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200-054
FROM: Sandra D. Lemke, ATO -704 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Core Photo well list DATE: 11/15/2019 Slope, Name CE1VED 2.ov-os,-1 Cvno4hiilips PJOV 15 2019 3 64 4 (o TRANSMITTAL ,AOCaCC; TO: Meredith Guhl AOGCC 222 W. Th Ave., Suite 100 Anchorage, Alaska 99501 Transmitted: 201 2P-417 Core photos 3 1 4 4 5 )03- 1- 3S-16 Core Photos 31444, ?OJ -C 5q Atlas 1 Core photos 31443 tot -0 15 CD2 -24 Core Photos 3 1 4 4 2 AI' 2 ALI Cirque 3 Core photos - TION 7 - lob - 12 Meltwater North 1 UV WL photos—1r2-5(o(o0 Sl`I(o Shark Tooth 1 Core photos —'I 2 iV49 ,A- C I%`o 1004025$35_Meltwater-N-1.pdf-'_25"Z) 0 1004278632_3S-16.pdf 3 1 4 4 4 OU -0 q DJ 1004282603 Rendezvous-A.pdf 3 1 4 4 6 please promptly sign, scan, and e-mail to Sandra D Lemke(aconocoohi/lioscom Receipt: Date: f I I Alaska/IT-GGRE I Co ocoPhil s Alaska I Office: 907.265.6947, Mobile 907 440.4512 • • A:\Rendezvous tree 2jpg (local) - Microsoft Internet Explorer Page 1 of 1 Kitt, k ' • 3 11 • 1 r CJZ:C aQp_ APR 1 2 2011 8/22/00 9:20:43 AM F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Re: Trailblazer A-I & H-I reviews Subjed: <Rè:.. Trailblazet Â:..l&H-I. .reviews From: John Norman <john_norman@admin.state.ak.us> Date: Tue, 24 Aug 2004 16:39: 18 -0800 To: jim - cowan@dnr.state.ak.us CC: JeffLandry<jefClandry@law.state.ak.us>, Julie Houle <julie_houle@dnr.state.ak.us>, Don Kxouskop<don Jerouskop@dnr.state.ak.us>, Don Brizzolara <don- brizzolara@dnr.state.ak.us>, Howard D Okland <howard - okland@admin.state.ak.us> Jim, In addition to data on the two Trailblazer wells, any additional well data you would like to review will be made available to you provided it is no longer confidential. Does this adequately answer your question? John Jim Cowan wrote: John, I've just received the fax of Conoco's 8/23/04 letter to you requesting, among other things, that Division of Oil and Gas staff not have access to confidential information from other wells in the NPR-A. This comports with our understanding of appeal protocol. However, during our review of well information prior to the initial showing and denial we also reviewed information from the Spark #1, the Moose's Tooth C and the Rendezvous #2 & #A wells and might ask to do so again if our division files for these wells are lacking. We will not seek access to information acquired subsequent to our initial review and decision to deny extended confidentiality for the two Trailblazer wells. Jim Cowan John K. Norman <John Norman@¿admin.state.us> Commissioner Alaska Oil & Gas Ccnservation Commission ;(öQ - (J S'- '1 1 of 1 8/25/2004 8:35 AM FW: Disclosure of 6 CPAI wells approved Subject: FW: Disclosure of 6 CPAI wells approved Date: Thu, 26 Jun 2003 10:16:06 -0800 From: "Jim Cowan" <jc~dnr. state.ak.us> Reply-To: <3im_Cowan~dnr. state.ak.us> To: <sarah_palin@admin.state.ak.us> ,CC: <Steve_Davies@admin.state.ak.us>, <Howard_Okland~admin.state.ak.us>, "Mark D. Myers" <mdm@dnr. state.ak.us>, "Bonnie Robson" <br~dnr. state.ak.us> Sarah, Steve and Howard, As follow-up to the message below, CPAI's land manager confirmed today that the only wells subject to appeal are the two Trailblazer wells. The Nigliq 1 & iA, Spark IA, Moose's Tooth C, Rendezvous A & 2 may be disclosed immediately. Thanks Jim Cowan Manager, Resource Evaluation Division of Oil and Gas 269-8765 ..... Original Message ..... From: Jim Cowan [~.~.~.~..!.J..~.~..~.~.~.~.~.~..~..~.~] Sent: Wednesday, June 25, 2003 4:05 PM To: sarah_palin@admin.state.ak.us Cc: Steve Davies@admin.state.ak.us; Howard Okland@admin.state.ak.us Subject: Disclosure of CPAI Trailblazer A-1 & H-1 wells appealed Sarah, Steve and Howard, The DNR received the anticipated appeal from ConocoPhillips regarding the Division of Oil & Gas' denial of extended confidentiality for data from the Trailblazer A1 & HI wells (NPR-A). That denial was issued on June 5, but release was delayed until tomorrow, June 26, so CPAI could utilize the 20-day notice-of-appeal period to formulate its position. The AOGCC is copied on the appeal letter and may have already have reached you. Consequently, we ask that you do not disclose confidential information and data from these two wells until we notify you that the appeal process is complete. Appeals of the similar denials for the other six wells are also due today, but have not yet been received. If we hear nothing more from CPAI I'll notify you in the morning that you may proceed with their release effective tomorrow, June 26. Thanks Jim Cowan Manager, Resource Evaluation Division of Oil and Gas 269-8765 SCANNED JUL FRANK H. MURKOWSKI GO VERNOR DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS 550 WEST -/.TH AVENUE, SUITE 800 ANCHORAGE, ALASKA 9950'1-3560 PHONE: (907) 269-8800 FAX: (907) 269-8938 CERTIFIED MAIL #7002 0860 0003 3538 7846 RETURN RECEIPT REQUESTED June 5, 2003 Richard P. Mott ConocoPhillips Alaska, Inc. Vice President, Exploration and Land P.O. Box 100360 Anchorage, AK 99501-0360 DECISION OF THE DIRECTOR Re: Request for extended confidentiality Spark lA, Rendezvous A & 2, Moose's Tooth C JUN 0 9 2003 Alaska Oil & Gas Cons. Commission Dear Mr. Mott: JnchoralTo I am responding to your April 10, 2003, letter to Commissioner Irwin in which you requested, on behalf of ConocoPhillips Alaska, Inc. (CPAI) and the working interest owners, extended confidentiality under 11 AAC 83.153 for the Spark lA, Rendezvous A, Rendezvous 2 and Moose's Tooth C well data, reports, and information filed with the Alaska Oil and Gas Conservation Commission (AOGCC). Originally scheduled for release during May 2003, the Division of Oil and Gas (Division) temporarily extended the confidentiality, of this well information until June 6, 2003, to allow CPAI to make a showing that the information is significant for the valuation of unleased land more than three miles from the wells. CPAI presented the information to the Division on May 29, 2003. CPAI requested that the Division authorize extended confidentiality for information derived from these wells until 90 days after the next federal NPR-A oil and gas lease sale (tentatively scheduled for mid-2004) or until the Bureau of Land Management rules that disclosure is appropriate (upon lease expiration or with earlier consent of the lessee), whichever first occurs. As you know, 11 AAC 83.153(a) provides that the commissioner may extend confidentiality for well information if the well is located more that three miles from unleased lands. 11 AAC 83.153(a) states, in part, "The commissioner will, in his or her discretion, extend confidentiality to reports or information required under AS 31.05. 035from a well located more than three miles from any unleased land if the owner of the well from which these reports or information are derived makes a sufficient showing that the reports or #~ormation contain significant information relating to the valuation ofunleased land beyond the three-mile radius." All wells subject to this request are more than three miles from unleased lands. "Develop, Conserve, attd Enhance Natural Resources for Present attd Future Alaskans." Having considered the information provided by CPAI, the request for extended confidentiality of reports and information derived from the referenced wells is denied. The reasons for this denial include, but are not limited to: While information from the wells is significant for evaluation of surrounding leased lands it is not significant for evaluation of unleased lands eight and more miles away and for which the applicant failed to submit bids in the June 2003 NPR-A lease sale. · Information from the Spark 1 well, the "mother" borehole for the Spark 1A sidetrack, has been released to the public. · CPAI disclosed in a press release dated May 21, 2001, that the Spark 1 and lA, Moose's Tooth C and Rendezvous A and 2 wells all targeted the Alpine producing interval and that all encountered oil or gas or condensate in what was believed to be three separate accumulations. · The same press release disclosed test information germane to the Spark 1A and Rendezvous A wells. · Long available to the public are the data and information from exploration wells drilled by the federal government during the U.S. Navy and U.S. Geological Survey NPR-A exploration programs. A number of these wells are located in the unleased areas used by the applicant to justify the requested extension of well confidentiality. Hence substantial information regarding the petroleum potential of these unleased areas already exists in the public record. By copy of this letter I am advising the AOGCC to release reports and information from the Spark lA, Rendezvous A & 2, and Moose's Tooth C wells on Friday, June 6, 2003, upon expiration of the previously granted temporary 45-day extension. A person affected by this decision may appeal it in accordance with 11 AAC 02. Any appeal must be received within 20 calendar days after the date of"issuance" of this decision, as defined in 11 AAC 02.040(d) and (d) and may be mailed or delivered to Mr. Tom Irwin, Co'mmissioner, Department of Natural Resources, 550 W. 7th Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1-907-269- 8918, or sent by electronic mail to d~.~r_appeals~dnr, state.ak.us. This decision takes effect immediately. If no appeal is filed by the appeal deadline, this decision becomes a final administrative order and decision of the department on the 31 st day after issuance. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court. A copy of 11 AAC 02 may be obtained from any regional information o ~ce o f the Department o f Natural Resources. Sincerely, Mark D. Myers Director Cci Sarah Palin, Commission Chair, AOGCC Jeff Landry, Department of Law Mike Kotowski Jim Cowan ALASKA OIL AND GAS CONSERVATION COM~[ISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 16, 2003 Mr. Richard P. Mott Vice President, Exploration and Land ConocoPhfllips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re' Requested notice before disclosure to DNR Dear Mr. Mott: When ConocoPhillips Alaska, Inc. ("ConocoPhillips") submitted to the Commission the data required under 20 AAC 25.071 for wells Spark lA, Moose's Tooth C, Rendezvous A, and Rendezvous 2, you asked the Commission to notify you before the data are disclosed to the Department of Natural Resources ("DNR") or the public. We understand that ConocoPhillips has applied to DNR for extended confidentiality for these wells under AS 31.05.035(c) and 20 AAC 25.537(d). DNR has informed us that it would like to review these well data at the Commission's offices on the afternoon of May 19, 2003, for the purpose of determining whether to grant the application for extended confidentiality. It is our understanding that DNR has the authority to review such confidential well data for that purpose. See 1984 Inf. Op. Att'y Gen. (661-84-0523; July 3); State, Dep't of Natural Resources v. Arctic Slope Regional Corp., 834 P.2d 134 (Alaska 1991). In light of your request that the Commission provide you advance notice in these circumstances, we are providing you this notice as a courtesy. drich, Commissioner Alaska Oil and Gas Conservation Commission CC: Jim Rudd, ConocoPhillips (mailed and faxed) Barbara Fullmer, ConocoPhillips (mailed and faxed) Paul Mazzolini, ConocoPhillips (mailed and faxed) Richard P. Mott, ConocoPhillips (mailed and faxed) John Bridges, Anadarko (mailed and faxed) SD \ RR/jj c Re: [Fwd: Request to inspect NPR-A well data] c6f J°t'/ Subject: Rë:. [Fwd: Requesttöjnsp~çtNJ>R-AwelldatÇ\] From: "Rob Mintz" <Rober(Mitltz@lâwlståtèlâkus> Dnte: TIm, 15 May 2003 16:52:50 -0800 To:~steve_davies@adnriq,.state~ak.t¡~'::":..:": ::" " ,",:" , ", ,~ >'( ",,' ",..", ;:" .. ' """, c, "F' ""J Steve, is this the same thing you e-mailed about yesterday? Subject: Re: [Fwd: RequesttojnspectNPR-A",elldat~] From: "Dan T. SeamollJ1t"<:DaJ1_Sêámount@ãdmiri.statè.akus> Date: '1'hu. 15 May 2003 15:09:54 -0800 , , To: Sarah Palin <sarah"'palin@a~min.stat~.~~ls>.:,~oþ Mjnt?:<Robert~Mint~.@law.state.ak.us> ," CC: RandoJ"ph'A RuedriçJ"i-:::rànd~,;:,riiP,~iéb'@adm" h""i:state.åkuš>,,~.;l~":,,',,"'" , '"::Y:¡":I~'3;:-;'!",:;i";",;,,,,,,~";)';;:ì',,: ,," ' ""....,.. ,./'-,.,'1[.,.." "'" "',.,,'."" """".'.."",._".'"",.",,"",,", , ,,~,:. ':..' ok by me. Sarah Palin wrote: ------------------------------------------------------------------------ Subject: Request to inspect NPR-A well data Date: Wed, 14 May 2003 15:56:52 -0800 From: "Jim Cowan "s..i.c@dc~£.:..§.!...~!:e. a_~.§..?: Reply-To: ~.:ri!!U::,~~~~dn!:...:....st~!:,~.:.-~~~ us> To: .s.~2.E"~~_E~1.~~~ad.!!l.!,~_:,,.f3_t a !:~,:",i3:_~..:_~I_~::: CC: "Mark D. Myers" :::,!!!..d..,~~9,J:1..!:.:_§.~_él..~~~-~!<....:_':1._~?. Good afternoon Sarah. ConocoPhillips Alaska has applied to the Division of Oil and Gas for extensions of the normal 24-month confidentiality period for eight wells, six of which are within the NPR-A. At Mark's request (and as is the Division's normal procedure), ConocoPhillips will be presenting their case to the Division next Wednesday. Inasmuch as the well data are archived only at the AOGCC and in order to prepare for CPAI's showing we would like to review the well data on your premises on the afternoon of Monday, May 19. This is to avoid having only the applicant's "spin" on the significance of the well data and information when arriving at our determination. This represents a rather recent and advantageous change in protocol between our two agencies and is the result of consultations between our respective attorneys, Mintz and Landry. I believe it's the first opportunity we've had to take advantage of it. With your approval I'll work out the details with Steve Davies. The wells of interest, but for which we have no information, are: Trailblazers A-I & H-l Spark lA Moose's Tooth C Rendezvous A Rendezvous 2 Nigliq 1 & lA are also on CPAI's list, but we have all appropriate data for those and need not review AOGCC files. Thanks for your help. Jim Cowan Manager, Resource Evaluation State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Ave., Suite 800 Anchorage, AK 99501-3510 lof2 8/11/20044:59 PM Re: [Fwd: NPRA wells in question are. . .] Subject:. R.~:IFwg:NPR.A Wt1l1s'ihqÜêstionare;i;:',:] From: "Rob Mintz" <Rober(Mintz@law.state.ak.us> Date: Wed, ,14 May 2003 15:44:28~0800 To: <steve_davies@ad",iiuitat~~ak.us>'!.';', . """. . . . What's the deal with CPAI "showing" to Mark? I am guessing that means CPAI has requested that DNR grant extended confidentiality for these wells and that they are approaching the end of their two-year confidentiality period. If that is the case, and the purpose of the review requested by Jim Cowan is to assist Mark in making the determination whether to grant CPAI's request, then I don't see a problem. Otherwise we should talk about it. Steve Davies <steve davies@admin.state.ak.us> 05/14/03 . -----.-----"--- 03:15PM »> Rob: Jim Cowan wells as described their staff to requests to view all files related to conhfidential below. Do we have an agreement with DNR that allows view confiedntial data? Thanks, Steve Davies 793-1224 ] of] An ,':; ."'.>' vJ ~ t: 1-'><1 ". : . . "'. " , . :; ",\ .'- .'. 8/] ]/2004 4:58 PM Re: NPRA wells in question are. . . SlIbject: Re: NPRA wells in qucstion are. . . From: Steve Davics <slcvc_davics@admin.state.ak.us> Date: Wcd, 14 May 2003 15: 17:31 -0800 ro:)iih_Ç()~an@dn~.state.~".us,,¡;;:~>;;~,!, ,::~fi¡i~;!!!:,;j':i':',;:'~f;:!>::".:,.' ."', ' c;;1-t~'(,. i/5. f ' . ':: jiL': ":::,;:,.~';:':!":::,t~:~,:~'.::,'.",;;~J!/,~.¡,i;i:~~¡¿,:i:L;;~::t.;:,:~>1~~,:,~!e:r,,) Jim: A formal request though Sarah Palin is the proper procedure. I have a call in to Rob Mintz about this. I have booked the small conference room for next Monday afternoon for your use if the request is approved. I'll let you know what Rob says. Steve D. Jim Cowan wrote: Trailblazers A-I Spark lA Mooses's Tooth C Rendezvous A Rendezvous 2 & H-l I'd like to bring Krouskop, Brizzolara and Houle over about 1:30 Monday afternoon, 5/19. for a quick cruise though the well files. We don't want to take anything away except our notes so would just like a room to work in that afternoon. CPAI is making their "showing" to Mark about 11:30 Wednesday morning. What's the proper protocol? Handle it through you, Jack and Tom or submit a more formal request through the Ms. Palin? Jim Cowan 269-8765 1 of I 8/11/20044:58 PM [Fwd: NPRA wells in question are. . .] SubjeCt: [F\vd: NPRA wetls in question From: Steve Davies <steve_davies@aJmin.statc.ak.us> Dnte: Wed, 14 May 200315:15:18 -0800 . ~ro; Rob Miilt,Z' <R9b~rt~ Min~låw .s~~te~ak¡ uk::.: d ot-:' - (J'i"y ..(Ii:í..,!.'.:, .\>, ";...'..:.'t"':;~r':'¡},::,;ít Rob: Jim Cowan requests to view all files related to conhfidential wells as described below. Do we have an agreement with DNR that allows their staff to view confiedntial data? Thanks, Steve Davies 793-1224 Subject: NPRA wells in question are From: "Jim Cowan" <jc@dnr.stute.ak.us> Date: Wed, 14 May 2003 13:56:30 -0800 ",," ',,' ,"" '.' ' To: '<steye - davies@~~min.'state.ak1l.s?:'\'Òí.:i;~!ii~;,:i:.¡*~~i:¡';:::;i:"'!~:!i!';" ,:.::. '~:':;I>::""i;<~:'Y': ..:i'":.:-:" iH;'.:: :, ", ,-"',.' , ','" , .-',~ ,"" .. . ., Trailblazers A-I Spark lA Mooses's Tooth C Rendezvous A Rendezvous 2 & H-l I'd like to bring Krouskop, Brizzolara and Houle over about 1:30 Monday afternoon, 5/19, for a quick cruise though the well files. We don't want to take anything away except our notes so would just like a room to work in that afternoon. CPAI is making their "showing" to Mark about 11:30 wednesday morning. What's the proper protocol? Handle it through you, Jack and Tom or submit a more formal request through the Ms. Palin? Jim Cowan 269-8765 wells in question are. . Content-Type: message/rfc822 Content-Encoding: 7bit lofl 8/1 ]/2004 4:57 PM NPRA wells in question are. . . Datè: 14 Ma:y200313:56:30 :r ~ ~'~iéye~ ~à~es@~4m!,ri&t~~~\i1k; ~~:'.;>.i, ,,:::~~ ::I: ;;i:ri¿)['i:~;~~'¡:~:;~~iL,': >~~tt",>;::!;.¡.',~, .;¡:;:j Trailblazers A-I Spark lA Mooses's Tooth C Rendezvous A Rendezvous 2 & H-l I'd like to bring Krouskop, Brizzolara and Houle over about 1:30 Monday afternoon, 5/19, for a quick cruise though the well files. We don't want to take anything away except our notes so would just like a room to work in that afternoon. CPAI is making their "showing" to Mark about 11:30 Wednesday morning. What's the proper protocol? Handle it through you, Jack and Tom or submit a more formal request through the Ms. Palin? Jim Cowan 269-8765 1 of 1 8/11/20044:)7 PM FRANK H. MURKO I,'VSKI GO VERNOR DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS CERTIFIED MAIL #7002 0860 0003 3538 7778 RETURN RECEIPT REQUESTED 550 WEST 7TM AVENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE:(907) 269-8800 FAX: (907) 269-8938 April 21, 2O03 Richard P. Mott ConocoPhillips Alaska, Inc. Vice President, Exploration and Land P.O. Box 100360 Anchorage, AK 99501-0360 DECISION OF THE DIRECTOR Re: Requests for Extension of Confidentiality under 11 AAC 83.153 Nigliq 1 Nigliq lA Trailblazer A-1 Trailblazer H- 1 Spark lA Moose's Tooth C Rendezvous A Rendezvous 2 50103203700000 50103203700100 501032036400 501032036900 501032031301 501032031500 501032031600 501032036300 I am responding to your letters of April 9 and 10, 2003, requesting extended confidentiality under 11 AAC 83.153 for well data, reports and information generated from the eight referenced wells and filed with the Alaska Oil and Gas Conservation Division (AOGCC)under AS 31.05.035. For wells more than three miles from unleased land, as is the case here, 11 AAC 83.153(a) grants the commissioner discretionary authority. 11 AAC 83.153(a) states, in part, "The commissioner will, in his or her discretion, extend confidentiality to reports or information required under AS 31.05.035 from a well located more than three miles from any unleased land if the owner of the well from which these reports or information are derived makes a sufficient showing that the reports or information contain significant information relating to the valuation of unleased land beyond the three-mile radius." Inasmuch as all wells are more than three miles from unleased lands, confidentiality for the eight referenced wells is extended for only 45 days from this date (through June 5, 2003) during which time the Division of Oil and Gas will require a showing to establish the significance of well data from the referenced wells to unleased OCS and NPR-A lands and to state lease ADL 390348 which is due to "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." expire September 30, 2003. The showing should be scheduled prior to May 30, 2003, to allow the Division to make a decision by June 5, 2003, regarding further extension of the confidentiality period. Extended confidentiality for the remaining four wells for which you requested extended confidentiality (Hunter A, 501032040500; Lookout 1,501032035900; Lookout 2, 501032041000; and Mitre 1, 501032040900) will be reviewed prior to their 2004 disclosure dates. Please submit that request on or about March 26, 2004, so that the 'significance of the well information can be evaluated in the context of activities up to that time. By copy of this letter I am notifying the AOGCC of the 30-day extension of confidentiality for the eight referenced wells. A person affected by this decision may appeal it in accordance with 11 AAC 02. Any appeal must be received within 20 calendar days after the date of"issuance" of this decision, as defined in 11 AAC 02.040(d) and (d) and may be mailed or delivered to Mr. Tom Irwin, Commissioner, Department of Natural Resources, 550 W. 7th Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1-907-269- 8918, or sent by electronic mail to dnr_appeals@dnr, state.ak.us. This decision takes effect immediately. If no appeal is filed by the appeal deadline, this decision becomes a final administrative order and decision of the department on the 31st day after issuance. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court. A copy of 11 AAC 02 may be obtained fi.om any regional information office of the Department of Natural Resources. Mark D. Myers Director Cc~ Sarah H Palin, Commission Chair, AOGCC JeffLandry, Department of Law J. R. Cowan, Division of Oil and Gas Permit to Drill 2000540 DATA SUBMITTAL COMPLIANCE REPORT 4115/2003 Well Name/No. RENDEZVOUS A Operator CONOCOPHILLIPS ALASKA INC APl No. 50-103-20316-00-00 MD 8353 'FVD 8353 Completion Dat 4/27/2001 Completion Statu P&A Current Status P&A UIC N REQUIRED INFORMATION Mud Log Sample ~ \/,~ / Directional Survey ~ y/CA.. DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Typ~ Media Fmt Name T Log Log Scale Media ~-'D~p o I e Sonic 5 ~ra Sonic Imager 5 ~Dip-dle Sonic 2 L..1,~t~73 (data taken from Logs Portion of Master Well Data Maint) ~'~NALYSIS ~>I~'EWR4 2/5 ~CNT/SLD 2/5 9660 ~PT LOT 2 2/5 ,~6¢uD 2 ~S'~ressfrac/SER DYN 5 F-.,.~F/SPF 5 Interval Run OH I No Start Stop CH Dataset Received Number FINAL 7500 8186 CH 6/11/2001 FINAL 3000 8190 CH 6/11/2001 FINAL 7450 8150 CH 6/11/2001 Comments _/r .... ~ ,, 7500-8186 ~ 3000-8190 ColQr_print 7450-8150 Color Prin.._.~t FINAL 7500 8186 CH 7/2/2001 70 8090 Open 6/6/2000 122 8344 Open 6/22/2000 7500 8186 Case 7/2/2001 1 OH 6/6/2000 /_.A-e~73 7500-8186, Digital Data 09630~-8090 ;~ c. ~'~ ~39660 122-8344 ~10173 7500-8186 9630~.-.SCHLUM DSI REPROC. 5~ ........... EJ~IAL~-,-437~--~530~.--~CH-~:----,6t27/200e ................ BE(C)'-4370-5530. )~, ff ~ il ~ - / 2 5~ 8065 8124 OH 6/22/2000 CORELAB 8065,1-8124.1 FINAL 0 8353 OH 6/22/2000 0-8353 FINAL 0 8353 OH 6/22/2000 0-8353 I OH 6/22/2000 C,9660 SPERRY DGR/EWR4/CTN/SLD 163 8353 OH 6/6/2000 SPERRY 163-8353. FINAL 62 8098 OH 6~6/2000 BL(C) 62-8098 FINAL 70 8090 OH 6/6/2000 70-8090 FINAL 8085 8164 OH 6/6/2000 8085-8164 FINAL 132 8333 OH 6/6/2000 EPOCH 132-8333 FINAL 7888 8201 CH 6/11/2001 7888-8201 BL, Sepia FINAL 7192 8192 CH 6/11/2001 7192-8192 BL, Sepia Well Cores/Samples Information: Permit to Drill 2000540 DATA SUBMITTAL COMPLIANCE REPORT 4/1512003 Well Name/No. RENDEZVOUS A Operator CONOCOPHILLIPS ALASKA INC APl No. 50-103-20316-00-00 MD 8353 TVD 8353 Completion Dat 4/27/2001 Completion Statu P&A Current Status P&A UIC N Interval Dataset Name Start Stop Sent Received Number Comments Core Chips 8065 8124 / ~ ,~ o~. - ....;i · . j ADDITIONAL INFORMATION Well Cored? ~ N Chips Received? {~ / N Analysis Y~ N R~c.~.ived? Daily History Received? (~/N Formation Tops ~/N Comments: Compliance Reviewed By: Date: NOTE TO FILE Because of the confidential nature of the attached documents, they are to be held in the confidential room until the release of LookOut A, permit number 201-003. The approximate release date of LookOut A is May 4, 2004. Thank You, Lisa Weepie Admin Clerk III Alaska Oil and Gas Conservation Commission. ALASKA OIL AND ~ CONSERVATION COM~IISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 James R. Winegarner District Landman Exploration and Land ConocoPhillips PO Box 100360 Anchorage AK 99510 September 17, 2002 Dear Mr. Winegamer: The Alaska Oil and Gas Conservation Commission ("Commission") has completed an audit of the NPRA wells drilled by Phillips Alaska, Inc. ("Phillips") to v. erify the well status and projected release dates. In letters accompanying data submittals for these NPRA wells, Phillips requested that the Commission provide notice prior to any public disclosure of confidential information so that Phillips might be heard on the issue. Pursuant to AS 31.05.035(c), the data Phillips provided as required by AS 31.05.035(a) will be kept confidential for 24 months following the 30-day filing period unless the owner of the well gives written permission to release the reports and information at an earlier date. The Commissioner of Natural Resources may extend the 24-month period of data confidentiality under certain circumstances. In the case of the Spark IA, Permit to Drill # 200-056, the Department of Natural Resources ("DNR") granted extended confidentiality for the well through September 3, 2002 although the Commission's records indicated that the status of this well is "Operation Shutdown". An audit of the Commission's records indicates that this status is in error. The Commission has determined that the Spark lA well was in fact completed (equipped and conditioned so that it was capable of producing or injecting fluids) on April 29, 2000 and is therefore subjeCt to release after September 3, 2002. Unless the Commission hears from Phillips before September 20, 2002, the Spark lA file will be released to the public on September 23, 2002. James R. Winegamer September 17, 2002 Page 2 of 2 The following is a list of Phillips' NPRA wells that have projected release dates. Rendezvous A PTD # 200-054 5/27/03 Lookout 1 PTD # 201-003 5/4/04 Rendezvous 2 PTD # 201-007 5/28/03 Hunter A PTD # 202-013 4/26/04 Mitre 1 PTD # 202-026 5/21/04 Lookout 2 PTD # 202-027 6/5/04 Mooses Tooth C PTD # 201-049 5/6/03 If you have any questions about these release dates, please contact Steve Davies at 793- 1224. Although it has been the practice of the Commission to publish well data release dates in advance on its website, it is the operator's or owner's responsibility to make a timely application to the Department of Natural Resources in the event that extended confidentiality is desired. You should not rely on receiving any reminders from the Commission regarding the release dates for these wells. Sincerely, Cammy Oechsli Taylor Chair COT:\jjc cc: Mark Meyers, DOG Permit to Drill No. 2000540 DATA SUBMITTAL COMPLIANCE REPORT 5/20/2002 Well Name/No. RENDEZVOUS A Operator PHILLIPS ALASKA INC. AP1 No. 50-103-20316-00-00 MD 8353 TVD 8353 Completion Date 4/27/2001 Completion Status P&A Current Status P&A UIC N REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Lo~/ Data Digital Digital Type Media Format Name Directional Survey Mo- Mud Log L Dipole Sonic---''''~ R CORE ANALYSI~''''''~ L Ultra Sonic Imag '--'"'~" 5 L DGPJEWR~- 25 ...--L-~-SGMT- L PERF/SPF'~ ~_ 5 L DSI QC-PLOT~'' 2 L DGR/CNT/SLD-..'~- 25 (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Scale Media No Start Stop CH Received Number Comments O 67672000 09630/,'~ 70-8090 FINAL 7450 8150 CH 6/11/2001 Color Print 1 8124 OH 6/22/2000 CORELAB 8065..1 C 7/2/2001 10173/--"~7500-8186 FINAL 3000 8190 CH 6/11/2001 Color Print FINAL 0 8353 OH 6~22/2000 L DSI _? L RFT L MUD / L Stressfrad SER L Dipole Sonic 5-~--~------~t~-4~70------5530 .... CFF ..... 6727/2000 ........... -BLOC) ...... ?'~-~'~ FINAL 7192 8192 CH 6711/2001 BL, Sepia FINAL 62 8098 OH 676/2000 BL(C) FINAL 0 8353 OH 6/22/2000 /, O 6/22/2000 09660 "~ 122-8344 FINAL 70 8090 OH 6/6/2000 FINAL 8085 8164 OH 676/2000 FINAL 132 8333 OH 6/6/2000 EPOCH FINAL 7888 8201 CH 6711/2001 BL, Sepia FINAL 7500 8186 CH 6711/2001 - 25 2 5 5 Core Chips Interval Start Stop 8065 8124 Dataset Sent Received Number Comments 1039 ADDITIONAL INFORMATION DATA SUBMITTAL COMPLIANCE REPORT 5/20/2002 Permit to Drill No. 2000540 Well Name/No. RENDEZVOUS A Operator PHILLIPS ALASKA INC. MD 8353 TVD Well Cored? & N Chips Received? ~ N Analysis Received? ~)/N 8353 Completion Date 4/27/2001 Completion Status P&A Daily History Received? Current Status Formation Tops Receuived? ~Y~ N AP1 No. 50-103-20316-00-00 P&A UIC N Corn ments: Compliance Reviewed By: Date: N~Y 13 ~02 0g:33~M ST-P~ DM~ N~TE~ gO? DEPARTMENT O~ NATURAL RESOURCES DIVI$10N OF Oil. AND GAS TONY KNO WLES, GOVERNOR SBO WEST 'i'm AVENUE, SUITE ~00 , ANOHOFtAeE, ALASKA or)SOl-3$10 PHONE: (g07) FAX: (;07) CER~D MAIL ~099 3220 0004 9021 6659 RETURN RECEIPT REQUESTED May 10, 2002 Richard P, Mort Vice President ... Exploration and Land Phillips Alaska, he,' ..................................................... P,O. Box 100360 Anchorage, Alaska 99510-0360 DECISION OF TIlE DIRECTOR Re: ~Request for Extension of Confidentiality under 11 AAC 83,153 ' Spark 1 API #501032031300 Rendezvous 2 APl #501032036300 I Spark IA API #501032031301 Lookout 1 API #$01032035900" Rendezvous A APi #501032031600 Moose's Tooth C API #501032031500 k Clover A API #501032031000 I am responding to your March 22, 2002, letter requesting extended confidentiality under 11 AAC 83.153 for well data, reports, and information generated from seven NPR-A wells, and. ti. ed with the Alaska Oil and Gas Conservation Commission under AS 31.05,035. Based on your presentation to the Division on May 8, 2002, I extend the confidentiality time period for the data, reports, and information generated from four of the seven wells listed in Attachment A to your !otter, This extension is granted based on the significance of the well information to evaluation of unleased acreage which will be offered for sale by the Bureau of Land Management's NPR-A sale now scheduled for June 3, 2002. No future extensions will be granted for these wells, The information generated from the other three wells---Rendezvous 2, Lookout 1, and Moose's Tooth C--does not become public under AS 31.05,035 until the middle of next year, so I am not extending the confidentiality time period for that information at this time, This confidentiality extension for the information from these four wells is through September 3, 2002, 90 days after the Bureau of Land Management's NPR-A lease sale scheduled for ~une 3, 2002. "Develop~ Conserve, and Enhance Natural Resources for Present and Future Alaskan.,,." By copy of this letter, I am notifying AOGCC of the extended confidentiality granted these wells, A person affected by this decision may appeal it in accordance with 11 AAC 02. Any appe.~l must be received within 20 calendar days after the date of "issuance" of this decision, as defi~ed in 11 AAC 02.040(c) and (d) and may be mailed or deli'~ered to Pat Pourehot, Commissioner, Department of Natural P. esources, 550 W. 7~ Avenue, Suite la00, Anchorage, Alaska 99501; faxed to 1-907-269- 8918, or scut by electronic mail to d__ur, ap. pea!a@.dx~r, state,ak.us, This decision takes effect immediately. If no appeal is filed by the appeal deadline, tl~s decision becomes a final adm.~nistrative order and decision of the department on the 31~t day after issuance. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appeal, lng thi. s decision to Superior Court. A copy of 11 AAC 02 may be obtained from any regions}, i,fonuat~on office of the Department of Natural Resources. Mark D, Myers Director Daniel Seamount, Commissioner, AOGCC Cammy Taylor, Commissioner, AOGCC Jeff Landry, Dept, of Law Don Brizzolara, DO&G MAY 13 '02 09:B~M ST-~P~/ DMR WATER Department of Natural Resource Division of Oil & Gas 550 West 7!t~ Avenue, Suite 800 Anchorage, AK 99501-3560 (907) 269-8942 TO: COMPANY: FROM: Number of pageg In=furling cover sheet: ~'~' [] For Review D Plea,e Comment i~i A~ Ynu Requtsled D t~! C',~Users~Kld~nx Form,doC 09/! 7/O 1 RECEIVED AiaskeOii& Gas Cons. Commieaion Anchorege PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 TO: AOGCC 333 WEST7TH ANCHORAGE, AK. ATTN:BOBCRANDALL DATE: APRIL 12, 2002 AIRBILL: 5131166 AFT#: PBV02-04-11-01 CHARGE CODE: 42374 OPERATOR: Phillips Alaska, Inc. SAMPLE TYPE: DRY NUMBER OF BOXES: 9 BUNDLES NAME: SAMPLES SENT: · ..,ONE COMPLETE SET OF DRY CUTTING AS RECEIVED FROM~,¢[_~. ~?~-~THE RIG ~2.,,.~O ,,-, O,1"l' S P A R K 1 '--"---~O'"1 f.¢ 100'-8850' "~'~- O~%SPAR K 1A ),,.~-~"'~ RENDEZVOUS A %~1 -b~"'/RENDEZVOUS 2 ~O~- 00"], LOOKOUT 1 ~,.t~1~-' O"iff MOOSES TOOTH C ~1~,3~-O~) HUNTER A b~¢ITRE 1 ;;Z02..- ~ LMITRE PB1 ~. bt~'"? CLOVER A 3350'-8522' 250'-8333' ~%0'-8651' l~ 2. 120'-8350' 16,~ 170'-8738' .,/0 ,~ i~ 100'-9600' I O~') ~.80'-~090', 587O -8240 [ b"/I 100'-8570' UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND SEND A SIGNED COPY OF THIS TRANSMITTAL TO: RECEIVED BY: D. GARRARD G. WILSON R. CRANDALL /'~" PAl PAl AOGCC Phillips Alaska Inc. BAYVIEW GEOLOGIC FACILITY P. O. BOX 100360 ANCHORAGE, AK. 99510-0360 ATTN: D. L. Przywojski ABV-100 DATE: o oa-oS / PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY EXPLORATION & LAND P.O. BOX 100360 ANCHORAGE, ~',LASKA 99510-0360 PHONE (907) 253-4556 FACSIMILE (907) 265-6339 Richard P. Mott Vice President March 22, 2002 Pat Pourchot, Commissioner State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Ave., Suite 1400 Anchorage, AK 99501-3510 RECEIVED APR 2002 Re.' Request for Extension of Confidentiality Alaska Statute 31.05.035 & Regulation 11 AAC 83.153 Phillips Alaska, Inc. ("PAl"), as operator for and on behalf of the working interest owners ("Lessees") of the wells listed in Attachment A hereto ("NPRA Wells"), hereby respectfully requests extended confidentiality for the reports and information generated from the NPR-A Wells and filed with the Alaska Oil and Gas Conservation Commission as required by state law ("Data"). All of the NPR-A Wells are located on federal lands located within the NPR-A. The Lessees make this request for the following reasons: (1) this Data is important to the Lessees in evaluating acreage in future federal oil and gas lease sales in the NPR-A; and (2) the Data for the NPR-A Wells is protected from public disclosure under federal law and state law. First, the Data from the NPR-A Wells contain significant proprietary and sensitive information relating to the valuation of unleased land within the NPR-A. Disclosing the Data to the public would cause financial harm to the Lessees because additional leasing of lands in the NPR-A will probably take place in the future. An EIS is currently underway for the planning of a federal oil and gas lease sale in the western NPR-A. Due to the remoteness of the lands that could be leased in the NPR-A and the restrictiveness of protections already in place for exploration and development of the leased lands within the NPR-A, disclosure of Data to the public about what the furore potential for development for the currently leased lands, which Data was obtained at the sole risk and expense of the Lessees, would be detrimental to the Lessees' competitive position in NPR-A. Second, the Data is protected from disclosure under federal law. Federal statute 5 USC 552(b)(9) exempts "geological or geophysical information and data, including maps, concerning wells" from the right of public inspection and disclosure provided in the Freedom of Information Act at 5 USC 552(a). The NPR-A lease terms under which Lessees leased the lands on which the Wells were drilled states as follows: During existence of this lease, information obtained under this section [section 5] shall be closed to inspection by the public in accordance with the Freedom of Information Act (5 U.S.C. 552). Pat Pourchot, Commissioner State of Alaska, DNR March 22, 2002, Page 2 Paragraph 2, Section 5, NPR-A Lease Form, a copy of which is attached hereto as Attachment B. When a record is protected under federal law, it is also protected under Alaska law. Pursuant to AS 40.25.120(a)(4), a record required to be kept confidential by federal law or regulation is not available for public inspection. The focus of the provision for release of well data after two years under AS 31.05.035 appears to be data taken on state lands, not federal lands over which the Department of Natural Resources does not have jurisdiction. Because the Data is protected from disclosure by federal and state law, the commissioner should extend the confidential status of the Data. If you have any questions or require any additional information, please call me or Mr. Jim Winegamer at 265-6914 and we will arrange a meeting to review this request in more detail. Sincerely, Richard P. Mott Vice President Exploration and Land RPM:JPW Cc: U.S. Department of Interior Bureau of Land Management 6881 Abbott Loop Road Anchorage, AK 99507-2591 Attn: Peter Ditton, Field Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ~t~: Cammy Taylor, Chairman Anadarko Petroleum Corporation 3201 C Street, Suite 603 Anchorage, AK 99503 Atto: John A. Bridges, Land Supervisor, Alaska State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Ave., Suite 800 Anchorage, AK 99501-3510 Attn: Mark Myers, Director Pat Pourchot, Commissioner State of Alaska, DNR March 22, 2002, Page 3 Attachment A Extended Confidentiality Requested for the following NPRA Wells Spark 1 Spark lA Rendezvous A API# 501032031300 API# 501032031301 API# 501032031600 05.13.02 Data Release Date 07.01.02 Data Release Date 06.03.02 Data Release Date Clover A API# 501032031000 05.22.02 Data Release Date Rendezvous 2 APl # 501032036300 05.30.03 Data Release Date Lookoutl API# 501032035900 06.01.03 Data Release Date Moose's Tooth C APl # 501032031500 07.01.03 Data Release Date · ( ~,ttatchment B ' aNITED STATES DEPA R ~MENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT ALASKA STATE OFFICE OFFER TO LEASE AND LEASE FOR OIL AND GAS Serial No. AA--081819 The undersigned (reverse) offers to lea.~e all or any of the lands in Item 2 that are available for lease pursuant to the Mineral Leasing Act of 1920, as amended and supplemented (30 U.S.C. 181 et seq.), the Mineral Leasing Act for Acquired Lands of 194'/, as amended (30 U.S.C. 351-359), the Attorney General's Opinion of April 2, 1941 (40 Op. Atty. Gen. 41), or the Naval Petroleum Reserve Production Act of 1976 (42 U.S.C. 6501 et seq.), as amended. 1. Name Street READ INSTRUCTIONS BEFORE COMPLETING ARCO Alaska Inc. (78%) P.O. Box 100360 Anchorage, Alaska 99510 and Anadarko Petroleum Corporation (22%) P.O. Box 1330 Houston, Taxes 77251 City, State, Zip Code 2. This application/offer/lease is for Public Domain Lands in the National Petroleum Reserve - Alaska (NPR-A) Legal description of land requested: *Tract No.: 99 l-H-070 *SEE INSTRUCTIONS BELOW PRIOR TO COMPLETING PARCEL NUMBER AND SALE DATE T. R. Meridian State TllN, R2E Umiat SE 1/4 Amount remitted: Filing fee $ Rental fee $ 28,780.00 DO NOT WRITE BELOW THIS LINE *Sale Date (m/d/y): May / 05 / 1999 County Total acres applied for 5,756 Total $ 3. Land included in lease: T. R. TllN, R2E SE 1/4 Meridian Umiat State County Tom ac~s in ~ 5,756 Rental retained$ 28,780.00 This lease is issued granting the exclusive right to drill for, mine, extract, remove and dispose of all the oil and gas (except helium) in the lands described ia Item 3 together with the right to build and maintain necessary improvements thereupon for the term indicated below, subject to renewal or extension in accordance with the appropriate leasing authority. Rights granted am subject to applleable laws, the terms, conditions, and attached stipulations of this lease, the Secretary of the Interior's regulations and formal orders in effect as of lease issuance, and to regulations and formal orders hereafter promulgated when not inconsistent with lease rights granted or specific provisions of this lease. NOTE: This lease is issued to the high bidder pursuant to his/her duly executed bid or nomination form submitted under 43 CFR Part 3130 and is subject to the provisions of that bid or nomination and those specified on this form. 'l'he pttrties agree ~1) that this lease form replaces the previous lease form executed by the parties for this lease; ~2) that this lease will be deemed to ]]ave been issued pursuant to this lease roma; (3) that this lease will be deemed to have been executed as of the original date each party cxeculcd the previous lease form: and (4) thal the effective date of this lease is September l. 1999. TI-I]E UNITED STATES OF AMERICA Type and primary term of lease: by [ ] Noncompetitive lease (ten years) [ ] Competitive lease (ten years) [ X ] Other Competitive NPR-A Lease (ten veers) \% .r-'w'., .._,-,-.'_, ~/\ ~... · (Signing Officer) . Sr. Leasable Minerals Adjudicator.. i 90?'''~,...,.',,_'. (Title) (Date) EFFECTIVE DATE OF LEASE September 1, 1999 AK-B130-1 (April 1999) 4. (a) Undersigned certifies that (1) offeror is a citizen of the ' States: an association of such citizens; a municipality; or a corp_~f' ,organtzea uncler the laws of the United States or of any State or TerritOry thereof; (2) all parties holding an interest in the offer I[ ,.~ompliance with 43 CFR Part 3100 and the leasing authorities: (~ _.,/or is not considered a minor under the laws of the State in which the lands covered by this offer are located. (b) Undersigned agrees that signature to this offer constitutes acceptance of this lease, including all terms, conditions, and stipulations of which offeror has been given notice, and any amendment or separate lease that may include any land described in this offer open to leasing at the time this offer was filed but omitted for any reason from this lease. The offeror further agrees that this offer cannot be withdrawn, either in whole or in part. This offer will be rejected and will afford offeror no priority if it is not properly completed and executed in accordance with the re~lations, or if it is not accompanied by the required payments. 18 U.S.C. Sec. 1001 makes it a crime for any person knowingly and willfully to make to any Department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. NOTICE The Privacy Act of 1974 and the regulations at 43 CFR 2.48(d) provide that you be furnished with the following information: AUTHORITY: 50 Stat. 900:25 U.S.C. 500 PRINCIPAL PURPOSE: The primary uses of the records are (I) to determine your qualification to receive an oil and gas lease: and (2) to provide information concerning oil and gas leases for administrative and public use. ROUTINE USES: BLM and the Department of the Interior (DOB may disclose your information on this form: (1) to members of the public who have a need for the information that is maintained by BLM for public record; (2) to the U.S. Department of Justice, court, or other adjudicative body when DOI determines the information is necessary, and relevant to litigation: (3) to appropriate Federal, State, local or foreign agencies responsible for investigating, prosecuting violations, enforcing or implementing this statute, regulation, or lease: and (4) to a congressional office when you request the assistance of the Member of Congress in writing. EFFECT OF NOT PROVIDING THIS INFORMATION: If you do not furnish all the information required by this form, your application may be rejected. Duly executed this day of ,19 SEE ATTACHED SIGNATORY PAGE(S) (Signature of Lessee or Attorney-in-fact) LEASE TERMS Sec. 1. Rentals - Rentals shall be paid to the proper office of lessor in advance of each lea.se year. Annual rental rates per acre or fraction thereof are: (a) Noncompetitive lease, $1.50 for the first 5 years; thereafter $2.00; (b) Competitive lease, $1.50; for the leu'st 5 years; thereafter $2.00: (c) Other, see attachment; or for NPR-A: $5 for Area A; $3 for Area B; as specified in the detailed statement of sale. If this lease or a portion thereof is committed to an approved cooperative or unit plan wi'rich includes a well capable of producing leased resources, and the plan contains a provision for al location of production, royalties shall be paid on the production allocated to this lease. However, annual rentals shall continue to be due at the rate specified in (a), (b), or (c) for those lands not within a pamcipating area. Failure to pay annual rental, within 30 days after receipt of a Notice of Delinquency shall cause this lease to terminate. Rentals may be waived, reduced, or suspended by the Secretary upon a sufficient showing by lessee. Sec. 2. Royalties - Royalties shall be paid to proper office of lessor. Royalties shall be computed in accordance with regulations on production removed or sold. Royalty roles are: (a) Noncomt0etitive lease, 12½%; (b) Competitive lease, 12½ok; (c) Other, see attachment, or for N'PR-A: 16~% for Area A; 12.5% for Area B as specified in the detailed staterr~nt of sale. Lessor reserves the fight to speeff'y whether royalty is to be paid in value or in kind, and the right to establish reasonable minimum values on products after giving lessee notice and an opportunity to be heard. When paid in value, royalties shall be due and payable on the last day of the month following the month in wh/ch production occurred. When paid in kind, production shall be delivered, unless otherwise agreed to by lessor, in merchantable condition on the premises where produced without cost to lessor. Lessee shall not be required to hold such production in storage beyond the last day of the month following the month in which production occurred, nor shall lessee be held liable for loss or destruction of royalty oil or other products in storage from causes beyond the reasonable control of the lessee. Minimum royalty in lieu of rental of not less than the rental which otherwise would be required for that lease year shall be payable at the end of each lease year beginning on or after a discovery in paying quantities. This minimum royalty may be waived, suspended, or reduced, and the shove royalty rates may he reduced, for all or portions of this lease ff the Secretary determines that such action is necessary, to encourage the greatest ultmUate recovery, of the leased resources, or is otherwise justified. An interest charge shall be assessed on late royalty payments or underpayments in accordance with the Federal Oil and Gas Royalty Management Act of 1982 (FOGRMA) (30 U.S.C. 1701). Lessee shall be liable tbr royalty payments on oil and gas lost or wasted from a lease site when such loss or waste is due to negligence on the pan of the operator, or due to the failure to comply with any rules, regulations, order, or citation issued under FOGRMA or the leasing authority. Sec. 3. Bonds - A bond shall be fried and maintained for lease operations as required under regulations. Sec. 4. Diligence, rate of development, unitization, and drainage - Lessee shall exercise reasonable diligence in developing and producing, and shall prevent unnecessary damage to. loss of. or waste of leased resources. Lessor reserves the right to specify rates of development and production in the public interest and to require lessee to subscribe to a cooperative or unit plan, within 30 days of notice, if deemed necessary for proper development and operation of area. field, or pool embracing these leased lands. Lessee shall drill and produce wells necessary to protect leased lands from drainage or pay compensatory royalty for drainage in amount determined by lessor. Sec. 5. Documents, evidence, and inspection - Lessee shall file with proper office of lessor, not later than 30 days after effective date thereofi any contract or evidence of other arrangement for sale or disposal of production. At such times and in such form as lessor may prescribe, lessee shall furnish detailed statements showing amounts and quality of all products removed and sold, proceeds therefrom, and arr~ unt used for production purposes or unavoidably lost. Lessee may be required to provide plats and schematic diagrams showing development work and improven~nts, and reports with respect to parties in interest, expenditures, and depreciation costs. In the form prescribed by lessor, lessee shall keep a daily drilling record, a log. information on well surveys and tests, and a record of subsurface investigations and furnish copies to lessor when required. Lessee shall keep open at all reasonable times for inspection by any authorized officer of lessor, the leased premises and all wells, improvements, rrumhinery, and futtur~s thereon. and all books, accounts, maps. and records relative to operations, surveys, or investigations on or in the leased lands. Lessee shall maintain copies of all contracts, sales agreements, accounting records, and docun'~ntation such as billings, invoices, or similar documentation that support costs claimed as manufacturing, preparation, and/or transportation costs. All such records shall be maintained in lessee's acoounting office for future audit by lessor. Lessee shall maintain required records for 6 years ~er they are generated or, if an audit or investigation is underway, until released of the obligation to maintain such records by lessor. During existence of this lea.se, information obtained under this section shall be closed to inspection by the public in accordance with the Freedom of Information Act (5 U.S.C. 552). Sec. 6. Conduct of operations - Lessee shall conduct operation in a manner that minimizes adverse impacts to the land, air, and water, to cultural, biological, visual, and other resources, and to other land uses or users. Lessee shall take reasonable measures deemed necessary by lessor to accomplish the intent of thi.s section To the extent consistent with lease fights granted, such measures may include, but are not limited to, modification to siting or design of facilities, timing of operations, and specification of interim and final reclamation n~asures. Lessor reserves the fight to continue existing uses and to author2e future uses upon or in the leased lands, including the approval of easeme.nts or fights-of-way. Such uses shall be conditioned so as to prevent un.necessary or unreasonable interference with fights of lessee. Prior to disturbing the surface of the leased lands, lessee shall contact lessor to be apprised of procedures to he followed and modifications or reclamation measures that may be necessary. Areas to be disturbed may require inventories or special studies to determine the extent of impacts to other resoumes. Lessee may be required to complete minor inventories or short term special studies under guidelines provided by lessor. If in the conduct of operations, threatened or endangered species, objects of historic or scientific interest, or substantial unanticipated environmental effects are observed, lessee shall immediately contact lessor. Lessee shall cease any operations that would result in the destruction of such species or objects. Sec. 7. Mining operations - To the extent that impacts from mining operations would be substantially different or greater than those associated with normal drilling operations, lessor reserves the right to deny approval of such operations. Sec. 8. Extraction of helium - Lessor reserves the option of extracting or having extracted helium from gas production in a manner specified and by means provided by lessor at no expense or loss to lessee or owner of the gas. Lessee shall include in any contract of sale of gas the provisions of this section. Sec. 9. Damages to property - Lessee shall pay lessor for damage to lessor's improvements, and shall save and hold lessor ham'fless from all claims for dan'uage or harm to persons or property as a result of lease operations. Sec. 10. Protection of diverse interests and equal opportunity - Lessee shall pay when due all taxes legally assessed and levied under laws or' the State or the United States: accord all employees complete freedom of purchase; pay all wages at least twice each month in lawful money of the United States, rn,.wintain a safe working environn~nt in accordance with standard industry practices; and take measures necessary to protect the health and safety oF' the public. l.~ssor re.ryes the n~ht to ensure that production is sold at rcay, onable pric~l~to prevent monopoly. If lessee opet'-',tes a p~peline, or owns controLLin~ interest in a pipe~e or a company operatin~ a p,peEne, wNch may be · operated accessible to oil derived from these lea, sod lands, les~e sh~ comply with section 28 of thc Mi.ner,"q Leasing Act of 1920. Lessee shall cowoly with Executive Ch'der No. 112a6 of Septem~r 24. 1965, as amended, and regulations and relevant orders of the Secretary of Labor issued pursuant thereto. Neither lessee nor lessee's subcontractors shall maintain segregated facilities. During the performance of this lease, the Lessee must comply fully with para.grapi't~. t I ) tt~ough {7) ora I CFR 60-1.0da) with respect to employment discrimination on the basis of race. color, religion. sex or national origin, and must incorporate the requirements set forth in thos~ parag_raphs in every, subcontract or purchase order, as provided by that regulation. Sec. 11. Transfer of lease interests and rellnquishn'~nt of lea~se - As required by regulations, lessee shrdl file with lest, or any assxgn.rmnt or other transfer of an interest in tl~is lease. Lessee may relinquish this lease or any legal subdivision by filing in the proper off.me a written relinquishment, which shall be effective as of the date of filing, subject to the continued obligation of the lessee and surety to pay all accrued rentals and royalties. Sec. 12. Delivery. of premises - A~ tin'~ as all or po,nions of this lease are returned to lessor, lessee shall place affected wells in condition for suspension or abandonment, reclaim the land as speeifi~ by. lessor and. within a reasonable period of ttme. remove equipment and m'~Provements not deemed necessary ~ lessor for preservation of producible wells. Sec. 13. Proceedings in ca,se of default - If lessee fails to comply with any provisions of this lease, and the noncompliance continues for 30 days after written notice thereof, this lease shall he subject to cancellation unless or until the leasehold comams a well capable of production ofoil and gas in pa~mg quantities, or the lease is committed to an approved cooperative or unit plan or comrnunitization a.grt-errt, m which contains a well capable of production of unitized substances in paying quantities. This provision shall not be construed to prevent the exercise by lessor of any other legal and equitable remedy, including waiver of the default. As such remedy or waiver shall prevent later cancellation for the san"~ default occurring at any other tirr~. Lessee shall be subject to applicable provisions and ~nalties of FOGRMA (30 U.S.C. 1701). Sec. 14. Heirs and successors-in-interest - Each obligation of this lease shall extend, to an~ he bindi~_ upon. and eveR I~nefit hereof shall inure to. the heirs, executors, adrnimstrators, successors, bene~iaries, or assignees of the respective parties hereto. INSTRUCTIONS A. General 1. The front of this form is to be completed only by parties filing for a noncompetitive lease. The BLM will complete front of form for all other types of leases. 2. Entries must be typed or printed plainly in ink. Offeror must sign Item 4 in ink. 3. An original and two copies of this offer must be prepared and filed in the proper BLM State Office. See regulations at 43 CFR 1821.2-1 for office locations. 4. If more space is needed, additional sheets must be attached to each copy of the form submitted. B. Special: Item 1 - Enter offeror's name and billing address. Item 2 - A single tract number and Sale Date shall be the only acceptable description. Item 3 - This space will be completed by the United States. PAPERWORK REDUCTION ACT STATEMENT The Paperwork Reduction Act of 1990 (44 U.S.C. 3501 et seq.) requires us to inform you that: 1. This information is being collected pursuant to the law. 2. This information will be used to create and maintain a record of oil and gas lease activity. 3. Response to this request is required to obtain a benefit. EFFECT OF NOT PROVIDING INFORMATION - If all the information is not provided, the offer may be rejected. See regulations at 43 CFR 3130. AK-3130-1 (April 1999) SIGNATORY PAGE FOR U,S, DEPT. OF INTERIOR B.L.M. OFFER TO LEASE & LEASE FOR OIL & GAS SERIAL NO, AA-081819 ARCO ALASKA, INC. e',~ Signat~r~ James M. R,,u'ud Attorney-in'Fact Lessee's Name (Print or Type) & Title January 31,2000 Date ARCO Alaska, Inc. Company Name THE UNITED STATES OF AMERICA STATE OF ALASKA This certifies that on the 31st day of January, 2000, before me, a notary public in and for the State of Alaska, duly commissioned and sworn, personally appeared James M. Ruud, to me known and known to me to be the person described in, and who executed the foregoing lease, .who then after being duly sworn according to law, acknowledged to me under oath that he executed same freely and voluntarily for the uses and purposes therein mentioned. WITNESS my hand and official seal the day and year in this certificate first above written. My Commission expires: 6-8-2003 SIGNATORY PAGE FOR U.S. DEPT. OF INTERIOR B.L.M. OFFER TO LEASE & LEASE FOR OIL & GAS SERIAL NO. AA-081819 ANADARKO PETROLEUM CORPORATION Lessee's Signature Todd L. Liebl Aqent and Attorney-in-Fact Lessee's Name (Print or Type) & Title January c¢¢, 2000 Date Anadarko Petroleum Corporation Company Name THE UNITED STATES OF AMERICA ) ) SS. STATE OF TEXAS ) This certifies that on the ,~ '//7/,~ day of January, 2000, before me, a notary public in and for the State of Texas, duly commissioned and sworn, personally appeared Todd L. Liebl, to me known and known to me to be the person described in, and who executed the foregoing lease, who then after being duly sworn according to law, acknowledged to me under oath that he executed same freely and voluntarily for the uses and purposes therein mentioned. WITNESS my hand and official seal the day and year in this certificate first above written. I : / / ~ ~ "--:/"" '-"~,~otary,..'7"u[:)~lc 'c~/_ ., ,.-,,.~ MyComm~ss~on expires: / ~ ~ SPECIAL STIPULATION(S) FOR LEASE AA-081819 Standard Lease Stipulation Numbers 1-24, 26-28, 30, 32, 34-38, 40-44, 46-48, 51, 53, 55-79, as identified and delineated in the Final Record of Decision and Detailed Statement of Sale, pertain to all leases created from the National Petroleum Reserve-Alaska Sale 991, and are herein incorporated by reference and made a part of this lease. The following Special Stipulation(s) is/are specifically delineated in the Record of Decision and Detailed Statement of Sale as pertaining to this tract, and is/am hereby made a part of this lease. This/these is/are a direct quote(s) from the Detailed Statement of Sale document. All references to Exhibit A pertain to Exhibit A of the Detailed Statement of Sale. No part of this lease is identified as Exhibit A.: The "No Permanent Oil and Gas Facilities" and "No Permanent Oil and Gas Facilities within 1/4 mile of Fish-Bearing Lakes Stipulations," Number 39, are identified on each specific tract in Exhibit A hereof. They pertain to some of the tracts in both Area A and Area B. ALASKA OIL AND GAS CONSERVATION COPl~IISSION Greg Wilson NPR-A Contact for Geologic Data Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510-0360 April 4, 2002 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dear Mr. Wilson: As operator of the following wells, Phillips Alaska, Inc. ("Phillips") is required to provide the Alaska Oil and Gas Conservation Commission ("AOGCC") with Certain data within 30 days after completion, suspension, or abandonment of a well.. A review of AOGCC records indicates that Phillips has failed to provide the AOGCC with samples of drill cuttings as required by 20 AAC 25.071(b)(2) for the following wells: Spark 1 Spark 1-A Rendezvous A Lookout 1 Rendezvous 2 PTD# 200-034 PTD# 200-056 PTD~~. PTD# 201-003 PTD# 201-007 · Please ensure that Phillips brings itself immediately into compliance with 20 AAC 25.071(b)(2). Please contact me at 793-1230 if you have any questions. Sr. Petroleum Geologist RC:jjc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Cammy O.Taylor, C~ DATE: Chair Tom Maunder, P.I. Supervisor August 12, 2001 FROM: Lou Grimaldi, Petroleum Inspector SUBJECT: Location Clearance Inspection Rendezvous A ~.hil!ips.AI.aska..lnc. Sunday, Auaust 12, 2001; I made a Location Inspection on Phillip's Plug and Abandoned well "Rendezvous A". This exploratory location was clean with no evidence of drilling activity other than the slightly high mound over the cellar area. This should subside over the next few years and blend in "OK". SUMMARY: I made a Location Inspection on Phillip's Plug and Abandoned Exploratory well "Rendezvous A". Attachments: Rendezvous A mound 8-12-01 LG.jpg Rendezvous A Airshot 8-12-01 LG.jpg c.c: Overstreet/Morrison (Phillip's Alaska Inc.) NON-CONFIDENTIAL Location Clearance Inspection Rendezvous A 8-12-O1 LG.doc \( ~{\. ~ '2-'0 0 -..J '--:> Y.\ ë100 -0 S\ ~" ;; .....- """'~"""-'-" ',-., \(~f\-.~t. ~'Jc)~~ ~ dOO-ù S~ '-8."--"--" PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DA TA * FROM: Sandra D. Lemke, AT01486 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Rendezvous A DATE: 06/29/2001 Lisa Weepie AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Transmitted herewith is the following: Rendezvous A 50103203160000 permit 200-054 Schlumberger-Cased-Hole Edit(LDVVG); Dipole Sonic Imager, 3-21-2001; CD date 5-22-2001; .lob 21160 Please check off each item as received, sign and return transmittal to address below All data to be held confidential until State of Alaska designated release date (AOGCC) Approx. 5/2003 *"On behalf of itself and [Anadarko Petroleum], Phillips Alaska, Inc. submits the attached data for the Rendezvous A Well, Drilling Permit No. 200-054 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the useof the Commission in carrying out its duties, we question whether any future disclosure to DNR or the public would be appropriate or valid. However, it is neither appropriate nor necessary to reSOlve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, SO that we may be heard on the issue." CC: Greg Wilson, PA]: Geologist Return receipt to: Phillips Alaska, Inc. ATrN: S. Lemke~ ATO-1486 700 G. Street Anchorage, AK 99501 Prepared by: Sandra D. Lemke Phillips Alaska IT Technical Databases RECEIVED JUL 0 2. 2001 Alaska 0ii & Gas Cons. C0mmmi0n Anchor~e r PLUGGI~u & LOCATION REPORT State of Alaska 0IL & GAS CONSERVATION CCHMiSSION Review the well file, a.,,~d-cr--~en= on plugging, well head an~ !oca=iun c!ear~nce - pr=vi~e loc. clear, code. Well hear =~,= c~_~: Harker Pos= or pla=a: Loca=ion Clearance: Conclusions: Date __PHILLIPS Alaska, Inc. A Subsidfmy of PHIl. UPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DATA* FROM: Sandra D. lemke, AT01486 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Rendezvous A DATE: 06/08/2001 Lisa Weepie AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Transmitted herewith is the follOwing: Rendezvous A 50103 203160000 permit 200-054 i reprod~c/b/e fi/m and I B/ue//ne log print each ~SsCch~l~l~l~errg;er:-Di;;~s;f°r;;C r[l~oargde:'s2;2ol;;0n~lmics 4-14-2001 v/Schlumberger-Perf record 4-13-2001 Co/or Log presentations v/Schlumberger - UltraSOnic Imager Log, 3-21-2001 v/Schlumberger - Best DT; Q.C. Plot Dipole sonic .lob 21160; 3-29-2001 Please check off each item as received, sign and return transmittal to address below All data to be held confidential until State of Alaska designated release date (AOGCC) Approx. 5/2003 *"On behalf of itself and [Anadarko Petroleum], Phillips Alaska, Inc. submits the attached data for the Rendezvous A Well, Drilling Permit No. 200-054 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). While we are sUbmitting this data for the use of the Commission in carrying out its duties, we' question whether any future disclosure to DNR or the public would be appropriate or valid. However, it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclOSure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, so that we may be heard on the issue." CC: Greg Wilson, PAI Geologist RECEIVE D Recei o-(-~-'9'~ Date: JUN 11 ;7001 Return receipt to: Phillips Alaska, Inc. ATTN: S. Lemke,, ATO-1486 700 G. Street Anchorage, AK 99501 Alaka 0il & Gas Cons. CommJaeen Anchorage Prepared by: Sandra D. Lemke Phillips Alaska 1T Technical Databases PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 June 6, 2001 Commissioner Camille Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Rendezvous A (200-054 / 301-021 and 301-101) Completion Report Dear Ms. Commissioner: Phillips Alaska, Inc., as operator of the Rendezvous A exploration well, submits the attached "Well Completion Report" (AOGCC form 10-407) to cover the recent testing operations. The report of daily well operations is attached. The Commission is requested to keep confidential the enclosed information due to the exploratory nature of this well. If you have any questions regarding this matter, please contact me at 263-4603 or Bill Lloyd at 265-6531. Sincerely, P. Mazzolini Exploration Drilling Team Leader PA1 Drilling PM/skad ' ('" ST^T o. · ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas D Suspended D Abandoned r~ Service D '2. Name of Operator ~ ~ 7. Permit Number Phillips Alaska, Inc. '~ ~")'3~ 200-54 / 301-021 / 301-101 3. Address .i '""'~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~_:~ 50--103-20316-00 4. Location of well at surface .... / ' '"' :--"-;:i~'-i 9. Unit or Lease Name 2247' FSL, 1255' FWL, Sec. 24, T10N, R1E, UM (ASP: 279253, 5927938.5) ........ , Exploration NPRA · t) · At Top Producing Interval O 10. Well Number ............... " Rendezvous A 2281' FSL, 1203' FWL, Sec. 24, T10N, R1E, UM (ASP: 279201.6, 5927972.6) ' ,~;.i~!,~:i;?.,.~,,.._ At Total Depth . ......... _.~._~--___ -----_ 11. Field and Pool 2281' FSL, 1203' FWL, Sec. 24, T10N, R1E, UM (ASP: 279201.6, 5927972.6) ......... ' ................ ' Exploration 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 25 feetI AD L AA-081803 ALK AK5148 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions I April 13, 2000 April 28, 2000 4/27/01 P&A I N/A feet MSL 0 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 8353' MD / 8352' TVD surface YES E] No [~]I N/A feet MD 277' MD 22. Type Electric or Other Logs Run LWD, Neutron/Density/4_phase/GR, DSI, USIT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# B Surface 108' 20" 200 cu. Ft. 7.625" 29.7# L-80 Surface 2661' 9.875" 253 sx AS I, 240 sx Class G 5.5" 15.5# L-80 Surface 8221' 6.75" 140 sx Class G, 84 sx CemPlus 3.5" 9.3# L-80 8221' 8328' 6.75" (included above) bridge plug set @ 150' .241 Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD Intew~l,'' SiZe and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 2893' N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8040'-8078' TVDSS Plug #1: 8 bbl Class G cmt (TOC @ 7890' MD) Plug ~2:45 bbl Arctic (Annulus) Plug #3:3.6 bbl AS 1 (surface) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 13, 2001 P&A Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 4/13/2001 90 hours Test Pedod > 1526 25550 35 2"I 16750 scf/stb Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') press. 250 psi N/A 24-Hour Rate > 407 6810 9 60° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. - GEOLOGIC MARKERS FORMATION TESTS ,. NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Perforated the Jurassic interval from 8,130' to 8,168' MD with -1,000 psi underbalance. Flowed for a total of 90 hours and recovered 1526 bbls of 60 dug APl oil, 25,550 MCF gas and 35 bbls Top Nanushuk 2856' 2767' water. Total GOR of 16,750 SCF/STB. All gas Top HRZ 7300' 7211' was flared onsite. Fluid was hauled to Alpine. Base HRZ 7362' 7273' Surface flowing tubing pressure was Top Jurassic 8054' 7965' approximately 250 psi and the bottomhole flowing pressure was approximately 400 psi. 31. LIST OF A'I-rACHMENTS Summary of Daily Operations 32. I hereby certify that the following Is true and correct to the best of my knowledge. Questions? Call Tom Brassfleld 265-6377 S Jgned~"'-'P~3,~,~ ,~~ Title D dllln.q Team Leader Date Paul MJzoliOni ~ ,, INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. ii'";~;'~i:. tI~'~, ii,.. ..... -' .: ~l~:,.~ ~..;;'~'~.'. !;i ~.i! Item 28: If no cores taken, indicate "none". Form 10-407 Operations Summary Rendezvous 'A' Rpt Date 03/18/01 12:00 AM 03/19/01 12:00 AM 03/20/01 12:00 AM 03/21/01 12:00 AM Comments MOVE SUB & SUPPORT COMPLEXES TO RENDEZVOUS 'A'. ON LOCATION, SPOT, SUB, COMPLEXES & PIPE SHED, 24.1 MILE MOVE TO RONDY F/RIG, 26.5 MILE MOVE F/CAMP TO MOOSE'S TOOTH 'C'. RIG PREP, SECURE EXITS, HOOK UP STEAM, WASTE HEAT, ELECTRICAL, SKATE. NIPPLE DOWN TREE, RIG ACCEPTANCE @ 1000 HR. 3/18/01. NIPPLE UP STACK, INSTALL CHECK VALVE ON KILL LINE SIDE, C/O BACK PRESSURE VALVE W/TWO WAY CHECK FOR BOPE TEST. P/U FLOOR VALVES, SUBS FOR BHA, MILL STACKED TONGS AND RELATED EQUIPMENT. STRAP 2-7/8" STRING, BHA, PREP TO P/U PIPE. R/U & TEST BOP'S & TEST VALVES. TEST BOPE, 250 LOW, 5000 HIGH, ANNULAR 250 LOW, 3500 HIGH 10 MINUTES EACH. ANNULAR FAILED. N/D PICTURE NIPPLE, C/O ANNULAR ELEMENT, N/U PICTURE NIPPLE, RIG UP TO TEST. TEST ANNULAR PREVENTER. RIG DOWN TEST EQUIPMENT. PULL TWO WAY CHECK VALVE. WORK ON PICTURE NIPPLE (SMALL LEAK). RIG UP,CIRCULATE FREEZE PROTECTION DIESEL FROM WELL, RIG DOWN. PULL TUBING HANGER & LAY DOWN. PULL & LAY DOWN 93 JTS 3-1/2" TUBING. INSTALL TEST PLUG & TOP & BOTTOM RAMS TO 2-7/8". TEST FLOOR VALVES & PIPE RAMS, pull test plug. TEST 2-7/8" RAMS & FLOOR VALVES, 250 & 5000 PSI. INSTALL WEAR RING. P/U BHA. RIH P/U DRILLPIPE TO 5890'. CIRCULATE HOLE CLEAN. WASH & DRILL F/5890-6080', CEMENT F/6080 TO STAGE TOOL @ 6120'. BLOW DOWN STANDPIPE/KELLY HOSE/OBSERVE WELL. P/U DRILLPIPE TO 6962'. SERVICE TOP DRIVE. P/U SINGLES TO 8211' ESTABLISH CIRCULATION-PUMP SWEEP-SEA WATER-DIRT MAGNET AND FOLLOW W/SEA WATER. RIG UP & TEST CSG TO 5000 PSI F/30 MIN-OK. PUMP SLUG OBSERVE WELL RIG DOWN TEST EQUIPMENT. POH, STAND BACK DRILLPIPE. LAY DOWN BHA & CLEAR FLOOR. PJSM, RIG UP SCHLUMBERGER. LOG RUN # 1 USIT BOND LOG. LOG RUN #2 DIPOLE SONIC. RIG DOWN SCHLUMBERGER. PJSM, RIG UP & RUN 1400 'TBG. FREEZE PROTECT TBG ANNULUS & TBG TO 1400'. POH LAY DOWN 3-1/2" TBG. PULL WEAR BUSHING. INSTALL TBG HANGER IN SPOOL. CLEAR FLOOR OF TOOLS. Operations Summary Rendezvous 'A' PJSM R/U LAY DOWN DRILLPIPE IN MOUSEHOLE. 03/22/01 12:00 AM LAY DOWN DRILLPIPE FROM DERRRICK. CHANGE UPPER & LOWER PIPE RAMS TO VARIABLE & 5" RAMS. NIPPLE DOWN BOPE. NIPPLE UP 5-1/8" TREE & TEST, SBMS SEAL LEAKING. NIPPLE DOWN TREE. WORK ON SBMS SEALS. NIPPLE UP TREE, INSTALL TUBING HANGER ADAPTOR, TEST TO 5000#, PULL BPV INSTALL TREE TEST PLUG, FILL W/DIESEL, TEST TO 5000# SECURE TREE. CLEAR FLOOR OF 2-7/8" DRILLPIPE HANDLING EQUIPMENT. PJSM CHANGE OUT SAVER SUBS. CUT DRLG LINE. PREPARE FOR MOVE RIG MAINTENANCE WAIT ON TRUCKS (19E RIG MOVING). PREPARE FOR MOVE, RIG MAINTENANCE, AWAIT ARRIVAL OF TRUCKS 03/23/01 12:00 AM FROM NABORS 19E RIG MOVE. RIG RELEASED @ 1200 HR, 3/23/01. 04/14/01 12:00 AM Perforated 8148' to 8168' MD w/900 psi underbalance. Perforated 8130' to 8148' MD w/800 psi underbalance. Opened well to flow. 4/14 to 4/18/2001 Tested Well 04/18/01 12:00 AM SI well for pressure build-up 04/21/01 12:00 AM Pull gauges from 8030' WLM & tag bottom at 8200' RKB. 04/22/01 12:00 AM Bullhead cmt down 5-1/2" x 7-5/8" annulus: Pump 200 bbl Sw. Start pumping 45 bbl diesel freeze protect. Bullhead 20 bbl diesel, ~,.~w,.~.~ ~ w,,~;~c.,) 200 bbl SW and 45 bbl Arctic Set 1 cmt, 266 sxs Cls G, 47.8% BWOC D53, 0.4% ~ ¢,.¢,_o~-~cCc.~. \,.-/ D65, 0.24% D13, 0.15% D46, 15.7 ppg slurry 04/23/0112:00 AM Attempted to run HES cement retainer unable to get down. Found cement @ 345'. Attempted to jet through with no success. 04/24/01 12:00 AM Mill cement from 314' to 414' CTM with 4.75" chomps mill. Lose Dowell pump, ~',.~ ~. oO~ cua,,,,.~r-- POOH, Chomps mill gummed up with cement. Swap to 4.75" PDC bit, resume milling with LRS pump. 04/25/01 12:00 AM Miled green cement from 414' to 1600' and stringers to 2800'. Continued to 8120' CTM with no obstructions. Verified injectivity at 1.5 bpm at 1200 psi. Made gauge run from surface with bit not turning. 04/26/01 12:00 AM Made gauge run with 4.75" PDC bit not turning from surface to 4000'. No obstructions, nIH with 5.5" EZSV set @ 8080'. 04/27/01 12:00 AM nIH w/2.875" MAH. Sting into EZSV. Inject into formation. Wash up cementers prep c,.~k.t,,,~\~:,~ ~,O ~-~'%,4' to pump. Begin cementing. 7890' TOC, let fresh water spacer around, lay in brine until confirm brine in surface then freeze protect to 150' w/diesel. Circulated 200 bbls c..x~o~,,~9- ~'~--~" c.~ ~,,~ ~:~\~,,,4 brine to surface in 5.5 casing. Rig up to 5.5" x 7 5/8" outer annulus. Pump 10 bbl '- ¢,..~ -"~,-~ diesel, 200 bbl water, & 45 bbl Arctic Set cement. Set bridge plug @ 150' MD. Spot ~,'"L.~ t- ~. ~ ¥ ~P~tic Set cement to surface. 4/28/2001 & 4/29/01 'Co~nplete surface P&A of Rendezvous "A". P&A witnessed by John Crisp w/ AOGCC. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' Julie Heusser, Commissioner THRU: Tom Maunder, P. I. Supervisor FROM: John Crisp, DATE: April 29, 2001 SUBJECT: Petroleum Inspector Surface Plug Rendezvous A PTD 200-054 Apri1 29, 2001: I traveled to NPRA to witness the final plug on Phillips Alaska's Exploratory Well Rendezvous A. I witnessed that all casing strings were cut more than 3' below tundra level. All strings of casing had cement to surface. A marker plate was welded on the outer most casing string with the appropriate well data on the plate. The Phillips Rep. in charge of the P & A informed me that the BLM Inspector requested a weep hole be drilled thru the center of the marker plate, SUMMARY: I witnessed the final well work for P & A of the. Exploratory Well Rendezvous A. Attachments: 1 Rondy A P & A 2JPG NON,CONFIDENTIAL 010429-Rondy A P & A-jc.doc PHILLIt:, S Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Torn Brassfield Phone (907) 265-6377 Fax: (907) 265-6224 Email: tbrass@ppco.com April 23, 2001 Daniel T. Seamount, Jr., Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Sundry approval to Plug and Abandon Phillips Rendezvous "A" Surface Location: 2247' FSL, 1255' FWL, Sec. 24, T10N, R1E, UM or ASP4, NAD 27 coordinates of X=279,253 & Y=5,927,938 Target Location: 2281' FSL, 1203' FWL, Sec. 24, T10N, RIE, UM BHL: 2281' FSL, 1203' FWL, Sec. 24, T10N, RI E, UM CONFIDENTIAL Dear Commissioner Seamount: Phillips Alaska, Inc. would like to permanently plug and abandon the Rendezvous "A" wellbore, located in the National Petroleum Reserve-Alaska. The well was originally drilled, cased, and completed with approximately 2900' of tubing on May 5, 2000 as part of the 1999/2000 Exploration program. The well was subsequently cleaned-out, perforated, and tested via the production casing as part of this year's winter exploration season. The attached Sundry and back-up information describes the P&A procedure for the existing wellbore and has been discussed with AOGCC personnel. A final decision has been made to complete the P&A before the end of this year's winter exploration season. If you have any questions or require any further information, please contact me at 263-4603 or Tom Brassfield at 265-6377. Sincerely, Paul Mazzolini Exploration/Cook Inlet Team Leader STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS CONFIDENTIAL 1. Type of Request: Abandon X Suspend_ Alter casing _ Repair well _ Change approved program __ Operation Shutdown __ Re-enter suspended well _ Plugging w Time extension _ Stimulate_ Pull tubing_ Variance m Perforate__ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2247' FSL, 1255' FWL, Sec. 24, T10N, R1E, UM At top of productive interval 2281' FSL, 1203' FWL, Sec. 24, T10N, R1E, UM At effective depth At total depth 2281' FSL, 1203' FWL, Sec. 24, T10N, R1E, UM 5. Type of Well: Development Exploratory X Stratigraphic __ Service 6. Datum elevation (DF or KB) 25' RKB Pad 62' 7. Unit or Property name Exploration 8. Well number Rendezvous "A" 9. Permit number 200-054 10. APl number 50-103-20316 11. Field/Pool Exploration feet 12. Present well condition summary Total Depth: measured drilling @8353 (approx) true vertical 8352 Effective depth: measured 8211 (approx) true vertical 8210 Casing Length Size Structural Conductor 83' 16" Surface 2636' 7.625" Production 8196' 5.5" 107' 3.5" feet feet feet feet Plugs (measured) (See attached proposal) Junk (measured) Cemented Measured depth True vertical depth 200 cf 108' 253 sx AS1,240 sx CIG 2661' 140 sx CI G, 84 sx CemPlus 8221' (incl. Above) 8328' 108' 2661' 8221' 8328' Perforation depth: measured 8130' to 8168' MD/TVD N/A Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None APR 3 ?gql Alaska Oil & Gas Cons. 13. Attachments Description summary of proposal X Detailed operation program __ BOP sketch __ Contact Paul Mazzolini at 263-4603 or Tom Brassfield @ 265-6377with any questions. LOT test, surface cement details and casing detail sheets 14. Estimated date for commencing operation 4/22/01 16. I, proposal was verbally approvedL(~'~'-(~ Name of approver Tom Maunder ' 4/20/01 15. Status of well classification as: Oil__ Gas__ Suspended X Date approved 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "-'~'~-~Pa~ Title Exploration/CooklnletTeamLeader Date FOR COMMISSION USE ONLY I Conditions of approval: ~e. tify Commission so representative may witness Plug integrity.~ BOP Test Location clearance ~. Mechanical Integrity Test_ Subseque~'form require 10~~t'~ ORIGINAL SIGNED B"' Approved by the order of the Commission D Taylor Seomm Form 10-403 Rev 06/15/88 Commissioner ,lAppr°va' N o~..) ~. -[O\ Date ~~_ "~/ SUBMIT IN TRIPLICATE Tom Maunder <tom_maunder@admin.state.ak.us> 04/23/01 06:38 AM To: Tom J Brassfield/PPCO@Phillips cc: greg_noble@ak, blm.gov, bo_brown@ak.blm.gov, AOGCC North Slope Office <aogcc_prudhoe_bay @ admin.state.ak, us> Subject: Re: Rendezvous "A" P&A Revised Tom, This note is for your records. Thanks for modifying the cement volume below the retainer above the perforations. Chuck Scheve and I reviewed your original proposal with the modification of the cement volume. We found your proposal acceptable with the modification and that determination was communicated to you by phone on Saturday. According to Chuck, the BLM inspector was on site so it was unlikely that Chuck would travel out to witness the plug setting. Chuck did indicate that he would like to view the the well when the casings are cut off. Please assure that your supervisor get in contact with one of the inspectors. Good luck. Tom Maunder, PE Petroleum Engineer AOGCC Tom J Brassfield wrote: Tom, per AOGCC's request we have modified the volume to be pumped below the retainer. (See attached file: Rondy A Agency P&A Proc by TJB 4 20 01.doc) (See attached file: Dowell Rondy A P&A Schematic in word 4 20 01.doc) Thanks, Tom 265-6377 (w) 275-7352 (p) 265-6916 (f) > Name: Rondy A Agency P&A Proc by TJB 4 20 01.doc > Rondy A Agency P&A Proc by TJB 4 20 01.doc Type: WIN-WORD File (application/msword) > Encoding: base64 > > Name: Dowell Rondy A P&A Schematic in word 4 20 01.doc > Dowell Rondy A P&A Schematic in word 4 20 01.doc Type: WIN-WORD File (application/msword) > Encoding: base64 tom_maunder.vcf Rendezvous "A" Final P&A CONFIDENTIAL Current Status: Rendezvous "A" was temporarily suspended on 5/4/2000. In March and April of this year the wellbore was cleaned-out, perforated, and tested via the production casing. The 5-1/2" casing is currently filled with produced fluids while the 7-5/8" x 5-1/2" annulus remains freeze protected to approx. 2000' MD.The decision has been made to finalize the P&A before the end of this year's winter exploration season. . Notify BLM/AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Mobilize and rig up D/S for well P&A operation. . RU D/S to the 5-1/2" tree and bullhead seawater to the perforations from 8130' to 8168' MD (approx. 194 bbls). Over displace perforations by 20 to 50 bbls depending on surface pressures. SI well and check SI pressure. . RU D/S to pump down the 7-5/8" x 5-1/2" annulus. Pump 200 bbls of water to flush annulus and verify injectivity- note rate and pressures. Bullhead 270 sx (44.7 bbls) of Arctic Set I cement into annulus. '"~r,,~,¢__~ 45'1~;~t.%. 5. Clear lines and shut down pumps. Rig down cementing unit and clean up. . RU CTU. RIH with cement retainer and set at 8080' MD (50' above top perforation at 8130' MD) Squeeze enough slurry below the retainer (approx. 25.1 cuft or 4.5 bbls) to fill to the bottom perforation at 8168' MD plus 100' of calculated volume. Pull out of retainer and spot 150' cement on top of retainer (approx. 20 cuft or 3.6 bbls). 7. Change over wellbore fluid to 9.6 ppg NaCI brine. Estimated reservoir pressure is 3770 psi at 8130' TVD/MD or 8.9 ppg EMW. POOH. 8. RIH with 2"d cement retainer and set at 150' MD. Spot 150' Arctic Set 1 cement plug to surface (approx. 20 cuft or 3.5 bbls). 9. Cut off wellhead and all casing strings at 3 feet below ground level. Verify cement is at surface in all strings. Send casing head with stub to Materials for repair/re-dressing. 10. Weld ¼" thick cover plate (at least 18" in diameter) over all casing strings with the following information bead welded into the top. Drill 1/8" weep hole in cover plate. Phillips ALASKA, INC Rendezvous "A" PTD# 200-54 APl# 50-103-20316 SHL: 2247' FSL, 1255' FWL, Sec. 24, T10N, R1 E, UM 11. Remove cellar. Back fill cellar with gravel as needed. Back fill remaining hole to ground level with gravel. Clear ice pad location and demob all materials and equipment. TJB 4/20/01 FILE: Rendezvous "A" TJB 4/20/01 Ren S ~r ' - Date 4/20/2001 Abhijeet Tambe rev by TJB 4/20/01 16" 65# H-40 @ +/- 80' MD Surface csg. 7-5/8" 29.7# LoS0 BTC ( 2661' MD / 2661' TVD) Cemented to surface Production Casing 5-1/2" 15.5# L-80 BTCM (8222' MD / 8222' TVD) Est. cement top @ 4720' MD Cut casing 3' below ground level, weld 1/4" steel plate w/weep hole, well name and location CIBP @ 150' MD. W/CTU cement to surface Arctic Set 1 22 sks Class G + 47.8% BWOC D53, 0.4% D65, 0.24% D13, 0.15% D46, 12.6% BWOW D44 Slurry Volume 20 Ft3 Slurry Weight 15.7 ppg Slurry Yield 0.93 Ft3/Sk Bullhead 5-1/2" x 7-5/8" annulus w/cement to surface Arctic Set 1 '~266 sks Class G + 47.8% BWOC D53, 0.4% D65, 0.24%D13,0.15%D46 Slurry Volume 246.94 Ft3 Slurry Weight 15.7 ppg Slurry Yield 0.93 Ft3/Sk 9.6 NaCI Brine Calculated Cement from 7930'- 8268' (.150' Cement on top of retainer) Halliburton Stage Tool @ 6104' MD Retainer @ 8080' MD Perfs: 8130'- 8168' MD 39 sks Class G Cement + 0.2% D46, 0.3% D65, 0.35% D167, 0.2% D800 Slurry Volume 45.2 Ft3 Slurry Weight 15.8 ppg Slurry Yield 1.16 Ft3/Sk TT @ 155 degF BHST 3.44 Hrs Production Stinger 3-1/2" 9.3# L-80 8rd EUE ( 8222'- 8328' MD) PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 700 G Street [99501] Post Office Box 100360 Anchorage, Alaska 99510-0360 J. L. "Von" Cawvey Engineering and Evaluation Manager Exploration and Land Telephone: (907) 265-6306 Facsimile: (907) 265-1608 Email: jcawvey@ppco.com February 27, 2001 HAND DELIVERED TO: Alaska Oil and Gas Conservation Commission Alaska Department of Administration 333 West Seventh Avenue Anchorage, AK 99501 .... ~;;~o ,, ... Attention: Jack Hartz and ...~.,'.~.'.~. Maunder' Subject: Rendezvous A Completion RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Gentlemen: Thank you for allowing us to provide additional information for your evaluation of the proposed monobore completion of the NPRA Rendezvous A well. Operations to be carried out in the completed well will include a fracture stimulation, flow test, and pressure buildup. Plans are then to abandon the well. At no time will operations be underway without adequate onsite monitoring. Attached are sheets of information including the proposed completion equipment, testing equipment, testing procedure, and contractor (Halliburton) standards. One other piece of information to point out is that the expected flow velocity of 47 ft/sec (35 MMSCFD in 5 ~" casing at 1000 psi WHP) will actually be less than the 72 fi/sec velocity expected in the 3 ~" Spark lA completion (expected 20 MMSCFD). While the Spark lA completion is considered more typical, there is actually less risk of erosion in the Rendezvous A wellbore and wellhead. As an FYI, we plan to use the same high level of monitoring on Spark lA as on Rendezvous A. All information contained herein is provided in support of the 10-403 Application for Sundry Operations. Any geological or reservoir data which may have been presented verbally or in writing as a justification for the proposed completion should be treated as confidential by the Alaska Oil and Gas Conservation Commission. We trust that this information will be sufficient for you to approve our proposed completion. Please advise if you have any questions or require additional information. Sincerely, PHILLIPS Alaska, Inc. is a Subsidiary of PHILLIPS PETROLEUM COMPANY Rendezvous A Tubingless Completion - Preliminary Testing Procedure Proposed Completion: ~ 5-1/2" L-80, 17 lb/ft casing, 4.892" ID, 7,740 PSI internal yield ~ 5-1/8" 5K Wellhead system, Cameron carbon steel tree ~ 5-1/2" casing hanger } 11" x 5-1/8" tubing head adapter with tubing hanger } 5-1/8" ID master } 5-1/8" ID actuated SSV } 5-1/8" ID flow cross with dual 5-1/8" wing valves } 5-1/8" ID swab valve and wireline tree cap Proposed Surface Testing Equipment: 4" OD 5K carbon steel flowline to Cyclone Desander unit 4" OD 5K carbon steel flowline to dual choke skid } Flowline is "Y'd" before and after Desander as it is a dual train piece of equipment } 3" OD 5K carbon steel flowline from choke skid to primary separator 4" flowline before and after the Desander will contain clamp on ultrasonic sand detectors. All piping on the upstream and downstream side of the Desander is standard service pipe with a Rockwell "C" hardness numbers greater than 22; Piping is A333 grade6 which is cold service piping to -50 F working @ 5K PSI All equipment from the 4" x 3" x-over to and through the choke manifold, heater, downstream piping to the flare, vessels, and up to the oil manifold at the tank farm, has a Rockwell "C" hardness of 22 or less as it is built to NACE MR-01-75 specifications. A sand probe will be installed downstream of the Desander. The sand detectors and sand probe will monitor for any sand carryover beyond the Desander unit. Proposed Testing Procedure: Note: This is a preliminary procedure which is subject to change due to well conditions and logistics and is presented here as a representation of what may occur. 1.) Drill out cement plugs to TD with the rig. Perform cased hole logging consisting of di-pole sonic and US1T. 2.) Perforate 50' of the Jurassic interval with casing guns. 3.) NU 5-1/8" wellhead assembly and move the rig off. 4.) Fracture stimulate the well with ~ 200K lbs of 16/20 ceramic proppant 5.) Perform a CT clean-out to TD to ensure the wellbore is clear. 6.) Tag bottom with slickline. 7.) Run dual pressure bombs on HWP packer set on E-line. 8.) Open well to flow at minimum rates to begin cleaning up load water. Flow will be through the Desander and choke but around the separator. 9.) Once sufficient gas flow rates are initiated, begin flowing through the test separator and light flare. 10.) Monitor liquid and gas rates until watercut is below 20%. Monitor pressure drop across Desander and monitor sand detectors and sand probe. Monitor piping and elbows with UT to determine if any wall loss is taking place. Note: If during the flow test the sand probe fails, the remaining piping will be UT'd to determine if any wall loss is occurring. Hot Oil will be rigged up onto the wellhead to pump kill fluids if needed. 11.) Begin multi-rate testing to determine non-Darcy flow effects, if any. 12.) Perform final rate flow test. 13.) Shut-in for pressure build-up test. 14.) UT test all piping and wellhead to determine if any wall loss has occurred. Contractor Standards: All Halliburton test packages are built and maintained in compliance with their Global Standards and Specifications. The standards are comprehensive and demanding and are designed to enhance service quality and reliability while minimizing liability for both the customers and Halliburton. Each piece of equipment has a Data Book, which contains complete fabrication and inspection documentation. (Examples: Mill specs and certifications, UI-A's, COC's to NACE, weld maps and procedures, x-rays, welder certifications, thickness tests, hardness tests, spectrographic analysis, magnetic particle inspections, annual inspection reports, etc. where applicable) The sand probes are made of stainless steel and can have varying wall thickness starting at 0.03" thick. We plan to start with the thinnest wall (0.03") probe to ensure it fails before any significant wall loss will occur. The sand probe is placed in the middle of the flow stream and is subject to the greatest erosion potential. Additionally, Halliburton will have UT testing equipment that they will use to check their piping thickness in critical areas every hour while we are flowing. All the piping has a current baseline to compare with real time readings. The wellhead will be pressure tested and UT tested as well for a baseline. The tree will be tested during the job if deemed necessary based on real time UT inspections of critical areas between the wellhead and Desander. It will be re-inspected after completion of the job to determine the amount of erosional damage. Such information will be of use in the consideration of future applications. Halliburton mans the testing operation with (2) 8 man crews working 12 hours shifts and a service supervisor. Additionally, Phillips will have 2 on-site representatives overseeing the operations. Phillips will have as one representative an engineer from the Exploration Group who is aware of the erosion concerns and who will ensure thorough monitoring of the piping and equipment. Meeting 2/20 í( ( Subject: Meeting 2/20 Date: Wed, 21 Feb 2001 10:08:58 -0900 From: Jack Hartz <jack_hartz@admin.state.ak.us> Organization: AOGCC To: "Cawvey (Phillips), Von" <JCAWVEY@ppco.com> CC: "Maunder, Thomast' <tom_maunder@admin.state.ak.us>, "Crandall, Robert" <bob_crandall@admin.state.ak.us> Van, Thank you, Andy and Bill for the additional information on your test plans on the Rendevouz Well. We had a further discussion wI commissioner after you left and a couple more questions were raised. 1. What is the contingency plan if or when an erosion probe fails? Has a procedure been devised to inspect piping, chokes and etc.? How will the well be handled? 2. What is the metallurgy of the probes more specifically and is it in fact softer/weaker than the metals in the piping? 3. We noted during the discussion that the slim hole and monobore completions do not appear to be appropriate for testing the type of wells in that area. The AOGCC does not prefer this type of completion for the type of evaluation work being conducted and will look at future projects on a case by case basis. The slim hole or monobore may be applicable in a development situation where conditions are known and can be optimized. In the current situation, very little is known and to us a monobore is almost a throwaway well because the options with it are so limited. We believe more consideration should be given to upsized completions and were pleased to hear that subsequent wells in this area wilt be completed with larger pipe. Lastly, during the last few weeks we have been asked to expedite work that will enable Phillips to implement its winter exploration and evaluation program. On several occasions, the information accompanying the initial proposals was lacking in depth and breadth and as such we were unable to evaluate them fully or were inclined to deny the request because there was little justification or explanation. In essence we feel we are being tight holed to some degree. The AOGCC is used to handling confidential information on a fairly routine basis and as such we need enough information to properly evaluate and recommend a decision. We are getting less inclined to chase down the information because of the amount of work coming in here on a regular basis. If we dontt get the backup with the proposal, it will be denied, as has been done on occasion, and then meetings have to be arranged and more detail comes out. It seems to take more time than necessary and causes crowding of deadlines. We want to work with the operators, however, we must have the information in full and timely. If you have any questions, give me a call. We'd like response the above questions before we act on the 403. Jack Hartz 10f2 3/5/01 12:24 PM ~Oa'-as~ ~..-:-:~.,.. ~s~,,,, Mark Wedman <Mark.Wedman@Halliburton.com> on 02/20/2001 11 :53:48 AM To: cc: Subject: Response to Andy's flowback request Andrew J Bond/PPCQ@Phillips Andy, I added one more to the initial responses and added a follow-up section below regarding erosion/flowback responses. Mark Initial Responses * South Texas - Zapata County. When I called on Chevron we did this kind of stuff all the time. Frac and flow, even multiple zones. * We have done 30 plus tubingless completions for Santos in Australia. Another place we do some tbg-less completions is Indonesia for VICO. Have done a few here in the states in the Buffalo area. Don't know the field names off hand. * We have done two fracs here in Argentina, in a well called xxxxxx, in March 2000. I suggest you ask people in Oman, they'll for sure have case histories. * "We have performed 850 tubingless completions with fracs up to 8000 sx and AOF flow testing in Burgos Field located in Mexico" Using tubingless 3.5 OD and 2 7/8" OD. * Your definition of tubingless is that the frac and well test will be down or up the casing. A large percentage of North America Land wells are frac'ed down casing. The numbers would be in the thousands. Operators have drilled wells then run tubing as the casing, the tubing would then be cemented and perforated. Exxon had a considerable amount completed this way in the marsh in S. Louisiana. Devon completed several well this way in East Texas since 1998. * In the Rockies we do more then 250 fracs per month and >95% are done down casing. * Balikpapan Indonesia has completed over forty monobore completions for Vico Indonesia ( now part of BP/Arco ) in the Nilam field located in E.Kalimantan on the Island of Borneo. The completions & flowbacks consist of running the modular guns, perforating, flowing back to a location pit for a clean up period and then to the pipeline to the satellite. * We have performed over 100 3 1/2" monobore 3.5" chrome tubing tubing fracs in the Cooper Basin, South Australia up to maximum treating pressures of 10,000 psi at 30 BPM on gas reservoirs through a Wellhead Isolation Tools (WHIT). We have done some 50 wells in 2000. * We have performed about 50 fracs down 5 1/2" casing in Queensland, Australia Coal Bed Methane wells. * Casing fracs are a daily occurrence in the Rockies, during my short time there we conducted 3 fracs per week, minimum, out of Rock Springs. * We have performed around 110 tubingless completions(frac jobs) in the Cuitlahuac, Arcos, Arcabuz, Culebra etc. fields located in the north-east of Mexico during the last year. Tubingless casings were 3 1/2" or 2 7/8". * We set Fas Drill Bridge Plugs in 2 7/8" tubingless completions that are then staged fraced and flow tested by competitors. This is in Phillip's Ada Field in North Louisiana. They are doing the same with 4 1/2" casing, FLOWBACK/EROSION RESPONSES * We are testing wells with Qg rates up to 14 MMCFTD never we had erosion problems most of wellheads are 10K . * With respect to erosion during flowback, we have recently started commingling our fracs with 20% nitrogen to aid in recovering the underdisplaced proppant without using CTU intervention. This allows us to cleanup the wells without killing the low bottom hole pressure wells. Consequently we get an initial return of proppant laden fluid ( we wait for closure before we start flowback - 1/2 hour) which tails off quickly. Rates are always hard to measure, but 2 BPM liquid is thought to be in the range and then with gas breakthrough we get a couple of MMSCFD as it slugs and cleans up to gas. Obviously the velocity is managed with a choke system so no erosion on the WHIT or wellhead has been observed in the first flowbacks. The choke system near the well head takes the pressure drop. We are also rigged up with a fixed bean choke on the end of the flareline at the pit as a secondary choke. This rigup and procedures are captured in the JSA and field procedures. In general here with over a hundred wells frac'd in recent years, mostly monobores in the past 3 years, wellhead erosion has not been an issue, proppant is held in the fractures and sand production is not an issue. We also do CBM frac work with energized systems down 5.5" casings, which is another "monobore" completion technique that has positive flowback history and experience. * We perform flowbacks on N2 foam coal bed methane wells and attached is a common configuration we use. We don't generally see wellhead erosion problems but we do go through a lot of chokes during the job. We recommend using brand new tubing and concrete blocks to secure the line for energized fluid flowbacks. * Bascially what we do is a rigless operation for perforating and flow backs. We run the modular guns anywhere from 10' intervals up to the longest here of 607' of interval. We then flow the well to a location pit ( rate not to excees 15mmcfd when tools are in the hole) which varies on clean up time and then retreive tools and divert flow to the satellite. Summary is * Gas flow rates are from .5 mmcfd to 45 mmcfd * Liquid rates are from 50 BOLPD to 1200 BOLPD * maximum FTHP seen in this field is 2700psi * Flow times are 1-8 hrs ( some have been longer i.e. lower gas rate wells so we flow overnight to the satellite while tools are in the hole) * Erosion, to date, has not been a problem for the Halliburton equip ( monitored by yearly thickness test) No wellhead erosion problems that we are aware off Mark Wedman Operations Manager - Alaska Tool, Testing & TCP PSL Phone: 907-275-2610 Cell: 907-223-5763 = 0 ro o?""'\ ~~ r:fJ ro ro ~ ~ 0 ~~ Þ< ~ ...... 0 ....... ("I .0 '@" ~ (l) > 0 t) en s- O Rendezvous A Testing Plans Production Testing Objectives . Conduct a Safe and Environmentally Excellent Testing Operation . Determine Productivity and Type of Fluid Production . Obtain Quality Pressure Transient Data to Quantify Reservoir Parameters ajb 2/01 Rendezvous A Testing Plans Production Test Details . Complete Well without Tubing (5-1/2" L-80 Monobore) . Perforate Bottom 40' of Jurassic with E-Line Guns . Fracture Stimulate with - 200,000 lbs. 16/20 Carbo-Lite . Perform Coiled Tubing Clean-Out . Initiate Flowback Through Cyclone Sand Separator and Production Equipment ~- ------------------------- --~ - -- ---- -------~ ~~~~~ ~œ.,=> \.J,?~~Ck~~~~Ö ~~~\-rtCkM ajb 2/01 Rendezvous A Testing Plans Production Test Details (cant.) . Flow Well until Water Cleaned Up (24 to 48 hours) . Location is Manned 24 Hours a Day with 6 Well Testers per 12 Hour Shift, Service Company Supervisor, Operating Company Supervisor ~ \t>O ~\ ~r-~ \? . All Pressure Drops will Occur at the Cyclone Separator and the Choke ~ \\ \--\t ~ \~\Ñ \\"C¿~ . Perform Multi-Rate Testing Over 4 to 6 Days . Shut-In Well and Perform 4 to 6 Day PBU Test . P & A Wellbore and Cut Off Tree Below Ground Level ajb 2/01 Rendezvous A Testing Plans ", " . Monobore Completions . Common Practice Throughout the World for Production Applications . Numerous Examples of Fracturing and Flowback with High Rates . Wellhead Erosion is Not Documented as a Problem, All Pressure Drops Occur at the Choke . Rendezvous A Would be a Short Term Flow Test and the P & A'd ajb 2/01 ~KA OIL AND GAS CONSERYA~FION COPl~II$SION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-353g PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Paul Mazzolini Mr. Bill Lloyd Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 February 2, 2001 Re: Rendezvous 'A' PTD 200-054 Sundry Request to Re-enter, Stimulate and Flow Test Dear Messers Mazzolini and Lloyd: Your application and subsequent information regarding the proposed stimulation and flow testing of the subject well haS been reviewed. re-entery, At this time we cannot approve your plan to flow test the well without tubing and a packer. 20 AAC 25.200 (d) requires ..."All producing wells capable of unassisted flow must be completed with.., suitable tubing and a packer that effectively isolate the tubing- casing annulus..."..Although a basis for your request was stated in the subsequent information provided, we do not feel that removing the pressure restriction of the tubing to allow a higher production rate is a sufficient reason omit the tubing.and packer. Please contact either myself at 793-1228 or Tom Maunder at 793-1250 to discuss the matter. sincerely, J. M. Heusser Commissioner 08-03-00 12:24pm From-KUPARUK £NVIRONI~NTAL 007-659771Z T-139 P. ' ",. " NOTESi . 1, COORDINAT£S SHOWN ARI? ASP ZONE 4. ,. N,D-27. '. . 2. CEOgRAPHIC COORDINA~S ARE NADp27. 3. ELEVA~ONS SHOWN ARE B.P.M,S.L. ~. ALL OlSTAN~JS ARE~ TRUE. ~ ~,~ ~ ,. ~/~, rB. u ~-~ ~, . . ..- , , ,. . ~...: ~ : , ~~ ~ 5 RENDEZVOUS "A" n~_~[ ~~~1~ ~ UMIAT MERIDIAN. ., ~ ~~%~ ~Au ~ LAT. = 7&' 12 19.g18 ~~~ ~ ~ LONG, = 151' ~6' 47,4&3" ~~ ' E~NDE~VOUS ~ : ............... ~ X = 27g,252.g8 ~ -~ ~- 2~,~' r.S.L., ~ss' r.W,L, . ~ ~ ~ GROUND ELEVATION = 59.7 ~ ? ~ TOP OF ICE PAD = 61.8' 2~¢~25 SUR~YOR'S CERTiFICATE ~' ~ ~~ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND ~;~,;,.' *....~,~, LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ~~ ~:..~ ALASKA AND THAT THIS PLAT REPRESENTS A SURLY ;'. 'l T~A~ ~L~ D/.~NS/ONS ANO 0~ D~r~/~S A~E CO~ECT AS OF MARCH 29. 2~. · ~ ~e~ '-. ~e~5 / ~ ............. ,,: -.--' ee~J~ss~°"~- ' ~/JS[ ~ ASSOCIATES, INC. -- -- anllll i _, IIII II I AROO Alas a, ~lnc. ~o~zvous . EXPL~ATORY ~ C~DUCTOR Subsidiory of Atlantic ~ichfiel~ Compony AS-BUILT LOOA~ 2 SENT BY :ARCO ALASKA I NC · 1-30- 1 · 1' 38PM ;PRB RESOURCE DEVELOP-,. ..~ 907 276 7542'g 1/ 3 P hi l lip,,, ,s Alaska, In,,c,. 700 G Street~ Anchorage, AK 9950! FAX Number of pages including cove,r sheet: IIIIIII II Phone: CC: Wells Group Phone: ~-~ Fax phone: Location: RI~MARKS: [~ Urgent ["] For your review l~] Reply ASAP [-] Please comment SENT BY:ARCO ALASKA INC : 1-30-1 ;1:38P~1 ;PRB RESOURCE DEVELOP~ 907 276 7542;# 2/ 3 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETF~OLEUM COMPANY P. o. Box 100300 Anchorage, Alaska 99510-0360 January 30, 2001 Alaska Oil and Gas Conservation Commission Alaska Department of Administration 333 West Seventh Avenue Anchorage, AK 99501 Attention: Tom Maunder Subject: Rendezvous A Completion Sundry Addendum Spark #lA Flow Test and Pressure Build-Up Results Gentlemen: Thank you for the opportunity to provide additional background information regarding Phillips' Sundry application for a tubing-less test on Rendezvous A. Per your request is information obtained from the Spark lA test conducted last spring which supports evaluating the Rendezvous A reservoir via the 5-1/2" casing. Additional information from the Spark #lA Flow th , Test and Pressure Build-Up results was submitted to Mr. Jack Hartz on January 17 which may also prove beneficial for your review. All information contained herein is provided for purposes of Phillips Alaska, Inc.'s Rendezvous A Application for Sundry Approval submitted on January 22, 2001. All geological, geophysical, reservoir and engineering information provided to the Alaska Oil and Gas Conservation' Commission (AOGCC) for verification is provided under 20 AAC 25.537(b), is confidential, and shall not be disclosed to any other person or agency for any purpose without the express consent of Phillips Alaska, Inc. Please advise if you have any questions or require additional information. William B. floyd ~ [ Senior Exploration Dn--~l~g Engineer Enclosures cc: Rendezvous A wellfile Andrew Bond - ATO 1310 PHILLIPS Alaska, Inc. Is a Subsidla~y ot PHILLIPS PI~TROLEUM COMPANY 30 2001 SENT BY :ARCO ALASKA INC · 1-80- 1 ' l:88PM 'PRB RESOURCE DEVELOP~ 907 276 7542:# 3/ 3 Rendezvous A Well Test Reservoir Potential and Geological Summary In Rendezvous A, a sandy Jurassic interval about 105 feet thick was drilled at a depth of about 8,000 feet. Core was oblained over the upper 60 feet of the interval. Unfortunately, that upper part of the interval was tight, very-fine-grained, and mostly non-reservoir. Only three horizontal plugs displayed air permeabilities in excess of one millidarcy. Of those, the highest was 1.62 millidarcies. No core was obtained over the lower, slightly more permeable sands. Conclusions regarding reservoir quality outlined below are derived from log calculations. Using a porosity cutoff of 15% and a water saturation cutoff of 50%, about 37 feet of pay is calculated in the Rendezvous A well. For that 37 feet of pay the average porosity is 16.6%, the average permeability is 5.24 millidarcies, and the average water saturation is 24.9%. The Jurassic sandstone in Spark #lA is about 45 feet thick. No conventional core nor sidewall cores were obtained from this interval, but an RFT and brief test were conducted. Conclusions regarding reservoir quality outlined below are derived from log calculations, Using a porosity cutoff of 15% and a water saturation cutoff of 50%, about 31 feet of pay is calculated in Spark #lA. For that 31 feet of pay the average porosity is 16,7%, the average permeability is 5,57 millidarcies, and the average water saturation is 24.0%. The well tested 190 to 250 BOPD of 48.5 degree APl crude with a GOR of 10,000 to 12,500 cubic feet per barrel. Engineering Discussion The Jurassic interval is the only interval that will be flow tested. The well was temporarily suspended with 5-1/2" casing and cement plugs after last season. The plan is to reenter the well this season to complete, perforate, fracture stimulate and flow test,. The completion design hinges on the results of the Spark #lA flow test, It is anticipated that the Spark well will flow at 10,000 GOR post-fracture as it did during last season's one day flow test, The total production rates are estimated to be 15 to 20 MMSCFD and 1,500 to 2,000 BOPD. Our hydraulics calculations indicate that the well will become tubing limiled at approximately 20 MMSCFD. The Rendezvous A well contains a higher amount of interval thickness and net pay and is estimated to have potential to flow at 30+ MMSCFD. If the well is completed with the same tubing completion as the Spark well, we will not be able to evaluate the maximum flowing potential of the reservoir. Additionally, with the thicker reservoir interval, a higher treating rate during fracture stimulation is desirable in the Rendezvous well. Again, the smaller tubing size will limit treating rate due to friction. Fracturing and flowing the Rendezvous well in 5-1/2" casing will allow a much better evaluation of the reservoir potential. The expected treating pressure during the fracture treatment would be approximately 2,500 PSI (please see attached spreadsheet) with a maximum allowable treating pressure of 5,000 PSI. The reservoir pressure is estimated to approximately 3,780 PSI so the maximum shut-in tubing pressure would be approximately 3,500 PSI. The anticipated flowing tubing pressure is 1,000 PSI. The anticipated length of flow test would be 3 to 5 days, [Fwd: Proposed Re-entry Rendezvous A] Subject: [Fwd: Proposed Re-entry Rendezvous A] Date: Mon, 29 Jan 2001 08:50:54 -0900 From: Lou Grimaldi <lou_grimaldi@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, AOGCC To: Tom Maunder <tom_maunder@admin.state.ak.us> Hi Tom, It seems to me that these guys anticipated problems with the reg's, thats why they included the pipe data. ! talked to Chuck and we both feel they are trying to slip one past you. Lets talk. Lou Subject: Re: Proposed Re-entry Rendezvous A Resent-From: aogcc_prudhoe_bay@admin.state.ak.us Date: Sun, 28 Jan 2001 11:20:10-1000 From: "William B Lloyd" <WLLOYD@ppco.com> To: Tom Maunder <tom_maunder@admin.state.ak. us> CC: "Paul Mazzolini" <PMAZZOL@ppco.com>, AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state,ak. us> (d) All producing wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer that effectively isolate the tubing-casing annulus from fluids being produced, unless the commission specifically approves production through the annulus to increase flow rate without jeopardizing ultimate recovery from the well. Tom, I'm not certain what your email is concerned with regarding this portion of the regulations. It seems logical to me this reg .does not disallow a tubingless completion (i.e. if an exception to the reg for producing up the annulus is allowed then this is not a pressure concern issue, rather, as the regulation mentions, it is more concerned with the ultimate recovery- a moot point in an exploration test). As indicated in the sundry, the the production casing in the well is more than adequate in terms of yield for what we intend to do and the pressures that are anticipated. This well is anticipated to be a high GOR well but PA! does have concerns regarding fluid compositions. This test will allow us properly identify flow and fluid characteristics of the reservoir, a requirement of a prudent operator. I'll call you first thing Monday to discuss. Bill 1 of 2 2/1/01 2:29 PM [Fwd: Proposed Re-entry Rendezvous A] Tom Maunder <tom_maunder@admin.state.ak.us> on 01/27/2001 10:29:25 AM To: William B Lloyd/PPCO@Phillips cc: Paul Mazzolini/PPCO@Phillips, AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> Subject: Proposed Re-entry Rendezvous A Bill, I have been looking at your proposed procedure for the operations on this well. Please reference 20 AAC 25.200 (d) with regard to your plans. Thanks. Tom Maunder (See attached file: tom_maunder.vcf) Tom Maunder <tom maunder~admin.state.ak, us> i Petroleum Engineer ,I 2 of 2 2/1/O1 2:29 PM Re: Proposed Re-entry Rendezvous A ' Subject: Re: Proposed Re-entry Rendezvous A Date: Sat, 27 Jan 2001 23:19:32 -0900 From: Lou Gdmaldi <lou_grimaldi@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, AOGCC To: Tom Maunder <tom_maunder@admin.state.ak.us> Hi Tom, I read the well plan and wondered about a packer. The question is; will there be enough reom to run coil tubing inside the production string to kick it off? They may have screwed up by setting 5 1/2 liner and not something a little bigger. They can fit 3 1/2 inside but I dont know if there is a packer that will work in this case. They will probably have to go with I 1/2 or 1 3/4. It is going to be tight huh? Are they going to pressure test the annulus to make sure the casing is still good above the packer? So many questions, so little time!!!! Lou Tom Maunder wrote: > Bill, > I have been looking at your proposed procedure for the operations on > this well. Please reference 20 AAC 25.200 (d) with regard to your >> plans.Torn MaunderThanks' ~-~ '~-'~x\ % ~.,.~\~-~ ~ ~)o.e._~,z__r~--~ ~,'%~-~ louis Gfimaldi <lou, fldmaldi~admin.state.ak, us> I of I 2/1/01 2;29 PM January 27, 2001 1110 Look at PPCo 403 for Rendezvous A...(200-054)...(300-021)...pr0posal is to re-enter this suspended well to test...proposal to flow test without tubing or a packer...send procedure to slope to Lou and Chuck. January 29, 2001 1005 Place a call to Lou and Chuck on the slope Discuss proposed testing proposal for Rendezvous A... Lou believes there should be some casing tests February 2, 2001 1105 Bill Lloyd...how goes Rendezvous...told him we would not approve testing without tubing and a packer. What about annular flow? Has only been approved on LP wells in Cook Inlet. February 20, 1500 Meet with PPCo representatives regarding tubingless completion for Rendezvous A. Much 2001 better information than presented previously. They have done their homework. Jack and ! discussed with Julie... our recommendation is to allow them to proceed. Need to put some caviats in the approval. April 19, 2001 Bill Lloyd regarding P&A of Rondy A...265-6531---ieave message requesting text and drawing. April 20, 2001 0820 Call from Tom Brassfield regarding P&A of Rondy A...looking at using coil...would like to totally downsqueeze the annulus. April 22~ 2001 1530 Meet with Julie regarding abandonment Rondy A April 23, 2001 1700 Call from Tom Brassfield...operational issues on Rondy A...pumped cement through wrong valve. May 2, 2001 2155 Look at PPCo 403 for Rendezvous A...200-O54...301-101...proposal is to P&A the wellbore...procedure had been discussed previously...had problems with operation, but recovered...pass on for approval. May 5,' 2001 ' 1120 Finish printing off reports... JC... Rendezvous surface plug PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COrvlPANY P. O, BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 15, 2001 Daniel 3. Seamount, 3r., Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approval: Rendezvous'A' Surface Location: 2247' FSL, 1255' FWL, Sec. 24, T10N-R1E At Top Productive Tnterval: 2281' FSL, 1203' FWL, Sec. 24, T10N-RIE Bottom Hole Location: 2281' FSL, 1203' FWL, Sec. 24, T10N-RIE Dear Commissioner Seamount, PHTLL]:PS Alaska, ]:nc. hereby submits an Application for Sundry Approval to complete and test the referenced well, located in the National Petroleum Reserve - Alaska. The well was originally drilled, cased, and completed with ~2900' of tubing on Hay 5, 2000 as part of the 1999/2000 Exploration program. ]:ncluded with the Application for Sundry Approval is a program outline and wellbore schematic indicating the proposed well work and the current and final completion string. After pulling the existing tubing, the well will be perforated, frac stimulated and tested with via the 5-1/2" production casing. Based upon the test information obtained from the proposed Spark lA completion, Rendezvous 'A' may be completed via a 3-1/2" tubing string. Anticipated start date of operations is dependent upon approval of tundra opening and construction of the required ice road and ice pad and at this point, is approximated at February 11, 2001. The duration of the work is estimated at 14 days. The following are PH]:LL]:P's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 If you have any questions or require further information, please contact Bill Lloyd at (907) 265-6531 or Paul IVlazzolini at (907) 263-4603 Sincerely, ,,~/// //~ William B.~iLIoyd kk I Senior Dr'~ng Engine¥2 CC: CONFIDENTIAL - Rendezvous A Well File Paul Mazzolini ATO-1570 Andy Bond ATO-1310 RECEIVED JAN 2, 3 2001 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _X Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator 5. Type of Well: Phillips Alaska, Inc. Development_ 3. Address Exploratory _X P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service_ 4. Location of well at surface ~/' v/' "/" 2247' FSL, 1255' FWL, Sec. 24, T10N, R1 E, UM At top of productive interval 2281' FSL, 1203' FWL, Sec. 24, T10N, R1E, UM (ASP: 279201.6, 5927972.6) At effective depth At total depth 2281' 'FSL, 1203' FWL, Sec. 24, T10N, R1 E, UM (ASP: 279201.6, 5927972.6) 6. Datum elevation (DF or KB feet) RKB 25 feet 7. Unit or Property name Exploration NPRA 8. Well number Rendezvous A 9. Permit number / approval number 200-54 '"'" 10. APl number 50-103-20316 v 11. Field / Pool Exploration 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 83' Surface 2636' Production 8196' 107' 8353 feet Plugs (measured) 8352 feet 6109 feet Junk (measured) 6109 feet Size Cemented 16" 200 cu. Ft. 7.625" 253 sx AS I, 240 sx Class G 5.5" 140 sx Class G, 84 sx CemPlus 3.5" (included above) Measured Depth 108' 2661' 8221' 8328' True vertical Depth 108' 2661' 8221' 8328' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 3.5" @ 2893' no packer, no SSSV RECEIVED JAN 2 3 ZOO/ Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal __X Detailed operations program _ BOP sketch _X Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic 15. Status of well classification as: 14. Estimated date for commencing operation February 11,2001 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correcl to the best of my knowledge. Signed ~ Paul Mazzolini Conditions of approval: ..... .Approved by order of the Commission Questions? Call William Lloyd 265-655 Title: Drilling Team Leader Date Prepared b~, Sharon Al/sup-Drake FOR COMMISSION USE ONLY Notify Commission so represent~j,'ve may witness .~(~ ~ ~'t ~ ~%~ ~ Approval no. Plug in,egdty __ BOP Test ~ Location clearance _ ' I ~ [ -- 0 Mechanical Integri~ Test Subsequent fo~ required 10- ~ ~ ~ ~ ~ ~ ~'~ ~ _ ,, Commissioner Date ~...~~ ~ Form 10-403 Rev 06/15/88 · ORIGINAL SUBMIT IN TRIPLICATE WELL INFORMATION: RENDEZVOUS 'A' 2247' FSL, 1255' FWL, Sec 24, T10N-RIE (Surface) 2281' FSL, 1203' FWL, Sec 24, T10N-R1E (TD) APl No. 50-103-20316-00 OVERVIEW On May 4, 2000, operations on the referenced well were temporarily suspended as a result of the terminus of the winter exploration season. This suspension was in accordance with the Well Completion or Re-completion Report and Log, Form 10-403, as submitted on June 12, 2000. The well was completed with 2893' of 3-1/2", 9.3#/ft L-80 tubing landed in the tubing hanger. A diesel cap from 2000' MD to surface was left both inside the 3.5" tubing and in the 3.5" x 5.5" annulus and a BPV was set in the 3.5" tree. All flanges were blinded, the master and wing valves secured and handles removed and stored in KRU. The purpose of this Sundry Notice, is to commence completing and testing of the referenced well during the upcoming winter exploration season. The following outlines the proposed procedure for this program: 1) MIRU Nabors 19e. ND Tree, NU BOPE and test to 5000 psi. Provide 48 hours notice to regulatory agencies prior to testing BOPE. 2) Circulate out diesel from tubing and tubing x casing annulus. Pull and LD 2893' of tubing from well. PU 4.75" mill and RIH on 3.5" tubing. Drill out stage tool @ 6109' MD. Clean out to top of 3.5" stinger @ 8196' MD. Pressure test casing to 5000 psi. Circulate well to clean 9.5 ppg mud and POOH, laying down 3.5" tubing. 3) ND BOP, NU new 4.5" tree and test same to 5000 psi. Freeze protect well. RDMO Nabors 19e. 4) RU Schlumberger and run CBL log. Perforate well from 8130' - 8168' MD. 5) RU Dowell, NU tree saver and test to 5000 psi. Perform frac stimulation on open perfs down casing, limiting pressure to no more than 5000 psi at surface (see attached documentation from US Steel for 15.5#/ft L-80 characteristics). Maximum calculated treating pressure = 2500 psi. 6) RU and secure hardline and surface testing equipment to well to PAl and regulatory requirements. 7) RU CTU and perform clean out below perfs. 8) Open well to surface testing equipment; use nitrogen for additional kick-off support, if needed. 9) Flow well to clean up. Upon reaching stabilized conditions, flow test well for additional 2-4 days as necessary. Perform pressure build-up test(s) as necessary. 11) Rig down test equipment and secure well. The completion and testing procedure as outlined is dependent upon the results found during testing of Spark lA. Based upon those results, the Rendezvous 'A' frac and test may be done with a string of 3-1/2" tubing and a production packer. A separate sundry will be provided in the event that decision is made. A separate sundry as well as a completion report will be submitted at the conclusion of the test for appropriate follow-up well work. RE. CEIVED JAN 2 3 ZOO1 Naska Oil & Gas Cons. Commission Ar~chorar~le 'Rendezvous Current Casing & Completion Schematic - Eft. Date 5/5/2000 .. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 16" 65# H-40 @ +/- 80' MD Surface csg. 7-5/8" 29.7# L-80 BTC ( 2661' MD / 2661' TVD) Cemented to surface Production Casing 5-1/2" 15.5# L-80 BTCM (8222' MD / 8222' TVD) Est. cement top @ 4720' MD Production Stinger 3-1/2" 9.3# L-80 8rd EUE ( 8222' - 8328' MD) 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE 8RD Tubing to Surface (OE @ 2893' MD t Proposed Perfs: 8130' - 8168' MD RECEIVED JAN 2, 3 2001 Alaska Oil & Gas Cons. Commission Anchorage WBL, 01/09/01 NON STANDARD CASING Page 1 of 1 IMPORTANT NOTICE: This information should be checked by the engineer responsible for the design to insure its accuracy. U. S. Steel makes no express or implied warranty of any kind in respect either to the information furnished or the materials referred to or as to the suitability thereof for any particular application, use or purpose, and expressly disclaims any and all such warranties. Anyone making use of this information does so at their own risk and assumes full responsibility as to its suitability for the use intended and any and all liability resulting from such use. (Before printing this document be sure that your printer is set to Landscape mode) OD U.S. STEEL SEAMLESS CASING Wall NON-STANDARD CASE WT/FT 15.6 ,,, BUTTRESS JOINT WITH COUPLING OF SAME GRADE ' COLLAPSE JOINT STRENGTH PLAIN END MINIMUM INTERNAL MILL TEST YIELD STRENGTH YIELD PRESSURE (PSI) PRESSURE (PSI) FEET @ ** KIPS KIPS PIPE PIPE ~ 'PIPE GRADE 1.125 PSI FT@I.8 BODY JOINT II END [[ JOINT 'L-80 8880" 4990' 1.3860 '38'9 361 7000 7000 3000 6400 * 15.60 is estimated nominal WT/FT for T&C casing; ** Value calculated for this column is based on the WT/FT estimate above except for grade USS 95 15.346 is WT/FT for plain end casing. Pipe Wall = 0.275 IN. Coupling OD = 6.050 IN. Calculations are based on the following thread dimensions, interpolated from API 5B or supplied by the user: [Please reconcile final dimensions with calculated joint properties!!!] Length of perfect thread, L7 = Pitch diameter, E7 = Factor in formula 34, API 5C3,(6th edition), I = Factor in formula 34, API 5C3,(6th edition), T = Hand-tight standoff, A = 1.841 IN. 5.454 IN. 0.500 IN. 0.063 IN. 1.000 TURNS Copyright 1998 USX Corporation RECEIVED JAN P~ 3 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage http://www.usstubular.com/scripts/pbis a60.dll/c asdes/n_tp_c st_casc at/of_generate 12/22/00 11" 5000 psi BOP Sta'i ': Nabors Drilling Rig 19e NPRA Exploration I Kill Line 1 5 4 3 2 Choke Line BOP Stack Test 2. CheI 1. Fill BckOtPh~ttaaC;~haor;dd.dmoawninfO~cdreWiwths aWraet~ily retracted. Predetermine Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 5 minutes. Increase pressure to 5000 psi and hold for 10 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi for 5 minutes and 5000 psi for 10 minutes. Continue testing all valves, lines, and chokes with a 250 psi Iow for 5 minutes and 5000 psi high for 10 minutes. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi for 5 minutes and 5000 psi for 10 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi Iow for 5 minutes and 5000 psi high for 10 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 5000 psi for 10 minutes. 12. Test kelly cocks and inside BOP to 5000 psi for 10 minutes with BOP test pump. 13. Record test information on blowout preventer test form and on pressure chart. Sign and send to drilling engineer. 14. Perform BOPE test a) when initially installed, b) whenever any seal subject to test pressure is broken, c) following related repairs, and d) at 30 day intervals. Functionally operate BOPE daily. 15. Pit drills are to be conductled weekly for each drilling crew. RECEIVED JAN 2, 3 2001 Alaska 0il & Gas Cons. Commission Anchorage 1. 16" Starting Head 2. 11" 5000 psi Through Bore System Wellhead 3. 11" 5000 psi Hydril SGL Gate (pipe rams), 4-1/16" 5000 psi Side Outlets w/Manual Locks 4. 11" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate 2 Kill valves - one 2" 5000 psi Hydraulic gate and one 2" 5000 psi Manual gate 1 Check valve in Kill Line - 5000 psi 5. 11" 5000 psi Hydril Double Ram (pipe rams on top, blind on bottom), 4-1/16" 5000 psi Side Outlets w/ Manual Locks 6. 11" 5000 psi Hydril Annular Preventer, Flange Connection wbl Rev 01/15/01 MEMORANDUM TO: Dan Seamount, Chairman State of Alaska Alaska Oil and Gas Conservation Commission ~.~~-~ DATE: August 3, 2000 THRU: Blair Wondzell, ~ P. I. Supervisor L~o FROM' Lou Grimaldi, /.db G- Petroleum Inspector SUBJECT: Location Inspection Suspended Well Rendezvous A PTD #200-054 Wednesday, August 2~ 2000; I made a Location Inspection on the suspended exploratory well Rendezvous A. I was accompanied today by Lee Gooding (Phillips environmental tech) and Rick Overstreet (Phillips KRU drilling superintendent). We flew to the location by helicopter and verified proper location by G.P.S. Coordinates. Rendezvous A was drilled and suspended this last winter exploratory season. It is planned to production test this well next winter. Other than the test tree and guardrail around it, there were no indications of any drilling activity on this location. We flew the ice road path this was clean and seemed well vegetated. The following is bead-welded on a marker plate bolted to the test tree; PHILLIPS ALASKA INC. Rendezvous A PTD #200-54 APl 350-103-20316-00 SHL: 2247' FSL, 1255 FWL SEC 24, T10N, R1E UM SUMMARY: I made a Location inspection on Suspended well Rendezvous A. No problems were observed. Attachments: Loc Insp Rendezvous A 8-2-00 LG.xls Digital Photographs (2); Rendezvous tree.jpg Rendezvous tree 2.jpg Rendezvous airshot.jpg "As Built" for location cc: Phillip's Petroleum Co. NON-CONFIDENTIAL Loc Insp Rendezvous A 8-2-00 LG.doc 6I 13/00 Dc'c,. Schlumberger NO. 238 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print CD SIGNED: 1 C-26 99450 MEM GR/CCL 991030 1 ' I 1 lb-125 tJl[" 20248 SCMT 000529 1 , , -- 1D-137 20249 SCMT 000604 1 1D-138 " 20250 SCMT 000604 1 ,, ,, · .... ,,, ,, .... .... ~(~~/ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax tO (907) 561-8317.,J~Jil~Fl~u. RECEIVED dUN 27 2000 Alaska 0il & Gas Cons. C0mmissl0n PHILLIPS Alaska, Inc.I A Subsidiary of PHILLIPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO1354 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 DATE: 06/20/2000 Ak. Oil &Gas Conservation Comm. ATTN: Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99507 Transmitted herewith is the following: Spark 1 (501032031300) ,,~OO · O~::> q Sperry Sun CD ROM: MWD WELL data 44-8795ind; log date 4/4/2000; + 1 US verification tape listing ~r 1 reproducible and 1 blueline print each: Sperry Sun MWD DGR/EWR - TVD; end logging 4/4/2000 Sperry Sun MWD DGR/EWR/ROP - MD; end logging 4/4/2000 Sperry Sun MWD DGR/CTN/SLD - TVD; end logging 4/4/2000 Sperry Sun MWD DGR/CTN/SLD - MD; end logging 4/4/2000 Spark lA (501032031301) 300 · O~ CD ROM Schlumberger Dipole Sonic DT's 0-8360ind; logged 4/27/2000 ~ ~ ~ CD ROM Schlumberger Open Hole edits; DSI; FMI LDWG; 25'-8320'; log date 4/27/2000~x,- q ¢ Schlumberger Best DT Dipole Sonic (color log) DSI/USIT; date processed 6/1/2000 1, reproducible and 1 blueline print each Schlumberger Repeat Formation Tester; 4/23/2000; 8110-8145 Schlumberger GR/CCL W/Pressure/Temp; 5/3/2000; 7800-8200ind Schlumberger Packer Setting record 4/28/2000; 7850-8020ind Schlumberger Dipole Sonic Imager; cased hole 4/27/2000 Rendezvous A (501032031600) ~ DO. O ~ q Sperry Sun CD ROM: MWD WELL data; 122-8344ind; log date 4/28/2000 + 1 LIS verification tape listing i blueline print each: Sperry Sun MWD DGR/EWR/ROP; MD/TVD; end logging 4/12/2000 Sperry Sun MWD DGR/CTN/SLD; MD/TVD; end logging 4/12/2000 Core Lab Core Analysis Results - Rendezvous A - ~copies (each with 3 5" 0~,)/ce,.,& . floppy digital report copy) /. I CC: Mark McDermott Approved for trans..mittal by: Greg Wilson ~.,~ .~?.~ Receipt: ~L~,~ ~'/- ,,.--~-a~~ Date: Ret rn re I u ceipt to: /hillips Alask01nc. ~TTN: S, Lemke, ATO-1354 700 G. Street Anchorage, AK 99501 Naska Oil &¢as Cons. Coffimission Prepared by: ~~ Lemke Phillips Alaska IT Geoscience Group PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Paul Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 June 20, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for Rendezvous A - Confidential Dear Mr. Commissioner: On behalf of itself and Anadarko, Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached Report of Sundry Well Operations for the exploration well Rendezvous A, Drilling Permit No. 200-54 / 300-116 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the use of the Commission in carrying out its duties, we question whether any future disclosure to DNR or the public would be appropriate or valid. However, it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, so that we may be heard on the issue. Please disregard the Completion Report (AOGCC form 10-407) sent earlier in June. The attachments to the Completion Report can be attached to this Sundry. If you have any questions regarding this matter, please contact me at 263.4603 or James Trantham at 265.6434. Sincerely, Paul Mazzolini Exploration Drilling Team Leader ' PA1 Drilling 2 2 2000 Gas Cons. Oom~ais,sion STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Pull tubing _ 2. Name of Operator: Phillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: Stimulate__ Plugging _ Perforate _ Alter casing_ Repair well_ Other_ Type of Well: Development Exploratory .X Stratagrapic _.~ Service __~ 6. Datum of elavation (DF or KB feet): 25' RKP 7. Unit or Property: Exploration NPRA 8. Well number: 2247' FSL 1255' FWL Sec. 24, T10N, R1E, UM(ASP: 279253, 5927938.5 At top of productive interval: 2281' FSL, 1203' FWL, Sec. 24, T10N, R1E, UM (ASP: 279201.6, 5927972.~: At effective depth: At total depth: 2281' FSL, 1203' FWL, Sec. 24, T10N, R1 E, UM (ASP: 279201.6, 5927972.~: 12. Present well condition summary Rendezvous A 9. Permit number/approval number: 200-54 / 300-116 10. APl number: 50-103-20316 11. Field/Pool: Exploration Total Depth: measured 8353' Plugs (measured) true vertical 8352' Effective Deptt measured 6109' Junk (measured) true vertical 6109' ORIGINAL Casing Length Size Cemented Conductor 83' 16" 200 cu. Ft, Surface 2636' 7.625" 253 sx AS I & 240 sx Class G Production 8196' 5.5" 140 sx Class G & 107' 3.5" 84 sx CemPlus Liner Measured depth 108' 2661' 8221' 8328' True verticaldepth 108' 2661' 8220' 8327' Perforation Depth measured N/A true vertical N/A Tubing (size, grade, and measured depth) 3,5", 9.3#, L-80 @ 2893' Packers and SSSV (type and measured depth) N/A 13, Stimulation or cement squeeze summary Intervals treated (measured~ N/A Intervals treated (measured) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A Subsequent to operation 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ Oil _ Gas _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,~/~~~,~.~ Title: "~R,L~ Suspended _X Service _ Date O~'/2~/oo Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE CORE LABORATORIES .200. CORE ANALYSIS RESULTS ARCO ALASKA, INC. "RENDESVOUS" A COLVILLE RIVER-SW FIELD UMIAT MERIDIAN; ALASKA RECEIVED JUN 22 2000 Alaska 0il & Gas t.;urm. ~t)mmission Anchorage Performed by: Core Laboratories 3430 Unicorn Road Bakersfield, CA 93308 (805) 392-8600 Final Report Presented June 7, 2000 The analyhCal results, opinions or Interpretations contained ~n this report are based upon Ir'~format*on and material supplied by the client for whose exclusive and confidential use this report has been made Tho analyt=csl results, oplmons or ~marore~a r,ors expressed represent tho best judgment of Core Laboralonos. Core Laboratories, however, makes no warranty or representation, express or implied, of any type. and expressly disclaims same as to the producPvlW, proeer eoer~3ttons or OroflfaU er~ess c.f any oil gas. coal or oilier m~neral, properly, wal~ or sand m connection wdh which Such report Is used or relied upon for any reason whatsoever. This report shaJl not bo reproduced, in wtlole or in p;~l't, Wltllout tho writton spprOVal of Core Laoor~4;or t;ff; TABLE OF CONTENTS SECTION DESCRIPTION OF SERVICES CORE ANALYSIS - TABULATED RESULTS HYDRAULIC UNIT CLASSIFICATION PROFILE PERMEAMETER 4 INTRODUCTION Core Laboratories was selected by Arco Alaska Inc. to perform a core analysis study upon samples recovered from the subject well. Conventional aluminum inner barrel cores were submitted. The detailed protocol for both field and laboratory handling and analysis provided by ARCO Alaska was adhered to throughout the project. Only a condensed summary of the requested tests and procedures is included in this report. This report is divided into four sections. The first section provides a description of services. Section 2 contains tabulated results of porosity, permeability, and fluid saturation determinations. Section 3 presents the reservoir quality index (RQI), flow zone indicator (FZI), and hydraulic unit determinations for each sample. Results of pressure-decay profile permeameter measurements performed upon the slabbed core are presented in the final section. In conjunction with the report, results of analysis are supplied on diskette in Excel format. CORE PROCESSING Cores were handled in the field, and all core processing performed by Core laboratories personnel from our Anchorage office. Core Gamma Surface Log Each core was scanned for natural gamma radiation utilizing Corelab's gamma spectrometer. Total gamma radiation is reported in APl units. Core Sampling and Slabbing The core was slabbed parallel to the core axis utilizing a 1/2 - 1/2 cut. Liquid nitrogen was used as the blade coolant. For photography, viewing, description and additional sample selection by ARCO's representatives the 1/2 sections were placed into slab boxes with Styrofoam inserts. Sample Preparation Both horizontally and vertically oriented one-inch diameter plugs were drilled from each foot of core. Isopar mineral oil was used as the bit coolant and lubricant. Each plug was weighed, wrapped with Saran wrap and aluminum foil, and sealed in a sample jar as drilling was completed. Upon completion of the sampling all plugs were packaged and shipped to our Bakersfield California facility. ANALYSIS TECHNIQUES Fluid Extraction Samples taken with horizontal orientation were weighed and placed into tared extraction thimbles. Water and oil were extracted from the sample plugs by Dean Stark methods with toluene as the solvent. The plugs were held in the Dean Stark extractors for a minimum of forty-eight hours and were removed only after no additional water was recovered in the receiving tubes. Complete hydrocarbon extraction was conducted using soxhlet extractors with methylene chloride as the solvent. Cleaned samples were removed from the soxhlets, dried in a convection oven at 180°F for four hours. Samples were then dried in a vacuum oven at 180°F for a minimum of twenty-four hours. Following the vacuum-oven drying, the sample weights were monitored for stability. Upon weight stabilization sample plugs were transferred to a desiccator and cooled to laboratory temperature pdor to analysis. Samples designated for vertical permeability determinations were "batch" cleaned in large Dean Stark extractors with toluene to remove water and then transferred to soxhlet extractors for batch cleaning with methylene chloride. Drying was performed as for the horizontal plugs prior to permeability measurements. Grain Density Determinations Grain volumes were determined using a Boyle's Law extended range helium porosimeter. Metal jacket and end-screen weight and volume corrections were applied to the jacketed samples. Grain density was calculated using Equation 1. 5ma = (1) Where: 8ma = Mg = vg = Matrix / grain density (g/cc) Grain mass (g) Grain volume (cc) Confining Pressure for Porosity and Permeability Measurements Following grain volume determinations, the plug samples were placed into a Hassler-type holder and a confining pressure was applied for porosity and permeability measurements. A confining pressure of 400 psig was used, which is essentially "ambient" conditions, preventing gas by-pass but not acting to compress the sample. Porosity Determination Direct pore volume measurements were performed upon confined samples utilizing Boyle's Law double-cell methods. Porosity values were calCulated using Equation 2. (2) Where: ~ = Porosity (%) Vp = Pore volume (cc) Vg = Grain volume (cc) Fluid Saturation Calculations Oil and water saturation results were calculated using Equations 3 and 4. SO -- ~ * 100 (3) Sw = (4) Where: So = Sw = Mf = Md = Mw Vw = 50 = Vp = Oil saturation (%) Water saturation (%) Fresh sample mass (g) Extracted and dried sample mass (g) Extracted water mass (g) Extracted water volume (cc) Density of oil Pore volume (cc) Permeability to Air Permeability determinations were made following the pore volume determinations again with the samples confined in Hassler-type holders. Permeability values were calculated utilizing Darcy's Equation for compressible fluids, Equation 5. Ka = I (?a · vg, 1000) APoP , I.Qa__~ L2 (5) Where: Ka = Permeability to air (md) Pa = Atmospheric pressure vg = Gas viscosity (cp) AP = Differential pressure P = Mean pressure Qa = Flow rate (cc/sec) L = Length (cm) Vb = Bulk volume (cc) Hydraulic Unit Analysis After rock property measurements had been completed, a hydraulic unit analysis was performed. Reservoir quality index (average pore throat size) and pore ratio values were calculated for each sample using Equations 6 and 7. RQI = 0.0314 · (6) PR = Where: RQI = Reservoir quality index Ka = Permeability to air (md) ~ = Fractional porosity PR = Pore ratio RQI and PR values determined for each sample are utilized to assign each foot of core to a hydraulic unit. Each hydraulic unit represents a unique pore geometry relationship and provides a foundation for the integration of core and electric log data. To facilitate selection of representative samples for additional testing, hydraulic unit classifications are presented both sorted by sample depth and by hydraulic unit. Pressure-decay Profile Permeameter (PDPK) The PDPK determines permeability of a sample by unsteady-state methods using a transient "blowdown" technique. A tank of known volume is first filled with nitrogen and then the gas is discharged through the core sample to atmosphere. The decaying tank pressure is monitored versus time, which allows determination of gas flow rate and pressure drop across the sample at any given time. The automated recording of flow rate versus pressure differential provides the data necessary for calculation of a Klinkenberg-corrected permeability as well as the permeability to air. The results of analysis are reported in tabular format and are presented on diskette in Excel format. Sample Disposition End-trimmings from both the horizontal and vertical plug samples were ~batch" cleaned using toluene followed by methylene-chloride as the solvents. The cleaned trimmings were forwarded to Geologics in Piano Texas for thin-section preparation. Upon completion of analysis all sample plugs will be packaged and held pending ARCO's final disposition instructions. ARCO ALASKA, INC: "RENDESVOUS" A COLVILLE RIVER-SW FIELD CL File No.: 57111 - 00094 CORE ANALYSIS RESULTS SamPie' DePth Permeability (Kai~) porOsity sa~rations Grain Description No. Horiz. Vert. ,He, Oil ! Water I 0/W' ! Total Density- - - ff. ,, md, ,md % , %Ill, % - Ratio % N/cc ....... Permeability and porosity measured using 480 pslg confining pressure. I 8065.1 0.09 0.05 13.6 22.2 45.0 0.49 67.2 2.68 Sst gry-lt tan vfgr vsity carb strks It s 2 8066.2 0.09 0.05 14.0 6.1 57.7 0.11 63.9 2.68 Sst gry-lt tan vfgr vslty carb strks It s 3 8067.2 0.12 0.06 16.6 8.0 46.9 0.17 54.9 2.69 Sst gry-lt tan vfgr vslty carb strks It s 4 8068.1 0.17 0.10 16.6 t0.0 43.6 0.23 53.6 2.68 Sst gry-lt tan vfgr vslty carb strks It s 5 8069.1 0.27 0.20 18.7 10.3 35.4 0.29 45.7 2.67 Sst gry-lt tan vfgr vslty carb strks It s 6 8070.1 0.26 0.17 t7.8 1.9 40.5 0.05 42.4 2.68 Sst gry-lt tan vfgr vslty carb strks It s 7 8071.1 0.25 0.16 17.2 8.8 41.1 0.21 49.9 2.68 Sst gry-lt tan vfgr vslty carb strks .It s 8 8072.1 0.20 0.15 17.2 11.1 40.8 0.27 51.9 2.68 Sst gry-it tan vfgr vslty carb strks It s 9 8073.1 0.22 0.24 17.4 8.7 40.6 0.21 49.3 2.68 Sst gry-lt tan vfgr vslty carb strks It s 10 8074.1 0.39 0.34 18.5 11.8 30.5 0.39 42.4 2.68 Sst gry-lt tan vfgr vslty carb strks It s 11 8075.1 0.09 0.06 13.5 8.2 51.8 0.16 60.0 2.69' Sst gry-lt tan vfgr vslty carb strks It s 12 8076.1 0.24 0.17 17.0 19.8 32.0 . 0.62 51.8 2.68 Sst gry-lt tan vfgr vslty carb strks It s 13 8077.1 0.30 0.24 17.3 15.6 33.3 0.47 48.9 2.68 Sst gry-lt tan vfgr vslty carb strks It s 14 8078.1 0.29 0.31 18.5 14.1 32.4 0.43 46.5 2.69 Sst gry-lt tan vfgr vslty carb strks It s 15 8079.1 0.22 0.19 17.8 24.2 25.8 0.94 50.0 2.72 Sst gry-lt tan vfgr vslty carb strks It s 16 8080.1 0.20 0.18 17.3 9.9 35.8 0.28 45.7 2.69 Sst gry-lt tan vfgr vslty carb strks It s 17 8081.1 0.19 0.14 16.1 36.4 21.9 1.66 58.4 2.70 Sst gry-lt tan vfgr vslty carb strks It s 18 8082.1 0.25 0.20 17.0 24.6 25.5 0.96 50.1 2.68 Sst gry-lt tan vfgr vslty carb strks It s 19 8083.1 0.27 0.16 17.2 34.1 15.5 2.20 49.6 2.67 Sst gry-lt tan vfgr vslty carb strks 20 8084.1 0.32 0.20 17.3 4.6 37.6 0.12 42.3 2.68 Sst gry-lt tan vfgr vslty carb strks 21 8085.1 0.24 1.51 16.8 10.1 41.1 0.25 51.2 2.68 Sst gry-lt tan vfgr vslty carb strks 22 8086.1 0.38 0.20 17.4 9.0 37.1 0.24 46.1 2.68 Sst gry-lt tan vfgr vslty carb strks 23 8087.1 0.42 0.29 18.1 11.2 33.4 0.34 44.5 2.68 Sst gry-ll tan vfgr vslty carb strks 24 8088.1 0.30 0.56 16.8 11.1 37.8 0.29 48.9 2.68 Sst gry-lt tan vfgr vslty carb strks 25 8089.1 0.39 0.14 16.5 9.7 34.9 0.28 44.6 2.68 Sst gry-lt tan vfgr vslty carb strks 26 8090.1 0.29 0.18 17.6 11.7 38.5 0.30 50.2 2.68 Sst gry-lt tan vfgr vslty cart) strks )td stn wh-no )td stn wh-no )td stn wh-no ~td stn wh-no ~td stn wh-no :)rd stn wh-no 3rd stn wh-no 3td stn wh-no 3rd stn wh-no )td stn wh-no 3rd stn wh-no 3td stn wh-no ~td stn wh-no 3td stn wh-no 3td stn wh-no 3td stn wh-no 3rd stn wh-no )td stn wh-no it s )td stn wh-no It s )rd stn wh-no sh It sptd stn wh- sh It sptd stn wh- sh It sptd sin wh- sh It sptd stn wh- sh It sptd stn wh- sh It sptd stn wh- Horiz. and Vert. sample depths may differ slightly. Page I Core Analysis Results ARCO ALASKA, INC~ "RENDESVOUS" A COLVILLE RIVER-SW FIELD CL File No.: 57111 - 00094 CORE ANALYSIS RESULTS Sample Depth Pmmeability (Kair) Porosity Saturations Grain Description No. eoriz. ~ Vert. (He) Oil I Wate'rl' o/W I T°t~l Density ff md md % , o,,~ !, % ! Ratio J % g/cc D .... kmty and porosity measured using 400 pslg confining pressure. ' ' ' 27 8091.1 0.16 0.09 15.8 13.6 43.9 0.31 57.5 2.68 Sst gry-lt tan vfgr vslty cart) 28 8092.1 0.12 0.08 13.5 16.3 48.3 0.34 64.6 2.69 Sst gry-lt tan vfgr vslty carb 29 8093.1 0.20 failed 17.3 11.9 37.7 0.32 49.6 2.68 Sst gry-lt tan vfgr vslty carb 30 8095.1 0.34 0.31 17,9 11,1 34.6 0,32 45.7 2.68 Sst gry-lt tan vfgr vslty carb 31 8096.1 0.20 0.09 16.4 10.8 36.2 0.30 47.0 2.69 Sst gry-lt tan vfgr vslty carb 32 8097.1 0.20 0.10 16.1 9.9 40.0 0.25 49.9 2.71 Sst gry-lt tan vfgr vslty cart) 33 8098.1 0.22 0.16 16.5 8.7 38.6 0.23 47.3 2.69 Sst gry-lt tan vfgr vslty carb 34 8099.1 0.40 0.18 18.5 10.0 37.5 0.27 47.4 2.69 Sst gry-lt tan vfgr vslty carb 35 8100.1 0.37 0.19 17.6 13.0 36.0 0.36 49.0 2.69 Sst gry-lt tan vfgr vslty carb 36 8101.1 0.31 0.20 17.5 11.3 35.3 0.32 46.6 2.69 Sst gry-lt tan vfgr vslty carb 37 8102.5 0.22 0.12 17.3 8.5 38.8 0.22 47.3 2.69' Sst gry-lt tan vfgr vslty carb 38 8103.7 0.31 0.18 17.3 7.1 45.9 - 0.16 53.1 2.68 Sst gry-lt tan vfgr vslty carb 39 8104.1 0.20 0.12 16.7 10.3 40.6 0.25 50.8 2.69 Sst gry-lt tan vfgr vslty carb 40 8105.1 0.25 0.19 17.2 9.5 40.9 0.23 50.5 2.69 Sst gry-lt tan vfgr vslty carb 41 8106.1 0.17 0.05 17.8 10.0 43.0 0.23 53.0 2.69 Sst gry-lt tan vfgr vslty carb 42 8107.1 0.16 0.14 16.9 14.8 42.5 0.35 57.3 2.69 Sst gry-lt tan vfgr vslty carb 43 8108.1 0.29 0.15 17.0 12.8 37.4 0.34 50.2 2.68 Sst gry-lt tan vfgr vslty carb 44 8109.1 0.32 0.26 18.2 15.3 37.3 0.41 52.7 2.68 Sst gry-lt tan vfgr vslty carb 45 8110.1 0.45 0,72 16.5 9.6 42.2 0.23 51.8 2.68 Sst gry-lt tan vfgr vslly carb 46 8111.1 0.40 0.49 17.0 8.2 42.8 0,19 50.9 2.68 Sst gry-lt tan vfgr vslty carb 47 8112.1 1.62 2.47 17.3 11.9 38.3 0.31 50.2 2.86 Sst gry-lt tan vfgr vslty carb 48 8113.1 0.88 0.57 17.4 11.5 37.9 0.30 49.4 2.67 Sst g~/-It tan vfgr vslty carb 49 8114.1 1.36 1.04 18.3 12.4 31.7 0.39 44.1 2.67 Sst gry-lt tan vfgr vslty carb 50 8115.1 0,72 0.38 17.8 10.4 36.9 0.28 47.3 2.68 Sst gry-lt tan vfgr vslty carb 51 8116.1 0.27 0.20 16.4 7.6 37.6 0.20 45.2 2.69 Sst gry-lt tan vfgr vslty carb 52 8117.1 0.47 0.20 16.5 4.5 31.9 0.14 36.4 2.68 Sst gry-lt tan vfgr vslty carb strks sh It sptd stn wh- strks sh It sptd stn wh- strks sh It sptd stn wh- strks sh It sptd stn wh- strks sh It sptd stn wh- strks sh It sptd stn wh- strks'sh It sptd stn wh- sh it sptd stn wh-no flL sh It sptd stn wh-no flL sh It sptd stn wh-no fl[ sh It sptd stn wh-no fit sh It sptd stn wh-no fl[ sh It sptd stn wh-no fl~ sh It sptd stn wh-no fl[ sh It sptd stn wh-no fl~ sh It sptd stn wh-no fl~ sh It sptd stn wh-no fl~ sh It sptd sin wh-no flL sh It sptd sin wh-no flL sh It sptd stn wh-no fl[ sh It sptd stn wh-no fl~ sh It sptd sin wh-no fl~. sh It sptd stn wh-no fl~ sh It sptd stn wh-no fit sh It sptd stn wh-no fl~ sh It sptd stn wh-no flL Horiz. and Vert. sample depths may differ slightly. Page 2 Core Analysis Results ARCO ALASKA, INC~ "RENDESVOUS" A COLVILLE RIVER-SW FIELD CL File No. ' 57111 - 00094 CORE ANALYSIS RESULTS san~pl~ D~i~th PermeabilitY (Kair)'' PoroSity ' ' satu'raflons Grain' Description ' No. Ho.z; VerL (He) 0ii ' ! Wat~'i O/W I Totai Density .... . . ..ft,. md .. md . , .% %! i i.% .RaUo, % .,. ~Jc¢ ....... 53 8118.1 0.44 0.30 16.9 10.3 31.8 0.32 42.2 2.68 54 8119.1 0.11 0.08 14.3 10.6 32.9 0.32 43.5 2.69 55 8120.1 1.18 0.50 20.4 10.4 27.5 0.38 37.8 2.68 56 8121.1 0.19 0.20 15.2 14.9 25.3 0.59 40.2 2.70 57 8122.1 0.21 0.06 15.6 9.7 30.4 0.32 40. t 2.70 58 8123.1 0.61 0.78 18.1 10.2 22.8 0.45 33.0 2.68 59 8124.1 0.62 0.39 17.8 13.4 21.0 0.64 34.4 2.68 Sst gry-lt tan vfgr vsity carb sh It sptd stn wh-no fl[ Sst gry-lt tan vfgr vslty carb sh It sptd stn wh-no fi[ Sst gry-lt tan vfgr vslty carb sh It sptd sin wh-no fl[ Sst gry-lt tan vfgr vslty carb sh It sptd sin wh-no fl[ Sst gry-lt tan vfgr vslty carb sh It sptd stn wh-no fk Sst gry-lt tan vfgr vslty carb sh It sptd stn wh-no fl~ Sst gry-it tan vfgr vslty carb sh It sptd stn wh-no fl[ Horiz. and Vert. sample depths may differ slightly. Page 3 Core Analysis Results ARCO ALASKA, INC. "RENDESVOUS" A COLVILLE RIVER-SW FIELD VERTICAL PERMEABILITY CL File No.: 57111 - 00094 Sample No. 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 26 27 28 Sample Depth fl Permeability Vert. md Description 8065.2 8066.1 8o67.1 8068.2 8069.2 8070.2 8071.2 8072.2 8073.2 8074.2 8075.2 .8076.2 8077.2 8o78.2 8079.2 8080.2 8o81.2 8o82.2 8083.2 8084.2 8O85.2 8086.2 8O87.2 8088.2 8089.2 8090.2 8091.2 8092.2 0.05 0.05 0.06 0.10 0.20 0.17 0.16 0.15 0.24 0.34 0.06 0.17 0.24 0.31 0.19 0.18 0,14 0.20 0.16 0.20 1.51 0,20 0.29 0.56 0.14 0.18 0.09 0,08 Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-it Sst gry-lt Sst gry-lt Sst gry-it Sst gry-it Sst gry-lt Sst gry-lt Sst gry-it Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gpj-lt Sst gry-it Sst gry-it Sst gry-it Sst gry-lt Sst gry-lt Sst gry-it Sst gry-lt tarl vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr tan vfgr vslty carb it sptd stn wh-no flu vsity carb It sptd stn wh-no flu vslty carb It sptd stn wh-no flu vslty carb It sptd stn wh-no flu vslty carb it sptd stn wh-no flu vslty carb it sptd stn wh-no flu vslty carb It sptd stn wh-no flu vslty carb it sptd stn wh-no flu vsity carb it sptd stn wh-no flu vslty carb it sptd stn wh-no flu vslty carb It sptd stn wh-no flu vslty carb It sptd stn wh-no flu vslty carb It sptd stn wh-no flu vslty carb It sptd stn wh-no flu vslty carb It sptd stn wh-no flu vslty carb it sptd stn wh-no flu vslty carb It sptd stn wh-no flu vslty carb It sptd stn wh-no flu vslty carb It sptd stn wh-no flu vslty carb It sptd stn wh-no flu vsity carb sh It sptd stn wh-no flu vslty carb sh It sptd stn wh-no flu vslty cart) sh It sptd stn wh-no flu vslty carb sh It sptd stn wh-no flu vslty carb sh It sptd stn wh-no flu vslty carb sh It sptd stn wh-no flu vslty carb sh It sptd stn wh-no flu vslty carb sh It sptd stn wh-no flu Page 6 VERT. PERMEABILITY ~'~"'~' !- "RENDESVOUS"A .~~.'. COLVILLE RIVER-SW FIELD Sample No. Sample Depth fl 29 8093.2 30 8095.2 31 8096.2 32 8097.2 33 8098.2 34 8099.2 35 8100.2 36 8101.2 37 8102.6 38 8103.8 39 8104.2 40 .8105.2 41 8106.2 42 8107.2 43 8108.2 44 8109.2 45 8110.2 46 8111.2 47 8112.2 48 8113.2 49 8114.2 5O 8115.2 51 8116.2 52 8117.2 53 8118.2 54 8119.2 55 8120.2 56 8121.2 CL File No,: 57111 - 00094 VERTICAL PERMEABILITY Permeability Vert, md Description failed 0.31 0.09 0.10 0.16 0.18 0.19 0.20 0.12 0.18 0.12 0.19 0.05 0.14 0.15 0.26 0.72 0.49 2.47 0.57 1.04 0.38 0.20 0.20 0.30 0.08 0.50 0.20 Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-it Sst gry-it Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-it Sst gry-it Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt Sst gry-lt tan vfgr vslty carb sh it s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh it s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It S tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh It s tan vfgr vslty carb sh it s tan vfgr vslty carb sh It s tan vfgr vslty carb sh it s tan vfgr vslty carb sh It s 3rd stn wh-no flu 3td stn wh-no flu 3td stn wh-no flu 3td stn wh-no flu 3td stn wh-no flu ~td stn wh-no flu ~td stn wh-no flu )td stn wh-no flu )rd stn wh-no flu )td stn wh-no flu )rd stn wh-no flu )td stn wh-no flu )td stn wh-no flu )rd stn wh-no flu )td stn wh-no flu ~td stn wh-no flu )rd stn wh-no flu )td stn wh-no flu ~td stn wh-no flu )td stn wh-no flu ~td stn wh-no flu 3td stn wh-no flu ~td stn wh-no flu ~td stn wh-no flu 3td stn wh-no flu 3td stn wh-no flu 3td stn wh-no flu ~td stn wh-no flu Page 7 VERT. PERMEABILITY ARCO ALASKA, INC. "RENDESVOUS" A COLVILLE RIVER-SW FIELD CL File No. · $7111 - 00094 VERTICAL PERMEABILITY Sample No. 57 58 59 Sample Depth ft Permeability Vert. md Description 8122.2 8123.2 8124.2 0.06 0.78 0.39 Sst gry-lt tan vfgr vsity carb sh It sptd stn wh-no flu Sst gry-lt tan vfgr vslty carb sh It sptd stn wh-no flu Sst gry-it tan vfgr vslty carb sh It sptd stn wh-no flu Page 8 VERT. PERMEABILITY ARCO ALASKA, INC. "RENDESVOUS" A COLVILLE RIVER-SW FIELD CL File No.: 57111 - 00094 HYDRAULIC UNITS 'SORTED BY SAMPLE'DEPTH"' Dep~ ' 'FIo~ Reservoir HydrauliC Zone Quality Unit , (ft). Indic, at, pr Index , , . 8065.1 0.1608 0.025 7 8066.2 0.1498 0.024 7 8067.2 0~1357 0.027 7 8068.1 o. 1597 0.032 7 8069.1 o. 1623 0.037 7 8070.1 0.1758 0.038 7 8071.1 o. 1837 0.038 7 8072.1 0.1648 0.034 7 8073.1 0.1686 0.036 7 8074.1 . 0.2020 0.046 7 8075.1 o. 1682 0.026 7 8076.1 0.1804 0.037 7 8077.1 0.1973 0.041 7 8078.1 0.1726 0.039 7 8079.1 0.1615 0.035 7 8080.1 0.1594 0.033 7 8081.1 0.1786 0.034 7 8082.1 0.1862 0.038 7 8083.1 0.1905 0.040 7 8084.1 0.2027 0.042 7 8085.1 o. 1851 0.037 7 8086.1 0.2204 0.046 8 8087.1 0.2149 0.048 8 8088.1 0.2095 0.042 8 8089.1 0.2436 0.048 8 8090.1 0.1889 0.040 7 - SORTED BY'HYD. UNIT" 'Depth' " Flow I~eservoir 'Hydraulic Zone Quality Unit , (,ft) I.,ndi .cato. r Index . 8065.1 0.1608 0.025 7 8066.2 0.1498 0.024 7 8067.2 0.1357 0.027 7 8068.1 0.1597 0.032 7 8069.1 0.1623 0. 037 7 8070.1 0.1758 0.038 7 8071.1 0.1837 0.038 7 8072.1 0.1648 0.034 7 8073.1 0.1686 0.036 7 8074.1 0.2020 0.046 7 8075.1 0.1682 0.026 7 8076.1 0.1804 0.037 7 8077.1 0.1973 0.041 7 8078.1 0.1726 0.039 7 8079.1 0.1615 0.035 7 8080.1 0.1594 0.033 7 8081.1 0.1786 0.034 7 8082.1 0.1862 0.038 7 8083.1 0.1905 0.040 7 8084.1 0.2027 0.042 7 8085.1 0.1851 0.037 7 8090.1 0.1889 0,040 7 8091.1 0.1664 0.031 7 8092.1 0.1886 0.030 7 8093.1 0.1633 0.034 7 8095.1 0.1976 0.043 7 Page 8 ttYDRAULIC UNIT9 ..~ ARCO ALASKA, INC. "RENDESVOUS" A ~~. COLVILLE RIVER-SW FIELD CL File No. · 57111 - 00094 HYDRAULIC UNITS SORTED BY SAMPLE DEPTH " "0epth ' ,Fi~W Reservoir Hydraulic Zone Quality Unit (fi) ,, indicator Index 8091.1 0.1664 0.031 7 8092.1 0.1886 0.030 7 8093.1 0.1633 0.034 7 8095.1 0.1976 0.043 7 8096.1 0.1773 0.035 7 8097.1 o. 1838 o. 035 7 8098.1 o. 1822 0.036 7 8099.1 0.2032 0.046 7 8100.1 0.2124 0.045 8 8101.1 .0.1975 0.042 7 8102.5 0.1706 0.036 7 8103.7 0.2001 0.042 7 8104.1 0.1732 0.035 7 8105.1 0.1821 0.038 7 8106.1 0.1423 0.031 7 8107.1 0.1495 0.030 7 8108.1 0.1990 0.041 7 8109.1 0.1859 0.041 7 8110.1 0.2616 0.052 8 8111.1 0.2363 0.048 8 8112.1 0.4594 0.096 9 8113.1 0.3347 0.071 8 8114.1 0.3824 0.086 9 8115.1 0.2901 0.063 8 8116.1 0.2059 0.040 7 8117.1 0.2692 0,053 8 SORTED BY'HYD. UNIT Depth FlOw ReservOir Hydraulic Zone Quality Unit (fi), , ,Indicator ., ,Index .... 8096.1 0.1773 0.035 7 8097.1 0.1838 0,035 7 8098.1 o. 1822 0.036 7 8099.1 0.2032 0.046 7 8101.1 0.1975 0.042 7 8102.5 0.1706 0.036 7 8103.7 0.2001 0.042 7 8104.1 0.1732 0,035 7 8105.1 0.1821 0.038 7 8106.1 0.1423 0.031 7 8107.1 0.1495 0.030 7 8108.1 0.1990 0.041 7 8109.1 0.1859 0.041 7 8116.1 0.2059 0,040 7 8119.1 0.1668 0,028 7 8121.1 0.1951 0,035 7 8122.1 0.1967 0.036 7 8086.1 0.2204 0,046 8 8087.1 0.2149 0.048 8 8088, t 0.2095 0,042 8 8089.1 0.2436 0.048 8 8100.1 0.2124 0.045 8 8110.1 - 0.2616 0,052 8 8111.1 0.2363 0.048 8 8113.1 0.3347 0.071 8 8115.1 0.2901 0,063 8 Page 9 HYDRAULIC UNITS ARCO ALASKA, INC. :~ :~'~=~ .... 'RENDESVOUS" A :~-~:=~ ~-~ COLVILLE RIVER-SW FIELD HYDRAULIC UNITS SORTED BY SAMPLE DEPTH Depth Flow Reservoir Hydraulic Zone Quality Unit (ft) Indicator Index CL File No. · 57111 - 00094 8118.1 0.2500 0.051 8 8119.1 0.1668 0.028 7 8120.1 0.2956 0.076 8 8121.1 0.1951 0.035 7 8122.1 0.1967 0.036 7 8123.1 0.2624 0.058 8 8124.1 0.2716 0.059 8 SbRTED BY HYD. UNIT 'DePth FI~W ' 'R~se~voir H~/draulic Zone Quality Unit , ,(fi), Indicator ,, Index ..... 8117.1 0.2692 0.053 8 8118.1 0.2500 0.051 8 8120.1 0.2956 0.076 8 8123.1 0.2624 0.058 8 8124.1 0.2716 0.059 8 8112.1 0.4594 0.096 9 8114.1 0.3824 0.086 9 ARCO ALASKA, INC. "RENDESVOUS" A COLVILLE RIVER-SW FIELD CL File No. - 57111 -00094 PROFILE PERMEAMETER RESULTS Sample Sample permeab!l!ty No. Depth Kair K~'* _ . _.;.( .ft) (md) , (md) * KlJnkenberg (gas slippage) corrected permeability 1 8065.03 0.26 0.16 2 8065.20 0.080 0.037 3 8065.40 0.053 0.020 4 8065.60 0.075 0.034 5 8065.80 0.089 0.042 6 8066.03 0.10 0.051 7 8066.40 0.048 0.019 8 8066.60 0.10 0.048 9 8066.80 0.077 0.035 10 8067.04 0.14 0.070 11 8067.41 0.21 0.12 12 8067.60 0.14 0.075 13 8067.80 0.18 0.098 14 8068.20 0.18 0.096 15 8068.40 0.18 0.10 16 8068.60 0.20 0.11 17 8068.80 0.2t 0.12 18 8069.01 0.31 0.18 19 8069.20 0.40 0.26 20 8069.41 0.24 0.14 21 8069.60 0.29 0.17 22 8069.80 0.26 0.15 23 8070.20 0.30 0.18 24 8070.40 0.26 0.15 25 8070.63 0.38 0.24 26 8070.80 0.24 0.14 27 8071.04 0.55 0.36 28 8071.40 0.20 0.11 Page 11 Profile Permeameter ARCO ALASKA, INC. "RENDESVOUS" A COLVlLLE RlVER-SW FIELD CL File No.: 57111 - 00094 PROFILE PERMEAMETER RESULTS , Sample Sample ,, Permeability No. Depth Kair , , (ft) (md) (md) * Klinkenbe~g (gas slippage) corrected permeability 29 8071.60 0.50 0.33 30 8071.80 0.15 0.079 31 8072.20 0.29 0.17 32 8072.40 0.68 0.46 33 8072.60 0.11 0.057 34 8072.80 0.24 0.14 35 8073.04 0.30 0.18 36 8073.20 0.68 0.46 37 8073.40 0.38 0.24 38 8073.60 0.47 0.30 39 8073.80 0.94 0.66 · 40 8074.02 0.42 0.26 41 8074.20 0.31 0.19 42 8074.40 0.32 0.19 43 8074.60 0.20 0.11 44 8074.80 0.11 0.052 45 8075.01 0.19 0.11 46 8075.20 0.19 0.11 47 8075.40 0.14 0. 073 48 8075.60 0.23 0.14 49 8075.80 0.25 0.14 50 8076.01 0.29 0.18 51 8076.20 0.28 0.16 52 8076.40 0.24 0.14 53 8076.60 0.37 0.23 54 8076.80 0.24 0.14 55 8077.02 0.26 0.16 56 8077.20 0.16 0.087 Page 12 Profile Permeameter ARCO ALASKA, INC. "RENDESVOUS" A COLVILLE RIVER-SW FIELD CL File No.: 57111 - 00094 PROFILE PERMEAMETER RESULTS SamPle Sample Permeability ' No. Depth Kair - K~* (ft) (md), , (md) * Klinkenberg (gas slippage) corrected permea~t~ 57 58 59 60 61 62 63 64 65 66 67 · 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 8077.40 0.31 0.19 8077.60 0.28 0.17 8077.80 0.32 0.19 8078.21 0.25 0.15 8078.40 0.18 0.10 8078.60 0.45 0.29 8078.80 0.27 0.16 8079.01 0.18 0.10 8079.20 0.20 0.11 8079.40 0.34 0.21 8079.60 0.37 0.23 8079.80 0.23 0.13 8080.02 0.53 0.35 8080.25 0.18 0.095 8080.40 0.26 0.16 8080.60 0.30 0.18 8080.80 0.26 0.16 8081.01 0.29 0.17 8081.20 0.19 0.11 8081.40 0.19 0.11 8081.62 0.25 0.15 8081.80 0.17 0.092 8082.01 0.30 0.18 8082.20 0.18 0.099 8082.40 0.30 0.18 8082.60 0.59 0.39 8082.80 0.42 0.27 8083.02 0.35 0.22 Page 13 Profile Permeameter ARCO ALASKA, INC. "RENDESVOUS" A COLVILLE RIVER-SW FIELD CL File No.: 57111 - 00094 PROFILE PERMEAMETER RESULTS Sarnpl'e ' Sample ' PermeabilitY No. Depth Kair K~o* , .,(fi) , (md) ,(md) * Klinkenberg (gas slippage) con'ected permeability 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 8083.20 1.6 1.2 8083.40 0.20 0.11 8083.60 0.37 0.23 8083.80 2.9 2.2 8084.00 0.77 0.53 8084.20 0.24 0.14 8084.40 0.18 0.098 8084.60 0.21 0.12 8084.80 0.22 0.12 8085.20 0.30 0.18 8085.40 0,64 0.43 8085,60 0.23 0.13 8085.80 0.59 0.39 8086.20 0.21 0.12 8086.40 0.21 0.12 8086.60 0,49 0.32 8086.80 0.78 0.54 8087.02 0.28 O. 16 8087.20 1.6 1.2 8087.40 0,28 O. 17 8087.60 0,28 0.17 8087.80 0,21 0.12 8088.00 0.11 0.054 8088.20 0.31 0.19 8088.40 0.47 0.30 8088.60 0.33 0.20 8088.84 0.35 0.22 8089.04 0.34 0.20 Page 14 Profile Permeameter ~~~.~ ARCO ALASKA, INC. "RENDESVOUS" A ~'~. COLVlLLE RIVE..SW FIELD CL File No. · 57111 - 00094 PROFILE PERMEAMETER RESULTS 'Sample 'Sample , , :.Pen~eability No. Depth Kair . Koo* · . (ft) ,. (..md.) (md)_ * Kl'mkenberg (gas slippage) corrected permeability 113 8089.20 0.11 0.057 114 8089.40 0.18 0.097 115 8089.60 0.27 0.16 116 8089.80 0.29 0.18 117 8090.00 0.37 0.23 118 8090.20 0.30 0.18 119 8090.40 1.6 1.2 120 8090.60 0.14 0.070 121 8090.80 0.16 0.083 122 8091.01 0.13 0.067 t23 8091.20 0.11 0.055 · 124 8091.40 0.11 0,052 125 8091.60 0.084 0.039 126 8091.80 0.12 0.062 127 8092.04 0.060 0.026 128 8092.20 0.10 0.050 129 8092.40 0.13 0.064 130 8092.60 0.13 0.069 131 8092.80 0.22 0.13 132 8093.00 0.68 0.46 133 8093.61 0.14 0.074 134 8093.83 0.56 0.37 135 8094.00 0.52 0.34 136 8094.23 0.83 0.58 137 8094.40 0.45 0.29 138 8094.60 0.17 0.094 139 8094.80 0.62 0.42 140 8095.03 0.73 0.50 Page 15 Profile Permeameter .~% "RENDESVOUS" A CL File No.: 57111 - 00094 COLViLLE RIVER-SW FIELD PROFILE PERMEAMETER RESULTS ,,, Sample Sample Pe ,rmeab'ility , ~ No. Depth Kair K~* .(ft) , (md.).. , , . (md) * KlJnkenberg (gas slippage) corrected permeability 141 8095.20 0.71 0.48 142 8095.40 0.37 0.23 143 8095.60 0.27 0.16 144 8095.80 0.34 0.21 145 8096.02 1.1 0.79 146 8096.20 0.11 0.054 147 8096.40 0.67 0.45 148 8096.60 0.51 0.33 149 8096.80 0.39 0.24 150 8097.02 0.30 0.18 151 8097.20 0.80 0.55 '152 8097.40 0.22 0.13 153 81397.60 0.26 0.15 154 8097.80 0.29 0.17 155 8098.02 0.81 0.56 1 56 8098.20 0.36 0.22 157 8098.40 0.20 0.11 158 8098.60 0.29 0.17 159 8098.80 0.30 0.18 160 8099.00 0.74 0.51 161 8099.20 0.20 0.11 162 8099.40 0.29 0.17 163 8099.60 0.59 0.39 164 8099.80 0.38 0.24 165 8100.00 0.36 0.23 166 8100.20 0.36 0.22 167 8100.40 0.24 0.14 168 8100.60 0.34 0.21 Page 16 Profile Pormeame~r ARCO ALASKA, INC. CL File No. · 57111 - 00094 "RENDESVOUS" A COLVILLE RIVER-SW FIELD PROFILE PERMEAMETER RESULTS Sample sample .permeability , , No. Depth Kair ~ K~* , . (ft) .... (md) (md) ' Klinkenberg (gas sfippage) corrected permeability 169 8100.80 0.14 0.075 170 8101.40 0.29 0.17 171 8101.60 1.3 0.93 172 8101.80 0.34 0.21 173 8102.03 0.37 0.23 174 8102.21 0.50 0.33 175 8102.40 0.17 0.089 176 8102.60 0.37 0.23 177 8102.80 0.22 0.12 178 8103.00 0.14 0.070 179 8103.22 0.60 0.40 ' 180 8103.40 0.91 0.63 181 8103.65 0.076 0.034 182 8103.83 0.30 0.18 183 8104.03 0.30 0.18 184 8104.20 0.10 0.050 185 8104.40 0.21 0.12 186 8104.60 0.54 0.35 187 8104.80 0.31 O. 19 188 8105.00 0.36 0.22 189 8105.20 O. 12 0.063 190 8105.40 0.18 0. t0 191 8105.60 0.19 0.11 192 8105.80 0.37 0.23 193 8106.05 0.30 0.18 194 8106.20 0.054 0.022 195 8106.40 O. 081 O. 037 196 8106.60 0.098 0.047 Page 17 Profile Permeameter ARCO ALASKA, INC. CL File No. · 57111 - 00094 "RENDESVOUS" A COLVlLLE RIVER-SW FIELD PROFILE PERMEAMETER RESULTS 'Sample Sample ' ,, ' Permeabil!ty i' No. Depth Kair . K~ .... (ft) .... (md), ,, (.md) ,, * Klinke~mrg (gas slippage) corrected permeability 197 8106.80 0.22 0.12 198 8107.20 0.12 0.059 199 8107.40 0.18 0.10 200 8107.60 0.064 0.028 201 8107.80 0.12 0.061 202 8107.99 0.13 0.069 203 8108.20 0.10 0.051 204 8108.40 0.28 0.17 205 8108.60 0.10 0.051 206 8108.81 0.24 0.14 207 8109.00 0.64 0.43 '208 8109.20 0.14 0.074 209 8109.41 0.27 0.16 210 8109.60 0.23 0.13 211 8109.80 0.32 0.20 212 8110.20 0.68 0.46 213 8110.40 0.78 0.54 214 8110.60 0.39 0.25 215 8110.80 0.33 0.20 216 8111.01 0.25 0.15 217 8111.20 0.27 0.16 218 8111.40 0.48 0.31 219 8111.60 1.6 1.2 220 8111.80 1.5 1.1 221 8112.00 0.67 0.45 222 8112.20 1.1 0.82 223 8112.40 1.3 0.97 224 8112.60 1.1 0.77 Page 18 Profile Pormoameter ARCO ALASKA, INC. CL File No. · 57111 - 00094 "RENDESVOUS" A COLVILLE RIVER-SW FIELD PROFILE PERMEAMETER RESULTS Sample " Sample ' ,Permeability No. Depth Kalr . K~* (f..t,) .... (md!, (md) ' Klinkenberg (gas slippage) corrected permeability 225 8112.80 0.66 0.44 226 8113.20 0.54 0.36 227 8113.40 0.78 0.54 228 8113.60 0.45 0.29 229 8113.80 1.0 0.73 230 8114.02 0.90 0.63 231 8114.20 1.0 0.74 232 8114.40 0.74 0.51 233 8114.60 0.97 0.69 234 8114.80 0.79 0.55 235 8115.01 0.99 0.70 '236 8115.20 0.64 0.43 237 8115.40 0.37 0.23 238 8115.60 0.22 0.13 239 8115.80 0.26 0.15 240 8116.03 0.29 0.17 241 8116.20 0.37 0.23 242 8116.40 0.29 0.17 243 8116.60 0.29 0.18 244 8116.80 0.25 0.14 245 8117.20 0.27 0.16 246 8117.40 0.39 0.25 247 8117.60 0.45 0.29 248 8117.80 0.81 0.56 249 8118.00 0.60 0.40 250 8118.20 0.25 0.15 251 8118.40 2.3 1.7 252 8118.60 0.29 O. 17 Page 19 Profilo Permeameter ARCO ALASKA, INC. "RENDESVOUS" A CL File No. · 57111 - 00094 COLVILLE RIVER-SW FIELD PROFILE PERMEAMETER RESULTS Sample Sample Permeability ' , No, Depth Kair - K~o* , , (,ft) ,,, (md) (md) ' Klinkenberg (gas slippage) corrected permeability 253 8118.80 0.16 0.088 254 8119.03 0.19 0.11 255 8119.21 0.21 0.12 256 8119.40 0.26 0.15 257 8119.60 0.24 0.14 258 8119.80 0.54 0.35 259 8120.00 1.1 0.79 260 8120.20 0.35 0.22 261 8120.40 0.20 0.11 262 8120.60 0.21 0.12 263 8120.84 0.21 0.12 '264 8121.00 0.30 0.18 265 8121.20 0.54 0.35 266 8121.40 0.93 0.65 267 8121.60 1.3 0.91 268 8121.80 1.2 0.86 269 8122.04 0.24 0.14 270 8122.20 0.24 0.14 271 8122.40 0.30 0.18 272 8122.60 0.57 0.38 273 8122.82 0.83 0.58 274 8123.00 0.71 0.48 275 8123.20 0.77 0.53 276 8123.40 1.4 1.0 277 8123.60 0.56 0.37 278 8123.80 0.65 0.43 279 8124.00 0.85 0.59 280 8124.20 0.61 0.40 Page 20 Profile Permeameter · ~?.2i:71'.~ "RENDESVOUS" A ~-~~ COLVILLE RIVER-SW FIELD CL File No. · 57111 - 00094 PROFILE PERMEAMETER RESULTS Sample Sample , permeability No. Depth Kair K~* .... !.ft)., (md) , (md) 281 282 283 284 * Klinkenberg (gas slippage) corrected permeability 8124.40 0.37 0.23 8124.60 0.65 0.44 8124.80 0.48 0.31 8125.05 0.95 0.66 Date: 05/31/00 ARCO ALASKA INC. WELL SUMMARY REPORT..~:,. ..~ Page: 1 WELL:RENDEZVOUS A STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: WILDCAT SPUD:04/13/00 START COMP: RIG:DOYON 141 BLOCK: FINAL: WI: 0% SECURITY:3 API NUMBER: 50-103-20316-00 04/11/00 (D1) MW: 0.0 VISC: 0 PV/YP: 0/ 0 TD/TVD: 0/0 ( 0) SPOTTING SUB OVER WELL -LAY MATTS SUPV:D.GLADDEN/J.TRANTHAM Move rig to Rendezvous A location. APIWL: 0.0 04/12/00 (D2) MW: 10.0 VISC: 65 PV/YP: 19/29 APIWL: 4.6 TD/TVD: 107/0 ( 107) HOLD PREP SPUD MEETING ON RIG FLOOR SUPV:D.GLADDEN/J.TRANTHAM Move rig to Rendezvous A location, spot sub over well. N/U diverter and function test. Prep rig floor for spud. 04/13/00 (D3) MW: 10.0 VISC: 57 pV/yp: 13/38 APIWL: 4.2 TD/TVD: 1514/1514 (1407) DRLG @ 1861' SUPV:DEARL W. GLADDEN Drilling from 108' to 1514' Circ hole clean. Monitor well. Wiper trip to 180'. 04/14/00 (D4) MW: 10.0 VISC: 54 PV/YP: 17/26 APIWL: 5.0 TD/TVD: 2669/2669 (1155) R/U TO RUN 7 5/8" CSG - PJSM SUPV:DEARL W. GLADDEN CBU, shakers loading up with clay. Drilling from 1514' to 2319'. Control drilling 200 fph or less to control packoff and cuttings problems. Drilling from 2319' to 2669'. Pump sweep, observe hole. Wiper trip to 2150'. Hole swabbing, will not take correct fill. TIH to bttm to condition. Circulate and condition. Wiper trip to 1094', minimal swabing spots from 2150' to 1500'. Circulate and con~tion for 7-5/8" casing run. 04/15/00 (D5) MW: 10.0 VISC: 48 PV/YP: 16/25 APIWL: 4.8 TD/TVD: 2669/2669 ( 0) TEST BOPS SUPV:DEARL W. GLADDEN Circulate and condition hole to run casing. Monitor well, static. PJSM. Run 7-5/8" casing. Cement casing. Pump LCM marker pill. Pump cement. Bumped plug, floats held. N/D diverter system. N/U casing head. N/U BOPE. 04/16/00 (D6) MW: 9.5 VISC: 47 PV/YP: 10/20 APIWL: 5.6 TD/TVD: 2669/2669 ( 0) DRILL OUT CMT SUPV:DEARL W. GLADDEN N/U BOPs and test to 250/5000 psi. Full blown spill drill. Safety meeting. Date: 05/31/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/17/00 (D7) MW: 9.5 VISC: 44 PV/YP: 12/20 APIWL: 5.6 TD/TVD: 3861/3861 (1192) DRLG 6 3/4" @ 4165' SUPV:DEARL W. GLADDEN Complete re-test of inside IBOP. TIH, tag cement @ 2315' Test casing to 3000 psi. Drilling cement, FC, cement, FS and 20' new hole to 2689' Pump sweep, Clean out mud, circulate until clean and balanced. Perform LOT, 15.9 EMW. Drilling from 2689' to 3861' 04/18/00 (D8) MW: 9.5 VISC: 44 PV/YP: 10/15 APIWL: 5.5 TD/TVD: 5707/5707 (1846) DRILLING AHEAD 6053' SUPV:MIKE WHITELEY Drill from 3861' to 4112' Pump sweep around. Circ clean. Made 15 stand wiper trip. Drill from 4112' to 5707'. 04/19/00 (Dg) MW: 10.9 VISC: 53 PV/YP: 12/28 TD/TVD: 6993/6992 (1286) DRILLING AHEAD AT 7274' SUPV:MIKE WHITELEY APIWL: 3.0 Pump sweep around, circ clean for wiper trip. Made 17 stand short trip from 5707' to 4070'. Drill from 5707' to 6993' Circ hole clean for short trip. Pre-reservoir meeting. Made 13 stand wiper trip to 5627', Circ clean. DisplaCe hole with KC1/GEM mud. 04/20/00 (D10) MW: 10.9 VISC: 40 PV/YP: 14/21 APIWL: 3.4 TD/TVD: 8050/8049 (1057) POOH FOR CORE BARREL SUPV:MIKE WHITELEY Finish displacing hole with 11.0 ppg 6% KC1/GEM mud system. Drill from 6993' to 7925'. Kick drill. Control drill from 7925' to 7995'. Circ bottoms up. Drill from 7995' to 8050' 04/21/00 (Dll) MW: 11.0 VISC: 43 PV/YP: 13/23 TD/TVD: 8125/8124 ( 75) POOH WITH CORE BARREL SUPV:MIKE WHITELEY 04/22/00 (D12) TD/TVD: 8125/8124 ( SUPV:MIKE WHITELEY APIWL: 2.9 Drill /circ for samples to core point at 8065', 1190 units gas. Made 11 stand wiper trip to 7020'. Hole in good shape. Pump sweep around, circ clean for wiper trip. Circ out 1" shale slivers. POOH for core barrel. PJSM. RIH with core barrel assembly. RIH to shoe. Hole taking mud. Circ at 5954'. Circ clean and condition mud. Shut pumps down, slight breathing, flowed back about 20 bbls mud. RIH, tagged up at 8009'. Circ at 6803', 7272' and 7646', full returns. Washed and reamed from 8009' to 8065' Slight packing off. Circ bttms up, shale running a little, small shale slivers. Cored from 8065' to 8125'. MW: 11.0 VISC: 44 PV/YP: 12/22 APIWL: 2.7 0) LOST RETURNS WHILE REAMING AT 8058' - SPOTTING LCM PIL Circ bottoms up for samples. Observe well. Well flowing, breathing. Flowed back 20 bbls mud. Circ bttms up. Observe well, flowing. POOH with core barrels. Swabbing from 8000' to 7400'. PJSM. LD inter barrels. Test BOPs to 250/5000 Date: 05/31/00 psi. had four leaks, repaired and retested. RIH, hit bridge ARCO ALASKA INC. Page: 3 WELL SUMMARY REPORT at 7432'. Wash and ream thru ledges from 7381' , 7494'. RIH, tagged up at 7632', pump hi vis sweep, Wash and ream from 7601' to 7650' 04/23/00 (D13) TD/TVD: 8125/8124 ( SUPV:MIKE WHITELEY MW: 11.0 VISC: 45 PV/YP: 12/26 APIWL: 2.8 0) REAMING TIGHT HOLE FROM 7995' - 8,032' AT 06:00 HRS. Ream tight spots from 7601' 7681', RIH to 7877'. Ream and clean out hole from 7877'-8058' Hole taking 10 bph mud, breathing. Shale running. Lost all returns at 8058'. Made 6 std wiper trip to 7200', hole in good shape. Circ at 8010', 2 bpm with full returns. Spotted 35 bbl LCM pill out DP. POOH to 7510' Circ. RIH to 8009'. Wash/ream/MAD pass from 8050' to 8121' Hole tight at 8065'. Work/jar on BHA for 1 hrs with max 150k overpull. No returns. Pipe came free. POOH to 7200' Circ, full returns, spot LCM pill. POOH. RIH with clean out BHA. 04/24/00 (D14) MW: 11.0 VISC: 45 PV/YP: 13/24 APIWL: 2.6 TD/TVD: 8143/8142 ( 18) DRILLED TO 8252' -POOH TO 7200'- ADD MUD TO ACTIVE SYS SUPV:MIKE WHITELEY Tagged up at 7942'. Wash and ream thru tight hole and drill on ledges at 7970', 8005'-8007', and 8040'-8050'~ Hole unloaded shale on bottoms up, some packing off while reaming. Lost complete returns at 8083', 8122' and 8125' Spot LCM pill. Pulled 3 stand to 7850' to build volume and increase LCM in system. Hole tight at 8050', jarred out. Mix LCM in system. RIH to 8003' hole in good shape, wash from 8003' to bottom at 8125'. Drill from 8125' to 8143' Lost 75 bbls mud. POOH to 7200' to increase LCM in system. 04/25/00 (D15) MW: 11.0 VISC: 44 PV/YP: 12/19 APIWL: 3.2 TD/TVD: 8300/8299 ( 157) DIPOLE SONIC SET DOWN AT 8104' - RIH WITH CLEAN OUT BH SUPV:MIKE WHITELEY Circ at 7200'. Increase LCM in mud. RIH to 8143', hole in good shape. Ledge at 7940'. Drill from 8143' to 8252' Losing 80 bph mud. POOH to 7200'. Circ, reciprocate add mud to pits and mix LCM to 30 ppb. RIH, tagged up at 8150' Washed to bottom at 8252'. Drill from 8252' to 8300' Lost 78 bbls mud. Circ bttms up, well flowing, circ bttms up, nothing on bottoms up, observe well flowed back 35 bbls (breathing). POOH. Hole started taking correct fill after 15 stands were pulled. PJSM. RU Schlumberger. Run #1, dipole sonic/GR from 7250' to 5000' Hold spill drill/fire drill. 04/26/00 (D16) MW: 11.0 VISC: 43 PV/YP: 10/21 APIWL: 3.3 TD/TVD: 8333/8332 ( 33) RUNNING RFT'S - TAKING PRESSURES AT 06:00 HRS SUPV:MIKE WHITELEY Finished running dipole sonic/GR from 7250' to surface. Date: 05/31/00 Logged up to 7200' POOH. RIH with clean out BHA, tagged up at 8104' Wash and rotate thru bridge at 8104'. RIH to 8265', hole in good shape. Washed 35' to bottom. Had 2' ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 fill. Drilled from 8300' to 8333'. No mud loss. Circ bottoms up. Observe well. Slight flow. Spot 75 bbls hi-vis LCM pill on bottom. POOH to 7450', RIH to 8300', no problems. PJSM. RIH with DPC RFT tool. 04/27/00 (D17) TD/TVD: 8333/8332 ( SUPV:MIKE WHITELEY MW: 11.0 VISC: 43 PV/YP: 13/21 0) DRILLING AHEAD AT 8343' APIWL: 3.1 RIH with DPC RFT's, intermittent down drag from 7730' to 7830'. Log across sand. POOH. 04/28/00 (D18) MW: 11.0 VISC: 44 PV/YP: 12/22 TD/TVD: 8353/8332 ( 20) RIH WITH 5.5" CSG SUPV:MIKE WHITELEY APIWL: 3.0 RIH with bit/LWD's to 8050'. MAD pass from 8050' to 8250' and 8250' to 8305'. Wash and drill out hard fill from 8305' to 8333'. Drilled 20' new hole to 8353'. Circ bottom up for wiper trip. Made 10 stand wiper trip to 7400'. Had 15' hard fill. Kick drill. Pumped 75 bbls hibh vis pill around. Made 5 stand wiper trip. POOH to 8000', spot LCM pill. POOH. RU to run 5.5" casing. PJSM. Run 5.5" casing. 04/29/00 (D19) TD/TVD: 8353/8332 ( SUPV:MIKE WHITELEY MW: 18.8 VISC: 52 PV/YP: 12/30 0) CIRC AND WORK CSG AT 7987' APIWL: 2.9 Run 5.5" casing to shoe. Circ bttms up at shoe. Run 5.5" casing to 6800'. Wash thru tight spots with pump at 5225' to 5385'. Circ and mud with partial returns, lost 200 bbls mud, cutting mud weight to 10.8 ppg. Returns decrease to a dribble coming. Pumped out 20 jts casing (swabbing). Attempt to circ, no returns. Run 5.5" casing, tagged up at 7977' 04/30/00 (D20) TD/TVD: 8353/8332 ( SUPV:MIKE WHITELEY MW: 10.8 VISC: 42 PV/YP: 11/19 0) WELL SHUT IN - WAITING ON CEMENT APIWL: 3.0 Attempt to work thru bridge at 7987'. Finish running and pumping down casing to 8303'. Circ and condition mud for cement job, no mud losses, well breathing. PJSM. Pumped first stage cement. Plug did not bump. Full returns throughout job. Well flowing. Shut well in and WOC. Floats held. Wait on cement. Well shut in 5 hrs. Well flowing. Circ and condition mud for second stage cement. No cement to surface from first stage. Full returns. PJSM. Pump 2nd stage cement. Full returns, plug bumped and closed stage collar at 1250 psi. Well flowing. Shut well in. 05/01/00 (D21) MW: 10.8 VISC: 42 PV/YP: 11/19 APIWL: 3.0 TD/TVD: 8353/8332 ( SUPV :MIKE WHITELEY Date: 05/31/00 0) RIH PICKING UP 3.5" TUBING Well shut in, waiting on cement. Installed 5.5" pack-off and tested to 5000 psi, held. Freeze protect well with ARCO ALASKA INC. Page: 5 WELL SUMMARY REPORT diesel. 05/02/00 (D22) MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 6100/8332 ( 0) PREPARE RIG FOR MOVE SUPV:DEARL W. GLADDEN PJSM. TIH with tubing open ended. Attempt to set TWC. Will not set. N/D BOPs. N/U tree and test to 250/5000 psi. Freeze protect well. Set BPV, secure tree. 05/03/00 (D23) MW: 0.0 VISC: 42 PV/YP: 0/ 0 TD/TVD: 6100/8332 ( 0) PREPARE RIG FOR DE-MOB SUPV:DEARL W. GLADDEN Rig down, move off location. APIWL: 0.0 05/04/00 (D24) MW: 0.0 VISC: 42 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 6100/8332 ( 0) RIG RELEASED @ 12:00 NOON 5/4/00 SUPV:DEARL W. GLADDEN Prepare rig for move. Clean camp. Release rig @ 12:00 noon 5/4/00 NOTES _.~/~, ~%~ ~'" .: .~% ~ ~ ~" "~' 1. COORDINATES SHOWN ARE ASP ZONE 4, ~ 3. ELEVATIONS SHOWN ARE B.PM.S.L. }'~ ~' ¢ 4. ALL DISTANCES ARE TRUE. ~ ~,~ "~ 5. DATE OF SURVEY: ~3/27/8B, FB. L 8~-13, , . ~N ~', Pg. 18. ; -. , , ~ J VICINITY MAP SCALE1'= 3 ~ILES , ~.[~ ~ RENDEZVOU, S '~A'~ ~ ~~~ .... ~ SEC. 24 TWP. 1~ N., RGE. 1 E. ., ~ ~_ ~~j~ ~ RIG ~ UMIAT MERIDIAN ~ ~~ N ~ LONG. = 151' 46' 47.4~3" X ~ ~' 2247' F.S.L., 1255' F.W.L. ~ o,OU,D ~L~W=O~ = ~.:' ~" ~ ~0~ O, ~C~ ~AD = ~.~' 23~24 261~25 SUR~YOR'S CERTIFICATE ~_ OF ~%_ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND '~'~'~"'" ;'...:~,. LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ~ . ~ '..z .~ ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY ~-Z ~gth._~~...~ OON~ BY M~ O~ UNDER ~Y DIRECT SUPerViSiON THAT ALL Di~N.SIONS AND OTHER O~TAiLS A~E CORRECT ~. ,~~1.~,~ ~* LOUNSBURY ',~yps,o~:~,- fl. 5t ~ ~ssoc~?ss. ~c. M1 XXXX M1 ~ RENDEZVOUS A ARCO ~--u-.,~.~., Inc. ~ [XPLORATORY ~ CONDUCTOR Subsidiory of Atlantic Richfield Company AS-BUILT LOOA~ON 'CADD FILE NO. DRA~NG NO: ISHEET: IREV: LK6elD338 3/29/2e~e QEA-M1XX-6e1D338 FROM: PHILLIPS Alaska, In;, A Subsidiary of PHIL, UPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DATA Sandra D. Lemke, ATO1354 Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Ak. Oil & Gas Conservation Comm. ATTN: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99510 DATE: 6/05/2000 Transmitted herewith is the following: . ~Rendezvous A 501032031600 Epoch Formation log (s.__ep__i~ CDROM data Schlumberger DSI · reprocessed merged Main Pass w/raw Customer Waveform DLIS format 4/26/200~1 of 2~ Raw customer waveform DLIS file 4/26/200~of 2~~. · Schlumberger Reproducible log films + 1 Bluelines each: ,"Schlumberger Dipole Sonic Imager 70-8090'md 4/26/2000 · 'Schlumberger Repeat Formation Tester 8085-8164' md 4/27/2000 Color Log Print Schlumberger Best DT Dipole Sonic Q.C. Plot - GEOFRAME processed interpretation (2 copies) Spark 1 (5Q,1032031300) ~ Epoch Formation Log (sepia film) Spark iA (50103.2031300) ~.OO- Epoch Formation Log (sepia film) ,/Schlumberger Ultrasonic Imager/CCL/GR 4/27/2000 5500-8287~nd Sperry Sun Directional Survey data; 1- 3.5" disk, Clover A, RendezvousA, Spark 1, lA (Sperry logging runs forthcoming) ~ o~- ~z ~ ~ ~ ~~,~~_,~ CC: Mark McDermott -- ~ .,., ' Approved for~;-_._..(/~ ~ ~ ~~ Receipt: .~ ~ Date: ,~][IN 0~) ~000 Return receipt to: (P~illips Alaska, Inc. '- ' -.., ,, ,-,... r',,.s Commissior, · '~TN: S. Lemke, ATO-1354 AlaSKa UU a ~o ,., .... .. Anf:hor_age 700 G. Street Prepared by: ~anara D. Lemke Anchorage, AK 99501 Phillips Alaska IT Geoscience Group From: Core Laboratories 600 W. 58th Ave., Unit D Anchorage, Alaska 99518 Core Laboratories - Alaska To: Alaska Oil & Gas Consewation Commissio; 3001 Porcupine Drive Anchorage, Alaska 99501 Date: 17-May-O0 Well Name: Number of Samples: Contact: GREG WILSON Description of Material: Depths: 806.5-8124 ARCO ALASKA INC. 59 RENDEZVOUS 263-4748 Core Chip Samples Sent By: TIM LAWLOR Received By: '\ North Slope Alaska Alaska State Plane 4 EXPL ORA TION_NON-PAD Rendezvous Surveyed: 13 April, 2000 SURVEY REPORT 16 May, 2000 Your Ref: AP!.501032031600 Surface Coordinates: 5927938.48 N, 279252.98 E (70° 12' 19.9179" N, Kelly Bushing: 90.9Oft above Mean Sea Level 151° 46' 47.4030" W) DRILLING SERVICE" Survey Ref: svy9214 Sperry-Sun Drilling Services Survey Report for Rendezvous Your Ref: API-501032031600 Surveyed: 13 April, 2000 North Slope Alaska Measured Depth (ft) Incl. 0.00 163.00 614.48 1071.07 1534.50 2003,41 2462.99 2600.25 3036.90 3504.90 3977.60 4445.90 4909.88 5382.42 5857.01 6291.49 6765.27 7233.04 7700.40 7939.06 8353.00 0.000 0.220 0.180 0.080 0.130 0.120 0.400 0.400 0.060 0.680 0.220 0.600 0.360 0.650 1.070 1.750 1.550 1.260 1.190 1.150 1.150 Azim. 0.000 330.710 41.120 40.830 1.420 74.780 75.000 34.410 230.130 16.570 41.010 318.480 233.690 219.520 273.790 251.490 286.240 318.020 322.440 329.240 329.240 Sub-Sea Depth (ft) -90.90 72.10 523.58 980.17 1443.60 1912.50 2372.08 2509.34 2945.98 3413.97 3886.66 4354.95 4818.92 5291.44 5765.98 6200.33 6673.92 7141.56 7608.81 7847.42 8261.28 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 163.00 614.48 1071.07 1534.50 2003.40 2462.98 2600.24 3036.88 3504.87 3977.56 4445.85 4909.82 5382.34 5856.88 6291.23 6764.82 7232.46 7699.71 7938.32 8352.18 0.00 N 0.00 E 0.27 N 0.15 W 1.56 N 0.11 W 2.34 N 0.57 E 3.12 N 0.79 E 3.78 N 1.28 E 4.32 N 3.29 E 4.84 N 4.03 E 5.95 N 4.71 E 8.45 N 5.32 E 11.83 N 6.71 E 14.34 N 5.68 E 15.30 N 2.89 E 12.35 N 0.01 W 10.57 N 6.14 W 8.73 N 16.48 W 8.22 N 29.49 W 13.82 N 39.01 W 21.48 N 45.40 W 25.50 N 48.14 W 32.64 N 52.39 W 5927938.48 N 279252.98 E 5927938.76 N 279252.83 E 5927940.05 N 279252.91 E 5927940.81N 279253.62 E 5927941.57 N 279253.86 E 5927942.22 N 279254.37 E 5927942.70 N 279256.40 E 5927943.20 N 279257.15 E 5927944.29 N 279257.87 E 5927946.77 N 279258.54 E 5927950.10 N 279260.04 E 5927952.65 N 279259.07 E 5927953.68 N 279256.32 E 5927950.82 N 279253.33 E 5927949.22 N 279247.15 E 5927947.69 N 279236.76 E 5927947.56 N 279223.74 E 5927953.43 N 279214.39 E 5927961.28 N 279208.22 E 5927965.38 N 279205.61E 5927972.64 N 279201.57 E Alaska State Plane 4 EXPLORATION_NON-PAD Dogleg Rate (°/100fl) Vertical Section (ft) Comment o.135 0.052 o.o22 o.o18 o.o32 o.o61 0.202 O.lO5 o.156 O. lO3 o.131 o.145 0.066 o.183 o.198 o.212 o.175 0.025 o.o61 o.o0o 0.00 0.27 1.56 2.34 3.12 3.78 4.32 4.84 5.95 8.45 11.83 14.34 15.30 12.35 10.57 8.73 8.22 13.82 21.48 25.50 32.64 Projected Survey Continued... 16 May, 2000 - 16:03 -2- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for Rendezvous Your Ref: API-501032031600 Surveyed: 13 April, 2000 North Slope Alaska Alaska State Plane 4 EXPLORATION_NON-PAD All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.238° (13-Apr-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8353.00ft., The Bottom Hole Displacement is 61.73ft., in the Direction of 301.927° (True). Comments Measured Depth (ft) 8353.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8352.18 32.64 N 52.39 W Comment Projected Survey Continued... 16 May, 2000 - 16:03 -3- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for Rendezvous Your Ref : APl-SO 1032031600 Surveyed: 13 April, 2000 North Slope Alaska Alaska State Plane 4 EXPLORATION_NON-PAD Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Depth (ft) 8353.00 Vertical Depth (ft) 8352.18 Survey Tool Description MWD Magnetic DrillQuest 1.05.05 16 May, 2000 - 16:03 - 4 - PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Paul Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 June 12, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for Rendezvous A - Confidential Dear Mr. Commissioner: On behalf of itself and Anadarko, Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached Completion Report for the exploration well Rendezvous A, Drilling Permit No. 200-54 / 300-116 as specified in 20 AAC 25.071. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). While we are submitting this data for the use of the Commission in carrying out its duties, we question whether any future disclosure to DNR or the public would be appropriate or valid. However, it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, so that we may be heard on the issue. Attachments to the Completion report include a summary of daily operations, a directional survey, and as-built. We will send under separate cover the logs, mud logs and core description. If you have any questions regarding this matter, please contact me at 263.4603 or James Trantham at 265.6434. Sincerely, Paul Mazzolini Exploration Drilling Team Leader PA1 Drilling ~t..~,~ ~,....d,~' .,..:,:,,, ~ ,~.,, ;.~:~-q.~,,~ dUN 14 2000 ..... ~ ,.~!0~ 1 Anchor~e STATE OF ALASKA i, ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS CONFIDENTIAL 1. Type of Request: Abandon __ Suspend _ Alter casing _ Repair well _ Change approved program __ Operation Shutdown X Re-enter suspended well _ Plugging __ Time extension _ Stimulate _ Pull tubing_ Variance__ Perforate__ Other 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development __ Exploratory X Stratigraphic __ Service 4. Location of well at surface: ASP NAD27 Coordinates X=279,253 & Y=5,927,938 2247' FSL, 1255' FWL, Sec. 24, T10N, R1E, UM At top of productive interval 2247' FSL, 1255' FWL, Sec. 24, T10N, R1E, UM At effective depth At total depth 2247' FSL, 1255' FWL, Sec. 24, T10N, R1E, UM 6. Datum elevation (DF or KB) 28' RKB Pad 62' 7. Unit or Property name N/A 8. Well number Rendezvous "A" 9. Permit number 200-054 10. APl number 50-103-20316-00 11. Field/Pool Exploration feet 12. Present well condition summary Total Depth: measured 8353 feet (approx) true vertical 8353 feet Effective depth: measured (approx) true vertical Casing Length Structural Conductor 80' Surface 2633' Intermediate na Production 8300' 8232 est. PBTD feet 8232 est. PBTD feet Size ORI61NAL 16" 7.625" Cemented Measured depth True vertical depth 200 cu. Ft. 108' 108' 253 sx AS Lite & 2661' 2661' 240 sx Class G 140 sx Class G + 8328' 8328' 84 sx CemPLUS Perforation depth: NONE Tubing (size, grade, and measured depth) Tubing tail to be left at 2900' MD with BPV in Tree Packers and SSSV (type and measured depth) 03 2000. 13. Attachments Description summary of proposal X Detailed operation program __ BOP sketch Contact Paul Mazzolini at 263-4603 with any questions. LOT test, surface cement details and casing detail sheets __ -- 14. Estimated date for commencing operation 5/1/00 16. If proposal was verbally approved j / Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended Service 17. I hereb, c~certify that the foregoing is true and correct to the best of my knowledge. Signed '/~ "~.~ Title Exploration/Tarn/Tabasco Team Leader Date Paul Mazzolini 263-4603 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance __ Mechanical Integrity Test_ Subsequent form require 10- &,rou~ Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED' BY Robert N. Cnristenson IApprovcJ N%.. , ?;ou--It(:, Commissioner D at e .._~'~'-' ~-~' O~:~) SUBMIT IN TRIPLICATE PROt .~SED Rendezvous "A" Operations {., ~utdown CONFIDENTIAL Revised 5/1/00 PURPOSE: Due to deteriorating Ice conditions on the North Slope Phillips Alaska, Inc. has decided to request an Operations Shutdown to secure the Rendezvous "A" wellbore until next Winter's exploration season. The intent would be to return in the 2000/2001 Winter season and complete/test the well. The proposed program is as follows: Notify BLM/AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. CURRENT STATUS: 5-1/2" casing has been run and cemented to 8328'. The first stage job at the shoe had full returns but did not bump the plug- pumped the calculated strokes. A second stage cement job was performed thru a DV Stage collar at 6100'. After pumping 37 bbls of slurry thru the DV tool into the annulus (TOC in the annulus is estimated at 4720' MD) the closing plug bumped and pressure tested to 1500 psi. 1. RIH with 3-1/2" tubing to 2900' and land in the wellhead. Pressure test casing to 1500 psi. 2. The top 2000' of tubing and 3-1/2" x 5-1/2" annulus will be freeze protected with diesel.10.8 ppg mud has been left in the casing above and below the DV stage tool. 3. Install BPV. Nipple down stack, nipple-up tree. Pull BPV. Install test plug. Test tree to 250 and 5000 psi. Pull test plug. 4. RU to 7-5/8" x 5-1/2" annulus and bullhead approx. 33 bbls diesel to 2000'. , Set BPV in tree. Close all valves and remove handles. Install blind flanges with 1/2" plugs screwed into the flanges on all outer valves and a bull plug with Y2" plug in the annulus valve on the wellhead. Release rig. · Risks: A spill could result if vandalism occurred during the Operations Shutdown. · Level: Low · Mitigation: All blind flanges will be blanked with plugs. 6. Clean-up cellar and location to prepare for inspections and Summer Operations Shutdown. 7. Hang sign on tree with the following information: Phillips ALASKA, INC Rendezvous "A" PTD Cf 200-054 APl # 50-103-20316-00 SHL: 2247' FSL, 1255' FWL, Sec. 24, T10N, RIE, UM TJB 5/1/00 FILE: Rendezvous "A" MAY 0 ;5 2000 Oil & Gas Cons. ComI~isaion ARCO~'-~r Calculations Cha~ = Sheet number ~u~,~c,~ d,....~..,,.,,,..,,~ '~ 0,.,,,.~.,,.~ J,.,,..,,,-~ ,...J.2,..,._ o, ,,,q "-,,.'x "x r~pv'/."/." ,... ~'~,'" ;,, ~x,N' ~ ~.~ ~ ..~ ,,,//, /...'K~ ~ -'~. ...... //.... . .... --,.-i'-'..'"':--.--"-'-.-- "i..../ ,.? ~!/~- /¢g,./.~ '"x, 'x ' ?~'~" ' /'/ .-'"' "- · -.,i "'-. ' ' ~,,/'" ~o· f¢---' z ~//, ,0 .... "'/' i ' ' ~': ~" ........... i---:.. ~.Jt;-' ' , "'"~"~'"'"'i-'x ~""~: : ~ ' ' ' ' 4 : : i x i ....... i ~ .... '7~.~...~z/-_,',,,,,,....~.2 ,,~',.... ~ .... ~ , ..... .~.. .............. : ' ' .... '-' ......... 'I~" ' J ' ' ' ........ . ~ ! ..... ~ ~ : ..... ~ ......... .~....,.~ ...... . ............ · ~ .zx..~.,,,.~x.~. ~..~; ....... . :! :i ', ' !~ ~ ~ !' ~ ............ i' '" "'" ' ......... : ............. , ............ ,~ .......... ' , .............. ~ ......... :":"'":.! ! .......... .............. i .......... .................. ~ ............................. '"": ~.":-,:i'..":"~...'r'.:'";'". '.' !:' :!''..'': ~ ........... "i ........ ~ .... :'t' ' ~ '.',...4,. ', , ~,. ,..-- . ..'.....:.... ...: : . ,,,~ , ..~... ...... , ~.~<_.'.,_.,.?,'...~...~ ,.~,~ ..... '.~,,:,' ! , i "'"x. : i ' ~ , ! ; ' ,,, .L. : ~ / , ::'~, .',':~,., ...... ",,,'..,i.,.".',,,,.',,,,',' ,~ ~'.. ~,'.:,:',i',., ;; ,, ,"; .,.' '"~ .......... ,~ ;', .., ,,,' .... ,','."" . .~( ..... /~ C,,,.M L..S~ .... : .." ~ :~ ! X/:. ~ ~ : i ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 1, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Sundry Application for Rendezvous "A" Operations Shutdown- CONFIDENTIAL Dear Mr. Commissioner: On behalf of itself and Anadarko, Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached application for sundry, Drilling Permit No. 200-054. We request that this data be held confidential as required under AS 31.05.035 ( c ) and 20 AAC 25.537 (d). While we are submitting this data for the use of the Commission in carrying out its duties, we question whether any future disclosure to DNR or the public would be appropriate or valid. However, it is neither appropriate nor necessary to resolve third party disclosure issues that will not mature until two years have passed. Therefore, we are merely putting you on notice of our concern and our intent to reserve all rights and arguments regarding disclosure of this data to DNR or the public. Please provide notice to us prior to any such disclosure, so that we may be heard on the issue. If you have any questions regarding this matter, please contact me at 263.4603 or Tom Brassfield at 265.6377. Sincerely, Paul Mazzolini Exploration Drilling Team Leader TJB 5/1/00 FILE: Rendezvous "A" R Ob, IVED MAY 03 2000 Oil & G~s Coas. BY' 5- 1- 0 ' 4:30PM ' ARCO. Alaska, Inc. -- ~' . _ alii. ii · ll,l __ ii 'FACSIMILE TRANSMI$SI .O.~N'~ .... . -- -- , .''" -- i i -- ii _ B i i .~~,,,: _ ~_ ,/, _ ~.,.. . .~_ . · ~ .... - --Ji ill I I i -., ~ ~:, 5 ...... 7' :_ ,',' · ":5, :_,, ARCO ALASKA~ 007 276 7542'# 1/ 2 ,. "' KupatuE Development.. · , " P. O, BOX 100360 ^NCHORAGE, AK' 99510~360 '. comments.' .SENT BY' 5- 1- 0 ' 4'30PM ' ARCO ALASK~ 007 276 7542:~ 2/ 2 Calculations Charl ,, ......... b ~ ~,~,~ f .................. ,, ,, ,,, ....... ~,. ,I .... , .......................................... ,,, ....... , ................................... ~ ..... . ............. , ........................ , ............... ,, ~ ~. ....... -~ .. ..,,~ ' ~>,~fidezvous "A" Operations Shutdown- CONFIDE~'~TIAL Subject: Rendezvous "A" Operations Shutdown- CONFIDENTIAL Date: Mon, 1 May 2000 16:08:31 -0900 From: "Tom J Brassfi¢ld" <TBRASS@mail.aai.arco.com> To: Blair Wondzell <blair_wondzell~admin.state.ak.us>, pditton~ak.blm.gov CC: bo_brown~ak.blm.gov, "Paul Mazzolini" <PMAZZOL@mail.aai.arco.com>, "James A Trantham" <JTRANTH~mail.aai.arco.com> Blair/Peter, due to deteriorating Ice conditions on the North Slope we have decided to request an Operations Shutdown on our Rendezvous "A" NPRA well. We have run and cemented the production casing to 8328'. TOC for the first stage of cement is estimated at 7400' MD. A second stage job was completed thru a DV stage collar at 6109' MD with TOC calculated at 4720' MD. 10.8 ppg kill weight mud is located below and above the DV shut-off plug which will be left in the hole. Please see the attached procedure for your review. We can fax a copy of the proposed wellbore schematic. We are planning on starting some of this work tonight after laying down drill pipe. Thanks, Tom (See attached file: Ren A BLM AOGCC Ops SD Proc by TJB Rev 5 1 00.doc) Name: Ren A BLM AOGCC Ops ~Ren A BLM AOG,CC Ops SD Proc by TJB Rev 5 1 00.doc SD Proc by TJB Rev 5 1 00.doc Type: Microsoft Word Document (application/msword) Encoding: base64 Description: Mac Word 3.0 I of I 5/1/00 4:15 PM PROi .,,SED Rendezvous "A" Operations ,,dtdown CONFIDENTIAL Revised 5/1/00 PURPOSE: Due to deteriorating Ice conditions on the North Slope Phillips Alaska, Inc. has decided to request an Operations Shutdown to secure the Rendezvous "A" wellbore until next Winter's exploration season. The intent would be to return in the 2000/2001 Winter season and complete/test the well. The proposed program is as follows: Notify BLM/AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. CURRENT STATUS: 5-1/2" casing has been run and cemented to 8328'. The first stage job at the shoe had full returns but did not bump the plug- pumped the calculated strokes. A second stage cement job was performed thru a DV Stage collar at 6100'. After pumping 37 bbls of slurry thru the DV tool into the annulus (TOC in the annulus is estimated at 4720' MD) the closing plug bumped and pressure tested to 1500 psi. 1. RIH with 3-1/2" tubing to 2900' and land in the wellhead. Pressure test casing to 1500 psi. 2. The top 2000' of tubing and 3-1/2" x 5-1/2" annulus will be freeze protected with diesel.10.8 ppg mud has been left in the casing above and below the DV stage tool. 3. Install BPV. Nipple down stack, nipple-up tree. Pull BPV. Install test plug. Test tree to 250 and 5000 psi. Pull test plug. 4. RU to 7-5/8" x 5-1/2" annulus and bullhead approx. 33 bbls diesel to 2000'. , Set BPV in tree. Close all valves and remove handles. Install blind flanges with ½" plugs screwed into the flanges on all outer valves and a bull plug with ½" plug in the annulus valve on the wellhead. Release rig. · Risks: A spill could result if vandalism occurred during the Operations Shutdown. · Level: Low · Mitigation: All blind flanges will be blanked with plugs. 6. Clean-up cellar and location to prepare for inspections and Summer Operations Shutdown. 7. Hang sign on tree with the following information: Phillips ALASKA, INC Rendezvous "A" PTD # 2OO-O54 APl # 50-103-20316-00 SHL: 2247' FSL, 1255' FWL, Sec. 24, T10N, R1E, UM TJB 5/1/00 FILE: Rendezvous "A" Re: Proposed P&A Procedure for Rendezvous "A"-. CONFIDENTIAL PTD #2004)54 Subject: Re: Proposed P&A Procedure for Rendezvous "A"- CONFIDENTIAL PTD #200-054 Date: Tue, 25 Apr 2000 15:33:01 -0800 From: Blair Wondzell <blair_wondzell@admin.state.ak.us> .~-~ Organization: State of Alaska, Dept of Admin, Oil & Gas To: Tom J Brassfield <TBRASS~mail.aai.arco.com> CC: Paul Mazzolini <PMAZZOL@mail.aai.arco.com>, Peter Ditton <pditton@ak.blm.gov> Tom, The procedure looks good to me. You have verbal approval to follow this program. If something changes, please let me know. If you want this 403 to be approved, please fax a signed copy. Thanks, blair Wondzell, 4/25/00. Tom J Brassfield wrote: > Blair, it looks like we are headed for a P&A on this wellbore at this time. We > have TD'd the hole and currently coming out to download LWD data from this lower > section of hole. Unless we get surprised by the data or lack of data, the next > step is to PU our tubing stinger and go to bottom to start laying cement plugs > per the attached procedure. This could happen tonight. Your comments and > permission to proceed ahead would be greatly appreciated. Will fax a copy of the > VISIO schematic. > Thanks again, Tom > > (See attached file: AOGCC Form 403 for Rend A P and A 4 25 O0.doc) > (See attached file: Rend A Agency P and A Proc by TJB 4 25 O0.doc) (See attached > file: Rend A P and A TJB 4 25 O0.vsd) > > Rend A P and A 4 25 O0.doc > AOGCC Form 403 for Rend A P and A 4 25 O0.doc Document (application/msword) > > > > Proc by TJB 4 25 O0.doc > Rend A Agency P and A Proc by TJB 4 25 O0.doc Document (application/msword) > > > > Name: Rend A P and A TJB 4 25 O0.vsd > Rend A P and A TJB 4 25 O0.vsd Type: application/x-unknown-content-type-vsd_auto file -- > Encoding: base64 Name: AOGCC Form 403 for Type: Microsoft Word Encoding: base64 Description: Mac Word 3.0 Name: Rend A Agency P and A Type: Microsoft Word Encoding: base64 Description: Mac Word 3.0 I of I 4/25/00 3:33 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS CONFIDENTIAL 1. Type of Request: Abandon X Suspend _ Alter casing _ Repair well _ Change approved program __ Operation Shutdown Plugging _ Pull tubing _ __ Re-enter suspended well _ Time extension _ Stimulate _ Variance_ Perforate__ Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 ~ 5. Type of Well: . Development -- Exploratory X Stratigraphic _ Service 6. Datum elevation (DF or KB) 28' RKB, Pad 62' feet 7. Unit or Property name N/A 4. Location of well at surface: ASP NAD27 Coordinates x = 279,253 & Y = 5,927,938 2247' FSL, 1255' FWL, Sec. 24, T10N, RIE, UM At top of productive interval 2247' FSL, 1255' FWL, Sec. 24, T10N, R1E, UM At effective depth At total depth 2247' FSL, 1255' FWL, Sec. 24, T10N, RIE, UM 8. Well number Rendezvous "A" 9. Permit number 20O-054 10. APl number 50-103-20316-00 11. Field/Pool Exploration 12. Present well condition summary Total Depth: measured 8300 feet (approx) true vertical 8300 feet Effective depth: measured 8300 feet (approx) true vertical 8300 feet Casing Length Size Structural Conductor 80' 16" Surface 2633' 7.625" Intermediate na Production na Cemented 200 cu. Ft. 253 sx AS Lite & 240 sx Class G Measured depth True vertical depth 108' 108' 2661' 2661' Perforation depth: Open Hole Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal X Detailed operation program BOP sketch Contact Paul Mazzolini at 263-4603 with any questions. LOT test, surface cement details and casing detail sheets 14. Estimated date for commencing operation 4/25/0O 16. If proposal was verbally approved Name of approver 15. Status of well classification as: Oil Gas Suspended X Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of m V knowledge. Signed Title Exploration/Tarn/Tabasco Team Leader Date Paul Mazzolini 263-4603 FOR COMMISSION USE ONLY Conditions of approval' Notify Commission so representative may witness Plug integrity BOP Test Location clearance -- __ -- Mechanical Integrity Test Subsequent form require 10- -- JApproval No. Approved by the order of the Com mission Commissioner Date Rendezvous Final P&A CONFIDENTIAL Notify BLM/AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Mobilize and rig up D/S for well P&A operation. , . . , . . 10. Spot a 500' balanced cement plug #1from 8300'MD (or as close to bottom as possible) to ?800' MD (500'). (Top stain at 8055' MD) Do not plan to tag the plug- close enough to bottom. Spot a 10 bbl hi visc pill from 5925 to 5700'. Spot a balanced cement plug #2 across the interval from 5?00' MD to 5200' MD (500') leaving 11.0 ppg mud in the lower section of hole. (Stains from 5600' to 5330' MD-very tight) Not required to tag the plug. By the down squeeze method through a retainer set 50' minimum above the shoe (or approx. 2610' MD) pump cement plug #3 as per BLM/AOGCC regulations. Pump sufficient cement through the retainer to extend 250' below (50' of 7-5/8" plus 200' of open hole with 35% excess) and lay a 100' cement cap on top of the retainer. Weight test retainer before pumping cement. Not required to tag the plug. Leave 11.0 ppg mud above and below the plug. Pressure test casing to 1500 psi. NOTE: Notify Slope BLM/AOGCC Inspectors before setting surface plug. Spot a balanced Arctic Set 1 cement plug #4 from 300' to surface. Clear lines and shut down pumps. Rig down cementing unit and clean up. Release Rig. .Cut off wellhead and all casing strings at 3 feet below original ground level. Send casing head with stub to Materials for repair / re-dressing. Weld cover plate over the 7-5/8" casing. Weld another plate across the 7-5/8" x 16" annulus. Drill 1/8" weep holes in both cap sections. Make sure the two sections are isolated from each other. Bead weld the following information on the 16" x 7-5/8" donut plate: ARCO ALASKA, INC Rendezvous "A" PTD # 200-054 APl# 50-103-20316-00 SHL: 2247' FSL, 1255' FWL, Sec. 24, T10N, R1E, UM Remove cellar. Back fill cellar with original soil/gravel as needed. Clear ice pad location and demob all materials and equipment. TJB 4/25/00 FILE: Rendezvous"A" Paul Mazzolini Exploration/Tarn Team Leader SENT BY' 4-25- 0 '11'1BAM ' ARCO Alaska, Inc I' "'{endezvous "A" ARCO ALASKA-+ <307 276 7542 !~' ~evised 4/25/00 T3B 2/ WELLBORE SCHEMATIC and Cement P and A Plan Conductor Port Co,a'i @ loo0'...M__D_ 9-7/8" Hole 7-5/8" Surface Casinq ,~ 2661' MD Cemented with 253 SX AS1 Lite, 240 sx G 85 sacks Arctic Set I Slurry Volume Slurry Weight Slurry Yield 300' Cmt Pluq @ Thickening Time Surface-300' MD 371' Cmt Plug @ 2510'-2881' MD (100' above and 250'below Ret. @ 100 sacks Class G cement + 0.2% 1346 AntiFoam 0,3% D65 Dispersant + 0.4% D167 Fluid Loss 0.5% S1 CaCI2 Accel. 26 Sacks above retainer 85 sacks below retainer Slurry Volume based on 35% excess below surface casing shoe Slurry Weight Slurry Yield Thickening Time 70 degF BI-IST 79 cu-ft 15,7 ppg 0.93 cu-ft/sk 2:37 hours 116 cu-ft 15,8 ppg 1.16 eu-ff/sk 4:38 hours 6-3/4" Hole Ai__I cement sack volumes, rounded u_p to nex_t Increment of__E TD at 8300' MD 500' Cmt Plug.~ 5700'-5200' MD Visc Pill 500' Cmt Pluq....~ 8300'-7800' MD 135 sacks Class G cement + 0.2% D46 AntiFoam + 0,27% D65 Dispersant + 0.25% D167 Fluid Los.~ + 0,19% D800 Retarder Shiny Volume based on/',b" OH 156.6 cu4t Slurry Weighl 15.8 ppg Slurry Yield 1.16 cu-ft/sk Thickening Time 130 degF BHST 4:04 hours 13,5 sacks Class G cement + 0.2% D46 AntiFoam + 0,3% D65 Dispersant + 0.22 % D800 Retarder + 0.4%0167 Fluid Loss Slurry Volume based on 7.5" hole size 156,6 cu-ft Slurry Weight 15,8 ppg Slurry Yield 1.16 cu-ft/sk Thickening Time, 195 degF BHST 3:37 hours SENT BY: ., 4-25- 0 'll'19AM ' ARCO, Alaska, !nc. . t 'FACSIMILE TRANSMI~;SION . .~ ~ ' , Pho "~- ~ 7~ ne: Lmtim: - ~~~,- ' ' Phone' .......... , , pi CO es To: ............... - ............ ~ ~ '""~_.. Subject: " ~ '~C~ ~omm~m~t = .......... _~ _,, . ................ - ARCO ALASKA'~ ~ ~eeem~eO . m m ~m mm ~ k mllllll mm II ~t11111~ · ~ mm~l m mm ~ ~ mm ~ ~m ~m mm ~ m~ t~ mm mm ~ I~ · mm mm mm mini, m ~ mi Il mlm ~ mm ~ i ~lm · mm ~ ~m mi 907 276 7542;# 1/ 2 ANCHORAGE[. ^K '9st$10.43360 · FAX.# 907 265-6224 _= · , , ., ARCO Spark #1 A & Rendezvous "A" ScenmSos- CONFIDENTIAL Subject: ARCO Spark #1 A & Rendezvous "A" Scenarios- CONFIDENTIAL Date: Fri, 21 Apr 2000 10:25:06 -0900 From: "Tom J Brassfield" <TBRASS~mail.aai.arco.com> To: Blair Wondzell <blair_wondzell~admin.state.ak.us>, pditton@ak.blm.gov CC: "Paul Mazzolini" <PMAZZOL@mail.aai.arco.com>, "James A Trantham" <JTRANTH@mail.aai.arco.com> Peter/Blair, we would like to get concurrence on some options for finishing out this season's NPRA wells. As the season nears an end we see the following possibilities: ARCO Spark #1 A: If we complete this well next week, our intent is to start testing the well before break-up. There is the possibility that we will not have enough time to complete the testing phase and will need to secure the well for a Summer shutdown. The intent would be to return next Winter season, complete the test, and then P&A the wellbore. Attached is a propsed "Operations Shutdown" procedure for your review and comment. ARCO Spark #1 A: if time and mother nature would cooperate, there is the remote possibility that we could finish the test and P&A the wellbore. Attached is a proposed "P&A" procedure for your review and comment. Rendezvous "A": We should know early next week if we want to complete this well. We would not have time to test this well. The intent would be to return next Winter season, thru tubing perforate, probably stimulate, complete a well test, and then P&A the wellbore. Attached is a proposed "Operations Shutdown" procedure for your review and comment. We have some schematics we can fax which should help explain the procedures. The depths on the schematics are very rough estimates. Thanks for considering these proposals and your assistance in completing a successful Winter Drilling season. Tom (See attached file: Ren A BLM AOGCC Ops SD Proc by TJB 4 21 00.doc) (See attached file: AS 1 BLM AOGCC Ops SD Proc by TJB 4 21 00.doc) (See attached file: AS 1 BLM AOGCC P&A Proc by TJB 4 20 00.doc) Name: Ren A BLM AOGCC Ops SD Proc by TJB 4 21 00.doc ~Ren A BLM AOGCC Ops SD Proc by TJB 4 21 00.doc Type: Rich Text Format r (application/rtf) Encoding: base64 Description: Rich Text Format ~AS 1 BLM AOGCC Ops SD Proc by TJB 4 21 00.doc Name: AS 1 BLM AOGCC Ops SD Proc by TJB 4 21 00.doc Type: Rich Text Format (application/nO Encoding: base64 Description: Rich Text Format 1 of 2 4/24/00 8:55 AM ARCO Spark #1 A & Rendezvous "A" Scenarios- CONFIDENTIAL ~AS 1 BLM AOGCC P&A Proc by TJB 4 20 00.doc Name: AS 1 BLM AOGCC P&A Proc by TJB 4 20 00.doc Type: Rich Text Format (application/rtl) Encoding: base64 Description: Rich Text Format 2 of 2 4/24/00 8:55 AM PROi ..,SED Rendezvous "A" Operations ~..Jtdown CONFIDENTIAL Revised 4/21/00 PURPOSE: In the event ARCO decides to complete the Rendezvous "A" wellbore, we will not have the time before break-up to test this well. ARCO requests an Operations Shutdown to secure the well until next Winter's exploration season. The intent would be to return in the 2000/2001 Winter season, perforate the well, complete a well test and P&A the wellbore. This proposed procedure assumes that the well has been completed with full tree on wellhead and no perforations. Notify BLM/AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. After running 5-1/2" casing and cementing, running a USIT bond log, a completion string with packer would be run into the well. Tubing and annulus would be pressure tested during this process. The well will NOT. be.. perforated at. tbis..!ime, but thru tubing perforated upon returning during the 2000/2001 Winter season. . The top 2000' of tubing and 3-1/2" x 5-1/2" annulus would be freeze protected with diesel. Kill weight fluid (Brine- weight to be determined from RFT if run or Mud log data) will be left in the tubing and annulus. Install BPV. Nipple down stack, nipple-up tree. Pull BPV. Install test plug. Test tree to 250 and 5000 psi. Pull test plug. RIH with wireline and set plug in "XN" Nipple at the tubing tail @ approx. XXXX' 5. RU to 7-5/8" x 5-1/2" annulus and bullhead approx. 33 bbls diesel to 2000'. l[~"'t ~.~ '~ii .,,,.. ,... ?~"'-6. ':'"S~t BPV in tree. Close all valves and remove handles. Release rig to next well. 7. Clean-up cellar and location to prepare for inspections and Summer Operations Shutdown. 8. Hang sign on tree with the following information: ARCO ALASKA, INC Rendezvous "A" PTD # 200-054 APl # 50-103-20316-00 SHL: 2247' FSL, 1255' FWL, Sec. 24, T10N, R1E, UM TJB 4/21/00 FILE: Rendezvous "A" MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson,~ Chairman DATE: April 22, 2000 THRU: Blair Wondzell, .~~ SUBJECT: P. I. Supervisor 5'/~l~ FROM: John H Spaulding Petroleum Inspector BOP test Phillips Alaska Inc Doyon 141 Rendevous A Wildcat PTD 200-054 April 22, 2000: I traveled to Phillips Alaska's wildcat well Rendevous "A" to witness the BOP test on Doyon 141. The AOGCC bop test is attached fro reference. As noted on the BOP test report form, 2 choke manifold valves had bonnet leaks, 1 flange leak on the stack and 1 IBOP failure. All items were repaired and testing while we were testing. SUMMARY: I witnessed the BOP test on; Doyon 141,4 failures, 22 valves, 6.5 hours Attachment: bop doyon 141 4-22-00js STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: Doyon Rig No. ARCO Alaska Inc Rendevous A Set @ Weekly X Other 141 PTD # Rep.: Rig Rep.: Location: Sec. TEST DATA 200-54 DATE: 4/22/00 Rig Ph.# 907-263-3110 Mike Whitely Jim Willingham 24 T. 1ON R. 1E Meridian Umiat MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gert) PTD On Location yes Standing Order Posted yes Well Sign yes Drl. Rig ok Hazard Sec. yes BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 25O/25OO P 25O/5, OOO P 250/5,000 P 250/5,000 P 25O/5, OOO P 250/5,000 P 250/5,000 P 250/5,000 P MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250/5,000 P 250/5,000 P 250/5,000 P 250/5,000 P* CHOKE MANIFOLD: No. Valves 14 No. Flanges 33 Manual Chokes Hydraulic Chokes 1 Test Pressure P/F 250/5,000 P* 250/5,000 Func~oned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3,000 I P 1,725 P minutes 39 3 minutes 5 X Remote: 5 .@ 235O avg. Psig. sec. sec. X TEST RESULTS =. Number of Failures: ~4I ,Test Time: 6.5 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within~ 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: 2 choke manifold valve bonnets leaked, 1 flange leak, 1 IBOP failure Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspe~t.(~lL (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: 141 4-22-00 js ex'pl. John H. Spaulding STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X Rig Change to Doyon 141 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2225' FSL, 1303' FWL, Sec. 24, T10N, R1E, UM At top of productive interval 2225' FSL, 1303' FWL, Sec. 24, T10N, R1 E, UM At effective depth At total depth 2225' FSL, 1303' FWL, Sec. 24, T10N, R1 E, UM 5. Type of Well: Development _ Exploratory _X Stratigraphic _ Service __ 6. Datum elevation (DF or KB feet) RKB 33 feet 7. Unit or Property name Exploration NPRA 8. Well number Rendezvous A 9. Permit number / approval number 200-54 10. APl number 50-103-20316 11. Field / Pool Exploration 12. Present well condition summary Total depth: measu red Effective depth: Casing Conductor Surface Production true vertical measu red true vertical Length Size feet feet Plugs (measured) feet feet Junk (measured) Cemented Measured Depth True vertical Depth Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) ORIGINAL RECEIVED APR 1 4 2.000 A~asks Oi~ & Gas Cons, Commissior~ Anchorage 13. Attachments Description summary of proposal__ Detailed operations program __ BOP sketch __X Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic __ 15. Status of well classification as: 14. Estimated date for commencing operation April 15, 2000 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title: Drilling Team Leader Paul Mazzolini Questions? Call James Trantham 265-6434 Date O~i-/ll/OO Prepared b~/ Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test_ ~ Location clearance Mechanical Integrity Test__ Subsequent form required 10- ~'~O'7' ORIGINAL SIGNED, BY Robert N. Chdstenson Approved by order of the Commission Commissioner Approval no~)O' lo I Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Doyon 141 Diverter Schematic Flowline 21N" 2,000 psi WP DRILLING SPOOL w/16" Outlet 211~,, HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) RECEIVED APR 1 4 ;~000 Alaska Oi~ & Gas Cons. ,Anchorage ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS L--I F] I I 3" 5,000 psi WP OCT MANUAL GATE V r--J KILL LINE ~r~ 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator E~ / I / DSA 13-5/8" 5,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple L 1 3" 5,000 psi WP Shaffer GATE VALVE ~/hydraulic actuator CHOKE LINE 13-5/8" 5,000 WP psi DRILLING SPOOL L1 w/two 3" 5M psi WP outlets I SINGLE 13-5/8" 5,000 psi WP, DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom x 11" 5,000 psi WP HYDRIL MPL BOP w/pipe rams RECEIVED APR 1 4 2.000 AJaska 0il & Gas Cons. Conlmission Anchorage ----- Rendezvous NPRA ---' Drillina Fluid System on Dovon Ria #141 : 3 - Derrick Flo-Line Cleaners Pioneer Model S2-12 Desander Tri-Flo 'Low Profile' Desilter Alpha-Laval Model DMNX 418 Centrifuge Pit Level Indicator (wi visual and audible alarms) Trip Tank Fluid Flow Sensor 8 - Brandt pit stirrers RECE\VED APR 1 4 2000 Alaska OU & Gas Cons. Comm\ssior Anchorage MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission _1 Robert Christenson~~) DATE' April 12, 2000 Chairman THRU: Blair Wondzell, P. I. Supervisor FROM: John Crisp?~ ¢_.... SUBJECT: Petroleum ICispector Diverter Function Test Doyon 141 , ,,~,.,-r ~Exp. April 12~ 2000' I traveled to Arco Alaska's Exploratory well Rendezvous "A" located in NPRA being drilled by Doyon 141 to witness the Pre-Spud Diverter function test. Function test went well with no failures. The AOGCC test report is attached for reference. I requested the Drilling Foreman or Toolpusher witness the Gas Detector test due to late hour of our function test. Test will be logged on IADC report book. SUMMARY: I witnessed Diverter Function Test on Doyon 141 drilling Rendezvous A for AAI. Diverter Function Test. No failures. Attachments: Div. Exp. Rend. A 4-12-00jc CC;, CONFIDENTIAL Div. Exp. Rend. A 4-12-00jcl Drlg Contractor: Operator: Well Name: Location: Sec. ALA~ STATE OF ALASKA ~,,,, OIL AND GAS CONSERVATION COI~-,..$SION Diverter Systems Inspection Report Doyon ARCO Rendezvous A 24 T. 1 0 R. Operation: Rig No. Development 141 PTD # Date: 4/1 2~00 Exploratory: X 200054 Rig Ph. # 263-3110 Dearl Gladden Oper. Rep.: Rig Rep.: 1E Patrick F. Krupa Merdian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok Reserve Pit: na (Gen.) DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Turns Targeted Long Radius: Well Sign: Drlg, Rig: Flare Pit: 21.25 yes yes 16 95 Da yes yes na ok ok na in, in. ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 2950 psig 1 600 psig min. 21 sec. 2 min. 57 sec. 5 @ 2200 psig MUD SYSTEM INSPECTION: Trip Tank: Mud Pits: Flow Monitor: Light Alarm ok ok ,, , ok ok ok ok GAS DETECTORS: Methane Hydrogen Sulfide: Light Alarm not tested not tested not tested not tested Wind Direction Rig Shop Camp Road Entrance Non Compliance Items 0 Repair Items Within N/A Day (s) And contact the Inspector @ 659-3607 Remarks: Tool Pusher or Drilling Foreman will witness function of gas detector system & log on IADC book. Distribution orig. - Well File c - Oper/Rep c- Database c - Trip Rpt File c - Inspector AOGCC REP' John Crisp OPERATOR REP.: Div. Exp. Rend. A 4-12-00jcl Dearl Gladden DVTRINSP.XLT (REV. 1/94) TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION Paul Mazzolini Drilling Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-$192 PHONE; (907) 279-1433 FAX: (907) 276-7542 Re: Rendezvous A ARCO Alaska, Inc. Permit No: 200-054 Sur. Loc. 2225'FSL, 1303'FWL, Sec. 24, TI0N, RIE, UM Btmhole Loc. 2225'FSL, 1303'FWL, Sec. 24, T10N, R1E, UM Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. S,~c, erely~ Chair BY ORDER OF TI/.'[.~ COMMISSION .DATED this ~" day of April, 2000 dlf/Enclosures cc: Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation w/o encl. Re: Rendezvous permit Subject: Re: Rendezvous permit Date: Mon, 3 Apr 2000 17:55:39 -0900 From: "James A Trantham" <JTRANTH~mail.aai.arco.com> To: "Sharon Allsup-Drake" <SALLSUP@mail.aai.arco.com>, Blair_Wondzell~admin.state.ak.us Sharon & Blair, I am in BOP school this week so thanks for forwarding this message. We do not plan to use the Rendezvous well for annular injection. Also, because of a scedule acceleration, we may need approval by this time next week for the well. I will keep you informed on the timing of the well. jt Sharon Allsup-Drake 04/03/2000 03:31 PM To: James A Trantham/AAI/ARCO@ARCO cc: Subject: Rendezvous permit James - Blair Wondzell callsed this afternoon to ask about the Rendezvous permit to drill we sent over to AOGCC. He was wondering if we intend on annular disposal down this well. We didn't include any provision for it in the permit package. Sharon I of I 4/4/00 8:15 AM r' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.0O5 la. Type';iWOrk: Drill r~ R~drill ' BI "'1 'ih. Type of well. Explor;iory '" ["~ Stratigraphic Test FI Development Oil r~ Re-entry ~] Deepen r'~I Service ~] Development Gas [-'] Single Zone [~] Multiple Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. GL 100 & 33' RKB feet 3. Address 6. Property Designation Exploration P.O. Box 100360 Anchorage, AK 99510-0360 AA-081803/AK5148 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 2225' FSL, 1303' FWL, Sec. 24, T10N, R1 E, UM Exploration NPRA Statewide At top of productive interval 8. Well number Number 2225' FSL, 1303' FWL, Sec. 24, T10N, R1 E, UM Rendezvous A #U-630610 At total depth 9. Approximate spud date ~/,,K-,~'~'~ 'Amou nt 2225' FSL, 1303"FWL, Sec. 24, T10N, R1E, UM ~ .... ......... ~,., ,_, ._9~_ $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1803' @ TD feet Fish Creek, 10 miles feet 5756 9000' MD / 9000 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: N/A MD Maximum hole angle N/A° Maximum surface 1700 psig At total depth (TVD) 4212 psig 18. Casing program Settin,(:j Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coup.I. in~ Length MD TVD MD TVD {include stage data) 20" 16" 62.5# B PEB 80' Surface Surf. 113' 113' 135 sx AS I 9.875" 7.625" 29.7# L-80 BTC 2967' Surf. Surf. 3000' 3000' 544 sx Class G 6.75" 5.5" 15.5# L-80 BTC-Mod 8967' Surf. Surf. 9000' .9000' 192 sx Class G ,,, ,,, 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary TotalDepth: ~:r~:al f::: Plugs(measured) 0 R I 61NA L Effective Depth: measured feet 'Junk (meaSured) true vertical feet Casing Length Size Cemented Measured depth 'True Vertical depth Conductor Surface Production RECEIVED Perforation depth: measured APR -3 2000 true vertical A~a~8 0il & Gas Cons. C0mmissbn Anc~or~Je 20: Attachments Filing"fee [~] Property Plat r-'] BoP Sketch [~] Diverter Sketch [~] Drilling program r'~ Drilling fluid program [~] Time vs depth plot r~Refraction analysis r"'] Seabed report [~] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct"to the best of my knowledge Questions? Carl James Trantharn 265-643, Paul Mazzolini pr~narp_d hv .~harnn AIIm]o-Dr~k~ Commission Use Onl) Permit Number APl number I Appro~t.~e ISee cover letter ~-. O(:~ -" ,.~-~ 50- ,,'/O ..~"" ~ (~ ~"~'I [' --~ ~¢~)~;) }for other reqUirements Conditions of approval Samples required 1~ Yes r'"] No Mud log required '~ Yes [-'] No Hydrogen sulfide measures D Yes ~ No Directional survey required ['"] Yes '~ No Requked working pressure for BOPE F-']2M; D 3M; r'~ (~ [~] lOM;B Other: ORIGINALRobert N. ChristensonSIGNED'BY by order of~'~ ,,~ ' Approved b~/ Commissioner the commission Date/'/'~"J~--,f.~' Form 10-401 Rev. 12/1/85, Submit in triplicate Rendezvous NPRA General Drillinq Procedure o , , . ! , , ! , 10. 11. 12. 13. 14. 15. 16. 17. Move in and rig up Nabors #19E over pre-installed 16" conductor casing. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (3000' MD). Run and cement 7-5/8" casing. Install and test BOPE to 5,000 psi. Test casing to 2,500 psi. Drill out cement and 20' of new hole. Perform leak off test. Drill 6-3/4" hole to 9000' MD with LWD tools. Run open hole evaluation logs. If the well is to be further evaluated, P&A this hole section to twin the well at approximately 200' step out. Drill and core the twinned well. Run open hole evaluation logs. If the well is to be tested, run 5-1/2", 15.5#, L-80, BTC-M production casing. Go to step 13. If the well will not be tested, P&A per BLM regulations. Go to step 17. Complete the well with 3-1/2", 9.3#, L-80, EUE 8rd tubing. ND BOPE. NU upper tree and test to 5,000 psi. Shut in and secure well. RDMO Nabors #19E. Hook up well for flow testing to surface tanks. Produced fluids will most likely be reinjected into the formation it was produced from or may be trucked to Kuparuk production facilities. When complete, plug and abandon the well as per BLM regulations and RDMO CTU. Thoroughly clean location and block off access ice road. Rendezvous i' NPRA Formations and Formation Evaluation DISCUSSION The following is a table of the estimated tops of important geological markers, formation pressures, and expected depths of water/oil/gas for the Rendevous well. Formation or Marker Pick Depth (ss) Uncertainty Water/Oil/Gas Est. Pore Pressure FORMATION EVALUATION The anticipated type of logging, coring and testing are detailed below: LOGGING PROGRAM A. LWD/MWD: GR/Resisitivity: Base surface csg to TD B. Wireline Logging Wireline #1 - Sonic (dipole), SP, Microlog Wireline #2 - GR/density/neutron Wireline Options - CMR, FMI (Torok) II. Full Diameter 2 1/2" core One-two 90' cores in Upper Jurassic III. CONTINGENCY SERVICES Wireline #3 - RFT Wireline #4 - Rotary Sidewall Cores CBL or USIT VSP-Cased hole vertical seismic profiles may be acquired. The profiles will be acquired using up to three vibroseis trucks. These trucks are off-road vehicles approved for tundra travel. The operation typically requires the vibroseis units to move along a line starting at the well bore and stop at varying distances from the well out to a total distance dependent on the depth of the well and the magnitude of any deviation of the well. For this project the vibroseis units will probably remain on the ice pads or roads. If the trucks do leave a pad, all VSP lines will lie within a Y2 mile radius of the surface location of the well or along the road. -1- Rendezvous i" NPRA Formations and Formation Evaluation IV. V, MUDLOGGING Mudlogging service should be in operation from the base of the surface conductor to TD. Service should include R.O.P. (recorded at 5' intervals), lithology, total gas, sample collection, gas analysis of cuttings, gas chromatography, and H2S detection. A. Cuttings: Sixty foot (60') wet and dry samples will be collected from surface to 4500' subsea. Thirty foot (30') wet and dry samples will be collected from 4500' subsea to the TD. Ten foot (10') wet and dry samples, or continuous samples will be collected across the Kuparuk, and Jurassic intervals. Testing Flow testing and pressure build-up tests will be used to determine formation properties and estimate the commercial nature of the NPRA prospects. Flow testing for any particular interval will consist of an initial unstimulated flow period and pressure build-up test. The flow period will be determined on site in response to the well's productivity. The well will be flowed to temporary surface production facilities consisting of gas separation system and fluid storage tanks. Produced fluids will either be trucked to an existing production facility or reinjected into the formation following completion of the flow testing. Depending on the production rate from the unstimulated flow period, an appropriate stimulation of the interval may be undertaken. The stimulation treatment may consist of an acid wash or fracture treatment. Once the stimulation treatment is completed, a second flow period and pressure build-up test will be completed. Additional prospective intervals may be tested as described above or may be commingled with previously tested intervals. If commingling is chosen, production logging will be performed during a flow test to determine the productivity of individual zones. -2- I Wellbore Schematic and Cement Design for Rendezvous 16" Conductor @80' RKB to GL Casing Size / Hole Size: 16"/20" Depth: 80' MD-RKB Top of Cement: Surface Excess Calculated: 100% Volume Calc: (80')(0.7854 cu-ft/ft)x(2) = 125.7 cu-ft Slurry Volume 125.7 cu-ft ARCTICSET I Slurry Weight 15.7 ppg Slurry Yield 0.93 cu-ft/sk Sacks AS 1 135 sks 9-7/8" Hole 7-5/8",29~0, BTC Mod, R3 Surface Casing @3000' MD-RKB 6-3/4" Hole 5-1/2", 15.5#, L-80, BTC Mod, R3 Production Casing @ 9000' MD-R~ Note: Design and calculations are preliminary. Base Permafrost ~ 900' MD '~-TOC - 75OO' MD Casing Size / Hole Size: 7 5/8" / 9 7/8" Depth: 3,000' MD Top of Cement: Surface Top of Tail Slurry 2700' Port Collar: 1,000' MD Excess Calculated: 45% Below Frost; 400% Above Frost BHT (Static): 70°F BHT (Circ): 70°F Tail Slurry: Volume(3000,.2200,)(0.2148 cu-ft/ft)(1.45) = (249.2 cu-ft)/(1.17 cu-ft/sk)=213 sacks (+ 21 sxs for shoe System 234 sacks Class G cement + 1% S1 (CaCI2) + 0.3% D65(dispersant) + 0.2% D46 (defoam) Slurry Volume 273.8 cu-ft Slurry Weight 15.8 ppg Slurry Yield 1.17 cu-ft/sk Thickening Time 3.5 - 4.5 hours Lead Slurry: Volume (2200'-900')(0.2148 cu-ft/ft)(1.45) = 404.9 cu-ft (900')(0.2148 cu-ft/ft)(5) = 966.6 cu-ft; 966.6 + 404.9 = 1371.5 cu-ft (1371.5 cu-ft)/(4.43 cu-ft/sk)= 310 sacks System : 310 sacks Class G + 9% D44(NaCI) + 30% D53(Gyp) + 50% D124(spheres) + 1.5% S1 (CaCI2) + 1.5% D79(extender) + 0.2% D46(defoam) Slurry Volume 1371.5 cu-ft Slurry Weight 10.7 ppg Slurry Yield 4.43 cu-ft/sk Thickening Time 6.0+ hours Casing Size / Hole Size: 5 1/2"/6 3/4" Excess Calculated: BHT (Static): BHT (Circ): Volume Calc: (9,000' - 7,500')(0.0835 cu-ft/ft)(1.75) = (219.2 cu-ft)/(1.2 cu-ft/sk) = 183 sacks (+9 sxs for shoe) 192 sacks Class G cement + 2 gps D600(latex) + 0.1 gps D135(stabilizer) + 0.2 gps D47 (defoam) + 3% D53(Gyp) + 0.6% D65(dispersant) + 0.1% D800(retarder) Slurry Volume Slurry Weight Slurry Yield Thickening Time 75% (depending on est. OH) 195°F 130°F 227.9cu-ft 15.8 ppg 1.20 cu-ft/sk 3.5 - 4.5 hours Rendezvous NPRA Leak Off Test Procedure After cementing casing and nippling up BOPE, RIH to top of cement and pressure test the casing to 2500 psi for 30 minutes and record on chart (AOGCC required casing integrity test). Record the information on the AAI LOT form (you can locate on the drilling web page). Plot Casing Pressure Test (volume vs. pressure and time holding pressure on casing). Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. 2. Drill 20' of new hole below the casing shoe. Circulate the hole to establish a uniform mud density throughout the system (required for a good FIT or LOT). PU into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill stem at 1/4 to 1/2 bpm. . On the LOT form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. 7. At leak off pump 3 bbls of mud into formation prior to shutting down the pump. , Shut down when the leak-off point is clearly seen and 3 bbls of mud has been pumped into the formation. Record initial shut-in pressure. With the pump shut down monitor, record and report the shut -in pressures for a minimum of 10 minutes or until the shut -in pressure stabilizes. Record time vs. pressure in 1-minute intervals and plot information. Bleed the pressure off and record the fluid volume recovered. Forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the Agencies. 11" 5000 psi BOP Sta .x Nabors Rig 19E I Kill Line 5 4 3 Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. I Choke Line BO.__~_P Stack Te__st. ~--2. CheI 1. FillBckOtPh~ttaa(~haor~_dmoawninfO~cdreWiwthsaWraet~urilyretracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 5 minutes. Increase pressure to 5000 psi and hold for 10 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi for 5 minutes and 5000 psi for 10 minutes. Continue testing all valves, lines, and chokes with a 250 psi Iow for 5 minutes and 5000 psi high for 10 minutes. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi for 5 minutes and 5000 psi for 10 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi Iow for 5 minutes and 5000 psi high for 10 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 5000 psi for 10 minutes. 12. Test kelly cocks and inside BOP to 5000 psi for 10 minutes with BOP test pump. 13. Record test information on blowout preventer test form and on pressure chart. Sign and send to drilling engineer. 14. Perform BOPE test a) when initially installed, b) whenever any seal subject to test pressure is broken, c) following related repairs, and d) at 30 day intervals. Functionally operate BOPE daily. 15. Pit drills are to be conductled weekly for each drilling crew. 1. 16" Starting Head 2. 11" 5000 psi Through Bore System Wellhead 3. 11" 5000 psi Hydril SGL Gate (pipe rams), 4-1/16" 5000 psi Side Outlets w/Manual Locks 4. 11" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate 2 Kill valves - one 2" 5000 psi Hydraulic gate and one 2" 5000 psi Manual gate 1 Check valve in Kill Line - 5000 psi 5. 11" 5000 psi Hydril Double Ram (pipe rams on top, blind on bottom), 4-1/16" 5000 psi Side Outlets w/ Manual Locks 6. 11" 5000 psi Hydril Annular Preventer, Flange Connection jt Rev 01/20/00 Date: March 24, 2000 Subject: Pore Pressure Prediction for NPRA area-- from 3D Seismic Inlines: 49222, 49240, 49555, 49663, 49709, 49710, 49744, 49866 Specifically-- Proposed Well: RENDEZVOUS A From: To: Ray Wydrinski ( Vastar-- formerly AEPT ) / Jerry Veldhuis ( AAI ) ATO-1308 James Trantham ATO-1204 This memo is to review the pore pressure prediction for the above NPRA proposed well location(s). The West Fish Creek #1 was the only offset well that was evaluated. Eight seismic inlines from the 1999 East 3D survey were also interpreted all of which have proposed well locations associated with them. All eight proposed well locations are normal pressure with no apparent shallow hazard problems. Seismic Processing: The accuracy of Geopressure prediction is highly dependent upon the accuracy of the seismic stacking velocity field that is used as input. This velocity field is generated by picking velocities at every fourth CDP location with an automated high resolution velocity analysis program (UHC! process developed by AEPT). This process produces a very accurate and densely sampled velocity field to cover each CDP location. The RMS velocities that are output have been smoothed over 300 ms vertically and 150 CDPs horizontally to normalize any instability in the velocity field that might result from noise, lack of signal or variations in CDP fold. Pressure Prediction Procedure: ARCO's PPFG software was used to calculate the pore pressures. The compaction trend looked very similar to what had been observed in Tarn and Alpine, giving reason to use the same models for NPRA. 1) A Normal Compaction Trend Line (NCTL) was determined for each seismic line. The slope of this line was 4.0.5 with an intercept of about 150. 2) A comparison was made between the NCTL and the wireline sonic DT (for W. Fish Creek #1) or the Seismic Integrated Travel Time (ITT, for the proposed wells). This difference is AAT. RECEIVED APR -3 000 Alaska Oil & Gas C~s. Commission Anchorage 3) From the Alpine and Tarn study, a Translational Trend model was developed to convert the AAT to equivalent mud weight (PP). This equation is: PP = C2 *AAT2 +C1 *AAT +C0 where C2 = -2.5769 e-04; C1 = .119231; CO = 8.94231 4) The fracture gradient was determined using the Eaton Method where the inputs are the bulk density (used from West Fish Creek #1) and Poisson's Ratio (from a West Cameron model). West Fish Creek #1 Figure #1 is the pore pressure calculation for this well. On the left is the wireline sonic DT (black curve) with the NCTL (red line). On the right is the pore pressure calculation (blue curve), actual mud weight (green curve), fracture gradient (red curve) and the overburden gradient (black curve). Labeled on the figure is the casing sizes, areas of hole problems, formation tops and areas of lithology changes. From this plot it appears that the models from Tarn and Alpine are similar to NPRA. No leak off data was available to validate the fracture gradient model. Seismic Pore Pressure Predictions (No Indication of Shallow Hazard) The following figures are the pore pressure predictions across the evaluated seismic lines in depth with an overlay of the seismic migration lines. Figure Number Seismic Line Well Name 14 49710 Rendezvous "A' The warmer the colors the higher the predicted mud weight (pore pressure). Based on the West Fish Creak #1, a kerogen shale is located at about 8,800'. This kerogen zone is about 500' thick and appears as an increase in pressure but is actually a lithology effect. Another lithology effect is the silt zone at about 10,000'. The NCTL is based on shales with some silt. The velocity through silts is slower than the shales giving a false increase in pressure. RECEIVED APR 2000 Ala~ka Oil & Gas Cons. Commission Anchorage The following figures are the pore pressure predictions across the evaluated seismic lines in time with an overlay of the seismic migration lines. Figure Number Seismic Line 15 49710 Well Name Rendezvous "A' Pore Pressure Prediction at Each Well Location The following figures are the pore pressure prediction for each proposed well location. On the left side of the figure is the seismic Integrated Travel Time (ITT, black curve) with the NCTL (red line). The right side of the figure is the pore pressure prediction (blue curve), fracture gradient (red curve) and the overburden gradient (black curve). Figure Number Seismic Line 27 49710 Well Name Rendezvous "A' Conclusions: 1. There are no apparent shallow hazards for any of the proposed well locations. 2) The West Fish Creek #1 shows that the pore pressure model used in Tarn and Alpine fields appear to work in NPRA. 3) The slope and intercept for the Normal Compaction Trend Line from the Alpine and Tarn study is the same as this NPRA study. There are some lithological effects due to kerogen and silts that give an indication of an increase in pore pressure between 8,000' and 10,000'. The predicted mud weights will range between 10.5 to 11.0 ppg. 4) If there are any further questions, please contact Project Geophysicist - - - Jerry Veldhuis (907) 265-6396 NPRA 2000 Drilling RECEIVED APR -;5 000 Alaska Oil & Gas Cons. Commiss',3n Anchorage Rendezvous Depth vs Time 0] MIRU I I I I - 1000 ........ -~- ~ .... ~ .... -~ .... 7 et 7-5/8" csq I -3000 -,- -, -7000 -8000 -9000 -10000 .... i- .... [ 1 .... I- = -I- -1 I- ~ .... ~- .... I ..... r- -i .... ~' .... I I I I I ~ i I I I i i ~ i ! i I I i I ~ I I I I I i i I 7 I I i 4000 ........... ~- ....... '- * .................................................. i I I i I I . I I I I I I t I I I I I j I I I I I I I I I ! I I I I I ~ I I I 1 I I I I I I I I I I I I i I J i i I i I I I I I I I , II I I I j I I I ; I I ! ~ i 5000 ................ ..... ~ .... T ........ -[ .... T .... 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'~ ....... i I ~: I / 0 5 I 0 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 TI~E TO DRILL (DAYS) jt 9/99 ~ARCO E×p orat on ~nd Production Technology Pore Pressure and Fracture Gradient System 09/17/99 R~a~nski Prolcct: NPR Cross Section: ]L49710 PP DataSet: ~L49710_PPG Seismic Parasol: L49710 SZ Method: Trend Curve NC'II,: 153-4$ Model: PLIESTOCENE 12.50 13.00 13.50 Fieure 14 Pore Pressure a~d Fracture Gradient System ~(:,n~: AVDIL49710 CO~P 09/20/99 Ra~Ld rinski IO(K) 6OOO I290C 40 6O 8O 100 NCTL Intercept at GL = 153 l,ogarithrnic Slope 12o 14o 16o8 9 IO 11 12 13 14 I5 16 17 18 19 20 PPG Figure 27 ARCO Technology and Operations Services pro.i~o,: NPR Cross Soctio~: IL49718 Por,,e Pressure and Fracture Gradient System StismicPPl)amStl:Dataset: IL49710_PPTL49710_ST 09/I6/99 Ray~drinski Scale: Vertical l ti~ = 607 rosco, }lo*qz~nml 1 in = 84 cdp 0 0000000000000000 0 00000000000000000000000000000000000000000000000 0 CDP2 333333333444444,1 4 ,I5555555555666666666677777777778888888888999999 9 9 1234567890123456 7 90123456789012345678901234567890123456789012345 6 0000000000000000 5 00000000000000000000000000000000000000000000000 8 PPg 0.0 Method: Trend Curve NCTL: 153-4$ Modcl: PLIESTOCENE 200.0 400.0 600.0 800.0 1000,0 ]400.0 T E 20(X).0 Fklure 1 5 I DRILLING TIME AND MUD WEIGHT CURVE -e-Depth ............ 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'. , , , , ~ , I ~ , , ~ r , , ~ ! ~ , , I ~ , , , ~ , , ! ~ ', ~ , ~ , , ~ ~--~-?¢F ~?T. ;' -~-~--~-FF [ q-~-~-~-~- F 5 %----I ~ '~- ~, , ~,,,, ,~,,,' ,, ,,, , ! ..... , Gas outmudl t , I~1 I . I I I I I : / I I I I I I ¢2 '. f i ~ , ~ ~ i ~ , i , , . 10000 12000 I I I I I [ I I Ii /1~ I : , I I I ' ' ' '_'__'_LLL~ ~ ~ ' ' ' ~ I!llillll 111! I~1 ,11 I r ti~fi --I----!--I--LLF I ~1~ i I i I ,,,, ~ ,11-:-'-F:-FF ~*~ -'-'-I-~ --I111 IIIllili~TTT'i[!ll -i~li · I .f~l~ IIIIIIII I %~i~-!-I-I-III IIII I~ ! I1[~1111 III .... '~-i-[- i TTT] -~-,-~-~-i- - F F ' '_1 ose/Regain Circulation ' ' ' ~_~___~__,_,_,_;_,_ ~ !' _ I i ! i i I i i i i i t i ] i i I I I I I J I I i ! I I I FI t I I -"" .... -- ~ _1 _1_1_ I I I I I I i I I I I I I I I I I I I I I I i I i i I I/ i i I i i i .....,,,,,,,,,,,,,,L .... !1' °1! T T r i ~-i-,-,-,-,-FFT~-77 ~ ii-,--, .......ogge 'l ........ L,, , ~ '_, I I [ i I ' I I I I ~I I ] I i I I I I I i I I I. I . . , . r ~ r B ir 9.0 8.8 8.6 8.4 8.2 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100 TIME TO DRILL (DAYS) jt 9/99 A 2000 4OOO 6OOO 8OOO DRILLING TIME AND MUD WEIGHT CURVE ; Depth North Inigok Test Well #1 ............. Mud Weight i ~ i i i J i ~ i i ii i i i i i i i i i i J J I ~ r ' m J J it i i i ~ i Move in rig 1/24/81f/Umiatj-i-,,, ......... , ..... , , , ,-~-'~-'-~, , ,~, ,' ,'~-L~, ,-, ..... ,,, '-J ...... , -~ .....~' , , ,' , , I' , , ,,' , ,, , q --I-- T --I-- -- --I-- ~- ~ --I-- -- --~-- T --i-- ~- U --I-- ~- --i-- T i I I I I I I I I I I I J I I I I ! I J I ! i ! I I I I I I I ~ I ! i I J.. ~j ~ :~;;/~.-~;;i:.::.] ~.-~:¢:j¢~. ~-~ ~.,;ff; ~z,¥.;::~ ~..:,. I J I ! L I I L ~ ' J ~':~ - - M - - ~ -- - 4 ...... ~-'-7-'-?n-rq-J-T-~-~n-rq-r~-i-~ ~-rT-J-~n-r~-FT-I-~n-j ~-r~-i-tn-rq-~7-~-;n-rq-r~-~-~-j-rn-~-~F-~-r ' I ' ~? 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L''' ~-I ~-~m-~-~-T-~-~n-r -i-~-i-~ -rq-~--~n-rq-F~-~-~ -r~-r~-,-tZ?-=~-~ '-,-~_~ ...... ~ .... ~--~-'-~-'-, ~-~-- , , , J , , , , j , J , ~ J , J J J J J J J J J J J J ', I ' ~ j J i J J ~' ' J J , i i I Iii J i i i J J , i , ~ i i J i i i i ~ ~ i i ' ' J ' ' J ~ J J ' ' ' ' J ' 'J I ' ' ~ I ' ' ' ' ~' ' ' I ' ' ' ''~ j ' I ' [ ' ' ' ~ ' ' ' ~ I I I I I I j I I I I I I I I I I I ~. I I I Il-- -- I I I I':; I I I I I I i I ~ ~ -, .................. ~i~.~ ......I Gore ~ r .... ~ -, ..... ~ ......... ~ ~~ ~, · , , , , , .... I I I I i I I I ! I ~_ ~ · I I , -- -- -- ~'~ ~ - - ~ ~- ~ .... l- '- -i- 12000 -L_I_ I I I I T ~ J_l_~_l_ Illl Illl ~-I-~-[- I!tl 10000 .... IIII !111 I111 IIII Ifil IIII I-rq-I- Jill M--M4--1- 1111 IIII Illl IIII J--LJ--I-- I111 IIII IIII Jill ~-~-i- IIII IIII I , I I I I I [ I I I I -I- i- ~- t- -I- ~- -I- T I I I I I i I I I I~? I i I I I I ................, , ,, ,,,, , ~-~"'-~, .... , , ~ , , .:~""-, , , , . -iRan 9-5/8" Casing , J ! , I , , J '~?' J I J I ? 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Rig Release0 4/5/81 I I J I I i I I I I I I r I I I I I I I I I I i I I I I I I I I i I I I i I i I ............ - ~.4 "~ - f- 'T --I-- LOT 2.0 I ..... ..... -"- ]1 core #$ " .!' .... ' ' o I I I ! i I I I I ~ I i I I ."-"'" 4tc° ," , ......,, - !,,' dli og, g,e' ' '" .... - "-'.,~,' :" -I8'88 6 I I I ! I I i f I i I i i i ........... ', 84 I I I I I I I i I I i i i I ° I-~ I i' ] ] I' I I I I I I I I [ I I I i I i 8.2 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 12.0 11.8 11.6 1 1.4 11.2 11.0 10.8 10.6 10.4 10.2 10.0 TIME TO DRILL (DAYS) jt 9/99 Rendezvous ~"' NPRA Pressure Analysis and Prediction (Per 20 ACC 25.005 (c) (7) and 20 ACC 25.033 (e)) DISCUSSION: An analysis and prediction of over-pressured strata was performed for the Rendezvous well as required by AOGCC regulations. ARCO does not expect to encounter abnormal pressure from any zones. The prediction is based on an evaluation of offset wells North Inigok Test Well #1, West Fish Creek #1, and South Harrison Bay #1. Attached are the following: Mud weight versus depth graph for these wells. Seismic analysis for Rendezvous with pore pressure, frac pressure and anticipated mud weight graph. Rendezvous ~ NPRA Pressure Information and Casing Design DISCUSSION The following presents the data used for calculation of the anticipated surface pressures (ASP) used for the design and drilling the Rendevous well. Casing Fracture i Pressure Pore ASP Drilling Size . Gradient i Gradient Pressure 16", 113' TVD 113' MD ~ 1.0 .p..[~ 8.5 ppg 52 ~s~ N A ..................................... 7-5/8; ............ i~ ............................................ 3000; ........................................................ TVD / 3000'~ ........................................ MD i! .......................................................... 14.8 ppg ~i ........................................................ 9.5 ppg t~ ................................................ 1500 psl'~ ............. ~i ....................................................... 1980 psi: .................. ............. .5..:.!...,.'.2..i.'. .................................. .9...0..0...0.1...T.VD / 9.0..0...0.1.....M.....D. ................................... .1.....7.....6.....p..p..g ............................ 1....0.......8...p...p...g. .............. i ............ .5.....0...5....0....P.S. ............................................. ..N....,'.'A.. ............................ Expected Maximum Mud Weights: 9-7/8" Surface Hole to 3000' TVD / 3000' MD: 10.5 ppg 6-3/4" Production Hole to 9000' TVD / 9000' MD: 11.5 ppg Procedure for calculating Anticipated Surface Pressure (ASP): ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP =[(FG x 0.052)-0.11] D Where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion factor from lb/gal to psi/ft 0.11 = Gas gradient in psi/ft D = True vertical depth of casing seat in ft. RKB OR 2) ASP = FPP-(0.11 x D) Where: FPP = Formation Pore Pressure at the next casing point ASP Calculations: 1. Drilling below conductor casing (16") ASP = [(FG x 0.052)- 0.11] D =[(11 x 0.052) - 0.11] x 113 = 52 psi OR ASP = FPP- (0.11 x D) = 1500- (0.11 x 3000) = 1170 psi -1- Rendezvous i" NPRA Pressure Information and Casing Desi.qn 2. Drilling below surface casing (7-5/8") ASP = [(FG x 0.052) - 0.11]D = [(14.8 x 0.052) - 0.11] x 3000 = 1980 psi OR ASP = FPP- (0.11 x D) = 5050- (0.11 x 9000) - 4060 psi Casing Performance Pro .p..erties t ~ Internal i ........................................................................ I '~'~'~'ii'~'"~'{~:'~'~'~ .......... S~ze Weight , Grade ] Connecbon ~ Y~eld t Collapse Jo nt ~ Body Conductor Casing 16 62.58 ppf 7-5/8" 29.7 .p..,p..f L-80 BTC 6890 .p...s 4790 p..si 575 M 683 M .............. ..................................... .5....'..!../..2.i'i' ........................................................................... .!....5..:.5....P..~.!. ............................. Casing Setting Depth Rationale 16"-113' RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. 7-5/8"-3000' TVD RKB 5-1/2"-9000' TVD RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling to next casing setting point. Production casing to cover all open hole and all previously set casing to allow comprehensive testing of the well. This casing will not be set if logs indicate the well is a dry hole. -2- Rendezvous NPRA Drillin,q Fluids Proqram i Spud to 7-5/8" i 5-1/2" Production ' Surface Casing. ' Casing,. Density i 10.5 t 8.6-11,5 PV ! 20-26 16-20 .................................................................................................................................................. i ............................................................................................................................................................................................................................ YP ~ 15-25 15-20 ................................................................................................................................................... ~ .................................................................................................................... ~ ...................................................................................................... i......v...!s..c..~s..!.!y.. ..................................................................................................... ! ............................................. 5.0,.,-..7,..0.. .................................................................................... .3..0....-..4...~ ....................................... Initial Gel i 5-15 4-6 1 O-Min. Gel i 15-40 i 6-8 APl Filtrate I 10-12 8-10 .p..H 9.5-10 9.5-10 '.....°./,.o.....S....o..!.id....s. ...................................................................................................... I ........................................... ~..~ oo/.o .................................................. ..4..-..?/..0.. ........................................ Drilling Fluid System on Nabors Rig #19E: 3 - Derrick FIo-Line Cleaners Demco Desander Derrick Desilter Derrick DE1000 Centrifuge Pit Level Indicator (w/visual and audible alarms) Trip Tank Fluid Flow Sensor 9 - Gallagher pit agitators Cuttings Dryer Drilling Area Risks: Examination of the 3 nearest offset wells North Inigok Test Well #1, West Fish Creek #1, and S. Harrison Bay #1; (see Attachments) reveal no subsurface shallow hazards such as abnormal pressure or lost circulation zones. No H2S is anticipated in drilling the NPRA Exploration wells because we will not be penetrating the Lisburne formation. The mud weights planned for the NPRA Exploration wells are conservatively based on those used during drilling of the offset wells. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 30, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Permit to Drill 50-103-20316-00 Confidential RECEIVED APR 000 Alaska 0il & Gas Cons. C0mmi~)n Anchora~o Dear Mr. Commissioner: ARCO Alaska, Inc. submits the enclosed additional information for the ARCO Rendezvous A application for Permit to Drill. The estimated spud date for the well is April 5, 2000. As noted in the General Drilling Procedure, the intent is to drill through the objective and if necessary, the well may be twinned to obtain core. We are applying to permit a pilot hole and twinned wellbore for core if quality reservoir is present. Please note that offset wells show no indication of H2S. However, monitoring equipment will be operational on the rig. Also, from analyzing offset wells and shallow hazards there are no indications that shallow gas will be encountered. This well is located on Federal Lands and will also be under the jurisdiction of BLM. Any coordination with the BLM on inspections would be appreciated because of limited bed space at the remote campsite. Please hold information on this well confidential. If you have any questions regarding this matter, please contact me at 263.4603 or James Trantham at 265.6434. Sincerely, P. Mazzolini Exploration Drilling Team Leader PM/JT/skad ARCO Alaska, Inc. '~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Distribution: Peter Ditton, BLM Jim Winegamer ARCO, ATO1496 TONY KNOWLE$, GOVERNOR ALAS~ OIL AND GAS CONSERVATION COMMISSION November 8, 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Mr. Paul Mazzolini Exploration Drilling Team Leader ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Subject: Review of Permit to Drill Applications for NPRA Dear Mr. Mazzolini: On November 5, 1999, the Alaska Oil and Gas Conservation Committee (AOGCC) received' your package containing ARCO Alaska, Inc.'s (AAI) Permit to Drill Applications for eight proposed exploratory wells in the NPRA. These applications are currently under review. We have assigned the following API numbers to AAI' s proposed drilling locations: Clover A Clover B Lookout A 50-103-20310-00 50-103-20311-00 50-103-20312-00 ARCO Spark # 1 Moose's Tooth A Moose's Tooth C Rendezvous A ...... Rendezvous B 50-103-20313-00 50-103-20314-00 50-103-20315-00 50-103-20316-00 50-103-20317-00 In accordance with AOGCC regulation 20 AAC 25.005, AAI must submit a separate Form 10-401 with complete supporting documentation for each proposed exploratory well. If you have any questions, please contact Mr. Robert Crandall or the undersigned at (907) 279-1433. Sincerely, ~- Petroleum Geologist ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 4, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Applications for Permit to Drill for NPRA Dear Mr. Commissioner: ARCO Alaska, Inc., as operator of the following exploration wells, submits the enclosed Applications for Permit to Drills. As discussed with Mr. Wondzell, these applications are currently on file and pending at the BLM office in Anchorage. The Department is requested to keep confidential the enclosed information due to the exploratory nature of these wells. Clover A: Clover B' T10N, R3E, Sec. 12, 601' FNL, 1781' FWL T10N, R4E, Sec. 6, 562' FNL, 1467' FWL Lookout A: T11N, R2E, Sec. 36, 239' FNL, 111' FWL Moose's Tooth A: ARCO Spark #1: Moose's Tooth C: T10N, R2E, Sec. 6, 161' FSL, 2427' FEL T10N, R2E, Sec. 8, 1679' FNL, 2431' FWL T10N, R1E, Sec. 3, 2149' FNL, 1007' FWL Rendezvous A: Rendezvous B: T10N, R1E, Sec. 24, 2225' FSL, 1303' FWL T10N, R1E, Sec. 23, 1521' FNL, 2392' FEL If you have any questions regarding this matter, please contact me at 263.4603 or James Trantham at 265.6434. Sincerely, Paul Mazzolini Exploration Drilling Team Leader JT/skad ARCO Alaska, Inc. Post Office Box i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 27, 1999 Mr. Nicholas Douglas District Manager USDI BLM Anchorage Field Office 6881 Abbot Loop Road' Anchorage, Alaska 99507 Subject: Permit to Drill for NPRA Dear Mr. Douglas: ARCO Alaska, Inc., as operator of the following exploration wells, submits the enclosed Permit to Drills. The Department is requested to keep confidential the enclosed information due to the exploratory nature of these wells. · z~,v-.c,~,? Clover A: T10N, R3E, Sec. 12, 601' FNL, 1781' FWL Clover B: T10N, R4E, Sec. 6, 562' FNL, 1467' FWL z o~.~o~ Lookout A: Moose's Tooth A: ARC° Spark #1: Moose's Tooth C: Rendezvous A: Rendezvous B' T1 IN, R2E, Sec. 36, 239' FNL, 111' FWL T10N, R2E, Sec. 6, 161' FSL, 2427' FEL T10N, R2E, Sec. 8, 1679' FNL, 2431' FWL T10N, R1E, Sec. 3, 2149' FNL, 1007' FWL T10N, R1E, Sec. 24, 2225' FSL, 1303' .FWL T10N, R1E, Sec. 23, 1521' FNL, 2392' FEL If you have any questions regarding this matter, please contact me at 263.4603 or James Trantham at 265.6434.. Sincerely, Paul Mazzolini ExplOration Drilling Team Leader ARCO Alaska, Inc. ~) AAI PAYABLES P.O. Box 102776 Anchorage, AK 99510-2776 ~..~. ~.. 205092215 839 PAY TO THE OCTOBER 28, 1999 0997579 ORDER OF: STATE OF ALASKA OIL .& GAS CONSERVATION COMMI 3001 PORCU.P-iNE~DRiVEi ~. '~'"'~- :~':-':: ':i :::::~...-:':~-:!:: EXACTLY *******~'~ *!*i~.O0.~'~L~4RS ~ 'i~ '~ '~ ~ :~ ~: ~' ' :'' '~ The First Nat"~,. "'"hk ~:':'"~h!~'~go_07,0 :~:[.."~:i: '~:-" ':: '--:~- ...... .- AND.. O0:i:CE~S ~*i**~.y¢~¢,.~, ~00.00 Ch i~-.-a-'g6;..';'l i i i n o i s Payable Th'o'd'h Republic Bank Shelbyvi lie, Kentucky TRACE NUMBER: 205092215 WELL PERMIT CHECKLIST FIELD & POOL ~ADMINISTRATION 1. Permit fee attached ....................... DATE EN(~INEERING COMPANY ,~",c..~ . WELL NAME ,,~J~.~.~'/.,.,'oc~_~' ~,PROGRAM: exp _~,~ dev INIT CLASS ,~--~,',~ ~',,~'/~,~.'-~ GEOL AREA 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included .......... 9. Operator only'affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... GEOLOGY 15. Surface casing protects all knoWn USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate we,bore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .5'O _~'"~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown .......... . 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. redrll serv wellbore seg ann. disposal para req UNIT# ON/OFF SHORE Y N (~N (~N N N N N N N R DAT~ ' ~~AL 33. Seabed condition survey (if off-shore). ...... ~.~.,. Y_ N 34. Contact name/phone for weekly progress reports [exploratory only~) N 35. With proper cementing records, this plan APPR DATE (A) will contain waste in a s~.~ble receiving zone;'..., i . . Y N (B) will not contaminateffre~hwater; or cause drilling waste... Y N (C) will noti. i~a'r~f th/e~ell u~.see~r disposal; Y U (D) w~rmation oHmp"air recovery from a Y N ool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ENGINEERING: UIC/Annular JDH -7'--.Z'--' ( ' TEM [.YL ~/ COMMISSION: co .......... Comments/Instructions: Z m z c:\msoffice\wordian\diana\checklist (rev. 09/27/99) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the hiStory file, To improve the readability of the Well History file and to simplify'finding informatiOn, information, of this nature is accumulated at the end of the file under APPENDIXi No Special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue May 23 21:25:23 2000 Reel Header Service name ............. LISTPE Date ..................... 00/05/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 00/05/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services RECEIVED JUN 22 000 Alaska Oil & Gas Cons. Oommissio~ Anchorage Scientific Technical oo' Scientific Technical Physical EOF Comment Record TAPE HEADER Exploration NPRA MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-00019 M. HANIK D. GLADDEN Rendezvous A 501032031600 ARCO Alaska, Sperry Sun 23-MAY-00 MWD RUN 2 AK-MM-00019 M. HANIK M. WHITELY Inc. MWD RUN 3 AK-MM-00019 M. HANIK M. WHITELY JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MWD RUN 4 AK-MM-00019 M. HANIK M. WHITELY MWD RUN 5 AK-MM-00019 R. KRELL MIKE WHITELY 24 I0N 1E 2247 MAD RUN 5 AK-MM-00019 R. KRELL MIKE WHITELY FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 1255 90.90 89.40 59.70 REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 113.0 6.750 7.625 2661.0 6.750 1. ALL DEPTHS ARE MEASURED DEPTHS AND TRUE VERTICAL DEPTHS (MD/TVD). 2. MWD RUNS l&4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUN 4 REACHED A TOTAL DEPTH (TD) OF 8300'MD/TVD, BUT THE WELL WAS DEEPENED TO 8333'MD/TVD ON A SUBSEQUENT CLEANOUT RUN. 3. MWD RUNS 2-3, 5 ARE DIRECTIONAL WITH DGR, EWR4, COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). RUN 3 IS A MEASUREMENT AFTER DRILLING (MAD) PASS OF THE CORED INTERVAL 8064'MD/TVD TO 8125'MD/TVD. ON THIS MAD PASS THE DRILLSTRING STUCK AT 8121'MD/TVD. RUN 5 IS A MAD PASS OVER THE INTERVAL 8050'MD/TVD TO 8333'MD/TVD, WITH DRILLED DATA FROM 8333' TO THE RUN 5 TD OF 8353'MD/TVD. RUN 3 DATA IS PRESENTED AS MERGED. ONLY THE FINAL 20' OF RUN 5 IS PRESENTED WITH MWD DATA; THE REMAINING MAD DATA IS PRESENTED AS A TAIL TO THIS LOG. 4. DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PDC GR LOG OF 04/26/00 (SWS DIPOLE SONIC-RFT MERGED GR). LOG HEADER AND BODY RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUNS 1-2 REPRESENT WELL RENDEZVOUS A WITH API#: 50-103-20316-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8300'MD, 8300'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SS MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBDC = SMOOTHED BULK DENSITY-COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSOPRPTION FACTOR. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. CURVES WITH AN "M" SUFFIX DENOTE MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.75" MUD DENSITY: 9.5-11.0 PPG MUD SALINITY: 15000-31000 PPM CHLORIDES FORMATION WATER SALINITY: 25000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number .... ' ....... 1.0.0 Date of Generation ....... 00/05/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE RPS RPD FET RPX RPM GR ROP PEF NPHI NCNT RHOB DRHO FCNT .5000 START DEPTH 115.5 115 5 115 5 115 5 115 5 122 5 162 5 2596 0 2662 0 2662 0 2662 0 2662 0 2662 0 STOP DEPTH 8351 5 8351 5 8351 5 8351 5 8351 5 8344 5 8364 5 8331 5 8315 0 8315 0 8331 5 8331 5 8315 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 122 5 137 153 157 165 169 170 175 187 196 199 202 217 222 234 359 392 395 493 510 548 552 560 565 600 655 660 662 666 670 678 686 694 699 707 712 721 733 763 781 785 787 845 863 871 883 893 905 908 912 922 926 933 944 5 5 0 5 0 0 5 0 0 0 5 5 5 0 5 0 5 2 0 0 0 0 0 5 5 5 5 .5 .5 .5 .0 .0 .5 .0 .0 .5 .5 0 0 5 5 0 5 5 5 5 0 .5 .5 .5 .5 .0 .0 961.5 965.5 GR 122 0 137 0 153 0 156 0 165 5 169 0 170 5 174 5 185 5 192 0 195 0 199 0 214 5 218 0 232.0 361.0 394.0 396.5 492 0 511 5 549 5 553 5 560 5 565 5 600 5 658 5 663 0 665 0 669 0 673 0 680 5 688 5 697 5 702.0 709 0 713 5 724 0 736 5 766 0 784 0 788 0 790 5 848 5 866 5 875 0 887 0 899 0 905 0 907 5 917 0 925.5 929.5 936.5 946.5 964.0 968.0 969.5 973.0 992.0 996 0 1004 5 1007 5 1025 0 1059 5 1074 0 1101 0 1112 0 1125 0 1126 5 1141 0 1145 0 1152 0 1154 0 1216 0 1235 0 1237 0 1261 0 1276 0 1282 0 1284 5 1298 5 1361 5 1386 0 1398 0 1438 0 1441 5 1443 5 1487 0 1516 0 1518 0 1521 5 1525 0 1548 5 1581 5 1585 0 1591 0 1604 0 1630 5 1662 0 1707 0 1764 5 1782 5 1844 5 1857 5 1872 0 1906 0 1914 0 1920 5 1924 5 1926 5 1979 0 1987 0 1993 5 2007 0 2008.0 2011.0 2013.5 972. 975. 994. 998. 1007. 1010. 1027. 1061 1076 1104 1116 1127 1128 1143 1147 1153 1155 1217 1237 1239 1263 1278 1284 1287 1300 1363 1388 1401 1442 1445 1447 1489 1518 1520 1523 1526 1551 1582 1586 1592 1605 1632 1663 1707 1765 1784 1845 1860 1872 1907 1915 1921 1925 1928 1980 1988 1995 2008 2009 2011 2013 0 5 0 0 0 0 5 5 5 0 0 0 5 0 0 0 5 5 0 5 0 5 5 0 0 0 5 0 5 5 5 5 0 0 5 5 0 0 0 5 5 0 0 5 5 0 5 5 0 0 5 5 5 0 5 0 0 0 0 5 0 2024 5 2026 5 2036 5 2038 0 2055 5 2067 5 2081.5 2128 0 2159 0 2161 5 2180 0 2208 5 2215 0 2279 5 2296 0 2310 5 2324 0 2492 0 2632 5 2638.0 2657 0 2659 5 2670 0 2673 0 2683 5 2686 0 2695 0 2703 5 2722 0 2748 0 2752 5 2760 0 2790 5 2793 5 2811 5 2813 0 2816 5 2820 0 2821 5 2828 5 2830 0 2847 0 2852 5 2856 5 2861 0 2867 0 2872 0 2878 0 2918 5 2932 5 2936 0 2943 0 2974 5 2984 5 2987 0 3001 5 3009 5 3022 0 3031 0 3052 0 3058 0 2025 0 2027 5 2038 5 2040 0 2056 5 2070 0 2082 5 2129 5 2160 5 2163 0 2181 5 2211 5 2218 5 2280 0 2296 5 2311 0 2325 0 2492 0 2632 0 2638 5 2656 5 2658 5 2668 5 2671 0 2681 0 2684 0 2693 5 2701 5 2721 0 2746 0 2751 5 2758 5 2788 5 2792 0 2808 5 2810 5 2814.0 2817 0 2819 0 2826 0 2827 5 2846 5 2850 5 2854 5 2858 5 2864 5 2871 0 2876 5 2915 0 2930.0 2933 5 2940 5 2971 5 2980 5 2983 0 2998 0 3008 5 3020 0 3029 0 3049 0 3055 5 3063 5 3065 5 3070 5 3073 0 3077 5 3079 5 3081 5 3090 5 3105 0 3139 5 3149 0 3164 0 3185 5 3215 5 3223 0 3247 0 3252 5 3262 0 3270 0 3279 0 3284 0 3289 0 3316 5 3368 0 3419 5 3427 0 3455 5 3457 5 3480 5 3499 5 3520 0 3528 0 3538 5 3549 0 3551 0 3553 5 3563 0 3572 5 3577 0 3579 5 3595 0 3599 0 3617 0 3628 5 3630 5 3636 5 3641 5 3644 5 3660 5 3686 0 3687 5 3695 0 3705 0 3719 0 3736 0 3768 5 3773 5 3777 5 3785 0 3794 0 3801 0 3061.0 3063.5 3068.5 3070.5 3074.0 3076.5 3079.0 3087.0 3102.5 3136.5 3145.5 3163.0 3183 5 3213 0 3221 0 3245 0 3250 0 3259 5 3267 5 3276 5 3281 0 3286 5 3313 5 3366 5 3416 0 3423 5 3453 0 3455 0 3478 0 3497 0 3517 5 3525 0 3534 5 3546 0 3548 0 3550 5 3559 5 3569 0 3573 0 3576 0 3591 5 3595 0 3613 5 3625 5 3627 5 3635 0 3638.5 3642 5 3658 0 3683 5 3685 0 3693 5 3702 5 3717 5 3733 5 3766 0 3771 0 3774 0 3781 5 3791 5 3797 0 3824. 3830. 3835. 3844. 3845. 3847. 3851. 3852. 3854. 3860. 3863. 3871. 3900. 4240 4257 4282 4295 4314 4339 4345 4352 4384 4408 4411 4453 4457 4458 4472 4474 4506 4507 4510 4517 4522 4529 4560 4574 4576 4585 4630 4637 4646 4662 4671 4674 4706 4708 4713 4716 4719 4727 4741 4744 4755 4761 4763 4764 4766 4767 4770 4772 5 5 0 0 5 0 0 5 5 5 0 0 5 5 0 0 5 0 5 5 0 0 5 0 5 0 0 5 5 0 0 0 0 5 5 5 0 0 5 0 5 0 0 5 5 5 0 5 0 0 0 5 5 0 5 0 5 0 5 0 0 3819 5 3826 5 3831 0 3841 5 3842 5 3844 0 3847 5 3849 0 3851 0 3857 0 3859 0 3867 0 3894 5 4235 0 4253 5 4278 5 4291 5 4309 5 4335 5 4341 5 4348 0 4380 5 4404 0 4406 5 4449 0 4453 0 4454 0 4469 5 4471 5 4502 5 4504 0 4506 5 4513 5 4518 5 4525 4556 4568 4570 4579 4624 4633 4641 4657 4666 4669 4701 4702 4707 4709 4714 4724 4736 4739 4750 4756 4758 4760 4761 4763 4765 4767 4774 5 4777 5 4779 0 4793 0 4804 0 4820 5 4827 0 4833 5 4835 5 4837 5 4838 5 4844 0 4864 0 4877 5 4880 0 4883 0 4893 0 4912 0 4918 0 4962 0 4973 0 4975 5 4982 5 4983 5 4985 5 4991 5 5002 0 5005 0 5015 5 5074 0 5082 0 5102 5 5107 5 5130 5 5145 0 5149 5 5151 5 5165 0 5169 0 5180 5 5183 0 5199 0 5206 0 5211 0 5214 0 5218 0 5220 5 5222 5 5232 0 5236 5 5245 0 5254 0 5256 0 5269 0 5271 0 5278 0 5289 0 5297.0 5301.0 5313.5 5315.5 4770 0 4773 0 4775 0 4790 0 48O0 0 4816 5 4822 0 4828 5 4830 5 4832 5 4834 5 4840 0 4861 0 4874 0 4876 5 4879 5 4889 5 4906 5 4914 0 4957 5 4968 5 4970 5 4978 0 4979 5 4981.5 4987 0 4997 5 5001 0 5010 5 5069 0 5077 0 5097 5 5102 0 5125 5 5140 0 5144 5 5146 5 5160 0 5164 0 5175.5 5178 0 5194 0 5201 5 5206 5 5209 5 5213 0 5215 5 5217 5 5227 0 5230 5 5239 5 5249 0 5251.0 5264 0 5266 5 5273 0 5284 5 5292 0 5295 5 5308 0 5310 0 5324.5 5330.5 5343.5 5353.5 5355.5 5357.5 5360 5 5379 0 5381 0 5383 0 5385 5 5399 5 5410 0 5412 0 5417 0 5419 0 5421 0 5424 0 5430 0 5432 0 5433 5 5438 5 5443 0 5445 0 5446 5 5454 5 5463 5 5467 5 5473 0 5476 5 5479 5 5484 0 5486 5 5488 0 5503 0 5507 0 5510 5 5512 5 5548 5 5550 0 5564 5 5566 0 5571 0 5573.0 5579.5 5581.5 5584.0 5585.5 5597.5 5604 5 5611 0 5614 5 5623 0 5626 0 5635 5 5637.0 5644.5 5646.5 5648.0 5661.0 5662.5 5319 5326 5339 5349 5350 5352 5355 5373 5375 5377 5380 5394 5405 5407 5412 5414 5415 5419 5424 5426 5428 5433 5437 5439 5441 5450 5459 5463 5468 5471 5475 5480 5483 5484 5499 5500. 5505 5507 5543 5544 5558 5560 5565 5567 5573 5575 5578 5581 5592 5599 5606 5608 5616 5619 5628 5630 5638 5640 5641 5654 5656 5668 5673 5675 5677 5678 5685 5690 5707 5710 5723 5735 5741 5743 5759 5790 5822 5837 5843 5844 5863 5868 5870 5876 5894 5899 5901 5913 5915 5916 5940 5947 5948 5962 5964 5966 5974 5976 5980 5981 5987 5990 6005 6007 6011 6014 6017 6031 6034 6036 6038 6041 6044 6048 6067 6068 6083 6099 6107 6110 6114 6115 5 5 5 0 0 5 0 5 0 5 0 5 5 0 5 0 0 5 5 5 0 5 5 0 0 0 5 0 0 5 5 5 5 0 5 5 5 0 0 0 0 0 5 5 5 0 0 0 0 0 0 0 5 0 0 0 0 0 0 0 0 5663 0 5667 5 5669 5 5671 0 5672 0 5679 0 5684 0 5701 0 5703 5 5717 0 5729 0 5735 5 5737 5 5753 0 5784 5 5815 5 5830 0 5837 0 5838 5 5857 5 5861 5 5863 5 5869 0 5886 5 5892 5 5894 5 5906 5 5908 0 5909 5 5933 0 5938 5 5940 0 5955 0 5958 5 5960 5 5967 0 5969 5 5974 5 5975 5 5980 5 5983 5 5999 0 6001 5 6005 5 6009 0 6010 5 6025 0 6028 0 6030 0 6031 5 6035 5 6038 5 6044 0 6062 5 6063 5 6078 0 6093.0 6100.5 6103.0 6107.0 6108.0 6131.0 6149.5 6156.5 6164.5 6166.5 6174.0 6175.5 6201.0 6216.0 6218.0 6222 0 6225 5 6227 0 6234 0 6235 5 6237 5 6240 0 6242 0 6248 5 6262 5 62 68 0 6275 0 6278 5 6281 0 6289 0 6301 5 6315 0 6318 5 6340 5 6345 0 6348 0 6358 0 6361 5 6366.0 6372 0 6398 0 6400 0 6413 0 6417 0 6424 5 6431 5 6436 0 6439.0 6457.0 6465.0 6466.5 6476.0 6479.0 6480.5 6482.0 6483.0 6484.5 6489 5 64 91 0 6512 0 6518 0 6523 5 6532 5 6535 0 6547 0 6548 0 6124 0 6142 5 6151 0 6158 0 6160 5 6167 5 6168 5 6193 5 6209 0 6211 0 6214 5 6217 5 6219 0 6225 5 6226 5 6228 5 6231 5 6233 5 6240 5 6255 5 6261 0 62 68 0 6272 0 6274 5 6282 0 6294 5 6308 0 6312 0 6334 0 6338 5 6341 0 6351 0 6355 0 6359 5 6365 5 6391 0 6393 6406 6410 6417 6424 6429 6432 6450 6458 6459 6468 6471 6473 6474 6476 6478 6483 6484 6504 6510 6516 6525 6528 6539 6540 6553.5 6563.0 6565.0 6566.5 6569.0 6572.0 6577.5 6578.5 6586.5 6588.0 6590 0 6602 0 6604 0 6610 5 6617 5 6619 0 6637 5 6639 0 6641 5 6644 0 664 6 5 6663 0 6665 5 6673 0 6676 0 667 9 0 6683 5 6686 5 6689 5 6701 0 6712 5 6715 0 6717 0 6733 0 6735 0 6737 5 6743 5 6755 0 67 62 0 67 64 0 67 65 5 6788 0 6791 0 6800 5 6806 5 6808.5 6821 5 6823 0 6827 0 6833 0 6840 5 6858 0 68 60 5 6862 5 6866 0 6869 5 6872 5 6879.5 6886.0 6889.0 6892.0 654 6 0 6556 0 6558 0 6559 5 6562 0 65 65 0 6570 5 6571 5 6580 0 6581 0 6583 0 6595 0 6596 5 6602 0 6609 0 6610 5 6630 5 6632 0 6634 0 6636 5 6639 0 6656 0 6658 0 6665 0 6668 5 6672 0 6676 5 6679 0 6681 5 6693 0 6706 0 6708 0 6709 5 6725 0 6727 0 6729 5 6735 0 6746 5 6755 0 6756 5 6757 5 6780 5 6783 0 67 92 5 6799 0 6801 0 6813 0 6814 5 6819 0 6825 5 6833 5 6849 5 6852 0 6854 5 6858 0 68 62 0 68 64 5 6871 5 6878.0 6881.0 6884.0 6898 5 6904 0 6909 0 6915 0 6920 0 6925 0 6941 5 6944 0 6956 5 6964 5 6982 0 6993 5 6996 5 7004 5 7031 0 7033 0 7050 5 7068 5 7071 5 7151 5 7159 0 7163 0 7166 5 7172 5 7175 0 7178 5 7180 5 7192 0 7197 5 7201 0 7203 5 7207 5 7228 5 7232 0 7238 0 7246 0 7252 5 7256 5 7266 5 7269 5 7271 5 7275 0 7279 5 7287 5 7304 0 7307 5 7312 0 7315 0 7318 0 7322 5 7328 0 7336 5 7338 0 7343 5 7345 5 7350 5 7358 0 7364.5 7395.5 7398.0 7399.5 6890 6896 6901 6907 6912 6917 6934 6936 6948 6956 6974 6986 6989 6997 7026 7028 7045 7063 7065 7144 7151 7155 7159 7164 7167 7170 7172 7184 7190 7193 7195 7200 7221 7224 7230 7239 7245 7249 7258. 7261. 7264. 7267. 7272 7280 7296 7300 7304 7307 7310. 7315. 7320. 7328 7330 7335 7338 7343 7351 7357 7388 7391 7393 5 0 0 0 0 0 5 0 5 0 5 5 5 5 0 0 0 0 5 0 5 5 0 5 0 5 5 0 5 5 5 5 5 5 5 0 5 0 5 5 0 0 0 0 5 0 5 5 0 0 0 0 5 5 0 5 0 5 5 5 0 7425 7428 7436 7440 7441 7448 7450 7452 7457 7459 7467 7469 7479 7481 7499 7503 7510 7511 7513 7519. 7525 7540 7546 7547 7556 7576 7600 7608 7613 7637 7641 7659 7661 7668 7680 7686 7687 7693 7694 7697 7722 7726 7731 7747 7769 7781 7787 7822 7829 7832 7834 7841 7844 7860 7868 7871 7885 7888 7891 7911 7912 7417.0 7421.0 7429.5 7432.5 7433.5 7440.5 7442.0 7444.5 7449.0 7451.0 7459.0 7461.0 7471.5 7473.0 7491.5 7495.0 7501.5 7503.0 7504.5 7510.5 7517.0 7531.5 7537.5 7538.5 7548.0 7567.5 7592.0 7599.5 7604.0 7628.0 7631.5 7650.5 7652.0 7660.0 7672.5 7678.5 7679.5 7685.5 7686.5 7689.0 7713.5 7717.5 7723.0 7738.5 7760.0 7772.0 7778.0 7813.0 7820.0 7824.0 7826.0 7834.0 7835.5 7852.0 7860.0 7862.5 7877.0 7879.5 7882.5 7902.0 7903.5 7922. 7935 7937 7948 7949 7951 7953 7958 7961 7963 7977 7979 7986 7987 8002 8005 8008 8009 8013 8015 8026 8036 8038 8043 8048 8050 8051 8054 8066 8068 8070 8074 8084 8100 8114 8119 8127 8364 $ # 5 5 5 0 5 5 5 0 0 0 0 0 0 5 0 0 0 5 5 0 5 5 0 0 5 0 5 5 0 0 5 0 0 5 5 0 5 5 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: 7914.0 7927.0 7929.0 7939 0 7940 5 7942 5 7944 5 7949 0 7951 0 7954 0 7968 0 7970 0 7977 0 7978 5 7992 5 7995 5 7999 0 8001 0 8004 5 8006 0 8016 0 8025 5 8027 5 8032 5 8038 5 8039 5 8041 0 8045 0 8055 0 8057 0 8059 5 8063 0 8072 5 8089 5 8103 5 8108 0 8116 0 8353 0 BIT RUN NO MERGE TOP MERGE BASE 1 115.0 2669.0 2 2620.0 8064.0 3 7973.5 8121.0 4 8070.0 8300.5 5 8001.5 8353.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FPH 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CC 4 1 68 44 12 DRHO MWD G/CC 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 Name Service Unit Min Max Mean Nsam DEPT FT 115.5 8364.5 4240 16499 ROP MWD FPH 1.12 1399.44 146.949 16405 GR MWD API 38.8 376.14 111.173 16445 RPX MWD OHMM 0.38 1821.39 5.50899 16473 RPS MWD OHMM 0.8 2000 13.5223 16473 RPM MWD OHMM 0.2 2000 14.1022 16473 RPD MWD OHMM 0.34 2000 12.819 16473 FET MWD HOUR 0.0059 70.679 2.17003 16473 NPHI MWD PU 12.44 94.49 29.8494 11307 FCNT MWD CNTS 95.6 858.5 349.454 11307 NCNT MWD CNTS 12229.8 31771 22296.2 11307 RHOB MWD G/CC 1.592 2.905 2.47933 11340 DRHO MWD G/CC -0.043 0.349 0.138453 11340 PEF MWD B/E 2.13 16.28 4.5711 11472 First Reading 115.5 162.5 122.5 115.5 115.5 115.5 115.5 115.5 2662 2662 2662 2662 2662 2596 Last Reading 8364 5 8364 5 8344 5 8351 5 8351 5 8351 5 8351 5 8351 5 8315 8315 8315 8331.5 8331.5 8331.5 First Reading For Entire File .......... 115.5 Last Reading For Entire File ........... 8364.5 File Trailer Service name..~ .......... STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE FCNT NCNT NPHI DRHO RHOB PEF GR FET RPD RPM RPS RPX RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: START DEPTH 8001.5 8001 5 8001 5 8017 0 8017 0 8017 5 8029 0 8036 0 8036 0 8036 0 8036 0 8036 0 8049 0 STOP DEPTH 8305.5 8285.0 8285.0 8300.0 8300.0 8300 0 8313 0 8320 0 8320 0 8320 0 8320 0 8320 0 8333 5 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 5 1 8001.5 8333.0 MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 NPHI MAD PU-S 4 1 68 32 9 FCNT MAD CNTS 4 1 68 36 10 NCNT MAD CNTS 4 1 68 40 11 RHOB MAD G/CM 4 1 68 44 12 DRHO MAD G/CM 4 1 68 PEF MAD BARN 4 1 68 48 52 13 14 Name Service Unit Min Max DEPT FT 8001.5 8333.5 RAT MAD FT/H 8.84 329.4 GR MAD API 40.75 135.76 RPX MAD OHMM 0.28 8.1 RPS MAD OHMM 0.62 25.31 RPM MAD OHMM 0.8 1160.32 RPD MAD OHMM 0.99 38.47 FET MAD HOUR 43.406 171.593 NPHI MAD PU-S 14.14 69.16 FCNT MAD CNTS 89.2 858.5 NCNT MAD CNTS 12229.8 30579.8 RHOB MAD G/CM 1.673 2.857 DRHO MAD G/CM -0.043 0.228 PEF MAD BARN 3.98 17.01 Mean 8167.5 112.395 87.9334 3.36069 3.87712 7.0668 5.52378 96.1735 25.4117 491.926 23915.4 2.45498 0.0955767 8.08578 Nsam 665 570 569 569 569 569 569 569 568 571 568 567 567 566 First Reading 8001.5 8049 8029 8036 8036 8036 8036 8036 8001.5 8001.5 8001.5 8017 8017 ,8017.5 Last Reading 8333.5 8333.5 8313 8320 8320 8320 8320 8320 8285 8305.5 8285 8300 8300 8300 First Reading For Entire File .......... 8001.5 Last Reading For Entire File ........... 8333.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment RecOrd FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH RPX 115.0 RPS 115.0 STOP DEPTH 2622.0 2622.0 RPM 115.0 RPM 115.0 FET 115.0 GR 122.0 ROP 162.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 2622.0 2622.0 2622.0 2629.5 2669.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 14-APR-00 Insite 65.41 MEMORY 2669.0 .1 .4 TOOL NUMBER PB01488HRGV6 PB01488HRGV6 9.875 113.0 KCL/Clayseal 10.00 53.0 9.1 31500 4.6 .170 .123 .100 .240 68.0 96.8 68.0 68.0 Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD010 FT/H GR MWD010 API RPX MWD010 OHMM RPS MWD010 OHMM RPM MWD010 OHMM RPD MWD010 OHMM FET MWD010'HOUR First Min Max Mean Nsam Reading 115 2669 1392 5109 115 3.26 1399.44 163.561 5015 162 52.22 223.29 114.968 5016 122 1.33 1196.32. 5.92265 5015 115 1.57 2000 30.9425 5015 115 1.64 2000 29.8957 5015 115 1.78 2000 20.761 5015 115 0.0059 4.204 0.621269 5015 115 Last Reading 2669 2669 2629.5 2622 2622 2622 2622 2622 First Reading For Entire File .......... 115 Last Reading For Entire File ........... 2669 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/23 Maximum Physical Record..65535 File Type ...... ~ ......... LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH PEF RPS RPX RPM RPD FET GR DRHO NPHI FCNT NCNT RHOB ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 2620 0 2622 0 2622 5 2622 5 2622 5 2622 5 2630 0 2661.0 2661.0 2661.0 2661.0 2661.0 2669.5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE:' TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLER'S CASING DEPTH FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: STOP DEPTH 7988 5 8017 0 8017 0 8017 0 8017 0 8017 0 8010 0 7988 5 7973 0 7973 0 7973 0 7988 5 8064 0 21-APR-00 Insite 0.41 MEMORY 8064.0 .1 1.8 TOOL NUMBER 1473GR4 1473GR4 1473GR4 1473GR4 6.750 2661.0 KCL/GEM GP 10.90 53.0 8.8 31000 3.0 .O8O .051 .000 .160 95.0 152.8 95.0 95.0 MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value .................... ..-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR NPHI MWD020 PU-S FCNT MWD020 CNTS NCNT MWD020 CNTS RHOB MWD020 G/CM DRHO MWD020 G/CM PEF MWD020 BARN Min Max Mean Nsam 2620 8064 5342 10889 1.12 339.64 142.397 10790 52.66 376.14 110.615 10761 0.38 1821.39 5.39776 10790 0.8 1719.14 5.54816 10791 0.2 2000 6.24696 10790 0.34 2000 8.87025 10790 0.34889 66.1234 1.32558 10790 12.44 94.49 30. 0849 10625 95.6 846.4 342.262 10625 12645.3 31771 22226.8 10625 1.592 2.905 2.48108 10656 -0.001 0.349 0.14045 10656 2.13 14.57 4.29244 10738 First Reading 2620 2669.5 2630 2622.5 2622 2622.5 2622.5 2622.5 2661 2661 2661 2661 2661 2620 Last Reading 8064 8064 8010 8017 8017 8017 8017 8017 7973 7973 7973 7988.5 7988.5 7988.5 First Reading For Entire File .......... 2620 Last Reading For Entire File ........... 8064 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT FCNT NPHI DRHO RHOB PEF RPD RPM RPS GR FET RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 7973.5 7973 5 7973 5 7989 0 7989 0 7989 0 8003 5 8003 5 8003 5 8010 5 8017 5 8017 5 8064 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8030 0 8030 0 8030 0 8045 5 8045 5 8046 0 8074 0 8074 0 8074 0 8067 0 8074 0 8074 0 8121 0 23-APR-00~ Insite 0.41 MEMORY 8121.0 .9 .9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER 1473GR4 1473GR4 1473GR4 1473GR4 6.750 2661.0 KCL/GEM GP 11.00 44.0 9.1 29000 2.7 .190 .086 .120 .220 68.0 158.4 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM PEF MWD030 BARN 1 68 1 68 48 52 13 14 Name Service Unit Min DEPT FT 7973.5 ROP MWD030 FT/H 7.52 GR MWD030 API 52.41 RPX MWD030 OHMM 0.69 RPS MWD030 OHMM 0.86 RPM MWD030 OHMM 0.93 RPD MWD030 OHMM 1.23 FET MWD030 HOUR 35.6673 NPHI MWD030 PU-S 24.67 FCNT MWD030 CNTS 115.2 NCNT MWD030 CNTS 13388.2 RHOB MWD030 G/CM 1.876 DRHO MWD030 G/CM 0.046 PEF MWD030 BARN 8.94 Max 8121 95 13 146 44 6 99 27 92 29 67 7 58 59.8499 53.14 290.4 22130.9 2.741 0.223 16.28 Mean 8047.25 69.4546 108.986 3.06411 3.6119 3.81563 3.41331 55.2719 39.6176 180.014 15984.6 2.22739 0.141211 13.4107 Nsam 296 114 114 114 142 142 142 114 114 114 114 114 114 115 First Reading 7973.5 8064.5 8010.5 8017.5 8003.5 8003.5 8003.5 8017.5 7973.5 7973.5 7973.5 7989 7989 7989 Last Reading 8121 8121 8067 8074 8074 8074 8074 8074 8030 8030 8030 8045.5 8045.5 8046 First Reading For Entire File .......... 7973.5 Last Reading For Entire File ........... 8121 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8070.0 RPS 8070.5 STOP DEPTH 8280.0 8287.0 RPD 8070.5 RPM 8070.5 FET 8074.5 RPX 8074.5 ROP 8121.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8287.0 8287.0 8287.0 8287.0 8300.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 25-APR-00 Insite 5.1 MEMORY 8300.0 1.1 1.1 TOOL NUMBER PB01489GR4 PB01489GR4 6.750 2661.0 KCL / GEM 11.00 45.0 8.7 29000 2.6 .200 .091 .130 .240 65.0 151.7 65.0 65.0 Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR R?X RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD040 FT/H 4 1 68 MWD040 API 4 1 68 MWD040 OHMM 4 1 68 MWD040 OHMM 4 1 68 MWD040 OHMM 4 1 68 MWD040 OHMM 4 1 68 MWD040 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 8070 8300.5 ROP MWD040 FT/H 1.95 337.18 GR MWD040 API 38.8 139.77 RPX MWD040 OHMM 1.79 22.87 RPS MWD040 OHMM 1.84 27.91 RPM MWD040'OHMM 1.83 31.34 RPD MWD040 OHMM 1.95 35.16 FET MWD040 HOUR 0.106893 70.679 Mean 8185.25 93.2173 84.7276 4.78775 5.88417 6.88624 7.4556 16.4126 Nsam 462 359 421 426 434 434 434 426 First Reading 8070 8121.5 8070 8074.5 8070.5 8070.5 8070.5 8074.5 Last Reading 8300.5 8300.5 8280 8287 8287 8287 8287 8287 First Reading For Entire File .......... 8070 Last Reading For Entire File ........... 8300.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI 8030 5 FCNT 8030 5 NCNT 8030 5 RPS 8037 0 RPD 8037 0 RPM 8037 0 RHOB 8046 0 DRHO 8046 0 PEF 8046 5 GR 8280.5 FET 8287.5 RPX 8287.5 ROP 8301.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8303.5 8303.5 8303.5 8340.0 8340 0 8340 0 8320 0 8320 0 8320 0 8333 0 8340 0 8340 0 8353 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: 28-APR-00 Insite 5.1 MEMORY 8353.0 1.1 1.1 TOOL NUMBER PB01473GR4 PB01473GR4 PB01473GR4 PB01473GR4 6.750 2661.0 KCL/GEM GP 11.10 44.0 9.2 29000 3.2 .080 .038 .140 .180 75.0 164.9 75.0 75.0 MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD050 FT/H 4 1 68 GR MWD050 API 4 1 68 RPX MWD050 OHMM 4 1 68 RPS MWD050 OHMM 4 1 68 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1 68 FET MWD050 HOUR 4 1 68 NPHI MWD050 PU-S 4 1 68 FCNT MWD050 CNTS 4 1 68 NCNT MWD050 'CNTS 4 1 68 RHOB MWD050 G/CM 4 1 68 DRHO MWD050 G/CM 4 1 68 PEF MWD050 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 8030.5 8353 ROP MWD050 FT/H 8.84 250.2 GR MWD050 API 88.81 135.76 RPX MWD050 OHMM 2.23 3.24 RPS MWD050 OHMM 0.62 25.31 RPM MWD050 OHMM 0.8 1160.32 RPD MWD050 OHMM 0.99 38.47 FET MWD050 HOUR 0.2985 68.4549 NPHI MWD050 PU-S 14.14 58.11 FCNT MWD050 CNTS 96.6 858.5 NCNT MWD050 CNTS 12229.8 30579.8 RHOB MWD050 G/CM 2.289 2.857 DRHO MWD050 G/CM -0.043 0.228 PEF MWD050 BARN 3.98 11.57 Mean Nsam 8191.75 646 115.414 105 108.051 106 2.61528 106 3.77727 607 6.73354 607 5.244 607 44.6017 106 23.1625 547 523.801 547 24914.2 547 2.50637 549 0.100576 549 7.41838 548 First Reading 8030.5 8301 8280.5 8287.5 8037 8037 8037 8287.5 8030.5 8030.5 8030.5 8046 8046 8046.5 Last Reading 8353 8353 8333 8340 8340 8340 8340 8340 8303.5 8303.5 8303.5 8320 8320 8320 First Reading For Entire File .......... 8030.5 Last Reading For Entire File ........... 8353 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 5 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT FCNT NPHI RHOB DRHO PEF GR RPX RPS RPM RPD FET RAT $ # LOG HEADER DATA DATE LOGGED: SOFTWARE 8001.5 8001 5 8001 5 8017 0 8017 0 8017 5 8029 0 8036.0 8036.0 8036.0 8036.0 8036.0 8049.0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8285 0 8305 5 8285 0 8300 0 8300 0 8300 0 8313 0 8320 0 8320 0 8320.0 8320.0 8320.0 8333.5 28-APR-00 Insite 5.1 MEMORY 8333.0 1.1 1.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ)': REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER PB01473GR4 PB01473GR4 PB01473GR4 PB01473GR4 6.750 2661.0 KCL/GEM GP 11.10 44.0 9.2 29000 3.2 .08O .038 .140 .180 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD051 FT/H 4 1 68 4 2 GR MAD051 API 4 1 68 8 3 RPX MAD051 OHMM 4 1 68 12 4 RPS MAD051 OHMM 4 1 68 16 5 RPM MAD051 OHMM 4 1 68 20 6 RPD MAD051 OHMM 4 1 68 24 7 FET MAD051 HOUR 4 1 68 28 8 NPHI MAD051 PU-S 4 1 68 32 9 FCNT MAD051 CNTS 4 1 68 36 10 NCNT MAD051 CNTS 4 1 68 40 11 75.0 164.9 75.0 75.0 RHOB MAD051 G/CM 4 1 68 DRHO MAD051 G/CM 4 1 68 PEF MAD051 BARN 4 1 68 44 48 52 12 13 14 Name Service Unit Min Max DEPT FT 8001.5 8333.5 RAT MAD051 FT/H 8.84 329.4 GR MAD051 API 40.75 135.76 RPX MAD051 OHMM 0.28 8.1 RPS MAD051 OHMM 0.62 25.31 RPM MAD051 OHMM 0.8 1160.32 RPD MAD051 OHMM 0.99 38.47 FET MAD051 HOUR 43.406 171.593 NPHI MAD051 PU-S 14.14 69.16 FCNT MAD051 CNTS 89.2 858.5 NCNT MAD051 CNTS 12229.8 30579.8 RHOB MAD051 G/CM 1.673 2.857 DRHO MAD051 G/CM -0.043 0.228 PEF MAD051 BARN 3.98 17.01 Mean 8167.5 112.395 87.9334 3.36069 3.87712 7.0668 5.52378 96.1735 25.4117 491.926 23915.4 2.45498 0.0955767 8.08578 First Nsam Reading 665 8001.5 570 8049 569 8029 569 8036 569 8036 569 8036 569 8036 569 8036 568 8001.5 571 8001.5 568 8001.5 567 8017 567 8017 566 8017.5 Last Reading 8333.5 8333.5 8313 8320 8320 8320 8320 8320 8285 8305.5 8285 8300 8300 8300 First Reading For Entire File .......... 8001.5 Last Reading For Entire File ........... 8333.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/05/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 00/05/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number .... ..01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File
