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189-074
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: 2K-12 (PTD #189-074) Failing MIT-OA Date:Wednesday, June 21, 2023 1:43:30 PM Attachments:image001.png MIT KRU 2K PAD page 1 06-20-23.xlsx AnnComm Surveillance TIO for 2K-12.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, June 21, 2023 11:58 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: 2K-12 (PTD #189-074) Failing MIT-OA Chris- KRU 2K-12 (PTD #189-074) failed the AOGCC witnessed MIT-OA yesterday. The well operates under 2B.048 which requires an AOGCC witnessed MIT-IA and MIT-OA. 2B.048 was issued for continued water injection only due to known IAxOA communication. The failure of the MIT-OA did not suggests worsening IAxOA communication but suggested the loss of integrity of the surface casing or surface casing shoe. Therefore, the MIT-IA will not be conducted until the well can be secured with a down hole plug to provide an additional barrier to formation. The well will be shut in and secured as soon as reasonably possible to verify the integrity of the remaining barriers. Attached is a copy of the current 90 day TIO plot, well bore schematic and 10-426 form from the failing MIT-OA. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1881180 Type Inj W Tubing 2675 2675 2675 2675 Type Test P Packer TVD 5944 BBL Pump 2.6 IA 510 3500 3420 3400 Interval V Test psi 3000 BBL Return 2.3 OA 340 690 700 710 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1881180 Type Inj W Tubing 2660 2660 2675 2675 Type Test P Packer TVD 5944 BBL Pump 0.7 IA 510 590 590 590 Interval V Test psi 1800 BBL Return 0.6 OA 300 2000 1920 1895 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1890820 Type Inj W Tubing 2675 2675 2675 2675 Type Test P Packer TVD 6007 BBL Pump 3.6 IA 550 3460 3300 3280 Interval V Test psi 3000 BBL Return 3.3 OA 180 540 550 550 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1890820 Type Inj W Tubing 2660 2675 2675 2675 Type Test P Packer TVD 6007 BBL Pump 1.2 IA 600 630 630 630 Interval V Test psi 1800 BBL Return 1.0 OA 130 2080 1990 1970 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1890590 Type Inj W Tubing 2725 2750 2750 2750 Type Test P Packer TVD 5987 BBL Pump 2.8 IA 480 3490 3300 3260 Interval V Test psi 3000 BBL Return 2.7 OA 310 610 610 610 Result P Notes: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1890740 Type Inj W Tubing Type Test P Packer TVD 6012 BBL Pump IA Interval V Test psi 3000 BBL Return OA Result Notes: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1890740 Type Inj W Tubing 2925 Type Test P Packer TVD 6012 BBL Pump 6.8 IA 540 Interval V Test psi 1800 BBL Return OA 230 1680 Result F Notes: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2110450 Type Inj W Tubing 2790 2790 2790 2790 Type Test P Packer TVD 6121 BBL Pump 2.2 IA 570 1980 1880 1870 Interval 4 Test psi 1530 BBL Return 2.1 OA 240 240 240 240 Result P Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Notes:MITIA to maximum anticipated injection pressure per AIO 2C.089 2K-05 2K-06 2K-05 Kuparuk / KRU / 2K Pad Kam StJohn Weimer / Borge 06/20/23 Notes:MITOA to 1800 psi per AIO 2C.089 2K-06 Notes:MITIA to maximum anticipated injection pressure per amended AIO 2C.054 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov 2K-12 2K-13A MITIA to maximum anticipated injection pressure per AIO 2B.048 Did not do due to OA failure. Notes:MITOA to 1800 psi per amended AIO 2C.054 MITOA to 1800 psi per AIO 2B.048 6.8 bbls away at 1 bpm. Never got over 1680 psi and dropped to 1400 psi. Shut in pump and fell to 330 psi. MITIA to maximum anticipated injection pressure per AIO 2B.017 2K-12 2K-10 Form 10-426 (Revised 01/2017)MIT KRU 2K PAD page 1 06-20-23 (002) Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 62' of Rathole) 6,858.0 5/3/2021 2K-12 rogerba Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: TAG 5/3/2021 2K-12 rogerba Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l…Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 3,021.4 Set Depth (TVD) … 2,943.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 7,054.9 Set Depth (TVD) … 6,469.9 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.1 Set Depth (ft… 6,616.5 Set Depth (TVD) (… 6,075.7 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.1 31.1 0.13 HANGER FMC TUBING HANGER 3.500 1,815.0 1,815.0 0.42 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 6,531.2 6,000.5 28.27 PBR BAKER PBR 2.850 6,544.9 6,012.5 28.20 PACKER BAKER HB PACKER 2.892 6,582.1 6,045.4 28.00 NIPPLE OTIS 2.813" XN NIPPLE w/2.75" NO GO 2.750 6,615.8 6,075.1 27.99 SOS BAKER SHEAR OUT SUB 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,686.0 6,692.0 6,137.0 6,142.3 C-4, UNIT B, 2K -12 6/6/1997 6.0 APERF 60 deg. Phasing; 2.5" HSD DP 6,736.0 6,748.0 6,181.1 6,191.7 A-5, 2K-12 6/6/1997 6.0 APERF 60 deg. Phasing; 2.5" HSD DP 6,764.0 6,796.0 6,206.0 6,234.5 A-4, 2K-12 10/22/1989 2.0 IPERF 180 deg. Phasing Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,350.3 2,338.3 19.22 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/30/1995 2 4,333.3 4,083.0 30.64 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/30/1995 3 5,763.8 5,330.0 28.26 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/30/1995 4 6,488.1 5,962.6 28.60 CAMCO MMG-2 1 1/2 GAS LIFT DMY BK 0.000 0.0 7/16/1995 Notes: General & Safety End Date Annotation 11/2/2010 NOTE: View Schematic w/ Alaska Schematic9.0 6/20/2010 NOTE: WAIVERED WELL IA x OA COMMUNICATION 2K-12, 5/4/2021 6:30:17 AM Vertical schematic (actual) PRODUCTION; 33.0-7,054.9 IPERF; 6,764.0-6,796.0 APERF; 6,736.0-6,748.0 APERF; 6,686.0-6,692.0 SOS; 6,615.8 NIPPLE; 6,582.1 PACKER; 6,544.9 PBR; 6,531.2 GAS LIFT; 6,488.1 GAS LIFT; 5,763.8 GAS LIFT; 4,333.3 SURFACE; 35.0-3,021.4 GAS LIFT; 2,350.3 SAFETY VLV; 1,815.0 CONDUCTOR; 36.0-115.0 HANGER; 31.1 KUP INJ KB-Grd (ft) 40.09 Rig Release Date 9/10/1989 2K-12 ... TD Act Btm (ftKB) 7,107.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032010900 Wellbore Status INJ Max Angle & MD Incl (°) 31.48 MD (ftKB) 3,900.00 WELLNAME WELLBORE2K-12 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2K-12 KUPARUK RIV UNIT 2K-12 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 2K-12 50-103-20109-00-00 189-074-0 W SPT 6012 1890740 1800 2925 230 1680 REQVAR F Kam StJohn 6/20/2023 MIT-OA to 1800 psi per AIO 2B.048 pumped 6.8 bbls away at 1 bbl got to 1680 psi and broke over to 1400psi. Shut down pump and psi went right to 330psi. Shut well in and did not do MIT-IA on this well 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2K-12 Inspection Date: Tubing OA Packer Depth 540IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230621142424 BBL Pumped:6.8 BBL Returned: Thursday, July 27, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 MIT-OA to 1800 psi AIO 2B.048 Shut down pump and psi went right to 330psi. James B. Regg Digitally signed by James B. Regg Date: 2023.07.31 14:42:22 -08'00' MEMORANDUM TO: Jim Regg 1 / P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector Well Name KUPARUK RIV UNIT 2K-12 Insp Num: mitLOL211020112459 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, October 29, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2K-12 KUPARUK RIV UNIT 2K-12 Src: Inspector Reviewed B P.I. Supry 2 Comm API Well Number 50-103-20109-00-00 Inspector Name: Lou Laubenstein Permit Number: 189-074-0 Inspection Date: 10/20/2021 ✓ Well zK-1z Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Type In—j �✓ "TVD 6013 Tubing zsao 2540 - 2540 ' 2540 - PTD 1890740 - Type Test SPT 'Test psi! 3000 IA - 730 3310 3260 3250 BBL Pumped: 1.5 BBL Returned: 1.5 OA 460 740 780 800 - Interval REQVAR PIF P ✓� Notes: MlT-IA to maximum anticipated injection pressure per AIO 213.048 ' Friday, October 29, 2021 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, October 29, 2021 To: Jim Regg --L—� � P.I. Supervisor IAC � I SUBJECT: Mechanical Integrity Tests ( ConocoPhillips Alaska, Inc. 2K-12 FROM: Lou Laubenstein KUPARUK RIV UNIT 2K-12 Petroleum Inspector Sre: Inspector Reviewed B P.I. Supry %1"r5i27- NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-12 Insp Num: mitLOL211020112712 Rel Insp Num: API Well Number 50-103-20109-00-00 Inspector Name: Lou Laubenstein Permit Number: 189-074-0 Inspection Date: 10/20/2021 - Pretest Initial 15 Min 30 Min 45 Min 60 Min 2540 2540 2540 - 2540 - 750 880 880 880 ' 640 1980 1920 1900 Friday, October 29, 2021 Page I of I Packer Depth Well 2K-12 Type Inj I� w "TVD 6013 Tubing PTD 1890740 IType Testi SPT ,Test psi 1800 '. IA BBL Pumped. 07 BBL Returned: 0.7 OA Interval, REQVAR LP[F P Notes' MIT -OA to 1800 psi per AIO 26.048 Pretest Initial 15 Min 30 Min 45 Min 60 Min 2540 2540 2540 - 2540 - 750 880 880 880 ' 640 1980 1920 1900 Friday, October 29, 2021 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 3Qerq -1/14q DATE: Wednesday, June 26, 2019 1 SUBJECT: Mechanical Integrity Tests P.I. Supervisor (( ConocoPhillips Alaska, Inc. 2K-12 FROM: Lou Laubenstein KUPARUK RIV UNIT 2K-12 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprvjbz— NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-12 API Well Number 50-103-20109-00-00 Inspector Name: Lou Laubenstein Permit Number: 189-074-0 Inspection Date: 6/8/2019 i Insp Num: mitLOL190610171542 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Y 2K -I2 'Type Inj W TVD 6013 Tubing 26 0 _ _osn 20=0 '650 PTD 1890240 -(Type Test srT Test psi 3000 IA IN 3:00 BBL Pumped: L7 ' BBL Returned: 1.6 1 OA 540 e40 eon n60 Interval i REQVAR P/F P r Notes: MIT -IA to maximum anticipated injection pressure per A10 26.048 Wednesday, June 26, 2019 Page 1 of I MEMORANDUM State of Alaska Initial Alaska Oil and Gas Conservation Commission TO.Jim Regg 2�j 9 DATE: Thursday, June 27, 2019 P.I. Supervisor" 7� yl�r SUBJECT: MechanicalIntegrityTests 1 Alaska, ConocoPhillips Alaska, Inc. 550 2K-12 FROM: Lou Laubensteln KUPARUK RIV UNIT 2K-12 Petroleum Inspector 11)W - 1,20 - Sre: Inspector Reviewed By: P.I. Supry �313{— NON-CONFIDENTIAL Comm I Well Name KUPARUK RIV UNIT 2K-12 Insp Num: mitLOL190610171938 Rel Insp Num: API Well Number 50-103-20109-00-00 Inspector Name: Lou Laubenstein Permit Number: 189-074-0 Inspection Date: 6/8/2019 Packer Depth Well 2K-12 Type Inj w TVD 1,01, PTD._ 1800-io - Type Test s1'1 Test psi 1soo BBL Pumped: 0 RBL Returned: o s Interval REQVAR P/F 1' Notes: MIT -OA to 1800 psi per AIO 2B.048 Thursday, June 27, 2019 Page I of I Pretest Initial I5 Min 30 Min 45 Min 60 Min Tubing 1,O 2650 2650 _(oO IA 470 - 550 570 X80 OA 510 2010 11)W - 1,20 - Thursday, June 27, 2019 Page I of I STATE OF AKA OIL AND GAS CONSERVATION COMMSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS DEC 14 2017 1.Operations Abandon 0 Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ •aerations shutdown ❑ Performed: Suspend 1:1 Perforate LI Other Stimulate 0 Alter Casing IDt'Aer gram ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Acid Stimulate 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 189-074 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service 0 6.API Number: 99510 50-103-20109-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 2K-12 ADL 25588 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7,107 feet Plugs measured None feet true vertical 6,517 feet Junk measured None feet Effective Depth measured 6,967 feet Packer measured 6,545 feet true vertical 6,390 feet true vertical 6,013 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 feet 16 " 115' MD 115 SURFACE 2,986 feet 9 5/8" 3,021' MD 2944 PRODUCTION 7,022 feet 7 " 7,055' MD 6470 Perforation depth Measured depth 6686-6692,6736-6748,6764-6796 feet True Vertical depth 6137-6142,6181 -6192,6206-6234 feet Tubing(size,grade,measured and true vertical depth) 3.5" J-55 6,616' MD 6,076'TVD Packers and SSSV(type,measured and true vertical depth) PACKER- BAKER HB PACKER 6,545'MD 6,013'TVD SAFETY VLV-CAMCO TRDP-1A-SSA 1,815'MD 1,815'ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A 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 0 372 476 2622 Subsequent to operation: 0 0 377 570 2563 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 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: 317-142 Contact Name: Jason Burke Authorized Name: Jason Burke Contact Email:jason.burke@cop.com Authorized Title: Staff Wells Engineer �'" Authorized Signatu ��/ Date:/7/J* / / Contact Phone: (907)265-6097 5. =/l.1.----- VTC //z //7 RBD S v/ DEw ' 4 2017 Form 10-404 Revised 4/2017 (� / Submit Original Only • 2K- 12 ACID STIMULATE DTTMST/JOBTY SUMMARYOPS 11/23/17 ACID RIH TO 6847' RKB. CIRCULATE 28 BBL DAD ACID TO END OF COIL. CLOSE CHOKE AND PUMP REMAINDER 76.8 BBL DAD ACID TO FORMATION WHILE MAKING CYCLE PASSES WITH COIL FROM 6800' - 6680'. CHASE DAD ACID WITH 3 BBL WATER AND 32 BBL SLICK DIESEL TO DISPLACE CT WHILE CONTINUING CYCLE PASSES. STOP PUMPING AND POOH. RIG DOWN.. NOTIFY DSO TO 3 KUP • 2K-12 ConocoPhillips $ Well Attrib . Max Angle a MD TD A+dGskc.,)111;,, Wellbore APL/UWI Field Name Wellbore Status ncl(3 MD(ftKB) Act Btm(ftKB) COM0C4hlgips 501032010900 KUPARUK RIVER UNIT INJ 31.48 3,900.00 7,107.0 ,.r., Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) .-Rig Release Date 2K-t2,12x7/20176:28:12 AM SSSV:TRDP Last WO: 40.09 9/10/1989 Verlmal schematic(actual) Annotation Depth(ftKB) End Date Annotation - Last Mod By End Date Last Tag:SLM 6,887.0 8/25/2016 Rev Reason.TAG pproven 8/29/2016 : Casing Strings HANGER;31.1 li- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 H-40 WELDED rii ..Il. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(...Grade Top Thread r SURFACE 95/8 8.921 35.03,021.4 2,9439 36.00 J-55 BTC 1ill Casing Descr ption OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)..WtlLen(I..Grade Top Thread PRODUCTION 7 6.276 33.0 7,054.9 6,469.9 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ibff) Grade Top Connection TUBING 31/2 2.992 31.1 6,616.51 6,075.7 9.30 J-55 EUE8rdABMOD I I r, "`"'Completion Details Nominal ID M CONDUCTOR;36.0-115.0 ;. Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Conn (in) 31.1 31.1 0.13 HANGER FMC TUBING HANGER 3.500 {e. 1,815.0 1,815.0 0.42 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 6,531.2 6,000.5 2827 PBR BAKER PBR 2.850 SAFETY VLV;1,615.0 a 6,544.9 6,012.5 2820 PACKER BAKER HB PACKER 2.892 6,582.1 6,045.4 28.00 NIPPLE OTIS 2.813"XN NIPPLE w/2.75"NO GO 2.750 6,615.8 6,075.1 27.99 SOS BAKER SHEAR OUT SUB 2.992 Perforations&Slots shot Dens GAS LIFT;2,350.3 Top(ND) Btm(ND) (shots) Top(ftKB) Btm(ftKB) (RKB) (ftKB) Zone Date ft) Type Com • 6,686.0 6,692.0 6,137.0 6,142.3 C-4,UNIT B, 6/6/1997 6.0 APERF 60 deg.Phasing 2.5 2K-12 HSD DP 6,736.0 6,748.0 6,181.1 6,191.7 A-5,2K-12 6/6/1997 6.0 APERF 60 deg.Phasing;2.5" HSD DP 6,764.0 6,796.0 6,206.0 6234.5 A-4,2K-12 10/22/1989 2.0 IPERF 180 deg.Phasing g ' Mandrel Inserts SURFACE;35.03,021.6 t,....,.,, St ti § o1 N Top(TVD) Valve Latch Port Size TRO Run GAS LIFT;4,333.3 �. Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,350.3 2,338.3 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/30/1995 it 2 4,333.3 4,083.0 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/30/1995 3 5,763.8 5,330.0 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/30/1995 GAS LIFT;5,763.8 4 6,488.1 5,962.6 CAMCO MMG-2 11/2 GAS LIFT DMY BK 0.000 0.0 7/16/1995 Notes:General&Safety .... End Date Annotation 6/20/2010 NOTE:WAIVERED WELL IA x OA COMMUNICATION 11/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;6,488.1 I FOR 6,531.2 ,- PACKER;6,544.9 NIPPLE 6,582.1 SOS;6,615.8 APERF,6,586.0-6,692.0 APERF;6,736.06,748.0— . — (PERF;8,764.0-6,796.0—. PRODUCTION,33.0-7,054.9 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg / / DATE: Wednesday,June 28,2017 P.I.Supervisor 7 l 1 l i 7 SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 2K-12 FROM: Chuck Scheve KUPARUK RIV UNIT 2K-12 Petroleum Inspector Src: Inspector Reviewed By:e�^ P.I.Supry JJ NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-12 API Well Number 50-103-20109-00-00 Inspector Name: Chuck Scheve Permit Number: 189-074-0 Inspection Date: 6/24/2017 Insp Num: mitCS170625095001 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2K-12 - Type Inj W TVD 6013 Tubing 2750 2750 - 2750 - 2750 - 2750 - PTD i 1890740 Type Test SPT Test psi 3000 IA 915 3510 - 3480 • 3460 - 3450 BBL Pumped: [ 1.5 - BBL Returned: 1.5 OA 840 1120 1150 - 1160 1170 - Interval REQVAR P/F P ✓ Notes: MITIA tested Per AIO 2B.048 .12s1-d (.130/,7 %JOB .#f€ 2 2a017 Wednesday,June 28,2017 Page 1 of 1 • • MEMORANDUM State of Alaska / Alaska Oil and Gas Conservation Commission TO: ` �/�I1 P.I.Jim Regg ( DATE: Wednesday,June 28,2017 , ` PSupervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 2K-12 FROM: Chuck Scheve KUPARUK RIV UNIT 2K-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-12 API Well Number 50-103-20109-00-00 Inspector Name: Chuck Scheve Permit Number: 189-074-0 Inspection Date: 6/24/2017 Insp Num: mitCS170625095403 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2K-12 Type Inj W 'TVD 6013 Tubing 2750 2750 - 2750 " 2750 • PTD 1890740 Type Test PPT Test psi 1800 • IA 850 960 960 - 960 • BBL Pumped: 0.6 BBL Returned: 0.6 • OA 880 2010 - 1950 1940 - Interval REQVAR P/F P Notes: MITOA tested Per AIO 2B.048 T-64 -a q3 (7 SCANNED AUG 2 2017, Wednesday,June 28,2017 Page 1 of 1 . 1.,or T4 • • r \��\Iy7,*4. THE STATE Alaska Oil and Gas to iA1,, LASKA l Conservation Commission ,. 7 � t fta 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Oji". *h Q, Main: 907.279.1433 ALAS4.1.. Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke Wells Engineer SCANNED APR 1 9 2017 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool, KRU 2K-12 Permit to Drill Number: 189-074 Sundry Number: 317-142 Dear Mr. Burke: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC 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. Sincerely, P.2104 ,4-, Cathy P. Foerster Chair DATED this it�of April, 2017. RBDMS L t Ir. 1 2 2017 • STATE OF ALASKA • RECEIVE® ALASKA OIL AND GAS CONSERVATION COMMISSION APR 0 6 2017 APPLICATION FOR SUNDRY APPROVALS A97-_.‘ 4��'j 7 CC 20 AAC 25.280 �� 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑✓ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Acid Stim_❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑ 189-074 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service PO Box 100360,Anchorage AK 99510 50-103-20109–00–00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes CINo ❑✓ f KRU 2K-12 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25588 Kuparuk River Unit/ Kuparuk River Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7107' - 6517' - 6967' ' 6390' - 4227 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 2986' 9-5/8" 3021' 2944' Intermediate Production 7022' 7" 7055' 6470' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6686'-6796' , 6137'-6234' 3.5" J-55 6616' Packers and SSSV Type: CAMCO TRDP-1A-SSA Packers and SSSV MD(ft)and ND(ft): 1815'MD&1815'ND t Baker HB Packer 6545'MD&6012'ND 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service ❑ ‘ 14.Estimated Date for 15.Well Status after proposed work: 4/18/2017 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑✓ ' GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jason Burke Email jason.burke@cop.com Printed Name Jason Burke Title Wells Engineer Signature Phone 907-265-6097 Date rxts. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 17 - 1y2. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ t-k, F 4141 Other: RBDMS (iv it" 122017 Post Initial Injection MIT Req'd? Yes LiNo Spacing Exception Required? Yes ❑ No ©/ Subsequent Form Required: 1 0 — L 6 4- APPROVED BY Approved by: / ,, COMMISSIONER THE COMMISSION Date:,,//,.,.7 r ��7/ R4Gc1aFcAnlivaIid Sub in ormane Form 0-403•evise. 11 AIVI for 12 months from the date of approval. Attachments in m Duplicatean 9 �i"!'?- • • • ConocoPhillips Alaska,Inc. Drilling&Wells ConocoPhillips Well Intervention Alaska 2K-12 DAD Treatment (TBD) Engineer: Jason Burke Wells Engineer 907-231-4568 DAD, dynamic acid dispersion, is an acid outside-phase emulsion prepared and stabilized with dispersing agent F103. The purpose of the dispersion is to simultaneously dissolve acid-soluble minerals and remove oil paraffinic deposits. Target areas can be tubulars, perforations or the critical matrix. Objectives: Spot Dynamic Acid Dispersion (DAD) treatment with CT into perforations to try to restore injectivity • Coiled Tubing: Spot DAD into formation 1. MIRU CT, MU 5 port wash nozzle BHA 2. Begin RIH, circulating at minimum rate until 6800' 3. Begin pumping DAD treatment. When treatment is 5 bbls from exiting the CT (depending on CT volume) shut in the backside choke and begin squeezing into formation. Chase the DAD treatment with produced water or diesel. a. Do not exceed 4500 psi surface pressure 4. As treatment is exiting begin POOH at 4 fpm up to 6680'. 5. RIH at 4 fpm back down to 6800' MD, and then begin POOH at 4 fpm until all the treatment is pumped. 6. After an additional 5 bbl of fluid has been injected behind the treatment POOH 7. RDMO CT. Return well to injection. Function SLB Code Concentration Quantity Acid corrosion inhibitor A264 4 gpt 15 gal HCl H036 221.4 gpt 934 gal Emulsifier F103 15 gpt 63 gal Iron Control L058 20 ppt 76 lbs Non-emulsifier W054 2 gpt 19 gal Xylene A026 100 gpt 420 gal April 5, 2017 2K-12 Well Work Procedure Page 1 of 1 KUP INJ • 2K-12 0 ConocoPhillips i° Well Attributes Max Angle&MD TD Alaska,Inc, Wellbore APIIUWI Field Name Wellbore Slates Incl(") MD(ftKB) Act Btm(ftKB) tixziocoRYeips 501032010900 KUPARUK RIVER UNIT INJ 31.48 3,900.00 7,107.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-12,8/29/20162:33:12 PM SSSV:TRDP Last WO: 40.09 9/10/1989 • Vertical schematic(actual) Annotation Depth(MEI) End Date Annotation Last Mod By End Date Last Tag:SLM 6,887.0 8/25/2016 Rev Reason:TAG pproven 8/29/2016 l:ii`i.. Casing Strings HANGER;31.11 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WI/Len(I...Grade Top Thread-1 CONDUCTOR 16 15.062 36.0 115.0 115.0 -40 WELDED l Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade Top Thread a SURFACE 95/8 8.921 35.0 3,021.4 2,943.9 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 33.0 7,054.9 6,469.9 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(113/t) Grade Top Connection TUBING 31/2 2.992 31.1 6,616.5 6,075.7 9.30 J-55 EUE8rdABMOD ' '' ' ' ' ' I a'"Com pletion Details Nominal ID MA CONDUCTOR;36.0-115.0- Top(ftKB) Top(TVD)(ftKB) Top Incl(") Rem Des Com (in) 31.1 31.1 0.13 HANGER FMC TUBING HANGER 3.500 1,815.0 1,815.0 0.42 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 6,531.2 6,000.5 28.27 PBR BAKER PBR 2.850 6,544.9 6,012.5 28.20 PACKER BAKER HB PACKER 2.892 SAFETY VLV;1,815.0 IIS 6,582.1 6,045.4 28.00 NIPPLE OTIS 2.813"XN NIPPLE w/2.75"NO GO 2.750 I6,615.8 6,075.1 27.99 SOS BAKER SHEAR OUT SUB 2.992 I Perforations&Slots Shot ns GAS LIFT;2,350.311 Top(TVD) Btm(TVD) (shotslf Top(ftKB) Btm(ftKB) (ftKB (ftKB) Zone Date t) Type Com 6,686.0 6,692.0 6,137.0 6,142.3 C-4,UNIT B, 6/6/1997 6.0 APERF 60 deg.Phasing;2.5" 2K-12 HSD DP 6,736.0 6,748.0 6,181.1 6,191.7 A-5,2K-12 6/6/1997 6.0 APERF 60 deg.Phasing;2.5" HSD DP 6,764.0 6,796.0 6,206.0 6,234.5 A-4,2K-12 10/22/1989 2.0 (PERF 180 deg.Phasing Mandrel Inserts SURFACE;35.0-3,0214*. . Stl ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Data Com GAS LIFT;4,333.3 ( 2,350.3 2,338.3 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/30/1995 2 4,333.3 4,083.0 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/30/1995 3 5,763.8 5,330.0 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/30/1995 4 6,488.1 5,962.6 CAMCO MMG-2 1 1/2 GAS LIFT DMY BK 0.000 0.0 7/16/1995 GAS LIFT,5,763.8 Notes:General&Safety End Date Annotation 6/20/2010 NOTE:WAIVERED WELL IA x OA COMMUNICATION ' 11/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;6488.1 PBR;6,5312 IE PACKER;6,544.9 " r i" NIPPLE;6,582.1 "II SOS;6,615.8 iii APERF;6,686.0-6,6920-- APERF;6,736.0-6,748.0-• IPERF;6,764.0-6,796.0--4 PRODUCTION;33.0-7,054.9 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: ; DATE: Friday,September 04,2015 Jim Regg •I`l/l _ P.I.Supervisor " ( j +I5 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-12 FROM: Johnnie Hill KUPARUK RIV UNIT 2K-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ,J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-12 API Well Number 50-103-20109-00-00 Inspector Name: Johnnie Hill Permit Number: 189-074-0 Inspection Date: 8/4/2015 Insp Num: mitJWH150809142641 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 2x-12 Type Inj W-TVD 6013. Tubing 825 825 825 825- PTD I 1890740 Type Test SPT Test psi 3100 - IA 1 3430 - 3430 - 3430 - 3430 - 1 Interval REQVAR PAF P ✓ OA 780 . 780 - 780 780 . Notes: Waiver compliance MITIA per AIO 2B.048 test#3 MITIA to max anticipated inject psi Allowed well to stabilize for 20 min monitored 30 min temp fell back to 120 deg SCAtiNED Friday,September 04,2015 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,August 27,2015 TO: Jim Regg "� P.I.Supervisor ' ep. 61(3//5 SUBJECT: Mechanical Integrity Tests CC CONOCOPHILLIPS ALASKA INC 2K-12 FROM: Johnnie Hill KUPARUK RIV UNIT 2K-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-12API Well Number 50-103-20109-00-00 Inspector Name: Johnnie Hill Permit Number: 189-074-0 Inspection Date: 8/4/2015 Insp Num: mitJWH150827093813 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ----- ------ --- Well 2K-12 - Type Inj W'TVD 6013 j Tubing 825 825 825 825 • 825 PTD 1890740 'Type Test psi,' 3100 IA 380 3360 3310 • 3270 ' 3230 - ' T e Testi Interval REQVAR P/F I OA 530 750 - 750 Iso 750 • Notes: Waiver Compliance MITIA per AIO 2B.048.Test#1 to maximum anticipated injection pressure.Test result inconclusive. �. Thursday,August 27,2015 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,August 26,2015 TO: Jim Regg P.I.Supervisor let q/3 Il SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-12 FROM: Johnnie Hill KUPARUK RIV UNIT 2K-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-12API Well Number 50-103-20109-00-00 Inspector Name: Johnnie Hill Permit Number: 189-074-0 Inspection Date: 8/4/2015 Insp Num: mitJWH150809141233 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2K-12 Type Inj w TVD 6013 - Tubing 825 1 825 825 825 PTD I 1890740 .TypeTest�SPT Test psi 3100 - IA 1 3230 - 3350 • 3340 - 3300 ' Interval REQVAR P/F 1 / OA 750 760 760 i 760 Notes: Waiver compliance MITIA per AIO 2B.048 Test#2 MITIA to max anticipated inject psi ,✓ SItNED Wednesday,August 26,2015 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: ( DATE: Wednesday,August 26,2015 Jim Regg q I I-1/,�,- SUBJECT: Mechanical Integrity Tests P.I.Supervisor I`��'`(((J CONOCOPHILLIPS ALASKA INC 2K-12 FROM: Johnnie Hill KUPARUK RIV UNIT 2K-I2 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-12 API Well Number 50-103-20109-00-00 Inspector Name: Johnnie Hill Permit Number: 189-074-0 Inspection Date: 8/4/2015 Insp Num: mitJWHI50810100948 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2K-12 Type Inj W TVD 6013 Tubing 825 - 825 825 . 825 PTD 1890740 Type Test SPT;Test psi 1800 - IA 330 , 470 - 445 - 412 . Interval REQVAR PAF t P / OA 500 2000 ' 1920 .! 1900 - Notes: Waiver Compliance MITOA per AIO 2B.048 MITOA to 1800 psi ,� Wednesday,August 26,2015 Page 1 of I Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts.- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds [] Other Complete COMMENTS: Scanned by: Beverly Bren (~~athan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: , Is~ NOTScanned.wpd • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 14, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 2K -12 Run Date: 7/9/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K -12 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 5-...1 CD Rom - 50 -103- 20109 -00 Injection Profile Log 1 Color Log 50 -103- 20109 -00 "_:� �; , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 • Fax: 907 - 273 -3535 klinton.wood@halliburton.com CP4 L Si 1 ` Date: _ � Signed: — 0 71 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 28, 2011 TO: Jim Regg ` 6 1( P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K -12 FROM: Chuck Scheve KUPARUK RIV UNIT 2K -12 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2K - 12 API Well Number: 50 103 - 20109 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS110727063644 Permit Number: 189 - 074 - Inspection Date: 7/26/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 2K -12 ' ( Type Inj. W ' TVD 6013 ' IA 1 660 —1 3040 - 3010 - 3010 P.T.DL 1890740 TypeTest SPT Test psi 2800 - OA 500 ' 600 610 610 Interval REQVAR P /I+ P ' Tubing 2475 2475 2475 2475 Notes: MITIA required every two years. A - z E A. P + E`' L0 i Thursday, July 28, 2011 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 28, 2011 TO: Jim Regg J P.I. Supervisor L6l tt SUBJECT: Mechanical Integrity Tests L CONOCOPHILLIPS ALASKA INC 2K -12 FROM: Chuck Scheve KUPARUK RIV UNIT 2K -12 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2K - 12 API Well Number: 50 103 - 20109 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS110727064211 Permit Number: 189 - 074 - Inspection Date: 7/26/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2 - Type Inj. W TVD 6013 - IA 600 750 750 - 750 P.T.D 1890740 "TypeTest SPT Test psi 1 1800 - OA 540 1880 - 1820 1810 , Interval RE P/F P Tubing l 2450 2450 2450 2450 Notes: MITOA required every two years. ZS 04'6 SEF 0 8 ZU Thursday, July 28, 2011 Page 1 of 1 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 9, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 5ridioiNED MAR ti 201 RE: Bottom Hole Pressure Survey: 2K -12 Run Date: 2/8/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K -12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103- 20109 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 I6 1 C2 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 401 rafael.barreto h ' T a= J ^ Date: MAR ' �� = Th � Signed: 6 SEAN PARNELL, GOVERNOR Brent Rogers Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Y,,,r„'ti4 w~A~ ~ ~ ~ .. ~ ~ c~i ~„ P.O. Box 100360 Anchorage, AK 99510-0360 RE: KRU 2K-12 (PTD 1890740) Request for Administrative Approval Kuparuk River Oil Pool Dear Mr. Rogers: In accordance with Rule 9 of Area Injection Order ("AIO") 02B.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby grants ConocoPhillips Alaska Inc. (CPAI)'s request for administrative approval to continue water injection in the subject well. Kuparuk River Unit ("KRU") 2K-12 exhibits inner annulus ("IA") by outer annulus ("OA") communication. Tests confirm communication; however it has not proven possible to positively locate the leak. CPAI does not plan to make to make repairs at this time. The Commission finds that, based upon reported results of CPAI's diagnostic procedures and wellhead pressure trend plots, KRU 2K-12 exhibits 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 KRU 2K-12 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall perform an MITIA every 2 years to the maximum anticipated injection pressure; 4. CPAI shall perform aMIT-OA to 1800 psi every 2 years. 5. CPAI shall limit the well's OA pressure to 1,000 psi; 6. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; ~1t(7 2B{14$ A~i7 ~~r?oli? }'ae 2 of 2 7s Af°ter well shut in due io a change in the well"s mechanical s:ondition; P-f)C'~C°C appro~ai 1 he resluia~d to resRart injection; and ~. "fhe i~IT' anni`re -delta is ~!-ugll~t 8, 20~-9 unless ~.PAI p~erfarms new 1V11Ts when the well is rat to operationd reECO~srorr~T roru .~n® As ~tr~ecr ~ e$.'S 3 !. Q~S.II$~a~, x 6tltiaa 2b dais afar u~rixraaa aao8ics uC 1ras~ eeMirg n~f >~ are dom. ar 3ceclxe Caet6rtr emcee ~ C a~a gaA~d aa. a aifacc+~M by a® asap f!e . tke ~a~eaa'a~occtts ~a ~ mge~~: ar~troe araw'r rrw sit. rCahe arm6i~e m~nigar. araaat tde I ~ r ~ 23 daecs. .4ro !' Farr .ate rasa aiz~ n~;uea:4 ~ :~a cir c~ as 9aeree~ed ~ ~ Krrt¢~rn~,. `nc~ €n ~rl ~ nclarse a}ae apprieaiian diw r ~ ~ ocixik ~ ~ p¢at ~~raua III a g ~ lik~_ Failrme br :~ er v~riQhiw 1I3rs ~ a areaaoar erf'rxcusn5i p+C ~' aienan. dm~. area s~ szr alms aawr dcraaal err ~714~. ! :aa~r Itr apgararod ~+ m 7E~ 5ril~' rfe ! ~tiittn 33 dm~ >~ dare awn °>arfiir2t t°t+armaca raairs, flR ~i ~svs ff a~ ~~nmoisarc+ra tlislrir3ulc~s, 7rae carder or ~ . . a.~:~r.~~ tbs es: try ea +a~bisra r~ appear ~'r1?;a'r be iircd w aabm ~ daps ~ trar date sm w9a~ra ~ applu,~[~rs Cex rialr:aa Eiffel ]C lrae £: - Laaaatc ~ C~ ra:uammit~raruc0. 9r9is atdesr e+s dt:e~ dais lirrsr. Ra9laer. the Qsrakr tX axe r e+rin be the F7~'+t.4L ardct e~ arsrixiora atfi tier (: aa~ a camp ~e ®. 'irrae 9Irt7~3` fl~ tared ~iWrea ~3 dais aal3er ilea date ~ rwirida the Causenaw raaa&~, {)It 3C daxs if irae C aA)>se~is2 d` esrdrr ~r eea re+~ Ag @~r~rickd in AS 3t.1}~.6{b~,'Jrltie ~ reviewed are tea] are liaacerB tQ the Pry cu tree Ccaaarussa b} tree ap~plcffiiaxa tcx res°s~aa~€"sdraa~+a° !aa a yarrikxr rnCtiraae abc~e flee dam ast etae eves ~ defaralt after rrh~b t~ ~~_°~ pe:rratl brr~vas to tetra as eu» ' m r'rr~- rbe last da. azt lrbc perirrd r~ ractc9_ ceok-sa a €ails axt a ~eekerr# car halidar. as sxrtich rara®t arse p~a>v rarxs a~teG ~ #~I p.m. a?n tlx r~e*ca afss trams ttoe Carr axr a wce4ea>'f ~ s4 lraliday. -1`. - - y 4 ~~ ~~ j s }c -i t. -,:cf i~'~o~ .. • ConocoPhiilips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri18, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: ~ R~C~IUEG ASR 1 ~ zoo ~~.~, ConocoPhillips Alaska, Inc. presents the attached proposal per AIO 2B, Rule 9, to apply for Administrative Approval allowing we112K-12 (PTD 189-074) to be online in water only injection service with known IAxOA communication. ConocoPhillips intends to pursue repairs should MI injection be desired in the future. If a successful repair is achieved we will request the well be returned to normal status and resume the ability to inject MI. If you need additional information, please contact myself or Martin Walters at 659-7224, or MJ Loveland / Perry Klein at 659-7043. Sincerely, Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Attachment • ConocoPhillips Alaska, Inc. Kuparuk Well 2K-12 (PTD 189-074) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue injection with known annular communication for Kuparuk injection well 2K-12. Well History and Status Kuparuk River Unit we112K-12 (PTD 189-074) was drilled as a development well in 1989. It was completed in 1989 and was converted to an injection well in 1991. 2K-12 was originally reported to the Commission on March 22, 2010 as showing signs of IAxOA communication. Recent tests and surveys performed are as follows: Date Test Result Comment 03/19/10 MITIA Passed 03/19/10 MITOA Passed ConocoPhillips intends to pursue repair of the leak when it can be justified. ConocoPhillips requests an AA which will allow the OA to equalize with the IA in water only injection at a pressure not to exceed 1000 psi. Well Integrity Supervisor 4/8/2010 Barrier and Hazard Evaluation r~ u Tubing: The 3.5" 9.3# J-55 tubing has integrity to the packer @ 6545' MD based on a passing MITIA as outlined above. Production casing: The 7" 26# J-55 (internal yield of 4980 psi) production casing has integrity to the packer @ 6545' MD based upon a passing MITIA as outlined above. However minor communication with the OA exists over a longer period of time. Surface casing: The 9-5/8" 36# J-55 (internal yield of 3520 psi) surface casing set at 3021' MD has integrity based upon passing MITOA as outlined above. Primary barrier: The production tubing is the primary barrier. Second barrier: The production casing is the secondary barrier. Third barrier: The surface casing and cement shoe will act as a third barrier should the tubing fail and a catastrophic failure of the production casing. Monitoring: Each well is monitored daily for wellhead pressure changes. Should any additional communication develop, it will be noted during the daily monitoring process and appropriate corrective action, up to and including ashut-in of the well. T/UO plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed), IA pressure may equalize with injection pressure; 2. Perform a passing MITT or MITIA every 2-years as per AOGCC criteria (0.25 x TVD @ packer, 1500 psi minimum); 3. Perform a passing MIT-OA to 1800 psi every 2 years; 4. IA & OA pressure not to exceed 1000 psi. 5. Submit monthly reports of daily tubing & IA pressures and injection volumes; 6. Shut-in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. Well Integrity Supervisor 4/8/2010 2 ~`~ ~ KUP • 2K-12 111 1~0~~~l~pS x Well Attributes Max An le & MD TD . A7 I~h,v It I _ Wellbore APIIUWI Field Name Well S[atus Prod/l nj Type Incl (°) MD (ttKB) 501032010900 KUPARUK RIVER UNIT INJ MI 31.48 3,900 Act Btm (RKB) 7,107 -~- -~ Comment H2S (ppm) SSSV. TRDP Date Annotation End Date Last WO: KBGrd (tt) 40.09 Rig Release Date 9/1011989 .'+M Wall ConM1 ~ 2K-12 2/620as '__<'_ 3~ Scnematk-ACluai - Annotation Depth (ttKBI End Date A nnotation Entl Date Last Tag: SLM 6,907 24/2009 Rev Reason: DRIFT 8 TAG 2/5/2009 Casin Strin s Casing Description String OD lint String ID Ilnl Top (ttKO) Set Deplh (RKB) Set Depth (ND) (RKB) String Wt (IbsRl) String Grade String Top Thrd CONDUCTOR 16 15.062 0 115 115.0 H-00 coNDUCroR, SURFACE 9518 8.765 0 3,021 2,943.5 J-55 11s PRODUCTION 7 6.151 0 7,050 6,465.4 J-55 Tubin Strin s _ Tubing Description String OD (in) String ID linj Top (RKB) Set Depth (RKB) Set Depth (ND) (RKB) String Wt (IbsHt) String Grade Strin Top Thrd sAfETV vLV, 1,815 TUBING 3 1/2 2.992 0 6,617 6,076 J-55 8RD AB-MOD Other In Hole All Jewel :Tubin Run 8 Retrievable, Fish etc. Top (RKB) Top Depth (ND) (RKB) Top Incl (^) Description Comment Run Date ID (in) 1,815 1,815,0 -0.11 SAFETY VLV Camco TRDP-IA-SSA 1024/1989 2.812 GAS LIFT, 2as9 2,350 2,337.9 19.00 GAS LIFT MERLA/TMPD/1/DMY/BK/// Comment: STA 1 4/30/1995 2.875 4,333 4,082.4 29.42 GAS LIFT MERLAJTMPD/1/DMY/BK/// Comment: STA 2 4/30/1995 2.875 5,764 5,330.1 28.14 GAS LIFT MERLAlfMPD/1/DMYBW// CommenC STA 3 4/30/1995 2.875 suRFACE 6.488 5,962.5 28.60 GAS LIFT CAMCO/MMG-2/1.5/DMY/RK///Comment: STA 4 7/16/1995 2.920 , 3 oat 6,531 6,000.0 27.56 PBR Baker PBR 10124/1989 3.000 6,545 6,012.4 27.63 PACKER Baker'HB' PACKER 1024/1989 2.890 6,582 6,045.2 27.82 NIPPLE Otis'XN' Nipple NO GO 10/24/1989 2.750 GAS LIFT, 6,616 6,075.3 27.99 SOS Baker 10/24/1989 2.992 9,333 6,617 6,076.2 28.00 TTL 10/24/1989 2.992 Perforations Tap (ttNB) Btm (ttKB) Top (ND) (RKB) Btm (TVD) (RKB) Lone Date Shot Dens (sh... Type Comment cns uFT, s,]6A 6,686 6692 6.137.0 6,142.3 C 2 -0, UNIT B, K-12 6/6/1997 6.0 APERF 60 deg. Phasing; 25" HSD DP 6,736 6,748 6,181.5 6,192.0 A -5, 2K-12 6/6/1997 6.0 APERF 60 deg. Phasing; 2.5"HSD DP 6,764 6,796 6,206.1 6,234.5 A -0, 2K-12 10/2211989 2.0 IPERF 180 deg. Phasing GAS LIfT, 6,688 P6R, 6 531 L PACKER. fi.695 "t P E 6 582 NI PL . , SOS 6 616 ~ . . TTL, 6.61] APERF, 6.686fi 692 APERF, 6,)36fi,]46 IPERF, 6.%646,]96 PRODUCTION. 7,050 TD, 7,10] II Name 2K-12 i Date 5/1/2010 rs 365 rt Date 5/1/2009 3000 2500 2000 .Q 1500 vz-m1- 100 psi Annular Communication Surveillance 140 120 100 80 LL. t~ d '~ 60 1000 500 0 a J m LL U f 40 20 0 0 May-09 Jun-09 Jul-09 Aug-09 Sep-09 Oct-09 Nov-09 Dec-09 Jan-10 Feb-10 Mar-10 Apr-10 May-09 Jun-09 Jul-09 Aug-09 Sep-09 Oct-09 Nov-09 Dec-09 Jan-10 Feb-10 Mar-10 Apr-10 Date Page 1 of 1 Regg, James B (DOA) ~ S~ ~ ~~ ~ .~ ~,~~ ~....~ ~.~~~~_~m~ ~e.~ e,~~,M,n.~....~ .~ ~..~ From: NSK Problem Well Supv [n1617@conocophillips.com] ~~~ ~~ ~~~" Sent: Monday, March 22, 2010 5:40 AM l To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 2K-12(PTD 198-074) Report of suspect IAxOA communication Attachments: 2K-12 schematic.pdf; MIT KRU 2K-12 03-19-10.x1s __.---.. Tom, Jim, Guy Kuparuk injector 2K-12 (PTD 189-074) has suspected IAxOA communication due to annulus pressure trends. The well passed a diagnostic MITIA and an MITOA (see a ace orm , owever over a longer period of time the IA and OA appear to communicate. It has been added to the monthly report. It is ConocoPhillips intention to leave the well on injection and an AA for water injection only will be submitted. Attached is a 90 day TIO plot and a schematic. .,- Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 ~- ~, h , Pager (907) 659-7000 pgr. 909 r `~~l~ti~ ~~ ~~'~ `= 4` ~ ~i ~~`' 3/23/2010 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: ConocoPhillips Alaska Inc. FIELD /UNIT /PAD: Kuparuk /KRU / 2K DATE: 03/19/10 OPERATOR REP: Colee /Phillips - AES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 2K-12 ,~ Type Inj. W TVD 6,012' Tubing 3,325 3,350 3,350 3,350 Interval O P.T.D. 1890740 Type test P Test psi ! 1503 Casing 700 X3,000 2,980 '2,975 P/F P Notes: Diagnostic MITIA OA 670 710 710 710 Well 2K-12 T pe Inj. W TVD 6,012' Tubing 3,350 3,350 3,350 3,350 Interval O P.T.D. 1890740 Type test P Test psi 1503 Casing 700 750 790 800 P/F P Notes: Diagnostic MITOA / OA 670 '` 1800. 1760 ~ 1750 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. T pe 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 0 =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2K-12 03-19-10.x1s KRU 2K-12 PTD 3/22/2010 Ti0 Pressures 3000. 200. 3000. 3000. 3000. SC 3000 2700 200 2100 1800 f7 0. 0. 0. 0. 0. 0. 1500 1200 900 600 300 0 PLOT START TIME MINOR TIME 21-DEC-09 16:56 MAJOR TIME WEER TAG NANE WL2R-12-CHORE SCRATCH 67 SCRATCH_67 SCRATCH_67 SCRATCH_67 DESCRIPTION FLOW TUBING CHORE FLOW TUBING PRESSURE FLOW TUBING TEMP INNER ANNULUS f' OUTER ANNULUS PRES PICK Tlxt. 20-MAR-10 00:30:.95 ~'-a 1 '~~ NEST 777777? 77a7??? 77???77 ????777 ??????? 7777777 7777777 +02160:00:00 HRS 21-MAR-10 16:56 • WELL NAM' WLRRU2R-12 ~fi"" -'~ ~ KUP • 2K-12 COtIOCO~F'Ii~~i~5 / T Well Attributes _ ___ IMax Angle 8 MD TD Wellbore APllUWI F ield Name Well Stat s Frod/In(Type Incl (°) MD (ttK6) Act Btm (RKB) ' ! 501032010900 KUPARUK RIVER UNIT INJ MI 31.48 3,900 7,107 "' i Eomment H2S (ppm) Date Annotation Entl Date KBl•rd (R) Rig Release Date Wen Confip' ~ - ' ~ ~~ AM ' SSSV; TRDP - Last WO: 40.09 9/10/1989 . .. . _ _ _ 5cnemanc-Acmai - . Annotation De pth (RKB) End Date gnnotation End Date Last Taq. SLM 6,907 2/42009 Rev Reason: DRIFT & TAG 2/5/2009 CasingString s _ ~ Strang O D String ID Set Depth Set Depth (TVD) String VY[ String N I ~, ~ ~ Gsing Description (IN Iinl Top (RKB) (RKB) (RKB) (Ibattt) Orade gtring TOp Thrd I $ ~ CONDUCTOR 1 6 15.062 0 115 ~ 115.0 H-40 CONDUCTOR, ~ ~ SURFACE 9 5/ 8 8.765 0 3,021 2,943.5 J-55 115 r-. PRODUCTION 151 7 6 0 7 050 485.4 6 J 55 o- j . , , 1 Tubin Strings ~... ~ String OD Suing ID _ -- i Sef Depth Set Depth (TVD) I String Wt Strang Tubing Description (in) (in) 7o (kK6) ~- (RKB) (ft KBI (IbsHt) Gratle String Top Thrd -- - SAFETY VLV, 1,a15 O~ TUBING 31/2 2.992 J-55 SRD AB-MOD 0, 6,617 6,076'. z Other In Hole All Jewelry: Tubin -- Run 8 Retrievable,_ Fish, etc.) ' Top Depth (ND) Top Incl ~ Top (RKB) (RKB) (^) Description Comment Run Date ID (In) ~ -' 1,815 1,815.0 -4.11 S AFETY VLV Camco TRDP-tA-SSA 10/24/1989 2.812 GASZ 3 0 ` ~ ~~ 2,350 2,337.9 19.00 G AS LIFT MERLAliMPD/1/DMY/BK///Comment: STA 1 4/30/1995 2.875 ~:,.; _. :-• 4,333 4,082.4 29.42 G AS LIFT MERLA/iMPO/1/DMYBK///Comment: STA 2 4/30/1995 2.875 g ~ 5,784 5,330.1 28.14 G AS LIFT MERLA/iMPD/1/DMY/BW//Comment: STA3 4/30/1995 2.875 suRF 6,488 5,962.5 28.60 G AS LIFT CAMCO/MMG-2/1.5/DMY/RK///Comment: STA 4 7/16/1995 2.920 aoz1' * 6,531 6,000.0 27.56 P BR Baker PBR 10/24/1989 3.000 6,545 6,012.4 27.63 P ACKER Baker'HB' PACKER 10/24/1989 2.890 _ _ ~ ~ 6,582 6.0452 27.82 N IPPLE Otis'XN' Nipple NO GO 10/24/1989 2.750 GAS LIFT, I 6,616 6,075.3 27.99 S OS Baker 1024/1989 2.992 4,333 ~ " C 6,617 6,076.2 28.00 TTL 1024/1989 2.992 -~• ---- -- ---- j Perforations _ _-__ Shot Top (ND) Btm (ND) Dens t Top (RKB) Btm (RKB ) (RKB) (RKB) Zone Date (sh"' Type Comment cns LIFT, ~ 686 6 69 6 2 6,137.0 6,142.3 C -4, UNIT B, 6/6/1997 6.0 APERF 60 deg. Phasing; 2.5" HSO DP 5,764 ~ ' , , 2 K-12 I 6,736 6,74 8 6,181.5 6,192.0 A -5, 2K-12 6/6/1997 6.0 APERF 60 deg. Phasing; 2.5" HSD OP ~ ~ 6,764 6,79 6 6,206.1 6,234.5 A -4, 2K-12 10/22/1989 2.0 IPERF 180 deg. Phasing GAS LIFT, 6,486 I I i L.: PBR, 6,531 i ) t'. , t l FF :.. ..1 •.. PACKER, 6,545 LL,,~ 3. NIPPLE. 6,582 i SOS, 6,616 I TTL, 6,617 I APERF, I 6,686-6.692 APERF, . 6.736-6,748 IPERF, . 6.764b,796 PRODUCTION, 7,050 TD. 7.107 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg 0 I ! P.I. Supervisor f;t1 b b 07 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-12 KUPARUK RIV UNIT 2K-12 Src: Inspector ~<\' 014- \ Reviewed By: P.I. Suprv ~ Comm FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2K-12 API Well Number: 50-103-20109-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070601 181 136 Permit Number: 189-074-0 Inspection Date: 6/1/2007 ./ Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K-12 Type Inj. w TVD 6013 IA 900 2320 2320 2320 I I P.T.D 1890740 TypeTest SPT Test psi 1503.25 OA 320 410 410 410 I I Interval 4YRTST P/F P /' Tubing 2500 2500 2500 2500 I I Notes: Pretest pressures were observed and found stable. Wen demonstrated good mechanical integrity. ./' SCANNED JUN 2 0 2007 Wednesday, June 06,2007 Page I of I ') ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reggï).d e¡lr,?J--- P.I. Supervisor' \t.fl í" -1 ò S> DATE: Wednesday, August 17,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-12 KUPARUK RIV UNIT 2K-12 ~b\' \cf..' 0 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv,..5tf'- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2K-12 Insp Num: mitCS050812191720 Rei Insp N urn: API Well Number: 50-103-20109-00-00 Permit Number: 189-074-0 Inspector Name: Chuck Scheve Inspection Date: 81l2/200S Packer Depth Pretest Initial ;;~I j-,~:~~:A~~::~~*~ ~:;PSi ~-- ¿:::s" ~~~r ::: ~E ___'___'-L-''_._''---L::_'_.__'___~__~,____,J_, . I -. - -+- ,IntervaJ 4YR!.S!_J~/F ___. p 1'.~bin~_L__~"j 2300 Notes: Pretest pressures observed for 30+ minutes and found stable. 15 Min. 30 Min. 45 Min. 60 Min. ,.T'-"'185.~_,_l.-1_~~,·--· i _ .,,__j-'~=--=---= i 460 I 460 I i __ L 23Õ~__J--- 2~_~.~,._L=-"nj~-=-~= ~',' " r,'," J'J.. :~ H,,- 11 'L f\ S, ED?: -:: f) r!Y¡:: "~\!,..JI,I, '1J!,'\~~~If.:., ,,' "I ,i /, ."' f..\J \..;.1 Wednesday, August 17,2005 Page 1 of 1 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24 2000 P M C:LORIhMFILM.IX~ E E L E W ATE R IA L U N D E TH IS M A.R K ER R STATE OF ALASKA A~L OIL AND GAS CONSERVATION COMMIS I ~ N REPORT OF SUNDRY WELL OPERATIONS ins Performed: Operation Shutdown _ Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development asks Inc. Exploratory RKB 154 fee _ _ Stratigraphic _ 7. Unit or Property name 100360, Anchorage, AK 99510 Service X Kuparuk River Unit of well at surface 8. Well number 94' FEL, Sec. 2, T10N, R8E, UM 2K-12 ~f productive interval 9. Permit number/approval number 1247' FNL, 1675' FWL, Sec. 12, T10N, R8E, UM 89-74 At effective depth 10. API number 1316' FNL, 1776' FWL, Sec. 12, T10N, R8E, UM 50-103-20109-00 At total depth 11. Field/Pool 1348' FNL, 1824' FWL, Sec. 12, T10N, R8E, UM Ku aruk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 7107 feet Plugs (measured) None true vertical 6517 feet Effective depth: measured 6967 feet Junk (measured) None true vertical 6390 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 16" Unknown 115' 115' Surface 2986' 9-5/8" 900 Sx AS III & 3021' 2944' Intermediate 375 Sx ClaSS G Production 7021' 7" 250 Sx Class G 7 0 51 ' 6 4 6 6' Liner Perforation depth: measured 6686'-6692', 6736'-6748', 6764'-6796' true vertical 6137'-6142', 6181'-6192', 6206'-6234' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 C~ 6616' Packers and SSSV (type and measured depth) Packer: Baker HB C«~ 6545' ;SSSV: Camco TRDP-1 A-SSA C~ 1815' 13. Stimulation or cement squeeze summary Perforate well on 6/6/97. Intervals treated (measured) 6686'-6692', 6736'-6748' Treatment description including volumes used and final pressure Perforated usin HSD char es w/ DP char es, 6 SPF, 60° hasin , f was 2700 si. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 1001 1790 2714 Subse uent to o eration 0 0 1699 1800 2692 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations X Oil Gas Suspended _ Service X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. si ned Title Wells Su erintendent Date Form 1 -404' Re~/06T15II~8' SUBMIT IN DUPLICATE ARCO Alaska, Inc. /\ \/ KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2K-12(W4-6)) WELL JOB SCOPE JOB NUMBER 2K-12 PERFORATE, PERF SUPPORT 0603971336.1 DATE DAILY WORK UNIT NUMBER 06/06/97 PERFORATE 8337 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 • Yes No • Yes No SWS-BAILEY BLACK FIELD AFC# CC# DAILY COST ACCUM COST ESTIMATE KAWWRK 230DS28KL $9,257 $10,684 Initial Tbq Press Final Tbq Press Initial Inner Ann Final Inner Ann Initial Outer Ann Final Outer Ann 2700 PSI 2700 PSI 2800 PSI 2600 PSI 400 PSI 300 PSI DAILY SUMMARY PERFORATE FROM 6686 TO 6692' AND FROM 6736' TO 6748' WITH 2112" HSD DP ~ 6 SPF & 60 DEG PHASED. TIME LOG ENTRY 12:30 MIRU SWS # 8337 W/ BAILEY-LEVY-LISTER 13:30 FINISH R/U. P!T TO 3500 PSI 14:00 RIH W/ 2.5" HSD/CCL. TIED IN TO HLS CBL DATED 9/24/89. 15:00 LOG INTO POSITION & PERFORATE F/ 6736 - 6748' ELM W/ 2.5" HSD ~ 6 SPF & 60 DEG PHASED. 15:15 POOH. HAD DIFFICULTY GETTING THROUGH SSSV. HAD TO PUMP SSSV PRESSURE UP TO 5000 PSI. 16:00 OOH. R/D GUN #1 ARM AND RIH W/GUN #2 SAME AS ABOVE . 18:00 LOG INTO POSITION & PERFORATE F/ 6686 - 6692' ELM W/ SAME GUNS AS ABOVE. 18:15 POOH 19:00 OOH. START RlD. 20:00 FINISH R/D. MOVE OVER TO 2K-24 F/ AM WORK. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $42.00 APC $250.00 $250.00 HALLIBURTON $0.00 $635.00 LITTLE RED $0.00 $750.00 SCHLUMBERGER $9,007.00 $9,007.00 TOTAL FIELD ESTIMATE $9,257.00 $10,684.00 STATE OFALASKA ~-~ 0 R I GIN A ALA,~r~ OIL AND GAS CONSERVATION COMMI~.x.'>ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter Stimulate m Plugging Perforate _ casing Repair well Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 21' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval t247' FNL, 1675' FWL, Sec. 12, T10N, R8E, UM At effective depth 1267' FNL, 1534' FWL, Sec. 1, T10N, R8E, UM At total depth 1348' FNL, 1824' FWL, Sec. 12, T10N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7107' 6517' feet feet Plugs (measured) None 6. Datum elevation (DF or KB) 154' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2K-12 19'-~ 8 S- 74Permit n u r~;~/a p.~r~.~a I.. I10. APl number 50-103-201 09 11. Field/Pool Kuparuk River Oil Pool number Effective depth: measured 6 9 6 7' true vertical 6390' feet feet Junk (measured) None Casing Length Structural Conductor 1 1 5' Surface 3 021 ' Intermediate Production 7 0 5 1 ' Liner Perforation depth: measured 6764'-6796' true vertical 6206'-6234' Size 16" 9 5/8" 7" Cemented 900 Sx AS III & 375 Sx Class G 250 Sx Class G Measured depth 115' 3021 ' 7051' 4.5" Ultrapal @ 2 SPF Tubing (size, grade, and measured depth) 3.5" J-55 set at 6616' Packers and SSSV (type and measured depth) Brown HB @ 6545', Camco TRDP-1A-SSA @ 1815' 13. Stimulation or cement squeeze summary True vertical depth 115' 2944' 6466' RECEIVED JUN 1 4 99I Alaska Oil & ~,~ fJ'~'no, Cu.imissJon Anchorage Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 580 1800 0 - 1300 295 Subsequent to operation - 0 - - 0 - 2000 1 000 21 00 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector ~ Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned " Title ~I. ;~/'[. Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, Subsidiary of Atlantic Richfield Com~. WELL SERVICE REPORT WELL - "~NTRACTOR REMARKS FIELD - DISTRICT- STATE /d~ p~,, . /¢ DAYS DATE / ~-/,,,,.~/ OPERATION AT REPORT TIME Iq :~9 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE Of ALASKA .? A~ OIL AND GAS CONSERVATION COMMb~,.,,ON _1 ¢'~'~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended we~ _ ' Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ARCO Alaska. Inc. Exploratory _ RKB 154 feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 21' FSL, 94' FEL, SEC 2, T10N, R8E, UM 2K-12 At top of productive interval 9. Permit number 1247' FNL, 1675' FWL, SEC 12, T10N, R8E, UM 88-74 At effective depth 10. APl number 1267' FNL, 1534' FWL, Sec.1, T10N, R8E, UM so-103-20109 At total depth 11. Field/Pool Kuparuk River Field 1348' FNL, 1824' FWL, Sec. 12, T10N, R8E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 7,1 0 7 feet Plugs (measured) true vertical 6,51 7 feet None Effective depth: measured 6,967 feet Junk (measured) true vertical 6,3 9 0 feet None Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 1 5' 1 6" 115' 115' Surface 3,021' 9 5/8" 900 Sx AS III & 3,021' 2,944' Intermediate 375 Sx Class G Production 7.051' 7" 250 Sx Class G 7,051' 6,4 6 6' Liner Perforation depth: measured 6,764'-6,796' MD w/ 4.5" 43C ULTRA @2 SPF true vertical 6,206'-6,234' Tubing (size, grade, and measured depth) 3.5" J-55 set at 6,616' Packers and SSSV (type and measured depth) Brown HB ~ 6~545'~ Camco TRDP-1A-SSA ~ 1~815' 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch _ Convert well from oil producer to water injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: March 1~)~1 Oil __ Gas ~ Suspended _ 16. I, p~p~o,sal~.~.was v~bally ap~[oved .~" 2 ~ "~ / Nar~'~:~rover~,~,,~"[ ~ 5,~ Date approved Service Water In!.ector 17. I here~certify,tha~theLForegoing is true and correct to the best of my knowledge. Sic~ned " - Title ;¢~¢., FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApprov_al, No./ Plug integrity __ BOP Test_ Location clearance __ Mechanical Integrity Test~/ Subsequent form require 10- ORIGINAL SIGNED BY Approved by order of the Commission l nNNIE C. SMITH Commissioner Date Form 10-403 Rev 09/12/90 SUBMIT IN TRIPLICATE ARCO Alaska, In= Date: Subject: From/Location: Telephone: To/Location: Internal Correap ~nce March 11, 1991 File Code: Well File: · Kuparuk Drill Site 2K Waterflood Convesions Wells 2K-05 and 2K-12 Eric Paerels ATO-1178 263-4339 R. Smith / J. Kralick NSK D. Miller / J. Blackwelder NSK 2K-05 2K-12 As we discussed, this writing includes a brief procedure outlining the well work for waterflood conversions of Wells 2K-05 and 2K-12. These two wells have been recommended for conversion by G. Targa¢ and K. Copeland in a memo dated 2-6-91 to J.Kralick and R. Sloan, These two conversions are in addition to the four wells that are presently being converted. Pressure Build-up (PBU) tests indicate that reservoir pressures in several areas of the drill site may have fallen below the bubble point. This pressure depletion can have a negative effect on the recoverable reserves of this drill site, The conversion of these two wells is of prime importance to maintaining the drill site reservoir pressure above the bubble point, Waterflood at Drill Site 2K should recover an incremental 20% of OOIP, or 24 MMBBL of oil. The estimated initial water injection rate is 3500 BWPD per injection well. This rate should fall off after several weeks of injection as the reservoir pressure increases and a water bank is established, All wireline and diesel costs should be charged to the old 1990 Downhole Work Waterflood AFE number 899381, All Manifold building work should be charged to the old 1990 Facility Waterflood AFE number 899399, New 1991 Waterflood AFE charge codes will be available in the near future, If you have any questions comments, please contact me at the above number or call Letha Chapman at 265-1355, Operations Engineer Attachments J. R. Brandstetter M. E. Eck G. K. Phillips S. M. Renke C. Victors / B. Fontenot/J. Kralick B. Sossamon / W. Carter C. House / A. Ealum CPF-2 Engineers ATO-1120 ATO-11 ATO-I~ ~N~~__~.~,~l'd t0 NSK w/o attachments ~l/$1q/ By ~ N:iCO Alaska Inc. is a sueaklia~/d Atlan~ Ri~I~I ~ Wells 2K-05 and 2K-12 Water Injection Conversions CC: Downhole 899381 Surface 899399 3/1 1/91 The following is intended only as an outline, existing well conditions will dictate the exact procedure. 1 ) Obtain final 12 hour welltest. 2 ) SI well and MIRU Slickline and diesel pump truck. 3 ) RIH and set SV in "XN" nipple. Wells 2K-05 and 2K-12 are currently on gas lift. 4 ) Pump diesel down casing while taking returns from tubing. Fill annulus with diesel. Casing displacement to bottom mandrel and mandrel depth are listed below: 2 K- 0 5 192 bbls 7275' MD-RKB 2 K- 1 2 172 bbls 6488' MD-RKB 5 ) RIH to replace all GLV's with DV's. Ensure annulus is filled with diesel. 6 ) Pressure test tubing to 2500 psi to ensure DV's are set, 7 ) RIH and pull SV. 8 ) RDMO Slickline. Notify the State of the upcoming Mechanical Integrity Tests(MIT's) 9 ) Conduct MIT tests. Packer depths and 7" annular pressures necessary are shown below. Bleed the annulus to 500 psi after completing the test. 'I'VD Deplh Required Casing Well .QJ.E.a~ka[ Pressure for MIT 2K-05 5945' 2170 PSI 2K-12 6013' 2195 PSI 1 0 ) Prior to initiating water injection, a diesel/xylene spear should be injected to clean up. the perforations. Pump 50 bbls of diesel with 10% xylene at 2 BPM. Initiate water injection at approximately 500 BWPD and gradually increase the injection rate until the maximum injection pressure is reached. WELL 2K-12 PRODUCER AP! # 501032010900 SURFACE LOCATION: 21' FSL, 94' FEL, SEC 2, T10N, R8E, UM TOP KUPARUK: 1251' FNL, 1680' FWL, SEC 12, T10N, R8E, UM DEPTHS: REFERENCED TO (7 RKB TUBING SPOOL ELEV: 31' RKB ALL DEPTHS MD-RKB 16": 62.5# H-40 @ 115' 9 5/8": 36# J-55 @ 3021' TREE: FMC GEN IV 5000 PSI BAKER PBR: 3.000" ID @ 6531' BROWN HB PKR: 2.892" ID @ 6545' OTIS 'XN' NIPPLE: 2.75" X 2.813" ID @ 6582' SHEAR OUT: 3.000" ID @ 6615' L ~. GLMI' GLM2: GLM3: GLM4: SPUD: 9/2/89 COMPLETION: 10/24/89 SSSV · CAMCO TRDP-1A-SSA ID 2.812" @ 1815' 2350' / 1.0" TMPD/GLV 4333' / 1.0" TMPD/GLV 5764' / 1.0" TMPD/GLV 6488' / 1.5" MMG-2/GLV 3.5" 9.3# J-55 EUE ABMOD IPC TUBING TAIL @ 6616' C A5 A4 A3 7": 26# J-55 @ 7050' PBTD: 6967' HOLE ANGLE ACROSS KUPARUK = 27 DEGREES MAX HOLE ANGLE = 31 DEGREES @ 3900' VOLUME TO TOP PERF = 63 BBLS 6764' 2 SPF~180° PHASING ORIENTED 128°CCW 6796' FILL TAGGED AT ????' REVISION: 3/12/91 /ELL 2K-05 PRODUCER APl # 501032009800 SURFACE LOCATION: 196' FSL, 94' FEL, SEC 2, T10N, R8E, UM TOP KUPARUK: 1467" FNL, 1432' FWL, SEC 1, T10N, R8E, UM DEPTHS: REFERENCED TO (7 RKB TUBING SPOOL ELEV: 31' RKB ALL DEPTHS MD-RKB 16": 62.5# H-40 @ 115' 9 5/8": 36# J-55 @ 4103' TREE: FMC GEN IV 5000 PSI J BAKER PBR: 3.000" ID @ 7318' BROWN HB PKR: 2.892" ID @ 7332' OTIS 'XN' NIPPLE: 2.75" X 2.813" ID @ 7370' SHEAR OUT: 3.000" ID @ 7404' 7": B ii @ 7906' A4 A3 26# J-55 L PBTD: 7824' SPUD: 8/1/89 COMPLETION' 10/30/89 SSSV · CAMCO TRDP-1A-SSA ID 2.812" @ 1808' GLM1: GLM2: GLM3: GLM4: 2631' / 1.0" TMPD/GLV 4956' / 1.0" TMPD/GLV 6518' / 1.0" TMPD/GLV 7275' / 1.5" MMG-2 /GLV 3.5" 9.3# J-55 EUE ABMOD IPC TUBING TAIL @ 7405' HOLE ANGM~ ACROSS KUPARUK = 32 DEGREES MAX HOLE ANGLE = 44 DEGREES @ 2800' VOLUME TO TOP PERF = 70 BBLS 7562' 4 SPF(4)90° PHASING ORIENTED35°CCW 7598' FILL TAGGED AT ????' REVISION: 3/12/91 October 12, 1989 Mr. Brit Brown Drilling Manager ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 MICROFILMED Re: Boss Gyroscopic Survey Job No. AK-BO-90109 Well: 2K-12 Field: Kuparuk Survey Date: 9/24/89 Operator: T. McGuire Mr. Brown: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Also enclosed is one diskette. As per A. Thompson, copies have been sent to UNOCAL and BP EXPL. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard District Manager Directional Services Enclosures 8537 Corbin Drive (99507) · P.O. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company ' "" ' STATE OF ALASKA ~'~'"x 0 I~ 16 ~ /~/1 %i ELL ALASKA ~,,IL AND GAS CONSERVATION COpY,-MISSION COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~. GAS ,ri SUSPENDED ~ ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 89-74 3. Address 8. APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50- 103-20109 4. Location of well at surface 9. Unit or Lease Name 21' FSL & 94' FEL, Sec. 2,. TION, R8E, UN ~ Kuparuk River Unit I LOCATIONS At Top Producing Interval VEF,/FIED 10. Well Number 1247' FNL, 1675' FWL, Sec. 12, TION, R8E, UM .~ 2K-12 Sur At Total Depth B.H.%,~ /h 11. Field and Pool 1348' FNL, 1824' FWL, Sec. 12, T10N, R8E, UM " ,- Kuparuk River/ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 154' RKB ADL:25588 ALK:2674 Kuparuk Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ! 15. Water Depth, if offshore 16. No. of Completions 09/02/89 9/07/89 10/24/89I --- feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7107'mctL'& 6517' t%'d 6967'md 6390,tv(]YESL_W~-~ NOIr,J 1815' feetMD --- 22. Type Electric or Other Logs Run DIL/SP/GR/SFL, FDC/CNL/CAL, CET, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" Surf 115' -- 9-5/8" 36# J-55 Surf 3021' 12-1/4" 900 sx AS III & .~75 .~x £1 7" 26# J-55 Surf 7051' 8-~" 250 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6764'-6796' MD w/4½" 43C Ultra ~ 2 spf 3½",9.3#,J-55 6616' 6545' 6206' -6234 ' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETc. ' ' ' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAS-OILRATIO TEST PERIOD I~ , Flow Tubing Casing Pressure CALCULATED,~ 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. RECEIVED WC1/24 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. NAME Kuparuk C Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 6686' 6723' TRUE VERT. DEPTH 6137' 6169' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. None 31. LIS-[' OF ATTACHMENTS Gyro 32. I hereby certify that the foregoing is true and correct tO the best of my knowledge Area Drilling Engr. 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. ~tem 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- lng 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 10407 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover opera[ions are started Daily work prior to spudding shou!d ~e summer;zed on the form givin<3 inclusive dates only. District ARCO ALASKA INC. KUPARUK RIVER UNIT ICounty, parish or borough ALASKA/NORTH SLOPE Lease or Unit ADL: 25588 ALK: 2674 Title COMPLETIONS te Well no. Field 2K-12 Auth. or W.O. no. AK3676 Operator ~CO Spudded or W.O. begun IDate Hour SPUD I 09/02/89 07: 00 Date and depth as of 8:00 a.m. 10/23/89 (10) TD: 7050 PB: 7107 SUPV:GB IARCO W.I. 55.8533 Prior status if a W.O. Complete record for each day reported NORDIC #1 PERFORATING 9-5/8"@ 3021' MW: 0.0 NaCl ACCEPT RIG 0830 10/22/89, ND DRYHOLE TREE, NU BOPE, LOAD PITS WITH 100 BBLS BRINE, TEST BOPE TO 3000 PSI AND MAKE REPAIRS, RU SWS, PERFORATE 6776-6796 AND 6764-6776 DAILY:SO CUM:$857,390 ETD:S857,390 EFC:$1,259,100 The above isj~rrect For form preparation J~ dfstribution, ~ see Procedures Man~aluJSectlon 10, Drilling, Pages 86 an~l'~7. AR3B-459-1-D INumber all dally well history forms consecutively aa they are prepared for each well. iPage no. ARCO Owl and Gas Company ,~, Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be Submitted also when operations are suspended for an indefinite or appreciable lenglh of time· On workovers when an olficial test is not required upon completion, report completion and representative test data in blocks provided. The "Fi¢lal Reporl" form may be used for reporting the entire operation if space is available, District ARCO ALASKA INC. Field KUPARUK RIVER UNIT Auth, or W.O. no, AK3676 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. County or Parish ALAsKA/NORTH SLOPE Lease or Unit ADL: 25588 ALK: 2674 Title COMPLETIONS JAccounting cost center code State IWell no. 2K-12 10/24/89 (11) TD: 7107 PB: 6967 SUPV:GB Old TD Released rig Classifications (oil, gas, etc.) Producing method Potential test data A.R.Co. W.I. Date 55'8533 09/02/89 Complete record for each day reported NORDIC #1 Iotal number of wells (active or inactive) on this pst center prior to plugging and J bandonment of this well our IPrlor status if a W.O. 07:00 RIG RELEASED 9-5/8"@ 3021' MW: 0.0 NaCl CONT. POH W/ PERF GUNS, RD E-LINE, NU FLOW NIPPLE, RU & RUN 3-1/2" SINGLE COMPLETION ASSEMBLY, LAND TBG HGR, TEST CONTROL LINE, DRAIN STACK, DROP BALL, SET PKR WITH 2500 PSI (TBG HELD OK), BLEED PRESS., PU AND SHEAR PBR, RELAND TBG, RILDS, TEST ANNULUS/PACKER TO 2500 PSI - OK, CLOSE SSSV, BLEED TBG PRESSURE TO 1000 PSI, SSSV HOLDING OK, PRESSURE UP TBG, OPEN SSSV, SHEAR BALL AT 3500 PSI, BLEED PRESS, CLOSE SSSV, INSTALL BPV, ND BO?E, NU TREE, PULL BPV, TEST TREE TO 5000 PSI, TEST PACKOFF TO 5000 PSI, PULL PLUG, OPEN SSSV, DISPL ANNULUS W/5 BBLS DIESEL, BULLHEAD 3 BBL DIESEL DOWN TBG, RELEASE RIG DAILY:S0 CUM:$857~,390 ETD:S857,390 EFC:$2,116,490 INew TD Date PB Depth Kind of r g Type completion (single, dual, etc.) Off c a reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day · Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Drilling, Pages 86 and 87. AR3B-459-3-C ,.-,tZ' ~ ~JhlE~'tu~¢~l history forma consecutively I ~. ~as. ~ foi each well, iPage no. Dlvltion o! AtlentlcRIchfleldCompany ADDENDUM WELL 2~12 3/9/90 Frac Kuparuk "A" sand perfs 6764'-6796' @ 2 spf 180 deg ccw in ten stages as follows. Stage 1: Stage Stage Stage Stage Stage Stage Stage Stage Stage Pmp 150 bbls YF240 prepad @ 24-25 bpm 7550-4430 psi 60 bbls YF240 prepad @ 20 bpm 4040-4390 psi 45 bbls YF240 prepad @ 15 bpm 3890-4390 psi 30 bbls YF240 prepad @ 10 bpm 3970-4010 psi 2:61 bbls Slick diesel flush @ 25 bbm 4700-3950 psi 3:900 bbls YF240 pad @ 25 bpm 3734-4290 psi 4:87 bbls YF240 w/2 ppg 16/20 Carbolite @ 25 bpm 4290-4080 psi 5:85 bbls YF240 w/4 ppg 16/20 Carbolite @ 25 bpm 4080-3990 psi 6:87 bbls YF240 w/6 ppg 16/20 Carbolite @ 25 bpm 3990-3890 psi 7:96 bbls YF240 w/8 ppg 16/20 Carbolite @ 25 bpm 3890-3840 psi 8:52 bbls YF240 w/8 ppg 16/20 Carbolite @ 25 bpm 3840-3890 psi 9:30 bbls YF240 w/8 ppg 16/20 Carbolite @ 25 bpm 3890-4140 psi 10:61 bbls Slick diesel flush @ 19-25 bpm 3600-4140 psi Tagged w/.4 mCi/1000 lbs Ir-192 total 18 mCi. Tagged w/1.8 mCi/1000 gal Sc-46 total 16 mCi. Tagged w/4 mCi/1000 lbs Au-198 total 60 mCi. Fluid to recover: 1,744 bbls Sand in zone: 97,7001bs Sand in csg: 980 lbs Avg pressure: 4200 psi Date SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA, INC. 2K-12 KUPARUK ALASKA COMPUTATION DATE: 9/25/89 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 0 .00 -154.00 100 100.00 -54.00 200 200.00 46.00 300 299.99 145.99 400 399.99 245.99 0 0 0 24 0 27 0 17 0 11 COURSE DIRECTION DEGREES N .00 E S 11.00 W S .20 E S 66.80 W S 88.30 W DATE OF SURVEY: 09-24-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90109 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE DLS TOTAL RECTANGULAR COORDINATES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 .00 .00 .41 .35S .07W .15 .10 1.10S .14W .53 .44 1.60S .37W .63 .13 1.71S .76W .37 500 499.99 345.99 600 599.99 445.99 700 699.99 545.99 800 799.99 645.99 900 899.99 745.99 0 19 S 12.50 W 0 26 S 7.80 W 0 16 S 56.30 W 0 6 S 71.40 W 0 15 N 30.90 W .33 1.99S .99W .13 2.64S 1.10W .33 3.16S 1.36W .19 3.32S 1.64W .25 3.16S 1.84W .35 .64 .73 .59 .34 1000 999.99 845.99 1100 1099.98 945.98 1200 1199.98 1045.98 1300 1299.98 1145.98 1400 1399.98 1245.98 0 15 0 18 0 11 0 12 0 7 S .90 W S 74.30 W S 53.60 W N 39.30 W S 30.50 W .49 3.20S 1.96W .34 3.50S 2.22W .15 3.67S 2.61W .28 3.63S 2.86W .28 3.58S 3.04W .27 .23 .01 .22 .39 1500 1499.98 1345.98 1600 1599.98 1445.98 1700 1699.98 1545.98 1800 1799.98 1645.98 1900 1899.97 1745.97 0 14 0 14 0 22 0 23 0 37 S 39.70 W .11 3.84S 3.23W - S 62.90 W .09 4.10S 3.55W - S 59.10 W .14 4.37S 4.02W - S 61.90 W .03 4.70S 4.60W -1 S 22.20 E .70 5.36S 4.70W - .39 .51 .73 .02 .71 1950 1949.94 1795.94 2000 1999.72 1845.72 2050 2049.15 1895.15 2100 2098.18 1944.18 2150 2146.84 1992.84 3 24 6 58 10 16 12 19 14 11 S 44.80 E S 50.10 E S 55.50 E S 55.90 E S 54.00 E 5.68 6.66S 3.55W 7.22 9.66S .18W 5 6.79 14.14S 5.83E 12 4.08 19.66S 13.93E 22 3.84 26.25S 23.30E 34 .98 .47 .96 .76 .22 2200 2195.11 2041.11 2300 2290.69 2136.69 2400 2385.10 2231.10 2500 2478.11 2324.11 2600 2569.50 2415.50 15 57 S 53.60 E 18 10 S 54.30 E 20 15 S 53.90 E 22 46 S 53.40 E 25 4 S 53.70 E 3.55 33.93S 33.79E 47 2.22 51.19S 57.52E 76 2.09 70.49S 84.17E 109 2.53 92.23S 113.70E 146 2.29 116.32S 146.32E 186 .22 .56 .46 .13 .67 2700 2659.40 2505.40 2800 2748.21 2594.21 2900 2836.65 2682.65 3000 2924.99 2770.99 3100 3013.42 2859.42 26 51 S 53.60 E 27 51 S 53.50 E 27 46 S 53.60 E 28 6 S 53.40 E 27 34 S 55.10 E 1.78 142.26S 181.57E 230 1.01 169.56S 218.53E 276 .09 197.29S 256.07E 323 .34 225.16S 293.74E 369 .96 252.45S 331.64E 416 .44 .38 .04 .90 .59 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, INC. 2K-12 KUPARUK ALASKA COMPUTATION DATE: 9/25/89 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 3200 3102.08 3300 3190.95 3400 3279.23 3500 3366.30 3600 3452.82 2948.08 27 31 3036.95 27 2 3125.23 28 57 3212.30 29 57 3298.82 30 13 DATE OF SURVEY: 09-24-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90109 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. S 56.20 E .51 278.55S 369.82E S 56.50 E .50 303.95S 407.99E S 54.40 E 2.15 330.60S 446.63E S 53.90 E 1.02 359.40S 486.49E S 53.70 E .29 389.00S 526.94E 462.83 508.66 555.59 604.76 654.89 3700 3539.00 3800 3624.77 3900 3710.19 4000 3796.13 4100 3882.56 3385.00 30 44 3470.77 31 9 3556.19 31 28 3642.13 30 1 3728.56 30 22 S 53.80 E .52 419.00S 567.84E S 53.40 E .47 449.51S 609.24E S 53.50 E .32 480.47S 651.00E S 54.20 E 1.50 510.63S 692.27E S 54.20 E .35 540.05S 733.06E 705.61 757.03 809.00 860.12 910.42 4200 3968.65 4300 4054.35 4400 4140.65 4500 4227.74 4600 4314.70 3814.65 3900.35 3986.65 4073.74 4160.70 30 47 31 14 29 25 29 27 29 43 54.40 E .43 569.74S 774.38E 54.10 E .48 599.85S 816.20E 53.90 E 1.81 629.53S 857.05E 53.70 E .10 658.55S 896.71E 54.00 E .31 687.68S 936.58E 961.29 1012.81 1063.31 1112.46 1161.83 4700 4402.08 4800 4489.83 4900 4577.33 5000 4664.67 5100 4751.82 5200 4838.76 5300 4925.45 5400 5011.89 5500 5098.24 5600 5185.51 4248.08 28 27 4335.83 28 52 4423.33 29 1 4510.67 29 15 4597.82 29 28 4771.45 30 2 4857.89 30 20 4944.24 30 14 5031.51 28 10 S 53~.50 E 1.29 716,42S 975.78E S 53.70 E .44 744.88S 1014.39E S 53.70 E .14 773.54S 1053.40E S 53.70 E .24 802.37S 1092.65E S 53.30 E .29 831.54S 1132.07E S 53.50 E .29 861.00S 1171.74E S 53.60 E .29 890.61S 1211.83E S 53.50 E .30 920.49S 1252.28E S 54.60 E .56 950.10S 1293.11E S 55.70 E 2.13 977.99S 1333.14E 1210.43 1258.39 1306.79 1355.48 1404.52 1453.93 1503.76 1554.04 1604.48 1653.27 5700 5273.64 5800 5361.73 5900 5449.63 6000 5537.21 6100 5624.48 5119.64 28 13 5207.73 28 16 5295.63 28 40 5383.21 29 2 5470.48 29 23 S 56.40 E .33 1004.38S 1372.34E S 56.70 E .15 1030.47S 1411.84E S 56.50 E .40 1056.72S 1451.64E S 56.30 E .39 1083.43S 1491.84E S 56.40 E .34 1110.48S 1532.48E 1700.50 1747.80 1795.45 1843.69 1892.48 6200 5711.57 6300 5798.60 6400 5885.50 6500 5972.88 6600 6061.03 5557.57 5644.60 5731.50 5818.88 5907.03 29 28 29 32 29 45 28 26 27 54 S 56.20 E .13 1137.75S 1573.36E S 56.90 E .35 1164.90S 1614.47E S 56.60 E .25 1192.03S 1655.84E S 56.60 E 1.31 1218.79S 1696.43E S 55.50 E .74 1245.16S 1735.60E 1941.60 1990.83 2040.26 2088.85 2136.04 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. 2K-12 KUPARUK ALASKA COMPUTATION DATE .' 9/25/89 DATE OF SURVEY: 09-24-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90109 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6700 6149.19 5995.19 28 25 S 54.50 E .69 6800 6237.98 6083.98 26 19 S 55.60 E 2.16 6900 6328.42 6174.42 24 8 S 56.50 E 2.20 7000 6419.66 6265.66 24 8 S 56.50 E .00 7100 6510.91 6356.91 24 8 S 56.50 E .00 1272.23S 1774.26E 2183.24 1298.57S 1811.92E 2229.20 1322.39S 1847.27E 2271.81 1344.97S 1881.39E 2312.70 1367.55S 1915.51E 2353.59 7107 6517.30 6363.30 24 8 S 56.50 E .00 1369.13S 1917.90E 2356.45 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2356.45 FEET AT SOUTH 54 DEG. 28 MIN. EAST AT MD = 7107 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 125.52 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. 2K-12 KUPARUK ALASKA COMPUTATION DATE: 9/25/89 DATE OF SURVEY: 09-24-89 JOB NUMBER: AK-BO-90109 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE 0 .00 -154.00 .00 .00 .00 1000 999.99 845.99 3.20 S 1.96 W .01 2000 1999.72 1845.72 9.66 S .18 W .28 3000 2924.99 2770.99 225.16 S 293.74 E 75.01 4000 3796.13 3642.13 510.63 S 692.27 E 203.87 VERTICAL CORRECTION .01 .26 74.73 128.87 5000 4664.67 4510.67 802.37 S 1092.65 E 335.33 6000 5537.21 5383.21 1083.43 S 1491.84 E 462.79 7000 6419.66 6265.66 1344.97 S 1881.39 E 580.34 7107 6517.30 6363.30 1369.13 S 1917.90 E 589.70 131.45 127.47 117.54 9.37 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. 2K-12 KUPARUK ALASKA COMPUTATION DATE: 9/25/89 DATE OF SURVEY: 09-24-89 JOB NUMBER: AK-BO-90109 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 .00 -154.00 54 54.00 -100.00 154 154.00 .00 254 254.00 100.00 354 354.00 200.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST · 00 .00 · 05 S .01 W .74 S .13 W 1.50 S .17 W 1.70 S .61 W MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 .00 .00 .00 .01 .00 · 01 .00 454 454.00 300 554 554.00 400 654 654.00 500 754 754.00 600 854 854.00 700 .00 .00 .00 .00 .00 1.75 S .93 W 2.30 S 1.06 W 3.02 S 1.18 W 3.29 S 1.56 W 3.32 S 1.74 W .01 .00 .01 .00 .01 .00 .01 .00 .01 .00 954 954.00 800 1054 1054.00 900 1154 1154.00 1000 1254 1254.00 1100 1354 1354.00 1200 .00 3.02 S 1.95 W .00 3.42 S 2.00 W .00 3.58 S 2.48 W .00 3.74 S 2.76 W .00 3.51 S 2.98 W .01 .00 .02 .00 .02 .00 .02 .00 .02 .00 1454 1454.00 1300 1554 1554.00 1400 1654 1654.00 1500 1754 1754.00 1600 1854 1854.00 1700 .00 3.70 S 3.11 W .00 4.01 S 3.38 W .00 4.21 S 3.76 W .00 4.55 S 4.33 W .00 4.92 S 4.86 W .02 .00 .02 .00 .02 .00 .02 .00 .03 .00 1954 1954.00 1800 2054 2054.00 1900 2157 2154.00 2000 2261 2254.00 2100 2366 2354.00 2200 .00 6.87 S 3.33 W .00 14.64 S 6.57 E .00 27.31 S 24.77 E .00 44.16 S 47.74 E .00 63.72 S 74.90 E 3 7 12 .07 .05 .93 .86 .39 2.46 .39 4.00 .85 5.46 2473 2454.00 2300.00 2582 2554.00 2400.00 2693 2654.00 2500.00 2806 2754.00 2600.00 2919 2854.00 2700.00 86.20 S 105.58 E 112.02 S 140.48 E 140.64 S 179.37 E 171.38 S 220.99 E 202.71 S 263.43 E 19 28 39 52 65 .85 7.01 .89 9.04 .95 11.06 .55 12.60 .61 13.06 3032 2954.00 2800.00 3145 3054.00 2900.00 3258 3154.00 3000.00 3371 3254.00 3100.00 3485 3354.00 3200.00 234.40 S 306.18 E 264.55 S 349.03 E 293.53 S 392.25 E 322.47 S 435.28 E 355.22 S 480.76 E 78.89 91.78 104.51 117.17 131.81 13.28 12.89 12.73 12.66 14.64 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. 2K-12 KUPARUK ALASKA COMPUTATION DATE: 9/25/89 DATE OF SURVEY: 09-24-89 JOB NUMBER: AK-BO-90109 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3601 3454.00 3300.00 389.41 S 527.49 E 147.36 15.55 3717 3554.00 3400.00 424.26 S 575.04 E 163.45 16.09 3834 3654.00 3500.00 460.05 S 623.43 E 180.16 16.72 3951 3754.00 3600.00 496.30 S 672.44 E 197.28 17.12 4066 3854.00 3700.00 530.26 S 719.49 E 212.90 15.62 4182 3954.00 3800.00 564.66 S 767.28 E 228.95 16.05 4299 4054.00 3900.00 599.72 S 816.02 E 245.59 16.64 4415 4154.00 4000.00 633.96 S 863.14 E 261.33 15.74 4530 4254.00 4100.00 667.33 S 908.67 E 276.16 14.83 4645 4354.00 4200.00 700.84 S 954.67 E 291.22 15.06 4759 4454.00 4300.00 733.18 S 998.47 E 305.09 13.87 4873 4554.00 4400.00 765.88 S 1042.97 E 319.32 14.23 4987 4654.00 4500.00 798.82 S 1087.83 E 333.76 14.44 5102 4754.00 4600.00 832.27 S 1133.06 E 348.50 14.74 5217 4854.00 4700.00 866.18 S 1178.75 E 363.56 15.05 5332 4954.00 4800.00 900.41 S 1225.12 E 378.98 15.42 5448 5054.00 4900.00 935.11 S 1272.11 E 394.79 15.81 5564 5154.00 5000.00 968.48 S 1319.20 E 410.26 15.47 5677 5254.00 5100.00 998.55 S 1363.57 E 423.71 13.46 5791 5354.00 5200.00 1028.19 S 1408.36 E 437.23 13.51 5904 5454.00 5300.00 1058.04 S 1453.63 E 450.98 13.76 6019 5554.00 5400.00 1088.61 S 1499.60 E 465.21 14.23 6133 5654.00 5500.00 1119.68 S 1546.33 E 479.88 14.67 6248 5754.00 5600.00 1151.07 S 1593.31 E 494.74 14.86 6363 5854.00 5700.00 1182.11 S 1640.81 E 509.72 14.98 6478 5954.00 5800.00 1213.16 S 1687.89 E 524.53 14.81 6592 6054.00 5900.00 1243.05 S 1732.53 E 538.05 13.52 6705 6154.00 6000.00 1273.74 S 1776.38 E 551.47 13.43 6817 6254.00 6100.00 1303.05 S 1818.46 E 563.88 12.40 6928 6354.00 6200.00 1328.72 S 1856.84 E 574.04 10.16 7037 6454.00 6300.00 1353.47 S 1894.23 E 583.63 9.59 7107 6517.30 6363.30 1369.13 S 1917.90 E 589.70 6.07 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 7 ARCO ALASKA, INC. 2K-12 KUPARUK ALASKA COMPUTATION DATE: 9/25/89 DATE OF SURVEY: 09-24-89 JOB NUMBER: AK-BO-90109 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER 3021 2943.52 2789.52 231.06 S 6686 6136.87 5982.87 1268.36 S 6692 6142.15 5988.15 1270.02 S 6723 6169.41 6015.41 1278.59 S 6862 6293.74 6139.74 1313.81 S 301.69 E 9 5/8" CSG 1768.83 E TOP KUPARUK C 1771.16 E BASE KUPARUK C 1783.17 E TOP KUPARUK A 1834.31 E BASE KUPARUK A 6900 6328.42 6174.42 1322.39 S 6967 6389.55 6235.55 1337.52 S 7050 6465.29 6311.29 1356.26 S 7107 6517.30 6363.30 1369.13 S 1847.27 E SURVEY DEPTH 1870.13 E PBTD 1898.45 E 7" CSG 1917.90 E TD ARCO ALASKA, INC. 2K-12 STRATIGRAPHIC SUMMARY BKB BKB SUB-SEA COORDINATES WITH REF. TO WELLHEAD ORIGIN: 21FSL 94FEL SEC 02 T10N R08E 9 5/8" CSG TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A 3021 2943.52 2789.52 231.06S 301.69E 6686 6136.87 5982.87 1268.36S 1768.83E 6692 6142.15 5988.15 1270.02S 1771.16E 6723 6169.41 6015.41 1278.59S 1783.17E 6862 6293.74 6139.74 1313.81S 1834.31E PBTD 6967 6389.55 6235.55 1337.52S 1870.13E 7" CSG 7050 6465.29 6311.29 1356.26S 1898.45E TD 7107 6517.30 6363.30 1369.13S 1917.90E COMPUTER PROGRAM - SPERRY-SUN THREE DIMENSION RADIUS OF CURVATURE DATE OF SURVEY: 09-24-89 COMPUTATION DATE: 9/25/89 JOB NUMBER: AK-BO-90109 KELLY BUSHING ELEV. = 154.00 FT. 2K-12 KUPARUK ALASKA 09-24.-89 -Sp E RR',,~,,-SUN HORTZONTAL DRLG. SVCS. PROJECTION START TVD = 0 FINISH TVD = 6517.30 SCALE IS 500 FEET/IN DEPARTURE soo 1ooo 1500 2000 2500' 0oOo 0 SO0 1000 1500 2000 2500 0000 I I I I I I I 107 ~SPERR" SUN VERTICAL 2K-12 KUPARUK ALASKA 09-24-89 D'RL G. ~,SVCS. PROJECTION START TVD = 0 FINISH TVD = 6517.30 SCALE IS 1000 FEET/IN 1000 2000 8000 4000 SO00 8000 ?000 710 2356.45 6 ~obo 2o~) soho .bo' soho soho VERTZCAL SECTION DZR£CTZON = 0.00 ARCO Alaska, Inc. Date: December 6, 1989 Transmittal #: 7620 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 2 Acoustic Cement Bond Log 9 - 2 4 -~ 8 9 4 5 8 8 - 6 9 0 6 2 K - 1 1 Acoustic Cement Bond Log 9 - 2 3- 8 9 4 9 9 8 - 6 7 7 0 2 K - 0 6 Acoustic Cement Bond Log 9 - 2 2 - 8 9 5 5 0 2 - 7 9 2 0 2 K - 0 5 Acoustic Cement Bond Log 9 - 2 6 - 8 9 5 3 5 6 - 7 8 0 3 2 K - 01 Acoustic Cement Bond Log 9 - 2 3 - 8 9 5 8 3 8 - 8 4 4 0 Receipt DISTRIBUTION' NSK Acknowledged: Drilling State of Alaska(+sepia) ' ' STATE OF ALASKA /-,~-~SKA OIL AND GAS CONSERVATION COMMISSION0 APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator Operation Shutdown X.~ Re-enter suspended well _ _. Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 21' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval 1248' FNL, 1712' FWL, Sec. 12, T10N, R8E, UM (approx) At effective depth 1317' FNL, 1776' FWL, Sec. 12, T10N, R8E, UM (approx) At total depth 1348' FSL, 1823, FWL, Sec. 12,T10N, R8E, UM (approx) 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical 71 07' feet 651 7' feet Plugs (measured) None 6. Datum elevation (DF or KB) RKB 154 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2K-12 9. Permit number 89-74 10. APl number 50-103-20109 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool 6967' feet 63 90' feet Casing Length Size . . Structural 8 0' 1 6" Conductor Surface 2986' 9 5/8" Intermediate Production 7022' 7" Liner Perforation depth: measured true vertical None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None !13. Attachments Description summary of proposal 14. Estimated date for commencing operation October, 1989 · 16. If proposal was verbally approved Junk (measured) None Cemented Measured depth 115' 900 Sx AS III & 3021' 375 Sx Class G 250 Sx Class G 7051' (approx) True vertical depth 115' 2944' 6465' Detailed operation program. X ... BOP sketch Name of approver Ap, proved by the order of the Commission Form 10-403 Rev 06/15/88 Date approved 15. Status of well classification as: Oil X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct.to the best of my knowledge. S.iCned ~)~~ ~'. ~~ Title Area Drilling Engineer × FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require ORIGINAL SIGNED BY LONNIE C. S~¢IITH Date 'J ~///~//,¢, ~' Commissioner JApproval No. uopy Returned Date [O_.~ ! ~ .-- ~ SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. KUPARUK J County, parish or borough NORTH SLOPE Lease or Unit ADL 25588 ALK 2674 Title DRILLING pre 2K-12 Field lWeil no. Auth, or W,O, no, AK3676 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 09/02/89 (1) TD: 115'( 115) SUPV: JER 09/03/89 (2) TD: 2655'(2540) SUPV:JER 09/04/89 (3) TD: 3034'( 379) SUPV:JER 09/05/89 ( 4) TD: 4939' (1905) SUPV:JER 09/06/89 (5) TD: 6392'(1453) JDate09/02/89 /Hour 7:00 Complete record for each day reported DOYON 14 BUILDING RAMP FOR VAC TRUCK MW: 8.5 VIS:102 MOVE RIG FROM 2K-9 TO 2K-12. NU DIVERTER SYSTEM. CLEANED UP 10 BBL MUD SPILL UNDER FROM CRACKED DUMP LINE. NU RISER AND FLOOR. CUT 595' DRILL LINE AND PU BHA. FUNCTION TEST DIVERTER, WITNESS WAIVED BY AOGCC. BUILD RAMP FOR VECO GUZZLER VAC TRUCK. DAILY:S24,114 CUM:$24,114 ETD:S24,114 EFC:$1,259,100 DRILLING @ 2655' MW: 9.1 VIS: 68 CONTINUE BUILDING RAMP FOR VAC TRUCK. SPUD WELL @ 0700 9/2/89. DRILL AND SURVEY 115'-1872'. CIRC HOLE CLEAN, TOH AND CHANGE BHA. TIH, AND KICK WELL OFF. MOTOR DRILL AND SURVEY 1925'-2655'. DAILY:S61,159 CUM:$85,273 ETD:S85,273 EFC:$1,259,100 RU TO TEST BOP 9-5/8"@ 3021' MW: 0.0 VIS: 0 CONTINUE DRILLING 2655'-3034'. CONDITION WELL AND MADE SHORT TRIP. CIRCULATE WELL, DROP SURVEY, TOH AND LD BHA. RU AND RUN 85 JTS 9-5/8", 36#, J-55, BUTT CASING. SHOE @ 3021', COLLAR @ 2939'. ATTEMPT TO CIRCULATE CASING, WOULD PACKOFF. RU DOWELL AND CEMENT WELL WITH 900 SX ASIII @ 12.1 PPG AND 375 SX CLASS G. DISPLACE WELL WITH MUD AND BUMP PLUG TO 2000 PSI, OK. FLOATS HELD, OK. HAD FULL RETURNS THROUGHOUT AND 10 BBL OF 11.0 PPG CEMENT @ SURFACE. CIP 2230, 9/3/89. RD DOWELL, ND DIVERTER AND NU BOP. PREPARE TO TEST. TEST WITNESS WAIVED BY AOGCC. DAILY:S200,173 CUM:$285,446 ETD:S285,446 EFC:$1,259,100 DRILLING @ 4939 9-5/8"@ 3021' MW: 9.2 VIS: 32 FINISH TESTING BOP AND INSTALL WEAR RING. PU BHA AND TIH TO FLOAT COLLAR. TEST CASING TO 2000 PSI, OK. DISPLACE TO NEW MUD AND DRILLOUT TO 3044'. TEST FORMATION TO 12.5 EMW WITHOUT LEAKOFF. DRILL AND SURVEY 3044'-4939'. DAILY:S68,364 CUM:$353,810 ETD:S353,810 EFC:$1,259,100 RIH W/ ROTARY ASSEMBLY 9-5/8"@ 3021' MW: 9.6 VIS: 34 CONTINUE DRILL AND SURVEY 4939'-5096'. CIRC BOTTOMS UP AND SHORT TRIP TO SHOE TEST FORMATION. FORMATION BLED TO 10.2 EMW FROM 10.6. TIH AND DRILL AND SURVEY 5096'-6392'. CIRC AND CONDITION WELL WITH FINE LCM IN MUD AND TOH TO CASING SHOE. TEST FORMATION TO 10.8 EMW. HELD OK. FINISH TOH. LD TURBINE AND PU ROTARY ASSEMBLY. TIH. DAILY:S87,835 CUM:$441,645 ETD:S441,645 JARCO W.I. 55J. 8533 JPrior status if a W.O. The above is co/I,e~t For form preparation an,~t~stri'but~on, ~ see Procedures Manual[, $4~ction 10, Drilling, Pages 86 and 87. EFC:$1,259,100 AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. jPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District jCountYi or Parish I State ARCO ALASKA INC. NORTH SLOPE AK Field Lease or Unit KUPARUK ADL 25588 ALK 2674 2K-12 Date and depth as of 8:00 a.m, 09/07/89 (6) TD: 7089' ( 69 SUPV:CD 09/08/89 ( TD: 7089 PB: 0 SUPV:CD 09/09/89 ( TD: 7089 PB: 0 SUPV:CD Complete record for each day while drilling or workover in progress DOYON 14 DRILLING 9-5/8"@ 3021' MW:10.3 VIS: 39 FINISH TIH W/ ROTARY ASSEMBLY. REAM LAST STAND AND DRILL 6392'-6709'. HAD DRILLING BREAK AND WELL BEGAN TO FLOW, SI WITH NO PRESSURE. CIRCULATE OUT GAS CUT MUD AND INCREASE MW TO 10.5 WHILE DRILLING 6709'-6761'. HOLE STARTED TAKING FLUID @ 3 BPM. ADDED LCMAND CONTINUED DRILLING 6761'-7089'. DAILY:S70,800 CUM:$512,445 ETD:S512,545 EFC:$1,259,000 CIRCULATING @ 6970' 9-5/8"@ 3021' MW:10.3 WBM CONTINUE DRILLING 7089'-7107'. CIRCULATE BOTTOMS UP AND MAKE 20 STAND SHORT TRIP. HOLE TIGHT @ 6215'. CIRCULATE WELL CLEAN AND TOH FOR LOGS. RU SOS AND ATTEMPT TO GET DOWN WITH LOGS. COULD NOT GO BEYOND 6440'. TOH, RD SOS. TIH, AND REAM TIGHT HOLE, 6500'-6700' AND TIH TO TD. ATTEMPT TO BREAK CIRCULATION, NO RETURNS. POH W/ 2 STANDS AND ATTEMPT TO CIRCULATE, LOST 100 BBLS. TOH TO SHOE, GAINED 3 BBL ON TRIP. ESTABLISH CIRCULATION AT SHOE. CIRCULATE AND CONDITION MUD, MUD CONTAMINATED W/ CO2, HIG VISCOSITY AND GELS, MW IN 10.3, MW OUT 10.6. STAGE INTO HOLE IN 10 STAND INCREMENTS AND CIRCULATE AND CONDITION MUD. HOLE STABLE. DAILY:S66,862 CUM:$579,307 ETD:S579,307 EFC:$1,259,100 RUNNING 7" CASING 9-5/8"@ 3021' MW:10.3 WBM CONTINUE CIRCULATE AND CONDITION MUD. REAM TO BOTTOM AND CIRCULATE WELL CLEAN TOH SLM. RU SCHLUMBERGER AND LOG FDC/CNL TD-6480', DIL/SFL/CAL/S? TD-3020', GR TD-1000'. RD SOS. TIH TO SHOE AND CUT DRILL LINE. CONTINUE IN HOLE AND CIRCULATE AND CONDITION MUD. SPOT PILL AND TOH, LDDP. RU CASING TOOLS AND PREPARE TO RUN 7" CASING. DAILY:S124,748 CUM:$704,055 ETD:S704,055 EFC:$1,259,100 RECEIVED OCT 1 1989 V, asl 0il & Gas :Cons. c0mmissi0; Anchorage Well no. The above,~correct Signat~l~ ~ For form preparati,~r~d distribution see Procedures Iv~al Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. rPage no. ARC~ Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, reporl completion and representative test date in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District County or Parish ARCO ALASKA INC. NORTH SLOPE Field Lease or Unit KUPARUK ADL 25588 Auth. or W.O. no. ]Title AK3676 J DRILLING ALK 2674 Accounting cost center code State AK 2K-12 JWell no. Operator J A.R.Co, W.I. ARCO 55.8533 Spudded or W.O. begun Date SPUD 09/02/89 Date and depth as of 8:00 a.m. 09/10/89 ( TD: 7089 PB: 0 SUPV:CD Complete record for each day reported DOYON 14 Iotal number of wells (active or inactive) on this Ost center prior to plugging and bandonment of this well our I Prior status if a W,O, I 07:00 RIG RELEASED 9-5/8"@ 3021' MW:10.3 WBM RUN 164 JTS OF 7" 26#, J-55 BTC R-3 CSG W/ FS AT 7050'. CIRC AND COND MUD. PUMP SPACERS AND 250 SXS OF CLASS "G" CMT AT 15.8 PPG. CIP AT 15:20 HRS, 09/09/89. SET SLIPS. CUT CSG. SET BACK STACK. INSTALL 7" PACKOFFS. NU TBG SPOOL. TEST PACKOFFS. NU LOWER TREE AND MASTER VALVE. RIG RELEASED AT 22:00 HRS, 09/09/89. DAILY:S153,335 CUM:$857,390 ETD:S857,390 EFC:$1,259,100 RECEIVED OCT 17191E) a _OJJ & Gas Cons, G mmls io - chorags Old TD Released rig INew TO PB Depth Date IKnd of rg Classifications (oil, gas, etc.) Producing method Potential test data Type completion (single, dual, etc.) IOff cial reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR I Gravity Allowable Effective date corrected The above.~rrect IDate / Signature~L~ For form preparation ~c~ distribution, -- G ~ ' SDer~lliPnr~,C~da;reesS 81~%~d 8~7.ection 10, AR3B-459-3-C INumberall daily well history forms consecutively Page no. I as they are prepared for each well. I I DlvlsJon of AtlantlcRIchfleldCompany ARCO Alaska, Inc. Date- September 22, 1989 Transmittal Ct: 7565 RETURN TO: ARCO Alaska, Inc. Attn: Brianna Knettle Cpf-3 Eng. Aide ATO-1152 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 2 K- 11 5" Dual Induction 2K-1 I 2" Dual Induction 2 K - 1 I Cyberlook 2K-11 CNL Porosity 2 K - 11 CNL Raw Data 2 K- 1 2 5" Dual Induction 2K-1 2 2" Dual Induction 2 K - 1 2 Cyberlook 2 K - 1 2 CNL Porosity 2 K - 1 2 CNL Raw Please acknowledge receipt and return ,-. 9-11 -89 113-3003 9-1 1 -89 1 13-3005 9-11 -89 1500-2950 9-1 1 -89 1 13-2976 9-11 -89 113-2976 9-08-89 1000-7088 9-08-89 1000-7088 9-08-89 6480-7050 9-08-89 6480-7064 9-08-89 6480-7064 Receipt Acknowledged- DISTRIBUTION: NSK D&M Drilling Franzen State of Alaska(+sepia) L. Johnston(vendor package) SEP-04-'89 13:14 TEL GB~ de~&oto~ HOR v~lv~ Che~k Wive SION '"' "' ~ ~" , R ECE IV E D omo...~.ed. SEP o 5 1989 ' ~ohorage o~iI - AL A OILAND GAS CONSERVATION COMM '")N 0 I1~ I G APPLICATION FOR SUNDRY APPROVALS INA[ 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well_ Change approved program ~ Pull tubing _ Operation Shutdown _ Re-enter suspended well _ Plugging _ Time extension _ Stimulate _ Variance _ Perforate _ Other 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service -- 4. Location of well at surface 21' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval (@ Target) 1320' FNL, 1620' FWL, Sec. 12, T10N, R8E, UM At effective depth At total depth 1402' FNL~ 1725' FWL~ Sec. 12~ TI ON~ R8E~ UM 12. Present well condition summary Total Depth: measured feet true vertical feet Plugs (measured) RKB 154' GL 118' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2K-12 9. Permit number 89-74 10. APl number 50-1 03-201 09 11, Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth' measured feet Junk (measured) true vertical feet None Casing Length Size Cemented Structural Conductor Intermediate Production Liner Perforation depth: measured true vertical Measured depth True vertical depth Tubing (size, grade, and measured depth Change in original permit due to the cored well Packers and SSSV (type and measured depth) being moved from 2K-10 to 2K-11 affecting this well's directional plan 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch Change in directional plan 14. Estimated date for commencing operation Spud estimated 9-30-89 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/'/~~ ,.~ ~ Title Area Drilling Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require Original Sig~ed By David W. Johnston Approved by the order of the Commission lO-/-/~7 Commissioner IApproval No. .-,- , Approved Copy Returned Date 7¢-' / T"'¢'~ , Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO ALASKA. Pad 2K, Wel I Not 12 Rev!eed Propoeal Kupar'uk Field, North Slope, Aleeka RI(B ELEVAT[ON~ 154' 1000 B/ PERIflAFROST TVD--1 424 T/ UONU SNDS TVD=1544 2OOO 3000 4000 KOP TVD=187'2 Tt'ID=!87'2 DEP=O 3 9 T~ W SAK SNDS TVD=2163 TMD=2164 DEP=22 15 BUILD 3 DEO PER ! O0 FT 21 27 B/ W SAK SNDS TVD=2734 TPID=2766 DEP=206 EOC TVD=2805 TMD=2847 DEP=243 9 5/8' CSG PT TVD=2934 TI'ID=2995 DEP=316 K-lO TVD=3183 TI'ID=3280 DEP=455 AVERAGE ANGLE 29 DEG ]5 MI N K-5 TVD=4608 TI'ID=491;3 DEP=125,3 5000 6000 ?000 T/ ZONE C TVD=6!57 T~D=6688 DEP=2!20 T/ ZONE A TVD=6193 TMD=6730 DEP=2140 TARGET CNTR TVD=6257 TMD=6803 DEP=2176 B/ KUP SNDS TVD=6320 TlflD=6875 DEP=2212 TD (LOG PT) TVD=6495 TPID=7075 DEP=2309 I ! ! 000 2000 VERTICAL SECTION I 3000 HOR,~---~ON T AL ..~ALE 1 IN. PROJECTION - !000 FEET ARCO ALASKA. Ine. Ped 2K, Well No, 12 I(upeeulr FI eld, Noeth Revlmed Propoaml Slope, Aleekm 1 000 SURFACE LOCAT ! ON ~ 21' FSL. 94.': FEL SEC. 2. TI ON. RSE 1 000 2000 1 000 0 I 3000 . WEST-EAST 1 000 2000 I I ;~000 I TD LOCATION~ , · .. : TARGET CENTER TVD=6257 TI"ID=6803 DEP-2176 SOUTH 1341 EAST 1714 TAROET LOOATION~ 1320' FNL. 1620' FWL SEC. 12. TION. RSE S 51 DEG 2176' (TO 58 MINE TAROET) 25O 200 150 100 5O 5O 100 250 200 1 50 1 O0 5v 0 50 I, ,~ I I I I ' ~ -\~oo ..... '~ --' soo~ ...... F . X A,oo 500 / / ~~goo ~5oo I /G~oo I ",500 I ° 500 ! /' 2~oo J / ',~oo j / %2100 '/2500 / "~300 / / ",a~oo I 2700 _ I I / / ~ -." ° 500 / 7'00 ~2go0~ ~ ~ ~ ~ Goo 1 50 , , ,~oo, "s°Q-,~1 J 250 200 1 50 1 O0 50 0 5O 250 200 150 100 5O 5O 100 150 July 18, 1989 Telecopy: (907)276-7542 Patrick J. Archey Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 ~chorage, Alaska 99510-0360 Re: Kuparuk River Unit 2K-12 ARCO Alaska, Inc. Pe~it No. 89-74 Sur. Loc. 21'FSL, 94'FEL, Sec. 2, T10N, RSE, UM. Btmhole Loc. t405'FRV~, I729'~L, Sec. 12, T10N, RSE, UM. Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from ~other governmental agencies, and does not authorize conducting drilling operations until all other 'required permitting detern~inagions ara made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Chaet~rt~n Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF ~E COMMISSION dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA JIL AND GAS CONSERVATION C.~,vlMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ,'~ Redrill -I lb. Type of well. Exploratory ~ Stratigraphic Test ,~ Development Oil Re-Entry - Deepen~-I Service - Developement Gas ~_ Single Zone ,~ Multiple Zone 2. Name of Operator ARCO Alaska~ Inc. 3. Address P_0_ Rnv ln~"~l'~ An~-hnra0~.; Al( 99510-0360 4. Loca~i0n of Wel[ at surface 21' FSL, 94' FEL, Sec. 2, T10N, R8E, UN At top of productive interval 1320' FNL, 1620' FWL, Sec. 12, T10N, R8E, UM At total depth 1405' FNL, 1729' FWL~ Sec. 12~ T10N~ R8E~ UM 12. Distance to nearest property line 5. Datum Elevation (DF or KB) RKB 154', Pad 118' GL feet 6. Property Designation ADL 25588. ALK 2674 7. Unit or property Name Kuparuk River Unit 8. Well number 2K-12 13. Distance to nearest well 9. Approximate spud date July 17, 1989 14. Number of acres in property 10. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 11. Type Bond (see 20 AAC 25.025) Statewi de Number # U630610 Amount $200,000 15. Proposed depth (MD and TVD) 2K-11 Conductor ~l, r~ Tn feet 25' at. ~,,rface feet 16. To be completed for deviated wells Kickoff depth1965 feet Maximum hole angle :30° 18. Casing program size Hole Casing 24" 16" 12U' 9-5/8 8¥' 7" Weight 62.5# 36.0# 26.0# Specifications GradeI Coupling iH-40 I Weld J-55 I BTC HF-ERWI ;J-55 I BTC HF-ER~I tLength 80' 2946' 6991 ' 2560 7025' MD 6419' TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 1661 psig At total del)th (TVD)~171 psig MD 35' 35' 34' Setting Depth Top Bottom I TVD I MD I TVD Quantity of cement (include stage data) ±200# CF 6755x ASZZ~ & 400sx Class G 20Usx Class G tail ~oo of ~ ~uu; abov~ Ku~aruk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth True Vertical depth 20. Attachments Filing fee [] Property plat [] BOP Sketch ~ Diverter Sketch '~ Drilling program ~r Drilling fluid program .~ Time vs depth plot [] Refraction analysis [] Seabed report ,% 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed P ~' ~:~..-h~-.~¥/ Title Area Drilling Engineer Date '7'/~",/',~F' /' Commission Use Only PD1/~ ~~ Permi~Number ~ ~ APl number _ ~ Approval date ' ~ See cover letter ~- ~ [ 50--/~ ~- ~/~.~ ] 0 7 / 18 / 8 9[ for other requirements Conditions of approval Samples required ~ Yes ~ No Mud log requi[ed ~ SN~~ Hydrogen sulfide measures ~ Yes ~ No Direchonal survey required ~Yes ~ No Required working p~sure f~r B~ 3M; ~ 5M; ~ 10M; ~ 15M Other: // ~/~~~ y~/~ Commissioner the commission Date Approvedby L ~'/' k Form 10-401 Rev. 12-1-85 ' Submit in triplicate ARCO 'ALASKAo ! r,e ' Pad 2K, Well Nol 12 Kuper`uk Field, Nor' th Pr'opoeed SI ope, Alaska 1 000. 2000. 3000 ...... RKB..ELEV&T[O#, 15.¥ B/ PERMAFROST TVD=I 424 T/ UI3NU SNDS TVD=1544 KOP TVD=1965 TMD=1965 DEP=O 3 · T/ W SAK SNDS TVD=2163 TMD=2163 DEP=IO 9 BU[ LO 3 DE{3 1 $ PER 100 FT B/ W SAK SNDS TVD=2734 TMD=2756 DEP=161 27 EOC / 9 5/8' CSG PT TVD=2934 TMD=2981 1(-10 TVD--3183 TMD=3270 DEP=410 DEP=264 400t AVERAGE ANGLE 30 DE G 28 M IN 5000 6OOO 7000 K-5 TVD=4608 TMD=4924 DEP=1249 T/ ZONE C TVD=6084 TMD=6636 DEP=2117 T/ ZONE A TVD=6120 TMD=6678 DEP=2139 TARGET CNTR TVD=6184 TMD=6752 DEP=2176 B/ KUP SNDS TVD=6247 TMD=6825 DEP=2213 TD (LOG PT) TVD=6419 TMD=7025 DEP=2315 I I 1 000 2000 VERTICAL SECTION I 3000 HOP ~NTAL PROJECTION S~,^LE 1 !N. = 1000 FEET ARCO ALASKA, !.~. Pad 2K. Wel I No, 12 PI-opo~ed Kuper. uk Field. Nol-th Slope, Alaeka SURFACE; LOCAT[ON, 21' FSL. 94' FEL SEC. 2. TION. R8E 1000 WEST-EAST 1000 0 1000 2000 .... i I I ¸m I 1000 _ 2000 _ 3ooo - TD LOC'AT [ O# ' 1405' FNL. 17'29' FWL SEC. 12. TIO#. RSE 3000 I SURE~ TARGET CENTER TVD-6184 THD-6?$2 DEP-21?6 SOUTH 1341 EAST 17'14 TARGET LOCAT[ON~ 1320' FNL. 1620' FWL SEC. 12. TION. R8E S 51 DEB 58 MINE 2176' (TO TARQET) 250 2OO 150 100 50 0 50 400 _ I 350 I I 300 .~ 250 "~ 200 _ 150 _ 100 _ 50 _ O ,,.= \ \ \ 900 100 '"",1300 %2700 \ \ \ "~ L.IO0 \ \ '" ~.500 I I I J TO0 70,~'500 500 7OO 5OO ""-900 ~"" 500 · 500 ~oo / 2300 · 500 · ~oo ~ ~"53oo / / / 2500 / / ~ ¢1500 ~2~00 - I 250 200 1 50 1 O0 50 0 50 400 350 300 250 200 150 100 50 _0 DRILLING FLUID PROGRAM Spud to 9-5/8" Drill out to Weight up surface casing weight up to TD Density 8.8-9.0 8.7-9.2 10.0 PV 15-30 5-15 1 1-16 YP 20-40 8-12 8-12 Viscosity 70-80 35-40 35-50 Initial Gel 5-15 2-4 3-5 10 Minute Gel 1 5- 3 0 4- 8 5-1 2 APl Filtrate 10-15 10-20 6 pH 9- 1 0 9.5-1 0.5 9.0-10.5 % Solids 10 +/- 4- 7 1 2-1 5 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.0 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - There are no wellbores within 200' of the proposed well as it is the seventh well to be drilled on the pad. The first six wells are at least 75' away at the surface, which would be the closest point to date. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and' cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) 'Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casin!). Pressure test to 3500 psig. 11) Downsqueeze Arctic pack' and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13} Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17} Perforate and run completion assembly, set and test packer. 18} ND BOPE and install Xmas tree. 19) Change over to diesel. 20} Flow well to tanks. Shut in. 21} Secure well and release rig. 22} Fracture stimulate. OEGASSER MUD CLEANER SHALE SHAKERS STI STIR STIR TYPICAL MuD SYSTEM SCHEMATIC KUPARUK. RIVER'UNIT 20" DIVERTER SCHEMATIC .I !_ DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP~)N WELD STARTING HEAD 3. FMC D IVERTER ASSEMBLY WITH TWO 2-1/16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL WI10" OUTLETS 5. 10" HCR BALL VALVES W/10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTEI=L VALVES CAN BE REMO~.LY CONTR(~ ! F_r3 TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION 3 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. ?_ CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES ~ ~i f ~" .... " JG 4/26/88 -7 6 DIAGEaM ti 1t-r-u/8' SCX30 PSI ~ BOP STAOI ACCLM. LAT~ CAPACI~ TEST 5 4 1~-5/8' B(IP STACK TEST I. FILL BCP STACK AFO Q4CKE MtNIFCM3 WITH ~IC DIESEL. 2. CIEO( THAT all LCI3( ~ ~ IN t~.LI-E. AD AR[ FLLLY RETRACTE~ iF, AT TEST PLLI~ IN ~ELLi. E. aD WITH RLI~II~ JT AI~. RLIq IN L(X3(1331~ ili31[t~E~, 3. CL.OSE AI~LL~ l~rV~ER ~ UMaJ~ KILL al~D C:I'O~ LIllE V~LViS tOJAiEN7 TO g S'I'iO(. ~.L VaLV~ MD ~ Sl40LLD ~ ClaEN. 4. PRESSI.J~ UP TO ~ ~ il~ HOLD FOR IO M[~ IN-. 'R C~EASE PI~gSI.I~ TO 3CX:X3 PSI AI~ HI~LD FI~ I0 BLEED PREg~I. RE TO 0 LII'~ VALVE& CLOSE TCP Pll~ RN~ ~ lICE CN KILL AM:) Q40(E LIltS. TEST TO 250 ~I al~D ~ ~I AS IN 5'1t:P 4. CI3~IN.E TESTII~ .ail Vii. VI!S, LIl~r.~ al~ WITH i 2513 PSI LOW il~ 3000 I~I I'tI(I~ 'rEST AS I.~ STEP 4. 2 [ I0,.CLOSE: BLII~) ~ ~ TEST TO 2~0 PSI ~ ~ PSI. M~/tlF'CLD N~ LIliES N~E FU.L CF NDN.-FI~EZING FLUID. SET ALL VALVES IN CRILLING POSlTI~ 12. TEST b"T~IPE VALVES,. Idql yo KELLY ~ CRILL PIPE SAFETY VALVE. At~ Ik6II:~ ~ TO 250 PSI 3000 PSI. '~' FCe~ SZ(~, A~O SOO TO mlU. ZN~ ~ISm. d~!i ~:!~ ,~.,,~ VF..EKLY THEI~AFTER F~I~Y CIPERATE BCPE: 51006400 ARCO Alaska, Inc. Post Office Box /00360 Anchorage, Alaska 99510-0360 Telephone 90'?" 276 1215 December 12, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Conductor As-Built Location Plat- 2K Pad /c~ (Wells i - 24) Dear Mr. Chatteron: Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4618. Si ncerely, If you have D. Marti n Engineering Aide DM'hf Enclosure RECEIVED DEC 1 1988 Alaska Oil & (~as Cons. Commissioj} Anchorage GRU13/010 ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany N.T.S. SECTION SECTION · WELLS 1-12 ARE LOCATED IN SECTION 2, T. I0 N., R. 8 E., UMIAT MERIDIAN. WELLS 13-24 ARE LOCATED IN SECTION II, T. I0 N., R. 8 E., UMIAT MERIDIAN. SECTION I PROTRACTED Notes: SECTION CORNER T ION \ I. COORDINATES ARE ASP. ZONE 4. SECTION ?. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S.L. RECEIVED 4. O.G. ELEVATIONS FROM CED- RIXX-3311, re~4. 5. HORIZONTAL POSITION BASED ON 2'K CONTROL MONUMENTS PER LOUNSBURY 8, ASSOCIATES. DEC 1 :~1988 6. REFERENCE FIELD BOOK, L 88-40, pg5. 55,56, 58,59, 65 8, 66. Well ASP's AlaSt':a uli c,. C,.a.'s Ck,,~:. Ca,'~ m:.~'.::".,".Dist. Dist. O.G. Pod No. 'Y' 'X' i..~'~I;1;MI~LI~ LONGITUDE F.S.L. EE.L. Elev. Elev. I 5,938,600.18 498,310.17 70°14'36.519" 150°00'49.133" 2~6' 94' 114.0 118.5 2 5,938,575.14 498,310.28 70o14' 36.273" 150°00'49.130'' 271' 113.9 3 5,938,550.30 498,310.35 70°14' 36.029" 150°00'49.128" 246' 113.8 4 5,938,525.46 498,310.06 70o14' 35.784" 150°00'49.136'' 22:2' 113.8 5 5,938,500.19 498,310.12 70o14' 35.536" 150°00'49.154'' 196' 113.8 6 5,938,475.14 498,310.33 70°!4'35.289" 150°00'49.128" 171' , 113.8 7 5,938,450.36 498,310.36 70014' 35.046" 150°00'49.12:7" 146' 113.8 8 5,938,425.30 498,310.18 70° 14' 34. 799'' 150° 00' 49.132:'' 121' 113.8 9 5,938,400.30 ~ 498,309.98 70o14' 34.553" 150°00'49.13T" 96' 113.8 I0 5,938,375.19 498,310.14 70° 14' 34.306'' 150°00'49.133" 71' 113.9 ! I 5,938,350.22 498,310.14 70°14'34.061 " 150°00'49.133'' 46' i' 113.9 t' 12 5,938,325.20 498,310.17 70°14'33.815'' 150°00'49.131" 2:1' 94' 113.9 118.5 i EN.L. 13 5,938,235.31 ~ 498,310.37 70° 14' 32.930" 150 °00'49.125'' 69' 94' 113.7 118.5 14 5,938,210.14 498,310.16 70o14'32.683" 150°00'49.131" 94' 113.7 15 5,938,185.12 I 498,310.16 70o14'32.437" 150°00'49.131" 119' 113.8 16 5,938,160.11 498,310.20 70°14'32.191" 150°00'49.130" 144' 113.8 17 5,938, 135.21 498,310.18 70Ol4'31.946'' 150o00'49.130'' 169' 113.9 ~ 18 5,938, 110.19 498,310.29 70°14'31.700" 150°00'49.12:?" 194' 114.0 19 5,938,085.20 498,310.27 70°14'31,454'' 150°00'49.12:?'' 219' 114.0 20 5,938,060.14 498,310.22 70°14'31.207" 150°00'49.128" 244' 1'14.1 21 5,9 38,035.16 498,310.16 70° 14' 30.962'' 150° 00'49. 130'' 269' I' 114.0 22 5,938,010.40 / 498,310.19 70°!4'30,718'' 150°00'49. 129" 294' 94' 114.0 23 5,937,985.32j 498'310'13 70°14'30.471'' 150o00'49.130'' 319' 95, 114.0 ' 24 .51937,960.;:'9 498,310.08 70°14'30.2Z5" 150° 00'49. 132" 344' 95' i 113.9 118.5 I HEREBY CERTIFY THAT I AM TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS BY ME OR UNDER MY DIRECT SUPER- VISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF NOVEMBER gO~ 19B8. ARCO Alaska, Inc. DRILL SITE 2.K CONDUCTOR AS-BUILTS Oe. ~y.' M.O'D CA.~y.;,5'G,,"/'/ ,$/~/'. I o~' I giefe.'ll/21/88 ~'.No. NSK 6.2:11. d 4 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE 1o (2 thru 8) 7- a- o (8) (3) Admin~ 9. (9 thru '13) 10. (10 and 13) 12. 13. (4) Casg (14 thru 22) (5) BOPE -~..~qf ~-$-$? (23 thru 28) thr% 31) (6) Add: Geology$ DWJ ~ Company;/~--c::~ Lease & Well No . /~--~ YES NO Is the permit fee attached .......................................... ~--- -- 2. Is well to be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ ~ 6. Is well to be deviated and is wellbore plat included .............. 7. Is operator the only affected party ............................... [ 8. Can permit be approved before fifteen-day wait .................... . 14. Is conductor string provided ........................................ ~ 15. Will surface casing protect all zones reasonably expected to 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. Eng.~n ~ee~ring: LCS ~/~/~ BEW / rev: 01/30/89 6.011 Does operator have a bond in force .................................. Z Is a conservation order needed ...................................... ~ Is administrative approval needed ............... · ................. Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ' .... serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing we!lbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate/~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~d)~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: .) 0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. ' To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. AbASKA COMPUTING CENTER WEbL NAME : 2K' 12 FZEbD KU:PARUK BOROUGH ~ NORTH SLOPE REFERENCE NO : ?3465 LIS Tape Verification Listin~ Schlumberger AlasKa Computin_~ Center 17'$EP']989 I6:13 **** REEL HEADER SERVICE NAME t EDIT DATF t 89/09/17 ORIGIN : FLIC REEL NAME : 73465 CONTINUATION # : PREVIOUS RE~L : COMVENT : ARCO ALASKA, INC, ,KUPARUK ,2K - 12 ,50-103-20109-00 **** TAPE HEADER SERVICE NAME : EDIT DATE : 89/09/17 ORIGIN : FLIC TAPE NAME : 73465 CONTINUATIO. # : ! PREVIOUS TAPE C~M~ENT : ARCO ALASKA, INC, ,KUPARUK ,~K - 12 ,50-103-20109-00 **** FI~E HEADER **** FXL~ NAME : EDIT ,001 SERV : 001A02 V~RSI§~ : F~IC : 89/09/17 : 102~ : PAGE: 1 SCH~UMBERGE~ WE~::SERV::IC. ES COMPANY NAME: ARCO A~A.SKA' INC, FIELD: NUMBER: 50,,,103-20109,,00 ~OCATIO , . 21 ,$~ & SECTION: 2 P: ION RANGE:: 'BE PER~ANENT DATUM: MSL EI~EVATION: O' Tape Verification Llstino chlumberoer AlasKa Computln~ Center 17-SGP-1989 16:13 PAGE: ELEVATIONS DATE LOGGED: RUN NUMBER: TD DRILLER: TD LOGGERs KB: 154' DF: 153' GL: 113' 08-SEP-1989 ONE 7106' 7097' 9 5/8" 47 LB ~ DRILLER DEPTH OF 302t' AND LOGGER DEPTH OF 3020' BIT SIZE 1: 8 1/2" ~ 7106' TYPE FLUID IN HOLE: bSND POLYMER DENSITY: 10,3 VISCOSIT¥I 39 PHI 9 FLUID LOSS: MUD RESISTIVITY1 FILTRATE RESISTIVITY: MUD CAKE RESISTIVITY: ,5 3 ~ 75 ,89 e 75 2,89 ~ 75 TIME CIRCUbATI. ON ENDED: 0g:45 g-8 TIME LOGGER ON BOTTOM: 14:15 g-8 MAXIMUM TEMP RECORDED: 129 bOGGING DISTRICTI LOGGING ENGINEER: RUDHOE BAY . WARNER_ LDWEN/DIXON ~9 NLM BC lO!b DIC DA417 CNC A1238i IE~ BDI290 FIELD REMARKS: I 1/2" STANDOFFS AND 2' HOLE FINDER ~ATRIX DENSITY., 2,6 NEUTRON MATRIX ~ SAN , 0 DATE jOB STARTED: 17-SEP-89 jOB::REFERENCE MOl 73465 LDP/ANA{ R, KRUWELL LIS TaPe Verif1cation Listing SChlumberger AlasKa Computing Center 17-8EP-1959 16513 50-103-2010g-00 "MAIN PASS LOG DATA" DATA SAMPLED EVERY -,5000 FEET DATA INCLUDED - TOOL EXTENSXON TOOL TYPE USED NAME D{T'D ,DXb FDC ,FDC CN~'A/D/H ,CNb GR ,CSG DUAL INDUCT20N FORMATION DENSITY COMPENSATED NEUTRON GAMMA RAY PAGES , TABLE TYPE { CONS TUN! VALU K ,12 SEC NT ORTHSLOPE DEFI e ame Field Location P ENGI T Service .O'rder:~Number permanent datum Log Measured From TOD FT , BLI FT ~ T Bottom Log Interval TLI FT : rCS ime cfrcuIation S'topped S~E.~ DEG'F 5, . Tape Verification Listing SChlumberger AlasKa Computing Center 17-SEP-1989 I6:I3 TABLE TYPE t CURV DEF! ILM IL-Me um Resisti BFLU SFL Unaveraqed SP Spontaneous Potential GR Gamma Ray TENS Tension DPHI Density Po~ositF RHOB BUI~ Density D~HO Delta FFDC Far FDC Count Rate NFDC Near FDC Count Rate RFFD Raw Far FDC Count Rate RNFD Raw Near FDC CouDt Rate CAS! Caliper G~ Gamma TENS Tenslon ~PH! NEUTRON POROSITY ~ON RATIO TNR POR NEUTRON POROSITY OUTPUT FRO~ AN APPLICATION PROGRAM PAGE: 4 65: 6 6 : : : : :: : Tape verification Listino Chlum~erger Alaska ComputlnO Center 17'SEP'Igsg 16:13 TYPE REPR CODE VALUE 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NRME SERV UNIT SERVICE APl AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT F O I 'I 4 68 0000000000 ILD DIL OHMM 548737 O0 000 O0 0 i 1 I 4 68 0000000000 ILM OIL OHMM 548737 O0 000 00 SF2U DIL OHMM 548737 00 000 00 BP DIL NV 548737 O0 G9 DIL GAPI 548737 O0 E NS DIL LB 548737 ~0 PHI FDC PU 548737 0 R , FDC 000 O0 000 O0 00~ O0 O0 O0 0 0 0 0 I I 1 4 68 0000000000 1 I 4 68 0000000000 ~ 0000000000 0000000000 LIS Tape Yeriflcatlon Listinq Schlumberger Alaska Computin~ Center 17-$EP-1989 16~13 TENS.FDC 1860.000 NPHI.CNL 37 RTNR,CNL 3,418 NPOR.CNL 36 CNTC,CNL 2072.422 CFTC,CN5 664 G~.CSG -999,250 TENS,CSG -999 DEPT SP RHOB RFFD TENS RTNR CNTC GR DEPT SP RHOB RFFD TEN8 RTNR CNTC DEPT SP RHOB GR DEPT SP DEPT T:F:NS , 7100, ,DIL '25, ,FDC FDC 2146 FDC 2154 CNL CNb 2071 CSG -999 ,DIL ,FDC ,FDC ,FDC .CNL ,CNL FDC F DC FDC NL FDC FDC CNL CNL FDC FDC FDC 903 TNPH,CNL 0 000 ILD 750 G~iDIL 341 DRH FDC 000 RNFD,FDC 000 NPHI.CNL 418 NPOR CNL 422 CFTCICN5 250 TENS,CSG 1807 37, 36, 664, '999. 7o : oo 34 i 224 185 000 3254 000 3 980 ooo 25O GR DRHO RNFD NPH! NPOR CFTC TENS ,DIL 2 .DIb 92 FDC 0 FDC 140t CNb 46 CNb 45 CNL 50O CSG -999 69O0 -1 2 405 264 "999 000 ILD.DIL 2 DRHO,FDC 0 000 RNFD,FDC ~t38:3 000 NPHI'CNL 44 840 NPOR,CNL 4:3 544 CFTC.CNL '498 250 TENS'CSG .999 000 I~D,DIb 250 ;R;DIL 42.5 DRRO'FDC 000 RNFD'FDC 000 NPHI,CNib 609 NPO CNL 6700 ~999 000 ILD GR 500 RNFD 000 NPHI 1.87 NPOR 460 CFTC 250 TENS 650 ILM DIL 3 TENS~DIb 000 CALl FDC 903 TNPH:CN~ 674 RCNT,CNL 701 GR,CNL 25O 6600 -3 2920 0!00 IL.D 545 GR 439 DRHO 00:0 RNFD 000 NPHi OO2 000 O45 000 419 25O 639 250 ,DIL 4,388 ,FDC . *:FDC: ~1,14 ,C. Nb :,34 ,CNL 796 ,CSG "999 250 4.5 .DIL ,FDC .FDC .CNL 053 36 674 2024:173 92.063 TNRA.CNL RCFT.CNL TEN$.CNL 3 172 584:004 1860.000 2.882 2154 000 1046 000 8 023 36 674 2024 173 92 063 SFLU.DIL DPHI,FDC NFDC,FDC GR,FDC TNRA,CNL RCFT,CNL TENS.CNL 3.474 18 745 922 500 92 063 3 172 584 004 2154 000 IL~,Dlb TENS DIL FFDC FDC CALl FDC T~PH CNb RCNT CNL GR CNb 2 3254 893 I0 42 1635 92 006 SFLU.DIL 000 DPHI'.FDC 000 NFDC,FDC 070 GR,FDC 475 TNRA,CNL 764 RCFT,CNL 000 TENS,CNL 2~'726 ,818 73 9~'500 ,000 3,800 405~338 3254,000 Ib~ ~E. NS FDC DIL 2 3264 659 840 SFLU,DIL 000 DP:HI * FDC 000 NFDC,FDC · FDC: ,CNL 3,300 15,996 701.500 9~ 625 GR D:!b:!: : 9,318 DIL' 3004.:000 DPHI'FDC 48~ DC,FDC GRi,FDC 5 9,O00 ,438 3004 I'LM 4 536 SFLU 4, CNb: 2! 66 CNL 84 Ib~, DIL :: ,',:, 45.6 758 ,FDC 5:44,: 500 NFDC,FDC :64 ;FDC ~ 9.461 GR;FDC 10~: TNPH~CN5 46,354 TNRA.CNL t/r verification Listing Schlumoerger Alaska Computing Center 17-SEP-1989 I6:I3 PAGEs RTNR.CNL 4,059 NPOR,CNb CNTC,CNL 1711,027 CFTC,CNb GR,CSG -999,250 TENS,CSG DEPT, SP,DIL RHOM,FDC RFFD FDC TENS FDC RTNR CNb CNTC CNb GR CSG DEPT, SP =MOB FDC RFFD FDC TFNS FDC R?NR CNb CNTC CNL GR CSG DEPT. SP.DIL DC R C .CNL ,CS~ DEPT. C:NTC DEPT FDC 46,208 RCNT,CNb 454,874 GR,CNL '999,=50 6~00,000 12.094 2,383 1137,000 3070,000 3,891 1814,799 '999,250 ILD DI5 GR DRHO FDC RNFO FDC NPH~ CNL NPOR CNL CFTC CN~ TENS CSG 2,924 184.625 0 013 1225 000 4~ ~83 39 21 529 277 -999 250 6400,000 '~3,039 '999,250 '999, '999,250 -999'250 -999,250 IbD.OIb GR.DIb DRHO.FDC RNFD,FDC NPHI,CNb NPOR,CN~ CFTC,CNL TEN$,CSG 3,078 226,250 '999.250 '999.250 '999,250 '999, '999,250 6300 -21 -999 -999 00 ILD,DIL 16 GR,DIL 250 DRMO~FDC 250 RNFD,FDC 250 NPH[,CNL 250 CFTC,CNb 250 TEN$,CS¢ 3 138 -99 -99~ 6200 000 ILD,DIL §,563 'GR.,DI~ ,250 DRHO.FDC H~ FDC CNL -999 TENS CSG 4 024 -99'9 '99'9 -999 250 000 766 ' 0 25 250 GR.DiL FDC FDC .FTC ENS 6000,000 IbD,DI~ 781 GR,DI~ 250 DRHD.FDC ~999 250 RNF ,~FDC 999 250 NPH~,CN~ iRTNE CNL -999 250 NPOR,CNL 1675,952 RCFT,CNL 102.125 TENS.CNL TEN$,DIb FFDC,FDC CALI,FDC TNPH,CNb RCNT,CNL GR,CNb 559, 9. 40, 1808, 184, 039 SFLU,DIL 000 DPHI.FDC 000 NFDC.FDC 711 GR.FDC 762 TNRA ~NL 994 RCFT: NL 625 TEN$.CNL ZLM.DI5 TENS,DIL FFDC,FDC CALI,FDC TNPH,CNL RCNT,CNL GR,CNL 3 234 SFLU.DIL ooo '9'999 =50 NFDCiFDC I~ DI~ ~EN D'I~ GR '999 ~ :,llSF[~U,DIb 000 DPHI,FDC 250NFDC-:FDC 250 ~R,'FDC 250 TN=A, 250 RCFT. 250 · TENS,CNL IbM DXL 4.235 SFSU 000 DIL! ~!8:6:0~ 250 ~FDC. FDC :999' FDC i !~999,25O' CN5 :999;250:GRTNRA 999~50 -9.99 -99'9 CNb - 999 C'N L ' 99'9 C.NL -999 :335FL:U,DIL 000 DPH'I.FDC 250NFDC,FDC 250 GR.FDC ' TNRA,CN!L::i999 RCFT,CNL 999 250 TENS,CNL -999 3, ILM,DIL 3 ::999; FFDC;FDC .999~250 CA~,FDC :999 -999,250 i TNPH'CN~ '99:9 -999,250 RCNT,CNL '999 55'7 :SFLU.DIL 000 DPHI,FD~ 250 NFDC~FDC 250 GR,FDC ~2501 'TNRA;CNL 250 RCFT,CNL 41~,357 292 ,000 1 . 09 606,000 184,625 3,597 47~,140 307 ,000 4 228 -999 250 -999 250 -999 250 -999 250 '999 250 -999 250 250 -999 2:50 4.792 250 3.750 -999 250 Tape Verification Listtnq ~hlumberger AlasKa Computlnq Center 17-SEP-1989 16113 PAGE{ CNTC CN5 -999,250 CFTC,CNL -999,250 GR,CNL G~:CSG -999,250 TEN$,CSG -999,250 DEPT, SP,DIL RHOB,FDC RFFD FDC TENS:FDC RTNR,CNL CNTC,CNL G~,CSG DEPT, SP.DIL RHOB FDC RFFD TENS RTNR CMTC DEPT SP RHOB RFFD TENS GR FDC FDC CNn CNL CS~ 5900 000 -26 328 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ILD,DIb GR,DIb DRHO,FDC RNFD,FDC NPHI,CNL NPOR,CML CFTC,CML TEN$.CSG 2,980 ILM,DIb 120,125 TEMS,DIh '999,250 FFDC,FDC '999,250 CALI,FDC '999,250 RC ~,CNL '999,250 GR,CNL '999,250 580O 000 '29 547 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 IbD GR,DIL DRHO,FDC RNFD.FDC NPHI,CN& NPOR,CNL CFTC,CNL TENS,CSG 2 940 119 500 -999 250 -999 250 -999 2~0 -999 250 -999 250 -999 250 IL~,DIL TENS,DIL FFD~,FDC CAL ,FDC TNPH,CNL ~CNT,CNL GR,CN~ 5700 ILD,DIL 4,140 ILM,DIh DIL -$6 GR,DIL . 85,000 DI,~ DRHO'FDC .999,250 FFDC,FDC FDC ~999 TENS, FDC ~999 RNFD,FDC ~999,250 CAL~ FDC ~999 NPH'i,CNL 999;250 TNPH CNL ~999 250 NPOR,CNL .-999=, CNL 999 250 CFTC;CML '999~ CSG -999 250 TEN$,CSG -999,250 s .oo DIL]] TENS,FDC ~999 RTNR ,C,NL ~999 ,CNL .'999 , CSG 999 DEPT ~R DIb 8 RNF~ 99 50 NPO ' 250 CFTC,Cb 999 250 TENS,CSG '999 5500 000 -27 547 'GR -999 250 DRHO FDC -999 FDC '9'99 CNL 999~ CSG -999,250 TENS NPH:.~ NPOR CFTC DEPT, 5~00,000 SP'DIL . 35,34.4 ,FDC ~999, ,FDC 999, TENS"FDC .:~999.,250 RTN~,CNL ~999,250 CNTC,CNL 1999,~250 IbM DIL FDC FDC CNb ,CNL -999 250 GR -999,250 TENS.CNL -999,250 3 094 SFLU DIL 2814 000 DPHI FDC -999 250 NFDC FDC -999 250 GR FDC -999 250 TNRA CNL -999 250 RCFT CNL -999 250 TENS,CML 3.313 -999 250 -999!250 -999 250 -999,250 -999,250 -999,250 3 059 SFLU,DZL ooo 999 25 GR,~DC -999 250 TNRA,CNL -999 250 RCFT,CNL -999 250 TENS,CNL 3,211 '999,250 '999,250 '999,250 '99 250 -99~' ,250 -999,250 4,217 SFLU DIL 4 529 FDC CNL '999 999 CN~ ~999 -999 CNL 999 2:50 :~TE.NS CNL -.999 250 3 142 SFLU, DIL . 2 925 2 FDC ~999 2!5:0 FDC 999 250 . FDC:: FDC :"99:9 CNL-999 CNL '999 CNL. 99 '~99 CML= -999,250 CNG CNL -999,250 CNL -999 250 NFDC FDC 250 ::0~ F.DC 250 TENS CML -999 250 Ta~e Yerlflc~tlo~ ~lstlng $chlUm erger Alaska ¢o~putfn~ Cen~er 17'~£P'1989 16~13 GR,CSG "999,250 TENS,CSG '999,250 DEPT. 5100.000 ILD,DIL RFFD:FDC :~g 250 RNFD.FDC TENS.FDC ~99,250 NPHI,CN5 RTNR,CNL 99,250 NPOR,CNL CNTC,CNL '99~.250 CFTC.CNL GR.CSG '99 .250 TEN$.CSG DFPT. RHOB FDC RFFD FDC TENS FDC RTNR CNG CNTC CNG GR SP DiG HOB,FDC FFD.FDC TENS FDC RTNR CNG 5200 000 -27 047 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ILD,DI~ D GR.DIL RHO'FDC RNFD,FDC NPHI,CNL NPO.R,CNL CFTC,CML TEN$,CSG DRHO'FDC RNFD'FDC ,CNb ,CNL ,CNG ,CSG DEPT 5000 FDC -999: FDC -999 -999 GR · 4~00,000 ILD,DIL ,DIS 32,563 GR,DI5 ,FDC '999~:250 DRHO,FDC 'FDC '999'250 RNF.D;FDC ,FDC :~999 -N ,CNG '2999 ,CNG .CNL C~ TC,CNL :~ ,CNG GR.CSG .CSG DEPT FDC FDC CNL CNG 4800 ILD DIG -999 -999'250 RNFD [DC -999,250 NP'HI NL '999,250 NPOR CNG '999,250 CFTC CNG -999;250 TEN$..CSG GR PAGE) 3 351 IbM,DIG 121:188 TENS,DIG -999,250 FFDC,FDC '999.250 CALI,FDC '999.250 TNPH'CNL '999.250 RCNT.CNL "999,250 GR.CNG '999.250 2,598 141,750 '999,250 "999,250 '999,250 '999,250 "999,250 '999,250 IbM TENS FFDC FDC CAL! FDC TNPH CNG RCNT CNG GR CNG TNPH, RCNT, GR,CNG 424 oI:ooo !99.250 99.250 99,250 99.250 999.250 DPHI DC NFDC FDC GR FDC TNRA CNL RCFT CNL TENS CNL 25O '999,250 -999.250 -999,250 -999.250 '999,250 2 657 SFLU.DIL 2530 000 DPHI.FDC -999 250 NFDC.FDC -999 250 GR.FDC -999 250 TNRA.CNL -999 250 RCFT.CNL -999:250 TENS.CNG 2,927 -999.250 -999 250 '999 250 -999 250 '99g,250 -99 ,250 -999 -999 - 99 -999 772 SFLU,DIL ~ 000 DPHI.FDC '99 250 NFDC, 250 GR, TNRA CN~'"999 RCFT' ,CNL "999 250 TENS-CNL '99,9 ,DiL 520 "':9:.9 ,.9999 · .999 250 3 258 . '"'999 250 GR FDC ":':"~99 FDC ' 99 999 CNL -999 ,,:250: R 'T ~NL ::: 199.:9 250 ::TNRA C:NL 250 RCFT: CNL 250 CNL -999 248: SFGU.DIL PHI:,FDC FDC;F'DC .50 GR.FDC 50 INRA.,CNb 250 !.RCFT,C,NL 25.0 LIS ?ape Verification List.inq Schlumberger Alaska Compt]tln~ Center PAGE{ I0 DEPT, SP,DIL RHOB.FDC RFFD,FDC T~NS,FDC RTNR,CNL CNTC,C~ GR,CSG 4700 000 -41 344 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 fLD,DI6 GR,DIL DRHO,FDC RNFD,FDC NPHf,CN6 NPOR,CN6 CFTC,CNL TENS,CSG DEPT, SP,DIL RHOB,FDC RFFD,FDC TENS,FDC RTNR.CNL CNTC,CNL GR,CSG 4600,000 '37,563 '999,250 '999,250 '999,250 '999,250 -999,250 -999.250 IbD,DI6 GR,DI6 DRHO,FDC RNFD,FDC NPHI,CN6 NPOR,CN6 CFTC,CNL TEN$,CSG DEPT. SP RHOB FFD RTNR C.TC GR 4500,000 OIL .'3B,094 FDC 999~250 ?DC :999;2S0 FDC 999e2'5o CNL :999,250 CNL 999.250 CSG '999,250 ILD, DX6 GR,DIL DRHO ~ FDC 3.5B5 IBN,DI6 .109,625 TENS,DX6 999,250 FFDCeFDC -999.250 CALI,FDC ~999,250 TNPH'CN5 .999,250 RCNT,CN6 999,25'0 GR.CNL -999.250 2 505 8~ 313 -99 250 -999 250 -999 250 -999 250 -999 250 -999 250 TENS FFDC FDC CALf FDC TNPH CNb RCNT CNL GR CNb 3,021 BB, -999' "999,250 ~CAL! -999;250 TNPH "999, -999; -999,250 DEPT, 4400,000 IbD,DI6 2 SP'DIL '43,3i3 GR~DX~ 137 RHO:B,FDC ~999,:250 DRHO.'FDC RFFD;FDC ~999,250 RNFD;FDC ':99 TENS'FDC ~999,250 NPH~,CNb -9!99 ,250 ' NPOR.,CNL 9:99 RTNR,CNL 2999 ,cur :299'9;250 cr c,cN ,csa 999,250 ?ENS,CS¢ " DEPT. 4300,000 ILD DI6 2 CNL -999 250 NPO CNL '999 250 CFT~ CSG -999 250 TENS.CSG -999 G~ 3.701 2454.000 -999.250 -999.2.50 -999.250 -999.250 -999.250 SFLU DIL DPH! FDC NFDC FDC GR FDC TNRA CNL RCFT CNL TENS CNL 4.144 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 .DIL RH'OB FDC RF'FD FDC CNL CSG 2 555 SFLU DIL 2520 000 DPHI FDC -999 .250 NFDC FDC -999 250 GR FDC -999 250 TNRA CNL -999 250 RCFT CNL -999 250 TENS CN~ 2.612 -999 250 -999 250 -999 250 -999 25O -999 25O -999 250 4200 000 ILD,DI. 6 '46 875 GR,.Di6 -999 ~,.rDC .FDC 250 NPH~,iCNL 250 NPO .CNL 250 CFTC,CNL 250 TENS~CSG DX6 3 045 SFLU.DIL 2 968 · FDC 250 ,FDC . 250 250 GR,FDC ~999 250 250 TNRA;CNL ~999 250 250 CFT,CNL 250 TE~S"CNL GR -999 '999 -9 ~99 UU, DI:L HZ, FDC 2.50 NFDC:, FDC: 2 50 GR' FDC 250 250 XLM DIL 2,704 SFLU,DIL 2 320,~000 FDC DPHI, :DIb: :::,.:~ ' 9 99:9~250 NFDC'FDC '999 FDC : 9:9 9:99'250 ::G:R,FD.C - 9 :.99 -9:9:9'250: TNRA;CNL '99:9 CN~.: :-999,250 RC~T'CNL CNL '999~2:50 TENS;CNL :':999 GR DIL :3'8I-7 ':SFSU,DI6 Di:L FDC ::999,25'0 FDC: 999,250 CNb ~-999,250 TNRA,C.Nb CN~ ~9991250~ RCFT~C~ 999,250 -999 2 5 0 LIS Tape Verification Listing Schlumberger AlasKa Computing Center 17'$EP-1989 16:13 .PAGE~ 11 DFPT. SP.DIL RHOR.FDC RFFD.FDC TENS.FDC RTNR CNL CNTCiCNL GR CSG 4100 000 -43 844 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ILD.DXL GR DXb DRHO FDC RNFD FDC NPH! CNL NPOR CNL CFTC CNL TENS CSG 2 896 72 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 TENS Dlb FFDC FDC CAbI FDC TNPH CNL RCNT CNb GR CNL 2 889 SFLU,DIL 232~ 000 DPHI,FD¢ -99 250 NFDC,FDC -999 250 GR,FDC '999 250 TNRA.CNL '999 250 RCFT,CNL -999 250 TENS.CNL 2 562 -999 250 -999 250 -99~ 250 -99 250 -999,250 -999.250 DEPT SP RHOB RFFD TENS RTNR CNTC DIL FDC FDC FDC CNL CNL 4000 000 -45:313 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 I.LD.DIL GR,DI5 DRHO.FDC RNFD,FDC NPHX,CNG NPOR.CNL CFTC,CNL TEN$.CSG 3 i19 103 938 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ILS DXL TENS DIL FFD FDC CALY FDC TNPH CNL RCNT CNL GR CNL 3 103 SFGU,D~L 2250 000 DPHI.FDC -999 250 NFDC,FDC -999 250 GR.FDC -9.99 250 /NRA,CNL -999 250 RCFT.CNL -999 250 TEN$,CNL 3 207 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 DEPT. SP RFFD TENS RTNR CNTC GR FDC F DC FDC cCNL NL ooo - 250 DRHO FDC -999 250 RNFD FDC -999 250 NPH! CN5 -999 -999 -9.99 2:50: ~TENS~CSG 2 785 92 750 -999 250 -999 250 IL~.DIL TEN&,DXL FFDC,FDC ALZ,FDC NPH,CN5 GR,CN5 ~I.I~755 SFnU.DIL 2999,000 DPHI,FDC 250 NFDC,FDC ,i999,~$0 GR,FDC :999.250 TNRA;CNL ',999&250:1 RCFT, -999.250 TENS. 2 575 '999 250 '999 250 '999 ~999 999 -999 -999 000 fLD,.DIL 125 GR,DXL 25:0 DRHO, FDC 250 RNFD~FDC 250 : .NPH~,.CN~ 250 NPOR~CNL 250 CFTC"-CN:~ 250 TEN$.~CSG '999: '999 ,8:t:7: iSFLU,DfL ~000 DPHi~'FDC -999;250 GR,FDC CNL : .-999,~.50 TNRA,CNL CNL -999;250 RCFT,~NL CN~ -9:99,:250 TE. NS.: NL ~99 DEPT. CSG 3700. 000 '47,' -999 -999 250 '999 250 99 -999 250 ILD DIG 2 919 ILM,DIb DIb ~94 ,DI.~ FDC -999 .FDC FDC CNL -999~2 0 TNPH CNL '9'99~250 TENS CSG '-999-25:0 999 25,0 FDC::,~999 250 TNRA CNL '999 ~CN:L: '999 CNL '999 DEPT, 3~00' SP,DIL 50 RHOB,FDC RFFD,FDC '99 TN~,CNL ~999 CNTC,CNL .999 GR.CSG 999 000 ILD,OIL 406 GR'DiL ,FDC ,FDC 250 : NPHI,CNL 250 ~POR~CNL 250 CFTC.CNL 250 TENS'CSG ,999' 3 T:EN$;DXL ~0'80~000 DPHI'FDC 2999; ;FDC '~9:99,250 . GR~FDC : :. 999,:250 ~99!9:;2 0 :R~NT;CNL 299'9;250 RCFT~ 999, GR,CNL 999..250 TEN:S~.CNL ' 0 25: IS Tape Yeriflcation Listing chlumberger AlasKa Computing Center 17-SEP-1989 16:13 1.2 DEPT, SP,DIb RHOB,FDC RFFD FDC TENS FDC RTNR CNL CNTC CNL GR DEPT, SP,DIL RHOM FDC RFFD:FDC TENS FDC RTNR:CNL CNTC,CNL GR,CSG DEP'T, SP R~OB FDC ~S FDC RTNP CNL CNTC CNL GR CSG DIL DEPT, GR DEPT SP RMOB RFFD 35O0 000 -49 875 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 3400,000 -51,844 -999,250 -999,250 -999,250 -999'250 -999,250 -999,250 3300 000 -54 -999 "'999 -999 -999 906 25O 25O 250 25O ILD.DIb GR,DIL DRHO.FDC RNFD.FDC NPHI,CNb NPOR,CNh CFTC,CNL TEN$,CSG ILD,DIL GR,DIL DRHO FDC RNFD:FDC NPMICNb NPOR!CNb CFTC CNL TEN$,CSG ILD,DIb GR,DIL DRHO'FDC RNFD,FDC NPHI'CNL ,CNb ,CNL TEN$,CSG ~000 ILD ~688 250 DRHO :250 RNFD 3100,000 DIL -54 FDC -999 ~999 999 CSG -999 250 30,00 DIL -138 FDC .-999 FDC '999 FDC -999 CNL '999 CNiL -999 CSg 51 ILD DIL FDC DC Nb TEN$~CSG 2 798 92 25O -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 4 027 63 594 -999 250 -999 250 -999 -9,99 2~0 -999 250 ILM.DIL TENS,DIL FFDC,FDC CALI,FDC TNPH.CNL RCNT,CNL GR,CNL ILM,DIL TENS.DIL FFDC,FDC CALI~FDC TNPH,CNb RCNT,CNL GR,CNb 2 657 SFLU,DIL ooo Dc 'ggg 250 TNRA NL '999,250 RCFT,CNL -999.250 TENS,CNL 3 889 SFLU 2025 000 DPHI:FDC -999 250 NFDC,FDC -999 250 GR,FDC '999 250 TNRA,CNL '999 250 RCFT,CNL -999 250 TENS,CNL 3,403 IL 3 '999,250 ggg -999, FDC. ~999 -999' CML 999 '999'250RCNT CNh -999 '999;250 G~ CNL '999 '999,250 '"999 'ggg '"999 '999 "9g.g I ,DIb 13 'DIL . 4:5 ,FDC ~999 ,FDC 9.919 250 NPH~,CN~ -999 2.50 NPOR,CN~ '999 ,250 CFTC,CNL -999 ,313 TEN$'CSG ~795 256 SFLU,DIL 000 DPHI,FDC 250 NFDC.FDC 250 TNRA,CNL 250RCF~C~L 250 TENS,CNL 3 3'59 250 ' g 99 '999 ~ CNb "'999 CNL ' 999 C.NL - 99:9 250NFDC 250 GR 250 TENS CNL 2 677 -99 250 -99~ 250 -999 250 -999 25O -999 250 -999 250 ~,L~,DIL 3 ~ENS,DIL ~:70 FDC;FDC 9:9 ~:CN'L 999: .,CNL~ !999 ,CNL 999 -99~ 442 25O -999 250 -999 250 -999 250 '999r250 '999.250 GR 3 227 -999 250 -999 250 ':999 '999 99:9 999 -99' 25I SFLU,DIL . 3 000 DPH~,. FDC ~999 250 ;~D¢ ,OIL 2000,O00 SFLU,DIL ,DIL 1880~000 DPHI.FDC ~FDC ,CNL ~99'9;250 R~FT;~NL ,CNL 999,.250: TENS,C~L 20090 -'9 g -999 317 IS TaPe Verification Listing chlUmberger Alaska Computin~ Center PAGE: 13 DEPT. 2900.000 SP.DI5 '999.250 RHOB.FDC '999.250 RFFD,FDC '999,250 TEN$.FDC '999.250 RTNR.CNL '999,250 CNTC.CNL '999.250 GR.CSG 41.b25 DEPT SP RHOB RFFD TENS RTN~ CNTC 2800,000 DIL '999.250 FDC '999,250 FDC '999,250 FDC '999.250 CNL '999'250 '999.250 63,000 DEPT, 2700 000 SP~DIL -999 250 2 ,o E~s~c ~9~ 250 R~N~ CNL -99~ GR CSG 47 ; ILD GR DIL DRHO FDC RNFO FDC NPHX CNb NPOR.CNL CFTC.CNL TENS,CSG ILD.DIL GR,DI[, DRHO.FDC RNFD.FDC NPHI.CNL NPOR.CNL CFTC CNL TENS:CSG ILD DIL GR:DIL DRHO.FDC RNFD,FDC NPHI.CNL ,CNL ,CNL TEN$,CSG DEPT RFFD TENS GR RHOB RFFD TENS RTNR CNTC.CNL 2500.000 ILD DIL 99 9999 250 GR DIL - 250 DRHO FDC 2400 '999 '999 '999 0:0 ILO 50 GR 250 NPHI. 250 NPOR '999.250 '999;250 '999.250 '999,250 '999.250 '999,250 1999.250 820.000 ILM,DIL TEN$.DIL FFDC.FDC CALI.FDC TNPH CNL RCNT CN6 GR CNL -999 250 SFLU DIL -999 250 DPHI.FDC -999 250 NFDC.FDC -999 250 GR.FDC -999 250 TNRA.CNL -999 250 RCFT.CNL -999 250 TENS.CNL '999 250 '999 250 '999 250 '999 250 '999 25O '999 25O '999 250 '999 '999 '999 '999 '999 '999 -999 1765 250 250 250 250 250 25O ooSO O0 ILM.DI6 TEN$.Di6 FFDC.FDC CALI.FDC TNPH,CN6 RCNT,CN6 GR.CNL '999 250 SFLU,DIL '999 250 DPHI.FDC '999 250 NFDC.FDC -999 250 GR.FDC -999 250 TNRA.CNL -999 250 RCFT.CNL -999 ~50 TEN$.CNL '999.250 -999,250 '999,250 =999 250 '999 250 '999 25O -999 250 -999 250 -999 250 -999 250 000 TENS FFDC DI6 -999 250 SFLU.DIL -999 250 DIL ~99 ~2:50 DPHI.'FDC -999 250 FDC ~ 99 250 NFDC.FDC -999 250 FDC -999 25.0 :GR,FDC CNL -999 250 TNRA.CNL ~99 250 TENS,cNL '999 999 25.0 99 -999 '"999 '999 2:5:0 GR 1745 000 ,~DI6::: "999.250 S.F6U,DIL ,DIL '9'gg;250~D~'~,FDC N. FDC, ,'FDC .:999.250 :CN~ ~ ;9~9,250 ~N~A,cNL ,CNn -999 250 '999 1710 250 IL~.DI6 ~999 250 TEN$:,DI:!~ ~99..9 250 F~b'~iFDC :999 250, : 'CAL:i,FDC 250 :TNPH;C'N~ '9 'CN~ 000 25!0 SFLU, DIL '999,250 ,:CNL : .- ,C'NL -9'99 TaPe Verification Llst!ng chlumberger AlasKa ComputlnQ Center PAGE~ 14 DEPT. SP,DI5 RHOB,FDC RFFD,FDC TEN$,FDC RTNR,CN5 CNTC.CNL 2300.000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 44 313 ILD.DIb GR.DIb DRHO,FDC RNFD,FDC NPHI.CNL NPOR,CNL CFTC,CNL TEN$.CSG 99 -999 -999 -999 -999 -999 1600 250 ILM,DI5 250 TEN$'DIb 250 FFDC,FDC 250 CALI.FDC 250 TNPH,CNb 250 RCNT,CN5 250 GR,CNL 000 -999 250 SFLU,DIL -999 250 DPHI,FDC -999 250 NFDC,FDC -999 250 GR FDC '999 250 TNRA:CNL '999 250 RCFT,CNL '999 250 TENS,CNL '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 DEPT SP, RHOB, RFFD TENS RTNR CNTC GR FDC FDC FDC CNb CNb 2200,000 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 42 094 ILD,DIb GR,DIL DRHO FDC RNFD FDC NPHI CML NPOR CNL CFTC CNb TENS CSG -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999~250 1545 000 IbM DIb TENS FFDC FDC CALl FDC TNPH CNL RCNT CNL GR,CNb -999 250 SFbU DIL -999 250 DPH! FDC -999 250 NFDC FDC -999 250 GR FDC -999 250 TNRA CN5 -999 250 'RCFT CNL -999 250 TENS,CNL -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 DF, PT RFFD TENS FDC FDC FDC C.NL CN5 2100 000 ILD,DIb '999 250 GR,DIb -999 250 DRHO.FDC ~999:250 RNFO;FDC 999 250 NPHI,CNL 250 N:pOR,~Nb 250 CFTC; Nb 26 609 TENS'CSG 999 FDC '99 ,2 0 GR 1510,000 =999 250 SFLU DIL 250 DPH! FDC 250 NFDC FDC 250 TNRA -99~ 250 250 250 250 50 CNb CSG ,250 ~,.DiL ,ggg ,,250 .DR~ .rOC ,250 RNF~'FDC 99:9 CNb CNL ' 9'9 DKPT, i900 000 ILD,DIL -999 250 ~HSP,DI'b GR,D:Ib R!!.OB~FDC RMO.~FDC · FDC ,~250: RNFD,FDC :999: ,FDC ,~.50 NPMI~CNb 999 ,CNb: .-999~250 N:POR,CNL 'r'999 .CNL -999,.250 CFTC'CN~ '999 G~,CSG 45 969 T'ENS:'CSG 13:80 000 DIb '999,250 'GF'bU D:lb: ~FDC '999~250' NFDC 'FDC :GR ;CNL ~'9:9'9;25'0 TNRA '¢NL DIL =999,250 ~:2:5::0 ,250 CNL :999'250'250 CNL: ::999,:250 C'NL ' 999:'250 ,CNb ,CSG RDRHO NFD FDC FDC .CNL CSG IbM EN$ GR,CNb -999 .2:50 TEN$,CNL '99:9 '999 '99:9 25O LIS TaPe Verification Li. stln Schlumberger AlasKa Computin~ Center 17-SEP-1989 16:13 PAGE{ 15 DFPT, SP,DIL RHOB,FDC RFFD,FDC TENS FDC RTNR~CNL CNTC,CNL GR,CSG DEPT SP~DIL RHOB FDC RFFD FDC TENS FDC RTNR CNL CNTC CNL GR CSt DEPT, RHSP,DIL '.'OB,FDC RFFD,FDC TEN$,FDC RTN~,CNL CNTC,CNL GR,CSG DIL RHOB FDC RFFD FDC F:DC CNL P I L FDC FDC FDC CNL CNL CSG DE DIL ,FDC .FDC TENS,FDC RTNR,CNL CNTC,CNL GR,CSG 1700,000 '999 250 '999 250 '999 250 '999 250 '999 250 '999.250 53,188 ILD,DIL GR,DIL DRHO,FDC RNFD,FDC NPHI,CN5 NPOR,CN5 CFTC.CNL TENS,CSG 1600,000 '999,250 '999,250 '999,250 '99~ 250 '99:250 '999,250 26,734 {LD,DIL GR.DIL DRHO,FDC RNFD,FDC NPHI,CNL NPOR,CNL CFTC,CNL TEN$.CSG 1500 000 -99 -99~ 250 25O -999 250 -999 250 -999 -999 37, 81 ILD DIL GR:DIL DRHO,FDC RNFD,FDC NPHi,CNL 'CNL TEN$.CSG -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 1330 000 '999 250 '999 250 -999 250 '999 25O '999 250 '999 250 -999 250 1290 000 -999 250 -999 -999 '999 -999 ~400,000 IL DIL 999,250 DRH ,,FDC "999 2999;250 RNF~'FDC -999 ~999,250 NPH4,CNb -999 ~999;250 NpO ,CN5 -999 999, CN~ -9~9 47; CSG i2 0 13.00 000 ILD 000 -999 250 'I'L~ IL~,DIL TEN$,DIL FFDC,FDC CALI,FDC TNPH,CNL RCNT,CNL GR.CNL IL~,DIL TENS,DIL FFDC,FDC CALI FDC TNPH CNL RCNT CNL 'GR CNL ILM DIL DI, L FDC -999 -999 17 8 4,4 DC "99 NL CSG ~200,000 999.250 ~.DIL '999,250 DRH 'DiL '999.250 RNF~'FDC ;FDC "999,250 NPH{,CNb '99~ 250 NPOR'CNL :2: o 000 -999 250 SFLU,DIL -999 ~50 DPHI,FDC -999 50 NFDC FDC -999 250 GRiFDC -999 250 TNRA CNL -999 250 RCFT,CNL -999 250 TENS,CN5 -999 '999 '999 -999 -999 '999 -999 50 250' 25O 250 25O 25O -999,250 SFbU.DIL -999,250 DPHI,FDC -999,250 NFDC,FDC -999 250 GR,FDC '999 250 TNRA,CN~ -999 250 RCFT,CNL -999 250 TENS.CNL -999 250 -999 250 -999 250 '999 250 '99 '99~ 250 25O -999,250 -999 999 999 -999 ,250 250 ,250 CNL ,250 .~.999~250 : ,999,:250 DIL -999,250 SFLU.DIL DIL -999i ,FDC FDC -999 ;'FDC FDC~: CNL '9:~9 ,~DC CNL:~ :i~99-9' CNL "9~9 BTCF~, ENS. -999 250 -999 250 -999 250 -999 25:0 SFLU:,DIL ' 9.9~9,i2:50 '999'250 250 : NFD~,FDC ~99:9,250 ~999;250 ,CNL '~99.9,250 4CNL ~9994250 250 ~.ENS'CNL! :9:99:'2:50 LIS Tape Vertticatlon Listing Schlumberger AlasKa ComPotinq Center 17-SEP-1989 16=13 PAGE= 16 DEPT. RHOB.FDC RFFD FDC TENS FDC RTNR CNL CNTC CNL GR CSG 1100,000 ILD -999,250 GR~ IL '999,250 DRHO,FDC -999,250 RNFD,FDC -999,250 NPHI,CNL -999250 NPOR,CNL . TEN$,CSG DEPT, SP,DIL RMOB,FDC RWFD,FDC TENS,FDC RTNR,CNL CNTC CNL GR' ,CSG !000,000 999,250 '999 250 -999 250 -999 250 -999 250 -999250 56 188 DEPT, SP DIL RHOB FDC RFFD FDC TENS FDC RTNR CNL CNTC CNb GR CSG 992 -999 -999 -999 -999 :999 999 43 000 250 25O 250 250 25O 25O ! 88 ** END OF DATA ILD GR DIL DRHO FDC RNFD FDC NPHZ CNL NPOR CNL CFTC,CNL TENS,CSG ILD OIL GR DIL DRHO FDC RNFD FDC NPHI CNL NPOR CNb CFTC CNL TENS,CSG -999250 -999250 -999250 -999250 -999250 -999250 -999250 1200 000 -999250 -999250 -999250 -999250 '999. 250 -999250 -999 250 1125 000 -999 250 '99~'250 -99 ,250 -999, '999, "9.99,250 '999,250 1135,000 ILM,DIL TENS FFDC FDC CALI FDC TNPH CNL RCNT CNL GR CNL ILM.DIL TENS,DIL FFDC,FDC CALI,FDC TNPH,CNb RCNT.CNL GR.CNL TEN$,DIL FFDC,FDC '999 250 SFLU,DIL -999 250 DPHI,FDC -999 250 NFDC.FDC -999 250 GR,FDC -999250 TNRA,CNL '999250 RCFT,CNL '999250 TENS.CNL '999250 '999250 '999250 '999250 '999250 '999250 '999250 '999 250 SFLU,DIL '999'999 ~5050 DPHI,FDC NFDC,FDC '999 250 G~,FDC -999 250 TNR ,CNL -999 ~50 RCFT,CN5 -999 50 TENS.CNL -999,250 -999.250 -999250 -999250 -999250 -999250 -999250 -999 999 -999 '999 250 SFLU,DIL -999 250 25.0 DPHI,FDC '99925.0 250 N R ~ ,CNL -999 'C~T, TENS, **** FILE TRAILER **** : EDIT ,001 : FbIC O0 AO LAST FILE : **** FILM 'HEADER : ,002 VERdi, ON = 00lA02 DAT : 89/09/I7 IZE : 10'24 : bO LAST FI:bE BIS Tape verification Listing schlumberger AlasKa Computtn~ Center 17-SEP-1989 16~13 PAGE 17 FILE - EDIT,002 ARCO ALASKA, INC, KUPARUK 2K - I2 50-103-20109-00 "HZGH RESObUTION DATA" DATA SAMPLED EVERY-,lO00 FEET DATA INCbUDED - TOOL EXTENSION TOOL TYPE USED NAME FDC ,FDH FORMATION DENSITY CNT.A/D/H ,CNH CONPENSATED NEUTRON TABLE'TYPE=CONS COU ENG WITN SON 1.09"'00 I.:,': F'St~ & 94"::: FEb Fie:ld.:,:boca:t:icn Section ano ov~nce me ber Permanent datum EDF STEM FT FT FT FT DEGF LOg ~easured FrOm LIS Tape Yerificatton Listing Schlumberger Alaska Computing Center PAGE~ 18 TABLE TYPE : CURV DEPT DEPTH CHANNEL NAME DPH! Density Porosity RHOB BuI~ DensitY DRHO Delta tho FFDC Far FDC Count Rate NFDC Near FDC Count Rate RFFD Raw Far FDC Count Rate RNFD Raw Near FDC Count Rate CAL! Caliper GR Gamma Ray TENS Tension NPH! NEUTRON POROSITY TNPH THERMAL NEUTRON POROSITY TNRA CALIBRATED THERMAL NEUTRON NPOR NEUTRON POROSITY OUTPUT FRO DN PROGRAM RCNT RAW CORRECTED NEAR THERMAL COUNTS RCFT RAW COR. RECTED FAR THERMAL COUNTS C~TC CORRECTED,NEAR THERMA~ COUNTS CFTC CORRECTED FAR THERMAL COUNTS R: :: Gamma- Ray ENS Tension DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64ED ** TYPE R. EPR" CODE VAbuE .1 66 ' 0 '~ 66 12 15 66 16 66 0 66 ~ .I$ Tape Verlfication 51stinq chlumberger Alaska Computin6 Center 17-SEP-1989 16:13 PAGE~ 19 ** SET TYPE - CHAN ** E SERV UNIT SERVICE APl API APl AP H MB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) -------------------------------------------------------;-------------------------~FT 548737 O0 000 00~ 2 ! 4 b8 0000000000 O0 000 O0 0 2 1 ~ 4 68 0000000000 DPH! FDH PU 548737 RHOP FDH G/C3 548737 O0 DRHO FDH G/C3 548737 00 FFDC FDH CPS 548737 O0 NFDC FDH CPS 548737 O0 RFFD FDH CPS 548737 00 RNFD FDH CPS 548737 O0 CALl FDH IN 548737 O0 GR FDH GAPI 548737 O0 TENS FDH b8 548737 O0 NPH! CNH PU 548737 00 TNp~ CNH PU 548737 00 TNRA CNN 5487:37 00 NPOR CNH PU 548'737 O0 0 O0 000 O0 0 2 000 O0 0 2 000 O0 0 2 000 O0 0 2 000 O0 0 2 000 O0 0 2 000 O0 0 2 000 O0 0 2 000 O0 0 2 000 O0 0 2 000 O0 0 2 ooo oo § 000 O0 00 O0 ,0 ~ O0 O0 0 1 1 4 68 0000000000 I ! 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 1 ~ 4 68 0000000000 I I 4 68 0000000000 1 I 4 68 0000000000 I I 4 68 0000000000 1 i 4 68 0000000000 I ! 4 68 0000000000 1 I 4 68 0000000000 ! I, 4 68 0:000000000 1 1 4 68 0000000006 I 4 1 4 0 1 oo o° o ** DATA DEPT FD~ FDH C~ C~H FDH 7 8~,867 GR 110.000 DPHi 5 ,500 NFDC 5'~:~'5:91 ~.NRA ,738:CNTC 1855,:000 FDH 3 894 R HO.B FDH FDH FDH 71;00 580 ~PHI,FDH FDC.FDH 3~ .FDH .CNH CNTC.CNH 2054 219 2.,586 DRHO. FDH I,:'19 !' :000 RNFD,,.FDH :36', 591 RCNT ,CNH 656'431 GR,CNH RHOB, FDH ' 2 RFFD' FDH 11:9 I TENS-, FD:H 2144 POR' CNH ':36 CF!TC, CNH 65:6 586 :DRHO,.FDH 000: 'RN'FD;FDH 000 NP.H!,CNH: 591 Ac T;c ,43:1 GR, CNH DEPT 7000,000 DPHI FDH :107~ FDR CNH 42 CNH CNH 449 CNH CNH 3154 000 3H 2 R HOB. FDH; 00'0 R. FFD, F:.DB 063 ::'TEN$:,F:D~ 611 : N~OR,~NH 0 6 , C)' C. C N 14: 2 215 DR[tO:.FDH ,FDH 717 R.CN T' .C N H 405 : G:R,~CNH 0 232 1'5:27 36 t0 4 bis Tape Verification bisting Schlumberger Alaska Computing Center 17-'SGP-1989 16~13 2O DEPT. FFDC,FDH CALI,FDH RCFT,CNH TENS,CNH 6900 000 649 000 9 016 45 483 435 838 3244 000 DPHI.FDH NFDC,FDH GR.FDH TNRA,CNH CNTC.CNH DEPT. FFDC.FDH CALl FDH TNPH' ,CNH RCFT,CNH TENS.CNH 6800 000 492 500 8 719 28 O83 857 138 2994 000 DPHI,FDH NFDC.FDH GR,FDH TNRA.CNH CNTC.CNH DEPT. FFDC FDH CALl FDH TNPH CNH RCFT CNH TENS CNH 6700.000 DPHI,FDH 450,000 NFDC,FDH 8,984 GR.FDH 36,632 TNRA CNH 628,842 CNTC:CNH 3024.000 DEPT FFDC CALl FDH FDH CN~ CN, CNM 6600,000 DPHI,:FDH 640;000 NFDC,FDH 9'484 GR'FDH 44;867 TNRA,CNH ~395'.172 CNTC,CNH 3010;000 DEPT TNPH CNH RCFT CNM TENS CNH 6500 000 DPHI FDH 59~ F.D~ 2884 00'0 FOB FDH 492 .GR FDH 151 TNRA CNH 837 CNTC CNM 000 END OF DATA ** 13 477 3 722 1766 693 RHOB,FDH RFFD'FDH TEN$,FDH NPOR,CNH CFTC.CNH 14 421 550 500 73 5 2768 346 RHOB,FDH RFFD,FDH TENS,FDM NPOR.CNH CFTC,CNH 10.110 RHOB FDH 580 500 RFFD FDH 85!438 TENS FDH 072 NPOR CNH 227~,224 CFTC CNH lo) 1698 344 RHOB, F,DH 000 RFFD,FDH ,FDH C:FT:C:,-C. NH 17 318 RHOB FDH FFD 1956 708 CiF:T:C CNH 2.428 1245.000 3244,000 45.190 478.773 DRHO FDH RNFD FDH NPHI CNH RCNT CNH GR CNH 2 412 DRHO.FDH 1031 000 RNFD.FDH 2994 000 NPHI,CNH 25 800 RCNT.CNH 1075 190 GR,CNH 2 483 DRHO,FDH 927 500 RNFD,FDH 3024 000 NPHI.CNH 3'6 674 RCNT,CNH 724 238 GR;CNH 4612. 427 ,FDH , FDH RCNT;CNM GR, CNM 3'64 DRHO, FDH 00:0 : RNFD,: FD.M: 00o N:P'~I 006:: :RC~T:,C~ 4'71 'GR,CNH 589 572 GR 0,119 1540,000 46,507 1664.134 96,688 '0 009 1062 000 26 650 286 7~ 277 875 0 026 1123 000 34 650 2285 ~083 85 438 082 00o I05 0,019 , .0 1t'30 :375 ~ISTape Verification 51stinq SchlUmberger Alaska Computin~ center 17-SgP-1989 16:13 PAGE{ **** FILE TRAILER ~ FILE NAME : EDIT .002 SERVICE : FLIC VERSION : OO1A02 DATE : 89/09/17 MAX REC SIZE : 1024 FILE TYPE ~ LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE ~ 89/09/17 TAPE NAME ~ 73465 CONTINUATION # PREVIOUS TAPE COMMENT : ARCO ALASKA, iNC. ,KUPARUK ~2K - 12 ,50-103-20109-00 SERVICE NAME EDIT DATE : 89/09/1.7 ORIGIN ~ FbIC : 73465 .- ARCO ALASKA, 'INC. ,KUPARUK : : : :: :: : ~ :: :. :: : : : :: :::. :::.:
