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176-042
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 04-10 (PTD #1760420) failed MIT-IA. Secured with downhole plug. Date:Thursday, May 5, 2022 12:19:13 PM Attachments:image001.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, May 1, 2022 3:09 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: NOT OPERABLE: Injector 04-10 (PTD #1760420) failed MIT-IA. Secured with downhole plug. Mr. Wallace, DHD performed a passing PPPOT-T and PPPOT-IC on 04/05/22 confirming the wellhead seals have integrity. On 04/06/22 an offline MIT-IA failed with a LLR of 2.6 gpm @ 1000 psi. On 04/25/22 Slickline set a downhole plug and E-line is currently scheduled to perform an LDL. The well will now be classified as NOT OPERABLE until the production tubing integrity has been restored. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, April 4, 2022 1:45 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector 04-10 (PTD #1760420) failed AOGCC MIT-IA Mr. Wallace, Injector 04-10 (PTD #1760420) operates under AA AIO 4E.036 for PWI only with TxIA communication. The well failed an AOGCC witnessed MIT-IA on 04/04/22. Operations is currently in the process of shutting the well in per condition #4 of the AA. It is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. DHD: PPPOT-T/PPPOT-IC 2. DHD: Offline MIT-IA/Establish LLR 3. Wireline (Pending): LDL 4. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector 04-10 (PTD #1760420) failed AOGCC MIT-IA Date:Tuesday, April 5, 2022 8:11:46 AM Attachments:image001.png 04-10 AA Approval 01-03-11.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, April 4, 2022 1:45 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector 04-10 (PTD #1760420) failed AOGCC MIT-IA Mr. Wallace, Injector 04-10 (PTD #1760420) operates under AA AIO 4E.036 for PWI only with TxIA communication. The well failed an AOGCC witnessed MIT-IA on 04/04/22. Operations is currently in the process of shutting the well in per condition #4 of the AA. It is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. DHD: PPPOT-T/PPPOT-IC 2. DHD: Offline MIT-IA/Establish LLR 3. Wireline (Pending): LDL 4. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. MEMORANDUM TO: Jim Regg J ' 4�y7 Z�Zv P.I. Supervisor y FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, April 20, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. 04-10 PRUDHOE BAY UNIT 04-10 Sre: Inspector Reviewed By: P.I. Sop" Comm Well Name PRUDHOE BAY UNIT 04-10 API Well Number 50-029-20213-00-00 Inspector Name: Guy Cook Permit Number: 176-042-0 Inspection Date: 4/18/2020 ' Insp Num: mit(iDC200418121741 Rel Insp Num: Monday, April 20, 2020 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 04 -10 Type Inj I u jTVD 7815 Tubing 1130 use - 125 PTD n6oazo 'Type Test SPT Test psi » !A lsst zags zt4622 BBL Pumped: 2.3 BBL Returned: 2.3 OA ss9 sat m Interval REQVAR PIF P - Notes: 2 year test as required by AA 4E.036 for water injection only. The test was done with a Little Red Services pump truck and calibrated gauges. Monday, April 20, 2020 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg a DATE: Wednesday,April 11,2018 P.I.Supervisor \�1 ( t SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 04-10 FROM: Guy Cook PRUDHOE BAY UNIT 04-10 Petroleum Inspector Src: Inspector Reviewed P.I.Supry J 1) NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 04-10 API Well Number 50-029-20213-00-00 Inspector Name: Guy Cook Permit Number: 176-042-0 Inspection Date: 4/10/2018 Insp Num: mitGDC180410152007 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I 04-10 Type Inj W •TVD 7835 - Tubing 836 - 837 " 834 - 832 - PTD 1760420 Type Test SPT Test psi 1959 • IA 1214 2296 2269 - 2259 BBL Pumped: 2.2 ; BBL Returned: 2.2 OA 188 247 253 267 - Interval REQVAR IP/F P ` Notes: AA 4E.036 for TxIA communication requires 24 month AOGCC MIT-IA to 1.2 times max anticipated injection pressure. A triplex pump was used for testing with a bleed trailer. SCANNED Wednesday,April 11,2018 Page 1 of 1 'RECEIVED , • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERA IONS MAR 2 3 2018 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing0 Opt 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 C4 am 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 176-042 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20213-00-00 7. Property Designation(Lease Number): ADL 028325 8. Well Name and Number: PBU 04-10 - 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 9154 feet Plugs measured 9038 feet true vertical 8941 feet Junk measured None feet Effective Depth: measured 9038 feet Packer measured 9769 feet true vertical 8782 feet Packer true vertical 7835 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 32-112 32-112 1530 520 Surface 2660 13-3/8" 32-2692 32-2692 5380 2670 Intermediate 8510 9-5/8" 30-8540 30-8371 8150/6870 5080/4760 Liner 913 7" 8238-9151 8087-8938 8160 7020 Scab Liner 1073 3-1/2" 7927-9000 7796-8799 10160 10530 Perforation Depth: Measured depth: 8838-9029 feet SCAMS ,. is _ ' ,, True vertical depth: 8649-8826 feet Tubing(size,grade,measured and true vertical depth) 5-1/2",17#,L-80 x 4-1/2",12.6#,L-80 28-8104 28-7961 Packers and SSSV(type,measured and 5-1/2"Baker SAB Packer 7969 7835 true vertical depth) No SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: RBDMbPR 0 4 IN 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 7733 16 824 Subsequent to operation: 0 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service I3 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Richards,Meredyth Contact Name: Richards,Meredyth Authorized Title: Petroleum Engineer Contact Email: Meredyth.Richards@bp.com Authorized Signature: 7g�� Date: 3/ '3/( O p Contact Phone: +1 9075644867 Form 10-404 Revised 04/2017 1/77._ 4/2fieSubmit Original Only .wy/Z> i • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) March 21, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Perforate for Well PBU 04-10, PTD #176-042. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • Daily Report of Well Operations PBU 04-10 ACTIVITYDATE SUMMARY ***WELL SHUT IN ON ARRIVAL*** (Perforating) DRIFT W/2.50" S. BAILER &TAG HARD BOTTOM @ 8999' SLM (sample of shmoo) DRIFT W/4" BRUSH, 2.50" CENT. & 1-3/4" S. BAILER &TAG @ 8996' SL Appear to be—7' inside TT) 2/10/2018 ***CONT. ON 02/11/18 WSR*** ***CONT. FROM 02/10/18 WSR*** (Perforating) BAILED THICK SCHMOO FROM 8996' SLM TO 9011' SLM W/ 10'x2.50" PUMP BAILER. TAGGED FILL AT 9015' MD W/2.50" CENT, TEL,AND 2.50" SMPL BAILER. DRIFTED TO 9014' SLM W/20' x 2.50" DUMMY GUNS (NO ISSUES) 2/11/2018 ***WELL TURNED OVER TO DSO*** ***WELL SHUT IN ON ARRIVAL*** (SLB E-LINE- PERF) INITIAL T/I/O = 0/0/0 RU/PT ELINE. 3/3/2018 ***JOB CONTINUED ON 04-MAR-2018*** ***JOB CONTINUED FROM 03-MAR-2018*** (SLB E-LINE - PERF) GUN 1: RIH WITH 2.5" POWERJET OMEGA, LOADED 20', 6 SPF, 60 DEG PHASING. PERFORATE INTERVAL 8970'- 8990'. GUN 2: RIH WITH 2.5" POWERJET OMEGA, LOADED 15', 6 SPF, 60 DEG PHASING. PERFORATE INTERVAL 8940'- 8955'. ALL PASSES TIED INTO SLB RESERVOIR SATURATION LOG DATED 08-JUL-2014. WELL SHUT IN ON DEPARTURE. FINAL T/I/O = 10/0/0 PSI 3/4/2018 ***JOB COMPLETE 04-MAR-2018*** T/I/O = 580/30/10. Temp = SI. Load IA Pre AOGCC (Reg Compliance). Initial IA FL @ 240' (10.5 bbls). Pumped 9.4 bbls down IA to raise FL to 40' (2 bbl). During pumping, TP increased 20 psi. Final WHPs = 650/50/10. 3/6/2018 Sv, WV, SSV= C. MV= O. IA, OA= OTG. 12:30 Fluids Summary Bbls Type 11 DIESEL TREE= FMC GEN t • • WELLFEAD= FMC • 04-10 SAFETY NOTES: ACTUATOR= AXELSON KB.ELEV= 52' BF.HEY= ? KOP= 5857' 20"CONDUCTOR, -{ 100' HI Max Angle= 23*@ 9154' 9411,H-40, Datum MD= 9057' 13=19.124' C2225' 5-1/2"OTIS ROM SSSV NP,D=4.562" Datum TVD= 8800'SS X .� — 2347' H9-5/8"FOC 9-5/8'CSG,47#,SOO-90/RS-95 XO H 2327' I — -� 2471' -9-5/8'FOC TO MPF80 BUTT 13-3/8"CSG,72#,N-80 BUTT,D=12.347' H 2692` 1 x 1 El ,6412'-6460' -15-1/2"WFD ER PATCH,D=2.880'(04/17/10) 81 E 9-5/8'CSG,47#,MN-80 XO H 5177' TO SOO-90/RS-95 BUTT Minimum ID = 2.880" @ 6412' m 7843' -15-1/2"OTIS XA SLD SLV,ID=? 5-112" WFD ER PATCH 1 r 7927' H4-1/2"G SEAL SW W/VVL ENTRY SKIRT TOP OF3-1/2"LNR H 7927' J 7'963' - 5-1/2"BOT FSR ASSY 15-1/7 TBG-PC.17#,L-80,.0232 bpi,D=4.892' j--j 7964'v! BEHIND /\I X 7969' -19-5/8"X 5-1/2'BKRSAB PKR,D=? JT LNR / 7975' -17"MEN LLOUr EXTENSION,13=? �L \ - 7976' -7"X 4-1/2"XO,D=? 7965' --14-1/2'FLUTED NO-GO SUB,D=2.991" I 8039' H4-1/2"OTIS XN NP,D=3.725" BEHIND [4-1/2"TBG-PC, -2-.S#,1-80,-80 -0152 bpf,D=3.958" - 8102' J J' 11( 8104' -14-112"MULESHOE,D=3.958" CT LNR 8093' Hata).MD TT LOGGED 09/30/80 TOP OF 7"LNR 1 8235' � 8235' -{9-5/8"X 7"BOT LNR HGR D=? D �'�' 9-5/8"CSG,47#,RS-95 BUTT, =8.681" H 8541' 4 i1�1; Mr.II i"----•,,, t 8275' HEST TOP OF CI UFT(07/01/96) v11I I ►11 04*, 3-1/2'LNR,9.3#,L-80 FL4S,.0087 bpf,D=2.992" H 9000' / 9000' -13-1/2"DAVIS LYNCH FLOAT SHOE FEfRFORATION SUMMARY I REF LOG:BHCS OF 06/15/76 I ANGLE AT TOP FETE:220©8837' ' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERFORATION INFORMATION teit e' 9038' -I CM2"FLUG(SET 10/31190) 7"LNR 29#,MN 80 BUTT,.0371 bpf.D=6.184" -{ 9149' 1.4 001/.1.. TD H 9154' DATE REV BY COM ENTS DATE REV BY COM E TTS PRUDHOE BAY UNIT 07/28/76 ROWAN 26 ORIGINAL COMPLETION 12/09/09 .Ruh/SV SET NEW ZIPPER PATCH VVF3L 04-10 08/13/80 Ni ES RWO 03/18/10 SWC/SV FILL PATCH(02/16/10) PERMIT No: 176-0420 07/03/96 PQES 3-1/2 CT SCAB LNR 04/20/10 W/SV SET LOWER PATCH(03/27/10) API No: 50-029-20213-00 10/14/06 COM'TLH CMT CORRECTIONS(1996) 04/20/10 SVVCJSV SET ZIPPER PATCH(04/17/10) SFC 27,T11 N,R15E 1403.9 FEL 3959.95 FTI. 10/23/07 RC/PJC DRAVVWG CORRECTIONS 03/05/18 NXW/JFuD ADFERFS(03/04/18) 10/24/07 BSE/PJC SET WRD PATCH BP Exploration(Alaska) • • 04-10 1 J X JO4 I m 1 ( ) X x / J PERFORATION SUIVMARY - REY LOG:81-CS OF 06/15/76 I �••�•� ��o I ANGLE AT TOP PERE:22"©883T /1111 Note:Refer to Production DB for historical perf data '1�1.. SIZE SPF NT132VAL Opn/Sgz DATE ,1111 1•4 114 3-1/8" 4 8837-8853 S 07/08/90 •11/1• 111114 2-1/2" 6 8838-8852 0 07/06/06 A ►��' 3-1/8' 4 8858-8872 S 07/08/90 2-1/2" 6 8860-8866 0 07/06/06 I 2-1/2" 6 8882-8896 0 07/06/06 I 3-1/8" 4 8883-8897 S 07/08/90 2-1/2" 6 8940-8955 0 03/04/18 ' ? 4 8962-8977 S 07/08/90 2-1/2" 6 8970-8990 0 03/04/18 ' ? 4 8984-9011 S 07/08/90 3-3/8' 6 9007-9019 0 07/21/90 ? 4 9025-9029 S 07/08/90 1�1�1�1�1�1�1�1 3-3/8" 6 9025-9029 O 08/03/90 1�1.1�1�1�0 ? 4 9029-9041 S 07/08/90 11/111111111/11 ? 4 9040-9044 S 07/08/90111111111111111 1111111111111i1 111111111111111 111111111111111 DATE REV BY COM E SITS DATE REV BY COMMENTS PRJDHOE BAY LJNFT 07128/76 ROWAN 26 ORIGINAL COMPLETION 12/09/09 JW/SV SET NEW UPPER PATCH WELL. 04-10 08/13/80 N1 ES RWO 03/18/10 SWC/SV RLL PATCH(02/16/10) PERMIT No: 176-0420 07103/96 N2ES 3-112 CT SCAB LNR 04/20/10 MN/SV SET LOWER PATCH(03/27/10) API 1b: 50-029-20213-1*) 10/14/06 COMTLH CMT CORRECTIONS(1996) 04/20/10 SVW/SV SET UPPER PATCH(04/17/10) SEC 27,T11 N,R15E 1403.9 F8 3959.95 FNL_ 10/23/07 RC/PJC DRAWING CORRECTION— S 03/05/18 NXW/JM D ADPERFS(03/04/18) 10/24/07 BSE/PJC SET VVRD PATCH BP Exploration(Alaska) MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg T � 2 2-31 1(‘' DATE: Wednesday,March 23,2016 P.I.Supervisor ✓ SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 04-10 FROM: Chuck Scheve PRUDHOE BAY UNIT 04-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 2-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 04-10 API Well Number 50-029-20213-00-00 Inspector Name: Chuck Scheve Permit Number: 176-042-0 Inspection Date: 3/19/2016 Insp Num: mitCS160319112712 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well oa-lo Type Inj W`TVD 7835 " Tubing 1578 1579 - 1579 - 1578 PTD 1760420 - Type Test SPT Test psi 1959 - IA 1609 2651 - 2639 2633 - Interval REQVAR P/F P ✓ OA 304 312 - 267 - 308 - Notes: Tested per A1O 4E.036 SCANNED SEP.2 6 2016 Wednesday,March 23,2016 Page 1 of 1 STATE OF ALASKA , ;KA OIL AND GAS CONSERVATION COMNii.)SION " REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate❑ Other 0 Bright Water Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waived] Time Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WE 2 Operator 4 Well Class Before Work. 5 Permit to Drill Number Name. BP Exploration(Alaska),Inc Development ❑ Exploratory 176-042-0 3 Address P.O Box 196612 Stratigraphic ❑ Service0 6.API Number Anchorage,AK 99519-6612 50-029-20213-00-00 7.Property Designation(Lease Number) 8.Well Name and Number: ADL0028325 PBU 04-10 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s). PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary: Total Depth measured 9150 feet Plugs measured None feet true vertical 8937 45 feet Junk measured None feet Effective Depth measured 9064 feet Packer measured 7962 35 feet true vertical 8858 05 feet true vertical 7828 78 feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"94#H-40 30 3-110 3 30 3-110 3 1530 520 Surface 2662.56 13-3/8"72#L-80 29 8-2692 36 29 8-2692.36 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet Q EMAR E IV ED True Vertical depth See Attachment feet ! • ACR 102015 Tubing(size,grade,measured and true vertical depth) See Attachment _ See Attachment See Attachment AOGC ,Packers and SSSV(type,measured and true vertical depth) 5-1/2"BAKER SAB PACKER 7962 35 7828 78 Packer/ None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) 8838'-8852',8860'-8866',8882'-8896',9007'-9019',9025'-9029'. SCANNED M n is 1 8 L'15 15 ,Treatment descnptions including volumes used and final pressure 6552 Gallons EC9660A Surfacent,31281 Gallons EC9398A Polymer, 1600 psi. 113 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation. 0 0 10919 1860 1564 Subsequent to operation 0 0 11606 1900 1649 14 Attachments: 15.Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service CI Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work. Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C O.Exempt N/A Contact Garry Catron Email Garrv.CatronaBP.Com Printed Name Garry Catron Title PDC PE Signature 2%A.A Phone 564-4424 Date 3/10/2015 VrL- 3/J-/i RBDMS3kk MAR 12 2015 A 4/7 /) Form 10-404 Revised 10/2012 Submit Original Only m Q,O000M OOOO NOO cN- ODNN-CO CN CO) C N CO r-- C.) �V O O O O 0 0 0 0 M LC) N- 1 O CO Cr) m• 10 CO CD CO CO cr CO Co M CO M I- CY) - M M CO M CO N cci � OON- 0) MC7) MCD coMMI- a) CD000) O CO CO CO CO N N- N- I- O• co O O a) O N co M coco � ON (,o N- CO N NI- O O O NM N t O t 0) CO O co C13 LO O CD Q) CO CO O O N I� CO cIni i i i i • N Q M OOO � NNMO (D � QN M N O CO N. co M N C CD O coco 00 10CD O CD O co ci) co Q , Z i J ' J J N *k 4k I's- *k M N N 4- CA - ✓ - - `•&" (V N Com° N r O � � � � - ch i N- " D7 I M 4 CA CA .c co46) co MM co M Cr)CO C COO N N O `- COO CA N CD N • O N N W W W C) Q Q Q CI- 00D yvwww w ✓ o ck c' � zz zwwwwwcmm p1- F- Hzz » D 0ggZJJc/) H1- N dl co N• - e- CnvNa) LO r` NC') Cc) NCOT Ln a OD W '0) N O CO t0 0 O Tr CO CO N t- O I4D 00 _ 03 01 > OD CO OD COC OD 00 OD O O CO CY Z LU LUa g g Y 0 0 p 0 0 w Y Y ~ I- CO CO ' r- CO N N J 0 0 w w w r CO N M C- LO M N M N CO J J J ...„0 CD Z ce LS CO 00 CO 0 0) CC) < < < Wzi 0 CO CO CO CO Co CO f� 00 O co Z Z Z O J J ? 0 O aoaoaoaoCIDOoaoOco co Q QQ = 0 0 d 0 u w w w w Z 0 Z 2 2 2 0 a) co O) co ¢) a>' CA Ca m t CO N 0 CO ' CO O 0) 0) 0) nt A d C'7 O CO CO C- O) CC) CO r N C at OD OD OD OD 00 CID 0 0) O O O O OD OD 00 OD OD 00 00 CID 0) 0) 0) d - - J = 0_ J CI- O 2 2 2 0 co co co In Cn ✓ N CS Q O ~ • 0 CO CIO N 0 CO N 0 N 1 O O J nMC'r) LC) COCO0o3 COONa O H OD OD 03 OD OD OD OD OOD CD CD) 00) 03 Q Co L ar C) 2 I d O. 100 0 c ° N IL N IL N li N N li li N t' oa- oa- CIaC3a0- CY O Cl) Q C/) C/) (I) Cl) OC OC Cl) 0. 0 t d O 0 w -J O. 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I KOP= 5857' 20"CONDUCTOR, — 100' Max Angle= 23 @ 9154' 944,H-40, Datum MD= 9057' ID=19.124" 2225' —15-1/2"OTIS ROM SSSV NIP, ID=4.562" Datum TVD= 8800'SS X_I 2347' —9-5/8"FOC 9-5/8"CSG,47#,SOO-90/RS-95 XO H 2327' —� 2471' H 9-5/8"FOC TO MN-80 BUTT 13-3/8"CSG,72#,N-80 BUTT, ID=12.347" — 2692' X $' El 6412'-6460' —5-1/2"WFD ER PATCH,ID=2.880'(04/17/10) 1/ 9-5/8"CSG,47#, MN-80 XO — 5177' TO SOO-90/RS-95 BUTT S 2 Minimum ID = 2.880" @6412' m 7843' —5-112"OTISXASLD SLV,ID=? 5-1/2" WFD ER PATCH r 7927' —4-1/2"G SEAL SUB W/WL ENTRY SKIRT TOP OF 3-1l2"LNR H 7927' IV/ ` J ) 7963' —5-1/2"BOT PBR ASSY 5-1/2"TBG-PC, 17#,L-80,.0232 bpf, ID=4.892" — 7964' BEHIND >< X 7969' -19-5/8"X5-1/2"BKRSAB PKR,ID=? CT LNR 7975' I 17"MILLOUT EXTENSION, ID=? 7976' -1 7"X 4-1/2"XO,ID=? 7965' —4-1/2"FLUTED NO-GO SUB, ID=2.991" il • 8039' —4-1/2"OTISXNNIP,ID=3.725" I BEHIND 8104' H4-1/2"MULESHOE, ID=3.958" CT LNR 4-1/2"TBG-PC, 12.64,L-80,.0152 bpf,ID=3.958" — 8102' I / 8093' —ELMD TT LOGGED 09/30/80 TOP OF 7"LNR 1 8235' 11•1 8235' H9-5/8"X 7"BOT LNR HGR,ID=? 9-5/8"CSG,47#,RS-95 BUTT, ID=8.681" H 8541' IA. o licml 8275' H EST TOP OF CEMENT(07/01/96) ►1111 ►1111 04 ►1111 ;114 3-1/2"LNR,9.34, L-80 FL4S, .0087 bpf,ID=2.992" H 9000' / 9000' —3-1/2"DAVIS LYNCH FLOAT SHOE PERFORATION SUMMARY I REF LOG: BHCS OF 06/15/76 I ANGLE AT TOP PERF: 22 @ 8837' I Note:Refer to Production DB for historical pert data SIZE I SPF I INTERVAL I Opn/Sqz I DATE I SEE PAGE 2 FOR PERFORATION INFORMATION 9038` —CMT PLUG(SET 10/31/90) 10�1�1�1�1�1,1 111111111111111 1111111111111111 7"LNR,294,MN-80 BUTT, .0371 bpf,ID=6.184" — 9149' 1111111/1/1111 111111111111111 TD -1 9154' 1.1.1.1.1.1.1.1 DATE , REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/28/76 ROWAN 26 ORIGINAL COMPLETION 12/09/09 JMF/SV SET NEW UPPER PATCH WELL: 04-10 08/13/80 NIES RWO 03/18/10 SWC/SV PULL PATCH(02/16/10) PERMIT No: 176-0420 07/03/96 N2ES 3-1/2 CT SCAB LNR 04/20/10 MV/SV SET LOWER PATCH(03/27/10) API No: 50-029-20213-00 10/14/06 COM/TLH CMT CORRECTIONS(1996) 04/20/10 SWC/SV SET UPPER PATCH(04/17/10) SEC 27,T11 N,RISE 1403.9 FEL 3959.95 FNL 10/23/07 RC/PJC DRAWING CORRECTIONS 10/24/07 BSE/PJC SET WRD PATCH BP Exploration (Alaska) P - 04-10 1 X ® x [ I u: i M l J X J PERFORATION SUMMARY 111 1111 1.41 REF LOG: BRCS OF 06/15/76 x'1'1, I&AAA) ANGLE AT TOP PERF:22 @ 8837' 1114 Note: Refer to Production DB for historical perf data 11.11 1.1.1' 11. h 11 1111 SIZE SPF INTERVAL Opn/Sqz DATE t 3-1/8" 4 8837-8853 S 07/08/90 2-1/2" 6 8838-8852 0 07/06/06 ' 3-1/8" 4 8858-8872 S 07/08/90 2-1/2" 6 8860-8866 0 07/06/06 I 2-1/2" 6 8882-8896 0 07/06/06 3-1/8" 4 8883-8897 S 07/08/90 I ? 4 8962-8977 S 07/08/90 I ? 4 8984-9011 S 07/08/90 3-3/8" 6 9007-9019 0 07/21/90 ? 4 9025-9029 S 07/08/90 rtft�1.v�t�•4 3-3/8" 6 9025-9029 0 08/03/90 X111141411.1.1` ? 4 9029-9041 S 07/08/90 11.1.11.1.1.1.1 ? 4 9040-9044 S 07/08/90 11.11�1�11.1.1.1 11...1.1.1.1.1.1 11.1...1.1.1...1 11.1.1.1.1.1.1.1 :4.4.4.4.4.4.4.1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/28/76 ROWAN 26 ORIGINAL COMPLETION 12/09/09 JMF/SV SET NEW UPPER PATCH WELL: 04-10 _ 08/13/80 N1 ES RWO 03/18/10 SWC/SV PULL PATCH(02/16/10) PERMIT No: 176-0420 07/03/96 N2ES 3-1/2 CT SCAB LNR 04/20/10 MV/SV SET LOWER PATCH(03/27/10) API No: 50-029-20213-00 10/14/06 COM/TLH CMT CORRECTIONS(1996) 04/20/10 SWC/SV SET UPPER PATCH(04/17/10) SEC 27,T11 N,R15E 1403.9 FEL 3959.95 FNL 10/23/07 RC/PJC DRAWING CORRECTIONS 10/24/07 BSE/PJC SET WRD PATCH BP Exploration(Alaska) Originated: Schlumberger PTS - PRINT CENTER 2525 GAMBELL STREET, STE. 400 ANCHORAGE, AK 99503 (907) 273-1700 main AGG,GG Delivered to: MakanaK Bender .; Natural Resources Technician II Alaska Oil & Gas Conservation Commission 333 W 7- Ave, Suite 100 Anchorage, AK 93601 TRANSMITTAL DATE TRANSMITTAL # = DATA LOGGED 2 /3W2011y M. K. BENDER WELL NAME 04-10 SERVICE OR ER' CBOO-00075 FIELD NAA SERVICE PRUDHOE BAY DESCRIPTION WL DELIVERABLE DESCRIPTION (PROF AIA TYK FINAL FIELD DATE LOGGUAkPRINTSJI 7 -Jul -14 • • 1 CDs 1 04-10 CBOO-00075 PRUDHOE BAY WL RST FINAL FIELD 7 -Jul -14 1 1 07-14C CFGK-00077 PRUDHOE BAY MEMORY PPROF FINAL FIELD 5 -Jul -14 1 1 15-28A CODG-00044 PRUDHOE BAY WL LDL & SBHPS FINAL FIELD 1 -Jul -14 1 1 GNI-04 CV6H-00029 PRUDHOE BAY MEMORY TEMP/PRESS FINAL FIELD 6 -Jul -14 1 1 H-21 C4W7-00136 PRUDHOE BAY WL PPROF FINAL FIELD 30 -Jun -14 1 1 Transmittal Receipt .�X—�1SeD� X Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. 7) 561-8317 fax A Transmittal Receipt signature confirms that a package (box, envelope, etc.) hasI�een e eived and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified correctness or quality level at this point. MEMORANDUM State of Alaska Inspector Name: .1ohn Crisp Inspection Date: 3/11/2014 Alaska Oil and Gas Conservation Commission TO: Jim Re 4 ��� '/ �'y DATE: Tuesday, April 01, 2014 P.I. Sup grvisor SUBJECT: Mechanical Integrity Tests W' BP EXPLORATION (ALASKA) INC 04-10 FROM: John Crisp PRUDHOE BAY UNIT 04-10 Petroleum Inspector 2480. 2473 Src: Inspectbr Reviewed By: 1760420 P.I. Suprvy)�'� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 04-10 Insp Num: miUCr140311150823 Rel Insp Num: API Well Number 50-029-20213-00-00 Permit Number: 176-042-0 Inspector Name: .1ohn Crisp Inspection Date: 3/11/2014 Packer Depth Pretest Initial 15 Min 30Miq 45 Min 60 Min Well 04-10 - Type Inj W' TVD 7835 - IA 1671 1 2507 • 2480. 2473 TD 1760420 Type Test sPT Test psi 1958 OA 375 402 380 423 Interval REQVAR P/F P I Tubing 1711 1700, 1702 1709 Notes: AA AIO 04E.36; 1.2 bbls pumped for test - OCTSWM 0 9 21 114 Tuesday, April 01, 2014 Page 1 of 1 I k c4-IG P- Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep [AKOPSFFWellOpsCompRep @bp.com] Sent: Tuesday, June 04, 2013 12:01 PM �`yG �� To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay \ i 6(41 ,3 Subject: FW: PBU/East Area/FS2/04 defeated pilots Mr. Regg, Here is the info you requested on the DS-4 water injectors that were temporarily SI yesterday for pigging operations. Well PTD 04-06 1760830 04-08 1760110 04-10 1760420 04-13 1780310 04-15 1780370 04-19 2012180 04-20 1831190 SataEll 04-25 1860490 04-27 1852950 04-45 1940340 I apologize for the time delay since the initial email was sent. I will have this data available for future notification emails since I now know it is required. Thank you, Lee Hulme From: AK, OPS FS2 DS Ops Lead Sent: Tuesday, June 04, 2013 8:35 AM To: AK, OPS FF Well Ops Comp Rep Cc: AK, OPS FS2 Facility OTL; AK, OPS FS2 OSM Subject: RE: PBU/East Area/FS2/04 defeated pilots Lee, All of the PWI wells are gagged during pigging operations in order to prevent inadvertent blocked flow and a stuck pig.— This is how-we always pig and how we will always pig every week in the future. It is a manned operation. The wells gagged yesterday were DS4-6,8,10,13,15,20,25,27,19,45. In `White Ak, Ops FS2 DS Lead 907-659-5493 Alt: James Barndt From: AK, OPS FF Well Ops Comp Rep Sent: Tuesday, June 04, 2013 7:43 AM To: AK, OPS FS2 DS Ops Lead Cc: Regg, James B (DOA); Redmond, Randy; AK, OPS FF Well Ops Comp Rep 1 Subject: FW: PBU/East Area/FS2/04 defeated pilots Importance: High Ron, Please supply me with a list of the water injectors on DS-04 that were defeated during the pigging operations yesterday so I can look up the PTD numbers and pass on to Mr. Regg. Thanks, Lee From: Regg, James B (DOA) [mailto:jim.regq @alaska.gov] Sent: Monday, June 03, 2013 9:08 PM To: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU/East Area/FS2/04 defeated pilots Our approvsl only covers injectors. And yes, I want a record of the injectors involved. Particularly since it is DS 4. Sent from Samsung Mobile Original message From: "AK, OPS FF Well Ops Comp Rep" <AKOPSFFWellOpsCompRep @bp.com> Date: 06/03/2013 6:32 PM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg @alaska.gov> Subject: RE: PBU/East Area/FS2/04 defeated pilots Mr. Regg, I just called the FS2 Field Lead Tech and he told me the pigging operation is completed and the temporary defeat for PWI wells has been lifted. It will take some research to determine which wells were involved since the DSD log blanketed the whole pad. I can get this data tomorrow if you still want it. Please advise. Lee Hulme FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony—7187 (Alternate: Ryan J Hayes) From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, June 03, 2013 5:01 PM To: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU/East Area/FS2/04 defeated pilots Please identify wells and PTD for each. Jim Regg AOGCC 2 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: AK, OPS FF Well Ops Comp Rep [mailto:AKOPSFFWellOpsCompRep@abp.com] Sent: Monday, June 03, 2013 4:25 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Redmond, Randy; AK, D&C Well Integrity Coordinator; Bill, Michael L(ASRC); Starck, Jennifer L; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, RES GPB East Wells Opt Engr Subject: PBU/East Area/FS2/04 defeated pilots Dear Mr. Regg, Per AOGCC waiver dated 3/11/13, PBU Oil Pool Low Pressure Water Injectors, BPXA is providing notification that wells on DS-04 are now operating with its SVS defeated as of 6/3/13 for pigging operations. Per the wavier, BPXA has tagged and logged the defeated components, and will notify AOGCC once the SVS is returned to service. Please contact me with any questions. Thank you, Lee Hulme FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony—7187 (Alternate: Ryan J Hayes) 3 Pt 04-10 Pr6 »(-04 i o Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com]7(z��1z Sent: Sunday, July 22, 2012 7:05 AM J To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 DS Operators; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Daniel, Ryan; Igbokwe, Chidiebere Cc: AK, D&C DHD Well Integrity Engineer; Clingingsmith, Mike J Subject: OPERABLE: Injector 04-10 (PTD #1760420) Two competent barriers confirmed Attachments: MIT PBU 04-10 07-21-12.xls MR Produced Water Injector 04-10 (PTD #1760420) operates under AA AIO 4E.036 for Tubing x IA communication. A Leak Path Evaluation was performed on the wellhead and the secondary seals appear to be holding indicating that the communication is not through the wellhead. An MIT -IA passed on07/21/2012 confirming two competent barriers to the release of well pressure. At this time, the well is reclassified to Operable and may be brought on injection for continued operation under AA. The MIT -IA form is attached for reference: <<MIT PBU 04-10 07-21-12.xls>> Thank you, M hreen Vazir BP Alaska - Well Integrity Coordinator rX WIC Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinator@BP.com Direct Cell: 832.651.5253 Direct Email: Mehreen.Vazir@BP.com SWIAfD OCT 0 9 20 From: AK, D&C Well Integrity Coordinator Sent: Thursday, June 07, 2012 10:22 AM To: AK, D&C Well Integrity Coordinator; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, O FS2 DS Operators; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, OPS PC C TL; Cismoski, Doug A; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Le , Daniel, Ryan; Igbokwe, Chidiebere Cc: Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Shane M; LeBaron, Mich J; King, Whitney; Yeager, Kevin E Subject: NOT OPERABLE: Injector 04-10 (PTD #1760420) TxIA commu ' tion unmanageable by bleeds 0 Injector 04-10 (PTD #1760420) has an AA for tubin y inner annulus communication manageable by bleeds. On 06/04/12 the inner annulus was bled from JX40 to 500 psi. As of 06/06/12 the IA has increased back to STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.regaitbalaska.gov: doa.aogcc.prudhoe.bayoalaska.gov: phoebe. brooksaalaska.gov: tom.maunderCcDalaska.gov OPERATOR: BP Exploration (Alaska), Inc. 12,"( �/J ?(Z FIELD / UNIT / PAD: Prudhoe Bay / PBU / 04 (Z/ DATE: 07/21/12 I N TVD OPERATOR REP: Mehreen Vazir 806 AOGCC REP: TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Form 10-426 (Revised 06/2010) MIT PBU 04-10 07-21-12 INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. Well 04-10 Type In'. I N TVD I - 7,835' Tubing 800 806 806 806 ' Interval p P.T.D. 1 1760420 Type test I P Test si 1958.75 Casing 11 2508 2456 -2430 P/F P Notes: Verify IA integrity Well operates on AA AIO 4E.036 for TxIA OA 8 8 8 8 ' Well Tye Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In'. TVD Tubing Interval P.T.D. I Type test I Test psi I Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. I Type test I Test psi Casing P/F Notes: OA Well Type In'. TVD Tubing Interval P.T.D. I Typetestl I Test psi I Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Form 10-426 (Revised 06/2010) MIT PBU 04-10 07-21-12 INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) Mt C4 -10 Regg, James B (DOA) PT 17 (004w From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] I�� b�7j Sent: Thursday, June 07, 2012 10:22 AM To: AK, D &C Well Integrity Coordinator; Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 DS Operators; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Daniel, Ryan; Igbokwe, Chidiebere Cc: Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Shane M; LeBaron, Michael J; King, Whitney; Yeager, Kevin E Subject: NOT OPERABLE: Injector 04 -10 (PTD #1760420) TxIA communication unmanageable by bleeds Attachments: Injector 04 -10 (PTD #1760420) TIO Plot.docx; Injector 04 -10 (PTD #1760420) TIO Plot.pdf; Injector 04 -10 (PTD #1760420) TIO Plot.pdf All, Injector 04 -10 (PTD #1760420) has an AA for tubing by inner annulus communication manageable by bleeds. On 06/04/12 the inner annulus was bled from 1440 to 500 psi. As of 06/06/12 the IA has increased back to 1440 psi. In addition, the well failed a pack off test performed on the tubing hanger on 06/06/12. This well is reclassified as Not Operable. The well will be shut in and secured until further diagnostics can be performed. The plan forward for this well is: 1. Wellhead: Positive pressure packoff test on tubing (PPPOT -T) - Failed 2. E -line: Set inflatable plug for secure 3. Fullbore: MIT -T to 3000 psi 4. Wellhead: Leak path evaluation Vii JUL 1 3 2012 5. E -line: Evaluate for a leak detect log (pending leak path evaluation results) A TIO plot , wellbore schematic, and copy of the AA have been included for reference. «Injector 04 -10 (PTD #1760420) TIO Plot.docx» «Injector 04 -10 (PTD #1760420) TIO Plot.pdf» «Injector 04 -10 (PTD #1760420) TIO Plot.pdf» Please call if you have any questions. Thank you, Whitney King filling in for Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 i PBU 04 -10 PTD #1760420 6/7/2012 TIO Pressures Plot Well 04 -10 4 OD° ■ • ■ I --F Tbp —II- -,n— OA 00A - -I— 000A 1 • • — On ■ ...._. .. tOdJ - �.r • i i 03/10 O11712 0324412 Ca31 i12 0V07/12 04+14 042702 04'21312 05/65.12 05712)12 051912 0526112 05+02 12 �_._�,. - -- --- ._�... .----- -- -- -...---- --- --- --- __._ - 1 TREE = FMC GEN I • • I WELLHEAD = _ FMC SAFETY NOTES: ACTUATOR = AXELSON 04-10 . KB. ELEV = 52' BF. ELEV = ? KOP = 5857' 20" CONDUCTOR, —I 100' J--' I Max Angle = 23 @ 9154' 94 #, 1+40, Datum MD = 9057' ID = 19.124" I 2225' H 5- 112 "OTIS RQM SSSV NIP, ID = 4.562" Datum TVD = 8800' SS _I 2347' 1-19-5/8" FOC I 9 -5/8" CSG, 47 #, SOO -90 / RS -95 XO —1 2327' 2471' 1- 19 -5/8" FOCI TO MN-80 BUTT 113 -3/8" CSG, 72 #, N -80 BUTT, ID = 12.347" I-1 2692' e �4 6412'- 6460'1- 15 -1/2" WFD ER PATCH, ID = 2.880' (04/17/10) I 9 -5/8" CSG, 47 #, MN -80 XO 5177' I I TO SOO -90 / RS -95 BUTT of 14 Minimum ID = 2.880" @ 6412' in I 7843' H 5 -1/2" OTISXA SLDSLV, ID =? I 5 -1/2" WFD ER PATCH 1 7927 _I— I4 -1/2" G SEAL SUB W/WL ENTRY SKIRT I I TOP OF 3-1/2" LNR I 7927' 7963' — I5 -1/2" BOTPBRASSY I 15 -1/2" TBG -PC, 17 #, L -80, .0232 bpf, ID = 4.892" H 7964' BEHIND ∎, 7969' Hi 9-5/8"X 5-1/2"BKR SAB PKR, ID = ? I CT LNR -17" 7975 MILLOUT EXTENSION, ID = ? I 1 7976' H 7" X 4-1/2" XO, ID = 2 I 7965' 1-14 -1/2" FLUTED NO -GO SUB, ID = 2.991" I 8039' I-14 -112" OTIS XN NIP , ID = 3.725" I BEHIND 8104' 1- 14 -1/2" MULESHOE, ID = 3.958" I CT LNR 4 -1/2" TBG -PC, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 8102' 8093' I —IELMD TT LOGGED 09/30/80 I I TOP OF 7" LNR H 8235' 1 si 111 8235' H 9 -5/8" X 7" BOT LNR HGR, ID = ? I 9 -5/8" CSG, 47 #, RS -95 BUTT, ID = 8,681" H 8541' P 111 1 8275' I_{ EST TOP OF CEMENT (07101196) I ► ..o.. ' W 13 -1/2" LNR, 9.3 #, L -80 FL4S, .0087 bpf, ID = 2.992" H 9000' 1 9000' H3 -1/2" DAVIS LYNCH FLOAT SHOE I PERFORATION SUMMARY REF LOG: BHCS OF 06/15/76 I ANGLE AT TOP PERF: 22 @ 8837' I Note: Refer to Production DB for historical perf data SIZE I SPF I INTERVAL I Opn /Sqz I DATE I SEE PAGE 2 FOR PERFORATION INFORMATION 9 1-1 CMT PLUG (SET 10/31/90) I I I I 1 � � * i • j 1 11111 N 1 1111111 7" LNR, 29 #, MN-80 BUTT, .0371 bpf, ID = 6.184" 1 9149' j 1111 1 1111 1 TD I-1 9154' .��� A 11 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/28/76 ROWAN 26 ORIGINAL COMPLETION 12/09/09 JMF /SV SET NEW UPPER PATCH WELL: 04 -10 08/13/80 NI ES RWO 03/18/10 SWC /SV PULL PATCH (02/16/10) PERMIT No: 176 -0420 07/03/96 N2ES 3 -1/2 CT SCAB LNR 04/20/10 MV /SV SET LOWER PATCH (03/27/10) API No: 50- 029 - 20213 -00 10/14/06 COM/TLH CMT CORRECTIONS (1996) 04/20/10 SWC/SV SET UPPER PATCH (04/17/10) SEC 27, T11 N, R15E 1403.9 FEL 3959.95 FNL 10/23/07 RC /PJC DRAWING CORRECTIONS 10/24/07 BSE/PJC SET WRD PATCH BP Exploration (Alaska) • • 04 -10 I i - I CI x IIIIMM =® mism x . x M M. ►I PERFORATION SUMMARY A ri +lffl 11 � REF LOG: BRCS OF 06/15/76 I 4 WM ANGLE AT TOP PERF: 22 @ 8837' �: Note: Refer to Production DB for historical perf data %!! �l� SIZE SPF INTERVAL Opn /Sqz DATE , *it h 3-1/8" 4 8837 - 8853 S 07/08/90 2 -1/2" 6 8838 - 8852 0 07/06/06 ' 3 -1/8" 4 8858 - 8872 S 07/08/90 2 -1/2" 6 8860 - 8866 0 07/06/06 , 2 -1/2" 6 8882 - 8896 0 07/06/06 3 -1/8" 4 8883 - 8897 S 07/08/90 I ? 4 8962 - 8977 S 07/08/90 I ? 4 8984 - 9011 S 07/08/90 3 -3/8" 6 9007 - 9019 0 07/21/90 ? 4 9025-9029 S 07/08/90 ; tVfl • 1' 3 -3/8" 6 9025 - 9029 0 08/03/90 `!!!llil` N!Nll ? 4 9029 - 9041 S 07/08/90 '!!!l ? 4 9040 - 9044 S 07/08/90 +il!!!l!!!lill� � l l ! ! ! l iill A 'AMAVWVA Ail A al DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/28/76 ROWAN 26 ORIGINAL COMPLETION 12/09/09 JMF /SV SET NEW UPPER PATCH WELL: 04 -10 08/13/80 N1 ES RWO 03/18/10 SWC/SV PULL PATCH (02/16/10) PERMIT No: 176 -0420 07/03/96 N2ES 3 -1/2 CT SCAB LNR 04/20/10 MV /SV SET LOWER PATCH (03/27/10) API No: 50- 029 - 20213 -00 10/14/06 COM/TLH CMT CORRECTIONS (1996) 04/20/10 SWC /SV SET UPPER PATCH (04/17/10) SEC 27, T11 N, R15E 1403.9 FE. 3959.95 FNL 10/23/07 RC /PJC DRAWING CORRECTIONS 10/24/07 BSE/PJC SET WRD PATCH BP Exploration (Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 17, 2012 TO: Jim Regg '---) II P.I. Supervisor 1se1I 24 l Z% SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 04 -10 FROM: John Crisp PRUDHOE BAY UNIT 04 -10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry _ 6.2-- NON - CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 04 - 10 API Well Number 50 029 - 20213 - 00 - 00 Inspector Name: John Crisp Permit Number: 176 - 042 - Inspection Date: 4/13/2012 Insp Num: mitJCr120415053423 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 04 -10 • Type Inj W iTVD 7835 - IA 1416 2510 2472 2457 - PTD 1760420 - Type Test SPT Test psi 2500 - OA 418 466 412 440 Interval REQVAR P/F P - Tubing 1160 1160 - 1160 1160 Notes: 2 year MIT for AA. I reviewed the TIO plots for 1 year & 1500 psi was max tubing pressure shown.1.88 bbls pumped for test. 50iiibiEDJUN 0 i,' 201? Tuesday, April 17, 2012 Page 1 of 1 • • 5 71[A j ® SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 4E.036 Mr. Doug Cismoski, P.E., Wells Intervention Manager Attention: Well Integrity Engineer, PRB -20 BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 , Luti RE: PBU 04 -10 (PTD 1760420) Request for Administrative Approval Dear Mr. Cismoski: In accordance with Rule 9 of Area Injection Order ( "AIO ") 04E.000, the Alaska Oil and Gas Conservation Commission ( "AOGCC" or "Commission ") hereby GRANTS BP Exploration (Alaska) Inc. ( "BPXA ")'s request for administrative approval to continue water injection in the subject well. PBU 04 -10 has a history of tubing by inner annulus communication which BPXA has deemed manageable by periodic pressure bleeds. Repairs employing tubing patches were attempted in October 2007 and again in April 2010. Subsequent mechanical integrity tests have passed, including Commission witnessed tests on November 19, 2007 and May 07, 2010. The well still, however, exhibits pressure communication to the inner annulus. Following the 2010 MIT, BPXA requested that the then effective administrative approval (AIO 4E.026) be cancelled. AOGCC finds that although BPXA has performed corrective action on PBU 04 -10 that the well continues to exhibit tubing x inner annulus communication. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures and wellhead pressure trend plots, PBU 04 -10 exhibits two competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in PBU 04 -10 is conditioned upon the following: 1. BPXA shall record wellhead pressures, injection rate, and pressure bleeds for all annuli daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; AIO 4E.036 • • January 3, 2011 Page 2 of 2 3. BPXA shall perform an MIT -IA every 2 years to 1.2 times the maximum anticipated well pressure; 4. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 5. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection, and 6. The MIT anniversary date is April 29, 2010. As provided in AS 31.05.080(a), 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 reconsideration. A request for reconsideration 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 reconsideration has been requested. F.t DONE at Anchorage, Alaska and dated January 3, 2011. c, _ • mot /� �� Daniel T. Se, ount, Jr. Cathy P. Foerster J P K. irr an — , y , ,O • Chair, Commissioner Commissioner Commissioner 'y )0 �� - `, RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • bp ®P Bxploretlon (Alaska) Ina. `i& Attn: well integrity Coordinator, PRE-20 Post Office Box 198812 Anchorage, Alaska 995194812 ' SIPZ December 16, 2010 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 1 Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit Well 04 -10 (PTD# 1760420) Request for Administrative Approval: Continued Water Injection Operations Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests approval for continued water injection operations into Prudhoe Bay Well 04 -10. Well 04-10 exhibits inner annulus repressurization where the inner annulus equalizes with the tubing pressure when on water injection. However, a mechanical integrity test on the inner annulus passed to 2500 psi on 04/29/10 after a tubing patch was set. Two barriers have been established and the well can be safely operated on water injection. Therefore, no repairs are planned at this time. In summary, BPXA believes Prudhoe Bay Well 04 -10 is safe to operate as stated above and requests administrative approval for continued water injection operations. If you require any additional information, please contact me at 564 -4303 or Torin Roschinger / Gerald Murphy at 659 -5102. Sincerely, Douglas A. Cismoskl, P.E. BPXA Wells intervention Manager • • Attachments: Technical Justification TIO Plot Injection Plot Welibore Schematic Cc: Doug Cismoski Steve Rossberg Bixby /Liddelow Murphy /Roschinger East Onshore Site Manager Flow Station 2 Operations Team Leader Olivia Bommarito Harry Engel • • Prudhoe Bay Oil Pool Well 04 -10 Technical Justification for Administrative Approval Request December 16, 2010 Well History and Status Prudhoe Bay Well 04 -10 (PTD #1760420) exhibits inner annulus repressurization while on water injection indicated by wellhead pressure trends on a TIO plot. An MIT -IA to 2500 psi passed on 04/29/10 indicating competent tubing and production casing. Recent Well Events: > 01/08/10: MIT -IA Failed, LLR 0.22 gpm @ 3000 psi > 02/15/10: LDL shows leak at lower packer of 5 1/2" WFD ER patch > 03/27/10: Set lower patch packer @ 6460' > 04/17/10: Set upper patch @ 6412' > 04/29/10: AOGCC MIT -IA Passed to 2500 psi > 05/13/10: IA pressure increased 850 psi overnight > 05/19/10: Passed MIT -IA to 3000 psi > 06/05/10: PPPOT -T and PPPOT -IC passed on wellhead > 07/13/10: Passed MIT -IA to 2500 psi Barrier Evaluation The primary and secondary barrier systems consist of tubing and production casing and associated hardware. A pressure test of the inner annulus passed to 2500 psi, demonstrating competent primary and secondary barrier systems. Proposed Operating and Monitoring Plan 1. Record wellhead pressures and injection rate daily. 2. The MI line will remain blinded to limit the well to water injections 3. Submit a report monthly of well pressures and injection rates to the AOGCC. 4. Perform a 2 -year MIT -IA to 1.2 times maximum anticipated injection pressure. 5. The well will be shut -in and the AOGCC notified if there is any change in the well's mechanical condition. . 0 • Well 04 -10 TIO Plot Welt 041111 4.000 ........ vaall.MONIBII.III0 .1•■•■•■■••■•• 3.050 t - IA j -ill- IA 2000 -.` OA 00A t - 000* ! o. 1 �� t • IA i r t 1 11729/08 12/29/09 01/29/10 03/01/10 04/01/10 06702/10 06/02/10 07/3/10 08/03/10 08/3110 1004/10 11/04/10 Well 04 -10 Injection Plot Ina 014$ 2200 -�� - 17.0 - 16002 2.COO - 15000 14.000 1 SGO 13D00 1,6 00 � 12.000 11000 1.100 - t0AC0 - �J18P 1100 - (7. 3 — P W # \l 1.000 - 8.000 ; _ al 7, 000 — 0r .. mss! Lh 800 ...� 6.000 ■ Cm I 5.000 4,000 i . 1 d00 . 3030 ■ 1 : f 2.000 11/28/00 — 12/2949 01/29/10 , 03101110 04/01/10 05/2/10 116402/10 07/03 /10 . 08 0 . 09/(73/10 10/04/10 1144 /10 41111 • , 4 • TREE= HAG Gehl t WtaLHEAD = Fa":': SAFETY NOTES: • AZIOKtOk":4--tiik§614 04-1 0 KB. ELEV. 52' SF. ELEV --. k = 5857. 20° CONDUCTOR 1 00' 111111 Max Angie = 23 J 91' 90,14-40, 2225' 5-1T2'OTS ROM SSSV NP, ID = 4.582 Datum MD . 9057' ID . 19.124° ' irl ,. Datum TVD . 83081 SS MIA 9-5/8 FOC 9-5/8' CSG, 478, S00-90 / RS-95 X0 2327' MUM 9.518* FOG TO MN.80 BUTT 1 3- 3/8" CSG, 7210, N430 BUTI, ID = 12.347" 2692' ..., 641Z 5. 1/2" WED ER PATCH, ID ,., 2.880' (04/17/10) - 9-5/8 - CSG, 478. 1184.80 X0 5177' I I TO 500.90/ RS-95 BUTT Minimum ID . 41 2.880" c 6412' ---1 OTIS XA sto a.v, a.) . ? 1 la 5 WFD ER PATCH . .1.. 7927' 1-14-1/LIEE±L21..231W1. ENYRY SKIRT] ITOPCF 3-1/2 I.NR H 192r 179 BOT MASSY I 5-112' TBG-PC, 178, L-80, .0232 bpi, to. 4.892" I 7964' BEHIND 7969' f 9-518`X 5.1 /2"SKR SAS N<R, ID = ? IBM CT LNR 7975' r Mi.LOUT aTENISION, 0 . ? \<......,.... 79 1 Z1 X0,10 = 7 7965' 1-14 -1/2" R.UTED NO-GO sua, to ,-;27:6 ' f i 8039' H4-1/2" OTIS XN NP , 0 . 3.725 I BEHIND 8104' --I4-1 /2" MULESHOE, ID . 3.958" 1 CT LNR 4-1/2' TBG-PC, 1 2.6*, L-80, .0152 bp& ( . 3.958" 8102' \ 80 3' --jEtito Tr LOGGED 00/30/80 I I TOP OF 7" LNR 8235" ,.. 3n--19•5/8* X r ROT MR FIGR 113 = i I 9.5/8 CSG, 478, RS.95 BUIII" 1 ..., a• 114 MN ;`0 . • EST TOP OF CEMENT ( 0710 MS) ktt V V9 r•T I 1 • • 4 ' 4 4, 144 I 3-1 /2" LNR, 9.'..iii,L-80 FL4S, .0670 bpl, ID = 2992' F., 90 ' ''00' 3-ta DAVIS LY NCH FLOAT SHOE PERPORATION SUIVIVIARY I REF LOG: 9140$ OF 08/15/76 I ANGLE AT TOP PERF: 22 @ 8837' Not: Refer to Production OS for historical pelf data S4E j SF* I INTERVAL f Opn/Sqz j DATE SEE PAGE 2 FOR PERFORATION INFORMATION 9033' CAT PLUG (SET 10/31/90) I I I I •••••••■ ,4•400.0, 0/118111 4+1./60 8,4,4A11,1,1,4, r LI4t, 298,1414-80 BUTT, .0371 Opt. 10 = 6.184' 9149' 4144014 ■•••••11 , ..14,114,8.44.4 TO Kum . . .rerc,-. s D. - -1 B iritfl PRUDHOE BAY UNIT 07128178 ROWAN 211 ONOINAL COMPLETION 12/09/09 JMF/SV SET NSW UPPER PAH TC .. WELL: 04-10 08/13/80 NIES RIM 03/18110 SWC/SV ALL PATCH (02/18/10) PERMIT No: 176-0420 ' , 1 ' , 7 - 1 L. ' 14/ i'l 1 Iffli ‘,"' L• , T* .A 17. (t /10 AP1No: 50-029-20213-00 10/14/06 COM'TLH CMI CORRECTIOFS 0 9a6) 04,2o/10 SET UFPER PATCH (04/17/10) SEC 27, 111N, R15E 1403.9 RR. 3959.95 PNL . 10/ "7 ^IP= ii`.. ve ITiFT - fr.:. ... , 10/2410? BSEM..10 SET INIAD PATCH .. PP Exploration (Alaska) 12/30/10 Schlwelorger NO. 5672 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth ( 333 West 7th Ave, Suite 100 V 6 Anchorage, AK 99501 Job # Log Description Date BL Color CD E -05 BL65 -00011 MEM DDL 12/18/10 1 1 38 AY1M -00056 PROD PROFILE a / 11/27/10 1 ( !j. 1 11 -12 BCZ2 -00033 PROD PROFILE j i — _ 12/06/10 1 (� 1 01 -25 BG4H -00022 INJECTION PROFIL � �� - 3 12/01/10 1 e).5 1 04 -24 AY1M -00058 PROD PROFILE / t,4 3 a ( 12/02/10 1 56'fc" 1 P2 -16 B5JN -00077 SBHPS 1T /P 11/26/10 1 2 �SLj(�, 1 A-41 BCZ2-00030 LDL d </ q T T$f 11/26/10 1 O "L, ' 1 04-08 BCRJ - 000566 INJECTION PR FILE O _ ,3 1 gyp- -O 12/06/10 1 Q 1 01-24A BBSK -00043 INJECTION PROFILE U ! 1 12/12/10 1 1 (' AV1H -00051 INJECTION PROFILE L) � J 12/07110 1 1 15.288 8D88 -00080 MEM PROD PROFILE ,�1 / 12/12/10 1 (- 1 2- 288/0.19 BCRJ -00055 PROD PROFILE � Q 11/30/10 1 o 1 • 07-235 AY1M -00056 SCMT c9' { Y 11/28/10 , a ( A 4 �1 1 02 -21A BBSK -00042 SCMT alai) — 4 11/23/10 A;'1' 1 1 02 -22B BL65 -00006 SCMT J O- 12/11/10 4 1 1 18 -12B BBUO -00029 SCMT (f 08/30/10 4 1 1 P2 -16 B5JN -00077 USIT 1. T_ I a.1 1 1 .- 1 1 05 -27B BAUJ-00049 MCNL ' Q / 09/18/10 1 0,5 % 1 16 -068 BBSK -00037 RST O ! ( 11/15/10 1 � 1 G -098 BGZ7 -00005 RST :a 09/20110 1 1 E -34L1 BD88 -00050 MCNL [ - j a 09/28/10 1 n 1 W -219 BGZ7-00012 CH EDIT PDC -GR (USIT) a/ U — / I) 5 11/22/10 •n� 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 S1 14) MAR 1 4 20r III AOGCC MITIA Forms for 04-10 (1720), 13-06 (1972180), 13-16 (182148~AGI-07 (20605... Page 1 of 1 Regg, James B (DOA) ~ ~~~-C~~Z From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Sunday, August 01, 2010 9:47 PM ~~~ ~IZ (f~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: AOGCC MITIA Forms for 04-10 (1760420), 13-06 (1972180), 13-16 (1821480), AGI-07 (2060520), B-13B (2100390), E-104 (2012080), L-111 (2020300), L-119 (2020640), L-123 (2051940) Attachments: July 2010 MIT forms GPB part 1.zip Jim, Tom and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: 04-10 (PTD #1760420) 13-06 (PTD #1972180) 13-16 (PTD #1821480) AGI-07 (PTD #2060520) B-13B (PTD #2100390) E-104 (PTD #2012080) L-111 (PTD #2020300) L-119 (PTD #2020640) L-123 (PTD #2051940) «July 2010 MIT forms GPB part 1.zip» Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 8/2/2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay /PBU / DS-04 DATE: 07/13/10 OPERATOR REP: Torin Roschinger AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 04-10 Type Inj. W TVD 7,835' Tubing 1,150 1,150 1,150 1,150 Interval V P.T.D. 1760420 Type test P Test psi 1958.7) Casing 1,460 ' 2,500 2,470 2,460 P/F P ~ Notes: MITIA for AA approval while on PWI ~ OA 50 70 70 70 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In'. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPEINJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU 04-10 07-13-10.x1s OPERABLE: Injector 04-10 (PTD #1760420) IA repressurization post tubing patch Page 1 of 2 • Maunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Thursday, July 15, 2010 4:39 AM To: AK, D&C Well Integrity Coordinator; Brooks, Phoebe L (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, RES GPB East Production Optimization Engineer; AK, OPS EOC Specialists; Daniel, Ryan; AK, D&C Wireline Operations Team Lead Cc: Bommarito, Olivia O; King, Whitney Subject: OPERABLE: Injector 04-10 (PTD #1760420) IA repressurization post tubing patch Attachments: 04-10 TIO Plot 07-14-10.doc; MIT PBU 04-10 07-13-10.x1s; 04-10.pdf All, Injector 04-10 (PTD #1760420) has slight TxIA communication while on water injection. However, on 07/13/10 an MITIA passed proving two competent barriers. The well has been reclassified as Operable while an AA for PWI is pursued. A TIO Plot, MIT Form and wellbore schematic have been included for your reference. «04-10 TIO Plot 07-14-10.doc» «MIT PBU 04-10 07-13-10.x1s» «04-10.pdf» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: AK, D8:C WeII Integrity Coordinator Sent: Thursday, July 08, 2010 10:55 AM To: AK, D&C WeII Integrity Coordinator; 'Brooks, Phoebe L (DOA)'; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; AK, OPS FSi OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, RES GPB East Production Optimization Engineer; AK, OPS EOC Specialists; Daniel, Ryan; AK, DBcC Wireline Operations Team Lead Cc: Bommarito, Olivia O; Sinyangwe, Nathan; King, Whitney Subject: UNDER EVALUATION: Injector 04-30 (PTD #1760420) IA repressurization post tubing patch AI I, Injector 04-10 (PTD #1760420) is showing signs of increased IA repressurization. An AOGCC MIT-IA passed on 04/29/10 post tubing patch verifying two competent barriers. The IA pressure build-up rate was reported around 60 psi/day stabilizing at 1450-1550 psi. In evaluating the well for Administrative Approval, a PPPOT-T Passed 06/05/10 indicating there is no communication across the well head, and aMIT-IA Passed to 2500 psi 06/17110. Since then, the IA repressurization rate has increased. The plan forward is: 1. D: Confirm IA stabilization pressure 2. D: MIT-IA to confirm competent barriers 3. WIC: Evaluate results to apply for Administrative Approval for TxIA communication 8/2/2010 OPERABLE: Injector 04-10 (PTD #1760420) IA repressurization post tubing patch Page 2 of 2 • The well will remain on water injection for diagnostic work up to 28-days. The MIT Form, TIO Plot, and wellbore schematic have been included for your reference. Please let me know if you have any questions. « File: MIT PBU 04-10 06-17-10 and TIO plot.xls » « File: 04-10.pdf » Thank you, Tiffany Quy (Filling in for Gerald Murphy/Torin Roschinger) Projects Well Integrity Engineer phone: (907} 659-5098 cell: (253) 576-6153 tiffg0@bp.com From: AK, D&C Well Integrity Coordinator Sent: Friday, June 18, 2010 4:54 PM To: 'Brooks, Phoebe L (DOA)'; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; AK, OPS FSl OSM; AK, OPS F52 Facility OTL; AK, OPS F52 DS Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, RES GPB East Production Optimization Engineer; AK, OPS EOC Specialists; Daniel, Ryan; AK, D&C Wireline Operations Team Lead Cc: Bommarito, Olivia 0; Clingingsmith, Mike J {CH2M Hill); AK, D&C Well Integrity Coordinator Subject: OPERABLE: Injector 04-10 (PTD #1760420) IA repressurization post tubing patch All, Injector 04-10 (PTD #1760420) is showing signs of TxIA communication post tubing patch as seen on the attached TIO plot. An AOGCC MIT-IA passed on 04/29/10 after the patch was set verifying two competent barriers. The IA pressure build-up rate is around 60 psi/day and stabilizes 1450-1550 psi. The well has been reclassified as Operable while an administrative approval for PWI only is pursued. A TIO Plot and wellbore schema#ic have been included for your reference. « File: 04-10 TIO Plot 06-18-10.doc » « File: 04-10.pdf » Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 8/2/2010 Well: 04-10 ~- Tbg f IA -~- OA OOA OOOA On 0 411 711 0 0412411 0 0 5101 11 0 05!0 811 0 05/1 5!1 0 05/22 /1 0 0 512 911 0 0 610 511 0 06/1 211 0 0 611 911 0 06/26/1 0 O7N9/10 07/10/10 AOGCC MITIA Forms for 03-36 (1760600), 03-12 (1790580), 03-37 (2090), 04-10 (... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Thursday, July 01, 2010 5:06 PM To: AK, D&C Well Integrity Coordinator Cc: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); AK, D&C Well Integrity Coordinator Subject: AOGCC MITIA Forms for 03-36 (1760600), 03-12 (1790580), 03-37 (2091390), 04-10 (1760420), 04-43 (1940130),04-44 (1940100),09-16 (1770370),09-19 (1770400), 09-31C (1960640), 09-36C (1951140), 09-37 (1940280) Attachments: June 2010 MIT Forms GPB part 1.zip Jim, Tom and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: 03-06 (PTD #1760600) 03-12 (PTD #1790580) -enclosed are 2 tests; original test from 6/12 /2010 and retest on 6/29/2010. 03-37 PTD #2091390 04-10 PTD #1760420) 04-43 (PTD #194013 04-44 (PTD #1940100) 09-16 (PTD #1770370) ~;,„+~;„ ,Jl~! ~= `'` ~U `~' 09-19 (PTD #1770400) 09-31 C (PTD #1960640) 09-36C (PTD #1951140) 09-37 (PTD #1940280) «June 2010 MIT Forms GPB part 1.zip» Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 7/2/2010 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay /PBU / DS-04 06/17/10 Torin Roschinger Packer Depth Pretest Initial 15 Min. 30 Min. ;'' ~ Well 04-10 Type Inj. W TVD 7,835' Tubing 1,200 1,200 1,200 1,200 Interv O P.T.D. 1760420 Type test P Test psi 1958.75 Casing 1,590 2,500 2,470 2,460 P/ P Notes: Eval TxIA Comm OA 90 90 90 90 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test )~,~ INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU 04-10 Oti-17-10.x1s OPERABLE: Injector 04-10 (PTD #1760420) IA repressurization post tubing patch Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Friday, June 18, 2010 4:54 PM To: Brooks, Phoebe L (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, RES GPB East Production Optimization Engineer; AK, OPS EOC Specialists; Daniel, Ryan; AK, D&C Wireline Operations Team Lead Cc: Bommarito, Olivia O; Clingingsmith, Mike J (CH2M Hill); AK, D&C Well Integrity Coordinator Subject: OPERABLE: Injector 04-10 (PTD #1760420) IA repressurization post tubing patch Attachments: 04-10 TIO Plot 06-18-10.doc; 04-10.pdf All, Injector 04-10 (PTD #1760420) is showing signs of TxIA communication post tubing patch as seen on the attached TIO plot. An AOGCC MIT-IA passed on 04/29/10 after the patch was set verifying two competent barriers. The IA pressure build-up rate is around 60 psi/day and stabilizes 1450-1550 psi. The well has been reclassified as Operable while an administrative approval for PWI only is pursued. A TIO Plot and wellbore schematic have been included for your reference. «04-10 TIO Plot 06-18-10.doc» «04-10.pdf» Thank you, Toxin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: AK, D&C Well Integrity Coordinator Sent: Wednesday, May 19, 2010 9:58 PM ,:,..~~I~~., ~ lil.!!a ~ ~j ~.~ii To: 'Brooks, Phoebe L (DOA)'; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; AK, OPS FSi OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, RES GPB East Production Optimization Engineer; AK, OPS EOC Specialists; Daniel, Ryan; AK, D&C Wireline Operations Team Lead Cc: Bommarito, Olivia 0; Clingingsmith, Mike ] (CH2M Hill); AK, DBcC WeII Integrity Coordinator Subject: UNDER EVALUATION: Injector 04-10 (PTD #1760420) IA repressurization post tubing patch All, Injector 04-10 (PTD #1760420) passed an AOGCC witnessed MITIA after a tubing patch was set 04/17/10. However, on 05/13/10 the IA pressure increased 850 psi overnight with stable injection rates indicating TxIA communication. On 05/19/10, an MITIA passed while on injection proving two competent barriers. The plan forward is to reclassify the well as Under Evaluation and monitor the TIO plot for 10 days to evaluate for an AA. The MIT Form, TIO Plot an wellbore schematic have been included for your reference. 8/2/2010 OPERABLE: Injector 04-10 (PTD #1760420) IA repressurization post tubing patch • Page 2 of 2 « File: MIT PBU 04-10 05-19-10.x1s» « File: 04-10 TIO Plot 05-19-10.doc» « File: 04-10.pdf» Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 8/2/2010 • • Well: 04-10 # Tbg -~ IA -~- OA OOA .- OOOA On 1 DDD • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay ala OPERATOR: BP Exploration (Alaska), Inc. K~'~ ~~~I ~`~ FIELD /UNIT /PAD: Prudhoe Bay /PBU / DS-04 DATE: 05/19/10 OPERATOR REP: Torin Roschinger AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 04-10 T pe Inj. W ~ TVD 7,835' Tubing 1,100 1,100 1,100 1,100 Interval O P.T.D. 1760420 Type test P Test psi 1958.75 Casin 1,120 ,~ 3,000 2,970 2,960 P/F P Notes: Eval TxIA Comm OA 60 60 60 60 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test ~~ ~ 1,'-Z77 ~ ( r e~~ ~2s~.~;~..~~ INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) ~~-II;~~ .~- MIT Report Form BFL 11/27/07 MIT PBU 04-10 05-19-10.x1s MEMORANDUM To: Jim Regg ~ ~t ~~~~~~ P.I. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, May 07, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 04-10 PRUDHOE BAY UNIT 04-10 Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv J('~c Comm Well Name: PRUDHOE BAY UNIT 04-10 Insp Num: mitJCr100504075541 Rel Insp Num: API Well Number: 50-029-20213-00-00 Permit Number: 176-042-0 Inspector Name: John Crisp Inspection Date: 4/29/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well o4-IO Type Inj. ~' TVD 7835 /~ IA 860 3000 2920 2900 P.T.D~0420 ~i TypeTest LSPT i Test psi 19sa / pA 20 zo 30 30 Interval ~IT~- p/F P Tubing laso Iaso ~ laso laso Notes: 5 bbls pumped for test ~~- ~.,. Friday, May 07, 2010 Page 1 of 1 ~~A~AND GAS CONSERVA ION COMMISSI~ Mnv ~~~14~T OF SUNDRY WELL OPERATIONS 1.Operations Abandon Repair Well ^ Plug Pertorations ^ Stimulate^ Other 0 tubing patch Performed: AI ~ Perforate New Pool ^ Waiver^ Time Extension ^ 6412' - 6460' Change Approved Program -Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ 176-0420 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ API Number: Anchorage, AK 99519-6612 50-029-20213-00-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ADLO-028325 ~ PBU 04-10 10. Field/Pool(s): Prudhoe Bay FIELD~Prudhoe Bay POOL 11. Present Well Condition Summary: Total Depth measured 9150 feet Plugs (measured) 9038' 8202' feet true vertical 8937.45 feet Junk (measured) None feet Effective Depth measured 9038 feet Packer (measured) 7969 true vertical 8834 feet (true vertical) 7835 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 94# H-40 30 - 110 30 - 110 1530 520 Production 2299 9-5/8" 47# R-S-95 28 - 2327 28 - 2327 8150 5080 Production 5474 9-5/8" 47# N-80 2327 - 7801 2327 - 7678 6870 4760 Production 740 9-5/8" 47# R-S-95 7801 - 8541 7678 - 8372 8150 5080 Liner 1073 3-1/2:" 9.3# L-80 7927 - 9000 7796 - 8799 10160 10530 Liner 914 7"29# MN-80 8235 - 9149 8085 - 8937 8160 7020 Pertoration depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# L-80 27 - 7964 27 - 7830 4-1/2" 12.6# L-80 7694 - 8104 7577 - 7962 Packers and SSSV (type, measured and true vertical depth) 9-5/8"x5-1/2" bkr sab bkr 7969 7835 12. Stimulation or cement squeeze summary: Intervals treated (measured): #c, f °~ P' ~°'; ~~ ~~~~~. ' jt~~ ~ .__ ~%1 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 68521 1180 Subsequent to operation: 16695 1472 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service Q Daily Report of Well Operations X Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^~ SPLUG ^ 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: 309-391 Contact Bob Chiwis Printed Name Bob Chivvis Title Production Engineer Signature 564-5412 Date 4/30/2010 Frm1- 04-10 176-042 PFRF ~TTO[:HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 04-10 4/29/77 PER 8,940. 8,955. 8,743.32 8,757.22 04-10 4/29/77 PER 8,962. 8,989. 8,763.7 8,788.69 04-10 4/29/77 PER 9,007. 9,019. 8,805.35 8,816.45 04-10 4/29/77 PER 9,025. 9,029. 8,822. 8,825.7 04-10 4/29/77 PER 9,040. 9,044. 8,835.87 8,839.57 04-10 10/22/84 APF 8,882. 8,896. 8,689.56 8,702.54 04-10 10/22/84 APF 8,836. 8,852. 8,646.86 8,661.71 04-10 10/22/84 APF 8,857. 8,871. 8,666.36 8,679.35 04-10 7/8/90 SQZ 8,836. 9,044. 8,646.86 8,839.57 04-10 7/16/90 FCO 8,836. 9,030. 8,646.86 8,826.62 04-10 7/21/90 RPF 9,007. 9,019. 8,805.35 8,816.45 04-10 8/3/90 RPF 9,025. 9,029. 8,822. 8,825.7 04-10 10/31/90 FIL 9,038. 9,044. 8,834.02 8,839.57 04-10 4/7/96 FIL 8,878. 9,000. 8,685.84 8,798.87 04-10 7/1/96 MIS 7,927. 9,000. 7,795.61 8,798.87 04-10 7/9/96 FCO 7,927. 9,042. 7,795.61 8,837.72 04-10 1/7/06 APF 8,882. 8,896. 8,689.56 8,702.54 04-10 1/8/06 APF 8,860. 8,866. 8,669.14 8,674.71 04-10 1/10/06 APF 8,838. 8,852. 8,648.71 8,661.71 04-10 7/6/06 APF 8,838. 8,852. 8,648.71 8,661.71 04-10 7/6/06 APF 8,860. 8,866. 8,669.14 8,674.71 04-10 7/6/06 APF 8,882. 8,896. 8,689.56 8,702.54 04-10 11/14/09 BPS 8,202. 9,044. 8,053.75 8,839.57 04-10 11/24/09 BPP 8,202. 9,044. 8,053.75 8,839.57 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 04-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 2/14/2010' T/I/0= 1800/20/40. Assist Slickline with LDL.(Eval T x IA comm) Load TBG. ;Pumped 2 bbls neat methanol, followed by 200 bbls diesel down TBG to load. Load ~ ~ IA. Pumped 2 bbls neat methanol, followed by 13 bbls of diesel to load. SL to RIH f with PDS LDL tool. Pump dsl to keep pressure on IA between 2500 and 3000 (continued on 2/15/10)_ _ . _ __ j~ ~ 2/14/2010*""WELL S/I ON ARRIVAL***(Idl) j IDRIFT W/ 4.50" CENT, 3.00" S.BAILER, TAG TOP OF WFD PATCH @ 6386' a f SLM NO PROBLEMS FL. 5630' SLM. 'RAN K.JT, 2.50" CENT, TEL, 2.50" S.BLR, LOC TT. @ 8983' SLM(1 T COR. TO 9000' MD) TAG STICKY BTM. @ 9011' MD, 18' OF FILL ABOVE LOWEST PERF. REC. 1 CUP OF SCHMOO. E LRS LOADED TUBING W/ 200 BBLS DIESEL. IA 13 BBLS DIESEL. ;RUN PDS TECWELL IN HOLE & BEGIN LOGGINGs_ 2/15/2010(continued from 2-14-10) Pump dsl down IA to assist slickline on LDL.Pumped 12 bbls dsl to keep pressure between 2500 and 3000 (wireline on well has control ,annulus valves open to gauges operator notified of departure) FWHP=500/0/40 2/15/2010"""CONTINUED FROM 2-14-10 WSR""* RAN PDS TECWELL FROM 8121' SLM TO SURFACE.(good data) PDS DATA SHOWS LEAK AT LOWER PACKER OF 5-1/2 WFD ER PATCH. !PULLED UPPER SECTION OF WFD PATCH.(intact, snap latch assembly intact) ;MADE 1 ATTEMPT TO PULL LOWER ANCHOR FROM 6423' SLM. *"*CONTINUED ON 2-15-10 WSR"** 2/16/2010;*'`*CONTINUED FROM 02-15-10 WSR**"* jPULL LOWER ANCHOR FROM 6123' SLM(intact) ~ E ~ RAN 4.50" DRIFT W/ NO PROBLEMS, TAG DEPLOYMENT SLEEVE @ 7904' ~ ';SLM. ~***WELL LEFT S/I, DSO NOTIFIED*** __ _ 3/27/2010**"WELL SHUT IN ON ARRIVAL*** (E-LINE SET LOWER ELEMENT PATCH) INITIAL T/I/0=1200/150/0 WF L ER ER PACKER OF PATCH MIDDLE OF ELEMENT AT 6460' .WITH TOP AT 6455.7'. MIN ID 3.00". TAGGED AFTER SET. ~ ;FINAL T/I/0=1200/150/0 1 *'"*JOB COMPLETE*** LJ 4/17/2010 4/17/2010 ***WELL S/I ON ARRIVAL"'"* (patch) SET LOWER SNAP LATCH AND SPACER PIPE IN WFD ANCHOR @ 6445'SLM ~ (30.32'LNG) ;SET UPPER PACKER @ 6412'SLM (17'LNG) j_MIT-IA TO 3000# -GOOD TEST. 100# DROP @ 15 MIN, 30# DROP IN SECOND 15 MIN. ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED**" 4/27/2010`T/I/O= 2100/100/20 Temp= SI Load Tbg with SW (DSO call in). Pumped 5 bbls mmeth, 200 bbls SW followed by 5 bbls meth. DSO to put on injection. Final WHPs ! 2100/100/20 '-WV,SSV,MV,IA,OA= Open SV= Shut _ ..._..~._.~ ..~~_ ~..~.~.w._... 4/29/2010rT/I/O=1480/360/20, temp =hot. AOGCC MIT-IA PASSED to 3000 psi (State Witnessed). Pressured IA to 3000 psi with 5 bbls 60/40 meth. MIT-IA lost 80 psi in 1st 15 minutes. and 0 psi in 2nd 15 minutes for a total of 80 psi during 30 minute test. Bled IAP to 350 psi. Final WHPs = 1480/350/20. SV, WV=S/I SSV, MV=O IA, OA=OTG Operator notified at dep. FLUIDS PUMPED BBLS 200 SW 20 METH 2 DIESEL 222 Total 'T/I/0= 1980/220/40 Temp= S/I. Assist Slickline as directed. MIT-IA PASSED to 3000psi. (Restore Tubing integrity) Pressured up IA to 3000 psi w/ 5 bbls Neat Methanol. MIT-IA lost 100 psi in 1st 15 mins, and 30 psi in 2nd 15 mins w/ a total loss of 130 psi over 30 min test. Bled IAP down. Bled back -4 bbls. FWHP's= 1980/280/40. SSL still on well at time of departure. **Casing valves left open to gauges upon departure"'" TREE = FMC GEN I WELLN.:AD =, FMC ACTUATOR = AXELSON KB. ELEV = 52' BF. ELEV = ~ KOP = 5857' Max Angle = 23 @ 9154' Datum MD = Datum ND = 9057' 8800' SS 20" CONDUCTOR, -L 94#, H-40, ID = 19.124" 9-518" CSG, 47#, SOO-90 ! RS-95 XO~~ TO MN-80 BUTT 13-3/8" CSG, 72#, N-80 BUTT, ID = 12.347" 9-5/8" CSG, 47#, MN-80 XO --{ TO SOO-90 / RS-95 BUTT Minimum ID = 2.991" @ 7965' 4-1/2" FLUTED NO-GO SUB TOP OF3-1/2"LNR --~ 5-112" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" --~ 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" J TOP OF 7" LNR 9-5/8" CSG, 47#, RS-95 BUTT, ID = 8.681" 51 O ~ - ~ 0 A FETY NOTES---~ 2225' -15-112"OTIS ROM SSSV NIP, ID = 4.562" 2347' 9-5/8" FOC 2471' 9-5/8" FOC /t343. I-(5-1/2" OTIS XA SLD SLV, ID = ? I 7927' 4-1/2" G SEAL SUB W/WL ENTRY SKIRT 7964' I 8102' I I 8541' I 7963' 5-112" BOTPBRASSY 7969' BEHIND 9-5/8"X 5-1/2"BKR SAB PKR, ID = ? ~ 7975' -- CT LNR ~7" MILLOUT EXTENSION, ID = ? 7976' 7" X 4-1/2" XO, ID = ? 7965' 4-1/2" FLUTED NO-GO SUB, ID = 2.991" 8039' 4-112" OTIS XN NIP, ID = 3.725 BEHIND 8104' -- -~4-1/2" MULESHOE, ID=3.958" CT LNR 8093' ELMD TT LOGGED 09/30/80 8235' 1--19-5/8" X 7" BOT LNR HGR, ID = ? EST TOP OF CEMEM (07/01!96) 1 13-112" LNR, 9.3#, L-80 FL4S, .0870 bpf, ID = 2.992 9000' REF LOG: BRCS OF 06(15/76 A NGLE AT TOP PERF: 22 @ 8837' Note: Refer to Production DB far historical pert data SIZE J SPF J INTERVAL OpnJSgz DATE SEE PAGE 2 FOR PERFORATION INFORMAT~N I_ 1 7" LNR, 29#, MN-80 BUTT, .0371 bpf, ID = 6.184" 9149' ( ~~ 9154' DATE REV BY COMMENTS DATE REV BY COMMENTS 07!28/76 ROWAN 28 ORIGINAL COMPLETION 12/09/09 JMF/SV SET NEW UPPER PATCH 08/13/80 07/03/96 N1 ES N2ES RWO 03118110 3-1/2 CT SCAB LNR SWC/SV PULL PATCH (02/16110) 10/14/06 COM~TLH CMTCORRECTIONS(1996) 10/23/07 RC/PJC DRAWING CORRECTIONS 10/24/07 BSE/PJC SET WRD PATCH PRUDHOE BAY UNIT WELL: 04-10 PERMIT No: 176-0420 API No: 50-029-20213-00 SEC 27, T11 N, R15E 1403.9 FEL 3959.95 FNL BP Exploration (Alaska) J3-112" DAMS LYNCH FLOAT SHOE CMT PLUG (SET' 10/31190) U • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska_gov; phcebe.brooks@alaska_gov; tom.maunder@alaska_gov; doa.aogcc.pn~hce.bay~alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay /PBU / DS-04 04J29110 Torin Roschinger John Crisp Packer Pretest Initial 15 Min. 30 Min. We11 04-10 T In'. W TVD 7,835 T 1,480 1,480 1,480 1,480 InteMal I P.T.D. 1760420 T test P Test 1958.75 360 3,000 2,920 2,900 P!F P Notes: Post-initial injection post-patch QA 2'0 20 30 30 Well T In'. TYD Tubi Interval P.T.D. T test Test P/F Notes: OA Well T In'. TVD T Interval P.T.D. T test Test P/F Notes: OA Well T In'. TVD T Interval P.T.D. T test Test P/F Notes: OA Well T In . TVD T Interval P.T.D. T test Test Casi P!F Notes: OA TYPE INJ Codes TYPE TEST Codes D =Drilling Waste M = Annulru Monitoring G =Gas P =Standard Pressure Test I =Industrial Wastewater R = Internal Radioartive Tracer S ~~ ~~~ ,~ I ~ I,~ ~ F; ~ ~ ~ N =Not Injecting A = Temperature Aramaly Survey '' W =Water D = Dilterrerrliai Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O = Olher (describe in notes) MIT Report Form BFI 11!27/07 MIT PBU 04-1004-29-10.x1s • SEAN PARNELL, GOVERNOR ALASSA OII, AI1TD rzAS 333 W. 7th AVENUE, SUITE 100 COI~TSERQATIOPIT COMDIISSIO~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 CANCELLATION FAX (907)276-7542 ADMINISTRATIVE APPROVAL Nth AIO 4E.026 Mr. Steve Rossberg, Wells Manager Attention: Well Integrity Engineer, PRB-20 O~~" BP Exploration (Alaska) Inc. its; °?. ~~~~~~ ~ ~~ P.O. Box 196612 ,~~ :,~ ~~'~==°t Anchorage, AK 99519-6612 RE: Cancellation of Administrative Approval AIO 4E.026 (Well PBU 04-10) Dear Mr. Rossberg: Pursuant to BP Exploration (Alaska) Inc. (BPXA)'s request dated March 17, 2010, the Alaska Oil and Gas Conservation Commission (Commission) hereby cancels Administrative Approval AIO 4E.026, which allows continued water injection in Prudhoe Bay Unit ("PBU") well 04-10. This well exhibited tubing by inner annulus communication and BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. BPXA has attempted unsuccessfully to repair the integrity loss. BPXA has determined not to operate PBU 04-10 until successfully repaired. Consequently, Administrative Approval AIO 4E.026 no longer applies to operation of this well. Instead, injection into PBU 04-10 will be governed by provisions of the underlying AIO No. 4E. DONE at Anchorage, Alaska and dated A 26, 2010. The Alaska Oil and G Con ervation Commission ,~~f ~ Daniel T. eamount, Jr. Jo rma Cathy P. F ers .~ ~oissioner, Chair om ' si er Commissioner ~~ ,~ . ~~ ~. yy ~aa &i ~. ~~ .SF6~ ~r, .~ • • ~i~' BP Exploration (Alaska} inc, Attn: Well Integrity Coordinator, PR@-20 Post Office Bax 196612 Anchorage, Alaska 99519-6612 March 17, 2010 Mr. Danie! Seamaunt, Chairman Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue Anchorage, Alaska 99501 APR ~ 2 ~20~o by ~las~ tail ~ Gas Cans. Commission Anchorage Subject: Prudhoe Bay Unit well 04-10 (PTD #1760420) Application for Cancel{ation of Administrative Approva14E.026 Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests cancellation of Administrative Approval number 4E.026 dated December 13, 2007. The administrative approval was for continued water injection into well 04-10 with slow T x IA communication. This wets failed a M{TIA for Administrative Approva{ compliance on November 5, 2009. The first attempt at re-patching the tubing was unsuccessful. The wel! remains shut-in while it is being evaluated for a second attempt at patching the tubing. Therefore it is requested to cancel the Administrative Approva{ for continued operations. A plot of wellhead pressures has been included for reference. If you require any additional information, please contact me at 564-5637 or Anna Dube Toxin Roschinger at 659-5102. Sincerely, ~/ t R. Steven Rossberg BPXA, Wells Manager Attachments: TIO Plot Cc: Bixby/Olsen Dube/Roschinger East Area Manager Bob Chiwis Harry Engel • • 04-10 (PTD #1760420) TIO~t w.t a-ie 4.000 3,000 2,000 1000 ~ Tbq -f- IA ~- OA OOA OOOA On 04-10 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, March 18, 2010 10:06 AM /~T,D 17Ca~D`~Z To: 'Chiwis, Robert' Subject: RE: 04-10 Request for second attempt to Patch Tubing under original Sundry Bob, This will work just fine. Proceed ahead..... Submit 404 after work is completed. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) ~~~~~ t~6P~r~ ~ t 2~~ __ _ _ __ From: Chiwis, Robert [mailto:Robert.Chiwis@bp.com] Sent: Thursday, March 18, 2010 9:53 AM To: Schwartz, Guy L (DOA) Cc: Chiwis, Robert; Preble, Gary B (SAIC) Subject: RE: 04-10 Request for second attempt to Patch Tubing under original Sundry Hi Guy, We are requesting authorization to make another attempt under our original Sundry to patch a tubing leak on Prudhoe Bay Well 04-10 . This time we are making the patch longer to cover the whole joint of tubing. Here is a summary of our work steps. I have attached the work program if you want more detail. Thanks, Bob 1 E Set Lower WFD 5.5" ER Packer Tubin Patch 2 S Set S acer Pi e & U er WFD 5.5" ER Packer Tubin Patch 3 F MITIA to 3000 si, Est LLR if Fails 4 FP AOGCC MITIA to 3000 si Est LLR if Fails From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, March 18, 2010 8:38 AM To: Preble, Gary B (SAIC) Cc: Chiwis, Robert Subject: RE: 04-10 Gary, You can operate under the original sundry. Please have Bob send me a request by email and outline the work steps and scope again. I assume it will be very similar to the original work request.... Then just submit another 404 for this wellwork. Better luck this time! Guy Schwartz Senior Petroleum Engineer 3/18/2010 04-10 • • Page 2 of 2 AOGCC 793-1226 (office) 444-3433 (cell) From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Thursday, March 18, 2010 6:26 AM To: Schwartz, Guy L (DOA) Cc: Chiwis, Robert Subject: 04-10 Guy, Well 04-10 (176-042) was patched on 12/19//09 and passed by the AOGCC I submitted a 10-404 (309-391) on 12/29/09 for the patch but it failed MIT-A on 118!10. See notes below. Are we required to resubmit a 10-403 to reset the tubing patch again or can we just continue to use the same sundry number? Thanks > 12/07/09: Set WFD patch from 6423'-6442'; MIT-IA Passed to 3000 psi > 12/19/09: AOGCC MIT-IA Passed to 2500 psi. AOGCC considers test inconclusive due to borderline results > 12/21/09: AP dump returned ~7 gal > 12/29/09: AP flush returned ~5 gal > 01/08/10: MIT-IA Failed, LLR 0.22 gpm @ 3000 psi > 02/15/10: LDL shows leak at lower packer of 5 1/2" WFD ER patch, pulled upper section of patch > 02!16/10: Pulled lower packer of patch Gary Preble Petrotechnical Data Team Coordinator Science Applications International Corporation Office 907.564.4944 Mobile 907.350.6879 preblegb@bp.com 3/1812010 by To: Jerry Bixby/Clark Olsen Well Operations Supervisors From: Jack Lau, Wells Engineer Subject: 04-10 Tubing Patch AFE: APBD04WL10 Please perform the following requested well work on 04-10: ~~ Date: March 16, 2010 (w: 564-5102 c: 227-2760) Cost: $65M IOR: 200 1 E Set Lower WFD 5.5" ER Packer Tubin Patch 2 S Set S acer Pi e ~ U er WFD 5.5" ER Packer Tubin Patch 3 F MITIA to 3000 si, Est LLR if Fails 4 FP AOGCC MITIA to 3000 si, Est LLR if Fails Well Detail Current Status: SI Produced Water Injector -Patch pulled 2/16/10 Previous Inj: 01/10/10: 6029 bwpd, WHIP 1187 psi Integrity Issues: Not Operable - TxIA Comm Previous Op: 02/16/09: TecWel located leak at lower packer of straddle, pulled straddle Previous Drift: 02!16/09: Pulled 5%" patch from 6404-6445' ELM 11/24/09: Pulled 3'/z" WRP from 8202'SLM Min ID: 4.562" through 5'h" Otis SSSV Nipple Max Deviation: 23°@ 9154'MD Last H2S Readina: N/A PWI 17L -al ~z~l s~c,..~~~ 30~ ~ 3 10-403 Sundry approval is required from AOGCC prior to commencing work. 10-404 Sundry submission is required within 30 days of completion. IL'" ~'` 3-Ib'-to Objective ~.~.. The following are the objectives of this well intervention design: 1) Restore tubing integrity by setting a tubing patch over the leaks identified by the TecWel LDL and the conventional LDL performed on 2/15/10 and 5/20/07, respectively. 2) Prove tubing integrity has been restored by performing a MITIA to 3000 psi. 3) Perform an AOGCC MITIA to 3000 psi prior to POI. Discussion Well 04-10 is a "Not Operable" produced water injector shut in TxIA communication. The well has a 3-1/2" liner which is cemented at the bottom and extends up into the tubing. The tubing was patched at 6405' to 6443' in Oct-07 with a WFD 5'/2" ER two set straddle and snap latch seal. A subsequent MITIA passed to 3000 psi indicating tubing integrity had been restored. The well was put on PW injection until 11/05/09 when an AOGCC MITIA failed. A TecWel LDL performed on 11/14/09 indicated a leak at the snap latch of the patch, just above the lower ER packer. The same day a 3%Z" WRP was set at 8202'SLM for secure. To restore tubing integrity Slickline pulled the upper 5'/" ER packer assembly and 3'/z" WRP, redressed the upper ER packer and snap latch seals, brushed the lower ER packer seal bore, and reset the 5'/" upper ER packer assembly with Halliburton's ETD setting tool. A passing post-patch repair MITIA proved the repair reestablished tubing integrity. On 01/08/10 apre-AOGCC MITIA failed at a LLR ~2.2 gpm at 3000 psi. No pressure response was seen on the tubing during the MITIA. A subsequent TecWel LDL identified a leak at the lower packer of the patch. Slickline pulled the upper and lower patch assemblies to prepare the well for a new patch. The plan forward is to restore tubing integrity by setting a new two run WFD ER patch. This patch was chosen because of its history of mechanical success and because the longest available single set patch is 20'. Tubing tally indicates 5'/" plastic coated tubing Note that Schmoo-B-Gone B&F treatments have been required in the past. A Schmoo- B-Gone treatment was not required while setting the 3'/" WRP on 11/14/09. Seeing the ER patch was pulled on 02/16/10, trouble reaching depth is not anticipated. Relevant Well Events > 05/21/07: LDL finds leak @ 6420' -6435' > 09/15/07: CMIT-TxIA Passed to 2500 psi > 09/22/07: Pull WRP, B&F, run DMY patch > 10/08/07: Set lower packer for patch @ 6443' > 10/19/07: Set WFD upper patch @ 6398' SLM > 10/20/07: MITIA Passed to 2500 psi > 11/05/07: Rapid IA re-pressurization > 11/06/07: MITIA Failed on stabilization > 11/15/07: MITIA Passed to 2500 psi > 11/19/07: AOGCC MITIA Passed to 2500 psi > 11/25/07: PPPOT-T Passed to 5000 psi, PPPOT-IC Passed to 3500 psi > 12/13/07: TxIA AA Approval for PWI > 11/05/09: MIT-IA Failed > 11/14/09: LDL found leak @ 6445', LLR 0.06 bpm or 2.6 gpm @ 2500 psi WRP set in liner @ 8202' > 11/15/09: CMIT-TxIA Passed to 2500 psi > 12/21109: AP dump returned ~7 gal > 12/29/09: AP flush returned ~5 gal > 01/08/10: MIT-IA Failed, LLR 0.22 gpm @ 3000 psi > 02/15/10: LDL shows leak at lower packer of 5 112" WFD ER patch, pulled upper section of patch > 02/16110: Pulled lower packer of patch 04-10 Tubing Patch 2 of 7 04-10 Tubing Patch 3 of 7 E-Line Tubing Patch -Set Lower Packer Assembly Please Review: Alaska Drilling and Wells .Recommended Practice: Tubing Patches Patch Specs and Depths • All depths are referenced to 05/19/07 SWS LDL. • WFD ER Patch - 54' element to element • Setting depths 6406-6460'ELMD -the proposed patch will cover the entire joint that has led to the three leaks. • 3 run WFD ER Packer Lower ER Packer Assembly - 5%" L-80 ER • 5'/" WFD ER (OD = 4.50", ID = 3.00"}. • OAL = ~5' • Packer is L-80 - • Setting depth -mid element at 6460'ELMD - 3D Caliper CD indicates good tubing +/- 4' around proposed setting depth (4' above is collar). 1. Contact WFD rep to prep lower ER packer assembly for 54' ER patch (element to element). 2. MIRU E-Line. 3. RIH w/ lower 5.5" ER packer assembly to below 6500' ELMD. 4. Tie into reference log SWS LDL dated 19-May-2007. 5. PUH and set mid element of lower ER packer at 6460' ELMD per WFD Rep instructions and PE Manual guidelines. 6. POOH. RDMO E-Line. Slickline Tubing Patch -Set Uaaer Packer Assembly Run#1 - E-Line set lower ER packer Run#2 -Snap Latch, Spacer Pipe, with SO Tieback • Snap latch seal assembly - (OD = 4.50", ID = 2.880"). • OAL = ~33' • Packer is L-80 • Ref Log: SWS LDL dated 19-May-2007. Run#3 -Upper ER Packer Assembly - 5'h" L-80 ER • Snap latch seal assembly - (OD = 4.50", ID = 2.992"). • OAL = ~25' • Packer is L-80 • Ref Log: SWS LDL dated 19-May-2007. 7. MIRU Slickline. • Not that Schmoo-B-Gone B&F treatments have been required in the past. A Schmoo-B-Gone treatment was not required while setting the 3'h" WRP on 11/14/09. 8. MU BHA to include second run of patch (2 of 3) -Snap Latch Assembly, 3.5" Spacer Pipe, and SO Tie-back. 9. RIH and sting snap latch into lower ER packer set at ~6460'ELMD. 10. Per WFD Reps instructions PU for positive indication that snap latch is engaged. 11. Release. POOH. 12. RIH 4.5" standing valve w/ SO tie-back seals (for 3" ID) and set in SO Tie-Back. 13. Perform CMIT-TxiA to 1000 psi to verify lower packer and snap latch are. holding.:. 14. POOH w/ standing valve. 15. Contact Halliburton to have rep and ETD setting tool on location. Using the Halliburton ETD setting tool will provide more time to verify the SO Tie-back seals are fully engaged. 16. Contact WFD rep (x2356} to prep upper ER packer assembly for 44' ER patch (element to element). 17. RIH w/ Halliburton ETD setting tool and WFD 5%2" L-80 upper ER packer assembly, 3.5" spacer pipe, and SO Tie-back Stinger. 18. Stab into SO Tie-back at 6431'ELMD and engage SO tieback seals. Per WFD. Reps instructions PU for positive indication that stinger is completely s#ung into seals. Mid element of upper packer should be at 6406'ELMD. 19. Set Upper ER Packer at 6406'ELMD per HES, WFD., and PE Manual recommended practices. 20. POOH. 04-10 Tubing Patch 4 of 7 Fut~bore Prove"Tubing ntegrity 21. MIRU Fullbore. Perform MITIA to 3000 psi with 60140 MethM/ater. Esfi LLR if Fails. RDMO. • Expect the IA to be loaded close to surface from TecWel LDL on 02/14/10. • Update AA for water injection. 22. MIRU Fullbore. Perform AOGCC MITIA to 3000 psi with 60/40 Meth/Water. Est LLR if Fails. RDMO. If you have any questions or concerns regarding this program, please contact Jack Lau at 907.564.5102 (work), 907.227.2760 (cell) or Brad Gathman at 907.242.2034 (cell). cc: G ANC Wellwork Program 04-10 Tubing Patch 5 of 7 ~~ ~. m. ~. ~ ~ n.. Q 4 4' c ~ ~ ~ .I1 tt3 ~ a ~ ~ h ~ ~ n ~y 3 ~ o T a ~~ t Leak Detection Log PressfTemplCCt~lGrad~or'Spanners 19-MAY-2007 4~J3.?7' FSL & !667.TJ9' ~El. EieW.: iC.S, dt Surface G.l.. D.F. Hsrmanent Uatum : MS~_____~ -- - , _- -- Eiev.: _ C tt-- Log Mea,ure~ From: RKB ___ ___ 5~2,Q Pt at;ov~ Qr+l~ma Measures Fromm _RKB____~ _ ~• C1 1 i ~ ~ :1 - - - •-- ~~ ~ 27' 3 2 5Q-J2 - 41 13-C:L r ~9~n~3 t?ate 1~S-May-2t~J7 n Num~r . _ z. i _._-.m~ ~. _ .~-...~ - pfn i~il9~i ~~ ~~lumt.~erc~er Depth Not Tagged ttosn :.og Inte-r.~al - _ 8325 a ~o~ ~ nt°rva l _ ~ _ - SG ~~ _ _ 5~n~ r lord ?ype ~~ .._~ ~ ~ 4L' Meth for LDt ~~~, 04-10 Tubing Patch Tnr......'. 1 i ~! 6 of 7 Inpu! DI.IS Flles 21-May2t107 19:41 ` °+ ~~L L~~.7 T14:4~fT~~, IJ. PrtoAcrive D'u~nostic SexvicES, INC. To: AOGCC Christine Mahnken 333 W, 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MIT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1j 2j Signed Leak Detection - WLD 14-Fe1r10 04-10 ~~~~~~ ~~~r~ ~ ~ ~~ ~~lp- d~~ 193~`~ Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : _ _,_ -_. WEBSITE C:':Documents and Settings~Diane W'il'uarnsDesktep~:T:ansmit BP.docx January AOGCC MIT1As for 04-1p (#1760420), GNI-03 (#1971890), MP~6 (#197084... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comJ Sent: Sunday, January 31, 2010 1:17 PM ~~~ l ZI ~ I ~`~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: January AOGCC MITIAs for 04-10 (#1760420), GNI-03 (#1971890), MPF-26 (#1970840), MPF-49 (#1970030), MPL-15 (#1940620), MPL-33 (#1971050), S-218 (#2090940) Attachments: MIT PBU 04-10 01-08-10.x1s; MIT PBU GNI-03 01-16-10 .xls; MIT MPU MPF-26 MPF-49 01- 23-10 .xls; MIT MPU MPL-15 MPL-33 01-23-10 .xls; MIT PBU S-218 01-16-10 .xls Jim, Tom, and Phoebe, Please find the attached MITIA forms for the following wells: 04-10 (#1760420) - - ~ J~ ~v`-~ne~s~ ~ Cc - c~.r%~ GNI-03 (#1971890) MPF-26 (#1970840) MPF-49 (#1970030) ~~l.~~e,5ser~~ ~,_ }„ MPL-15 (#1940620) .T.~s~~- ~~F~ MPL-33 (#1971050) S-218 (#2090940) «MIT PBU 04-10 01-08-10.x1s» «MIT PBU GNI-03 01-16-10 .xls» «MIT MPU MPF-26 MPF-49 01-23- 10 .xls» «MIT MPU MPL-15 MPL-33 01-23-10 .xls» «MIT PBU S-218 01-16-10 .xls» Please let us know if you have any questions. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 ~~~~ ~~t~ ~ ~ ~~~~. 2/1/2010 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay /PBU / DS-04 DATE: 01 /08/10 OPERATOR REP: Torin Roschinger AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 04-10 Type Inj. W TVD 7,835' Tubing 1,050 1,050 1,050 1,050 Interval V P.T.D. 1760420 Type test P Test psi 1958.75 Casin 1,210 3,000 2,960 2,930 P/F F Notes: OA 20 120 180 230 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well T pe In'. TVD Tubing Interval P.T.D. T pe test Test psi Casing P/F Notes: OA Well Type In'. TVD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA TYPEINJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Ahomaly Survey D =Differential Temperature Test ~~ INTERVAL Codes 1 =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover 0 =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU 04-10 01-OS-10.x1s NOT OPERABLE: 04-10 (PTD 60420) MITIA Failed post tubing pate Page 1 of 1 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, January 08, 2010 8:37 PM To: NSU, ADW Well Integrity Engineer; Brooks, Phoebe L (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Quy, Tiffany; Chivvis, Robert Subject: NOT OPERABLE: 04-10 (PTD #1760420) MITIA Failed post tubing patch All, Well 04-10 (PTD #1760420) is a produced water injector that recently had an AA for TxIA communication. On 12/07/09, a tubing patch was set followed by a successful AOGCC witnessed MITIA on 12/19/09. On 01/06/10, the IA pressure appeared to be tracking the tubing pressure and a subsequent MITIA on 01/08/10 was performed for diagnostics that failed. The well has been reclassified as Not Operable and needs to be shut-in as soon as it can be freeze protected. The plan forward is as follows: 1. Pumping: MITIA -FAILED 2. Slickline: Set TTP 3. Pumping: CMIT-TxIA 4. E-Line: Leak detect log Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 4/26/2010 ~~` ~ ~~' UNDER EVALUATION: 04-10 ~D #1760420) Tubing tracking IA posting patch Page 1 of 3 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, January 06, 2010 8:47 PM To: NSU, ADW Well Integrity Engineer; Brooks, Phoebe L (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Williams, Carrie; Chivvis, Robert Subject: UNDER EVALUATION: 04-10 (PTD #1760420) Tubing tracking IA post tubing patch Attachments: 04-10 TIO Plot 01-06-10.doc; 04-10.pdf AI I, Well 04-10 (PTD #1760420) is a produced water injector that recently had an AA for TxIA communication. On 12/07/09, a tubing patch was set followed by a successful AOGCC witnessed MITIA on 12/19/09. On 01/06/10, the IA pressure appeared to be tracking the tubing pressure. The well has been reclassified as Under Evaluation to perform diagnostics while the injector is online. The plan forward is as follows: 1. DHD: MIT-IA to 2500 psi, LLR if fails 2. DHD: AOGCC MIT-IA to 2500 psi 3. WIC: Eval for AA A TIO Plot and wellbore schematic have been included for reference. «04-10 TIO Plot 01-06-10.doc» «04-10.pdf» Please call with any questions or concerns. Thank you; Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Friday, December 25, 2009 8:58 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartr, Guy (DOA)'; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Williams, Carrie; Chiwis, Robert; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 04-10 (PTD #1760420) Tubing integrity restored post patch All, ~~~ ~C~ 4/26/2010 UNDER EVALUATION: 04-10 ~D #1760420) Tubing tracking IA posting patch Page 2 of 3 Well 04-10 (PTD #1760420) passed an AOGCC witnessed MIT-IA to 2500 psi on 12/19/09. While the MIT-IA was a passing test, it was a borderline passing test. Due to the borderline pass we will continue to monitor this well for 1-2 months prior to applying for the cancellation of the AA the well currently injects under. The well has been reclassified as Operable. Please continue injection as needed. Included is a current TIO & Injection Plot and a copy of the MIT-IA results. « File: 04-10 TIO & Injection Plots.ZlP » Please contact me with any questions. « File: MIT PBU 04-10 12-19-09.x1s » Thank you, Taylor Taylor Wellman filling in for Anna Dube/Toxin Roschinger Office: 659-5102 Pager: 659-5100 x 1154 om: NSU, ADW Well Integrity Engineer Sen Tuesday, December 08, 2009 8:24 AM To: N ,ADW Well Integrity Engineer; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DO ;GPB, Area Mgr East (FSl/2/COT eawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU DW Well Operations Supervisor; GPB, Wells Opt g; Chiwis, Robert; GPB, EOC Specialists Cc: Williams, Carrie Subject: UNDER EVAL TION: 04-10 (PTD #1760420) Tubing integrity restored post patch All, Well 04-10 (PTD #1760420) pass an MITIA after a tubing pa was set on 12/07/09. The passing test verifies tubing integrity has been restored. well has been reclas ~ led as Under Evaluation so that it may be placed on injection for a state witnessed MITIA. Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1 4 From: NSU, ADW We ntegrity Engineer Sent: Saturday, N ember 07, 2009 9:47 PM To: NSU, AD Well Integrity Engineer; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; (FSl/2/COT eawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW GPB, Well pt Eng; Chiwis, Robert; GPB, EOC Specialists; GPB, Gas Lift Engr Williams, Carrie ^t: NOT OPERABLE: 04-10 (PTD #1760420) TxIA Communication Area Mgr East 19{~erations Supervisor, 4/26/2010 • 04-10 (PTD #1760420) TIO Plot d.UDii 3 iifn7 20~ 1 OLO • ~ T6p a w -+- oA OOA OOOA On 11/07/09 11/14/09 11/21/09 11 86/09 12!05109 12/12/09 12/19/09 7226.+09 01 JOZ/10 STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS E ~v `~ `~ >Cl~ 1. Operations Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate^ ~j Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ ~" ?~?~' Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory 176-0420 3. Address: P.O. Box 196612 Stratigraphic^ Service ~ .API Number: Anchorage, AK 99519-6612 50-029-20213-00-00 8. Property Designation (Leas@ Number) : .Well Name and Number: ~ ADLO-028325 PBU 04-10 10. Field/Pool(s): ~ Prudhoe Bay FIELD / Prudhoe Bay POOL 11. Present Well Condition Summary: Total Depth measured 9150 feet Plugs (measured) 9038' 8202' feet true vertical 8937.45 feet Junk (measured) None feet Effective Depth measured 9038 feet Packer (measured) 7969 true vertical 8834 feet (true vertical) 7835 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 94# H-40 30 - 110 30 - 110 1530 520 Production 2299 9-5/8" 47# R-S-95 28 - 2327 28 - 2327 8150 5080 Production 5474 9-5/8" 47# N-80 2327 - 7801 2327 - 7678 6870 4760 Production 740 9-5/8"47# R-S-95 7801 - 8541 7678 - 8372 8150 5080 Liner 1073 3-1/2:" 9.3# L-80 7927 - 9000 7796 - 8799 10160 10530 Liner 914 7"29# MN-80 8235 - 9149 8085 - 8937 8160 7020 Pertoration depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# L-80 27 - 7964 27 - 7830 4-1/2" 12.6# L-80 7694 - 8104 7577 - 7962 rt~~ Packers and SSSV (type, measured and true vertical depth) 5-1/2" Baker SAB Packer 7969 -'~ 7835 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~gy ~(~\ ~i ~~jj (~ yy Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 15927 1890 Subsequent to operation: 8256 1064 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service Q Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^~ SPLUG ^ 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: 309-391 Contact Bob Chivvis Printed Name Bob Chiv vis Title Production Engineer ? ~ Signature ~~J~`~ ~t'`-"~"~~'~r" Phone 564-5412 Date 12/29/2009 Form 1 .Ly!~ I~ 30 ~~ ~1 ~ /1 •.30.0 9 ,--~'t ~5 04-10 176-042 DFDC ATTA~_1-IMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 04-10 4/29/77 PER 8,940. 8,955. 8,743.32 8,757.22 04-10 4/29/77 PER 8,962. 8,989. 8,763.7 8,788.69 04-10 4/29/77 PER 9,007. 9,019. 8,805.35 8,816.45 04-10 4/29/77 PER 9,025. 9,029. 8,822. 8,825.7 04-10 4/29/77 PER 9,040. 9,044. 8,835.87 8,839.57 04-10 10/22/84 APF 8,882. 8,896. 8,689.56 8,702.54 04-10 10/22/84 APF 8,836. 8,852. 8,646.86 8,661.71 04-10 10/22/84 APF 8,857. 8,871. 8,666.36 8,679.35 04-10 7/8/90 SQZ 8,836. 9,044. 8,646.86 8,839.57 04-10 7/16/90 FCO 8,836. 9,030. 8,646.86 8,826.62 04-10 7/21 /90 RPF 9,007. 9,019. 8,805.35 8,816.45 04-10 8/3/90 RPF 9,025. 9,029. 8,822. 8,825.7 04-10 10/31/90 FIL 9,038. 9,044. 8,834.02 8,839.57 04-10 4/7/96 FIL 8,878. 9,000. 8,685.84 8,798.87 04-10 7/1/96 MIS 7,927. 9,000. 7,795.61 8,798.87 04-10 7/9/96 FCO 7,927. 9,042. 7,795.61 8,837.72 04-10 1/7/06 APF 8,882. 8,896. 8,689.56 8,702.54 04-10 1/8/06 APF 8,860. 8,866. 8,669.14 8,674.71 04-10 1/10/06 APF 8,838. 8,852. 8,648.71 8,661.71 04-10 7/6/06 APF 8,838. 8,852. 8,648.71 8,661.71 04-10 7/6/06 APF 8,860. 8,866. 8,669.14 8,674.71 04-10 7/6/06 APF 8,882. 8,896. 8,689.56 8,702.54 04-10 11/14/09 BPS 8,202. 9,044. 8,053.75 8,839.57 • • 04-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 12/2/2009,'"*'`WELL SHUT IN ON ARRIVAL ***(patch) RIH W/ 3.50" CENT, 3-1/2" BRUSH TO LOWER PKR AT 6437' SLM ;FLUSH TBG W/ HOT DIESEL WHILE BRUSHING TOP OF PKR. ~"**CONT WSR ON 12/3/09*** i 12/2/2009 T/I/0=50/40/0 Temp=S1 Assist slick line with patch (Restore tubing integrity by resetting the upper patch assembly) Pumped 5 bbls neat methanol spear and ~swaped to diesel. ***Continue AWGRS on 12-03-09*** 12/3/2009*""'Continued AWGRS from 12-02-09***~Assist slick line with patch/ MIT IA to 3000 psi -job postponed due to high wind (Restore tubing integrity by resetting the upper' patch assembly) Pumped 250 bbls diesel down tbg while Slick line brushing. Slick ;line unable to reset upper ER packer assembly due to high winds. FWHP's=600/560/0 Slick-line on well at departure ~ ~_ _ _ _ _, ~___w 12/3/2009i"*"CONT WSR FROM 12/2/09""*(patch) ATTEMPT TO RUN WFD UPPER PKR/PATCH, RDMO DUE TO WIND. ; ~"**LEFT WELL SHUT IN,PAD OP NOTIFIED'"'"* ~~~~~~ 12/6/2009 ~ (Assist s-Ime w/brush n flush; MIT IA /Set TBG patch) Standby for S-Line. Awgers continued on 12-07-09 j 12/6/2009 T/I/0=270/20/0+. Temp=S1. IA FL (for slickline). No AL. IA FL @ 174' (7.6~bbl) *"'"`slickline in control of well*"" _ _ __ _ __ _ 12/6/2009 ***WELL S/I ON ARRIVAL (Set upper WFD patch)*** R/U SLICKLINE UNIT "**CONTINUED ON 12/7/09''** ~ __...~n ~,~ m~~..~~.~~~®,~.... ~ ..~ ®~ .! 12/7/2009.*'"`CONTINUED FROM 12/6/09*** RAN 3.63" CENT. 3-1/2" BRUSH TO LOWER PATCH @ 6436' SLM BRUSH PATCH @ 6432' SLM W/LRS PUMPING HOT DIESEL (TOTAL OF 206 ,BBLS PUMPED) ?SET 5-1/2"WFD ER PACKER/PATCH @ 6442' SLM (OAL- 39') ,/MIT-IA TO 3000 PSI (PASS)....SEE LRS WSR FOR DETAILS ~ T/I 0=350/0/0 =5-1/2"WFD ER PATCH, ID= 2.880" 6404'-6445' ELM (10/08/07 & NEW UPPER 12/07/09) ***WELL S/I ON DEPARTURE**" 12/7/2009 .__.._. __W._. ~_. _.W__. ~.~_..~__ T/I/0= 200/0/20 Assist S Line Brush and Flush, MITx IA 3000 psi **Passed** (Set Tbg Patch) Pump 120 bbls diesel @ 180* followed by 40 bbls diesel @ 30* down TBG. S-Line RIH. Pump 47 bbls diesel down TBG while S-Line Brushes TBG patch area. S-line to set Tbg Patch. Pump 6.4 bbls 60/40 down IA to pressure up to 3000 psi. MIT IA-Passed 2nd test IAP lost 30 psi 1st 15 min, 10 psi 2nd 15 min. FWHP's= 0/100/60 S-line in control of well IA, OA=OTG tags hung DSO notified at LRS dep. 12/15/2009 T/I/0=1280/1500/340. Temp=135''. Monitor WHPs. On inj. "*Integral on IA*". SV=Closed. WV, MV, SSV=Closed. IA & OA=OTG. NOVP. 12/17/2009 T10=1120/1510/620. On Inj. Bleed IAP <300 psi, OAP <100 psi (pre-AOGCC MIT- IA). Bled IAP to 250 psi in 20 mins (all fluid), bled OAP to 60 psi, fluid and small amount of arctic pack returned. SI bleed monitor for 30 mins. No change in IAP or OAP. Integral installed on IA. Final WHPs=1120/250/60 **Job Complete** SV=C. WV,SSV,MV=O. IA,OA=OTG. NOVP _ _ _e._~._______ ~_~~_._._._.~_~_ 12/19/2009 T/I/0= 1150/1020/220 Temp= Inj. MIT-IA PASSED to 2500 ~~AOGCC Statg witnessed by Lou Grimaldi) Pressured up IA to 2500 psi with 2.8 bbls 60/40 MVV. ;1st 15 min IA lost 30 psi, 2nd 15 min IA lost 20 psi, 3rd 15 min IA lost 15 psi with a ; ;total loss of 65 psi in 45 min test. Bled back 3 bbls. Final WHPs= 1150/1000/320 I"Valves are SV=closed, WV,SSV,MV,IA and OA open on departure" FLUIDS PUMPED BBLS 14 60/40 METH 458 DIESEL 472 Total TREE = FMC GEN I WELLH,[=AD = FMG ACTUATOR = AXELSON'. KB. ELEV = 52'''. BF. EIEV = ?' KOP = 5857' 20" CONDUCTOR, Max Angle = 23 @ 9154' 94#, H-40, Datum MD = 9057' ID = 19.124" Datum TV D = 8800' SS 9-5/8" CSG, 47#, 500-90 ! RS-95 XO - TO MN-80 BUTT 13-318" CSG, 72#, N-80 BUTT, ID = 12.347" - 9-518" CSG, 47#, MN-80 XO TO SOO-90 / RS-95 BUTT SAFETY NOTES: 04-10 2225'-15-1/2"OTIS RQM SSSV NIP, ID = 4.562" ,. 2347' 9-5/8" FOC 232T 2471' 9-5/a° Foc TOP OF 3-112" LNR ~ 7927' 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 7964' Minimum ID = 2.880" @ 6404' 5-1i2" WFD ER PATCH j 4-112" TBG-PC, 12.6#, 1-80, .0152 bpf, ID = 3.958" $102' ~ TOP OF 7" LNR ~- j f3Z35• 9-5/8" CSG, 47#, RS-95 BUTT, ID = 8.881" $541 ` V - 6445' ELM 5-112" WFD ER PATCH, ID = 2.880" (10!08/07 & NEW UPPER 12107/09)) 7843' ~-- ~ 5-1/2" OTIS XA SLD SLV, ID = ? 7927' 4-1/2" G SEAL SUB W/WL ENTRY SKIRT 7963' - 5-1/2" BOT PBRASSY BEHIND 7969' 9-5i8"X 5-1/2"BKR SAB PKR, ID = ? CT LN R 7975' 7" MILLOUT IXTENSION, ID = ? 7976` 7" X 4-112" XO, ID = ?~ 7965' 4-1/2" FLUTED NO-GO SUB, ID = 2.991" $039' 4-1/2" OTIS XN NIP , ID = 3.725" BEHIND $104' 4-1/2" MULESHOE, ID=3.958° CT LNR 80~ EIMD TT LOGGED 09!30180 8235' I~ 9-518" X 7" BOT LNR HGR, ID = ? ~ EST TOP OF CEMENT (07/01/96} I ~ ~ 3-112" LNR, 9.3#, L-80 FL4S, .0870 bpf, ID = 2.992" ~~ 9000' PERFORATION SUMMARY REF LOG: BHCS OF 06!15!78 ANGLE AT TOP PERF: 22 @ 8837' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERFORATION INFORMATION 7" LNR, 29#, MN-80 BUTT, .0371 bpf, ID = 6.184" ~ 9149' 9154' 9000' 1--13-112" DAMS LYNCH FLOAT SHOE g03$' i-I CMT PI-UG (SET 1013 DATE REV BY COMMENTS DATE REV BY COMMENTS 07/28/76 ROWAN 26 ORIGINAL COMPLEf10N 12109!09 JMF/SV SET NEW UPPER PATCH 08!13180 N1 ES RWO 07!03196 N2ES 3-112 CT SCAB LNR 10/14/06 COM/TLH CMT CORRECT~NS (1996) 10/23/07 RC/PJC DRAWING CORRECTIONS 10/24/07 BSE/PJC SET WRD PATCH PRUDHOE BAY UNff WELL: 04-10 PERMfT' No: 176-0420 API No: 50-029-20213-00 SEC 27, T11 N, R15E 1403.9 FEL 3959.95 FNL BP Exploration (Alaska} OPERABLE: 04-10 (PTD #17604~T'ubing integrity restored post patch • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, December 25, 2009 8:58 PM `` Q(~ ~ ~ Z~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Williams, Carrie; Chivvis, Robert; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 04-10 (PTD #1760420) Tubing integrity restored post. patch Attachments: 04-10 TIO & Injection Plots.ZlP; MIT PBU 04-10 12-19-09.x1s All, Well 04-10 (PTD #1760420) passed an AOGCC witnessed MIT-IA to 2500 psi on 12/19/09. While the MIT-IA was a passing test, it was a borderline passing test. Due to the borderline pass we will continue to monitor this well for 1-2 months prior to applying for the cancellation of the AA the well currently injects under. The well has been reclassified as Operable. Please continue injection as needed. Included is a current TIO & Injection Plot and a copy of the MIT-IA results. «04-10 TIO & Injection Plots.ZlP» «MIT PBU 04-10 12-19-09.x1s» Please contact me with any questions. Thank you, Taylor Taylor Wellman filling in for Anna Dube/Torin Roschinger ~~ ~~t~ ~ ~ ~~~ Office: 659-5102 Pager: 659-5100 x 1154 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, December 08, 2009 8:24 AM To: NSU, ADW Well Integrity Engineer; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; Chiwis, Robert; GPB, EOC Specialists Cc: Williams, Carrie Subject: UNDER EVALUATION: 04-10 (PTD #1760420) Tubing integrity restored post patch All, Well 04-10 (PTD #1760420) passed an MITIA after a tubing patch was set on 12!07/09. The passing test verifies tubing integrity has been restored. The well has been reclassified as Under Evaluation so that it may be placed on injection for a state witnessed MITIA. Please call with any questions or concerns. Thank you, 12/28/2009 OPERABLE: 04-10 (PTD #17604~Tubing integrity restored post patch • Page 2 of 2 Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Saturday, November 07, 2009 9:47 PM To: NSU, ADW Well Integrity Engineer; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; Chiwis, Robert; GPB, EOC Specialists; GPB, Gas Lift Engr Cc: Williams, Carrie Subject: NOT OPERABLE: 04-10 (PTD #1760420) TxIA Communication All, Well 04-10 (PTD #1760420) has an AA for TxIA communication while on water injection. However, an MITIA failed on 11/06/09 verifying the tubing integrity has been compromised. The well has been reclassified as Not Operable and will be shut-in as soon as it can be freeze protected. The plan forward is as follows: 1. Pumping: MIT-IA to 3000 psi -FAILED 2. DHD: Est LLR 3. Eline: Eval for leak detect log A wellbore schematic and TIO plot have been included for reference. « File: 04-10.pdf» « File: 04-10 TIO Plot.doc » Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 12/28/2009 04-10 TIO Plot: 12 month ,«,o z.~ _~ '~, I ~, r--- -~-r''.~ 04-10 Injection Plot: 12 month :mo ~ >,m ,~ !, ~~ ~~~ I TT ,~~ ~;, 1.~ Vi I, lam I~~ J 1~ ~uw~ '~~ mm~m ovz I ~~~ ~~~ ' ',-:~s y p~. _~'~_... ~~~- ,,;:9~, uvxrm m mmms mmms nsa:as ior~mi ~ ~ ~-~4 ~ ~.~ ~a ~, OOn oaaa . a~ 15 ~Gi le YC -WNM ~~ ~, sw - ~ r 1 ~~ '.J 5~ aom 3rd 2~xn I~ •!~~ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT !PAD DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay /PBU / DS 04 12/19/09 Anna Dube ~- Lou Grimaldi /Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. Well 04-10 Type Inj. W ~ TVD 7,835' Tubing 1,150 1,150 1,150 1,150 Interval V P.T.D. 1760420 Type test P Test psi 1958.75 Casing 1,020 °2,500 2,470 x,450 P/F P Notes: 2-year MITIA to 2500 psi for AA. Post tubing patch OA 220 330 320 390 Pressured IA w/ 2.8 bbls of MEOH 45 Min. Well Type In'. TVD Tubing 1,150 Interval P.T.D. Type test Test psi Casing 2,435 P/F Notes: OA 430 Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU 04-10 12-19-09.x1s MEMORANDUM TO: Jim Regg ~~, ~ (Z~~ ~ 0 P.I. Supervisor `~~ FxoM: Lou Grimaldi Petroleum Inspector S~e of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, January 19, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) II1C 04-10 PRUDHOE BAY UNIT 04-]0 NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 04-10 API Well Number: 50-029-20213-00-00 n Insp Num: mitLG091220144458 Permit Number: 176-042-0 In Rel Insp Num: MITOP000002910 / Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 04-10 Type Inj. "~' TVD 7835 IA 1020 2500 2470 2450 2435 P.T.D 1760420 TypeTest SPT Test psi 1958 OA 220 330 320 390 430 J -- - - Interval Other (describe in notes) p~ Fail Tubing 1150 1150 1150 1150 1150 Post tubing patch to remove Administrative Approval MIT. Results not 100%. Informed Anna Dube that determination would be made in office Otes: as I did not feel these results proved patch was not leaking. Email from BP indicates well is under evaluation for possible TxIA communication; additional Mffs scheduled (plb 1-13-10). ~J~,2 G~ci ~tc~, ~ ~1S IG~k~ I/'I.T~I' GL ~~ l 'IZu~eo Tuesday, January 19, 2010 Page 1 of 1 Src: Inspector UNDER EVALUATION: 04-10 (~D #1760420) Tubing integrity restorec#y~ost patch Page 1 of ~n Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj Sent: Tuesday, December 08, 2009 8:24 AM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; Chivvis, Robert; GPB, EOC Specialists Cc: Williams, Carrie Subject: UNDER EVALUATION: 04-10 (PTD #1760420) Tubing integrity restored post patch All, Well 04-10 (PTD #1760420) passed an MITIA after a tubing patch was set on 12/07/09. The passing test verifies tubing integrity has been restored. The well has been reclassified as Under Evaluation so that it may be placed on injection for a state witnessed MITIA. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 Fr m: NSU, ADW Well Integrity Engineer Se Saturday, November 07, 2009 9:47 PM To: NS W Well Integrity Engineer; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schw ,Guy (DOA)'; GPB, Area Mgr East (FS1/2/COTU/Se er); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Eng arty R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; C ~ Robert; GPB, EOC Specialists; GPB, Gas Lift Engr Cc: Williams, Carrie Subject: NOT OPERABLE: 04-10 (PTD #17 0) TxIA All, Well 04-10 (PTD #1760420) has A for TxIA communication ile on water injection. However, an MITIA failed on 11/06/09 verifying t ubing integrity has been compromise .The well has been reclassified as Not Operable and will be shu ~ as soon as it can be freeze protected. The plan forty is as follows: 1. Pump :MIT-IA to 3000 psi -FAILED 2. DHD: Est LLR 3. Eline: Eval for leak detect log A wellbore schematic and TIO plot have been included for reference. Q ~~~ 4/26/2010 ~`~' S Tr LE SEAN PARNELL, GOVERNOR ,Lri‘J ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1►IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. Bob Chivvis Production Engineer BP Exploration (Alaska), Inc. 6 0 P.O. Box 196612 0 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU 04 -10 Sundry Number: 309 -391 4L NE NO 2 7 2009 Dear Mr. Chivvis: 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, ,I Joi inn. Co ssioner DATED this 1i day of November, 2009 Encl. STATE OF ALASKA ,t,f e RECEIVED ALAS.IL AND GAS CONSERVATI O N COMM I SS� NOV ;��(J 1 8 �(�Q9 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 (mom18 OH Gas Cons. Commission 1. Type of Request: Abandon Suspend Operational shutdown Perforate Re -enter Suspenc Igt'a* Alter casing Repair well Plug Perforations Stimulate Other El Specify: tubing patch Change approved program Pull Tubing Perforate New Pool Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development Exploratory 176 -0420 3. Address: P.O. Box 196612 Stratigraphic Service 0 6. API Number: Anchorage, AK 99519 -6612 9 50- 029 20213 -00 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 04 -10 Spacing Exception Required? Yes No 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO 028325 i Prudhoe Bay Field Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9150 8937.45 9038 8834 9038' 8202' NONE Casing Length Size MD TVD Burst Collapse Liner 914 7 "29# MN -80 8235 9149 8085 8937 8160 7020 Conductor 80 20" 94# H-40 30 110 30 110 1530 520 Production 2299 9 -5/8" 47# R -S -95 28 2327 28 2327 8150 5080 Production 5474 9 -5/8" 47# N -80 2327 7801 2327 7678 6870 4760 Production 740 9 -5/8" 47# R -S -95 7801 8541 7678 8372 8150 5080 Liner 1073 3 -1/2" 9.3# L -80 7927 9000 7796 8799 10160 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4 -1/2" 12.6# L -80 7964 8104 SEE ATTACHED 5 -1/2" 17# L -80 27 7964 Packers and SSSV Tvoe: PACKER Packers and SSSV MD and TVD (ft): 7969 7835 12. Attachments: Description Summary of Proposal IS 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Development Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/25/2009 Oil Gas WDSPL Plugged 16. Verbal Approval: Date: WINJ 0 GINJ p WAG Abandoned Commission Representative: GSTOR SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bob Chivvis Printed Name Bob Chivvis Title Production Engineer Signature 0 c Phone Date rlJ 564 -5412 11/18/2009 Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 369- 3?/ Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 05 5 tf 1 Mss 1 I al I i n'1 I A I /r9,�y ed 07/2••• t I j t L. a l Submit in Duplicate 04 -10 176 -042 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 04 -10 4/29/77 PER 8,940. 8,955. 8,743.32 8,757.22 04 -10 4/29/77 PER 8,962. 8,989. 8,763.7 8,788.69 04 -10 4/29/77 PER 9,007. 9,019. 8,805.35 8,816.45 04 -10 4/29/77 PER 9,025. 9,029. 8,822. 8,825.7 04 -10 4/29/77 PER 9,040. 9,044. 8,835.87 8,839.57 04 -10 10/22/84 APF 8,836. 8,852. 8,646.86 8,661.71 04 -10 10/22/84 APF 8,857. 8,871. 8,666.36 8,679.35 04 -10 10/22/84 APF 8,882. 8,896. 8,689.56 8,702.54 411 04 -10 7/8/90 SQZ 8,836. 9,044. 8,646.86 8,839.57 04 -10 7/21/90 RPF 9,007. 9,019. 8,805.35 8,816.45 04 -10 8/3/90 RPF 9,025. 9,029. 8,822. 8,825.7 04 -10 10/31/90 SQZ 9,038. 9,044. 8,834.02 8,839.57 04 -10 1/7/06 APF 8,882. 8,896. 8,689.56 8,702.54 04 -10 1/8/06 APF 8,860. 8,866. 8,669.14 8,674.71 04 -10 1/10/06 APF 8,838. 8,852. 8,648.71 8,661.71 04 -10 7/6/06 APF 8,838. 8,852. 8,648.71 8,661.71 04 -10 7/6/06 APF 8,860. 8,866. 8,669.14 8,674.71 04 -10 7/6/06 APF 8,882. 8,896. 8,689.56 8,702.54 04 -10 11/14/09 BPS 8,202. 9,044. 8,053.75 8,839.57 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED 0 FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE by 0 To: Jerry Bixby /Clark Olsen Date: November 16, 2009 Well Operations Supervisors From: Jack Lau, Wells Engineer (w: 564 -5102 c: 227 -2760) Subject: 04 -10 Tubing Patch Cost: $50M AFE: PBD04WL10 IOR: 200 Please perform the following requested well work on 04 -10: 1 S Pull Upper ER packer assembly. Pull WRP. Caliper. Set Upper ER packer assembly w/ HES setting tool. MITIA to 3000, est LLR if fails. Well Detail Current Status: SI Produced Water Injector Secured with 31" WRP Previous In]: 11/11/09: 15,927 bwpd, WHIP 1890 psi Integrity Issues: Not Operable TxIA Comm, TecWel indicates patch leaking Previous DH Op: 11/14/09: TecWel LDL, Set 3 WRP 8202'SLM Min ID: 2.880" through 51" WFD ER Patch 6405'MD Max Deviation: 23°@ 9154'MD Last H2S Reading: N/A PWI Objective The following are the objectives of this well intervention design: 1) Pull the upper WFD 51" ER packer assembly and leaking snap latch seals. 2) Pull the 31/2" WRP. 3) Access mechanical condition of the 51" tubing and 31/2" liner by performing a 24- Arm Caliper 4) Restore tubing integrity by resetting a redressed WFD 51" ER packer assembly with snap latch seals into the existing lower ER packer. 5) Perform a MITIA to prove tubing integrity has been restored. Discussion Well 04 -10 is a "Not Operable" produced water injector shut in TxIA communication. The well has a 3 -1/2" liner which is cemented at the bottom and extends up into the tubing. The tubing was patched at 6405' to 6443' in Oct -07 with a WFD 51" ER two set straddle and snap latch seal. A subsequent MITIA passed to 3000 psi indicating tubing integrity had been restored. The well was put on PW injection until 11/05/09 when an AOGCC MITIA failed. A TecWel LDL performed on 11/14/09 indicated a leak at the snap latch of the patch, just above the lower ER packer. The same day a 31/2" WRP was set at 8202'SLM for secure. s The plan forward is to restore tubing integrity by pulling the upper 51/2" ER packer assembly and 31/2" WRP, redressing upper ER packer and snap latch seals, brushing the lower ER packer seal bore, resetting the 51/2" upper ER packer assembly with Halliburton's ETD setting tool, and performing a MITIA to prove tubing integrity. Using the Halliburton ETD setting tool will provide more time to ensure the snap latch seals are fully engaged into the lower ER packer. A caliper will also be run to access the mechanical condition of the tubing. Basic Program Phases Slickline Pull and Reset Upper ER Packer Assembly Pull Upper WFD 51/2" ER packer Pull 31/2" WRP 24 -Arm Caliper log from bottom of 31/2" liner to surface Redress upper ER packer and snap latch seals Brush the lower ER packer seal bore Reset Upper WFD 51/2" upper ER packer assembly with Halliburton's setting tool Fullbore Prove Tubing Integrity MITIA to 3000 psi, Est LLR if either Fails Relevant Well Events 05/21/07: LDL finds leak 6420' -6435' 09/15/07: CMIT -TxIA Passed to 2500 psi 09/22/07: Pull WRP, B &F, run DMY patch 10/08/07: Set lower packer for patch 6443' 10/19/07: Set WFD upper patch 6398' SLM 10/20/07: MITIA Passed to 2500 psi 11/05/07: Rapid IA re- pressurization 11/06/07: MITIA Failed on stabilization 11/15/07: MITIA Passed to 2500 psi 11/19/07: AOGCC MITIA Passed to 2500 psi 11/25/07: PPPOT -T Passed to 5000 psi, PPPOT -IC Passed to 3500 psi 12/13/07: TxIA AA Approval for PWI 11/05/09: MIT -IA Failed 11/14/09: LDL found leak 6445', LLR 0.06 bpm or 2.6 gpm 2500 psi WRP set in liner 8202' 11/15/09: CMIT -TxIA Passed to 2500 psi Pre Intervention 1. Contact WFD rep to ensure they will be onsite to retrieve and redress upper ER packer and snap latch seals. A 2' box by box pup will be ready to be added to upper patch assembly to avoid the area of tubing previously engaged by slips 2. Contact Halliburton to have rep and ETD setting tool on location. Using the Halliburton ETD setting tool will provide more time to ensure the snap latch seals are fully engaged into the lower ER packer. Slickline 04 -10 Tubing Patch 2 of 8 Pull and Reset WFD 51" ER Upper Packer Assembly Patch Specs and Depths All depths are referenced to 05/19/07 SWS LDL. Lower ER Packer 51" L -80 ER packer is currently in hole and is thought to be competent. 51/2" WFD ER (OD 4.50 ID 3.00 OAL 4.98' Packer is L -80 Mid element of lower packer set at 6443' Current Upper ER Packer 51/2" L -80 ER packer is currently in hole and snap latch is thought to be leaking. Snap latch seal assembly (OD 4.50 ID 2.880 OAL 36.80' Packer is L -80 Mid element of upper packer set at 6406' New Upper ER Packer 51/2" L -80 ER packer with redressed snap latch seals and ER packer. 2' box by box pup will be added to upper patch assembly to avoid the area of tubing previously engaged by slips. Snap latch seal assembly (OD 4.50 ID 2.880 OAL 38.80' Packer is L -80 Mid element of upper packer set at 6404' Please Review: Alaska Drilling and Wells Recommended Practice: Tubing Patches 3. MIRU Slickline. Not that Schmoo -B -Gone B &F treatments have been required in the past. A Schmoo -B -Gone treatment was not required while setting the 31/2" WRP on 11/14/09. 4. RIH and pull 51" Upper ER packer from 6405'MD. See existing patch drawing in accompanied excel spreadsheet, take notice of the multiple tabs. The lower ER packer will be left in hole as it is less than 2 years old and appears to be in working condition. The newly redresses upper ER packer assembly will 04 -10 Tubing Patch 3 of 8 sting into the lower ER packer via snap latch and seals. 5. Contact WFD Rep at x2356 to redress Upper 51/2" ER packer and Snap Latch Seals. Ensure the 2' box by box pup will be ready to be added to upper patch assembly to avoid the area of tubing previously engaged by slips 6. RIH and pull 31/2" WRP from 8202'MD. Seeing that the well is a water injector the WRP packing should not swell and create problems pulling up through the lower ER packer and snap latch. 31" WRP was set on 11/14/09 without problems getting through patch. Lower ER packer ID is 3.00" 7. Run 24 -Arm caliper log from 31" tubing tail at 9000' to surface. Max angle is 23° at 9154'MD Previous caliper was performed on 11/01/06 without problems. 8. RIH w/ 3.5" BLB and brush the lower packer seal bore at 6439'MD. This will help to ensure the seal bore is clean and the snap latch seals can reengage. 9. RIH w/ Halliburton ETD setting tool and WFD 51/2" L -80 upper ER packer assembly with redressed snap latch seals. Ensure 2' box by box pup joint is included for an OAL of 38.80'. 10. Stab into lower packer seal bore to engage snap latch seals per WFD recommended practices and PE manual. PU to ensure snap latch is engaged. Mid element of upper packer should be at 6404'. 11. Set Upper ER Packer at 6404 per HES, WFD, and PE Manual recommended practices. POOH. Fullbore Prove Tubing Integrity 12. MIRU Fullbore. Perform MITIA to 3000 psi with 60/40 Meth /Water. Est LLR if Fails. RDMO. Expect the IA to be loaded close to surface seeing a CMIT -TxIA passed to 3000 psi post -WRP. If you have any questions or concerns regarding this program, please contact Jack Lau at 907.564.5102 (work), 907.227.2760 (cell) or Brad Gathman at 907.242.2034 (cell). 04 -10 Tubing Patch 4 of 8 cc: G ANC Wellwork Program TREE= FMC GEN I WELLHEAD FMC O4 A I SAFETY NOTES I ACTUATOR AXELSON KB. ELEV 'S2 BF. ELEV KOP- 58 20' CONDUCTOR, 100' 0 Max Ante 23 9154' 944, 1440. I 2225' I 15 1J2'OTIS ROM SSSV NP, 0 4.562° I Datum MD 9057' ID= 19.124' r] Datum TVD= 00' SS 2347' 9 -518° FOC 9-518° CSG, 47 SOO -90 RS-95 XO H 2327' II ma. 9-5/8' FOC TO MN-80 BUTT 113 -318' CSG, 72#, N-80 BUTT. ID 12.347' H 2692' 6405' 6445' ELM H 5-112" WFD ER PATCH, 0 2880' 9 -518" CSG. 47 MN-80 XO -I 5177' (10/8/07 8 10/19)07) TO SOO.901 RS-95 BUT"/ m I 7843' H5 112° OTS XA SLD SLV, ID I I 7927' H4 -1/2° G SEAL SUB W /WL ENTRY SKRT I (TOP OF 3 -1/7 LNRJH 7927' 7963' 5- BOT PBRASSY I 15- 112° TBG -PC. 17 L -80, .0232 bpf. 0 4 892" 7964' BEHIND IM 7969' 9-5/8°X 5- 112 "BKR SAB PKR ID CT LNR II Minimum ID 2.880" 6403' 7975' D I 5 -112" WFD ER PATCH 4 I 7976' H7 x4- 112 *xO.O I 7965' H4 FLUTED NO-GO SUB. 0 2.991' I 8039' H4 -112° OTfS XN NP. ID= 3 725° I 8104' I- 4- 1/2' ,TAIU BEHIND retILESHOE 0= 3.958° CT LNR I4- 112" TBG -FC. 12.6 L -80, .0152 by ID 3.958' H 8102' 8093' H ELMO TT LOGGED 09/30/80 TOP OF 7" LNR 8235' 8235' H9-5/8' X 7" BOT LNR HGR, 0= I 1 9 -5J8° CSG, 47 RS-95 BUTT, I D 8.681 8541' v v., vt ill NM 8275' HEST TOP OF CEMENT (07/01196 I 'I 4*, 4* 3 -1/7 LNR, 9.3#, L-80 FL4S. .0870 bpf, ID= 2.992" 9000' 9000' 3- 112" DAVIS LYNCH FLOAT SHOE 04 -10 Tubing Patch 5 of 8 I 1 S i 1 6400 1 1 3 TOP OF PATCH f 1. I I i t I i BTM OF PATCHSIGNATURE -7-1 r r r j z! 11 i I r i r 6 500 I I 1 s Snapshot from TecWel LDL dated 14- Nov -09. The patch is a two set patch with a snap latch seal in between the upper and lower packers. 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ElEtiE� �IO -YEE -YEi ■I■ E ►+a- MINEMIEI 6400 YY- um um E.• a WIMIL ali-r7Ea1•Yr'lisailiE� 1_Y- ECaYiriM -Flom Y! 1..- -sia—�r amm .amism East-- Yatr_ -■MEN -tY i� iY- ---E►�-i.1- IMMENI -O■ /.AYtYYMEM Y EEEY--- .ME.ECAII-- E.. -.aE EM _r______. 1_11■IAT�EEEMMI EIMMEEE.M -RaMM l•mm. E� �I \�Y -rr -f/ INEM i i mMEEE -i iEE.- Y �I°`'`''- y■YYY— ailla►.7 Eia ri■YY iY—M —aF —M -E. —EE■ .".....i ia MM I__ 1.■E Y --MIY 411I4E1 Il ■I■ s MMM -ISM :i� :'PMT ��a MEI sM [Yiil.11. Y\�t"'`-'• Ems!'. -M Elm �E:JMIeM -YY-. rnE- YIE■Y l- a�:rrl�El.- EE.EE.EM.l.alli -Mi1Y. gram mg■ ..Mid___ /■■M■M m om= EE■ —Ed. Ea. —aaE,— .a 11 MMMMi --i MIN M .•____M_l is awJ nEmom EE■— a.— li.E1'- �.tiME I a milmomE�IYC —E�11� EEE— Y4111E�— .f1— M MMl E .ai —E1111 MO—NE r M- i_ 7_ ___w EI IIIMMNEEMIMIMMIIIEMEEI w i .i� Y aI M- ltaE. 1 =En -ia EMI Mil MiI� M i I.EIIIII w 04 -10 SWS LDL 05/19/07 04 -10 Tubing Patch 7 of 8 .4+' Client: Address: BP Alaska Lease: OA Field rudhoe Bay d® Parish INeathertor Patch OCS -G Platform: Company Man Ron Doshier Drilling 8 Intervention Well Number: DS 04 -10 Phone 659 -5810 Services Type of Operation: 35' 5 1/2" patch Item C/T to Surface Tool Description Tool O/D Tool 1/D Length Depth Connection Asset No. I Setting Adapter 4.465" on 0.92 255678 1.75' OAL M"' Top of Packer 6404 2 Weatherford 4.530 3.000 4.98 3 1/2 10 rd NU box ER Packer Serial BP 550001 i Release 88004 4.30' Center of Element Setting Depth to TOP of Packer 6408 liMi 3 Spacer Pipe 3.500 2.992 29.10 3 1/2 10 rd NU pin x 3 1/2 NU lOrd pin I 4 ir71' Snap Latch 4.500 2.880 2.72 3 1/2 10 rd NU box Seal Assembly Serial 4 BPS 55003 Release 140004 DRILLING INTERVENTION SERVICES THRU TUBING PACKER INTERVENTION II Total Length of B.H.A. II 11.50 (Meters) II 37.72 (Feet) I B.H.A Prepared by Date Please note that all 0 /D's and I /D's are approximate, and are given as a guideline only (B.H.A. 18) (Run 2 Aaron McDonough 1 Oct PROACTIVE DIAGNOSTIC SERVICES INC. ~iL~ Lei TR.4f~~/T`~.4 To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection[Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ~~~ DES ~ ~ 200 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907J 245-8952 1) Leak Detection - WLD 14-Nov 09 04-10 UsC t~~'~~ ~ c9c~ 6 1 BL / EDE 50-029-20213-00 2) I '~ Signed : Date Print Name; PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (9071245-8951 FAx: (9071245-88952 E-MAIL --_----- ~~__ ~~ _d~_' wEBSITE : _ ~ _._~' ~ ° __ C~Docnmenti and Szltings~Diane Williuns\DesktopCPransmit. BP-doc~ NOT OPERABLE: 04-10 (PTD 60420) TxIA Communication • Page 1 of 1 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, November 07, 2009 9:47 PM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; Chivvis, Robert; GPB, EOC Specialists; GPB, Gas Lift Engr Cc: Williams, Carrie Subject: NOT OPERABLE: 04-10 (PTD #1760420) TxIA Communication Attachments: 04-10.pdf; 04-10 TIO Plot.doc All, Well 04-10 (PTD #1760420) has an AA for TxIA communication while on water injection. However, an MITIA failed on 11/06/09 verifying the tubing integrity has been compromised. The well has been reclassified as Not Operable and will be shut-in as soon as it can be freeze protected. The plan forward is as follows: r, ~ ~_ ttt. 1. Pumping: MIT-IA to 3000 psi -FAILED "~>~~~ u ~°' ~`~ r~ °' 2. DHD: Est LLR 3. Eline: Eval for leak detect log A wellbore schematic and TIO plot have been included for reference. «04-10.pdf» «04-10 TIO Plot.doc» Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 S~C ~~ ~sf'c~ 4/26/2010 a,DDD 3,000 2,000 1,000 04-10 (PTD# 1760420) TIO Plot t ibg -f- IA -a- OA OOA ~ OOOA On 08/08!09 08/15/09 05/221D9 081"l5l09 09/05!09 D9r12/09 09/19/09 09/28/09 10/03!09 10/10!09 lU/17I09 10!24/09 10/31/09 11/D7~09 • Page 1 of 2 Re James B DOA • 99, ( 1 ~ ~ _ ~'~ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, December 11, 2007 1:32 PM ~'? Z To: Regg, James B (DOA) ~e~ ~ ~ Cc: NSU, ADW Well Integrity Engineer Subject: RE: PBU 04-10 Admin Approval Request ~;;~,~,I~~~; ~lf~l~ ~. ~. 2(DfJ~~ Jim, An OA bleed was conducted on 04-10 on 12/08107. T/I/O = 1620/1720/680. Temp = 142 deg. Bleed OA to 300 psi (eval forAA). OA FL,@_surface. Bled OAP from 680 psi to 270 psi into BT in 10 min. Monitored pressures for 30 min. FinaNW~IP's= 1620/1720/270. --_ A monitor the next day found: T/I/0= 1650/1720/270. Temp= Hot. Monitor WHP's (eval for AA). Tubing pressure increased 30 psi. No change in IAP or OAP. The initial conclusion that the OAP increase observed on the TIO plot was due to thermal effects seems to be correct. ~ We will continue to monitor the OAP for several days and will notify the AOGCC if any changes are observed. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Thursday, December 06, 2007 10:03 AM To: 'Regg, James B (DOA)' Cc: NSU, ADW Well Integrity Engineer Subject: RE: PBU 04-10 Admin Approval Request Jim, Please see the attached MIT forms for 11/06!07 and 11315f07. In addition, I have included the service report of the PPPOTs completed on 11125/07. The cover letter has a mistaKe in that the well shows repressurization while on water injection. The v3rell has not be on gas injection in over a year. The TIOs are 170011760/680 psi today. The IA and OA FL are at surface. The plot indicates that the OA pressure inoreased when the well was brought on-line, but has been stabile since 11120107. it appears that the OA was undergoing annular fluid expansion. Please call with any questions or concerns. ~ D ~cM~'r~~~ (.t~~ i ,~~ ~'~~ ..1,~L~'~~z~ ~ ~ ~/lC~c'r Thank yore, n p y'M~;~`K~ " ~E'S ~~~ ~(~ ~ ~- - ~ ~ (''BLS Andrea Hughes -'leilC~r ~rt~~ ,~.s cv~~ f~ ~- ~s 12/11/2007 • Page 2 of 2 • From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, December 04, 2007 2:59 PM To: NSU, ADW Well Integrity Engineer Cc: Engel, Harry R Subject: PBU 04-10 Admin Approval Request Missing info and clarification sought - MITs done 11/6/2007 and 11/15/2007; copies should be provided with AA (we have all other referenced MITs on file); - PPPOT tests done 11/25/2007; do you have some documentation for the tests that could be provided? - Dates of gas injection in this well; cover letter says T and IA pressures equalize when on gas injection - Why the sudden increasing OA pressure? Has OA been bled since injection was restarted to see if it re-pressures? Thank you Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 12/11 /2007 • WELL SERVICE REPORT • Page 1 of 1 WELL JOB SCOPE UNIT Ql~-1 ~ ANN-COMM NONE DATE DAILY WORK DAY SUPV 11/25/2007 AC-LDS/POT; AC-PPPOT-IC; AC-PPPOT-T; AC- ~ BILLECI WELLHEAD TESTING COST CODE PLUS KEY PERSON NIGHT SUPV PBD04WL10-I CAM-BILLECI MIN ED DEPTH TTL SIZE 0" OFT 0" 1700!1750/600 Temp Hot PPPOT-T (PASS) PPPOT ~ x IA post PPPOT-T RU 2 HP bleed tools onto THA 0 psi on void, flush void until clean re#urns achieved. Pressured to 5000 psi for 30 ,/ minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bleed void to 0 psi, RD test equipment. Attempt cycle and torque LDS "Standard style" (8) stuck pins will need help getting on them w/ pipe wrench. PPPOT-IC RU 2 HP bleed tools onto 1C test void 500 psi to 0 psi. Pressured to 3500 psi for 30 minute test, 3450/ 15 minutes, ~: 3450/ 30 minutes. Bleed IC void to 0 psi, Rt? test equipment. Attempt cycle and torque LDS "Standard style" (9) stuck pins will need help cletiing on them w/ pike wrench. JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL CAMERON $833 $833 CH2MHILL LABOR $0 $510 WAREHOUSE $0 $486 LITTLE RED PLUS 20 PERCENT $0 $468 V ECO $0 $480 LITTLE RED $0 $2,340 TOTAL FIELD ESTIMATE; $833 $5,117 PACKOFF TEST TESTED BY WELL TYPE AND GEN CONTROL BALANCE Billeci FMC Gen I TUBING HANGER TEST CASING HANGER TEST INIT TEST PORT 0 BLED TO 0 PSI? YES INIT TEST PORT 0 BLED TO 0 PSI? YES PRESS PRESS PRESSURED TO 5,000 LDS TIGHTENED? NO PRESSURED TO 3,500 LDS TIGHTENED? NO 15 MIN 5,000 TORQUE? 15 MIN 3,400 TORQUE? 30 MIN 5,000 PASS? YES 30 MIN 3,400 PASS? YES COMMENTS COMMENTS Casing: 13 6/8" x 20" x 20" 2M x 13 5/8" FMC (1) 3" Mod 75 PPPOT-IC RU 2 HP bleed tools onto IG test void 500 psi to 0 Tubing:l3 5/8" x 13 5/8" (2) 3" Mod 75 psi. Pressured to 3500 psi for 30 minute test, 3450/ 15 SSV: Baker minutes, 3450/ 30 minutes. Bleed 1C void to 0 psi, RD test BPV Protile: 6" CIW J plug equipment. Attempt cycle and torque LDS "Standard style" (9) McEvoy 6" Mod C tree stuck pins will need help getting on them w/pipe wrench. "' AEI tree & W/H equipment 5M except 2M between starting and casing spool ""* PPPOT-T RU 2 HP bleed tools onto THA 0 psi on void, flush void until clean returns achieved, Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bleed void to 0 psi, RD test equipment. Attempt cycle and torque LDS "Standard style" (8} stuck pins will need help getting on them w/pipe wrench. ;/ file://C:1P~•ogram Files\AWGRS\Reports\Repat•t.htm 12/6/2007 C • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov `~ OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay /PBU / DS 04 11 /06/07 Andrea Hughes i ~~ ~~ Packer Depth Pretest Initial 15 Min. 30 Min. Well 04-10 Type Inj. W TVD 7,835' Tubing 1,640 1,640 1,640 1,640 Interval O P.T.D. 1760420 Ty e test P Test psi 2500 Casing 400 2,500 2,480 2,460 P/F F Notes: MIT-IA post-tubing patch. OA 130 220 220 220 Well T e In'. TVD Tubing Interval P.T.D. T e test Test si Casing P/F Notes: OA Well Ty e In'. TVD Tubin Interval P.T.D. T e test Test si Casing P/F Notes: OA Well Ty e In'. TVD Tubing Interval P.T.D. Ty e test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test ~~ INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU 04-10 11-06-07.x1s • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay /PBU / DS 04 11 /15/07 Anna Dube ~~ /0 \~ Packer De th Pretest Initial 15 Min. 30 Min. Well 04-10 T pe In~. W TVD 7,835' Tubing 1,700 1,700 1,700 1,700 Interval O P.T.D. 1760420 Type test P Test si 2500 Casing 1,760 2,500 2,490 2,480 P/F P Notes: MIT-IA post-tubing patch. OA 180 180 180 180 Well Type Inj. TVD Tubing Interval P.T.D. T e test Test psi Casing P/F Notes: OA Well T e In'. TVD Tubing Interval P.T.D. T e test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU 04-10 11-15-07.x1s • MEMORANDUM TO: ~ Jim Regg ~~, ~ /~ ~~ >-~~~ P.I. Supervisor ` ~ T FROM: gab Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November Z1, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 0410 PRUDHOE BAY UNIT 04-10 Src: Inspector NON-CONFIDENTIAL • `~ ~- o~~ Reviewed By: P.I. Suprv ~.~~ Comm Well Name• PRUDHOE BAY UNIT 04-10 Insp Num: mitRCN07 1 1 20075244 Rel Insp Num: ApI Well Number: so-o29-20213-00-0o permit Number: t76-042-0 Inspector Name: Bob Noble Inspection Date• l 1/19/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 04-IO Type Inj. i `r' ~ TVD { 7sss '"' ~ IA i ~7so ~ zsoo ~ za9o ~ za9o p T j n6oazo ~TypeTest ~ SPT ~ Test psi ~ zsoo ~" pA~ s7o 6so ~ s9o 6IO Interval oT~R P/F P ./ Tubing _ I67o ~ I6so i I~zo ~ vzo NOteS: MIT-IA post patch ~~~~~9 ~~~ ~. ~. 2~~7 Wednesday, November 21, 2007 Page I of 1 04-10 (PTD #1760420) UNDE~ALUATION for IA repressurization Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ ~ ~l +~~~ 7 Sent: Tuesday, November 06, 2007 8:59 PM I To: GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GC1/3/FS3}; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Regg, James B (DOA); Maunder, Thomas E (DOA); Chivvis, Robert Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC}; Lau, John, Jack; Julian, Jennifer Y Subject: 04-10 (PTD #1760420) UNDER EVALUATION for IA repressurization Attachments: 04-10.pdf; 04-10 TIO PIot.BMP Hi all, // Well 04-10 (PTD #1760420} has been found to have TxIA communication evidenced by IA repressurization. The well passed a MITIA on 10/20/07 after patching the tubing. The well was placed on injection on 10/31/07. Wellhead pressures were T/I/O equal to 1340/1690/200 on 11/5/07 when the IA pressure was bled to 450 psi and repressured to 1720 psi in 30 minutes. The well has been classified as Under Evaluation. The plan for ward is: 1. WOE: Leave the well on injection ~ ~"'~~- 2. F: MITIA to 2500 psi 3. WIC: If MITIA passes, request an AOGCC AA for TxIA comm. If MITIA fails, shut-in well and evaluate for repair. ~Q1~( rte ~` c~ ~(~ J~~Cic., L~ ~-c.. C~P~ ~t ~~(~7 ~ = ~r~~u C~~r~>fi,~,t,t.~ ~~ l ~ ~C:~ccv1 ~L~ C~-ff~~~s-~cs I 1 i7i2oo7 ~~~ b4-~~ ~~ ! 7 ~ - v4z a,ooo :...:_._. - ..~_.:_.~.... 04-10 TIt3 Plot ,^ . ____ _- _ ....__ ...._.._ ~ Tbg 3,000 -~- IA 2.000 t ~, r:i.~ASP .-a- nn 1,[ -+~ OOA ~ OOOA .] • TRF~ = FMC GFN 1 Ub'ELLHEACJ - F~d1C ACTUATOR= KB. ELEv == AXELSON 52` ~~.. ___~,.,,.,o. KOP = ~~„~_,.,~ 5857' Max Angie. 2S ~ 9154` Datum h~1C7 - DatumTVD= ~9a57` _880a'SS 2€)" CONDUCTOR, 100' 94#, H-40, iD= 19.124„ 3-518" CSG, 47#, SOO-90 / RS-95 XO ~ 2327' TO MN-aa BUTT 13-318" CSG, 72#, N-Sa BUTT, ID = 12.347" 2692" 9-5!8" CSG, 47#, MN-8a X~ 5177` TO 500-90 ! RS-95 BUTT 04-10 SAFETY NOTES: 2225. -j~_1;z„OTES Rca~,h ssSV NtP, tD = a.5a2" 2347" 9-5/s" FOC 2471' 9-51s" Foc 5' ELM I--j 5-112" wFD ER PATCH, 1D = 2.sa0" 11{10181x7 & 10i19107j 7$43° ~-{5-112" OTiS xA SLD SLV, Ct3 = 7 4-112" TBG-PC, 12.6##, L-ax, .0152 6pP, ED = 3.95x" $102' TOP QF 7" LNR $235' 9-5.'8" CSG, 47#, fdS-95 BUTT. ID = 8.681" $541' 7~ 927` ~ --~4-112" G SF1~L SUB W;WL ENTRY SKIRT 7963" 5-1/2" BOTPBRASSY ~EH~~Iti 79$9' 9-5;8"X 6-1 t2"BKR SAB PKR, lD = ? ~.~. L R 797$' 7" MILLOUT EXTENSION, ID = ? 7g76' 7" X 4-112"' XO, 1D = '? 7965` 4-112" FLUTED N0-GO SUB, ID = 2.991„ $$$ 4-112'° 0T1S XN NEP : iD = 3.725" ~'°~~~® $104" 4-1;2" TUBING TAIL! E~IULESHOE ID = 3.958" ~"~R $(}$" ELhItD TT LOGGED a9l30180~ $235` ~ ~ 5'8'° X 7" BOT I_NR HGR, ID = ? $275` ~-j EST TOP OF CEMENT (07{x1196} J 3-1(2" LNR. 9.3#, L-8a FL4S, .a87x bpf; ID = 2.992" I~ 9000° PERFORATION SUt41MARY REF LOG: BHCS 01= 06115;76 ANGLE AT TOP PERF: 22 @ 8837' Note: Refer to Production DB for historical perf data Si7_E SPF fNTEF2LlAL OpniSgz LATE SEE PAGE 2 FOR PERFORATION INFORh•1ATiON 7" LNR; 29#, MN-aa BUTT, .0371 bpf; iD = 4.184" ~ 9149` -rD 9154` 9000' (-f 3-112,. DAVIS LYNCH FLOAT SHOE 903$" ~--~ C;141T PLUG (SET 10131190) DATE REV BY COMIL~IENTS DATE REV BY COMI~•1ENTS 07!2$!75 RC1AlV 25 ClE1iG1 L CtJPLETIt3hI _.....~®mm..~.m_.~ 1Or2307 Rt:iPJC DRAbU{NG C:ORRECTlC 0$!13180 At1 ES Rt3 10!24!4?7 BSE'PJC ._... .._.~_.~ SET UVRD PA"i~GH 07!03!95 P32ES 3-112 CT SCAB LNR 1x;2<,3!07 JLJfTLH PATCH DEPTH CORRE 10f14fx6 COM,'TLH CMTCORRECTIONS(1996;~ 11110!06 JLJITLH `dVRPSET{1111!06] 09.`28!07 F'JC,i RCT PUi..L WRP (ru 8353'i CO}7REC7-lC>NS PRUDHOE BAY UNIi~ `vtiElL: xa-1x F'ER;t9fT No: 17#i-x42x API No: 50-x29-2x213-ax SEC 27, T11 N, R15E 14x3.9 FEL '3959.95 FNL BP Explaration (Alaska} l.. J PERFORATION SUMMARY REF LJG: BNCS JF 66f15/76 ANGLE AT T4P PERF: 22 @ 8£37` ~ Note: Refer to Praduction DB for historical serf data ! SIZE SPF fNTERVAL QpnTSgz GATE 3-1i8" 4 8837 - 8853 S 471D8/90 2-1;'2" 6 8838 - 8852 fl D7'46.?D6 , 3-1,'8" 4 8858 - 8872 S 47?48190 j 2-1i2" 6 8860 - 8866 O D7iD6t46 ~ 2-1I2" 6 8882 - 8896 fl 43?D6146 ~ 3-1!8" 4 8883 - 8397 S 47tD8%9£7 ? ~ 8962 - 8977 5 D7/D8!9(1 ? ~ 8984 - 90'11 S D7?D8i96 ~ 3-3;8" 6 96D7 - 9619 Q D712119f1 ~ 962.5 - 9429 S D71D8(90 3-318" 6 9625 - f~429 Q 48/03190 ? 4 9629 - 944" S D7?D8i9f I ? 4 964(1 - 9644 S D7?{38190 ~ • DATE REV E3Y COMMENTS DATE REV BY COMMENTS 07t2$t76 F2CJWAN 2ii QRfGINAL CC?PL.ET'tQN 14123(07 RC;'PJC DRA~rVtNG CflRRECT4flRS 0$r`13180 td1ES #ilNt7 10;24;'07 BSEfPJC 5E1-1~`t1RDPATCH 07f03t96 I~i2ES 3-112 CT SCAS LNF2 16/29iD7 JLJ.?TLH PATCH DEPTH CORRECTIONS 14,`14;66 CC)~NTLH CNITCORRLCTIC7NS{1996} 11:`14!46 JLJiTLH ~tiR#' SEf {11?4106] 09l28?07 i'JCi RCT PULL U;1RP t~ 8353'! CORRECT({:NS PRUDHC3E BAY UNR" 4A~'ELL: 04-1 D PER~11T Na: 176-042D API No: 50-029-20 2 1 3-40 SEC 27, T11 N, R15G 9443.9 FEL 3959.95 FNm SP Expforatinaa {Alaska) 04-10 STATE OF ALASKA ~~ ~QV ~ ~ ~~~~ ~~ ALA•OIL AND GAS CONSERVATION COM~ION as Cona. Commission ~~ Alaska Otl & G REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ tubing patch Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well [] 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 176-0420 3. Address: P.O. Box 196612 Stratigraphic Service / 6. API Number: Anchorage, AK 99519-6612 50-029-20213-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 52 KB - PBU 04-10 8. Property Designation: 10. Field/Pool(s): ' ADLO-028325 Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 9150 feet Plugs (measured) CMT PLUG 9038' true vertical 8937.45 feet Junk (measured) None Effective Depth measured 9038 feet true vertical 8834 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 30 - 110 30 - 110 1530 520 Production 2299 9-5/8" 47# R-S-95 28 - 2327 28 - 2327 8150 5080 Production 5474 9-5/8" 47# N-80 2327 - 7801 2327 - 7677.61 6870 4760 Production 740 9-5/8" 47# R-S-95 7801 - 8541 7677.61 - 8371.94 8150 5080 Liner 1073 3-1/2" 9.3# L-80 7927 - 9000 7795.61 - 8798.87 10160 10530 Liner 914 7" 29# MN-80 8235 - 9149 8084.84 - 8936.53 8160 7020 Perforation depth: Measured depth: 8838 - 8852 8860 - 8866 8882 - 8896 9007 - 9019 9025 - 9029 True Vertical depth: 8649 - 8662 8669 - 8675 8690 -8703 8805 - 8816 8822 - 8826 Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 27 - 7964 4-1/2" 12.6# L-80 7976 - 8104 7969' Packers and SSSV (type and measured depth) 9-5/8"x5-1/2"" BK S AB R n' r+a~nn ,,yy ~~,, ii~~, ~ ~~;~r"itN~BC~~ 1V~~ ~ ~ LU~~ O 0 0 12. Stimulation or cement squeeze summary: Wk.~l S~ S~r~ Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ~ - ~°~, ~~~If .~a~~ ~~~~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 Subsequent to operation: 0 0 14. Attachments: 15. Well Class after proposed work: copies of Logs and surveys Run Exploratory ~' Development ~I Service ~' Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG GINJ ! WINJ ~' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-319 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 11/2/2007 Form 10-404 Revised 04/2006 i i ~ ~ ~ ~ (~ ~ ~ t ~a'C~ Submit Original Only } '~ ~ • 04-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 10/8/2007 ""'"' DSO4-10i - ELINE SET WEATHERFORD 5.5 PATCH""~"" INITIAL T/I/O: 0/0/0 PSI RIH W/ MH22-PEK-B-AH83-PGGT-D-AH66-CPST-AA- WEATHERFORD ER PACKER SER. BP550008, 4.5" OD 3" ID 4.98" LONG, CCL TO CENTER OF ELEMENT 167" '$ET LOWER PACKER @ 6443 FT MID ELEMENT ;FINAL T/I/O 0/0/0 PSI **"SLICKLINE TO SET UPPER PACKER -JOB INCOMPLETE'`'`* 10/18/2007'"**WELL S/I ON ARRIVAL'`** (patch tubing) R/U SLICKLINE UNIT & 3RD PARTY CRANE ***CONTINUE ON 10-19-07*** _._ - 10/19/2007;"""CONTINUED FROM 10-19-07*"" (patch tubing) =SET 5.5" WFD UPPER PATCH ANCHOR ASSY. (38' OAL) @ 6433' SLM, 6443' ';ELM. f [ - 38' LENGHT OF PATCH = 6395' SLM, 6405' ELM. (TOP OF PATCH ) '***WELL S/I ON DEPARTURE, DSO NOTIFIED'""' 10/19/2007' T/I/0= 1240/0+/5. Temp= SI. IA FL pre-MITIA (eval for patch). IA FL @ 486' (21 bbls). 10/20/2007'; T/I/0=240/0/0 MIT IA PASSED to 2500 psi. (Eval for patch to restore tubing 'integrity) First test - IA pressured up to 2500 psi with 25 bbls neat methanol. IA lost 30 psi in first 15 minutes and 30 psi in second 15 minutes. For a total of 60 psi in 30 :minutes. Bled back --2 bbls to tighten a fitting. Second test - IA pressured up to 2500 psi with 1.7 bbls neat methanol. IA lost 10 psi in first 15 minutes and 0 osi in second 15 minutes. For a total of 10 psi in 30 minutes. Bled back ~2.3 bbls_Tagged :wing, IA valve and notified DSO of results. All other casing valves open to gauges. 'FWell left SI at wing valve. FWHP's=300/0/0 -JOB COMPLETE*** FLUIDS PUMPED BBLS 1 Diesel 1 Total 04-10 (PTD #1760420) UND~EVALUATION for IA repressurization Page 1 of 1 • Maunder, Thomas E (DOA) From: NSU, ADW Wel{ Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com) Sent: Tuesday, November 06, 2007 8:59 PM To: GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GG1f3fFS3}; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Regg, James B (DOA); Maunder, Thomas E (DOA); Chivvis, Robert Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); Lau, John, Jack; Julian, Jennifer Y Subject: 04-10 (PTD #1760420) UNDER EVALUATION for IA repressurization Attachments: 04-10.pdf; 04-10 TIO PIot.BMP Hi all, We1104-10 (PTD #1760420) has been found to have TxIA communication evidenced by IA repressurization. The well passed a MITIA on 10f20f07 after patching the tubing. The well was placed on injection on 10f31/07. Wellhead pressures were T!I/O equal to 1340f1690/200 on 11l5f07 when the fA pressure was bled to 450 psi and repressured to 1720 psi in 30 minutes. The well has been classified as Under Evaluation. The plan for ward is: 1. WOE: Leave the well on injection 2. F: MITIA to 2500 psi 3. WIC: If MITIA passes, request an AOGCC AA far Tx1A comm. If MITIA fails, shut-in well and evaluate for repair. A wellbore schematic and TIO plot have been included for reference. «04-10.pdf» «04_10 TIO PIot.BMP» Please call with any questions. Thank you, Anna ~u6e, ~ E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 11/8/2007 ~4,~4D 3,~D ~,~~ ~~ ~~ ~I~~~ t,~OD ~~ry-~ ~~-~~ TNT ~~at E:x"~' ,~=:~r "~~J~G~T 9~ I ~U~~ f CV~J~~:Q~ 1 ~'2''~~'~,:~T l i ~l~ 119~1l~O:iT + 1~~ -E-I~ f ~~~: • 04-10 (PTD #1760420) Recl~~ed as Operable Page 1 of 1 • Maunder, Thomas E (QQAj From: NSU, ADW Wetl Integrity Engineer [NSUADWWelllntegrityEngineer@BP.com} Sent: Monday, October 22, 2007 12:30 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2lCOTU OTL; GPB, FS2 DS Ops Lead; Fleckenstein, Robert J (DOA); GPB, Wells Opt Eng; Chivvis, Robert; Engel, Harry R Cc: NSU, ADW Welf Operations Supervisor, NSU, ADW Well Integrity Engineer; NSU, ADW Wt Tech Subject: 04-10 (PTD #1760420} Reclassified as Operable Attachments: MIT PBU 04-10 10-20-07.x1s All, Well 04-10 (PTD #1760420) passed an MITIA to 2500 psi post-tubing patch on 10!20/07. The passing MITIA verified a competent patch set which mitigated the TxIA communication. The well has been reclassified as Operable. The plan forward is as follows: 1. E: Patch tubing -DONE 2. F: MITIA to 2500 psi -PASSED 3. WICNVOE: Put on produced water injection 4. F: AOGCC MITIA Please notify Well Integrity if any indication of TxIA communication still exists. In addition, be cautious of annutar fluid expansion in the IA when bringing the well on-line. «MIT PBU 04-1010-20-07.x1s» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 11 /8/2007 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton Aubert~adminstate.ak.us; Bob Fleckenstein~adminstate.ak.us; Jim Regg~adminslate.ak.us; Tom Maunder~adminstate.ak.us OPERATOR: 8P Expkxatron (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay / PBU / DS 04 ~ ,~ D I G DATE: 10YLQ/Q7 ~ ~ "~ OPERATOR REP: Andres Hughes AOGCC REP: Packer Depth. Pretest kt~iat t5 tdkit. 30 tJbn. Well 0410 T In'. N TVD 7830 T 240 300 300 300 Interval O P.T.D. 1760420 Type test P Test psi 2500 O 2500 2470 2440 P/F P Notes: MITIA post tubing patch. QA 0 0 0 0 Well T tnj. TYD Tubeg Interval P.T.D. Type test Test Casirxl p/F Notes: OA Well T Inj. TVD T Interval P.T.D. Type test Test Casing pIF Notes: pA Welt T { '. TVD T Interval P.T.D. Type test Test psi p/F Notes: OA Well T fnj. TVD T friterval P.T.D. Type test Test psi p~ Notes: qp TYPE INJ Codes TYPE TEST Cocks INTERVAL Codes D = Drilling Waste M = Arm tdonhoring I =Initial Test G =Gas P = S~Ward Pressure Test 4 = Faur Year Cycle I =Industrial Wastewater R = Irttemat Ra<fioactaae Tracer Surrey Y =Required by Variance N =Not Injecting A = Ternp~ure Ananaly Survey T =Test during W orkover W =Water D = D~erer~at Temperatwe Test O = Ottrty (describe in notes) MIT Report Form BFL 9/1/05 hMTPBtJ 09-10 t42Q-07.xls 04-10 (PTD # 1760420) Reclassif~as Operable • Page 1 of 1 Regg, James B (DOA) From: Sent: To: Cc: Subject: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Monday, October 22, 2007 12:30 PM Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Fleckenstein, Robert J (DOA); GPB, Wells Opt Eng; Chivvis, Robert; Engel, Harry R NSU, ADW Well Operations Supervisor; NSU, ADW Welf Integrity Engineer; NSU, ADW WI Tech 04-10 (PTD #1760420) Reclassified as Operable Attachments: MIT PBU 04-10 10-20-07.x1s All, ~~~ I~Z~~~~7 Well 04-10 (PTD #1760420) passed an MITIA to 2500 psi post-tubing patch on 10120/07. The passing MITIA verified a competent patch set which mitigated the 7xIA communication. The well has been reclassified as Operable. The plan forward is as follows: 1. E: Patch tubing -DONE 2. F: MITIA to 2500 psi -PASSED ;% 3. WIC/WOE: Put on produced water injection 4. F: AOGCC MITIA Please notify Well Integrity if any indication of TxIA communication still exists. In addition, be cautious of annular fluid expansion in the lA when bringing the well on-line. «MIT PBU 04-10 10-20-07.x1s» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907} 659-5100 x1154 ~~~ NOV 1 ~ 2pQ7 10/30/2007 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. ~ ~~-,1?~~~~`7 FIELD /UNIT /PAD: Prudhoe Bay /PBU / DS 04 ~`~~ Ll o ~~ DATE: 10/20/07 (_ OPERATOR REP: Andrea Hughes AOGCC REP: Packer Dep Pretest Initial 15 Min. 30 Min. Well 04-10 Type Inj. N TVD 7830 Tubing 240 .300 300 300 Interval O P.T.D. 1760420 Type test P Test psi 2500 Casing 0 r 2500 2470 2440 P/F P Notes: MITIA post tubing patch. OA 0 0 0 0 Well Ty e Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval . P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In}. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Weli Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPEINJ Codes D =Drilling Waste G=Gas l =industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I = Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9!1/05 2007-1020_MI7 PBU 04-10.x1s · . ~~~~Œ (ID~ t%~t%~æ~ / / I AIfASIi.& OIL AlQ) GAS / CONSBRVATlON COMMISSION / SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Chivvis Production Engineer BP Exploration Alaska, Inc. PO Box 196612 S&,;ANNED NOV {} 1 2001 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 04-10 Sundry Number: 307 -319 Dear Mr. Chivvis: 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 me 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. DATED this vi day of October, 2007 Enc!. ~ 1~ cL(9 D75 /o/~7' eft l()/(?¡'o'1 ...~..., RECEIVED '.1 STATE OF ALASKA a.;.I9-t'rl~ ALASKA OIL AND GAS CONSERVATION COM~SION U;~( OCT 1 7 2007 APPLICATION FOR SUNDRY APPROVAl k· !'> OtiJ~o. G C C .. 20 AAC 25.280 -JmS. or as ons. oml11lSSIOn Operational shutdown Wai Grage Other " Plug Perforations 0 Stimulate 0 Time Extension 0 Tubing Patch Perforate New Pool 0 Re-enter Suspended Well 0 4. Current Well Class: 5. Permit to Drill Number: 1. Type of Request: Abandon Alter casing 0 Change approved program 0 2. Operator Name: Suspend Repair well 0 Pull Tubing 0 Development 0 o 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Stratigraphic 8. Well Name and Number: / 11. Total Depth MD (ft): 9150 Casing Conductor Production Production Production Liner Liner Perforation Depth MD (ft): 8838 - 8852 8860 - 8866 9007 - 9019 9025 - 9029 8882 - 8896 Packers and SSSV Type: No o Exploratory 0 176-0420 ' Service ø 6. API Number: 50-029-20213-00-00 ./ PBU 04-10 ADLO-028325 / 10. KB Elevation (ft): 11. Field/Pools(s): 52 KB , Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 8937 ' Effective Depth MD (ft): Effective Depth TVD (ft): 9038 8834 Length Size MD TVD 80 20" 94# H-40 30 11030 2299 9-518" 47# R-S-95 28 2327 28 5474 9-5/8" 47# N-80 2327 7801 2327 740 9-5/8" 47# R-S-95 7801 8541 7677.61 1073 3-1/2" 9.3# L-80 7927 9000 7795.61 914 7" 29# MN-80 8235 9149 8084.84 Perforation Depth TVD (ft): 8649 - 8662 8669 - 8675 8805 - 8816 8822 - 8826 8690 - 8703 5-1/2" Baker SAB Packer 4-1/2" BAKER S-3 PERM 9-5/8" BAKER ZXP Tubing Size: 5-1/2" 17# 4-1/2" 12.6# Anchorage, AK 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 9. Property Designation: Tubing Grade: L-80 L-80 3-1/2" 9.3# LNR-CT Packers and SSSV MD (ft): L-80 7964 9449 9489 o 0 13. Well Class after proposed work: Exploratory 0 Developm ent 0 12. Attachments: DescriDtive Sum mary of Proposal ø Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: Plugs (measured): Junk (measured): CMT PLUG 9038' None Burst Collapse 110 1530 520 2327 8150 5080 7678 6870 4760 8372 8150 5080 8799 10160 10530 8937 8160 7020 Tubing MD (ft): 27 - 7964 7964 - 8102 7927 - 9000 Service ø 10/31/2007 Date: 15. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ ø WDSPL 0 Prepared by l.:>è1ry nt:ule 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Title Signature Phone 564-5412 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 Contact Date Robert Chivvis Production Engineer 10/17/2007 Sundry Number: BOP Test 0 Mechanical Integrity Test ~ Location Clearance 0 Subsequent Form Required: '-' ~ '-\ Other: ",,\\,,~~,,"~\--\\~,....,.-~,~rr~ (\, _ \\ \' A \ _ L\ 7~ cJ .', v.. ,,~\. .( Ù c....-\-~, "'J Cè- <:>..... - \ V'-([ f' s \ú. Y.) ((-- Approved by: RBDMS 8Ft 0 C1 2 4 2007 APPROVED BY THE COMMISSION . ,,;' . bp To: C. Olsen /J. Bixby GPB Well Operations Team Leaders Date: September 11 , 2007 From: Janet Sack! Wells Engineer Bob Chiwis/Production Engineer cc: PBD04WL 1 O-N Subject: 04-10i Tubinq Patch Est.Cost: $70,000 Est. lOR: injector - 200 bopd equivalent lOR Curent Status: Normal inject. rates: Max Deviation: Min. 10: Last Tag TO: Last Downhole Op: Latest H2S value: PWI, Shut in since high IA pressure July 2006 ../ 15,000 bwpd 23° @ 9154' md 2.992", G Seal Sub at 792T md 09/14/06 900T SLM 11/01/06 caliper tubing and set plug at 8353' SLM injector with possible H2S in returns Well 04-1 Oi is an injector with TxlA communication. The well is secured with a WRP set at 8353' SLM. It has a 3-1/2" liner which is cemented at the bottom and extends up into the tubing. A caliper done on 11/01/06 showed the 5-1/2" tubing and 3-1/2" liner to be in good to fair condition with the exception of a 45% penetration at 7832' just above the 5-1/2" sliding sleeve. A CMIT-TxIA passed and a MIT-T failed on 11/08/06. An MIT-IA could not be performed due to the IA casing valve not holding. It appears that they were able to pump at about 0.5 BPM down the tubing while the IA tracked during the failing MIT-T. The IA casing valve was changed out on 12/2/06. On 05/14/07 stud bolt issues were remediated on the well. A LDL run on OS/21/07 found two leaks in the tubing at 6420' and 6435'. The objective of this procedure is to restore tubing integrity by setting a 5-1/2" L-80 patch over both holes. Please call Bob Chiwis at x5412 or 346-1859 hm or Jennifer Julian at x5663, 274-0929 (home) or 240-8037 (cell) with any questions or comments. CC: Well File . . Fullbore (Pre-Patch) 1. CMIT TxlA to 2500 psi. Establish LLR if fails. Slick Line (Pre-Patch) 2. RU SL. Pull WRP from 8353' SLM. 3. Brush and flush patch area. 4. Drift with 5-1/2" Weatherford patch dummy to 7927' SLM (top of liner), at Wireline supeNisor's discretion. Patch Specs 5-1/2" L-80 Weatherford Patch. (Carbon steel recommended for injectors -Please do not use chrome). Use manufacturer's recommended setting procedure. Patch Depth All depths are referenced to 05/19/07 SWS LDL. Patch Setting Depths are 6408'- 6443' ELM Patch Length: 35' from element to element. Relevant Top Depths or Collar locators 42' Joint 6370' ELM 44' Joint 6412' ELM 42' Joint 6456' ELM 42' Joint 6498' ELM Eline Set Patch 5. RU EL. MU Weatherford patch and running tool with GR/CCL. RIH and tie into the sliding sleeve at 7838' MD using 05/19/07 SWS LDL. Log up to setting depth. 6. Set Weatherford patch from 6408'- 6443' ELM (element to element) per manufacturer's recommendations. 7. POOH. 8. RDMO EL. . . Fullbore (Post Patch) 9. MITIA to 2400 psi. Establish LLR if it fails. 10. POI, if MITIA passes. · 04-10 I Si\F8Y /\PTES~ IZtf CONOUCTOR H 10!l' 7927' 4-112' {~ SEAL SW 'l'/ì'WL ENffiY $KIRf 113<,1$' (;$0, 7ZII, L'OO, IP= 1Z,347' 1-" TOP OF 3, 112'" LNR, CT $, IIZ' OOT FBR AS$Y (ÆHfrÐ CT lNR¡ Minimum ID = 2.992" 7927' 4-1/2'1 G SEAlSUS W/LEG g,5I$*X.S,IIZ'ßI\KER:$A$ iPJi(R (SEHNDCT lN~ $, t!Z" X 4, 1 ,12' XO (BlIHtfiOCT lNi!) 5- liZ' TSG,P:;, 17#, L,BO, ,0232 ÞpI, ID" 4,8'~2'" 4, 1/2' FLUTED /\p, GO SI.ß ITOF'OF4'liZ"1BG,PC H 7964' (" 8G33' 4-1IZ" otIS XNNlF' (BEHIND CT LNR¡, 10" 3.725' 4,¡¡::t BOT $HEARûl.IY SUB (BEHIND CT lN~ 4, 1.IZ' TBG,F(';, ¡¡tIl2' 8235' 6541' 8!l98' 4t!Z'1\.!SIf',Q TAIL (ÆHtÐ CT t.NR¡ HElWTTLOGGEDOOI30ÆO (BEHI!Ð CT LNR) HiiRFORi', i10N SLMMABY R:iif LOO:BHCS OF (,16/15/76 AN:jiUiiA T 'lPPÆRF: 22 @ 8831' Nolø:Røfør 10 Froóllc¡bn 08 fot hModcal þ<1tf data SIZE SPF tN/ail/At. QpnlSqz õI\ TE ~118' 4 8831, 8853 S 07/08100 2,1/Z' ¡¡ $838, 8852 G 01¡'()ô!OO :>'1/8' 4 $858, $812 S 011Oô!00 2,1IZ' ¡¡ $000, 800$ 0710$100 .2,1IZ- 6 8002"' 8896 C 0710$100 3,1111' 4 8883, 8897 S 071OIYOO ? 4 8002, 8977 S 0710$1'90 ? 4 $004, 9011 $ 0110$100 :hJi8' 6 9007 * 9019 G 071Z1100 ? 4 9025,9029 S 07iOl',IOO :>'3/8' 6 9025 * 9029 0,,'0;$'00 '{ 49029, 904 ¡ S 07i0!Y9l) '{ 4 9040, 9044 S 071OIYOO 9000' ",1/2'" DAVIS L y~ FlO<\ T SfCE GMT FtUG (S'Ef' 10/%'80) T' LNR, 29#, L*80, ,O,,?1 bpt'.1D - iU54' ID DATE REV iSY OOI\o'l\~ENíS Ot!.2!!i76 O~GlNAL COMPLETION Oa.l1 ::\<'80 LAST WORKOVER 12127ml RN'iP CœRt3::i1ONS 01i1ŒOO tlFR$PJC PERfORATIONS 05.!$01OO IJiM WEUHÐ\ü GOmECi1Ö'>1 01106100 f'W$I'PAG RJ5.PERF$ DATE R818Y OOMI,AENTS 1ŒT4/00 OOMlf'LH CMHXYRR!iiCTIONS (1900) 11/\0100 JWt11.H WRP SET (11/U06) ffi1..Vl-iŒ BAY UNrr VVELL: 04*10 PERMIT t.b: 17&0420 AA 110: 5IH)Z¡¡';W213·{)O sa:: ,;a, n IN, RISE 1403,9 FEl 3959,95 FN. liP Exproratjon (Alaska) . . 04-10 SWS LDL 05/19/07: Please set patch from 6408'- 6443' ELM ·.......__'n·.____..,_,_.,..____,...____..n__,' I I o - ...£ab'e(~~r£1L - 2õõ LiiI õ···· .n.n.........,. .x[I!!'~!'~'~~~!~~~p~I.~,!!,~.1.(~~m... .....n........... :iöi '-. .. -. /' .~- .. r -- L--. .. --....... .. _I : I""'" I ~ ,~J '-- 1--- - -. .-.--. .6300 ~TE r- - --- ,.. ~ .. " ;> , , , , , , , , : , , , , : -- I -r--- '--- ..... 1__ '" .- ""',' - "- f--- --. -:--- --., - 'r-- I / ./ ""'"'- "> ../ - .. , .. , -- , t , , --- ~L -- --' , -f- f-- - - , ~ , , I: , , , , , I , , , , I , -- , , -- L - ~ , - ("' P FL ............. S)IF . -- -- f-- ..- \ 1 6400 - I . -- " III' .." '" - - - ~ .' - "-" \ -..,- .,- .- , .<¡-.. I-J , :-- ..- <I" .. ," \-- , - II' , . "- , , , '" , /' , , , .. , E- o <__n .. , '. c .... ". - , ..- ...'.,...., .:.~~_--.:: -." - --='-- ~. ---' ~ .---- Well Job# LOti Description Date BL Color CD L5-23 11733320 PRODUCTION PROFILE 04/30107 1 W-38A 11660532 MEM PROD PROFILE 05/02/07 1 Z-38 11660534 MEM PROD PROFILE 05/05/07 1 17-22 11745213 LDL 04/29/07 1 W-19A 11628772 MEM PROD PROFILE 05/07/07 1 Y-24 11630477 LDL 05/08/07 1 16-0SA 11686747 LDL 05/20107 1 G-05 11773110 LDL 05/13/07 1 16-03 11686743 LDL 05/11/07 1 14-07 11637334 PRODUCTION PROFILE 05/08/07 1 V-03 11628770 MEM LDL 04/30/07 1 MPF-91 11628759 MEM TEMP SURVEY 03/09/07 1 MPF-89 11628758 MEM TEMP SURVEY 03/08/07 1 MPS-10A 11638630 INJECTION PROFILE 05/07/07 1 B-34 11594500 INJECTION PROFILE OS/22/07 1 04-10 11594498 LDL 05/19/07 1 B-07 11657125 PRODUCTION PROFILE 05/11/07 1 H-24 11745216 PPROF/GLS 05/02/07 1 04-24 11773112 PRODUCTION LOG 05/19/07 1 C-28A NIA LDL 05/09/07 1 M-07 11630476 LDL 05/07/07 1 P1-14 11745214 INJECTION PROFILE 04/30/07 1 P1-16 11594494 INJECTION PROFILE 05/01/07 1 Schlumberger 1 2007 Alaska Data & Consulting Services 2525 Gambel! Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Commii5::ìiolrt PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. SCANNED JUN .·2 1 20D7 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ( ) -:r (' ___ 1~-'ð:Hd 'ð11-J 06/07/07 NO. 4290 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . . Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ Received by: ~ ---- o/u/~ STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COMMISSION . I\P¿ RECE\VED SEP 2 2 2006 REPORT OF SUNDRY WELL OPERA TI~~QiI & Gas Cons. Commission 1. Operations Performed: Anchorag,e AbandonO Repair WellO Plu¡¡ PerforationsO Stimulate 0 OtherU Alter Casing 0 Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate IKJ Re-enter Suspended WellD 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development 0 ExploratoryD 17R-ß.t20 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceŒl 50-029-20213-00-00 7. KB Elevation (ft): 9. Well Name and Number: 52.00 04-10 8. Property Designation: 10. Field/Pool(s): ADL-028325 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 9150 feet true vertical 8937.0 feet Effective Depth measured 9038 feet true vertical 8834.0 feet Plugs (measured) Junk (measured) CMT Plug @ 9038 (10/31/1990) None Casing CONDUCTOR SURFACE PRODUCTION LINER LINER Length 80 2663 8513 914 1073 Size 20" 94# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# MN-80 3-1/2" 9.3# L-80 MD TVD Burst Collapse 30 - 110 30.0 - 110.0 1530 520 29 - 2692 29.0 - 2692.0 4930 2670 28 - 8541 28.0 - 8372.0 6870 4760 8235 - 9149 8085.0 - 8937.0 8160 7020 7927 - 9000 7796.0 - 8799.0 10160 10530 Perforation depth: Measured depth: 8838-8852,8860-8866,8882-8896,9007-9019,9025.9029 "fr'A· 11I.\"". E'i\ qr.-D 2. '7 2nD5 .~"" . n!'! ¡¡.., ,.;!..! J. ~ True vertical depth: 8649-8662,8669-8675,8690-8703,8805-8816,8822-8826 Tubin¡¡ (size, ¡¡rade, and measured depth): 5-1/2" 17# L-80 @ 27 - 7964 4-1/2" 12.6# L-80 @ 7964 - 8102 3-1/2" 9.3# LNR-CT L-80 @ 7927 - 9000 Packers & SSSV (type & measured depth): 9-5/8" Baker ZXP Packer @ 8998 4-1/2" Baker S-3 Perm PKR @ 9449 9-5/8" Baker ZXP Packer @ 9489 4-1/2" HEX X Nipple @ 2003 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS 8FL SEP 2 () 2006 13 -- Representative Dailv Averaae Production or Injection Data Gas-Mef Water-Bbl Casing Pressure --. 20434 1100 --- 15763 1600 Tubing Pressure 1846 1633 Oil-Bbl Prior to well operation: Subsequent to operation: --- 14. Attachments: ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil 0 GasD DevelopmentO ServiceŒ Copies of Logs and Surveys run _ Daily Report of Well Operations _ WAG 0 GINJD WINJŒ] WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 Sundry Number or N/A if C.O. Exempt: IN/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWay~ R. Schnorr L''f-:. 'JL , .. 1 ~ JI" 11 Form 1 0-404 Revised 4/2004 U K \ ï \ \ \\ J-\ L Title Petroleum Engineer Signature a . Phone 564-5174 Date 9/20/06 . . 04-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/18/2006 TestEvent ---Inj Press, psi: 473 Type: PW Vol: Shut-in 09/15/2006 T/1I0=0/250/0. (Reg Campi). MIT T to 3000 psi. Failed. Tbg has leak into IA. Attempt LLRT. Pressure tracked between tbg & IA. No LLR. CMIT Tx IA to 3000 psi. Failed. Lost 500 psi on tbg & 200 psi on IA in 15 minutes. PT tree to 3000 psi. Tree lost 20 psi in 5 minutes. TTP must leak. Bleed tbg pressure down to 0 psi. FWHP=0/400/0. 09/14/2006 TAGGED BOTTOM W/ 2.75 CENT, S. BAILER @ 9007 SLM, 9016' MD (SHMOO IN BAILER) LOCATED DAVIS FLOAT SHOE @ 8991' SLM (9' CORR. TO MD) SET BB BRIDGE PLUG & PRONG @ 8366' SLM, 8375' MD. WELL ON VAC WHEN SET. ***GIVE WELL BACK TO DSO, LEFT SI*** 09/13/2006 ***WELL S/I ON ARRIVAL *** RUNNING IN HOLE W/ 2' STEM, 2.75 CENT, XO, S. BAILER 07/23/2006 T/I/0=480/850/30, Temp=SI. IA FL (pre-MIT-IA). IA FL @ Surface. 07/14/2006 T/I/0=1600/2050/450. Temp=HoUWell on injection. Bleed lAP < 300 psi, monitor BUR (TxIA comm). IA FL @ surface. Bled lAP to slop trailer for 2 hrs, all fluid (5 bbls), no change in lAP. SI bleed, called DSO to SI injection. TBGP decreased to 1300 psi. Bled lAP from 2050 to 1500 psi in 5 min. TBGP decreased 300 psi & OAP decreased 160 psi. Called WIE, SI monitored for 30 min. lAP decreased 140 psi, TBGP decreased 230 psi. Final WHP's 770/1350/290. 07/06/2006 PERFORATED INTERVALS 8838' - 8852',8860' - 8866', AND 8882' - 8896' USING 2.5" HSD 2506 PJ OMEGA GUNS. ALL SHOTS CONFIRMED DETONATED AFTER POOH. WELL TURNED OVER TO DSO. FINAL T/ I /0 = 1100/350/ 150 PSI. ******* JOB 06/16/2006 ***WELL INJECTING ON ARRIVAL *** (add perf) DRIFT TUBING W/ 12' OF 2.5" DUMMY GUN & SAMPLE BAILER TO 8,995' SLM W/ NO PROBLEMS (TARGET DEPTH 8896' MD). RECOVERED SAMPLE OF SHMOO. ***GIVE WELL BACK TO DSO, LEFT SI*** 03/23/2006 PERFORM INJECTION PROFILE AT INJECTION RATE OF 6900 BWPD, 146 DEG F, 1000 PSIA. LOGGED FROM 8650' - 8950' PERFORMED STOP COUNTS AT 8700',8800', 8857',8875',8930', AND 8950'. FOUND 100% OF FLOW EXITING THROUGH FILL AND BELOW 3-1/2" LINER. FLUIDS PUMPED BBLS 1 Methanol --- PT Surface Equipment 1 Diesel --- PT Surface Equipment 15 Crude 17 TOTAL Page 1 TREE = FMC GEN I SAFETY NOTES: I WELLHEAD = FMC 04-1 0 ACTUATOR = AXELSON KB. ELEV = 52' BF. ELEV = ? KOP= 5857' Max Angle = 23 @ 9154' 2225' -1 5-1/2"OTIS RQM SSSV NIP, ID = 4.562" I Datum MD - 9057' re Datum TVD = 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" I 2692' µ ~I -15-112" OTIS XA SLIDING SL V I 7838' J.L I TOP OF 3-1/2" LNR - CT I 7927' I 7927' -l4-1/2" G SEAL SUB WfWL ENTRY SKIRT I t l 7944' -15-112" BOT PBRASSY (BEl-UND CT LNR) I Minimum ID = 2.992" @ 7927' 4-1/2" G SEALSUB W/LEG 7964' H9-5/8"X5-1/2"BAKER SAB PKR(BB-IIND CT LNR) ~ 2S. I 7964' -15-1/2" x 4-1/2" XO (BEHIND CT LNR) I r::: ~ 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" I 7964' 'f 7964' -14-1/2" FLUTED NO-GO SUB I TOPOF4-1/2"TBG-PC I 7964' r I 8038' -14-1/2" OTIS XN NIP (BB-IIND CT LNR), ID = 3.725" I ,/'l 8101' H4-1I2" BOT SHEA ROUT SUB (BB-IIND CT LNR) I 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 8102' 1/ I 8102' H4-1/2" TUBING TAIL (BEHIND CT LNR) I I I TOP OF 7" LNR 8235' I-- II I I 8093' H ELMD TT LOGGED 09/30/80 I 19-5/8" CSG, 47#, L-80, ID = 8.681" 8541' l ~ ~ 13-1/2" LNR-CT, 9.3#, L-80, ,00870 bpf, ID = 2.992" 8998' ~ [] Ì'-. ÆRFORA TION SUMMARY REF LOG: BHCS OF 06/15/76 I 9000' H 3-1/2" DAVIS LYNCH FLOAT SHOE I ANGLEATTOPÆRF: 22 @ 8837' [] Note: Refer to Production DB for historieal perf data SIZE SPF INTERV A L Opn/Sqz DATE [] 3-1/8" 4 8837 - 8853 S 07/08/90 2-1/2" 6 8838 - 8852 0 07106/06 I 9038' HCMTRUG (SET 10/31/90) I 3-1/8" 4 8858 - 8872 S 07108/90 2-1/2" 6 8860 - 8866 0 07106/06 1 2-1/2" 6 8882 - 8896 0 07/06/06 3-1/8" 4 8883 - 8897 S 07108/90 ? 4 8962 - 8977 S 07/08/90 1 ? 4 8984 - 9011 S 07108/90 3-3/8" 6 9007 - 9019 0 07121/90 ] ? 4 9025 - 9029 S 07108/90 3-3/8" 6 9025 - 9029 0 08/03/90 ? 4 9029 - 9041 S 07108/90 ~I ? 4 9040 - 9044 S 07/08/90 I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 9149' I C!Ð-{ 9154' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 07/28/76 ORIGINAL COMPLETION 07/06/06 TWS/PAG RE-ÆRFS WELL: 04-10 08/13/80 LAST WORKOVER ÆRMIT No: 176-0420 01/22/01 SIS-LG REVISION API No: 50-029,20213-00 12/27/01 RNlTP CORRECTIONS SEC 27, T11N, R15E 1403.9 Fa. 3959.95 FNL 01110/06 DFRlPJC ÆRFORA TIONS 05/30/06 DTM WELLHEAD CORRECTION BP Exploration (Alaska) R.~~~i v L...Ù AUG 0 8 2006 Scblumberger ~.iJaka Oil & Gas Cons. Co~ NO. 3883 Anchorage ., 1~ ' )\' 1[.' ~ l: ,")cl',·fì.P l;'('"' r", 1\)~,:-n " ~ " ':;;: ....", ,J -'i'!ti-Jr'!,;" ,':'...r"..,..,·.'·I. ;.~v eel: ' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 tJI C- 1~-(JL(d- Field: Prudhoe Bay Well Job# Loa DescriDtion Date BL Color CD NK-43 11211388 PROD PROFILr:: vv/ur::r- J 04102/06 1 NK-zzA 10568415 n__. ._FILI: W/OI:t"T 02/26103 1 L4-12 N/A WFULDL 05/09/06 1 L2-21A 10670034 MEM PROD PROFILE 09/20/04 1 13-06A 11217266 INJECTION PROFILE 07/12/06 1 01-17B 11209602 MEM PROD PROFILE 04/27/06 1 09-08 11296705 INJECTION PROFILE 07/21/06 1 09-19 11296704 INJECTION PROFILE 07/20/06 1 09-25 11296703 INJECTION PROFILE 07/19/06 1 04-09 11211398 INJECTION PROFILE 04/28/06 1 04-10 11211380 INJECTION PROFILE 03/23/06 1 17-21 11223104 PROD PROFILE W/DEFT 03/22/06 1 18-03B 11057071 SBHP 12/02/05 1 X-15A 11212877 US IT 07/18/06 1 J-01B 11511430 US IT 07/24/06 1 15-12A 11221595 US IT 07/25/06 1 Z-14B 11217268 USIT 07/29/06 1 S-400 10987564 CH EDIT PDC-GR OF USIT 01/26/06 1 D-03A 11217269 USIT 07/31/06 1 05-28A 11217267 US IT 07/28/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 08/01/06 . . 04-10 (PTD #1760420) ConfIrmed TxIA communication e All, Well 04-10 (PTD #1760420) has been found to have sustained casing pressure on the IA. The IA pressure was 2080 psi on 07/12/06 after bleeding the IA on 07/11/06 to 1200 psi and building 880 overnight. The well will be added to the Monthly Injection Report. The plan forward for this well is as follows: 1. DHD: Bleed lAP, monitor BUR - Confirm TxlA communication 2. WOE: Leave well on-line for diagnostics 3. FB: MITIA to 3000 psi, LLR 4. WIE: Evaluate for secure and LDL A wellbore schematic has been included for reference. Please call if you have any questions. Thank you, Jact W'Ïnsfow for )lnna (])u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 «04-10.pdf» Content-Description: 04-10.pdf 04-10.pd Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 7/13/20063:18 PM TREE" FMC GEN I e _I SAFETY NOTES: I WELLHEAD = FMC 04-1 0 ACTUATOR = AXELSON KB. ELEV = 52' BF. ELEV = ? KOP= 5857' Max Angle = 23 @ 9154' I 2225' H 5-1 /2"OTIS ROM SSSV NIP, 10 = 4.562" Datum MD = 9057' . DatumTVD= 8800' SS - 113-3/8" CSG, 72#, L-80, 10 = 12.347" I 2692' µ ~¡ 7838' H5-1/2" OTIS XA SLIDING SLV I ..!..L ¡TOP OF 3-1/2" LNR - CT I 7927' I I 7927' -14-1/2" G SEAL SUB WIWL ENTRY SKIRT I L J l I 7944' 1-15-1/2" BOTPBRASSY {BEHIND CT LNR) I Minimum 10 = 2.992" @ 7927' 4-1/2" G SEALSUB W/LEG I 7964' H9-5/8"X5-1/2"BAKERSAB PKR(BEHIND CT LNR) ~ X I 7964' -15-1/2" X 4-1/2" XO (BEHIND CTLNR) I r; ~ 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, 10 = 4.892" I 7964' "'f 7964' -14-1/2" FLUTED NO-GO SUB I ¡TOP OF 4-1/2" TBG-PC I 7964' f'" I 8038' 1-14-1/2" OTIS XN NIP (BEHIND CT LNR), 10 = 3.725" ~ 8101' -¡ 4-1 /2" BOT SHEA ROUT SUB (BEHIND CT LNR) I 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" I 8102' 1/ I 8102' -14-1/2" TUBING TAIL (BEHIND CT LNR) I I I TOP OF 7" LNR I 8235' l- I I 8093' H ELMD IT LOGGED 09/30/80 I I 9-5/8" CSG, 47#, L-80, 10 = 8.681" I 8541' l ~ ~ 13-1/2" LNR-CT, 9.3#, L-80, .00870 bpf, 10 = 2.992" I 8998' ~ [] PERFORATION SUMMARY '" I 9000' H3-1/2" DAVIS LYNCH FLOAT SHOE I REF LOG: BHCS OF 06/15/76 [] ANGLE AT TOP PERF: 22 @ 8837' Note: Refer to Production DB for historical perf data StzE SPF INTERV AL Opn/Sqz DATE [] 3-1/8" 4 8837 - 8853 S 07/08/90 2-1/2" 6 8838 - 8852 0 07/06/06 I 9038' HCMTPLUG(SET10/31/90) I 3-1/8" 4 8858 - 8872 S 07/08/90 2-1/2" 6 8860 - 8866 0 07/06/06 ] 2-1/2" 6 8882 - 8896 0 07/06/06 3-1/8" 4 8883 - 8897 S 07/08/90 ] ? 4 8962 - 8977 S 07/08/90 ? 4 8984 - 9011 S 07/08/90 3-3/8" 6 9007 - 9019 0 07/21/90 ] ? 4 9025 - 9029 S 07/08/90 3-3/8" 6 9025 - 9029 0 08/03/90 ? 4 9029 - 9041 S 07/08/90 I ? 4 9040 - 9044 S 07/08/90 I 7" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" 9149' I cmJ-{ 9154' I DATE REV BY COMMENTS DATE REVSY COMMENTS PRUDHOE SA Y UNIT 07/28/76 ORIGINAL COMPLETION 07/06/06 TWS/PAG RE-PERFS WELL: 04-10 08/13/80 LAST WORKOVER PERMIT No: 176-0420 01/22/01 SIS-LG REVISION API No: 50-029-20213-00 12/27/01 RN/TP CORRECTIONS SEC 27, T11N, R15E 1403.9 FEL 3959.95 FNL 01/10/06 DFRlPJC PERFORATIONS 05/30/06 DTM WELLHEAD CORRECTION BP Exploration (Alaska) ~ STATE OF ALASKA a AlA~ Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS RECEIVED ç¡:Q 1 4 ?f\nh 1. Operations Abandon D Repair Well D Plug Perforations D Stimulate D Otherg Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Ti~fa~t~rairUasConS. ComrmsSlon Change Approved Program D Operat. Shutdown D Perforate 0 Re-enter Suspended Welll:t. 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 176-0420 3. Address: P.O. Box 196612 Stratigraphic D Service M 6. API Number: Anchorage, AK 99519-6612 50-029-20213-00-00 7. KB Elevation (ft): 9. Well Name and Number: 52 KB 04-10 8. Property Designation: 10. Field/Pool(s): ADL-028325 Prudhoe Bay Field/ Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 9150 feet Plugs (measured) None true vertical 8937.45 feet Junk (measured) None Effective Depth measured 9038 feet true vertical 8834.02 feet ~tANNE[; f EJ3 1 4 2005 Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 30 - 110 30 - 110 1530 520 Surface 2663 13-3/8" 72# L-80 29 - 2692 29 - 2692 5380 2670 Production 8513 9-5/8" 47# L-80 28 - 8541 28 - 8371.94 6870 4760 Liner 914 7" 29# MN-80 8235 - 9149 8084.84 - 8936.53 8160 7020 Liner 1073 3-1/2" 9.3" L-80 7927 - 9000 7795.61 - 8798.87 10160 10530 Perforation depth: Measured depth: 8838 - 8852 8860 - 8896 9007 - 9019 9025 - 9029 True Vertical depth: 8648.71 - 8661.71 8669.14 - 8702.54 8805.35 - 8816.45 8822 - 8825.7 Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 27 - 7964 4-1/2" 12.6# L-80 7964 - 8102 Packers and SSSV (type and measured depth) 5-1/2" Baker SAB Packer 7964 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft FEB 1 4 2006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 17691 840 1752 Subsequent to operation: 0 0 18613 900 1820 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development Service M Daily Report of Well Operations X 16. Well Status after proposed work: Oil D Gas D WAG GINJ D WINJ M WDSPl D. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal P",'oo Nam, Sh..ma'" V"tal ~~ Title Data Mgmt Engr Phone 564-4424 Date 2/9/2006 Signat~2 , Form 10-404Revised 04/2004 0 RIG I ~J A L Submit Original Only .. e e , 04-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 1/7/2006 PERFORATED WITH GUN #1, INTERVAL = 8882' - 8896'; CCL STOP DEPTH = 8874.75' WHILE RUNNING GUN #2, THE 2" 'FLOW HOSE' FROZE. ATTEMPTED TO BREAK LUBRICATOR OFF WELL HEAD, LIFTED LUBRICATOR AND HAD SMALL LEAK INTO SPILL CONTAINMENT & ONTO WELLHEAD. LEAK WAS REPORTED TO 'NON-EMERGENCY SPILL RESPONSE' & CLEANED UP BY E-LlNE CREW. JOB SHUT DOWN FOR THE NIGHT. ***JOB CONTINUED ON 01-08-06*** 1/8/2006 DAY #2 PERFORATED INTERVAL FROM 8860' TO 8866'; CCL STOP DEPTH = 8852.75'; CCL TO TOP SHOT = 7.25' DURING RIG DOWN, HYDRAULIC HOSE CAME OFF UNDERNEATH CRANE, 41 GAL HYDRAULIC OIL SPILLED ON PAD & INTO SPILL DIKE UNDER CRANE. *** JOB CONTINUED ON 01-09-2006*** 1/9/2006 *** CONTINUED FROM 01/08/2006*** CRANE FIXED BY MECHANICS PRESSURE EQUIPMENT RIGGED DOWN 1/10/2006 PERFORATED INTERVAL 8838' - 8852' CCL STOP DEPTH = 8828.8'; CCL TO TOP SHOT = 9.2' FINAL RUN OF THREE PERFORATING RUNS FLUIDS PUMPED BBLS 3 1 4 I Diesel Meth TOTAL l\'IEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector --;' 7115/L4' "\c-Y1 \Vell Name: PRUDHOE BAY UNIT 04-10 Insp Num: mitCS040711195609 Rellnsp Num: 'Veil 04-10 IT~lpe Inj. N P.T. 1760.[!O TypeTest SPT Interval ~YRTST P/F Packer I Test psi I P TVD State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday Jul) 14. 2004 SlIBJECT: !\1echanlcallntegnry Te,;¡s BP E XPLORA TION I.-\LASK..-\ I TNC 04- ](1 PRUDHOE BAY UNIT 04-10 Src: InspectOr NON-CONFIDENTIAL API 'Veil Number: 50-ù29-2û213-00-úü Permit Number: 176-042-0 Depth 8941 IA OA Tubing Pretest Initial 150 ~490 Rniewed B,,: P.I. Supr\' 5ß2-- Comm Inspector Name: Chuck Scheve Inspection Date: 7/11/2004 15 Min. 30 Min. 45 Min. 60 Min. 2400 2390 1957.5 0 0 0 0 70{l -I~) 700 700 Notes: Pretest pressures observed for 30+ minutes and found stable. Well demonstrated good mechanical integnty. Wednesday. Jul) 14.2004 Page I of I STATE OF ALASKA ALASKA tl AND GAS CONSERVATION CC( IISSION REPORT Or: SUNDRY WELL OPERATIONS 1. Operations performed: OpeCa~ion shut~c, wn Stimulate Alter casing Pull tubing 2. Name of Operator ARCO Alaska~ Inc. Plugging Perforate Repair well~ Other X~ 5. lype of Well 6. Datum of elevation(DF or KB) Development 52' RKB Exploratory .~. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 442' N & 667' W of SE cr Sec. 27, T11N, R15E, UM. At top of productive interval 1153' N & 1329' W of SE cr Sec. 27, T11N, R15E, UM. At effective depth At total depth 1317' N & 1408' W of SE cr Sec. 27, T11N, R15E, UM. 12. Present well condition summary Total depth: measured 9154 feet true vertical 8941 feet Stratigraphic Service X 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-10i 9. Permit number/approval number 76-42 10. APl number 50 - 029-20213 11. Field/Pool Prudhoe Bay Oil Pool Plugs(measured) Fill Tagged @ 9027' MD (7/10/96) feet Effective depth: measured true vertical Casing Length Conductor 80' Surface 2640' Production 8489' Liner 914' Scab Liner 1073' 9027 feet 8824 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 500 Sx PF II 80' 80' 13-3/8" 4900 Sx PF II 2692' 2692' 9-5/8" 750 Sx Cl G & 275 sx PF II 8541' 8372' 7" 250 Sx Cmt 9149' 8372' 3-1/2" 5.5 Bbls LARC ~,'~ ~eer~'~' E IV F.., Perforation depth: measured 9007 - 9019'; 9025 - 9029' JUl. true vertical 8805 - 8816'; 8822 - 8826' Alask~ 0.]1 & (~as Co~s. C~.mmission Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 7964' MD; 4-1/2", 12.6#, L-80, PCT @ 8102' MD. Packers and SSSV (type and measured depth) Otis RQY SSSV @ 2225' MD; Baker SAB Packer @ 7964' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached 14. ORIGINAL Treatment description including volumes used and final pressure Reoresentative Daily Averaae Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation .... 6690 Subsequent to operation .... 10233 15. A~achments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~ Oil Gas ,, Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "'~./.,~. "'~. Form 10-404 Rev 06115/88 Title Engineering Supervisor Service Tubing Pressure 1526 AJB cc: JWP. 1450 Injector Date SUBMIT IN DUPLICATE 4-10i DESCRIPTION OF WORK COMPLETED CT CONYEYED SCAB LINER INSTALLATION FOR PROFILE MODIFICATION 5/26/96: RIH & tagged PBTD at 8885' MD. 6/29/96: MIRU CTU & PT equipment. RIH w/nozzle jetting Seawater to PBTD tagged at 8889' MD. Attempted to jet a fill cleanout, but could not get below 8889' MD. POOH w/nozzle. MU & RIH w/milling BHA. Milled through fill down to 9038' MD while circulating biozan. POOH w/mill. RIH w/nozzle to bottom & pumped 5 bbls of gelled sand slurry to spot an isolation sand plug across the open perforation intervals located at: 9007 - 9019' MD (Z1B/1A) 9025 - 9029' MD (ZIA) Ref Log: BHCS 6/15/76. Tagged settled sand top at 8976' MD, then reversed off top of sand plug to 9002' MD. Made final TOS tag at 9005' MD & POOH w/nozzle. MU & RIH w/CT conveyed 3-1/2" Scab Liner assembly. 6/30/96: Ran Scab Liner to sand top tagged at 8997' MD. Could not locate XN nipple. POOH w/scab liner. Modified No-Go to set liner assembly on 5-1/2 x 4-1/2" XO. RIH w/liner & landed at 8980' MD. Attempted to work liner down for set in XO without success. POOH w/liner. RU SLU. 7/1/96: RIH & tagged XO at 7967' MD & PBTD at 9011' MD. Made dump bailer runs & dumped 150 lbs of 20/40 mesh sand to raise the sand plug to 8996' MD. RDMO SLU. RIH w/liner & landed liner on the 5-1/2" x 4-1/2" XO. Pumped 27 bbls of 15.8 ppg cement & set the liner assembly from 7927' to 9000' MD, to isolate two targeted leaking squeezed thief perforation intervals at: 8835 .- 8852' MD (Z2: Sqzd/leaking) 8857 - 8871' MD (Z2: Sqzd/leaking) Ref Log: BHCS 6/15/76. Displaced cement by liner shoe w/Seawater & squeezed 5.5 bbls of cement behind pipe at 1000 psi maximum squeeze pressure. POOH & WOC. Estimated TOC behind liner at 8275' MD. 7/2/96: RIH w/milling BHA & tagged cement at 8450' MD. & PT liner top at 2000 psi for 10 minutes. Milled cement from liner down to float collar 7/3/96: Continued milling liner cement to the cement/sand interface at 8996' MD while circulating biozan. POOH w/milling BHA to let cement set. ND/NU. Secured well. RDMO CTU. 7/9/96: MIRU CTU & RIH w/milling BHA. Milled out float shoe to 2.85" & circulated out the sand plug w/biozan to 9042' MD to uncover the open perforation intervals (above). POOH w/mill. RD. 7/10/96: RIH & tagged PBTD at 9027' MD. R ~ C ~V ~ ~ jut .... 2.. 3 !996 Placed the well on produced water injection & obtained a valid injection rate. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sher,'ie NO. 1O131 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 4/17/96 Field: Prudhoe Bay Anadrill Anadrill Anadrill Floppy Well Job # Log Description Date BL RF Sepia Survey Program Performance Disk Calculation Letter D.S. 2-26 ~,~. ~7 ~DUAL BURSTTDT-P BC 960406 I 1 , D.S. 4-10 '~:'~ ' ':'~ !INJECTION PROFILE LO 960407 I .. 1 D.S. 5-16A ~ /,~ CEMENT BOND LOG S1960409 I 1 D.S. 6-5 7~~ PRODUC~ON PROFILE 960403 I 1 ~ , p.s. DU LBURSTTDT- BC 0405 ' D.S. 7-15 ~ I ~ DUAL BURST TDT-P ac 9 6 04 0 6 I 1 ID.S. 16-19 ~ ~~ ISTA~CPRESSURESUR 960404 I I .. - S I G N E D: DATE: RECEIVED AI:,-.+.~ (.,il & Gas Cons. Commissi011 Anclt0rage ARCO Alaska. Inc. P.O.Box 100360 Anchorage. Alaska 00510 DATE: 3-12-93 REFERENCE: -42 -49 · ~_'_ %,11-1A ~...~t.~.4-24 ARCO CASED HOLE FINALS 8-4-92 TMD (Boron) 7-3-92 DSN **Corrected** 1-2-93 USIT Color 1-3-93 CBT Color 1-3-93 USIT Color 12-9-91 TMD 1-9-93 Segmented Bond/GR/CCL 1-14-93 Segmented Bond/GR/CCL R~m Run Run Run R~ 1! Please sign and return the attached copy as receipt of d~ta. RECEIVED BY__~_~~T~ Have A Nice Day! Sonya Wallace ATO- 1520 APPROVED___~_____ Trans# 93031 $ch 8ch $ch HI~ Arks Atlas # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL PB WELL FILES R&D # BPX # STATE OF ALASKA, TEXACO RECEIVED MAI~ 1 9,199~t Alaska Oil & Gas Cons. Commission .Anchorage !., Anchorage, Alaska 995~1~ REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS loSST ~V 1:~1-9~ · o DaN l~m 1 J~;~l~ Please sign and return ~e attached copy as receipt of data. # CZNTRAL FILES (CH) # PHILLI~ PB WEI~ ~ R&D #BPX # STATE OF ALASKA TEXACO CBEVRON D&M BOB OCANAB (OH/GCT) # EXXON MARATHON MOBIL * The correct APl# for I-5ST is 50-029-20076-00. /0 P.O.Hox 100360 Anchorage, ~kl,_~lr, 99510 DATE: 5-15-92 2~-~ 4-xo 4.-17 ~z-~ ~1-# ~' ~ o- ~ ~ O~W-~ ~ o -- ~- ~ ~- OWDW~ ~ o-- ~ 80WDW-~W Term wenA ARCO CASED HOLE FINALS 5~92 PDK-~00/C.m/C~ 0~on=} ~ ~, ~' 5-2-92 InJ Prof/Caliper Run 1. f' 5-2-92 InJ Profile Run 1. fi' 4.3o~ Jewelry l~m 1. f' 5-2-92 Prod Profile Run 1. ff' 5-9-92 FDK-100/GR/CCL 0~ax} Rim 1, f' 4-29-92 Prod Profile Run 1. f' 5-3-92 PIT8 l~,n 1. f' 5-1-92 PIT8 Run 1. f' 5~2-92 PITS Rrm 1, ff' 5-8-92 CCI, ~ Run 1, f' Please si~ and return the attached copy as receipt of data. RECEIVED BY Have A Nice Day! Sonya Walkee AT0-1529 - p, ECEIVED MAY 2 1 'S92. APPROVED___~[/'% Commiss!o.Trans# 92101 ~ ' Alaska & Gas Cons. Anchorage # CENTRAL FILES # C, IiEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHIIJAPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO ARCO ALASKA, INC, ~ P,,O, BOX ~(~(~S66~ ' AN(]I"IORA[~I!~. AL.A....I(A . i (:) D A T E · 5 - 6 - 9 ~ REFE]I";:I:"'N[';E' ARCO CA£'li"'D I"lOl_li.'". F:'iNAI...$ i --' 3 () 4-4-9i 2--'t 6 4--i 3"-'9 i S .... i7 4-i s-.gi '1, 4 .... i~,.') 4-..6-.9i - ~ -5; 2(~ 4 .... 22-9i 6 .... i ':~' 4-'8 9i 6....2(.) ,I"'-6-9i 9....4 4 .... i 3....9 i 9"" 9 4 .... 5-' 9 'I JO - Io] 4--:::t .... q - o q ':)"" 4 4 -. ? i ii .... i q .... '~"-'(~i ~,, i i .... 3 4""2""9i ii-4 q .... 3'"9t i2 .... 23 4""6'"'9 i t 2'"'25 4 .... i4-9i · :'(' i 4""2S 3'"3'-9 i i 4-35 4-..S--9 i t '7 '- i 4 '" 3 '" 9 i ~/ JJ,~ T E Pi F' E R A T U R E L !.:.'; A !< D E 'f' IE C 'f' I 0 N i... E: A K I) E T E C T I 0 N :!' N ,J Ii: C: T I 0 N CBI" I- I-., 0 I, ..J C. T' :1: C) N F:' R C) I) LJ C l" I 0 N I... E: A K D E 'f' E C'I' I 0 N I... Iii: A i< I) E'f' E C 'i" I C) N .... )!... I... A R / F:' I!.". R F" [; A M M A / C:- C i... / ...J Iii: W Iii: l.. R Y I... E A I< iT) Iii: T Ii"' C'f' I 0 N L. E A K D E: T E C 1 l C.I N F:' I T ;!'," / I N ,.J E C 'f' I 0 N I N ...J E C 'T' I 0 N I N ,.J Ii"' C T I 0 N F"' R 0 D LJ C; 1' I 0 N COLI_AI:: P R OD U C T I 0 N 'f'EHF'/SF' I N N ii'.'. I':,' RLJN i , "-'-':" C'AMCO F;JUN i , ., CAMCO F;.:I.JN i, i " CAMCO "~' I! '-. -.' RUN i, .., CAMCt] I:;:U N i, 5S" S C I"1 RUN t, 5" CAliCO RLIN i, 5" CAMCO RUN t, 5" ' CAMCO RUN i, 2"&5' CAMCO 5" F;,'UNi, ATI_A$ Rt. JNt, .5" C;AMCO I-::t. JN i , ., CAMCO RLJN t, C;AMCO I:~t. JN t , 5" C.AMCO Rt.J Nt, 5" C A i"J C C) RUN t, 5" C, AMCO RLJN i, 5" CAi~tCO RUN t, .5" C~Ht.,r.] · - : ~¥~ '", .. RLIN i, '.:>" [,~ RUN t, 5' CAMCO FI_E:.A,.%E:. SIGN AND '"" I",E:.TUF(N THE ATTACHED COPY AS F~'.E:C:EEIF:'I' 01::' DATA, I',.ECI:. I VED BY .. . I"IAV[:' A NICF DAY! I) I $ T R I B LJ l' I 0 N · ,,.'"' b !::. N ¥ i',, A !... F I L Iii; S .,,.'"' F' i-.i I I_ L I. F' · ,.'" E:Hlii:VRON PB WEL. L FILE..,' "~' D & M F(& D :,~.'E X T E N ,S' I 0 N. E. X F:' I... 0 R A T I 0 N .,,-'"' B F:'X · ,,.'"' EXXON. -..'"' ,S"Y'ATE OF ALASKA M A R A l' H 0 N T E X A C; 0 '"' MOBIL , T !..I I $ I $ A I) U F:' L I C A T E 0 F-' T FIE I... 0 C; Y 0 LJ A i.. R E A I) Y R E C E I V EL I), E. X C E P l' T H E." A F' I ,* I.S' C*OF;,'I:,'F"CI'Ii..'D, F'LEA,.gE THF<OW '¥1-.11:.:. F'REVIOLJ,~: COPY WITH 'IFHF:' WRONG API:I~ AWAY, STATE OF ALASKA ALASKf'''~ ~ND GAS CONSERVATION C.~<'' .~SION REPORT"' i SUNDRY WELL OPP_.ttATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging ~ Perforate ~ Pull tubing Alter casing, Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 442' N & 667'W of SE cr, Sec. 27, T11N, R15E, UM At top of productive interval 1153' N & 1329' W of SE cr, Sec. 27, T11N, R15E, UM At effective depth At total depth 1317' N & 1408' Wof SE cr, Sec. 27, T11N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well Development Exploratory Stratigraphic Service 9154 feet Plugs(measured) 8941 feet 6. Datum of elevation(DF or KB) 52 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-10i 9. Permit number/approval number 76-42/90-068 10. APl number 50 - 029-20213 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 9064 feet true vertical 8857 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 500 sx PF II 80' 80' Surface 2640' 13-3/8" 4900 sx PF II 2692' 2692' Production 8489' 9-5/8" 750 sx Cl 'G' & 275 sx PF II 8541' 8372' Liner 914' 7" 250 sx 9149' 8936' RE(ZEiV[D Pedoration depth: measured 9007-9019'; 9025-9029 DEC 1 1 true vertical 8805-8816'; 8822-8826' Alaska 0il & Gas Cons. Anchorag~ Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 7964' MD; 4-1/2", 12.6#, L-80, PCT tail @ 8102' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 7964' MD; Otis RQY SSSV @ 2225' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure Reoresentative Daily Aver{~qe Production or Iniectioll Dat~, OiI-Bbl Gas-Mcf Water-Bbl Prior to well operation .... 27538 Casing Pressure .. Tubing Pressure 1688 Subsequent to operation .... 6876 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations -- I Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sig ned '~-~" "'/" ' ~"~-~ Form 10-404 Rev 06/15/88 Service Title Sr. Area Operations Engineer 1237 Injector 585 REK c: J. Gruber, ATO-1478 SH Date SUBMIT IN DUPLICATE DS 4-10i DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE: INJECTION PROFILE MODIFICATION 5124190: Performed a nitrofied fill cleanout w/acrylic polymer to 9064' MD. 616190: RIH w/CT & performed a fill cleanout to 9044' MD. POOH. RD. 6/8190: MIRU CTU & Stimulation equipment. PT equipment to 4000 psi. RIH w/CT and washed perforations at: 8836 - 8852' MD Ref. Log: BHCS 6/15/76. 8857 - 8871' MD 8882 - 8896' MD 8940 - 8955' MD 8962 - 8989' MD 9007 - 9019' MD 9025 - 9029' MD 9040 - 9044' MD Pumped: 10 bbls Xylene, followed by, 60 bbls 12% HCl w/10% Xylene, followed by, 60 bbls 12-3% HCI-HF, followed by, 39 bbls 6% HCl, followed by 125 bbls 2% NH4Cl. Flushed w/Seawater & Meth-Mater. POOH. RD. 6116190: MIRU & PT equipment to 4000 psi. Fluid packed wellbore w/seawater, then performed a CTU cement squeeze. Pumped 97 bbls of acid resistive cement w/mica, to squeeze perforations at: 8836 - 8852' MD Ret Log: BHCS 6/15176. 8857 - 8871' MD 8882 - 8896' MD 8940 - 8955' MD 8962 - 8989' MD 9007 - 9019' MD 9025 - 9029' MD 9040 - 9044' MD Placed 70 bbls of cement behind pipe at 1400 psi maximum squeeze pressure. Contaminated cement with Biozan, & cleaned cement out of wellbore. POOH. RD. 6117190: RIH & tagged bottom at 8992' MD. 6/19190: RIH & w/underreamer & underreamed down to 9027' MD. 6/20~90: RIH & tagged bottom at 9046' MD. 6/21190: RE£EIVrr. D DEC I 1 1990 Alaska Oi) & Gas Cons. Commlss'to~ Performed an Injectivity test that indicated a resqueeze was required. Anchorage DS 4-10i DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE · INJECTION PROFILE MODIFICATION 718190: MIRU & PT equipment to 4000 psi. Fluid packed wellbore w/seawater, then performed a CTU cement resqueeze. Pumped 91 bbls of acid resistive cement, to resqueeze perforations at: 8836 - 8852' MD Ref. Log: BHCS 6/15/76. 8857 - 8871' MD 8882 - 8896' MD 8940 - 8955' MD 8962 - 8989' MD 9007 - 9019' MD 9025 - 9029' MD 9040 - 9044' MD Placed 82 bbls of cement behind pipe at 1850 psi maximum squeeze pressure. Contaminated cement with Biozan, & cleaned cement out of wellbore. POOH. RD. Note: A cement plug (w/top @ 8780' MD) was left in the wellbore. 7/13190: RIH & w/underreamer & underreamed cement down to 9040' MD. 711 6~90: Performed a fill cleanout to 9030' MD. 7119/90: Performed an Injectivity test that indicated no resqueeze was required.. 7/21/90: Reperforated: 9007 - 9019' MD Ref. Log: BHCS 6/15/76. 7~27~90: Performed a fill cleanout from 9024 to 9040' MD for reperforations. 8/3/90: Reperforated: 9025 - 9029' MD Ref. Log: BHCS 6/15/76. 10/29/90: RIH & w/underreamer & underreamed fill down to 9040' MD. Returned well to seawater injection, and obtained a valid injection test. RECEIVED Alaska 08 & Gas Cons. Co.m.m. issiOn Anchorage ARCO ALASKA, INC. F'.O. BOX iSG3&8 ANCHORAGE, ALASKA DATE' t8-29-98 REFERENCE' ARCO CASED HOLE FINALS 2-4 9-29-98 F'RODUCTION PROFILE RUN t, 5" 2-t3 9-26-98 F'ITS RUN i, 5" 2-t4 9-28-98 PRODUCTION PROFILE RUN t, 5 · 3-27 9-27-9G SF'INNER/TEMP' RUN 1, 5" 4-6 9-28-98 INJECTION PROFILE RUN i 4-~8 9-38-98 INJECTION PROFILE RUN t, 5" 6-28 9-29--9G LEAK I)ETECTION RUN 7-23 ~ 8-~ -98 F'ITS/HPFM RUN 9-3 9-28-98 LEAK DETECTION RUN 9-38 9-28-9e INJECTION F'ROFiLE RUN ~, 5" ~--~9-'~-~~m~~~,~ ~oN F:'LEA,S'Ei] SIGN AND I:;:E'I'URN ~i~1~ i~'~'~.iD coPY A,S' I:;:ECEIF'T OF' DATA, ~ ~ ~.,-" .T. v E ~ ~ Y ~' HAVE] A ,S'AL.L.Y I-I0 F'F'ECI(Ei:;,' APPROVED ATO-~ 529 TRAN£'-~ 9('Ir4i CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DISTRIBUTION '"' CENTRAl_ I:' Ii_ES ~ F'HILL. IF'S "il' '.,I:CHEVRON F'B WELL F]:i_FS g & M !;,' & D .~ EXTENSION EXF'I_ORATION .~' BPX .il. ,~ EXXON .·-" STATE OF ALASKA MARATHON I:EXACO ' MOBIL F',O, BOX i O(~3&(~ ANCHORAGE, ALASKA DATE' 9-~ 3-9(~ REFERENCE' ARCO CASED HOLE FINALS J -j ~ 8-i ~-90 F'ERF' REC'ORD RUN 4-4 7-Ji-gc, F'ERF RECORD RUN i, 4-i~-) 7-'"~-'~'.~.. , ~ GAMMA CORR, W/ F'ERF RECORD RUN 4-~ (~ 8-3-9C, F'ERF RECORD F~UN ..-5 t t 8-i8-9(-) F'IT$ RLJN i, 6-~"¢ r ~ .e PERF RECORD RUN J., 7--3 7-3i--9(:) F'ERF RUN t , '7-9 7-3~-~e F'ERF RECORD .I~UN -, 7-- t 3 8- i 9-'9e F' I TS RUN 7-34 7-22--9~3 PERF REt. OkD RUN i , 9-4J 8-t 5-9~ GR/COLLAR RUN t , i~-4 8-8-9e F'RODUCTION PROF'ILE * RUN ~, t J--28 8-i 8-98 COLLAR RUN i , ~2-ti 7-25-9~ F'ERF RECORD RUN ~, t 3-7 8-i 5-9~ F'IT$ RiJN i , ~ 3-7 8-~ 7-9~ PITS RUN ~ , ~ 3-~ 2 8-t 6-9e F'RE-FRAC TEMF' RUN ~ , ~ 4-3 8-2e-ge COLLAR RUN ~, i6-7 8-t7-9Q PRODUCTION PROFILE RUN ~6.-2e 8-JS-9e F'RODUCTION PROFILE RUN t, i6-22 7-6-90 GA~A CdL. L.~R/FEEF RECDRD RU~ -, PLEASE SIGN AND RETUF;,'N THE ATTACHED COPY AS RECEIPT OF DA'FA~ RECEIYED BY ~._._~ ....... .. .IV O. £AL_I_Y i-iOF'FECK ER ATO-i 529 SEP 19 Oil & Gas Cons. Anchorage AF:'F'ROVED ~~~/ I'RAN$~ 9 DISTRIBUTION CENTRAL FILE£ CHEVRON D &M EXTEN,~ION EXPLORATION EXXON MARATFION MOBIL ,,'"' PHILLIPS F'B WELL. FILES R&ID -~ BF'X STATE OF- ALASKA TEXACO .~.' .,,:. ..:. 5" .,.' .5' 5' 5" 5" HL2 H L 6," CAMCO J..,I ! I i I.. H I_.'b" CAMCO HL.,'~ CAMCO CAMCO CAMCO I-tL,~' CAMCO CAMCO CAMCO CAMCO ,AMCO CAMCO * THE-' CORRECTED AF'I.,'~ FOR i-.t8 I~' 50-,S, 29-2(~i69. ARCO ALASKA, INC. P.O. BOX tOG~6G ANCHORAGE, ALASKA REFEREN_.E ARCO CA£ED HOLE F'INALS' t-'5 6-5-90 PRODUCI"ION PROFILE RUN t, 5" 1-t ~n &-f'?-gG COI_.i_AR RUN t , 5' 4-i 6-i 5-9(:) CCL. RLJN t , 5" 4-t ,:.") 6-t i -9(.') I:;/I;: £URYEY i:;;I. JN i , 5 ' .5:-5 6-t6--90 COLLAR RUN i , 5" 5-t 8 6-t o-ge DUAL BUR;,k"'I' I'DT'--F' RUN 6-2,r-,, 6-tt-90 DLIAL BUR,.gT TDi'-F' r.;tUN 7-25 6--t ~--':?G DUAl_ BURST 'I'D'I'-P RUN t '2-t 7 ..-5-..t 5-90 CC)L.L. AR RUN t , 5:" t ~..-t 2 5-~'~t-gr.j LEAK DETECT.ION '5'URVEY '" RUN iS.-3.S 6-6-90 PUMP-IN TEMP F'LOW RUN C A M C 0 A"I" I_ A ~;' A 'FI...A ~; C A M C 0 A'FL.A~;' .'-':,' C i-~ ~'CH AT'L.A ~'' CAMCO CAMCO PL. EA,.~E ,DIGN AND RE'I,URN 'I,HE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY HAVE A NICE DAY! ,DAL. L.Y HOF'FECKER AI'O-t 529 .. JUN ~ T 1990 Alask~ Oil & Gas Cons. commission Anchorage DISTRIBUTION ~ CEN'I'RAI.. FILE£ ~,.'"' CI..IEVI:;:O N D & M ~ EXTENSION EXPLORATION 'Ir ~.Ir EXXON MARATHON ~.Ir MOBIL · . PHILLIPS PB WELL FI R & D ~ BF'X .Ir $'I,A'T'E OF ALASKA TEXACO ARCO AL.A~'KA, INC. F'.O. BOX tGG36G ANCHORAGE, ALA3'KA 995i0 DATE' 6/t~/9G REFERENCE' ARCO CASED HOLE FINALS 2-t 5-23-90 F'RODUCTION PROFILE RUN 2-'2i 5-2S-9(') F'RODUCTION PROFILE RUN t, 2-28 5-28-~ TEMPERATURE ~URVEY RUN i 4-iG 5-26-90 INJECTION PROFILE RUN 4'-S" 5-2'7-'?~ TEMPERATURE LOG RUN t ii-7 5-'26-9G INJECTION PROFILE RUN i, 5' i i - i 6 ':~- ''~ '~ , ~ ~-90 F'I:~ODUCI'ION F'ROFILE RUN t tt-t'7 5-22-~0 F'RODUCTION FROFII_E RUN t 2-~ 5-25-90 COLLAR RUN CAMCO CAM(](] C A M C CAMCO C A M C 0 C A M C 0 C A M C 0 C A ~ C 0 CAMCO PI_EASE SIGN AND RETURN THE A'IFTACH'~D COF'Y AS RECEIPT OF DATA. RFCEI VI-':D BY ....... _~ HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 ~ CENTRAL FILES ~" CHEVRON D & M -"' EXTF. EN~' I ON EXPLORATION ~I° , .11, · ~ EXXON MARATHON ~ MOBIl_ 'Ii' ~,- PHIi_LIF'S' ,.. PB WELL FILE,S' ,ii, ~. BF:'X STA';'E OF ALAS'KA TEXACO ARCO Alaska, In~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 10, 1990 Mr. John Boyle Alaska Oil and Gas Consen~ation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear John: Please cancel the following 14 Forms 403 for which no Forms 404 were written. Per the drill-site engineers, this work has not been done and is no longer planned. D.S, Abbr. # Date Sianed . . 1987 3-4 7-51 1/26/87 4-6 7-263 4/20/87 4-10 7-188 3/20/87 4-10 7-238 4/8/87 4-14 7-264 4/20/87 5-8 7-624 9/23/87 9-16 7-291 4/27/87 14-13 7-399 6/18/87 14-30 7-100 2/13/87 16-24 7-117 2/26/87 1988 3-9 8-826 11/2/88 3-13 8-8,.54 11/17/88 6-13 8-316 4/28/88 9-34 8-864 11/21/88 Please call me at 263-4310 if you have any questions concerning these Sundries. S. T. H,~'feck Recc~'ds Pr¢~/e~sso r STH/ab/034 cc: J.L. Glaeser - ATO 1528 ~ RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichtieldCompany APR 1 8 1990 ARCO Alaska, In~" Prudhoe I~. ~-ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager February 1, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Re: DS 4-10, Permit No. 76-42 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/REK/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 4-10)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany AR3B--6132-C '~'. Type of Request: STATE OF ALASKA ALASI~'"" [.~_,~A.NPiui~i GAS CONSERVATION APPLIC ,-. FOR SUNDRY A'PPROVAES' Abandon , Suspend , Operation shutdown ---- Re-enter suspended well ~ Alter casing~ Repair well Plugging ~ Time extension Stimulate ~ Change approved program Pull tubing Variance P~rforate X Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 442'N & 667' Wof SE cr, Sec. 27, T11N, R15E, UM At top of productive interval 1153' N & 1329' Wof SE cr, Sec. 27, T11N, R15E, UM At effective depth 5. Type of Well Development X Exploratory Stratigraphic Service At total depth 1317' N & 1408' W of SE cr, Sec. 27, T11N, R15E, UM 12. Present well condition summary Total depth: measured 6. Datum of elevation(DF or KB) 52 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-10 9. Permit number 76-42 10. APl number 50 - 029-20213 11. Field/Pool Prudhoe Bay DiI~pQoJ ,.., ;, ,. .~ t,, ..~ ~ ., ,,.. :,., c~V~I,~ 9154 feet Plugs(measured) true vertical 8941 feet '~ '~::" ;.'..'ii ~.". ,~::'~ ~!i~ ',' Effective depth: measured 9064 feet true vertical 8857 feet Junk(measured) ' .~ ..~.i.!i ~;:~,, ,~-~ (~,~"~, iii'.:~::;!?" ~'. ;'.,.. .... Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 500 sx PF II 80' 80' Sudace 2640' 13-3/8" 4900 sx PF II 2692' 2692' Production 8489' 9-5/8" 750 sx Cl 'G'& 275 sx PF II 8541' 8372' Liner 914' 7" 250 sx 9149' 8936" Perforation depth: measured 8836-8852'; 8857-8871'; 8882-8896'; 8940-8955'; 8962-8989'; 9007-9019'; 9025-9029'; 9040-9044' true vertical 8647-8662'; 8666-8679'; 8689-8702'; 8743-8757'; 8765-8789'; 8805-8816'; 8822-8826'; 8836-8839' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 7964' MD; 4-1/2", 12.6~, L-80, PCT tail @ 8102' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 7964' MD; Otis RQY SSSV @ 2225' MD 13. Attachme~-~ts 14. Estimated date for commencing operation February 1990 16. If proposal was verbally approved Name of approver Description summary of proposal ~ I Date approved I Service Detailed operations program ~ BOP sketch x 15. Status of well classification as: Oil ~ Gas ._.. Suspended --_ Injector 17. I herebyAertify that~the foregoing is true and correct to the best of my knowledge. Signed _..._ _ Title Operations Engineering Manager FOR 1~I3MMIR~Ii3N Hill= nNLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- .~"~'~ ORIGINAL SIGNED B~! LONNIE C. ?..,I~,.51TH .~.,..,, ...... C~Y Returned Commissioner Approved by order of the Commissioner Form 10-403 Rev 06/15/88 283 R. E. Krause Approval ,o. ~'~). ~t ~ SUBMIT IN TRIPLICATE Well 4-10i Coiled Tubing Unit Cement Squeeze Project AFE #AP6168 Preliminary Procedure Objective: Perform a CTU cement squeeze to shut off a channel to an Upper Victor injection thief and establish injection into the Lower Romeo. 1. Perform a FCO to establish sufficient rathole below the lowest set of perfs. 2. Perform a Water Injection Profile. 3. Perform a full strength mud acid perforation wash/biocide treatment using the CTU to pump the following: HCL Mud Acid. Ammonium Chloride Water 2500 gallons 2500 gallons 5000 gallons 4. RIH with CT. Pack the well with filtered seawater. 5. Pump 92 bbls of cement followed by 5 bbls of fresh water. Squeeze off the following perforations: Zone Present Ipterval Shot Density 2B 8836-8852 4 SPF 2B 8857-8871 4 SPF 2B 8882-8896 4 SPF 2 8940-8955 4 SPF 2 8962-8989 4 SPF lB 9007-9019 4 SPF 1^ 9025-9029 4 SPF lA 9040-9044 4 SPF 6. Pump 200 bbls of contaminant following the fresh water and dilute the cement in the wellbore. 7. Jet or reverse out the contaminated cement 24 hours later. 8. Reperforate the following interval two weeks later: (Ref: BHCS 2/25/78) Zone Pro.Dosed Interval Shot Density 1 B/1A 9007-901 9 FSD Reperf 1^ 9025-9029 FSD Reperf lA 9040-9044 FSD Reperf 9. Evaluate injectivity into Romeo. Perform Lower Romeo only stimulation/biocide as per attached procedure. 10. Perform injectivity test and possibly an injection profile to evaluate stimulation results. 11. Perforate the following Romeo interval only after satisfactory injection has been established into the previously perforated interval. This interval is not being shot immediately because it would preclude the use of the CTU isolation packer for exclusively stimulating the lower Romeo. (Ref: BHCS 2/25/78) Proposed Interval Shot Density 1B 8976-8989 LSD Reperf 1B *8989-8996 LSD Adperf *Previously approved interval. 12. Perform Injection Profile. Evaluate injectivity into Romeo. 13. Reperforate Upper Romeo and Tango intervals: (Ref: BHCS 2/25/78) Zone Prooosed Interval Shot Derlsity 2 8836-8852 LSD Reperf 2 885 7- 8871 LSD Reperf 2 8882- 8896 LSD Reperf 2 8940-8955 LSD Reperf 2/1 B 8962-8976 LSD Reperf 14. Put the well back on injection. Other well information: Current status: On produced water injection--33 MBWPD at 1785 psig ITP. Expected static bottomhole pressure: 3680 psi at 8800' SS Expected fluid in wellbore at reperforation: seawater. Drill Site 4-10i Lower Romeo Selective Matrix Stimulation ARCO Alaska, Inc. proposes to perform the following stimulation treatment: 1. If fill is above 9044' MD then perform a nitrified FCO. 2. Load the following fluids: a. 3000 gals. of 12% HCl acid with additives. b. 2000 gals. of 6% HC1:1.5% HF with additives c. 2000 gals of 3% HCl with additives d. 2000 gal 5% HOOH (hydrogen peroxide) in 4% NaCl water e. 5000 gals of 2% NaCl f. 2500 gals of 2% NaCI gelled with 50 Ibs/Mgal HEC and 1000 lbs BAF g. 100 bbl Methanol 3. MIRU CTU. Rig up CT with 3" x 7" packer and tubing end Iocator. 4. RIH with CT. Locate tubing tail using the tie-in log. Locate and inflate the packer element at 9000°MD. 5. MIRU transports and pump trucks. 6. Pump the following fluids down the coiled tubing to stimulate the Lower Romeo interval (9007' to 9044'MD): a. 1000 gal 12% HCl with additives to clean the CT b. 1000 gal gelled 2% NaCI with BAF c. 1000 gal 2% NaCl d. 1000 gal 5% HOOH e. 1 Coiled Tubing Volume (24 or 32 bbl) of 2% NaCl f. Shut down for 3 hours g. 500 gal 2% NaCl with BAF h. 1000 gal 12% HCI with additives i. 1000 gal 6% HC1:1.5% HF with additives j. 1000 gal 3% HCl with additives k 500 gal gelled 2% NaCI with BAF I. 1000 gal 2% NaCl m. 1000 gal 5% HOOH n. 1 Coiled Tubing Volume (24 or 32 bbl) of 2% NaCI o. Shut down for 3 hours p 500 gal gelled 2% NaCl with BAF q. 1000 gal 12% HCI with additives r. 1000 gal 6% HC1:21.5% HF with additives s. 1000 gal 3% HCI with additives t. 2000 gal warm Methanol (75 deg F) to dissolve BAF 7. Release CT packer and POOH 8. RD and release CTU, pump truck and transports Reference Log BHCS 6/15/76 6 5 4 3 2 COILED TUBING UNIT BOP EOU ] PMEN~' 1. SC)00 PSi-?" W£LLH£AD CONNECTOR FLAJ~0£ 2. 5C)00 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSi 4 1/6" SHEAR RAMS S. 5000 PSi 4 1/6" BLIND, RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 2 H]REL ]NE BOP EOU] PHENT 1. 5000 PSI ?" WELLHEAD CONNECTOR Ir. LA~G£ 2. 5000 PSI WIRELIN[ RAIDS (VARIABLE SIZE) 3. SO00 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-Orr ARCO ALASKA, INC. P.O. BOX ~8~8~ ANCHORAGE, ALASKA DATE: REFERENCE: ~8-4 ARCO MAGNEI'IC TAPES W/LIS'rING t2/4-5/88 CH: PDK'-~Oe/DIFF I'EMP 2/26-27/8? CH: CN/M$ (4 F'A$$) JOB~J628 JOBSJ'?3~ PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. ATLAS ATLAS RECEIVED BY .... HAVE A NICE DAY! SALLY HOFFECKER AT0-~529 APPROVED _[~__ Alaska Oil & Gas Cons. ~ Anchorage Commis$ioa DISTRIBUTION CENTRAL FILES (CH) CHEVRON D&H TAMMA$ BROWN (OH) EXXON NARATHON MOB I L PHILLIP~ PB WE[.[. FILES SAPC STATE OF ALASKA TEXACO ARCO ALASKA, INC. ~. P.O. BOX J88368 ~ ANCHORAGE, ALA£KA 995t8 DATE' t -t '7-89 REFERENCE ARCO CA~'ED HOLE FINALS 3-t7 4-7 * 4-t8 5-t6 tt-i t2-2 t2-2t t 2-28 t2-5-88 COLLAR/PERF t 2-9-88 COLLAR/PERF t2/4-5/88 BIF/$IGMA BOREHOLE OVERLAY t 2-~ 2-88 COLLAR/PERF t 2-~ 6-88 COLLAR/PERF ~ 2-~ ~-88 COLLAR/PERF ~ 2-t 2-88 COLLAR/PERF t 2-i 7-88 COLLAR/PERF RUN RUN RUN RUN RUNS RUN RUN RUNS F'LEA$'E SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA, GEAR GEAR ATLAS GEAR GEAR GEAR GEAR GEAR HAVE A NICE DAY! £ALLY I-IOI--I--ECKEI~ ,J~l~l .I. ~ ~l~q ~ ~ .TRAN$ APF:'ROVED _q'.~ ..... DISTRIBUTION '" CENTRAL FILE~' · "" '.- .PHILLIF',S' ~ CHEVRON F'B WELL. FILES D & M R& D ~,~ EXI'EN,~'ION EXPLORATION ~ ' ,SAF'[," '"" ~, EXXON ~ £TATE OF ALASKA MARATHON ~ ~ TEXACO ~ MOBIL * THI~' LOG I$' PRINTED WITH THE WRONG AF'I~; IT ~'HOUI_I) BE ARCO ALASKA, INC. F'.O. BOX i08360 ANCHORAGE, ALASKA 995i8 DATE: REFERENCE' ARCO CASED HOLE FINALS 4--i0 4-t0 4-i0 9-3 i i -~'~ t2-i5 t2/4-5/88 GAMMA RAY RUN t2/4-5/88 PDK-.iOO/GAMMA RAY/CCL RUN t, i2/4-5/88 DIFFERENTIAL TEMP RUN i, 5" i2-24-88 COMF:'LETION RECORD RUN i, ti-9-88 RIC$/RAI'O OVERLAY, CNL/PI)K OVERLAY RUN i2-22-88 COLLAR/PERF RUN 5, 5" PLEASE SIGN AND RETURN THE:' ATTACHED COF'Y AS RECEIPI' OF DATA. RECEIVED BY ....... HAVE A NICE DAY! SALLY HOFFECKER ATO-i52~ 'FRANS APPROVED ................................................ DISTRIBUTION RTL. AS Al'LAS A'T'LA.~' SCIH $CH A l'l_A$ ~ F'HILL. IF'$ CENTRAL FILES ~ CHEVRON F'B WELl_ FILES D&M R&D EXTENSION EXPLORATION ='~ SAPC EXXON ~ ~ STATE [)F ALASKA MARATHON ~ I'EXACO MOBIL ARCO Alaska, Inc.{ Prudhoe Bay ,.ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 3, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 4-10 Permit No. 76-42 Dear Mr. Chatterton: Attached is the "Application for Sundry Approval" detailing work to be performed on the above-referenced well. This is a resubmittal of this application because of a revision in the perforating procedure following the cement squeeze. Additional perforations are requested from 8989-8996' and more intervals will be perforated at limited shot densi- ties. Very truly yours, D. F. Scheve DFS/TAB/jp At t a chment cc: Standard Alaska Production Company P1 (DS 4-10)W1-3 ... , WELLS/53 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASi .... .)IL AND GAS CONSERVATION COM{ ~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension ~ Change approved program ~ Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska, Inc, 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 442' N & 667' W of SE Cr. Sec. 27, TllN, R15E, UM At top of productive interval 1153' N & 1329' W of SE Cr. Sec. 27, TllN, R15E, UM At effective depth l~jtlt~IalNde&ptl~408' W of SE Cr. Sec. 27, TllN, R15E, OM 5. Datum elevation (DF or KB) 52' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 4-10 8. Permit number 76-42 9. APl number 50-- 029-20213 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 9154 feet 8941 feet Plugs (measured) Effective depth: measured true vertical 9064 feet 8857 feet Junk (measured) Casing Length Structural Conductor 80 ' Surface 2692' Intermediate Production 8541 ' Liner 914' Perforation depth: measured Size 20" 13-3/8" 9-5/8" 7" 8836-8852' 8857-8871' 8882-8896' 9040-9044' true vertical 8648-8840 ' Tubing (size, grade and measured depth) 5½" 171; L-80 8102' MD Cemented Measured depth True Vertical depth 500 Sx 80' 80' 4900 Sx 2692' 2692' 750 Sx & 2755 Sx 8541' 8366' 250 Sx 9149-8235' 8936-8066 , 8962-8989' , 8940-8955' , 9007-9019' Packers and SSSV(type and measured d~ Baker SAB Packer @ 7964', Otis @ 2225' , 9025-9029', ,. .. 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation 5/1/87 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 2~,~~ Title Operations Engineering Manager Date Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ~l~etroved Co~y ur,~ed ... ~-,t~:~ _ . , , ~ ,,, , Approved by Form 10-403 Rev 12-1-85 Commissioner I Approval No. =,~ .,- ~J ~ by order of ,.~,'~; f_~'_.. ~,~..' ,~/ the commission Date /~[~ c' WELLS/53 T. A. Billingsley, ATO-1506, 265-6871 Submit in triplicate DS 4-10 PWI REVISED CTU SQUEEZE PROCEDURE AFE #794201 1. Tag PBTD. (Last PBTD was 9031 on 10/31/86.) ® Rig up coiled tubing unit, clean out fill to 9064' and perform biocide treatment. Lowest perf at 9044'. Stop PWI injection until after reperforating following the squeeze. 3. Acid wash perforations concentrating on upper interval 8836-8852'. Ensure well is fluid packed by pumping down 5%" tubing prior to obtaining squeeze pressure. 5. Pump 24 bbls of cement down CTU. 6. Pressure up on squeeze to 5200 BHP and hold for 45 minutes. . GIH contaminating cement to PBTD.. Slowly bleed wellhead pressure while contaminating to leave a minimum of 200 psi differential into the format ion. . WOC a minimum of 12 hours. Reverse out contaminated cement. Freeze protect and leave positive pressure on the well. 9. Wait one week prior to reperforating. 10. Nitrogen lift top 2000' of fluid from tubing for drawdown during perforating. 11. Reperforate Lower Romeo only: (Ref. BHCS 6/15/76) 8976-8996' 4 spf 9007-9019' 4 spf 9025-9029' 4 spf 9040-9044' 4 spf (8989-8996' are add perfs) 12. Evaluate injectivity into Romeo. Perform stimulation if necessary. (Separate AFE.) 13. Reperforate Upper Romeo, Tango and Victor: (Ref. BHCS 6/15/76) 8836-8852' Limited shot density 8857-8871' " 8882-8896' " 8940-8955' " 8962-8976' " 14. Place well on injection. 15. Run post-squeeze injection profile/temperature survey. TAB/92 4 1. 5DOD PSI '7" W£LLHE.A~ CONNECIDR FLANGE ~. 5DOD PSI WIR£LIN£ R&~$ (VARIABLE SI2'E) 3. 5ODD PSI 4 1/6" LUBRICA'I'OR 4. 5000 PSI 4 1/6" FLOW 'I'UB£ PACK-OFF 2 I,IIRELINE BOP EQUIPMENT ii i _ 4 2 1. 5000 PSI ?" WELLH[.A~ CONNECTOR rLANG£ 2. 5000 PSI 4 1/16" PIPE RAI~S 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RA]~IS 5. 5000 PSI 4 1/6" BLIND RAUS 6. 5000 PSI 4 1/16" STUFFING BOX CO ! LEO TttB ]: NG lin ] 1' BOP EGU ! PHENT ARCO Alaska, Inc. ~ Prudhoe Bay P_.ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 19, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 4-10 Permit No. 76-42 Dear Mr. Chatterton: Attached is the "Application for Sundry Approval" detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TAB/jp Attachment cc: Standard Alaska Production Company P1 (DS 4-10)W1-3 RECEIVED MAR 2 0 1987 Alaska 0il & 6s~ Cons. C0mmission · "~", ~-. ~' ,m. WELLS / 53 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany L STATE OF ALASKA A A ,-, OIL AND GAS CONSERVATION CO .._,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other 2. Name of Operator ARCO A]_as~, Tnc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 442' N & 667' W of SE Ct. Sec. 27, TllN, R15E, UM At top ~ productive interval 1153' & 1329' W of SE Cr. Sec. 27, TllN, R15E, UM At effective depth 1Ajtlt~;alNcle~t~408' W of SE Ct. Sec. 27, TllN, R15E, UM 5. Datum elevation (DF or KB) 52' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 4-10 8. Permit number 76-42 9. APl number 50-- 029-20213 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 9154 feet 8941 feet Plugs (measured) Effective depth: measured 9064 feet true vertical 8857 feet Junk (measured) Casing Length Size Structural Conductor 80 ' 20" Surface 2692' 13-3/8" Intermediate Production 8541 ' 9-5/8" Liner 914' 7" Perforation depth: measured Cemented Measured depth WueVerticaldepth 500 Sx 80' 80' 4900 Sx 2692' 2692' 750 Sx & 2755 Sx 8541' 8366' 250 Sx 9149-8235' 8936-8066 , 8940-8955', 8962-8989', 9007-9019', 9025-9029', 9040- RECEIVED AF¢ 2 o 1987 Alaska 0il & Gas Coll~. Commission 8836-8852', 8857-8871', 8882-8896' true vertical 8648-8840 ' Tubing (size, grade and measured depth) 5½", 17#, L-80, 8102' MD B P, ackers and SSSV (type and measured dseb_P~;~) a~:er SAB Packer @ 7964', Otis @ 2225' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch Mt, 13. Estimated date for commencing operation 5/1/87 14. If proposal was verbally approved Name of approver Date approved 15. I hereby ~rtify that the fgregoing is true and correct to the best of my knowledge Signed ~~~~~ Title Operat'lons En§ineerinE Mat,_ag;er Date~;//~ Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance /v~roveCl C~Y ~~~ ~ by order of ... Approved by ~.~ [~J~ ,~, ~1~ Commissioner the commission Date ~ Form 10-403 Rev 12-1-85 WELLS/53 T. A. Billingsley, ATO-1506, 265-6871 Submit in triplicate )044 DS 4-10 PWI CTU SQUEEZE PROCEDURE AFE #794201 1. Tag PBTD. (Last PBTD was 9031 on 10/31/86.) . Rig up coiled tubing unit, clean out fill to 9064' and perform bioc~de treatment. Lowest perf at 9044'. Stop PWI injection until after reperforating following the squeeze. 3. Acid wash perforations concentrating on upper interval 8836-8852'. . Ensure well is fluid packed by pumping down 5~" 2 tubing prior to obtaining squeeze pressure. 5. Pump 24 bbls of cement down CTU. 6. Pressure up on squeeze to 5200 BHP and hold for 45 minutes. . GIH contaminating cement to PBTD. Slowly bleed wellhead pressure while contaminating to leave a minimum of 200 psi differential into the formation. 8~ WOC a minimum of 12 hours. Reverse out contaminated cement. protect and leave positive pressure on the well. Freeze 9. Wait one week prior to reperforating. 10. Nitrogen lift top 2000' of fluid from tubing for drawdown during perforating. 11. Reperforate Romeo only: (Ref. BHCS 6/15/76) 8940-8955' 4 spf 8962-8989' 4 spf 9007-9019' 4 spf 9025-9029' 4 spf 9040-9044' 4 spf 106' total 12. Evaluate injectivity into Romeo. Perform stimulation if necessary. (Separate AFE.) 13. Reperforate Tango and Victor: (Ref. BHCS 6/15/76) 8836-8852' 8857-8871' 8882-8896' Limited shot density 4 spf 4 spf 14. Place well on injection. 15. Run post-squeeze injection profile/temperature survey. AFE2/90 4 3 1. 5000 PSI '7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI YVlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" L UBRICA'I'OR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF 2 ~ I REL ! NE BOP EQU ! PMENT i im SlO~BqO06 REV. F:' "; P,o x i 0(-)S6(') .-. :..~ .,. ... Ant h or.::',g e, A r., ~,.r,::. · N o v e m b e r i 8 i 9 8 6 ;~/.'1 ! I.. .~ R E F' E R I!"' N C E ·A R C 0 C a .s' e,'.:l H o L e F:' i 'n a I. I::' I. e a .s' e s i g n ;:l ¥~ ci r e t: u r n 't h e m .!: -~. a c: h e d c: o p y ;..'~ .s' r e c:: e i p 't' o 'f d a t: a ~ Received By ............................................................................ HAVE A NIClii: I) AY! i::.' o $' a l'l I'~ e I::f e e k ATO-. t 52.9 · ,,. o 6 '? 4 4 'l" R A N S .,,.,., · ..'"' C e n 't r @ I. "" I (. ~'I e v I- r.) I'i D & M · ,,.'"' Exf. en.s'ion Exp Lo;"ai' io'n '"' E x x o l'l '!1' Ha'fa 'thon · "' M, ob i I. '11' D I ,S' T R I Anr~no:?,g~ " '"" L i I:; .s' F:' i I. e '..~~ .~ .','I: F:'I, i I. F:' B¥.,'. ' ,':-.,... L L F:' i L e $ R & I) ,11. · ,,. ,S' o h i o ? . . ' ~ St'a't'e of A l.a.sl,.a ,11, '"' 'T'e x ,.ii ~Z AR[;(] Almm-km, Inc. Anchorage, Alaska DAI'E: September 26, i986 REFERE:NCE: ARCO Cased Hole Final ~ ~-..~8 9-.~8-.86 Step Ra~e Inj, F'rofiLe/GR Ru¥~ ~, 5" Camco ~4-.-~ 9--2~-86 F:'rocluc~ion F'rofi Le Run ~, 5" Camco ~-4"-'? 9-'-~-86 Temp, Log/Inj, F'rofi [e Run ~, 5" Camco ~4-.9 9~.~5-.86 Inj. F'rofi [e R~n J, 5" Cmmc:o ~4-.te 9-..t~-.86 Temp. Log Run t, 5' Cmmco ~4-18 9-.t5-86 In.j. F'rofi Le Run t, 5" Camco ~9-.t2 ?-tl/t2....86 Spinner/I~'~j. F:'rofiLe Run 3, 5" Camco ~-~2 9---~J/~2-86 l'emp, log Run ~, 5' Camc:o ~-..~ 2 9-..~ 5-.86 l'emp. Log Run ~, 5' Camco ~-~? ~-.~-86 Inj. Profi[e Run ~, 5" Camco ~9--'~? ?.-.~--.86 Temp. Log Run ~, 5' Camco ~9-.28 ~-J2-86 In]. ProfiLe Run J, 5' Camc:o ' -2 9-t 4-86 2pinner/Temp, Survey Run t, 5" Camco ~1t t~ 9-.2~/2t-86 2p inner Log Run t, ~' Camco ~t t1 S).-1~/14 86 2pinner/Production F'rofi [e Run 2, ...... . 5 ' C ~ m c: o ~t6--.2 9-t5-86 Te;np, Log Leak De,eot ion Run t, 5" Camco R e c e i v e d B y ......... -'-~'~-'/'~/-'/- [ 'f6SEPF 8 1986 HAVE A NIC~ .......... ~ ~ RI~ O~ & Bas. Cons. ~ummissi0n R o ~ a n n e~:'e e k / ......... ~chorage ~TO.-~ 5~ 'lr'RAN$ ~:86597 DI$1'RIBUI'ION ~ CentraL Fi Les · ,r~''' Chevr o1'! D&H '"' Exien.~ion ExpLora~:ion ~ Exxon Mara 'thon ~' Mob i [ · Ir . ~,." Phi [ [ i ps F'B Well F'i Les R& D · "'~. $oh i o ' State of ALaska T~ Texaco ARCO ALmskm, Inc F'.'~O. Box 100360 A',",chorage, Alaska 99."5 i 0 DATE' Apri I '7, i986 "1 .... i "' · # I:,,EF E.I',,I.".NCE ' ARCO Ca.s'ed HoLe Final. ~D,S' t-2 S .... t9-86 Spinner Run t 5:" ~ D,S' 4.-.'6 'i --Si .... 86 Inj, ,S'p inner l;:un i 5" ~ ](),.~ 4-i (.) 3-.2t .... 86 ~'p inner Run ""~D,S' 4 .... i i ;.~.-..2f'-86 ,S'I:) inner F'(un i '"'~I),:';.' 4-..t 4 3....23...-86 ,S'p inner R~n 'i ~ D,S' 9 .... i 3- i 4.....86 X..-Y Cal. iper F'(un t 5" ~ D,S' i ~ .... 8 3.... 2 (.)...- 86 S I::' i n n e r R u~ n i '5 C a m c o Go C a m c o C a m ¢: o C a m c o Ca mc o Camco TF;,'AN$ :'..':8623 i I) I S T R I B U'l' I 0 N · "' Ce~,tra I. I::'i I.e.s' "" (., h E'**' v I" o I'1 'Ir D &M · ..'"' E x t e n .s i o n E x p I. o r a ~: i o n · "' Iii: x x (.3 n M a r a t h o n ~'. Mc)bi I. · '".,,. F' h i I. LiP ~; F.I.! W~LI. R & D '"' ,S' o h i o '11' :,'J: ,S' i' a 't e o 'f 'q' l' E'> X 8 C 0 '11' F:"i Les' A lam'l<a ARCO Aiazka, Inc. P.O· Box t00360 Anchorage, Alaska DATE: March tt, t986 REFERENCE: ARCO Ca zed HoLe Final ~'DE 3-29 t~-3~-85 TDT ~D$ 4-8 t-3t-86 Spim~er Survey "~ DS 4-t0 2-3-86 Spinner '"\DS 4-2t t2-30-85 ACBL/VDL/$ig/GR DE 6-4 ii-22-84 TDT "~ DE 6-5 t-9-85 ~DE 6-9 t t-3-85 ~'D$ 6-t3 t0-t2-85 DS 6-t3 t0-t2-85 Comp· Record · F'DK 100 CNL Mu [f i-Space Run 5" R~in Run ~ 5 · Run Run t 5;" Run 3 5" Run 2 5" Epi Log LAC Anaty$iz Run 2 5" 9-7 t-23-86 $pinner/GR Run t 5" $ch O'tiz Ca I~lC 0 DA $ch $ch DA DA DA PLeaze zign and return the at~ached copy as receip~ of da~a· Received By, : . _~ ''2 ~__., .. HAVE A NICE DAY! . · Irma CarLin ATO-t42?F TRANE ~8~t96 DISTRIBUTION Central FiLes Chevron D&M Extension Exp [orat io~ Exxon Marathon Mob i [ Phi [Lips F'B WeLL Fi Les Soh i o ~:'~-'~tate, of. ALaska TexaCo I::'.~f')~ Box 'i00~60 Anchorage, AI.a.sk~ 99510 Rli!:I::ERE:NCE' ARCO Ca.sed Hol. e Final..s ...... ., ,:., ~. i n ne'," D~ $ ~ i .... ,' i i .... ~..'"',.,°'"',..,° 4 I) i 'f" f Te m p I... o g · I) ~ ,S', i .... "i" ~" i i .... 28"" 84 C F:'.S' / 3' I::' i n n e r D., ,S;,i .... 26 --"' t t .... i 0..-. 84 C I"1 C N i... I) ~ :'7, :3 .... i 5:---~,.--- i '2 ..... i '7 ...- 84 I::' L.. D,$, 4 iO'/' i2 ..... 16.-..84 ,'.','pinner l..og D~ :S' ~o., .... ~..9 ./' i ~... ''~ .... i,.~ '~ .... ,.,° ..~'~I..'" I... ~,"" D ~"' 9..-.''-' ~/' ,., .... ...,-.. o ~ ..~ ~ ,., i ~.:. i ,., · ,:, 4F:'I... S I) ~ ,'..;', 9.... 4 ~ i '2 .... i 5---. 84 F:' I....S' .~ ,~ ' ' (' '! }':~ I) ,~: 9-.. ~ i ~"'" i 2 .... t 6 -.. 8,.,. I...,S' I)~ ..S' , i S .... ~... ''~ g ~'" i i .-. ~.. ''~ ,., TM .... ,..q .., '~ C. o !. I. o r / F:'e r 'f" L. o g D, ,'.';' ~ t J.; ...- ~..":~ i 'i .... 6 .... 8 '.5 ..~:' i:* i n n e r L. o g D S i :..z,....2ii .... ~- .... q ...... ,., ,:...,. C o I. I. ia r I.. o g I)., ,.,~ ~ i '~-,.., .... ,.,"~ 4 -'-' i i .... o., .... o,...-.,.~ Ii; H Il; N L ~-, ? ..-~ .... ,.~.... q .~ (i; ~ .... I),..,.. ~ i .'.'~. .... i 4 i ~... .,... ,...--~ I::' ,::. / S r.~ inn e r D, ~ ,.,q" ., '~. 4 .... i 6 '~ i i .... ":'~... ~.. .... ,..,° ..~/' Ii.'. F:' .S' / ,'.';' p i n n e r. i)~ ,'..'.,' , I '":.'..., .... 4 / i i .... i (.).-. 84 C I..I C.. N. I... I)~ :S' ~ i '.5.... '7 -' 9 .... ,.,.~. .... ....q ..~/' [;.R .... -"'i 2 .... i CF,?;'/3:p inner I),. 7,.i 6....""' 2-84 ..... D ~' '} 6..-.S'~'~ .... ,., . i .,... ''* 'I' ''~... '::.~ '~ ~') i 'f" f l"e m p I... o g ~. .~ m.;. %,J "'~' ,t. I),....q', i.6 .... i i "" i ,.... ''* .... '~. .... 84 CF'."';'/:';'I:~ inner D ,.? i6 .... ii ." i'".. ~ ~ ,..:.-.i .... 84 Di'l"f 'I'emp I) ~ ,? ,~:l 6 .... i,... ''~ ~' i~.:.": ....,....,... ''~ ''~ .... ...~:l 4 ,? p ~' 'r'~ner l..,::'.,g D2~ i 6'-- i :5 ..... "i '"'....":' ''.~ .... o ..~ "i:.' ' ' '" x.. ,:.. ,:.. ~.~ "~' ,:> I n ri e I" }... o g · ~[:" [ e a s' e .'.r i q ............. I'i .:':1 ~'1 d I" r::...I.- ~.! i" '~'~ .I. h e a t .I. a c: h e ~.:I c o !:.~ y ...'..'~ ..':,' r' ~::. c. e i F:' *,. :3. 'f". e I..[ i"l i .z~:[' ~ ['.. & I'l'l C: 0 Run i 5" [;0 Ru.n i ':~" " .., Run 2.J-'"'"E-. 0.. R u n i...:.':"' ' .I",, g R 1.1 i'1 ":) ':~'" I": ~.~ hi c' ;'~ .~ .... ..' ........ R un i 5" DA Run ~ .....'~:" DA R u n '1..,.~"-'" i.':, g R u n i 5" i) A Run ~ .... 3...~'":'" GO Run ~ 5:" C,.'~m¢:o R ~..t n ~ ..,.':~'" C a m c o Run 2 ..'5" [:;[3 I::: u n i ..,':~'" [; 0 IRun f 5" [;0 Run 2 5:" [;0 I;:un i 15" $c::h R ,~. .... n i ':~'..." (.'; 0 R ti n~ ...,':r ,, [';0 I::.'. ti n i ..:':~'" (1; 0 Ru.n i ,r,, f'; ,,..' .... I::.'. :...'. n i..;.'":' ' C a m c' ,'.:> Run i.,':::"Cam,.'::o Chevron I) & M Explora'~ion Service.s Ex~en:'ion Expl-o'rai'ion Ex xon Getty Ma ra '~ h on ARCO Alaska! ,.. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4245 Donald F. Scheve Regional Operations Engineer November 20, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Re: DS 4-6 (22-3-10-15) Permit No. 76-83 DS 4-8 Permit No. 76-10 DS 4-10 Permit No. 76-42 DS 4-11 Permit No. 78-6 DS 4-14 Permit No. 78-36 DS 4-15 Permit No. 78-37 Dear Mr. Chatterton: Enclosed are the Sundry Notices and Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JB/mjb Enclosure~ cc: SOHIO Alaska Petroleum Co. File P1 (DS 4-6) W4-3 File P1 (DS 4-8) W4-3 File P1 (DS 4-10) W4-3 File P1 (DS 4-11) W4-3 File P1 (DS 4-14) W4-3 File P1 (DS 4-15) W4-3 RECEIVED NOV 2 0 ARCO Alllk·, Inc. I1 · 8ublldlery of AtllntlcRIchfleldCompany STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I--1 COMPLETED WELLZ~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 76-42 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. LocationofWell (Surface) 442' FSL, 667' FEL, Sec. 27, TllN, R15E, UM (Producing Interval) 1153'N & 1329'W of SE cr Sec 27, TllN, R15E, UM (Total Depth) 1317'N & 1408'W of SE cr Sec 27, TllN, R15E, UM 5. Elevationinfeet(indicateKB, DF, etc.) 52' RKB 6. Lease Designation and Serial No. ADL 28325 8. APl Number 50-- 029-20213 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 4-10 11. FieldandPool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [-I Alter Casing [] Perforations Stimulate [] Abandon [] StimuLation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 10/22/84. RU, pressure tested equipment. RIH w/gun $1, shot interval 8882'-8896'MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun $2, shot interval 8857'-8871'MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun $3, shot interval 8836'-8852' MD (4 SPF). Shut-in well, POOH, all shots fired. Secured well, RD. Ref: BHCS 6/15/76 RECEIVED "~' '"'" AlasKa 0ii & ~..,~ ...... 14. I hereby cer~t~fy thatthe foregg~g is true and correct to the best of my knowledge. Signed ~/(/~//~ Title Regional Engineer The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ., ~', STATE OF ALASKA " ALAS , OI- AND GAS CONSERVATION ('. .VllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE J~] Water Injecto~ 2. Name of Operator 7. Permit Number AN30 Alaska, Inc. 76-42 3. Address 8. APl Number P.O. Box 100360, Anc~ge, Alaska 99510 50- 029-20213 4. Location of well at surface 9. Unit or Lease Name ' 442'N & 667'W of SE cr Sec 27, TI/N, R15E, ~ Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1153'N & 1329'W of SE cr Sec 27, TI/N, R15E, ~ DS 4-10 At Total Depth 11. Field and Pool 1317'N & 1408'W of SE cr Sec 27, TI/N, R15E~ [~4 Prudhoe Bay Field 5. Elevation in feet (indicate KB, 'DF, etc.) I 6. Lease Designation and Serial No. P~ Bay Oil Pool 52' RKBI ADL 28325 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 5/6/76 6/15/76 7/28/76I N/A feet MSLI 1 17. TotalDepth(MD+TVD) '8. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set 121. Thickness of Permafrost 9154'~D 8941'TVD 9064' ~D 8857'TVD YES [] x NO [] 2?9.5 feet MD 1900' 22. Type Electric or Other Logs Run DIL; ]~-]~/GR= FDC/Q~E.,/GR; f~T,/VDT,/GR/Ct'T, 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 949Vetco H-40 80' 30" A~ 500 sx PF II 13-3/8" 72~Butt N-80 2692' 17%" 4900 .sx ~~_ II ( r~-_' .9-5/8" 47#Butt ~ 8541' 12%" 750 sx ~]~ G ~ & S-95 2nd Stg. w/275 ~ PF Ii 7" (linez) 8235' 9149 250 sx ' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. 'TUBIN(~' RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) *8836 ' -8852 '. ~D 5~" 8113" 7972' '8857'-8871' ~D with 4 SPF *8882'-8896' [vD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETc. 8940'-8955' FD *e____¢3c%~ 10/22/84. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ' ' 8962 ' -8989' MD 9007 '-9019' MD TVD of Perfs: N/A 9025 ' -9029' MD 8648-8840 , . 9040'-9044' MD , 27. PRODUCTION TEST Date Fir~/~roduction I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE sIZE GAS-OIL RATIO TEST PERIOD ""~=low Tubing Casing Pressure 'CALCULATED '=1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAViTY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA , Brief description of lithology, porosity, fractures, apParent dips and presence of oil, gas or water. Submit core chips. RECE1V D Alaska Oil & 6~s (;Dos. Oorr~m~ssion Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top SaOle~t Base Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH 9050' TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32, I hereby certify that the foregoing is true and correct to the best of my knowledge Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ,' ARCO Alaska, It', Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer October 18, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 4-6 DS 4-8 DS 4-10 DS 4-11 DS 4-14 DS 4-15 Permit No. 76-83 Permit No. 76-10 Permit No. 76-42 Permit No. 78-6 Permit No. 78-36 Permit No. 78-37 Enclosed are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JB/la · Attachments cc: SOHIO Alaska Petroleum Co. File Pi(DS 4-6)W1-3 File PI(DS 4-8)W1-3 File Pi(DS 4-10)W1-3 File Pi(DS 4-11)W1-3 File PI(DS 4-14)W1-3 File Pi(DS 4-15)W1-3 ARCO Ala.ka, Inc. I,, m Sublldlary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASI(' ._ AND GAS CONSERVATION( .MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [~X OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 442' FSL, 667' FEL, Sec. 27, TllN, R15E, UM (Surface) 5. Elevation in feet (indicate KB, DF, etc.) 7. Permit No. 76-42 12. 8. APl Number 50- 029-20213 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 4-10 11. Field and Pool Prud~hoe Bay :Field 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit i.n Duplicate) Perforate X .[] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] [] [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations on DS 4-10 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, .tested to 1.2 times the maximum expected surface pressure.' The SSSV will be installed at the conclusion of the perforating and cleanup operation. Proposed Perforation Intervals: 8836-8852' MD 8857-8871' MD 8882-8896' MD Reference Log: BHCS 6/15/76 w/4 spf Subsequent 'Work Reported on 14. I hereby,egrtify that the foregoin_q.is true and correct to the best of my knowledge. Signed ........ Title Regional Enqineer The space below for Commission use Conditions of APproval, if any: Date Approved by. 'Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc, Post Offic,e .... -x 360 Anchora~ aska 99510 Telephone 907 277 5637 March 19, 1984 Reference: ARCO Cased Hole Finals D.S. 4-1 '/''' 12-5-83 D,S. 4-10 '"" 12-9-83 D.S. 4-11-' 12-5-83 D,S, 4-13-/ 12-9-83 D.S. 5-2'- 1-13-84 'D.S. 6-8~' 12-9-83 D S 6-11/.. 12-21-83 D S 7-15/ 12-18-83 D.S. 9-7~' 12-4-83 D S 9-16~' 2-20-84 D.S. 9-17,/. 12-4-83 D S 14-5~/ 3-4-84 D.S'. 16-1~/ ' 3-9-84 D.S. 16-11,-. 3-10-84 D.S. 16-16-'" 3-10-84 MS/CNL/GR EPL MS/CNL/GR CET Lo§ Collar Log CH CNL CH CNL Perforating Record MS/CNL/GR Collar and Perforating Log MS/CNL/GR Collar & Perforating Log Collar & Perforating Log Collar & PerforatinE Log Collar & Perforating Log Run 1 5" DA Run 1 5" Sch Run 3 5" DA Run 1 5" Sch Run 1 5" Camco Run 2 5" Sch Run 3 5" Sch Run 1 5" Sch Run 1 5" DA Run l&2 5" GO Run 1 5" DA Run 1 5" GO 5" GO R~n 1 5" GO Run 1 5" GO Please' sign and return the attached copy as receipt of data. HAVE A NICE DAY Kelly McFar land ATO-1429F Trans. # 101 DISTRIBUTION Chevron Mobil D&M Mobil E & P Dallas Phillips Drilling Prudhoe Bay Well Files Ext. Exploration R&D Exxon Getty Marathon Carolyn Smith State of ~aski ~ -~ ~~_f, ~,~,. ~ ~'~ ~ala~'ka 0~ & ~.?:~s Cons. . . 6~ ~'.2,~':4=:~C.':& ."~ . ,. ARCO Alaska, Inc. ! Prudhoe Bay 'Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 13, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive · Anchorage, AK 99501 RE: DS 4-10 Permit No. 76-42 Dear Mr. Chatterton: Attached is a Sundry Notice for Prudhoe Bay Unit well DS 4-10, Permit No. 76-42, which has been converted from a producing well to produced water injection service. Sincerely, D. F. Scheve Regional Engineer DFS/MAM/la cc: J. C. Dethlefs J. R. Schuyler Sohio Alaska Petroleum Co. Well File DS 4-10 ARCO Alaska, Inc, is a Subsidiary of AtlanflcRIchfleldCompany STATE OF ALASKA ALASKA{" _ AND GAS CONSERVATION C~I .vllSSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL i-I COMPLETED WEL~ 2. Name of Operator ARCO Alaska, Ina. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 442' FSL, 667' FEL, Sec. 27, TllN, R15E, OM (Surface) 5. Elevation in feet (indicate KB, DF, etc.) 52' RKB 12. I 6. Lease Designation and Serial No. ADL 28325 7. Permit No. 76-42 8. APl Number 50~29-20213 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 4-10 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data OTHER [] NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [~] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] ' Repairs Made [] Other 1~1 Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) . , 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of Starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. has converted Drill Site 4-10 from a producing well to a water injection well. Produced water from Flow Station 2 is being injected into the Sadlerochit reservoir in this well as part of a secondary recovery/pressure maintenance program. 14. I hereby c,,ertify that the foregoing is true and correct to the best of my knowledge. s,,n. Title 'R~c~n~'l The space below for Commission use Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska. Inc. Post Oil,ce ,.T.." ' 360 Anchorage.{ .,-,a 99510 T"eiephone 907 277 5637 October 25, 1983 Reference' Arco Cased Hole Finals D.S. 4-10" 9-19-83 D.S. 4-10 9-30-83 D.S. 4-10 9-30-83 D.S ' 16-11z 7-30-83 D.S. 4-15 ~'~8-6-83 D.S. 4-i5 ~'""8-3-83 D.S. 5-15/ 10-4-83 D.S. 6-24 ~''' 8-7-83 D.S. 14-17 9-11-83 D.S. 14-18 ...... '9-30-83 Perforation & Collar Log Caliper Log Collar Log Diff Temp EPL 'Completion Record Collar Log EPL Temperature Survey Temperature . . Run 5 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run ! Sch Run 1 5" Sch ' Run 1 5" Camco Run 1 Sch Run 1 5" camco Run 1 5" Otis Pleasesign and return the attached copy as .receipt of data. Kelly McFarland ATO-1429F Trans. # 592 'c hey=on D & ~ Dallas Drilling Exxcn Getty Marathon Mobil ,DISTRIBUTION North. Geology phillips ,' Prudhoe Bay R & D Caroline ~m'itk ,~.. ~,~ ,,~, -~,., . ,, . ~,,,..u~ ,, _... _ State o ARCO Alaska, Inc.j' Prudhoe Ba} ,..ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer August 16, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: DS 4-10 Permit No. 76-42 Dear Mr. Chatterton: Enclosed is "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/TDM/la Attachment cc: Sohio Petroleum Well File P100.0 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany " STATE OF ALASKA ALASK~(i ..~.AND GAS CONSERVATION (~' .,MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 442' FSL, 667' FEL, Sec. 27, TllN, R15E, UM (Surface) 5. Elevation in feet (indicate KB, DF, etc.) 52' RKB 6. Lease Designation and Serial No. ADL 28325 12. 7. Permit No. 76-42 8. APl Number S0-029-20213 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 4-10 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to convert Drill Site 4-10 from a producing well to a water injection well. This well will inject produced water from the Flow Station 2 area into the Sadlerochit reservoir as part of a secondary recovery/pressure maintenance program. Work 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~at~. _W_J~_ ~~~ Title Regional ~..ngineer The space below for Commission use Conditions of APproval, if any: Date Approved by BY It~ll~Y iii. ILtll~L[!~,, Approved Copy ~.Returned _ ' ' ..... 22. A"..~ By Order of COMMISSIONER the Commission' Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc~" Post Office'~ 360 Anchorage, AJaska 99510 Telephone S07 277 5637 February 18, 1982 Reference: ARCO PRESSURE DATA D.S.4-10 12/3/81 Pressure Survey (Static) ./~lease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #972 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO' GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Alaska. Inc. is a sul~31nlary ot AH--,nllcRichfie!clCompany ARCO Oil and Gas Company Norlh Alaska" ' trict Post Office ~ ,60 Anchorage. Alaska 99510 Telephone 907 277 5637 Jerry .A. Rochon District Operahons Engineer January 18, 1982 Reference: ARCO .~ASED HOLE FINALS D.S.6-6 12/17/81 D.S.11-5 1/1/82 D.S.12-7A 12/28/81 D.S.11-5 12/19/81 D.S.ll-5 12/29/81 D.S.4-10 12/3/81 D.S.16-9 1/7/82 Gamma Ray Collar Log Collar Log ACSL/WL Collar Log . Gamma Ray Collar Log Perforation'& Collar Log Spinner Survey Run 1 5" Run 1 2"/5" Run 1 5" Run 1 2"/5" Run 1 2"/5" Run 1 5" Run 1 5". se sign and retrun the attached copy as receipt of data° Mary F, Kellis North Engineering Transmittal # 888 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE ,OF ALASKA, ,, EXXON , .MOBi'L ,GETTY ' ' so, o ' MARATHON Alaska Oil & Gas Cons, Corem--lot~ts; CHEVRON /~cborag~ ARCO O,I and Gas Company is a Divismo'n gl AtlanhcRichfieldCompany · ARCO Oil and Gas/"~mpany North Alas( istrict Post Office~Jox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 14, 1980 Reference: ARCO Cased Hole Finals ,.-~""~.S. 4-10 8/8/80 Diff Temp Run I 5" o.s. 4-1o 8/8/80 CCA Run 1 5" O.S. l?-l 8/6/80 CNA Run 1 5" D.S. 17-1 8/6/80 CBL/VDL Run 2 5" D.S. 17-1 8/16/80 CCA Run 1 2" a 5" '.,~ ~Please sign and return the attached copy as receipt of data. Mary Kellis North Engineering TRANSMITTAL #701 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS DaM SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany. ARCO Oil and Gas Company North Ala~J~ istrict Post Office~ . $50 Anchorage, Alaska 99510 Telephone 907 277 5637 Jorry A. Rochon District Operations Engineer September 29,-1980 Reference: ARCO Cased Hole Finals D.S. West Gas In,iection #2 CNL Run ! D.S. 12-2 DSTNDC Run 1 D.S, <['.':' 4-10 _.~.....' Pipe analysis Run 1 log 5" 5" ', I['NG -'1 '~'r_:-~ G'--- _ J 3ENG I 4"i~h~_ ._ ~.J 1GEOL I 3 GEOL ~'__ .., I STAT TEC .... I STAT TEC-- 1 CONFER.' Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering TRANSMITTAL #636 DISTRIBUTION North Geology R & D Drilling Eng. Manager D&M Geology State of Alaska ARCO Oil and Gas Company ~ a D;vi$ion ol AllanhcR~chl~eldCompany Sohio Marathon Chevron ARCO Oil and Gas( pany Alaska Post Office ~o× 360 Anchorage. A;aska :)95'!0 Telephone 907 277 5S37 September 9, 1980 Mr. Hoyle Hamil ton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Subject' DS 4-4 DS 4-10 Dear Sir' (Pemit no. 71-11) (Permit no. 76-42) Enclosed please find our Sundry Notices of Subsequent Report, for the subject wells, detailing our individual well repair operations. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/sp Enclosures ,. Form 10-403 REV. "1-10-73 ' Subml t "1 ntentions" In Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for propos&ls to clrlll or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) '1' O,L ~ aAS l'-'1 WELL!''1 WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company ~. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4, LOCATION OF WELL At surface / 422' FSL, 667' FEL, Sec. 27, TllN, R15E, UM 13. ELEVATIONS (Show whether DF, RTl GR, etc.) 52' RKB 5. APl NUMERICAl- CODE 50-029-20213 6. LEASE DESIGNATION AND SERIAL NO. AgL-28325 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 4-10 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field / Prudhoe Oil Po, 11. SEC., T., R., M,, (BOTTOM HOLE OBJECTIVE) Sec. 27, TllN, R15E, UM 12. PERMIT NO. 76-42 1.4. Check Appropriate Box To Indicate Nature of Notice, Re )ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF L----J PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PI.ANS (Other) SUBSE(~UENT REPORT OF: .. WATER SHUT-OFF REPAI RING W~LL FRACTURE TREATMENT ALTER lNG CASING SHOOTING OR AClDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state ell I~ertlnent details, and give pertinent dates, Including estimated date of starting any proposed work. Repair opns. commenced 8/6/80. Bled off tbg pressure. Installed BPV, and found 9-5/8" packoff lea'king. RU lubricatOr and test same. Attempt unsuccessfully to open tbg sliding sleeve. Circ brine down tbg through leak and rec diesel and gas-cut diesel returns. Perf tbg 7915- 7919. Could not circulate. Reperf tbg 7880 - 7890. Circ tbg and 5½" x 9-5/8" annulus w/brine. Run CCL/temp log 7940 - surface. ~ und tbg leak @ 6685'. Perf tbg 6586 - 65.94. Reverse circ w/brine and rec gas-cut returns. Circ out gas cut brine. Install BPV. ND tree and NU BOP stack. Pull 5½" tbg. Found no perf holes in tbg, TIH w/DP and retrieve K-Anchor. Test 9-5/8" csg w/2950 psi, ok. TIH w/DP and 2-3/8" tbg stinger, tag tailpipe plug at 8049', TOH. Rerun 5½" tbg, engage K-Anchor, shear out of PBR, land tbg..ND BOP, - NU tree and test same. Open sliding sleeve and displace well to diesel. Close and test sliding sleeve. Attempt to pull tailpipe plug and couldn't. Perf tbg 7984 - 92 w/4 SPF. Set SSSV and test. Set BPV. Released ri~ 0800 hourS, 8/17j~8~.("~ .... , ........... ~'~ '~,. '~ ...... ~,i, i ~ ~' ~i ~,', 16. I hereby certify that the fof~olng Is trJ~t and correct (This space for State office use) TITLE District Drilling Engineer DATE APPROVED BY, CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton ~~ Chairman/Commissid~ Thru: Lonnie C. Smith Commissioner ~ Bobby Foste~'~'~- Petroleum Inspector August 19, 1980 Inspected BOPE on Nabors Rig 1-ES and Witnessed Accumulator Test in Pre- paration for Work-over on ARCO's D.S. 4-10. ~nday August 10~ 1980 After completing the BOPE.test on ARCO's D.S. 11-14 I traveled to D.S. 4-10 after learning that the personel on location were having difficulties testing the BOPE. Upon arriving on location I met with Mr. Ray Wadley, toolpusher, and Mr. Steve Lewis, A~co drilling foreman. They informed me that all the BOPE tes~ OK except for the 2 auxiliary kill line valves and the 2 auxiliary choke line valves. Mr. Wadley said the four valves would not hold the 5000 psig test pressure so they were removed and four new valves were installed and tested OK.. Due to this test being conducted at the same time as the one on D.S. 11-14 I did not witness any of the pressure test but I was able to witness the accumulator test and the N2 back up system check. The results.of these tests were excellent. In summary, I witnessed the accumu}ator and N2 back up system on Arco's D.S. 4-10. This well is being worked over due to commun- ication between 5% tubing and 9 5/8 casing. ,, ARCO Oil and Ga( ~pany .~[aska '..2 . Post Office Bc:.: 350 Anchorage. Alaske Telephone 907 277 July 31, 1980 Mr. Hoyl e Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine. Drive Anchor. age, Alaska 99501 Subject: DS 4-10, Permit No. 76-42 .i' ]J' COMM - i_iCOMM'~' I COMM RES ENG J 3 EN,'.) ~, .... 2 GE'~ 3 GE ......... STAT TEC STAT TE~-- CONFER: FILF: Dear Sir: Enclosed please find a Sundry Notice notifying you of the timing for work planned on the above mentioned well.. Very truly yours, P. A. Van Dusen District Drilli.ng Engineer PVD/jh Encl osure ARCO Oil =nd Gas Comp;~.~'~:,' is ~.~ Form ! 0-403 REV. 1-10-.73 Submit "1 ntentlons" In Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL! I OTHER 2. NAME OF OPERATOR Atlantic Richfield Corn anp_~_n~L_ 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL' At SU trace 422'N & 667'W of SE cr Sec. 27, T11N, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 52' RKB 14. 5. APl NUMERICAL CODE 50-029-20213 6. LEASE DESIGNATION AND SERIAL NO. ADL 28325 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEAS NAM Prudhoe Bay Unit 9. WELL NO. DS 4-10 Prudhoe Bay Field-Prudhoe Oil Pool 11. SEC., T., R., M., (BOi I OM HOLE OBJECTIVE) Sec 27, T11N, R15E, UM 12. PERMIT NO. 76-42 Check Appropriate Box To Indicate Nature of Notice, Report, or ~ata NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* . CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTINQ OR ACIDIZING ABANDONMENT. (Other), (NOTE; Report results of multiple completion on Well COm.Dletlon or Recompletlon Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS. (Clearly gate all I~rtlnent cletalls, anti give pertinent ~lates, Including estimated date of starting any proposed work. ,. Atlantic Richfield Company proposes to commence work on this well previously described on. the Sundry Notice dated 5/14/80. This work to repair leaks in the 5-1/2" tubing and 9-5/8" casing will begin approximately on 8/6/80. Alaska 'Oi! & 5 ,¢ 16. I hereby certify ~J;Lat the foregglng Is true and correct ~ SIGNED~T~TLE District Drilli~ DATE (This space for State office use) APPROVED BY, CONDITIONS OF APPROVAL, IF ANY: TITLE See Instructions On Reverse Side DATE App.roved..,oPF "' Returned --' I L I _ ARCO Oil and G~' .pany North Alas[ ~istrict Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 15, 1980 Hoyl e Hamil ton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject. DS 4-10, Permit No. 76-42 Dear Sir- Enclosed please find a Sundry Notice detailing repair work to be done on the above-mentioned well. Very truly yours, P. A. VanDusen District Drilling Engineer sp Enclosure !980 ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Fo~ REV. 1-10-73 Submit "1 ntentlons" In Triplicate ...' & "Subsequent Reports" in Duplicate ~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. O,L ~ GAS r-'! WELL1 -I WELL OTHER NAME OF OPERATOR Atlantic Richhfield Company ADDRESS OF OPERATOR P,O, Box 360 Anchoraqe~ AK 99510 APl NUMERICAL CODE 50-029-2P. 213 LEASE DESIGNATION AND SERIAL NO. ADL 2R.t25 7. IF INDIAN, ALLOTTEE OR TRIBE NAME ii. UNIT, FARM OR LEASE NAME Prudhoe Ray !!nit :9. WELL NO. DS /z-lO 4o LOCATION OF WELL IOL FIELD AND POOL. ORWlLDCAT At surface Prudhoe Bay Field- . Prlldhnp nil Po.o.]. ._. 11. SEc;; Y.,-R.~-M.; (BOTTOM HOLE OBJECTIvP.) 442'N & 667'W of SE er Sec 27, T11N, R15E, UM ! sec 27, T11N, ELSE, IlM I 13. ELEVATIONS (Show whether DF, RT, GR, etc.) I 12. PERMrF NC~. 52' RKB I . _76-/*2 14. 'Check Appropriate Box To Indicate Nature of Notice, Report; ~-r'Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING L FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF N m REPAIRING WELL . . FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZlNG ABANDONMENT* (Other) (NOTEI Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and 9lye pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes to. repair leaks in both the 5-1/2" tubinq and 9-5/8, production casing by killing the well & pulling'the 5-1/2" tubinq, The leak in the 9-5/8" casing will be located & evaluated, The 9-5/8" casinq will then be patched and/or. squeeze cemented, New plastic coated 5-1/2" tubino will then be run, I~-}/R" 5nnn psi RSRRA BOP stack will be used, " The BOp equipment will be pressure tested each week and operationally tested each trip. Necessary provisions for subsurface safety equipment will be rerun. A non-freezino fluid wii1 be left in all uncemented annuli within the permafrost interval. A'Snn~ esi wp wireline Iubricator, tested to working pressure, wiI1 be used on all wireline work. NeI1 will be flowed to production facilities durino testinq. The downhole safety vaIve will . be instalIed and tested upon concIusion of th~ job. F C F IV [! n 16..I hereby~h, ~, ~at t.~~co3ct SIGNED , -- _TITLE.,Dist' Drlq. Enqr. .L--- , APPROVED B¥ / ~ ~_1_ TITLE- CONDITIONS O~PPROVAL, I~V: BY ORD~.R Or TH~ CO[{~ISSION DATE S/!~/nn See Instructions On Reverse Side Form 10-403 REV. 1-10~73 Submit "1 ntentlons" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) O,L i-Iq GAS I---1 WELLI.."J WELL.iI OTHER 2. NAME OF OPERATOR Atlantic Richhfield Company 3. ADDRESS OF OPERATOR P.0. Box 360 Anchoraqe~ AK 99510 4. LOCATION OF WELL At surface 442'N & 667'W of S.E er Sec 27, TllN, R15F., UM 13. ELEVATIONS (Show whether DF, AT, GA, etc.) 52' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAl- CODE 50-029-2R213 6. LEASE DESIGNATION AND SERIAL NO. APL 28325 7. IF INDIAN, ALLOTTEE OR TRIBE NAME UNIT, FARM OR LEASE NAME Prudhoe laav I!nit 9. WELL NO. DS a-l~ 10~ FIE~D AND. POOL ORWILDCAT ~ruonoe ~ay Field- Pw,]_dhoe Ril P_nol 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 27, T11N, R15F., IIM 12. Ja~RMrr NO. 76-b, 2 ,on, o-tOther Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTEI Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state ell eertln®nt 0etelll, and give pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes to repair leaks in both the 5-1./2" tubino and 9-5/8"' production casing by killing the well & pulling the 5-1/2" tubinq. The leak in the 9-5/8".casing will be located & evaluated. The 9-5/8" casinq will then be patched and/or nte~. New plastic coated 5-1/2" tubing will then be run. 13-3/R" snnn psi RSRRA BOP stack will be used. ~ ~ .... The BOP equipment will be pressure tested each week and operationally tested each trip. Necessary provisions for subsurface safety equipment will be rerun. A non-freezino fluid will be left in all uncemented annuli within the permafrost interval. A 5Ron psi WP wireline lubricator, tested'to working pressure, will be used on all wireline work. Well will be flowed to production facilities durino testino. The downhole safety valve wi].]. be installed and tested upon conclusion of the job. See Instructions On Reverse Side DATE 5/la/~n DATE. Approwd C~,;>? ARCO Oil and Gas Company I" '~ [.~ p, Ic,.~., i~ .' rio',, ::,'~. '.c;rr':q,, A'.. ,F,a rieL) If.'.., January 28, 1980 .f [:.N C-, .. 4 ENO E! '~ ~I;o~ .... -q-~"~c~o,~' _ I szA~ ~.--~ ..... ! .... FILF: Mr. Hoyle Hami. lton State of Alaska Alaska Oi'l & Gas Conservation Commission 3001 Porcu, pine D.ri've Anchorage, AK 9_9501 Subjectz Dear Si;r¢ DS 2~.8, Permit N.o, 74~63 DS 2-.lt Permit No. 70~29. D~5 , Permi't No, 79~95 DS 4-4, Pe'rmi't No: 71-11 ~ . ,,// ,, ~..~ DS. 4-:10, Permit. No. 76?42' ~ ~ ~ ~ ~ ~, ]~-~"..,~ .. :-,.,N...,' .... ,....., ~"~. Enclosed please fi'nd. Sundry Notices outlining our plans for the above~menti'oned wells,. 'Very. truly yours~ · P. A, VanDusen District Drilling Engineer ,, PAV/mb ' and Gas. gompany I~, ~Di'vlsion ol, Atl')~hd~chfleld~ ' ' ' Company" ' Forr~ ! 0-403 Submit "1 ntentlons" In Triplicate ' REV. 1-10~73 & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 5, APl NUMERICAL CODE 50~. 029.-20213 6. LEASE DESIGNATION AND SERIAL NO. SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to ~leepen Use "APPLICATION FOR PERMIT--" for such proposals,) ADL 28325 l-fl n 7. o. L WELL.L i OTHER 2. NAME OF OPERATOR Atlantic Richfield Company Prudhoe Uni"t 3. ADDRESS OF OPERATOR . 9. WELL NO. P.O. Box 360, Anchorage, Alaska 99510 DS 4.-10 4,LOCATION OF WELL At surfaco hoe Bay Fi'eld,Prudhoe Oil Pool 1. SEC., T., R., M., (BO.I TOM HOLE OBJECTIVE) 442'N & 667'W of SE cr Sec 27, TI]N, R]5E, UN :, 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Sec 27 UM 52' RKB 1~. PERMIT NO. 14. Check Appropriate Box To Indicate Natu~-~ Notice, Report, or ata NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: FRACTURE TREAT MULTIPL.E COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR AClDIZE ABANDON* sNoOTING OR AClDIZlNG ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) -- (Other) Tern0raril Pl u Wel 1 (NOTE, Report results of multiple completion on Well · . Cemlaletlon or Recompletlon Report and Log form.) OESCRIBE ·PROPOSED OR COMPLETED OPERATIONS. (Clearly state all Dertlnent detell~, and give pertinent dates, including estimated date of starting any proposed work. · Atlantic Richfield Company has wireline set a plug in the 4-1/2'" tailpipe of this well due to pressure being noted on the 5-1/2" 'x 9-5/8" annulus. The well w.ill remain shut-in with plug in place until an evaluation of the well is made. Results of the evaluation and status of well will be reported when available. Tailpipe plug was set and well shut-in on 12/31/79. 16. I hereby certify that the foregoing Is true and correct SIGNED ' ~'~J~ ~~ ''TL.E~ CONDITIONS OF AI~. VAL ~' TITLE '.~' . iF AN¥~' "' ....:"" OATE November 1.3, 1979 Reference: Enclosed are Pressure Surveys for tIie following ARC~ wells': 9-~:. ...... 10/28/79 Gearhart~Ckven 4~.10 ]10/30/79. ,', "- Please sign and'return the attach'ed copy as receipt of data,. · , K. J. Sahlstrom North Engineering TRANSMITTAL # 472 DISTRIBtrrlON Nor~ Geology Drilling Eng. Manager R E D Geology State o£ Alaska DAM I'JXXOI1 Mobil Getty SoM. o ~hrathon Phillips Chev'ron. ARCO Oil and G~.,~ Company Alaska Dj( t Post Olfid,. ~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 SAbIPLE TRANSMITTAL SHIPPED TO: State of Alaska Division of Oil ~.Gas Conservation $001 Porcupine Dr. .Anchorage, AK' 99S01 Attn- Wm. Van A~len DATE' · August 21, 1979. OPERATOR: Arco SAMPLES SENT: 8606 8671 - 875S 8749 - 8771 8776.- 88S9 8877 - 9802 892S - 9080 Drillsite 4-10 NUMBER OF BOXES: RECEIVED ^U~ ~ ! 1979 Anchorage . · SHIPPE~ B~ ' (Paleo Lab Tech) J/ ~ ~ " '"d-'-' ...... '~' .... UPON ~C~ZPT 0F T~S~ S~S ~AS~ NOT~ COPf O~ ~S ~0~ TO- ARCO 0IL ~ GAS CO. P. O. BOX 360 ANCHORAGE, ALASKA ATTN: DICK BROOKS 99510 DATE ARCO Oil and Gas Company is a Division of AtlanlicRichlieldCompany ARCO Oil and Ga/ npany North AlasP,.. ,Jistrict Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 2, 1979 Mr. Hoyle Hamilton State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 l~l ":~ '-'.' "':" i I 2 ENG. . ' 'i" ~r~r'~':-; ~l"-I I 2.'G~~ I 3 OE'OL ~ .... I STAT T~C . .... I STAT TEC I CONFER: .............. FILF: Subject: Core Summary, D.S. 4-10 Dear Mr. Hamilton' Enclosed please find the Core Summary for D.S. 4-10, submitted as Item No. 36 on Form P-7 for the above well. Very truly yours, Sr. Geological Associate RWC' kdm Enclosure ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany DRILL SITE 4-10 ARCo Sec. 27, TllN, R15E, UM Core No. Depths 8671 - 8731 8731 - 8749 8749 - 8776 8776 - 8836 8836 - 8871 8871 - 8926 8926 - 8986 8986 - 9046' 9046 - 9082' Recovery 60', 100% 6', 33% 24', 89% 60 , 100% 35 , 100% 55 , 100% 60, 100% 60, 100% 34 , 94% Lithology Sandstone, Mudstone Conglomerate, Sandstone Conglomerate, Sandstone Sandstone, Conglomerate Sandstone, Mudstone Sandstone, Conglomerate & Mudstone Sandstone, Claystone Sandstone Shale, Siltstone RECEIVED Anchurage NOr :;I North Alaska l'?i ;ct Post O l,g c c.~.~[ An cho:'a.q e?,,~,S~a 99510 Telephone 907 277 5.S37 Reference' Enclosed are the following PressUre Buildups' . ]DS 1-4 4/23/79 · S 2-9 4/20/79 /'~~ 4/18/79 · 4/18/79 / x-n~__4.:~ ........ " a/2s/79 [ DS 9-6 2/26/79 ~_~ DS 4-5 ' 2/28/79 . . . Please sig.n and return the copy as receipt of data. Sincbrely, V.G.' Reimers ' North. Engineering ..i TRANSMITTAL #162 DISTRIBUTION North Geology Exxon Drilling Eng. Manager ',.~ Rf D'~- Geology State of Alaska D ~ M .-,.'" Mobil. Getty Sohio ,~2rathon ~illips Chevron AtlanticRichfieldCompany North Arneri/" ', Producing Division Alaska Post Offic~-,,;'ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 15, 1978 Reference: Enclosed are copies of the following Transient Pressure Buildup Surveys: ,/D.S. #4~6 10/2-3/78 ~D.S. (/4-7 10/4-5/78 v'D.S. #4,8. . 10-03-78 '~.S,~,,.,,,i{!i~'i",-,"'i.0.." .:.":'"; 10/6-7/78 wD.S. #9-3 10/12-13/78 ~.D.S. #9-4 ~.D.S. (;9-8 '~ 'D.S. (;9-10 wD. S. wD.S. (/9-15 10/14-15/78 10/18-19/78 10/16-17/78 10/20-21/78 10/22-23/78 Camco Camco Camco Camco Camco Camco Camco Camco Camco ..Camco Please.sign and return the attached copy of the transmittal letter as receipt of data'. Very truly yours, /. R.A. Logue North Ope.rations Engineering Transmittal #615 DISTRIBUTION North Geology Drilling Eng. Manager Dallas'Geology State of Alaska D & M R & D EXXO~ Sohio Mobil Marathon 'Phillips Chevron Getty AtlanticR~chfieldCompany .. North Am~.-';"' ' Producing Division North Ala~. -,istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 14, 1978 Mr. Hoyle H. Hamilton State o'f Alaska Department of Natural Resources Division of Oil and Gas 30'01 Porcupine Drive Anchorage, Alaska 99501 .. '-]-'-'~' .::,:c '~ "i°~''' '-'i 5' Ih"'. ~,0.. '~'''' '"~ '~ <.?~t ':~- ....... ...J ...... ~ I...... .;~.i-Z..~..~...~ .... CONFER: "'~i~z .......... ~,_ Subject: DS 4-1 DS 4-2 DS 4-3 DS. 4-4 DS 4-5 DS 4-6 'DS 4-7 DS 4-8 Permit No. 70-42 Permit No. 70-63 Permit No. 71- 5 Permit No.'71-11 Permit No. 71-25 Permit NO. 76-83 Permit No. 75-77 Permit No. 76-10 ermit No. 76-30 ermit No. 76-42 Dear Sir: ~O.fio~.) Enclosed please find.a Completion Report~.~f0r the above- mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer FMB: lr Attachments RECEIVED .... · ,'.. ,...,,. SUBMIT IN STATE OF ALASKA :'ev~rse side: OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: WELl. W£[oL ~ DRY Other b. TYPE OF COMPLE~ON: w}:I.L ~ m'~ ~ ~ ~ n*CK nssv,. Other Perforated ')NAME OF 0PgRATOR ~.. Atlantic Richfield Company 3. ADDRESS 0F OP~'-RATOR P.O. Box 360, Anchorage. Alaska qqR][~ 4. l.oc~r~r.)x or wr.l.~. (Report location clearly and in accordance with any State requirements)* At surface 442'N & 667'W of SE cr Sec 27, At top prod. interval reported below 1153'N & 1329'W of SE cr Sec 27, At total depth 1317'N a 1408'W of SE cr Sec 27, TllN-R15E, UM TllN, R15E, UM TllN-R15E, UM 5. AP1 XUA'IP_A%ICAL CODE 50-029-20213 ~6. LEASE DESIGNATION A-ND SERLAL NO. .a, DL 28325 7. IF INDI&N, A3~LOT/*EE OR TRIBE NAa%LE 8. UNIT,FA/IAI OR L~.-%SE iNA.ME Prudhoe Bay Unit 9. %VELL NO. DS 4-10 (33-27-11-15) 10. FLFJ.~ A_ND P,,OOL, OR~%¥1LD~C.~T ~rudhoe ~ay ~'~e±a ?rudhoe O5] Pool 11. SEC.. T., R., M., <BOSOM HO~ 3.ec 27, TllN-R15E 12. PERbXIT NO. ?6-42 ~OWiV[A.~Y* ROTARY TOOLS CABLE TO0t, S 9154'MD, 8941'TVD ~9064'MD,8857'TV Single All =.PRODUCING!N'r~.VAL(S),OF ~ISCO~P~TIO~--TOP, BO~OM, NAME(MD AND'I"v'D)- =.WA,SDIaECTIO,NAL Top Sadlerochit 8668'MD, 8490'TVD i SURVEYM'ADE Base Sadlerochit 9050'MD, 8845'TVD i Yes 24. TYPE E~,CT[IlC AND OTH~ LOGS RUN DIL, ,BHC/GR! FD_C/CNL/GR, CBL/VDL/GR/CCL , CASING RECORD (Report all strings set in well) 9 5?8" ,,,, ,,, ~6. 20" 94~ Vetc~ H-40! ~80' 79a.n,,+'~] ~-~n.[ 2692" 147~ gG££IMN-§61 8541_' I " 4s- s i , -[ 149'{250sx. 7" '" 8235'.' ' 91 28. PE~FO.R,ATIONS OP~ TO PRODUC'I'IOH (Intcrval, size and number) 8940'-8955' 8962'-8989'' 9007'-9019". w/4 shots per ft 9025'-9029' ,~% 9040' 9044'~: ....... ~' I 30, PI%OD[/G~ION HOLE SIZE [ CE5iLNTING RECO}%D ~ ,~OUNT PULLED 30"j' Approx 500 sx PF II / 17-1/2'~ 4900 ]12-l-/g'~ 750 TUB~G SCi'I.E~ [MD) [ SIZE [ DEPlX{ SET (~D? i PACI~ER SET (~D) 5-1/2" ! 8113' I 7972 I ,I · {i'J.":,~V' ." DATE FIRST Pi~OD'UCTI. ON June 1977 DATE OF TEST, [ttOURS TESTED '[CI'iOXE SIZE [PROD'N FOR [ [ [TEST PI!lit!OD 9/20/77 4.1 4° 55/64 -----')' I~LESS. ! 124-HOUR RATE I I o , / ; 'l 31..'DISPOSITION OF 0~S (8old, ~sed ~or ~uel, vented etc.) Reinj ected PRODUCTION ME'I.HO'D (Flowiug, gas 1i£~, pumping--size and type of, pump) .Flowinq 32. LIST OF ATTACHMENTS OII~--Br~L. l]42.R ] GAS--IV[CF. [ 4486 ] WELL STATUS (Producing or unut-ln) P ~duc G.%S--A~CF. WATEI%--BBL. / GAS-OIL 766.q I 0 I 670 WATER--BBL. [ OIL GRAVITY-APl (CORR.) 0 ,I 27_n , ,. ....... ITEST WITNESSED BY Production 0Deration~ -- 33. I hereby certify that the fgsegoing and attached information is complete and correct as determined from all-available records ~~.~¢.¢ ' - ~ TiTLe. District Dr lg Engineer D,T~ ~~f~~ ........ *(Se~ Ins*ructions ~n~ S~ces tot A~aifionol Do,~ on R~wne Si~e) INSTRUCTIONS ~.eI, General: This form is designed for submitting a complete and correc! , ,, comple!ion report a~d log on all types of lan-_Js and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any a:tachments. Items 20, ~,nci 22:: If this well is completed for separatc- prcduction from more than one ~nterval zone (multiple completion), so state ~n item 20, and in item 22 shov,, the prcJucir~g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interva! reported in iter'n 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the ackJitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately pro.duc~d. (See instruction for items 20 and 22 above). '" 34..~UMMAIt¥ OF F¢)I{MA'I'ION TES'I'.'~ IN('L.UI)IN(; INTERVAL TF.L~TED. PR~URE DATA ~ ~OV~I~ OF OIL: GAS. 35. G~GIC MAHK~ WA~ AND MUD MEAS_ D~t ~ V~T. Top 8adlerochit 8668' 84~0 3ase Sadlerochit 9050 ' 8845 . . ~,. cO,,~ ..~...',-,'.c,, ~m~ .~'~i~s or"u.,to~o~. ~.Os~. r.a~.~...~ :m ...... DRILL SITB #4-10 ~r, PERFORATION AND CLF~OP RECOPd~ April 26- 29, 1977 D.S. #4-10 has a bottom hole location in the southeast corner,. Section 35, TllN, RiSE, Prudhoe Field. Depths of interest' Measured Depth Subsea Depth Zone Top of Sadlerochit Gas/Oil Contact Perforations Water/Oil Contact Base of Sadlerochit Junk Left in Hole 8666' 8436' 8816' 8578' 9040-9044' 8784-8788' 9025-9029~ 8784-8788' 9007-9019' 8753-8764' 8962-8988' 8711-8735' 8940-8955' 8691-8705' Not Present 9048' 8791' None SMB SMB sm/ s LBS Dropped first gun on swab valve when pres'sure.., testing lubricator. Charges became misaligned, but this was not realized and. th.e.gun was not exchanged. RIH and logged CCL strip. Perforated 9040'-9044' with. ~e. open to 56/64". Observed no flow across turbine meter and no {ubing pres.~a~e.~ RIH with second gun (select fire) and' rep'er'ferated 9040' -9044' and also 9025' - 9029' with choke on 36/64". Observed no. tubing pressure or flow. RIH with third gun and perforated ~7-90'19'" While open on a' 36/64" choke. Ob- served an immediate 200 psi tubing., pressure and a rate of 2000 BOPD. RIH with fourth gun to perforate 8'96Z"'-gggS.'" .but .gun misfired. RIH with fifth gun and perforated 8962:t-ggBg:~'.while flowing on a 36/64" choke. Saw 200 psi increase in tubing pressure~and 'flow rate was 4500 BOPD. SI well to correct leaky flange on surge tank~ .Opened up well on 68/64" choke to clean it up. Initial flow rate was 5000.:BOPDand soon exceeded flow totalizer capacity. Flowed well for 80 minutes. CaC12'.water went by in a slug before any samples were kept and the first sample showe'd: 100% oil. Final flowing tubing pressure, temperature, and average rate were 1060. psi, 78°F, and 13788 BOPD. RIH with Fluid Density tool and fmmd'.CaC12 water/oil contact at 9037'. RIH with sixth gun and perforated 8940"-8955' while flowing on 36/64" choke. Observed the tubing pressure increase-from 1210 to 1320 psi in 4 minutes. RIH with dual Amerada bombs making static stops near bottom. Flowed well for 75 minutes on 60/64" choke. Final flowing, tubing pressure, temperature, and average flow rate were 1250 psi, 74°F, and 12806 BOPD. SI well for 2 hour buildup, recovered Amerada bombs, and determined that the static pressure at 8800' ss was 4357 psi and the maximum drawdown' while flowing was 389 psi, giving us an approxi- mate Productivity Index of 32.9 STB/psi.-, Maximum bottom hole temperature was 184°F. The total, volumes of oil and gas produced during the perforating operations are estimated at 1198 bbls. of o~! and 899 MCF of gas. PDL 6/2/77 · . T i~, A iq 5 i,.l .[ '1' ']' A ],~ }:TO;l!: J. A. Roc]~cm/R. A. I,o. u,.. (I I~'-;,~,'~ i~:d here~.:~t1~ are thc .f'O].].Ol~'.~l~2 fol' i:]lO. ¢"':~;o. ct well' No. Scale Xerox Sep.ia 'I)~L· Li Acid or Fract~rg 'lYeatment LOg l __....-...._ BlIP Buildup [ Flo':,; Profile Sur~'ey llorehole GeometD~ 1,og -=--7-- Carbon Oxygen. Log . Casing Collar Log Cement Bond Log ........ ConB~ensat. ed Neutron. 1,6g - Cased IIole. Core Analysis - Inte'm, al Core. No. ~.~..}.}.~y.(:ore t~,scripti'oa (SMC). - Interval ICore Dascripti.on (Cony.) - Core No. .: ...... Directional Survpy- Gyro . - 8ing~-~ot --.. · ... 'Engineering Procluct~on' Log " '. ' .. Fluid Analysis ..,L_'.?:tuid l~nsity Gain:ua' Ray . Location Plat ..... ~lud l.og . ........ Perforating Record . State Reservoir Pressure Report Surveillance Reports ..Temperature Log ' ....... '.TVD Logs - 1)uel Induction Laterolog -- Compbnsated Formation Density 1,og - Compensated Neutron-Formation Dansity I,og - Borel:ole Compensated Sonic Log -' Pm'osit), l,og .a.~- ' ' ;t.q(l Rc't:t~rn Recc:ii~t To:. Ms R A Logue Atlantic Rich[ield. Co:npany P. O. Box 560 Ancliorage, Alaska 995 Il ( ) l)ate' D:'~O~-, a~.d Gas b0.'r~s~a?~ti0n ........ Anchor~a: ' ....... Divis~ of Oil and (~s Cc~servatic~ O. K. Gilbreth, Jr Feb~_~y 9, 1978 Director Chief Petrole~a EngineerlV' Test Surf~ Safety Vales (SSV), Subsurface Safety Valves (S~), L~f Pressure Pilots and Aunular Pressures c~ ARED's Drill Sites %1, %4 Subject. test involved t~o separate trips to Prudhoe Bay, the first on January 16, 1978, and the seo~%d on January 22, 1978, with eight ~-:~ tire days spent testing. Part of the second trip was utilized retest- lng ~ wells on drill site %1 after guide liD~s ~ agreed upcn at a m~e~g bet~en agency and AROD production persc~nel on January SSSV' · SSSV 9 5/8" Tested Test Annulas ~__~_~ ~ ~ults . ,, L.P.Pilot Initial SSV SS~ .'. Actua~ Flowing Tested'Test .... @: pSI_ ._ Pres__~e .~ PSZ ,' Bem/lts 1-1 1-2 1-3 1-4 1-5 1-6 1-7 1-8 1-9 1-10 4-1 4-2 . 4-3 4-4 4-5 4-6 4-7 4-8 720 7OO 7O0 ' 660 "' 700 , 700 7OO 70O 700 ~50 1270 790 1020 900 155'0 1140 1140 '1600, 780 1400 2075 680 1300 775 1450 670 1560 . 700 1300.. 7O0 1500 700 1350 650 960 650. 1450 * Not tested ** SSSV inoperable. *** SSSSV would not close, 640 675 620 680 740, ',. 8O0 .., ..~ 695 740 970 .,, 70o ~ . 750 750 700 , 775 70O 660 700 ' Being .p,~l 1~,~. OK 825 OK 720 OK 660 .5{ 700 'OK 700 , OK .,. ~ 810. OK "650 OK ' 750 Failed '1000 ** OK · 700 *** OK' 750 OK 750 OK 890 - '. 700 OK 760 OK 650 Failed Failed Failed Failed Failed Failed. Failed 25 0 0 0 9O 0 6O 0 0 0 0 0 0 0 100 0 0 100 50 0 0 100 0 50, .0 0 100 0 250 0 0 0 0 0 0 0 ARCO D.$. · February 9, 1978 tested after it was found the SSSV's in the ~lls ~0uid. not test. three SSV's ~kll be tested when SSSV's in 'these %~lls have been r~T~ired. .Field inspe~ re~ were ~ed and copies mailed to A1 Brown, · production zuperin~t, and Don Franks, assistant production superintendm_nt. Originals of the field ~specticn reports are attached to this report. Atta~t Drlg. Permit No. Opera tor _~ ~_~ A1 Oil and Gas Conservation Commi :. Field Inspec~ion Report ~-)~ Wel 1 / BmlmlWm~m Represented by ._~='~~~ Name & Number Sec__T__R , M Satisfactory Type Inspection Yes No Item ( ) Location,General ( ) ( ) 1. ~'~ell Sign () () () () () () () () () () () () () () () () () () () 2. General Housekeepino t. Reserve Pit-( )open( )filled 4. Ria (~/"Safety Valve Tests 5. Surface-No. Wells_.~ 6 Subsurface-No. Wells-~ ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , , 9. BS&W __,-- ,--,-- 10. Gr. Bbls. ( ) Final Abandonment () () () () () () () () () () () () () () () () 11. P&A Marker ( ) ( ) lZ. Water well-( )capped( )plugged ( ) ( ) Satisfactory Type Inspection Yes No Item ( ) BOPE Tests ( ) ( ) 15. "Casinq set ( ) ( ) 16. TesL fluid-( )wtr.--:--~-)mud ( ) oil ( ) ( ) 17. Master Hyd. Control Sys.- psia ( ) ( ) 18. N2 btls. , , , psiQ" ( ) ( ) 19. Remote Control~---- ' 20. Drilling spool- "outlets 21. Kill Line-( ) Check valve 22. Choke Flowline ( ) HCR valve 23. Choke Manifold No. valvs flos 24. Chokes-( )Remote( )Pos.(-~dj" 25. Test Plug-(')Wellhd( )csg( )none' 26. Annular Preventer, psi~ 27. Blind Rams 28. Pipe Rams ~psiq 29. Kelly & Kelly-cock ~]~sig ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve psi.o ( ) ( ) 14. Pad leveled ( ) ( ) 31 Safety Floor valves--Y~-'-)~BV / )Dart Total inspection observation time ~_~,~ hrs/oWmj~. Total number leaks and/or equip, failures / Remarks days or when ready Inspected by_~ate/- ~_-.~ North Alaska Distric_.t Fngineering T RAN S B! I T TA L ' · . .. From: J.A. Rochon/ R. 'A. · . · . '" "' " ;:. ;<.' · ' · "' :..:. .'.i · . {. 1Vell Nmme'~ . · ' :. .. .- . ~ .,' ...- , ...'.. .. . . · - -., . . ,.. BHC Sonic/Caliper' Log' '" ... BHC Sonic/Calipe~ - Gmraa Ray. Log · BHC Sonic/Gamma' Ray Log .. Caliper/CCL .'.' ..., ...: ..' '.....' . ,Cement Bond LOg/~L '"' :'.' " o, .. Scale Xero~ · · L6g' "..: Density.: · Compensated Formation DensitM Compensated Neutron. Formation . Compensated Neutron Log .' ' Core Analysis -. Interw. al . ' " .'. -. ' Core' No. "'" ".. Core Des.cription, (SWC) - Interval. Core Description {Cony.) - Core. No.~ ' ' ' Directional Survey...- Gyro' · · , .'Single S]~ot' ' · .. : ~hltishot " Dril'l Stem Test'- ~est No. zec~ipt Acknojfledged For- .o Date: ~l.ease return receipt to:. · . · · Dual Induction' Laterolog. , Fo~nation Density Log : , ' "" E.["/i: 9"- a~a ~M/CCL , . ' ' , ', , Laterolog ' ",. .. j.~,~:'~ Location Plat . ". '..-. · ' " . .... ~crolaterolo~ .. Db~isi~n .ti Microlog . . ' ~og- Inte~al . "'. ....... Sample Log (A.R.c~) Inte~al S~ergetic Log' " ' ... · ,.. ~ DIL " ' . ~'~ . . - . . . ~-2o=0s~tr'~':. · .'. " ' ' At'~: 3ir, ' reno/van, jackson /~tJ/antic Richfield Co~,~an7 . K~rth Alaska Engineering P. O.. Box 560 · Anchorage, Alask~ 99510 .. , · . · . . Sepia " BL Line"'". '.~ . : . .. :..- · . · . - ~ , ,, ,., _ · : _ = - .. . , . _~,, . " · . · . · ,-~ · ' ., i . _ - :,~1~ · · · · . . . . . · , v ~.,- . ..::~ .. .,.. . .. . ... · ~ -: ~!, ' ~ , · Run No. Transmitted herewith are th.e f611oi~ing for' the subject well:' . . ';-'"" '" " · . .' · .; . ; . . ' · . . .. '.. , .:_ · . . North Al asks Dis't'.fi. ct. Engineer:ing T R A N S M I T T A L FTOm' .J J. A. Rochon/~ R: Jackson 'Date' May 31, 1977 Well Nav..e' D.S. #4-10 Transmitted herewith are the following for the subject well' Run No. Scale BHC Sonic/Caliper Log ,BHC Sonic/Caliper - Gmnma Ray Log' ....... BHC Sonic/Gamma Ray Log Caliper/CCL --.- Cement Bond Log/VOL ,. Compensa.?:ed Formation Density Log .............. Comper,.sated Neutron-Formation Densit.~ Comper~.2:...:.:-,'~:ed Neutron Log Core .Analysis - Interval Core. No. ........ .Core 9escr..i.ption (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro Si~,....' ';[j' Shot l~h]. ,....t shot , . Drill Stem Test - Test No. · . .. Dual. 'md. uction. Laterolog ...... Fon':~'...;i. on I)e'o....i.'..'i..ty Log Fon'['..."'~.t.ion Density Log/ga~na P~y Ganma Ray/CCL · , , ,, " .'Laterolog Location Plat , Ni crolaterolog Micz't'..,log __. _ _ ~dlog - Interval Samp].e Log (A,R. Co'.) - Interval Synergetic Log TVI.)-DIL .. 'IYD-Porosity Log Receipt Acknowledg,ec.l For: ...'. .~ .'.Da,.te: ,,.. ..... ' /' ',~2 ~ .... "~;' f~ - . Please remi~:':..r'ece:ilS~, to.: Atta_~. c Richfield Company North 'Alaska Engineering Manager P, O. Box 360 ~chorage, Alaska 99510 Xerox Sepia BL Line #436 02-001B , STATE of ALASKA DEP~ CF NATURAL Division of Oil and Gas C2mls~xvation TO: ~ FROM: Hoyle H. D~r kmmxie C. Smith ..'~/?~., Chief Petrolem% ~gineer SUBJECT: To Witness Subsurfaoe Safety. Valve and Surfaoe ~1 Safety Valve for Aroo DS ~10 T~esday, .May 3, 1977 - John Craig.,. s~ f~r Arco, and I w~nt directly to DS 4-i0 fr~'DS. 468 to ~ SSSV and ~ on DS 4-10. ~ 5:00 PM. The SSSV was open with 1450 psi on tubing.. The SCSV.was ~ and' pressure above the SCSV was bled to ...zero. X ohsezved 'tl~ pressure for 10 minutes with no buildup of pressure. The SCSV was opened and the sssv was closed and the 1450 psi above SSSV ~ not bleed down, indi~ 'a leak. The SS~V was... 6.:30 PM and did not ~t. John Craig shut do~n op~r~ o~ DS 4-10 f~r the Wedr~sday., .May 4, 1977- I ~t'... D8 4~.9. which ..had.'..just' he~n tested and we~t. back to DS 4-10, ....... The"$~ was .a~ua~ se~ai .times. At 10:20 AM the S~ was closed again hut still., lea_k~d SSSV was actuated open and closed thre~ m~re times. At. 10:50 AM ~he SS~V was closed and px~ss~re abo~e valve wss bled to 775 psi. I observed the pressure f~r 20 minutes with no build~, . indicating the S~V w~s not 'leaking. The~e wss 600 psi put ~ balan~ line. before final test. '., ' .- ~s~ m m 4-10. ~ f~,. ~S~S' were ~ ,~S',.f~, " At~% ,; , . Drlg. Permit No. Operator A1 a and Gas Conservation Commi ;e field Inspection Report Wel 1/Platfm Sec Represented by. Name & Number . . Satisfactory Type Inspection Yes No Item ( ) Location,General ( ) ( ) 1. Well Sign ( ) ( ) 2. General Housekeeping ( ) ( ) 3. Reserve Pit-( )open( ]filled () () 4. Rig ("..) Safety Valve Tests ,,, ( ) ( ) 5. Surface-No. Wells (.'.) ( ) 6. Subsurface-No. Wells , SatisFactory Type Inspection Yes No Item ( ) BO.DE Tests () () () () () () () () () () () () () () () () () () () () () () () () () () ( ) Well Test Data ( ) ( ) 7. Well Nos. , , , ( ) ( ) 8. Hrs. obser , , , ( )' ( ) 9. BS&W ,--, ( ) ( ) 10. Gr. Bbls., , , ( ) Final Abandonment ( ) ( ) 11. P&A Marker ( ) ( ) ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) ( ) ( ) 13. Clean-up ( ) ( ) ( ) ( ) 14. Pad' leveled ( ) ( ) 31 Safety Floor valvesz( )BV ( )~art Total inspection observation time ":i~"" "~h~/days Total number ieaks and/or equip, failures Remarks .... '.' :'..~" " .. '.'.,'" .~:~~",,'"'", ,.'"' .~.~;,. ...... ',~' ' . .,'. '.'. ,..'i.' .'~. .... ~<::".....,.~ .'.~ .~'."......... ,. . ..~.., ..:, ,".-' ...... :' ' '" ",, .?'".'"'"..'.: .... i,'" ,~ 15. "Casing set @ 16. Test f'luid-( )w. tr.--:-~-)mud ( ) oil 17. Master Hyd. Control Sys.-__psig 18. N? btls. , ,__,__pslg 19 Remote Controls 20. Drilling spool- "outlets 21. Kill Line-( ) Check valve 22. Choke Flowline ( ) HCR valve 23. Choke Manifold No. valvs fl~s 24. Chokes-( )Remote( )Pos.(~dj~ 25. Test Plug-( )Wellhd( )csg( )none 26. Annular Preventer, psig 27. Blind Rams,__psig 28. Pipe Rams ___.psig 29. Kelly & Kelly-cock ___.psi9 30. Lower Kell.y valve psig CC' days or when ready Inspected by Ub: DIS'TRIBUTED TO~ STATE OF AL'AfiKA. 'DIVISION. OF OIL North Al,~ka District Eng!~' TRANSMITTAL . . May 10,1977 lfell r_-~=- · D.S. 4-10 T.ran~.mitted herm.,~th are the £ol!owing for the subject well: · · Run No. - '. - : Scale · C~liper/CCL .. , , ,.., ~:.. :._ ~__~o_mpC~._n~atea Neutron-Ponm~bh' ~'-~ity ,~- - '-'~:/""'Z:-~," :-..~--, ...- . ~~~atea Neu~dn Log . . ' -- . '..._.. Core ~_~~. - ~te~ .' ' '. ".'~'.- /--; ,' · . . Co~e'No.' ~ · ' ..... . ' "' '~re ~s -'- t' ' ' ..... =~'- ""~ :'":' TM ~'""~ , '-'"" / " .._ '_ ~ ~ ~u ~gn [an~j - Inte~ ---- '. 0i,,~ ..... . ' . .''- · '; -' '- -Core D~s~i~Zion [Conv.~ - Core . ?, _ .~ m?a?~' s~=~ -. ~o:. ~. ".'.:. -'.'" ~ ~ """: :~'''''.-,:,::~''?~:.~''::,':,...~.,,, .' ~' - - .' . ,.. S~Zl~ S56t '. '.. " ))~lt~shot ' · D~ill 8te~'te~t '- Test No. ~ Dual Inauction Late~olog - e. , ",':ReCeipt Ac3mot~,leclged For: · .... . '": ': "~'~a-e~ r · , , . . o. . Please return ' ~:"'"~"~: '"'-:~ Atlantic P&chEield Co. ,.-vo any ~orth Alaska Engineeri~ P. O. Box 350 ; ' "', ""-"'"' A [::::' ' ' ·., # 325' AtlantL,:.~ichlieldCompany North American Producing Division North Alas~" ':strict Post Office\. .360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 6, 1977 Mr. Hoyl e Hami 1 ton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Drill Site 4-7 (31-34-11-15) Drill Site 4-8 (33-26-11-15) Drill Si te 4~3-35-11-15) Drill ~-27-11-15) Dear Sir' .. l..C.. ! i ::~.~c, '[. k "~;':C,' 'i '., ,.., I- ~ -.:"r.':L I' ... 2 C"OL { ' 0~,.~',~T I ..... cc',,q'~'~:' ' 'F IU::: .............. ~ermit No. 75-77 ~ ~. Permit No. 76-10 Permit.No. 76-30 Permit No. 76-42 Enclosed Please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned well. Very truly yours, Frank' M. Brown Di stri ct Dri 1 l'i.ng Engineer ./vp Enclosure RECEIVED tdA¥ 1 Ig77. r. tl~,' "~' 'r Form 10-403 REV. 1-10-,73 Subml t "1 ntentlons" In Triplicate ("' & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) g GAS O 1. Ow~LLL WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Co~ 3. ADDRESS OF OPERATOR P. O. Box 360 Anchorage, Alaska 4. LOCATION OF WELL 99510 At surface 442'N & 667'W of SE cr Sec. 27, T11N, R15E, UM 13, ELEVATIONS (Show whether DF, RT, GR, etc.) 52' RKB Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20213 6. LEASE DESIGNATION AND SERIAL NO. ADL 28325 7. IF INDIAN, ALLOTTEE OR TRIBE NAM'~--~ 8. UNIT, FARM OR LEASE NAM Prudhoe Bay 9. WELL NO. Drill Site 4-10 (33-27-11-15) Prudhoe Bay Field-Prudhoe Oil Pool 11, SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 1317'N & 1408'W of SE cr Sec. 27, T11N, R15E, UM 12. PERMIT NO. 76 - 42 ;)ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L..__J FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING L~ MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZlNG ABANDONMENT* (Other) mm Perforate (MOTEl Report results of multiple completion on Well Compl__~lon or Recompletlon Report and Log form.) 15, DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all Pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Began installing perf equip on 4/19/77. Tstd tree, csg & tbg. Ran temp survey. 'Pulled dummy valve. Ran GR/CNL/CCL logs. Tstd BOP to 5000 psi OK. Perf'd interva, ls 9040'-9044', 8984'-9011', 8962'-8977' w/4 shots per ft. Ran static BH press survey. Flowed well. SI *for press bui'idup. Ran & set ball valve @ 2163'. Tstd balance & control lines to 5000 psi OK. Bled press above ball valve to 0 psi, held OK. Installed & tstd tree cap to 5000 psi OK. Released well to Production Dept on 4/29/77. RECEIVED MAY 2 1971 Division of Oil 16. I hereby certify that the foregoing is true and correct (This space for State office usa) APPROVED BY, CONDITIONS OF APPROVAL, IF ANY: TITLE .... DATE TITLE - DATE.,, . See Instructions On Reverse Side AtlanticRichfieldCompany ,. North Amerj~! Producing Division North Alask% strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 25, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Drill Site 4-1 (23-35-11-15) Drill Site 4-2 (.13-26-11-15) Drill Site 4-3 (.23-34-11-15) Drill Site 4-4 (14-36-11-15) Drill Site 4-5 (23-27-11-15) Drill Site 4-6 .(22-03-10-15) Drill Site 4-7 (31-34-11-15) Drill Site 4-8 (33-26-11-15) 1 ~_ :..q~J-~= 4~_9.L .. ~(33-35-11-15) Dear Sir: Permit No. 70-42 Permit No. 70-63 Permit No. 71- 5 Permit No. 71-11 Permit No. 71-25 Permit No. 76-83 Permit No. 75-77 Permit No. 76-10 Permit No. 76-30 Permit No. 76-42 Enclosed please find a Sundry Notice outlining our plans for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /vp Enclosure Form 10-403 REV. 1-10-73 Submit "Intentions" In Triplicate & "Subsequent Reports" In Duplicate ..,. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE · SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WELLI I OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR 1:,. O. ]~ox 360 4.. LOCATION OF WELL Anchorage, AlaSka 99510 At su trace 442' N & 667' W of SE cr Sec. 27, T 11 N, R 15 E, UM 13. ELEVATIONS (Show whether DF, AT, GR, etc.) 52' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re (. 5. APl NUMERICAL CODE 50 - 029 - 20213 6. LEASE DESIGNATION AND SERIAL NO. ADL 28325 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. Dr±ll Site 4-10 (33-27-11-15) 10. FIELD AND POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM HO.LE.OEIJECTIVE) 1317' N & 1408' W of SE cr Sec.. 27, T 11 N, R 15 E, UM 12. PERMIT NO. 76.- 42 3ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF ~ PULL OR ALTER CASING ~ WATIERSHUT-OFF ~ REPAIRING WELL , FRACTURE TREAT, MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING · SHOOT OR ACIDIZE ABANDON* SHOOTING OR AClDIZING ABANDONMENT* REPAIR WELL CHANGE PLANS, (Other) " (Other) Perforate {NOTE.' Repo~ results of multiple completion on Well , SUBSEQUENT REPORT OF: · - Compl?tlon or Recompletion Report and Log form.) 15, DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all 13ertlnent details, and give pertinent dates, including estimated date of .starting any proposed work. Atlantic Richfield Company proposes to perforate selected intervals within the Sadlerochit interval. All perforated intervals will be reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be .utilized with all wireline work. All perforations will be made with .hollow carrier type guns at 4 shots per foot. Well will be flowed to a surge tank to recover load fluids and any produced well fluids. All recovered liquids will be retained in the surge tank, then trucked to the oily waste disposal' facilities for disposal. Any produced gas will be vented to the ~tmosphere duringI perforating operations. The down hole safety valve will be installed and tested upon conclusion of J°b"~"['~L..~l~,'] ? Estimated start da'te' 'Hay 28, 1977 D:vision c,f, Oil a~d f:b:~-~. 1.6. I,.heeeby certify that the foregoing Is true and correct TITLE District Drilling Engineer DATE, '.."[~r'hls'.space for State office use) "CON.'D~IONS OF APPROVAL, IF A'NY~ 'See Instructio,ns'On Reverse.Side DATE 3-30-77 ....... NTiA~L ............ ~ ............................ '" ........... CONFIDE "~' ~ ^ ~ s ~,~ :, .~. ,r A ~.. I)ISTIilllUTED TO: STATE ()F A'LAS~ i)IVISION ()F OIL & O~ Date- Sept. 28, 1976 I"r om: J.A. Roc:}~on/W. To] .i. ve'.-. Transmitted herewith are the following- ~rco v,,'elZ ]).-S'~'ii'~'~'i~)""~.;3-27-:1.1-14) s~,' O~t/CO., mm ~t]. '"_Arco 'lVell D~S.f12zg'(34-25Zllz14) 21.t ~ 5" 6IV, CCI,.~ Run _AF,,co'hro].l D.S.tt 2-10 (36-11-14) 5" GR/CCL, lltul t~1 .. · , ... Receipt .'\cta~owledged For' Date: ' 'rt:cc::ij)t l(~: Al'(!j/~l.i.(: NorLJl A.La.'4]ia ]:ll".illCCf'.Lllg 'l,l,'.tiiagur P.O. Box 36Cl Ancl~orage Alaska 9951O By .... LJ[1.I North Alaska [Ji~sl~irt Post Offi~c" "~x 360 Anchora[, .lask,~ 99510 Telephone 907 277 5637 August ll, 1976 Mr. Hoyl e Hami 1 ton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 RE- DS 3,.4 (11-13-110-.15) DS 4-10 "(33-27-11-15) NGI #7 (11-12-11-14) Dear Sir: Enclosed are the.Well Completion Reports along with the Well History and .Directional SurveY for the above mentioned wells. Very truly yours,, C. R. Knowles District Drill ing .Engineer CRK/jr Enclosures Form P--7 ,) SUBMIT IN STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE I WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: on, J~J t~As WELL WELL ['--] DRY F'--] Other b. TYPE OF COMPLETION: · --~ ~ "o',1-1 D--P-I--1 PL~,I--I D'--.F--) ovrm z.~ Othe,Suspended W ELI. hACK RESVR. 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOIt P. 0. Box 360, Anchorage, Alaska 99510 .. ..... - ,~.? r-.. ~. LOCATZO,~ Or: WZL~.-~(Report location clearl~ and ia accordance with an~ $~ate requirements)* At su~ace ., . ~ ..' ~. 442'~ ~ 667'~ of sE cr Sec 27, Tll~-~ldE,~ At top prod. interval reported below ~-' ....... ,, ~]~[~ 1329'~ of SI cr Sec 27, 111~, R15[, ~g ' 1317'N & 1408'W of SE cr Sec 27, TllN-R15E;' ' . ,.'..UM.':i!' ': . . .. 0~her in- sl ructions on reverse side) 5. AlmI 1N'Ub~ CODE 50-029-202]3 6. LKASE DI~IGNATION AND S~ NO. ADh Z8325 8. UNIT~F~ OR ~SE Prudhoe Bay ' · '1 · ' P~dhoe Bay-Sad]eroch~t Po I1. }8~C., T., g., ~., (~O~ HO~ ~ O~IVE) Sec 27, 111 ~-R15E 12. P~IT NO. 76-42 5/6/76 16/15/76 'I7/28/76 ~""52~KB I 18.. T~ ~1'~, DRILLED BY 54' & 8941' 064' & 8857' S Y' . ,~,oo:. Ngne ~. ~O~gCI~O I~'r~A~(~), O~ '~ ~.~-~~, ~0~, ~ (~ ~ 'rye)' J:. ~AS gI~O,~ None 21. ~z z~c'rmc ~n o~ m ~ ,I ~OS DIL, BHC/GR, FDC,/CNL,,/G,R, CBL/VDL/GR/CCL CASING RECORD (Report all strings set in ,.veil) cAsmOs,zE Jl,b/ft-.thd'"l["G~- j n~'msET.(~, J .o~s=E 20" 194#-Vet~o 'Jrt-,40 ~_80' b,e)Pd'130" 13-3/8" J72#-Butt' / N-80 I 2692 . 117~ 9-5/8" 147#-Butt I MN-801 8541 'i 112~. ,l &ls- s i i'I ' ~. LINER i:LECOi:II) . SIZE 'I TOP(MD)' [ IBOTTOM (MD) J SACI~S CEM~TT. 7" 8235' ' 9149' 250 sx ' ' (Interval, size and number) NA DATE FIRST PI%ODUC'I~OI%I NA .TUBING ' 31'. DISPOSITION OF PRODUCTION CEM:.~TI:brG RECOit.D I AMOD-NT pUrl.ED 'Approx 500 sx PF II 4900 sx Permafrost II cml; 1750 sx Class G cmt 12nd sl;~qe w/275 s~ PF II I J 27. TUBING i~I~GOI%D '. SCREEN(MD) [ SIZE [ D~SET(M?/ ' PACKER SET (MD). . 5½" 8113' 7972' i 1, 29. ACID, S.iIOT, F?x4~C'I'LTRE, C~M. ET~TT SQUEEZE, ETC. DEPIt-I Ih'TERvAL (MD) NA pRoDUCTION METHOD (Flowh~g, gas lift, pumping--size and type of pump) HOURS TESTED 'JCHOXE SiZE JPROD'N FOR OIL--BBL. GA..%--i~CF. 'r 1 1 A.MOUN'£ ~'d~lD I{/ND O,F MATeR/AL USED 32. LIST ATTACHMENTS B~'ill. lnn Fllcfn~-v and B(t-arf(nnal 88. I hereb~ ee~tff~ that ~hFfore~ol~ afl4 ~t~e~eB-lfiIOr~afl6n'fi eom}lete an~ correct am determined from all:avaflmble records SIGNED TITLE DATE *($=~ I.**m=fio.= ~.$ $~=~, Ior Ailifio.~l D~*~ o. R~r~ ~) J WELL STATUS (Producing or ' r. nut-in)' Unnert~oratcd Cnmol P. ti01 I , i General: This form is designed for submitting a complete and ccrrect vve~l comp!etlon report end log on all types of lands and leases in Alaska. . Item: 16: Indicate which elevation is used as reference (vvhe,'e not otherwise shown) for depth measure- ments given in cther spaces on lhis form and in any attazhme:~,Is. . Items 20, and 22:: If this well is completed for separate- prcduction from more than one ~nterval zone (multiple completion), so state ~n item 20, and in item 22 show the p~cducir~£~ interval, o: ~n~e, vals, top(s), bottom(s) and name (s) (if any) for only the interv,J! reported in item 30. Submit ~ separate report (page) on this form, adequately identified, for each additional inte, vol to be seperately produce.d, show- ing the additional data pertinent to such interval. It®m26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 21i: Submit a separate completion report on this form for each interval to be separately produc~l. (See instruction for items 20 and 22' above). 34. SUMMAIt¥ OP FO~TMATIoN TF.~'I'$ IN¢'LUDIN(; INTERVAT-T~STED. I'H~U~E DATA ~ ~OVERI~ OF OIL GAS. 35 O~Ol~ MARK~ WA~ AND MUD MEA$ D~i r ~ k~ V~RT' D~ Top Sadlerochit 8668' 8490' Base Sadl erochi t 9050' 8845' , . '" 36. COI{~E DATA. A3'FAClt' {I~I'EF ~¢~'(~S O~'~.I~IlOLOGY PORt, TV. AN'~. ~}~}) SHows O~ OIL, .. ............................................................ ATLANTIC RICHFIELD COMPANY DS 4-10 (33-27-11-15) ..... ;....¥~. ,....~:. ..... API 50-029-20213, ADL 28325, Permit No. 76-42,..-.:....i' Drilling Hi stor}, Spud @ 0430 hrs 5-6-76. Drilled 17½" hole to 2700'. Ran 13-3/8" 72# N-80 Buttress csg w/shoe @ 2692' and FC @ 2615'. Cemented 13-3/8" csg w/4900 sx PF II cmt. Washed and blew dry 13-3/8" x 20" annulus thru 2-3/8" riser. Landed 13-3/8" csg, cemented thru ruser w/150 sx PF II cmt. NU and test BOPE. Drilled and surveyed 12-1/4" hole to 5640'. Directionally drilled 1~-'' hole from 5640' to 8564' RU and ran 9-5/8" 47# MN-80 and S-95 Buttress csg w/shoe @ 8541' a~d FC @ 8454'. Cemented w/750 sx Class G cmt. RIH w/8½" bit, drilled cmt 6429'-8423', pressure test 9-5/8" csg w/2500 psi. Drilled cmt, FC, shoe and cT6-~'6~""'6'~i'i: to 8564' Established circ around 9-5/8" shoe to surface. RIH w/E-Z drill plug ~nd set @ 8425'. Cemented 9-5/8" shoe w/750 sx Class G cmt. POH. RIH w/RTTS and shifting tool, opened lower FO @ 2471', cemented w/275 sx PF "C" cmt. Closed and tested FO w/3000 psi. Opened upper FO @ 2347', washed 9-5/8" x 13-3/8" annulus, pumped 292 bbls Arctic Pack w/final returns 0% water. Closed and tested FO w/3000 psi to 8564'TD. Tested formation to ll.5#/gal gradient. Ran CBL/Temp log showing good bond 8340'-8360'. RIH w/E-Z drill retainer and set 94' above 9-5/8" shoe. Tested cmt job below retainer to 2000 psi on 11.5# mud. Tested csg to 2000 psi and reversed out hole to water and.:.water to Oil Faze mud. POH. Drilled out retainer, cleaned out junk to 8670'. POH. R~H, cont core #1, rec 6,0'; Core #2, 8731'-18749', rec 18'; Core #3 8749-8776', rec 22 , Core #4 8776'-8836' rec 60'; Core #5 8836'-8871', rec 25': Core #6 8871'-8926', rec 35';, Core #7 8926'-8986', rec 59'; Core #8 8986'-9046', rec 60'; Core #9 9046'-9082', rec 35'. RIH w/8½"" bit and drilled to 9154' RU and ran 7" 29# MN-80 Buttress liner w/shoe @ 9149' and top @ 8235.'. C~mented 7" liner w/250 sx Class G cmt. RIH w/8½" bit, tagged cmt @ 81~15.', drilled to liner hanger @ 8235' .RIH w/6" bit, cleaned out cmt stringers in liner from 8650' to 9071' Ran 7'~ RTTS to 9020' and pumped thru 7" shoe @ 1600 psi. Tested lap to 250~ psi - OK. Ran 6" bit.-)~ and cleaned out LC @ 9071' No cement between LC and shoe,'.'drilled out shoe. Ran CBL/VDL/GR/CCL. Made ~it and scraper run. RIH and set E-Z drill @ 9124' .on WL. Spotted 200 sx of Class G cmt. PU and laid 57' plug on top of E-Z drill. RIH w/6" bit drilled cm~, pressure tested csg @ 3000 psi POH ' Ran and set ~aker Model "K" Bridge Plug @ 9064'. 'RIH w/RTTS and set ~kr @ ~123. Open tool for 3 hr test w/slight blow 1st hr. POH w/DST tools. Test tools failed mechanically. RIH w/DST tools, set pkr @ 8184'. Opened tool for 3 hr test-had light blow for 50 min, dead balance of test. Close for 1 hr. SI. POH w/50' net rise. RIH w/6" bit and.'7" scraper to 9064'. Displaced oi'l base mud w/lO.8 calcium chloride wtr. Changed and tested BOPE rams. RU and run 5½" completion assembly w/packer @ 7990', RQ nipple @ 2196' and shear sub @ 8132'. NU and test xmas tree. Pulled and rerun dummy valve. Dropped bali and sheared 2/3350 psi. Pressure test tubing and 9-5/8" annulus. Tubing pressure dropped @ average of 3 psi/min w/annulus holding. Continue pressure check w/no commumication between tubing and 5½" x 9-5/8" annulus. Ran GO International noise log which indicated possible leak opposite 9-5/8" shoe. RU and pulled 5½" tubing. Recovered PBR and Baker pkr. Ran temperaturelogs to locate fluid leak w/no results. Ran WSO test on liner lap, test okay. Set RTTS pkr @ 7983' with acid below. Pressure dropped from 3300 psi to 2600 psi.in 15 min w/fluid loss @ 1 bbl/hr rate. eted acid, ._s_q_~ueezed_.a.w~a~ lb BPM. Squeezed lap w/65~x Class--G- cmt. uFe tested w/3000 psi, 6k'~. Ran WSO test, liner lap leaked. Attempted squeeze diesel and acid w/very little fluid movement. RU and shot 4 holes 8537' 8538', and 8531-32'. Set E-Z Drill @ 8450' Squeezed shot holes w/200 sx Class G cmt. Would not hold pressure. Resq~eezed thru E-Z Drill @ 8435'. w/200 sx Class G cmt. Drilled retainer @ 8435' and cmt to 8538' Pressure tested perforations w/3000 psi. Bled to 2770 in 2 hrs. Ran RTT~ and pressure test liner lap w/3000 psi okay. Set E-Z drill @ 8335', ran WSO test w/packer setti.ng @ 8193'. Liner lap test okay. Drilled retainer @ 8335' and CO to 8600'. Ran WSO test w/packer @ 8193' Opened tools and had very little blow then dead balance of 1 hour test. Drilled cmt and retainer to 8602', CO to 9068'~ Ran 5½" 17# 8rd LT&C (A-B tbg). Set SAB pkr @ 7972', RQ nipple @ 2163', and shoe @ 8113'. ND BOPE, NU and test xmas tree. Set packer, opened sliding sleeve, displaced tubing w/diesel. Closed and pressure tested sliding sleeve. Set dummy valve in RQ nipple and test control lines. Ran GR/CCL and dummy gun. Released rig @ 2400 hrs 7-28-76. ~ I~ l Eastman ~ ~ Whipsto¢l{'l )~ A PEIRO~N£ Ct~PA3~ REPORT of SUB-SURFACE i"' DIREC TIONA L SURVEY ..... ,,. Atlantic Richfield D. S, ~-10 COMPANY Prudhoe WELL NAME LOCATION JOB NUMBER A576 S0129 TYPE' OF SURVEY Multi-shot DATE 8-6-76 SURVEY BY Shyam Talwar OFFICE Alaska // m .--?TA-GNETIC-qqUL'T I'~.$HOT SURVEY' -~ -R-A-DTU$--OI=J-.' CUR VAT UR E' NETFTOl~F--~3Tqq~U~F~ I ON -: COMPUTeD-FOR EASTMAN WHIPS'TU~~'~,-~F, M';' LIND.S~Y AND A$$0CIA-'r~$' ~'~COR'~ OF' s'uRVE'S' ~ A L L ' C A L C U L A 'r 'I o N 5" P ET-~--F-O'R-R-E-D---B-~-'-i~q---ff L ~ C T R O. N I C CONPUTER- DffiF$ IOTA[.. CUONI.).INAI~ C 'L-I~-.~ $,13--R- ~2--5' 5~_~I-1~' .S'F_~T-IO]N D-IR'_~C' D I'-,.qT'ANCE. -A-N-G'iZ-E- ........ D' F..-c~/'S'O-'O-F-Y-~-' 'b- I-' "~"{N-C-~' ---26'5--0 0 0 2-613'O'OO.. 2598,00---S-I]~,-,00E - 15DS.13.iN ' 324,'69 W [5-gg'~-N 1'1 56 3-2 W 0,000' 2'75-~ ' 0'~1.5~ -~?~b,:99 2698,99~ S15,00E 1534,91 N 324,63 W. 1560,87 N- 1"1' 56 ~1 W ~ 0,2'48 2939 0'-. ~ 2938,~g 288.6,99--S25,00E. · 1534,05:'N. 1535.10 - 31~-~---1''~ o ........ 3-2-2. t 0 55 3TiZ 1' 0 ~,b'Zcf~ 1- 10 3~0~.93 ~5-~2 [----0 350'1.91 .... .... ]-e;-~-O?---0--zT0---~% 8-8-8-,--8'9 .--T-.. ~-&-3% , 8. 9 sT-9%-b-0'E 1 ,. ~'7-~----0-55---' 3~77-, 8-8- 3825 · .~032-'~98 "2980.98; 518~0-0~""~533..,03. N 3].'~-7~'3'-o?~z+-.~--/ ..... Sz,;W-.'O'O'E--'~Y£~TF9 ~.,.: N 3'220,96 31.68,96 S35,00E 1530.71(N 33'1'4,9'5 3262,95 S 3,00E 1529,23::N S33,00E 1527,55~ N S-'/5-.-0-0'~---i-5-2 5.91. N 524, ~... N 52~,0'1 522',05. N 5'2-0,90'N 321.21 W 1562.60 N 11 51 ~4 w 0.07~ 320.66 w i960.~5 N 11 51 19 w 0.181 320.10 W 1559';'~2'N I1 50 51 w o,183. 0.075 153o.10' ; 152~.60 . 1526,6.5 !- 319,73 W 1557.z~8.N 11 50 46 W 0,296. N 319,38 w 319,40 W 15'21.30 319;66 W 1554,13'N 11 52 11 W 0.453 ____i ....... 3-9'-T2;=b 55' 3971.86 3919.86 ~oR~ '0-;40 ~065.86 4013.86 -~--~v160 O- 50. '4'15-9,8-5 4i0-7.85 -Sll.OOW '- 1519,~1:N 320.00 W 536.00W 1518,22 N- 320.52 W S 7.0OW: 15'17,03 .,N, 320.97 W 4264 0 40 4.263.84 4211.84 S 4.00E-. 1515,71~iN> 321.01W ~.~8---0'--15 z~357,83 ~305,83 S41,00W-' 15:15,01:~ 321,2~ W ~5i" 0-15 4450,83 4398,83_. S. 6,O0W 1514.64 N 321,4. o w' 45~-5'--0 0 4544,83- 4492,83 S22,00W'- 151.4,45:NI321,45 W 1552.7g-N-ii 53'36 W 0.069 1551,~8- N 11 bS: lb W 0.277 1550.66' N-ii 56 *6 W o.l~._~__ i5!_7..39 i549,33 N-ii 57'28 W 07_1_63: 1548,~.9._.~1. 11' 5~ is w 0.447' _i54_'~__.92 .... !,LA.i_. .... 5.S____~t_V___!,,__o, ia2 . __._:]._.5.~5. 15, 4 ~. 19._6..__1_! .... ~ 9 .... _1_.'3'~ ........ Q...__2..66_,____.1_.~_1_. ~...,_.l~_j .RECORD OF.-SURYE'Y ALL -C. AL'CULAT:[ON$ PERFORMED .BY I B M,i.EL~ECTRON!C COMPUTER. i TRUE :,';'-'-D-~--i'-FT VER.T ! CAL SUB ,DR ! FT TOTAL _COORDINATES -H ANGLE D_EP..T: H D ~ SEA D [ RF:..~ ... ' -DE.(? ' C L D__$_U R___E__S ........... D.I ~'i'AI"-ICE . _A~.GLF . .D __.gL .... S DOG LEG SE~E~I]LY_ 5.E_C3!0~ DEGA!O.OFT, 78 0 10 .~6~'-7,8~. ;/-'--0-To---~.3 b. 8 3 _6 .0 15 4825,8~ .4585,83 S22,-00W .1514,32 N 4678,83 $57,00E .477~'-'~'3 $ 9,005-1513.79 .N ____ S 5..OOW 1513.!8 '0 .0 ~0 ~91-9.83 %----0 30 5b~13~8~3 ~6961.83 ',-~ 0 30 5107,82 5055.82 321.50 w 15~8.07 '321.43 W 1'547.82 -32~, 24 W 1947.50 'N B2!.22 W 15.46.90 $'5,00W'' .~512,.~.6 .N 321,29 W 1546.11 $ 6.,OOW 15]11.5~ .N' 321.37 W 1~.5.33 ;'I'---0 30 52~-.0.-82' 5~1-~8 · 82 5'57. OOW 15 !,0.87' 'N' 321,78 W 1544.76_, !51:0;27 :N 322.4`3 W 154f+.'/0 15.0'9.~9 N 323,21 W 154~.71 15.08,50. N 32~,13 W 1'542 t507,5.1 9 0 -2 0--55 6 · .93 N N 11 59 11 W 0.1~3 . l~15',__08_ N 11 59 8 W 0 · 233 ..... __1_ _5.._1_~__'-8_~_ N 11 5~ 6 w N _1___1___._5_9_..3. _~__w_ ..... 12 i 23 W 0.463 lp_1.2.,.~05_ 12 3 5_ ?,' 0 · 0.9_~ .... 15.13.__._75_ 12 5 ~ 12. 7 36 W 0.194 '-5294`,18-2' $-Zz;2.82 537.00W b388,,81 5336.81. "'$'-5-3,0.0W---- 54`-+81,80 5429,80 $3~-,OOW' ~'--14` 35 603?-;'-7-%-- 5985.76 N4`7,00W .'"8--~6' 20"~6:["2-'8--'~~~'-----~-'~7-;"O-Ov'gT-'-~.f566,53- 5 21-~0 6304,95 ~252.95 N4`6.50w 1608.24` ~--2~ ~0 $39~,25 6340.25 N45.50W 1632.~ -2-~-1---i'5 647~-J8~' 6426,80 N4`6,00W 1656,!8 5 ~1 45 6565.33 65i~-~'33 N47,50W' 1679.53 .N '325.~3 .W ' 1542.22 N 12 10 ~_~ ...... . N 329,08 W 1542,92 .N 12 18 5'4 W 2,646 N 337,11 W 1549.~5 N 12 33-:~'~ W-- 4.560 -,, N 347,58 W 1561,53 N 12 51 41W 2.226 N 3 ~0';% ~ -~ ..... £5'Y~]-~i'"-f--i'3 ..... ........... N 3'76,51W 1594,53 N 13 39 29 W 2,b74` 1569.44 .N 39~.84 W 1615.b3 N 14 8 .48 W 1.862 lb92.48 N 415,67 W 1639.36 N 14 41 17 W 3.044 N 4~9.75 W 1667,28 N-15 17 34 W 2,844 ~ 464,81 b 1697,32 N 15 53 36 W 0,232 N 489,1 ~ W 172'~-~i--'~'"i-6-'-2'7 .... 19 W ........O. 457 1.'%% Z_,_~.l__ ................................................... N 514,00 W 1756,43 N 17 0 58 W 0,581 539,26 W 564,94 W 1786,42 N 17 34 11 W 0.178 1775.75 1817,4,9 N 1~ 6 35--iii ......... (~-~'~3-9'5 1-8-0'8-,-~'~- 590.3,. w ~8~.~-1 N ~ ~7 2~'-W o.~dS-- ~'~-b-J~-3~ 615;1'7 W i8'79.89 N 19 6 4 W 0.29~' 1673.48 639.39 W 1912,19 N i'9 32 4-'-'W 0,415 1906.81 .......... ~63,74 W 1943.95 N 19 57 92 W 0,691 1939,51' _._ 688,84 W 1975,97'N 2~ 24 8 W 0,668 1972,42 R'E C Dr~)--OF'--5-U'RV E Y 'A-[E--C-A-L-CCllzxTro'N~-P-EF4'FO-R74./ED--BY'--I- B N --E L~ CITRON I C C TRUE DRIFT VERTICAL SUB DRIFT TOTAL COORDINA. TES DOG LEG C L 0 $ U IR .IF. $ SEVERITY ,SECT --DEPTH ANGLE .D EiS'T H SF_A DIREC ..... 0 ' M 'DEG. ~-- DISTANCE ANGLE DEG/1GOFT D M S 7~"5'/+---2'2-- 0 7-2-~9 · ~9 Y207-'J'4-~ N44.00W 18-7-'/.66 "---7~4~~~4%i-8~~--J~%'50W ':i. g-O-F, 10 7542 20 35 7434.67 7'~'P..2.67 N41..OOW 1928,33 7636 20 10 7522,79 7~70'-~-9 N4X,5.0W 1952,9/+ ' :- 7731 20 15 '7611.94 ~'.5-~'§";-9~+.N40,~0%--~---19~1 ' --~-8- ~. 4---2-i-----6---~' 6-9-6' ~'-9-i~ ...... %6'Z+ 6'.-.~ ..... ~ :~-9-;-5-~) W 2002,81 7918 20 0 7787-~"~3 ..... 77'3~'-6~--~]~9.00W '2028,~0 --8012 20 ~0 7875.17 7'~']"~7 N37,00W 205~,05 8105 ~0 5 79 ~ 2~'-J~ ....... 7-~'~-'0-, 3 ~ N~9,OOW 2080,2~ ----713.61 w 2008,70 N 20 48 34 W 0.628 7:37.13 W 2040,87 N'21 fO 22 W 0.871 759,26 W 207~2,4~--~<1- 21-'--~9---~-9 W 0,705 780,84 W 2103.2~ N 21 47 3~+ W 0.451 802.37 W 2134,28 N 2;~ 4 58 W 0.152 82~,43 W 2%65,-4-~-'-~'-2 20 57 W 844.26 W 2196,99 N 22 35 5& W 2228,50 N 22 49 19 2038 ,-'~ ' 27 .92 .... 2196.4~ .... ......... ~:~ I9 ~, .... 1'9 -~0 ......... e'o~+~. ~ 5'- ? 997 .a S ....... N~ ~-;'0'0W ........ 2"1'0-~ ;'~'5-- i;~ .......... 90['.'01 ..... W ........... 22'9'0,9'~/-'N'"'Za ....... 9-3 ~ '~'~-~'9'~-20 0--8138.~2 8086,32 N33,OOW 2132,99 N 918,3i W 2322,27 N 23 17 35 W 0 · 7&O 2228.i~ · 678 2190.~1 W 0,532 2~22.17 ''-'-'gf~-'~i-6--2-0'--1-0---~-2'2'-6~'~0 .... :~-~74'J6o N32.00W 2160,21 N --8z~8o 20 ~'0 8~%'z~';,",'4 .... -8262,'7-~ .... N~I.OOW 'L~l'-~-7.91 N 8-3..-~'4--2050 83-9-73-.~2 tt-.~41.3'2--N.~0.00%¢ 2213.43 N · 935.~ W 2354.14 N 23 25 8 W 952,97 W . 238~,~4 N 23 32 9 W 957,19 W 2394.45 N 23 33 46 W 0.916 2415,91 N Z~ ~7 29 W 0,~47 968.16 W 0.221 0.351 2.354.08 '---DATA B6TWggN 8-6_-6-~--2'].--I'0---8 4--8-"3-78-'7' .... 8'4.3-1%8-'T---N2-8 ,-;-0-~W 2 24 ~'%' d 4 8~7~-$--Z l- 30 ~.STz;.%'2'2---~'5~2-2-;-~2---~J~50W' 2-275 · 0.7 B"8--~3. D 0 BY)"6'4',-'3 7 ...... 8~,I'2-; 3-T---6T2-6--,-50W---2-$-0-6%-9-9 " '~"g'52T'-'22--1-07 .... 'S75-A-;--2,"0'---.~T02, ~0 .N2'~";UOW"---2-~-~-~--72 ~~-9"'"'"'2~2'""2"~8.8 ~i-Z,.-4.-,-'r~ $-~8'79~2':-O-~"'~,~'2-N-;-'6'0'W 2 :~7 '~-%-.~4 22 45 8940~-99. ~888.99 N2~..,O0~.~' 985.02 IO01,45 ' ~-0-1=.-~'. 71 N 1033.50 W N 10~8.76 W N 10~4.85 W W 2450.53 N 23 42 ~W 0.4~4 W £52~.~0 N 23 ~8 1~ W--0.378 25. 25~7.81 N 2~ We'"~'~W 0.40~ --2~7'.82' 299~,62 N 23 50 29 W Q.307 2594.6'-~ 2634,96-N: 23 50 10 W 0,~36 2634,96 ......... ~'~ET AT-.N' 22, 5-0 10 'V'E~y-i~C-^L~ DEPTH' TOi';A%- ' ¢OORD ~ NATES ._C L O_~~,L_E ' 5.U.B. · D Z .5,T6 N .c:_~%_.__~_~.' ~.,LJ~ ......sEA D r,~ ,5 2453°05. N 23 ~2 19 W 8~38.40 9050' 90'84; 8844".'9? 2373.5'6 2378~45' ~0z+8.92 V¢ 2595.00. N 23 50 29 W 1_."0~53.~,09 W 280¢.35 ~',i 23 50 3-0 W 8805_...?_~. "!EAS~J. RED*DEPTH AND OTHER DA.__T.A.___F'._.O_R_'~_V_~'.i~'--I~-'-E~ _~'.FF'ET OF _.5~__B._~_E_A..__D_E_P__T._t--t. - · · ,, " 'TR__U_E MEASURED' '-VE'RTICAL SUB--I,,D-TVD 'VERTICAL DEPTH DEPTI,4 ,SEA DIFFERENCE -..CORRECTION TOTAL COORDINATES 1"'52' t52.__ 100 0 -0 ~ 153~.1'3 N _3_2_4.,_6_9._W 252 .252. 200 0 .0 3 5 2 3 5 2 · ~ 0 0 0 .0 4.52 4,52, 400 0 -0 1535,13 N 324..69 W ~ ............... 5.52 . -552.. 500 0 O 1535.13 N 32~+.69 W ................. 652 652'. 600 0 '0 1535.13 N 524.69 W 752 752, 700 0 0 1535'. 13 N '8.52 852. 800 0 0 1-'~-3-5,i3 N--32'4].69 W 952 952. 900 0 Om~ i 1052 1052, 1000 0 0 ! 1152 1152, 1100 '0 0 1 1252 1252, 1200 0 0 1 ~352 1352. 130'0 0 .0 · I 14.52 1452. 14.00 0 -0 i 1552 1552, 1500 1-6-52 1652' · 1600 17'5-2 17'-5-2- · 1700 1-8-5-2 1-8-5-F,----[8-00- 1'~5'-2 19-5-2-T--'~i-9-0-0 20'52' 2'6F5'2' ;'" ..... 2000 .............. 0 23.52 2152. 2100 0 2'2-52 2252".------f2-60' ........ 0 2352 2352.--2300 0 2452 24.52, 2400 2-5-5-2 25~-2-.-----2-~'0-0 2652 265-2-~- 2~'0'0-- 2752 2752-. 0 1 0 '1535.13 N .0 1535,13 N 535.13 lq 324,69 W 535,13 N 324,69 W ' 535,1'3 N 324,69 W 5 3 5.1 ~ N .. 535.13 N 32~.69 W 535,13 N 32~,69 W ...................... 535.13 N 324.69 W 32~.69 W " -0 1535,13 tN 326.69 W o .................... 15'~ ~ .-f~--i~ ............ 3 2 ~. 6 9 w C 1535.13 N 326,69 W 0 1535,13 N 0 1535.1-3 N -0 1535~-13 N O 1535.13 · 0 1535.12-N -. 3~,91 N 0 0 !5 2852 2852. 2800 -0 O 1534.60 N 2952 2952, 2900 0 0 1533.90 N 3052 3052, 3000 0 0 1532.84 N 5-1-~'2 3152, 3100 0 .0 1531.61 N 3252 3252, 3200 0 0 1530.27 N 3352 3352. 330'0 0 0 1528.57 N 3452 34,52. 3400 0 0 1526.80 N 3552 3552.. 3500 0 0 1525.05 N 324,69 W 324,69 W 324,69 324,~9 %%' 324.68 W ........ 329.63 32~.3~ W ........... 325,72 .......................... 323.32 W .. _ 322,43 W 32!.47 W 321~10 W ~. ~0_._2 ?_w 3.!%..':?..6.. w MEASURED VERTICAL SUB MD-TVD 'VERTICAL DEPTH DE~TH SEA DIFFERENCE CORR'ECT I.ON TOTAL COORDINATES , 3652 3.652. 3600 0 -0 ~ 3~9.47 ;3752 3752, '37.00 0 1523.47 1522.34 3852 .3852. 3'800 0 .0 3952 .9952. 3900 0 ..~ 1519.7~+ 4052 4052. 4000' 0 0 '151~.36 N 4152 ' 4't52, 4100 -.0 .¢ 1517.20 N 4252 ,4252. 4200 0 :0 1515;~6 N 4352 4'3'52. ~300 0 -0 1515.03 -4452 4452. 4400 0 .0 1514..64 · 4552 -45512.. ,4500 0 :0 1514.44 ......... 4652 4652. 4600 0 0 151~.2B N · 4~-52 4752.--4T00----0 ,0 151~, 03 N 319.35 W 319,94 W ._ 320...._.(.Lg W 320.95 p," 3_g.k.__O.2._.W ' 3_g ]._,_Z2.__W __j..~_;~.aS_.~, ................ 3_2_..;L.....~_W ................................... 321.38 W 4~52 485Z. 48'00 0 ' tO 1513.66 N ~952 4952. 4900 '0 .0 1512.90 N 5052 505'2, 50.00 0 -0 1512.03 N '5152 5152, 5100 0 .O ~511,1~ N -5252 5252. 5200 0 C 1510.59 N 5452 ~952, 565.2 5352. 5300 0 0 1509.80 0 '0 '0 ' 322.14 VC ................................. 322.85 W .-0 '5652. 5600 .0 '0 .l?.~!~...._~.~__._?,.;' ....... ~.~..~: u ~...W .............................................. lb07.70 1507.26 N 32~J,04 5753 5752. 5700 ~0 -0 1511.38 N- 5852., '5~00 1 1 1522,02 N 5952, 5900 ~ 2 1535.45 N '5854 '5956 335.95 W 347. I z~ '.,': 361.51 W :6059 6052. 6000 6 -- '3 1551.99 6163 6152 , 6100 .10 4 ! 571.. 3~ · 6268 ,6252, 6200 16 6 ~376 -6.352. 6300 '24 8 159~,32 N 424.76 162.1,36 N 453.21 6483 .64.~2. ..... ~-4-~b 3'1 7 6552. 6500 3:8 6~'f2-. .... 6~00 4% 481,51 W 1676.01 N 510,02 W · 1703.05 N ~39.26 W 6806 6752. 6700 6914 6852. 6800 .6-1 ,. 8. t730.83 N 568.43 W 1758,83 N 597.57 W 7022 6952. 6900 70 9 '7130 '7052. 7000 '77 7 1~-17.37 N 1787..82 N 626.05 W 653 · 70 W "'~MEA-SUR. E:-D DEPTH .AND',OTHER .DATA --' F O R -E V _~ Y 'E V E N. 1 O'0 ..:F E E'_T._._O'F .~L8 _ ~ E_kA__D_E_ P_TJ:i., .... ,, 'TRUE ' MEASURED VER'T!CAL SUB ND-TVD 'VERT!CAL DEPTH ,DEPTH ..SEA D'IFFERE;',!CE CORRECTION TOTAL COORDINATES 7238 7152, '7100 85 7346 7252, 7200 94 i I 7453 7352. 7300 101 7 ...... ~_9.~,~6 7560 7452. 7400 10.8 7 1933.10 N ·. ._ 7667 7552. 7500 115 7 1961,03 N I ..................- 7774 7652, 7600 121 .6 1959,17 N 81i,91 ~St~ 7752, 7700 129 8 2018.'37 N 7987 7852. 7800 _682 ,__7_~_.__~'Z 71.L, 50 .... ~'i 763.40 W 787,83 W 8094 7952, 7900 142 6 20~+7,05 N B'bg.0~+ W --~- .-7 2077' lB N 881.-~-~'-~--~ $ 'i · 8200. 8052, 800.0 1~8 6 2106.91N 8307 8152,'' 8100 1SA -6 2137,17 N 8413. 8252, 8200 161 7 21~8,12 N 8~20 83~2. 8300 167 ' 6 219~.90 N " 8627 8452, 8400 174 8734 8552, 8500 ~+2-- 8652° ~500 ~9~+9 875.2, 9-0-5'-8 8-~-2. !82 7 2233 · Gl N 901 ..36 w ' " 921,02 W 940.60 VI ,. 960.24 W 99..7.,A! ,8.0 7 2302.68 N 1015.25 W 8700 197 8 2338,76 N 1032.87 W 8800 2o-5 8 2376-,-fi-~i---- ~ b"5 b' J~-o-':~ ........... ",a " ~,4, ~,~?u~.6-~ ~o VALUES. FOR D-E-P-T-F[ 'D~I--I-- SEA- TOTAL COORD ]NATES loob looo~ 94~. 15S5.i~ N~' SZ~.69 2000 2000, 1948, 15~5.13 N' 324,69 -~'0.00 2999, 2947, 5000 4999, 6000 .. 4947; 5995, '5943, 1518.99 ,~ ~2o.ll w 151'2,48- N 321.2~ w 1542,17 N 7000 69~1', 6879. 2050,67 N 861.81 9-0-0-0 8 ?-9%, 87 ~ 6 '. 2356,21 . ~ .... ' .......... ~j-y'-.- ..... : .............. ~ ............. ~ ......... 4 ............. t HOEI ZONTAL'.j~IEW. ............... :' '. . _ _' .... ; _.~ ............ l ............. .: ......... L ................ { ................. L__.. _--,,, .__~-,. ................... t- ........... ~ .... ! ..... i ....... ! I : t ,' . . 5UALIr_.. I .: DUU .................. t----4----- ...~ .... ~`~--....:~;~;;;~-'```.~--;-~-~-~.~-~;~--~.;~[`~``-.;-~-~;~.E;~;~.~;~;~; i-';~- :"-.;..~' .--'-- ;;--~---'~-;--'-.; . ATLANTIC--RICHFIELD cOMPANY ~- .... I ~ m - 'i ..... ; ' ' ' i .... '~ "; ........ ;'{ ....... : ........... t ..... ;' .......... 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'.i~:. i'~,I~ --T--...~ .............................. ~ ............... t ........~ ................................................... . ........................... ~ .......................... ...... : ............... : ...... ......... ....... ..... To: AiLANTIC RI~.,i~[,'IELD COMi.'ANI jqrth Alaska District Engineer" CONFIDE I)~STI~IBUTEI) TO: T R A N S M I T T A L STATE ()F AI~ASKA DIVISION OF OIL & CAS From' J.A. Rochon/W. Toliver Date' August 4, 1976 Well Name' D.S,# 4-10 (33-27-11-14) Transmitted herewith are the following for the subject well: Run No. Scale Xerox Sepia BL Line '1 / 1 1 1 BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL 2"~5" 511 511 Compensated Fomation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro Single Shot Eastman - Multishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Gamma Ray/CCL Laterolog ' Location Plat Microlaterolog Micro log Mudlog- Interval Sample Log (A..R.Co.)-Interval] Synergetic Log T~q)-DIL TVD-Porosity Log BI{C Sonic/6R 'Cfirst tool]. ('-,~..c, ,.lo: . C;,,.~., //a,- f_~?v A576 S0129 11 5II Receipt 'Acknowledged For' Date' Please return receipt to' Atlantic Richfield. Company North Alaska Engineering Manager . P. O. Box 360 Anchorage, Alaska 99510 AtlanticRichfieldCompany .~' North An]eri.r.~ P;'o(iucing Divisiul, North Alasl,~' strict Post Offic({. x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 12, 1976 Mr. O. K..Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 : ]l-13-10-15), Permit No. 76-51 33-27-11-15), Permit No. 76-42 1-12-11-14), Permit No. 76-38. Dear Sir' Enclosed please find the Monthly Report of Drilling Operations for the above mentioned wells. Sincerely, C. R. Knowles District Drilling Engineer CR'K/BDR/jr Enclosures JUL 1 -1976 DIVISION OF O.It. AND GAS 1PG~ No. P--4 ~.EY. 8- I-?O STATE OF ALASKA OIL AND GAS CONSERVATION COMMIT'rEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WILL WELL 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPEI:tATOR P. O. Box 360, Anchorage, AK 99510 SUBMIT IN DLTPLICATE bODE 50-029-20213 6 LEASE DES:GNATION A.~-D SERTAL NO. ADL 28325 IF INDIA]4'. ALOTTEE OR TR1BE NA)~E 8. L.~IT F.~-RA{ OR LEASE NAME Prudhoe Bay 9 WELL NO DS 4-10 (33-27-11-15) 4. LOCATION OF Wl~-T-T- I0. ~F~D A_ND POOL. OR WILDCAT 442'N & 667' W of SE cr Sec 27, ~~ROEE ~ ~~~Prudh°e~ s~~~Bay-Sadlerochit(~o~,,o~ Pool ~UL. ~. ~ ~97~ Sec 27, TllN, RlBE 1~. P~IT NO. DWISlON OF OiL A~g ~AS 76-42, '"13. R~ORT ~TAL D~ AT ~D OF MON~. C~NG~ IN HOLE S~~~ C~NG JOBS INCLUDING DEPTH ~T ~ VOL~ USED, P~ORATIONS. ~TS ~ ~SULTS FISHING JO~ J~K ~ HO~ ~D SIDE-~CK~ HO~ ~D ~Y O~ SIGNIFIC~T ~G~ ~ HO~ ~ITIONS. Report on operations for the month of June. RIH w/8-1/2" bit, drilled cmt 6429'-8423', pressure test 9-5/8" csg w/2500 psi. Drilled cmt, FC, shoe and cleaned out to 8564'. Established circ around 9-5/8" shoe to surface. RIH w/E-Z drill plug and set @ 8425'. Cemented 9-5/8" shoe w/750 sx Class G cmt. POH. RIH w/RTTS and shifting tool, opened lower FO @ 2471', cemented w/275 sx PF "C" cmt. Closed and tested FO w/3000 psi. Opened upper FO @ 2347', washed 9-5/8" x 13-3/8" annulus, pumped 292 bbls Arctic Pack w/final returns 0% water. Closed and tested FO w/3000 psi to 8564'TD. Tested formation to ll.5#/gal gradient. Ran CBL/Temp log showing good bond 8340'-8360". RIH w/E-Z drill retainer and set 94' above 9-5/8" shoe. Tested cement job below retainer' to 2000 psi on 10.5# mud. Tested csg to 2000 psi and reversed hole to water and water to Oil Faze mud. POH. Drilled out retainer, cleaned out junk to 8670' POH. RIH, cent core #1, rec 60'; core #2 8731-8749', rec 18'; core #3 8749-b776' ' ' ' ' ' , rec 22 ; core #4 8776-8836', rec 60 ; core #5 8836 8871 , rec 25 ; core #6 8871-8926', rec 35'; core #7 8926' 8986', rec 59'; core #8 8986-9046', rec 60'; core #9 9046:9082' rec 35'..RIH w/8-1/2" bit and drilled to79154'. RU and ran 7" 29# MN-80 Buttress liner w/shoe @19149' and top @ 8235'. Cemented 7" liner w/250 sx Class G cmt. RIH w/8-1/2" bit, tagged cmt @ 8115', drilled to liner hanger @ 8235'. RIH w/6" bit, cleaned out cmt stringers in liner from 8650' to 9071'. Ran 7" RTTS to 9020' and pumped thru 7" shoe @ 1600 psi. Tested lap to 2500 psi-OK. Ran 6" bit and cleaned out LC @ 9071' No cement between LC and shoe, drilled out shoe. Ran CBL/VDL/GR/CCL. Made bit Jnd scraper run. RIH and set E-Z drill @ 9124' on WL. Spotted 200 sx of Class Gccmt. PU and laid 57' plug on top of E-Z drill. RIH w/6" bit, drilled cmt 8978' -9068', pressure tested csg @ 3000 psi. POH. Ran and set Baker Model K BP @ 9064' RIH w/RTTS and set pkr @ 8123'. Open tool 3 hr test w/slight blow 1st hour. P~H w/DST tools, Test tools failed mechanically. RIH w/DST tools, set pkr @ 8184'. Opened tool for 3 hr test-had light blow for 50 min, dead balance of test. Close for 1 hr. SI. POH w/50' net rise. RIH w/6" bit and 7" scraper to 9064'. Displaced oil base mud w/lO.8 calcium chloride wtr. Changed and tested BOPE rams.~-RU--~nd run 5-1/2" completion assembly'~T~k-f' , 14. I hereby certify that~he ~oregoin~ ~ts true and correct ~" '~ '~" - / /7~ N E'--Rel)ort n this for i required rea h calendar,',, ,- h~ rdle. s t up ions, and must Im flied 'in duplicate with tho oil and gas conservation committee by tho 15th'°f'}~e suoceeding'month, unle.8 Otherwise directed. DS 4-10 (33-27-11-15~' Report on operations '~or the month of June. Page 2 @ 7990', R~O~ipple ~ 2196' and shear sub @ 8132'. NU and test xmas tree. Pulled and-rerun~u~my valve. Dropped ball and sheared w/3350 psi. Pressure test tubing and 9-5/8" annulus. Tubing pressure dropped @ averag~ of 3 psi/min w/annulus holding. Continue pressure ch~ck w~no communication 6~tween tubing and 5-1/2" x 9-5/8" annulus. Running noise logs on July 1. JUL 1 1976 DM$IOH OF 0i~ ANO GAS AtlanticRichfieldCompany North Ame~,~ f · *oducing Division North Alasl%, . .,ct Post Office I~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 3, 1976 Mr. O. K. Gilbreth Stage of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 RE: DS 4-10 (33-27-11-15) Permit No. 76-42 Dear Sir: Enclosed please find the Monthly Report of Drilling Operations for the above mentioned well. Sincerely, C. R. Knowles District Drilling Engineer CRK/jr Enclosure Form No. P-4 REV. 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. OIL WELL ~] GAS D WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, AK 99510 4. LOCATION OF WELL 442'N & 667'W of SE er Sec 27, TllN, R15E, UM 5. AP! NUMERICAL CODE 50-029-202%~ 6. LEASE DESIGNATION AND SERIAL NO. ADL 28325 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. DS 4-10 (33-27-11-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay-Sadlerochit Pool 11. SEC. T. R. M. (BOTTOM ltOLE OBJECTIVE) Sec 27, TllN-R15E, UM 12. PERMIT NO. 76-42 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEFFH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report on operations for the month of May. Spud @ 0430 hfs 5-6-76. Drilled 17-1/2" hole to 2700'. Ran 13-3/8" 72# N-80 Buttress csg w/shoe @ 2692' and FC @ 2615'. Cemented 13-3/8" csg w/4900 sx PF II cmt. Washed and blew dry 13-3/8" x 20" annulus thru 2-3/8" riser. Landed 13-3/8" csg, cemented thru riser w/150 sx PF II' cmt. 'NU and test BOPE. Drilled and surveyed 12-1/4" hole tO 5640'. Directionally drilled 12-1/4" hole from 5640' to 8564'. RU and ran 9-5/8" 47# MN-80 and S-95 Buttress csg w/shoe @ 8541' and FC @ 8454'. Cemented w/750 sx Class G cmt. Preparing to drill out 9-5/8" csg on June 1. 14. ! h~eby c~ify that the foregoing is true an~correct SIGNED ..... ' TITLE DATE NOTE-Report on this form is required for each calendar mo r- ardless o t stat f · -g o operations· ana must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month, unless otherwise directed. 02..001B FROM: STATE uEr. ARTi ,E~,~ (}F RESOURCES Division of 9il and Gas O. K. Gilbreth, Jr. ~ Di rector ,~/~/~,~ ~. Thru' Hoyle I). Hamilton ,'"~' Chief Petroleum EnFinee~ Petrol eu~'~; Inspector DATE ' ,~,;ay 27, ! 97,-r,, SUBJECT: L!OPE Test Arco 4.-10 )qay 20, 1976 - Departed my home at 6:00 AF! for 6:2S N,! sho~.:~-up and a 7:25 A,q departure via Wien flight -~9 for Deadhorse. Arrived Deadhorse at 9:05 At4 and ,y~as driven 'to Ro'~an Rig #25 Arco' , , s DS 4-10 at 9:45 A~'i. Drilling foreman for Arco was George Bean. Tool pusher for Ro~,~an was L. C. Baker. Nippling up was still .in progress. Temperature +20° F, light snow, light wind. ~e toured the location which .b~as well organized, reserve pit v.~ell built, well sign in place, rig in good repair and steel ~>~elded fuel tanks not bermed. Accumulator pressure was 2750 psig. N2 backup bottles tested 800, 1150, 2100, 24.00, 2100 a)~d 2100 psig. Two bottles were empty. Tests began at 8:00 PH, but ~o flange leaks occurred immediately and had to be repaired. Tests resumed at 8:50 PN with the hydril testing to 3000 psig. Another flange leak developed, was repaired, and tests resumed at 10-25 PM with top and bottom pipe rams, blind rams, both wing valves on the choke line and both wing valves on the kill line testing to 5000 psig. ):~ay 21.i,. 1~976 - By 12:15 AM we..tested 13 valves and 40 flanees in the choke manifold' to 5000 nsie.. The manual adjustable choke ~,a.s free moving and the Swaco superchok~ w~s actuated both open and close. The ball in the check valve in the kill line was bad. They will notify us when repairs have been made and this has' been so noted on the field inspection report. Tests resumed at 1:45 N.;! with kelly cock and lower kelly valve testing to 5000 psig. Both dart and ball type floor valves were on the floor. Tests were concluded at 2:20 N'.i. A Field Inspection Report was .prepared'with the original 9oino. to George Bean, a copy mailed to Bob Hines and a copy attached to this ~eport. Departed Deadhorse at 1'30 PIq arriving in Anchorage via Fairbanks at 4:00 PM and at my home at 4'30 P[~.~. In summary I witnessed successful BOPE test at Arco's DS 4-10. Attachment ., Alas Jil and Gas Conservation CofllfllittI~ Field Inspection Report Drl g. Permit No...'m"~.''' m~],~ Wel 1/P,le.'~f~m Sec Operator ...';'~?...~ Represented by.;':[;", r..,,,.,...,.....,,.'.:'L, Nam~ & Number . ii,' .... ~. ,. .-'; , ~ ."' Satisfactory Type Inspection ....... Si/t:isFac~ory Type Inspection Yes No Item (..,,)'~' Location,General Yes No Item (,,J/~BOPE Tests (~,.),.. ( ) (,~,,), ..... ( ) (,,,.) ..... ( ) (.:.'.)--- ( ) () () () () () () () () () () () () () () 1. Well Sign ~.:.~ ( ) 2. General Housekeeping j:,,)~"' ( ) 3. Reserve Pit-( )open( )filled :~)~( ) 4. Rig ,~) .... ( ) ( )Safety Valve Tests ~, .... ( ) 5. Surface-No. Wells ~.,} ...... ( ) 6, Subsurface-No. Wel 1 s ~,,},,'"' ( ) ( ) Well Test Data ~,.}..:~]( ) 7. Well Nos. , , , ,~),,~ ( ) 8. Hrs. obser__, ,~,__ ~,,,,),,.'~' ( ) 9. BS&W __,__,__,~ ,,~,~'( ) 10. Gr. Bbls.__,__,__,__ J~ ( ) ,( )Final Abandonment . 11. P&A Marker ~,~.~" ( ) 12. Water well-( )capped'( )plugged .(,,;,,)~' ( ) 15. ,'.,,.~:~!'r~,ing e:. 16.' ~t fluid-( )wi~ )mud (~,,)'"'6il 17. Master Hyd . Control Sys.-,,: ',',,,~,~,''.'','"~,,~,~,s i ~.. 18. N~ btl s .,.~,.,:,,~).~,? ,. ~,~il~,j.,~,:,~:~~sig .~.,, ~,'.'>,~.'J. 19. R~mote Controls 20. Drilling spool- :~-~' "outlets .c. 21. Kill Line-~;t,.,) Check valve 22. Choke Flowline ( ) HCR valve 23. Choke Manifold No valvs,,~,~?'fles';:,,m,.Z,,' 24. Chokes-(~.~'E~mote( )Pos.('~dj 25.. Test Plug-(~:,.,)'~611hd( )csg( )none 26. Annular Preventerjj'.~s~psig 27. Blind Rams,j~sig · . ~. ~, , 28. Pipe Rams,.~.:F}~.:~ ps~g 29 Kelly & Kelly-~OcK,¢l~psig ( ) ( ) 13. Clean-up (~,.)~.() 30. Lower Kelly ( ) ( ) 14. Pad' leveled . (&,),.'~() 31 Safety Floor valves-(,J;~B~/' (y,;)~)art Total.inspection observation time ~ hrs/d~ Total number leaks and/or.eQuip, failure,s , ~ .' ~ ~ d"'~' ,,~. . , ~, , ,. . . ................ . _, , ~ ~ ~'..~ ~.-.~ ~....,~z ,,~', . ~.~ ( ~.~,, ,~...e~. ,,m.. m.,, ~ ......... ,.,, ,~) , ,,,,,¢q,Y, :+~ ,~.,,,~ ...... ~ .~,~.,~. ,',? ,~.,~ ~ .,,m~ ,r;~t,,~,.,~,....,.;v.r~;~,,~ ,+~I;~. ,,, .~') JC?~',~',~l~ ;~"~".Jv.!. . ' ' m,,,,,,,,~-;~K~;'.~,;, y' '~,,q~':,s~ ...2,.~.,.,~'..~. , ' ' , ' ' ' ' ' ' I ' ~ m , , "~ ' ' .,'~V d '-~' ... CC :' ~(~:'~j~.~ .,,,~,,'.,,;,~;~,.,~¢~¢-.;.,, ~,.),.NotifY in ~ays or when read~,, InSPected ~':.~...~ ..,. by,,%~. ,~ .~ ~ ......... ~,,...~.~.,,%.,,., Datej,.~, ,,<r/.,-v ,~.. April 12, 1976 State Pemit No. 76-42 , , .... C. R. Knowles District 1)r,tlltng Engineer , Arian. tic Richfield .Company. P..O. Box 360 Anchorage, Alaska 99510 *. Prudhoe Bay DS 4-10 (33-27-11-15) Atlantic Rtch¢teld Company Dear St r: Enclosed is the, approved appl..~catton for pemit to drtl'l' 'the :above referenced well at a 1..ocatton tn. Section 27, Township 1i~1', 'Range 15E, U. i~. Well samp.les, .core. chtps and a mud: log are not eequtred A dtrect.~onal survey t's required. ' ,, Many r.J'vers 'Jrt Alaska and their dratnage systems have been cl.asstfted as ... important 'for the, spawning or migration these areas are subject to AS 16.50,.870 and the. regulations .promulgated theretmder (Title S, Alaska. 'Administrative Code).., Prtor to commencing. operatl.ons you may be contacted by the Habitat CoerdJnator"s office, Oepart- merit of Fish and Game.. Pollution of .any waters of the state is..prohibited by AS .46, Chapter .03, ArUcle 7 and the regulations prolmulgated ttmreunder .(Title 18, Alaska Ad~iatstrattve Code,. Chapter 70) and 'by the Federal {~ater. Pollution .Control Act, as amended, Prior to. commenc{ng operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38,40, Lo. cat Hire Under State Leases,. the .Alaska Department of Labor 'is being notifJed of' the issuance of.thfs.pemtt to drill.. To aid us in scheduling field work, we would appreciate your 'notifying this .office within 48 hours after the well is spudded.. ~{e. would a.lso like to be notified so that a representative of 'the Ot.vl.s'Jon may be Present. to witness testing of blowout preventer equipment before surface casing' shoe is drill.ed. C. R. Knowles 2- Apr11 12, 1976 Tn the event of suspension or 'abandonment please gtve thts offtce adequate advance notification so that tm may have a wttness present. Very truly yours, O. K. Gtlbreth, ~Ir. Chatrman Alaska 0tl and .Gas Conservatt.on Con~ntttee Enclosure CC: Department of Ftsh and''' ..Game, Habttat Sectton w/o .eric1. Depar~t of Environmental Conservation w/o eric1. Depar13met of Labor, Supervisor, Labor. Law Compliance Dirts'ton, w/ eric1, AtlanticRichfieldCompany North Amer( North Alaskf roducing Division Lrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 5, 1976 Hr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: Drill Site 4-10 (33-27-11-15]) Dear Hr. Gilbreth: Enclosed is our Application for Permit to Drill Drill site 4-10 and the $100.00 filing fee. The required survey plat is also enclosed. For your information, as well as for the State Department of Labor, the surface and target location are on Lease ADL 28525. The effective date for the lease is October 1, 1965, with an termination date of M~3rch 27, 1984. Very truly yours, C. R. 'Knowles District Drilling Engineer /cs Enclosures Form 10-401 ' REV. !-1-71 SUBMIT IN *r,~ ' (Off, er instt~ ft'¥ef$~'% .. OIL AND GAS CONSERVATION ~iTTEE~./):. PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL F~l b. TYPE OF WELL WELL WELL OTHER DEEPEN F'l DIVI$!ON OF OIL AND GAS SINGLE~ MULTIPLE ZONE ~ ZONE 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska, 99510 4. LOCATION OF WELL At surface 442'N & 667'W of SE cr Sec 27, TllN, R15E., UM At proposed prod. zone @8800'ss - 1320'N & ll90'W of SE cr Sec 27, TllN, R15E, UM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOlVN OR POST OFFICE* Approximately 6-1/2 miles northeast of Deadhorse. · . ... ~,PI ;50-02~-202]~ $. 6. LEASE DESIGNATION AND SEI~IALNO. ADL 28325 7. !!.' INDIAN, ALLO~rEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. DS 4-10 (33-27-11-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay-Sadl erochi t Po l !. SEC., T., R., M., (BOTTOM IIOLE OBJECTIVE) Sec 27, TllN, R15E, UM 14. BOND INFORMATION: TYPE Statewidesurctyand/orNo. Federal Insurance Co. #8011-38-40 Amovnt$100,000 15. DISTANCE FROM PROPOSED * [ 16. No. OF ACRES IN LEASE 17. NO,ACRF'.S ASSIGNED LOCATION TO NEAREST [ TO Tills WELL , . PROPEI{.'I~Y OR LEASE LINE, FT. ' (Also to n~arest drig, unit, ffany)1190' ' 2560 .320 18. DISTANCE FROM PROPOSED LOCATION 19. PROmSED DEFrlt 20. ROTARY OR CABLE TOOLS. TO NEAREST WELL DRILLING, COMPLETED, ' ' OR APPLIED FOR, FT. 2300' 9220~ Rotary 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX. DATE WORK WILL START May 1'0; 1 976" 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH " QnantiW of cement .... 30"' 20" 94# H-40 +80' Circ to surf approx 500 sx II 811 --~ · __17-1/2 13-3/ 72# MN-80 +2700' Circ to surf approx 5500 sx 12-1/4." 9-5/8" 47# MN-80 +8532' -+1900' cml colm' on 1st st9 750 &500_95 . 8-1/2" .7 29# MN-80 +9120' 3fOr.~,m nm~ " -T'D' to.. t6p.'6f'lnr': '~uu sx The Atlantic Richfi.eld Co'mpany proposes to directionally drill this well to +9220'MD, (8942'T. VD) to produce the Sadlerochit. The Sadlerochit interval will be cored with an oil based mud. Logs will be run across selected intervals. A 13-3/8", 5000 ps'i, Hydril and 13-5/8", 5000 psi, pipe and blind rams will be used on the 13-3/8" casing. The BOP equipment will be pressure tested each week and operationally tested each trip. A non-freezing fl'uid will be left in all uncemented annuli within the permafrost interval. A single 5-1/2" tubing completion will be run and the well suspended in an unperforated condition. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. 24. I he~Iby Certify that the Foregoing is True and Correct (This space!£~r State office usc) CONDITIONS OF APPROVAL, IF ANY: SAMPLES AND CORE CIIIPS REQUIRED [ MUD LOG r-lYES ~NO '[ [] YES ~] NO DIRECTIONAL SURVEY REQUIRED ~9 YES [] No OTItER REQUIREMENTS: A.P.I. NUMERICAL CODE 50-029-20213 PERMIT NO. 76-t42 -,, . APPROVAL D'~TE April APPOVEDBY,,~"~,~ ~~"~4~%' .~.-i~,man, 0|] F., GaS DATE Apl'ii ~ ;See Instructg°nr~ne h~eq~'ldeCOmmi t tee 12, )976 I 27 34 26 35 't SECTION 26, 27, 34 8, 35 T. ]] N., R. 15E.~ U.'M. WELL No. ASPC ZONE 4 7 LAT. 70° 16' 19.3485 Y 5 951 945 88 LONG. 148°16'59.8786 X 712 235.09 8 LAT. 70° 16' 19.5028 LONG. 148°17'00,6144 Y 5 952 062.4.8 X 712 206.52 9 L AT. 70° i6' 20.652 LONG. 148° 17'01:344 ,o I0 LAT. 70° 16' 21.805 LON6. 148° 17' 02.069 Y 5 952 178.52 x 712 i78.18 Y 5 952 295.07 X 712 149.98 DIMf"~!ON OF 0~. AND SCALE 1" = $00' CERTIFICATE 'OF SURVEYOR I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA' AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPER- VISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. MARCH 24, 1976 DATE SURVEYOR ASBUILT --'~-~'~'~-~' ATLANTIC RICHFIELD CO. .-.,,.,,........,.o..,, _, _-, ~..' · ~~ %:~;,,, SI T E N o. 4 ~ ¢ ~SI.~,,~ '. ~ ~. ' WELL No. I0 E "/2 of PROTRACTED SEC. 27, T. IIN.,R.15E., ~ ~ % /Oar*/ D. D~.asl~lll~..°"~ ~ UMIAT MERIDIAN,ALASKA ~ ¢_~,.,,'% zz~4-~ ~.".~. ~ PREPARED BY -j:,-,,o,F...o. oooO%,~'__,=, HEWITT V. LOUNSBURY 8, A.SSOC. '~./'ESSlONAL ._,~'~' 725 W. 6th. AVE., ANCHORAGE, ALASKA ~'~'%*~'~""~ DATE OF SURVEY 3-19-761 SCALE NOTED / AFE 2929;51 CHKD BY GD I 'FIELD BK CHECK LIST FOR NEW ~'JELL PERHITS . Is the permit fee gttached ........ Company /Z~f~O Yes No Remarks Is well to be located in'a defined pool ............. ~ _ o Is a registered survey plat attached ................. . Is ~.~ell located proper distance from property line ..... . .... Is well located proper distance from other wells .......... ~ '. Is sufficient undedicated acreage available in this pool ...... ~ s well to be deviated ................... ~ ;. ~s operator the only affected party ...... Can permit be approved before ten-day wait ............. ~( I. Does operator have a bond in force .................. ~;~ . Is a conservation order needed ................... !. Is administrative approval needed ' . ........... I. Is conductor string provided .................... ~ ~. Is enouah cement used to circulate on conductor and surface ..... ~>~ _ ,~ ,l.,ill cement tie in surface and intermediate or production strings . ~., __ '3. ~ 011 cement cover all known productive horizons .......... ,~. . . Will surface Casing protect fresh water zones ............ B. Will all casing give adequate safety in collapse, tension &"burst . Does BOPE have sufficient pressure rating '.... .......... dditional Requirements' : Lease & Well No. ~. ~, Approval Recommended' Geology Enaineering' TRM JAL~ HI:JK .~../~L,,~., OK~ ,,,~ HHH L C S'"'i~' ~ .~-~'J C M ~_~/' ' Revised 1/15/75 o,, Well Histo.ry 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 .APPEN. DIX~ ,, No 'special'effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ****************************** * ............................ * ....... SCHLUMBERGER ....... * ............................ ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D. S. 4-10 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292021300 REFERENCE NO : 96350 JAI 03 ]997 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/12/31 ORIGIN : FLIC REEL NAME : 96350 CONTINUATION # : PREVIOUS REEL : COM~4ENT : ARCO ALASKA INC, D.S. 4-10, PRUDHOE BAY, 50-029-20213-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/12/31 ORIGIN : FLIC TAPE NAME : 96350 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, D.S. 4-10, PRUDHOE BAY, 50-029-20213-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 4-10 API NUMBER: 500292021300 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 31-DBC-96 JOB NUMBER: 96350 LOGGING ENGINEER: R. WALSH OPERATOR WITNESS: M. REYNOLDS SURFACE LOCATION SECTI ON: 27 TOWNSHIP: 1 IN RANGE: 15E FNL: 442 FSL: FEL : FWL: 667 ELEVATION (FT FROM MSL O) KELLY BUSHING: 52. O0 DERRICK FLOOR: 51. O0 GROUND LEVEL: 15. O0 WELL CASING RECORD 1ST STRING 2ND STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9. 625 47.00 7.000 29.00 3.500 9.30 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: ECS GR 15-JUN-76 SCHLUMBERGER WELL SERVICES BASELINE DEPTH .............. 88888.0 9003.5 8993.0 8958.5 8947.5 8926.5 8925.5 8919.5 8915.0 8905.5 8901.0 8900.5 8896.0 8891.5 8887.5 8873.0 8871.5 8864.5 8858.5 8855 0 8849 5 8847 5 8843 0 8836 0 8833 5 8829 5 8826 5 8825 0 8819 5 8810 5 8798 0 8789 5 8783 0 8733 0 8711 5 8709 5 8695.5 8691.5 8688.0 100.0 $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88897.5 88888.5 8957.0 8934.5 8924.0 8910.5 8900.0 8897,0 8878.0 8867.0 8864.0 8856.5 8840.5 8837.0 8832.5 8812.5 8800.0 8786.5 8723.0 8701.5 110.0 9004.0 8996.5 8957.0 8934.5 8924.0 8908.5 8899.5 8897.0 8882.5 8872.5 8856.5 8850.5 8840.0 8834.5 8829.5 8800.0 8742.0 8719.5 8707.0 8697.5 109.5 REMARKS: This file contains the cased hole edit for ARCO Alaska well D.S. 4-10 TDT-P. This well was logged in two parts, an upper section and a lower section. There are three baseline upper passes and three baseline lower passes. PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 There are two borax upper passes and two borax lower passes. There is only one average pass presented. The three upper and lower edited baseline passes have been spliced and the average of these passes presented. The depth adjustments shown above reflect cased hole GR to open hole BCS GR and cased hole SIGM to open hole GR. Ail other TDTP curves were carried with the SIGM shifts. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8992.0 8684.0 TDTP 9021.0 8684.0 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP REMARKS: This file contains TDTP Pass #1 (Lower Base Pass #1), No pass to pass shifts were applied to this data. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DBC-1996 11:00 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100612 O0 000 O0 0 1 1 1 4 68 SIGM TDTP CU 100612 O0 000 O0 0 1 1 1 4 68 TPHI TDTP PU-S 100612 O0 000 O0 0 1 1 1 4 68 SBHF TDTP CU 100612 O0 000 O0 0 1 I 1 4 68 SBHN TDTP CU 100612 O0 000 O0 0 1 1 1 4 68 SIGC TDTP CU 100612 O0 000 O0 0 1 1 1 4 68 SIBH TDTP CU 100612 O0 000 O0 0 1 1 1 4 68 TRAT TDTP 100612 O0 000 O0 0 1 1 1 4 68 SDSI TDTP CU 100612 O0 000 O0 0 1 1 1 4 68 BACK TDTP CPS 100612 O0 000 O0 0 1 1 1 4 68 FBAC TDTP CPS 100612 O0 000 O0 0 1 1 1 4 68 TCAN TDTP CPS 100612 O0 000 O0 0 1 1 1 4 68 TCAF TDTP CPS 100612 O0 000 O0 0 1 1 1 4 68 TCND TDTP CPS 100612 O0 000 O0 0 1 1 1 4 68 TCFD TDTP CPS 100612 O0 000 O0 0 1 1 1 4 68 TSCN TDTP CPS 100612 O0 000 O0 0 1 1 1 4 68 TSCF TDTP CPS 100612 O0 000 O0 0 1 1 1 4 68 INND TDTP CPS 100612 O0 000 O0 0 1 1 1 4 68 INFD TDTP CPS 100612 O0 000 O0 0 1 1 1 4 68 GRCH TDTP GAPI 100612 O0 000 O0 0 1 1 1 4 68 TENS TDTP LB 100612 O0 000 O0 0 1 1 1 4 68 CCL TDTP V 100612 O0 000 O0 0 1 1 1 4 68 GR ECS GAPI 100612 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: ** DATA ** DEPT. 9100. 000 SIGM. TDTP SBHN. TDTP -999. 250 SIGC. TDTP SDSI. TDTP -999. 250 BACK. TDTP TCAF. TDTP -999.250 TCND. TDTP TSCF. TDTP -999. 250 INND. TDTP TENS. TDTP - 999.250 CCL. TDTP DEPT. 7900. 000 SIGM. TDTP SBHN. TDTP - 999. 250 SIGC. TDTP SDSI. TDTP -999. 250 BACK. TDTP TCAF. TDTP -999. 250 TCND. TDTP TSCF. TDTP -999.250 INND . TDTP TENS. TDTP - 999.250 CCL . TDTP -999.250 TPHI. TDTP -999.250 SIBH. TDTP -999.250 FBAC. TDTP -999.250 TCFD. TDTP -999.250 INFD. TDTP -999.250 GR.BCS -999. 250 TPHI. TDTP - 999. 250 SIBH. TDTP -999. 250 FBAC. TDTP -999. 250 TCFD. TDTP -999. 250 INFD. TDTP -999 . 250 GR .BCS -999.250 SBHF. TDTP -999.250 TRAT. TDTP -999.250 TCAN. TDTP -999.250 TSCN. TDTP -999.250 GRCH. TDTP 106.776 - 999. 250 SBHF. TDTP -999. 250 TRAT. TDTP - 999 . 250 TCAN. TDTP -999. 250 TSCN. TDTP - 999 . 250 GRCH. TDTP 58. 092 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 00IC01 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH GRCH 8985.0 TDTP 9016.0 STOP DEPTH .......... 8684.0 8684.O LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88897.5 88888.5 9003.5 9004.0 8991.5 8994.5 8987.0 8989.5 8983.5 8985.5 8979.5 8981.0 8975,5 8977.0 8971.5 8981.0 8974.0 8964.5 8974,0 8958.0 8956.5 8928. 0 8923.5 8931.5 V~EVT~ : 89~s H~o~ : 8928'~0n0~0~ 8901.0 8910.5 8899.5 8899.0 8891.5 8899.5 8894.0 8888.5 8892.5 8886.5 8896.0 8883.5 8892.5 8871.s 8878.s 8881.o 8869.5 8878.5 8864.5 8872.5 8858.5 8867.0 8855.5 8862.0 8851.5 8857.5 8848.0 8856.5 8843.5 8849.5 8839.5 8845.0 8835.5 8840.0 8827.5 8832.0 8824.0 8834.0 8823.5 8828.5 8819.5 8823.5 8829.5 8815.5 8819.5 8811.5 8815.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 8807.5 8810.5 8803.5 8807.5 8799.5 8802.0 8795.5 8798.0 8791.5 8793.5 8789.5 8800.0 8787.0 8789.5 8767.5 8774.0 8764.0 8774.0 8752.5 8759.0 8739.0 8746.5 8733.5 8742.5 8723.0 8731.5 8718.0 8727.5 8717.0 8724.5 8712.5 8723.0 8700.0 8711.0 8696.5 8706.5 100.0 110.0 111.0 $ REMARKS: This file contains TDTP Pass #2 (Lower Base Pass #2). The depth shifts shown above relect GRCH Pass #2 to GRCH Pass #1 and SIGM Pass #2 to SIGM Pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: ** SET TYPE - CHAN ** ....................................................................................... NAME SBRV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100612 O0 000 O0 0 2 1 1 4 68 SIGMTDTP CU 100612 O0 000 O0 0 2 1 1 4 68 TPHI TDTP PU-S 100612 O0 000 O0 0 2 1 1 4 68 SBHF TDTP CU 100612 O0 000 O0 0 2 1 1 4 68 SBHN TDTP CU 100612 O0 000 00 0 2 1 1 4 68 SIGC TDTP CU 100612 O0 000 O0 0 2 1 1 4 68 SIBH TDTP CU 100612 00 000 O0 0 2 1 1 4 68 TRAT TDTP 100612 00 000 00 0 2 1 1 4 68 SDSI TDTP CU 100612 O0 000 O0 0 2 1 1 4 68 BACK TDTP CPS 100612 O0 000 O0 0 2 1 1 4 68 FBAC TDTP CPS 100612 O0 000 O0 0 2 1 1 4 68 TCAN TDTP CPS 100612 O0 000 O0 0 2 1 1 4 68 TCAF TDTP CPS 100612 O0 000 O0 0 2 1 1 4 68 TCND TDTP CPS 100612 O0 000 00 0 2 1 1 4 68 TCFD TDTP CPS 100612 O0 000 O0 0 2 1 1 4 68 TSCN TDTP CPS 100612 O0 000 O0 0 2 1 1 4 68 TSCF TDTP CPS 100612 O0 000 O0 0 2 1 1 4 68 INND TDTP CPS 100612 O0 000 O0 0 2 1 i 4 68 INFD TDTP CPS 100612 O0 000 O0 0 2 1 1 4 68 GRCH TDTP GAPI 100612 O0 000 O0 0 2 1 1 4 68 TENS TDTP LB 100612 O0 000 O0 0 2 1 1 4 68 CCL TDTP V 100612 O0 000 O0 0 2 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 8997. 275 SIGM. TDTP 15. 680 TPHI. TDTP 37. 005 SBHF. TDTP SBHN. TDTP 47. 465 SIGC. TDTP 1. 251 SIBH. TDTP 53. 866 TRAT. TDTP SDSI. TDTP O. 506 BACK. TDTP 95. 554 FBAC. TDTP 25. 912 TCAN. TDTP TCAF. TDTP 8150. 677 TCND. TDTP 20360.176 TCFD. TDTP 5787. 604 TSCN. TDTP TSCF. TDTP 1866. 839 INND. TDTP 1467. 703 INFD. TDTP 252. 356 GRCH. TDTP TENS. TDTP 1240. 000 CCL. TDTP O. 000 DEPT. 8694.275 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999. 250 CCL. TDTP -999. 250 38.102 2.005 22256.480 5097.645 -999.250 -999.250 -999.250 -999.250 -999.250 36.125 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8992.0 8690.0 TDTP 9024.0 8690.0 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9003.5 8993.0 8981.0 8966.5 8958 5 8954 5 8950 5 8947 5 8946 5 8942 5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88897.5 88888.0 8976.0 8967.5 8963.5 8959.0 8956.0 8951.0 9003.5 8996.0 8982.5 8957.0 8949.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 10 8938.0 8926 5 8925 5 8923 5 8922 5 8919 5 8915 0 8909.5 8903.5 8900.5 8897.5 8890.5 8887.5 8882.5 8882.0 8872.5 8872.0 8864.5 8863.5 8858.5 8854.5 8850.0 8846.5 8845,O 8842,0 8835.5 8830.0 8826.0 8825.0 8822.5 8819.5 8818.5 8814.5 8810.5 8806.5 8802.5 8798.5 8794.5 8786.5 8782.5 8765.0 8762.5 8756.0 8746.5 8738.5 8718.0 8710.0 8700.0 8696.5 100.0 $ R~W~RKS: 8946.5 8934.5 8934.5 8931.0 8931.0 8924.0 8923.5 8913.0 8903.5 8899.5 8897.5 8899.5 8896.5 8889.0 8888.0 8881.5 8878.0 8872.5 8870.5 8866.5 8867.0 8862.0 8856.5 8852.0 8853.0 8847.5 8839.0 8835.0 8832.5 8834.5 8826.5 8829.0 8821.5 8817.5 8812.5 8809.0 88O4.O 8800.5 8796.0 8796.5 8784.0 8774.5 8769.0 8762.5 8755.0 8747.0 8728.0 8719.5 8710.5 8706.5 110.0 110.5 This file contains TDTP Pass #3 (Lower Base Pass #3). The depth shifts shown above relect GRCH Pass #3 to GRCH Pass #1 and SIGM Pass #3 to SIGM Pass #1. LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 11 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SBRV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELM CODE (HEX) ................................................. T ..................................... DEPT FT 100612 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 100612 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 100612 O0 000 O0 0 3 I 1 4 68 0000000000 SBHF TDTP CU 100612 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 100612 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 100612 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 100612 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 100612 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 100612 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 100612 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 100612 O0 000 O0 0 3 1 1 4 68 0000000000 TCANTDTP CPS 100612 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 100612 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 100612 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 100612 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 100612 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 100612 O0 000 O0 0 3 1 1 4 68 0000000000 Ih-lTD TDTP CPS 100612 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 100612 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 12 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) GRCH TDTP GAPI 100612 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 100612 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 100612 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9001.500 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SBHN. TDTP -999.250 SIGC. TDTP - 999.250 SIBH. TDTP -999.250 TRAT. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999. 250 INND. TDTP -999. 250 INFD. TDTP -999. 250 GRCH. TDTP TENS. TDTP -999 . 250 CCL. TDTP -999. 250 DEPT. 8700. 000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999. 250 CCL. TDTP -999. 250 -999.250 -999.250 -999.250 -999.250 70.750 -999.250 -999.250 -999.250 -999.250 81.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: LiS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 13 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCR~FIENT : O . 5000 FILE SUF~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8224 . 0 8000.0 TDTP 8258.0 8000.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH 88888.0 8208.5 8201.0 8195.5 8192.5 8185.0 8168.0 8164.5 8160.0 8142.5 8138.0 8134.0 8131.0 8121.5 8114.5 8102.5 8100.5 8087.5 8077.0 8073.5 8065.0 8054.0 8052.5 8048.0 8045.O 8035.5 8028,0 8026.5 8015.0 8008.5 8003.5 8002.0 100.0 $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88889.5 88905.0 8210.0 8200.0 8194.0 8209.5 8199.5 8182.0 8163.5 8158.5 8157.0 8136.0 8149.5 8129.0 8117.5 8113.5 8118.0 8099.0 8083.5 8088.0 8069.5 8061.5 8061.0 8050.5 8054.5 8050.5 8040.5 8027.0 8024.0 8015.0 8015.0 8003.0 8010.0 99.5 108.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 14 REMARKS: This file contains TDTP Pass #4. (Upper Base Pass #1). No pass to pass shifts were applied to this data. The depth adjustments shown above reflect cased hole GR to open hole ECS GR and cased hole SIGM to open hole GR. Ail other TDTP curves were carried with the SIGM shifts. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100612 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM TDTP CU 100612 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 100612 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 100612 O0 000 O0 0 4 1 1 4 68 0000000000 SBHN TDTP CU 100612 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 100612 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 100612 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 100612 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 100612 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 100612 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 100612 O0 000 O0 0 4 1 1 4 68 0000000000 TCANTDTP CPS 100612 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 100612 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 100612 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 15 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) TCFD TDTP CPS 100612 TSCN TDTP CPS 100612 TSCF TDTP CPS 100612 INND TDTP CPS 100612 INFD TDTP CPS 100612 GRCH TDTP GAPI 100612 TENS TDTP LB 100612 CCL TDTP V 100612 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 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 8247. 000 SIGM. TDTP 19. 652 TPHI. TDTP 47. 754 SBHF. TDTP SBHN. TDTP 78.534 SIGC. TDTP 1.654 SIBH. TDTP 124.346 TRAT. TDTP SDSI. TDTP 0. 412 BACK. TDTP 144 . 033 FBAC. TDTP 25.610 TCAN. TDTP TCAF. TDTP 383. 528 TCND. TDTP 9509. 660 TCFD. TDTP 1540. 039 TSCN. TDTP TSCF. TDTP 90. 373 INND. TDTP 1574. 453 INFD. TDTP 184.205 GRCH. TDTP TENS. TDTP 1150. 000 CCL. TDTP O. 000 DEPT. 7999.500 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999. 250 CCL. TDTP -999. 250 69.459 2.001 1967.348 463.579 -999.250 -999.250 -999.250 -999.250 -999.250 58.500 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01COi DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 16 FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCRJ~4ENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8226.0 8000.0 TDTP 8258.0 8000.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 4 BASELINE DEPTH 88888.0 8209.5 8195.0 8181.5 8175.0 8160.5 8159.5 8155.5 8153 0 8140 5 8138 5 8134 0 8132 5 8130 5 8117 5 8111 5 8089 5 8079 0 8078 5 8077 0 8071 0 8059 5 8053 5 8047 5 8038 0 8035 5 8030 5 8030 0 8028 5 8026.0 8014.5 8012.0 8007.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88887.0 88903.5 8194.0 8180.0 8158.5 8153.5 8151.5 8139.0 8136.0 8132.0 8128.5 8115.0 8110.5 8074.0 8056.0 8034.0 8029.5 8027.0 8014.5 8007.5 8225.0 8189.0 8175.0 8149.5 8104.5 8091.5 8088.0 8078.0 8065.0 8054.5 8050.5 8040.5 8033.5 8021.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 17 100.0 $ 100.0 109.0 R~4ARKS: This file contains TDTP Pass #5 (Upper Base Pass #2). The depth shifts shown above relect GRCH Pass #5 to GRCE Pass #4 and SIGM Pass #5 to SIGM Pass #4. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100612 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM TDTP CU 100612 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 100612 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF TDTP CU 100612 O0 000 O0 0 5 1 1 4 68 0000000000 SBHN TDTP CU 100612 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC TDTP CU 100612 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH TDTP CU 100612 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT TDTP 100612 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI TDTP CU 100612 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 100612 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 100612 O0 000 O0 0 5 1 1 4 68 0000000000 TCANTDTP CPS 100612 O0 000 O0 0 5 1 i 4 68 0000000000 TCAF TDTP CPS 100612 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 18 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) TCND TDTP CPS 100612 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 100612 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN TDTP CPS 100612 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF TDTP CPS 100612 O0 000 O0 0 5 1 1 4 68 0000000000 INND TDTP CPS 100612 O0 000 O0 0 5 1 1 4 68 0000000000 INFD TDTP CPS 100612 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 100612 O0 000 O0 0 5 1 1 4 68 0000000000 TENS TDTP LB 100612 O0 000 O0 0 5 1 1 4 68 0000000000 CCL TDTP V 100612 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP 8245 500 72 659 3 032 1837 507 98 214 1125 000 DEPT. 8000. 000 SBHN. TDTP -999. 250 SDSI. TDTP -999. 250 TCAF. TDTP -999. 250 TSCF. TDTP -999. 250 TENS. TDTP -999. 250 SIGM. TDTP 51. 322 TPHI. TDTP 89. 975 SBHF. TDTP SIGC. TDTP O. 000 SIBH. TDTP 111. O19 TRAT. TDTP BACK. TDTP 149.099 FBAC. TDTP 28.916 TCAN. TDTP TCND. TDTP 9467. 205 TCFD. TDTP 1525.105 TSCN. TDTP INND. TDTP 1610. 010 INFD. TDTP 182. 418 GRCH. TDTP CCL. TDTP O. 000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP BACK. TDTP -999.250 FBAC. TDTP -999. 250 TCAN. TDTP TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP INND. TDTP -999. 250 INFD. TDTP -999. 250 GRCH. TDTP CCL. TDTP -999.250 73.792 2.078 9915.762 469.538 -999.250 - 999. 250 - 999. 250 -999.250 -999.250 80.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 19 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 6 DEPTH INCR~ENT: O. 5000 FILE SUMF1ARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 8220.0 7992.0 TDTP 8250.0 7992.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 4 BASELINE DEPTH 88888 0 8212 5 8205 5 8203 5 8197 5 8189 0 8185 5 8170 0 8147 0 8144 0 8140 5 8134 5 8123 5 8117 5 8089 0 8078 5 8O78 0 8069.5 8068.5 8064.0 8050.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88876.5 88895.5 8220,0 8194.0 8178.5 8174.0 8158.5 8135.5 8128.5 8122.5 8113.0 8106.5 8064.0 8056.5 8050.5 8038.5 8212.5 8203.5 8174.5 8149.5 8088.0 8078.0 8066.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 20 8038.0 8027.0 8034.0 8033.5 8025.0 8015.0 8022.0 8022.0 100.0 90.0 100.0 $ R~ARKS: This file contains TDTP Pass #6 (Upper Base Pass #3). The depth shifts shown above relect GRCH Pass #4 to GRCH Pass #4 and SIGM Pass #6 to SIGM Pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64BE ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100612 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM TDTP CU 100612 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI TDTP PU-S 100612 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF TDTP CU 100612 O0 000 O0 0 6 1 I 4 68 0000000000 SBHN TDTP CU 100612 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC TDTP CU 100612 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH TDTP CU 100612 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT TDTP 100612 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI TDTP CU 100612 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 21 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) BACK TDTP CPS 100612 O0 000 O0 0 6 1 1 4 FBAC TDTP CPS 100612 O0 000 O0 0 6 1 1 4 TCAN TDTP CPS 100612 O0 000 O0 0 6 1 1 4 TCAF TDTP CPS 100612 00 000 00 0 6 1 1 4 TCND TDTP CPS 100612 O0 000 O0 0 6 1 1 4 TCFD TDTP CPS 100612 O0 000 O0 0 6 1 1 4 TSCN TDTP CPS 100612 O0 000 O0 0 6 1 1 4 TSCF TDTP CPS 100612 O0 000 O0 0 6 1 1 4 INND TDTP CPS 100612 O0 000 O0 0 6 1 1 4 INFD TDTP CPS 100612 O0 000 O0 0 6 1 1 4 GRCH TDTP GAPI 100612 O0 000 O0 0 6 1 1 4 TENS TDTP LB 100612 O0 000 O0 0 6 1 1 4 CCL TDTP V 100612 O0 000 O0 0 6 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 8237.500 SIGM. TDTP 45.340 TPHI. TDTP 74.207 SBHF. TDTP 66.846 SBHN. TDTP 81.381 SIGC. TDTP 0.710 SIBH. TDTP 130.804 TRAT. TDTP 1.784 SDSI. TDTP 2. 377 BACK. TDTP 160. 349 FBAC. TDTP 29. 298 TCAN. TDTP 8594. 492 TCAF. TDTP 1877.286 TCND. TDTP 7779. 773 TCFD. TDTP 1517. 485 TSCN. TDTP 435.122 TSCF. TDTP 97. 510 INND. TDTP 1522. 433 INFD. TDTP 191. 809 GRCH. TDTP - 999.250 TENS. TDTP 1125. 000 CCL. TDTP O. 000 DEPT. 7990.000 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 94.938 TENS. TDTP - 999. 250 CCL. TDTP -999. 250 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 22 **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : 001C01 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 7 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 7 DEPTH INCREMENT: 0.5000 FILE SUF~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8220.0 8000.0 TDTP 8254.0 8000.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 4 BASELINE DEPTH 88888.0 8205.5 8192.0 8189.5 8185.0 8170.0 8169.5 8163.0 8154.0 8148.0 8143 5 8143 0 8135 5 8135 0 8123 0 8121 5 8120 0 8118 0 8115 5 8115 0 8110 5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88876.5 8194,0 8178.5 8173.5 8158.5 8151.0 8141.5 8136.0 8132.0 8122.5 8113.0 8110.5 8106.5 8102.0 8097.5 88895.0 8212.5 8199.5 8174.5 8149.0 8140.5 8117.5 8113.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 23 8104.0 8090.5 8095.5 8100.0 8089.0 8092.5 8088.0 8074.0 8082.0 8088.0 8058.0 8064.0 8054.0 8061.5 8045.0 8034.5 8040.0 8050.0 8037.0 8043.5 8032.5 8040.5 8026.0 8033.5 8025.0 8015.0 8011.5 8003.0 100.0 91.5 107.5 $ R~W~ARKS: This file contains Upper Borax Pass #1 of the TDTP. The depth adjustments shown above reflect Upper Borax Pass #1 GRCH to Base Pass #4 GRCH and Upper Borax Pass #1 SIGMA to Base Pass #4 SIGMA. Ail other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 24 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100612 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM TDTP CU 100612 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI TDTP PU-S 100612 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF TDTP CU 100612 O0 000 O0 0 7 1 1 4 68 0000000000 SBHN TDTP CU 100612 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC TDTP CU 100612 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH TDTP CU 100612 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT TDTP 100612 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI TDTP CU 100612 O0 000 O0 0 7 1 1 4 68 0000000000 BACK TDTP CPS 100612 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC TDTP CPS 100612 O0 000 O0 0 7 1 1 4 68 0000000000 TCAN TDTP CPS 100612 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF TDTP CPS 100612 O0 000 O0 0 7 1 1 4 68 0000000000 TCND TDTP CPS 100612 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD TDTP CPS 100612 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN TDTP CPS 100612 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF TDTP CPS 100612 O0 000 O0 0 7 1 1 4 68 0000000000 INND TDTP CPS 100612 O0 000 O0 0 7 1 1 4 68 0000000000 INFD TDTP CPS 100612 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH TDTP GAPI 100612 O0 000 O0 0 7 1 1 4 68 0000000000 TENS TDTP LB 100612 O0 000 O0 0 7 1 1 4 68 0000000000 CCL TDTP V 100612 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 8237. 000 SIGM. TDTP 46. 888 TPHI. TDTP 92. 807 SBHF. TDTP SBHN. TDTP 72. 537 SIGC. TDTP O. 000 SIBH. TDTP 110. 743 TRAT. TDTP SDSI. TDTP 2. 063 BACK. TDTP 150.213 FBAC. TDTP 32.289 TCAN. TDTP TCAF. TDTP 2405. 983 TCND. TDTP 10438. 395 TCFD. TDTP 1803. 486 TSCN. TDTP TSCF. TDTP 127. 605 INND. TDTP 1433. 435 INFD. TDTP 176. 905 GRCH. TDTP TENS. TDTP 1100. 000 CCL. TDTP O. 000 DEPT. 7991. 500 SIGM. TDTP SBHN. TDTP -999. 250 SIGC. TDTP SDSI. TDTP -999. 250 BACK. TDTP TCAF. TDT£ -999. 250 TCND. TDTP TSCF. TDTP -999. 250 INND. TDTP TENS. TDTP - 999.250 CCL . TDTP -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 63.643 2.185 12342.457 688.794 -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SIBH. TDTP -999. 250 TRAT. TDTP - 999. 250 FBAC. TDTP -999,250 TCAN. TDTP -999.250 TCFD. TDTP -999. 250 TSCN. TDTP - 999. 250 INFD. TDTP -999. 250 GRCH. TDTP 98. 750 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 25 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 8 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 8 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8220.0 7970.0 TDTP 8254.0 7970,0 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 4 BASELINE DEPTH 88888.0 8227.5 8206.0 8205.5 8200.5 8190.0 8188.5 8186.0 8185.0 8183.0 8178.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP .............. 88875.5 88892.5 8193.5 8188.0 8178.5 8176.0 8174.0 8171.0 8232.0 8209.5 8189.0 8181.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 26 8171.5 8175.0 8171.0 8158.5 8163.0 8151.5 8158.5 8145.0 8152.5 8141.5 8157.0 8148.0 8136.0 8144.5 8149.5 8141.5 8128.5 8136.0 8123.0 8135.0 8139.0 8122.0 8110.5 8110.0 8097.5 8109.5 8117.5 8089.5 8092.0 8088.5 8074.5 8087.0 8072.0 8080.0 8064.5 8073.5 8061.0 8069.5 8056.5 8068.0 8054.5 8067.5 8064.0 8052.0 8038.0 8046.5 8034.5 8037.0 8033.5 8025.5 8015.0 8020.5 8016.5 8007.5 100.0 91.0 95.0 REMARKS: This file contains Upper Borax Pass #2 of the TDTP. The depth adjustments shown above reflect Upper Borax Pass #2 GRCH to Base Pass #4 GRCH and Upper Borax Pass #2 SIGMA to Base Pass #4 SIGMA. Ail other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64BB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 27 TYPE REPR CODE VALUE 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) DEPT FT 100612 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM TDTP CU 100612 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI TDTP PU-S 100612 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF TDTP CU 100612 O0 000 O0 0 8 1 1 4 68 0000000000 SBHN TDTP CU 100612 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC TDTP CU 100612 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH TDTP CU 100612 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT TDTP 100612 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI TDTP CU 100612 O0 000 O0 0 8 1 1 4 68 0000000000 BACK TDTP CPS 100612 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC TDTP CPS 100612 O0 000 O0 0 8 1 1 4 68 0000000000 TCAN TDTP CPS 100612 O0 000 O0 0 8 1 1 4 68 0000000000 TCAF TDTP CPS 100612 O0 000 O0 0 8 1 1 4 68 0000000000 TCND TDTP CPS 100612 O0 000 O0 0 8 1 1 4 68 0000000000 TCFD TDTP CPS 100612 O0 000 O0 0 8 1 1 4 68 0000000000 TSCN TDTP CPS 100612 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF TDTP CPS 100612 O0 000 O0 0 8 1 1 4 68 0000000000 INND TDTP CPS 100612 O0 000 O0 0 8 1 1 4 68 0000000000 INFD TDTP CPS 100612 O0 000 O0 0 8 1 1 4 68 0000000000 GRCH TDTP GAPI 100612 O0 000 O0 0 8 1 1 4 68 0000000000 TENS TDTP LB 100612 O0 000 O0 0 8 1 1 4 68 0000000000 CCL TDTP V 100612 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 8234. 500 SIGM. TDTP 40. 878 TPHI. TDTP 68. 679 SBHF. TDTP SBHN. TDTP 75. 690 SIGC. TDTP 2. 045 SIBH. TDTP 117. 895 TRAT. TDTP SDSI. TDTP 2. 595 BACK. TDTP 168.817 FBAC. TDTP 30.137 TCAN. TDTP TCAF. TDTP 2094. 742 TCND. TDTP 8283. 654 TCFD. TDTP 1635. 614 TSCN. TDTP TSCF. TDTP 129. 639 INND. TDTP 1486. 020 INFD. TDTP 202.241 GRCH. TDTP TENS. TDTP 1105. 000 CCL. TDTP 0. 000 70. 735 1. 756 9477. 193 503. 969 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 DEPT. 7981. 000 SIGM. TDTP -999. 250 TPHI. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP SDSI. TDTP -999. 250 BACK. TDTP -999. 250 FBAC. TDTP TCAF. TDTP - 999. 250 TCND. TDTP - 999. 250 TCFD. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP TENS. TDTP -999.250 CCL. TDTP -999.250 -999.250 SBHF. TDTP - 999.250 TRAT. TDTP -999.250 TCAN. TDTP -999. 250 TSCN. TDTP - 999.250 GRCH. TDTP PAGE: 28 -999.250 -999.250 -999.250 -999.250 112.813 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 9 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 9 DEPTH INCR~IENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 8982.0 8760.0 TDTP 9012.0 8760.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 29 88888.0 8993.5 8985.0 8981.0 8958.5 8956.5 8948.0 8944.5 8940.5 8935.5 8929.5 8926.0 8924.5 8920.0 8912.5 8908.5 8905.5 8902.5 8900.5 8892.5 8889.0 8888.0 8884.5 8880.5 8876.5 8874 0 8870 5 8868 5 8865 0 8860 5 8859 0 8855 5 8852 5 8850 5 8848 5 8845.5 8843.5 8839.5 8835.5 8831.0 8827.0 8825.0 8823.0 8822.0 8818.5 8814.0 8793.0 8778.0 8765.0 100.0 $ 88896.5 8965.0 8953.0 8948.5 8943.5 8936.5 8933.0 8921.0 8917.5 8901.0 8896.5 8893.0 8888.5 8883.0 8879.5 8876.5 8868.0 8864.0 8860.5 8856.5 8848.5 8835.0 8832.5 8826.5 8815.5 8795.5 8781.0 103.0 88890.0 8995.5 8987.0 8982.5 8957.0 8949.5 8934.5 8924.0 8908.0 8902.0 8899.5 8892.5 8883.0 8878.5 8872.5 8867.0 8856.5 8853.0 8844.5 8839.5 8834.5 8832.0 8829.0 8788.0 8774.5 109.5 REMARKS: This file contains Lower Borax Pass #1 of the TDTP. The depth adjustments shown above reflect Lower Borax LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 30 Pass #1 GRCH to Base Pass #4 GRCH and Lower Borax Pass #1 SIGMA to Base Pass #4 SIGMA. Ail other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SBT TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100612 O0 000 O0 0 9 1 I 4 68 0000000000 SIGM TDTP CU 100612 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI TDTP PU-S 100612 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF TDTP CU 100612 O0 000 O0 0 9 1 1 4 68 0000000000 SBHN TDTP CU 100612 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC TDTP CU 100612 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH TDTP CU 100612 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT TDTP 100612 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI TDTP CU 100612 O0 000 O0 0 9 1 1 4 68 0000000000 BACK TDTP CPS 100612 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC TDTP CPS 100612 O0 000 O0 0 9 1 1 4 68 0000000000 TCAN TDTP CPS 100612 O0 000 O0 0 9 1 1 4 68 0000000000 TCAF TDTP CPS 100612 O0 000 O0 0 9 1 1 4 68 0000000000 TCND TDTP CPS 100612 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD TDTP CPS 100612 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN TDTP CPS 100612 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 31 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) TSCFTDTP CPS 100612 O0 000 O0 0 9 1 1 4 68 0000000000 INND TDTP CPS 100612 O0 000 O0 0 9 1 1 4 68 0000000000 INFD TDTP CPS 100612 O0 000 O0 0 9 1 1 4 68 0000000000 GRCH TDTP GAPI 100612 O0 000 O0 0 9 1 1 4 68 0000000000 TENS TDTP LB 100612 O0 000 O0 0 9 1 1 4 68 0000000000 CCL TDTP V 100612 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 8997. 000 SIGM. TDTP 19. 585 TPHI. TDTP 29. 885 SBHF. TDTP SBHN. TDTP 81.216 SIGC. TDTP O. 399 SIBH. TDTP 125. 685 TRAT. TDTP SDSI. TDTP 0. 897 BACK. TDTP 167. 428 FBAC. TDTP 33. 342 TCAN. TDTP TCAF. TDTP 3746. 515 TCND. TDTP 10149. 686 TCFD. TDTP 3203. 612 TSCN. TDTP TSCF. TDTP 856. 006 INND. TDTP 1465. 404 INFD. TDTP 284. 085 GRCH. TDTP TENS. TDTP 1215,000 CCL. TDTP O. 000 DEPT. 8763. 000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999,250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999. 250 CCL. TDTP -999. 250 69. 029 1.576 8556. 658 1955. 031 - 999. 250 -999.250 -999.250 -999.250 -999.250 61.875 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SBRVICE : FLIC VBRSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 32 FILE HEADER FILE NUMBER: 10 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 10 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8985.0 8750.0 TDTP 9018.0 8750.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9007.5 8997.5 8993.5 8981.0 8977.5 8973.5 8967.5 8965.5 8958.0 8954.0 8947.5 8946.5 8943.5 8939.0 8927.5 8925.5 8923.5 8921.5 8915.5 8908.5 8902.0 8901.5 8900.5 8900.0 8896.0 8896.0 8893,5 8893.5 8891.5 8889.0 8886.5 8883.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP .............. 88897.5 88889.5 8977.0 8963.5 8956.0 8952.0 8947.5 8935.0 8932,5 8924.0 8911.0 8908.5 8906.0 8902.5 8900.5 8895.5 8890.5 9009.0 8999.5 8996.0 8982.0 8979.0 8975.5 8967.5 8956.0 8949.5 8934.5 8927.0 8913.0 8902.0 8899.5 8897.5 8895.5 8892.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 33 8875 5 8871 5 8871 5 8870 0 8867 5 8865 0 8863 5 8859 0 8858 5 8855 5 8851 5 8847 5 8843.5 8843.5 8839.5 8835.5 8831.5 8830.0 8825.0 8824.0 8819.5 8819.0 8815.5 8811.5 8807.5 8803.5 8799.5 8789,5 8787.5 8783.5 8764.5 8757.5 100.0 8882.5 8878.O 8874.5 8871.0 8867.0 8862.0 8858.0 8853.0 8848.5 8845.0 8840.5 8836.0 8829.5 8823.5 8818.5 8814.0 8809.5 8806.0 8801.5 8788.5 8785.0 8763.5 106.0 8881.0 8878.5 8872.5 8867.0 8852.0 8840.0 8834.5 8828.5 8800.0 8774.0 109.5 REMARKS: This file contains Lower Borax Pass #2 of the TDTP. The depth adjustments shown above reflect Lower Borax Pass #2 GRCH to Base Pass #1 GRCH and Lower Borax Pass #2 SIGMA to Base Pass #1 SIGMA. Ail other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 '66 0 2 66 0 3 73 88 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 34 TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100612 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM TDTP CU 100612 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI TDTP PU-S 100612 O0 000 O0 0 10 1 1 4 68 0000000000 SBHF TDTP CU 100612 O0 000 O0 0 10 1 1 4 68 0000000000 SBHNTDTP CU 100612 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC TDTP CU 100612 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH TDTP CU 100612 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT TDTP 100612 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI TDTP CU 100612 O0 000 O0 0 10 1 1 4 68 0000000000 BACK TDTP CPS 100612 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC TDTP CPS 100612 O0 000 O0 0 10 1 1 4 68 0000000000 TCANTDTP CPS 100612 O0 000 O0 0 10 1 1 4 68 0000000000 TCAF TDTP CPS 100612 O0 000 00 0 10 1 1 4 68 0000000000 TCND TDTP CPS 100612 O0 000 O0 0 10 1 1 4 68 0000000000 TCFD TDTP CPS 100612 O0 000 O0 0 10 1 1 4 68 0000000000 TSCN TDTP CPS 100612 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF TDTP CPS 100612 O0 000 O0 0 10 1 1 4 68 0000000000 INND TDTP CPS 100612 O0 000 O0 0 10 1 1 4 68 0000000000 INFD TDTP CPS 100612 O0 000 O0 0 I0 1 1 4 68 0000000000 GRCH TDTP GAPI 100612 O0 000 O0 0 10 1 1 4 68 0000000000 TENS TDTP LB 100612 O0 000 O0 0 10 1 1 4 68 0000000000 CCL TDTP V 100612 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 8997. 316 SIGM. TDTP 18. 683 TPHI. TDTP 32.182 SBHF. TDTP 68. 048 SBHN. TDTP 81. 932 SIGC. TDTP 0. 255 SIBH. TDTP 127. 778 TRAT. TDTP 1. 665 SDSI. TDTP O. 804 BACK. TDTP 181. 999 FBAC. TDTP 44. 768 TCAN. TDTP 9410. 598 TCAF. TDTP 3954.518 TCND. TDTP 10146.264 TCFD. TDTP 3189. 864 TSCN. TDTP 2151. 836 TSCF. TDTP 904.244 INND. TDTP 1405.375 INFD. TDTP 268.159 GRCH. TDTP -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 35 TENS. TDTP 1200. 000 CCL. TDTP 0.000 DEPT. 8756.316 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 68.250 TENS. TDTP -999.250 CCL. TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : 001C01 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 11 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, 4, 5, 6 TDTP REMARKS: The arithmetic average of passes 1, 2, 3, 4, 5 & 6 was computed after all depth shifts and clipping was applied. The average is presented as one curve starting with =he lower pass and ending at the top of the upper passes. Absent values are presented between the curves. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 36 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100612 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM PNAV CU 100612 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI PNAV PU-S 100612 O0 000 O0 0 11 1 1 4 68 0000000000 SBHF PNAV CU 100612 O0 000 O0 0 11 1 1 4 68 0000000000 SBHN PNAV CU 100612 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC PNAV CU 100612 O0 000 O0 0 11 1 1 4 68 0000000000 SIBH PNAV CU 100612 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT PNAV 100612 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI PNAV CU 100612 O0 000 O0 0 11 1 1 4 68 0000000000 BACK TDTP CPS 100612 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC TDTP CPS 100612 O0 000 O0 0 11 1 1 4 68 0000000000 TCAN PNAV CPS 100612 O0 000 O0 0 11 1 1 4 68 0000000000 TCAF PNAV CPS 100612 O0 000 O0 0 11 1 I 4 68 0000000000 TCND PNAV CPS 100612 O0 000 O0 0 11 1 1 4 68 0000000000 TCFD PNAV CPS 100612 O0 000 O0 0 11 1 1 4 68 0000000000 TSCN PNAV CPS 100612 O0 000 O0 0 11 1 1 4 68 0000000000 TSCF PNAV CPS 100612 O0 000 O0 0 11 1 1 4 68 0000000000 INND PNAV CPS 100612 O0 000 O0 0 11 1 1 4 68 0000000000 INFD PNAV CPS 100612 O0 000 O0 0 11 1 1 4 68 0000000000 GRCH TDTP GAPI 100612 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 37 ** DATA ** DEPT. 9001.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND. PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD. PNAV -999.250 GRCH. TDTP 22.656 DEPT. 7999.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND. PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND. PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP 58.500 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 9035.0 8689,5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 38 $ 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 TDTP TDTP TDTP TDTP TDTP TDTP TDTP $ GA~A RAY SOURCE THERMAL DECAY TDTP DETECTOR CART. TDTP CARTRIDGE TDTP SONDE DETECTOR TDTP SONDE GENERATOR MINITRON 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 (DBGF) : 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): 16-NOV-96 CP 44.2 1049 16-NOV-96 9024.0 9018.0 8000.0 9011.0 1800.0 TOOL NUMBER CGRS 863 CPLC 805 TDIC 8337 TNC-P 390 TND-P 395 TNG-P 400 ~TTRN 8729 0.0 8541.0 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): 13000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 39 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: THIS FILE CONTAINS RAW DATA FROM LOWER BASELINE PASS #1. TIED INTO SWS BHC DATED 6-15-76 LOGGED TDTP TO DETERMINE IF 3.5" LINER TOP IS LEAKING LOGGED BASELINE PASSES WHILE INJ 1~ KCL AT 1 BPM LOGGED BORAX PASSES WHILE INJ AT 3 BPM ALL PASSES LOGGED AT 30 FPM PUMPED 150 BBLS OF BORAX AND 420 BBLS OF SEAWATER TOP OF LINER APPEARS TO BE LEAKING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100612 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM PS1 CU 100612 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI PS1 PU 100612 O0 000 O0 0 12 1 1 4 68 0000000000 SBHF PS1 CU 100612 O0 000 O0 0 12 1 1 4 68 0000000000 SBHN PS1 CU 100612 O0 000 O0 0 12 1 1 4 68 0000000000 SIGC PS1 CU 100612 O0 000 O0 0 12 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 40 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) SIBH PS1 CU 100612 O0 000 O0 0 12 1 1 4 68 TRAT PS1 100612 O0 000 O0 0 12 1 1 4 68 SDSI PS1 CU 100612 O0 000 O0 0 12 1 1 4 68 BACK PS1 CPS 100612 O0 000 O0 0 12 1 1 4 68 FBAC PS1 CPS 100612 O0 000 O0 0 12 1 1 4 68 TCAN PS1 CPS 100612 O0 000 O0 0 12 1 1 4 68 TCAF PS1 CPS 100612 O0 000 O0 0 12 1 1 4 68 TCNDPS1 CPS 100612 O0 000 O0 0 12 1 1 4 68 TCFD PS1 CPS 100612 O0 000 O0 0 12 1 1 4 68 TSCN PS1 CPS 100612 O0 000 O0 0 12 1 1 4 68 TSCF PS1 CPS 100612 O0 000 O0 0 12 1 1 4 68 INND PS1 CPS 100612 O0 000 O0 0 12 1 1 4 68 INFD PS1 CPS 100612 O0 000 00 0 12 1 1 4 68 TENS PS1 LB 100612 O0 000 O0 0 12 1 1 4 68 GR PS1 GAPI 100612 O0 000 O0 0 12 1 1 4 68 CCL PS1 V 100612 O0 000 O0 0 12 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 9028.000 SIGM. PS1 22.626 TPHI.PS1 0.000 SBHF. PS1 SBHN. PS1 85.422 SIGC, PS1 0.021 SIBH.PS1 101.978 TRAT. PS1 SDSI.PS1 5.672 BACK. PSI 10.946 FBAC.PS1 10.787 TCAN. PS1 TCAF. PS1 0.000 TCND. PS1 -999.250 TCFD. PS1 -999.250 TSCN. PS1 TSCF. PS1 0.000 INND. PS1 -0.372 INFD.PS1 -0.367 TENS.PSI GR.PS1 22.656 CCL.PS1 0.030 DEPT. 8682.500 SIGM. PS1 12.245 TPHI.PS1 26.715 SBHF. PSI SBHN. PS1 58.936 SIGC. PS1 0.757 SIBH. PS1 76,990 TRAT. PS1 SDSI.PS1 0.269 BACK. PSi 67.430 FBAC, PS1 13.712 TCAN. PS1 TCAF. PS1 12435.334 TCND. PS1 21136.777 TCFD. PS1 6821.261 TSCN. PS1 TSCF. PS1 2878.261 INND.PS1 1710.320 INFD.PS1 245.261 TENS.PSI GR.PS1 16.281 CCL.PSI 0.000 128.985 0.000 0.000 0.000 920.000 54.079 1.776 28121.652 6508.989 1225.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 41 **** FILE HEADER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 9029.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): STOP DEPTH 8690.0 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 TDTP TDTP TDTP TDTP TDTP TDTP TDTP $ GAMMA RAY SOURCE THERMAL DECAY TDTP DETECTOR CART. TDTP CARTRIDGE TDTP SONDE DETECTOR TDTP SONDE GENERATOR MINITRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: 16-NOV-96 CP 44.2 1101 16-NOV-96 9024.0 9018.0 8000.0 9011.0 1800.0 TOOL NUMBER ........... CGRS 863 CPLC 805 TDIC 8337 TNC-P 390 TND-P 395 TNG-P 400 ~NTRN 8729 0.0 8541.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 42 FLUID DENSITY (LB/G): SURFACE T~PERATURE (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): 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): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: THIS FILE CONTAINS RAW DATA FROM LOWER BASELINE PASS #2. TIED INTO SWS BHC DATED 6-15-76 LOGGED TDTP TO DETERMINE IF 3.5" LINER TOP IS LEAKING LOGGED BASELINE PASSES WHILE INJ 1~ KCL AT 1 BPM LOGGED BORAX PASSES WHILE INJ AT 3 BPM ALL PASSES LOGGED AT 30 FPM PUMPED 150 BBLS OF BORAX AND 420 BBLS OF SEAWATER TOP OF LINER APPEARS TO BE LEAKING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 LIS Tape Verification Lis=ing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 43 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100612 O0 000 O0 0 13 1 1 4 68 0000000000 SIGM PS2 CU 100612 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI PS2 PU 100612 O0 000 O0 0 13 1 1 4 68 0000000000 SBHF PS2 CU 100612 O0 000 O0 0 13 1 1 4 68 0000000000 SBHNPS2 CU 100612 O0 000 O0 0 13 1 1 4 68 0000000000 SIGC PS2 CU 100612 O0 000 O0 0 13 1 1 4 68 0000000000 SIBH PS2 CU 100612 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT PS2 100612 O0 000 O0 0 13 1 1 4 68 0000000000 SDSI PS2 CU 100612 O0 000 O0 0 13 1 1 4 68 0000000000 BACK PS2 CPS 100612 O0 000 O0 0 13 1 1 4 68 0000000000 FBAC PS2 CPS 100612 O0 000 O0 0 13 1 1 4 68 0000000000 TCANPS2 CPS 100612 O0 000 O0 0 13 1 1 4 68 0000000000 TCAF PS2 CPS 100612 O0 000 O0 0 13 1 1 4 68 0000000000 TCND PS2 CPS 100612 O0 000 O0 0 13 1 1 4 68 0000000000 TCFD PS2 CPS 100612 O0 000 O0 0 13 1 1 4 68 0000000000 TSCN PS2 CPS 100612 O0 000 O0 0 13 1 1 4 68 0000000000 TSCF PS2 CPS 100612 O0 000 O0 0 13 1 1 4 68 0000000000 INND PS2 CPS 100612 O0 000 O0 0 13 1 1 4 68 0000000000 INFD PS2 CPS 100612 O0 000 O0 0 13 1 1 4 68 0000000000 TENS PS2 LB 100612 O0 000 O0 0 13 1 1 4 68 0000000000 GR PS2 GAPI 100612 O0 000 O0 0 13 1 1 4 68 0000000000 CCL PS2 V 100612 O0 000 O0 0 13 1 1 4 68 0000000000 ** DATA ** DEPT. 9022.000 SIGM. PS2 12.245 TPHI.PS2 26.715 SBHF. PS2 SBHN. PS2 58.936 SIGC. PS2 0.757 SIBH. PS2 76.990 TRAT. PS2 SDSI.PS2 0.269 BACK. PS2 67.430 FBAC. PS2 13.712 TCAN. PS2 TCAF. PS2 12435.334 TCND. PS2 21136.777 TCFD.PS2 6821.261 TSCN. PS2 TSCF. PS2 2878.261 INND. PS2 1710.320 INFD. PS2 245.261 TENS.PS2 GR.PS2 190.500 CCL.PS2 0.021 54.079 1.776 28121.652 6508.989 905.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 44 DEPT. 8683.000 SIGM. PS2 11.352 TPHI.PS2 SBHN. PS2 57.197 SIGC. PS2 1.052 SIBH. PS2 SDSI.PS2 0.270 BACK. PS2 122.418 FBAC. PS2 TCAF. PS2 12590.107 TCND. PS2 21115.980 TCFD.PS2 TSCF. PS2 2927.459 INND. PS2 1681.573 INFD.PS2 GR. PS2 36.906 CCL. PS2 0.000 26.373 SBHF. PS2 72.624 TRAT. PS2 21.978 TCAN. PS2 6820.272 TSCN. PS2 247.097 TENS.PS2 44.794 1.806 28595.191 6648.971 1210.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : 001C01 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .014 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 14 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 9028.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : STOP DEPTH 8689.0 16-NOV-96 CP 44.2 1115 16-NOV-96 9024.0 9018.0 8000.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 45 BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 9011.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP TDTP TDTP TDTP TDTP TDTP TDTP $ GAMMA RAY SOURCE THERMAL DECAY TDTP DETECTOR CART. TDTP CARTRIDGE TDTP SONDE DETECTOR TDTP SONDE GENERATOR MINITRON TOOL NUMBER CGRS 863 CPLC 805 TDIC 8337 TNC-P 390 TND-P 395 TNG-P 400 b~TTRN 8729 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 0.0 8541.0 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 (EPITHBRMAL 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): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: THIS FILE CONTAINS RAW DATA FROM LOWER BASELINE PASS #3. TIED INTO SWS BHC DATED 6-15-76 LOGGED TDTP TO DETERMINE IF 3.5" LINER TOP IS LEAKING LOGGED BASELINE PASSES WHILE INJ 1~ KCL AT 1 BPM LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 46 LOGGED BORAX PASSES WHILE INJ AT 3 BPM ALL PASSES LOGGED AT 30 FPM PUMPED 150 BBLS OF BORAX AND 420 BBLS OF SEAWATER TOP OF LINER APPEARS TO BE LEAKING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100612 O0 000 O0 0 14 1 1 4 68 0000000000 SIGM PS3 CU 100612 O0 000 O0 0 14 1 1 4 68 0000000000 TPHI PS3 PU 100612 O0 000 O0 0 14 1 1 4 68 0000000000 SBHF PS3 CU 100612 O0 000 O0 0 14 1 1 4 68 0000000000 SBHN PS3 CU 100612 O0 000 O0 0 14 1 1 4 68 0000000000 SIGC PS3 CU 100612 O0 000 O0 0 14 1 1 4 68 0000000000 SIBH PS3 CU 100612 O0 000 O0 0 14 1 1 4 68 0000000000 TRAT PS3 100612 O0 000 O0 0 14 1 1 4 68 0000000000 SDSI PS3 CU 100612 O0 000 O0 0 14 1 1 4 68 0000000000 BACK PS3 CPS 100612 O0 000 O0 0 14 1 1 4 68 0000000000 FBAC PS3 CPS 100612 O0 000 O0 0 14 1 1 4 68 0000000000 TCANPS3 CPS 100612 O0 000 O0 0 14 1 1 4 68 0000000000 TCAF PS3 CPS 100612 O0 000 O0 0 14 1 1 4 68 0000000000 TCND PS3 CPS 100612 O0 000 O0 0 14 1 1 4 68 0000000000 TCFD PS3 CPS 100612 O0 000 O0 0 14 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 47 NAME SERV UNIT SERVICE API API API API FILE NU~fB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) TSCN PS3 CPS 100612 O0 000 O0 0 14 1 1 4 68 0000000000 TSCF PS3 CPS 100612 O0 000 O0 0 14 1 1 4 68 0000000000 INNDPS3 CPS 100612 O0 000 O0 0 14 1 1 4 68 0000000000 INFD PS3 CPS 100612 O0 000 O0 0 14 1 1 4 68 0000000000 TENS PS3 LB 100612 O0 000 O0 0 14 1 1 4 68 0000000000 GR PS3 GAPI 100612 O0 000 O0 0 14 1 1 4 68 0000000000 CCL PS3 V 100612 O0 000 O0 0 14 1 1 4 68 0000000000 ** DATA ** DEPT. 9029.500 SIGM. PS3 11.352 TPHI.PS3 26.373 SBHF. PS3 44.794 SBHN. PS3 57.197 SIGC. PS3 1.052 SIBH. PS3 72,624 TRAT. PS3 1.806 SDSI.PS3 0.270 BACK. PS3 122.418 FBAC. PS3 21.978 TCAN. PS3 28595.191 TCAF. PS3 12590.107 TCND.PS3 21115.980 TCFD. PS3 6820.272 TSCN. PS3 6648.971 TSCF. PS3 2927.459 INND.PS3 1681.573 INFD.PS3 247.097 TENS.PS3 875.000 GR.PS3 74.313 CCL.PS3 0.048 DEPT. 8690.000 SIGM. PS3 27.400 TPHI.PS3 47.974 SBHF. PS3 53.460 SBHN, PS3 66.243 SIGC. PS3 2.804 SIBH. PS3 96.464 TRAT. PS3 1.723 SDSI.PS3 1.048 BACK. PS3 146.063 FBAC.PS3 30.521 TCAN. PS3 13452.467 TCAF. PS3 4187.071 TCND. PS3 13978.010 TCFD,PS3 3418.290 TSCN. PS3 1679.251 TSCF. PS3 580.279 INND. PS3 1618.171 INFD.PS3 218.095 TENS.PS3 1190.000 GR.PS3 81.000 CCL. PS3 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .014 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .015 SERVICE : FLIC VERSION : 001C01 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 48 FILE HEADER FILB NU~ER 15 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCRJ~VlENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 8254.5 $ LOG HEADER DATA STOP DEPTH 7992.5 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 TDTP TDTP TDTP TDTP TDTP TDTP TDTP $ GAMMA RAY SOURCE THERMAL DECAY TDTP DETECTOR CART. TDTP CARTRIDGE TDTP SONDE DETECTOR TDTP SONDE GENERATOR MINITRON 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): 16-NOV-96 CP 44.2 1129 16-NOV-96 9024.0 9018.0 8000,0 9011.0 1800.0 TOOL NUMBER CGRS 863 CPLC 805 TDIC 8337 TNC-P 390 TND-P 395 TNG-P 400 MNTRN 8729 0.0 8541.0 THERMAL LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 49 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 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): FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: THIS FILE CONTAINS RAW DATA FROM UPPER BASELINE PASS #1 (PASS #4). TIED INTO SWS BHC DATED 6-15-76 LOGGED TDTP TO DETERMINE IF 3.5" LINER TOP IS LEAKING LOGGED BASELINE PASSES WHILE INJ 1~ KCL AT 1 BPM LOGGED BORAX PASSES WHILE INJ AT 3 BPM ALL PASSES LOGGED AT 30 FPM PUMPED 150 BBLS OF BORAX AND 420 BBLS OF SEAWATER TOP OF LINER APPEARS TO BE LEAKING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 50 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP BL~4 CODE (HEX) DEPT FT 100612 O0 000 O0 0 15 1 1 4 68 0000000000 SIGM PS4 CU 100612 O0 000 O0 0 15 1 1 4 68 0000000000 TPHI PS4 PU 100612 O0 000 O0 0 15 1 1 4 68 0000000000 SBHF PS4 CU 100612 O0 000 O0 0 15 1 1 4 68 0000000000 SBHNPS4 CU 100612 O0 000 O0 0 15 1 1 4 68 0000000000 SIGC PS4 CU 100612 O0 000 O0 0 15 1 1 4 68 0000000000 SIBH PS4 CU 100612 O0 000 O0 0 15 1 1 4 68 0000000000 TRAT PS4 100612 O0 000 O0 0 15 1 1 4 68 0000000000 SDSI PS4 CU 100612 O0 000 O0 0 15 1 1 4 68 0000000000 BACK PS4 CPS 100612 O0 000 O0 0 15 1 1 4 68 0000000000 FBAC PS4 CPS 100612 O0 000 O0 0 15 1 1 4 68 0000000000 TCANPS4 CPS 100612 O0 000 O0 0 15 1 1 4 68 0000000000 TCAFPS4 CPS 100612 O0 000 O0 0 15 1 1 4 68 0000000000 TCNDPS4 CPS 100612 O0 000 O0 0 15 1 1 4 68 0000000000 TCFD PS4 CPS 100612 O0 000 O0 0 15 1 1 4 68 0000000000 TSCN PS4 CPS 100612 O0 000 O0 0 15 1 1 4 68 0000000000 TSCF PS4 CPS 100612 O0 000 O0 0 15 1 1 4 68 0000000000 INNDPS4 CPS 100612 O0 000 O0 0 15 1 1 4 68 0000000000 INFD PS4 CPS 100612 O0 000 O0 0 15 1 1 4 68 0000000000 TENS PS4 LB 100612 O0 000 O0 0 15 1 1 4 68 0000000000 GR PS4 GAPI 100612 O0 000 O0 0 15 1 1 4 68 0000000000 CCL PS4 V 100612 O0 000 O0 0 15 1 1 4 68 0000000000 ** DATA ** DEPT. 8250.500 SIGM. PS4 27.400 TPHI.PS4 47.974 SBHF. PS4 53.460 SBHN. PS4 66.243 SIGC. PS4 2.804 SIBH. PS4 96.464 TRAT. PS4 1.723 SDSI.PS4 1.048 BACK. PS4 146.063 FBAC. PS4 30.521 TCAN. PS4 13452.467 TCAF. PS4 4187.071 TCND. PS4 13978.010 TCFD. PS4 3418.290 TSCN. PS4 1679.251 TSCF. PS4 580.279 INND. PS4 1618.171 INFD. PS4 218.095 TENS. PS4 1055.000 GR.PS4 71.813 CCL.PS4 0.026 DEPT. 7988.500 SIGM. PS4 38.207 TPHI.PS4 73.500 SBHF. PS4 57.717 SBHN. PS4 65.761 SIGC. PS4 0.116 SIBH. PS4 95.369 TRAT. PS4 1.939 SDSI. PS4 1.851 BACK. PS4 155.959 FBAC. PS4 29.493 TCAN. PS4 9114.947 TCAF. PS4 2315.309 TCND.PS4 11384.752 TCFD. PS4 2435.559 TSCN. PS4 1067.951 TSCF. PS4 282.812 INND. PS4 1513.455 INFD. PS4 204.502 TENS.PS4 1100.000 GR.PS4 68.813 CCL.PS4 0.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 51 **** FILE TRAILER **** FILE NAME : EDIT .015 SERVICE : FLIC VERSION : 001C01 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .016 SERVICE : FLIC VERSION : 001C01 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 16 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCRI~ENT: O. 5000 FILE SU~FIARY VENDOR TOOL CODE START DEPTH TDTP 8256.5 $ 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 TDTP TDTP TDTP TDTP TDTP TDTP STOP DEPTH 7993.0 GAM~A RAY SOURCE THERMAL DECAY TDTP DETECTOR CART. TDTP CARTRIDGE TDTP SONDE DETECTOR TDTP SONDE GENERATOR 16-NOV-96 CP 44.2 1140 16-NOV-96 9024.0 9018.0 8000.0 9011.0 1800.O TOOL NUMBER ........... CGRS 863 CPLC 805 TDIC 8337 TNC-P 390 TND-P 395 TNG-P 400 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 52 TDTP MINITRON FINTRN 8729 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 0.0 8541.0 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): 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): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: THIS FILE CONTAINS RAW DATA FROM UPPER BASELINE PASS #2 (PASS #5). TIED INTO SWS BHC DATED 6-15- 76 LOGGED TDTP TO DETERMINE IF 3.5" LINER TOP IS LEAKING LOGGED BASELINE PASSES WHILE INJ 1% KCL AT 1 BPM LOGGED BORAX PASSES WHILE INJ AT 3 BPM ALL PASSES LOGGED AT 30 FPM PUMPED 150 BBLS OF BORAX AND 420 BBLS OF SEAWATER TOP OF LINER APPEARS TO BE LEAKING. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 53 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE RBPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 3KIMB 3K. IMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) DEPT FT 100612 O0 000 O0 0 16 1 1 4 68 0000000000 SIGM PS5 CU 100612 O0 000 O0 0 16 1 1 4 68 0000000000 TPHI PS5 PU 100612 O0 000 O0 0 16 1 1 4 68 0000000000 SBHF PS5 CU 100612 O0 000 O0 0 16 1 1 4 68 0000000000 SBHNPS5 CU 100612 O0 000 O0 0 16 1 1 4 68 0000000000 SIGC PS5 CU 100612 O0 000 O0 0 16 1 1 4 68 0000000000 SIBH PS5 CU 100612 O0 000 O0 0 16 1 1 4 68 0000000000 TRAT PS5 100612 O0 000 O0 0 16 1 1 4 68 0000000000 SDSI PS5 CU 100612 O0 000 O0 0 16 1 1 4 68 0000000000 BACK PS5 CPS 100612 O0 000 O0 0 16 1 1 4 68 0000000000 FBAC PS5 CPS 100612 O0 000 O0 0 16 1 1 4 68 0000000000 TCAN PS5 CPS 100612 O0 000 O0 0 16 1 1 4 68 0000000000 TCAF PS5 CPS 100612 O0 000 O0 0 16 1 1 4 68 0000000000 TCND PS5 CPS 100612 O0 000 O0 0 16 1 1 4 68 0000000000 TCFD PS5 CPS 100612 O0 000 O0 0 16 1 1 4 68 0000000000 TSCN PS5 CPS 100612 O0 000 O0 0 16 1 1 4 68 0000000000 TSCF PS5 CPS 100612 O0 000 O0 0 16 1 1 4 68 0000000000 INNDPS5 CPS 100612 O0 000 O0 0 16 1 1 4 68 0000000000 INFD PS5 CPS 100612 O0 000 O0 0 16 1 1 4 68 0000000000 TENS PS5 LB 100612 00 000 O0 0 16 1 1 4 68 0000000000 GR PS5 GAPI 100612 O0 000 00 0 16 1 1 4 68 0000000000 CCL PS5 V 100612 O0 000 O0 0 16 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 54 ** DATA ** DEPT. 8252.500 SIGM. PS5 SBHN. PS5 65.761 SIGC. PS5 SDSI.PS5 1.851 BACK. PS5 TCAF. PS5 2315.309 TCND. PS5 TSCF. PS5 282.812 INND.PS5 GR.PS5 131.375 CCL.PS5 DEPT. 7989.000 SIGM. PS5 SBHN. PS5 68.382 SIGC. PS5 SDSI.PS5 1.759 BACK. PS5 TCAF. PS5 2307.243 TCND.PS5 TSCF. PS5 294.623 INND. PS5 GR.PS5 94.250 CCL.PS5 38.207 TPHI.PS5 0.116 SIBH. PS5 155.959 FBAC. PS5 11384.752 TCFD.PS5 1513.455 INFD. PS5 0.026 36.224 TPHI.PS5 1.603 SIBH. PS5 160.598 FBAC. PS5 11249.473 TCFD.PS5 1468.671 INFD.PS5 0.000 73.500 SBHF. PS5 95.369 TRAT. PS5 29.493 TCAN. PS5 2435.559 TSCN. PS5 204.502 TENS.PS5 68.944 SBHF. PS5 101.316 TRAT. PS5 30.896 TCAN. PS5 2418.565 TSCN. PS5 185.315 TENS.PS5 57.717 1.939 9114.947 1067.951 1030.000 58.209 1.890 9117.781 1033.763 1080.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .016 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .017 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 17 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 8256.0 7990.5 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 55 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): 16-NOV-96 CP 44.2 1151 16-NOV-96 9024.0 9018.0 8000.0 9011.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP TDTP TDTP TDTP TDTP TDTP TDTP $ GAMMA RAY SOURCE THERMAL DECAY TDTP DETECTOR CART. TDTP CARTRIDGE TDTP SONDE DETECTOR TDTP SONDE GENERATOR MINITRON TOOL NUMBER CGRS 863 CPLC 805 TDIC 8337 TNC-P 390 TND-P 395 TNG-P 400 MNTRN 8729 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 0.0 8541.0 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): 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): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 56 NEAR COUNT RATE HIGH SCALE {CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: THIS FILE CONTAINS RAW DATA FROM UPPER BASELINE PASS #3 (PASS #6). TIED INTO SWS BHC DATED 6-15-76 LOGGED TDTP TO DETERMINE IF 3.5" LINER TOP IS LEAKING LOGGED BASELINE PASSES WHILE INJ lb KCL AT 1 BPM LOGGED BORAX PASSES WHILE INJ AT 3 BPM ALL PASSES LOGGED AT 30 FPM PUMPED 150 BBLS OF BORAX AND 420 BBLS OF SEAWATER TOP OF LINER APPEARS TO BE LEAKING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100612 O0 000 O0 0 17 1 1 4 68 0000000000 SIGM PS6 CU 100612 O0 000 O0 0 17 1 1 4 68 0000000000 TPHI PS6 PU 100612 O0 000 O0 0 17 1 1 4 68 0000000000 SBHF PS6 CU 100612 O0 000 O0 0 17 1 1 4 68 0000000000 SBHN PS6 CU 100612 O0 000 O0 0 17 1 1 4 68 0000000000 SIGC PS6 CU 100612 O0 000 O0 0 17 1 1 4 68 0000000000 SIBH PS6 CU 100612 O0 000 O0 0 17 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 57 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LO~ 'I~'PE CI.~SS MOD ~ SAMP ELJ~Vl CODE (HEX) TRAT PS6 100612 O0 000 O0 0 17 1 1 4 68 0000000000 SDSI PS6 CU 100612 O0 000 O0 0 17 1 1 4 68 0000000000 BACK PS6 CPS 100612 O0 000 O0 0 17 1 1 4 68 0000000000 FBAC PS6 CPS 100612 O0 000 O0 0 17 1 1 4 68 0000000000 TCANPS6 CPS 100612 O0 000 O0 0 17 1 1 4 68 0000000000 TCAF PS6 CPS 100612 O0 000 O0 0 17 1 1 4 68 0000000000 TCND PS6 CPS 100612 O0 000 O0 0 17 1 1 4 68 0000000000 TCFD PS6 CPS 100612 O0 000 O0 0 17 1 1 4 68 0000000000 TSCN PS6 CPS 100612 O0 000 O0 0 17 i 1 4 68 0000000000 TSCF PS6 CPS 100612 O0 000 O0 0 17 1 1 4 68 0000000000 INNDPS6 CPS 100612 O0 000 O0 0 17 1 1 4 68 0000000000 INFD PS6 CPS 100612 00 000 O0 0 17 1 1 4 68 0000000000 TENS PS6 LB 100612 O0 000 O0 0 17 1 1 4 68 0000000000 GR PS6 GAPI 100612 O0 000 O0 0 17 1 1 4 68 0000000000 CCL PS6 V 100612 O0 000 O0 0 17 1 1 4 68 0000000000 ** DATA ** DEPT. 8256.000 SIGM. PS6 47.760 TPHI.PS6 78.864 SBHF. PS6 SBHN. PS6 74.714 SIGC. PS6 0.000 SIBH. PS6 115.681 TRAT. PS6 SDSI.PS6 3.135 BACK. PS6 171.095 FBAC. PS6 66.290 TCAN. PS6 TCAF. PS6 1794.088 TCND. PS6 8158.732 TCFD.PS6 1513.917 TSCN. PS6 TSCF. PS6 97.672 INND. PS6 1501.621 INFD.PS6 186.341 TENS.PS6 GR.PS6 113.813 CCL.PS6 0.000 DEPT. 7996.000 SIGM. PS6 37.114 TPHI.PS6 67.821 SBHF. PS6 SBHN. PS6 72.699 SIGC. PS6 0.000 SIBH. PS6 111.110 TRAT. PS6 SDSI.PS6 1.815 BACK. PS6 154.991 FBAC. PS6 31.071 TCAN. PS6 TCAF. PS6 2410.689 TCND. PS6 9817.523 TCFD. PS6 2286.858 TSCN. PS6 TSCF. PS6 292.047 INND. PS6 1456.084 INFD.PS6 201.382 TENS. PS6 GR.PS6 92.000 CCL. PS6 0.000 59.811 1.853 8163.705 473.730 1100.000 67.263 1. 837 8773. 961 1044. 251 1080. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT . O17 SERVICE : FLIC VERSION : 001C01 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 58 **** FILE HEADER **** FILE NAME : EDIT .018 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 18 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 7 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... TDTP 8255.0 $ LOG HEADER DATA STOP DEPTH 7995.0 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 TDTP TDTP TDTP TDTP TDTP TDTP TDTP $ GAMMA RAY SOURCE THERMAL DECAY TDTP DETECTOR CART. TDTP CARTRIDGE TDTP SONDE DETECTOR TDTP SONDE GENERATOR MINITRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: 16-NOV-96 CP 44.2 1200 16-NOV-96 9024.0 9018.0 8000.0 9011.0 1800.0 TOOL NUMBER CGRS 863 CPLC 805 TDIC 8337 TNC-P 390 TND-P 395 TNG-P 400 MNTRN 8729 0.0 8541.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 59 FLUID DENSITY (LB/G): SURFACE T~PERATURE (DEGF) : BOTTOM HOLE T~PERATURE (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): 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): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REFIARKS: THIS FILE CONTAINS RAW DATA FROM UPPER BASELINE BORAX PASS #1 (PASS #7). TIED INTO SWS BHC DATED 6-15-76 LOGGED TDTP TO DETERMINE IF 3.5" LINER TOP IS LEAKING LOGGED BASELINE PASSES WHILE INJ 1~ KCL AT 1 BPM LOGGED BORAX PASSES WHILE INJ AT 3 BPM ALL PASSES LOGGED AT 30 FPM PUMPED 150 BBLS OF BORAX AND 420 BBLS OF SEAWATER TOP OF LINER APPEARS TO BE LEAKING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 60 TYPE REPR CODE VALUE .............................. 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100612 O0 000 O0 0 18 1 1 4 68 0000000000 SIGM BX1 CU 100612 O0 000 O0 0 18 1 1 4 68 0000000000 TPHI BX1 PU 100612 O0 000 O0 0 18 1 1 4 68 0000000000 SBHF BX1 CU 100612 O0 000 O0 0 18 1 1 4 68 0000000000 SBHN BX1 CU 100612 O0 000 O0 0 18 1 1 4 68 0000000000 SIGC BX1 CU 100612 O0 000 O0 0 18 1 1 4 68 0000000000 SIBH BX1 CU 100612 O0 000 O0 0 18 1 1 4 68 0000000000 TRATBX1 100612 O0 000 O0 0 18 1 1 4 68 0000000000 SDSI BXl CU 100612 00 000 00 0 18 1 1 4 68 0000000000 BACK BX1 CPS 100612 O0 000 O0 0 18 1 1 4 68 0000000000 FBAC BX1 CPS 100612 O0 000 O0 0 18 1 1 4 68 0000000000 TCANBX1 CPS 100612 O0 000 O0 0 18 1 1 4 68 0000000000 TCAF BX1 CPS 100612 O0 000 O0 0 18 1 1 4 68 0000000000 TCNDBX1 CPS 100612 O0 000 O0 0 18 1 1 4 68 0000000000 TCFD BX1 CPS 100612 O0 000 O0 0 18 1 1 4 68 0000000000 TSCN BX1 CPS 100612 O0 000 O0 0 18 1 I 4 68 0000000000 TSCF BX1 CPS 100612 O0 000 O0 0 18 1 1 4 68 0000000000 INNDBX1 CPS 100612 O0 000 O0 0 18 1 1 4 68 0000000000 INFDBX1 CPS 100612 O0 000 O0 0 18 1 1 4 68 0000000000 TENS BX1 LB 100612 O0 000 O0 0 18 1 1 4 68 0000000000 GR BX1 GAPI 100612 O0 000 O0 0 18 1 1 4 68 0000000000 CCL BXl V 100612 O0 000 O0 0 18 1 1 4 68 0000000000 ** DATA ** DEPT. 8256.000 SIGM. BX1 36.224 TPHI.BX1 68.944 SBHF. BX1 58.209 SBHN. BX1 68.382 SIGC.BX1 1.603 SIBH. BX1 101.316 TRAT. BX1 1.890 SDSI.BX1 1.759 BACK. BX1 160.598 FBAC.BX1 30.896 TCAN. BXl 9117.781 TCAF. BX1 2307.243 TCND.BX1 11249.473 TCFD.BX1 2418.565 TSCN. BX1 1033.763 TSCF. BX1 294.623 INND.BX1 1468.671 INFD.BX1 185.315 TENS.BX1 1140.000 GR.BXl 123.313 CCL.BXl 0.030 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 61 DEPT. 7990.500 SIGM. BX1 SBHN. BXl 64.027 SIGC. BX1 SDSI.BX1 2.358 BACK. BX1 TCAF. BXl 2168.976 TCND.BX1 TSCF. BX1 263.390 INND.BX1 GR.BX1 106.063 CCL.BX1 37.344 TPHI.BX1 1.955 SIBH.BX1 165.181 FBAC.BX1 10956.947 TCFD.BX1 1475.743 INFD.BX1 0.000 65. 551 SBHF. BX1 91 . 437 TRAT. BX1 29.308 TCAN. BXl 23 68 . 815 TSCN. BX1 216. 281 TENS. BXl 52.577 1.799 8323.471 923.898 1075.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .018 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .019 SERVICE : FLIC VERSION : 001C01 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 19 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 8 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 8256.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): STOP DEPTH 7966.0 16-NOV-96 CP 44.2 1309 16-NOV-96 9024.0 9018.0 8000.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 62 BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 9011.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP TDTP TDTP TDTP TDTP TDTP TDTP $ GAMMA RAY SOURCE THERMAL DECAY TDTP DETECTOR CART. TDTP CARTRIDGE TDTP SONDE DETECTOR TDTP SONDE GENERATOR MINITRON TOOL NUMBER CGRS 863 CPLC 805 TDIC 8337 TNC-P 390 TND-P 395 TNG-P 400 FI~TRN 8729 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 0.0 8541.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DBGF) : 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): 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): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: THIS FILE CONTAINS RAW DATA FROM UPPER BASELINE BORAX PASS #2 (PASS #8). TIED INTO SWS BHC DATED 6-15-76 LOGGED TDTP TO DETERMINE IF 3.5" LINER TOP IS LEAKING LOGGED BASELINE PASSES WHILE INJ 1~ KCL AT 1 BPM LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 63 LOGGED BORAX PASSES WHILE INJ AT 3 BPM ALL PASSES LOGGED AT 30 FPM PUMPED 150 BBLS OF BORAX AND 420 BBLS OF SEAWATER TOP OF LINER APPEARS TO BE LEAKING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100612 O0 000 O0 0 19 1 1 4 68 0000000000 SIGM BX2 CU 100612 O0 000 O0 0 19 1 1 4 68 0000000000 TPHI BX2 PU 100612 O0 000 O0 0 19' 1 1 4 68 0000000000. SBHF BX2 CU 100612 O0 000 O0 0 19 1 1 4 68 0000000000 SBHNBX2 CU 100612 O0 000 O0 0 19 1 1 4 68 0000000000 SIGC BX2 CU 100612 O0 000 O0 0 19 1 1 4 68 0000000000 SIBH BX2 CU 100612 O0 000 O0 0 19 1 1 4 68 0000000000 TRAT BX2 100612 O0 000 O0 0 19 1 1 4 68 0000000000 SDSI BX2 CU 100612 O0 000 O0 0 19 1 1 4 68 0000000000 BACK BX2 CPS 100612 O0 000 O0 0 19 1 1 4 68 0000000000 FBACBX2 CPS 100612 O0 000 O0 0 19 1 1 4 68 0000000000 TCANBX2 CPS 100612 O0 000 O0 0 19 1 1 4 68 0000000000 TCAF BX2 CPS 100612 O0 000 O0 0 19 1 1 4 68 0000000000 TCND BX2 CPS 100612 O0 000 O0 0 19 1 1 4 68 0000000000 TCFD BX2 CPS 100612 O0 000 O0 0 19 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 64 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) TSCNBX2 CPS 100612 O0 000 O0 0 19 1 1 4 68 0000000000 TSCF EX2 CPS 100612 O0 000 O0 0 19 1 1 4 68 0000000000 INNDBX2 CPS 100612 O0 000 O0 0 19 1 1 4 68 0000000000 INFD EX2 CPS 100612 O0 000 O0 0 19 1 1 4 68 0000000000 TENS EX2 LB 100612 O0 000 O0 0 19 1 1 4 68 0000000000 GR EX2 GAPI 100612 O0 000 O0 0 19 1 1 4 68 0000000000 CCL EX2 V 100612 O0 000 O0 0 19 1 1 4 68 0000000000 ** DATA ** DEPT. 8258.000 SIGM. BX2 37.114 TPHI.BX2 67.821 SBHF. BX2 67.263 SBHN. BX2 72.699 SIGC. BX2 0.000 SIBH. BX2 111.110 TRAT. BX2 1.837 SDSI.BX2 1.815 BACK. EX2 154.991 FBAC.BX2 31.071 TCAN, BX2 8773.961 TCAF. BX2 2410.689 TCND,BX2 9817.523 TCFD.BX2 2286.858 TSCN. BX2 1044.251 TSCF. EX2 292.047 INND.BX2 1456.084 INFD.BX2 201.382 TENS.EX2 1010.000 GR.BX2 309.750 CCL.BX2 0.061 DEPT. 7968.000 SIGM. BX2 35.791 TPHI.BX2 51.986 SBHF. BX2 52.161 SBHN. BX2 65.498 SIGC.BX2 1.933 SIBH.BX2 94.774 TRAT. BX2 1.566 SDSI.BX2 1.947 BACK. EX2 162.205 FBAC.BX2 24.012 TCAN. BX2 8865.412 TCAF. BX2 2694.370 TCND.BX2 10465.557 TCFD.BX2 2497.647 TSCN. BX2 994.408 TSCF. BX2 330.931 INND.BX2 1392.094 INFD.BX2 206.539 TENS.EX2 1070.000 GR.BX2 40.250 CCL.BX2 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .019 SERVICE : FLIC VERSION : O01COI DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .020 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 65 FILE HEADER FILE NUM~ER 20 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 9 DEPTH INCRI~4ENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 9021.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): STOP DEPTH .......... 8755.0 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 TDTP TDTP TDTP TDTP TDTP TDTP TDTP $ GAMMA RAY SOURCE THERMAL DECAY TDTP DETECTOR CART. TDTP CARTRIDGE TDTP SONDE DETECTOR TDTP SONDE GENERATOR MINITRON 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) : 16-NOV- 96 CP 44.2 1309 16-NOV-96 9024.0 9018.0 8000.0 9011.0 1800.0 TOOL NUMBER ........... CGRS 863 CPLC 805 TDIC 8337 TNC-P 390 TND-P 395 TNG-P 400 MNTRN 8729 0.0 8541.0 THERMAL LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 66 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 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): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REFIARKS: THIS FILE CONTAINS RAW DATA FROM LOWER BASELINE BORAX PASS #1 (PASS #9). TIED INTO SWS BHC DATED 6-15-76 LOGGED TDTP TO DETERMINE IF 3.5" LINER TOP IS LEAKING LOGGED BASELINE PASSES WHILE INJ 1~ KCL AT 1 BPM LOGGED BORAX PASSES WHILE INJ AT 3 BPM ALL PASSES LOGGED AT 30 FPM PUMPED 150 BBLS OF BORAX AND 420 BBLS OF SEAWATER TOP OF LINER APPEARS TO BE LEAKING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 1I 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 67 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API APG API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100612 O0 000 O0 0 20 1 1 4 SIGM BX3 CU 100612 O0 000 O0 0 20 1 1 4 TPHI BX3 PU 100612 O0 000 O0 0 20 1 1 4 SBHFBX3 CU 100612 O0 000 O0 0 20 1 1 4 SBHNBX3 CU 100612 O0 000 O0 0 20 1 1 4 SIGC BX3 CU 100612 O0 000 O0 0 20 1 1 4 SIBH BX3 CU 100612 O0 000 O0 0 20 1 1 4 TRAT BX3 100612 00 000 O0 0 20 1 1 4 SDSI BX3 CU 100612 O0 000 O0 0 20 1 1 4 BACK BX3 CPS 100612 00 000 O0 0 20 1 1 4 FBAC BX3 CPS 100612 O0 000 O0 0 20 1 1 4 TCANBX3 CPS 100612 O0 000 O0 0 20 1 1 4 TCAF BX3 CPS 100612 O0 000 O0 0 20 1 1 4 TCND BX3 CPS 100612 O0 000 O0 0 20 1 1 4 TCFD BX3 CPS 100612 O0 000 O0 0 20 1 1 4 TSCN BX3 CPS 100612 O0 000 O0 0 20 1 1 4 TSCF BX3 CPS 100612 O0 000 O0 0 20 1 1 4 INNDBX3 CPS 100612 O0 000 O0 0 20 1 1 4 INFD BX3 CPS 100612 O0 000 O0 0 20 1 1 4 TENS BX3 LB 100612 O0 000 O0 0 20 1 1 4 GR BX3 GAPI 100612 00 000 O0 0 20 1 1 4 CCL BX3 V 100612 00 000 O0 0 20 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. SBHN. BX3 SDSI.BX3 TCAF. BX3 TSCF. BX3 GR.BX3 9019 500 SIGM. BX3 35.791 TPHI.BX3 65 498 SIGC.BX3 1.933 SIBH. BX3 1 947 BACK.BX3 162.205 FBAC. BX3 2694 370 TCND.BX3 10465.557 TCFD.BX3 330 931 INND.BX3 1392.094 INFD.BX3 79 188 CCL.BX3 0.035 DEPT. 8753 000 SIGM. BX3 10.532 TPHI.BX3 SBHN. BX3 68 914 SIGC.BX3 0.718 SIBH.BX3 SDSI.BX3 0 258 BACK. BX3 166.857 FBAC.BX3 TCAF.BX3 13408 715 TCND.BX3 17625.281 TCFD.BX3 TSCF. BX3 3091 277 INND.BX3 1560.369 INFD.BX3 GR.BX3 50 188 CCL.BX3 0.000 51.986 SBHF. BX3 52.161 94.774 TRAT. BX3 1.566 24.012 TCAN. BX3 8865.412 2497.647 TSCN. BX3 994.408 206.539 TENS.BX3 i OSS.O00 20.922 SBHF. BX3 52.334 93.275 TRAT. BX3 1.632 27.671 TCAN. BX3 26906.797 6519.262 TSCN. BX3 6203.157 243.452 TENS.BX3 1170.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 68 **** FILE TRAILER **** FILE NAFIE : EDIT .020 SERVICE : FLIC VERSION : 001C01 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .021 SERVICE : FLIC VERSION : 001C01 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 21 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 10 DEPTH INCREMENT: 0.5000 FILE SU~M. ARY VENDOR TOOL CODE START DEPTH TDTP 9024.5 $ 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 ......................... TDTP TDTP TDTP TDTP TDTP TDTP STOP DEPTH 8748.0 GAMMA RAY SOURCE THERMAL DECAY TDTP DETECTOR CART. TDTP CARTRIDGE TDTP SONDE DETECTOR TDTP SONDE GENERATOR 16-NOV- 96 CP 44.2 1335 16-NOV-96 9024.0 9018.0 8000.0 9011.0 1800.0 TOOL NUMBER CGRS 863 CPLC 805 TDIC 8337 TNC-P 390 TND-P 395 TNG-P 400 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 69 TDTP MINITRON ~TTRN 8729 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 0.0 8541.0 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): 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): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: THIS FILE CONTAINS RAW DATA FROM LOWER BASELINE BORAX PASS #2 (PASS #10). TIED INTO SWS BHC DATED 6-15-76 LOGGED TDTP TO DETERMINE IF 3.5" LINER TOP IS LEAKING LOGGED BASELINE PASSES WHILE INJ it KCL AT 1 BPM LOGGED BORAX PASSES WHILE INJ AT 3 BPM ALL PASSES LOGGED AT 30 FPM PUMPED 150 BBLS OF BORAX AND 420 BBLS OF SEAWATER TOP OF LINER APPEARS TO BE LEAKING. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 7O ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEbl CODE (HEX) DEPT FT 100612 O0 000 O0 0 21 1 1 4 68 0000000000 SIGMEX4 CU 100612 O0 000 O0 0 21 1 1 4 68 0000000000 TPHI BX4 PU 100612 O0 000 O0 0 21 1 1 4 68 0000000000 SBHF EX4 CU 100612 O0 000 O0 0 21 1 1 4 68 0000000000 SBHNBX4 CU 100612 O0 000 O0 0 21 1 1 4 68 0000000000 SIGC EX4 CU 100612 O0 000 O0 0 21 1 1 4 68 0000000000 SIBH BX4 CU 100612 O0 000 O0 0 21 1 1 4 68 0000000000 TRATBX4 100612 O0 000 O0 0 21 1 1 4 68 0000000000 SDSI EX4 CU 100612 O0 000 O0 0 21 1 1 4 68 0000000000 BACK EX4 CPS 100612 O0 000 O0 0 21 1 1 4 68 0000000000 FBAC EX4 CPS 100612 O0 000 O0 0 21 1 1 4 68 0000000000 TCANEX4 CPS 100612 O0 000 O0 0 21 1 1 4 68 0000000000 TCAF BX4 CPS 100612 O0 000 O0 0 21 1 1 4 68 0000000000 TCNDBX4 CPS 100612 O0 000 O0 0 21 1 1 4 68 0000000000 TCFD BX4 CPS 100612 O0 000 O0 0 21 1 1 4 68 0000000000 TSCN EX4 CPS 100612 O0 000 O0 0 21 1 1 4 68 0000000000 TSCF BX4 CPS 100612 O0 000 O0 0 21 1 1 4 68 0000000000 INNDBX4 CPS 100612 O0 000 O0 0 21 1 1 4 68 0000000000 INFD BX4 CPS 100612 00 000 O0 0 21 1 1 4 68 0000000000 TENS BX4 LB 100612 O0 000 O0 0 21 1 1 4 68 0000000000 GR BX4 GAPI 100612 O0 000 O0 0 21 1 1 4 68 0000000000 CCL EX4 V 100612 O0 000 O0 0 21 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-DEC-1996 11:00 PAGE: 71 ** DATA ** DEPT. 9022.500 SIGM. BX4 10.532 TPHI.BX4 SBHN. BX4 68.914 SIGC. BX4 0.718 SIBH.BX4 SDSI.BX4 0.258 BACK. BX4 166.857 FBAC.BX4 TCAF. BX4 13408.715 TCND.BX4 17625.281 TCFD.BX4 TSCF. BX4 3091.277 INND. BX4 1560.369 INFD.BX4 GR.BX4 102.313 CCL.BX4 0.035 DEPT. 8746.000 SIGM. BX4 SBHN. BX4 58.752 SIGC. BX4 SDSI.BX4 0.287 BACK. BX4 TCAF. BX4 12818.754 TCND.BX4 TSCF. BX4 2958.812 INND.BX4 GR.BX4 68.688 CCL.BX4 11.265 TPHI.BX4 0.671 SIBH. BX4 164.598 FBAC. BX4 20212.512 TCFD.BX4 1437.929 INFD.BX4 0.000 20.922 93.275 27.671 6519.262 243.452 25.260 75.628 28.530 6669.594 232.062 SBHF. BX4 TRAT. BX4 TCAN. BX4 TSCN. BX 4 TENS. BX4 SBHF. BX4 TRAT. BX4 TCAN. BX4 TSCN. BX4 TENS.BX4 52.334 1.632 26906.797 6203.157 915.000 47.180 1.768 28419.098 6559.667 1170.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .021 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/12/31 ORIGIN : FLIC TAPE NAME : 96350 CONTINUATION # : 1 PREVIOUS TAPE : COF~IENT : ARCO ALASKA INC, D.S. 4-10, PRUDHOE BAY, 50-029-20213-00 ****. REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/12/31 ORIGIN : FLIC REEL NAME : 96350 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, D.S. 4-10, PRUDHOE BAY, 50-029-20213-00 * ALASKA COMPUTING CENTER * ****************************** * ............................ * ....... SCHLUMBERGER ....... * ............................ ****************************** R GEIYED ttOV 08 COMPANY NAME : ARCO ALASKA INC. WELL NAME : D. S. 4 - 10 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292021300 REFERENCE NO : 96258 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/11/ 1 ORIGIN : FLIC REEL NAME : 96258 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, D.S. 4-10, PRUDHOE BAY, 50-029-20213-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/11/ 1 ORIGIN : FLIC TAPE NAME : 96258 CONTINUATION # : 1 PREVIOUS TAPE : CO~4~ENT : ARCO ALASKA INC, D.S. 4-10, PRUDHOE BAY, 50-029-20213-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D. S . 4-10 API NUMBER: 500292021300 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: O1-NOV-96 JOB NUMBER: 96258 LOGGING ENGINEER: G. SCHWARTZ OPERATOR WITNESS: CISMOSKI SURFACE LOCATION SECT I ON: 27 TOWNSHIP: 1 iN RANGE: 1SE FNL: 442 FSL: FEL: FWL: 667 ELEVATION (FT FROM MSL O) KELLY BUSHING: 52.00 DERRICK FLOOR: 50. O0 GROUND LEVEL: 15. O0 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 7.000 9149.0 29.00 3.500 8998.0 9.20 5.500 7964.0 17.00 4.500 8102.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH .............. 88888.0 8997.0 8996.0 8958.0 8957.0 8957.5 8957.0 8936.5 8934.5 8936.0 8934.5 8925.0 8924.0 8914.0 8911.0 8899.0 8897.5 8897.5 8897.0 8875.0 8872.5 8871.0 8870.5 8869.5 8868.0 8863.5 8863.0 8837.0 8837.0 8835.0 8834.5 8830.0 8829.5 8799.5 8800.0 8779.0 8779.5 8200.0 8200.5 8197.0 8199.5 8183.0 8182.0 8176.0 8174.5 8167.5 8168.0 8148.5 8149.5 8090.5 8088.5 8088.0 8088.0 8051.0 8050.5 8030.0 8029.0 8014.5 8015.0 8004.0 8003.0 100.0 100.5 99.0 $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP .............. 88887.5 88887.0 R~wLARKS: This tape contains a cased hole TDTP/Borax edit for ARCO ALASKA Well D.S. 4-10. There are 3 baseline passes, 2 borax passes, an average pass. The passes were logged over two intervals, 8200-8000' ~D and 9022-8750' FID. Each pass has been combined with absent values in between. to open hole BCS GR and cased hole SIGM to open hole GR. Ail other TDTP curves were carried with the SIGM shifts. Reference Gamma Ray provided by client. $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 96/11/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~VlARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8990.0 7996.0 TDTP 9014.0 7996.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP R~MARKS: This file contains TDTP Pass #1 (Base Pass #1). pass to pass shifts were applied to this data. $ LIS FORMAT DATA No ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 ~AGE: TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 ** SET TYPE - CHAN ** N3J,IE SERV ONIT SERVICE API API API API FILE 3t'O~B 3FdMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELI~I CODE (HEX) DEPT FT 500517 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM TDTP CU 500517 00 000 00 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 500517 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 500517 O0 000 O0 0 1 1 1 4 68 0000000000 SBHNTDTP CU 500517 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 500517 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 500517 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 500517 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 500517 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 500517 O0 000 00 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 500517 00 000 O0 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 500517 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 500517 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 500517 00 000 00 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 500517 00 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 500517 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 500517 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 500517 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 500517 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 500517 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 500517 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 500517 00 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 500517 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9119.500 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: TENS. TDTP -999.250 CCL. TDTP -999.250 GR.BCS DEPT. 7267 . 000 SIGM. TDTP -999.250 TPHI. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999. 250 SIBH. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP TCAF. TDTP -999.250 TCND. TDTP -999. 250 TCFD. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP TENS. TDTP -999.250 CCL. TDTP -999.250 GR.BCS 98.196 - 999 · 250 SBHF. TDTP -999 . 250 TRAT. TDTP -999 . 250 TCAN. TDTP -999 . 250 TSCN. TDTP -999 . 250 GRCH. TDTP 68.204 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 96/11/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AFJMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCR~ENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8990,0 8742.0 TDTP 9014.0 8742,0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 LIS Tape Verification Lis~-ing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: BASELINE DEPTH 88888.0 9003.0 9002.5 8991.0 8990.0 8968.5 8967.5 8957.5 8957.0 8936.5 8934.5 8933.0 8932.0 8932.0 8930.0 8925.5 8924.0 8911.0 8908.5 8899.0 8897.5 8897.5 8897.0 8881.0 8879.0 8875.0 8873.0 8869.0 8868.5 8868.0 8866.5 8859.0 8857.5 8855.0 8854.0 8853.5 8853.5 8846,0 8845.5 8835.0 8834.5 8834.5 8834.0 8829.5 8829.5 8803.0 8804.5 8800.0 8800.5 8774.5 8775.0 8769.0 8769.5 8182.5 8182.0 8181.0 8181.5 8173.0 8172.0 8167.5 8168.5 8163.5 8164.0 8152.5 8153.0 8148.5 8149.5 8140.0 8140.5 8126.5 8126.5 8093.0 8093.0 8090.0 8088.5 8087.5 8088.0 8075.5 8075.0 8059.0 8057.5 8050.0 8050.0 8029.5 8028.5 8017.0 8017.0 8014.5 8014.5 8005.0 8005.0 7998.5 7998.0 100.0 100,0 99.5 $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88887.5 88887.5 R~F~%RKS: This file contains TDTP Pass #2 (Base Pass #2). The depth shifts shown above relect GRCH Pass #2 to GRCH LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: Pass #1 and SIGM Pass #2 to SIGM Pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500517 O0 000 O0 0 2 1 1 4 68 0000~00000 SIGM TDTP CU 500517 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 500517 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 500517 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN TDTP CU 500517 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 500517 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 500517 O0 000 00 0 2 1 1 4 68 0000000000 TRAT TDTP 500517 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 500517 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 500517 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 500517 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 500517 O0 000 O0 0 2 1 I 4 68 0000000000 TCAF TDTP CPS 500517 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS '500517 O0 000 00 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 500517 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 500517 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 500517 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 500517 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) INFD TDTP CPS 500517 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 500517 O0 000 00 0 2 1 1 4 68 0000000000 TENS TDTP LB 500517 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 500517 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9013. 500 SIGM. TDTP 18. 077 TPHI. TDTP 26. 829 SBHF. TDTP SBHN. TDTP 45.527 SIGC. TDTP 2.368 SIBH. TDTP 48.896 TRAT. TDTP SDSI. TDTP O. 643 BACK. TDTP 164. 303 FBAC. TDTP 35. 019 TCAN. TDTP TCAF. TDTP 10982,277 TCND. TDTP 24713.188 TCFD. TDTP 7319. 674 TSCN. TDTP TSCF. TDTP 2314.311 INND. TDTP 1959.182 INFD. TDTP 361.706 GRCH. TDTP TENS. TDTP 1400. 000 CCL. TDTP O. 000 DEPT. 7995.500 SIGM. TDTP 37.516 TPHI.TDTP 76.183 SBHF. TDTP SBHN. TDTP 68. 046 SIGC. TDTP O. 831 SIBH. TDTP 100. 554 TRAT. TDTP SDSI. TDTP 1 . 539 BACK. TDTP 99 . 947 FBAC. TDTP 20. 227 TCAN. TDTP TCAF, TDTP 3042.169 TCND. TDTP 13225. 969 TCFD. TDTP 2769. 305 TSCN. TDTP TSCF, TDTP 337.363 INND. TDTP 1812,193 INFD, TDTP 253.314 GRCH. TDTP TENS. TDTP 1270. 000 CCL, TDTP O. 000 33.494 1.689 26102.824 5500.687 -999.250 55. 649 2. 012 12349. 098 1309.318 - 999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUF~ER : 3 DEPTH INCR~4ENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 8990.0 8739.0 TDTP 9014.0 8739.0 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9003.0 8990.5 8988.5 8973.5 8968.0 8967.0 8957.0 8947,5 8936.5 8933.5 8925.0 8910.0 8899.0 8897.5 8878.5 8869.0 8854.5 8835.0 8829.5 8823.0 8796.0 8774,5 8769,5 8206, 0 8182.5 8175.0 8167.0 8148.5 8145.0 8126.0 8119.0 8090.5 8086.5 .......... EQUIVALENT UNSHIFTED DBPTH .......... GRCH TDTP 88886.5 88887.0 9002.0 8990.0 8987.0 8973.5 8967.5 8967.0 8956.5 8946.5 8934.5 8932.0 8924.0 8908.0 8897.5 8897.5 8877.0 8869.0 8867.5 8854.0 8834.5 8829.5 8823.5 8797.0 8775.5 8770.0 8205.0 8182.0 8175.0 8174.0 8168.0 8149.5 8146.0 8126.5 8119.5 8091.0 8088.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: 10 8049.5 8050.0 8047.5 8051.0 8040.0 8043.0 8030.0 8029.0 8015,5 8019.0 8014.5 8014.5 8002.5 8002.5 8000.5 8005.0 100.0 100.0 104.5 $ REF~ARKS: This file contains TDTP Pass #3 (Base Pass #3). The depth shifts shown above relect GRCH Pass #3 to GRCH Pass #1 and SIGM Pass #3 to SIGM Pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELM CODE (HEX) DEPT FT 500517 00 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 500517 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 500517 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 500517 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 500517 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: 11 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELI~4 CODE (HEX) SIGC TDTP CU 500517 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 500517 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 500517 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 500517 O0 000 00 0 3 1 1 4 68 0000000000 BACK TDTP CPS 500517 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 500517 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 500517 O0 000 00 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 500517 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 500517 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 500517 O0 000 00 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 500517 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 500517 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 500517 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 500517 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 500517 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 500517 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 500517 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9013. 000 SIGM. TDTP 17. 272 TPHI. TDTP 24. 929 SBHF. TDTP SBHN. TDTP 40. 067 SIGC. TDTP 3 . 043 SIBH. TDTP 40. 067 TRAT. TDTP SDSI . TDTP 0. 630 BACK. TDTP 186.614 FBAC. TDTP 35. 959 TCAN. TDTP TCAF. TDTP 10907. 068 TCND. TDTP 24423. 910 TCFD. TDTP 7343. 780 TSCN. TDTP TSCF. TDTP 2302. 403 INND. TDTP 1946.193 INFD. TDTP 372. 937 GRCH. TDTP TENS. TDTP 1405. 000 CCL. TDTP O . 000 DEPT. 7992. 000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999 . 250 CCL. TDTP - 999. 250 35.601 1.711 26263.523 5544.040 -999.250 -999.250 -999.250 -999.250 -999.250 69.938 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: 12 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCRJ~4ENT: 0.5000 FILE SU~M_ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8990.0 8742.0 TDTP 9014,0 8742.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88886.5 88887.0 9003.5 9002.5 8997.5 8996.0 8983.0 8981.5 8968.5 8967,5 8968.0 8967.0 8958.0 8957.0 8957.5 8956.5 8936.5 8934,5 8936.0 8934,0 8925.0 8924.0 8911.0 8908.0 8899.5 8897.5 8897.5 8897.0 8895.0 8893,5 8880.0 8877.5 8875.0 8872.5 8869.5 8869.0 8869.0 8867.5 8858.5 8857.5 8854.5 8853.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: 13 8846.0 8845.0 8835.0 8834.5 8830.0 8829.5 8825.5 8825.5 8800.0 8800.0 8796.0 8797.0 8775.0 8775.5 8769.5 8770.0 8206.5 8206.0 8174.5 8172.5 8168.5 8168.5 8161.0 8160.5 8156.0 8155.5 8149.5 8149.5 8146.0 8146.0 8143.0 8141.5 8126.0 8125.0 8091.0 8091.0 8080.0 8079.0 8070.0 8067.5 8063.5 8062.0 8051.0 8050.0 8031.0 8028.5 8021.5 8018.5 8015.5 8014,5 8003.5 8002,5 8001.5 8000.0 100.0 99,0 98.5 REMARKS: This file contains Borax Pass #1 of the TDTP. The depth adjustments shown above reflect Borax Pass #1GRCH to Base Pass #1 GRCH and Borax Pass #1 SIGMA to Base Pass #1 SIGMA. Ail other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: 14 TYPE REPR CODE VALUE .............................. 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) DEPT FT 500517 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM TDTP CU 500517 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 500517 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 500517 O0 000 O0 0 4 1 1 4 68 0000000000 SBHN TDTP CU 500517 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 500517 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 500517 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 500517 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 500517 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 500517 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 500517 O0 000 O0 0 4 1 1 4 68 0000000000 TCANTDTP CPS 500517 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 500517 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 500517 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 500517 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN TDTP CPS 500517 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 500517 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 500517 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 500517 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 500517 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 500517 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 500517 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9013. 000 SIGM. TDTP 19. 710 TPHI. TDTP 22. 902 SBHF. TDTP 69. 076 SBHN. TDTP 85.798 SIGC. TDTP 0.000 SIBH. TDTP 125.958 TRAT. TDTP 1.385 SDSI. TDTP O. 823 BACK. TDTP 131 . 040 FBAC. TDTP 31 . 380 TCAN. TDTP 10926.105 TCAF. TDTP 5674 . 619 TCND. TDTP 10679. 266 TCFD. TDTP 3846. 687 TSCN. TDTP 2236. 400 TSCF. TDTP 1161.504 INND. TDTP 1944.944 INFD. TDTP 369.329 GRCH. TDTP -999.250 TENS. TDTP 1410. 000 CCL. TDTP O . 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: 15 DEPT. 7994.500 SIGM. TDTP 37. 923 TPHI. TDTP 67. 770 SBHF. TDTP 63. 643 SBHN. TDTP 68. 773 SIGC. TDTP O. 070 SIBH. TDTP 102.204 TRAT. TDTP 1 . 818 SDSI. TDTP 1 . 763 BACK. TDTP 96. 063 FBAC. TDTP 20. 461 TCAN. TDTP 10 903.258 TCAF. TDTP 2990.586 TCND. TDTP 11255,811 TCFD. TDTP 2578.549 TSCN. TDTP 1137.146 TSCF. TDTP 328. 924 INND. TDTP 1729. 624 INFD. TDTP 260.523 GRCH. TDTP - 999.250 TENS. TDTP 1270. 000 CCL. TDTP O. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SO?4MARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8990.0 7996.0 TDTP 8990,0 7996.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH TDTP LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: 16 88888.0 9003.0 8991.0 8968.5 8957.5 8947.5 8936.5 8936.0 8933.5 8910.5 8899.0 8897.5 8891.5 8880.0 8875.0 8869.0 8855.5 8855.0 8835.0 8829.5 8823.0 8811.5 8796.5 8781.0 8766.0 8186.5 8176.0 8168.5 8156, 0 8153,0 8149.0 8147,0 8146.0 8143.5 8128.5 8096.0 8060 0 8051 5 8030 0 8015 5 8002 0 100 0 $ 88887.0 88887.5 9002.5 8990.0 8967.5 8956.5 8946.5 8934.5 8897.0 8869.0 8854.0 8823.5 8766.5 8168.0 8153.0 8146.0 8128.0 8095.5 8050.0 8028.5 8015.0 99.5 8934.5 8931.5 8908.0 8897.5 8890.0 8877.5 8872.5 8867.5 8854.0 8834.5 8829.0 8812.5 8797.0 8781.5 8185.0 8174.0 8155.5 8149.5 8146.5 8143.5 8057.5 8000.0 98.0 REMARKS: This file contains Borax Pass #2 of the TDTP. The depth adjustments shown above reflect Borax Pass #2 GRCH to Base Pass #1GRCH and Borax Pass #2 SIGMA to Base Pass #1 SIGMA. Ail other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: 17 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API APi API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELD CODE (HEX) DEPT FT 500517 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM TDTP CU 500517 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 500517 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF TDTP CU 500517 O0 000 O0 0 5 1 1 4 68 0000000000 SBHN TDTP CU 500517 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC TDTP CU 500517 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH TDTP CU 500517 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT TDTP 500517 O0 000 00 0 5 1 1 4 68 0000000000 SDSI TDTP CU 500517 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 500517 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 500517 O0 000 O0 0 5 1 1 4 68 0000000000 TCAN TDTP CPS 500517 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF TDTP CPS 500517 O0 000 O0 0 5 1 1 4 68 0000000000 TCND TDTP CPS 500517 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 500517 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN TDTP CPS 500517 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF TDTP CPS 500517 O0 000 O0 0 5 1 1 4 68 0000000000 INND TDTP CPS 500517 O0 000 O0 0 5 1 1 4 68 0000000000 INFD TDTP CPS 500517 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 500517 O0 000 00 0 5 1 1 4 68 0000000000 TENS TDTP LB 500517 00 000 O0 0 5 1 1 4 68 0000000000 CCL TDTP V 500517 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: 18 ** DATA ** DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP 9013 500 88 775 0 861 5563 989 1141 952 1435 000 DEPT. 7994. 000 SBHN. TDTP 69. 835 SDSI. TDTP 1. 789 TCAF. TDTP 2886. 907 TSCF. TDTP 320. 494 TENS. TDTP 1265. 000 SIGM. TDTP 19. 484 TPHI. TDTP 20. 402 SBHF. TDTP SIGC. TDTP O. 257 SIBH. TDTP 132.116 TRAT. TDTP BACK. TDTP 165.131 FBAC. TDTP 37. 250 TCAN. TDTP TCND. TDTP 10214. 525 TCFD. TDTP 3721.876 TSCN. TDTP INND. TDTP 1748.493 INFD. TDTP 361.178 GRCH. TDTP CCL. TDTP O. 000 SIGM. SIGC. BACK. TCND. INND. CCL . TDTP 37. 364 TPHI. TDTP 71. 607 SBHF. TDTP TDTP O. 324 SIBH. TDTP 104. 613 TRAT. TDTP TDTP 115. 960 FBAC. TDTP 23. 983 TCAN. TDTP TDTP 11096.232 TCFD. TDTP 2521.310 TSCN. TDTP TDTP 1791. 507 INFD. TDTP 252. 668 GRCH. TDTP TDTP O. 000 69.701 1.320 10246.996 2103.091 -999.250 55.669 1.913 11042.975 1153.787 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 96/11/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001C01 DATE : 96/11/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 6 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS TDTP 1, 2, 3, $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: 19 REFIARKS: The arithmetic average of passes 1, 2 & 3 was computed after all depth shifts and clippin9 was applied. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500517 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PNAV CU 500517 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PNAV PU-S 500517 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PNAV CU 500517 O0 000 O0 0 6 1 1 4 68 0000000000 SBHNPNAV CU 500517 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PNAV CU 500517 O0 000 O0 0 6 1 I 4 68 0000000000 SIBH PNAV CU 500517 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PNAV 500517 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PNAV CU 500517 O0 000 O0 0 6 1 1 4 68 0000000000 BACK TDTP CPS 500517 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC TDTP CPS 500517 O0 000 O0 0 6 1 1 4 68 0000000000 TCANPNAV CPS 500517 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF PNAV CPS 500517 O0 000 O0 0 6 1 1 4 68 0000000000 TCND PNAV CPS 500517 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PNAV CPS 500517 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PNAV CPS 500517 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PNAV CPS 500517 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Compu ting Center 1-NOV-1996 12:11 PAGE: 20 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) INND PNAV CPS 500517 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PNAV CPS 500517 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH TDTP GAPI 500517 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9013.000 SIGM. PNAV 18.000 TPHI.PNAV 28.689 SBHF. PNAV 35.816 SBHN. PNAV 43.191 SIGC. PNAV 2.615 SIBH. PNAV 44.867 TRAT. PNAV 1.765 SDSI.PNAV 0,619 BACK. TDTP 142.950 FBAC. TDTP 29.734 TCAN. PNAV 26708.031 TCAF. PNAV 10706.525 TCND. PNAV 24753.191 TCFD.PNAV 7282. 424 TSCN. PNAV 5617. 080 TSCF. PNAV 2251.929 INND. PNAV 1947.438 INFD.PNAV 367.482 GRCH. TDTP -999.250 DEPT. 7995.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH, PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 77.708 FBAC, TDTP 15.533 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND. PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND. PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP -999,250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001C01 DATE : 96/11/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/11/ 1 ORIGIN : FLIC TAPE NAME : 96258 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, D.S. 4-10, PRUDHOE BAY, 50-029-20213-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-NOV-1996 12:11 PAGE: 21 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/11/ 1 ORIGIN : FLIC REEL NAME : 96258 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, D.S. 4-10, PRUDHOE BAY, 50-029-20213-00 HALLIBURTON COMPANY:· WELL:- APl'#: DATE:· FIELD: BOUROUGH: STATE: LOGS'. · · · . .-. DS '4; 10i ' ' 50:029-20213.' ~,¢~:::; . 08'-04-'92 · ~'~,, .... ;. :."f.. 0.~ )9~$ .:' PrUdhoe Bay ~ o!/~! .~ ~ .... '"'"" ' "' ~*~o~ ~O~h'SIope. . . .. ~-~~ ~ia~k~ "'" · . : . .. .. Thermal Multigate .Decay Log. LIS TAPE VERIFICATION LISTING LDWG FORMAT Page i REEL HEADER RECORD TYPE 132 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER PREVIOUS REEL NAME COMMENTS: --- COMCEN --- 93/01/'m8 --- 847605 --mm ****************************************************************************** TAPE HEADER RECORD TYPE 130 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER PREVIOUS TAPE NAME COMMENTS: --- COMCEN --- 93/01/18 --- ANCH --~m i ****************************************************************************** COMMENT RECORD TYPE 232 TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: 04-10i API NUMBER: 500292021300 OPERATOR:' ARCO ALASKA INC. LOGGING COMPANY: HALLIBURTON LOGGING SERVICES TAPE CREATION DATE: 18-JAN-93 JOB NUMBER: L84760-5 LOGGING ENGINEER= D. McKAY OPERATOR WITNESS: R. ORTIZ SURFACE LOCATION SECTION: 27 TOWNSHIP: llN RANGE: 15E FNL: FSL: 422 FEL: 667 FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: 52.00 DERRICK FLOOR: 50'.00 GROUND LEVEL: 15.00 WELL CASING RECORD OPEN HOLE CASING DRILLER'S CASING Page 2 BIT SIZE(IN) SIZE(IN) DEPTH(FT) WEIGHT (LB/FT) 1ST STRING 13.375 2692.0 72.00 2ND STRING 12.250 9.625 8541.0 47.00 3RD STRING 8.500 7.000 9149.0 29.00 PRODUCTION STRING 8.500 4.500 8102.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: GR PBU CURVE CODE: FDC RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH TMD EQUIVALENT UNSHIFTED DEPTH .......... 8717.5 8748.0 8778.5 8799.0 8832.0 8864.0 8896.0 8923.5 8956.5 8996.0 9028.0 REMARKS= 8716.5 8747.0 8778.5 8800.0 8834.0 8867.0 8899.0 8926.5 8959.0 8998.0 9030.0 PASS #1-2-3 ARE NON-BORAX BASELINE PASSES. PASS $4-6-7 ARE BORAX INJECTION PASSES. TUBING VOLUME TO TOP OF THE PERFORATIONS = 225 BBLS. TOTAL PUMPING VOLUME AND FLUID TYPE: 805 BBLS SEAWATER AND 251 BBLS BORON $ ****************************************************************************** FILE HEADER RECORD .......... TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.001 --- 93/01/18 --- 1024 --- LO ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: EDITED CURVES 01 Page 3 Depth shifted and clipped curves for each pass in separate files. PASS NUMBER= 01 DEPTH INCREMENT= 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TMD 9008.0 8717.5 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE= GR PASS NUMBER= 01 ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH TMD 338 BBLS SEAWATER PUMPED PRIOR TO PASS #1. PUMPING INFORMATION FOR NON-BORAX PASS #1= START TIME= 0945 HRS STOP TIME= 1002 HRS RATE= 1.0 BBLS/MIN VOLUME & TYPE= 62 BBLS BORON TOTAL PUMPED= 400 BBLS SEAWATER/BORON LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS= TYPE SIZE REPR. CODE ENTRY i i 66 0 2 i 66 0 3 2 79 68 4 1 66 1 5 i 66 1 8 4 73 60 9 4 65 .liN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 I 66 68 16 i 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS= MNEM SERVID SERVICE~ UNITS DEPT F SGFN TMD 847605 CU SGFF TMD 847605 CU SGBH TMD 847605 CU API CODE FILE# SIZE 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 ~SAMP REPR. 1 68 i 68 i 68 i 68 Page 4 NSBF THD 847605 CPS 00000000 0 4 i 68 FSBF THD 847605 CPS 00000000 0 4 i 68 NTMD TMD 847605 CPS 00000000 0 4 1 68 FTMD TMD 847605 CPS 00000000 0 4 1 68 RTMD TMD 847605 00000000 0 4 1 68 CRNF TMD 847605 00000000 0 4 1 68 PHIT TMD 847605 PU 00000000 0 4 1 68 SGFM TMD 847605 CU 00000000 0 4 1 68 SIGQ TMD 847605 00000000 0 4 1 68 RSBF TMD 847605 00000000 0 4 1 68 SGIN TMD 847605 CU 00000000 0 4 1 68 SIGC TMD 847605 00000000 0 4 1 68 GRCH TM/) 847605 GAPI 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9008.000 SGFN = 21.005 SGFF = 17.849 SGBH = 72.228 NSBF = 14.713 FSBF = 3.718 NTMD = 14002.750 FTMD = 2073.133 RTMD = 6.754 CRNF = 7.328 PHIT = 52.090 SGFM = 17.665 SIGQ = .982 RSBF = .729 SGIN = 16.576 SIGC = 1.066' GRCH = -1.000 DEPT = 8808.000 SGFN = 21.275 SGFF = 18.383 SGBH = 69.103 NSBF = 55.997 FSBF = 5.774 NTMD = 21279.410 FTMD = 3580.062 RTMD = 5.944 CRNF = 6.385 PHIT = 36.130 SGFM = 17.950 SIGQ = .983 RSBF = .607 SGIN = 16.885 SIGC = 1.063 GRCH = 47.877 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.001 --- 93/01/18 --- 1024 --- LO --- COMCEN.002 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.002 --- 93/01/18 --- 1024 --- LO --- COMCEN.001 ****************************************************************************** Page 5 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER= 02 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER= 02 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TMD 9018.0 8749.5 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 .......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH TMD NO PASS TO PASS DEPTH SHIFTS REQUIRED. PUMPING INFORMATION FOR NON-BORAX PASS #2: START TIME: STOP TIME: RATE: VOLUME & TYPE: TOTAL PUMPED: $ LIS FORMAT DATA 1012 HRS 1027 HRS 1.0 BBLS/MIN 8 BBLS BORON 408 BBLS SEAWATER/BORON ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY i i 66 0 2 i 66 0 3 2 79 68 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .lin 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 i 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: Page 6 MNEM SERVID SERVICE# UNITS API CODE FILE~ SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 SGFN TMD 847605 CU 00000000 0 4 1 68 SGFF TMD 847605 CU 00000000 0 4 1 68 SGBH TMD 847605 CU 00000000 0 4 1 68 NSBF TMD 847605 CPS 00000000 0 4 1 68 FSBF TMD 847605 CPS 00000000 0 4 1 68 NTMD TMD 847605 CPS 00000000 0 4 1 68 FTMD TMD 847605 CPS 00000000 0 4 1 68 RTMD TMD 847605 00000000 0 4 1 68 CRNF TMD 847605 00000000 0 4 1 68 PHIT TMD 847605 PU 00000000 0 4 1 68 SGFM TMD 847605 CU 00000000 0 4 1 68 SIGQ TMD 847605 00000000 0 4 1 68 RSBF TMD 847605 00000000 0 4 1 68 SGIN TMD 847605 CU 00000000 0 4 1 68 SIGC TMD 847605 00000000 0 4 1 68 GRCH TMD 847605 GAPI 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9018.000 SGFN = 21.041 SGFF = 18.420 SGBH = 72.032 NSBF = 49.936 FSBF = 8.088 NTMD = 15179.110 FTMD = 2357.926 RTMD = 6.437 CRNF = 6.963 PHIT = 45.658 SGFM = 17.704 SIGQ = .982 RSBF = .882 SGIN = 16.618 SIGC = 1.065 GRCH = -1.000 DEPT = 8818.000 SGFN = 20.609 SGFF = 17.753 SGBH = 66.057 NSBF = 84.477 FSBF = 8.'612 NTMD = 20985.930 FTMD = 3418.576 RTMD = 6.139 CRNF = 6.553 PHIT = 38.816 SGFM = 17.248 SIGQ = .986 RSBF = .583 SGIN = 16.124 SIGC = 1.070 GRCH = 32.966 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.002 --- 93/01/18 --- 1024 --- COMCEN.003 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION --- COMCEN. 003 --- 93/01/la Page 7 MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- 1024 --- LO --- COMCEN.002 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 03 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 03 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TMD 9018.0 8796.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH TMD 332 BBLS SEAWATER PUMPED AFTER PASS $2. NO PASS TO PASS DEPTH SHIFTS REQUIRED. PUMPING INFORMATION FOR NON-BORAX PASS #3: START TIME: 1308 HRS STOP TIME: 1320 HRS RATE: 1.0 BBLS/MIN VOLUME & TYPE: 18 BBLS SEWATER TOTAL PUMPED: 758 BBLS SEAWATER/BORON $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY i i 66 0 2 i 66 0 3 2 79 68 4 i 66 1 5 i 66 1 8 4 73 60 9 4 65 .liN 11 2 79 14 Page 8 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 I 66 1 0 I 66 0 DATUM SPECIFICATION BLOCKS= MNEM SERVID SERVICE# UNITS API CODE FILE~ SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 SGFN TMD 847605 CU 00000000 0 4 1 68 SGFF TMD 847605 CU 00000000 0 4 i 68 SGBH TMD 847605 CU 00000000 0 4 I 68 NSBF TMD 847605 CPS 00000000 0 4 1 68 FSBF TMD 847605 CPS 00000000 0 4 i 68 NTMD TMD 847605 CPS 00000000 0 4 1 68 FTMD TMD 847605 CPS 00000000 0 4 1 68 RTMD TMD 847605 00000000 0 4 1 68 CRNF TMD 847605 00000000 0 4 I 68 PHIT TMD 847605 PU 00000000 0 4 1 68 SGFM TMD 847605 CU 00000000 0 4 1 68 SIGQ TMD 847605 00000000 0 4 i 68 RSBF TMD 847605 00000000 0 4 1 68 SGIN TMD 847605 CU 00000000 0 4 1 68 SIGC TMD 847605 00000000 0 4 i 68 GRCH TMD 847605 GAPI 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9018.000 SGFN = 21.404 SGFF = 19.147 SGBH = 70.565 NSBF = 15.520 FSBF = 6.903 NTMD = 11443.380 FTMD = 1514.733 RTMD = 7.555 CRNF = 8.288 PHIT = 70.628 SGFM = 18.087 SIGQ = .985 RSBF = .893 SGIN = 17.033 SIGC = 1.062 GRCH = -1.000 DEPT = 8818.000 SGFN = 19.960 SGFF = 18.734 SGBH = 61.942 NSBF = 54.839 FSBF = 6.027 NTMD = 20529.870 FTMD = 3383.191 RTMD = 6.068 CRNF = 6.420 PHIT = 36.689 SGFM = 16.564 SIGQ = .980 RSBF = .695 SGIN = 15.383 SIGC = 1.077 GRCH = 36.881 ****************************************************************************** FILE TRAILER RECORD ............... TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.003 --- 93/o1/18 --- 1024 --- COMCEN.004 Page 9 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.004 --- 93/O1/lS --- 1024 --- COMCEN.003 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER= 04 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER= 04 DEPTH INCREMENT= 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TMD 9028.0 8797.0 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE= GR PASS NUMBER= 01 .......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH TMD 181 BBLS BORON AND 87 BBLS SEAWATER PUMPED AFTER PASS #3. NO PASS TO PASS DEPTH SHIFTS REQUIRED. PUMPING INFORMATION FOR BORAX PASS #4: START TIME: 1427 HRS STOP TIME: 1439 HRS RATE= 0.75 BBLS/MIN VOLUME & TYPE= 12,BBLS SEWATER TOTAL PUMPED= 1038 BBLS SEAWATER/BORON LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS= TYPE SIZE REPR. CODE ENTRY Page 10 1 1 66 0 2 1 66 0 3 2 79 68 4 i 66 1 5 1 66 1 8 4 73 60 9 4 65 .lin 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS API CODE FILE~ SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 SGFN TMD 847605 CU 00000000 0 4 1 68 SGFF TMD 847605 CU 00000000 0 4 1 68 SGBH TMD 847605 CU 00000000 0 4 i 68 NSBF TMD 847605 CPS 00000000 0 4 1 68 FSBF TMD 847605 CPS 00000000 0 4 1 68 NTMD TMD 847605 CPS 00000000 0 4 1 68 FTMD TMD 847605 CPS 00000000 0 4 i 68 RTMD TMD 847605 00000000 0 4 1 68 CRNF TM/) 847605 00000000 0 4 i 68 PHIT TMD 847605 PU 00000000 0 4 1 68 SGFM TMD 847605 CU 00000000 0 4 1 68 SIGQ TMD 847605 00000000 0 4 1 68 RSBF TMD 847605 00000000 0 4 1 68 SGIN TMD 847605 CU 00000000 0 4 I 68 SIGC TMD 847605 00000000 0 4 1 68 GRCH TMD 847605 GAPI 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9028.000 SGFN = 23.480 SGFF = 24.557 SGBH = 89.530 NSBF = 40.270 FSBF = 12.371 NTMD = 10174.460 FTMD = 1284.345 RTMD = -999.000 CRNF = -999.000 PHIT = -999.000 SGFM = 20.286 SIGQ = .991 RSBF = 1.006 SGIN = 21.500 SIGC = 1.030 GRCH = -1.000 DEPT = 8828.000 SGFN = 26.454 SGFF = 23.870 SGBH = 112.988 NSBF = 58.068 FSBF = 6.395 NTMD = 5247.484 FTMD = 945.351 RTMD = 5.551 CRNF = 6.425 PHIT = 36.762 SGFM = 23.455 SIGQ = .990 RSBF = .804 SGIN = 24.782 SI~C = 1.021 GRCH = 97.530 ****************************************************************************** FILE TRAILER RECORD .............................. TYPE 129 FILE NAME --- COMCEN.004 Page 11 SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME ------ 0 --- 9~1o1118 --- 1024 --- LO --- COMCEN.005 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.O05 --- 9~101118 --- 1024 --- LO --- COMCEN.O04 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 05 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 05 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TMD 9027.0 8795.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER~ 01 ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH TMD NO PASS TO PASS DEPTH SHIFTS REQUIRED. PUMPING INFORMATION FOR BORAX PASS #5: START TIME: 1445 HRS STOP TIME: 1457 HRS RATE: 0.75 BBLS/MIN VOLUME & TYPE: 9 BBLS SEWATER TOTAL PUMPED: 1047 BBLS SEAWATER/BORON $ LIS FORMAT DATA Page 12 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS= TYPE SIZE REPR. CODE ENTRY i i 66 0 2 i 66 0 3 2 79 68 4 i 66 1 5 i 66 1 8 4 73 60 9 4 65 .lIN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 i 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS= MNEM SERVID SERVICE# UNITS DEPT F SGFN TMD 847605 CU SGFF TMD 847605 CU SGBH TMD 847605 CU NSBF TMD 847605 CPS FSBF TMD 847605 CPS NTMD TMD 847605 CPS FTMD TMD 847605 CPS RTMD TMD 847605 CRNF TMD 847605 PHIT TMD 847605 PU SGFM TMD 847605 CU SIGQ TMD 847605 RSBF TMD 847605 SGIN TMD 847605 CU SIGC 'TMD 847605 GRCH TMD 847605 GAPI API CODE FILES SIZE #SAMP REPR. 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 i 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 i 68 00000000 0 4 i 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 I 68 00000000 0 4 1 68 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9027.000 S~FN = 23.695 SGFF = 35.787 S~BH = 83.436 NSBF = 61.035 FSBF = 18.854 NTMD = 3359.569 FTMD = 109.298 RTMD = -999.000 CRNF = -999.000 PHIT = -999.000 SGFM = 20.515 SIGQ = .991 RSBF = .972 SGIN = 21.562 SIGC = 1.038 GRCH = -1.000 DEPT = 8827.000 SGFN = 23.733 SGFF = 21.458 SGBH = 107.615 NSBF = 81.346 FSBF = 8.171 NTMD = 6651.129 FTMD = 1159.611 RTMD = 5.736 CRNF = 6.576 PHIT = 39.187 SGFM = 20.557 SIGQ = .989 RSBF = .662 S~IN = 21.794 Page 13 SIGC = 1.028 GRCH = 101.536 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.005 --- 93/01/18 --- 1024 --- LO --- COMCEN.O06 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.006 --- 93/01/18 --- 1024 --- LO --- COMCEN.005 ****************************************************************************** COMMENT RECORD ...... TYPE 232 FILE HEADER FILE NUMBER: 06 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 06 DEPTH INCREMENT= 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TMD 9027.0 8799.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH TM]) NO PASS TO PASS DEPTH SHIFTS REQUIRED. PUMPING INFORMATION FOR BORAX PASS #6: START TIME: 1503 HRS STOP TIME: 1515 HRS RATE: 0.75 BBLS/MIN Page 14 VOLUME & TYPE: TOTAL PUMPED: $ LIS FORMAT DATA 9 BBLS SEWATER 1056 BBLS SEAWATER/BORON ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY I i 66 0 2 i 66 0 3 2 79 68 4 i 66 1 5 1 66 1 8 4 73 60 9 4 65 .lIN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 i 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F SGFN TMD 847605 CU SGFF TMD 847605 CU SGBH TMD 847605 CU NSBF TMD 847605 CPS FSBF TMD 847605 CPS NTMD TMD 847605 CPS FTMD TMD 847605 CPS RTMD TMD 847605 CRNF TMD 847605 PHIT TMD 847605 PU SGFM TMD 847605 CU SI~Q TMD 847605 RSBF TMD 847605 SGIN TMD 847605 CU SIGC TMD 847605 GRCH TMD 847605 GAPI API CODE FILE~ SIZE #SAMP REPR. 00000000 0 4 i 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9027.000 SGFN = 23.161 SGFF = 28.862 S~BH = 87.580 NSBF = 73.936 FSBF = 14.168 NTMD = 6345.848 FTMD = 585.464 RTMD = -999.000 CRNF = -999.000 PHIT = -999.000 SGFM = 19.948 SIGQ = .993 RSBF = .945 SGIN = 21.089 SIGC = 1.034 GRCH = -1.000 Page 15 DEPT = 8827.000 SGFN = 24.370 SGFF = 22.608 SGBH = 107.393 NSBF = 95.816 FSBF = 10.043 NTMD = 5377.344 FTMD = 985.577 RTMD = 5.456 CRNF = 6.296 PHIT = 34.744 SGFM = 21.234 SIGQ = .991 RSBF = .666 SGIN = 22.491 SIGC = 1.026 GRCH = 110.934 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.006 --- 93/01/18 --- 1024 --- LO --- COMCEN.007 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.007 --- 93/01/18 --- 1024 --- LO --- COMCEN.006 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER= 07 AVERAGED CURVES Compensated Neutron= Arithmetic average of edited passes for all curves. Pulsed Neutron= Unaveraged edited Pass i gamma ray and background countsl arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT= 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS TMD 01,02,03 AVERAGE OF NON-BORAX PASSES ~1-2-3. $ LIS FORMAT DATA ****************************************************************************** Page 16 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS= TYPE SIZE REPR. CODE ENTRY I i 66 0 2 i 66 0 3 2 79 68 4 i 66 1 5 I 66 1 8 4 73 60 9 4 65 .lIN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 I 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS API CODE FILE# SIZE ~SAMP REPR DEPT F 00000000 0 4 i 68 SGFN PNAV 847605 CU 00000000 0 4 1 68 SGFF PNAV 847605 CU 00000000 0 4 1 68 SGBH PNAV 847605 CU 00000000 0 4 I 68 NSBF PNAV 847605 CPS 00000000 0 4 i 68 FSBF PNAV 847605 CPS 00000000 0 4 i 68 NTMD PNAV 847605 CPS 00000000 0 4 I 68 FTMD PNAV 847605 CPS 00000000 0 4 I 68 RTMD PNAV 847605 00000000 0 4 I 68 CRNF PNAV 847605 00000000 0 4 i 68 PHIT PNAV 847605 PU 00000000 0 4 1 68 SGFM PNAV 847605 CU 00000000 0 4 i 68 SIGQ PNAV 847605 00000000 0 4 i 68 RSBF PNAV 847605 00000000 0 4 I 68 SGIN PNAV 847605 CU 00000000 0 4 i 68 SIGC PNAV 847605 00000000 0 4 i 68 GRCH PNAV 847605 GAPI 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9008.000 SGFN = 20.855 SGFF = 18.460 S~BH = 69.228 NSBF = 14.713 FSBF = 3.718 NTMD = 16111.570 FTMD = 2514.368 RTMD = 6.437 CRNF = 6.928 PHIT = 45.161 S~FM = 17.507 SI~Q = .982 RSBF = .761 SGIN = 16.405 SIGC = 1.067 GRCH = -1.000 DEPT = 8808.000 SGFN = 21.324 SGFF = 18.517 SGBH = 68.260 NSBF = 55.997 FSBF = 5.774 NTMD = 20451.240 FTMD = 3458.639 RTMD = 5.913 CRNF = 6.340 PHIT = 35.423 S~FM = 18.002 SI~Q = .986 RSBF = .605 S~IN = 16.941 SI~C = 1.063 GRCH = 47.877 Page 17 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.007 --- 93/01/18 --- 1024 --- LO --- COMCEN.008 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.008 --- 93/01/18 --- 1024 --- LO --- COMCEN.007 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 08 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER= 01 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD 9025.0 $ 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 GAMMA RAY 8716.5 04-AUG-92 DLS 4.01 0945 04-AUG-92 9026.0 9021.0 8716.5 9014.0 1200.0 NO TOOL NUMBER 106312 Page 18 TMD TMD BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S 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): 106315 8.5OO 9149.0 SEAWATER 152 .O 0.0 40.0 THERMAL SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 8950.0 BASE NORMALIZING WINDOW (FT): 9000.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 190 FAR COUNT RATE HIGH SCALE (CPS): 5990 NEAR COUNT RATE LOW SCALE (CPS): 3000 NEAR COUNT RATE HIGH SCALE (CPS): 36000 TOOL STANDOFF (IN): 0.0 338 BBLS SEAWATER PUMPED PRIOR TO PASS #1. PUMPING INFORMATION FOR NON-BORAX PASS ~1: START TIME: 0945 HRS STOP TIME: 1002 HRS RATE: 1.0 BBLS/MIN VOLUME & TYPE: 62 BBLS BORON TOTAL PUMPED: 400 BBLS SEAWATER/BORON $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY i I 66 0 2 i 66 0 3 2 79 80 Page 19 4 1 66 1 5 i 66 1 8 4 73 30 9 4 65 .lZN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICES UNITS API CODE FILE~ SIZE DEPT F 00000000 0 4 SGFN' TMD 847605 CU 00000000 0 4 SGFF TMD 847605 CU 00000000 0 4 SGBH TMD 847605 CU 00000000 0 4 NSBF TMD 847605 CNTS 00000000 0 4 FSBF TMD 847605 CNTS 00000000 0 4 NTMD TMD 847605 CNTS 00000000 0 4 FTMD TMD 847605 CNTS 00000000 0 4 RTMD TMD 847605 00000000 0 4 CRNF TMD 847605 00000000 0 4 PHIT TMD 847605 DECI 00000000 0 4 SGFM TMD 847605 CU 00000000 0 4 SI~Q TMD 847605 00000000 0 4 G4ER TMD 847605 00000000 0 4 RSBF TMD 847605 00000000 0 4 ABTN TMD 847605 00000000 0 4 SGIN TMD 847605 CU 00000000 0 4 SIGC TMD 847605 00000000 0 4 GR TMD 847605 GAPI 00000000 0 4 CCL TMD 847605 MV 00000000 0 4 #SAMP 1 1 1 1 1 1 1 1 1 1 1 1 1 **************************************************************** DATA RECORD TYPE 0 REPR. 68 68 68 68 68 68 68 68 68 68 68 68 68 I 68 i 68 i 68 I 68 i 68 I 68 1 68 DEPT = 9025.000 SGFN = 16.339 SGFF = SGBH = 168.333 NSBF = 44.034 FSBF = NTMD = .000 FTMD = .000 RTMD = CRNF = -999.000 PHIT = -999.000 SGFM = SI~Q = .926 ~4ER = -.116 RSBF = ABTN = 2944.964 SGIN = 11.970 SIGC = GR = -1.000 CCL = -1.000 38.091 280.441 -999.000 12.779 .052 1.068 DEPT = 8925.000 SGFN = 43.749 SGFF = SGBH = 80.264 NSBF = 38.830 FSBF = NTMD = 8123.930 FTMD = 1133.523 RTMD = CRNF = 7.916 PHIT = .632 SGFM = SIC, Q = ..964 G4ER = .004 RSBF = ABTN = 34747.140 S~IN = 44.243 SIGC = GR = 98.107 CCL = 13.565 40.375 6.366 7.167 42.088 .972 .951 DEPT = 8825.000 SGFN = 21.904 S~FF = 19.215 Page 20 SGBH = 67.891 NSBF = 52.559 FSBF = 6.228 NTMD = 19541.340 FTMD = 3112.334 RTMD = 6.279 CRNF = 6.732 PHIT = .417 SGFM = 18.616 SI~Q = .985 G4ER = .014 RSBF = .596 ABTN = 28224.620 SGIN = 17.607 SIGC = 1.057 GR = 43.469 CCL = 12.734 DEPT = 8725.000 SGFN = 19.654 SGFF = 15.742 SGBH = 71.094 NSBF = 69.435 FSBF = 6.646 NTMD = 21998.270 FTMD = 4580.453 RTMD = 4.803 CRNF = 5.266 PHIT = .201 SGFM = 15.959 SIGQ = .990 G4ER = .010 RSBF = .769 ABTN = 36317.480 SGIN = 14.727 SIGC = 1.084 GR = 24.716 CCL = 8.800 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.008 --- 93/01/18 --- 1024 --- LO --- COMCEN.009 ****************************************************************************** FILE HEADER RECORD ......... TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.009 --- 93/01/18 --- 1024 --- COMCEN.008 ****************************************************************************** COMMENT RECORD' TYPE 232 FILE HEADER FILE NUMBER: 09 RAW CURVES Curves and log header data for each pass in separate files~ raw background pass in last file. PASS NUMBER: 02 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD 9033 . 5 8748.5 $ Page 21 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 04-AUG-92 DLS 4.01 1012 04-AUG-92 9026.0 9021.0 8748.5 9014.0 1200.0 NO TOOL NUMBER GR GAMMA RAY TMD TMD $ 106312 106315 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 9149.0 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): SEAWATER 152.0 0.0 40.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 8950.0 BASE NORMALIZING WINDOW (FT): 9000.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 190 FAR COUNT RATE HIGH SCALE (CPS): 5990 NEAR COUNT RATE LOW SCALE (CPS): 3000 NEAR COUNT RATE HIGH SCALE (CPS): 36000 TOOL STANDOFF (IN): 0.0 REMARKS NO PASS TO PASS DEPTH SHIFTS REQUIRED. PUMPING INFORMATION FOR NON-BORAX PASS ~2: START TIME: 1012 HRS STOP TIME: 1027 HRS RATE: 1.0 BBLS/MIN Page 22 VOLUME & TYPE: TOTAL PUMPED: $ LIS FORMAT DATA 8 BBLS BORON 408 BBLS SEAWATER/BORON ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 i 66 0 2 I 66 0 3 2 79 80 4 i 66 1 5 i 66 1 8 4 73 30 9 4 65 .lIN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 i 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICES UNITS DEPT F SGFN TMD 847605 CU SGFF TMD 847605 CU SGBH TMD 847605 CU NSBF TMD 847605 CNTS FSBF TMD 847605 CNTS NTMD TMD 847605 CNTS FTMD TMD 847605 CNTS RTMD TMD 847605 CRNF TMD 847605 PHIT TMD 847605 DECI SGFM TMD 847605 CU SIGQ TMD 847605 G4ER TMD 847605 RSBF TMD 847605 ABTN TMD 847605 SGIN TMD 847605 CU SIGC TMD 847605 GR TMD 847605 GAPI CCL TMD 847605 MV API CODE FILE~ SIZE ~SAMP REPR. 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 I 68 00000000 0 4 i 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 i 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 I 68 00000000 0 4 i 68 00000000 0 4 i 68 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9033.500 SOFN = 18.881 SOFF = 14.750 SGBH = 70.551 NSBF = 71.572 FSBF = 7.487 NTMD = .000 FTMD = .000 RTMD = -999.000 CRNF = -999.000 PHIT = -999.000 SGFM = 14.957 Page 23 SIGQ = .985 G4ER = .010 RSBF = .699 ABTN = 34108.270 SGIN = 13.641 SIGC = 1.096 GR = -1.000 CCL = -1.000 DEPT = 8933.500 SGFN = 37.138 SGFF = 32.142 SGBH = 80.979 NSBF = 73.143 FSBF = 8.065 NTMD = 9993.395 FTMD = 1536.463 RTMD = 6.504 CRNF = 7.156 PHIT = .490 SGFM = 33.890 SIGQ = .986 G4ER = -.011 RSBF = .910 ABTN = 33637.330 SGIN = 34.674 SIGC = .977 GR = 78.120 CCL = 6.776 DEPT = 8833.500 SGFN = 24.120 SGFF = 22.581 SGBH = 63.715 NSBF = 84.057 FSBF = 8.617 NTMD = 17055.950 FTMD = 2588.547 RTMD = 6.589 CRNF = 7.027 PHIT = .468 SGFM = 20.968 SIGQ = .964 G4ER = .012 RSBF = .911 ABTN = 31208.860 SGIN = 20.155 SIGC = 1.040 GR = 51.344 CCL = 24.602 ****************************************************************************** FILE TRAILER RECORD ........ TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.009 --- 93/01/18 --- 1024 --- LO --- COMCEN.010 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.010 --- 93/01/~8 --- 1024 --- LO --- COMCEN.009 ****************************************************************************** COMMENT RECORD ............... TYPE 232 FILE READER FILE NUMBER: 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 03 DEPTH INCREMENT: 0.2500 Page 24 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD LOG HEADER DATA 9O32.5 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 8795.5 04-AUG-92 DLS 4.01 1308 04-AUG-92 9026.0 9021.0 8795.5 9014.0 1200.0 NO TOOL NUMBER GR GAMMA RAY TMD TMD $ 106312 106315 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT)= 8.500 9149.0 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): SEAWATER 152 .O 0.0 40.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE .TOP NORMALIZING WINDOW (FT): 8950.0 BASE NORMALIZING WINDOW (FT): 9000.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 190 FAR COUNT RATE HIGH SCALE (CPS): 5990 NEAR COUNT RATE LOW SCALE (CPS): 3000 NEAR COUNT RATE HIGH SCALE (CPS): 36000 TOOL STANDOFF (IN): 0.0 Page 25 332 BBLS SEAWATER PUMPED AFTER PASS #2. NO PASS TO PASS DEPTH SHIFTS REQUIRED. PUMPING INFORMATION FOR NON-BORAX PASS #3: START TIME: STOP TIME: RATE: VOLUME & TYPE: TOTAL PUMPED: $ LIS FORMAT DATA 1308 HRS 1320 HRS 1.0 BBLS/MIN 18 BBLS SEWATER 758 BBLS SEAWATER/BORON ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 I 66 0 2 I 66 0 3 2 79 80 4 i 66 1 5 I 66 1 8 4 73 30 9 4 65 .lIN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 i 66 1 0 I 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICES UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 i 68 SGFN TMD 847605 CU 00000000 0 4 i 68 SGFF TMD 847605 CU 00000000 0 4 i 68 SGBH TMD 847605 CU 00000000 0 4 1 68 NSBF TMD 847605 CNTS 00000000 0 4 1 68 FSBF TMD 847605 CNTS 00000000 0 4 I 68 NTMD TMD 847605 CNTS 00000000 0 4 i 68 FTMD TMD 847605 CNTS 00000000 0 4 1 68 RTMD TMD 847605 00000000 0 4 i 68 CRNF TMD 847605 00000000 0 4 1 68 PHIT TMD 847605 DECI 00000000 0 4 i 68 SGFM TMD 847605 CU 00000000 0 4 1 68 SIGQ TMD 847605 00000000 0 4 1 68 G4ER TMD 847605 00000000 0 4 1 68 RSBF TMD 847605 00000000 0 4 1 68 ABTN TMD 847605 00000000 0 4 1 68 SGIN TMD 847605 CU 00000000 0 4 i 68 SIGC TMD 847605 00000000 0 4 i 68 GR TMD 847605 GAPI 00000000 0 4 i 68 CCL TMD 847605 MV 00000000 0 4 i 68 ****************************************************************************** Page 26 DATA RECORD TYPE 0 DEPT = 9032.500 SGFN = 17.699 SGBH = 65.715 NSBF = 93.491 NTMD = .000 FTMD = .000 CRNF = -999.000 PHIT = -999.000 SIGQ = .981 G4ER = .015 ABTN = 33688.520 SGIN = 12.522 GR = -1.000 CCL = -1.000 SGFF = 14.463 FSBF = 9.263 RTMD = -999.000 SGFM = 13.924 RSBF = .738 SIGC = 1.112 DEPT = 8932.500 SGFN = 40.328 SGBH = 79.411 NSBF = 39.237 NTMD = 8761.922 FTMD = 1249.263 CRNF = 7.721 PHIT = .594 SIGQ = .974 G4ER = -.002 ABTN = 33681.820 SGIN = 40.001 GR = 84.619 CCL = 7.919 SGFF = 37.859 FSBF = 6.636 RTMD = 7.014 SGFM = 38.388 RSBF = 1.002 SIGC = .960 DEPT = 8832.500 SGFN = 29.552 SGBH = 68.959 NSBF = 53.543 NTMD = 14552.720 FTMD = 2250.985 CRNF = 6.954 PHIT = .455 SIGQ = .986 G4ER = .001 ABTN = 21338.230 SGIN = 26.509 GR = 72.686 CCL = 9.828 ********************************************** FILE TRAILER RECORD ....... FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.010 --- 93/01/18 --- 1024 --- COMCEN.011 SGFF = 26.371 FSBF = 6.406 RTMD = 6.465 SGFM = 26.776 RSBF = .536 SIGC = 1.010 ******************************** TYPE 129 ****************************************************************************** FILE HEADER RECORD ......... TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.011 ~-- 93/01/18 --- 1024 --- LO --- COMCEN.010 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER Page 27 FILE NUMBER= 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER= 04 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD 9035.0 $ 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 8796.0 04-AUG-92 DLS 4.01 1427 04-AUG-92 9026.0 9021.0 8796.0 9014.0 1200.0 NO TOOL NUMBER OR GAMMA RAY TMD TMD .$ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 106312 106315 8.5OO 9149.0 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): SEAWATER 152 .O 0.0 40.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 8950.0 BASE NORMALIZING WINDOW (FT): 9000.0 Page 28 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 190 FAR COUNT RATE HIGH SCALE (CPS): 5990 NEAR COUNT RATE LOW SCALE (CPS): 3000 NEAR COUNT RATE HIGH SCALE (CPS): 36000 TOOL STANDOFF (IN): REMARKS: 0.0 181 BBLS BORON AND 87 BBLS SEAWATER PUMPED AFTER PASS #3. NO PASS TO PASS DEPTH SHIFTS REQUIRED. PUMPING INFORMATION FOR BORAX PASS ~4: START TIME: STOP TIME: RATE: VOLUME & TYPE: TOTAL PUMPED: $ LIS FORMAT DATA 1427 HRS 1439 HRS 0.75 BBLS/MIN 12 BBLS SEWATER 1038 BBLS SEAWATER/BORON ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY i I 66 0 2 1 66 0 3 2 79 80 4 i 66 1 5 i 66 1 8 4 73 30 9 4 65 .liN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F SGFN TMD 847605 CU SGFF TMD 847605 CU SGBH TMD 847605 CU NSBF TMD 847605 CNTS FSBF TMD 847605 CNTS NTMD TMD 847605 CNTS FTMD TMD 847605 CNTS RTMD TMD 847605 CRNF TMD 847605 PHIT TMD 847605 DECI SGFM TMD 847605 CU SIGQ TMD 847605 G4ER TMD 847605 API CODE FILE# SIZE 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 #SAMP REPR. i 68 i 68 i 68 i 68 i 68 i 68 I 68 i 68 I 68 i 68 i 68 i 68 1' 68 i 68 Page 29 RSBF TMD 847605 00000000 0 4 1 68 ABTN TMD 847605 00000000 0 4 1 68 SGIN TMD 847605 CU 00000000 0 4 i 68 SIGC TMD 847605 00000000 0 4 1 68 GR TMD 847605 GAPI 00000000 0 4 i 68 CCL TMD 847605 MV 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9035.000 SGFN = 21.987 SGFF = 38.453 SGBH = 51.742 NSBF = 75.111 FSBF = 29.504 NTMD = .000 FTMD = .000 RTMD = -999.000 CRNF = -999.000 PHIT = -999.000 SGFM = 18.704 SIGQ = .952 G4ER = -.071 RSBF = 1.826 ABTN = 29225.070 SGIN = 19.501 SIGC = 1.057 GR = -1.000 CCL = -1.000 DEPT = 8935.000 SGFN = 29.702 SGFF = 26.208 SGBH = 94.989 NSBF = 45.140 FSBF = 7.162 NTMD = 6897.336 FTMD = 1241.987 RTMD = 5.553 CRNF = 6.315 PHIT = .350 SGFM = 26.933 SIGQ = .994 G4ER = .004 RSBF = 1.524 ABTN = 28546.630 SGIN = 28.370 SIGC = 1.014 GR = 78.906 CCL = 6.219 DEPT = 8835.000 SGFN = 22.488 SGFF = 19.531 SGBH = 103.863 NSBF = 56.485 FSBF = 6.373 NTMD = 8012.773 FTMD = 1423.345 RTMD = 5.630 CRNF = 6.446 PHIT = .371 SGFM = 19.238 SIGQ = .994 G4ER = .008 RSBF = .575 ABTN = 14391.130 SGIN = 20.433 SIGC = 1.032 GR = 59.956 CCL = 33.859 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.011 --- 93/Ol/18 --- 1024 --- COMCEN.012 ****************************************************************************** FILE HEADER RECORD ....... TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE --- COMCEN.012 --- 93/01/18 --- 1024 --- LO Page 30 OPTIONAL PREVIOUS FILE NAME --- COMCEN.011 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER= 05 DEPTH INCREMENT= 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD 9035.5 $ 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)= 8794.5 04-AUG-92 DLS 4.01 1445 04-AUG-92 9026.0 9021.0 8794.5 9014.0 1200.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GAMMA RAY TMD TMD $ 106312 106315 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 9149.0 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): SEAWATER 152 .O 0.0 40.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL Page 31 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NOI~IALIZING WINDOW (FT): 8950.0 BASE NORMALIZING WINDOW (FT): 9000.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 190 FAR COUNT RATE HIGH SCALE (CPS): 5990 NEAR COUNT RATE LOW SCALE (CPS): 3000 NEAR COUNT RATE HIGH SCALE (CPS): 36000 TOOL STANDOFF (IN): REMARKS 0.0 NO PASS TO PASS DEPTH SHIFTS REQUIRED. PUMPING INFORMATION FOR BORAX PASS #5: START TIME: STOP TIME: RATE: VOLUME & TYPE: TOTAL PUMPED: LIS FORMAT DATA 1445 HRS 1457 HRS 0.75 BBLS/MIN 9 BBLS SEWATER 1047 BBLS SEAWATER/BORON ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY I i 66 0 2 i 66 0 3 2 79 80 4 i 66 1 5 1 66 1 8 4 73 30 9 4 65 .lIN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 i 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS= MNEM SERVID SERVICE~ UNITS DEPT F SGFN TMD 847605 CU SGFF TMD 847605 CU SGBH TMD 847605 CU NSBF TMD 847605 CNTS FSBF TMD 847605 CNTS NTMD TMD 847605 CNTS FTMD TMD 847605 CNTS API CODE FILE~ SIZE 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 ~SAMP REPR. i 68 I 68 I 68 i 68 1 68 I 68 1 68 i 68 Page 32 RTMD TMD 847605 00000000 0 4 1 68 CRNF TMD 847605 00000000 0 4 i 68 PHIT TMD 847605 DECI 00000000 0 4 1 68 SGFM TMD 847605 CU 00000000 0 4 1 68 SIGQ TMD 847605 00000000 0 4 1 68 G4ER TMD 847605 00000000 0 4 1 68 RSBF TMD 847605 00000000 0 4 1 68 ABTN TMD 847605 00000000 0 4 1 68 SGIN TMD 847605 CU 00000000 0 4 1 68 SIGC TMD 847605 00000000 0 4 1 68 GR TMD 847605 GAPI 00000000 0 4 i 68 CCL TMD 847605 MV 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9035.500 SGFN = 19.774 SGFF = 17.082 SGBH = 107.158 NSBF = 80.958 FSBF = 6.358 NTMD = .000 FTMD = .000 RTMD = -999.000 CRNF = -999.000 PHIT = -999.000 SGFM = 16.032 SIGQ = 1.002 G4ER = -.005 RSBF = .395 ABTN = 6896.633 SGIN = 17.125 SIGC = 1.046 GR = -1.000 CCL = -1.000 DEPT = 8935.500 SGFN = 29.459 SGFF = 26.100 SGBH = 94.448 NSBF = 70.209 FSBF = 8.748 NTMD = 6470.805 FTMD = 1111.649 RTMD = 5.821 CRNF = 6.581 PHIT = .393 SGFM = 26.673 SIGQ = .990 G4ER = -.020 RSBF = 1.440 ABTN = 26094.000 SGIN = 28.102 SIGC = 1.014 GR = 91.611 CCL = 9.439 DEPT = 8835.500 SGFN = 22.914 SGFF = 19.141 SGBH = 102.093 NSBF = 81.269 FSBF = 8.351 NTMD = 7285.688 FTMD = 1291.846 RTMD = 5.640 CRNF = 6.445 PHIT = .371 SGFM = 19.687 SIGQ = .993 G4ER = .016 RSBF = .633 ABTN = 14725.200 SGIN = 20.896 SIGC = 1.031 GR = 77.980 CCL = 15.935 ****************************************************************************** FILE TRAILER RECORD ....................... TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.012 --- 931o1118 --- 1024 --- COMCEN.013 ****************************************************************************** FILE HEADER RECORD TYPE 128 Page 33 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.013 --- 93/01/18 --- 1024 --- LO --- COMCEN.012 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER= 06 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD LOG HEADER DATA 9035.5 8798.0 DATE LO~GED: 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 mmmmmmmmmmmmmmmmmmm GR GAMMA RAY TMD TMD $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S 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): 04-AUG-92 DLS 4.01 1503 04-AUG-92 9026.0 9021.0 8798.0 9014.0 1200.0 NO TOOL NUMBER 106312 106315 8.500 9149.0 SEAWATER 152 .O 0.0 Page 34 WATER CUTS (PCT)= GAS/OIL RATIO= CHOKE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 40.0 THERMAL SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 8950.0 BASE NORMALIZING WINDOW (FT): 9000.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 190 FAR COUNT RATE HIGH SCALE (CPS): 5990 NEAR COUNT RATE LOW SCALE (CPS): 3000 NEAR COUNT RATE HIGH SCALE (CPS): 36000 TOOL STANDOFF (IN): 0.0 VOLUME & TYPE: TOTAL PUMPED: LIS FORMAT DATA NO PASS TO PASS DEPTH SHIFTS REQUIRED. PUMPING INFORMATION' FOR BORAX PASS #6: START TIME: 1503 HRS STOP TIME: 1515 HRS RATE: 0.75 BBLS/MIN 9 BBLS SEWATER 1056 BBLS SEAWATER/BORON ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY i i 66 0 2 i 66 0 3 2 79 80 4 i 66 1 5 i 66 1 8 4 73 30 9 4 65 .lIN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 i 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS DEPT F SGFN TMD 847605 CU API CODE FILE~ 00000000 0 00000000 0 SIZE ~SAMP REPR. 4 i 68 4 i 68 Page 35 SGFF TMD 847605 CU 00000000 0 4 i 68 SGBH TMD 847605 CU 00000000 0 4 i 68 NSBF TMD 847605 CNTS 00000000 0 4 i 68 FSBF TMD 847605 CNTS 00000000 0 4 1 68 NTMD TMD 847605 CNTS 00000000 0 4 i 68 FTMD TMD 847605 CNTS 00000000 0 4 1 68 RTMD TMD 847605 00000000 0 4 i 68 CRNF TMD 847605 00000000 0 4 i 68 PHIT TMD 847605 DECI 00000000 0 4 i 68 SGFM TMD 847605 CU 00000000 0 4 1 68 SIGQ TMD 847605 00000000 0 4 i 68 G4ER TMD 847605 00000000 0 4 i 68 RSBF TMD 847605 00000000 0 4 i 68 ABTN TMD 847605 00000000 0 4 I 68 SGIN TMD 847605 CU 00000000 0 4 1 68 SIGC TMD 847605 00000000 0 4 i 68 GR TMD 847605 GAPI 00000000 0 4 i 68 CCL TMD 847605 MV 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9035.500 SGFN = 20.087 SGFF = 17.173 SGBH = 123.711 NSBF = 104.157 FSBF = 8.470 NTMD = .000 FTMD = .000 RTMD = -999.000 CRNF = -999.000 PHIT = -999.000 SGFM = 16.278 SIGQ = .999 G4ER = -.001 RSBF = .387 ABTN = 7079.574 SGIN = 17.379 SIGC = 1.045 GR = -1.000 CCL = -1.000 DEPT = 8935.500 SGFN = 29.297 SGFF = 25.262 SGBH = 89.306 NSBF = 86.946 FSBF = 10.265 NTMD = 5708.297 FTMD = 1096.653 RTMD = 5.205 CRNF = 5.939 PHIT = .294 SGFM = 26.498 SIGQ = .990 G4ER = .006 RSBF = 1.560 ABTN = 26215.880 SGIN = 27.926 SIGC = 1.014 GR = 103.742 CCL = 5.945 DEPT = 8835.500 SGFN = 21.764 SGFF = 20.703 SGBH = 95.275 NSBF = 92.212 FSBF = 8.997 NTMD = 6365.246 FTMD = 1171.893 RTMD = 5.432 CRNF = 6.196 PHIT = .332 SGFM = 18.468 SIGQ = .992 G4ER = .029 RSBF = .697 ABTN = 14226.710 SGIN = 19.638 SIGC = 1.035 GR = 87.786 CCL = 42.168 ****************************************************************************** FILE TRAILER RECORD ............. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE --- COMCEN.013 --- 93101118 --- 1024 --- ~0 Page 36 OPTIONAL NEXT FILE NAME ****************************************************************************** TAPE TRAILER RECORD TYPE 131 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER NEXT TAPE NAME COMMENTS= --- COMCEN --- 93/o~/~s ~tm 0 ****************************************************************************** REEL TRAILER RECORD .............................. TYPE 133 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER NEXT REEL NAME COMMENTS= --- COMCEN --- 9~1o~1~8 --- 847605 ****************************************************************************** END OF TAPE ENCOUNTERED Page 37 PROGRAM: LI. SCAN REVISION: 5.1 Start of execution: Tue ? MAR 89 4:50p **** REEL LIS .88/05/12 HEADER **** A TL'AS 01 'LIS CUSTOMER LIBRARY **** TAPE HEADER **** LIS 88/05/1'2 3626 0.1 TAPE" PART NUMBER: W5790-PE32 "PDK-IO0: 8932-B5'62, DIFF TEMP-DOWN: 7710-8966 & UP: 8970-8194" · .~ FILE #'" 1:' ****"'FILE'"M'EAD:ER ****'" " " . . .".. 'BKGRN.D'..O01 1024 CN WN' FN COUN STA.T :. ARCO· ALASKA INC. : D..S. 4-'1..0i : PRUDHOE BAY : ,NORTH SLOPE. · :A'LASKA. .. * FOR.MAT RECORD. .(.TY'PE#..6.4) ONE DEPTH·PER'FRAME 'TAPE DEPT.H U'N.I'T ' FT .. 1,9 CURVES :. NAME COD I CCL 68 · 2. SPD' 58 '3 '"LS 68 4 SS 68 5' G1 '68 6 GEis 68 7 G'2' 6'8 8. GR 68 SAMPLE~ U. NI.T · I V'OLT I :T 1' CTS 1. C"TS .1 CTS 1 CTS 1 CTS '1 ApI BYTES 4 4 10 MS'D 6'8 1 CTS. 4. 11 SGMA 68 I DIM 4 12 CSS 68 I CTS 4 13 ISS 68 1 CTS 4 14 BKL 68 1 CTS 4 15 .BKS 68 1 CTS 4 16 R~TO 65 I DIM 4 17 RICS. 65 I DIM 4 18 RIN 68 I OIM 4 19 RBOR 68 1 DIM ~ * DATA RmCORD (TYPE# 0)' 966 BYTES * DEPTH CCL SPD LS SS G1 GElS G2 .GR MON MSD SGMA CSS ISS BKL BKS RATO RICS RIN RBOR '" 8930.0'00 0,000000'0 23.99762 ,..' I 29. 9870 99.99001 I 59. 9840 38 i'000.2~3. 0,2760'5.1 5 1 29'. 9870 .,' 169.. 983.0 3. 028188 0'. 9'230.76.6 · ..... 888'0.000 ..... 0 .'000'0'000. 2'4.34261 39.99599 149.98'50 17'9.98.20 10.1'05.99 I 1 9.98.80 2'.39. 9760 2.400000 3,333332 . 11.70300 5.7.1 2799 257. 0447 '9065. 168 ...' ..... .... '"~., . 68.0.580'1. '. 138999, 6 '6.8.75'1 ·98" ........ ' ' ........ s .8. ,'. .' .... .,.,~,,~.:......~:.~,....~:...,..;.., 12.9 ~8." . 2.44..08.30 ..4'.7.350'62.. .. I ,1.'.339.1.0' 0.. 1.943.574'E- 03 · I .,02.846'3' ' . . . · ,'.':~...' 88'30..~.000 '. :.'"'."' '.7"1"4 ,'1 499 · ' 2'4.82"1 2'0'"' · 2'5'.:3'.2.'1"01 · 9:7'. '9"1'8.00' " . ~.~:.:.. .. . · . ~.'.'"' "41'1'27'0.0 1944.69. 6 '' 62 0.0200. "2'67 9670 . ' '9098. 125 i:",'.'. ' ' ' ' ' ' ' ' ' ' ~.:':'?i'..'.: ....',7.., '8255'..34. ' - 4 .. ~6' 3' 8.'97.1. 62..5..7..0. 02" .. · 5 9.96 901 ' 3 '22.." 9'05'3 · .....'.. 2'79. 9709 .. ..4...'134139 '0..9584'303 0'. 5'186144'E-03 . O. 82630.31 .. .. .. .. .. ":~'.' "'..8'780.'.000' ... '0...00'0'0000' 24'.60391 "' '25 .'21 6'02 ' 13'. 3.1.600' · 1'5' 3.81'00" 1'831'82 9 23' 519'700. .77 109'21 9114 .9.6.9 ..:.};::.,..... . ......... . .m .... . .. ... 15 4'6836 -2"9 44~2.7 .16 1.2'80..1 37..48401. 80..93.800 /...:. ', ... 0. . , . . · :. .~ .... . .. . . ,.. :/~.'." 7'9.76001 .0.5.3067'89. 2':3'.241"57. 0..2.089248 E-03 7.803.600 ...., ..' . . .. .. . . .i.,'.8.'7"3'0.0'0'0". .0.., 0'000'000 24.627'01 10,"69800 "'1'4. 86800 "::'.."' "8',2"7'2.9'99. ' 1"59862,8. ' ...... .1'7:,5.340i' "~ 44,'91'4'09' ' : 911'4,969 '"' '23.78343 .-89,'55132 14:.39300 .. . .1.8.73700 '72". 7.1.1.9..9 .. .5'0;3.0598 1.4'781.48 1.,3'01.81.3' ...0,6439405E-04 0.7.544811 '.... .......... .. . . .. ...... .. . . .. . .... .'!" '8680.00'0 ' 0,0000000 24.99'751 19,50601 32.8140'0 33 ."3.7100 ..33.001.3.9 33 0.88.'99 76 ,,3.1 0.50:. .908.2..4~...5 ..i" '44.6'46'5'5 -60,1'6980 2'6...24.001 23,'.4'7:90'0" 10'1,2910 102,7940 1.60'5010. 0.89477.88 0,.22.896.88. E-.03. 1.839754 .. .. -. . . . .. 8630.000 27.1.4500 18,26286 3"03.9841.. 0.0000000 211'900.7 -379.34.'2'0 0.6067756. '24.99751 2'!.85699 .26.4970.1 1.92051'9 '.47.1'1900 239.6971 50 · 8'8.8'00 · '0., .1114839.E'-03. 28.86900 90..31. 063. 340.3921 ,2.229'3?3 .: · . . 18.2.3021 1'1.41839 0.0000000 0.0000000 ~i.9'.'96~'~ 339.9661 0.0000000 0.0000000 0.0000000 1.000244 TOTAL DATA RECORDS : STARTING TAPE .DEPTH = **** ~ILE TRAILER **** 59 8930.00 ENDING TAPE DEPTH = 8578.00 FILE # 2 PASS 1.002 **** FILE HEADER **** 1024 .i .. ...' FORMAT ONE'DEP RECORD (TYPE# 64) TH PER FRAME TAPE DEPTH UNIT : FT 1'9 CURVES : NAME 1 .CCL.. ' '" : '"""Z"" "." ........ · . ......... 3...:..L.S ..... .. 4 6 7 8 9 .10 "1:t 12 13 114 15 16 1'7 18 1.9 SS G't'.' .GELS 62".. G.R HON. .MSD SG'MA CSS ISS BKL B.KS RATO 'RICS RI'N .RBOR CODE SAM .~.,...~...,~8.. .. ; .., :. 6'8 68 68 '" 68 68 68 68 68 68. 68 68 68 68 " 68 68' 68 PLE# UNIT 1..... ..... ..V::.O.,..LT.. 1 FT. .1 C..~ S.. 1 ...¢'T'S '1 :. C'T S 1 CTS 1 CTS.' 1 API . . I C. 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'...., · ....., "..~.. ..;, ..' . '. · · ;.... .... ... 1449.795 1449.795 9.885355 23.96782 1461 .514 9. 61726'0 1461.514 .23 "9976.2 '1'478,886 6.941495 . . 14'78.88'6: 23.99762 · **** FILE' ;TRAI'LER :. . . . . ., , , · , ,,, . · *.*'* T A..P E .': T R A'I L'E R LIS · '"'"'.." 88/05/'1.2 .' T.O:,TA.'L'D.A'.TA ..R.'.ECO..R."DS'.:..'- .STA'R'T'I"N"G""T'AP'E"'.D'E"PTH"'" *~*~. .. . .. ,,. "'8192, O0 :ENDI'N'G: TAP'E.' DE'PTH"=" · , 8960.0'0 ,. 01. ... TOTAL R ECO.R D.S . . . .. . .: . .... .. ... .. ****' REEL TRAILER **** LIS 88../0'5 / 1.2.. . .. .. AT.LAS. 01 . , .IN. THIS 'LOGICAL .TAPE : 993 .,. TOTAL "RECORDS IN THIS LOGIC'AL REEL : 994 TOTAL .RECORDS I.N THI. S' PHYSICAL REEL: 994. . . . End of e.xec'u~&on: Tu.e 7' MAR 89 4:54p. .'.. Elapsed SYSTEM exec.ution time RETURN COD~ = 0 minutes, 3'~ .0 seconds.
