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Home My WebLink About196-063 S • PTIJ I '14 -Oe.,3 Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 vv BP Exploration AlaskaI900 E. Benson Blvd.IRoom: 788D1Anchorage, AK From: Lastufka,Joseph N Sent:Thursday,August 3, 2017 1:26 PM To:Victoria.Loepp@alaska.gov Cc:Leemhuis,Jacob<I ' ` 'is@bp.com> Subject: FW: New Parker NOV 6012 BOP Stack Victoria, Please update the sundry#317-239 for P1-04(PTD#196-063)and replace the previous BOP sketch to this one. The rams sizes are also different then what we had listed. • Annular • 3-1/2"x 5-1/2"VBRs • Blind/Shear SCAN A 1 9 20th • 2-7/8"x 5"VBRs SCANNED I'll be sending you a list of approved sidetracks which will have a configuration change at some point as well. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 x t i Al A I BP Exploration Alaska1900 E. Benson Blvd.1Room: 788D1Anchorage, AK 2 STATE OF ALASKA • •ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Q Re-enter Susp Well 0 Other:Repair SSSV Control 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 196-063 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22666-00-00 7. Property Designation(Lease Number): ADL 0034624 8. Well Name and Number: PTM P2-44 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PT MCINTYRE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 10013 feet Plugs measured feet true vertical 9400 feet Junk measured feet DEC 2 3 2015 Effective Depth: measured 9927 feet Packer measured 4952 feet /�� ((/`�'��)(�r(� true vertical 9319 feet Packer true vertical 4915.8 feet AOGCC V V Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 46-126 46-126 1530 520 Surface 5073 9-5/8"47#NT8OS 45-5118 45-5064 6870 4760 Intermediate Liner 27 7"26#L-80 4945-4972 4910-4934 7240 5410 Liner 5045 4-1/2"12.6#13Cr8 4972-10017 4934-9404 8430 7500 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr8 42-4990 42-4950 Packers and SSSV(type,measured and 7"Baker ZXP Packer 4952• -- 4915.8 true vertical depth) ,„ 4-1/2"QOS SSSV 2111 2109.97 12.Stimulation or cement squeeze summary: Intervals treated(measured): SSSV Surface Control Line,42-2111. Treatment descriptions including volumes used and final pressure: 11 Cans GX Sealant w/Hydro SCANNED 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 541 1147 6218 2120 781 Subsequent to operation: 974 1204 6152 2047 741 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Cattroron,Garry R(Wipro) Title PDC Principal Engineer Signature 7�, / ( Phone +1 907 564 4424 Date 12/22/15 — Form 10-404 Revised 5/2015 VT �tDCC 8 LO�J J/t-//f!o �j Submit Original Only • • a) v, to m co In M O I,- 00 CO ,...._ CO cr 0) CC) Nr N L V- O N CO CO N 00 0 CO CO CO 0) CO 11M0 V 046 V ,.(1.3 00 (flO 0) Co Co 03 Co 0) CA CA OCA O O O O O Co CO Co Co Co Co Co Co Co 0) 0) 0) 0) CA O. 0 I- CA Co In M 0) N Co OpV- 4 CA 0 V- t Co '- O N- CO M N Co M CO Co Co M C. M 0 ct 0 0 CO 4 (3) 0) CD r- CO o) 0 0 00 00 00 CC) OO 0) 0) 0) O 00000 > o CO 0o0ococo0o00CA00O) 0) 0) 0) 0) 0 2 wcc 0 0 0 w Z 1- ~ a w a) co ggY � o > co 00 < O co.. Co N- N N St CO O) 4 V- '- CN V- 4 co !n J U U W w L.L. 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MONO c WE LFEAD= FMC P2-44 2-44 BORE COMPLETION. ""4-112-CHROME TBG&LNR""' ACTUATOR= BAKER-5 KB.ELEV53.1' I I KOP 43_42' Max Angle 33 l�6272' 2111• —4-1/2"HES TRSSSV(FLOW SLV DAMAGED), ID=3.50"(LOCKED OUT 05/27/12) O Datum N = 9436' Datum TVD= 8800'SS GAS UFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 3.50" @ 2111' 1 3989 3988 4 MMG-M DMY RK 0 12/28/98 4-112"TRSSSV(DAMAGES FLOW SLV) l 2 4901 4869 25 MMG-M SO RK 20 09/11/05 4940' —{BKR TIEBACK SLV,ID=7.50' TOP OF 4-112'LNR — 1'4-1/T TBG,12.61t,13CR-110 NSCT, — 4965. e 494T —9.5/8'X r BKR ZXP PKR w/FLEX LOCK LNR HGR,ID=6.313" 4112 TBG,12.61F,13CR 80 NSCT, — 5• � 4966' —T X 6"x),ID=4.875" .0152 bpf,ID=3.956" 496T —{6'BKR ,ID=4.75" 4985' —{4 1/2'BKR GBHPBR22S4 SEAL ASSY,ID=3.958" 1 I1 5085' —4-1/2"HES X NIP,ID=3.813" 9-5/8"CSG,47#,NT-80S NSCC,ID=8.681' H 5113' -"i , F13RFORATION S(J $kRY 8 —14-1/2"HES X NP,D=3.813'('ELME))REF LOG:SINS CDWGR ON 04/08/96 I I ANGLE AT TOP FE F:17"r,9432' Nobe:Refer to Ftoduction DB for historical pert data a SIZE SFf INTERVAL Opn/Sqz DATE 2-1/2" 18 9432-9482 0 05/07/96 I 3-3/8" 6 9482-9512 S 04/29/98 3-3/8" 6 9513-9523 S 11/20/96 2-7/8" 6 9514-9544 0 05/30/01 I 2-7/8" 6 9544-9574 0 05/30/01 3-3/8" 6 9601-9611 0 05/07/96 2-1/T 12 9611-9651 0 11/07/98 2-1/T 12 9664-9674 0 11/26/98 PBTD H 992T 4-1/2"LNR,12.6#,NT13CR-80 NSCT, — 10012' '.'.'.'4'1 .0152 bpf,ID=3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS POINT MCINTYRE UNIT 04/12/96 ORIGINAL COMPLETION 06/17/12 PJC DRAWING CORRECTIONS WELL:P2-44 06/13/03 MS/KAK PERF CORRECTIONS PERMIT No:9960630 08/10/04 BMcWTLP NIP CORRECTION!8 9346' API No:50-029-22666-00 09/11/05 KSB/TLH 'GLV GO SEC 14,T12N,R14E,1632.71'FEL&1258.08'FNL 02/18/11 MB/JMD ADDED SSSV SAFETY NOTE I, 06/05/12+ LEC/JMD TRSSSV LOCK OUT(05/27/12. BP Exploration(Alaska) • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612: Anchorage, Alaska 99519 -6612 May 20, 2012 D AUC 0 8 ZU1L X 63 Mr. Jim Regg IQ�' Alaska Oil and Gas Conservation Commission r r 333 West 7 Avenue V 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 extemal 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, 4tb 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: 04/302012 Corrosion Vol. of cement Anal 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 10.20 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 -336 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 P241 1952050 50029226330000 1.5 NA 1.5 NA 17.00 6/9/2009 P242 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 ,ma7 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 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 11/01/10 Schim berjer NO. 5637 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD MPG -13 BCRJ -00038 X -FLOW CHECK/IBPSET RECORD -- 0 09115/10 1 1 MPS-43 AYKP -00104 SCMT 08126110 1 1 P1 -09 BCRJ -00036 PRODUCTION PROFILE ® 09/12/10 1 1 W -37A BD88.00048 MEM PRODUCTION PROFILE 09111/10 1 117 ;L W -31A AZ2F -00064 MEM PRODUCTION PROFILE 09/16/10 1 06 -19A AWJI -00112 MEM PRODUCTION PROFILE 09/19/10 1 1 12 -OSAL1 BAUJ -00050 MEM PRODUCTION PROFILE 09/20/10 1 1 P1 -16 SCRJ -00049 INJECTION PROFILE 10/06110 1 1 04 -03 BCRD -00059 PRODUCTION PROFILE 09/27110 1 1 P -03A AZ2F -00065 MEM INJECTION PROFILE f — 10/06110 1 1 G -19B AWJI -00114 MEM PRODUCTION PROFILE 10/04/10 1 1 7 BD88.00058 MEM GLS 10/09/10 1 1 3 6 PRODUCTION PROFILE 09111/10 1 1 BAUJ -00043 MEM INJECTION PROFILE 09/13/10 1 1 AWJI -00118 MEM PRODUCTION PROFILE 10114110 1 1 BBUO -00023 PRODUCTION PROFILE BP CORRECTION 06108/10 1 1 H -38 AZ2F-00068 MEM PRODUCTION PROFILE -- 10/16110 i 1 P2-44 BCRD -00063 PRODUCTION PROFILE 10/15/10 1 1 B -13B AYKP -00091 CH EDIT PDC -GR (SCMT) -� 07/02110 rO 7 02 -22B IOAKA0069 OH MWD /LWD EDIT 07/07110 2 1 W -192 BCRJ -00034 CH EDIT PDC -GR (SCMT) 09/07110 1 i OWDW -SE APBPD3WELL RST REDO - PRINTS 09/23110 1 OWDW -NW BBSK -00033 RST 09/24110 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 N U V a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing_ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 383' FNL, 3977' FEL, Sec. 14, T12N, R14E, UM At top of productive interval 1214' FNL, 1806' FEL, Sec. 14, T12N, R14E, UM At effective depth At total depth 1260' FNL, 1630' FEL, Sec. 14, T12N, R14E, UM 5. Type of Well: Development __X Exploratow~ Stratigraph lc__ Service__ (asp's 681548, 5998199) (asp's 683739, 5997422) (asp's 683917, 5997381) 6. Datum elevation (DF or KB feet) RKB 51.9 feet 7. Unit or Property name Point Mclntyre Unit 8. Well number P2-44 9. Permit number / approval number 196-063 10. APl number 50-029-22666 11. Field / Pool Point Mclntyre Oil Pool 12. Present well condition summary Total depth: measured true vertical 10020 feet 9407 feet Effective depth: measured 9623 feet true vertical 9030 feet Plugs (measured) Casing Length Conductor 120' Surface 5061' Liner 5072' Junk (measured) Size Cemented 20" 260 Sx AS 9-5/8" 1381 Sx PFE & 375 Sx Class G 4-1/2" 927 Sx Class G Tagged PBTD @ 9623' MD on 5/24/2001. Measured Depth True Vertical Depth 120' 120' 5113' 5059' 10012' 9399' Perforation depth: measured 9432' - 9482'; 9514' - 9574'; 9611' - 9651'- 9664' - 9674'. true vertical 8848' - 8896'; 8926' - 8984'; 9019' - 9057'; 9069' - 9079'. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR Tubing @ 4947' MD. Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" Baker Liner Top ZXP Packer @ 4947' MD. 4-1/2" HES Series 10 TRSSSV @ 2111' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operationS~23~2001 Subsequent to operationG/06/2001 OiI-Bbl 270 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 264 683 938 554 4881 Casing Pressure Tubing Pressure 776 788 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ___X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that ~e foregoing, i.s-tl'ue and correct to the best of my knowledge. /' Signed /~/~. - Title: PT Mac Surveillance Engineer Form 10-404 Rev 06/15/88 · ORIGINAL Date June 15. 2001. Prepared by Paul Rauf 564-5799 SUBMIT IN DUPLICATE P2-44 DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 5/24/2001: 5/30/2001: RIH w/3-3/8 dummy gun & drifted to 9553'. Drifted w/2-1/2" dummy gun / sample bailer to 9623' & w/2-7/8" dummy gun to 9616' SLM. MIRU ELU. PT'd equip to 3000 psi. RIH w/perforating guns & shot the following add perforations in 2 separate runs from: 9514' - 9574' MD (UB4/3 Zone) Reference Log: SWS CDR/GR 4/08/1996. Used 2-7/8" carriers & all shots @ 6 SPF, 60° phasing, & random orientation. POOH w/ guns- ASF. RD ELU. Placed well BOL & obtained a representative welltest. Page 1 O1'4 OR BEFORE W STATE OF ALASKA ALASKA. .... % AND GAS CONSERVATION COMMISF REPORL SUNDRY WELL OPERATi,.-NS · Operations performed: Operation shutdown __ Stimulate ~'' Plugging ~ Perforate Pull tubing __ Alter casing __ Repair well __ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. BOX 100360, Anchorage, AK 99510 4. Location of well at surface 382' FNL, 3978' FEL, Sec. 14, T12N, R14E At top of production interval 1214' FNL, 3474' FWL, Sec. 14, T12N, R14E At effective depth At total depth 1258' FNL, 1632' FEL, Sec. 14, T12N, R14E 5. Type of Well: Development Exploratory Stratigraphic Service Datum elevation (DF or KB) KB 53 feet 7. Unit or Property name POINT MCINTYRE UNIT 8. Well number P2-44 9. Permit number/approval number 96-63 / 10. APl number 500292266600 11. Field/Pool Point Mclntyre 12. Present well condition summary Total Depth: measured: Effective Depth: Casing Conductor Surface Intermediate Liner true vertical: measured: true vertical: Length 120' 5070' Perforation depth: Size 20" 9 5/8" 5072' 4 1/2" 10020 feet Plugs (measured) None· 9407 feet 9927 feet Junk (measured) None. 9319 feet Cemented Measured depth 260 SX Arcticset 120' 1280 sx PF 'E', 375 sx 'G', 5111' 101 sx PF'E' True vedical depth 120' 5058' 927 SX Class G 10012' 9399' measured 9432-9482,9611-9631',9631-9681' truevertical 8848-8896',9019-9038',9038-9086 x 8 5/8 PKR @ 4957' MD, 3 4/5 x 4 1/2 TRSSSV @ 2111' MD Tubing (size, grade, and measured depth) 4 1/2 in. 12.6# CR13 @ 0-9926' MD, Packers and SSSV (type and measured depth) 4 RECEiV D JUL 22 1999 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure please refer to the attached documents 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure n/a n/a n/a 823 546 148 I16. Status of well classification as: Oil~x Gas __Suspended 17.1 hereby cedi~at the .fo~g~ truex and correct to the best of my knowledge. Tubing Pressure n/a 765 Service Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE P2-44 Data Frac 9/23/96 1 RU frac equipment 2 Breakdown. Pumped at 25 BPM & 15 BPM, ISIP 1882. Data frac pumped at 10 PBM, ISIP2207, closure approx. 5 minutes. Frac Pad and 2# 20/40 stage pumped at 10 BPM. Ramp and 10# stage pumped at 15 BPM. Flush pumped at 15 BPM, slowed to 6 BPM. Placed 59972# behind pipe; 672# left in pipe. 3 RDMO P2-44 Add Perfs 11/20/96 RIH w/3 3/8" HSD gun and added perforations at: 9513' - 9523' MD 9664' - 9674' MD All shots at 6 SPF, 60 degrees phasing and random orientation. P2-44 Sand Plug 2/6/98 1 Laid in 3270# 20/40 sand. Sand top at 9573' CTM P2-44 WSO Squeeze 2/11/98 1 RU service company and held pre-job safety meeting 2 WSO Squeeze with LARC to 3500 psi on perfs 9432-8523' MD. Cleanout to hard cement. Sand cap at 9549' CTM. 2/12/98 3 Squeeze #1 40 BBP no pressure increase. Squeeze #2 BBP (10 neat, 28 aggregate), hesitate to 3500 PSI 4 Freeze protect and RDMO P2-44 Add Perforation 4/29/98 RIH w/3 3/8" HSD gun and added perforations at: 9432'- 9482' MD All shots at 6 SPF, 60 degrees phasing and random orientation. P2-44 WSO Squeeze 8/24/98 1 RU service company and held pre-job safety meeting 2 Washed perfs with 10 BBL of diesel/Xylene/musol. Squeezed 20 BBL neat LARC behind pipe plus approx. 17 BBL LARC with aggregate 3 Attempted to build squeeze pressure to 3000 but kept breaking back to 2500 psi. 4 RD P2-44 WSO Squeeze 10/19/98 1 RU service company and held pre-job safety meeting 2 Pumped squeeze, cement job, 53.8 BBL with aggregate. Flushed clean with BIO to PBTD. Left TEA in perfs. Left 500 psi on well 3 RDMO P2-44 Reperforation 11/7/98 1 RU service company and held pre-job safety meeting 2 Call for radio silent; arm gun 3 RIH with 20' x 2.5" gun and GR. 4 Tie in, shoot gun at 9611-9631' MD 6 shots per foot -UB. POOH 5 At surface, all but one shot fired (at bottom of gun) 6 Arm Gun #2 and RIH with 30' x 2.5" gun and CCL 7 CCL failed. POOH 8 Replace CCL with gun and RIH. Tie in and fire gun; gun didn't fire. POOH 9 Disarm gun and RD 11/8/98 1 RU service company and held pre-job safety meeting 2 Call for radio silent; arm gun 3 RIH with 20' x 2.5" gun. 4 Tie in, shoot gun at 9432-9482' MD, 6 shots per foot. POOH 5 RDMO P2-44 Reperforation 11/26/98 1 RU service company and held pre-job safety meeting 2 Arm Gun and RIH with 30' x 2.5" gun 3 Tie in and fire gun at 9631-9651' MD at 6 shots per foot. Good fire. POOH 4 RDMO P2-44 Add Peroration 12/24/98 1 RU service company and held pre-job safety meeting 2 Arm Gun and RIH with 10' x 2.5" gun 3 Tie in and fire gun at 9664-9674' MD at 6 shots per foot. Good fire. POOH 4 RDMO Well' P2-44 GPMA WEB Date- 4/15/99 TRSSSV-- PKR -- XNIP-- X NIP Perf ------ Perf ~ Perf Perf - Perf Perf ~ Perf --------, Perf - Perf - APl: 500~92266600 Well Type: PROD Angle @ TS: deg @ SSSV Type: CAT I - SSSV Annular Fluid: AL TO 39 Reference SWS CDR/GR Log: Last Tag: 9760 SLM Last Tag Date: 11/22/98 Orig Compltn: 4/12/96 Last W/O: Ref Log Date: 4/8/96 Angle @ TD: 19 deg @ 10012 Rev Reason: CO GLV's Last Update: 12/31/98 TD: 10012 ftKB Max Hole 33 deg @ 6272 Angle: Safe, Notes::: : Date Note 4/13/96 Minimum ID: 3.813" HES SERIES 10 TRSSSV AT 2111' MD General:Notes: Date Note 4/13/96 Well Status: ACTIVE 4/13/96 Tubing Hanger: FMC 6 @ 38' MD :Other (plUgs,:equip., etc.) - JEWELRY Depth TVD Type Description 2111 2110 TRSSSV 4-1/2" HES SERIES 10, ID=3.813" 4957 4920 PKR 9-5/8" X 4-1/2" BAKER LINER TOP ZXP PACKER 5084 5034 X NIP 4-1/2" HES X NIPPLE, ID=3.813" 9346 8766 X NIP 4-1/2" HES X NIPPLE, ID=3.813", ( ' ELMD) :caSi n g st ri n g s ::. A I!:: ID 3.813 4.000 3.813 3.813 Size Weight Grade Top Btm Feet Description 9.625 47.00 NT80/NT95 0 5111 5111 PROD. CASING Tubing:Strings:, Ail: Size Weight Grade Top Btm Feet Description 4.500 12.60 CR13 0 9926 9926 TUBING Gas Liff::Mandrel~alVes ] Stn MD 'rVD Man Man VMfr VType VOD Latch Port TRO Date Vlv Mfr Type Run Comment 1 3989 3987 CA MMG-M CA DV 1.5 RK 0.000 0 12/28/98 2 4900 4869 CA MMG-M CA OV 1.5 RK 0.250 0 12/28/98 perforations:Summary } Interval TVD Zone Status Feet SPF Date Type Comment 9432- 9482 8848-8896 9482- 9512 8896- 8924 9513-9523 8925-8935 9601-9611 9009-9019 9611-9631 9019-9038 9631- 9651 9038-9057 9664- 9674 9069-9079 50 18 11/8/98 REPEl; 60 deg phase, 2-1/2" guns 30 6 5/7/96 IPERF (SQZD 8/24/98 & 10/19/98) 10 611/20/91APERF (SQZD 8/24/98 & 10/19/98) 10 6 5/7/96 IPERF 600 PHASE, 3-3/8" GUNS (SQZD 8/24/98 & 10/19/98) 20 12 11/7/98 REPEl; 60 deg phase, 2-1/2" guns 20 1211/26/91 REPEl; 60 deg phase, 2-1/2" guns 10 1212/24/91APERF 60 deg PHASE, 2-1/2" GUNS PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS -- 96-063 96-063 PERF RCD 7151 ~EPIA ~/~CDR/CDN MWD & MAD 96-063 96-063 CDR CDR-TVD /~8-10013 ~'~7498-10013 96-063 CDN ~L~7498-10013 96-063 CDN-TVD 7498-10013 96-063 PERF ~m~9200-9812 96-063 PROD PROF 10-407 DAILY WELL OPS J~'~9300- 9790 R~OMPLETION DATE J7 ~2 / ~ ~ / Are dry ditch samples required? yes ~_~_And received? Page: 1 Date: 05/13/98 RUN DATE RECVD 1 05/23/96 1 07/26/96 FINAL 07~26/96 FINAL 07/26/96 1 07/26/96 1 07/26/96 1 12/13/96 FINAL 02/14/97 a~ ye-s--~o_ Was the well cored? Are well tests required? ~es ~Q~.~). Received? Well is in compliance Initial COMMENTS yes .~Analysis & description received? _y~es no y~ ..... GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10769 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 2/5/97 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27/NK-28)] Well Job # Log Description Date BL Floppy RF Sepia Disk P2-20 PRODUCTION LOG 9 61 2 0 3 I 1 P 2-44 PRODUCTION PROFILE 9 7 01 2 7 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ---- STATE OF ALASKA ~?ALASK,-, ..,~L AND GAS CONSERVATION CU,,4MISSION WELL COMPLETION OR RECOMPLETION 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. 96-63 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22666 4. Location of well at surface ?.?:. 1,: ... ----~I1~1~1~1~ - 9. Unit or Lease Name 384' SNL, 1302' EWL, SEC. 14, T12N, R14E ....... ?;~' ~!:.:!':-i ~ Point Mclntyre At t°P °f pr°ductive interval! i ~,~/¢~¢'I 10. Well Number 1214' SNL,-'32¢.4_' EWL, SEC. 14, T12N, R14E ,.- P2-44 Att°taldepil~"?5~ i~~:'~' 11. Field and Pool 1259' SNL,-9966' EWL, SEC. 14, T12N, R14E =---/--,._.~ .... ............. Point Mclntyre 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 51.9'I ADL 034624 12. Date Spudded03/31/96 113' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °ffsh°re I 16' N°' °f C°mpleti°ns04/08/96 05/07/96 N/A MSLI One :fT. Total Depth (MD+TVD)! 18. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set,.1. Thickness of Permafrost 10012 9399 F'r1 9927 9318 FT] [] Yes [] No I 2111' MD! 1800' (Approx.) 22. Type Electric or Other Logs Run Gyro, MWD, LWD, CDN/CDR '~3. CASING, LINER AND CEMENTING RECORD °ECl IVED CASING SE'I-rING DEPTH HOLE [1%, SIZE WT. PER FT. GRADE TOP BO-FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 120' 30" 260 sx Arctic Set (Approx.) FEB 1997 9-5/8" 47# NTDOS 41' 5113' 12-1/4" 1280 sx PF 'E', 375 sx 'G', 101 sx PF 'E' 4-1/2" 12.6# 13CR80 4940' 10012' 8-1/2" 927 sx Class 'G' Aiu~k~ 0il & "~ ..... A hr, Il ~ron*~ ,l~J i~1 i 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13CR80 4985' 4947' MD TVD MD TVD 9432'-9512' 8848'-8924' 9601'-9651' 9009'-9057' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect w/150 bbl diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) May 14, 1996 I Flowing '~ate of Test Hours Tested PRODUCTION FOR OIL-EEL GAS-MCF WATER-EEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD · I Flow Tubing Casing Pressure OALCULATED. OIL-EEL GAS-MCF WATER-BEE OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geoldgic Marke._ 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Kuparuk River 9432' 8848' Zone UC1 9473' 8887' Zone UB1 9601' 9009' RECEIVED FEB ,S 1997 AJaska 0il & Gas Cons. C0mlniSsi0n Anch0rag0 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I herebYsigned certify that the~trune ~°~ (/~~~t~' the best of my knowledge /--r.~./ SteveShultz Title Senior Drilling Engineer Date Prepared By Name/Number: Kathy Carr~oamo~, 564-5122 INSTRUCTIONS GENEF~AL: This form is designed for submitting a complete and correct well completion report and Icg 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 cementing and the location of the cementing tool. ITEM 2?: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: P2-44 Rig Name: Pool 7 AFE: 2C0090 Accept Date: 03/30/96 Spud Date: 03/31/96 Release Date: 04/1 2/96 Mar 31 1996 (1) Rig moved 100 %. Held safety meeting. Rigged up divertor. Made up BHA ¢1. Apr I 1996 (2) Made up BHA ¢1. Made up BHA ¢1. Serviced block line. Rigged up survey wireline unit. Tested divertor. Circulated at 45 ft. Drilled to 500 ft. Took Gyro survey at 500 ft. Drilled to 1579 ft. Apr 2 1996 (3) Drilled to 2110 ft. Took Gyro survey at 2110 ft. Drilled to 2800 ft. Circulated at 2800 ft. Pulled out of hole to 847 ft. RIH to 2800 ft. Drilled to 3858 ft. Circulated at 3858 ft. Pulled out of hole to 2800 ft. RIH to 3858 ft. Drilled to 4244 ft. Apr 3 1996 (4) Drilled to 5120 ft. Circulated at 5120 ft. Pulled out of hole to 3800 ft. RIH to 5120 ft. Circulated at 5120 ft. Pulled out of hole to 805 ft. Pulled BHA. Rigged up casing handling equipment. Apr 4 1996 (5) Rigged up casing handling equipment. Ran casing to 5113 ft (9.625 in OD). Rigged up handling equipment. Circulated at 5113 ft. Mixed and pumped slurry- 572 bbl. Displaced slurry- 368 bbl. Rigged down casing handling equipment. Rigged down divertor. Mixed and pumped slurry- 35 bbl. Rigged up BOP stack. Apr 5 1996 (6) Rigged up BOP stack. Tested well control. Serviced drillfloor/derrick. MU BHA ¢2. Laid down fish. Held safety meeting. Made up BHA ¢2. Held safety meeting. Singled in drill pipe to 3797 ft. RIH to 5020 ft. Tested casing. Drilled cement to 5130 ft. Circulated at 5130 ft. Performed formation integrity test, 14.8 ppg EMW. Drilled to 5369 ft. Apr 6 1996 (7) Drilled to 6332 ft. Circulated at 6332 ft. Pulled out of hole to 5100 ft. Serviced drillfloor/derrick. RIH to 6336 ft. Drilled to 7463 ft. Operations Summ'ary for: Apr 7 1996 (8) Drilled to 7500 ft. Circulated at 7500 ft. Pulled out of hole to 200 ft. Pulled BHA. Serviced BOP stack. Made up BHA #3. RIH to 1000 ft. Serviced drillfloor/derrick. RIH to 7500 ft. Drilled to 8155 ft. Circulated at 8155 ft. Apr 8 1996 (9) Circulated at 8155 ft. Drilled to 9010 ft. Circulated at 9010 ft. Pulled out of hole to 7450 ft. RIH to 9010 ft. Circulated at 9010 ft. Circulated at 9010 ft. Drilled to 9947 ft. Apr 9 1996 (10) Drilled to 10012 ft. Circulated at 10012 ft. Pulled out of hole to 8800 ft. RIH to 10012 ft. Circulated at 10012 ft. Pulled out of hole to 9440 ft. RIH to 10012 ft. Circulated at 10012 ft. Pulled out of hole to 265 ft. Pulled BHA. Serviced BOP stack. Rigged up sub-surface equipment - Liner hanger. Rigged up casing handling equipment. Apr 10 1996 (11) Rigged up casing handling equipment. Ran casing to 5100 ft (4.5 in OD). Rigged up sub-surface equipment - Liner hanger. Circulated at 5120 ft. Ran drillpipe on landing string to 10012 ft. Circulated at 10012 ft. Mixed and pumped slurry - 338 bbl. Displaced slurry - 179 bbl. Circulated at 4932 ft. Apr 11 1996 (12) Circulated at 4932 ft. Cleared mud shakers. Laid down 4921 ft of Drillpipe. Rigged up sub-surface equipment - Setting tools. Rigged up sub-surface equipment - Other sub-surface equipment. Ran drillpipe in stands to 4980 ft. Tested mechanical packer- via annulus. Reverse circulated at 4960 ft. Laid down 4980 ft of Drillpipe. Retrieved bore protector. RU tubing handling equipment. Ran tubing to 2060 ft (4.5 in OD). Apr 12 1996 (13) Ran tubing to 4985 ft (4.5 in OD). Rigged up sub-surface equipment - hanger assembly. Circulated at 4940 ft. Ran tubing on landing string to 4985 ft. Rigged down BOP stack. Installed Xmas tree primary components. Removed hanger plug. tested tubing - via annulus and string. Freeze protect well - 150 bbl of diesel. installed hanger plug. Apr 13 1996 (14) Installed hanger plug. Rigged down lubricator. RECEIVED Rigged down drillfloor/derrick. FEB 3 1997 'Alaska Oil & Gas Cons. Commission Anchorage Page 2 RECEIVED FEB Oil & Gag Cons. Con:rnig~i~n ^nehorage ft ft ft ft lO0~O0 iC,':3~0 i00~00 -0.~02 0~17 :300,¢,1: i,:}0,0 :3-00,00 0,:3'.:.-' 400 ~. 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"':'=~' ='-' 'L0"/.,": FY5 ~ '~ ':. i .: -:'--" ~ -:"2: -' .~ -': ~ =' !9'5'2:. ,5.5 zl ,::,': J,:, l i :t~ 202P,55 2 ! 7.5..,T.:" !il :20 20?7 ,,56, 2248.:.,5..{, iii 2129,0.5 22~,i, :,5 ;. i !, :04 ........ xoi,J, '~ *. ! !0 ... '--'-..,=-' r - .-' ...:. ~ 2"~38 :-76 2:]73,73 i!(', ,73 22,fy" ~53 24%,2..}: .'-'.. i 0 .:. $5 22??, 4../0 2d53,'?? :. !0,57 2?iS, 72 24.75, Si i i(:', 5'/..: 0 ...-.'.;., i+,.l,7 f_'-, 64 q. F-% O, ',"'5 '), '..:' i ':L:, ?2 RECEIVED FEB 1997 Alaska 0il & Gas Cons. Commission Anchorage 12/13/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10639 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 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 P2-07 PRODUCTI(~N PROFILE LOG I 96111 4 I 1 P2-12 PRODUCTION PROFILE LOG 961116 I 1 P 2-20 PRODUCTION PROFILE 961 203 1 1 P2-21 PRODUCTION LOG PROFILE 96111 5 I 1 P2-44 PERFORATION RECORD 961120 1 1 Rp_-CEI SIGNED: DEC 15 1996 Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 7/26/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10303 Company: Alaska Oil & Gas Cons Comm Attn: Howard Okland 3001 Porcupine Drive Anchorage, AK 99501 JUL 2 6 ~99,3 Alasi~ Oil & Gc.s Cons. Commission And]0~,~e 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 P2-44 ~ ~ - L'r~ ~.., 96119 CDR/CDN 960408 ..... 1 P2-44 CDR 960408 I 1 P2-44 CDN 960408 I 1 ...... P2-44 CDR/TVD 9 6 0 4 0 8 I 1 ............ P2-44 \/' CDN/TVD 9 6 0 4 0 8 I 1 N.PRUDHOE BAy ST.#3 ~ '?_,. - Icl~' PR0~)U. CT!ON. PROFIEE 960713 I 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. MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David Johns~ Chairman' ~' Blair Wondzell~~ P. I. Supervisor'~~ FROM' Lou Grimaldi,~_~-' SUBJECT: Petroleum Inspector DATE: March 31, 1996 FILE NO: E21JC5DD.DOC Diverter inspection Arco P2-44 Point Mclntyre Field PTD 96-63 Sunday, March 31, 1996: ! traveled to Pad #2 in the Point Mcintyre field to witness the Diverter function test on Pool rig #7 which was preparing to drill surface hole on Arco's well #P2-44. The rig was ready when i arrived and the function test of the Diverter assembly went well. The twenty inch annular preventer had a closure time of 28 seconds which is acceptable for this equipment. The accumulator had a recharge time of 2 minutes 25 seconds. The gas detection system was tested and showed a fault in the H2S detector in the pit area. I walked the vent line and found three flanges that had not had gaskets installed between them, these were installed before I left location. I received a call from Jimmy Greco later this day who informed me that the problem with the H2S detector was traced down to a bad wire connection and had been repaired. SUMMARY: I witnessed the Diverter function test on Pool rig #7. Two failures noted. Attachments: E21JC5DD.XLS attachments: Scott SigurdsenFFom Horten (Prudhoe Bay drilling) Drlg Contractor: Operator: Well Name: Location: Sec. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Pool Arco Alaska P2-44 14 T. 12N R. Operation: Development Rig No. 7 PTD # Date: X Exploratory: 96-63 Rig Ph. # Tommy Johnson Oper. Rep.: Rig Rep.: 14E 3/31/96 659-4815 Jimmy Greco Merdian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P Reserve Pit: N/A Well Sign: (Gen.) Drlg. Rig: Flare Pit: DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Turns Targeted / Long Radius: 2O P P 16 150 N/A P P N/A P P N/A in. in. ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 3OOO 1650 0 min. 34 2 min. 25 Six Bottles psig psig sec, sec. MUD SYSTEM INSPECTION: Trip Tank: Mud Pits: Flow Monitor: 2000 psi average psig Light Alarm P P GAS DETECTORS: Methane Hydrogen Sulfide: P P P P Light Alarm P P F F DIVERTER SCHEMATIC North Non Compliance Items 2 Repair Items Within N/A Day (s) And contact the Inspector @ 659-3607 Remarks: Gaskets missing from vent line flanges. H2S detector in pits malfunctioned. All items repaired before rig drilled out I Distribution orig. - Well File c - Oper/Rep c- Database c - Trip Rpt File c - Inspector AOGCC REP.: OPERATOR REP.: Louis R. Grimaldi E21JC5DD.XLS DVTRINSP.XLT (REV. 1/94) ALASKA OIL AND GAS CONSERVATION COMMISSION TONY K/VOWLE$, GOVERIVOt~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 29, 1996 Steve Shultz, Senior Drilling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re' Point Mclntyre P2-44 ARCO Alaska, Inc. Permit No: 96-63 Sur. Loc. 384'SNL, 1302'EWL, Sec. 14, T12N, R14E, UM Btrnhole Loc. 1286'SNL, 3821'EWL, Sec. 14, T12N, R14E, UM Dear Mr. Shultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC; Department offish & 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 20 AAC 25.005 la. Type of work Drill [] RedrillFlllb. Type of well. Exploratoryl-I Stratigraphic TestO Development Oil[] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 15. Datum Elevation (DF or KB) 10. Field and Pool ARC©Alaska, Inc. Plan RTE= 51.3 feet Point Mclntyre 3. Address 6. Property Designation P.,©. 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) 384' SNL, 1302' EWL, SEC. 14, T12N, R14E Point Mclntyre At top of productive interval 8. Well number Number 1189' SNL, 3556' EWL, SEC. 14, T12N, R14E P2-44 U-630610 At total depth 9. Approximate spud date Amount 1286' SNL, 3821' EWL, SEC. 14, T12N, R14E 04/01/96 $200,000.00 12. Distance to nearest 13.. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ADL 365548, 1286 feet P2-46, 63' @ 4500'MD feet 2560 10040'MD/9360' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle29.~ o Maximum surface 3290 psig At total depth (TVD) 8800'/4350 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 94# H-40 Weld 80' Surface Surface 80' 80' 260 sx Arcticset (Approx.) 12-1/4" 9-5/8" 47# NTCOS NSCC 5066' 41' 41' 5107' 5051' 1060 sx PF 'E', 375 sx 'G', 250 sx PF 'E' 8-1/2" 4-1/2" 12.6# 15CR80 NSCT 5083' 4957' 4910' 10040' 9360' 990 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate Production . MAR 2_ 6 1996 Liner Perforation depth: measured Alaska 0il & 8as Cons. Commission true vertical Anchorage 20. Attachments - Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling prograr~ ~ Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] fluid 'certify~he-- for¢¢~'ng is t~ue a~nd correct to the best of my knowledge 21. I hereby Signed ,//'~~L~',4\~ ~v'¢'^ ,/~k/~--....~,,,, Title Senior Drillin~l En~lineer Date · - '""Commission Use Only Permit Number APl number Approval date /See cover letter ~'-~'.~ 50- ~2_~-- ~ .2_ ~'~"~ ~//3-.~/~(.¢ for other requirements Cohditions of approval Samples required [] Yes [] No Mud Icg'required []Yes,~ No Hydrogen sulfide measures ~ Yes .I-I No Directional survey required J~ Yes [] No Required working pressure for BOP. E':-':. 1-12M; 1-13M; [~5M; I-IIOM; i--115M; .~". Other: . 0rigina.! Signed By by order of _~/~./'(,,,//~//~ Approved by David W, Johnston Commissioner [ne .cdmm~ss'ion Date Form 10-401 Rev. 12-1-85 Submit it ]Well Name: [P2-44 Well Plan Summary I Type of Well (producer or injector): ]Producer Surface Location: 384' FNL, 1302' FWL, SEC 14, T12N, R14E Target Location: 1189' FNL, 3556 FWL, SEC 14, T12N, R14E Bottom Hole 1286' FNL, 3821' FWL, SEC 14, T12N, R14E Location: I AFE Number: 12C0090 I I Rig: I Pool#7 I Estimated Start Date: I April 1, 1996 I I Operating days to complete: 117 ]MD: ] 10040' I [TVD: 19360' [ I KBE: ]Well Design (conventional, slimhole, etc.): IMonobore 53.2' Formation Markers: (all depths feet RKB) Formation Tops MD TVD Base Permafrost 1787 1786 UG4A (K-15) 5085 5136 Lower Ugnu 6270 6321 West Sak 6885 6936 Minimum mud weight required: 9.5 ppg K-10 8444 8495 K-5 8519 8570 HRZ 8609 8660 Kalubik Not Present Not Present Kupamk 8804 8855 Minimum mud weight required: 10.0 ppg Miluveach 9222 9273 Casing/Tubing Program: (all depths feet RKB) Hole Csg/ Wt/Ft Grade Conn. Length Top Btm Size Tbg OD MDfrVD MD/TVD 30" 20" 94g H-40 WLD 80 GL 80/80 12 1/4" 9 5/8" 47# NT80S NSCC 5066 41/41 5107/5051 8 1/2" 4 1/2" 12.6# 13CR80 NSCT 5083 4957/4910 10040/9360 TBG 4 1/2" 12.6# 13CR80 NSCT 4917 40/40 4957/4910 P2-44 Well Plan Sumn. j Page 2 Logging Program: Open Hole Logs: Surface Production Cased Hole Logs: MWD ordy MWD GRJResistivity (From top of HRZ to TD) GR from West Sak to Kuparuk (MAD) GR/USIT/CET/CCL (optional) Mud Program: I Special Considerations~ [ 3% KCL mud through Kupamk Surface Mud Properties: Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.7 300 40-60 30-60 60-80 9-10 15-25 Intermediate Mud Properties: Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.5 50 20-40 15-20 20-30 9-10 4-6 Production Mud Properties: 3% KCL (open hole change over) Density PV Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.8 to 8-15 25-30 5-15 10-20 9-10 4-6 10.2 HTHP< 15 Well Control: Well control equipment consisting of 5000 psi WP pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional' KOP: 500' Maximum Hole Angle: Close Approach Wells: 29.5° angle @ 110° azimuth P2-46 (producer): 63' @ 4500'; shut-in to 4700' 3/25/96 SMS P2-44 Well Plan Sumn. j Page 3 P2-44 Drilling Hazards/Risks Abnormal differential reservoir pressure are not expected in this well. Original reservoir pressure is 4350 psi at 8800' TVD. The most likely reservoir pressure is estimated at 4200 psi (9.5 ppg), but could range from 4250 to 4350 psi at 8800' TVD. P2-46 are close approach wells and will be shut-in from spud until passing the shut-in zone. Well Control: Well control equipment consisting of 5000 psi WP 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. Contact: Adrian Clark 564-5510 Superintendent Steve Shultz 564-5405 SDE Larry Wolfson 564-4720 Ops Engineer 3/25/96~SMS P2-44 Well Plan Sm. a, Page 4 Operations Summary o . . . . . . 10. POST 11. MIRU drilling rig. NU and function test diverter. Spud well and drill 12 1/4" hole to the KOP at 500' MD. Kick-off and build angle to 29.5° inclination at 110° azimuth. Hold angle to 5107' MD (surface hole casing point). Run and cement 9 5/8" casing; perform top job. Test casing to 3000 psi for 10 minutes. Nipple up Bop's and test same to 5000 psi. Note AOGCC witness or waiver on the morning report. PFLI 8 1/2" BHA, drill 10' new hole and perform LOT. Drill ahead holding tangent angle and azimuth to top of HRZ at 9238'. Perform open-hole change over to 3 % KC1 polymer mud at 10.0 ppg and drill to 10040'. Obtain LWD logs through Kupamk and MAD pass on trip out of hole. POH and stand back drill pipe. Run 4 1/2" NT-13Cr-80 liner and cement per attached cement program--displace with seawater. Bump plug and set liner top packer. Release and displace 9 5/8" casing to filtered seawater. Run dummy seal assembly and test the casing to 4000 psi for 30 minutes. Run 4 1/2" NT- 13Cr-80 tie-back string/completion assembly. Sting liner tieback seals into liner top. Test tubing and annulus to 4000 psi. Shear RP valve in top GLM. Displace tubing to diesel, U,tube to freeze protect the annulus. ND BOP and NU tree assembly. Test tree assembly to 5000 psi. Secure well, release rig. RIG WORK Replace RP valve with dummy or GLV as required. Perforate and flow test well. 3/25/96 SMS P2-44 Cement (Excel4) Surface Casing Casing depth 5107 ft Spacer 75 bbls Fresh water Casing size 9.625 in Casing ID 8.681 in LEAD (TYPE 'E' PERMAFROST) Casing weight 47 Ib/ft Volume 1060 Sacks (2301 ft3) (410 bbls) Bit diameter 12.25 in Length 4319.16 ft Excess factor 1.7 Yield 2,17 ft3/sack Shoe track 80ft Density 12 ppg !ClRC TEMP 501 Deg F TOC 40 ft MD Top of Lead 40 ft Mix water ,11.55 gps 50° - 65° Fresh Top of Tail 4359,16 ft Thicken time :4 hrs TAIL (Class 'G' + 2% CaCl2 accelerator ) Volume 375 Sacks' (431 ft3) (77 bbls) Length 747,84' ft Yield 1.15 Density 15.8 ppg TOC 4359.16 ft Mix water 5 gal/sk Fresh Thicken time 3.5 hrs i TOP JOB (Type 'E' PERMAFROST) Volume 250 Sacks (115 ft3) (21 bbls) Yield 2.17 ft3/sack Density 12 ppg Mix water 11.55 gal/sk Fresh Production Liner Casing depth 10040 ft Spacer 70 bbls NSCI SPACER Casing size 4.5 ~n Casing ID 3.958 in Slurry Class 'G' cement Casing weight 12.6 Ib/ft 15 #/sk Silicalite Hole dia. w/wash 9.75 in 0.3% CFR3 dispersant Excess factor I 0.8% HALAD 344 Fluid loss Shoe track 80 ft HR-5 (as required ) CIRC TEMP 140 Deg F Top of Cement 5085 ft Volume 990 Sacks (2030 ft3) (361 bbls) Length 4955 ft Yield 2.05 ft3/sack Density 13.1 PPg TOC 5085 ft MD Thicken time 3 1/2 to 4 1/2 hrs Page I P~c F.~-44. ~3 -'JOo o 500 VE~TZON_ S~CT~O~I ~, TVD 9360.15 I~ VS E~,77 N/S c~01.89 .....~ ~.~..._:: , ~.?.~,,v,, ~ Su~cy Reformat: W~ J HEAD Refctga~c World Coordinak~ LaL 70.24.01 N - Long. 48.31.20 W Refea~oe GRID SyUea: ,~t~, Smc Plane Zoee: AI~ "~ 4 Refc~ace GRID Cooaiiaa~: (fi): 5998199.21 N 68L~. $7.57 E NO~lh Alisncd To: TEU~ NORTH Proposal Report Calculated using the Minimum Curvature Method Computed u~ing WIN-CADDS REI/2.2.1 Vet'fica/Section Plane: 109.69 deg. WELLPLAN FEASIBILITY STUDY This pfaff Il ~or f~atibillly porpo~s o~ly it hos not yet been c~rtlfladl Daa:: 3/2: Time: 2:25 Last Revision: 3/2: m.44 w~ lVkata~d Ltd DdR Subsea TVD Co~ .se T O T A L GRID Coordinates aosm'e Vertical Build Walk DIS Cum. Expected Toud Max Hot Min Hot Dir. Vcn Survey Tool [k-lxh Dir. Dcplh · Lct.".h RectangulatOffsc~s Norflfing F. auling Dist. Dir. Scction Rate Ratc Dogleg RcclangularCoords Enor Favor MaxErr Eaor (f0 (deg.) (deg.) (f0 (fi) C'.) (ft) (ft) (f0 (fi) (ft) (deg.) (fi) (dg/100f0 (dg/100ft) (dg/100ft) (deg) (ft) (ft) (fi) (ft) (deg.) (fi) 0.00 0.00 0.00 -50.80 0.00 .00 0.00N 0.00E 5998199.21 681547.57 0,0C@ 0.00 0.00 0.00 0.00 0.00 0.0 0.00N 0.00E 0.00 0.00 0.00 0.00 BPHM-PBD KOPISTART OF BUILD @ 1.00deg/100 ft 500.00 0.00 0.00 449.20 500.00 50;,:00 0.00N O.00E 5998199.21 681547.57 0.0C@ 0,00 0.00 0,00 0.00 0.00 0.0 0.00N 0.00E 2.32 2.32 0.00 0,67 BPHM-PBD 600.00 !.00 325.00 549.19 599.99 10O.00 0.7IN 0.SCW 5998199.91 681547.05 0.8-/@325.00 -0.71 1.00 0.00 1.00 !.0 0.7iN 0.SC'W 2,46 2.46 55.00 0.82 BPHM-PBD 700.00 2.00 325.00 649.16, 699.96 10,'.00 2.86N 2.{EW 5998202.02 681545.50 3.4~;@325.00 -2.85 i.00 0.00 1.00 2.0 2.86N 2.01W 2.63 2.62 55.00 0.98 BPHM-PBD 800.00 3.00 325.00 749.06 799.86 I{~ 00 6.43N 4.5CW 5998205.53 681542.91 7.85@325.00 -6.41 !.00 0.00 '!.00 3.0 6.42N 4.52W 2.83 2.80 55.00 1.13 BPHM-PBD END OF BUILD 900.00 4.00 325.00 848.88 899.68 10 .00 11.43N 8.01W 5998210.44 681539.29 13.9~@325.00 -! 1.39 i.00 0.00 1.00 4.0 ! i.41N 8.0~V 3.05 2.99 55.00 1.28 BPHM-PBD START OF CURVE ~ 1.00 deg/100 ft !100.00 4.00 325.00 1048.39 1099.19 2t2'. X) 22.86N 16.01W 5998221.67 681531.01 27.91@325.00 -22.77 0.00 0.00 0.00 4.0 22.82N 16.0EW' 3.57 3.41 55.00 !.58 BPHM-PBD 1200.00 3.00 325.00 i!48.20 !199.00 lC" )0 27.86N 19.51W 5998226.59 681527.39 34.01~325.00 -27.75 -I.00 0.00 !.00 5.0 27.82N 19.57W 3.83 3.63 55.00 1.73 BPHM-PBD 1300.00 2.00 325.00 1248.10 1298.90 10 ~0 31.43N 22.01W 5998230.10 681524.80 38.37~325.00 -31.31 -i.00 0.00 !.00 6.0 31.39N 22.0~/ 4.08 3.86 55.00 1.88 BPHM-I~D · 1400.00 1.00 325.00 1348.07 1398.87 10 )0 33.58N 23.51W 5998232.21 681523.25 40.9~@325.00 -33.45 -i.00 0.00 i.00 7.0 33.53N 23.5L~ 4.31 4.08 55.00 2.02 BPHM-PBD 1500.00 0.00 0.00 1448.06 1498.86 10' '}0 34.29N 24.01W 5998232.91 681522.73 41.8'/@325.00 -34.16 -I.00 0.00 1.00 8.0 34.25N 24.0LAW 4.53 4.31 55.00 2.17 BPHM-PBD B. Penmfto~ 1786.94 0.00 0.00 1735.00 1785.80 28(:.:}4 34.29N 24.01W 5998232.91 681522.73 41.8'/@325.00 -34.16 0.00 0.00 0.00 8.0 34.25N 24.0L~/ 5.18 4.99 55.00 2.60 BPHM-PBD 2000.00 0.00 0.00 1948.06 1998.86 21:' ~6 34.29N 24.01W 5998232.91 681522.73 41.87@325.00 -34.16 0.00 0.00 0.00 8.0 34.25N 24.0L~r 5.67 5.50 55.00 2.92 BPHM-PBD START OF BUILD ~ :Lr~0 deg/100 ft ·I/ 3900.00 0.00 0.00 3848.06 3898.86 190( '~) 34.29N 24.01W 5998232.91 681522.73 41.87@325.00 -34.16 0.00 0.00 . 0.00 8.0 34.25N 24.08W 10.38 10.28 55.00 5.77 BPllM-PBD 4000.00 2.50 110.20 3948.03 3998.83 i0;.' '~ 33.54N 21.9'/W 5998232.21 681524.80 40.0S0326.78 -31.98 2.50 0.00 2.50 10.5 33.48N 22.04W 10.65 10.53 49.69 5.94 BPHM-PBD 4100.00 5.00 110.20 4047.81 4098.61 10C,)0 31.28N 15.83W 5998230.10 681530.99 35.0~@333.16 -25.44 2.50 0.00 2,50 13.0 31,19N 15.91W 10.94 10.77 41.58 6.14 BPHM-PBD ~200.00 7.50 il0.20 4147.21 4198.01 10~. gO 27.52N 5.61W 5998226.59 681541.29 28.0S@348.48 -14.56 2.50 0.00 2.50 15.5 27.34N 5.73W . 11.27 10.98 35.43 6.38 BPHM-PBD 4300.00 10.00 !10.20 4246,04 4296.84 10C.gO 22.27N 8,66E 5998221.69681555,69. 23.9C@ 21.26 0,66 2.50 0.00 2.50 18.0 21.92N 8,49£ 11.65 11.18 31.52 6.65 BPHM-PBD : .. Proposal Report Pa~ Date: 3/22 Wellpath ID: P2-44 ¥ Measured incl Drift Sub~,ea TVD Ce ~ T O T A L GRID Coordinates Closure Vertical Build Walk DIS Cum. Expected Total Max Hot Min Hot Dir. Vert Survey Tool Depth Dh'. Depth Lc -.~h R~ctangular Offsets Northing Fasting Disc Dir. Section Rate Rate Dogleg Rectangular Comds F. nor Error Max Ea' Error (fi) (deg.) (deg.) (ft) (fi) ".) (f0 (ft) (fi) (ft) (fi) (deg.) (fi) (dg/100ft) (dg/10Oft) (dF/100ft) (deg) (ft) (ft) (ft) (fi) (deg.) (ft) 4400.00 12.50 110.20 4344.11 4394.91 I~,:.00 15.54N 26.97E 5998215.40 681574.16 31.1-~O 60.05 20.16 2.50 0.00 2_50 20.5 14.93N 26.70E 12.11 !1.36 28.97 6.97 BPHM-PBD 4500.00 15.00 110.20 4441.23 4492.03 !¢.=:.00 7.33N 49.28E 5998207.74 681596.65 49.820 81.54 43.93 2.50 0.00 2.50 23.0 6.37N 48.87E 12.67 11.51 27.20 7.31 BPHM-PBD 4600.00 17.50 ! 10.20 4537.23 4588.03 I¢'..00 2.33 S 75.54E 5998198.72 681623.14 75.5'/0 91.76 71.91 2.50 0.00 2.50 25.5 3.78 S 74.95E 13.35 11.66 25.91 7.69 BPHM-PBD 4700.00 20.00 110.20 4631.92 4682.72 I:..00 13.42S 105.70E 5998188.36 681653.56 106.550 97.24 104.05 2.50 0.00 2.50 28.0 15.50S !04.89E 14. i9 11.79 24.92 8.11 BPHM-PBD 4800.00 22.50 110.20 4725.11 4775.91 IC'.~.~00 25.94S 139.72E 5998176.68 681687.87 142.1COI00.52 140.29 2.50 0.00 2.50 50.5 28.80S 138.61E 15.23 11.90 24.14 8.55 BPHM-PBD 4~00.00 25.{X} !!0.20 4816.63 4867.43 ' I~. =.00 39.84S 177.51E 5998163.70 681725.99 181.93Oi02.65 180.56 2.50 0.{30 2.50 33.0 43.67S 176.05E 16.47 12.00 23.52 9.03 BPHM-PBD 5000.00 27.50 110.20 4906.31 4957.11 lC ~.00 55.11S 219.02E 5998149.45 681767.85 225.840!04.12 224.78 2.50 0.00 2.50 35.5 60.08S 217.14E 17.96 12.10 23.02 9.53 BPHM-PBD END OF BUILD 506~..21 29.13 110.20 4963.72 5014.52 6.'..:21 65.79S 248.04E 5998139.48 681797.12 2.56.620104.85 255.71 2.50 0.00 2.50 37.1 71.595 245.86E 19.05 12.16 22.74 9.87 BPHM-PBD CASINO i=OINT ODs9~/Sin. ID=8.68in. We~ht,.'47.001b/ft. 5106.74 29.13 110.20 5000.00 5050.80 4..54 72.77S 267.02E 5998132.96 681816.26 276.7~OI05.24 275.93 0.00 0.00 0.00 37.1 72.77S 267.02E 0.00 0.00 0.{30 0.00 BPHM-PBD W. Sak 7264.69 29.13 110.20 6885.00 6935.80 215'..95 435.44S 1252.91E 5997794.47682810.64 1326.42@!09.16 1326.36 0.00 0.00 0.00 37.1 469.295 1240.40E 64.16 21.34 20.82 15.32 BPHM-PBD 9238.32 29.13 110.20 8609.00 8659.80 197~.63 767.14 S 2154.59 E 5997485.00 683720.13 2287.080 109.60 2287.08 0.00 0.00 0.00 37.1 826.15 S 2132.83 E 106.95 30.70 20.56 20.88 BPHM-PBD Tarot 8/9/95/'fKU 9461.56 29.13 110.20 8804.00 8854.80 22.~.'24 804.66 S 2256.58 E 5997450.00 683823.00 2395.75@ 109.63 2395.75 0.00 0.00 0.00 37.1 866.52 S 2233.77 E i 11.$1 31.78 20.54 21.52 BPHIvl-PBD OWC 9764.93 29.13 !!0.20 9069.00 9119.80 30'.37 855.64S 2395.18E 5997402.45 683962.80 2543.420109.66 2543.42 0.00 0.00 0.00 37.1 921.37S 2370.95E 118.43 33.26 20.52 22.41 BPHM-PBD 9929.88 29.13 !10.20 9213.08 9263.88 16.~95 883.36S 2470.53E 5997376.59 684038.82 2623.710109.68 2623.71 0.00 0.00 0.00 37.1 951.20S 2445.53E 122.02 34.07 20.51 22.89 BPHM-PBD D.4LV 9940.08 29.13 ! 10.20 9222.00 9272.80 I'(i :21 885.08 S 2475.20 E 5997374.99 684043.52 2628.680 109.68 2628.68 0.00 0.00 0.00 37.1 953.04 S 2450.15 E 122.25 34.12 20.51 22.92 BPHM-PBD ,, CASING POINT OD s 4 I/2 in, ID =: 3.92 in. Weight t.~13.50 lb/fL 10040.08 29.13 !10.20 9309.35 9360.15 10C~0 901.89S 2520.88E 5997359.31 684089.60 2677.3(~@109.69 2677.36 0.00 0.00 0.00 37.1 971.12S 2495.36E 124.43 34.60 20.51 23.21 BPHM-PBD ~...' .. ~ ,o TREE: 4" CRA - 5M CIW WELLHEAD: 11" FMC Monobore Gen 6 P2-44 RT-GL = 40.7' GL-SL = 12.2' 4 1/2", 12.6 #/ft, 13CR80, NSCT Tubing (3.958"1D) 2100' Tie Back Sleeve 4940' Liner Top Pkr-ZXP 4957' Liner Hanger 4967' 9-5/8", 47#/ft, HS-95, 5107' -- NSCC (8.681") KOP: 500' MAX ANGLE: 29.5° to TD 4 1/2" 12.6#/ft, 13Cr80, 10040' NSCT (3.958" ID) 00' 4 1/2" TR SSSV HES Series 10 GAS LIFT MANDRELS (Camco MMG 4-1/2" x 1-1/2") No MD (RKB) TVD Valve I I jt above Deal assy Dummy 2 ± 4000' _+4000' RP-2900 5050' X Nipple (3.813" ID) 2 jts below the liner hanger PERFORATION SUMMARY Ref Log: Size Interval SPF Open/Sqzd 8700' X Nipple (3.813" ID) _+100' above TKU 9960' Landing Collar DATE 3/25/96 REV. BY COMMENTS SMS Proposed Completion Point Mclntyre WELL: P2-44 APl NO: 50-029-xxxxx Shared Services Drilling MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 23, 1996 THRU: Blair Wondzell, d3,J~,~ FILE NO: P. I. Sula.er~isor a211cwdd.doc FROM: John Spaulding ~/.,,, SUBJECT: Petroleum lnsp. BOPE Test Pool 7 ARCO Pt. Mclntyre P2-20 Prudhoe Oil Pool PTD 96-59 Saturday March 23, 1996: I traveled to ARCO's Pt. Mc Intyre Field well P2-20 to witness the BOPE Test on Pool Rig 7. The AOGCC BOPE test report is attached for reference. The B©PE tested well with 3 failures observed, all failures were valves located on the choke manifold. These valves were greased and re-tested OK. I found the rig to be very good condition and well laid out. All access areas to the rig were being kept open and clean. Summary' I witnessed the successful BOPE test on Pool rig 7, 3 failures, 3 hour test time. Attachments: a211cwdd.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8" Test: Initial Workover: DATE: Pool Rig No. 7 PTD # 96-59 Rig Ph.# ARCO Rep.: Jim Davidson P2-20 Rig Rep.: Tommy Johnson Set @ 5072'md Location: Sec. 14 T. 12N R. 14E Meridian Umiat Weekly X Other 3/23/96 659-4815 TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location ok Standing Order Posted yes BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign yes Drl. Rig ok Hazard Sec. yes Quan. Test Press. P/F I 300/3,000 I 500/5,000 I 500/5,000 I 500/5,000 I 500/5,000 2 500/5,000 I 500/5,000 N/A FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Test Pressure P/F 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 16 Test Pressure P/F 500/5,000 P* 38 500/5,000 P 2 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 2,950 I P Pressure After Closure 1,400 I P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 32 Trip Tank ok ok System Pressure Attained 3 minutes 15 Pit Level Indicators ok ok Blind Switch Covers: Master: X RemS)re: Flow Indicator ok ok Nitgn. Btl's: 6 @ 2100 average Math Gas Detector ok ok Psig. H2S Gas Detector ok ok sec. sec. X TEST RESULTS Number of Failures: 3 "' ,Test Time: 3.0 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The first bank of 3 valves on the choke manifold leaked and were greased and re-tested ok." Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24- HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-021L (Rev.12/94) A21LCWDD.XLS .,eLL PERMIT CHECKLIST FIELD POOL COMPANY INIT CLASS PROGRAM: exp [] dev~ redrll [] serv [] wellbore seg [] UNIT# //~ ON/OFF SHORE ~ ADMINISTRATION ENGINEERING 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 ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. 10. Operator has appropriate bond in force ........ ll. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... REMARKS D~TE 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18 CMT will cover all known productive horizons ...... 19 Casing designs adequate for C, T, B & permafrost .... 20 Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23 If diverter required, is it adequate .......... 24 Drilling fluid program schematic & equip list adequate 25 BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~ psig~ 27. Choke manifold complies w/API RP-53 (M~y 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y )Y / _ ~ 33. Seabed condition survey (if off-shore) ........ ~ N ~ 34. Contact name/phone for weekly progress reports . . ./. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: Z O -! .... ~,,~klist rev 11195 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. .. No special effort has been made to chronologically organize this category of information. JUL Anchor~e * ALASKA COMPUTING CENTER * . * ....... SCHLUMBERGER ....... . ............................ ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAIVE : P2-44 FIELD NAME : POINT MCIAFI~'RE BOROUGH : NORTH SLOPE STATE : ALASKA API 1VTJMBER : 50-029-22666-00 REFERENCE NO : 96119 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : P2-44 FIELD NAME : POINT MCINTYRE BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22666-00 REFERENCE NO : 96119 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUL-1996 14:oJ PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 96/07/25 ORIGIN : FLIC REEL NAI~E : 96119 CONTINUATION # : PREVIOUS REEL : CO~ : ARCO ALASKA, INC., POINT MCINTYRE P2-44, API# 50-029-22666-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/07/25 ORIGIN : FLIC TAPE NAME : 96119 CONTINUATION # : 1 PREVIOUS TAPE : COM~fEi~f : ARCO ALASKA, INC., POINT MCINTYRE P2-44, API# 50-029-22666-00 TAPE HEADER POINT MCINTYRE t~rDIM~D 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 1ST STRING 2ND STRING P2-44 500292266600 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 25-JUL-96 BIT RUN 1 ......... 96119 LEVAD PEAK BIT RUN 2 BIT RUN 3 14 12N 14E 384 1302 53.05 53.05 11.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9. 625 5114.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUL-1996 14:o2 3RD STRING PRODUCTION STRING REMARKS: Well drilled 06-APR through 08-APR-96 with CDR/CDN. Ail data was collected in a single bit run. MAD data was collected as washdown data prior to drilling this interval. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUFiBER: 1 EDITEDMERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUN, ViablY LDWG TOOL CODE START DEPTH STOP DEPTH MAD 4995.0 7498.0 MWD 7498.0 10013.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH .............. $ MERGED DATA SOURCE LDWG TOOL CODE $ No depth adjustments were made per Gordon Pospisil. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... MAD MWD BIT RUN NO. MERGE TOP MERGE BASE .............................. 1 4995.0 7498.0 1 7498.0 10013.0 LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUL-1996 14:oJ PAGE ** 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 O. 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 ** NAFiE 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 630370 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OHMM630370 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OH~k~630370 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OPi~ff~630370 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OI~4M 630370 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OPE~M630370 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 630370 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 630370 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630370 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB MWD G/C3 630370 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 630370 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 630370 O0 000 O0 0 1 1 1 4 68 0000000000 CALNMWD IN 630370 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 630370 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10012.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 137.373 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF. MWD CALN.MWD -999.250 NPHI.MWD -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUL-1996 14:o~ PAGE: DEPT. 10000.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 131.776 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN. MWD -999.250 NPHI.MWD -999.250 DEPT. 8000.000 RA.MWD VRP.MWD 3.317 DER.MWD GR.MWD 103.120 RHOB.MWD CALN. MWD 8.730 NPHI.MWD DEPT. 6000.000 RA.MWD VRP.MWD 1.994 DER.MWD GR.MWD 62.620 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 4995.000 RA.MWD VRP.MWD -999.250 DER.MWD GR.MWD 27.060 RHOB.MWD CALN. MWD -999.250 NPHI.MWD 3.602 RP.MWD 3.422 ROP.MWD 2.492 DRHO.MWD 26.900 2.024 RP.MWD 2.021 ROP.MWD -999.250 DRHO.MWD -999.250 -999.250 RP.MWD -999.250 ROP.MWD -999.250 DRHO.MWD -999.250 3.340 207.832 0.032 2.020 -999.250 -999.250 -999.250 -999.250 -999.250 VRA . MWD FET.MWD PEF. MWD VRA . MWD FET.MWD PEF. MWD VRA . MWD FET.MWD PEF. MWD -999.250 -999.250 -999.250 3. 525 O. 402 3. 428 2.009 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAIVE : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE : 96/07/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE lqUM~ER: 2 EDITED~!ERGEDMAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: 0.5000 FILE SUMMARY LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUL-1996 14:oJ PAGE: LDWG TOOL CODE .............. $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: START DEPTH STOP DEPTH 4995.0 7498.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE This file contains the MAD data collected as washdown data prior to drilling the lower interval. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAi~E 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 630370 O0 000 O0 0 2 1 1 4 68 0000000000 RA MAD 0P~4~630370 O0 000 O0 0 2 1 1 4 68 0000000000 RP MAD 0P~4~630370 O0 000 O0 0 2 1 1 4 68 0000000000 VRA MAD 0H~I630370 O0 000 O0 0 2 1 1 4 68 0000000000 VRP MAD OH~ 630370 O0 000 O0 0 2 1 1 4 68 0000000000 DER MAD 0H~630370 O0 000 O0 0 2 1 1 4 68 0000000000 FET MAD HR 630370 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing. Schlumberger Alaska Computing Center 25-JUL-1996 14:oJ PAGE: NA~E SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) GR MAD GAPI 630370 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7438.000 RA.MAD 3.163 RP.MAD 2.955 VRA.MAD VRP.MAD 2.957 DER.MAD 3.022 FET.MAD -999.250 GR.MAD DEPT. 6000.000 RA.MAD 2.024 RP.MAD 2.020 VRA.MAD VRP.MAD 1.994 DER.MAD 2.021 FET.MAD -999.250 GR.MAD DEPT. 4995.000 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD VRP.MAD -999.250 DER.MAD -999.250 FET.MAD -999.250 GR.MAD 3.094 -999.250 2.009 62.620 -999.250 27.060 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED MAD PASSES Depth shifted and clipped curves; for each pass of each run in separate files. MAD RUNNUM~ER: 1 MAD PASS NUMBER: 1 DEPTH INC~: 0.5000 FILE SUMMARY LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUL-1996 14:uJ PAGE: LDWG TOOL CODE START DEPTH MAD 4995.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (M~ASUREDDEPTH) STOP DEPTH .......... 7498.0 BASELIArEDEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... MAD ....... This file contains the MAD data collected as washdown data prior to drilling the lower interval. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 32 66 1 66 0.5 FT 32 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630370 O0 000 O0 0 3 1 1 4 68 0000000000 RA MAD OH~ 630370 O0 000 O0 0 3 1 1 4 68 0000000000 RP MAD OH~I 630370 O0 000 O0 0 3 1 1 4 68 0000000000 VRA MAD OH~ 630370 O0 000 O0 0 3 1 1 4 68 0000000000 VRP MAD OH~ 630370 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUL-1996 14:~ PAGE: 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) DER MAD 0PE~4630370 O0 000 O0 0 3 1 1 4 68 0000000000 FET MAD HR 630370 O0 000 O0 0 3 1 1 4 68 0000000000 GR MAD GAPI 630370 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 7438.000 RA.MAD 3.163 RP.MAD 2.955 VRA.MAD VRP.MAD 2.957 DER.MAD 3.022 FET.MAD -999.250 GR.MAD DEPT. 6000.000 RA.MAD 2.024 RP.MAD 2.020 VRA.MAD VRP.MAD 1.994 DER.MAD 2.021 FET.MAD -999.250 GR.MAD 3.094 -999.250 2.009 62.620 DEPT. 4995.000 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD -999.250 VRP.MAD -999.250 DER.MAD -999.250 FET.MAD -999.250 GR.MAD 27.060 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 96/07/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUM~ER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREME2VT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUL-1996 14:uJ PAGE: FILE SU~R~RY VENDOR TOOL CODE START DEPTH MWD 7498.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (M~4ORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10013.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... CDR RESIST./GR CDN NEUT./DENS. $ 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 CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OPf~f) AT TEMPERATURE (DEGF): MUD AT MEASO-RED 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): REMARKS: ************ RUN 1 ************* DRILLED INTERVAL 7498' - 10013' MAX ANGLE AT 6272' OF 32.6 DEG 08-APR-96 FAST2.5 5.0 MEMORY 10013.0 4995.0 10013.0 80 18.8 29.9 TOOL NUMBER ........... RGS751 NDS055 8.500 5114.0 LSND 10.20 48.0 16000 O. 230 68.0 0.235 68.0 SANDSTONE 2.65 1.0 20000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUL-1996 PAGE: 10 RES TO BIT: 61.31'; GR TO BIT: 72.31' NEUT TO BIT: 125.49'; DENS TO BIT: 118.97' TD WELL @ 05:30 08-APR-96 MAD PASS DATA COLLECTED (CDR ONLY) 5114'-7498' DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFIE 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 630370 O0 000 O0 0 4 1 1 4 68 0000000000 RA LW1 OIff4M630370 O0 000 O0 0 4 1 1 4 68 0000000000 RP LW1 OPff~4 630370 O0 000 O0 0 4 1 1 4 68 0000000000 DER LW1 OH~ff4630370 O0 000 O0 0 4 1 1 4 68 0000000000 ROP LW1 FPHR 630370 O0 000 O0 0 4 1 1 4 68 0000000000 FET LW1 HR 630370 O0 000 O0 0 4 1 1 4 68 0000000000 GR LW1 GAPI 630370 O0 000 O0 0 4 1 1 4 68 0000000000 RHOB LW1 G/C3 630370 O0 000 O0 0 4 1 1 4 68 0000000000 DRHO LW1 G/C3 630370 O0 000 O0 0 4 1 1 4 68 0000000000 PEF LW1 BN/E 630370 O0 000 O0 0 4 1 1 4 68 0000000000 CALNLW1 IN 630370 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI LW1 PU-S 630370 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUL-1996 14:o~ PAGE: 11 ** DATA ** DEPT. 10012. 000 RA. LW1 ROP. LW1 137.373 FET. LW1 DRHO. LW1 -999. 250 PEF. LW1 DEPT. 10000. 000 RA. LW1 ROP. LW1 131. 776 FET. LW1 DRHO. LW1 - 999. 250 PEF. LW1 DEPT. 8000. 000 RA. LW1 ROP. LW1 207.832 FET. LW1 DRHO . LW1 O . 032 PEF. LW1 DEPT. 7373. 000 RA. LW1 ROP. LW1 -999. 250 FET. LW1 DRHO. LW1 - 999. 250 PEF. LW1 -999. 250 RP. LW1 -999. 250 GR. LW1 -999. 250 CALN. LW1 -999. 250 RP. LW1 -999. 250 GR. LW1 -999. 250 CALN. LW1 3. 602 RP. LW1 O . 402 GR. LW1 3. 428 CALN. LW1 -999. 250 RP. LW1 -999. 250 GR. LW1 -999. 250 CALN. LW1 -999. 250 DER. LW1 -999. 250 RHOB. LW1 -999. 250 NPHI. LW1 -999. 250 DER. LW1 -999. 250 RHOB. LW1 -999. 250 NPHI. LW1 3.340 DER.LW1 103 . 120 RHOB. LW1 8. 730 NPHI.LWl -999. 250 DER. LW1 -999. 250 RHOB. LW1 -999. 250 NPHI. LW1 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.422 2.492 26.900 -999.250 -999.250 30.800 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/25 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: 1 MAD PASS NUFiBER : 1 DEPTH INCREM~Fr: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUL-1996 14:oJ PAGE: 12 MAD 4995.0 $ LOG HEADER DATA 7438.0 DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR CDN NEUT./DENS. $ 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 CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~ff4) AT TEMPERATURE (DEGF) : MUD AT MEAStHAFJ9 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): 08-APR-96 FAST2.5 5. OC MEMORY 10013.0 4995.0 10013.0 26.3 32.0 TOOL NUMBER ........... RGS751 NDS055 8.500 5114.0 LSND 10.20 48.0 0.230 68.0 O. 235 68.0 ************ RUN1 ************* DRILLED INTERVAL 7498' - 10013' MAX ANGLE AT 6272' OF 32.6 DEG RES TO BIT: 61.31'; GR TO BIT: 72.31' NEUT TO BIT: 125.49'; DENS TO BIT: 118.97' 20000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUL-1996 14:u~ PAGE: 13 TD WELL @ 05:30 08-APR-96 MAD PASS DATA COLLECTED (CDR ONLY) 5114'-7498' DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 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 SAMP ELE~ CODE (HEX) DEPT FT 630370 O0 000 O0 0 5 1 1 4 68 0000000000 RA MAI OP~4~ 630370 O0 000 O0 0 5 1 1 4 68 0000000000 RP MAI OH~ 630370 O0 000 O0 0 5 1 1 4 68 0000000000 DER MAi OH~ 630370 O0 000 O0 0 5 1 1 4 68 0000000000 FET MAi HR 630370 O0 000 O0 0 5 1 1 4 68 0000000000 GR MAI GAPI 630370 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 7438.000 RA.MA1 3.163 FET.MA1 -999.250 GR.MA1 -999.250 RP.MA1 2.955 DER.MAI 3. 022 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUL-1996 14:0~ PAGE: 14 DEPT. 6000. 000 RA.MA1 2. 024 FET.MA1 -999. 250 GR.MA1 62. 620 DEPT. 4995.000 RA.MA1 -999.250 FET.MA1 -999.250 GR.MA1 27.060 RP.MA1 RP . MAI 2. 020 -999.250 DER.MAI DER. MA1 2. 021 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 96/07/25 ORIGIN : FLIC TAPE NAME : 96119 CONTINUATION # : 1 PREVIOUS TAPE : COMPiENT : ARCO ALASKA, INC., POINT MCINTYRE P2-44, API# 50-029-22666-00 **** REEL TRAILER **** SERVICE NAM~ : EDIT DATE : 96/07/25 ORIGIN : FLIC REEL NA~E : 96119 CONTINUATION # : PREVIOUS REEL : COf4FiENT : ARCO ALASKA, INC., POINT MCINTYRE P2-44, API# 50-029-22666-00