTAL $183.96 $183.96 $0.00 $0.00 $0.00 $0.00 $0.00 Teresita Peralta, 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 individuals. Signed .~ ~' C ~`~ Subscribed and sworn to me before this date: a ~ Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska MY COMMISSION EXPIRES: GI ~ ~ 7 ..~,.~ ~®~IJ1)11113~ STATE OF ALASKA - SUPPLEMENTAL NOTICE OF PROPOSEd CHANGES IN THE REGULATIONS OF THE ALASKA OIL AND GAS CONSERVATION COMMISSION The Alaska-Oil and Gas Conservation Commission ("AOGCC"7 Aroposes to adopt regulation changes in Title 20, tt[apter 25, of the Alaska AdminisTra- five Code, decline with blowout preveniion'pquip- ment. This is a SUPPLEMENTAL:NOTICE adding To the NOTICE OF'PROPOSED CHANGES dated April 16, 2004concerningthese proposed regulationg,re- ' visions.' Except as provided in this supplemental notice, the contents in fihe AOGCC's noticeaf April 16i 2004 are incorporated by reference,: This supplemental notice is being .issued because the AOGCC has changed the date for. the oral hearing and has extended the period for receiving written comments. You mar comment on the proposed regulation" changes, including the potential costs To l3rivate persons of complying with the proposed chances, br submitting written comments to the. Alasko Oil and Gas Conservation Commission, 333 W.?th Av- enue, Suite 100, Anchorage;. AK 99501. The com- ments must be received no,fdter than 4:30 p. m. on .June 8, 2004.. - Oral or written commerlfs also may be'submiTted at a hearing to be held on June 8, 2004.,:at he AOGCC offices, 333 W. 7th Avenue,Suito 100, An- chorage,. Alaska. The hearing will begin at 9:00 a.m. and might be extended from day'"to'dax if necessary to accommodate those present before 9:30 a.m. who did not have an opportunitv'to com- ment. If you are a person with a disability who rnar need a special accommodation, auxiliary aid or service,. or alternative communication format in order to .participate in theprocessan'the proposed regala- Tion, please contact Jodv Colombia at (907) 793-T221' by 4:00 p.m., June i, 2004, to ehsure Thar any aec- essarv accommodations can be provided. Statutory Authorifv: AS 31.05.030 STatut~s Being lmplemeated, interpreted, Or Made Specific: AS 31.05:030 Fiscal Information: The proposed regulation changes are not expected to repuire an increased appropriation. Date: April 20, 2004 John K. Norman,: Chair Alaska Oil and Gas Conservation Commission A0-02414030.'. Publish: April 22, 2004 $183.96 Supplemental Notice Subject: Supplemental Notice From: Jody Colombie <jody colombie@admin.state.ak.us> Date: Tue, 20 Apr 2004 16:32:46 -0800 To: ur~cii~closcd-recipients:; BCC: ringel~~ ~~'el~b <angle_webb(a;admir~.state.ak.us=-, Cynthia B Mciver <bren mcivE~-r~i.~adinin.state.ak.us> Please replace the original Notice with the attached Supplemental Notice. The original notice was e-mailed on 4/16/04. I changed the date of the hearing. The original Additional Regulation Notice Information sheet was not changed, so it can remain as is on line. I am sorry for the inconvenience.-Jody Content-Type: application/msword BOPE supplement notice.doc! Content-Encoding: base64 1 of 1 4/20/2004 4:45 PM Notice • Subject: Notice From: Jody Colombie <jody colombie@admin.state.ak.us> Date: Tue, 20 Apr 2004 16:33:48 -0800 To: Legal Ads Anchorabc Daih~~ Nc~~~~ <legalads~cZadn.co~Y~=~~ Please publish on 4/22/04. Thank you. ,r Content-Type: application/msword BOPE supplement notice.doc i Content-Encoding: base64 1 of 1 4/20/2004 4:44 PM ~ 4 i MEMORANDUM T°~ John K. Norman, Chair Alaska. Oil and Gas Conservation Commission Dept. of Administrration From: Deborah E. Behr Assistant Attorney General and Regulations Attorney Legislation and Regulations Section i State of Alaska Department of Law Date: April 20, 2004 File No.: 993-04-0159 Tel. No.: 465-3600 Re: Regulations File Opening Re: Blow Out Prevention Equipment (20 AAC 25.035; 036) We have received your memorandum of April 16, 2004 regarding this project, along with a copy of the proposed regulations and related documents. The project has been assigned to Assistant Attorney General Rob Mintz, phone number 269-5100. Our department's file number for this project is 993-04-0159. This file number should be used on any further correspondence pertaining to this project. DEB:pvp cc: Kevin Jardell, Regulations Contact Dept. of Administration Jody Colombie Alaska Oil & Gas Conservation Commission Dept. of Administration Robert Pearson, AAC Coordinator Lt. Governor's Office Wilson Condon, Supervising Attorney Oil, Gas, and Mining Section ~~~C~U~~ ApR 2 +~ 2004 Alaska OiS ~ ~~s Cn~s, i~~:~~Rs~~n Ancrora~e Rob Mintz Assistant Attorney General Anchorage ~3 STATE OF ALASKA NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING ORDER ~ ~ INV UST BE IN TRIPLICATE SHOWING ADVERTISING ORDER ERTIFIED AFFIDA IT OF PUBLICATION (PART2 OF THIS FORM) WITH ATTAC COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE /~ 0.02414029 A SEE BOTTOM FOR INVOICE ADDRESS " R AOGCC 333 W 7th Ave, Ste 100 AGENCY CONTACT Jod Colombie DATE OF A.O. Aril 16 2004 ° M Anchorage, AK 99501 PHONE PcN DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News P O Box 149001 Arichora e AK 99514 g ~ April 19, 2004 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: STOF0330 Advertisement to be published was e-mailed Type of Advertisement X Legal ^ Display ^ Classified ^Other (Specify) SEE ATTACHED SEND INVOICE IN TRIPLICATE TO AOGCC, 333 W. 7th Ave., Suite 100 Anchors e AK 99501 PAGE 1 OF 2 PAGES TOTAL OF ALLPAGES$ REF TYPE NUMBER AMOUNT DATE COMMENTS 1 VEN s ARC 02910 3 4 FIN AMOUNT SY CC PGM LC ACCT FY NMR DIST LIQ ~ 04 02140100 73540 2 3 4 REQUISITIONED B %~ r ~.,.... DI SIO 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM 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 blowout prevention equipment, including the following: 20 AAC 25.035 and 25.036 are proposed to be amended to change the time intervals for testing blowout prevention equipment, change the types of tests required. for blowout prevention equipment, and add a requirement that use of blowout prevention equipment to prevent fluid flow from a well be reported to the AOGCC. 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. 7th Avenue, Suite 100, Anchorage, AK 99501. The comments must be received no later than 4:30 p.m. on May 27, 2004. Additionally, oral or written comments may be submitted at a hearing to be held on May 27, 2004, at 333 W. 7t'' Avenue, Suite 100, Anchorage, AK 99501. The hearing will begin at 9:00 a.m. and might be extended from day to day if necessary 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, auxiliary aid or service, or alternative communication format in order to participate in the process on the proposed regulation, please contact Jody Colombie at 793-1221 by 4:00 p.m., May 25, 2004 to ensure that any necessary accommodations can be provided. Copies of the proposed regulation changes may be obtained from the AOGCC office, 333 W. 7th Avenue, 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 fmal regulations may be different from that of the proposed regulations. YOU SHOULD COMMENT DURING THE TIME ALLOWED 1F YOUR INTEREST COULD BE AFFECTED. Written comments received are public records and are subject to public inspection. Statutory Authority: AS 31.05.030. Statutes Being Implemented, Interpreted, or Made Specific: AS 31.05.030. Fiscal Information: The proposed regulation than es are not expected to require an increased appropriation. ~~ /~~ Date: April 16, 2004 Oil and Gas Conservation Commission Published: April 19, 2004 AO-02414029 ADDITIONAL REGULATIONS NOTICE INFORMATION (AS 44.62.190(d)) 1. Adopting agency: Alaska Oil and Gas Conservation Commission. 2. General subject of regulations: blowout prevention equipment. 3. Citation of regulations: 20 AAC 25.035 and 25.036. 4. Reason for the proposed action: updating regulatory requirements in light of experience and information. 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. 7th Avenue, Suite 100, Anchorage, AK 99501, (907) 279-1433. 8. The origin of the proposed action: 9. Date: Aprill 10. Prepared by: Alasl~PSil and Gas Conservation Commission (907) 279-1433 ~nchorage Daily News ~ .a , ` X2°"4 Affidavit of Publication 1001 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 131039 04/19/2004 02414029 STOF0330 $221.92 $221.92 $0.00 $0.00 $0.00 $0.00 $0.00 $221.92 STATE OF ALASKA THIRD JUDICIAL DISTRICT Teresita Peralta, 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 farm) 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 individuals. Signed ~~~ ~J Subscribed and sworn to me before this date: ~ L Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska ~~yy MY COMMISSION EXPIRES: ~~ ~W / ~ ~ /1 I i ``~tttl,~¢'f ~ ~'~(~/jP r ~~~ ~~ ~. ~ ,. . r o ..s ~' ~ ,•~. ~~~I1J1UlIti STATE AF ALASKA NOTICE-0F 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 Administra- tive Code., dealing with blowout prevention equip- ment, including the following: 20 AAC 25.035 and 25.036 are proposed to be amended To change the time intervals for testing blowout prevention equipment, change the Types of tests required for blowout. prevention equipment, qnd add a requirement that use of blowout prevention equipment to prevent fluid flow from a well be reported #o the AOGCC. You may comment on the proposed regulation changes, including the potentiaF 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 re- ceived no IaTer than 4:30 p. m. on Mav 27,.2004. Additionally, oral or written comments may be submitted at a hearing to be held on MaY 27, 2004, at 33&W: 7Th Avenue, Suite 1D0, Anchorage, AK 99501, The hearing will begin at 9:00 a.m. and might be extended from day to day if necessary to accommodafethose 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, auxiliary aid or service, or alternative communication format in order to participate in the process on The proposed regula- tion, please contact Jody Colombie at 793-1221 by 4:00 p.m., May 25, 2004 to ensure fihak any neces- sary accommodafions can be provided. Copies of the proposed regulation changes may be obtained from the AOGCC office, 333 W. 7th Av- enue, Anchorage, Alaska 99501, or by telephoning the AOGCC at 907-793-1221, or on the AOGCG web- site at: htip://www.aogcc.a laska.govr After The public comment period ends, the AOGCC will either adopTihis or another proposal dealing with the same subject, without further ngtice, or decide to take no action on it. The language of the final regulations may be different from thdT of the proposed regulations. YOU SHOULD COMMENT DURING THE TIME ALLOWED LFYOURIN- TEREST COULD BE AFFECtED. Written com- meets received are public records and are subiecT TO pabllC inSpeCtlOn. Statutory Authority: AS 31.05.030. Statutes Being Implemented,. Interpreted, or Made Specific: AS 31.05.030. Fiscallnformation: The proposedYegulation changes are not expected to require an increased appropriation. Date: Apri116,2004 John K. Norman, Chair Alaska Oil and Gas Conservation Commission AO-02414029 Publish: Apri619, 2004 STATE OF ALASKA NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING ~ INVO UST BE IN TRIPLICATE SHOWING ADVERTISING ORDER ERTIFIED WITH ATTACHED C PY OF AFFIDAVIT OF PUBLICATION PART 2 OF THIS FORM A 0.02414029 ORDER ( ) A ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE SEE BOTTOM FOR INVOICE ADDRESS F AOGCC AGENCY CONTACT DATE OF A.O. R 333 West 7'h Avenue Suite 100 ° , Anchorage, AK 99501 PHONE P N M 907-793-1221 - DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News April 19, 2004 P O Box 149001 C Anchora e AK 99S 14 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS g ~ ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: AFFIDAVIT OF PUBLICATION United states of America REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. division. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. Before me, the undersigned, a notary public this day personally appeared ATTACH PROOF OF PUBLICATION HERE. 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 2004, and thereafter for consecutive days, the last publication appearing on the day of .2004, 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 2004, Notary public for state of My commission expires 02-901 (Rev. 3/94) AO.FRM Page 2 PUBLISHER Notice Subject: Notice From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Fri, 16 Apr 2004 1.5:05:11 -0800 'To: Legal Ads Anchorage Daih~ Ne~~-s ~~~=legalads«<~adn.com> Please publish on Content-Type: application/msword Notice of 14 Day BOPE Test.doc Content-Encoding: base64 1 of 1 4/ 16/2004 3:07 PM RE: Ad Order • Subject: RE: Ad Order From: legalads <legalads@adn.com> Date: Fri, 16 Apr 2004 16:07:38 -0800 To: Jody C~~l~»~~bie ~ jody_coiombie@admin.statie.ak.us~== Hi Jody: Thanks for the AO, Following is the confirmation information on your legal notice. Please let me know if you have any questions or need additional information. Account Number: STOF 0330 Legal Ad Number: 131039 Publication Date(s): April 19, 2004 Your Reference or PO#: 02414029 Cost of Legal Notice: $221.92 Additional Charges Web Link: E Mail Link: Bolding: Total Cost to Place Legal Notice: $221.92 Ad Will Appear on the web, www.adn.com: Ad Will Not Appear on the web, www.adn.com: XXXX Thank You, Kim Kirby Anchorage Daily News Legal Classified Representative E-Mail: legalads@adn.com Phone: (907) 257-4296 Fax: (907) 279-8170 From: Jody Colombie Sent: Friday, April 16, 2004 3:53 PM To: legalads Subject: Ad Order «File: Ad Order form.doc» Kim, Pm sorry! -Jody 1 of 1 4/16/2004 4:26 PM Notice __ Content-Type: application/msword Notice BOPE Test.doc - Content-Encoding: base64 Subject: Notice From: Jody Colombie <Jody_colombie@admin.state.ak.us> Date: Fri, 16 Apr 2004 15:02:51 -0800 To: CynthiaB Mever <bren mciverC admin.state.ak.us> Please publish on line Content-Type: application/msword Notice of 14 Day BOPE Test.doc' ': Content-Encoding: base64 1 of 1 4/16/2004 3:07 PM Public Notice • Subject: Public Notice From: Jody Colombie <jody colombie@admin.state.ak.us> Date: Fri, 16 Apr 2004 15:02:11 -0800 To: Angela Webb ti~~~~gie~~ ebbr.~z admin.state.al:.us-= Please publish on line. Content-Type: application/msword Notice of 14 Day BOPE Test.doci', Content-Encoding: base64 1 of 1 4/16/2004 3:07 PM Regulation Notice Subject: Regulation Notice From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Fri, 16 Apr 2004 15:18:39 -0800 To: undisclosed-recipients:: BCC: Rutiert E Mintz <robert mintr(~i;la~w.statc.ak..us:=. Christine Hansen <c.hansen«Giogce.state.ok.us>, Tcrric Hubble ~=~hubbletlr~i;bp.com=~ _ S~~ndra Stewman <Ste~~~°maSD(uBP.com-', Scott ~ CaYnmy Taylor °~stay~lor~u:alaska.net--. stanekj -~=stanei:j<<i:uno~aLconv, eci~la~-v <-ecola«~c~;arustees.ora ~, roseragsdale ~'a-oscragsdale~a;,~~ei.nc;t>_ trnljrl °~trmjrl ~~i:aol.com==. jbriddle ~~"jbriddle~a.marathonoil.com~-~, rockhill ~~:rockhill~d a~~~~a.or«- , .hake ~~shane~~(~revergree,n~as.c~~i7~=-. , )d~uli~~~~ton ~~~darlin~ton(u~fiorest~~il.c~>n~=~. nelson <nelsc~n(~r':~~~i.net=. eboei~ly <cbodd~~~ci:~,usibelli.com='. R~arl: Dalton <mark.daltonr~ihdrine.co~~~~-, Shannon Donnelly <Shannon.donnelly(u;conoeo~~hillips.con~>, "Mark. P. Worccstcr~~ <mark.p.~yorcester~a.cunocohhillips.com=-. °Jerrv G Uethlcfs" =j~rry.c.dcthlcis(u?c.ono~ophillips.com>, Bob ~~-bob(rc~~inlztkee}~er.org=~. ~~~d~~ ~~=wd~rridnr.st~~te.ak.us~~. tjr •-tjr(u-:dnr.state.ak us%, bbritch <bbriteh«ialaska.nct==, n7jnelson <mjnclson~,rz.~.purvin~~rtz.~om=-. Charles (~'Donncll <charles.o'donnell~u ~cco.coni%~_ "Randy L. Skillen~" <Ski]IeRL(u BP.com%. "Jeanne H. Dickey" ~DickevJH(cL~F3P.com>, "Deborah J. Janes" <Jone,DE~~ci~13P.com-=_ "fatal G. Hyatt" ==hvatthg~a; BP.coni>. "Steven R. R~ssberg" ~ RossbeRSfuBP.com~ ,Lois <Ioislu-inletkecher.orc=-, "Joseph F. Kirchner" ~-_KirchnJF~cr;BP.com=>, Gordon Pospisi] <P~~spisG(cz;13P.com%~~, "Francis S. Sommc;r" <SommerFS~a~BP.com ~, Y1ikel Schultz ~~ 1\1ikel.SchultirciBP.com>. "brick V~~'. Glover" <GloverN~~"~u;BP.com~ ~. "Daryl J. Kleppin" =KlephiDC(u'BP.com=~, ".lanet D. Platt" <PlattJDr~r~.13P.a~m>, "Rosanne M. Jacobsen" <JacobsRMlci;:BP.com=~, ddonkcl =~=ddonkel~u;cfl.rr.com~., Collins !~~lount ~~collins_mount(u:;revenuz.state.ak.us=~, mckay ~~mckay~a'gci.net=, Barbara F Fullmer ~bai•t~~lra.i~.fullm~r~~r~eun~cophilli~s.nom=>, bocast~~~f <hoeast~tif(~r;b}~.eom~, Charles Barker <barkcr-L usgs.gov=~. , dour schultre ~ dou~schultrc ~u'xto~nergv.~om>, F-Ias~k .allord <-hank.aifordlu!elxi~nmobiLcom=~, Mark Ku~aC <yesnol(ci:gci.net%, gspfoff =gshtoft~(«:-aurorapow~er.com=, Greg Nady~~gregg.nady(ci; hell.com=. 1=rid Stc~cc =Fred.steece(cl;state.sd.us%, rcrotty ~~rcrotty(u~ch2m.com>, jcjones = jejonesi~iaurorapo~yer.con~=>. dapa <:dapa!~i;alaska.net=~~, jroderick ~~ jrodenek~ci,gci.net>. cyancy <cyancy(ci:seal-tite.net% "lames ~~,1. Ruud" ~jamcs.m.ruud~a~conocophillips.com =, Brit Lively <=mapalaska r~ak.nct=. jah <jah~;dnr.state,ak.us==, Kurt E Olson <kurt Olson@legis.state.ak.us==. buonoje °~=Eiuonoje("~rhp.con~=~_ Mark Haillcy <mark hanlcy~u;:anadarko.com= , lorcn Leman <Ioren_ Icman~agov.state.ak.us =~. Harry R Bader <-harm bader(ci;dnr.state.ak.us>. Julie Houle ~ _juke houle~cl;dnr.state.akus-,, John ~~' Katz j~~~katz(a-ssu.or~==, Suzan J HiII <suran_ hill(udec.state.ak use=~, tablerk ~ tahlerk~a-unoc-al.com=-, Brady ~=brady(ci';aoga.or<~=, Brian Ilavelock <_beh<<z~dnr.state.ak.us>, bpi~pp ~hpopp(crborough.kcnai.ak.us-;,Jim White ~~~jim~~~hite<«~.satx.rr.com>. "John S. H~~~~~orth,~ <john.s.hawurth("u;exxonmobiLcom >, many ~mart~(,usalaska.Eiiz->, ~~han»~~on5 -~~trh<immons~ci;aol.com=~, rn~cle~u~ <-n~~clean(upobo~.alaska.nef>> , Ja~1~~.s S~hciT jamcs.schct~~l~c!mms.go~~~=, n~1:m72U0 ~mkm7200~u::ac~Lcor~i> additional regulation Content-Type: application/msword Content-Encoding: base64 i of 2 4/16/2004 3:19 PM Regulation Notice . Content-Type: application/msword Notice of 14 Day BOPS Test doc Content-Encoding: base64 2 of 2 4/16/2004 3:19 PM Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Ciri Land Department PO Box 93330 Anchorage, AK 99503 David Cusato 600 West 76th Ave., #508 Anchorage, AK 99518 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Schlumberger Drilling and Measurements 3940 Arctic Blvd., Ste 300 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 North Slope Borough PO Box 69 Barrow, AK 99723 David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 Supplemental Notice Subject: Supplemental Notice From: Jody Colombie <jody colombie@admin.state.ak.us> Date: Tue, 20 Apr 2004 16:44:09 -0800 To: undisclosed-recipients:: BCC: Robert E Mintz ~=robertmintz_(<<-law.state.ak us= ,Christine Hansen ~~=c.hansen(~iut~cc.state~.ok us=>, Terrie Huhble °~~hubbletl(~cbp.com%, S~~ndra Steti~~man Ste~~~~maSD(ct.;BP.cor1~ ~~, Scott & C~ni~mv Taylor =~-staylor(~r:alaska.nct~-, stanekj ~~~stanekj(c~~unocal.com=-=, eeola~~~ ~-ccolaw(~ltrustees.ur~=~. roseragsdale <rosera~sdaleiu.~~ci.net-=. tr-~»jrl <trmjrl(ci;aol.com>, jbriddlc ~jbriddlcur:marathonoil.com=•, rockhill <:rockhill~u'aoga.or~-, shane~~ <:shanc;g4ie~ cr~rccn~~as.com==, jdarlin~ton <jdarlingtonla torestoil.com =. nelson 'nelson~u `~ci.net ~, cboddy ~'cbodd~~r~lusibclli.com>, Mark Dalton -~mark.daltonr~iihdrinc.com%, Shannon Donncll~.: ~shannon.donnelly~lci;~conocophillips.cnm>, ,~~'~ark P. Worccster~~ ~~mark.p.~~,orcester~cl~~cunocophillip~.com=>, °Jerrv C. Dethlefis'~ _je~ny.c.d~thlefti~uconoeophillips.cc~m=~, Bob ~bob(~i:inletkccpcrorg=, wdv =~«d~rir~dnr.state.ak.us~~, tjr ~ -tjr~u?dnr.state.ak.us-~, bhritch ~~-bbritch~a.alaska.net==, mjnelson °~mjnelson~~i;purvingertz.com ~-, Charles O'Donnell <eharles.o'donnelli~l vca~.com==, "Randy L. Skillern" ~Ski11eRL(~i;BP.com-~. „Jeanne. I~.Dickey" <Die~~y~H@BP.~om>, "Deborah .l. Jones" ~~Jone~D(,~«;BP.~om%. "Paul G. Myatt" -~"hvattp~r<<i;BP.com>, "Steven R. Rossberg" °~RossheRS(c13P.com%, Lois ~lois(r~,inletkecpcr.or~->, "Joseph F. Kirchner" ~~;KirchuJF<«;BP.com~>, Gordy>n Pospisil __-Posl~isG~;~i;BP.com=~_ "1^~rancis S. Sonul~er" ~~SommerFSru.BP.com=, ylikel Schulti ~~9ikcl.Schulti(~BP.com>, "Nick ~~i. Glover" ~=Glo~erNW~~i,BP.com~-, "Daryl J. kleppin" <KleppiDE~'u-:BP.eom- °Janct D. Platt" ~~=PlattJD(ri:BP.com>, "Ro~ann~ ~~9. Jacobsen" <lacobsRM(r~B1J'.com>, ddonkel <ddonkel~acfl.rr.com=>. Collins Mount <collins mount cr,re~~enue.statc.ak.us=~, mckay ~~mcka~~~a~ei.net~%. Barbar~i F Fullmer -'Barbara.f.fullnlcr'u:conocophillip5.com-=, bocastwf ~~-bocaslwf(u;bp.com~, Charles Barker -~Barherl~t~USt~s.gov= , dou~schultze ~'dourschultz~~uat~~ener~~~.cum>. Hank Alti~rd -hankalfi~rdiu~~ex?:viunobil.com~%, Mark X101 al; <ye5no 1(a gci.net: -_ ~spt~~ff <<~spfiott~caurorapower.c~rm%, Gre~~ Nad~~ ~~~re~~.nady~a~shell.coil~%. Fred Steed ti~ed.stccce~u~state.sd.us=~, rcrott}' <rcrotty~i~ch2m.com=,, j~Joncs ~ jejoncs~daurorapotiver.com:°, dapa <dapa!"~~-alaska.net==, jroderi~.k<jroder:ick~c~;.gci.net=°, cvancv ~-eyancy<<i:'scal-tite.nct=~, "James ~V1. Ruud" <-james.m.ruudrn~;conocophi~lips.com ~. Brit Lively <-mapalaskarcc~ak.nct=~, jah jahi«,dnr.statc.ak.us >. Kurt EOlson -<kartolson(ulegis.state.ak.us=>, buonoje -~=buonuje~c~7rbp.com=-, Mark Manley'markhanleytc~anadarko.com==, Iorcnlcman <-Lorenleman%u~,~rov.state.ak.us=. Harry R Bader ~-harry-baderrci~dnr.state.ak.us~, Julie Houle =juliehoulc~adnr.state.akus ~, Jahn W Matz <j~~katz~a;sso.org~=, Suzan J Hill ~suzan_hill(rl;dec.state.ak.us ~, tablerk <-tabl.rk!~i;unocal.com=>, Brady <brady<<t;aoga.org=~, Brian 1lavc;loek ~ hchru;dnr.state.al.us?, bpupp -'-bpopp~~zhi~rou~~h.kenai.ak.us=, Jim White <;jimwhrte(cc;satx.n-.com=-, "John S. Haworth" <john.s.ha~i~c~rth~«'exxi~nn~obil.com=', many ~~~mar~ty<<cusalaska.biz?, <ahtuni~~ons ~~~h~rt~~mc~ns(c~;aol.c~~m>_ rmclean<r~ncl~an(u;pob~~.aids#~a.nct~>, James S~Irerr ~james.schcrr!u-mrns.`~ov-> mkm7?()0 <_mkm7?0~'~aol.conl=, Brian Gillespie. <itBmg~u%uaa.alaska.edu=, David L Boclcns <dboel~ns~auror:.rpo~~er.~om=~, Todd Durkcc <~T D U RKE~. ~ a :KMG.com= _. _ _ Content-Type: application/msword Additional Regulation Notice.doc! Content-Encoding: base64 1 of 2 4/20/2004 4:44 PM Supplemental Notice Content-Type: application/msword BOPE supplement notice.doc Content-Encoding: base64 2 of 2 4/20/2004 4:44 PM V! or kLir-l-M MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Deborah E. Behr Assistant Attorney General And Regulations Attorney Legislation and Regulations Section FROM: DATE: April 16, 2004 SUBJECT: File-opening request for new regulations project on blow out prevention equipment 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 blow out prevention equipment. Enclosed is a copy of the public notice, Additional Regulations Notice Information, and a draft of the regulation. Please assign Assistant Attorney General Robert Mintz to this project. Our contact person for the project is Jody Colombie at 793-1221. • 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 blowout prevention equipment, including the following: 20 AAC 25.035 and 25.036 are proposed to be amended to change the time intervals for testing blowout prevention equipment, change the types of tests required for blowout prevention equipment, and add a requirement that use of blowout prevention equipment to prevent fluid flow from a well be reported to the AOGCC. 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. 7~' Avenue, Suite 100, Anchorage, AK 99501. The comments must be received no later than 4:30 p.m. on May 27, 2004. Additionally, oral or written comments may be submitted at a hearing to be held on May 27, 2004, at 333 W. 7`h Avenue, Suite 100, Anchorage, AK 99501. The hearing will begin at 9:00 a.m. and might be extended from day to day if necessary 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, auxiliary aid or service, or alternative communication format in order to participate in the process on the proposed regulation, please contact Jody Colombie at 793-1221 by .4:00 p.m., May 25, 2004 to ensure that any necessary accommodations can be provided. Copies of the proposed regulation changes may be obtained from the AOGCC office, 333 W. 7`~ Avenue, Anchorage, Alaska 995.01, or by telephoning the AOGCC at 907-793-1221, or on the AOGCC website at: httn://www.ao ~cc.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 fmal regulations may be different from that of the proposed regulations. -YOU SHOULD COMMENT DURING THE TIlVIE ALLOWED IF YOUR INTEREST COULD BE AFFECTED. Written comments received are public records and are subject to public inspection. Statutory Authority: AS 31.05.030. Statutes Being Implemented, Interpreted, or Made Specific: AS 31.05.030. Fiscal Information: The proposed regulation char es are not expected to require an increased appropriation. ~~ /'~ Date: April 16, 2004 Oil and Gas Conservation Commission Published: April 19,.2004 AO-02414029 Register ~ 2004 MISCELLANEOUS BO~ 20 AAC 25.035 (e)(10) is repealed and readopted and a new paragraph is added to read. (10) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a well classified as "development" or "ser- vice", and unless the Commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to ex- ceed fourteen days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be pressure-tested to the required working pressure specified in. the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (B) when installed, repaired, or changed on a well classified as "exploratory" or "strati- graphic test", and at least once a week thereafter, BOPE, including kelly valves, emer- gency valves, and choke manifolds, must be pressure-tested to the required working pres- sure specified in the approved Permit to Drill, using anon-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, it must be pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit Register ~ 2004 MISCELLANEOUS BO~ to Drill, using anon-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 exclusive of blind rams must be function tested weekly 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 per- formed as soon as possible .after the workstring is pulled out of the well and the BHA clears the BOP; blind rams must be function tested at least every thirty days; (E) BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1); (F) at least 24 hours notice of each BOPE pressure test must be provided so that a com- mission representative can witness the test; (11) instances of BOPE use to prevent the flow of fluids from a well must be reported to the commission within 24 hours of use. 2 Register 2004 MISCELLANEOUS BOARDS 20 AAC 25.036(d) is repealed and readopted and a new subsection is added to read: (d) A BOPE assembly must be tested as follows: (1) when installed, repaired, or changed on a well classified as "development" or "ser- vice", and unless the Commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPS performance, at time intervals not to ex- ceed fourteen days thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested to the required working pressure specified in the ap- proved Permit to Drill, using anon-compressible fluid, except that an annular type pre- venter need not be tested to more than 50 percent of its rated working pressure; (2) when installed, repaired, or changed on a well classified as "exploratory" or "strati- graphic test", and at least once a week thereafter, BOPE, including emergency valves, and choke manifolds, must be pressure tested to the required working pressure specified in the approved Permit to Drill, using anon-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 well- head pressure .after each installation of the well .control equipment and before wellbore entry, except that if testing against the annular type preventer, pressure testing need not exceed 50 percent of the rated working pressure of the annular type preventer; 1 Register 2004 MISCELLANEOUS BOARDS (4) if BOP sealing ram type equipment has been used, it must be pressure tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-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 exclusive of blind rams 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; blind rams must be function tested at least every thirty days; (6) test results must be recorded as part of the daily record required by 20 AAG 25.070(1); (7) at least 24 hours notice of each function pressure test must be provided so that a rep- resentative of the commission can witness the test. (g) Instances of BOPE use to prevent the flow of fluids from a well must be reported to the commission within 24 hours of use. 2 ~1 Re 'ster 2(J~ MISCELLANEOUS BOA~a Draft 8/11/04 20 AAC 25.035(e)(10) is repealed and readopted and a new paragraph is added to read: (10) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a development or service well and, unless the commission determines that a weekly BOPS pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to exceed each fourteen 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 anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (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 anon-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, it must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-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 exclusive of 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) BOPS test results must be recorded as part of the daily record required by 20 AAC 25.0'70(1); (F) at least 24 hours notice of each BOPE function pressure test must be provided to the •~ E US BOARDS Draft 8/11/04 Register 200_ MISCELLAN O commission so that a commission representative can witness the test; (11) 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. 4/13/80, Register 74; am 2/22/81, register 77; am 4/2/86, Register 97; am 11/7/99, Register 152; am / / ,Register _~ Authority: AS 31.05.030 20 AAC 25.036(d) is repealed and readopted and a new subsection is added to read: (d) A BOPE assembly must be tested as follows: (1) when installed, repaired, or changed on a development or service well and, unless the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to exceed each fourteen 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 anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (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 BOP sealing ram type equipment has been 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 2 • ~ MISCELLANEOUS BOARDS Draft 8/11/04 Register 200_ of its rated working pressure; (5) BOP ram and annular components exclusive of 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) test results must be recorded as part of the daily record required by 20 AAC 25.070(1); (7) at least 24 hours notice of each fiznction pressure test must be provided to the commission so that a representative of the commission can witness the test. (g) 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 3 ~ f 20 AAC 25.035 (e) l~_(}~ is repealed and readopted and a navy para~~-al~h is added to read (10) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a well classified as "development" or "ser- vice", and unless the Commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPS performance, at time intervals not to ex- ceed fourteen days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be pressure--tested to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (B) when installed, repaired, or changed on a well classified as "exploratory" or "strati- graphic test", and at least once a week thereafter, BOPE, including kelly valves, emer- gency valves, and choke manifolds, must be pressures-tested to the required working pressure specified in the approved Permit to Drill, using anon-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, it must be pressure-=tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-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 exclusive of blind rams must be function tested weekly 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 per- formed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; blind rams must be function tested at least every thirty days; (E) BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1); (F) at least 24 hours notice of each BOPE pressure test must be provided so that a com- mission representative can witness the test:; (11) ~linstances of BOPE use to prevent the flow of fluids from a well must be reported to the ~~"ommission within 24 hours of use. 20 AAC 25.0360 is repealed and readopted anti. a ne~~l sul7sec:tio~i is added to reads ~' _ =s. (d) A BOPE assembly must be tested as follows: (1) when installed, repaired, or changed on a well classified as "development" or "ser- vice", and unless the Commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to ex- ceed fourteen days thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested to the required working pressure specified in the ap- proved Permit to Drill, using anon-compressible fluid, except that an annular type pre- venter need not be tested to more than 50 percent of its rated working pressure; (2) when installed, repaired, or changed on a well classified as "exploratory" or "strati- graphic test", and at least once a week thereafter, BOPE, including emergency valves, and choke manifolds, must be pressure tested to the required working pressure specified in the approved Permit to Drill, using anon-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 well- head pressure after each installation of the well control equipment and before wellbore entry, except that if testing against the annular type preventer, pressure testing need not exceed 50 percent of the rated working pressure of the annular type preventer; (4) if BOP sealing ram type equipment has been used, it must be pressure tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-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 exclusive of blind rams 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; blind rams must be function tested at least every thirty days; (6) test results must be recorded as part of the daily record required by 20 AAC 25.070(1); (7) at least 24 hours notice of each function pressure test must be provided so that a rep- resentative of the commission can witness the test. (gc) Instances of BOPE use to prevent the flow of fluids from a well must be reported to the . > con~n7ission within 24 hours of use. ~~.~z~.=~'.,.`'-'c~i-m;~~rm e . ~F, acdea m~a .~..~dsPE~a as T^ G..a I;~). Register 200_ MISCEL~OUS BOARDS 20 AAC 25.035 (e)(10) is repealed and readopted and a new paragraph is added to read. (10) the BOPE r~xtSt be tested as follows: d (A) when installed, repaired, or changed on a well classified as1"developmen ' or,~ "servic ', and unless the Commission determines that a weekly BOPE pressure test in- terval is indicated by a particular drilling rig's BOPE performance, at time intervals not zcA.Ca°~ to exceed~fourteer days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, t be pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (B) when installed, repaired, or changed on a well classified as "exploratory" or "stratigraphic test", and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, r>be pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon-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, it r~Cst be pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-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 exclusive of blind rams rat be functio~i tested weekly 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 Register 200_ MISCEL~OUS BOARDS • performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; blind rams must b~e.Qfu~nction tested at least every thirty days; 5~'~" (E) BOPE test results rust be recorded as part of the daily record required by 20 AAC 25.070(1); ~ ~~~SS ~ 11~ (F) at least 24 hourslnotice of each BOPE pressure test npxist be provided~o that a commission representative can witness the test; (11) instances of BOPE use to prevent the flow of fluids from a well rryu~t be reported to c~ the commission within 24 hours of~~ 20 AAC 25.036(d) is repealed and readopted and a new subsection is added to read. (d) A BOPE assembly must be tested as follows: (1) when installed, repaired, or changed on a well classified as\"developmen " or "servic ", and unless the Commission determines that a weekly BOPE pressure test in- terval is indicated by a particular drilling rig's BOPE performance, at time intervals not to exceed~fourteen days thereafter, BOPE, includingemergency valves and choke mani- folds, t be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type pre- venter need not be tested to more than 50 percent of its rated working pressure; (2) when installed, repaired, or changed on a well classified as "exploratory" or "stratigraphic test", and at least once a week thereafter, BOPE, including emergency Register 200_ MISCEL~EOUS BOARDS valves and choke manifolds essure tested to the. re uired workin ressure p q gp specified in the approved Permit to Drill, using anon-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 mtr~t be pressure-tested to the maximum poten- tial wellhead pressure after each installation of the well control equipment and before wellbore entry, except that ~g-aga~s~-fie annular type preventer,~s~~~r~e~est~g need not end 50 percent of rated working pressure ; (4) if BOP sealing ram type equipment has been used, it t be pressure tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-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 exclusive of blind rams rust 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 ri s~~t b performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; blind rams rest be function tested at least every thirty days; ~~ (6) test results ~zfst be recorded as part of the daily record required by 20 AAC 25.070(1); ~ ~ ~ ,~ ~ ~ ,~ (7) at least 24 hours~notice of each function pressure test r~dst be provided~so that a representative of the commission can witness the test. Register 200_ MISCEL~OUS BOARDS • ... .5~` (g) Instances of BOPE use to prevent the flow of fluids from a well rry~t be reported to the commission within 24 hours of use.. (Eff. 11 /7/99, Register 152; am / / , Register _) ~'~~~- Authority: AS 31.05.030 4 Register ~ 2004 MISCELLANEOUS BO~ 20 AAC 25.035 (e)(10) is repealed and readopted and a new paragraph is added to read. (10) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a well classified as "development" or "ser- vice", and unless the Commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to ex- ceed fourteen days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (B) when installed, repaired, or changed on a well classified as "exploratory" or "strati- graphic test", and at least once a week thereafter, BOPE, including kelly valves, emer- gency valves, and choke manifolds, must bepressure-tested to the required working pres- sure specified in the approved Permit to Drill, using anon-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, it must be pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit 1 Register ~ 2004 MISCELLANEOUS BO~ to Drill, using anon-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 exclusive of blind rams must be function tested weekly 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 per- formed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; blind rams must be function tested at least every thirty days; (E) BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1); (F) at least 24 hours notice of each BOPE pressure test must be provided so that a com- mission representative can witness the test; (11) instances of BOPE use to prevent the flow of fluids from a well must be reported to the commission within 24 hours of use. 2 Register • 2004 MISCELLANEOUS BO~ 20 AAC 25.036(d) is repealed and readopted and a new subsection is added to read. (d) A BOPS assembly must be tested as follows: (1) when installed, repaired, or changed on a well classified as "development" or "ser- vice", and unless the Commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to ex- ceed fourteen days thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested to the required working pressure specified in the ap- proved Permit to Drill, using anon-compressible fluid, except that an annular type pre- venter need not be tested to more than 50 percent of its rated working pressure; (2) when installed, repaired, or changed on a well classified as "exploratory" or "strati- graphic test", and at least once a week thereafter, BOPE, including emergency valves, and choke manifolds, must be pressure tested to the required working pressure specified in the approved Permit to Drill, using anon-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 well- head pressure after each installation of the well control equipment and before wellbore entry, except that if testing against the annular type preventer, pressure testing need not exceed 50 percent of the rated working pressure of the annular type preventer; 1 Register • 2004 MISCELLANEOUS BO~ (4) if BOP sealing ram type equipment has been used, it must be pressure tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-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 exclusive of blind rams 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; blind rams must be function tested at least every thirty days; (6) test results must be recorded as part of the daily record required by 20 AAC 25.070(1); (7) at least 24 hours notice of each function pressure test must be provided so that a rep- resentative of the commission can witness the test. (g) Instances of BOPE use to prevent the flow of fluids from a well must be reported to the commission within 24 hours of use. 2 Register , 200_ • MISCELLANEOUS BOARDS 20 AAC 25.035(e)(10) is repealed and readopted and a new paragraph is added to read: (10) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a well classified as "development" or "service" and, unless the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to exceed each fourteen days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be pressure- tested to the required working pressure specified in the approved Permit to Drill, using anon- compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (B) when installed, repaired, or changed on a well classified as "exploratory" or "stratigraphic test" and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon-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, it must be 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 exclusive of blind rams must be function-tested weekly 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; blind rams must be function-tested at least every thirty days; (E) BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1); (F) at least 24 hours prior notice of each BOPE pressure test shall be provided to the Register , 200_ • MISCELLANEOUS BOARDS commission so that a commission representative can witness the test; (11) instances of BOPE use to prevent the flow of fluids from a well must be reported to the commission within 24 hours of use. (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 / / ,Register ) Authority: AS 31.05.030 20 AAC 25.036 (d) is repealed and readopted and a new subsection is added to read: (d) A BOPE assembly must be tested as follows: (1) when installed, repaired, or changed on a well classified as "development" or "service" and. unless the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to exceed each fourteen days thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (2) when installed, repaired, or changed on a well classified as "exploratory" or "stratigraphic test" and at least once a week thereafter, BOPE, including emergency valves, and choke manifolds, must be pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon- 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 BOP sealing ram type equipment has been used, it must be pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon- compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its Register , 200_ • MISCELLANEOUS BOARDS rated working pressure; (5) BOP ram and annular components exclusive of blind rams 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 shall be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; blind rams must be function-tested at least every thirty days; (6) test results shall be recorded as part of the daily record required by 20 AAC 25.070(1); (7) at least 24 hours prior notice of each function pressure-test shall be provided to the commission so that a representative of the commission can witness the test. (g) Instances of BOPE use to prevent the flow of fluids from a well must be reported to the commission within 24 hours of such use. (Eff. 11/7/99, Register 152; am / / ,Register -) Authority: AS 31.05.030 3 Register 2~ MISCELLANEOUS BOA 20 AAC 25.035(e)(10) is repealed and readopted and a new paragraph is added to read: (10) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a well classified as "development" or "service" and, unless the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to exceed each fourteen days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be pressure- tested to the required working pressure specified in the approved Permit to Drill, using anon- compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (B) when installed, repaired, or changed on a well classified as "exploratory" or "stratigraphic test" and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon-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, it must be 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 exclusive of blind rams must be function-tested weekly 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; blind rams must be function-tested at least every thirty days; (E) BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1); (F) at least 24 hours prior notice of each BOPE pressure test shall be provided to the Register ~ MISCELLANEOUS BOA commission so that a commission representative can witness the test; (11) instances of BOPE use to prevent the flow of fluids from a well must be reported to the commission within 24 hours of use. (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 / / ,Register ) Authority: AS 31.05.030 20 AAC 25.036(d) is repealed and readopted and a new subsection is added to read: (d) A BOPE assembly must be tested as follows: (1) when installed, repaired, or changed on a well classified as "development" or "service" and. unless the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to exceed each fourteen days thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (2) when installed, repaired, or changed on a well classified as "exploratory" or "stratigraphic test" and at least once a week thereafter, BOPE, including emergency valves, and choke manifolds, must be pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon- 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 BOP sealing ram type equipment has been used, it must be pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon- compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its 2 Register ~ MISCELLANEOUS BOA rated working pressure; (5) BOP ram and annular components exclusive of blind rams 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 shall be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; blind rams must be function-tested at least every thirty days; (6) test results shall be recorded as part of the daily record required by 20 AAC 25.070(1); (7) at least 24 hours prior notice of each function pressure-test shall be provided to the commission so that a representative of the commission can witness the test. (g) Instances of BOPE use to prevent the flow of fluids from a well must be reported to the commission within 24 hours of such use. (Eff. 11/7/99, Register 152; am / / ,Register -) Authority: AS 31.05.030 3 Register 2~ MISCELLANEOUS BOA 20 AAC 25.035(e)(10) is repealed and readopted and a new paragraph is added to read: (10) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a well classified as "development" or "service" and, unless the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPS performance, at time intervals not to exceed each fourteen days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be pressure- tested to the required working pressure specified in the approved Permit to Drill, using anon- compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (B) when installed, repaired, or changed on a well classified as "exploratory" or "stratigraphic test" and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon-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, it must be 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 exclusive of blind rams must be function-tested weekly 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; blind rams must be function-tested at least every thirty days; (E) BOPE test results must be recorded as part of the daily record required by 20 AAC 25.070(1); (F) at least 24 hours prior notice of each BOPE pressure test shall be provided to the Register ~ MISCELLANEOUS BOA commission so that a commission representative can witness the test; (11) instances of BOPE use to prevent the flow of fluids from a well must be reported to the commission within 24 hours of use. (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 / / ,Register _) Authority: AS 31.05.030 20 AAC 25.036(d) is repealed and readopted and a new subsection is added to read: (d) A BOPE assembly must be tested as follows: (1) when installed, repaired, or changed on a well classified as "development" or "service" and. unless the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to exceed each fourteen days thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (2) when installed, repaired, or changed on a well classified as "exploratory" or "stratigraphic test" and at least once a week thereafter, BOPE, including emergency valves, and choke manifolds, must be pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon- 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 BOP sealing ram type equipment has been used, it must be pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon- compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its Register 2~ MISCELLANEOUS BOA rated working pressure; (5) BOP ram and annular components exclusive of blind rams 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 shall be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; blind rams must be function-tested at least every thirty days; (6) test results shall be recorded as part of the daily record required by 20 AAC 25.070(1); (7) at least 24 hours prior notice of each function pressure-test shall be provided to the commission so that a representative of the commission can witness the test. (g) Instances of BOPE use to prevent the flow of fluids from a well must be reported to the commission within 24 hours of such use. (Eff. 11/7/99, Register 152; am / / ,Register -~ Authority: AS 31.05.030 3 Register 2~ MISCELLANEOUS BOA 20 AAC 25.035(e)(10) is repealed and readopted and a new paragraph is added to read: (10) the BOPE must be tested as follows: (A) when installed, repaired, or changed on a well classified as "development" or "service" and, unless the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to exceed each fourteen days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be pressure- tested to the required working pressure specified in the approved Permit to Drill, using anon- compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (B) when installed, repaired, or changed on a well classified as "exploratory" or "stratigraphic test" and at least once a week thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon-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, it must be 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 exclusive of blind rams must be function-tested weekly 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; blind rams must be function-tested at least every thirty days; (E) BOPS test results must be recorded as part of the daily record required by 20 AAC 25.070(1); (F) at least 24 hours prior notice of each BOPE pressure test shall be provided to the Register 2~ MISCELLANEOUS BOA commission so that a commission representative can witness the test; (11) instances of BOPE use to prevent the flow of fluids from a well must be reported to the commission within 24 hours of use. (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 / / ,Register ) Authority: AS 31.05.030 20 AAC 25.036(d) is repealed and readopted and a new subsection is added to read: (d) A BOPE assembly must be tested as follows: (1) when installed, repaired, or changed on a well classified as "development" or "service" and. unless the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance, at time intervals not to exceed each fourteen days thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (2) when installed, repaired, or changed on a well classified as "exploratory" or "stratigraphic test" and at least once a week thereafter, BOPS, including emergency valves, and choke manifolds, must be pressure-tested to the required working pressure specified in the approved Permit to Drill, using anon- 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 BOP sealing ram type equipment has been used, it must be pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon- compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its 2 Register 2~ MISCELLANEOUS BOA rated working pressure; (5) BOP ram and annular components exclusive of blind rams 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 shall be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; blind rams must be function-tested at least every thirty days; (6) test results shall be recorded as part of the daily record required by 20 AAC 25.070(1); (7) at least 24 hours prior notice of each function pressure-test shall be provided to the commission so that a representative of the commission can witness the test. (g) Instances of BOPE use to prevent the flow of fluids from a well must be reported to the commission within 24 hours of such use. (Eff. 11/7/99, Register 152; am / / ,Register Authority: AS 31.05.030 3
