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Home My WebLink About197-2127. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU D-15A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 197-212 50-029-20461-01-00 12086 Surface Intermediate Scab Liner Liner Liner 9021 2654 9704 5165 1116 2977 11202 13-3/8" 9-5/8" 7" x 4-1/2" 7" 2-7/8" 9026 27 - 2681 26 - 9730 3995 - 9160 9215 - 10331 9109 - 12086 27 - 2681 26 - 8344 3926 - 7898 7942 - 8844 7857 - 9021 12013, 12018 2670 4760 7020 7020 13890 11202 4930 6870 8160 8160 13450 11050 - 12000 4-1/2" 12.6# 13cr80, 24 - 8966 9023 - 9022 Conductor 80 20" 28 - 108 28 - 108 4-1/2" Baker S3 Packer 8879 7673 Torin Roschinger Area Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028285 24 - 7743 N/A N/A 354 1371 33111 4249 76 516 400 200 940 1350 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 8879, 7673 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:49 am, Jun 05, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.06.05 06:30:47 -08'00' Torin Roschinger (4662) WCB 1-8-2024 DSR-6/12/23 RBDMS JSB 071723 ACTIVITY DATE SUMMARY 3/7/2023 ***WELL FLOWWING ON ARRIVAL*** R/U POLLARD #57 ***WSR CONT ON 3-8-23*** 3/8/2023 ***WSR CONT FROM 3-7-23*** RAN KJ, 2.25" CENT, 1-3/4" S, BAILER, DEVIATED OUT @ 10,665' SLM KJ, 24' x 2" DUMMY GUNS ( max swell 2.29"o.d.) DRIFT FREELY & S/D @ 10,665' SLM ***JOB COMPLETE, WELL LEFT S/I*** 3/17/2023 Barriers = MV & SSV. 4" CIW "FLS" inline Wing Valve repair (stripped in closed position). Removed & replaced Gate, Seats & rebuilt Bonnet. Pressure Tested 300/low & 5,000/high (passed). ***Job complete*** 3/23/2023 ***WELL S/I ON ARRIVAL*** PRESSURE TEST PCE TO 200#LP-3,000#HP RIH W/ 1-7/16" CHD (1" FN), 2-1/4" PUMP DOWN SUB, 1-11/16" GR/CCL, 1-11/16" BRT, 2" PERF GUN (LOADED 20' W/ 6.5 GRAM RAZOR CHARGES), 1-11/16" LS SETTING TOOL, CIBP (2.1" RIH OD, 43.5' OAL) PUMPED 190 BBL KCL TO LOAD WELL & PUMP TS TO DEPTH PUMPED 38 BBL CRUDE FP ON TUBING TOOL ISSUES AT BOTTOM, UNABLE TO SHOOT THROUGH ADDRESSABLE SWITCHES TROUBLE SHOOT AT BOTTOM POOH TO CHECK TOOLS, SWAP OUT SWITCHES, BRT, & GR/CCL INSTALL & PT NIGHTCAP, LAY DOWN FOR THE NIGHT ***WELL LEFT S/I*** JOB CONTINUED 3/24/2023 3/23/2023 2460/450/0 Assist Eline with pump down TBG, Pumped 4 BBLS 60/40, 190 BBLS KCL, 40 BBLS Crude Eline in control of well upon departure 3/24/2023 JOB CONTINUED FROM 3/23/2023 ***WELL S/I ON ARRIVAL*** PRESSURE TEST PCE W/ T-BIRD TO 200#LP-3,000#HP RIH W/ 1-7/16" CHD (1" FN), 2-1/4" PUMP DOWN SUB, 1-11/16: GR/CCL, 2" BRT, 2" PERF GUN (LOADED 20' W/ 6.5 GRAM RAZORS), 1-11/16" LS, 2.1" CIBP (44' OAL) TOOLS HANG UP GOING INTO LINER, PUMP 2 BPM AND GET TOOLS MOVING, UP TENS NORMAL ONCE TOOLS ARE FREE CONTINUE RIH W/ HAVING TO WORK TOOLS DOWN COMING ON & OFF THE PUMP UNABLE TO PASS 9,950', ATTEMPT TO PUMP 130BBL OF SLICK KCL & 40 BBL CRUDE TO FREE UP TOOLS (UNSUCCESSFUL) SET CIBP @ 9,945' ELMD ***WELL LEFT S/I*** 3/24/2023 T/I/O= 150/450/0 Assist E-line (Perforating) , Pumped 1.5 bbls of 60/40 methanol spear followed by 134 bbls of Crude down the tubing. Pumped 130 bbls of 90* Slick 1% KCL down the tubing. Freeze protected tubing w/ 40 bbls of crude and 2 bbls of 60/40 methanol. FWHPs= 0/450/0 Tag hung on WV, E-line in control of well upon departure. 3/30/2023 CTU #9 1.75" CT 0.156". Job Scope: Mill CIBP & push to btm MIRU CTU 9. MU BOT 2.30" 4 bladed junk mill. RIH ***Continue on WSR 3/31/23*** Daily Report of Well Operations PBU D-15A Daily Report of Well Operations PBU D-15A 3/31/2023 CTU #9 1.75" CT 0.156". Job Scope: Mill CIBP & push to btm RIH w/ BOT 2.312" 4 bladed junk mill. Tagged CIBP @ 9971' CTM / 9986' Mech. Start milling CIBP taking returns. After 35 mins lost WHP. Work plug to bottom @12005'. Dry drift from 9800' to 12013'. FP coil w/ diesel. FP well w/ 38bbls diesel. ***Job Complete. Rig Down for pipe swap and maintenance*** 5/25/2023 LRS CTU #2 - 1.75" Blue Coil. Job Scope: Set CIBP and AddPerf MIRU & MU HES GR/CCL logging toolstring with 2.25" BDJSN. Counter issues at 9000', POOH and Inspect. Make up GR/CCL logging toolstring and RIH. Drift to TD tag at 12018' CTMD and log up to 10000', painting red tie-in flag at 10148'. POOH. ...Continued on WSR 5-26-23.... 5/26/2023 LRS CTU #2 - 1.75" Blue Coil. ***Cont. from WSR 5-25-26*** Job Scope: Set CIBP and AddPerf RIH with GR/CCL logging BHA with 2.25" nozzle to TD tag at 12018' CTMD and log up to 10000', paint red tie-in flag at 11148'. POOH and confirm good data (-12'). MU 2- 7/8" CIBP, RIH and unable to pass ~ 9058' CTM. POOH and add two 1.75" x 4' stingers. RBIH and tag at the same spot. POOH to check tools and the CIBP had sheared off at the shear stud. Make up Venturi BHA with 3.70" mule shoe and RIH. Venturi from 8900' to tag at liner top of 9119' CTMD. POOH and recover only coil shavings. Make up 1.69" milling BHA with 2.25" 6-bladed junk mill and RIH. ...Continued on WSR 5-27-23... 5/27/2023 LRS CTU #2 - 1.75" Blue Coil. ***Cont. from WSR 5-26-26*** Job Scope: Set CIBP and AddPerf RIH with milling BHA and tag CIBP at 11320'. Mill CIBP and push to TD at 12018' CTMD. PU to ~ 9024' and dry drif to 11227' (clean). POOH and MU 2-7/8" CIBP with 1-1/2" bowspring centralizer. RIH and set plug at 11200' . POOH and MU HES GR/CCL logging toolstring in 2.20" carrier with 2.25" BDJSN. RIH and tsg top of CIBP and log up to 10000'. Confirm -11' correction and top of CIBP at 11202' MD. ...Continued on WSR 5-28-23.... 5/28/2023 LRS CTU #2 - 1.75" Blue Coil. ***Cont. from WSR 5-27-26*** Job Scope: Set CIBP and AddPerf Make up Perf gun run #1 with 41' of 2.0" Maxforce perf gun, 6 spf, and RIH. Tie-in to CIBP and Perforate 11069'-11110'. POOH and MU 2.0" x 19' Maxforce, 6 SPF, 60 degree phase gun. RIH, tie-in to CIBP, and perforate 11050' - 11069'. POOH and freeze protect the tubing to 2450' TVD with diesel. RDMO. ***Job Complete*** MU 2-7/8" CIBP withy() 1-1/2" bowspring centralizer. RIH and set plug at 11200'. POOH Make up Perf gun run #1 with 41' of 2.0" Maxforce perf gun, 6 spf, and RIH. Tie-in togg CIBP and Perforate 11069'-11110'. POOH and MU 2.0" x 19' Maxforce, 6 SPF, 60 degree phase gun. RIH, tie-in to CIBP, and perforate 11050' - 11069'. POOH MU HES GR/CCL logging toolstring in 2.20" carrier with 2.25" BDJSN. RIH and tsg top of CIBP g g gg g g g and log up to 10000'. Confirm -11' correction and top of CIBP at 11202' MD Stephanie Pacillo Data Manager Schlumberger Oilfield Services WIRELINE 2525 Gambell St, Ste. 400 Anchorage, AK 99503 Z: Office: (907) 273-1770 DATE: 9 -Jan -14 TRANS#: 6579 DATALOGGED t /9 12014 M K BENDER REC'E JAN 0 8 2011 IDG MakanaK Bender Natural Resources Technician II Alaska Oil & Gas Conservation Commission 333 W. Tn Ave, Suite 100 Anchorage, AY 99501 WELL W -32A CLAF-00051 F Final Field Final X Edit OH LOGDESCRIPTION PPROF 9 -Oct -13 1 1 CD W -32A CLAF-00052 X CNL W/ BORAX 10 -Oct -13 1 1 CD 15-16B CFGK-00041 X PPROF 20 -Oct -13 1 1 CD NK -28 CLAF-00046 X LDL 17 -Sep -13 1 1 CD V-203 CFGK-00035 X PP W/ DEFT W/ GHOST 26SEP113 1 1 CD S-120 BD88-00100 X IPROF 25 -Apr -13 1 1 CD 1-09AIL-21 CNHP-00026 X RST/SIGMA 1 -Dec -13 1 1 CD P2-53 CJ 2C-00113 X PPROF 23 -Nov -13 1 1 CD W-200 C4W7-00088 X PPROF 24 -Sep -13 1 1 CD W-202 CFGK-00028 X MEM PPROF 2 -Sep -13 1 1 CD MPC -10 CCJZ-00082 X (PROF 18 -Sep -13 1 1 CD MPC -06 CCJZ-00081 X (PROF 17 -Sep -13 1 1 CD MPC -19 CCJZ-00083 X (PROF 19 -Sep -13 1 1 CD 01-31 CFMH-00057 X (PROF 22 -Dec -13 1 1 CO 01-31 C4W7-00092 X ISLT 21 -Oct -13 1 1 CD 6-15A C5XI-00122 X PPROF 20 -Oct -13 1 1 CD D -03A C5XI-00123 X PPROF 23 -Oct -13 1 1 CO B -13B CLW -00012 X IPROF 19 -Jul -13 1 1 CD Please return a signed copy to: BP PDC LR2-1 900 E Benson Blvd Anchorage AK 99508 Attn: Sarah Gunkel scNtA14 X / rE,C/lrizee .—K -401 00/ Please return a "signed copy to: Wireline 2525 Gambell St, Suite 400 Anchorage AK 99503 • . bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 March 06, 2011 . a - : U 1 V,. -- j 5 RECEIVED Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 210 333 West 7 Avenue ; ska Oil & Ges Cols. Cut ss fl Anchorage, Alaska 99501 awomtl6 Subject: Corrosion Inhibitor Treatments of GPB D Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D Pad 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, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger 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) Date: 03/04/11 Corrosion • Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement pumped cement date inhibitor sealant date ft bbls ft na gal 0-01 A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 D -05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 D -07B 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 D -08A 2021230 50029203720100 NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 D -10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 D-11B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 0-12 1800150 50029204430000 NA 1.3 . NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 ....................> D -14A 1961530 50029204500100 NA 0.2 NA 0.85 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 • D -17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -19B 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 0-20 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 0-21 1820520 50029207880000 NA 0.2 NA 3.40 2/10/2011 D -22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 D -24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 D -27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 D -29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 D -30B 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D-31A 1960950 50029226720100 _ NA 3.3 NA 27.20 1/19/2011 0-33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 KI::L;I::IVt:U STATE OF ALASKA I A~ OIL AND GAS CONSERVATION COM SION JUL 1 9 2006 REPORT OF SUNDRY WELL OPERA TIONSAlaska Oil & Gas Cons. Commission Anr.horane 1. Operations Performed: o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 197-212 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20461-01-00 7. KB Elevation (ft): 71.4' 9. Well Name and Number: PBU D-15A 8. Property Designation: 10. Field / Pool(s): ADL 028285 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 12086 feet true vertical 9021 feet Plugs (measured) None Effective depth: measured 12022 feet Junk (measured) None true vertical 9022 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2679' 13-3/8" 2679' 2679' 4930 2670 Intermediate 9730' 9-518" 9730' 8344' 6870 4760 Production Liner 1116' 7" 9215' - 10331' 7942' - 8844' 8160 7020 Liner 2977' 2-7/8" 9109' - 12086' 7857' - 9021' 13450 13890 Scab Liner 5083' 7" 3995' - 9078' 3926' - 7832' 7240 5410 ~G.f4t~'~!i;:' .~, t Perforation Depth MD (ft): 11302' - 12000' : \,:";:~,,.' ~:;.., ~/ Perforation Depth TVD (ft): 9021' - 9022' Tubing Size (size, grade, and measured depth): 4-1/2", 12.6# 13Cr80 / L-80 9160' Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Otis 'MHR' packer; 9160'; 7" x 4-112" Baker 'S-3' packer 8879' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft JUL 2 0 2006 Treatment description including volumes used and final pressure: Cut (-9071') and pulled tubing. Run 7" Scab Liner, cement with 150 Bbls (842 cu ft /726 sx) Class 'G'. Run new Chrome tubing. 13. Representative Daily AveraQe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure TubinQ Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Service 181 Daily Report of Well Operations o Exploratory 181 Development 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG DGINJ DWINJ o 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: Contact Doug Cismoski, 564-4303 306-233 Printed Name Terrie Hubble Title Technical Assistant /fð Ar\' tl t2 M'17 07!10¡/V(P Prepared By Name/Number: Signature l/1 ~.YTV '"'I: Phone 564-4628 Date Terrie Hubble, 564-4628 ' Form 10-404 Revised 04/20060 RIG I N A L Submit Original Only e TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum ND = 4" CrN OCT (FMC) BAKER C 71.42' 47.17' 3100' 94@11221' 10364' 8800' 55 e D-15A FROM DRLG - DRAFT 1 13-3IS" CSG, 72#, L-SO, D = 12.347" I I TOP OF 7" SCAB LNR H 3995' Minimum ID = 2.441" @ 9109' TOP OF 2-7/8" LINER 8895' TOP OF2-7/S" LNR H 9109' TOPOF7"LNR I 9215" TOPOF 4-112" TAR..PlPE I 9225' 4-112" TBG, 12.6#, L-SO, .0152 bpf, ID = 3.958" I 19-5/8" CSG, 47#, L-80, D = 8.681" I 9730' PERFORA TlON SUfvNA RY REF LOG: SÆRRY MWD GR ON 02101198 A NGLE AT TOP PERF: 92 @ 11302' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11116" 4 11302 - 11596 C 02107198 1-11/16" 4 11699 - 12000 C 02107/98 SAFETY NOTES: 700@ 10583' AND 90° @ 10795' -·-CHROME TBG*-· 2100' 4-112n HES X NIP, D = 3.813" 2612' -19-5/8" DV PKR I GAS LIFT MANDRELS ST MD lVD DEV TYPE VLV LATCH 4 3211 3207 12 ~ OCR RI< :3 604$ 5494 43 KBG2 DMV RK 2 7911 6901 39 KBG2 DMV RK 1 8770 7588 37 KBG2 DMV RI< PORT DATE o 07105106 o 07105106 o 07105106 o 07105106 8848' 8878' 4-112" HES X NP, D = 3.813" 7" X 4-1/2" Baker 8-3 PKR, D = 3.875" 8953' 4-1/2" HES X NIP, ID = 3.813" 9143' 9160' 9215' 4-1/2" PKR SWS NIP, D = 3.813" 9275' -14-1/2" PKR SWS NIP, D = 3.813" (BEHIND PIPE) 9296' -14-1/2" PKR SWN NIP, D = 3.725" (BEHIND PIPE) 9308' 4-1/2" WLEG TT, D = 3.854" (BEHIND PIPE) 9500' -I BOTTOM OF CEMENT I I MlLLOUT\MNDOW 10331' PBID, LATCH COLLAR 2-7/8" LNR, 6.16#, L-80, .0058 bpf, D = 2.441" DA TE REV BY 07120110 10/04191 02/07198 RRW/CJ COM\ENTS ORIGINAL COMPLETION RWO SIŒTRACK COMPLETION DATE REV BY COWMENTS PRUDHOE BAY UNrr W8...L: D-15A PERMfT No: '1972120 API No: 50-029-20461-01 SEC 23, T11 N, R13E, 2600' SNL & 1067' WEI.. BP Exploration (Alaska) e e D-15A Rig Workover Prudhoe Bay Unit 50-029-20461-01 197-212 Accept Spud: Release: Ri: PRE"RIG WORK 01/11/06 RAN 3.71" CENT TO TOP OF LINER, TAG AT 9098' SLM /9109' MD. SET WEATHORFORD WRP PLUG AT 9067' SLM /9075' MD. BLED PRESSURE OFF TUBING, GOOD SET. 06107/06 PULLED 41/2" WRP PLUG AT 9080' SLM, SET 4.5" PGSL AT 9100' SLM PERFORM CMIT TXIA 2500 PSIG, PASSED. DUMPED (2) 9'X3" DUMP BAILERS FILLED W/ SLUGGITS ON 4.5" PGSL 9099' SLM. 06/08106 DRIFTED TUBING W/3.775" CENT, 3.50" LIB, SD AT 9094' SLM FOR CHEM CUT (LIB SHOWED NO CONCLUSIVE MARKS). 06/10/06 TAGGED TD AT 9108'. SHOT TWO STRAND STRING SHOT FROM 9067' - 9079'. SHOT MEDIUM CHARGE TUBING PUNCHER FROM 9052' - 9054'. SHOT 3.63" CHEMICAL CUTTER AT 9077', MIDDLE OF FIRST FULL JOINT ABOVE TAG. JARRED ONCE TO GET CUTTER FREE. NO PROBLEMS RIH OR POOH. WELL LEFT SHUT IN. TURNED OVER TO DSO. JOB COMPLETE. e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-15A D-15A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/21/2006 Rig Release: 7/6/2006 Rig Number: Spud Date: End: 7/6/2006 6/26/2006 14:30 - 16:00 1.50 MOB P PRE Move off D-25A Install Scaffolding In Cellar for Measurements and to Clean Out CMT from Riser and Drip Pan. Continue to Move to D-15A. 16:00 - 17:00 1.00 MOB P PRE Spot and Shim Rig Over D-15A. 17:00 - 19:30 2.50 RIGU P PRE Installed Double Valve on Annulus, Spot and Berm Cuttings Tank, Spot #2 Pump Mod, Spot #4 Gen Mod. 19:30 - 20:00 0.50 RIGU P DECOMP RlU DSM and Pull BPV, RID DSM. 20:00 - 00:00 4.00 CLEAN P DECOMP RlU tJ Circulate, Take On Sea Water Mixed 40 bbl Hi-Vis Sweep, Test Lines tJ 3000 psi, Reverse Circulated Out Freeze Protection From Tubing at 8 bpm with 800 psi. Pumped 40 bbl Sweep Displaced Well w/140 deg Clean Sea Water at 11.5 bpm with 1260 psi. Monitor Well 6/27/2006 00:00 - 00:30 0.50 WHSUR P DECOMP RlU Set Two Way Check Valve, Tested to 1,000 psi. 00:30 - 01 :00 0.50 WHSUR P DECOMP Bled Off Well Head Pressure,B/D RID Circulating Equipment, 01 :00 - 02:00 1.00 WHSUR P DECOMP Nipple Down Production Tree and Adapter Flange, Check LDS 02:00 - 04:30 2.50 WHSUR P DECOMP Nipple Up BOPE. 04:30 - 12:30 8.00 WHSUR P DECOMP Testing BOPE. 250 psi Low Test, 3,500 psi High Test. Held all Tests for 5 minutes. C/O Choke Valve #14, Repaired Choke Valve #4,5,9. AOGCC Witness of Test Waived By Chuck Sheve 18:006/26/2006. Witnessed By BP WSL and Doyon Tool Pusher. B/D Choke and Kill Line. 12:30 - 13:30 1.00 PULL P DECOMP RlU to Pull 4.5" Completion, RlU to Spool Control Line. 13:30 - 14:00 0.50 BOPSU P DECOMP Test Floor Valves RID Test Equipment. 14:00 - 14:30 0.50 WHSUR P DECOMP RlU DSM Pull Two Way Check, RID DSM. 14:30 - 15:30 1.00 WHSUR P DECOMP M/U Spear Assembly Spear Tubing Pull Hanger @ 150,000# Lay Down Spear Assembly and Hanger. 15:30 - 16:30 1.00 WHSUR P DECOMP Circulating Bottoms Up at 13.5 bpm and 2,000 psi. 16:30 - 19:00 2.50 WHSUR P DECOMP Monitor Well UD 4.5" Tubing. Spooling Control Line. RID Spooling Unit. Recovered 25 Rubber Clamps and 4 SS Bands. All Clamps and Bands Accounted For. 19:00 - 00:00 5.00 WHSUR P DECOMP Continue Laying Down 4.5" Tubing. Total 235 jts Tubing, 5 GLMs, 1 SVLN, 1 Cut Jt =19.87', Cut Jt Approx 4.5"Diameter at cut 19.88 Length. 6/28/2006 00:00 - 01 :00 1.00 PULL P DECOMP Clear and Clean Rig Floor. 01 :00 - 04:00 3.00 FISH P DECOMP M/U BHA #1, BHA Components 8.5" Wash Shoe, TSWP EXT, TSWP Boot Basket, XO, 2 - 7" Boot Baskets, 9.625" CSG Scraper, Bit Sub, Bowen LBS, Bowen Jar, Pump Out Sub, XO, 9 - 4.75" Drill Collars. BHA =331.82' 04:00 - 04:30 0.50 FISH P DECOMP P/U 4" HT-38 Drill Pipe From Pipe Shed to 809'. 04:30 - 05:00 0.50 FISH P DECOMP Service rig. 05:00 - 14:00 9.00 FISH P DECOMP RIH picking up drill pipe from 809' to 9054'. 14:00 - 14:30 0.50 FISH P DECOMP Obtain parameters. Tag 41/2" tubing stub @ 9071'. Rotate & circulate over stub to 9083'. 14:30 - 15:30 1.00 FISH P DECOMP Pump 40 bbl high vis sweep @ 14 bpm @ 3520 psi. 15:30 - 18:30 3.00 FISH P DECOMP Monitor well. POH from 9083' to BHA @ 332'. 18:30 - 19:30 1.00 FISH P DECOMP POH with 9 5/8" casing scraper assy. UD all tools except drill collars. 19:30 - 20:00 0.50 FISH P DECOMP Clear & clean rig floor. 20:00 - 00:00 4.00 FISH P DECOMP P/U 9 518" HES RTTS & RIH to 8437'. 6/29/2006 00:00 - 00:30 0.50 EVAL P DECOMP Continued In Hole w/RTTS to 9,060'. 00:30 - 04:30 4.00 EVAL P DECOMP Set RTTS At 9,060' Pressure Tested to 3,500 psi, Test Failed. Released RTTS Pulled Up Hole to 9,027' Set RTTS, Pressure Tested to 3,500 psi, Test Failed. Pulled Up Hole to 8,917' Set Printed: 7/10/2006 7:22:17 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-15A D-15A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/21/2006 Rig Release: 7/6/2006 Rig Number: Spud Date: End: 7/6/2006 6/29/2006 00:30 - 04:30 4.00 EV AL P DECOMP RTTS, Pressure Tested to 3,500 Psi, Test Failed. On all Pressure Tests above Commuication Between IA and DP Fluid Observed at Surface. Pulled Up Hole to 4,019' Set RTTS Pressure Tested to 3,500 psi For 30 Charted Minutes Good Test. 04:30 - 06:00 1.50 EV AL P DECOMP POOH f/4,019', Stand Back Collars. 06:00 - 06:30 0.50 EVAL P DECOMP Pump Out BOP Stack and Pull Wear Ring. 06:30 - 08:30 2.00 WHSUR P DECOMP RlU to Pull 9 518" Pack Off Through Stack. Pulled Pack Off to Rig Floor. 08:30 - 09:30 1.00 WHSUR N SFAL DECOMP Repair Lock Down Screw. One Lock Down Screw Was Not backed Out Completely, Damaged Lock Down Screw While Pulling Pack Off Past LDS. Remedial Work Required. 09:30 - 11 :00 1.50 WHSUR N SFAL DECOMP RIH with Storm Packer and 3 Stds of 4 3/4" Drill Collars, and 5 stds DP, Set at 100' Below Wellhead. Tested Storm Packer to 1,000 psi for 5 mins. 11 :00 - 12:00 1.00 WHSUR N SFAL DECOMP Nipple Down BOPE, to Repair LDS. 12:00 - 13:30 1.50 WHSUR P DECOMP Prepare and Grind 1 Lock Down Screw Flat. Install Pack Off RILDs. 13:30 - 14:30 1.00 WHSUR N SFAL DECOMP Nipple Up BOPE. 14:30 - 15:00 0.50 WHSUR P DECOMP Pressure Test Pack Off to 5,000 psi for 30 minutes. 15:00 - 16:00 1.00 WHSUR P DECOMP Retrive Storm Packer, POOH. UD Same. 16:00 - 16:30 0.50 WHSUR P DECOMP Install Wear Ring. 16:30 - 18:30 2.00 CASE C TIEB1 Prepare, Drift, and Tally 7" Casing. 18:30 - 00:00 5.50 CASE C TIEB1 Waiting On Tie Back Components from BOT. 6/30/2006 00:00 - 01 :00 1.00 CASE P TIEB1 Prepare Tools From Baker, RlU to Run 7" 26# L-80, BTC-M Casing. 01 :00 - 08:00 7.00 CASE P TIEB1 PJSM wI Rig Crew, Doyon Casing, Baker Packer Hand, On Running 7" Liner. P/U and Run Unique Over Shot, Seating Nipple, and Ported Sub, Drop Bailin Ball Set Sub and Put 100 Ibs 20-40 River Sand. 08:00 - 08:30 0.50 CASE P TIEB1 Change elevators, P/U liner hanger & ZXP liner top packer. UWT = 156K, DWT = 145K. 08:30 - 09:00 0.50 CASE P TIEB1 Circ liner volume, pump @ 7 bpm @ 400 psi. 09:00 - 11 :30 2.50 CASE P TIEB1 RIH with liner on drill pipe, fill pipe @ 10 stand intervals and break circulation. Pump @ 6 bpm @ 400 psi. 11 :30 - 12:00 0.50 CASE P TIEB1 Tag 41/2" tubing stub @ 9071'. Slack off and shear pins in Unique over shot with 17K down. Swallow stub down to 9078'. Pull up to neutral weight + 2'. 12:00 - 12:30 0.50 CASE P TIEB1 RlU cement head. 12:30 - 13:30 1.00 CASE P TIEB1 Circ, pump @ 4 bpm, RlU cement lines and hoses. 13:30 - 15:00 1.50 CEMT P TIEB1 PJSM with drill crew, cementers, Veco, Tool pusher & WSL. Pump 5 bbl of water & test lines to 4000 psi. Mix & pump 150 bbl (726 sx) of 15.8 ppg class "G" cement without latex. Drop 4" wiper plug & displace with seawater @ 8 bpm @ 580 psi. Did not see liner wiper plug latch up. Displace @ 9 bpm, caught cement with 80 bbl into disp. Slow pump & bump plug with 2800 psi. CIP @ 15:00 hrs. Floats held. 15:00 - 15:30 0.50 CEMT P TIEB1 Set Hanger and Packer Release f/Hanger Pump B/U @ 13.5 bpm 2820 psi. 20 bbls of Cement Back to Surface. 15:30 - 16:00 0.50 CEMT P TIEB1 RID CMT Head, UD 1 jt Drill Pipe. 16:00 - 17:00 1.00 CEMT P TIEB1 Pump 20 bbls Citric Acid and 20 bbl Sweep, Circulated 2X B/U @ 14 bpm With 1,600 psi. Reciprocatred Drill Pipe While Circulating. Printed: 7/10/2006 7:22:17 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-15A D-15A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/21/2006 Rig Release: 7/6/2006 Rig Number: Spud Date: End: 7/6/2006 6/30/2006 17:00 - 18:00 1.00 CEMT P TIEB1 POOH 18:00 - 19:00 1.00 CEMT P TIEB1 BID UD Liner Hanger running Assembly. P/U and Rig Down Cement Head. 19:00 - 20:00 1.00 CASE P TIEB1 Pull Riser and Wear Ring Clean Cement Off and Reset, M/U Jet Sub and Wash Stack. Install Riser. 20:00 - 21 :00 1.00 CASE P TIEB1 P/U and Break Down 6 3/4" Jar and Bumper Sub and 8.5" Shoe and Extendsion. Tools UD From Previous Run In One Piece, That Where to Be Rerun. Run Cancelled Due to Need for 7" Tie Back Liner. 21 :00 - 22:00 1.00 CASE P TIEB1 M/U Drill Out Assembly, BHA Consists Of 6.125" Bit, 2-Boot Baskets, 7" Scraper, Bit Sub, LBS, Jar, XO, 9 - 4 3/4" Drill Collars. 22:00 - 00:00 2.00 CASE P TIEB1 RIH , Tagged Cement Stingers at 8,947' 7/1/2006 00:00 - 01 :30 1.50 CASE P TIEB1 RIH wI Clean Out Assembly. Tagged up at 8,947'. Obtain Parameters, Up Weight-182,000#, Down Weight-140,000#, Rotating Weight-155,000#, 40 rpm, 6,000 ft-Ibs Torque. 01 :30 - 02:00 0.50 CASE P TIEB1 Pressure Tested 7" Tie Back Liner to 3,500 psi For 30 Minutes. Good Test. 02:00 - 02:30 0.50 CASE TIEB1 RID Test Equipment. 02:30 - 03:30 1.00 CASE P TIEB1 Cut and Slip Drilling Line. 03:30 - 04:30 1.00 DRILL P TIEB1 Drill Cement Stingers f/8,947 to 9,031 " with 40 rpm, 7,000 ft-Ibs of Torque, 9 bpm, with 1,600 psi, 5,000# WOB. Drilling Cmt Plugs and Landing Collar at 9,030'. 04:30 - 11 :30 7.00 DRILL P TIEB1 Drilled Wiper Plug and Landing Collar From 9,031' to 9,054', with 40 to 80 rpm, 7,000 to 8,000 ft-Ibs of Torque, 9 bpm, with 1,600 psi, 5,000# to 18,000# WOB. 11 :30 - 14:00 2.50 DRILL P TIEB1 POOH 14:00 - 15:00 1.00 DRILL P TIEB1 UD 9-4 3/4" Drill Collars and BHA. 15:00 - 15:30 0.50 DRILL P TIEB1 Clean and Clear Rig Floor. 15:30 - 16:00 0.50 DRILL P TIEB1 M/U BHA #4 CIO assembly Consists of, Junk Mill, Bit Sub, 3 jts 27/8" Pac DP, XO, 2 - Boot Baskets, Bit Sub, LBS, Jar, XO. BHA = 132.12'. 16:00 - 18:30 2.50 DRILL P TIEB1 RIH to 9,044'. 18:30 - 20:00 1.50 DRILL P TIEB1 Attempt to Circulate, Assembly Plugged. Surged Pipe, POOH to 8,662' Worked Pipe, Established Circulation. Reverse Circulated DP Volume @ 7.5 bbl/min With 2,140 psi. Washed f/8,662' t/9,052' 20:00 - 21 :00 1.00 DRILL P TIEB1 Pumped 20 bbl Weighed Hi-Vis Sweep at 9.5 bpm With 3990 psi. 21 :00 - 22:30 1.50 DRILL P TIEB1 Washed Sand f/9,052' t/9,063', Drilled Ball Seat Sub t/9,064' With 10,000 wob, 70 rpm, 8,000 ft-Ibs Torque, Washed Down to 9,081' 22:30 - 00:00 1.50 DRILL P TIEB1 Pumped 20 bbl Weighted Hi-Vis Sweep Cleared DP, Pumped Second 20 bbl Weighted Hi-Vis Sweep at 10 bpm With 3,980 psi. 71212006 00:00 - 03:00 3.00 DRILL P TIEB1 POOH f/9,054'to BHA. 03:00 - 04:00 1.00 DRILL P TIEB1 UD BHA #3, Clean Junk Baskets. Recovered Approx 2.5 Gals of Sand, Cement, and Metal Cuttings. 04:00 - 04:30 0.50 DRILL P TIEB1 M/U BHA #4,Consisting Of 3.375" Reverse Circulating Basket, Bit Sub, 3 - Jts Pac DP, XO, 2 - Boot Baskets, Bit Sub, LBS, Oil Jar, XO, BHA = 136.11'. 04:30 - 06:00 1.50 DRILL P TIEB1 RIH to 6'500'. Printed: 7/1012006 7:22:17 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-15A D-15A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/21 /2006 Rig Release: 7/6/2006 Rig Number: Spud Date: End: 7/6/2006 7/2/2006 06:00 - 08:30 2.50 DRILL P TIEB1 Attempt to Circulate Reverse Circ Basket, Plugged, Pull Up Hole 4 Stands. Surged Pipe Established Circulation. Circulate DP Volume at 9.5 bpm with 2100 psi. 08:30 - 10:30 2.00 DRILL P TIEB1 PIU 6 jts From Shed, Continue RIH, Break Circulation Every 5 Stds. 10:30 -11:00 0.50 DRILL P TIEB1 Obtain Parameters Up Weight=183,000#, Down Weight=125,000#, Rotating Weight=150,000#, 11 :00 - 11 :30 0.50 DRILL P TIEB1 Tagged Up On Junk @ 9,082' Worked Pipe. 11 :30 - 12:00 0.50 DRILL P TIEB1 Dropped Reverse Circ Ball. 12:00 - 12:30 0.50 DRILL P TIEB1 Work Reverse Basket f/9,082' to 9,104, Pumping 8 bpm with 2,320 psi. 12:30 - 13:30 1.00 DRILL P TIEB1 Pump Hi-Vis weighted 40 bbl Sweep @ 10 bpm With 3,980 psi, Monitor Well. 13:30 - 15:30 2.00 DRILL P TIEB1 POOH f/9,104'. 15:30 - 16:30 1.00 DRILL P TIEB1 B/O UD Jars and Bumper Sub Service Junk Baskets UD Reverse Circulating Basket. Recovered 3 gals of Cement Sand and Metal Cutting In Baskets. 16:30 - 17:00 0.50 DRILL P TIEB1 Clean and Clear Rig Floor. 17:00 - 18:00 1.00 DRILL P TIEB1 MIU and RIH wlMule Shoe Assembly to 3,998'. 18:00 - 20:00 2.00 DRILL P TIEB1 Reverse Circulated DP and Annulus Volume at 15 bpm with 3,000 psi. Circulated 40 bbl Hi-Vis Sweep at 15.5 bpm with 2,000 psi. Reverse Circulated DP and Annulus Volume again and 15 bpm with 3,000 psi. Sweep Returns Showed Sand Cement and Fine Metal Cuttings. 20:00 - 21 :00 1.00 DRILL P TIEB1 POOH From 3,998'. 21 :00 - 22:00 1.00 DRILL P TIEB1 M/U P-GSL Latch Assembly. 22:00 - 00:00 2.00 DRILL P TIEB1 RIH t/6,058'. 7/3/2006 00:00 - 01 :30 1.50 DRILL P TlEB1 RIH wIGS Spear fl6,058' to 9,101' 01 :30 - 02:00 0.50 DRILL P TIEB1 Obtain Parameters, Pump On 30 spm at 580 psi, Up Weight=185,000# Down Weight=130,000#, Rotating Weight=150,000#. 02:00 - 03:30 1.50 DRILL P TIEB1 Washed Down From 8,816', Attempted to Reverse Circulate at 9,101 '. Plugged Off, Pull Two Stands, Surged Pipe to Unplug Established Circulation, Washed Down to 9,101'. 03:30 - 04:30 1.00 DRILL P TIEB1 Pump 20 bbl Hi-Vis Sweep at 8 bpm with 2665 psi. 04:30 - 05:00 0.50 DRILL P TIEB1 Attempted to Reverse Circulate Staged Up Pumps at 10 stk Increments, at 30 stks minute Plugged Up. 05:00 - 06:00 1.00 DRILL P TIEB1 Pulled Up Hole to 8,816', Established Circulation, Circulated to 9,101. 06:00 - 07:30 1.50 DRILL P TIEB1 Pumped 40 bbl Hi-vis Sweep, Displace Well To Clean Sea Water at 7.5 bpm at 2,840 psi. 07:30 - 08:30 1.00 DRILL P TIEB1 Attempt to Reverse Circulate Well, Unable to Reverse. Continue to Circulate Down DP. 08:30 - 09:00 0.50 CASE P TIEB1 Test Casing to 2,500 psi Good Test. 09:00 - 09:30 0.50 DHB P TIEB1 RIH to Latch P-GSL Plug, Unable To Confirm Good Latch. 09:30 - 10:00 0.50 DRILL P TIEB1 Drop Ball and Circulate to Pump Out Sub at 3.5 bpm with 3,200 psi. 10:00 -11:00 1.00 DRILL P TIEB1 Reverse Circulated Well 10 bpm with 3,000 psi. 11 :00 - 12:00 1.00 DRILL P TIEB1 Attempt to Establish Injection Rate, Well bore Held 2,400 psi. 12:00 - 12:30 0.50 DHB P TIEB1 Attempt to Latch P-GSL Plug, Unable to Retrieve Plug. Pump Dry Job. 12:30 - 15:00 2.50 DRILL P TIEB1 POOH Printed: 7/10/2006 7:22:17 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-15A D-15A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/21/2006 Rig Release: 7/6/2006 Rig Number: Spud Date: End: 7/6/2006 7/3/2006 15:00 - 15:30 0.50 DRILL P TIEB1 Handle BHA, Service Boot Baskets, Break Down Circ Sub and Spear. Circulating Sub Ball Was Missing. 15:30 - 16:00 0.50 DRILL P TIEB1 Clear and Clean Rig Floor, Redress Circulating Sub, 16:00 - 16:30 0.50 DRILL P TIEB1 Handle BHA M/U Spear Assembly. 16:30 - 20:00 3.50 DRILL P TIEB1 RIH Circ Pipe Volume Every 30 Stands t/9,048'. 20:00 - 22:00 2.00 DRILL P TIEB1 Circulated Down f/9,048' to 9,109. Missing Circ Sub Ball prematurly Opened Circ Sub, Pumped 40 bbl Hi-Vis Sweep @ 13.5 bpm with 3,950 psi, Attempt to Latch P-GSL Plug Several Times. 22:00 - 00:00 2.00 DRILL P TIEB1 POOH f/9,109', t/2,618'. 7/4/2006 00:00 - 01 :30 1.50 DRILL P TIEB1 Continue to POOH f/2,616'. 01 :30 - 02:00 0.50 DRILL P TIEB1 UD P-GSL Latch Assembly. 02:00 - 02:30 0.50 DRILL P TIEB1 Clear and Clean Rig Floor. 02:30 - 03:00 0.50 CASE P TIEB1 Pull Wear Ring, RlU to Test BOPE. 03:00 - 08:00 5.00 CASE P TIEB1 Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. Test was Witnessed by the Doyon Toolpusher and BP WSL. 08:00 - 08:30 0.50 CASE P TIEB1 RID Test Assembly, Install Wear Bushing. 08:30 - 09:30 1.00 CASE P TIEB1 Redress Pump Out Sub. M/U P-GSL Assembly. 09:30 - 13:00 3.50 CASE P TIEB1 RIH with 4" DP to 8,762'. 13:00 - 14:00 1.00 CASE P TIEB1 Slip and Cut Drilling Line. 14:00 - 15:30 1.50 CASE P TIEB1 RIH to 9,048', Wash Down to 9,109' at 9 bpm with 3,680 psi Pump Pressure 15:30 - 16:30 1.00 CASE P TIEB1 Pump 20 bbl Weighted Hi-Vis Sweep. 20 bpm at 3,680 psi. Latch and Pull Plug Free at 195,000#.Well Taking Fluid, Initial Loss Rate of 140 bph Slowing to 36 bph. Drop Ball and Attempt to Open Circulating Sub, Unable to Open Sub. 16:30 - 00:00 7.50 CASE TIEB1 POOH Laying Down DP to 741'. 7/5/2006 00:00 - 01 :00 1.00 CASE TIEB1 POOH UD DP 01 :00 - 01 :30 0.50 CASE TIEB1 UD BHA, P-GSL, and Latch Assembly. 01 :30 - 02:00 0.50 CASE TIEB1 Clear and Clean Rig Floor. 02:00 - 02:30 0.50 RUNCO RUNCMP Pull Wear Bushing. 02:30 - 04:00 1.50 RUNCO RUNCMP RlU to Run 4.5" Tubing, RlU Torque Turn Equipment. 04:00 - 17:00 13.00 RUNCO RUNCMP Hold PJSM with All Personnel Involved, Run 4.5", 12.6#, 13CR-80, Vam Top Tubing. Use Jet Lube Seal Guard Pipe Dope. Ran 208 Joints of Tbg, 3 X Nipples, 4 GLM's and 1 Baker S-3 HydroSet Packer. Set at 8,966'. Up Weight 145,000#, Down Weight 110,000#. 17:00 - 18:00 RUNCMP Run in Lock Down Screws on Hanger. 18:00 - 21 :00 RUNCMP Reverse in 136 bbls of 120 Degree Seawater Followed by 307 bbls of Inhibited Seawater. 3 bpm at 150 psi. 21 :00 - 23:30 RUNCMP Drop Rod and Ball, Set Packer with 2,500 psi. Test Tubing to 3,500 psi for 30 Minutes, Good Test. Bleed Tubing to 1,600 psi. Pressure Annulus to 3,500 psi for 30 Minutes, Good Test. Bleed Down Tubing Side and Shear DCR Valve. 23:30 - 00:00 RUNCMP Circulate Both Ways to Ensure DCR Valve Sheared. RID Circulating Head and Landing Joint. 7/6/2006 00:00 - 00:30 0.50 BOPSU WHDTRE Set TWC and Test From Below to 1,000 psi. 00:30 - 01 :30 1.00 BOPSU P WHDTRE Nipple Down and Stand Back BOP Stack. 01 :30 - 03:30 2.00 WHSUR P WHDTRE Nipple Up Adaptor Flange and Tree. Test Both to 5,000 psi for 30 Minutes. 03:30 - 04:30 1.00 WHSUR P WHDTRE RlU DSM Lubricator and Pull TWC. RID Lubricator. 04:30 - 06:30 2.00 WHSUR P WHDTRE RlU Little Red Services. Pump 150 bbls of Diesel Freeze Printed: 7/10/2006 7:22:17 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-15A D-15A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/21/2006 Rig Release: 7/6/2006 Rig Number: Spud Date: End: 7/6/2006 7/6/2006 04:30 - 06:30 06:30 - 07:30 07:30 - 08:30 08:30 - 09:00 2.00 WHSUR P 1.00 WHSUR P 1.00 WHSUR P 0.50 WHSUR P WHDTRE Protect. 5 bpm at 1,050 psi. WHDTRE RIU and U-Tube Diesel Freeze Protect. WHDTRE Install BPV and Test to 1,000 psi. WHDTRE Nipple Down Secondary Annulus Valve Secure Tree. Rig Released at 09:00 Hrs. Printed: 7/10/2006 7:22:17 AM r1\.ì '=;-r J-;;' t;"'? rG \\, P ¡J/H P .,' \' d !Lq d L cQ) iLU'"lJ ¡j Lb e ~; !""P ....~ ij i.. ¡J. i'. ~.I ~,. '-..'.. ' ~ ' .' ,.;;;;¡ I· ï, j 1 ,I 'Ii} J. " ".' .,. '~u e FRANK H. MURKOWSKI, GOVERNOR AItASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Doug Cismoski Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-15A Sundry Number: 306-233 r~; Dear Mr. Cismoski: 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 thisbay of July, 2006 Encl. \C(¡ - ~)ld 7/ S-/h (ft1' 1,,3..0(' &~' b)3ð!c6 W~1t 113/2.0Dfp _ STATE OF ALASKA ~ RECEIVED ALASKA OIL AND GAS CONSERVATION OMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 OTS 1. Type of Request: 0 Abandon o Alter Casing o Change Approved Program .. . 181 Repair Well 0 Plug Perforations 0 Stimulate 181 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Other o Operation Shutdown 0 Perforate 0 Time Extension 0 Re-Enter Suspended W 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 71.4' 4. Well Class Before Work: / 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 197-212 .-/ 6. API Number: 50-029-20461-01-00 r 9. Well Name and Number: PBU D-15A -' 8. Property Designation: 10. Field / Pool(s): ADL 028285 Prudhoe Bay Field / Prudhoe Bay Pool 1,1.." ' ," ','", '" " "_, ,,' , Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft) Plugs (measured): Junk (measured): 12086 9021 12022 9022 9109 None Casing Length Size MD / TVD Burst Collapse Structural Conductor Surface Intermediate Production Liner 110' 20" x 30" 110' 110' 2679' 13-3/8" 2679' 2679' 4930 2670 9730' 9-5/8" 9730' 8344' 6870 4760 1116' 7" 9215' - 10331' 7942' - 8844' 8160 7020 2977' 2-7/8" 9109' - 12086' 7857' - 9021' 13450 13890 12. Attachments: 181 Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 14. Estimated Date for Commencing Operations: June 29, 2006 16. Verbal Approval: D¥ 6/29/2006 Commission Representative: W;nton AubJ!rt 17. I hereby certify that the foregoing is tru&-and çøfrect to the best of my knowledge. Printed Name Doug Cismoski~ Title Drilling Engineer Signature ~ _I. ./ ¿ ¿ L Phone 564-4303 ./ Commission Use Only Liner Perforation Depth MD (7ft)· I Perforation Depth TVD (ft): 11302' - 12000' 9021' - 9022' Packers and SSSV Type: 9-5/8" x 4-1/2" Otis 'MHR' packer Tubing Size: Tubing Grade: 4-1/2", 12.6# / L-80 I Packers and SSSV MD (ft): 9160' / 13. Well Class after proposed work: // o Exploratory 181 Development 0 Service Tubing MD (ft): 9160' 15. Well Status after proposed work: 181 Oil 0 Gas o WAG 0 GINJ o Plugged OWINJ o Abandoned o WDSPL Contact Doug Cismoski, 564-4303 Date "/¿9ht.. Prepared By Name/Number: Terrie Hubble, 564-4628 . o Plug Integrity &BOP Test Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: _~ tJ - ,.:2,,~~ o Mechanical Integrity Test 0 Location Clearance Other: T-es T ßO \) f- to "$«;00 ~ S,bs"",", Fo= R",,'ce,' I 0 ~ Approved By:.( .~ ~ Fo= 'û-40' R~;,ed 0712005 0 'R{ Gm A L . RBDMS BFl JUL 062006 COMMISSIONER APPROVED BY THE COMMISSION Date 17 51 () 6 'ubmfln Duplicate - e e G D-15A Rig Workover Original Scope of Work: Pull the 4-1/2" completion, changeout the 9-5/8" packoffs, and run new 4-1/2" ,// chrome completion. /.. 9-5/8" Production casing failed a pressure test below 4000' while the workover is in progress. The rig has pulled the 4-1/2" completion and changed out the 9-5/8" packoffs. Revised Scope of Work: Run 7" scab liner from top of 4-1/2" tubing stub (-9077') to 4000', fully cemented.)ìun 4-1/2" chrome completion. / MASP: ;232Q/psi Well TyIp'Er."Producer Estimated Start Date: Doyon 16: Workover In-Progress Pre-Rig Work: F 1 CMIT T x IA to 3500 si. CMIT to 3000 si assed on 02/09/2006. / o 2 Check the tubing and casing-hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage. PPPOT - T & IC. Well is secured with a Weatherford WRP and a assin CMIT - TxlA to 3000 si on 02/09/2006. S 3 Pull WRP and drift (pre-chemical cut). L&K well. Run L TTP. CMIT-TxIA to 2000 psi. Dump bail slu its. P-GSL without dogs was set on 6/07/2006 E 4 Punch tubing holes, run string shot and chemical-cut tubing (-9070' MD) in middle of first joint above deployment sleeve. Reference 10/04/91 tubin tally. TUBING CUT @ 9077' on 6/10/06 F 5 Circulate wellbore with clean seawater and freeze-protect w/ diesel. MITOA - 2400 P. CMIT TxlA - 3500 (F) Est. LLR = 0.8bpm @ 3400psi. o 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure / 1. MIRU. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-Y2" tubing string to the cut. / 3. RIH w/ RTTS to tubing stub @ 9077' pressure test 9-5/8" casing - Test Failed on 6/29/06. /" 4. PUH w/ RTTS to pressure test casing above 4000' - Test Passed to 3500 psi on 6/29/06. 5. C/O 9-5/8" packoff through BOP's /' é 6. RIH w/ 7" scab liner frE top of tubing stub (-90??) to 4000' ./' 7. Cement 7" liner wI -150 bbls of Class G cement 8. Drill out shoe track, r'e -rse circulate down to the top of the 2-7/8" liner 9. Fish P-GSL plug from the top of the 2-7/8" liner. 10. Run 4-Y2"13Cr-80 completion with 7" x 4-1/2" Baker S-3 packer at 8970' MD. 11. Displace the fA to packer fluid and set the packer. 12. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. / 13. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = IiVELLHEAÐ = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVO = 4" CrN OCT (FMC) BAKER C 71.42' 47.17' 3100' 94 @ 11221' 10364' SSOO' SS e D-15A S.NOTES: 70o@ 10583' AND90o@ 10795' . 2100' -14-1/2" CAM SSSV NIP, 10 = 3.813" TOPOF7" LNR I TOP OF 4-1/2" TAILPlÆ I 2612' -1 9-5/8" OV PKR I 1 13-3/S" CSG, 72#, L-SO, ID = 12.347" I Minimum ID = 2.441" @ 9109' TOP OF 2-7/8" LINER ITBG PUNCH (06/10/06) I 9052' - 9054' I CHEM CUT (06/10/06) 9077' I TOP OF 2-7/8" LNR I GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LATCH 5 3000 2925 8 MERLA OMY RM 4 5292 4862 41 MERLA DMY RM 3 7353 6392 39 MERLA DMY RM 2 8554 7337 36 MERLA OMY RM 1 8895 7610 37 MERLA DMY RM PORT OA TE o 01/04/06 o 01/04/06 o o o 9215' 9225' -10EPLOYMENTSLEEVE I -i 4-1/2" PGSL SET (06/07/06) I 9143' -14-1/2" PKR SWS NIP, 10 = 3.813" I 9154' H RT HAND RELEASE 'SAP SEAL ANCHOR I 9160' -19-5/S" x 4-1/2" OTIS MHR PKR, 10 - 3,85" 9215' -i TOP OF CEMENT , 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3,95S" I 14-1/2" TBG, 12.6#, L-80, ,0152 bpf, ID = 3.958" I 9275' -14-1/2" PKR SWS NIP, 10 = 3,813" (BEHIND PIPE) 9296' -14-1/2" PKR SWN NIP, 10 = 3,725" (BEHIND PIPE) -14-1/2" WLEG TT, 10 = 3.854" (BEHIND PIPE) 9500' -1 BOTTOM OF CEMENT I I 9-5/S" CSG, 47#, L-80, ID = 8.681" I 9730' ÆRFORA TION SUMMARY REF LOG: SÆRRY MWO GR ON 02/01/98 ANGLE AT TOP ÆRF: 92 @ 11302' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 11302 -11596 C 02/07/98 1-11/16" 4 11699-12000 C 02/07/9S 10320' I TOP OF WHIPSTOCK I PBTD I I MILLOUTWINDOW 10331' 17" LNR, 29#, L-80, ,0371 bpf, 10 = 6,184" I 1 0730' 12-7/8" LNR, 6,16#, L-80, ,0058 bpf, ID = 2.441" OA TE REV BY COMMENTS 07/20/80 ORIGINAL COMPLETION 02/07/98 RRW/CJS SIDETRACK COM PLETION 09/17/03 CMO/TLP REF LOG AND LOCATION 01/04/06 KDClPJC GL V C/O 01/16/06 KSB/PAG WRP PLUG @ 9075' (01/11/06) 02/28/06 PJC B&tIND PlÆ CORRECTIONS DA TE REV BY COMMENTS 06/07/06 ORF/PAG PULL WRP / SET PGSL 06/10/06 RRD/PJC TSG PUNCH & CHEM CUT PRUDHOE SA Y UNIT WELL: D-15A ÆRMIT No: '1972120 API No: 50-029-20461-01 SEe 23, T11 N, R13E, 2600' SNL & 1067' WEL BP Exploration (Alaska) , , D-15A Proposed Minimum ID = 2.441" @ 9109' TOP OF 2-7/8" LINER 1 13-3IS" eSG, 72#, L-SO, ID = 12.347" H 2681' TOP OF 7" SCAB LINER 5-112" x 7" roRTED XO, ID = 4.892" TOP OF 2-7/8" LNR TOP OF 7" LNR I TOP OF 4-112" TAILPIPE I 4-112" TBG, 12.6#, L-BO, .0152 bpf, ID = 3.958" /9-5/8" CSG, 47#, L-80, ID = 8.681" I 9730' PERFORATION SUI\IIIN\RY REF LOG: SFERRY MND GR ON 02101/98 ANGLE AT TOP PERF: 92 @ 11302' r-bte: Refer to Production DB for historical perf data SIZE SfT INTERVAL Opn/Sqz DATE 1-11/16" 4 11302-11596 C 02107/98 1-11/16" 4 11699-12000 C 02107/98 2100' 4-112" HES X NIP, ID = 3.813" 2612' GAS LIFT MÞ.NJRELS ST MD iVD DE\! TYPE VLV LATCH 4 3204 IVMG OCR RK 3 6054 IVMG DMY RK 2 7909 M\IIG DMY RK 1 8940 MMG DMY RK FORT o o o o DATE ,-- -14-112" HES X NIP, ID = 3.813" I -8970 -19-518" X 4-1IZ' Baker S-3 PKR, ID = 4-112" HES X NIP, ID = 3.813" 9143' 9160' 9215' -4-112" PKRSWS NIP,ID=3.813" I --j9-5I8" X 4-1/2" OTIS MHR PKR, ID = 3.85" --j TOP OF CEMENT I 9275' H4-1IZ' PKR SWS NIP, ID = 3.813" (BEHIND PIPE» 9296' - 4-1/Z' PKR SWN NIP, ID = 3.725" (BEHIND PIPE» 9308' -4-112" WLEG TT, ID = 3.854" (BEHIND PIP~ 9500' --j BOTTOM OF CEMENT I I MJLLOUTWlNOOW 10331' 12-7/S" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" DATE REV BY COMlt9ß"S 07/20/80 ORIGINAL COM PLETION 10104I91 RWO 02107/98 RRWICJS SIŒrRACK COM PLETION DATE REV BY COMl/BoITS PRUDHOE BAY UNIT WELL: D-15A PERMT r-b; "1972120 API r-b; 50-029-20461-01 SEC23, T11N, R13E. 2600' SNL & 1067' WEL BP exploration (Alas ka) D-15A (PTD #1972120) Classified as Problem Well e e Subject: D-1SA (PTD #1972120) Classified as ProblemWèll.. '. . . . From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Sat, 24 Dec 200S 12:S2: 17 -0900: To: "AOOCC \\\inton~ubert (E-mail)'; <wÍ . n _rtµbert@admin.state. '. ~us>; "AOGCC,lifu,¥.egg ... (E-mail)..<.fim-.lbgg@·.·:.ilJ.stllte.ak.Us>. "R ' berg, R Steven"'¿S. ", ossberg@BP';:co '>,';¡Ñ ...>,.. . .. . '1.;"" ";.. . .... "NSU, APW"W .... p '. s Supervisor".< A~WWellOperati() ,jsor@BP.c. , "N§;ø, ADW ~L': . ion Supervisor" <WL&CompletionSupe '. ., r@BP.co "NSWf 4DW W~ìt '··Engineer" <N ., elllntegrityEngineer@BRcom>, "y:?;,µn '" RobertO" ~L ~obert'.~qll, r@ir.com>, "OPB a MW" <6PBOCl T~, ·.com>, w(j¡:J , CrWellp Lead" <qlb lW' padLead@BP,'. . PB,':}Vells Opt En ',I , 'WellsOpŒ BRcom:> '!GPB, Prti ~ 01"," <GPBProdCo 01 BP.com> qC:"Winslow, ack Lit <LY9~~@BP.c(fm> '. ..... All, Well 0-15A (PTO #1972120) has been found to have sustained casing pressure on the inner annulus and has been classified as a Problem well. TID pressures were 2250/2210/110 psi on 12/23/05 when the well failed a TIFL. The plan forward for this well is as follows: 1. SL: Caliper tubing. Pending caliper results, attempt OGLVs to repair or set plug to secure. A wellbore schematic has been included for reference. Please call if you have any questions. «O-15A.pdf» Rob Mielke Well Integrity Engineer, BP Exploration, (Alaska) Inc. Office: 1-907-659-5102 Pager: 1-907-659-5100 #1154 robert.mielke@bp.com eo Content-Description: D-1SA.pdf D-15A.pdf Content-Type: application/octet-stream Content-Encoding: base64 OA SC~ ( p<:>',) LZ lO 1\0 p. ') ~'. 6'b70 53eo % ~'(f -- 32.l~ 2.0~ 7.' ð ~- fki" Ci;{ft"¿ J L 4'5'20 j),;J:<-{f1) ~1 'J 1\~1 IZ(24/0f.) 1 of 1 12/27/20059:24 AM TREE = WB..LHEAO = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = OatumMO= OatumTVO = 4"CIW ocr (FMC) BAKER C 71.42' 47. 17' 3100' 94 @ 11221' 10364' 8800' SS D-15A SAFETY NOlES: 700@ 10583' AND 900@ 10795' . 2100' 4-1/2" lAMSSSV NIP, 10- 3.813" 13-318" CSG, 72#, L-80, 10= 12.347" 2612' Minimum ID = 2.441" @ 9109' TOP OF 2-7/8" LINER ~ GAS LIFT M6.NDRB..S ST MO NO OBI TYPE VLV LATCH PORT D'\TE 5 3000 2925 8 MERLA RA 4 5292 4862 41 MERLA RA 3 7353 6392 39 MERLA RA 2 8554 7337 36 MERLA RA 1 8895 7610 37 MERLA RA TOPOF 2·7/8" LNR 9109' 9109' ŒPLOYMENT SLEEVE 9143' 4-112" PKR SWS NP, 10 = 3.813" 9154' HRf H/\NORB..EASE'SAP SEAL ANCHOR 14-112" TBG, 12.6#, L-80, .0152 bpf, 10 - 3.958" I 9160' 9160' 9-5/8" X 4-1/2" OTIS MHR PKR, 10 = 3.85" 9215' TOPOF CENENT 9275' 4-1/2" PKR SWS NP, 10 - 3.813" 4-1/2" WLB3 TT, 10 = 3.854" 9296' 4-112" PKRSWNNP, 10=3.725" 4-112" TBG, 12.6#, L·80, .0152 bpf, 10 = 3.958" 9308' 9308' 9500' BOTTOM OF CB\IIENT 9-5/8" COO, 47#, L·80, 10 - 8.681" 9730' Note: SIZE 1-11/16" 1-11/16" ÆRFORA TION SUMIIIARY REF LOG: SÆRRY MWD GR ON 02/01/98 ANGLEATTOPPERF: 92 @ 11302' Refer to Production DB for historical perf data SPF INTERVAL Opn/Sqz DATE 4 11302·11596 0 02/07/98 4 11699 -12000 0 02/07/98 I 10320' I MILLOlJfWlNOOW 10331' AHO, LATCH COLLA R 17" LNR, 29#, L-80, .0371 bpf, 10 =6.184" 12.7/8" LNR, 6.16#, L·80, .0058 bpf, 10 = 2.441" I DATE 07/20/80 02/07/98 03/03/02 03/03/02 09/17/03 REV BY COMIIIENTS ORIGINAL COM PLETION RRW/CJS SlDErRACK COMPLETION RN'TP CORRECTIONS RN'TP CORRECTIONS CMO/TLP REF LOG AND LOCA 1l0N D'\ TE RBI BY COMMENTS ffiUOHOE BAY UNIT WELL: D-15A PERMrrNo: 1972120 A A No: 50·029-20461·01 SEC 23, T11N, R13E: 2600' SNL & 1067' WEL BP Exploration (Alas ka) STATE OF ALASKA ALASK,-~IL AND GAS CONSERVATION O_.~MISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 5. Type[~ well: 6. Development [] Exploratory [] Stratigraphic 99519-6612 [] Service 4. Location of well at surface 8. Acid Datum Elevation (DF or KB) KBE = 71.42' 7. Unit or Property Name Prudhoe Bay Unit Well Number 2600' SNL, 1067' WEL, SEC. 23, T11N, R13E, UPM At top of productive interval 1495' NSL, 714' WEL, SEC. 14, T11N, R13E, UPM At effective depth (n/a) At total depth 1476' NSL, 875' EWL, SEC. 13, T11N, R13E 12. Present well condition summary Total depth: measured 12086 feet true vertical 9002 feet Effective depth: measured 12022 feet true vertical 9021 feet Plugs (measured) Junk (measured) D-15A 9. Permit Number / Approval No. 97-212 10. APl Number 50- 029-20461-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KOP (window) 10326' - 10335'. 7" Liner abandoned from 10326' to 10730'. Casing Length Size Cemented MD TVD Structural Conductor 110' 20"x 30" 126 c.f. 134' Surface 2655' 13-3/8" 4464 c.f. 2679' Intermediate 9706' 9-5/8" 1374 c.f. 9730' Production Liner 1112' 7" 390 c.f. 9214' - 10326' Sidetrack Liner 2977' 2-7/8" 127 c.f. 9109' - 12086' 134' 2679' 8344' 7914'-8840' 7857'-9021' : Perforation depth: measured Open Perfs 11302' - 11596', 11699' - 12000' true vertical Open Perfs 9021'-9022', 9021'-9022' Tubing (size, grade, and measured depth) 4-1/2" 12.6#, L-80 tubing to 9160'. Top of 4-1/2" tailpipe @ 9225' and bottom @ 9308'. Packers and SSSV (type and measured depth) 9-5/8" Otis MHR PKR @ 9160', 4-1/2" Camco SSSVLN @ 2100'. 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge scott LaVoie Title Technical Assistant Date ~'/~/~,/~ .,~ ,~ De Wayne Sc"~hndCrr 564-5174 Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Submit In Duplicate D-15A .... DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04/11/2001 ACID: PRE ACID TIFL 04/24/2001 ACID: ACID PICKLE SUMMARY 04/11/01 T/I/O = 160/270/260. FMC. TIFL PASSED ( Pre Acid). Initial FL @ 5383'. SI well, TBG pressure increased to 2040 psi. Monitor for 4 hours. No change in IA pressure. Final IA FL @5352'. Final WHP's=2040/270/260. POP w/o AL 04/21/01 RU DS AND HB&R AND PUMP 13 BBL MEOH/WATER, 24 BBL 50/50 DIESEL/XYLENE,'24 BBL 12/10 DAD ACID FOLLOWED BY 115 BBLS CRUDE. AVE RT= 4 BPM AVE PSI= 1200 PSI. POP WELL WITH PBGL. Fluids Pumped BBLS. Description 13 MEOH/WATER, 24 50/50 DIESEL/XYLENE, 24 12/10 DAD ACID 115 CRUDE 176 TOTAL THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03 2001 P L E W M ATE IA L U N D ER TH IS M ARK ER C:LORIWW~M.DOC 197-212-0 PRUDHOE BAY UNIT D-15A 50- 029-20461-01 BP EXPLORATION MD 12086 TVD 09002 t~omPletion Date: ~-~/8/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D D 8410 ~ SPERRY GR OH 4/8/98 4/8/98 L MTN ,5~)/(,O/~ CH 5 6/24/98 6/24/98 T L NGP-MD I~AL 10343-12085 OH 4/8/98 4/8/98 L NGP-TVD /~4~XL 8778-8949 OH 4/8/98 4/8/98 R SRVY CALC {~ 10300.-12086. OH 3/26/98 4/1/98 T 8557 ~ SCHLUM MCNL OH 7/24/98 6/24/98 Daily Well Ops !//~I/~]~- ~/~? c/ff Are Dry Ditch Samples Required? yes ~__..~And Rece'~-' Was the well cored? yes~.~_~r Analysis Description Receive ? o a pte~Se~ Comments: Thursday, February 03, 2000 Page I of 1 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11283 Company: Field: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 6/24/98 Well Job # Log Description Date BL RF Sepia LIS Tape D-15A ~ ;>~_~'-7 98290 MEMORYCNL 980206 1 I 1 .-29 .~ ;~'- ~.-/~/' 98291 CNTD __ 980209 ..... 1_ I I .... -- -- -- -- -- , , -- -- ,, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 ,errS-sun I~) F:i I I--I_ I N ~S S~ FI~/I I~ IE S To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Tavlor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs D-15A, AK-MW-80112 April 8, 1998 D-15A: 2" x 5" MD Gamma Ray Logs: 50-029-20461-01 2" x 5" TVD Gamma Ray Logs: 50-029-20461-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: '~///~/~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries. Inc. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Tavlor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs April 8, 1998 D-15A, AK-MW-80112 1 LDWG formatted Disc with verification listing. APl#: 50-029-20461-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-66 ! 2 Date: 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Inc. STATE OF ALASKA ALASF AND GAS CONSERVATION COMIV 3N CT Sidetrack WELL COF~TION OR RECOMPLETION REPOR'r=~--~ID LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-212 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20461-01 4. Location of well at surface ! i:,:_.. ;:..~ :' .!--- !-~, 9. Unit or Lease Name 2600' SNL, 1067' WEL, SEC. 23, T11N, R13E, UPM~ ~,~.; .... ' Prudhoe Bay Unit At top of productive interval !-~L~,~'.~ ? i~10. well Number 1495' NSL, 714' WEL, SEC. 14, T11N, R13E, UPM. .,~;~,,._,;~; ,~ D-15A At total depth i_..~~__~..~!i 11. Field and Pool 1476° NSL, 875' EWL, Sec 13, T11N, R13E ........... ~.._, .'.. Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 71.42 AMSLI ADL 028285 12. Date Spudded1/27/98 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if °ffsh°re t16' N°' °f C°mpleti°ns2/4/98 2/8/98 N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)119. Directional SurveyI 20. Depth where SSSV set[21. Thickness of Permafrosl 12086, 9002 FT 12022 9021 FTI []Yes [] No I 2100 MD ! 1900' (Approx.) 22. Type Electric or Other Logs Run GR/CNL 23. CASING, LINER AND CEMENTING RECORD CASING S E'I-FING DEPTH HOLE SiZE WT. PER FT. GRADE TOP Bo'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 2 7/8" 6.16# L-80 9109 12022 3 3/4" 127 c.f. 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) MD TVD 11302-11596 9020-9021 1-11/16; 4spf 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 11699-12000 9020-9021 1-11/16; 4spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 3/15/98 I Flowing ' Date of Test iHours Tested PRODUCTION OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OIL RATIO FOR TEST I Flow Tubing Casing Pressure CALCULATED O~L-BBL GAS-MCF WATER-BBL O~L GRAVITY-APl (CORR) · Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and prese,nce of oil, gas or water. Submit core chips. ORIGINAL /'.,?R O ! 1998 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate r 29. Geologic Marke~ _r -- ~ 30. ~.-ormation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. BKB ss Sag R 9850 8367 Shublik 9886 8396 Ivishak 9984 8477 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~r- j~~ ~ Title Coiled Tubin~l Drillin~l TA Date "~ ~:,~ ~ ~) Prepared By Name/Number: Theresa Mills 564-5894 INSTRUCTIONS G£UERAL: 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: D-15A Accept 1/26/98 Field Prudhoe Bay Spud 1/30/98 APl 50-029-20461-01 Release 2/8/98 Permit 97-212 CTD Unit Nordic #1 Date Day Depth 1/26/98 1 Rig on Stand-by. Waiting on Weather to move. Ambient temperature = -45 deg. Wind chill = -90 deg. At 0330 hrs the ambient Temp is -36. Start moving rig off D-22a Rig accepted at 0600 hrs 1/26/98. 1/27/98 2 10331 Finish rig up and run lines. NU BOP. Test BOP. PU Baker Window Milling BHA. Install CT Connector, pull test to 35,000#, pressure test to 3500 psi. TIH Tagged SWN at 9252', Corrected 24' to 9228' Took <lmin to mill out SWN ID, backed reamed. TIH and tagged the top of the WS at 10324.8' Milling window, started after 3 stalls. Milled 6.5' in 2 1,4 hrs to 10331.1'. POOH. Mill looks correct. Change out BHA, TIH, Reamed out SWN nipple at 9228'(2 stalls). TIH and tagged at 9290' PUH and pulled tight at SWN nipple. Backed reamed SWN nipple again. (Clean) Gas to surface. Place well on choke, Cir out gas through buster. (Small amount of gas). Max pressure at surface = 400 psi, Work CT and Circ. bottoms up. POOH to run WL drift. RUWL. 1/28/98 3 10331 RU WL to tag obstruction at 9290'. Tag up at 9228' WLM. Impression indicated top of 4 1/~,, tubing. Re-run 3.5" LIB w/TTL. Tag up at 9224' WLM, EOT at 9185' WLM. Compensating for stretch in wireline indicates tailpipe unscrewed at or near bottom of packer at 9160'. TIH w/milling assembly to attempt to work fish down to whipstock. TIH and tagged at 9290'. Worked mill thro 9290' and WR in the hole. Tagged at 10326' PUH and free. (Fish could be 81' long, the entire TT). POOH to run Eline. Found crimped CT at 9558'-will need to replace CT reel. OOH and RD BHA. Wait on Dresser Altas. RU Atlas and blow down CT. Will swap out CT reel in the AM when crane available. Run #1 with GR/CCL stopped at 9170'. Had 1200# overpull to get free. POOH. Add centralizer on bottom of TS. Run #2 and log from 8800- 10320' (whipstock). Looks like TP is 60' lower than it should be. Had 1400# overpull getting by 9190'. RD Atlas. WO crane to XO CT reel. 1/29/98 4 10331 WO crane to C/O reel. RU crane. Pick out reel. All drive pin sleeves and one drive pin need to be replaced. Set new reel in place. Stab CT in injector. Fill CT with SW. Pump 1.25" ball and recover. Install CTC. Pull test at 35K, PT 3600 psi. MU cementing BHA. 1/30/98 5 10333 RIH with cementing BHA and 3.2" OD nozzle. Unable to get past liner top at 9230' CTM. POOH. MU 3.7" OD stabilizer on top of nozzle. RIH. No problems getting down or up through fish. RIH and tag window at 10329'. Lay in 40 bbls 150K LSRV FIo-Pro from window to 9500'. Mix class G cement with 2.5#/bbl fiber. Hold pre-job meeting. Pump 2 bbls FW, 12 bbls fiber cement, 2 bbls FW and chase with SW. Lay in cement 9500' - 9160' at 1.5 BPM, 800 psi. Pull to safety, let cement settle. Recip and jet cement to TOL at 9200'. POOH. LD cementing BHA. WOC until 1500 psi. MU and RIH w/BHA #4 (UG mill and string reamer). Tag TOC at 9219' CTD. Drill firm cement thru tailpipe to 9325'. Backream clean to 9150' (saw btm of~"~.?~ ..... ii~: packer at 9157'). Resume drilling firm cement to 9437' and then got into stringers to 9550'. RIH clean to top of whipstock at 10324' CTD. Begin reaming on window at 10332'. Begin displacement to used FIo Pro mud. 2/1/98 7 10538 Finish POOH with string reamer/mill assy. OOH and PU window milling BHA with PDC bit. TIH and tagged the top of the fish at 9220' Worked through and TIH. Tagged the top of the WS at 10320' Worked window area from 10326.7' to 10335', backed reamed 3 times, clean POOH. Change out BHA, TIH. Tagged window at 10326'. Orient TF to 80R and TIH through window. Drilled to 10340' and orient TF to HS. Corrected depth to RA Marker at 10329'(+7'). Drill from 10340' building and turning to 10538'. POOH for motor. Change out bit, motor and MWD. RIH with BHA #9. No problem at fish or window (73R). Tie-in and subtract 10.0'. RIH. 2/2/98 8 11144 Finish RIH with BHA #9. Back on bottom drilling. Survey. Azimuth not correlating to original survey. Trouble shoot tools. The original probe was in error.(Bad azimuth data) Re-survey hole. Checked survey, Drilling. Landed at 10727'MD, 8959' TVDss and 90°. POOH. Change out motor and bit. TIH. Tagged bottom at 10727', Oriented TF to 80R. Drill horizontal from 10727-10883' (saw HOT). Orient to 80L. Drill from 10883-10930'. Backream to window. Tie- in, no correction. Drill from 10930-11087' and displace to new FIo Pro mud. Slow drilling and sticky 10942-11062'. Backream to window. Orient to high side and drill fast hole from 11087- 11144'. Losing angle drilling at high side. POOH for motor. 2/3/98 9 11729 Change bit, motor bend. RIH with BHA #11. TIH and tie-in and corrected -10', TIH. Tagged bottom at 11145', Orient TF to HS. Drilling. Wiper trip to window at 11244'. Orient to LS and drilling. Lost Nordic's Centrifuge. At 1200 hrs(bearing) Called out MI Solids Van. Drilling an wagging TF. Wiper trip at 11455'. Drill from 11455-11589'. MWD quit. POOH for MWD. Downtime started at 1930 hrs 2/2/98. Found washout in Sperry flow tube. Change bit, motor and MWD. RIH with BHA #12. Tag fish at 9220' CTD. RIH thru window at 15R. Tie-in, subtract 9.0'. Precautionary ream to corrected TD at 11591'. Back on clock at 0230 hrs 2/3/98. Phz 1. Drill from 11591' holding angle. Penetration rate slowed in cherty streak from 11629- 11729'. Backreamto 11160' to check MWD. Log with MWDfrom 11160-11190'. RIH. Phz2. 2/4/98 10 12086 RIH after short trip to 11150'. Drill from 11729' to 11817' Phase II weather conditions. Wiper trip to window, Tie-in. No correction. WR to bottom. Orient TF. Pp are high to mud density and flowrate required to operate MWD tool. POOH (1100hrs NE time started). OOH and changed out directional probe. Impleller was tighter than normal. TIH. Work to get thru fish at 9220' CTD several times. Tie-in at GR marker-subtract 10.0'. Precautionary ream to corrected TD at 11825'. Back on clock at 1800 hrs. Drill horizontal from 11825-11983'. Backream to window. Tie-in, no correction. Drill from 11983-12083'. Penetration rate was too slow to continue (dull bit). Shale showed at 12030'. Backream to window and tie-in, add 3'. RIH to corrected TD at 12086'. POOH for memory CNL log. 2/5/98 11 12086 Backream to window. POOH for logs. LD drilling BHA. MU and RIH with SWS GR/CNL Memory tool. Sat down at 9210' CTD (top of fish). Could not get past. POOH. LD logging tools. Will log after liner is cemented. MU 95 jts of 2-7/8" 6.164' L-80 STL/FL-4S mixed string. RIH on Baker CTLRT on 2-3/8" CT to TD. Circ and wait on vac truck with 2% KCI water. 2/6/98 12 12022 Circulate and wait on vac truck. Circ. 2% KCL water and recover FIoPro. Recip. Liner with water in annulus. Drop 5/8" ball and displace to CTLRT. Release Liner at 2000 psi. Held Safety meeting with crews. Pump 5 BBLS water ahead and 23.0 BBLS, 15.8 PPG, G cement. Drop Baker Dart and pump 2 bbls water. Check for and found dart in reel valve. Work dart free and displace. Dart on wiper plug seat and sheared at 3200 psi. Displace liner wiper plug at 3.5 BPM and 3600 PSI. Slow to 1 BPM 2 bbls early and land plug in landing collar on schedule. Pull free from liner and jet top of liner. POOH with CT. Layout Baker tools. RIH with 2.25" nozzle on CSH workstring. Tie-in at flag. Run in top of 2 7/8" liner at 9109 ft with no wt loss. RIH at 50 FPM jetting liner with 2% KCI to 12021' CTD (on depth to landing collar). POOH jetting to surface. Standback CSH. WO SWS loggers to finish on another job and then fix data downloader problem. MU SWS Memory GR/CNL. 2/7/98 13 MU logging tool. RIH with SWS Memory GR/CNL on CSH. RIH to PBTD of 12,022 ft BKB with no problems. Log down from 10,200 - 12,022 ft at 50 FPM. Log 300 ft repeat section off PBTD. Circulate in new high viscosity FIoPro for perforating and log up from 12,022 - 10,100 ft. POOH. Recover 100% of logging BHA. Download CNL/GR information on location. Load SWS 1 11/16" perf guns into pipe shed. Test liner at 2500 psi for 15 minutes. Safety mtg. MU 600' of 1-11/16" perfs guns with 100' blank. PU 37 stands of CSH. RIH on 2-3/8 CTto PBD. Load ball. Park at perf depth. Displace ball to seat with 2% KCI. Guns shot at 3400 psi. Perforated 11302-596' and 11699-12000' w/1-11/16" guns at 4 spf. POOH in Iow gear (injector problems). 2/8/98 14 Parked at 6000' working on injector. POOH with perf guns. Stand back 37 Stds of CSH. Safety Meeting with all personnel. Lay out 32 perf guns, All shots fired. PERFORATED INTERVALS: 11,302 - 11,596 and 11,699 - 12,000 FT BKB. 4 SPF, I 11/16" SWS Repaired injector head. [Partially plugged high/Iow gear shifting valve]. RIH and freeze protected 4 1/2" tubing to 2000 ft with MEOH. Displaced CT to Nitrogen for rig move. Changed out borrowed annular from Rig 2, with repaired annular. [new bag, seals and seal ring and threads re-dressed]. Empty rig pits. ND BOPE and secure. Scope down derrick. Load out misc equipment. Move off well. Install tree cap. Rig released at 0030 hrs 2/8/98. Move DS/N #1 to Q-07 for CT sidetrack (-32° F, CF -65° F). TREE: 4" CIW WELLHEAD: OCT (FMC) D-15a KB. ELEV = 71.42' 9-5/8" DV Packer 1261 13-3/8", 72#/ft, L-80, BTRS I2681 IKOP: 2700' I MAX ANGLE: 43°/6100' 4-1/2", 12.6#/ft, L-80, TDS TUBING TUBING ID: 3.958" CAPACITY: .0152 BBL/FT SSSVLANDING NIPPLE I 2100 I ( CAMCO)(3.813" ID) GAS LIFT MANDRELS Merla w/RA Latch) N° MD(BKB) TVD(SS) 5 3000 2925 4 5292 4862 3 7353 6392 2 8554 7337 1 8895 7610 Top of 2-7/8" 6.16# L-80 Liner 2.441" ID, 0.0058 bbl/ft TOPOFBOT I 7" LINERPBR 9215 9-5/8", 47#/ft, L-80, BTRS I 9730 I Bottom of cement I 9500 4 1/2 .... SWS" NIPPLE I 9143 ( 3.813" ID ) (parker) Right Hand Release I 'SAP' SEAL ANCHOR 91 54 9-5/8" OTIS MHR Packer 9160 ( 3.85" ID) 4 1/2", 12.6#/ft, L-80 TAILPIPE (ELMD) 9225 4 1/2 .... SWS" NIPPLE 9275 (Parker) (3.813" ID) 4 1/2 .... SWN" NIPPLE (Parker) (3.80" ID) 9296 4 1/2" TBG TAIL I WLEG (3.854" ID) 9308 SIDETRACK PERFORATION SUMMARY REF LOG: SPERRY SUN GR/ROP MWD Size SPF Interval Open/Sqz'd 1.69 4 11,302 - 11,596 Open 1.69 4 11,699 - 12,000 Open Abandonded Well Bore Cement top unknown-downsqueezed thru whipstock with cement and pressure tested 7" 29#/ft L-80 Liner @ 10730' PBD @ 10658' CTD HORIZONTAL SIDETRACK Latch Plug at PBTD I 12022 2-7/8" 6.16# L-80 STI_/FL4S I 12086 ! Company: Well: Calculation ~Method: Vertical Sect. iPlanc: '~ Measured From: Meas. Depth 10300.0 30.25 10320.0 30.98 10330.3 10366.6 35.51 10389.4 10422.9 10449.2 10482.6 10518.5 10552.4 582.8 il0 10667.0 10694.4 10725.6 10764.3 10795.0 10832.3 10863.5 10900.3 10936.5 10972.0 '11000.6 SI RV.E' LCU.LA HONS Coordinates provided, in: TRU'E and GRI.D relative to Wellheaq and ALASKA STATE PLANE .BP EXPLORATION INC, Rig: D-il 5AEOW Field: M.inimumTM ' (,urvamrc. Mag. Declination: 96.025 TRUE 94.9 GRID G rid Correction.: MD from RKB~ Total Correction: TVD from Sea level Subsea Vertical Coords.- TRUE TVD Section N(+)/S(-) E(+)/W(-) (ft) from TIP Lat. (Y) Dep. (X) 8746.30 0.00 4246.80 421.00 ORiGIN,AL Norq[c #1 aad D/S CT trait AFE No: Pn~d:hoe Bay BHI Rep: 28.301}~ Job Start Date: '75 Job End Date: 2Z125 iDLS per (ft / m ): 4.254.,2(~ 8763.51 3.00 4256.19 424.94 2 8772.26 4.60 4261.18 427.08 22.>!4"t 8802.33 11.20 4279.59 435.72 25.4.0 8820,50 16.30 4291.79 442.08 27..";0 4299.61 8845.69 25,50 4310.74 453.39 g i,?¥) 43'~ ~;.79 8864.17 35.30 4325.56 464.78 4.(i'.65 8886.12 51.70 4342.77 483.09 50.28 435 'l ,.:!.2 8907.51 72.40 4360.56 505.77 51!. ~ 8924.88 94.10 4377.50 529.41 55.15 8937.54 115.80 4392.23 552.77 57.97 8946.65 138.50 4405.36 576.95 ,,,'.-',,2.6() 4,4, t 5.!)2 8952.01 160.20 4415.92 599.85 65.50 4-42(-3.95 8955.56 186.30 4426.17 627. '7 '! .~)~ 44?7.76 Coords. - ASP N'(4.)/S(-) E(+)/W(-) Lat. (Y) Dep. (X) 5962655.22 654440.83 337..55 5962664.69 654444.58 339.5'9 5962669 654446.62 5962688.30 654454.87 3.53.9,5 654460.99 3d4..gg 5962719.811 654471.91 37'5.9d 5962734.86 654482.99 3%.9t. 5962752.44 654500.94 4t6.22. 5962770.69 654523.25 439.5! 5962788.12 654546.54 .4~.2.56 5962803 654569,59 4.~:i.46 5962816.94 654593.49 5i?.!5 5962827.97 6546116.18 5~6.24 5962838.78 654643.27 552.44 5962846.49 654669.47 592.92 5962853.02 654699.95 63~.i~ 5962858.77 654738.21 ~3~3.7'7 5962861.34 654768.80 654806. (.)5 5962863.17 654837.21 8957.60 211.70' 4433.34 653.52 7('>.2ti 4445.4'7 8958.72 241.50 4439.24 684.12 7v.60 8959.13 279.20 4444.21 722.49 ~,457.75 8959.05 309.40 4446.15 753.13 8958.04 346.40 4446.92 790.40 8956.57 377.50 4446.58 821.56 %.?0 4462. i Turn DLS °/lOOft. °/l.O(~ft. 0.00 0.00 -0.10 3.65 7.77 :16.72. 8.26 9.14, 8.33 15.1:1 13.43 1.7.27 33.65 27.1.3 28.83 24.44, 2.31 14.58; 11.92 21.. '18; 9.28 21..951 15.97 26.85 11.24 26.49' 18.71 22.78 18.98 19.68 10.90 14.36, 9.56, 12.38 13.31 2.95 4.56, 8.01 8.62. 3.26 3.2'7' -11.05 11.45 -8.17 8.64. 8954.55 414.10 4444.99 858.27 '~; !..9~ 44.5!.3 t 76('3.. ~:'2 5962862.33 654873.95 8952.93 450.20 4444.31 894.42 ~,; 7.'::! 4..:V; i_3 S ~:;('~::' .t:7 5962862.40 654910.10 8952.00 485.20 4445.78 929.88 ,:,5.o[) 44(!,?..58 ~:',~i';,49 5962864.60 654945.52 8951.51 513.40 4447.86 958.40 ~¥.!. 3,'.) 44.:56.24. ~%6.q<'!, 5962867.26 654973.99 -2.45 2.45 Meas. Incl. TRUE Subsea vertical Coords.- TRUE ("~,P~ ~'~:~ ~..,~,.~, l('3c0s.~.~d!~;~. .- .(;~]it:'All~!~ C(mrds. - ASP Build Turn DLS Depth Angle Azi. TVD Section .... N(+)/S(-) E(+)/W(-) ~.,~ ~'' ~.~.,. N (+)/S(-.0 ~i.;(+'~/W('.) "Ni+)/S(~)'" E(+)fW(.i) (deg) (deg) (ft) from TIP Lat. (Y) Dep. (X) ('~:~'.:~,!9 L:~.~:,,, (5?)~3~:% (X) La~. (Y) 'Dep. (X) °/100ft. °/100ft. °/l~0ft~ ....... 11037.6 89.90 90.08 8951.21 550.00 4449.30 995.36 ~,~'~ ...... ,o ~,:::~ 12,4-3 12.78 ,&, ..... ,,~ ,'+,,~ o~'~ ?.t.~, 9('t5 ~ 59628(39.46 655(tl. 0.91. -2.97 .... 11084.6 87.30 93.98 8952.36 596.80 4447.64 1.042.30 ~.,,:..,,,, ~'~ '~'"'~ 4,467.74. !~0>0, ..... o.-.,7o5962868.76 655057.88 -5.53 8.30 (.)...9"t ..... 11117.4 87.20 94.78 8953.94 629.60 4445.14 1074.97 !?B.:50 44.,~:. 5.~:~ ~. 9~;3 ~56 5962866.93 655090.59 -0.30 2.44 2.4.(5; 11145.2 86.90 96.18 8955.37 657.40 4442.49 1102.60 ~5 Oil .4~..:~.,.,,.,.l~_:~ .!,~.i~11 it..25 5962864.85 6552118.28 -1.08 5'.04 5.114, ..... 11186.8 92.72~ 102.38 8955.51 698.80 4435.79 1143.62 10't.20 4.4.57.!.;7'"'~,.,..,..z~a'~'~'~ ....... 'i:i'~.)1 59(32858 99 655159.42 13.99 14.90 2().44 11221.1 94.20 105.18' 8953.44 732.80 4427.64 1176.87 ~!):k(tO 44.5~1.5[ I~01i:.5.:'~0 5962851..53 655192.t;13 4.31 8.16 9.22 11262.5 93.10 106.08 8950.80 773.50 4416.52 1216.66 1,04. '90 4.4.'-1.f~ 9"I t ~ .... ~"~ ............ .5': (., ~: 5962841.22 6552132.84 -2.6.6 ........ 2.17 3..4.3: }97.1 91.90 103.08 8949.29 807.70 4407.82 1250.11 ~0'1~..9t) 4.4.32.1.9 i! !59.4.3 5962833.21 655266.46 -3.47 '8.'67 9.33 35.1 90.90 99.88 8948.36 845.40 1287.33 c}.<, "t ..'~""'5 4400.26 ,,, ,.:,.. ,.;,,, ,. ~,..., ~.::.~ !~ 96 ,~', ~. 5962826.412 655303.83 -2.63 -8.42 8.82 ...... ,c5,t~ } . . ?362.2 90.60 96.58 8948.01 872.60 4396.39 1314.15 95,4(t 4422,(>'7 t.223,(i,9 5962823,09 655330,72 -1.11 -12.18 ;12.23 11399.3 90.00 94.78 8947.81 909.70 4392.72 1351.06 93:4~ .t. 0 4,4. II 9.16 ~. 26.0 ~6~3 5962820.18 655367.71 -1.62 -4.85 5.1 '1 11432.2 90.20 99.78 8947.76 942.50 4388.55 1383.69 '91¢~60 4.4~5,05 }.'~9~i..!:~g 59628116.68 65540i').41 0.61 15.20 15.21 11468.0 90.70 105.38 8947.47 978.10 4380.76 1418.61 ~,.~4.~..0 59 ~'v"'5~.4.(~; 5962809.61 655435.49 1.40 15.'64 15.7() 11509.3 88.40 110.28 8947.80 1018.50 4368.13 1457.91 [.09 1.(]~ 4.39676 ~"~3,~:I.~"~".0[~", 59(32797.78 655475.041 -5.57 11.86 '13.111 11540.3 86.92 113.48 8949.06 1048.30 4356.59 1486.65 ~ ~ .~ ~,~.~ '?i~.~ .::~."~! ~:~ ~"~'~ i 390.9i~ 5962786 84 655504.0l -4.77 10.32 l 1.37 11582.7 88.60 116.48 8950.72 1088.30 4338.70 1525.05 ~t5.31f 4..?~68.72 }.435,.'7.::t.5962769.74 65554.5!.77 3.96 7.08 8.1© 11614.8 90.10 121.28 8951.09 1117.90 4323.21 1553.15 ~2~5>. t~'l .... "" I'~. ' ": '~ '~ .~.l..~ :,.',. ~ t 4.~,.;,-:-. ~ 5 5962754.83 6555711..118 4.67 14.95 15.67 11642.9 90.70 1.25.08 8950.89 1142.90 4307.83 1576.67 [21';.90 433I!;.~;'2 ! 44~7.97 5962739.94 655595.00 2.14 13.52 ;13.69 ...... ' 5 ~' 9. 11677.6 91.40 128.18 8950.25 1172.80 4287.14 1604.51 ~7'~;41 43 ~.17,.:5.;0 i>,t6.23 5962719.82 65..62:,.26 2.02' 8.93 16 11704.7 92.50 132.98 8949.33 1195.00 4269.53 1625.07 t'~ <":~ ~"~(, : ...... , 't ............~.:~.~',, l~.(,.,i '[ :~.', ~. 16> 9627()2.6.~ 655644.1.9 4.06 17.71 118.16 11735.2 92.40 136.88 8948.03 1218.80 4248.01 1646.64 [':i.'~. ">'it~'¢ .... ' ~ 559. 6 ...... ~.~,,.. ~t >.~ ii 1 5962681.56 655666.19 -0.33 12.79 '12.78 11763.6 90.80 140.88 8947.23 1239.60 4226.63 1665.31 [ 39,.'?'~,) 4'2:.'!).551 ..~ 5"?l';~2'75962660.57 655685.30 -5.63 14.08 15.16. 11791.3 88.70 136.88 8947.35 1259.90 4205.77 1683.52 'i.'3: ~'~ .45"~<:~ ~';7 :~'?(., (.~!) '- "t' / ........ ~ 5962640.09 -7.58 -14.44 '16..> 1 -, ...... 6>..'>70:,. )3 i827.4 88.10 132.98 8948.36 1288.00 4180.29 1709.071 ~.;~.~) 4.214..~:2 ~.::,22.96 5962615.14 655729.99 -1.66 -10.80 '10.93 ,~ ....... ":?' ~'"' '" ~'" .... ',~ ":;~-('~; .... 5962596.10 655753.76 -4.26 -20.33 ~>('* 75 .. 57.9 86.80 126.78 8949.72 1313.20 4160.77 1732.44 t'~q 6i3' -*~ .~.~...~o .... .'_,~ ..... 11893.0 87.40 119.58 8951.50 1344.40 4141.60 1761.76 ~ I?~ .... ~-'~ ,41-''''~, ,..-,..'::~',~ X.~:; ~'~'~ 4.4-I 5962577.54 655783.47 1.71 -20.51 ~'~0.56. 11926.7 90.40 116.78 8952.15 1375.60 4125.69 1791.46 '! !5.(',~ 4.1~:,i..22 :..7<;'¢.-1-6 59(32562.24 655813.4-9 8.90 -8.31 12.18 11959.2 91.20 113.58 8951.69 1406.30 4111.87 1820.86 ti2 '"' . ... .~.~ -~i4.8.0 i ~ 7~:('; !4- 5962549.03 655843.17 2.46 -9.85 10.15 11991.6 91.40 109.08 8950.96 1437.50 4100.10 185i'.03 i07 9~ :.i..3,(:.,~?;.5 37.(56 54 59(;2537.87 655873.57 0.62 -13.89 t3.90 12022.0 91.20 106.28 8950.27 1467.30 4090.87 1879.98 ~05.5.0 4~2','~ ~'2 :: 7!.)3.(:;..g 5962529.24 655902.71 -0.66 -9.21 9.23 12050.1 90.97 104.68 8949.74 1495.10 4083.37 1907.06 'i:"~3.5() --i-i21.2'~'; i ~22.90 5962522.30 655929.931 -0.82 -5.69 5.75 , """ '"' "-"'~' !SS',':? 5 5962518.81 655946.16 0.00 -16.27 16.26 12066.7 90.97 101.98 8949.45 1511.50 4079.55 1923.21 ~..{...~ .... ¢i i .,.:, 12086.0 90.97i 98.84 8949.13 1530.70 4076.06 1942.19 ,:)"7 ,:-:,,.-,; .:i-~ !,4.('i'.;~ !:~5~. i"7 59625115.7l 655965.20 0.00 -16.27 .16.27 ., ma EXPLORATION : :,- · , Attention: ;; , Date: Jan, 28, l gg8 Alaska Oil & Gas Conservation Commission 3001 Poroupine Drive Anchorage, Alaska 99501 Blair Wondzell Sr, Reservoir Engineer Well D-15a Tubing Tailpipe Our conve~sation about this well yesterday incorreotly assumed that the tailpipe had fallen all the way,to the 7"whipstock, This has been found to b~ incorrect. The following describes the current situation and the fo~ard' plan. The 4.5', 8,3 ft long tu,bing tailpipe was inadvertently backed off while milling out!:the 8WN topple which,la a part of this tailpipe. A Gamma Ray CCL rpg was run across the mt,erval and confirmed that the tailpipe fei! into the 7" liner but is being held at the top of t.he liner by the 8,$" x ~,5" oross over that backed off from the production packer. :, Sidetrack drilling and completion operations can be conducted through this 4.5" t~i'iipipe if further movement of the tailpipe can be arrested. A balanced 'bar cement plug will be layed from 200 ft below to 20 ft. above the Iailpipe, Cement will then be milled throu.~h and below the tailpipe to .~nable sidetrack drilling Operations to continue. The 2 7~8' approx, 3( liner cema approx. 4( A schema' Ted Stagg CT Drillin{! Engineer cc: Well Fiie Petrot~chnical Data Center liner top will be extended to place the top of the liner feet above the 4.5" $W$ nipple at 9143'MD~ The 2 718' nt volume will be estimated to place the top of liner cement !0 ft above the window 10,330'. ic diagram of the planned completion is affached. TREE; WELLHEAD: ACTUATOR; 15-3t8", 72;q~lt, ' . M~ ANGLE: 43"~10ff TUBING TUBING ID: ~PACI~: .0152 BBUFT TO. OF BOT i 921 7" LINER PaR · 4,5" Tailpipe backe8 off and lodged in top of 7" (~ner. ~11 s~bilize tailpipe w~h ~ment b~om continuing s~d~rack. L-80, BTR~ 2 718" Cemented Liner Bm of whipetoo~ and top of squeeze cmt. approx, t0,32t' Abandonment amt. ~queezed PERFORATION 8U~ REF LOG: $W$-BHC~- ?-16-80 .I il.II i$1ze l SPF Interval iJ OperVSqz'd 3.3/a,,I 6 10,343- :10,~,3¥- Open ?, I L!; :- "~-~ KB. ELEV --- 71.42' 4" ClW [ ocr(FMc) D-tSA Proposed Completion eF, ELEV=47,tT' BAKER .', ;' 8SSV LANDING NIPPLE ( CAMCO)(3.813" ID) 2100 PBTD 7"', 29 #/fl, L-80, BTRS GAS LIFT MANDRELS Merle w/IRA Lalctt) ~1o_MD(BKB) MD(Ss) s 3000 2925 4 5292 4862 3 ?363 6392 :t 8554 7337' I 8895 76t0 .. . 4 1/~" "~WS" NIPPLE ( 3,813" ID ) (parker) Right Hand ReleaM 'SAP' SEAL ANCHOR ~.5/8" OTIS MHR Paoker ( 3.8S' ID) 4 I/;Z", ~12.6~, L.80 TAILPIPE 9143 9't64, 9160 4, 1/2" "SWS" NIPPLE (Parker) (3.813" ID) 4 1/2" "SWN" NIPPLE (Parker) (3.750" ID) 4 1/2" TBG TAIL WLEG (3.854" ID) MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 26, 1998 THRU: Blair Wondzeil, ~ P. i. Supervisor ~/~.~[~ FILE NO: AHUKAZFE.DOC FROM: Chuck Scheve, Petroleum Inspector SUBJECT: BOPE Test Nordic 1 PBU D-15 A PTD 97-212 Monday January 26.1998: I traveled to BPXs PBU D Pad to witness the initial BOPE Test on Well D-15A being drilled by the Dowell Schulumberger / Nordic 1 coil tubing drilling unit. As the attached AOGCC Test Report shows,the test lasted 2.5 hours and there were no failures. The testing went very well with good test procedures being employed by the Nordic crew. The Rig was clean and all related equipment appeared to be in good condition. SUMMARY: I witnessed the initial BOPE test on Nordic Rig 1 drilling BPXs D-15A Well. Nordic 1, 1/26198, Test Time 2.5 hours, 0 Failures Attachments: ahukazfe.xls X Unclassified Classified Unclassified with Document Removed STATE OF ALASKA ..... OIL AND GAS CONSERVATION COMMISSION Coil Tubing Unit BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: DS / Nordic Rig No. I PTD # 97-2~2 Operator: SSD Rep.: Well Name: D-15A Rig Rep.: Casing Size: Set @ Location: Sec. Test: Initial X Weekly Other DATE: 1/26/98 Rig Ph.# 659-0247 Charlie Parker Zane Montague 23 T. I~N R. ~3E Meddian UM BOP STACK: Coil Tubinq Unit: Pipe/Slip Rams Pipe/Slip Rams Blind Rams Reel Isolation Valve Deployment: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Test Test Quan. Pressure P/F Pressure P/F 200/4000 P 200~4000 I 200/4000 P CHOKE MANIFOLD: Quan, No. Valves ~5 P No. Flanges 30 200/4000 P Manual Chokes 1 Functioned P Hydraulic Chokes ~ Functioned P 200/4000 I 200~000 P 1 200~000 P 1 200~000 P 2 200~000 P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Bti's: 3~2~00 2 OK 2900 2100 , , minutes 25 minutes 50 Remote-: Psig. sec. sec. OK MUD SYSTEM: Visual Alarm Tdp Tank OK OK Pit Level Indicators OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK . MISC. INSPECTIONS: Location Gen.: Housekeeping' Permit to drill: Standing Order Posted OK OK Yes Yes Well Sign OK Drl. Rig OK Hazard Sec. Yes Number of Failures: 0 ,Test Time:' 2.5 Hours. Number of valves tested 21 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 If your call is not returned by the inspector within 12 hours please contact the P. !. Supervisor at 279-1433 REMARKS: Good Test Distribution: odg-Well File c - Oper.tRig 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: Chuck Scheve Form Revised 2/20/97 L.G. Ahukazfe 1126198 TONY KNOWLE$, GOVERNOR AL&SKA OIL AND GAS CONSERVATION CO~IISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 19. 1997 Ted Stagg Coiled Tubing Engineer BP Exploration (Alaska) Inc. POBox 196612 ,Anchorage., AK 99519-6612 Re' Prudhoe Bay Unit D-I 5A BP Exploration (Alaska) Inc. Permit No: 97-212 Sur. Loc.: 2600'SNL, 1067'WEL. Sec. 23. T11N. RI3E. UM Btmhole Loc: 1450'NSL 4406'WEL. Sec. 13. T11N. R13E. UM Dear Mr. Stagg: 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 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling beloxv 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. · Chairman BY ORDER OF THE COMMISSION dlf/enclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Envinornment Conservation w,'o encl. -- STATE OF ALASKA ALASKA ..,.~ .,_ AND GAS CONSERVATION CO,..¢IlSSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic TeSt [] Development Oil la. Type of work [] Re-Entry E~ D...eepenl E~]Service [] Development Gas [] Single Zone I"-i Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 71.42 AMSL Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028285 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2600' SNL, 1067' WEL, SEC. 23, T11N, R13E, UPM . ..P. rudhoe Bay Unit At top of productive interval 8'.'" Well Number Number 2S100302630-277 1495' NSL, 714' WEL, SEC. 14, T11N, R13E, UPM D-15A At total depth 9. Approximate spud date Amount $200,000.00 1450" NSL, 4406' WEL, Sec 13, T11N, R13E 11/26/97 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028280 @ 3829'I no close approach 2560 12,101 , 8925 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10,316 Maximum Hole Angle 90° Maximum surface 3300 psig, At total depth (TVD) 8949' 4209 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3 3/4" 2 7/8" 6.16# L-80 ST-L 2840 9225 9220 12,065 8,926 112 c.f. -~. 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~;:~ ,... !;..r~, ~.~ Present well condition summary , ......, .! Total depth: measured 10730 feet Plugs (measured) '~.:'? v true vertical BKB 9190 feet Effective depth: measured 10658 feet Junk (measured) fill at 10612' MD (08/89) ...... .. true vertical BKB 9128 feet ?;?,._?..,.~ ..... U~'~ :;~ Casing Length Size Cemented MD TVD Structural Conductor 110 20x30 14 c.y. 134 134 Surface 2655 13 3/8 4464 c.f. 2679 2679 Intermediate 9706 9 5/8 1374 c.f. 9730 8343 Production Liner 1516 7 390 c.f. 9214-10730 7941-9190 Perforation depth: measured 10421'-10467',10477'-10494',10504'-10525' true vertical 8922'-9012' (three intervals) '~'O. Attachments [] Filing Fee [] Drilling Fluid Program [] Property Plat []Time vs Depth Pict [] BOP Sketch [] Refraction Analysis [] I Contact Engineer Name/Number: Ted Stagg 564-4694 Prepared By Name/Number: Theresa Mills 564-5894 ~'i.I hereby certif~ th~t,t~.e foregoing is true and correct to the best of my knowledge Signed ~/~~'/'/~/~'~ 5"~,~--"~(¢~,/ Title Coiled Tubing Drilling Engineer Date Commission Use Only Permit Number I APl Number I APpr°va-I 'D6~ ISee cover letter .~ ~-"~ Z.. 50- c'~ 2__ ? - 2. O ~/~" / '- ~ / l ("' ! c~ for other requirements Conditions of Approval: Samples Required [] Yes ~[~ No Mud Log Required [] Yesfj~l No Hydrogen Sulfide Measures ~Yes [] No Directional Survey Required "~ Yes [] No [] [] ~ ~-,,,~ [] [] Required Working Pressure for DOPE 2M; ~~M";'" 5M; byorc~e0rl~¢ 15M iApproved By (,.}ri~irls. l Si,qflP~(] I~,¥ Commissioner the commission Date Form 10-401 Rev. 12-01-85 David W. Johnston Submit In Triplic~tte BPX D-15A Sidetrack Summary of Operations: D-15 is currently shut-in due to high GOR. The sidetrack, D-15A, will target the 21P sand with an inverted tail into the 22P sand. This sidetrack will be conducted in two phases. Phase 1' Set whipstock and squeeze abandonment cement: Planned for 11121/97. · D-15 has passed a tubing integrity test. The well will be drifted and a Kinley caliper run to evaluate liner condition. · A permanent whipstock will be set on ELine at approximately 10,305' MD. · Existing perorations will be abandoned with approx. 20 bbls of cement by downsqueezing cement past the permanent whipstock. Abandonment cement will be pressure tested to 1500 psi with AOGCC witness. Phase 2' Mill Window and Drill Directional Hole: Planned for 11126197. Directional drilling coil tubing equipment will be rigged up and utilized to mill the window and drill the directional hole as per attached plan to planned TD of 12,065' MD (8,926'-I-VDss). Mud Program: - Phase 1' Seawater - Phase 2: FIo-Pro (8.8 - 8.9 ppg) Casing Program' - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 9225' MD and cemented with approx. 20 bbls. cement. The well will then be perforated with coil tubing conveyed guns. Well Control: - BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 10,316' MD (8,760' -I-VD ss) - TD: 12,065' MD (8,926' 'I-VD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · CTE-Line conveyed open hole logs including GR/Induction. D-15 0 Vertical Section 500 1 ,ooo 8600 8650 Path Distance(Feet) 1,500 2,000 2,500 3,000 TZ3 ..... ........ TZ2C Angle @ K.O.= 30 deg MD:10318 30 deg DL 2= 18 deg/100 Marker Depths @Orig Wellbore TSAD TZ3 8,9601 8,9601fl TVD 8,9251 8,9251ft TVD I s, sol D I 8,650 ft TVD Kick Off Deprtr @KO 8,7621ff TVD lO,3181ff MD 4,291 ff 10,318 1783 12,101 8,92S MD KO Pt MD New Hole Total MD TVD TD DLS deg/100 Tool Face Length Curve 1 Curve 2 Curve 3 Curve 4 Curve 5 18 35 90 90 Curve 6 8 180 Curve 7 8 -90 4O2 769 9O 180 84 249 1,783 Drawn: 11/4/97 16:59 Plan Name: Case 201 D-15 0 500 1,000 1,500 2,000 2,500 X distance from SfcLoc IWellName D-15 I CLOSURE Distance 4,615 ft I Az 18 deg I NEW HOLE E/W (X) N/S (Y) IKick Off Ti~tate Plane 3371 4,263 1,4391 4,385 655,5461 5,962,786 Surface Loc 654,107 5,958,401 DLS deg/100 Tool Face Curve 1 Curve 2 Curve 3 18 35 90 Length 9 402 769 Curve 4 8 0 90 Curve 5 8 90 180 Curve 6 8 180 84 Curve 7 8 -90 249 Drawn: 11/4/97 16:59 Plan Name: Case 201 1,783 TREE: 4" ClW WELLHEAD: OCT (FMC) ACTUATOR: BAKER D-15A Proposed Completion KB. ELEV = 71.42' BF. ELEV = 47.17' 9-5/8" DV Packer I 2612' 13-3/8", 72#/ft, L-80, BTRS 2681' KOP: 2700' MAX ANGLE: 43°/6100' 4-1/2", 12.6/¢/ft, L-80, TDS TUBING TUBING ID: 3.958" CAPACITY: .0152 BBL/FT TOP OF BOT , 7" LINER PBRI 921 9-5/8", 47#/ft, L-80, BTRS I 9730' I 2 7/8" Cemented Liner Bottom of whipstock and top of squeeze cmt. approx. 10,321' IAbandonment cmt. squeezed through whipstock. PERFORATION SUMMARY REF LOG: SWS-BHCS- 7-16-80 ISize,,I SPF 3-3/8 J 6 Interval 10,343 ~ 10,353' 10,421 ~ 10,467' 10,477 ~ 10,494' 10,504 - 10,525' Open/Sqz'd Open Sqz'd Open Open PBTD 7" , 29 #Iff, L-80, BTRS J 10658'I 07301 SSSV LANDING NIPPLE I ( CAMCO)(3.813" ID) J 2100 GAS LIFT MANDRELS Merla wi RA Latch) NO MD(BKB) I-VD(SS) 5 3000 2925 4 5292 4862 3 7353 6392 2 8554 7337 I 8895 7610 4 1/2 .... SWS" NIPPLE ( 3.813" ID ) (parker) Right Hand Release 'SAP' SEAL ANCHOR 19143 9154 9160 9215 9-5/8" OTIS MHR Packer ( 3.85" ID) 4 1/2", 12.6#/ft, L-80 4T~2PI P~/S'' NIPPLE (Parker) (3.813" ID) 4 1/2 .... SWN" NIPPLE (Parker) (3.750" ID) 4 1/2" TBG TAIL WLEG (3.854" ID) (ELMD) 9237 9248 9239 D-15A CT Drilling & Completion BOP 12" UJ 22.5" 18"I 38" 7 1/16" Annular 7 1/16" 5000 psi 7 1/16 I Pipe/Slip I ~1~ ~ 2 3/8" Slips ~ -~ 2 718" 7 1/16" Pipe ~ ~ 2 3~8" 7 1/16" x 5,000 psi SWAB OR MASTER VALVE · WELL PERMIT CHECKLIST COMPANY '<~:;',~ WELL NAME ,,~_~ ,~-,,~.'5"',,,~ PROGRAM: exp [] dev~/redrll,~serv [] wellbore seg U ann. disposal para req [] FIELD & POOL ~"z-~O_,/'_~'~ INIT CLASS ._//~ .//~,,~/~// GEOL AREA ~'?,:~) UNIT# //g',.>~'<d ON/OFF SHORE ,/"24_,] ADMINISTRATION 1. Permit fee attached ....................... N 2. Lease number appropriate ................... N 3. Unique well name and number .................. N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unit boundary .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included ............... N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N ENGINEERING 14. Conductor string provided ................... Y N 15. Surface casing protects all known USDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg ........ Y N 18. CMT will cover all known productive horizons .......... ~) N'~ 19. Casing designs adequate for C, T, B & permafrost ....... (~ N 20. Adequate tankage or reserve pit ................. ~N 21. If a re-drill, has a 10-403 for abandonment been approved... ,.Y,_ N 22. Adequate wellbore separation proposed ............. ~ N 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... ~,,,~'~i 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~ ~'-'I~-L~ psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. REMARKS GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. //Y N 34. Contact name/phone for we.eklyprogress repqrts ...... / Y N lexplora~ory only] GEOLOGY: ENGINEERING' COMMISSION: BE~~' JDH_~~ DWJ~ RNC~_.~ CO ~ Comments/Instructions: HOW/lit - A:\FORMS\cheklist rev 09/'97 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. * ALASKA COMPUTING CENTER * . . .............................. * ............................ * ****************************** COMPANY NAME : BP EXPLORATION (ALASKA) WELL NAME : D-15A FIELD NAlVlE : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292046101 REFERENCE NO : 98290 LIS. Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-1998 15:56 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/06/23 ORIGIN : FLIC REEL NAFiE : 98290 CONTINUATION # : PREVIOUS REEL : CO~_~VT : BP EXPLORATION, PRUDHOE BAY, D-15A, API #50-029-20461-01 **** TAPE HEADER **** SERVICE NA~E : EDIT DATE : 98/06/23 ORIGIN : FLIC TAPE NA~E : 98290 CONTINUATION # : 1 PREVIOUS TAPE : COM~iENT : BP EXPLORATION, PRUDHOE BAY, D-15A, API #50-029-20461-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAMe: D-15A API NIIM~ER: 500292046101 OPERATOR: BP EXPLORATION (ALASKA) LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 23-JUN-98 JOB NUMBER: 98290 LOGGING ENGINEER: J SPENCER OPERATOR WITNESS: R WHITLOW SURFACE LOCATION SECTION: 23 TOWNSHIP: 1 iN RANGE: 13E FNL: 2600 FSL: FEL: 1067 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 71.40 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 7. 000 10330.0 26. O0 2ND STRING 2. 875 12086.0 6.16 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS' Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-1998 15:56 PAGE: BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .............. 88888 0 11982 5 11981 5 11943 5 11943 0 11937 5 11937 0 11927 5 11927 0 11921 0 11920 0 11908.0 11907.5 11902.5 11902.0 11891.0 11886.5 11886.0 11871.5 11870.5 11811.0 11810.5 11807.5 11807.0 11745.0 11743.5 11733.5 11732.5 11697.0 11696.0 11688.5 11687.0 11681.5 11681.0 11571.0 11570.0 11540.0 11532.5 11503.0 11502.0 11469.0 11452.0 11451.0 11433.5 11418.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNT 88885.5 88884.5 11979.0 11941.0 11935.5 11924.5 11920.0 11906.5 11900.5 11891.0 11884.5 11869.0 11808.5 11803.5 11738.5 11727.5 11690.5 11682.5 11674.5 11565.5 11535.5 11529.0 11499.5 11467.0 11451.0 11434.0 11418.0 11979.0 11941.0 11935.5 11924.5 11920.0 11906.5 11900.5 11891.0 11884.5 11869.0 11808.5 11803.5 11738.5 11727.5 i1690.5 11682.0 11674.5 11565.5 11535.5 11529.0 11499.5 11467.0 11451.0 11434.0 11418.0 LIS' Tape Verification Listing Schlumberger Alaska Computing Center 11407.5 11405.5 11405.5 11375.0 11375.5 11375.5 11366.0 11363.0 11363.0 11347.0 11346.5 11346.5 11335.5 11334.0 11334.0 11327.0 11324.0 11324.5 11309.5 11307.5 11307.5 11282.5 11280.0 11281.5 11280.0 11274.5 11272.5 11274.0 11272.5 11245.0 11245.0 11245.0 11231.5 11230.0 11230.0 11227.0 11227.0 11196.5 11197.5 11183.5 11183.5 11183.0 11183.5 11180.5 11179.5 11170.0 11170.5 11170.5 11164.0 11163.0 11163.0 11160.5 11160.0 11160.0 11160.0 11157.0 11157.0 11156.0 11157.0 11152.0 11152.5 11152.0 11146.0 11145.5 11145.5 11145.0 11142.5 11141.5 11141.5 11141.5 11129.5 11130.0 11128.5 11130.0 11123.0 11124.0 11122.5 11124.0 11117.5 11118.0 11118.0 11115.5 11115.5 11115.5 11102.0 11100.0 11100.0 11064.5 11063.5 11063.5 11063.5 11058.5 11057.5 11057.5 11052.0 11051.0 11051.0 11051.0 11040.5 11042.0 11042.5 11036.0 11037.5 11037.5 11019.5 11022.0 11019.0 11021.5 11012.0 11013.5 11011 . 0 11013.5 10998.5 10999.0 10998.0 10999.0 10991.5 10991.5 10991.0 10991.5 10966.0 10967.0 10965.0 10966.5 10961.0 10962.0 10960.5 10962.0 10935.5 10937.5 23-JUN-1998 15:56 PAGE: 3 LIS' Tape Verification Listing Schlumberger Alaska Computing Center 10934.5 10936.5 10930.0 10930.5 10929.5 10931.0 10918.5 10918.5 10918.0 10918.5 10906.0 10907.0 10905.5 10906.5 10898.0 10899.0 10897.5 10899.0 10875.5 10878.0 10878.0 10872.0 10872.5 10870.5 10872.5 10866.5 10868.0 10865.5 10868.0 10863.5 10865.0 10863.0 10865.0 10860.5 10861.5 10860.0 10861.0 10855.0 10856.0 10853.0 10854.5 10851.5 10853.0 10851.0 10853.0 10849.5 10848.5 10849.0 10848.5 10841.0 10839.5 10839.5 10834.0 10834.0 10834.0 10832.5 10833.0 10832.0 10833.0 10826.5 10828.0 10826.0 10828.0 10825.5 10826.0 10826.0 10821.5 10823.0 10820.0 10821.0 10820.5 10818.5 10818.5 10808.0 10810.5 10810.5 10794.5 10797.0 10797.0 10790.5 10790.0 10790.0 10790.5 10784.5 10785.5 10785.5 10779.5 10780.0 10778.5 10780.0 10773.0 10774.5 10772.5 10774.0 10768.0 10770.0 10763.5 10767.0 10756.5 10758.0 10758.0 10742.0 10744.0 10744.0 10726.0 10725.5 10725.5 10718.5 10718.0 10718.0 10718.0 10715.5 10715.0 10715.0 10715.0 10700.5 10701.5 10700.0 10701.0 10683.5 10684.5 10684.0 10669.5 10668.0 23-JUN-1998 15:56 PAGE: LIS.Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-1998 15:56 PAGE: 5 10669.0 10668.0 10661.5 10659.0 10660.5 10659.0 10652.0 10651.0 10651.5 10651.0 10648.5 10647.0 10647.5 10647.0 10644.5 10642.5 10642.5 10640.5 10638.5 10638.5 10635.0 10633.5 10634.5 10633.5 10615.5 10615.5 10615.5 10611.5 10610.5 10610.5 10605.0 10603.0 10604.5 10603.0 10603.0 10601.5 10601.5 10599.0 10598.0 10598.0 10596.5 10594.0 10595.0 10594.0 10594.5 10592.5 10593.0 10592.0 10578.5 10577.0 10577.0 10568.0 10568.0 10568.0 10566.5 10566.0 10566.0 10562.0 10561.5 10561.5 10559.0 10557.5 10557.5 10553.5 10552.5 10552.5 10546.5 10546.5 10546.0 10546.5 10543.5 10542.5 10542.5 10542.0 10540.5 10540.5 10535.5 10535.5 10535.5 10527.5 10526.0 10526.0 10519.0 10519.5 10519.5 10515.0 10515.5 10515.5 10508.5 10503.5 10503.5 10501.5 10495.5 10500.5 10495.5 10488.5 10485.0 10485.0 10479.0 10477.5 10477.5 10475.0 10472.0 10472.0 10470.5 10468.0 10468.0 10464.0 10461.0 10463.5 10461.0 10460.5 10458.0 10459.5 10458.0 10448.0 10446.0 10446.0 10446.0 10445.0 10445.0 10444.0 10441.5 10441.5 10438.0 10437.5 10437.5 10437.5 10430.5 10428.5 10428.5 10426.0 10424.5 10425.5 10424.5 10422.5 10421.5 10421.5 10420.5 10419.0 10419.0 LIS~ Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-1998 15:56 10419.0 10417.5 10417.0 10416.5 10414.0 10416.0 10414.0 10409.5 10410.0 10410.0 10399.0 10397.5 10398.5 10397.5 10393.0 10393.0 10393.0 10391.0 10391.5 10391.5 10388.0 10386.5 10386.5 10386.5 10385.0 10385.5 10385.0 10377.5 10376.5 10375.5 10374.0 10375.0 10374.0 10373.5 10372.5 10372.5 10370.0 10367.5 10368.0 10366.5 10366.0 10366.0 10364.5 10358.5 10356.0 10357.5 10356.5 10354.5 10352.0 10352.0 10347.5 10346.0 10346.0 10343.5 10342.0 10342.0 10331.5 10332.0 10332.0 10329.0 10329.5 10328.5 10329.5 10327.0 10326.5 10326.5 100.0 99.5 99.5 $ CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNT DATA AQUIRED ON BP EXPLORATION'S D-15A WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE MWD GAf4~A RAY, ALSO PASS #1 NRAT AND THE MWD GAM~A RAY, CARRYING ALL CNT CURVES WITH THE ArRAT SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS--ER: 1 LIS. Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-1998 15:56 PAGE: DEPTH INCREMENT: 0.5000 FILE SUMIVlARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 12007.5 1 O144.5 CNT 12018.5 10144.5 $ CURVE SHIFT DATA - PASS TO PASS (F~EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNT .............. REMARKS: THIS FILE CONTAINS CASED HOLE CNT PASS #1. NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS- Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-1998 15:56 PAGE: ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNT GAPI 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 NCNTCNT CPS 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 FCNTCNT CPS 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12018. 500 GRCH. CNT -999. 250 NCNT. CNT 6263. 530 FCNT. CNT NRA T . CNT 11. 864 DEPT. 10144.500 GRCH. CNT 23.914 NCNT. CNT 4592.830 FCNT. CNT NRAT. CNT 9.620 394.052 316.928 ** END OF DATA ** **** FILE TRAILER **** FILE NA~IE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAi~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS--ER: 2 DEPTH INCREMENT: 0.5000 LIS. Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-1998 15:56 PAGE: FILE SO?4M_ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12010.0 11677.5 CNT 12019.5 11681.0 $ CURVE SHIFT DATA - PASS TO PASS (ICEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS--ER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH CNT 88888.0 88888.0 88885.5 12016.0 12013.5 12009.5 12006.0 12007.5 12004.0 11992.5 11989.0 11989.5 11989.5 11981.0 11979.5 11979.0 11978.5 11976.5 11974.0 11970.0 11966.0 11969.0 11967.5 11963.5 11960.5 11959.5 11958.0 11958.0 11957.5 11956.5 11955.5 11950.5 11947.5 11950.0 11947.0 11942.0 11937.5 11937.0 11934.0 11936.0 11935.5 11933.5 11932.5 11928.5 11926.0 11924.5 11923.0 11921.0 11920.0 11920.0 11920.0 11914.5 11913.5 11912.0 11910.5 11904.5 11906.5 11902.5 11900.5 11899.0 11900.5 11897.0 11898.0 11893.0 11892.5 11890.0 11884.0 11887.5 11882.0 11882.5 11884.5 11880.5 11874.0 11874.0 11869.0 11867.0 11867.5 11861.5 11861.5 11849.5 11845.0 LIS. Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-1998 15:56 PAGE: 10 11847.5 11846.5 11841.0 11841.0 11833.5 11833.0 11831.0 11824.0 11830.5 11828.5 11829~5 11821.0 11822.5 11813.5 11811~5 11808.5 11804.0 11800.5 11798.0 11796.0 11794.0 11792.5 11791.5 11791.0 11791c0 11786.5 11788.5 11784.0 11774.5 11770.5 11772.5 11769.5 11764.5 11762.0 11759.5 11758.0 11757.0 11754.0 11754.5 11752.0 11753.0 11750.5 11750.5 11751.5 11748.5 11748.5 11745.0 11744.0 11737.0 11737.5 11730.5 11727.5 11729.0 11727.5 11727.5 11723.0 11726.5 11725.5 11722.5 11723.0 11719.0 11715.0 11718.5 11719.5 11715.0 11710.5 11712.5 11712.5 11708.0 11707.5 11700.0 11701.0 11694.5 11696.0 11686.0 11687.0 11685.0 11682.5 100.0 97.5 101.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE CNT PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NRAT PASS #2 AND NRAT PASS #1, CARRYING ALL CNT CURVES WITH THE NRAT SHIFTS. $ LIS FORMAT DATA LIS-Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-1998 15:56 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 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 NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNT GAPI 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 NCNTCNT CPS 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 FCNTCNT CPS 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CArT 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12019.500 GRCH. CNT -999.250 NCNT. CNT 6365.218 FCNT. CNT NRA T. CNT 10o 590 413.867 DEPT. 11677.500 GRCH. CNT NRAT. CNT -999.250 27.087 NCNT. CNT -999.250 FCNT. CNT -999.250 ** END OF DATA ** LIS. Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-1998 15:56 PAGE: 12 **** FILE TRAILER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 3 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS--ERS 1, 2, CNT THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1 & 2. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ 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 LIS. Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-1998 15:56 PAGE: 13 TYPE REPR CODE VALUE 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 - CHAlV ** NANiE SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNAV GAPI 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 CVEL CNAV F/HR 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 NCNTCNAV CPS 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 FCNTCNAV CPS 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNAV 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12018.500 GRCH. CNAV -999.250 CVEL.CNAV FCNT. CNAV 399.078 NRAT. CNAV 11.758 25. 911 NCNT. CNAV 6325. 119 DEPT. 10144.500 GRCH. CNAV 23.914 CVEL.CNAV -999.250 NCNT. CNAV -999.250 FCNT. CNAV -999.250 NRAT. CNAV -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS. Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-1998 15:56 PAGE: 14 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : OFILE HEADER FILE NUMBER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCRuEFIFIVT: 0.5000 FILE SUF~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12031.3 10132.6 MCNL LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY MCNL MEMORY CNL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TE~fPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 06-FEB-98 RELOO31A 12086.0 12026.0 10145.0 12022.0 TOOL NUMBER GR MCNL 12086.0 LIS-Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-i998 15:56 PAGE: 15 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 1000 NEAR COUNT RATE LOW SCALE (CPS): 300 NEAR COUNT RATE HIGH SCALE (CPS): 15300 TOOL STANDOFF (IN): REMARKS: RANMEMO CArL @ BOTTOM OF COIL TUBING. TIED INTO SPERRY G2 2-FEB-98. THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 255 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LISt Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-1998 15:56 PAGE: 16 ** SET TYPE - CHAN ** NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD~ SAMP ELEM CODE (HEX) DEPT FT 0000000 CVEL PS1 F/HR 0000000 GR PS1 GAPI 0000000 NCNTPS1 CPS 0000000 FCNTPS1 CPS 0000000 NRAT PS1 0000000 ETIM PS1 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10132.643 CVEL.PS1 -999.250 GR.PS1 -999.250 NCNT. PS1 FClgT. PS1 -999.250 NRAT. PS1 -999.250 ETIM. PS1 -999.250 DEPT. 12031.342 CVEL.PS1 -999.250 GR.PS1 -999.250 NCNT. PS1 FCNT. PS1 -999.250 NRAT. PS1 -999.250 ETIM. PS1 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : OFILEHEADER FILE NUFIBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS AU3?4~ER: 2 LIS~ Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-1998 15:56 PAGE: 17 DEPTH INCREMENT: 0.5000 FILE SUF~W_ARY VENDOR TOOL CODE START DEPTH 12030.9 MCNL LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIFiE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAJV~IA RAY MCNL MEMORY CNL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH .......... 11668.3 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 06-FEB-98 RELOO31A 12086.0 12026.0 10145.0 12022.0 TOOL NUMBER ........... GR MCNL 12086.0 THERMAL SANDSTONE 2.65 LIS. Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-1998 15:56 PAGE: 18 FAR COUNT RATE HIGH SCALE (CPS): 1000 NEAR COUNT RATE LOW SCALE (CPS): 300 NEAR COUNT RATE HIGH SCALE (CPS): 15300 TOOL STANDOFF (IN): REMARKS: RAN I~MO CArL @ BOTTOM OF COIL TUBING. TIED INTO SPERRY G2 2-FEB-98. THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 255 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 CVEL PS2 F/HR 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS2 GAPI 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 NCNTPS2 CPS 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 FCNTPS2 CPS 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 NRAT PS2 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 ETIM PS2 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 LIS.~ Tape Verification Listing Schlumberger Alaska Computing Center 23-JUN-1998 15:56 PAGE: 19 ** DATA ** DEPT. 11668.334 CVEL.PS2 FCNT.PS2 -999.250 NRAT. PS2 DEPT. 12030.934 CVEL.PS2 FCNT. PS2 -999.250 NRAT. PS2 -999.250 GR.PS2 -999.250 ETIM. PS2 -999.250 GR.PS2 -999.250 ETIM. PS2 -999.250 -999.250 -999.250 -999.250 NCNT. PS2 NCNT. PS2 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/06/23 ORIGIN : FLIC TAPE NAME : 98290 CONTINUATION # : t PREVIOUS TAPE : COlW~4ENT : BP EXPLORATION, PRUDHOE BAY, D-15A, API #50-029-20461-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/06/23 ORIGIN : FLIC REEL NAME : 98290 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, PRUDHOE BAY, D-15A, API #50-029-20461-01 Sperry-Sun Drilling Services LIS Scan Utility Thu Apr 02 23:19:25 1998 Reel Header Service name ............. LISTPE Date ..................... 98/04/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Tape Header Service name ............. LISTPE Date ..................... 98/04/02. Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW- 80112 B. JAHN HILDRETH / SEV M C OF LMED D-15A 500292046101 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 02-APR-98 MWD RUN 3 MWD RUN 4 AK-MW-80112 AK-MW-80112 B. JAHN B. JAHN HILDRETH/SEV HILDRETH / SEV JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 5 AK-MW-80112 B. JAHN HILDRETH/SEV MWD RUN 6 MWD RUN 7 AK-MW-80112 AK-MW-80112 S. LATZ S. LATZ HILDRETH/SEV HILDRETH/SEV 23 liN 13E 2600 1067 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 71.40 .00 .00 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 9730.0 7.000 10330.0 2.875 12086.0 12086.0 3.750 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUN 1 CONTAINS NO VALID DATA AND IS NOT PRESENTED. 4. MWD RUNS 2 THROUGH 7 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND GREG BERNASKI OF BP EXPLORATION (ALASKA), INC. ON 23 MARCH, 1998. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12085'MD, 8949'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10315.0 12058.5 ROP 10343.0 12084.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 2 10343.0 10538.0 3 10538.0 10728.0 4 10728.0 11145.0 5 11145.0 11589.0 6 11589.0 11822.0 7 11822.0 12085.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10315 12084.5 11199.8 3540 10315 GR 7 315.69 29.353 3488 10315 ROP 17.57 2102.46 106.953 3484 10343 Last Reading 12084.5 12058.5 12084.5 First Reading For Entire File .......... 10315 Last Reading For Entire File ........... 12084.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10315.0 ROP 10343.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.01 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10510.0 10538.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 01-FEB-98 MSC 1.32 NGP 6.90, DEP 2.21, PCD MEMORY 10538.0 10343.0 10538.0 32.7 56.1 TOOL NUMBER PCG 8 3.750 3.8 Flo Pro 8.80 65.0 9.2 30000 6.6 .000 .000 .000 .000 63.3 TOOL STANDOFF (IN) : .3 EWR FREQUENCY (HZ): # REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 .68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10315 10538 10426.5 447 10315 GR 16.55 315.69 37.9114 391 10315 ROP 17.57 147.83 57.6932 391 10343 Last Reading 10538 10510 10538 First Reading For Entire File .......... 10315 Last Reading For Entire File ........... 10538 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10512.0 ROP 10539.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.01 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 NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: STOP DEPTH 10698.5 10727.0 01-FEB-98 MSC 1.32 NGP 6.90, DEP 2.21, PCD MEMORY 10728.0 10538.0 10728.0 62.3 89.4 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL NUMBER PCG 58 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 3.750 3.8 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Flo Pro 8.80 65.0 9.2 30000 · 6.6 .000 .000 .000 .000 63.3 .3 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10512 10727 10619.5 431 10512 GR 17.75 146.32 32.3426 374 10512 ROP 23.38 1940.51 105.577 377 10539 Last Reading 10727 10698.5 10727 First Reading For Entire File .......... 10512 Last Reading For Entire File ........... 10727 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10701.0 ROP 10729.0 STOP DEPTH 11116.5 11145.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.01 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 NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMIC) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 02-FEB-98 MSC 1.32 NGP 6.90, DEP 2.21, MEMORY 11145.0 10728.0 11145.0 87.2 93.2 TOOL NUMBER PCG 58 3.750 3.8 Flo Pro 8.80 65.0 9.8 28000 6.0 .000 .000 .000 .000 65.6 .3 PCD Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10701 11145 10923 889 10701 GR 10.66 120.71 29.961 832 10701 ROP 30.7 478.38 114.096 833 10729 Last Reading 11145 11116.5 11145 First Reading For Entire File .......... 10701 Last Reading For Entire File ........... 11145 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11116 . 5 11558 . 5 ROP 11145 . 0 11588 . 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE 2.01 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 02-FEB-98 MSC 1.32 NGP 6.90, DEP 2.21, PCD DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMI/M ANGLE: MAXIMI/M ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MEMORY 11589.0 11145.0 11589.0 86.9 94.2 TOOL NUMBER PCG 8 3.750 3.8 Flo Pro 8.8O 65.0 9.8 28000 6.0 .000 .000 .000 .000 72.6 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 11116.5 11588.5 11352.5 945 GR 20.65 76.94 28.7909 885 ROP 40.45 2102.46 132.337 888 First Last Reading Reading 11116.5 11588.5 11116.5 11558.5 11145 11588.5 First Reading For Entire File .......... 11116.5 Last Reading For Entire File ........... 11588.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.00.6 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY ~ VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11555 . 0 11794 . 0 ROP 11585 . 0 11822 . 0 $ LOG HEADER DATA DATE LOGGED: 03-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.01 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 11822.0 TOP LOG INTERVAL (FT) : 11589.0 BOTTOM LOG INTERVAL (FT) : 11822.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 88.7 MAXIMUM ANGLE: 92.5 MSC 1.32 NGP 6.90, DEP 2.21, PCD TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE ~(MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER PCG 58 3.750 3.8 Flo Pro 8.80 65.0 9.5 5.6 .000 .000 .000 .000 70.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11555 11822 11688.5 535 11555 GR 7 29.82 18.1142 479 11555 ROP 35.7 1881.92 113.194 475 11585 Last Reading 11822 11794 11822 First Reading For Entire File .......... 11555 Last Reading For Entire File ........... 11822 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11795 . 5 12058 . 5 ROP 11823 . 0 12084.5 $ LOG HEADER DATA DATE LOGGED: 04-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.01 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 12085.0 TOP LOG INTERVAL (FT): 11822.0 BOTTOM LOG INTERVAL (FT): 12085.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.8 MAXIMUM ANGLE: 91.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAPIMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): MSC 1.32 NGP 6.90, DEP 2.21, PCD TOOL NUMBER PCG 8 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.8 Flo Pro 8.80 65.0 9.5 5.8 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 70.3 First Name Min Max Mean Nsam Reading DEPT 11795.5 12084.5 11940 579 11795.5 GR 23.37 52.88 31.1274 527 11795.5 ROP 40.67 638.19 81.3692 524 11823 First Reading For Entire File .......... 11795.5 Last Reading For Entire File ........... 12084.5 Last Reading 12084.5 12058.5 12084.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/04/02 Origin ................... STS Ta~ Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ....... ' .......... STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/04/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File