The URL can be used to link to this page

Home My WebLink About195-096 • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 ~' Anchorage, Alaska 99519 -6612 May 20, 2012 Mr. Jim Regg — 0616 gg (� ,� i Alaska Oil and Gas Conservation Commission t 1 — , -6 333 West 7 Avenue �-- Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA PM -2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA PM -2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, L Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) GPMA PM-2 Date: 0413W2012 Corrosion Vol. of cement Final top of Cement top Corrosion inhibitor/ sealant Well Name PTD # API # Initial top of cement pumped cement off date inhibitor date ft bbls ft na gal P2 -01 1970730 50029227610000 0.3 NA 0.3 NA 1.70 6/22/2009 P2 -03 1970440 50029227490000 2.0 NA 2.0 NA 10.20 6/22/2009 P2-04 1981560 50029229070000 1.0 NA 1.0 NA 5.10 6/22/2009 P2-06 1931030 50029223880000 4.0 NA 4.0 NA 30.60 6/22/2009 P2 -07 1940580 50029224690000 2.0 NA 2.0 NA 13.60 6/22/2009 P2-08A 2061690 50029228960100 0.8 NA 0.8 NA 4.30 6/21/2009 P2 -09 1980660 50029228760000 0.3 NA 0.3 NA 0.85 6/21/2009 P2 -10 1980970 50029228860000 0.3 NA 0.3 NA 1.70 6/21/2009 P2 -11A 2060260 50029229230100 3.5 NA 3.5 NA 69.70 6/21/2009 P2 -12 1931150 50029223950000 Sealed conductor NA NA NA NA NA P2 -13 1970600 50029227570000 0.5 NA 0.5 NA 2.60 6/21/2009 P2 -14 1981050 50029228880000 1.5 NA 1.5 NA 10.20 6/21/2009 P2 -15A 2070320 50029224090100 Sealed conductor NA NA NA NA NA P2 -16 1931230 50029223970000 3.0 NA 3.0 NA 28.10 6/20/2009 P2 -17 1981370 50029229020000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -18 1940600 50029224710000 0.8 NA 0.8 NA 2.60 6/20/2009 P2 -19A 2070120 50029227650100 0.3 NA 0.3 NA 0.90 6/20/2009 P2 -20 1960590 50029226640000 0.5 NA 0.5 NA 2.60 6/20/2009 P2 -21 1940530 50029224670000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -22 1972490 50029228500000 1.0 NA 1.0 NA 7.70 6/20/2009 P2 -23 1940320 50029224530000 1.3 NA 1.3 NA 11.10 6/20/2009 P2 -24 1980080 50029228540000 1.5 NA 1.5 NA 1020 6/15/2009 P2 -25 1971110 50029227760000 1.8 NA 1.8 NA 17.90 6/10/2009 P2 -27 1971250 50029227850000 1.3 NA 1.3 NA 8.50 6/10/2009 P2 -28 1950440 50029225510000 3.3 NA 3.3 NA 37.40 4/18/2012 P2 -29 1931470 50029224070000 10.3 NA 10.3 NA 71.40 6/15/2009 P2 -30 1920950 50029222890000 2.8 NA 2.8 NA 17.90 6/10/2009 P2-31 1940360 50029224560000 2.2 NA 2.2 NA 21.30 6/20/2009 P2 -32 1951350 50029225930000 Surface casing leak NA NA NA NA NA P2 -33B 1972310 50029228120200 2.0 NA 2.0 NA 16.60 6/9/2009 P2 -34 1950660 50029225580000 1.5 NA 1.5 NA 11.50 6/9/2009 P2 -35 1951790 50029226200000 1.0 NA 1.0 NA 13.60 6/9/2009 P2 -36A 2060220 50029228010100 1.1 NA 1.1 NA 6.00 6/9/2009 P2 -37A 2050570 50029225760100 2.0 NA 2.0 NA 23.00 6/9/2009 P2 -39 2111230 50029234540000 0.8 NA 0.8 NA 10.20 4/30/2012 P2-40 1972260 50029228370000 0.5 NA 0.5 NA 5.10 6/9/2009 P2 -41 1952050 50029226330000 1.5 NA 1.5 NA 17.00 6/9/2009 P2-42 1931430 50029224050000 19.3 NA 19.3 NA 121.60 6/20/2009 P2-43 2050240 50029232500000 0.8 NA 0.8 NA 6.00 6/8/2009 P2-44 1960630 50029226660000 2.3 NA 2.3 NA 23.80 6/8/2009 P2-45B 2080210 50029227690200 0.8 NA 0.8 NA 5.10 6/8/2009 P2-46 1931320 50029224010000 2.3 NA 2.3 NA 25.50 6/8/2009 P247 1951900 50029226280000 0.0 NA 0.0 NA NA NA P248 1921260 50029223090000 0.2 NA 0.2 NA 1.70 4/18/2012 P249 1920240 50029222520000 2.5 NA 2.5 NA 18.70 6/7/2009 --3 P2 -50B 1950960 50029222610200 2.0 NA 2.0 NA 23.00 6/8/2009 P2 -51 1920380 50029222620000 0.3 NA 0.3 NA 0.85 6/7/2009 P2 -52 1972010 50029228260000 3.8 NA 3.8 NA 47.60 6/7/2009 P2 -53 1960410 50029226560000 2.0 NA 2.0 NA 21.30 6/7/2009 P2 -54A 2030300 50029224700100 0.8 NA 0.8 NA 3.40 6/7/2009 P2 -55 1920820 50029222830000 4.0 NA 4.0 NA 79.90 6/22/2009 P2 -56 1951620 50029226100000 2.8 NA 2.8 NA 17.90 6/7/2009 P2 -57A 2022140 50029221830100 15.5 NA 15.5 NA 77.40 6/22/2009 P2 -58 1900080 50029220000000 Sealed conductor NA NA NA NA NA P2-59A 1982010 50029220960100 Sealed conductor NA NA NA NA NA P2-60 1910910 50029221920000 8.3 NA 8.3 NA 56.10 3/13/2012 1. Operations' Abandon D Repair Well 0 Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: I STATE OF ALASKA .--fffð¡ J ~·~·2 5 tOO? ALAS A OIL AND GAS CONSERVATION COM l0ti:!s.ka Oi! & Gas REPORT OF SUNDRY WELL OPERATIÖNs D D D P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Stimulate D Other D Liner Lap Squeeze Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 195-0960 - 3. Address: Exploratory Ser\iÌce 6. API Number: 50-029-22261-02-00 9. Well Name and Number: 51.5 KB P2-50B ADLO-034624 / 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PT MCINTYRE OIL Pool ' 8. Property Designation: Total Depth measured true vertical 15155 ' 9207.58 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 15083 feet true vertical 9146 feet Casing Length Size MD TVD Burst Collapse Production 80 20" 94# H-40 38 - 118 38 - 118 1530 520 Surface 4884 13-3/8" 68# L-80 37 - 4921 37 - 3997.85 4930 2270 Production 12339 9-5/8" 47# L-80 36 - 12375 36 - 7055.6 6870 4760 Liner 2969 7" 29# 13CR80 12186 - 15155 6977.37 - 9207.58 8160 7020 Perforation depth: Measured depth: 14886 - 14986 True Vertical depth: 8978.1 - 9063.29 - - SCANNED JUL 3 1 2007 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13cr80 35' - 14827' Packers and SSSV (type and measured depth) 7" TIW Liner Top PKR 4-1/2" Baker S-3 Perm Packer o o 12194 14772 o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFl JUl 3 0 2007 Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl Shut-in Shut-in Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after proposed work: Exploratory Development R 16. Well Status after proposed work: Oil P Gas WAG Tubing pressure o o 13. Serllice x Contact Gary Preble WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 306-388 Signature Title Data Management Engineer Phone 564-4944 Date 7/24/2007 sed 04/2006 0 R , G , N A I Âtì/;¡ l/ ./ ~,6/ Submit Original Only . . P2-50B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/18/2007 CTU #5. Cement Liner Lap. MIRU. InterAct not publishing. ***Job Continued on 7/19/07 WSR*** 7/18/2007 ***Continued from 7-17-07*** Assist E-line, Circ well to dead crude, Pumped 790 bbls crude down IA taking returns up Tubing through Flowline. E-line RIH, sat down high. Pumped another 20 bbls crude down IA taking returns up tbg down flowline.. E-line set fasdrill poppet retainer. Pumped 18 bbls crude down tbg to verify ability to pump through. RU to IA to test fasdrill poppet retainer from bottom side. Pumped 1.2 bbls crude down IA to reach 600 psi (500 psi above tbg pressure.) Monitored for 10 mins. Bled lAP back to 200 psi. Tagged IA stating IA & tbg fluid packed with crude. Notified pad op of well status. FWHP's=1 00/200/1 00 7/19/2007 CTU #5*** Job Continued From 7/18/07 WSR*** InterAct not publishing. RIH with 2.5" BDN for cement job. Tag retainer at 11945' ctmd. PUH 10' after getting weight back and correct to elm. Paint flag at 11920'. Standby on cement blend. Circulate 290 bbls of 140* F 1 % KCI in tubing to warm tubulars. RU cementers. Pump 14bbls 15.8ppg Unislurry through retainer for liner squeeze. Job Continued on 7/20/07 WSR 7/19/2007 IBP MONTHLY RENTAL FOR 06/20/07 - 07/17/07. MO 5TH NOTE: IBP SET 02/20/07. NOTE: PULLED 07/17/07 7/20/2007 CTU #5 Liner cement squeeze ***Continued from WSR 07/19/2007 *** InterACT not working. Pump 15bbls 15.8ppg Unislurry for cement squeeze of liner. Shut down pumping after 15bbls cement through retainer. Line up to take returns to 40 bbl gauge tank. Dump WHP to 40bbl tank. Less than .5bbl returned before returns stopped. No change noted in IA pressure. Pressure up IA to 1000 psi and saw no response on production tubing. POOH maintaining 1000 psi on IA and replacing coil voidage. OOH, secure well. Weekly BOPE test. Wait on lab results for compressive strength. MU BHA#2: Weatherford drilling string with 3.65" concave mill. Tag softly at 11900' ctm. Begin milling with 1 % XS KCI. Appeared to tag cement retainer at 11945' ctm, Continue milling. Broke through at 12081 'ctmd. RIH to 14596 for dry tag. POOH for BHA change. *** Job Continued on 7/21/07 *** 7/21/2007 CTU #5 ***Job Continued from 7/20/07 WSR*** InterAct Not Publishing POOH to change mill sizes. OOH. RIH with Weatherford BHA with 3.48" 3 Bladed Junk Mill. Dry tag at 14600'. Mill from 14300' using 2% XS KCI. Encountered 3 stalls in vicinity of GLM #7 at 14715' ctm. Proceeded to mill with no restrictions to 14940'. Shut down and dry tagged at 14986' ctm. Pumped 20 bbl Biozan sweep at tubing tail. POOH out of hole at chrome running speeds pumping 2% XS KCI to 100' ctm. Cement fines noted in returns. Run in hole and freeze protect tubing with 50/50 meth from 2100'. RDMO CTU. Notify DSO of well status. *** Job complete *** . . P2-50B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 1130 2% XS KCL 20 1.5pbb BIOZAN 2 01 ESEL 60 50/50 METH 1212 TOTAL ~¡ ~ E-., r\ fiE'~~ C'~:-'_',l! "lj~; 04/16/07 Schlumbel'ger APR 2 0 Z007 NO 4214 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ;í;~~ka Oil tk Gas Cons. GQf~ml~~~ Ai1chç~~ iCJS- -()C}~ Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description Date BL DS 04-01 11637323 SCMT 03/13/07 2-34/P-14 11638622 USIT 03/20/07 N-22B I 11594483 SCMT 03/06/07 N-22B NIA USIT (CORROSION) 02/13/07 N-22B . N/A USIT (CEMENT BOND) 02/13/07 P2-50B 11626472 SCMT 03/17/07 09-11 :: 11638619 USIT (CEMENT EVALUATION) 03/16/07 09-11 ." 11638619 USIT (CORROSION) 03/16/07 09-11 .' 11638621 CEMENT BOND LOG 03/19/07 L2-32 11221617 RST 10/13/06 A-24 11221856 RST 03/23/06 Color CD 1 1 1 1 1 1 1 1 1 ( PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Petrotechnical Data Center LR2-1 900 E, Benson Blvd. SCANNED APR 2 5 2007 Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: Received by: .-:;- e ob og escrlption Date BL Color CD 17-20 11536189 PRODUCTION PROFILE 12/13/06 1 N-22A 11538587 LDL 12/10106 1 R-04 11536188 LDL 12/12/06 1 17-12 NIA PRODUCTION PROFILE 11/27/06 1 B-01 NIA LDL 11/28/06 1 J-12 11513655 PRODUCTION PRO PILE 11/29/06 1 13-24A 11522675 MEMORY INJECTION PROFILE 11/28/06 1 L2-06 11487579 LDL 11/29/06 1 DS 04-15 11477943 INJECTION PROFILE 12/01106 1 P-25L 1 11513656 LDL 12/05/06 1 W-29 11549353 USIT 12/18/06 1 P2-50B 11513652 SCMT 11/26/06 1 03-08 11536186 SCMT 12/10/06 1 M-15 11486170 USIT 12/02/06 1 S-31A 11478134 USIT 11/27/06 1 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WII J # ,gS-oC](o L D 01/05/2007 NO. 4101 5CANNEP JAN 1 () 20m Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Received by: .' :; ! SARAH PALIN, GOVERNOR i j AIASKA OIL AND GAS CONSERVATION COMMISSION f 333 W. 71h A VENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-75423 Ross Warner Production Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, P2-50B Sundry Number: 306-388 ~ ~ Dear Mr. Warner: .'~f'" /iJ.. ff;¡tj..~~·,,-, ~~~~'-:t,,~ ...:.., Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this I~y of December, 2006 Encl. ()rv:s;' IZ¡Izl'/' If lZ" ¡¡..,lJ¡' O(V~.J KI::\..,t::IV~ /z.-/ILll.D"01.- -ö V STATE OF ALASKA f)n.... J~ðh ~J/¡i ¡ 0 A~ A OIL AND GAS CONSERVATION COMMI ON 0 E C 0 8 1006 rr" APPLICATION FOR SUNDRY APPROVdMka Oil & Gas Cons. Commission 20 AAC 25 280 . , 1. Type of Request: Abandon U Suspend D Operational shutdown U Perforate U vvcuv", LJ Other 0 Alter casing D Repair well 0 Plug Perforations D Stimulate D Time Extension D Liner Lap Squeeze Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ø Exploratory 0 195-0960 /' 3. Address: P.O. Box 196612 Stratigraphic 0 / Service 0 6. API Number: / Anchorage, AK 99519-6612 50-029-22261-02-00 7. KB Elevation (It): 9. Well Name and Number: 51.5 KB P2-50B /' 8. Property Designation: 10. Field/Pools(s): ADL-034624 PRUDHOE BAY Field 1 PT MCINTYRE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (It): ITotal Depth TVD (It): Effective Depth MD (It): Effective Depth TVD (It): IPlugs (measured): IJUnk (measured): 15155 9207.58 15083 9146.08 None None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94.5# H-40 38 118 38 118 1530 520 Surface 4884 13-3/8" 68# L-80 37 4921 37 3998 5020 2270 Production 12339 9-5/8" 47# L-80 36 12375 36 7056 6870 4760 Liner 2969 7" 29# 13CR80 12186 15155 6977.37 9208 8160 7020 Perforation Depth MD (It): Perforation Depth TVD (It): Tubing Size: Tubing Grade: Tubing MD (It): 14886 - 14986 8978.1 - 9063.29 4-1/2" 12.6# 13CR80 35 - 14827 /' Packers and SSSV Type: 7" TIW Liner Packer Packers and SSSV MD (It): 12194 4-1/2" Baker S-3 Perm Packer 14772 12. Attachments: DescriDtive Sum mary of Proposal ø 13. Well Class after proposed work: / Detailed Operations Program ~ BOP Sketch 0 Exploratory 0 Developm ent ø Service 0 14. Estimated Date for 1~06 15. Well Status alter proposed work: Commencing Operations: Oil ø / Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: <../ Date: WAG 0 GINJ 0 WINJD WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ross Warner Printed Name Ross Warner Title Production EnQineer - Signature C ·~_~/Á.A,. Phone 564-5359 Date 12/4/2006 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness SUndry Number: .~t11ì -ÔßÖ Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: Subsequent Form Required: to - 4'~ ~~7 ~ (:(COMMISSIONEA APPROVED BY Date: /'¡,,./t,.06 Approved by: THE COMMISSION V ;rNAL Form 10-403 Revised 11/2004 RBDMS Bft DEC 1 3 2006 Submit in Duplicate OR'G,N . . õ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, AK. 99519-6612 December 6, 2006 Alaska Oil & Gas Conservation Commission Attention: Mr. Winton Aubert 333 west 7'h Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Winton Aubert: RECEIVED DEC 0 8 2006 A'å§k~ Qil &GåS Con~. Commission Anchorage Reference: Sundry Notice for P2-50B---Liner Lap Squeeze. BP Exploration (Alaska) Inc. proposes to perform a Liner Lap Squeeze on well P2-50B. Attached is the program for restoring this well to its full capabilities as an oil producer. Summary: Step Type Summary 1 S PulllBP @ 14,786 f1. Make gauge run for Quik Drill and Retainer 2 E Set Quik Drill at 14,480'. Punch tubing 14,445-47. Ref: SCMT 11/27/06 3 FB Circulate well to dead crude 4 C Set Weatherford one trip cement retainer. Squeeze liner top. Mill cement, retainer and plug. 5 0 Pressure Test IA. 6 S Install new gas lift design. 7 0 Put well on production. Currently this well is shut-in. Service work will begin when approval is received from your organization. If you have any questions please contact me at 564-5359. Sincere.IY, .J ~ ~ f>L, y~ Ross L. Warner, GPMA Production Engineer Attachment . . r"'\__ ___ ö To: Jerry Bixby / Clark Olsen GPB Wells Operation Supervisors Date: December 6, 2006 From: Ross Warner, GPMA Production Engineer Subject: P2-50B Liner Lap Squeeze PMP02WL50-N Est. Cost: $250M lOR: 800 BOPD Please perform the attached liner squeeze procedure: Step Type Summary 1 S PulllBP @ 14,786 ft. Make gauge run for Baker Quik Drill composite plug and Weatherford Retainer. Quik Drill 00 = 3.595". Weatherford Retainer is 3.593" 00. Note: GLMs #5 & #61.0.=3.65". 2 E Set Quik Drill at 14,480'. Punch tubing 14,445-47. Ref: SCMT 11/27/06 3 FB Circulate well to dead crude 4 C Set Weatherford one trip cement retainer. Squeeze liner top. Mill cement, retainer, and plug. Coil drift to bottom set of perforations. 5 0 Test IA. 6 S Install new gas lift design. 7 0 Put well on production. Current Status: Shut In Max Deviation: 68 deg @ 4,874' Hole Angle @ Top Perfs. 32 deg @ 14,886' Minimum 10: 3.25" cement sheath 14,551-14,778' Last TO tag: SL Tagged @ 14986' ELMO with 3.25" CENT (10/28/05) Last Downhole Operation: Ran SCMT log on 11/27/06 Last CT Operation: 7/30/06. Completed packer squeeze. Latest H2S value: 15 ppm on 7/10/2001. BHP: -4300 psia @ 8800' SS. 14,742' MD. Temperature: 130 F - 180 F. Top of liner to Production Packer. Fish See well sketch Page 1 of 9 P2"50B Squeeze P2-50B liner Squeeze holes Annulus TOC Packer Leak 12,194 ft. Casing Cement Volume in Annulus (14550-1 X .0175::: 41 bbl. (12194-12044) X .0535::: 8 bbl Cement Volume in (14480-14335) X .0152::: 2.2 bbl 4-1/2" 12.6 Iblft Totals TOC ft. Cement in Set Retainer @ Punch Plug 14,480' ELM TOC: 1 ELM 14756-14758 Cemented. Ouring Packer 07/30/2006 Packer 7130106 Packer @ 1 4-112" 3.50" 10 1 OB-6 Nip. EOT 14827 .. 7" liner 2 . P2-50B Liner Squeeze . BackQround P2-50B is a PAL well that has been shut in since 2000 due to annular communication problems. On 5/1/2000, a LDL revealed a leak at GLM #7. After running a DGLV, a MIT-T to 3000 psi passed on 10/14/04 but the CMIT-TxIA failed, suggesting PC leak or a packer leak. A WFL run 7/16/2005 confirmed that the well had a packer leak. This ~1,7, leak rate was 6.5 gpm at 1100 psig on 7/16/05. On 7/14/06 (these dates are correct) ã Quik Drill Bridge plug was set at 14,786'. The tubing was punched at 14,756-758' on 7/22/06. The leaking packer was successfully repaired and this job was completed 7/30/06. The ensuring pressure test of the tubing was good, but a MIT-IA failed with leak rate of -0.5 bpm. A TecWel Leak Detection Log was run November 3,2006 which clearly illustrated that the liner lap was leaking and the production packer integrity was good. A Schlumberger SCMT was run 11/27/06 to determine the cement top in the IA. The log clearly indicated the TOC at -14,550 ft. Objective The objective of this procedure is to repair the liner lap leak. Perforations will be protected with a Baker Quik Drill Composite Bridge Plug. The tubing will be punched and circulation will be established. Coil tubing will set a Weatherford One Trip Cement Retainer above the tubing punched holes and cement will be circulated into the IA through these holes. Enough cement will be pumped into the IA to fully cover the liner lap area. Although this procedure will cover GLMs #5 & #6 (#7 was covered during the packer squeeze) the well will operate OK utilizing the four remaining stations. The cement in the tubing, retainer, and the Composite Bridge Plug will be milled when the cement develops 500-psi compressive strength (-5 hours, will use sample in cement lab for time). An MIT IA will then be conducted to evaluate the results of the job. By using the Unislurry cement only one coil trip to the well will be necessary. Note: Only a Baker Quik Drill Bridge Plug (3.595") will pass through the GLMs #5 & #6. The ID of these two mandrels is 3.65". The Halliburton FasDrill and Weatherford FracGuard both have running ODs of 3.660" If there are any questions please contact: Ross Warner: (W) 564-5359, (H) 333-9017, (C) 250-3441, or Jennifer Julian: (W) 564-5663, (H) 274-0929, (C) 240-8037. Note: JJ's phone may not work from the CT unit-you may heave to use the truck phone. Attachments: Tie in log and tubing tally. CC: Well File Amy Frankenburg GPB, LPC Lead Drill Site Operator GPB, LPC Drill Site Operator 3 . P2-50B Liner Squeeze . SQueeze TarQet Place cement in the tubing by IA annulus to repair confirmed liner lap leak. LLR through the liner lap was 0.35-0.50 bpm at 2900-3000 psi on 11/04/2006 (with IBP in tubing) Baker IBP set 8/19/06 @ 14,786'. MIT-T to 3000 passed &MIT-IA failed on 8/26/06 IA volume to top of cement at 14,550 is 693 bbls. Tubing volume to Baker Quik Drill Composite Plug to be set at 14,480' ELM is 220 bbls. Note: Well has TRSSV. NOTE: Have Dowell lab run tests for cement. Rough draft of cement blend is 15.8 Unislurry with 0.2% 0046, 0.2% 0065, and 0.35% 0167. Speak with the lab technician (659-2434) 2 days prior to rig up. He will need to be available to run the lab sample during the job. Cement temperature range is large, 130 F - 180 F. This range is from the top of the Liner to the Production Packer. Run tests for both high and low expected temperature. Use warmer temperature for 500 psi development strength to make sure cement doesn't set up too quickly. Pre-SQueeze Slick Line. E-Line. & Fullbore 1. Slickline: Pull inflatable bridge plug which is at 14, 786'. 2. Run a 3.625" gauge for the Baker Quik Drill bridge plug and one trip squeeze retainer. (00 3.595") On 8/15/06 a 3.625" gauge made it to 14,502' SLM. If the gauge will not go SL will have to broach tubing. If this does not work, coil will have to mill out the tubing. Note: Cement sheath in tubing from 14,551-14,778' that would only pass 3.25" gauge. During these operations it is not necessary to go to these depths. 3. Shoot fluid levels in the tubing and IA. Both should be fairly full of crude after Leak Detection Logging. 4. Rig up E-Line, pumps, and a crude supply. Rig up to pump down tubing and take returns up IA. 5. Pick up the Baker Quik Drill and set same at 14,480 Ft. Reference log for depth control is the Schlumberger SCMT run 11/27/06. Tie into the GLM #5 going down and the collars just above setting depth. Do not run plug into cement sheath in tubing from 14,551-14,778'. 6. Pressure test tubing to 3,000 psi after setting plug. 7. If the test is OK pick up a 2 ft. 1-11/16" tubing puncher gun (9 charges). Punch holes in the tubing at 14,445-47'. The bottom shot will be 2 ft. above the collar at 14,449'. Tag the Quik Drill plug so the CT operator knows the exact depth. 4 . P2-50B Liner Squeeze . 8. Fluid pack IA and tubing with crude. Establish circulation rate down tubing, taking returns up IA holding 100 to 200 psi backpressure. This has to be done by LRS as Schlumberger will not pump crude. CTU Liner SQueeze NOTE: This well has CHROME tubing and liner. It is important that the IA is liquid packed with crude during the squeeze. Shortly before the squeeze, shoot a fluid level on the IA to see if the annulus is liquid packed. 9. RU the CT and squeeze equipment. NOTE: Rig up surface equipment to allow returns from both the IA and the CTxTbg annulus. 10. Before commencing the job pump down the tubing and up IA again to confirm circulation through the punched holes by pumping down tubing and taking returns from the lA, holding 100-200 psi backpressure. Confirm 1-for-1 returns to an open-top tank. 11. Pick up the BHA with a Weatherford FH One Trip Cement Retainer. RIH and tag the top of Composite Plug. Pick up full string weight and correct depth to EL setting depth of plug. PUH and position Retainer at 14,400 ft. Drop ball to set retainer. Confirm retainer is set by pressure testing tubing by CT annulus to 1000 psi. If pressure test is OK pump down the CT to confirm injection through the retainer. Do not sting out of retainer at any time until squeeze is completed. / Batch mix 51 pumpable bbl 15.8 ppq Unislurrv cement which will give 500 psi compressive strength in 5-7 hours and -2000 psi ultimate compressive strength. Cement temperature range is large, 130F - 180 F. Top of Liner to Production Packer. · Catch a sample of the cement for QC testing. (This needs to go to the lab to know when the blend should reach the right strength. Lab must be notified prior to the job.) Once the blend is approved, conduct a Job Scope meeting to ensure that participants know the upcoming operations. Line up cementers to the coil. · Ensure all gas is out of the system. Do not proceed with squeeze unless the tubinQ is liquid packed and qas free. 12. Line out cementers to the CT. Pump the following down the coil: . 10 bbl spacer water . 51 bbl Unislurry · One coil volume of spacer water · 1 .5# biozan gel for cement clean-out 5 . P2-50B Liner Squeeze . SAFETY: 51 barrels of cement would extend up the tubing to 11.045 ft. if no cement is placed below the retainer. (Retainer is at 14400' ft). 13.lf CT pressure increases to -3000 psi while pumping into the retainer, plan to un- sting from the retainer and lay in remaining cement. Go to the clean out in step # 12. According to Weatherford there is no problem pulling the stinger out of the retainer under pressure. The valve travels into a fully closed position before the shear pins can be affected to release the stinger. Also, pressure differentials, while pumping, are positive down on the stinger because the retainer 10 is smaller than the coil 00. That fact, plus whatever weight that can be applied from surface by sitting down on the retainer is more than enough to keep from becoming un-stung due to any pressure the coil will experience during the operations. 14. With one bbl of cement left in the coil, un-sting coil from retainer and lay in the remaining bbl of cement on top of the retainer. PUH to safety at 11,045 ft. With the retainer at 14,400 ft. the top of the cement in the annulus should be -12,044 ft. and there should be about 65 ft. of cement on top of the retainer. NOTE: Monitor IA pressure during the squeeze to ensure retainer remains set. 15. Open the choke on the backside (tubing x CT annulus) and begin pumping biozan down the CT for clean out to 14,380 ft. 16. Switch to friction reduced water. Make a couple of passes from the retainer to safety. Take barrel count to ensure 1:1 returns. Jet uphole at 80% running speed and max CT pressure, washing all jewelry thoroughly noting the GLMS and TRSV. Monitor wellhead pressure for inflow in case the retainer valve didn't hold. 17. Freeze protect the top 2,500' of the well bore while POOH. 18. RU with mill and motor to mill through -65' of cement, retainer and bridge plug. Use a bit recommended by Weatherford, but ensure it is smaller than the 4-1/2" Camco OB-6 Nipple at 14,804'. 10 of this profile is 3.5". A 3.450" mill was used during the packer squeeze drill out 7/29/06. Before beginning to mill, wait until the lab sample has reached 500 psi compressive strength at the lower temperature of 130 F. This should take about 5-7 hours. Note IA pressure after drilling out retainer. 19. Orift to below perfs to ensure perfs are clear of debris. Target depth is 14,990 ft. 20. POOH, making sure to freeze protect the well. ROMO. 6 . P2-S0B Liner Squeeze . Post-Liner Lap SQueeze 21.After 3 days woe, MIT-IA to 3000 psi. 22.lf the MIT-IA passes rig up slickline to install a new GL Design and put the well on production. This program is on the slope. The design was written December 2, 2006. 7 . P2-50B Liner Squeeze . ':, ',' ","1'" : . . . c " ..., ,'. ",;" 23&18 FTON J' ,f.~..~ ,.., ......:..,.,,:;. i;..'. 'ff-#} :.:.'.,.:.... 'if," ITEM Descr:iD_n includes: S E ITEM ID 00 LENGTH TOP BOTTOM WlEG 3.88 4.95 1.35 14825.28 14826.63 PUD Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 19.42 14805.86 14825.28 OB-6 Nipple w/ RHC pluQ ( No shear lock) 3.50 5.00 1.40 14804.46 14805.86 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.68 14794.78 14804.46 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 19.22 14775.56 14794.78 Baker S-3 Hyd Permanent Packer 3.94 5.94 3.80 14771.76 14775.56 PUD Jt, 4-1/2H 13Cr, NSCT 3.94 4.94 9.68 14762.08 14771.76 1 Jt 4-1/2" 13Cr, NSCT TbQ (#1) 3.94 4.94 39.73 14722.35 14762.08 Pup Jt. 4-1/2" 13Cr, NSCT 3.94 4.94 9.00 14713.35 14722.35 GLM #1 - Cameo 4.5 x 1", KBG-2LS w/ OV 3.65 5.80 7.20 14706.15 14713.35 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.81 14696.34 14706.15 27 Jts 4-1/2" 13Cr Tba (#2-#28) 3.94 4.94 1076.97 13619.37 14696.34 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.01 13610.36 13619.37 GLM #2 - Cameo 4.5 x 1", KBG-2LS w/OV 3.65 5.80 7.20 13603.16 13610.36 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.88 13593.28 13603.16 14 Jts 4-1/2" 13Cr Tba (#29-#42) 3.94 4.94 566.76 13026.52 13593.28 PUD Jt. 4-1/2" 13Cr, NSCT 3.94 4.94 9.00 13017.52 13026.52 GLM #3 - Cameo 4.5 x 1", KBG-2LS wi OV 3.65 5.80 7.20 13010.32 13017.52 PUD Jt, 4-1/2" 13Cr. NSCT 3.94 4.94 9.84 13000.48 13010.32 24 Jts 4-1/2í, 13Cr Tba (#43-#66) 3.94 4.94 964.94 12035.54 13000.48 Pup Jt, 4-1/2" 13Cr. NSCT 3.94 4.94 9.01 12026.53 12035.54 GLM #4 - Cameo 4.5 x 1.5", MMG wi OV 3.83 7.03 8.65 12017.88 12026.53 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.80 12008.08 12017.88 37 Jts 4-1/2" 13Cr Tba (#67-#103) 3.94 4.94 1460.46 10547.62 12008.08 Pup Jt. 4-1/2" 13Cr, NSCT 3.94 4.94 9.01 10538.61 10547.62 GLM #5 - Cameo 4.5 x 1.5", MMG wi OV 3.83 7.03 8.64 10529.97 10538.61 PuP Jt, 4-1/2" 13Cr. NSCT 3.94 4.94 9.67 10520.30 10529.97 48 Jts 4-1/2"13Cr TbQ (#104-#151) 3.94 4.94 1933.70 8586.60 10520.30 PUD Jt, 4-1/2" 13Cr NSCT 3.94 4.94 9.03 8577.57 8586.60 GLM #6 - Cameo 4.5 x 1.5", MMG wi OV 3.83 7.03 8.66 8568.91 8577.57 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.36 8559.55 8568.91 89 Jts 4-1/2" 13Cr Tba (#152-#240\ 3.94 4.94 3576.09 4983.46 8559.55 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.03 4974.43 4983.46 GLM #7 Cameo 4.5 x 1.5" MMG wi RP shear 3.83 7.03 8.67 4965.76 4974.43 PuP Jt. 4-1/2" 13Cr, NSCT 3.94 4.94 9.82 4955.94 4965.76 68 Jts 4-1/2" 13Cr Tba 1#241-#308) 3.94 4.94 2738.18 2217.76 4955.94 Pup Jt, 4-1/2" 13Cr. NSCT 3.94 4.94 9.70 2208.06 2217.76 SSSV-CamcoTRCF4A 3.81 6.38 7.16 2200.90 2208.06 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.67 2191.23 2200.90 54 Jts 4-1/2" 13Cr Tba 1#309-#362) 3.94 4.94 2153.53 37.70 2191.23 FMC Tubina hQr w/13 Cr DUP 3.94 10.75 2.73 34.97 37.70 Pool Rot Tbl to Tba Har LOS 34.97 34.97 ö . P2-50B Liner Squeeze . ..~-..."-.;. . "-'-~ e¡ ~þ" ~ Retainer set at 14,400' ELM (SWS log SCMT run 11/27/06) Tubing punched at 14,445-14,447' ELM Baker Quik Drill Plug set at 14,480'. ELM 9 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 1 00 Anchorage, Alaska 99501 RE: Cased Hole/Open Hole/Mechanical Logs and jar Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7) EDE Disk P2 - 508 Leak Detect - WLD 03-Nov~6 , ---I'" ·;;¡'C.t.i"\N~-p- },..t·~if·~\¡;'~;~" "'" ,0 S- - 0'1 (P li.fQDQ Signed: Q<2~ :j1 Print Name: ...QJ/\ r\s -H IA 0 iÍVla \A \A 1.( ª l^, Da~: _ _ _._. _._. ',~ ,:JJ~to© ;{)~~ d~ ::ì~~ '\,:-e:DSôL;-'Çrm å ~~~jj ~ PROAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (901)245-8952 E..MAIL: ?D~)Þ.0j(:H<)Ft~\(~E@~v¡E~viC)¡~Y~_.Ot3.Gi)ß.·J WEBSITE: If\flJì¡lj\j.MEj\jl0R''{L'-JG"CO~1 D:\OO ~ PDSANC-2006\Z _ W ord\Dístribution\Transmittal _ Sheets\TransmiUJriginal.doc RECEIVED STATE OF ALASKA. , ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 0 4 2006 REPORT OF SUNDRY WELL OPERA TI8NSI & Gas Cons. Commission . 1. Operations Perfonned: Abandon 0 Alter CasingD Change Approved Program 0 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. Repair Well£&) Plug PerforationsD Pull TubingD Perforate New PaolO Operation ShutdownD Perforate 0 4. Current Well Class: Development ŒJ Stimulate 0 WaiverD ge OtherD Time ExtensionD Re-enter Suspended WellD 5. Penn it to Drill Number: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): ExploratoryD 51.50 8. Property Designation: ADL-034624 11. Present Well Condition Summary: StratigraphicO 9. Well Name and Number: P2-50B 10. Field/Pool(s): Prudhoe Bay Field 1 pt Mcintyre Oil Pool ServiceD 6. API Number 50-029-22261-02-00 Total Depth measured 15155 feet true vertical 9207.6 feet Plugs (measured) IBP set @ 14786 (08/19/2006) Effective Depth measured 15083 feet Junk (measured) Milled down to 14980 (07/30/2006) true vertical 9146.1 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H-40 38 - 118 38.0 - 118.0 1530 520 SURFACE 4884 13-3/8" 68# L-80 37 - 4921 37.0 . 3998.0 4930 2270 PRODUCTION 12339 9-5/8" 47# L-80 36 - 12375 36.0 - 7056.0 6870 4760 LINER 2969 7" 29# 13Cr80 12186 - 15155 6977.0 - 9208.0 8160 7020 " C \ (,' Perforation depth: Measured depth: 14886-14986 True vertical depth: 8978-9063 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 80Cr13 @ 35 14827 Packers & SSSV (type & measured depth): 9-5/8" TIW Liner Packer @ 12194 4-1/2" Cameo TRCF-4A TRSV @ 2201 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS BFt (J CT (} 4 2006 13 Prior to well operation: Subsequent to operation: Oil-Bbl 51 51 ReDresentative Dailv Averaae Production or Iniection Data Gas-Mef Water-Bbl Casin Pressure o o o o Tubin Pressure 49 274 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD Development[! ServiceD Signature WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: 305-355 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Petroleum Engineer Phone 564-5174 Date 1 0/2/06 Fonn 10-404 Revised 4/2004 . . P2·50B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/26/2006 T/l/O=800/300/100 MIT IA 3000 psi (FAILED) MIT TBG 3000 psi (PASSED)(Packer squeeze)(Shut in) Pumped 3.4 bbls of 55* crude down TBG to reach 3000 psi for MIT TBG 1 st test 1 st 15 min lost 80 psi 2nd 15 min lost 0 psi for a total of 80 psi in 30 min bleed TBG psi to 500 psi bleed back gas Pumped 29 bbls of 55* crude down IA to reach 3000 psi for MIT IA 1 st test 1 st 15 min lost 1320 psi Pumped up TBG to 3000 psi w/1.8 bbls of meth for CMIT TxlA Pumped 4.3 bbls of crude and 9 bbls of meth down IA for CMIT TxlA but unable to reach test psi established LLR test down IA of .42 bpm at 3000 psi for 8 bbls pumped 11 bbls total bleed well head psi down Final Whp's=350/300/150 08/25/2006 T/I/O=800/300/100 MIT IA 3000 psil MIT TBG 3000 psi (Packer squeeze}(Shut in) pumped 2.5 bbls of 75* crude down TBG wing leaking job in progress 08/19/2006 WELL SHUT-IN ON ARRIVAL. TIIIO = 550/340/100. SET 2-1/2" BAKER IBP IN 4-1/2" TUBING AT 14786' MID-ELEMENT. TOP OF PLUG 7.12' FROM MID-ELEMENT. TWO 5- 3/4" SEALING ELEMENTS, ONE 1" STIFFENER RING.. 1.375" FISHING NECK. 08/17/2006 TIIIO = 570/170/90. Temp = SII. AL spool disconnected. WHPs and TBG FL (pre-IBP). TBG FL near surface. IA is fluid packed. 08/15/2006 ***WELL WAS SHUT-IN ON ARRIVAL*** (pre mit - pit maint) RAN ASSORTED CENTRALIZERS & SWAGES TO FIND OUT WHAT SIZE HOLE IS THROUGH CEMENT SHEATH, FOUND THAT A 3.25 CENTRALIZER PASSES ALL THE WAY OUT THE TBG TAIL (SEE WSR). DRIFTED WITH 10' OF 3" DRIVE DOWN BAILER TO 14,850' SLM. NO OBSTRUCTIONS. ****LEFT WELL SHUT-IN, E-LlNE WILL COME BACK AND SET A IBP**** 08/05/2006 SET 41/2" WIDDON @ 12983' SLM JOB SCOPE CHANGE PULLED WIDDEN, RDMO ***WELL LEFT SII, DSO NOTIFIED*** 08/04/2006 ***WELL SII ON ARRIVAL*** (set gas lift design) RIG UP IN PROGRESS. 08/04/2006 T/IIO=350/290/100. Temp=SI. MIT-IA FAILED to 3000 psi (post-Packer Squeeze). AOGCC State Witnessed by Chuck Scheve. Pumped 15 bbls fluid to MIT-IA to 3000 psi. lAP decreased 300 psi in 1st 3 mins. Pumped 5 bbls to establish LLR of 19.75 gpm @ 2940 psi. Bled lAP to 1350 psi (9 bbls returns). Final T/I/O=350/1350/125. 08101/2006 TIIIO= 400/270/80 Temp= SII TBG & IA FL (Pre MIT-IA) TBG FL= At surface. IA FL = At surface. AIL spool is dropped. Has integral flange on IA. 07/30/2006 CTU #6, Packer Sqz; RIH with 2 7/8" WFD underreemer dressed with 6" blades to 14,980' tag, start underreaming up to 14,840' and back down to 14,980', made two more passes. Did not see any significant motor work. Open circ sub and pump biozan sweep off bottom. POOH. Freeze protect well with diesel from 2500' while POOH. Well left shut in. RD CTU #6. Page 1 . . P2-50B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/29/2006 CTU #6, Packer Sqz; Continue standby for cement results. Rih with 3.450" 5 Bladed Junk Mill to 14551', dry tag. Begin milling hard cement at 14,551' to 14,778"and milled through Fasdrill plug. Did not see any sign of communication with IA after milling through GLM #7 and the squeeze holes. lAP has not responded to changes in WHP. POOH. 07/28/2006 T/I/O=0/0/400 Assist Coil Tubing Pumped 130 bbls 48* diesel down IA to freeze Protect IA 07/28/2006 CTU #6, Packer Sqz; Circ gas out ia with 1% KCL. Top IA with 130 bbls diesel. Lay 6 bbls of cement in tubing from 14772'. Close in backside and displace 2.8 bbls into IA. Maintain balance and RIH jetting biozan to 14585'. POOH at 80% circulating. Standby and wait on lab results for compressive strength. 07/27/2006 CTU #6; Packer Sqz; MIRU CTU #6. Circ gas out of tbg and IA. 07/25/2006 T/I/O=800/570/140 Temp=S/I Bleed TBG & IA (Pre CMIT-TxIA) TBG FL @ surface, IA FL @ 132' (7-24) Bled lAP from 570 (gas) psi to 440 psi in 30 min (fluid to surface), SI for 15 min, lAP increased to 510 psi. Did same procedure 3x with same results each time. AIL line has 350 psi and flow line shows 100 psi. lAP increased from 440 psi to 520 psi in 30 min. Bled TBP to 430 psi (crude) (lAP tracked)and monitor for 30 min. TBP up to 600 psi but lAP remaining @ 420 psi. 3 bbls crude to tank. TB & IA FL @ surface. FWHP=600/420/140 07/24/2006 TIIAlOA = 860/560/160. Temp = SII. WHPs & IA FL (pre CMIT- TxIA). IA FL @ 132' (8 07/22/2006 TUBING PUNCH 4.5" TUBING OVER INTERVAL 14,756-14,758 FT. BRIDGE PLUG TAGGED AT 14,782 FT. TIIIO 900/580/150 DEPTH CORRELATED TO SLB IBP SETTING RECORD DATED 24-JAN-2000. JOB COMPLETE. 07/21/2006 TIIIO = 850/600/150. RAN IN HOLE TO PUNCH TUBING. 07117/2006 T/I/O=900/620/150 Assist E-Line with LDL. Pumped 41 bbls crude as directed down tubing. FWHP's=2100/1500/300 07/17/2006 LEAK DETECT LOG. LEAK FOUND IN GLM #7 AT 14710'. 0.5 BPM LEAK DOWN TUBING. LESS THAN 0.1 BPM LEAK FROM IA TO FORMATION. COULD NOT TAKE RETURNS DOWN FLOWLINE. NO LEAK SEEN IN TUBING PLUG. ASSUMED FLUID EXITED IA THROUGH PACKER. JOB COMPLETED. FLUIDS PUMPED BBLS 5 Diesel --- PT Surface Equipment 22 Methanol 407 Diesel 95 Crude 1099 1 % KCL Water 2501 1 % Extra Slick KCL Water 49 Fresh Water 151 1.5# Biozan 6.1 15.8 PPQ Uni-Slurry Cement 4335.1 TOTAL Page 2 , TREE = WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 4-1/16" FMC FMC AXELSON 51.5' 3?' 1190' 68 @ 4874' 15383' 8800' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" H 4921' Minimum ID = 3.500" @ 14804' 4-1/2" CAMCO DB-6 NIPPLE I TOP OF TIW TlEBA CK SL V I 19-5/8" X 7" TIW LNR HGR I 19-5/8" CSG, 47#, L-80, ID = 8.681" I TUBING PUNCH SOl'D (07/29/06) I 14756' -14758" 14-112" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" I 14772' /4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" I 14825' PERFORA TION SUMMARY REF LOG: SWS CDR ON 08/06/95 ANGLEATTOPPERF: 32 @ 14886' Note: Refer to Produetion DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 14886 - 14986 C 07/12/01 P2-50B . SAFETY : PRE- SDTRK WB-LBORE NOT SHOWN BS-OW 9- 8" MILLED WINDOW@ 12375'. "4·1/2" CHROMETBG & 7" LNR 9-5/8" CSG SET ON EMERGENCY SLIPS. LOST TWO RUBBER S-EM ENTS PULLING 3-3/8" IBP ON 02/02/00. IA CEM ENTED ABOVE GLM # 7 (07/29/06). 1" GL V IN WS-L. DEPTHS UNKNOWN. **4-1/2" CHROMETBG*" 2201' -l4-1/2" CAMCO TRCF-4A, TRSV, ID = 3.812" I GAS LIFT MANDRELS ST MD TVD DEV TYÆ VL V LATCH PORT DA TE 1 4966 4015 67 MMG DMY RK 0 06/18/04 2 8569 5511 66 MMG DMY RK 0 07105/01 3 10530 6307 66 MMG DMY RK 0 06/18/04 4 12018 6908 66 MMG DMY RK 0 07105/01 5" 13010 7410 40 KBG-2-LS DMY BK 0 07105/01 6" 13603 7892 32 KBG-2-LS DMY BK 0 07/05/01 7" 14706 8826 33 KBG-2-LS DMY BK 0 07/05/01 "NOTE: MINIM UM ID = 3.65" -19-5/8" X 7" TIW LNR A<R I -1 ESTIMA TED TOC IN IA (A<R SQZ 07/29/06) 9-5/8" SIDETRACK WINDOW 12375' - 12455' (SECTION MILL) 14772' -17" X 4-112" SKR 8-3 PKR, ID = 3.875" I 14786' -12-1/2" BKR IBP SET (08/19/06) I 14804' -14-1/2" CAMCO DB-6 NIP, ID = 3.500" 14827' -14-1/2" WLEG, ID = 3.88" I 14823' H ELMD TI LOGGED 08/20/95 14866' -l7" MARKER JOINT (19') I I 7" LNR, 29#, 13-CR-80, .0371 bpf, ID = 6.184" I DATE OS/15/95 12/03/02 06/18/04 11/06/05 11/15/05 07/14/06 REV BY COMMENTS ORIGINAL COM PLETION ?ITP CHANGEGLV SIZE-SAFEfY RIVÐKAK GLV C/O RAClTLH PULL TIP/ MIN GLV CORRECT. RW/PJC KB/BF CORRECTIONS DFRlPJC SET BKR QUICKDRILL PLUG DA TE REV BY COMMENTS 07121/06 DFRlPJC TUBING PUNCH 07/30106 SRB/PAG A<R SOl @ 14756 08/21/06 DFRlPAG SETBKRIBP@ 14768'(08/19106) 09/05/06 DFRlPJC 2-1/2" ISP DEPTH CORRECTION PRUDHOE SA Y UNIT WELL: P2-50B PERMIT No: '1950960 API No: 50-029-22261-02 see 14, T12N, R14E495' FNL & 1256' FWL BP Exploration (Alaska) Scblumberger RECEIVED NO. 3980 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth OCT 0 4 2006 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ Oil & Gas ConS. Gomfl1ÌS$ÍÇr¡ Ar1chcrnge Field: Prudhoe Bay WI C el Job# Log Description Date BL Color D L5-28A 11320994 STATIC PRESSURE LOG 07/30/06 1 P2-50B 11212876 LDL 07/17/06 1 H-26 11225990 LDL 07/09/06 1 K-02D 11209593 SCMT 07/20/06 1 J-09A 11321005 LDL 08/29/06 1 D.S.04-19A N/A INJECTION PROFILE 08/02106 1 J-06 11321006 PRODUCTION PROFILE 08/29/06 1 G-24 N/A SCMT 08/08/06 1 2-18/L-16 11225986 LDL 07/04/06 1 F-05A 11216212 MCNL 09/03/06 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage. AK 99503-2838 ATTN: Beth lC)S -69k 2; ~ÇANNE~) " 10/02/06 . . .r MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg -; û ' " ¡ l' P I S . 1/ e¿ ¿;;! ' vi, ,--,6 .. upervlsor ,.......... 1(; , , I DATE: Wednesday, August 09, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC P2·50B PRUDHOE BAY UN PTM P2-50B \q6-,oq(P FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .j>¡2-- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN PTM P2-50B API Well Number 50-029-22261 -02-00 Inspector Name: Chuck Scheve Insp Num: mitCS060805 I 50035 Permit Number: 195-096-0 Inspection Date: 8/4/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~..~ !Type Inj. ! -,----'~.. ! I Well i P2-50B ,TVD 8881 ! IA 290 3000 I i I I ~ ¡TypeTest : SPT! Test psi I I t---.. i -- P.T. 1950960 I 2220.25 ! OA 100 I 175 ¡ I I I ,---' ....L.. -----L__..l..- ,/ Tubing! 350 375 : I , Interval OTHER PIF F I I I I I -- Notes This Well is a producer that has a packer leak. An attempt had been made to cement the packer in plcae to repair the leak. When the intended test pressure of 3000psi was reached a leak rate of.47 bbl per minute was established. ~e ~. , CC . ,,«''1''¡Q[. \ SCANNED l~UG 2 ,1 2006 Wednesday, August 09,2006 Page I of I 1'-.1...... f UU 1 ..;..-JVU 1 au\,,;u iVU 1 . . Jim, We currently have a plan in place to secure the well with an IBP due to the recently failed packer squeeze attempt. Thank you, Andrea Hughes x5102 -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Friday, August 18, 2006 11:25 AM To: NSU, ADW Well Integrity Engineer Subject: PBU P2-50B Failed MIT Inspector witnessed MIT on 8/4; report attached. Status of well? 1 of 1 8/18/2006 11 :38 AM Well Job# Loa DescriDtion Date BL Color CD I P2-22 í '11 - d'-l9 11136744 GL.S 117ßT05 1 1"2-1ti IS::/,. - I~-=< 11058238 WFL 08/18/05 1 I P2-36 í C¡'t - I (',.,() N/A LDL 07/13/05 1 -r-,,"\ - 0"7 ~ N/A LDL 07/16/05 1 16-03 '7.-/-C' ¡I 11076454 INJECTION PROFILE 07/28/05 1 P2-36 ¡C¡t -/{?Ó 11051061 GLS/LDL 06/15/05 1 4-18/5-30 Î"fI'Í\ - 11 6 10564459 PSP GLS 04/18/03 1 1-33B/L-24 J G x - ~~5 10889175 SCMT 10/12/04 1 04-41A ¡c1- - éyÇ~ N/A LDL 07/18/05 1 15-09A ì~1 ::: -I.~"i< N/A OIL PHASE BOTTOM HOLE SAMPLE 02/02/05 1 09-17 t -:t-- -,..~LÇ( 11076460 INJECTION PROFILE 08/18/05 1 16-09A 1'1 { - ()3~ 11051089 PRODUCTION LOG W/DEFT 08/18/05 1 16-11 i~(-" -1/7( 11058249 LDL 09/14/05 1 17-02 í ~(' - OrO N/A SENSA MEMORY LDL 10/17/05 1 NK-38A f~J(~~1 -::J4 I 10687734 MDT 02/27/05 1 R-35 ¡C¡-=<-/f¡¡ 11212863 USIT OS/26/06 1 D-09A I CìLì - -)j r,,- 11221576 US IT OS/27/06 1 L5-16 ¡-'X t - n 10, 11212864 US IT OS/28/06 1 K-08A ~ .~~ -. /4(', 11054182 MCNL .:$I: ì·-:::(...¡q~ 06/06/05 1 1 H-04A V~:':¡'-I(/( 10715365 MCNL 0# I:~ <./s '=<' 11/27/03 1 1 RECE\VED Scblumberger JUN 0 8 2006 \~ Oil .& Gas CoOS. ccmmi&SiOO .A~rage c- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Petrotechnical Data Center LR2-1 900 E, Benson Blvd, Anchorage, Alaska 99508 /'" {¡' / t .I ,I ! (~!j ..../' . ;oj i I , -'I i J ~jv~_ 06/01/06 NO. 3828 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman ¡~~:~~~:~hA~v~9~~~te 100 .~, Field: Prudhoe Bay \.,ÇïG·"'O .' e e Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ~~ Tr· "rf : '.! " " : î :; ¡'.' ;::¡.. ~n) Pn I' ! ~" :' . UUUU~ e './IT.1 ~ ...Æ.8 \ I.M.I.../ß.\.~.~ ~. 7 . ® ~ U lru tbLrlJ æJ uÙ~~ e AI¡ASIiA OIL AM) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR Ross Warner Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 333 W. ]T" AVENUE, SUITE 1QO ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: PT McIntyre P2-50B ~^NNELY DEC 1 (32005 Sundry Number: 305-355 ... . ~ Dear Mr. Warner: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisÆ day of November, 2005 Encl. ® 1. Type of Request: Abandon U Suspend D Operational shutdown U Perforate U Waiver U AnC - erU Alter casing D Repair well 0 Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: ../ 5. Permit to Drill f'41.¡mber: Development ~ 0 ¡;If;fIfl//' ¡. BP Exploration (Alaska), Inc. Exploratory ....... . 3. Address: P.O. Box 196612 Stratigraphic 0 Service 0 6. API Number: Anchorage, AK 99519-6612 50-029-22261-02-00 ,/ 7. KB Elevation (ft): 9. Well Name and Number: / 51.5 KB P2-50B 8. Property Designation: 10. Field/Pools(s): ADL-034624 PRUDHOE BAY Field / PT MCINTYRE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): ITotal Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): IPlugs (measured): IJUnk (measured): 15155 9207.58 15083 9146.08 None None Casing Length Size MD / TVD Burst Collapse Conductor 80 20" 94.5# H-40 38 118 38 118 1530 520 Surface 4884 13-3/8" 68# L -80 37 4921 37 3998 5020 2270 Production 12339 9-5/8" 47# L-80 36 12375 36 7056 6870 4760 Liner 2969 7" 29# 13CR80 12186 15155 6977.37 9208 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 14886 - 14986 8978.1 - 9063.29 4-1/2" 12.6# 13CR80 35 - 14827 Packers and SSSV Type: 7" TIW Liner Packer Packers and SSSV MD (ft): 12194 4-1/2" Baker S-3 Perm Packer 14772 12. Attachments: Descriptive Summary of Proposal ~ 13. Well Class after proposed work: / Detailed Operations Program ~ BOP Sketch 0 Exploratory 0 Development ~ Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/29/2005 Oil ~ Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ross Warner Printed Name Ross Warner Title Production Engineer Signature ~d~ ~/.h Phone 564-5359 Date 11/15/2005 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness lSUndry Number: CDS - M~C; Plug Integrity 0 BOP Test 0 Mechanical Integrity Test [Ø" Location Clearance 0 Other: S'b"'''m 04 · 'FU3DMS 8Ft NOV 2 1 2005 APPROVED BY //Í If¡ ír Approvedlj:,- _..,J ~~ COMMISSIONER THE COMMISSION Date: '-"" \.-/" O'RrGIN ( / , Form 10-403 Revised 11/2004 Submit in Duplicate ~ ¡¡.... 17, OS _ STATE OF ALASKA _ AL~ OIL AND GAS CONSERVATION COMM~N APPLICATION FOR SUNDRY APPROVAL 20 AAC 25 280 REeEt}4lzJ)ûOi- NOV 1 6 2005 Alaska Oil & Gas Cons. Commission e e õ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Ak. 99519-6612 November 16, 2005 Alaska Oil & Gas Conservation Commission Attention: Mr. Winton Aubert 333 west ih Avenue, Suite 100 Anchorage, AK 99501 RECF~~' NOV 1 6 Z005 r)' :~'''t<: . Alaska Oil & Gaii CiJì.$. i.,.íJillmìs$Î9r! Anchorage Dear Mr. Winton Aubert: Reference: Sundry Notice for P2-50B---Packer Squeeze. BP Exploration (Alaska) Inc. proposes to perform a Packer Squeeze on well P2-50B. 0' Attached is the program for restoring this well to its full capabilities as an oil producer. Summary: Step Type Summary 1 E Set Fas Drill Bridge Plug and Punch Tubing. 2 C Packer squeeze. 3 S woe 3 days. Tag TOC. MIT-IA / 4 C Mill cement & plug. Underream Casing. 5 0 MIT-IA Currently this well is shut-in. Service work will begin when approval is received from your organization. If you have any questions please contact: Jennifer Julian at 564-5663 or Ross Warner at 564-5359 Sincerely, ~~~ Ross L. Warner Attachments e e bp To: J. Bixby / D. Cismoski, GPB Well Ops TL Date: November 15, 2005 From: Ignatius Sorman, Wells Engineer, for Ross Warner Subject: P2-50B Packer Squeeze PMP02WL50B-N Est. Cost: $200 M lOR: 1000 BOPD PI rf th tt h d k d ease pe orm e a ac e pac er squeeze proce ure. Step Type Summary 1 E Set Fas Drill Bridge Plug and Tubing Punch. 2 C Packer squeeze. 3 S wac 3 days. Tag TOC. MIT-IA / 4 C Mill cement & plug. Underream Casing. 5 0 MIT-IA Current Status: Shut In. Max Deviation: 68 deg @ 4874' Hole Angle @ Top Perfs. 32 deg @ 14886' Minimum 10: 3.5" @ 14804' 4-1/2" Camco DB-6 Nipple Last TO tag: SL Tagged @ 14986' ELMO with 3.25" CENT on 10/28/2005 Last Downhole Operation: SL Pulled TTP, D&T to 14986' ELMO on 10/28/2005 Last CT Operation: Bead Blaster down to 14960' CTM on 1/15/2000 Latest H2S value: 15 ppm on 7/10/2001 P2-50B is a PAL well that has been shut in since 2000 due to annular communication / problems. On 5/1/2000, a LDL revealed a leak at GLM #7. After running a DGLV, a MIT- T to 3000 psi passed on 10/14/04, however CMIT-TxIA failed, suggesting PC leak or a packer leak. A WFL run 7/16/2005 confirmed that the well has a packer leak. The objective of this procedure is to repair the packer leak. Perforations will be protected with a Halliburton Fas Drill Bridge Plug. Cement will be circulated into the IA through holes that are shot with a tubing puncher gun. A cement plug will be left in the / tubing to prevent possible U-tubing of cement back into the wellbore. After wac, the cement and the composite plug will be milled up. Another CMIT-TxIA will then be conducted to evaluate the results of the job. If there are any questions please contact: Jennifer Julian: (W) 564-5663, (H) 274-0929, (C) 240-8037. Ross Warner: (W) 564-5359, (H) 333-9017, (C) 250-3441. Page 1 of 7 e P2-50B Packer Squeeze e TOC at 14630' 4-1/2" TBG at 14772' 00 OB-6 NIP at 14804' DD 4.5" TT at 14823' ELMD 7" liner TBG Punch Holes at 14740' Fas Drill Plug set at 14785' DD Cement Volume in Tubing (147851-146301) * .0152 = 2.4 2.4 bbls r Cement Volume in Annulus (14772-146301) * .0175 = 2.5 2.5 bbls ('. Total Cement to Pump 2.4 + 2.5 ../ = 5 bbls total 2 e P2-50B Packer Squeeze e Saueeze TarÇlet Place cement in the tubing by IA annulus to repair confirmed packer leak. LLR through the packer was 6.5 gpm at 1100 psi on 7/16/2005 (with TTP in hole) ../' MIT-T to 3000 passed on 10/14/2005 .r' IA volume to packer is 698 bbls Tubing volume to Fas Drill plug to be set at 14785'00 is 225 bbls Note: Well has TRSV. Pre-Saueeze Slickline & Fullbore 1. Shoot fluid levels on IA and tubing. 2. RU EL, pumps, and crude. Rig up to pump down tubing and take returns up IA. 3. Load tubing. 4. Pick up a special Halliburton Fas Drill Bridge Plug, 3.60" running 00, and set it at 14785' DO (in the middle of the 20' pup above DB-6 Nipple). See attached tubing tally. Use jewelry in tubing for tie in purposes. Ken Bulloch discussed this special 00 Plug with Halliburton during the month of October. Mandrels #5, #6, & #7 are suppose to be 3.62" 10. I have attached the Kinley Caliper blow up of #7. Note: Drift run to 14768' SLMD with 3.63" Gauge Ring was done on 10/21/2005. 5. MIT-T to 3000 psi to ensure Fas Drill plug is holding. 6. Punch holes in the tubing at 14740' DO (in the middle of the 40 ft joint above BKR S-3 Packer). Shoot a 1-1/16" two ft. gun with 9 punchers. The tubing is being punched rather than attempting to pull the GL V at Station #7 as the latch is broken on this valve. 7. Fluid pack IA and tubing with crude. Establish circulation rate down tubing, taking returns up IA holding 100 to 200 psi backpressure. CTU Packer Saueeze Note: This well has Cr tubing and liner. It is important that the IA is liquid packed with crude during the squeeze. Shortly before the squeeze, shoot a fluid level on the IA to see if the annulus is liquid packed. 3 e P2-50B Packer Squeeze e 8. RU CT and squeeze equipment. NOTE: Rig up surface equipment to allow returns from both the IA and the CTxTbg annulus. 9. Pump down tubing and up IA to confirm circulation through the punched holes on the tubing by opening up returns from the lA, holding 100-200 psi backpressure. Confirm 1-for-1 returns to a 40 bbl open-top tank. 10. RIH with Cement nozzle (no checks). Tag Fas Drill plug. Pick-up until full string weight is observed. Correct depth to top of Fas Drill plug (SL). PUH 10' and flag pipe. PUH & park coil at 14600 ft. 11. Batch mix 5 pumpable bbls LARC cement to meet the following specifications. (Use current BP liner blend, per Dowell Lab) Volume to Pump Cement Type Filter Cake Thickening Time Fluid Loss Target Acceptable Range Rheology ~ bbls total 5 bbls Neat LARC w/B-82, 3% BWOC .85" firm cake ± 0.15" in lab 3-5 hours at 182°F SBHT . 75 cc/30-minutes at 160°F BHCT 50 - 90 cc/30-minutes at 160°F BHCT YP>5 with no settling or gelation in fluid loss cell. · Catch a sample of the cement for QC testing. Once the blend is approved, conduct Job Scope meeting to ensure that participants know the upcoming job sequence. Line up cementers to the coil. · Ensure all gas is out of the system. Do not proceed with squeeze unless the tubinq is liquid packed and qas free. · First step will be to lay in all cement in tubing and then pull CT to safety and park. Then IA will be opened and cement will be circulated into IA as detailed in steps below. 12. RIH to flag. Line out cementers to the CT. Pump the following down the coil: · 10 bbls spacer water · 5 bbls neat LARC cement · One coil volume of spacer water · 1.5# biozan gel for cement clean-out SI in IA and take returns up the backside (tubing x CT annulus) while pumping water spacer. Switch to LARC while continuing to take returns up the backside. Maintain 100-200 psi backpressure. Pump 1 bbl LARC out the nozzle (66' of cement above nozzle) and then lay-in 1:1 while PUH (This step is to ensure that you don't dilute cement as you pull up). Strap returns in the 40 bbls tank. 4 e P2-50B Packer Squeeze e · Monitor IA pressure while laying in cement in tubing to account for cement U- tube. · Water flush volume is critical, so use the internal 1 0 bbls tanks in the pump van to gauge flush volume. SAFETY: 5 barrels of cement would extend up the tubing to 14455' DD if no cement is placed in the annulus (assuming Fas Drill plug at 14785' DD). 13. With the nozzle at safety of at least 14300', SD pumping, SI backside (tubing x CT annulus). Compare pump volume to return volume in the 40 bbl tank. 14. Open IA to returns to the 40 bbl tank. Begin pumping at minimum rate down the CT. Circulate 2.5 bbls through the tubing punched holes and up the IA. SIIA and gauge volume of returns. Monitor the IA and tubing pressures at equilibrium. NOTE: With Fas Drill plug at 14785' DD, the final cement top in the tubing and annulus should be -14630' or -110' above the tubing punched holes. 15.0pen the choke on the backside (tubing x CT annulus) and begin pumping biozan down the CT for clean out. Launch ball and begin jetting with biozan down maximum depth of 14620' MD. 16. Switch to friction reduced water. Make 3 down passes and 2 up passes at 80% from 14620' to -14200', Take barrel count to ensure 1:1 returns. Jet uphole at 80% running speed and max CT pressure, washing GLM's and TRSV thoroughly. Replace voidage trying to maintain a balanced well bore. This step is critical to the success of this job-particularlv on this job which has very little cement in the annulus. 17. Freeze protect the top 2,500' of the well bore while POOH. Continue to closelv monitor the chanaes in wellhead pressure to maintain a balanced well bore. 18. Leave tubing and JA pressures so the well bore will be balanced between the tubing and casing at the packer (approximately 300 psi in the tubing and 700 psi in the IA). 19. RDMO Post-Saueeze DHD 20. After 3 days WOC, MIT-IA to 3,000 psi. Establish LLR if MIT-IA fails. ../ 5 e P2-50B Packer Squeeze e Post-SQueeze SL 21. RU slickline unit. Tag cement top. Post-SQueeze CT Mill Cement and Fas Drill Plua 22. RU CTU and RIH with mill and motor to mill through -155' of cement and Fas Drill plug. Note: Use Halliburton guidelines for milling Fas Drill plug. 23. Drift to below perfs to ensure perfs are clear of debris. POOH at 80%. 24. Make up another BHA and underream the 7" liner to the bottom of the perforations. Note comments on well diagram concerning fish(s) in the liner. Use guidelines for milling scale at pt. Mcintyre. POH. 25. MIT-IA to 3000 psi. Contact State inspectors to witness testing. ,,/ 27. If MIT-IA passes put the well on production. Attachments: CC: Well File Andy Parker Jennifer Julian Ignatius Sorman G ANC Well Work LPC Lead Drill Site Operator LPC Drill Site Operator 6 e P2-50B Packer Squeeze e II~> TUBING SUMMARY '1", FIG POOL 7 Date 8/7/95 WELL I . / e2-50B TUBING ·.:·-ij·.5 '"'' '13Cr-80 NScr , "",,: TUBING WT. 12.6# , , 380 JTS ON RACK 362 JTS RAN 36.97 OKB TO BF 15238.18 FT ON RACK 1 451 0 FT RAN I"rEM Description includes: SIZE, TYPE CONNECTION (JTS I-I) ITEM ID OD LENGTH TOP BOTTOM WLEG 3.88 4.95 1.35 14825.28 14826.63 PUP Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 19.42 14805.86 14825.28 OB-6 Nipple wI RHC pluq ( No shear lock) 3.50 5.00 1.40 14804.46 14805.86 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.68 14794.78 14804.46 PuP Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 19.22 14775.56 14794.78 Baker S-3 Hvd Permanent Packer 3.94 5.94 3.80 14771.76 14775.56 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.68 14762.08 14771.76 1 Jt 4-1/2" 13Cr, NSCT Tbg (#1) 3.94 4.94 39.73 14722.35 14762.08 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.00 14713.35 14722.35 GLM #1 - Camco 4.5 x 1", KBG-2LS wI DV 3.65 5.80 7.20 14706.15 14713.35 PuP Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.81 14696.34 14706.15 27 Jts 4-1/2" 13Cr Tbq (#2-#28) 3.94 4.94 1076.97 13619.37 14696.34 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.01 13610.36 13619.37 GLM #2 - Cameo 4.5 x 1 ", KBG-2LS wlDV 3.65 5.80 7.20 13603.16 13610.36 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.88 13593.28 13603.16 14 Jts 4-1/2" 1 3Cr Tbq (#29-#42) 3.94 4.94 566.76 13026.52 13593.28 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.00 13017.52 13026.52 GLM #3 - Cameo 4.5 x 1 ", KBG-2LS wI OV 3.65 5.80 7.20 13010.32 13017.52 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.84 13000.48 13010.32 24 Jts 4-1é 13Cr Tbg (#43-#66) 3.94 4.94 964.94 12035.54 13000.48 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.01 12026.53 12035.54 GLM #4 - Cameo 4.5 x 1.5", MMG wI DV 3.83 7.03 8.65 12017 .88 12026.53 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.80 12008.08 12017.88 37 Jts 4-1/2" 13Cr Tbg (#67-#103) 3.94 4.94 1460.46 10547.62 12008.08 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.01 10538.61 10547.62 GLM #5 - Cameo 4.5 x 1.5", MMG wI DV 3.83 7.03 8.64 10529.97 10538.61 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.67 10520.30 10529.97 48 Jts 4-1/2"13Cr Tbq (#104-#151) 3.94 4.94 1933.70 8586.60 10520.30 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.03 8577.57 8586.60 GLM #6 - Cameo 4.5 x 1.5", MMG wI DV 3.83 7.03 8.66 8568.91 8577.57 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.36 8559.55 8568.91 89 Jts 4-1/2" 13Cr Tbq (#152-#240) 3.94 4.94 3576.09 4983.46 8559.55 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.03 4974.43 4983.46 GLM #7 Cameo 4.5 x 1.5" MMG wI RP shear 3.83 7.03 8.67 4965.76 4974.43 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.82 4955.94 4965.76 68 Jts 4-1/2" 13Cr Tbq (#241-#308) 3.94 4.94 2738.18 2217.76 4955.94 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.70 2208.06 2217.76 SSSV - Camco TRCF-4A 3.81 6.38 7.16 2200.90 2208.06 Pup Jt, 4-1/2" 13Cr, NSCT 3.94 4.94 9.67 2191.23 2200.90 54 Jts 4-1/2" 13Cr Tbq (#309-#362) 3.94 4.94 2153.53 37.70 2191.23 FMC Tubing hqr wI 13 Cr pup 3.94 10.75 2.73 34.97 37.70 Pool Rot Tbl to Tbg Hgr LOS 34.97 34.97 7 TREE = 4-1/16" FMC e SAF:eOTES: PRE- SDTRK WEL L BORE NOT SHOWN WELLHEAD = FMC P2-50Br BEL -5/S" MILLED WINDOW @ 12375'. - 4-1/2" ACTUA TOR = AXELSON CHROMETBG & 7" LNR 9-5/S" CSG SET ON EMERGENCY KB. ELEV ~ '. 51, ~~ SLIPS. LOST TWO RUBBER ELEM ENTS PULLING 3-3/S" BF. ELEV " IBP ON 02/02/00. FOUND EM PTY POCKET IN # 7 GLM ON ................... KOP= 1190' 02/14/00. 1" GL V IN WELL. DEPTHS UNKNOWN. Max Angle = 68 @ 4874' **4-1/2" CHROMETBG** Datum MD = 15383' DatumTVD= 8800'SS 1-14-1/2" CAMCO TRCF-4A, TRSV. ID = 3.812" I . 2201' 113-3/8" CSG, 68#, L-80, ID = 12.415" I 4921' 1--4 ~ GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE Minimum ID = 3.500" @ 14804' 1 4966 4015 67 MMG DMY RK 0 06/18/04 L 2 8569 5511 66 MMG DMY RK 0 07/05/01 4-1/2" CAMCO DB-6 NIPPLE 3 10530 6307 66 MMG DMY RK 0 06/18/04 4 12018 6908 66 MMG DMY RK 0 07/05/01 5- 13010 7410 40 KBG-2-LS DMY BK 0 07/05/01 6- 13603 7892 32 KBG-2-LS DMY BK 0 07/05/01 7- 14706 8826 33 KBG-2-LS DMY BK 0 07/05/01 -NOTE: MINIM UM ID = 3.65" I TOP OF TI\IV TIEBA CK SL V I 12186' I ¿ 19-5/8" X 7" TI\IV LNR HGR I 12199' 'X M 12194' H 9-5/8" X 7" TI\IV LNR PKR I III! 19-5/8" CSG, 47#, L-80, ID = 8.681" I 12375' 9-5/8" SIDETRACK WINDOW 12375' - 12455' (SECTION MILL) 14-1/2" TBG, 12.6#, 13-CR. .0152 bpf, ID = 3.958" I 14772' D< I 14772' 1-17" X 4-1/2" BKR 503 PKR, ID = 3.875" I I I 1 14804' 1-4-1/2" CAMCO DB-6 NIP, ID = 3.500" I 14-1/2" TTP, 12.6#, 13-CR. .0152 bpf, ID = 3.958" I 14825' I I 14827' 1-14-1/2" WLEG, ID = 3.88"1 I 14823' H ELMO TT LOGGED 08/20/95 I Î 14866' 1-17" MARKER JOINT (19') I ÆRFORA TION SUMMARY REF LOG: SWS CDR ON 08/06/95 ANGLE AT TOP PERF: 32 @ 14886' Note: Refer to Production DB for historical perf data PBTD1-i 15083' I SIZE SPF INTERVAL Opn/Sqz DATE r I 2-7/8" 6 14886 - 14986 0 07/12/01 ~, ~3 ~3ã 1~ I I 7" LNR, 29#, 13-CR-SO, .0371 bpf, ID = 6.184" I 15155' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT OS/15/95 ORIGINAL COM PLETION WELL: P2-50B 1 0108/01 CI-VKAK CORRECTIONS PERMfT No: "1950960 06/20/02 JM/TLH CORRECTIONS API No: 50-029-22261-02 12/03/02 ?ITP CHANGE GL V SIZE -SAFElY SEC 14, T12N, R14E495' FNL & 1256' FWL 06/18/04 PWE/KAK GL V C/O 11/06/05 RA ClTLH PULL TTP/ MIN GL V CORRECT. BP Exploration (Alaska) THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON :OR' BEFORE JANUARY 03, '2001, M PL ATE IA L E U N D W E R T H IS M ARK E R C..LORIkM~ILM.DOC 'f"b P E F-: f','i :tl T AOGC,3 Zr',d-~v'¥duai We'l i Geo'log'ical Mat:er"ials Inven'.i:or't,' DAf.,, T DA'TA F'I..US 9 B --~ 096 (: D N 9 5 .... 0 9 6 C D R 95 .... 096 ,.J EWL/'GR/CCL 95 ...... 096 F'ERF F:ECORD 9.5 .... 096 6839 ~ '1~692--15059 ~* l,q- 780-- 't 50q. 2 ~..~, ' . i23'76'~15'155 CD R/ ,'".JDN ~.F't' C,3,~,IP! ETIC, N DATE ~/~/ ,,"uTj-,/ · " 02 / 97 Da't.'e: 06/, , I:.,' IJ i"..I I:, A ']" I+ ..... f-;: I![ C V [) os/'ss/gs 'j r.) 8/' 25/' 9 5 1 09/' 05/' !ii 5 . . // 1 09 / 0 S 95 '1 09/? 5 / 95 DAZLY WELl... OPS I"e dr'-y' d"¥'t:c:h s,:.)rnples r"equ~r'ed? yes~trl~.. A'ilc~' r"eceYve(t .... as -lc. he wel'i cot"ed ?,, yes~' c~. Analys'is & descr"'ip'k'i'on r'ece'¥v,sd°., y~?~;~ W STATE OF ALASKA , ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAs [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 95-96 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6.612 5 o- 029-22261-02 4. Location of well at surface ~:i' C'C:¥~i:'~.i-'!:.'.' i:' i ~- ............... ~. 9. Unit or Lease Name 495' SNL, 1256' EWL, SEC. 14, T12N, R14E;' ~--~ "2/ ~',:; ,~ i ~ . ~ Point Mclntyre · i" ~/:~'_-L~.-_~//'~'~'/~"~ ~' :~:-~'~:"-:'~"~;~';: ~ 10. Well Number P2-50B ~ ,- ~ 11. Field and Pool At Total Depth .................. ~ -~- Point Mclntyre 536' NSL, 4702' ~L, SEC. 13, T12N, R14E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 48' ~ ADL 034624 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ~15. Water Depth, if offshore 16. No. of Completions 7/30/95 8/5/95 8/21/95~ N/A feet MSL One 17. Total Depth (MD+~D) 18. Plug Back Depth (MD+~D', 19. Directional Su~ey 120. Depth where SSSV set 121. Thickness of Permafrost 15155' MD/9209' ~D 15083' MD/9147' TVD ~ ~ ~ ~~ 2201' feet MD~ 1750' (Approx.) 22. Ty~ Electric or Other Logs Run G~RES/NEU/DEN 23. CASING, UNER ~D CEME~I~ ~ S~NG DE~ MD CASING SIZE ~. PER ~. G~ T~ ~ HO~ Sl~ C~~ RE.RD ~OU~ PULED 20" 94.5~ H-40 38' 110' 30" 246 cu fl CS II 13-3/8" 68~ N-80 37' 4929' 16" 3960 cu ~ cs 11/4~ cu fl "G' 9-5/8" 47~ NT-80S 33' 12371' 12-1/4" 937 cu fl geY690 cu fl "G" 7" 29~ NT-80S 12186' 15155' 8-1/2" 4556 cu fl Class "G" 24. Pedorations open to Production (MD+~D of Top and Bo~om and 25. ~BING RE.RD inte~al, size and number) SIZE DEP~ S~(MD) PACKER S~ Gun Diameter 3-3/8" 6 spf 4-1/2", 13CR80 14827' 14772' MD ~D (Su~) 1~86~ 14986' 8922~9007' 26. ACID, F~C~RE, CEM~ SQU~ ~C. DEPTH INTERVAL (MD) ~OU~ & KIND OF MATERIAL USED 27. PR~U~ ~ Date First Production Method of Operation (Flowing, gas lift, etc.) 8/21/95 Gas Lift Date of Test Hours Tested PRO~~ ~ OIL-BBL GAS-MCF WATER-BBL CH~S~ ~GAS~IL RATIO ~ PERIOD ~ I Flow Tubing Casing Pressure C~CU~D OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (corr) Press. 24-HOUR ~TE ~ 28. CORE DATA Bdef description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 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. Subsea Kalubik 14826' 8871' Kuparuk River 14882' 8918' 31. LIST OF A'I-rACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _,~ ~L~ Title$OniorDri/lingEngineer Date 4//¢/~''~--~ INSTRUCTIONS 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 only 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: P2-50B BOROUGH: NORTH SLOPE UNIT: POINT MCINTYRE FIELD: POINT MCINTYRE LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 07/21/95 04:00 SPUD: RELEASE: OPERATION: DRLG RIG: POOL 7 WO/C RIG: POOL 7 07/21/95 ( 1) TD: 0 PB: 0 07/22/95 ( 2) TD: 0'( 0) 07/23/95 (3) TD: 0' ( 0) 07/24/95 ( 4) TD: 0' ( 0) 07/25/95 ( 5) TD: 12284' (12284) CHANGE OUT TBG SPOOL MW: 0.0 ACCEPT RIG @ 04:00 HOURS ON 7/21/95. CHECK WELL F/PRESSURE. CHANGE OUT TBG SPOOL--APPEARS DAMAGED. RIGGED UP RAMS MW: 0.0 VIS: 0 WELLHEAD WORK. REMOVED CASING SPOOL. INSTALLED CASING SPOOL. INSTALL NEW TUBING SPOOL AND PACK OFF TEST TO 3500 PSI. NIPPLE UP ALL RAMS. RIGGED UP ALL RAMS. REPAIRED TOP DRIVE MOTOR MW: 0.0 VIS: 0 NIPPLE UP ALL RAMS. TEST WELL CONTROL EQUIP. TESTED BOPE 500 LOW 5000 PSI HIGH. HYDRILL 500 LOW AND 3000 PSI HIGH. BHA RUN NO. 1. BHA NO. 1 MADE UP. R.I.H. TO 502 FT. CBU @ 500 FT. OBTAINED CLEAN RETURNS 1.25 HOLE VOLUME. CBU @ 502 FT. OBTAINED BOTTOMS UP 100% ANNULUS VOLUME. POOH TO 20 FT. PULLED BHA. BHA LAID OUT. BHA RUN NO. 1. BHA NO. 1 MADE UP. R.I.H. TO 12284 FT. TOP DRIVE MOTOR FAILED - CHANGE OPERATION. REMOVE TOP DRIVE FROM DERRICK. RIG DOWN TOP DRIVE. REPAIRED TOP DRIVE MOTOR. RIGGED DOWN LOGGING MW: 0.0 VIS: 0 REPAIRED TOP DRIVE MOTOR. BHA RUN NO. 1. CBU @12284 FT. BREAK CIRC. POOH TO 150 FT. PULLED BHA. RIGGED UP LOGGING. RAN ELECTRIC LOGS. USIT SHOWS 40 TO 50% WEAR FROM 1750' TO 1930', 880' TO 1200' AND 530' TO 800'. COMPLETED LOGGING RUN W/GR FROM 12150 FT. TO 0 FT. RIGGED DOWN LOGGING. POOH TO 6000 FT. MW: 0.0 v~s: 0 WELL : P2-50B OPERATION: RIG : POOL 7 PAGE: 2 07/26/95 ( 6) TD:12284' ( 0) 07/27/95 ( 7) TD: 2462' ( 0) 07/28/95 (8) TD: 2478' ( 16) 07/29/95 (9) TD:12225' (9747) CBU @ 2460 FT. MW: 0.0 VIS: 0 BHA RUN NO. 2. POOH TO 212 FT. PLANNED MAINT. COMMISSIONED KELLY. M/U KELLY. BHA RUN NO. 3. RIH TO 1017 FT. TESTED CASG. RIH TO 1960 FT. TESTED CASG. POOH TO 724 FT. POOH PRESSURE TESTED @915", 820' 724' AND 631. TESTED CASG. VIA ANNULUS. POOH TO 20 FT. PULLE BHA. BHA LAID OUT. BHA RUN NO. 4. RIH TO 3480 FT. AT SETTING DEPTH 3480 FT. SET RBP @3480. PRESSURE TEST COMP. SUCCESSFULLY 500 PSI. POOH TO 20 FT. PULLED BHA. BHA LAID OUT. RUN CASING 7" O.D. RAN CASING TO 35 FT. P/U 1 JT. OF 7" CASG. SET OF SLIPS. DUMP 2500# OF SAND ON TOP OF BRIDGE PLUG. AT TOP OF HANGER 35 FT. LAID DOWN CASG. TO 35 FT. COMPLETED OPERATIONS. BHA RUN NO. 5. MADE UP BHA RUN NO. 5. RIH TO 3425 FT. RIH TAG SAND @3425'. AT TOP OF FILL 3425 FT. POOH TO 2460 FT. AT SETTING DEPTH 2460 FT. FUNCT. DOWNHOLE TOOLS AT 2462 FT. EQUIP. WORK COMP. CBU AT 2460 FT. RIGGED DW. CASG HANDL EQUIP MW: 0.0 VIS: 0 BHA RUN NO. 5. CBU AT 2460 FT. OBTAINED BOTTOMS UP (100% ANNULUS VOL.) POOH TO 20 FT. PULLED BHA. NIPPLE DOWN BOP STACK. NIPPLE UP BOP STACK. RIGGED UP FLUID SYSTEM. NIPPLE DOWN BOP STACK. RIGGED UP HANDLING EQUIP. NIPPLE UP BOP STACK. PULL CASG. 9 5/8" O.D. RIGGED UP CASG. HANDLING EQUIPMENT. LAID DOWN CASG. TO 40 FT. PERFORM INTEGRITY TEST. TEST BOP STACK. R/U CIRC. HEAD AND TEST STACK TO 250 PSI. PULL CASING. LAID DOWN CASG. TO 2460 FT. 63 JTS. LAID OUT. RIGGED DOWN CASING HANDLING EQUIP. TESTED CASING MW: 0.0 VIS: 0 PULLED CASG. BHA RUN NO. 6. BHA NO. 6 MADE UP. RIH TO 2460 FT. WORKED TOOLSTRING AT 2460 FT. COMP. OPERATIONS. CBU AT 2460 FT. OBTAINED REQ'D FLUID PROPERTIES - 150 % HOLE VOL. POOH TO 340 FT. PULLED BHA. BHA RUN NO. 7. RIH TO 2460 FT. POOH TO 30 FT. RUN CASG. WORK COMP. RAN CASG. TO 2460 FT. EQUIP. WORK COMPLETED. WORKED TOOLSTRING AT 2478 FT. COMPLETED OPERATIONS. TESTED CASG. RIGGED DOWN DRILLFLOOR MW: 0.0 VIS: 0 RUN CASG. TESTED CASG. RIGGED DOWN CASG. HANDLING EQUIP. NIPPLE DOWN BOP STACK. NIPPLE UP BOP STACK. TEST WELL CONTROL EQUIP. BHA RUN NO. 8. RIH TO 3462 FT. CBU AT 3480 FT. OBTAINED CLEAN RETURNS. 300% HOLE VOLUME. POOH TO 0 FT. BHA RUN NO. 9. P/U MWD AND SURFACE TEST W/KELLY. NO TEST, C/O MWD AND RETEST - OK. TOP DRIVE FAILED. REPAIR. RIGGED DOWN DRILLFLOOR/DERRICK. L/D KELLY. WORK COMP. WELL : P2-50B OPERATION: RIG : POOL 7 PAGE: 3 07/30/95 (10) TD:12284' ( 59) 07/31/95 (11) TD:12666' ( 382) 08/01/95 (12) TD: 12939' ( 273) 08/02/95 (13) TD: 13765' ( 826) RIGGED UP TOP DRIVE MW: 0.0 VIS: 0 REPAIRED DRILLFLOOR/DERRICK. L/D KELLY. EQUIP. WORK COMP. BHA RUN NO. 9. P/U BHA. BHA NO. 9 MADE UP. RIH TO 12250 FT. ON BOTTOM. EVAC. DRILL. REPAIR. RIGGED UP TOP DRIVE. DRILLED TO 12666 FT. MW: 0.0 VIS: 0 BHA RUN NO. 9. DRILLED CEMENT TO 12376 FT. CBU AT 12376 FT. HOLE SWEPT W/SLUG 150% HOLE VOLUME. CBU AT 12376 FT. HOLE DISPLACED 100% DISPLACED. 48 JTS. P/U. DRILLED TO 12388 FT. CBU AT 12388 FT. OBTAINED CLEAN RETURNS 175% HOLE VOLUME. DRILLED TO 12400 FT. CBU AT 12400 FT. DRILLED TO 12666 FT. DRILLED TO 12939 MW: 0.0 VIS: 0 BHA RUN NO. 9. DRILLED TO 12852 FT. CBU AT 12852 FT. OBTAINED CLEAN RETURNS 180% HOLE VOLUME. POOH TO 11900 FT. BHA RUN NO. 9. POOH TO 258 FT. PULLED BHA. BHA RUN NO. 10. BHA NO. 10 MADE UP. RIH TO 8500 FT. SINGLED IN DRILL PIPE TO 9690 FT. 39 JTS. P/U. BHA RUN NO. 10. RIH TO 12852 FT. DRILLED TO 12939 FT. CBU @ 13765 FT. MW: 0.0 VIS: 0 BHA RUN NO. 10. DRILLED TO 13765 FT. CBU AT 13765 FT. 08/03/95 (14) TD:14288' ( 523) 08/04/95 (15) TD:14775' ( 487) 08/05/95 (16) TD:14775' ( 0) PULL BHA MW: 0.0 VIS: 0 CBU @ 13765. OBTAINED 175% HOLE VOL. POOH 10 STNDS. HOLE IN GOOD SHAPE. RIH T/13765. DRILL T/14288. TRQ. CHANGED -- BIT QUIT. CBU. OBT. 150% HOLE VOL. POOH T/258 & PULL BHA. CBU MW: 0.0 VIS: 0 PULL BHA CHANGE BIT. SERVICE THE BOP STACK. RIH T/l1500. SERVICE THE BLOCK LINE. RIH T/14288. HIT BRIDGE @ 14024. REAM 90' T/BTTM. DRILL T/14775. CBU. LOGGED HOLE W/LWD MW: 0.0 VIS: 0 BHA RUN NO. 11. CBU AT 14775 FT. OBTAINED CLEAN RETURNS 180% HOLE VOLUME. POOH TO 258 FT. PULLED BHA. BHA STOOD BACK. TESTED WELL CONTROL. TEST BOPE, TEST ALL CHOKE MANIFOLD VALVES, HCR & MANUAL VALVES, FLOOR VALVES, TOP DRIVE VALVES AND RAMS TO 250/5000 PSI. TEST HYDRIL TO 250/2500 PSI. TEST KOOMEY. WITNESSING OF TEST WAIVED BY THE STATE MAN, DOUG AMOS. PRESSURE TEST COMPLETED SUCCESSFULLY - 5000 PSI. BHA RUN NO. 12. RIH TO 14310 FT. REAMED TO 14625 FT. REAM TIGHT HOLE F/14310 TO 14500'. PRECAUTIONARY REAM TO 14625'. LOGGED HOLE WITH LWD. WELL : P2-50B OPERATION: RIG : POOL 7 PAGE: 4 08/06/95 (17) TD:15155' ( 380) 08/07/95 (18) TD:15155' ( 0) 08/08/95 (19) TD:15155' ( 0) 08/09/95 (20) TD:15155' ( 0) 08/10/95 (21) TD:15155' ( 0) 08/11/95 (22) TD: 0 PB: 0 08/12/95 (23) TD:15083' ( 0) PLANNED MAINT. MW: 0.0 VIS: 0 BHA RUN NO. 12. LOGGED HOLE W/LWD. ON BOTTOM. DRILLED TO 15155 FT. REACHED PLANNED END OF RUN. CBU AT 15155 FT. OBTAINED CLEAN RETURNS 180% HOLE VOLUME. POOH TO 12350 FT. PLANNED MAINT. EQUIP. WORK COMPLETED. REAMED TO 14850 FT. MW: 0.0 VIS: 0 REPAIR. BHA RUN NO. 12. RIH TO 14325 FT. REAMED TO 15155 FT. ON BOTTOM. CBU AT 15155 FT. HOLE SWEPT W/SLUG 300 % HOLE VOLUME. POOH TO 250 FT. WASH AND BACKREAM TO 14860, PULL TIGHT TO 14350'. PULL TO 13431' PUMP DRY JOB, POOH. PULLED BHA. BHA STOOD BACK. BHA RUN NO. 13. BHA RUN NO. 13 MADE UP. RIH TO 10000 FT. PLANNED MAINT. RIH TO 14308 FT. REAMED TO 14850 FT. POOH TO 14400 FT. MW: 0.0 VIS: 0 BHA RUN NO. 13. REAMED TO 15155 FT. REAM TO BOTTOM. CBU AT 15155 FT. OBTAINED CLEAN RETURNS - 180% HOLE VOLUME. CBU CLOSED IN WELL AT 15155 FT. BHA RUN NO. 13. POOH TO 13730 FT. SHORT TRIP 15 STDS. RIH TO 15155 FT. ON BOTTOM. CBU AT 15155 FT. OBTAINED CLEAN RETURNS - 180% HOLE VOLUME. POOH TO 14400 FT. RUNNING CASG MW: 0.0 VIS: 0 POOH T/13700. RIH T/14400. REAMED T/15155. CBU. WT UP T/10.6 PPG. OBTAINED 250% HOLE VOL. POOH T/700. MONITOR WELL. LD BHA. RU & RUN CASG T/640'. LD DP MW: 0.0 VIS: 0 RAN CASG T/2969. RAN DP T/12300. CBU. OBTAINED 100% ANNULUS VOL. MIX & PUMP 317 BBLS SLURRY. BUMP W/3000PSI. PRESS UP T/4500 T/SET LINER HANGER & PACKER. CBU OBTAINED 125% HOLE VOL. LD DP T/11286. DISPLACE TO SEAH20 MW: 0.0 PULL DP TEST WELL CONTROL EQUIP. T/5000. SET WEAR BUSHING. MU BHA #14. RIH T/15083. CBU. OBTAINED 100% ANNULUS VOL. TEST CASG T/3500. CBU. & DISPLACE T/SEAH20. CBU MW: 0.0 VIS: 0 CBU. DISPLACE HOLE W/SEAWATER 100%. PUMP OUT OF HOLE T/12191 -- LINER TOP. CBU. WELL : P2-50B OPERATION: RIG : POOL 7 PAGE: 5 08/13/95 (24) TD:15083' ( 0) 08/14/95 (25) TD: 0 PB: 0 RUNNING TBG MW: 0.0 VIS: 0 CBU. HOLE IS 120% DISPLACED W/SEAWATER. RIH T/15083. CBU OBTAINED 200% HOLE VOL. POOH T/2900 LD BHA. REMOVE WEAR VUSHING. & RUN 4-1/2 COMPLETION TBG T/7000. ND BOPE MW: 0.0 RAN TBG T/14826. CBU. 100% DISPALCED. ND BOP STACK. 08/15/95 (26) TD: 0 PB: 0 08/16/95 (27) TD: 0 PB: 0 RIH W/WL UNIT MW: 0.0 RD RAMS. INSTALL TREE. TEST TREE & VALVES T/5000. FREEZE PROTECT THE WELL W/340 BBLS OF DIESEL. DROP BALL T//SET PKR.--BALL DIDN'T SEAT. RU HLS WL UNIT T/CHASE THE BALL T/BTTM. RIG RELEASED MW: 0.0 RIH CHASE BALL & ROD T/BTTM. PRESS T/200. VERIFY SETTING. POOH. RU SL UNIT. TEST PACKER T/4300/30 MIN. TEST PACKER & ANNULUS T/3500/30 MIN. BLEED PRESS OFF TBG, SHEAR OUT RP AND RP SHEAR VALVE IN TOP MANDREL. INSTALL BPV. RELEASE RIG @ 16:00 HOURS. SIGNATURE: (drilling superintendent) DATE: tGINAL" i ~D6,Sb~.."- 0 £NTERVAL D~'TH. DE?TH ~* ft : % !£2'.::J~',.:'._': '-~f'~' ....... :. "-25-52,C,,:; 172,0 712'?-',0-'.'; 1259:?,02 47,0 12-55-4,?( 55,? 7180.51 !2675. i? 40,3 7202,45 ........-..:. ,.~.:.~.pv taLC; ![ A'fTr~?;S __,.~, t.,. ,.- .... *****:**~*~**. CIRCULAR ARC METHOD**~* TARGET ¢i'~T?~ AZIMUTH SECTION iNCLN, fr deo de~ ft f~,hO '~=:.,AP '.",-"', "',~ -~-':.'hl .,,:.I .-. ~-~- ,_'_-'. -_ ,_- :' £Oe 'J.~ :: ,~.~ ,---~ 3, ---:.~ /:.i ,65 ~'.Wn qA -,~~A'.::' ~ A9 -, ." ...~ _.~.u. ~...~ 6,70 60,22 i,~ o: _~n.--,c, .~ ~,-;-"' ,.-'u ->'-,.'--' .,' , /L_: ft ft 7548,86 9000.61 7679,78 9!54,~8 7715,77 9i95.66 //20,~.~ .~. 7788,7! 9276,95 AZIMUTH 122,9~ i22,% ~22,93 ~L: ~:/ !OOft 8,09 ~^ ~ 72A~,2! J~ . -- 42<3 7256,50 7,40 12%0,I: 13025,9! 12125.72 13167,79 42,7 7388~36 45,8 7423,27 -- ~ v~a~45 4!.! .7534,73 · ~o.:o 94~1~ =,n~ 38,.03 n.-, .r. =~,= ,,,.. 7993,77 7483,0~ !22,55 ~085,17 o=",40.,~ez !22,2.5 81i0,5~ 9580,72 122,i~ 7.E! 7,77 6,43 ~/'~ .7,9.7 i32!i~2¢ 13265,01 i3359,3g 43~4 7559,78 51,3 7656,90 43,1 7AgP,?A '=" ~ ~' '73,40 -5093,77 ,8~,30 oo ~ i= ~. -5083,!7 209,4? 34,48 58,53 -5G5.9,66 '?g?.~g 35,'?~ 47,46 -5036,0! 5!35,17 9578,31 122,05 ....... oA~A~7i l'P~ ~lO~,~o ,. ......... RI~A-AA C~q!,~ u~u:~3~ 9A.41~R~ izi,:.43 ~.~,.-, ..... ~m t~_, 6,46 7,-'..',4 i3453~60 13549,84 ~3~07~97 13643,38 55,7 78i4~53 4rj~6 C5 ~ '7Q07 35,4 7'727~i9 .... ~ : 497~ 33'?~37 '~'~-^~ ~,41 -~.,-.,~._,..: -' !40!5',a; ,.'i. 7'~. 0,;53 2, i? ;. ff £ z:.., ~ .._._. '.ffL~ l l ~?0-.4', 2S £-,ff'j-2', 71 14495,79 92,6 n,~ ,', '~ t2 .-~ "t ....~: nm:Z,'-_, iq · / ,..,'? .: ~.. -: :.: z. 74,7 ,3.57'3,17 ?3, ! 8652,2? !,09 !,17 14591,'?2 !4876,63 97,0 6892,2! 93 2 ~o?, ~.-, 1,34 0,22 SUF. S~S¥ P~O.-"-B'S?3, TO ?-"D SURVEY ~i4LYS!S ***~****** CIRCULAR ARC MH?HOD~****~** F'2-50B 12380,0 7052,70 0,00 -~, ,0~ *~='~=" 7129,00 ~'~.-.:.~.., 7i51,84 -i,42 ?URN 0,00 0~00 0~00 0,00 0,00 ~,,o -~,V3 - -- -?,, .... -$.Tn 0,48 oo -3,87 u,=~ .... CL£~URE ?OOL_?ACE DLS DLSR? ¢* deq r:~''~'~<~~_~/~v,~ ~eo/iOOfv~2 _oa,',r, =- 0,0o 0,00 -9243~32 173,77 3,'P'3 .~ ,o i757,5 7256,50 -~032 -i3,07 -3,i3 -2~3 12839,7 79A9 ....... - '~ -A qA ,~ ~c. -~,o~ -i6,~} -i.~ ,o==o c 72IA.q~ -3,05 -iY,~.~ ...... ~ ........ '- :: -/,v~ -!,23 -7,80 -6,23 -2,35 -2,88 -7,28 122,d.3 ~,~ ~? 4,0! 164,37 A.,~; !.38 ~.~ /,40 1,8.3 _~..~'~,', .... ~? 6,74 !,21 13025,9 ..... ~' ~ _. t3072,? 7460,02 -i.i? !3i87,8 7534,?S -i,75 -24,22 -5,60 -3,15 -2~.A2 -26,46 -4,38 -4,28 -27,I0 -27,08 1,09_. -6 ,~,,,o -40,04 .. -- ~ 7~ -7~37 -9.34 -?,47 -I~ ~O -1!,12 -9508,,.~°~ i30,55 7~77 0,57 -9534,0! 114,77 6,43 2,84 -~560~20 ~4~42 ?.,70 2,40 13211.2 13265,0 7614,46 -0,60 ...... ~ ..... "~ 0,63 ~OO~7+q 7A~P.OA -31,03 -5,08 -5,i2 -49..64 -3!,83 - i ,,~',, -7,9~. . , -ET. 77_: ,,, -3!,20 I,,-. '=:, -a ,'?~_ -64,7! m,-, ~,q ~ ~ -L .t~ 7~ 7Q -11,79 -!4,75 -!3,52 -i1,'?0 -'~596,48 12S~4.5 6,56 !,35 -';%1 ~ .... ' .... £1 -:n ...... ~.:: i,33,4':. ~., +.:. ~,,-'~ _-':L".:~ 5'2- g."- -r.,= '" = .... - ..... .: ~,'..:7,69 1,4-, -96.37~$6 74,:.'.6 6,46 5',66 _,:--:.7: o: "':"~ '::' Y:O4 1,0'? ..-.~/ ..- ;: , :~._..'-:., :Oq...,O,,5 _F; .-, _~,"; ,, c-:,,,::'..' :, ...... ..,,06 -0,?3 -,6,82 -82,::,0 , ,..,.,. ,DS -: ~? --_,1 -3,04 1354'.'-"',8 7846,26 .,', c--', ,-.. -v,:: -,:,:, 9'?-' -u.:4 -0,71 :'~-'"',A :", 78'.~7,10 -!,/~': -2q. 7:":,~,..., .- _c...,,~::.;j 13643,4 ......... ' -'~' '~ .......... _o~ " -i6,76 -9,93 -i,74 -7,81 4,62 -'¢A54.36 ..... !25',50 6,42 ..,~,~.~r ,,_:..~,vv z17,.,~ ~, :. 12+~F:-.. -7651~47 !2.6,72 5,16 6,97 13830,1 -~ 99 1,04 1 d''~2 D .... '~ '""" i4307,2 84'.'?'--:,62 -0,'70 ,,-n~,? ...... 0,79 --:4v,: ~5.." ._'. ~ i,' 14497.0 &65..2,';c''~, 0,97 -32,:0 :,30 -0,?8 -92,60 -32,68 -0,63 i,51 ~.~. ~m -- ~; .-_~. ...... -~. A~ 0 ! ,63 -1,40 '.j -2,?'.:.' -~A~4,gS .... ,~6 ;-;:~ O,q~ .- ...... ~C ~,-~: ~., -964!,45 156,A9 F~.,?(: ..... -': ~'"': ~: ..... :,6F ' "=" ..... 14666,4 6810,68 -0,23 14783,4 -, 14676,6 A~7i,~9 -,t..---, _-:o~=,.,~,..~~,~,' ''= 0,62 -32,26 -0,24 ' 1,56 -92,47 .~ ,~ ~7 ~.77 _~ 7~ -34,i! -0,66 !,~5 -34,09 0,02 -O,3S -90~23 0,65 -0,42 MD ~7~ 1~2 ~H: "i:~:~ ~' p~?~ _ ~"~^:~ ~n ~tl .........CLOSUF~ TOOL FACE DL$ D~Fg f: ;~ ~e~ deq '-~*~ deq d~ dee/!~f~ f~ deo deg/lOOf~ dee/!OOf~**2 · .. . ~g~ ~VV, . . ' -~ .- - ' 173,10 0,28 0.06 v,~ ~,,.~ 0,02 0,29 15155,0,~,~a ar 0.00 -34+36 0,00 0,00 -~0,17 "^n -7629~3! "'~ A~ 9/22/95 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9749 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 (~ ~/~ Field: Greater Point Mclntyre Area ...././~ . ~' [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27)] ~ "") Floppy Well Job # Log Description Date BL RF Sepia Disk P2-50B CDR 950806 1 1 P2-50B CDN 950806 I 1 P2-50B 95301 CD~CDN 950806 1 , S I G N E D' DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED Oil & Gas COns. Anchorage ~ission 915195 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'I'TN: Sherrie NO. 9695 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27)] SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Date: Subject: From: .~, ARCO Alaska Inc. G~_..ter Point McIntyre Engineering September 1, 1995 Transmittal Number ARCO Alaska, Inc. 753 To: Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 The following and your cooperation in maintaining confidentiality is appreciated: Well Name Data Description Run # O. 31" LPC-02 Perforation Record Safe System ~,- ,8,4 SPF 1 . ~ p2-34 Cement Bond Log, CBT- GR 1 P2-34 Ultra Sonic Imager Cement & Corrosion I ,~' P2-50b Greater Point McIntyre Area data are enclosed. This information is confidential Date Run 4/9/95 7/28/95 7/28/95 Company Schlumberger Ultrasonic Imager Corrosion Log Schlumberger Schlumberger 1 7/24/95 Schlumberger P2-28 Ultra Sonic Imager Cement & Corrosion 1 7/13/95 Schlumberger p2-28 Cement Bond Log, CBT- GR I 7/13/95 Schlumberger O. 3/ - x~- P2-28 Perforating Record, ~,- ~8,6 spf, 4HJII 1 7/14/95 Schlumberger .~ignT!9_..n_..e~~ .~ilar~d~:.rgtttrn?t6f"i: G En~ Aide, ATO-462 " ~CO ~aska, ~c. P.O. Box 100360 ~ch~~~~ 9510-0360 02 1995 ~ ~ '.~ ~,:. - . ~:.¥, ' ...... ,,: ~ ;~ Transmittal Number: 753 Page: 1 I,ASKA OIL AND GAS 'CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 19, 1995 Adrian Clark, Drlg. Engineer Supvr. ARCO Alaska Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc P2-50B Revised ARCO Alaska Inc 95-96 495'SNL, 1256'EWL, Sec. 14, T12N, R14E, UM 4759'SNL, 4659'EWL, Sec 13, T12N, R14E, UM Dear Mr Clark: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated June 19, 1995, are in effect for this revision. Yo Chairman ~ BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl BP EXPLOFLA~ION Memorandum To: Alaska Oil & Gas Conservation Commission Date: July 10, 1995 From: Terrie Hubble Technical Assistant Subject: Permit to Drill, P2-50B (Permit #95-96) The Permit to Drill for P2-50B was submitted with several errors. Type of work (la.) should have been 'Redrill'. (4.) incorrect East/West locations (EWL vs. WEL), and' consequently (12.) Distance to nearest property line was incorrect. I then asked the Drilling Engineer to review these changes and he determined that the BHL was incorrect on the original Redrill Plan Summary (+/- 25'). Attached is a corrected Permit To Drill. Please accept my apologies for these errors. Sincerely, Terrie L. Hubble JUL i 4 !995 0ii & Gas Cons. Commission STATE OF ALASKA ~ REVISION - 07/10/95 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill E'lllb. Type of well..Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and P0ol ARCO Alaska, Inc. KBE = 48 fe et Point Mclntyre 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034624 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 495' SNL, 1256' EWL, SEC 14, T12N, R14E Point Mclntyre At top of productive interval 8. Well number Number 4884' SNL, 4578' EWL, SEC 13, T12N, R14E P2-50B U-630610 At total depth 9. Approximate spud date Amount 4759'SNL, 4659' EWL, SEC 13, T12N, R14E 07/20/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD andTVD) property line ADL 034627 621 feet No CloseApproach feet 2560 15038'MD/9116'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 12,387 MD feet Maximum hole angle 8~ o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD -I-VD MD TVD (include stage data) 8-1/2" 7" 29# 13CR80 NSCC 1681' 12230' 6983' 15038' 9168' 500 sx Class 'G' RECeiVED JUL 4 1995 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~r~ ~,,, ~ ....... .,. ,~,,,,,,,,,,~,, .... Anch0r~'" Present well condition summary Total depth: measured 14600 feet Plugs (measured) Cement Plugs 13050'- 12720', true vertical 8247 feet 12493'- 12225' Bridge Plug Effective depth: measured 12225 feet Junk (measured) true vertical 6986 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 65' 20" 245 Cu Ft CS II 55' 55' S u rfac e 4884' 13-3/8" 3960 cu Et CS//& 4921' 4000' Intermediate 460 Cu Ft Class 'G' Pro d u ct i o n 15299' 9-5/8" 937 Cu Ft Gel 'G' & 15336' 8 799' Lin e r 690 Cu Ft Class 'G' Perforation depth: measured None true vertical None 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[Z] 20 AAC 25.050 requirements[] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed -~.--~¢~.-~ ~ .... Title Drilling ~6er Date '?/~/~.~ · Commission Use Only Permit Number APl number Approval date See cover letter 95-96 50-029.22261.02 06-29-95 for other requirements Conditions of approval Samples required [] Yes ii, No Mud log required []Yes ~ No Hydrogen sulfide measures ,El Yes [] No Directional survey required [] Yes [] No Required working pressure for DOPE [] 2M; 1-13M; '~]5M; 1-110M; I-I15M; Other: Original Signed By by order of ..-? / / Approved by David W. Johnston Commissioner me commission Date Form 10-401 Rev. 12-1-85 Submit in tripl I Well Name: I P2-50B . Redrill plan Summary Type of Redrill (producer or injector): [ Producer Surface Location: 495 FNL, 1256, FWL, S14, T12N, R14E Target Location: 4884 FNL, 4578 FWL, S13, T12N, R.14E UM Bottom Hole Location: 4759 FNL, 4659 FWL, S13 T12N, R14E, UM I AFENumber: 12C0080 I I Rig: I Pool7 I I Estimated Start Date: 17/17/95 Operating days to complete: ] 14 I IMD: I 15038 I I TVD: 19116'rkb I IKBE: 148' I I Well Design (conventional, slimhole, etc.): i conventiona1 .......... [ Objective: ] The objective of this sidetrack is to relocate the bottomhole location to Kupamk I reservoir north-west of the current dry hole location. Mud Program: A 9.5 - 10.00 ppg Biozan polymer/KC1 water based mud will be used. ISpecial design considerations none Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 9.5 10 20 5 10 5 0 5 to to to to to to to to to TD' 10.0 18 30 15 30 6 0 10 Directional'. IKOP: I 12,387MD [ Maximum Hole Angle:, I 65°(sidetrack portion) Close Approach Well: NONE The above listed wells will be secured during the close approach. Redrill Plan Summary JUL 1 4 1995 Gas Cons. CommissioP, ALASKA OIL AND GAS CONSERVATION COMMISSION / TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 29, 1995 Adrian Clark, Drlg Engineer Supvr ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Point McIntyre P2-50B ARCO Alaska, Inc. Permit No. 95-96 Sur. Loc. 495'SNL, 1256'WEL, Sec. 14, T12N, R14E, UM Btmnhole Loc. 4785'SNL, 4641'WEL, Sec. 13, T12N, R14E, UM Dear Mr. Clark:~ Enclosed is the approved application for permit to redrill the above referenced well.' · The permit to redrill 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at _ Chairma~ - BY ORDER OF TH~ COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill FIIlb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 48 feet Point Mclntyre 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034624 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 495' SNL, 1256' WEL, SEC 14, T12N, R14E Point Mclntyre At top of productive interval !8. Well number Number 4884' SNL, 4578' WEL, SEC 13, T12N, R14E P2-50B U-630610 At total depth 9. Approximate spud date Amount 4785' SNL, 4641' WEL, SEC 13, T12N, R14E 07/20/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL034627 4641 feet NoCIoseApproach feet '2560 15038'MD/9116'TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ¢2,38z MD feet Maximum hole angle 85 o Maximum surface 3330 psig At total depth (TVD) 8~00'/4390 psig 18. Casing program Specifications Setting Depth raze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# 13CR80 NSCC 1681' 12230' 6983' 15038' 9168' 500 sx C/ass 'G' P, ECE IVLLJ JtJiXl 2 ,'5 19. To be completed for Redrill, Re-entry, and Deepen Operations. t:~;~s~(a U~l & Gas 60ns. 6ommissi Present well condition summary Total depth: measured 14600 feet Plugs (measured) Cement Plugs 13050'- 7z/zu, true vertical 8247 feet 12493'- 12225' Bridge Plug Effective depth: measured 12225 feet Junk (measured) true vertical 6986 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 65' 20" 245 Cu Ft CS II 55' 55' Surface 4884' 13-3/8" 396o Cu Ft CS//& 4921' 4000' Intermediate 460 Cu Ft C/ass 'G' Pro d u ct io n 15299' 9-5/8" 937 cu Ft Gel 'G' & 15336' 8799' Liner 690 Cu Ft Class 'G' Perforation depth: measured None true vertical None 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid progr.~ [] Time vs de!~th pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] Signed¢~ (,~~' Title Drillin~l En~lineering Supervisor Date ~/2-.-2_./~ Commission Use Only / Permit Number IAPI number /Approval date ISee cover letter ~('_ ¢~ 15o.o.z_?- ~...,Z..2,~/-'o 2.-{ (~., ~ q, ¢~,~," Ifor other requirements Conditions'of approval Samples required [] Yes .J~ No Mud Icg required []Yes ~ No Hydrogen sulfide measures I~ Yes [] No Directional survey required ~ Yes [] No Other:Required working pressure fO~urlglnalBOPE blgrleO'"J-12M; [~VEI3M;., ~SM; [-IIOM; []15M; / by order of Approved by David W. Johnston Commissioner me commission DateO,//~, r/¢ Form 10-401 Rev. 12-1-85 Submit )licate I Well Name: I P2-50B Redrill Plan Summary Type of Redrill (producer or injector): I Producer Surface Location: 495 FNL, 1256, FWL, S14, T12N, R14E Target Location: 4884 FNL, 4578 FWL, S13, T12N, R14E UM Bottom Hole Location: 4785 FNL, 4641 FWL, S13 T12N, R14E, UM ]AFENumber: 1 2C0080 I I Estimated Start Date: I~m: I ~5038 I 17/20/95 ling: I Pool 7 I Operating days to complete: 114 ITVD: 19~6'rkb I IKBE: 15~.7' Well Design (conventional, sHmhole, etc.): I conventional IObjective: I The objective of this sidetrack is to relocate the bottomhole location to Kupamk I reservoir north-west of the current dry hole location. Mud Program: A 9.5 - 10.00 ppg Biozan polymer/KC1 water based mud will be used. Special design I considerations none Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 9.5 10 20 5 10 5 0 5 to to to to to to to to to TD' 10.0 18 30 15 30 6 0 10 Directional: IKOP: 112,387MD I Maximum Hole Angle:, 65°(sidetrack portion) Close Approach Well: NONE The above listed wells will be secured during the close approach. Redrill Plan Summary Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MDfrVD MD/TVD 8.5" 7" 29# 13CR80 NSCC 1681 12,230/6983 15,038/9168 Tubing 4.5" 12.6 13CR80 NSCT 14660 40/40 14,700/8881 Cement Calculations: ]Liner Size: ] ] Basis:] 50~o open hole ex~ess, 80' shoe joint, 150' liner lap and 150' excess above linei' with DP. Total Cement Volume: 500 sxs of Class G Blend @ 1.17 ft3/sx Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Redrill Plan Summary P2-50B INFORMATION Objective Currently, the P2-50 bottom hole location is just outside of the reservoir boundary. Sidetracking to the proposed location will utilize the existing intermediate casing to reach a bottom hole location capable of producing up to 10,000 BOPD. The well is currently suspended without production tubing. The existing window cut in the 9-5/8" casing will be utilized for the sidetrack. The well will be kicked-off and drilled to TD after changing the well over to drilling mud. LWD information will be sufficient in the well so no open hole logs will be run. The well will be completed with 7" production liner and 4-1/2" 13-Cr tubing with five GLMs. Scope (Capital Sidetrack) 1) Remove bridge plug from well at 600' MD. 2) Displace well to milling fluid. 3) Run casing inspection Icg and gyro. 4) Kick off from existing window at 12,375 and drill to TD at 15,039'. 5) Obtain LWD logs GR-Res-Den-Neut. 6) Cement 7" liner in place. 7) Run 4 1/2" chrome tubing. Timing' Pool 7 will be making a well to well move from well P2-28 to P2-50B on or about July7, 1995. This sidetrack is expected to take 13 days to complete. Gas Cons. Commission Redrill Plan Summary Page 3 1-6, , , , 10. 11. 12. 13. 14. 15. 16. 17. RECEIVED P2-50B SUMMARY PROCEDURE: P2-50A Abandonment portion. N 2 ,'5 1995 Gas Cons. Commission RIH with 8-1/2" steerable drilling assembly and dress off cement to 5' below the top of section. Kickoff well and directionally drill to align well with target. Drill with a 8-1/2" directional assembly to total depth of 15,039' MD/9168' TVDss or 125' MD below the OWC. LWD with GR-Res-Den-Neut from 150' above the Kuparuk to TD. GR from West Sak to Kuparuk. Multi-Shot survey w/Sperry-Sun ESS on final trip out of the hole for AOGCC survey requirements. Run 7" 29# 13CR80 NSCC standard liner assembly to TD with liner top packer and +/- 150' lap. Crossover to 7" 29# L80 liner +/- 300' md above top of Kuparuk @ 14,812' MD/8976' tvd. Liner top packer and hanger assembly are to be plain 4140 grade carbon steel. Cement liner calculating cement volume at ~)% open hole excess, 80' shoe joint, 150' liner lap and 150' excess above liner with DP (Approximately 413 sacks) Clean out liner to PBTD and test to 3500 psi. Change over to clean inhibited seawater. Test to 3500 psi for 30 minutes. RIH with 4-1/2" 12.6# 13CRL80 NSCT completion string w/7" packer positioned +/- 100' md above top of Kuparuk. M/U tubing hanger- test SSSV lines to 5000 psi for 10 mins. Orient SSSV balance line as indicated in well plan attachment, Land tubing hanger and RILDS. Test tubing hanger packoff to 5000 psi. Back out & L/D the landing joint. Set blanking plug. N/D BOPE. N/U tubing head adaptor and 4" tree. Test control lines to 5000 psi. Test 4" tree and adaptor to 5000 psi. Pull the test plug with a lubricator. Pressure up on the 4-1/2" 12.6# 13CR80 tubing to 4000 psi to set the production packer. Maintain tubing pressure at 4000 psi for 30 minutes after setting packer and record as the tubing test. Bleed off 4-1/2" tubing pressure to +/- 1500 psi. Pressure test tubing x 9-5/8" annulus to 3500 psi for 30 minutes. Record the test on a Barton chart. Bleed off the annular pressure prior to bleeding off the tubing pressure. Bleed off the tubing pressure. Pressure up to 2900 psi on the annulus to shear out the RP valve in the top GLM position. Displace the tubing w/enough diesel to freeze protect the annulus to 2000' tvd. Allow the diesel to U-tube to the tubing. If possible have the well freeze protected by gas by Drill Site Maintenance in the EOA. Redrill Plan Summary ~ALE ~0 IL / DP/IS[ON TYD [{EF: VERTICAL SECTION P~F: WELLHgAD BPX-Shared Alaska State Plane: Pt Mac : PM2 P2-50B P2-50b Wp8 Services Drilling Zone4 51 L5 ~ l~687 ~ 46.7~ ~ 1~787 HD 4a.~7' ~ 1~807 MD 35,57' ~ [3007 HD 33.00' E 13167 HD 31,~6' Q [3867 ~D 30.50' e L3387 ~0 3D.Bt' ~ 13487 M~ 31.48' ~ 13547 H~ E~D DF CURVE 344 65,P_B' I~ IE135 HO IZest 65,55' E [E387 MD KOP / TIE IN / iNTERPOLaTED PDTNT / START BF CUR~ ~ 6,00'/100 Ft CRIT[C~ PGIN~ D~TA RD Iht flz;, B. P~rm=¢~st T8OE L4,LT' L~L,~' UE4A (K-tS) ~Ot G6.Bt' iE4,Ta' We;t S~k t~136 65.~B' tE3,43' [o= / TKC l~ / ~387 65.53' t~3,~' DF C~VE ~ S,OO'/LO0 FI ~D OF ~E &~47 3L.4g' ~.75' ~ (K-LO) ~43E0 3~.49' H~ L4701 3L .49' 1787 96 S 147 G95~ 4700 g 73G4 7036 49(~ S 7334 889L 4438 S 9573 897G 4399 ~ I OD HD [~ c ~ i TYD ~qr~el N~m~ TYD NS ~!~ Grid X Potyoon t 6976 4396 $ 843~ E 6~0(X50 5!~JrJ~DO Polygon ~ 6976 4398 S 04:3~ E &gOIPSD ¥~3900 ~81 E ~97G 4389 S 86~ ~ G9~15 ~3914/ / HORIZONTAL ~ (TRUg NORTH) SCALE ~§O rt./ O~SlO~ HALL I BURTON 6/1419S tO,~7 ~m 7 In 01], I~ 9L68 TVB 4 748 31.48' E L43~0 HD C!43 (K-tO) 9'~7 lOO5 lose ILE3 3L.40' e 1470t MI) tt~Z 31.48' (~ 14813 140 %~r~et ;~ ! Kupmruk 3L.48' l! 14913 MD 7 In OD, ~ 15038 HO, ~iG8 TVg .48' ~ 15036 MD I -L='50 0 PSD SDe 730 tO00 IP-50 LSO0 YER~ICAL SECTfON PLANE: 33.00 791) 0 7E50 75D0 77:50 BO00 8;~50 eSOD I I I 8750 9000 9E50 9500 PROPO$~D ~HI, D~'be Pto:c:ceN , 6/t4/95 · _ WeD Plan FeaslbtllLT ~ ~t an ~.pp~oved Thiand~- trna not ~ BPX-Shared Services Drilling Alaska State Plane' Zone& Pt Mac' PM2 P2-§OB P2-50b Wp8 H~LLIBURTg~ 6/L4/95 10~13 a~ 5500 5750 6000 6a50 6500 6750 7000 7250 7500 7750 8000 3508 --~750 ---4000 -4;~50 --4500 ~.750 I I I I 8a50 8500 8750 9000 ~000 --6250 CRITICAL PB[N7 ORCA 95 $ 147 E a~18 $ 400P E | I~ IRc Azm. ~t/3 9. Perm:xR'-ost: I$OE 14,17'.-I.~t.91t' 1707 UG4R (K-t3) 770L 6S.2t' t;4,7~' :15~ gest S=~ IEI3G G5,28" 123,43' 695~ KO~ / T(E IX / 1~387 S3.53"123,t&' 7056 [NTERP~_AIE~ POfNT / ~T~qr 6.oe'/[oe ft END DF OdR.VE 13547 31.40" ~.7~" 7896 ~3 LK-LO) lq3~O 3t,48' 3~.73' ~6 ~Z t47Ok ~l.4O' 3~,73" ~Ot / 14813 31.48' 3~.7~' ~76 4945 S BE47 E 460G $ 84~5 £ 4438 $ 9573 £ i 438~ $ ~604 E rerge~ Nar~e TuB Ns E~ Grid X Gr;d Y Polygon I 8976 439P $ 8~39 E 69D0~0 :r993900 Potygo~ 2 6976 439a-~ 8439 [ &gO~D 5993900 I~a~O~t ~ 8976 ~B9 $ 8604 ~ 699~13 ~993914 7 In 15038 31.49" 32.75' 9168 4290; 855] E [l)a-t:e Pto~:ce~ ~ 6/14/95 · WeU Pltu Feasibility OAt TI~;~ L~ r[n! .,an An{~mv~.d f}e_qipn · F STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIbolON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend ~ Operation Shutdown__ Re-enter suspended well ~ Alter casing ~ Repair well. .... Plugglng X L Time extension ~ Stimulate __ Change approved program.. Pull tubing ~ Variance __ Perforate ~ Other __ Plugback for Reddll 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska,/nc, Development X KBE = 48 Exploratory ~ 3. Address Stratigraphlc ~ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service: Point Mclntyre 4. Location of well at surface 8. Well number 495' SNL, 1256' EWL, SEC. 14, T12N, R14E, UM At top of productive interval N/A At effective depth 61' SNL, 3424' EWL, SEC. 24, T12N, R14E, UM At total depth 768' SNL, 19' WEL, SEC. 24, T12N, R14E, UM P2-50A 9. Permit number 92-65 10. APl number 50- 029-22261-01 11. Field/Pool Point Mcintyre / Undefined feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 65' Surface 4884' Intermediate Production 15299' Liner Perforation depth: measured None 14600 8247 12225 6986 Size 20" 13-3/8" 9-5/8" true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) feet feet feet feet Plugs (measured) Cement Plugs 13050'- 12720', 12493'- 12225' Bridge plug @600' Junk (measured) Cemented Measured delth True vertical/depth ~ 55' / 55' · 15330' 8799' 937 cu ft gel G & ' / 690 cu fl Class / /// 245 cuft CS II 3960 cu fl CS II & 460 cuft Class "G" / ECEIVED JUN 2 3 1995 laska 0il & Gas Cons. Commission 13. Attachments Description summary of proposal × Detailed operations program BOP sketch 14. Estimated date for commencing operation O7/2O/95 16. If proposal was verbally approved Oil~ Gas __ Name of approver Date approved Service 17. I here, by certify/(~at the foregoing is trpe and correct to the best of my knowledge. Signed ~~~ TitleDrillin~7En~Tineefin~TSupervisor ' /t FOR coMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness 15. Status of well classification as: Suspended x Date Plug integrity __ BOP Test Mechanical Integrity Test __ Location clearance Subsequent form required 10- I Approval NO. ~.,-"~//42~.~ Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88. SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST COMPANY /~. ~-r INIT CLASS ADMINISTRATION ENGINEERING APPR DATE 1. Permit fee attached ................... 2. Lease number appropriate ................ 3. Unique well name and number ............... 4. Well located in a defined pool .............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells .... ' 7. Sufficient acreage available in drilling unit...~. 9. Operator only affected party ........ ~ . . '...Y 10. Operator has appropriate bond in force~ J ...... 11. Permit can be issued without conservat~dn order ..... 12. Permit can be issued without administrative approval.'. 13. Can permit be approved before 15-~ay wait ........ 14. Conductor string provided ............... 15 Surface casing protects all known USDWs 16. CMT vol adequate to circulate on conductor & surf csg. C.T vol adequate to tie-in long string to surf csg . . 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ N 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ 24. Drilling fluid program schematic & equip list adequate ~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~--O ~O psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. Y N GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Seismic analysis 9f shallow gas zones .......... Data presented on potential overpressure zones ..... Y 32. 33. Seabed condition survey (if off-shore) ....... ./~ Y N 34. Contact name/phone for weekly progress reports . ./.. Y N [exploratory only] GEOLO~.: ENGINEERING: JD~/ RAD COMMISSION: Comments/Instructions: TAB o I.-I HOW/jo - A:%FORMS%cheklist my 03/94 WELL PERMIT CHECKLIST COMPANY dev [] redrll~ serv [] ON/OFF SHORE (2~/0 ADMINISTRATION 1. Permit fee attached .................. · · 2. Lease number appropriate ............... 3. Unique well name and number ............... 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from ~ther 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 ........ ENGINEERING 15. Surface casin9 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 abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schema%lc & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~-O Oc~ psig.~ 27. Choke manifold complies w/AP1 P~P-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of E2S gas probable ............ GEOLOGY 30. 31. 32. 33. 34. Permit can be issued w/o hydrogen sulfide measures .... Y ~/ _ Data presented on potential overpressure zones ..... Y/N Seismic analysis of shallow gas zones .......... 7 N Seabed condition survey (if off-shore) ........ /Y N Contact name/phone for weekly progress reports . . ./6 . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/jo - A:~FORMS~cheklist rev 03/94 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. 'Fo 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 APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASIC~ COMPUTING CENTER ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : P2-50B FIELD NAME : POINT MCINTYRE BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292226102 REFERENCE NO : 95301 ~ape Verification Listing schlumberger Alaska Computing Center 21-SEP-1995 20:19 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 95/09/21 ORIGIN : FLIC REEL NAME : 95301 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC.,POINT MCINTYRE P2-50B, API #50-50-029-22261-02 PAGE: **** TAPE HEADER **** SERVICE NAME ~: EDIT DATE : 95/09/21 ORIGIN : FLIC TAPE NAME : 95301 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC.,POINT MCINTYRE P2-50B, API #50-50-029-22261-02 TAPE HEADER POINT MCINTYRE MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD BIT RUN 1 95301 RUMINER LES PEAK 1ST STRING 2ND STRING P2-50B 500292226102 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 21-SEP-95 BIT RUN 2 BIT RUN 3 14 12N 14E 495 1256 51.50 51.50 11.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ........ ,dpe Verification Listing ' ochlumberger Alaska Computing Center 21-SEP-1995 20:19 3RD STRING PRODUCTION STRING REMARKS: THIS TAPE CONTAINS 1 RUN OF MWD DATA AND 1 RUN OF MAD DATA USING ANADRILLS CDR AND CDN TOOLS. NO DEPTH CORRECTIONS HAVE BEEN MADE AS PER INSTRUCTIONS FROM GORDON POSPISIL. $ **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CDR 14775.0 15155.0 CDN 14775.0 15155.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH CDR CDN # MERGED DATA SOURCE LDWG TOOL CODE $ BIT RUN NO. MERGE TOP MERGE BASE REMARKS: THIS FILE CONTAINS THE CLIPPED CDR AND CDN DATA OF RUN #1MEASURMENT WHILE DRILLING. THERE WAS ONLY ONE RUN OF MWD DATA. NO DEPTH CORRECTIONS WERE MADE ' AS PER GORDON POSPISIL. LIS FORMAT DATA ,ape Verification Listing · ~chlumberger Alaska Computing Center 21-SEP-1995 20:19 i PAGE: 3 TABLE TYPE : CONS TUNI VALU DEFI .................................... .............. ................... FN POINT MCINTYRE Field Name WN P2-50B Well Name APIN 500292226102 API Serial Number FL 0495 FNL & 1256 FWL Field Location SECT 14 Section TOWN 12N Township RANG 14E Range COUN NORTH SLOPE County STAT ALASF,~q State or Province NATI USA Nation LATI 70 23 59.945 N Latitude LONG 148 31 21.710 W Longitude WITN LES PEAK Witness Name SON 36359 Service Order Number PDAT MEAN SEA LEVEL Permanent datum EPD FT O. Elevation of Permanent Datum LMF DRILL FLOOR Log Measured From APD FT 51.5 Above Permanent Datum EKB FT 51.5 Elevation of Kelly Bushing EDF FT 51.5 Elevation of Derrick Floor EGL FT 11.5 Elevation of Ground Level TDD FT 15155. Total Depth - Driller TDL FT 15155. Total Depth - Logger BLI FT 15155. Bottom Log Interval TLI FT 12376. Top Log Interval DFD G/C3 10.4 Drilling Fluid Density RMS OHMM 0.184 Resistivity of Mud Sample MST DEGF 74. Mud Sample Temperature RMFS OHMM 0.131 Resistivity of Mud Filtrate S MFST DEGF 74. Mud Filtrate Sample Temperatu RMCS OHMM 0.29 Resistivity of Mud Cake Sampl MCST DEGF 74. Mud Cake Sample Temperature BHT DEGF 140. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT RA RP VRA VRP DER ROP FET GR RHOB Depth CDR ATTN RESISTIVITY CDR PHSF RESISTIVITY QRO VERY ENHANCED AMPLITUDE RESISTIVITY QRO VERY ENHANCED PHASE RESISITIVTY DIELECTRIC RESISITIVTY RATE OF PENETRATION TIME AFTER BIT Gamma Ray Bulk Density ..~ Tape Verification Listing · Schlumberger Alaska Computing Center 21-SEP-1995 20:19 DEFI DRHO Delta RHO PEF PhotoElectric Factor NPHI Thermal Neutron Porosity CALN NUCLEAR CALIPER PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ..... ..... 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** DEPT FT 36359 O0 000 O0 0 1 1 1 4 68 ---6666666566- RA MWD OHMM 36359 O0 000 O0 0 i 1 i 4 68 RP MWD OHMM 36359 O0 000 O0 0 I I 1 4 68 VRA MWD OHMM 36359 O0 000 O0 0 i 1 1 4 68 VRP MWD OHMM 36359 O0 000 O0 0 1 1 i 4 68 DER MWD OHMM 36359 O0 000 O0 0 1 1 1 4 68 ROP MWD FPHR 36359 O0 000 O0 0 1 1 i 4 68 FET MWD HR 36359 O0 000 O0 0 I 1 1 4 68 GR MWD GAPI 36359 O0 000 O0 0 1 i i 4 68 RHOB MWD G/C3 36359 O0 000 O0 0 1 1 1 4 68 DRHO MWD G/C3 36359 O0 000 O0 0 1 1 1 4 68 PEF MWD BN/E 36359 O0 000 O0 0 i 1 1 4 68 NPHI MWD PU-S 36359 O0 000 O0 0 1 1 1 4 68 CALN MWD IN 36359 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ~ ~ape Verification Listing · Schlumberger Alaska Computing Center 21-SEP-1995 20:19 PAGE: ** DATA ** DEPT. 15155.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 20.666 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD NPHI.MWD -999.250 CALN.MWD -999.250 DEPT. 14775.000 RA.MWD 1.563 RP.MWD 1.611 VRA.MWD VRP.MWD 1.459 DER.MWD 1.591 ROP.MWD 49.047 FET.MWD GR.MWD 137.236 RHOB.MWD 2.351 DRHO.MWD 0.081 PEF.MWD NPHI.MWD 43.800 CALN.MWD 9.126 ** END OF DATA ** -999.250 -999.250 -999.250 1.480 1.483 7.233 **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED MAD PASSES Depth shifted and clipped curves; MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 # FILE SUMMARY LDWG TOOL CODE START DEPTH CDR 12346.0 CDN 14525.0 for each pass STOP DEPTH 14775.0 14775.0 of each run in separate files. _~ Tape Verification Listing · Schlumberger Alaska Computing Center 21-SEP-1995 20:19 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH CDR CDN REMARKS: THIS FILE CONTAINS THE CLIPPED CDR AND CDN DATA OF RUN #1MEASURMENT AFTER DRILLING. THERE WAS ONLY ONE RUN OF MAD DATA. NO DEPTH CORRECTIONS WERE MADE AS PER GORDON POSPISIL. $ LIS FORMAT DATA PAGE: 6 TABLE TYPE : CONS TUNI VALU DEFI ON ---~-~[~[-i~] ...... Company Name FN POINT MClNTYRE Field Name WN P2-50B APIN 500292226102 FL 0495 FNL & 1256 FWL SECT 14 TOWN 12N RANG 14E COUN NORTH SLOPE STAT ALASKA NATI USA LATI 70 23 59.945 N LONG 148 31 21.710 W WITN LES PEAK SON 36359 PDAT MEAN SEA LEVEL EPD FT O. LMF DRILL FLOOR APD FT 51.5 EKB FT 51.5 EDF FT 51.5 EGL FT 11.5 TDD FT 15155. TDL FT 15155. BLI FT 15155. TLI FT 12376. DFD G/C3 10.4 RMS OHMM 0.184 MST DEGF 74. RMFS OHMM 0.131 MFST DEGF 74. RMCS OHMM 0.29 MCST DEGF 74. Well Name API Serial Number Field Location Section Township Range County State or Province Nation Latitude Longitude Witness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Bottom Log Interval Top Log Interval Drilling Fluid Density Resistivity of Mud Sample Mud Sample Temperature Resistivity of Mud Filtrate S Mud Filtrate Sample Temperatu Resistivity of Mud Cake Sampl Mud Cake Sample Temperature L~S Tape Verification Listing · Schlumberger Alaska Computing Center 21-SEP-1995 20:19 ~ PAGE: 7 TUNI VALU DEFI BHT DEGF 140. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth RA CDR ATTN RESISTIVITY RP CDR PHSF RESISTIVITY VRA QRO VERY ENHANCED AMPLITUDE RESISTIVITY VRP QRO VERY ENHANCED PHASE RESISITIVTY DER DIELECTRIC RESISITIVTY ROP RATE OF PENETRATION FET TIME AFTER BIT GR Gamma Ray RHOB Bulk Density DRHO Delta RHO PEF PhotoElectric Factor NPHI Thermal Neutron Porosity CALN NUCLEAR CALIPER DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 i .IS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1995 20:19 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 36359 O0 000 O0 0 2 1 I 4 68 0000000000 RA MAD OHMM 36359 O0 000 O0 0 2 1 I 4 68 0000000000 RP MAD OHHM 36359 O0 000 O0 0 2 1 i 4 68 0000000000 VRA MAD OHMM 36359 O0 000 O0 0 2 i I 4 68 0000000000 VRP MAD OHMM 36359 O0 000 O0 0 2 1 1 4 68 0000000000 DER MAD OHMM 36359 O0 000 O0 0 2 1 1 4 68 0000000000 ROP MAD FPHR 36359 O0 000 O0 0 2 1 i 4 68 0000000000 FET MAD HR 36359 O0 000 O0 0 2 1 I 4 68 0000000000 GR MAD GAPI 36359 O0 000 O0 0 2 1 1 4 68 0000000000 RHOB MAD G/C3 36359 O0 000 O0 0 2 1 1 4 68 0000000000 DRHO MAD G/C3 36359 O0 000 O0 0 2 I i 4 68 0000000000 PEF MAD BN/E 36359 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI MAD PU-S 36359 O0 000 O0 0 2 1 I 4 68 0000000000 CALN MAD IN 36359 O0 000 O0 0 2 I 1 4 68 0000000000 ** DATA ** DEPT. 14775.000 RA.MAD 1.563 RP.MAD 1.611 VRA.MAD VRP.MAD 1.459 DER.MAD 1.591 ROP.MAD 49.047 FET.HAD GR.MAD 137.236 RHOB.MAD 2.351 DRHO.MAD 0.081 PEF.MAD NPHI.MAD 43.800 CALN.MAD 9.126 DEPT. 12346.000 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD -999.250 FET.MAD GR.MAD 61.588 RHOB.MAD -999.250 DRHO.MAD -999.250 PEF.MAD NPHI.MAD -999.250 CALN.MAD -999.250 1.480 1.483 7.233 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LiS Tape Verification Listing · Schlumberger Alaska Computing Center **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 21-SEP-1995 20:19 PAGE: FILE HEADER FILE NUMBER: 3 EDITED MERGED MAD Depth shifted and clipped curvesF all MAD runs merged using earliest passes. DEPTH INCREMENT: 0.5000 # FILE SUMMARY LDWG TOOL CODE CDR CDN $ MERGED DATA SOURCE LDWG TOOL CODE REMARKS: START DEPTH STOP DEPTH 12346.0 14775.0 14525.0 14775.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE THIS FILE CONTAINS THE CLIPPED CDR AND CDN DATA OF RUN #1 MEASURMENT AFTER DRILLING. THERE WAS ONLY ONE RUN OF MAD DATA. NO DEPTH CORRECTIONS WERE MADE AS PER GORDON POSPISIL. $ # LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI .................................... .............. ................... FN POINT MCINTYRE Field Name WN P2-50B Well Name APIN 500292226102 API Serial Number FL 0495 FNL & 1256 FWL Field Location SECT 14 Section TOWN 12N Township RANG ~ 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation LATI 70 23 59.945 N Latitude LIS Tape Verification Listing ~ Schlumoerger Alaska Computing Center 21-SEP-1995 20:19 : PAGE: 10 TUNI VALU DEFI LONG 148 31 21.710 W Longitude WITN LES PEAK SON 36359 PDAT MEAN SEA LEVEL EPD FT O. LMF DRILL FLOOR APD FT 51.5 EKB FT 51.5 EDF FT 51.5 EGL FT 11.5 TDD FT 15155. TDL FT 15155. BLI FT 15155. TLI FT 12376. DFD G/¢3 10.4 RHS OHMM 0.184 MST DEGF 74. RMFS OHMM 0.131 MFST DEGF 74. RMCS OHMM 0.29 MCST DEGF 74. BHT DEGF 140. Witness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Bottom Log Interval Top Log Interval Drilling Fluid Density Resistivity of Mud Sample Mud Sample Temperature Resistivity of Mud Filtrate S Mud Filtrate Sample Temperatu Resistivity of Mud Cake Sampl Mud Cake Sample Temperature Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth RA CDR ATTN RESISTIVITY RP CDR PHSF RESISTIVITY VRA QRO VERY ENHANCED AMPLITUDE RESISTIVITY VRP QRO VERY ENHANCED PHASE RESISITIVTY DER DIELECTRIC RESISITIVTY ROP RATE OF PENETRATION FET TIME AFTER BIT GR Gamma Ray RHOB Bulk Density DRHO Delta RHO PEF PhotoElectric Factor NPHI Thermal Neutron Porosity CALN NUCLEAR CALIPER LIS Tape Verification Listing - Schlumoerger Alaska Computing Center 21-SEP-1995 20:19 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** coo 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ** SET TYPE - CHAN ** NAHE SERV UNIT SERVICE API API API API FILE NUHB NUHB SIZE REPR '-~6~-- ID ORDER # LOG TYPE CLASS HOD NUHB SAHP ELEH CODE (HEX) DEPT FT 36359 O0 000 O0 0 3 1 1 4 68 --~~-'- RA MAD OHMM 36359 O0 000 O0 0 3 1 1 4 68 0000000000 RP HAD OHMH 36359 O0 000 O0 0 3 1 1 4 68 0000000000 VRA MAD OHMH 36359 O0 000 O0 0 3 1 ! 4 68 0000000000 VRP MAD OHMM 36359 O0 000 O0 0 B 1 I 4 68 0000000000 DER MAD OHMH 36359 O0 000 O0 0 3 1 1 4 68 0000000000 ROP MAD FPHR 36359 O0 000 O0 0 3 1 1 4 68 0000000000 FET MAD HR 36359 O0 000 O0 0 B 1 1 4 68 0000000000 GR MAD GAPI 36359 O0 000 O0 0 3 1 ! 4 68 0000000000 RHOB MAD G/CB 36359 O0 000 O0 0 3 1 1 4 68 0000000000 DRHO MAD G/C3 36359 O0 000 O0 0 3 1 1 4 68 0000000000 PEF MAD BN/E 36359 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI MAD PU-S 36359 O0 000 O0 0 3 i 1 4 68 0000000000 CALN MAD IN 36359 O0 000 O0 0 3 1 1 4 68 0000000000 PAGE: 11 ** DATA ** DEPT. 14775.000 RA.MAD 1.563 RP.MAD 1.611 VRA.MAD VRP.MAD 1.459 DER.MAD 1.591 ROP.MAD 49.047 FET.MAD GR.MAD 137.236 RHOB.HAD 2.351 DRHO.MAD 0.081 PEF.MAD NPHI.MAD 43.800 CALN.MAD 9.126 1.480 1.483 7.233 LIS Tape Verification Listing - Schlumberger Alaska Computing Center 21-SEP-1995 20:19 PAGE: 12 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH CDR 14775.0 CDN 14775.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TO? LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (R~M) HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 15155.0 15155.0 06-AUG-95 FAST 2.5 V4.0 MEMORY 15155.0 14775.0 15155.0 85 61.7 LIS Tape Verification Listing · Schlumoerger Alaska Computing Center 21-SEP-1995 20:19 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY CDN DENSITY NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN DRILLERS CASING DEPTH FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDE. S .(PPM): FLUID LOSS (C. 3): . RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF /IN/: EWR FREQUENCY HZ TOOL NUMBER RGS055 NDS022 8.500 12376.0 10.40 0.184 0.131 0.290 SANDSTONE 2.65 1.0 74.0 74.0 74.0 REMARKS: ************ RUN 1 ************* RESISTIVITY TO BIT: 44.10', GR TO BIT: 54.52' DENSITY TO BIT: 99.80', NEUTRON TO BIT: 106.78' MAD PASS FROM 12376' TO 14775' DRILLED INTERVAL FROM 14775' TO 15155' MAXIMUM DEVIATION: 61.7 DEG @ 12552' WELL TD AT 21:22 05-AUG-95 $ LIS FORMAT DATA PAGE: 13 TABLE TYPE : CONS TUNI VALU DEFI -~ .................................... ~-~[~[-i~ ............ Company Name FN ' POINT MCINTYRE Field Name WN P2-50B Well Name APIN 500292226102 API Serial Number FL 0495 FNL & 1256 FWL Field Location SECT 14 Section LIS Tape Verification Listing . 21-SEP-1995 20:19 Schlumberger Alaska Computing Center PAGE: 14 TUNI VALU DEFI TOWN 12N Township RANG 14E ¢OUN NORTH SLOPE STAT ALASKA NATI USA LATI 70 23 59.945 N LONG 148 31 21.710 W WITN LES PEAK SON 36359 PDAT MEAN SEA LEVEL EPD FT O. LMF DRILL FLOOR APD FT 51.5 EKB FT 51.5 EDF FT 51.5 EGL FT 11.5 TDD FT 15155. TDL FT 15155. BLI FT 15155. TLI FT 12376. DFD G/¢3 10.4 RMS OHMM 0.184 MST DEGF 74. RMFS OHMM 0.131 MFST DEGF 74. RMCS OHMM 0.29 M¢ST DEGF 74. BHT DEGF 140. Range County State or Province Nation Latitude Longitude Witness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Bottom Log Interval Top Log Interval Drilling Fluid Density Resistivity of Mud Sample Mud Sample Temperature Resistivity of Mud Filtrate S Mud Filtrate Sample Temperatu Resistivity of Mud Cake Sampl Mud Cake Sample Temperature Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth ATR CDR ATTN RESISTIVITY PSR CDR PHSF RESISTIVITY ATVR QRO VERY ENHANCED AMPLITUDE RESISTIVITY PSVR QRO VERY ENHANCED PHASE RESISITIVTY DER DIELECTRIC RESISITIVTY ROPE RATE OF PENETRATION TAB TIME AFTER BIT GR Gamma Ray DPHI Density Porosity TNPH Thermal Neutron Porosity RHOB Bulk Density DRHO Delta RHO PEF PhotoElectric Factor DCAL Differential Caliper CALI NUCLEAR CALIPER LIS Tape Verification Listing - Schlumberger Alaska Compuling Center 21-SEP-1995 20:19 PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE --i .......... ~ .......... ~ .... 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAHP ELEM CODE (HEX) -~ ........ ~---~"~---~--~ .... ~---~ .... i ..... i ..... ~ ..... ~ .... ~~--- O0 000 O0 0 4 1 I 4 68 0000000000 ATR LW1 OHMM 36359 PSR LW1 OHMM 36359 O0 000 O0 0 4 i I 4 68 ATVR LW1 OHMH 36359 O0 000 O0 0 4 1 1 4 68 PSVR LW1 OHMM 36359 O0 000 O0 0 4 1 i 4 68 DER LW! OHMM 36359 O0 000 O0 0 4 1 1 4 68 ROPE LW1 F/HR 36359 O0 000 O0 0 4 1 1 4 68 TAB LW1 HR 36359 O0 000 O0 0 4 I i 4 68 GR LW1 GAPI 36359 O0 000 O0 0 4 i I 4 68 DPHI LW1 PU 36359 O0 000 O0 0 4 1 1 4 68 TNPH LW1 PU 36359 O0 000 O0 0 4 1 1 4 68 RHOB LW1 G/C3 36359 O0 000 O0 0 4 1 1 4 68 DRHO LW1 G/C3 36359 O0 000 O0 0 4 1 1 4 68 PEF LW1 BN/E 36359 O0 000 O0 0 4 1 1 4 68 DCAL LW1 IN 36359 O0 000 O0 0 4 1 1 4 68 CALI LW1 IN 36359 O0 000 O0 0 4 1 i 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** LIS Tape Verification Listing - Schlumberger Alaska Computing Center DEPT. 15155.000 ATR.LW1 PSVR. LW1 -999.250 DER.LW1 GR. LW1 -999.250 DPHI.LW1 DRHO.LW1 -999.250 PEF.LW1 DEPT. 14775.000 ATR.LW1 PSVR. LW1 1.459 DER. LW1 GR. LW1 137.236 DPHI.LW1 DRHO.LW1 0.081 PEF.LW1 21-SEP-1995 20:19 -999.250 PSR.LW1 -999.250 ROPE.LW1 -999.250 TNPH.LW1 -999.250 DCAL.LW1 1.563 PSR.LW1 1.591 ROPE.LW1 23.400 TNPH.LW1 7.233 DCAL.LW1 -999.250 20.666 -999.250-999.250 1.611 49.047 43.800 0.626 ATVR. LW1 TAB. LW1 RHOB. LW 1 CALI.LW1 ATVR.LW1 TAB.LW1 RHOB.LW1 CALI.LW1 PAGE: -999.250 -999.250 -999.250 -999.250 1.480 1.483 2.351 9.126 16 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001¢01 DATE : 95/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER w*** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001¢01 DATE : 95/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: MAD PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE CDR CDN $' LOG HEADER DATA DATE LOGGED: SOFTWARE: 1 1 O. 5000 START DEPTH 12345.0 14525.0 STOP DEPTH 14775.0 14775.0 06-AUG-95 LIS Tape Verification Listing ~ Schlumberger Alaska Computing Center 21-SEP-1995 20:19 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (Fl): TOP LOG INTERVAL (FT): . BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 61.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY CDN DENSITY NEURTON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 10.40 MUD VISCOSITY (S): MUD PH: MUD CHLORIDES .(PPM): FLUID LOSS (C. 3): . RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : HUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF /IN/: 1.0 EWR FREQUENCY HZ FAST 2.5 V4.0 MEMORY 15155.0 12345.0 14775.0 85 TOOL NUMBER RGS055 NDS022 8.500 12376.0 0.184 0.131 0.290 SANDSTONE 2.65 74.0 74.0 74.0 REMARKS: ************ RUN i ************* RESISTIVITY TO BIT: 44.10', GR TO BIT: 54.52' DENSITY TO BIT: 99.80', NEUTRON TO BIT: 106.78' MAD PASS FROM 12376' TO 14775' DRILLED INTERVAL FROM 14775' TO 15155' MAXIMUM DEVIATION: 61.7 DEG @ 12552' WELL TD AT 21:22 05-AUG-95 $ LIS FORMAT DATA PAGE: 17 LIS Tape Verification Listing ~ Schlumberger Alaska Computing Center 21-SEP-1995 20:19 ' PAGE: 18 TABLE TYPE :CONS TUNI VALU DEFI .................................... .............. ................... POINT MCINTYRE Field Name FN WN P2-50B Well Name APIN 500292226102 API Serial Number FL 0495 FNL & 1256 FWL Field Location SECT 14 Section TOWN 12N Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation LATI 70 23 59.945 N Latitude LONG 148 31 21.710 W Longitude WITN LES PEAK Witness Name SON 36359 Service Order Number PDAT MEAN SEA LEVEL Permanent datum EPD FT O. Elevation of Permanent Datum LMF DRILL FLOOR Log Measured From APD FT 51.5 Above Permanent Datum EKB FT 51.5 Elevation of Kelly Bushing EDF FT 51.5 Elevation of Derrick Floor EGL FT 11.5 Elevation of Ground Level TDD FT 15155. Total Depth - Driller TDL FT 15155. Total Depth - Logger BLI FT 15155. Bottom Log Interval TLI FT 12376. Top Log Interval DFD G/¢3 10.4 Drilling Fluid Density RMS OHMM 0.184 Resistivity of Mud Sample MST DEGF 74. Mud Sample Temperature RMFS OHMM 0.131 Resistivity of Mud Filtrate S MFST DEGF 74. Mud Filtrate Sample Temperatu RMCS OHMM 0.29 Resistivity of Mud Cake Sampl MCST DEGF 74. Mud Cake Sample Temperature BHT DEGF 140. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT ATR PSR ATVR PSVR DER ROPE TAB GR DPHI Depth CDR ATTN RESISTIVITY CDR PHSF RESISTIVITY QRO VERY ENHANCED AMPLITUDE RESISTIVITY QRO VERY ENHANCED PHASE RESISITIVTY DIELECTRIC RESISITIVTY RATE OF PENETRATION TIME AFTER BIT Gamma Ray Density Porosity LIS Tape Verification Listing ~ Schlumoerger Alaska Computing Center 21-SEP-1995 20:19 DEFI TNPH Thermal Neutron Porosity RHOB Bulk Density DRHO Delta RHO PEF PhotoElectric Factor DCAL Differential Caliper CALI NUCLEAR CALIPER PAGE: 19 DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ~¥~ ~p~ coo~ --v^~u~- 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ** SET TYPE - CHAN ** ~^~ s~v u~, s~v~c~ ^p~ ~ ^~ ^~ ~--~--~--~i~--~---~~--- -~ ........ ~---~;~;¢'-~---~--~ .... ~---; .... i ..... i ..... ~ ..... ~ .... ~~--- ATR MD1 OHMM 36359 O0 000 O0 0 5 1 1 4 68 0000000000 ps~ ~ol OH~ ~6~ O0 000 O0 0 ~ 1 1 ~ 68 0000000000 ATVR MD1 OHMM 36359 O0 000 O0 0 5 1 1 4 68 PSVR MD1 OHMM 36359 O0 000 O0 0 5 1 1 4 68 DER MD1 OHMM 36359 O0 000 O0 0 5 1 1 4 68 ROPE MD1 F/HR 36359 O0 000 O0 0 5 1 1 4 68 TAB HD1 HR 36359 O0 000 O0 0 5 1 1 4 68 GR ~D1 GAPI 36359 O0 000 O0 0 5 1 1 4 68 DPHI MD1 PU 36359 O0 000 O0 0 5 1 1 4 68 TNPH MD1 PU 36359 O0 000 O0 0 5 1 1 4 68 RHOB MD1 G/C3 36359 O0 000 O0 0 5 1 1 4 68 DRHO MD1 G/C3 36359 O0 000 O0 0 5 1 I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 LIS Tape Verification Listing ~ Schlumoerger Alaska Computing Center 21-SEP-1995 20:19 PAGE: 20 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ~ ~o~ ~/~ ~9 oo ooo oo o ~~ ~ ~ ~ oc^~ ~o~ ~ ~ oo ooo oo o ~~ ~ ~ ~ oooooooooo C^L~ Mo~ ~N~9 O0 000 O0 0 ~~ ~ ~ ~ 0000000000 ....................................................................................... ** DATA ** DEPT. 14775.000 ATR.MD1 1.563 PSR.MD1 1.611 ATVR.MD1 PSVR.MD1 1.459 DER.MD1 1.591 ROPE.MD1 49.047 TAB.MD1 GR.MD1 137.236 DPHI.MD1 23.400 TNPH.MD1 43.800 RHOB.MD1 DRHO.MD1 0.081 PEF.MD1 7.233 DCAL.MD1 0.626 CALI.MD1 DEPT. 12345.000 ATR.MD1 -999.250 PSR.MD1 -999.250 ATVR.MD1 PSVR.MD1 -999.250 DER.MD1 -999.250 ROPE.MD1 -999.250 TAB.MD1 GR.MD1 64.523 DPHI.MD1 -999.250 TNPH.MD1 -999.250 RHOB.MD1 DRHO.MD1 -999.250 PEF.MD1 -999.250 DCAL.MD1 -999.250 CALI.MD1 1.480 1.483 2.351 9.126 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/09/21 ORIGIN : FLIC TAPE NAME : 95301 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC.,POINT MCINTYRE P2-50B, API #50-50-029-22261-02 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1995 20:19 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/09/21 ORIGIN : FLIC REEL NAME : 95301 CONTINUATION # : PREVIOUS REEL : . COMMENT : ARCO ALASKA INC.,POINT M¢INTYRE P2-50B, API #50-50-029-22261-02 PAGE: 21