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189-118
Originated: Delivered to:10-Apr-25 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1Y-27 50-029-22379-00 909953476 Kuparuk River Packer Setting Record Field- Final 1-Apr-25 0 1 2 1Y-27 50-029-22379-00 909915690 Kuparuk River Packer Setting Record Field- Final 20-Mar-25 0 1 3 1Y-27 50-029-22379-00 909953476 Kuparuk River Packer Setting Record Field- Final 31-Mar-25 0 1 4 1Y-29 50-103-21852-00 909915382 Kuparuk River Multi Finger Caliper Field & Processed 23-Mar-25 0 1 5 2A-04 50-103-20026-00 909976821 Kuparuk River Multi Finger Caliper Field & Processed 31-Mar-25 0 1 6 2K-20 50-103-20120-00 909966603 Kuparuk River Multi Finger Caliper Field & Processed 26-Mar-25 0 1 7 2T-20 50-103-20215-00 909915691 Kuparuk River Multi Finger Caliper Field & Processed 13-Mar-25 0 1 8 2V-10 50-029-21310-00 909915383 Kuparuk River Packer Setting Record Field- Final 17-Mar-25 0 1 9 3T-731 50-103-20905-00 909991288 Kuparuk River Cement Evaluation with CAST Field & Processed 2-Apr-25 0 1 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 193-088 188-091 184-053 189-118 195-029 185-048 224-156 T40310 T40310 T40310 T40311 T40312 T40313 T40314 T40315 T40316 4/10/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.10 14:23:59 -08'00' 62K-20 50-103-20120-00 909966603 Kuparuk River Multi Finger Caliper Field & Processed 26-Mar-25 0 1 189-118 MEMORANDUM TO: Jim Regg `i 3�1��7.t1Lt7 P.I. Supervisor FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 11, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2K-20 KUPARUK RIV UNIT 2K-20 Ste: Inspector Reviewed By,: P.I. Supry Comm Well Name KUPARUK RIV UNIT 2K-20 API Well Number 50-103-20120-00-00 Inspector Name: Matt Herrera Permit Number: 189-118-0 Inspection Date: 3/6/2020 IRSp Num: mitMFH2O0307083222 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well zK-zo Inj�SPTTe tType 6143 Tubing 2660 2660 - 2660 - 2660 . PTD 1891180 T¢ 1500 IA 560 610 - 625 - 625- BBL Pumped: 10.8 BBL Returned: 0.8 CIA 130 1990- 1920 1900- Interval REQVAR P/F I P Notes: MIT -OA 2 Year Interval to Allowable OA Pressure Per AIO 2C.041 ✓ Wednesday, March 11, 2020 Page l of 1 MEMORANDUM To: Jim RBBB 'elY 3II ZvJ� P.I. Supervisor FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 11, 2020 SUBJECT: Mechanical Integrity Tests ConoccPhillips Alaska, Inc. 2K-20 KUPARUK RIV UNIT 2K-20 Src: Inspector Reviewed By: P.I. Suprvl:9?Z Comm Well Name KUPARUK RIV UNIT 2K-20 API Well Number 50-103-20120-00-00 Inspector Name: Matt Herrera Permit Number: 189-118-0 Inspection Date: 3/6/2020 , Insp Num: mitMFH2O0307082356 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2K-20 Type Inj W TVD 1 6143 1 Tubing 1 2660 - 2660 - 2660- 2660 - PTD 1891180 Type Test SPT Test psi 2700 - IA 1660 3300 3200 3185 BBL Pumped: 2.6 ' BBL Returned: 2.6 - OA zaa aoo 390 - 385 - Interval REQVAR P/F P Notes: MIT -]A to Maximum Anticipated Injection Pressure 2 year interval per AIO 2C.041 Wednesday, March 11, 2020 Page 1 of 1 Wallace, Chris D (GED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Tuesday, March 17, 2020 9:22 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: KRU 2K-20 (PTD 189-118) Report of suspect IA pressure increase Attachments: 2K-20 90 -day TIO plot 3-17-20.pdf; 2K-20.pdf; MIT KRU 2K-20 03-06-20 .xlsx Chris, KRU injector 2K-20 (PTD 189-118) (AIO 2C.041) had been shut in since December 27th, 2018 and recently brought back on seawater injection February 23rd, 2020. The well passed a state witnessed MIT -IA on March 6th, 2020. After MIT -IA, the IA began showing pressure increases that seemed to be influenced thermally, however, the IA pressure stabilization period has been longer than expected. Therefore, CPAI is going to conduct initial diagnostics to verify the integrity of the well and investigate the IA pressure increase. The well will be monitored for 30 -days after the initial diagnostics are completed. If diagnostics or pressure monitoring indicate communication, the well will be shut in and secured as per NO 2C.041. Attached is a 90 -day TIO plot, a wellbore schematic, and the completed 30-426 from March 61h, 2020. Please let us know if you disagree or have any questions with this plan. Regards, Paul Duffy for Jan Byrne/Dusty Freeborn Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TERM cnmc�ips STATE OF ALASKA RECEIVED ALA.OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS MAR 2 0 2018 1.Operations Abandon H Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ j er tea' ih o vn ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: _packoff sealant_ ❑ 2.Operator ConocoPhillips Alaska, Inc 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development p ❑ Exploratory ❑ 189-118 3.Address: P.O.Box 100360 Stratigraphic ❑ Service ❑✓ 6.API Number: Anchorage AK 99510 50-103-20120-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25588 KRU 2K-20 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 9805 feet Plugs measured n/a feet true vertical 6590 feet Junk measured n/a feet Effective Depth measured 9450 feet Packer measured 9117 feet true vertical 6356 feet true vertical 6143 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 3688' 9-5/8" 3724' 2906' Intermediate Production 9769' 7" 9805' 6590' Liner Perforation depth Measured depth 9320-9396 feet SCANNED True Vertical depth 6273-6321 feet Tubing(size,grade,measured and true vertical depth) 2-7/8" L-80 9168'MD 6175'TVD Packers and SSSV(type,measured and true vertical depth) Packer Baker HB Retrievable 9117'MD 6143'TVD SSSV Otis FMX 1794'MD 1719'TVD 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: n/a n/a n/a n/a n/a Subsequent to operation: n/a n/a n/a n/a n/a 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 2 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 2 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: 317-573 Authorized Name: Kelly Lyons Contact Name: Kelly Lyons/Jan Byrne Authorized Title: Well Integrity Supe isor Contact Email: n1617@cop.Com Authorized Signature: Date:3-16-18 Contact Phone: 659-7224 RBDMS MAR 212018 Form 10-404 Revised 4/2017 Submit Original Only • ConocoPh i I I IV i ps Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 March 16, 2018 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 2K-20 (AIO 2C.041, PTD 189-118) for an attempt to repair an inner casing packoff void leak using Seal-tite. The pressure-activated sealant was pumped in December 2017. However,the inner annulus by outer annulus communication is still present. Therefore, an amendment to AIO 2C.041 will be submitted. Work was performed under Sundry#317-573. Please call Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, f Kelly Lyons Well Integrity Supervisor Attachments • , Date Event Summary 04/16/17 Reported to AOGCC for slow IAxOA communication due to leak in wellhead packoff. 12/15/17 (AC EVAL) : IC-PO Seal-Tite Repair(In-progress). Initial T/I/0 = si1075/260/285. IA FL @ 156' (4.7 bbls). OA FL @ 54' (1.6 bbls). Installed heat on wellhead. Bled IA to 30 psi in 76 min (multiple bleeds of gas only, FTS). Bled OA to 60 psi in 60 min (multiple bleeds of gas only, FTS). Seal-Tite rep repeatedly purged IC-PO to clean out old sealant. Left 2500 psi on IC-PO for overnight fall off. Final T/I/0 = si1075/30/75. 12/18/17 (AC EVAL) : IC PO Seal-Tite Repair(In progress). Initial T/I/0 = SI 1075/30/130. IA FL @ 150' (decimeter, 4.5 bbl FUV). OA FL @ 72', 1.9 bbl FUV). IC PO @ 130 psi. Bled OA to 35 psi in16 min (gas). FTS. Pressured OA incrementally to 1500 psi w/2.95 bbls diesel. Bled IC PO void to flush out sealant. As OA pressure increased, IC PO bleed returns ceased to exist. Bled OA to 40 psi in 5 min (fluid). Pressured IA incrementally to 3000 psi w/ 10 bbls diesel. IC PO did not build pressure while IA was pressurized. Bled IA to 25 psi in 27 min (fluid). Seal-Tite rep repeatedly purged IC PO void to flush out old sealant. Final T/I/0 = SI 1075/50/60. 12/19/17 (AC EVAL) : IC-PO Seal-Tite Repair(In-progress). Initial T/I/0 = si1075/75/100. Installed heater on well head. Seal-Tite Rep pumped Gly-Flo into IC-PO & incrementally stepped the pressure up to 3000 psi, still having minor leak off(-25-50 psi in 15 min). Seal-Tite Rep mixed & pumped Pac-Seal into IC-PO. PO held 3000 psi for 2 hours. Left 2800 psi on wellhead for overnight cure time. Left heater on wellhead, notified DSO, well house door left open. Final T/I/0 = si1075/60/115 12/20/17 (AC EVAL) : IC-PO Seal-Tite Repair(Complete). MIT-IA to 3000 psi (Passed). Initial T/I/0 = SI 1075/60/120. IA FL @ SF. Seal-tite rep performed cold/heat cycle on IC-PO post seal-tite treatment. Pressured IA to 3000 psi w/4.85 bbls diesel. Starting T/I/0 = 1100/3000/370. 15 min T/I/0 = 1100/2940/365 (-60). 30 min T/I/0 = 1100/2920/365 (-20). Bled IA to 50 psi in 24 min (fluid, 5.4 bbls). IC-PO did not track IA during MIT-IA or IA bleed. Seal-tite rep performed second cold cycle on IC-PO post seal-tite treatment. Left IC-PO @ 2000 psi. Left heater on wellhead, notified DSO. Wellhouse door left open. Final T/I/0 = SI 1080/90/110. • • 12/25/17 (AC EVAL) : Pressure IC-PO post seal-tite. Initial T/I/O = SI 1540/825/110. IA FL @ 102' (decimeter, 3.1 bbl FUV). OA FL NS. Stung into IC-PO w/850 psi. Pressured IC-PO to 1500 psi. Periodically re-pressured IC-PO until stabilized @ 1500 psi for 30 min. Final T/I/0 = SI 1540/825/110. 01/23/18 (MISC) PRESSURE IC PO TO 1500 PSI / PRESSURE OA TO 400 PSI. Initial T/I/O = SI 1125/643/200. IA FL @ 84' (decimeter) FUV=2.5 bbl. OA FL @ 24' (decimeter) FUV=0.7 bbl Seal-tite IC PO @ 736 psi. Pressured the IC PO with hydrulic fluid to 1500 psi. Bled the OA to 70 psi in 7 min (gas). FTS Pressured up the OA to 400 psi with 0.74 bbl of diesel Final T/I/O = SI 1125/643/400 Well remained shut in until March 1, 2018 to observe well because prior to Seal-tite repair attempt, communication was more evident while shut in. 03/12/18 (SW/WC) : State witnessed (Brian Bixby) MIT-OA Passed to 2010 psi & MIT-IA Passed to 3200 psi. Initial T/I/0 =2540/850/290. IA FL @ surface. OA FL @ surface. Pressurized OA to 2010 psi w/0.8 bbls diesel. Starting T/I/0 = 2540/870/2010. 15 min T/I/0 =2540/890/1960. (-50). 30 min T/I/0 = 2540/890/1940. (-20). Bled OA to 290 psi (bled back 0.8 bbls). Initial T/I/O= 2540/860/350. Pressurized IA to 3200 psi w/4.2 bbls diesel. Starting T/I/0 = 2540/3200/610. 15 min T/I/0 = 2540/3100/610. (-100). 30 min T/I/0 = 2540/3090/610. (-10). Bled IA to 860 psi (bled back 4 bbls). Re-bled OA to 150 psi (fluid). Final T/I/0 = 2540/860/150. Executive IAxOA communication via packoff leak developed in the well. Attempt to repair the leak with Summary pressure-activated sealant was unsuccessful. However the well is still able to pass MITIA and MITOA. Therefore an amendment to AIO 2C.041 will be submitted, to allow the well to remain on water-only injection. • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regg@alaska.gov. AOGCC.Inspectors(a�alaska.clov; phoebe.brooks(aialaska.gov chris.wallace('7a alaska.gov OPERATOR: ConocoPhillips Alaska Inc, FIELD/UNIT/PAD: Kuparuk/KRU/2K Pad DATE: 03/12/18 OPERATOR REP: Miller/Beck AOGCC REP: Brian Bixby Well 2K-20 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1891180 Type Inj W Tubing 2540 2540 2540 2540 Type Test P Packer TVD 6143 BBL Pump 4.2 IA 860 3200 3100 3090 Interval V Test psi 2700 BBL Return 4.0 OA 350 610 610 610 Result P Notes: MIT-IA to maximum anticipated injection pressure per AIO 2C.041 and per Sundry 317-573 post seat-tite treatment Well 2K-20 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1891180 Type Inj W Tubing 2540 2540 2540 2540 Type Test P Packer TVD 6143 BBL Pump 0.8 IA 850 870 890 890 Interval 0 Test psi 1800 BBL Return 0.8 OA 290 2010 1960 1940 Result P Notes: MITOA to 1800 for future AIO 2C-041 amendment application. Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result 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 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT KRU 2K-20 3-12-18.xlsx KUP INJ • 2K-20 " ConocoPhillips 01Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) c.ar000gylhpc 501032012000 KLJPARUK RIVER UNIT INJ 58.57 2,900.00 0,808.0 -°. Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date • 2K-20,9/27/201312.44'.27 PM SSSV:TRDP Last WO: 39.89 12/12/1989 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,458.0 8/1/2013 Rev Reason:SURFACE CSG PATCH osborl 9/27/2013 € I Casing Strings HANGER;31.1 . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread - �� CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 3,724.0 2,905.5 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(MKS) Set Depth(ftKB) Set Depth)T/D)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 33.0 9,805.2 6,589.9 26.00 J-55 BTC Tubing Strings i Tubing Description 'String Ma...I ID(in) 'Top(ftKB) I Set Depth(ft..J Set Depth(ND)(...I Wt(lb/ft) 1 Grade 'Top Connection maLya 9aa,TUBING 27/8 2.441 31.1 9,167.81 6,174.9 6.501 L-80 EUEBrdABMOD Completion Details - Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 31.1 31.1 0.01 HANGER FMC GEN IV TUBING HANGER 2.875 - 1,793.9 1,719.4 36.37 SAFETY VLV OTIS FMX SAFETY VALVE 2.313 .AAI CONDUCTOR;36.4115.0r44.nMls .MMA., 9,103.5 6,134.3 51.24 PBR BAKER 80-32 PBR w/10'STROKE 2.890 9,117.4 6,143.1 51.09 PACKER BAKER HB RETRIEVABLE PACKER 2.890 9,155.3 6,167.0 50.68 NIPPLE CAMCO D NIPPLE NO GO 2.250 9,166.9 6,174.3 50.56 SOS i BAKER SHEAR OUT SUB 2.375 SAFETY VLV;1,793.9 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) GAS LIFT;2,718.1 SURFACE CASING PATCH:54"X10".500 wall x 9/6/2013 658 tight fitting SC sleeve starting at the bottom of the starter head Perforations&Slots Shot Den Top(ND) Btm(ND) (shotsif Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 9,320.0 9,330.0 6,272.5 6,278.9 A-5,2K-20 3/7/2010 4.0 APERF 2 1/8"HES Strip Gun, Deep Star Millenium,+/- SURFACE;35.03,724.0-4 45 degree phase 9,362.0 9,396.0 6,299.4 6,321.21 A-4,2K-20 5/8/1990 4.0 IPERF 160 deg.Phase,4.5" GAS LIFT;5,602.2 Casing Guns Mandrel Details St I i I ati C °^ Top(ND) Valve latch Port Size TRO Run o GAS LIFT;7,475.1Et N° Top(ftKB) (ftKB) Make Motlel OD(in) LIFT Type Type (in) (psi) Run Date m 1 2,718.1 2,335.6 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/6/1991 2 5,602.2 3,992.6 MERLA TMPD 1 4GAS LIFT DMY BK 0.000 0.0 3/6/1991 ` 3 7,475.1 5,101.6 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/10/1990 4 8,561.3 5,800.2 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/6/1991 GAS LIFT;9561.3111 5 9,055.6 6,104.4 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/6/1991 Notes:General&Safety End Date Annotation _ 11/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;9,055.9ILE PBR;9,117.4 igii- PACKER;9,117.4 NIPPLE;9,155.3 SOS;9,166.9 APERF;9,320.09,330.0 - IPERF;9,362.0-9,396.04 PRODUCTION;33.0.9,805.2 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,March 19,2018 Jim Regg P.I.Supervisor�e 4 31e'‘)/6 SUBJECT: Mechanical Integrity Tests I I CONOCOPHILLIPS ALASKA,INC. 2K-20 FROM: Brian Bixby KUPARUK RIV UNIT 2K-20 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvJ&- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-20 API Well Number 50-103-20120-00-00 Inspector Name: Brian Bixby Permit Number: 189-118-0 Inspection Date: 3/12/2018 Insp Num: mitBDB180313045606 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 18911802K20Type Testi SPT~ 6143 fTubmg lI 2540 - 2540 • 2540 2540 PTDTest psi Well zK-zo Type Inj W850 870 890 890 ---_ 1800 IA I YP11 BBL Pumped: 0.8 BBL Returned: I o.s OA 290 1 2010 - 1960 • 1940 Interval OTHER 1P/F P Notes: This is a MIT-OA conducted to amend AIO 2C.041 Sundry Number 317-573.Thye had a passing MIT-IA for the current AIO a few months ago. les--dte. 44301w 7. wzu wcy sz tom ( p letca' i . Nec Pleo-tIA zoig SCANNED Monday,March 19,2018 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,March 19,2018 TO: Jim Regg 2 P.I.Supervisor, \ 3 2v�,� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 2K-20 FROM: Brian Bixby KUPARUK RIV UNIT 2K-20 Petroleum Inspector Src: Inspector Reviewed B P.I.Supry Jee— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-20API Well Number 50-103-20120-00-00 Inspector Name: Brian Bixby Permit Number: 189-118-0 Inspection Date: 3/12/2018 Insp Num: mitBDB180313050240 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2K-20 Type Inj W-TVD 6143 -Tubing 2540 25402540 2540 - PTD 1891180 'Type Test SPT Test psi 2700 - IA 860 3200 - 3100 - 3090 BBL Pumped: 4.2 BBL Returned: 4 " OA 350 610 - 610 - 610 - Interval REQVAR P/F P Notes: This is a MIT-1A conducted to amend AIO 2C.041 Sundry Number 317-573.They had a passing MIT-IA for the current AIO a few months ago. dui- 6/3O/-7 ; ( w(-s SZ t44411 19tAte,C « services Al ever zooe, SCANWEV Monday,March 19,2018 Page 1 of 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Saturday, March 17, 2018 7:53 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: KRU 2K-20 (PTD 189-118) Update and plan forward Attachments: 2K-20 AA amendment packet 3-16-18.pdf Chris, 2K-20 was returned to injection on March 1st and a passing witnessed MITIA and MITOA were performed on March 12th. The IA and OA pressures are holding a good differential pressure now. But this is not unexpected because this well was known to display the IAxOA communication usually only when off-line. Therefore I put together an AA amendment application packet and sent it off yesterday afternoon. Attached is an electronic copy for your reference. CPAI intends to keep the well online while the amendment request is processing. Please let us know if you disagree. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 From: NSK Well Integrity Supv CPF1 and 2 Sent:Wednesday, February 21,2018 7:57 PM To:Wallace, Chris D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: KRU 2K-20(PTD 189-118) Update and plan forward Chris, KRU injector 2K-20(PTD 189-118) (AIO 2C.041)was reported on April 16,2017 for exhibiting a very slow OA pressure increase. Previous reporting to the AOGCC and diagnostics showed that the Inner Casing Pack Off seals were known to be compromised and failed previous testing. Under sundry#317-573 an attempted repair of the Inner Casing Pack Off was attempted with a SealTite product. Unfortunately the repair was not successful as the OA pressure has resumed a very slow increase during the offline monitor period (the pressure communication has been easier to observe while the well is offline). At this point COP plans to bring the well on injection for a 30 day monitor period to observe for pressure build up while the well is online with the intent to amend AIO 2C.041 to additionally allow for IAxOA communication. An MITIA and MITOA will be performed during the monitor period. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 WELLS TEAM .41Conoc os 1 • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Wednesday, February 21, 2018 7:57 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 2K-20 (PTD 189-118) Update and plan forward Attachments: 2K-20 90ay TIO trend 2-21-18.JPG Chris, KRU injector 2K-20(PTD 189-118) (AIO 2C.041)was reported on April 16,2017 for exhibiting a very slow OA pressure increase. Previous reporting to the AOGCC and diagnostics showed that the Inner Casing Pack Off seals were known to be compromised and failed previous testing. Under sundry#317-573 an attempted repair of the Inner Casing Pack Off was attempted with a SealTite product. Unfortunately the repair was not successful as the OA pressure has resumed a very slow increase during the offline monitor period (the pressure communication has been easier to observe while the well is offline). At this point COP plans to bring the well on injection for a 30 day monitor period to observe for pressure build up while the well is online with the intent to amend AIO 2C.041 to additionally allow for IAxOA communication. An MITIA and MITOA will be performed during the monitor period. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 4111WELLS TEAM scow Conocataips 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Thursday, December 21, 2017 7:30 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of OA pressure anomaly 2K-20 (AIO 2C.041, PTD 189-118) update 12-21-17 Chris, Under sundry#317-573,we are currently in the process of repairing 2K-20's IC packoff seals utilizing Seal-Tite. Over the last several days,treatment has been applied and initial indications are that the seals are now holding. In the sundry application,we had proposed initially leaving the well shut in for 30 days post repair to ensure that the IAxOA communication was no longer present(the communication was only observed when the well was shut in). However, with Seal-Tite's recommendation, CPAI intends to return the well to water injection for up to 3 days to allow for a full thermal cycle of the treating product so that we can fully assess the efficacy of the repair. We will then shut the well back in and monitor for 30 days and continue with the plan as proposed in the sundry application. Please let us know if you disagree with the plan forward. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 swop From: NSK Well Integrity Supv CPF1 and 2 Sent:Sunday,April 16, 2017 5:09 PM •:chris.wallace@alaska.gov Cc: ••en, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: Re• of OA pressure anomaly 2K-20(AIO 2C.041, PTD 189-118)04-16-17 Chris, KRU injector 2K-20(AIO 2C.04 , 'TD 189-118) is currently AA'ed for TxIA communication while on gas injection. The well has been shut in for reservoir m. :ement since 01-26-17. During preparation of the monthly report,the OA was identified with a very slow unexplained rise'• •ressure. The inner casing packoff seals are known to be compromised and have repeatedly failed their packoff testing. - efore they are suspected to be the cause of the anomaly. It appears that there has been intermittent very slow IAx• ommunication going back several years now, initially reported to your office in January 2014 and most recently in •tember 2016. The well will remain shut in until a path forward can be established. Prior to returning the well to water in tion, proper paperwork will be submitted. Attached are the schematic and 90 day TIO plot. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7224 Mobile Phone (907)943-0170 1 IMMImiammeisivimme Ati OF T4, S • � � 7," SA THE STATE Alaska Oil and Gas 1,41 ;-s �, of® ®® sKA Conservation Commission Mist 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 rR ""���11�11RRfMain: 907.279.1433 o4t'ALAS1 Fax: 907.276.7542 www,aogcc.alaska.gov DEC Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-20 Permit to Drill Number: 189-118 Sundry Number: 317-573 Dear Ms. Lyons: 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, Cathy P. Foerster Commissioner DATED this ?Clay of December, 2017. RBDMMS 1 2017 • • STATE OF ALASKA • I RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS;} DEC O 7 20 AAC 25.280 2017 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well El ' Operations shutdown❑ Suspend ❑ Perforate 111 Other Stimulate 1:1 Pull Tubing ❑ '''t etioree9sremssictsw- An Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other:"4IIC-packo .d I 2.Operator Name: 4.Current Well Class: 5.Permit to DriIIT7uhi er.'- ConocoPhillips Alaska,Inc Exploratory ❑ Development ❑ 189-118 • 3.Address: . 6.API Number: Stratigraphic El ✓ PO Box 100360,Anchorage,AK 99510 50-103-20120-00 • 7.If perforating: N/A 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Wr KRU 2K-20 • Will planned perforations require a spacing exception? Yes ❑ No I I! {)2 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25588 • Kuparuk River Field/Kuparuk River Oil 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): 9805' • 6590' • 9450' • 6356' • 2750 none none Casing Length Size MD TVD Burst Collapse Structural 79' 16" 115' 115' Conductor Surface 3688' 9-5/8" 3724' 2906' Intermediate Production - 9769' 7" 9805' 6590' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9320'-9396' 6273'-6321' 2-7/8" L-80 9168' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV:Otis FMX - 1794'MD,1719'TVD Packer:Baker HB Retrievable • 9117'MD,6143'TVD 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑✓ • 14.Estimated Date for 11-Dec-17 15.Well Status after proposed work: 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. Authorized Name: Kelly Lyons Contact Name: Kelly Lyons/Jan Byrne Authorized Title: W- - egrity Supervises Contact Email: n1617t cop.com V/ Contact Phone: 659-7224 Authorized Signature: —llOir. Date: 3-Dec-17 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 11 1 3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yeso ❑ RBD 4 S (AL DEC 1 1 2017 Spacing Exception Required? Yes ❑ Nog Subsequent Form Required: JO ` go or i APPROVED BY Approved by COMMISSIONER THE COMMISSION Date:/2.E. /7 1 4117- i/n'-' `z/DI/ - ///���''' Submit Form and Form 10-403 Revised 4/2� Approved roved applica on is valid for 12 Rt GctttaAdt al. Attachments in Duplicate • • ConocoPhillips RECEIVED Alaska DFL 0 7 201? P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 ACC December 3, 2017 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 2K-20 (AIO 2C.041, PTD 189-118). The request is for approval to repair inner annulus by outer annulus communication via the packoffs using Seal-tite, a pressure-activated sealant. ✓ Please call Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, Kelly Lyons Well Integrity Supervisor Attachments ID • ConocoPhillips Alaska,Inc. Kuparuk Well 2K-20 (AIO 2C.041,PTD 189-118) SUNDRY NOTICE 10-403 INNER CASING PACKOFF SEAL REPAIR 12/3/17 This Sundry is a request for approval to repair inner annulus by outer annulus (IAxOA) communication in ConocoPhillips Kuparuk Well 2K-20 (AIO 2C.041, PTD 189-118) by pumping Seal-Tite, a pressure-activated sealant, into the inner casing packoff void/The well is currently operating under AIO 2C.041 because of a gas-only tubing by inner annulus (TxIA) communication leak. An additional leak developed, causing slow, intermittent IAxOA communication to be present when the well is shut in and the wellhead is cold. Communication is suspected to be via the wellhead packoffs based on failing inner casing packoff testing and the intermittent, temperature-dependent nature of the leak. After the Seal-Tite is pumped, the well will be monitored for a minimum of 30 days while still shut-in to ensure the communication has been repaired. REPAIR PLAN sealant, into the inner casing Pump Seal-Tite, a pressure-activatedg packoff void. 2. Perform pre-injection MITIA. 3. Establish appropriate differential pressures (minimum 300psi) between the inner annulus and outer annulus and monitor for minimum of 30 days to ensure repair of annular communication. 4. If IAxOA communication persists, an amendment for existing AIO 2C.041 or other appropriate paperwork will be needed prior to returning to injection. Otherwise, bring on water injection and allow to stabilize. 5. AOGCC-witnessed MIT to maximum anticipated injection pressure per AIO 2C.041. 6. Submit 10-404 post-repair. • KUP INJ 2K-20 e ConocoPhillips ti. Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) lmocoMvmpt; 501032012000 KUPARUK RIVER UNIT INJ 58.57 2,900.00 9,808.0 --- _. Comment 92S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 2K-20,9/27/201312,44:27 PM SSSV:TROP Last WO: 39.89 12/12/1989 ' Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,458.0 8/1/2013 Rev Reason:SURFACE CSG PATCH osborl 9/27/2013 Casing Strings HANGER;31.1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 .115.0 115.0 62.50,H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 3,724.0 2,905.5 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 1 PRODUCTION 7 6.276 33.0 9,805.2 6,589.9 26.00 J-55 BTC Tubing Strings Tubing Description (String Mo...l ID(in) (Top(ftKB) I Set Depth(ft.1 Set Depth(ND)(...I Wt(Ibift) (Grade (Top Connection iiimi dia TUBING 27/8 2.441 31.1 9,167.81 6,174.9 6.50 L-80 EUE8rdABMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com lin) 31.1 31.1 0.01 HANGER FMC GEN IV TUBING HANGER 2.875 1,793.9 1,719.4 36.37 SAFETY VLV 'OTIS FMX SAFETY VALVE 2.313 .A,v CONDUCTOR;36.0-115.0 9,103.5 6,134.3 51.24 PBR BAKER 80-32 PBR w/10'STROKE 2.890 9,117.4 6,143.1 51.09 PACKER BAKER HB RETRIEVABLE PACKER 2.890 I9,155.3 6,167.0 50.68 NIPPLE CAMCO D NIPPLE NO GO 2.250 �: 9,166.9 6,174.3 50.56 SOS BAKER SHEAR OUT SUB 2.375 SAFETY VLV;1,793.9 i Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) GAS LIFT;271Bi SURFACE CASING PATCH:54"X10".500 wall x 9/6/2013 658 tight fitting SC sleeve starting at the bottom of the starter head Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shots/f Top(ftKB) Btm(MB) (ftKB) (ftKB) Zone Date t) Type Com 9,320.0' 9,330.0 6,272.5 6,278.9 A-5,2K-20 3/7/2010 4.0 APERF 2 1/8"HES Strip Gun, Deep Star Millenium,+/- SURFACE;35.0.3.724.0-' - 45 degree phase 9,362.0 9,396.0 6,299.4' 6,321.2 A-4,2K-20 5/8/1990 - 4.0 (PERF 180 deg.Phase,4.5" Casing Guns GAS LIFT;5,6022 Mandrel Details St all C on GAS OFT;7.475.1 No Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 1 2,718.1 2,335.6 MERLA 'TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/6/1991 2 5,602.2 3,992.6-MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/6/1991 3 7,475.1 5,101.6 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/10/1990 4 8,561.3 5,800.2 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/6/1991 GAS LIFT;6,561.3 5 9,055.8 6,104.4 MERLA TGPD 11/2 GAS LIFT DMY RK 0.000 0.0 3/6/1991 Notes:General&Safety End Date Annotation 11/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;9.055.8 PBR:9,103.5 PACKER;9,117.4 NIPPLE;9.155.3 SOS;9,166.9 APERF;9,320.09,330.0-- IPERF;9.362.0.9,396.0-- PRODUCTION;33.0.9,805.2 ` • • Pro Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Saturday, December 02, 2017 8:40 PM To: NSK Well Integrity Supv CPF1 and 2 Subject: Re:Seeking verbal approval for sundry work to repair a packoff leak on 2K-20 (AIO 2C.041, PTD 189-118) Please submit sundry.There's time to process before the 12/11/17 so verbal is not necessary. Sent from my iPhone On Dec 2,2017, at 4:12 PM, NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com>wrote: Hi Victoria, KRU injector 2K-20(A1O 2C.041, PTD 189-118) is currently AA'ed because of a gas-only TxIA communication leak. The well is restricted to water-only injection, so effectively acts as a 'normal' injector. An additional leak developed causing slow, intermittent IAxOA communication to be present when the well is shut in and the wellhead is cold. We believe that the communication is via the wellhead packoffs based on failing packoff testing and the intermittent,temperature-dependent nature of the leak. The well is still able to pass an MITIA, but we would prefer to attempt a repair to eliminate the slow communication before asking for an amendment to the AA. We would like to pursue the repair by pumping Seal-tite,a pressure-activated sealant product, into the packoff void. Seal-tite personnel are mobilizing to the slope next week for a job for BP and we were hoping to begin our job immediately following theirs on Monday, December 11. I will be sending out the 10-403 sundry request this coming Monday. However,due to the tight timing with wanting to begin work so soon, I am requesting a 'verbal'approval so that we can begin the repair. Also,can you confirm that we even need a 10-403. I can find no direct reference to packoff repairs in the current sundry matrix but because this would be repairing an annular communication problem, I am assuming one would be needed. Please let me know if you need any additional information. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 SCOW 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday, April 16, 2017 5:09 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of OA pressure anomaly 2K-20 (AIO 2C.041, PTD 189-118) 04-16-17 Attachments: 2K-20 90 day TIO 4-16-17.jpg; 2K-20 schematic.pdf Chris, KRU injector 2K-20 (AIO 2C.041, PTD 189-118) is currently AA'ed for TxIA communication while on gas injection. The well has been shut in for reservoir management since 01-26-17. During preparation of the monthly report, the OA was identified with a very slow unexplained rise in pressure. The inner casing packoff seals are known to be compromised and have repeatedly failed their packoff testing. Therefore they are suspected to be the cause of the anomaly. It appears that there has been intermittent very slow IAxOA communication going back several years now, initially reported to your office in January 2014 and most recently in September 2016. The well will remain shut in until a path forward can be established. Prior to returning the well to water injection, proper paperwork will be submitted. Attached are the schematic and 90 day TIO plot. Kelly Lyons/ Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 APR 2-017'S` titAID • • p dwej,e�1o43 8 O ttj 0 I ► ,I . ►. I .I I. ► i ► .I I. 1 ,1 . ► r .I I. _ I• �ii -• ui) p - r 2 - C71 N r+ r d N Q // - D - LL • - N r - r G • _ --CL 1�3 ti W •{ 1 i' i 'I 4 I• I 'I I l• i i I• I •i I•'i 'Ico Q ISd •• • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, November 06, 2016 1:13 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: RE: Kuparuk injector 2K-20 (PTD# 189-118) report of suspected IAxOA communication. update 11-6-16 Attachments: 2K-20 90 day TIO 11-6-16.PNG Chris, With continued repressurization of the IA, it became clear that 2K-20 was exhibiting signs of TxIA communication while on gas injection. The well was shut in on 11/3/16 and then WAG'ed to water injection yesterday and will be on a 30 day clock to confirm that the leak is only present while on gas injection. Assuming a successful monitor, an AA will be submitted at the conclusion of the monitor period. Please let me know if you disagree. Attached is the updated TIO plot. Kelly Lyons/Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 SCANNED MAY 2 6 2017, Mobile Phone (907) 943-0170 From: NSK Problem Well Supv t: Monday, October 24, 2016 8:59 AM To: ce, Chris D (DOA) <chris.wallace@alaska.gov> Cc: NSK Pro Well Supv<n1617@conocophillips.com>; Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: RE: Kupa injector 2K-20 (PTD# 189-118) report of suspected IAxOA communication. Chris, The 30 day monitor period is ending. The - did not show signs of IAxOA communication during the monitor period. The elevated IA pressure was to exaggera he differential pressures to verify the lack of communication. There were some IA pressure increases at were originally attributed to rate and temperature variation combined with the diagnostic MITIA that was perforrd as seen on the attached 30 day TIO plot. The plan forward is to bleed the IA down and verify the pressure increase is notattributed to TxIA communication while monitoring the pressures for 30 more days. At that time a follow up email will be sent with an updated TIO plot. Please let me know if you have any questions or disagree with this plan. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr. 909 1 W a , C Zz a a a a a a a a a a a a a a a a a W W W W W W W W W W W W W F F W V o o = o N Yi00 V 0 0 0 0 0 0 ';..,',I, U O O 411 O O Q. c:, O t. 0 Y, UI Cl M O O O 40 O N 1< 11 W u1 ._ , n C7 01 4T W ,_ W W . 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N a1 co a"a ISd � 4n0w • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, October 24, 2016 8:59 AM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; Senden, R.Tyler Subject: RE: Kuparuk injector 2K-20 (PTD # 189-118) report of suspected IAxOA communication. Attachments: 2K-20 30 day TIO plot.JPG Chris, The 30 day monitor period is ending. The well did not show signs of IAxOA communication during the monitor period. The elevated IA pressure was to exaggerate the differential pressures to verify the lack of communication. There were some IA pressure increases that were originally attributed to rate and temperature variation combined with the diagnostic MITIA that was performed as seen on the attached 30 day TIO plot. The plan forward is to bleed the IA down and verify the pressure increase is not attributed to TxIA communication while monitoring the pressures for 30 more days. At that time a follow up email will be sent with an updated TIO plot. Please let me know if you have any questions or disagree with this plan. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 4111LVELLS TEAMConocoPhillips SCANNED MAY 1 9 201 Z From: NSK'P-roblem Well Supv Sent: Friday, Septem er 16, 2016 4:55 PM To:Wallace, Chris D (DO <chris.wallace@alaska.gov> Cc: Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: Kuparuk injector 2K-20 (P\ 189-118) report of suspected IAxOA communication. Chris- Kuparuk injector 2K-20(PTD# 189-118) was reported by operations for having suspect IAxOA communication. There has been a history of IAxOA communication on this well but all diagnostic monitor periods have ended with the IA and OA showing the ability to maintain integrity between the two. The inner casing pack offs were plastic packed as an attempt to repair the IAxOA communication and the recent temperature change from WAGing the well to gas injection may have affected the plastic packing. It is CPAI's intentions to have DID perform a series of diagnostics in an attempt to identify if the well is still capable of IAxOA integrity. If the well shows signs of IAxOA integrity after the initial diagnostics have been completed the well will be monitored for 30 days to verify at the IA and OA maintained integrity. If the well is not capable of maintaining IAxOA integrity or no repair option re available, an application for administrative approval will be submitted for continued injection with IAxOA communication. Please let me know if you have any questions or disagree with the plan. Attached is a well bore schematic and a 90 day TIO plot. Dusty Freeborn /Jan Byrne Well Integrity Supervisor 1 52 W • 1 J W tel VcxerEs ' � eA -- W W EL', • V - - 4 O O N . & O 0 O Ua t. i W t to .toto N N e. a 0 eQ . 0O O = O O 2 0 O Ti O ✓ a d W til y . 0. 0 0 0 0 LV 0 0 CC N N M M f N 11.1 tO W N N o O o H r N (v v tv N 0 o m a m O n• 0 0 0 0 0 J N N N N N J Y Y Y Y Y 75C N N N N N OoMno 0 M0 OD N-- CR nuo W/ 1 1 1 I 1 8 0 ,_ w d CI C .0:4 l>1. Cn"...."" "'SI-4' ,c, c o co . u 6 8 o c c E E Li RI t0 o c C Q m ID i La Lo o vfO rvpN to tr ,1 7,...„ N M N - O N CO O 40 to xscE C I I ,c, OD to O R O O co O O O O 0 O- - Y. 8 it 1 X „ + ' O = to 7 en e l C4 V7 O V7 Z.4,1; 1t +._A C 14 R !Sd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg JJ30115- DATE: Thursday,November 19,2015 P.I.Supervisor et47 I(1 ,L1 1 S SUBJECT: Mechanical Integrity Tests L CONOCOPHILLIPS ALASKA INC 2K-20 FROM: Chuck Scheve KUPARUK RIV UNIT 2K-20 Petroleum Inspector Src: Inspector Reviewed By: fsfrrnn P.I.Supry J — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-20API Well Number 50-103-20120-00-00 Inspector Name: Chuck Scheve Permit Number: 189-118-0 Inspection Date: 11/13/2015 Insp Num: mitCS151115071912 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2K-20 -Type Inj W''TVD 6143 - Tubing 2375 2400 ' 2400 - 2400 - PTD 1891180 - Type Test SPT 1Test psi 1536 - IA 450 1850 - 1790 - 1780 - Interval 4YRTST P/F P ✓ OA 375 375 - 375 ` 375 Notes: SCANNED SEP 1 6 2016 Thursday,November 19,2015 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re �qq DATE: Tuesday,July 14,2015 P.I.Supervisor et---7 U(/z1/S SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-20 FROM: Chuck Scheve KUPARUK RIV UNIT 2K-20 Petroleum InspectorscoNED u� l e 'U .i- CJ Src: Inspector Reviewed B P.I.Supry 36 —" NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-20 API Well Number 50-103-20120-00-00 Inspector Name: Chuck Scheve Permit Number: 189-118-0 Inspection Date: 7/10/2015 Insp Num: mitCS150713094956 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2K-20 Type Inj [ N'1-TVD I 6143 - Tubing 2650 2650' 2650 - 2650 ' ' = PTD 1891180 - IType Test'SPT{Test psi I 1536 - IA I 1160 1980 - 1940 -; 1940 - T Ir- Interval 4YRTST p/F P '' pA 420 420 - 420 _ I 420 Notes: Tuesday,July 14,2015 Page 1 of 1 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. /~/~-//~' File Number of Well History File PAGES TO DELETE Complete 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 COMMENTS: Scanned by: Bevedy Br~ Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well r Plug Perforations r Perforate Other SC Repair Alter Casing r Pull Tubing r Stimulate- Frac r Waiver r Time Extension r Change Approved Program j""Operat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 189-118 ' 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-103-20120-00 ' 7. Property Designation(Lease Number): 8.Well Name and Number: ADL0025588 ' 2K-20 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 9808 feet Plugs(measured) None true vertical 6592 feet Junk(measured) None Effective Depth measured 0-> feet Packer(measured) 9117 true vertical 0 feet (true vertical) 6143 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 1640 630 SURFACE 3689 9.625 3724 2906 3520 2020 PRODUCTION 9772 7 9805 6590 4980 4330 SLEEVE 4'6" 10".500 wall x 65# RECEIVED cr ANHE�� SEP 1 6 2013 Perforation depth: Measured depth: 9320-9330, 9362-9396 True Vertical Depth: 6272-6279,6299-6321 G C Tubing(size,grade,MD,and TVD) 2.875, L-80, 9167 MD,6174 TVD Packers&SSSV(type, MD,and TVD) PACKER- BAKER HB RETRIEVABLE PACKER @ 9117 MD and 6143 TVD: 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 N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service P ' Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG I ' GINJ r SUSP r SPLUG r 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: 313-375 Contact MJ Loveland/Martin Walters Email n1878(c�conocophillips.com Printed Name Martin Walters Title WI Project Supervisor Signature .ice / Phone:659-7224 Date 9/10/13 'tgei IV7 IL/ 0-i i - t7-4_.F j c/'c/i 3 RBDMS SEP 18 fir' Form 10-404 Revised 10/2012 ,leKe. Submit Original Only • 111P7 • • RECEIVED ConocoPhillips SEP 1 6 2013 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 September 10, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 2K-20, PTD 189-118, Sundry 313-375 surface casing repair. Please call MJ Loveland or Martin Walters at 659-7043 if you have any questions. Sincerely, /74( 424- Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • Name of Recipient Page 2 of 2 09/10/13 il� • • 2K-20 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/02/13ISET CA-2 @ D-NIP @ 9155' RKB. 08/07/13 Cut two 18"X 20"windows in conductor and removed cement. Buffed and cleaned SC for further inspection. Kakivik performed a UT inspection. Found hole 20 1/2 "from the bottom of p p P starter head at the 1:00 position. 08/08/13 Civil welder rigged up and cut off conductor. TOC= 17'4". Buffed SC clean for Kakivik inspection. Kakivik showed up and determined and marked where the A&B bands would be located. 08/09/13INotified state of opportunity to inspect SC damage before sleeve is installed. 08/18/13 Staged and fitted 54"X 10" .500 X65 tight fitting SC sleeve into place, Did a 3 pass vertical on the sides of the SC sleeve 09/06/13 Cooper heat started heating the starter head to 500* F. Once temp was reached welders did another 3 pass weld to finish sealing up top and bottom of SC sleeve. 9/7/13 1E-mailed AOGCC to inform them of opportunity to witness repair to SC. 9/9/13 Initial T/I/O= Si0/0/50. Post SC repair MITOA(PASS). De watered cellar box. Kakivik did MT inspection on SC sleeve welds. Rigged up equipment and pressured,OA to 1800 PSI for 1 hour test, 15 min= Si0/0/1780, 30 min= Si0/0/1740,Re pressured up to 1800 PSI to restart 1 hour test, 15 min= Si0/0/1790,30 min= Si0/0/1780,Re pressured up to 1800 PSI to restart 1 hour test,15 min= Si0/0/1790, 30 min= Si0/0/1790,45 min= Si0/0/1790, Final= Si0/0/1790.Welders installed 76"X 16"62.58# .375 conductor. i max..,.«... eea�.:+^ ...,., -m ...•,awe- w r b, _, ,s�- O d a Q Q to O N _c o Q _c _ s 3 E .2 d O O O O O ' ... a.O o 0 O CO N N O o 0 -o s o U FE U m Q 3 O 'r.. 9 ate'. I . 7 6 l',1-17.-N411 1 i 4. �_� � _�� la �srtir r rr�' i i/r/r �l�l�Lt 1Llt ( t tl �a .x.\ V_ is t . :. ,..,tea, va „ ,,:„„,,,;...:..,. . ,...,,,,,,. , ., ..,.. ., ,,,, .. #0,.',/,, i. ,„,„,„,, , , , ,.....,„„,,,,, ... ,, , . , ,, „,„ ., „, f , ,.....„. ,,,,,,,, , ..„,. ,:. n .,,,,' ,-.1'.'"''''.7'..'1.''''''''''',:::'',.:-.;''' +a,.,..„ , .., ,,: ,.., fix.. Pk � f©ConocoPhillips Alaska, Inc This photo is copyright by ConocoPhillips Alaska, ° Inc. � ' �� ,� and cannot be released or published without express �� s` written consent of �� ConocoPhillips Alaska �� 411iiiiiiiiiitiosit_ v w,,`+ y w w.. < ”' r � 1,; ` et '.cam y°, 0 af ,. `a ax r. w' r • OF T • �/ce s THE STATE Alaska Oil Gas . f � Conservation ASS GOVERNOR SEAN PARNELL 333 West Seventh Avenue w,R OF t+ Anchorage, Alaska 99501-3572 ALAS Y- Main: 907.279.1433 Fax: 907.276.7542 Martin Walters WI Project Supervisor SC�� D � "� ConocoPhillips Alaska, Inc. I P.O. Box 100360 �9 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-20 Sundry Number: 313-3 75 Dear Mr. Walters: 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair ISM DATED this/day of August, 2013. Encl. 91�(,,,t RECEIVED STATE OF ALASKA + A KA OIL AND GAS CONSERVATION COMPSIA VI %' JUL 2 13 APPLICATION FOR SUNDRY APPROVALS S 81 63 20 AAC 25.280 AOU 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:SC Repair I✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 189-118. 3.Address: 6.API Number: Stratigraphic r Service 17€ P. O. Box 100360,Anchorage,Alaska 99510 50-103-20120-00. 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No J' 2K-20. 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025588• Kuparuk River Field/Kuparuk River Oil Pool. 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 98080 6592• Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115' 115' 1640 630 SURFACE 3689 9-5/8 3724' 2906' 3520 2020 PRODUCTION 9772 7 9805' 6590' 4980 4330 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9320-9330, 9362-9396- 6272-6279,6299-6321 2.875 L-80 9167 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER=BAKER HB RETRIEVABLE PACKER MD=9117 TVD=6143' SSSV=OTIS FMX SAFETY VALVE MD=1794 TVD=1719- 12.Attachments: Description Summary of Proposal , jy'' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 1' 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/15/2013 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG p'. Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Martin Walters Email: n1878(a conocophillips.com Printed Name Martin alters Title: WI Project Supervisor Signature /. '✓�///(4/1_7/7/./;;.,, . Phone:659-7224 Date:7/10/13 c Commission Use Only 3)3-57 Sundry Number: S Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: RBDMS AUG — 2 20tss , Spacing Exception Required? Yes ❑ No 1 Subsequent Form Required: /® -40 /^/ APPROVED BY Q Approved by: / COMMISSIONER THE COMMISSION Date: CJ l —/ pproved application is valid for 12 months from the date of approval. Form 10-403(Revis 10/2012) Submit Form and Attachments in Duplicate e `"b UGC-- 7/3x /13 ORIGINAL ob • S . . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 10, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2K-20, PTD 189-118 surface casing inspection and repair. Please contact MJ Loveland or me at 659-7043 if you have any questions. Sincerely, J (� , - i Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska,Inc. Kuparuk Well 2K-20 (PTD 189-118) SUNDRY NOTICE 10-403 APPROVAL REQUEST July 10, 2013 This application for Sundry approval for Kuparuk well 2K-20 is for the inspection and repair of surface casing with a reported surface casing leak. This well was reported to AOGCC on 5/27/13 as being suspected of a surface casing leak. Subsequent diagnostics indicate that the leak is relatively shallow. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with a plug(s)and/or BPV. 2. Remove the floor grate,well house, flow lines, and other equipment from around the wellhead. 3. Remove gravel around well head and build—9' working cellar. 4. Install nitrogen purge equipment for the conductor(and OA if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary.Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform MITOA 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s)and/or BPV and return the well to production. 13. File 10-404 with the AOGCC post repair. Well Integrity Project Supervisor 7/10/2013 114 KUP 2K-20 ConocoPhillips Well Attributes Max Angle&MD TD Wellbore API/UWI Field Name Well Status Inc/(°) MD(ftKB) Act Btm(ftKB) Alaska'III` 501032012000 KUPARUK RIVER UNIT INJ 58.57 2,900.00 9,808.0 ComcoPhdriRi Release Date _-- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig ••• SSSV:TRDP Last WO: 39.89 12/12/1989 Well Confiu:-2K-20,7/17/2012 7:30:39 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod... End Date Last Tag:SLM 9,440.0 4/1/2011 Rev Reason:WELL REVIEW osborl 7/17/2012 Casing Strings I Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(ND)... String Wt... String... String Top Thrd HANGER,31 ! CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED ' Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(TVD)... String Wt... String... String Top Thrd SURFACE 9 5/8 8.921 35.0 3,724.0 2,905.7 36.00 J-55 BTC Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(TVD)... String Wt... String... String Top Thrd PRODUCTION 7 6.276 33.0 9,805.2 6,589.9 26.00 J-55 BTC AMOR Tubing Strings Tubing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(TVD)... String Wt... String... String Top Thrd TUBING 2 7/8 2.441 31.1 9,167.8 6,174.8 6.50 L-80 EUE8rdABMOD Completion Details . Top Depth Nomi... (TVD) Top Inc! II)(in) Top(ftKB) (�B) (1 Item Description Comment 31.1 31.1 0.07 HANGER FMC GEN IV TUBING HANGER 2.875 1,793.9 1,719.4 36.37 SAFETY VLV OTIS FMX SAFETY VALVE 2.313 CONDUCTOR, 9,103.5 6,134.0 50.43 PBR BAKER 80-32 PBR w/10'STROKE 2.890 36-115 9,117.4 6,142.8 50.40 PACKER BAKER HB RETRIEVABLE PACKER 2.890 9,155.3 6,166.9 50.31 NIPPLE CAMCO D NIPPLE NO GO 2.250 1. 9,166.9 6,174.3 50.28 SOS BAKER SHEAR OUT SUB 2.375 SAFETY v o Perforations&Slots 1,794 4 Shot ( Top(TVD) Btm(TVD) Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment GAS LIFT, 9,320.0 9,330.0 6,272.4 6,278.9 A-5,2K-20 3/7/2010 4.0 APERF 2 1/8"HES Strip Gun,Deep Star 2,718 Millenium,+/-45 degree phase 9,362.0 9,396.0 6,299.4 6,321.2 A-4,2K-20 5/8/1990 4.0 IPERF 180 deg.Phase,4.5"Casing Guns Notes:General&Safety End Date Annotation 11/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE, 35-3,724 GAS LIFT, 5,602 1 GAS LIFT, irt 7,475 GAS LIFT, 8,561 GAS LIFT, 9,056 tr, _ 1 PBR,9,104 J PACKER,9,117 I NIPPLE,9,155 II a SOS,9,167 el Mandrel Details Pod Top Depth Top APERF, (TVD) Inc/ OD Valve Latch Size TIRO Run 9,320-9,330 mmm _ Stn Top(ftKB) (f(KB) (1 Make Model (In) Sery Type Type (in) (psi) Run Date Corn... 1 2,718.1 2,331.8 48.36 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/6/1991 2 5,602.2 3,992.4 52.92 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/6/1991 IPERF, _ • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Wednesday, July 17, 2013 11:39 AM To: 'n1878 @conocophillips.com' Subject: KRU 2K-20: Application For Sundry Approval Good morning Martin, Under 20 AAC 25.380, an application for sundry approval must include a wellbore schematic of the current well condition. This may be submitted to me via email. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis @alaska.gov. 1 S • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Wednesday, July 17, 2013 11:41 AM To: 'Jerry.C.Dethlefs @cop.com' Subject: FW: KRU 2K-20: Application For Sundry Approval Jerry, Please see the below email. Thank you, Patricia From: Bettis, Patricia K (DOA) Sent: Wednesday, July 17, 2013 11:39 AM To: 'n1878 @conocophillips.com' Subject: KRU 2K-20: Application For Sundry Approval Good morning Martin, Under 20 AAC 25.380, an application for sundry approval must include a wellbore schematic of the current well condition. This may be submitted to me via email. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettisPalaska.gov. 1 • S Bettis, Patricia K (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] Sent: Wednesday, July 17, 2013 11:39 AM To: Bettis, Patricia K(DOA) Subject: Out of Office: KRU 2K-20: Application For Sundry Approval Martin and MJ are currently out of the office until August 7th. For urgent business, please contact Jerry.C.Dethlefs(acop.com. Otherwise Martin will get back to you on 8/7 or slightly thereafter. You may also phone: WI Field Supervisor Perry Greenwood / Roger Winters @ 907-659-7506 Or Problem Well Supervisor, Brent Rogers / Kelly Lyons @ 907-659-7224 Or WI Director, Jerry Dethlefs @ 907- 265-1464 Or MJ's Cell phone @ 907-943-1687. Or Martin's Cell phone @ 907-943-1720 1 • s Bettis, Patricia K (DOA) From: Dethlefs, Jerry C [Jerry.C.Dethlefs @conocophillips.com] Sent: Wednesday, July 17, 2013 11:41 AM To: Bettis, Patricia K(DOA) Subject: Out of Office: KRU 2K-20: Application For Sundry Approval I will be out of the office until July 22; contact the Problem Wells Supervisor (659-7224) or Well Integrity Projects (659-7043) regarding Well Integrity, Samir Patil (265-1618) for Subsidence. 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 28, 2011 TO: Jim Regg ' ) P.I. Supervisor kep 7( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K -20 FROM: John Crisp KUPARUK RIV UNIT 2K -20 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv. NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2K - 20 API Well Number: 50 103 - 20120 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr110628110844 Permit Number: 189 - 118 - Inspection Date: 6/24/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K -20 ' Type Inj. Fw ' TVD I 6143 ' I IA 720 2100 " 2000 1980 - P.T.D 1891180 ' TypeTest 1 SPT Test psi 1535 ' OA 180 200 — 200 200 Interval 4YRTST - P/F P _ Tubing 2600 2650 2650 2650 Notes: 2.3 bbls pumped. No problems witnessed. Tuesday, June 28, 2011 Page 1 of 1 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Q'~_.~ i~ August 1, 2010 ` `-' r ~~.. ~~ Commissioner Dan Seamount ~~~ Alaska Oil & Gas Commission 4 ~~1C 333 West 7~' Avenue, Suite 100 ~ ~-ss~a° rr~~" Anchorage, AK 99501 ~ ,~ ~• - ~ ~~ ~ ' ; ~ '. ~ / ~-~ ''~ ~~~' Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 21St. The corrosion inhibitor/sealant was pumped July 30tH, 31St 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Il Report of Sundry Operations (10-404) Kuparuk Field Date 8/01/10 ~Q ~~ ~T onn Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 26-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7/31/2010 2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7/31/2010 2K-20 50103201200000 1891180 10" Na 10" Na 2 7/31/2010 2K-23 50103201250000 1900140 SF n/a 18" n/a 2.6 7/31/2010 2K-24 50103201220000 1891300 SF n/a 18" n/a 2.6 7/31/2010 2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010 2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7/30/2010 2T-20 50103202150000 1950290 SF n/a 23" n/a 2.6 7/30/2010 2T-21 50103202120000 1950130 SF n/a 21" n/a 3.4 7/30/2010 2T-26 50103202230000 1950820 SF n/a 27" n/a 4.3 7/30/2010 2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7/30/2010 2T-30 50103202190000 1950570 SF n/a 30" n/a 6 7/30/2010 2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7/30/2010 2T-36 50103202280000 1951020 SF 0.40 12" 7/21/2010 2.6 7/30/2010 2T-39 50103203920000 2011830 30" 0.54 14" 7/21/2010 4.3 7/30/2010 2T-201 50103202300000 1951220 60" 1.57 32" 7/21/2010 7.7 7/30/2010 2T-204 50103203270000 2000160 SF n/a 24" n/a 5.1 7/31/2010 2T-209 50103202810000 1982430 40" 1.20 19" 7/21/2010 4.8 7/31/2010 2T-218 50103204490000 2030170 31" 0.73 9" 7/21/2010 2.6 7/31/2010 2T-220 50103202830000 1982530 38" 0.49 19" 7/21/2010 5.1 7/31/2010 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2K-20 Run Date: 3/7/2010 May 18, 2010 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-20 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20120-00 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 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto .~~ fi,~ ~ .~ ~ ~;~ ,_ Date: ~~ ~'~' / ~ ~~ S~ ~;_~~ ~ ~~ Signed: ~ ~~ ~~~ STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~. perations~oerf ~ ~: Z~ andon ~ Repair w ell ~""' Rug Perforations Stimulate J"""` Other "` F'~ ~ Alter "' Pull Tubing ~ Perforate New Pbol ~ Waiver ~"~ Time Extension ""°° Ch ogram Operat. Shutdown "`~ Pizrforate Re-enter Suspended Well or ~ 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development `"' Exploratory °" 189-118 3. Address: Stratigraphic `°° Service .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20120-00 7. Property Designation: ` 8. Well Name and Number. ~ ADL 25588 ~ 2K-20 9. Field/Pool(s): Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9808 feet Plugs (measured) None true vertical 6592 feet Junk. (measured) None Effective Depth measured 9700 feet Packer (measured) 9117 true vertical 6518 feet (true vertuca-) 6143 Casing Length Size MD ND Burst Collapse CONDUCTOR 115 16 115 115' SURFACE 3723 9.625 3723 2905 PRODUCTION 9805 7 9805 6590 in ~ Perforation depth: Measured depth: 9320'-9330', 9362-9396' •~~t :' True Vertical Depth: 6272'-6279', 6299'-6321' Tubing (size, grade, MD, and TVD) 2,875, L-80, 9168 MD, 6175 TVD ~ and 6143 TVD Packers & SSSV (type, MD, and TVD) PACKER -BAKER'HB' RETRIEVABLE PACKE @ 9117 TRDP - OTIS 'FMX' @ 1794 MD and 1719 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: • 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 728 Subsequent to operation 847 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development Service . Well Status after work: a1vL '~ Oil "`' Gas "" WDSPL "` erations XXX ort of Well O Dail Re / t3~ t'~ p y p GSTOR WAG GASINJ ~"` WINJ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none Contact John Peirce ~ 265-6471 Printed Name John Peirce Title Wells Engineer Signature ~ _ Phone: 265-6471 Date ~ ~~~ )~~ Form 10-404 Revised 7/2009 RBDMS APR ~ 3 ZO1O .~ Submit Original only `~ ~,/,a 2K-20 Well Events Summary DATE SUMMARY 3/3/10 TAGGED @ 9434' SLM. DRIFTE~G WITH 10' x 2.125" TO 9340' SLM. SALE OBTAINED. READY FOR E/L. 3/7/10 PERFORATE THE A5 SAND FROM DEPTH OF 9320-9330' WITH 2-1/8", DEEP STAR MILLENIUM CHARGES, 4 SPF, 45 DEGREE PHASE. CORRELATED TO SWS CBT LOG DATED 24-DEC-1989. PULLED JEWELRY LOG FROM 9386' TO GLM #5 @ 9056' RKB. WELL LEFT SHUT-IN FOR SLICKLINE TO PERFORM SBHP 3/9/10 MEASURED POST PERF BHP @ 9330' RKB (4807 PSIA, 110 DEGF) COMPLETE. **"*POSSIBLE FROZEN SSSV C/L**** ,~-. KUP ~G7f1(~C3~11~~l 15 ell Attributes ~ ,. °se.~d1l' _ \Nelll~ore APVU WI 'Field Name W 1, Su1 0 3 201200 0 iKUPARUK FYVEI-UNIT IF C merit H2S {ppml Dale Annotal ( II -{SSSV: TRDP LastW WeY CO fig ISp-3f29/2U10 ~.~ aq ~,a Scheme/ Acloal A otation Depth (ft KB) End D to Annotation ( ( Last Tag: SLM 9 434 0 3°5_ 010 Rev Reason: PERFOR C.aSln $trlD S _- String OD j Str°ng ID _ _ _. Set Dep , i. ,,, ~ k!itilY U ?is ,,, f Casing Description t (in) 1 ) ToP (ftKB) (ftKB) . . ,, . CONDUCTOR 161 15062 0.0 it coNDUCroR, SURFACE 95/8, &~lf9 0.0 3. /2 116 PRODUCTION 7 6 i51 0.0 9,8C ' Tubing. Stri_ngs_ String OD Striiny ID Set Dep ~. Tubing Description I (in) lin) Top (ftKB) (ftKB) 2K-20 ).00 i~ 9.808.0 Y) (Rig Release Date 89 12/12/1989 By End Date ~UOr 3120/2010 String Grade SAFETY VLV~ TUBING 2 7/8 ~: 421 0.0 9,168.01 6,175.0' 6.501E-80 IEUEBrdAB MOD Other I n Hole ( All Jewelry: Tubin Run & Retrievable Fish etc ) Top Depth , , . g ', (TVD) Top Inc! Top (ftKe) (ftK6) (°) Description Comment Run Date ID (in, 1,794 1,719.5 36.37 SAFFi1Y VLV Otis'FMX' 5110/1990 2.31; GAS UFT,--. 2 718 2 331 7 48 35 GAS LII I MERLA/TMPDl1/DMY/BKO/Comment:STA1 3/6/1991 2 37! z.]13 , , . . . I 5 602 I 3,992.3 52.92 GAS LII I MERLA/TMPDl1/DMY/BK!!/ Comment: STA 2 3/6/1991 2.37! j 7,475 5,101.6 52.39 GAS LIFT MERLA/TMPD/1/DMYBK2///Comment: STA3 5/1011990 2.37! 8,561 5,799.9 51.84 GAS L.II=T MERLA/TGPD/t5/DMY/RK///Comment: STA4 3/6/1991 2.37! SURFACE. 3.n3 1 9,056 6,104.9 51.76 GAS LII= T MERLA/TGPD/1.5/DMY/RW// Commenr STA 5 3/611991 2.37! I 9,104 6,134.3 50.43 PBR Baker PBR'80-32'w/10'Stroke 5!10/1990 2.891 ' 9,117 ~ 6,142.5 50,40 PACKER Baker'HB' RETRIEVABLE PACKER 5/1011990 2.891 GAS UFT, i 9,155 6,166.7 50.37 NIPPLE Camco'D' Nipple NO GO 5/1017990 2.251 ss9z 9,167 6,174.3 50.28, 505 Baker 5/10/1990 2.44' 9.168 6,175.01 Sd28',T TL TTL ELMD = 9155' ON HES JEWELRY LOG 3!7/2010 5/10/1990 1 244' Perforations 8 Slots .. snot I GAS LIFT ~ Top (TVD) Btn {TVDi Dens , 7,g75 ~ .,Top (ftKB) 8trn (ftK6) (ftKB) (flKBl Zone Data (h-~ Type Comment 9,320 9,330 6,2724 .. !8 9 A-5, 2K-20 3/712010 4.0 APERF 2 1/8" HES Strip Gun, Deep Star F i Millenium, +/-45 degree phase ~~ 9,362 9,396 6,299.4 6 321 2 A-4, 2K 20 5/8/1990 4.0 IERF 1180 deg. Phase, 4.5" Casing Guns GAS LIFT. 8.561 .r _ .'~Y ~~~""" C n GAS LIFT, 9.056 G ' ~BR, 9.1W I~ 4 "._"...i~} !'ACKER. 5.11] ~ NIPPLE, 9,155 SOS, 9,16] TTL, 9,168 APERF, 9,320-9,330 __ IPERF, 9,3629,396 PRODUCTION, 9,805 \ TD. 9,808 -- -- MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 711' G!þ!D 7 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-20 KUPARUK RIV UNIT 2K-20 Src: Inspector G-,\\lb \~-\ FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UNIT 2K-20 API Well Number: 50-103-20120-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070601181850 Permit Number: 189-118-0 Inspection Date: 6/1/2007 ~ Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K-20 Type Inj. W TVD 6143 IA 1200 2390 2340 2340 P.T.D 1891180 TypeTest SPT Test psi 1535.75 OA 500 560 560 560 Interval 4YRTST P/F P /' Tubing 2500 2500 2500 2500 Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. /' NON-CONFIDENTIAL Reviewed By: P.I. Suprv .:JB'fZ- Comm SCANNED JUN 2 0 2007 Wednesday, June 06, 2007 Page 1 of 1 MEMORANDUM TO: Randy Ruedrich Commissioner P.I. Supervisor ' FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission ?/,'.~,.7/Z)~ DATE: June 14, 2003 SUBJECT: Mechanical Integrity Tests Conoco/Phillips Kuparuk River Field 2K Pad Kuparuk River Unit NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I We,,I 2K-20 Type,nj.I S I*.v.~. 1~4~ I Tubingl 2435 ]2435 I~ I~ I,nterva, I 4 I P.T.D.I 1891180 TypetestI P ITestpsil 3000 I Casingl 400 I 2900 I 2875 I 28501 P/F I _P I Notes: OA 0 psi. during test. 4 BBL. Pumped I WellI 2K-24 ITvPo, j.I s I,.v.~. I~o, I Tubingl 24a5 12435 I~,~ I~ I,,te~a,I 4 I P.T.D.I 1891300 ITypetestl P ITestpsil 3000 I Casingl ~300I 2880 I 28201 28001 P/F I E I Notes: OA 300 psi during test. 5 BBL. Pumped. I P.T.D.I Notes: WellI ~-*.~.1 ~oto~: W~II[ ~.~.~.1 ~ot,~: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING 4 year MIT's witnessed. No failures. Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 2 Attachments: Number of Failures: 0 Total Time during tests: 2 hrs. CC: MIT report form 5/12/00 L.G. ;;~NNEC,",~U~ 0 ~ 2003 2003-0614_M IT_KRU_2K-24_jc.xls 6/24/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/2K 06/14/03 Sauvageau/Brake - APC John Cdsp Packer Depth Pretest Initial 15 Min. 30 Min. WelII2K-05 i ~pe,n~l s~ i ~.V.D. I~ ITubing I 22001 22001 22001 22°°l'ntervall ~I P.T.D. It881180 Type Test Test psil 1500 I Casing I 13801 29801 29401 29301 P/F Notes: Welll2K-06i i T.v.o.I~00~ ,Tubing , 23101 2310, 2310, 2310, P.T.D. I1890820 Type Test T~tpsiI 1502 I Casing I 13201 30101 29801 29751 P/F Notes: w~,,l~-,o TypelnjI ~ I~'v'~' I~°~ I mubingl ~°1~°1 ~°1 ~°l'nte~'l ~ P:T.D. I1890590 TypeTest Test psiI 1500 I Casing I 4101 29601 29101 29751 P/F Notes: we,,~-,~ I,~,~,n,I g I,.~.~. ~o ~,~,n~ ~ ~,o~ ~o~ ~,o~ ~o~,n~,l ~I ~.1:~.1t8,0~0 lypelest l~tpsiI ~Sos I Casin~I ~2201 20~01 2aTsI ~a~oI ~ote~: , ~,D2118~080 lypeTest lest psiI ~500 I Casin~ I ~320~ 20001 2~201 2000I ~ot~: P:T,~Di,.,I,,'t'891,180' Type Test Test psiI 1536 I Casing I 4001 29001 28751 28501 P/F Notes: We"12K'24I~"e'"i I s~ i ~.v.~.I~0~ I Tubing I 24351 24351 24351 243511ntervall 4P :P.T;'D, I1891300 TypeTest Test psiI 1551 I Casing I 13001 28801 28201 28001 P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 05/19/02 $C~N~:,,~U~ (~ ~ 2[303 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test 2003-0614_MIT_KRU_2K-05 06 10 13 18 20 24.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) 6/25/2003 ~KRU 4 yr MITs 2K & 2~ Subject: KRU 4 yr MIT's 2K & 2T Date: Sun, 15 Jun 2003 16:23:23 -0800 From: "NSK Problem Well Supv" <nl 617~conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, jim_regg~admin.state.ak.us, tom_maunder@admin.state.ak.us CC: "nl 617" <nl 617@conocophillips.com> Tom, Bob, Jim, Attached are the 4 yr MIT's for injection wells on 2K and 2T. Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224 (See attached file: MIT KRU 2T 06-14-03.xls) (See attached file: MIT KRU 2K 06-14-03.xls) ] Name: MIT KRU 2T 06-14-03.xls ] %~_~MIT KRU 2T 06-14-03.xlsiI Type: EXCEL File (application/msexcel)] ,IEncoding: base64 ] ~.~ MIT KRU 2K 06-14-03.xls Name: MIT KRU 2K 06-14-03.xls :i Type: EXCEL File (application/msexcel) 1 Encoding: base64 I of 1 6/25/2003 1:45 PM STATE OF ALASKA ~'~ 0 Al ~A OILAND GAS CONSERVATION ~Mto~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown m Pull tubing Alter casing Stimulate m Plugging Perforate _ 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 4. Location of well at surface 244' FNL, 94' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 746' FSL, 606' FWL, Sec. 11, T10N, R8E, UM At effective depth 494' FSL, 399' FWL, Sec. 11, T10N, R8E, UM At total depth 431' FSL, 348' FWL, Sec. 11, T10N, R8E~ UM 12. Present well condition summary Total Depth: measured true vertical 9808 6586' feet Plugs (measured) feet None 6. Datum elevation (DF or KB) 154' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2K-20 '~' 9. Permit number/approval ~number 10. APl number so-103-201 20 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 9700' true vertical 6519' feet Junk (measured) feet None Casing Length Size Structural Conductor 8 0' 1 6" Surface 3688' 9 5/8" Intermediate Production 9775' 7" Liner Perforation depth: measured 9362-9396' 4 SPF, true vertical 6298'-6319' Tubing (size, grade, and measured depth) 2 7/8" J-55 6.5#, ABMOD, EUE @ 9167' Packers and SSSV (type and measured depth) Baker HB @ 9117'~, Otis FMX ~ 1794' 13. Stimulation or cement squeeze summary Cemented Measured depth True vertical depth 80' 80' 1200 Sx AS III & 3723" 2904' 450 Sx Class G 300 Sx Class G 9 8 0 8' 6 5 8 6' 180° phasing , I~ska Oit & (-;~s Cons. 6o~n~'lissio~ Anchora~i~ Intervals treated (measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 460 328 -0- 1000 295 Subsequent to operation -0- -0- 935 900 2100 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(:::jn~ ~~ ~~) ' ~ Title Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE WELL CONTRACTOR lARKS BDT WELL SERVICE REPOR FIELD- DISTRICT- STATE OPERATION AT REPORT TIME IDAYS / I~^TE CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Ir ,) Sul~idlary of Atlarttic Rtcl~field Comoa~y WELL 3NTRACTOR REMARKS IPBDT IFIELD - DISTRICT- STATE IOPER~TION AT REPORT TIME I d~,~zr~ .... WELL SERVICE REPOR STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate __ Pull tubing _ 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 Exploratory Stratigraphic Service 4. Location of well at surface 244' FNL, 94' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 746' FSL, 606' FWL, Sec. 11, T10N, R8E, UM At effective depth 494' FSL, 399' FWL, Sec. 11, T10N, R8E, UM At total depth 431' FSL, 348' FWL, Sec. 11, T10N, R8E, UM 12. Present well condition summary Total Depth: RKB 154' 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-20 feet 9. Permit number 89-118 10. APl number 5o-103-201g0 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool measured true vertical 9808 feet Plugs (measured) 6 5 8 6' feet None Effective depth: measured true vertical 9700' feet Junk (measured) 6 51 9' feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: ~ngth 80' 3688' 9775' measured 9362'-9396' Size Cemented 16" 9 5/8" 1200 Sx AS III & 450 Sx Class G 7" 300 Sx Class G 4 SPF, 180° phasing Measureddepth Trueve~icaldepth 115' 115' 3723' 2904' 9808' 6586' true vertical 6298'-6319' Tubing (size, grade, and measured depth) 2 7/8" J-55, 6.5#, ABMOD, EUE @ 9167' Packers and SSSV (type and measured depth) Baker HB @ 9117'~ Otis FMX ~ 1794' 13. Attachments Description summary of proposal Convert well from oil producer to water injector. 14. Estimated date for commencing operation November 20, 1990 16. If proposal was verbally approved Name of approver (Wellbore 15. Date approved RECEIVED NOV u 6 .Oil.& Gas Cons. Detailed operation program ~ schematic attached). Status of well classification as: Oil Gas BOP sketch Service Water Injector Suspended _ the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ON~.Y Conditions of approval: Notify Commission so representative may witness Plug integrity __ , ,,BOP Test _ Location clearance Mechanical Integrity Test~j~ Subsequent form require 10- - -z-~"edo_._.,,.~CoPY ORIGINAL SIGNED BY SMITH Approved by order of the Comr~ ' Commissioner JApDroval Form 10-403 Rev 09/12/90 SUBMIT IN TRIPLICATE WELL 2K-20 PRODUCER APl # 501032012000 SURFACE LOCATION: 244' FNL, 94' FEL, SEC 11, T10N, R8E, UM TOP KUPARUK: 763' FSL, 606' FWL, SEC 11, T10N, R8E, UM DEPTHS: REFERENCED TO 0' RKB TUBING SPOOL ELEV: 31' RKB ALL DEPTHS MD-RKB 16": 62.5# H-40 @ 115' 9 5/8": 36# J-55 @ 3723' TREE: FMC GEN IV 5000 PSI J BAKER PBR: 2.500" ID @ 9104' BROWN HB PKR: 2.375" ID @ 9117' CAMCO 'D' NIPPLE: 2.25" ID @ 9155' SHEAR OUT: 2.441" ID @ 9167' L ~. GLMI' GLM2: GLM3: GLM4: GLM5: SPUD: 12/3/89 COMPLETION: 5/10/90 SSSV. OTIS FMX ID 2.313" @ 1794' 2718' / 1.0" TMPD/DV 5602' / 1.0" TMPD/DV 7475' / 1.0" TMPD/DV 8561' / 1.5" TGPD/DV 9056' / 1.5" TGPD/DV 2.875" 6.5# L-80 EUE ABMOD IPC TUBING TAIL @ 9168' C B A5 A4 A3 7": 26# J-55 @ 9805' i PBTD: 9706' HOLE ANGI I:: ACROSS KUPARUK = 50 DEGREES MAX HOLE ANGLE = 58 DEGREES @ 2900' VOLUME TO TOP PERF = 61 BBLS 9362' 4 SPF ~. 180° PHASING ORIENTED 17° CCW 9396' FILL TAGGED AT 9441' (6/27/90) REVISION: 10/30/90 Messrs. Kralick and October 29,~ 1990 Page 2 Drill Site 2K Initial Water Injection Conversions CC: Downhole 899381 Surface 899399 10/29/90 1) 2) 3) 4) This wireline work should be completed approximately one week prior to the completion of the water injection piping work at DS-2H. The spool piece work inside the manifold building should be completed at the same time. MIRU Slickline and diesel pump truck. RIH and set SV in "XN" or "D" nipple. Wells 2K-06, 18 and 20 are currently on gas lift. Well 2K-10 has not been gas lifted. RIH and pull the bottom DV and replace with a CV in Well 2K-10. 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 6 195 bbls 7361 feet 2 K- 1 0 166 bbls 6270 feet 2 K- 1 8 186 bbis 7035 feet 2 K- 2 0 274 bbls 9056 feet 2-7/8" TBG 6 ) RIH and pull all GLV's, OV's and CV's and replace with DV's. Ensure annulus is filled with diesel. 7) 8) 10) 11) Pressure test tubing to 2500 psi to ensure DV's are set. Place 2000 psi on casing while pressure testing to prevent tubing buckling. RIH and pull SV. RDMO Slickline. Prior to initiating water injection, a diesel/xylene spear should proceed 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 ramp up the injection rate until the WHP reaches 1500 psi. Keep the injection rate constant until Operations Engineering can pedorm a step rate test. Once the step rate test is complete, open wells to maximum injection pressure. STATE OF ALASKA , ~ : ALASKA OIL AND GAS CONSERVATION coMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [--~ GAS ~ SUSPENDED r~ ABANDONED E~] SERVICE [--"] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 89-118/9-1096 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20120 4 Location of Well at surface 9 Unit or Lease Name 244'FNL, 94'FEL, SEC 11 T10N, RSE UM 'i ~'/'~}~,~/, ! ~ ~.~:' , ~ ~-~:-r~ ~ ~.:. %,' :. ' " KUPARUK RIVER At Top Producing Interval ./- .'" 10 Well Number 746' FSL,606' FWL,SEC 11, T10N, RSE UM I ~"'~ i!, 2K-20 At Total Depth . 11 Field and Pool 431' FSL, 348' FWL, SEC 11, T10N, R8E UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Sedal No. KUPARUK RIVER OIL POOL RKB 154' ADL: 25588 ALK: 2674 1'2 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 12/3/89. 12/9/89. 6/22/90. NA feet M SLJ 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost & 6590' TVD 9700' MD & 6518' TVD YES [~] NO ['-'] 1794' feet MD 1400' APPROX 9808' MD 22 Type Electric or Other Logs Run DILISFLIGRISP/FDCICNLICALICBLIGYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BoTroM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 170 SX AS II 9 5/8" 36# J-55 SURF 3724' 12-1/4" 1200 SX AS III, 450 SX CLASS G 7" 26# J-55 SURF 9805' 8-1/2" 300 SX CLASS G ..... 24 Perforations open to Production (MD+'rVD of Top and Bottom and 25 TUBING RECORD interval, size and number) ~IZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 9167' 9117' 9362' - 9396' W/4-1/2" @ 4 SPF MD 6298' - 6319' TVD 26 ACID, FRACTURE. CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED SEE ATTACHED ADDENDUM 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ,,~ , FIowTubing 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. R[ EIVED J[JL ES 1990 Alaska 0il & Gas Cons. Anchorag, , . Form 10-407 Submit in duplicate Rev. 7-1-80 C,(~TINUED ON REVERSE SIDE 29. ' 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, ME..AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 9259' 6231' NA KUPARUK C BOTTOM 9269' 6238' !KUPARUK A TOP 9299' 6257' KUPARUK A BOTTOM 9502' 6388' , ,,, 3ii LIST OF ATTACHMENTS GYRO, FRAC 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S ig n e d _~~/,~____~~--~,,~ Title AREA DRILLING ENG NEER Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History - Initial Report - Daily Inetmctionl: Prepare and submit the "lldllll RIII~I~' on the first Wednesday after a wall i8 spudded or workover operations are started. Dally work prior to spudding Ih~ul~l be summarized on the form giving Inclusive dates only. District .: ICounty, parish or borough Istate .'M~CO AZ~SKA INC. I NORTH S:]'.~3PE I AK Field ILease or Unit KUPARUK RIVER ~NIT I ADL: 25588 ALK: 2674 Auth. or W.O. no. ITM AK4354 ] COMPLETIONS I Well no. KRU 12K-20 Operator IARCO W.I. ~CO I 55. 8533 Spudded orW.O, begUnSPUD IData 12/03/89 IH°ur 00=00 JPrlorstatusifaW,O. Date and depth as of 8:00 a.m. 05/09/90 (11) TD: 9808 PB: 9700 SUPV:GB 05/10/90 (12) TD: 9808 PB: 9700 SUPV:GB Complete record for each day reported NORDIC i CHANGE ELEMENT ON ANNULUAR BOP 7"@ 9805' MW:10.0 NaC1 MOVE RIG FROM 2K-21, ACCEPT RIG 0130 5/9/90, ND DRY HOLE TREE, NU BOPE AND TEST TO 3000 PSI, CHANGE OUT SEAL ELEMENT ON ANNULUAR BOP DAILY:S22,215 CUM:$985,083 ETD:S985,083 EFC:$1,200,00 TEST SSSV 7"@ 9805' MW:10.0 NaC1 CONT. C/O SEAL ELEMENT ON ANNULUAR BOP, RU HLS E-LINE, PU & RIH W/ PERF GUN#l, CCL FAILED, POH, REPAIR CCL, RIH GUN #1, PERFORATE 9382-9396, POH, ASF, PU & RIH W/ GUN #2, PERFORATE 9362-9382, POH, ASF, RD HLS E-LINE, RU & RIH W/ 2-7/8" SINGLE COMPLETION ASSEMBLY, MU CONTROL TO SSSVAND TEST, CONT. RIH, MU CONTROL LINE TO TBG HGR AND TEST, LAND TBG, RILDS, DROP BALL, PRESS TBG TO 2500 PSI TO SET PKR, PRESS ANNULUS TO 1000 PSI, BLEED ANNULUS PRESS, BLEED TBG PRESS TO 1200 PSI, BOLDS, PU & SHEAR PBR, BLEED TBG PRESS, RELAND TBG, RILDS, TEST SSSV DAILY:S29,907 CUM:$1,014,990 ETD:S1,014,990 EFC:$1,200,00 The above isv~rrect For form preparat~"~nd distribution, see Proc_edures__l~j.~al, Section 10, Drilling, Pages 86 and 87. Date / / I Number all daily well history forms consecutively as they are prepared for each well. Page no. AR3B-459-1-D ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "FIitel Rel~ert" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish State arco aLA$~ I~:. I .DJ. SLOP~. aK Field ILease or Unit I Well no. KUPARUK RIVER UNIT I ADL: 25588 ALK: 2674 KRU 2K-20 Auth. or W.O. no. ~Title AK4354 I COMPLETIONS I Operator ARCO A.R.Co. W.I. 55,8533 Spudded or W.O. begun Date SPUD 12/03/89 Date and depth as of 8:00 a.m. 05/11/90 (13) TD: 9808 PB: 9700 SUPV:GB Complete record for each day reported NORDIC 1 I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our IPrior status If a W.O, I 00:00 RIG RELEASED 7"@ 9805' MW:10.0 NeC1 CONT. TEST SSSV, BLEED PRESS, SET BPV, ND BOPE, NU TREE, PULL BPV, TEST TREE TO 5000 PSI, PRESS TEST ANNULUS TO 2500 PSI, PRESS TBG AND SHEAR BALL, BLEED PRESS, DISPLACE ANNULUS WITH 6 BBLS DIESEL, BULLHEAD 6 BBLS DIESEL DOWN TBG, RELEASE RIG AT 1000 5/10/90 DAILY:S146,821 CUM:$1,161,811 ETD:S1,161,811 EFC:$1,200,00 Released rig I Date IKtnd ofrig Classifications (oil, gas, etc,) Type completion (single, dual, etc.) Producing method Officixal reservoir name(s) Potential test data ..... Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pumo size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected ,, ,,. The above_.~ correct ~ ~ sFe°er ~%oced .... ~"anuaal?%edi~tir~nbU~i0,~)' ' ~ ~ ~' ~'~ ~ Drilling, Pages 86 and 87. Mummer all daily wsll hlsto~ lorma ~[~utlval~ - I Page as tha~ ar~ pr~Darod lot each wall. I A~3B-45~-3-G ADDENDUM WELL 2K-20 6114/90 Frac Kuparuk "A" sand perfs 9362'-9396' 180 deg oriented 17 deg ccw in ten stages as follows. Stage 1: Pmp 200 bbls YF240 Gel H20 prepad @ 18-20 bpm 7500-6450 psi Stage Stage Stage Stage Stage Stage Stage Stage Stage 45 bbls YF240 Gel H20 prepad @ 15 bpm 5500-5675 psi 30 bbls YF240 Gel H20 prepad @ 10 bpm 4550-5150 psi 2:60 bbls Gel H20 @ 20 bbm 6500-6050 psi 3:100 bbls Gel H20 Meter/Strap check @ 20 bpm 6000-5800 psi 4:1003 bbls YF240 Gel H20 pad @ 20bpm 6300-5900 psi 5:98 bbls YF240w/2 ppg 16/20 Carbolite @ 20 bpm 5000-5400 psi 6:121 bbls YF240 w/4 ppg 16/20 Carbolite @ 20 bpm 5400-5800 psi 7:131 bbls YF240 w/6 ppg 16/20 Carbolite @ 20 bpm 5800-6300 psi 8:52 bbls YF240 w/8 ppg 16/20 Carbolite @ 20 bpm 6300-6500 psi 9:30 bbls YF240 w/10 ppg 16/20 Carbolite @ 18 bpm 6500-6670 psi 10:48 bbls Slick Diesel flush @ 18-16 bpm 6670-7580psi Fluid to recover: 1715 bbls Sand in zone: 69,970 lbs Sand in csg: 3,500 lbs Avg pressure: 5800 psi Date SUB. SURFACE DIRECTIONAl. SURVEY ~"~ UIDANCE MICROFILMED I~OOL ,., ~_~!~.!,~_o. .., Company Well Name 2 K,- 20 (244' Field/Location KUPARUK,, Job Ref. erence No,.. 73622 MCBRIDE ARCO ALASK, A, INC. i FNL~,9,4' ,FEL~SEC ll,TION,R8E,,UM) _ NORTH SLOPE,; AL, ASKA SCHLUMBERGER OCT OIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 2K - 20 KUPARUK NORTH SLOPE, ALASKA SURVEY D~TE: Z~-DEC-1989 ENGINEER: M.MCBRIDE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATI3N AND AZIMUTH INTERPOLATION: LINE~D VERTICAL SECT!ON: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 47 DEG 3! MIN WEST CrJNPUTATI~N DATE: 4-JAN'-90 PAGE ARCO ALASKA, INC. 2K- 20 KUPARUK NORTH SLOPE~ ALASKA DATE OF SURVEY: 24-DEC-lgSg KELLY BUSHING ELEVATION= 154.00 FT, ENGINEER= M.MCBR~DE INTERPOLATED VALUES FOR EVEN 100 ~EET DF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DBG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST gIST. AZIMU'TH FEET DEG/IO0 =EET ~EET FEET DEG MIN 0.00 0.00 -'154. O0 0 0 N 0 O E 100.00 100o00 -54.00 0 3 S 79 49 W 200°00 200.00 46.00 0 1 S 9 59 W 300.00 300.00 146.00 0 3 N 89 49 W 400.00 400.00 246.00 0 8 S 27 15 W 500.00 500.00 346.00 0 20 S 14 19 W 600.00 600.00 446.00 0 31 S 14 37 W 700.00 699.99 545.99 I 18 S 39 23 W BO0.O0 799.78 645.78 6 4 S 58 6 W 900.00 898.80 744.80 9 0 S 59 11 W 0.00 0.00 0.00 N 0.00 E 0.04 0.09 0.03 S 0.02 W 0.13 0.08 0.10 S 0.09 W 0.15. 0.00 0.09 S 0.13 W 0,32 0.00 0.21 S 0.24 W 0.66 0.00 0.58 S 0.37 W 1,26 0.27 1.28 S 0,53 W 2.60 2.05 2.55 S 1.19 W 8.28 6.31 5.82 $ 5.90 W 21.91 1.25 13.12 S 17.70 W 0.00 N 0 0 E 0.0¢ S 27 33 W 0.13 S 43 3 W 0.15 S 54 47 W 0.32 $ 49 5 W '~ 0.69 S 32 13 W ,) 1,39 S 22 36 W 2.81 S 25 5 W 8.28 S 45 22 W 22.03 S 53 28 W 1000.00 997.40 $43.40 10 18 1100.00 1095.32 941.32 13 26 1200.00 1191.68 1037.68 17 13 1300.00 1286.47 1132.47 19 55 1400.00 1379.56 1225.56 23 1500.00 1470.10 1316.10 27 9 1600.00 1558.06 1404.06 29 39 1700.D0 1642.62 148B.62 34 24 1800.00 1724.42 1570.42 36 30 1900.00 1801.73 1647.73 41 21 S 62 37 W 38.12 2.18 S 65 21 W 57.54 4.01 S 64 36 W 82.84 3.08 S 60 6 W 113.64 2.91 S 56 52 W 149.46 3.86 S 52 12 W 191.54 3.77 S 52 11 W 238.95 4.48 S 55 42 W 291.91 1.92 S 54 54 W 348.84 6.43 S 51 40 W 411.92 1.26 21.18 S 32.30 W 38.62 S 56 45 W 30.06 S 50.49 W 58.76 S 59 14 W 41.03 S 74.76 W 85.28 S 61 14 W 55.93 S 102.88 W 117.10 S 61 28 W 75.02 S 133.95 W 153.53 S 60 45 W 99.70 S 168.42 W 195.72 S 59 23 W 129.11 S 205.77 W 242.93 S 57 54 W 160.35 S 248.97 W 296.14 S 57 13 W 192.81 S 296.45 W 353.63 S 56 58 W 230.96 S 347.04. W 416.87 S 56 2:1 W 2000.00 1876.00 1722.00 43 33 2100.D0 1945.95 1791.95 46 31 2200.00 2014.12 1860.12 49 4 2300.00 2076.18 1922.18 52 52 2400.00 2136.72 1982.72 52 43 2500.00 2197.65 2043.65 52 8 2600.00 2259.91 2105.91 50 46 2700.00 2323.5!3 2169.58 50 12 2800.00 2386.45 2232.46 52 57 2900°00 2441.81 2287.81 58 34 S 50 3 W 478.74 S 48 39 w 550.16 S 47 1 W 623.30 S 45 30 W 701.65 S 45 56 W 781.21 S 45 57 W ~60.47 S /+6 I W 938.69 S 4,6 I W 1015.78 S 45 23 W 1093.&9 S 4.5 9 W 1176.64 6.94 0.79 7.96 0.44 0.35 0.77 0.87 0.25 7.22 272.95 S 399.1'9 W 483.58 S 55 38 W 319.83 S 453.0'9 W 554.61 S 54 47 W 368.67 S 507.55 W 627.32 S 54 0 W 423.14 S 563.91 W 795.01 S 53 7 W 478.74 S 620.87 W 784.01 S 52 22 W 533.84 S 677.89 W 862.85 S 51 47 W 538.19 S 734.19 W 940.74 S 51 18 W 641.72 S 7!39.69 W 1017.55 S 50 54 W 695.90 S 845.44 W 1095.01 S 50 33 W 754.64 S 904.40 W 1177.89 S 50 9 W 3000.00 2493.89 2339.89 58 33 3100.00 2546.39 239Z.39 58 7 3200.00 2599.41 2445.41 57 52 3300.00 2654.07 2500.07 54 44 3400.00 2713.13 2559.13 53 28 3500.00 2772..51 2618.51 53 45 3600.00 2831.43 267T.43 54 7 3700.00 2890.19 2736.19 53 43 3800.00 2948.90 2794.90 54 25 3900.00 3007.00 2853.00 54 33 S 45 I9 w 1261.94 S 45 21 W 1346.99 S 45 4~ W 1431.73 S 47 59 W 1515.43 S 49 9 W 1596.11 S 49 25 W 1676.53 S 49 42 W 1757,28 S 49 36 W 1838.14 S 49 44 W 1919.03 S 4.9 31 W 2000.37 0.40 1.12 0.00 4.95 0.21 0.29 0.35 0.73 0.15 0.22 814.75 S 965.02 W 1262.96 S 49 .50 W 874.61 S 1025.52 W 1347.83 S 49 32 W 933.93 S 1086.10 w 1432.42 S 49 18 W 991.52 S 1146.86 W 1516.05 S 49 9 W 1044.72 S 1207.54 W 1596.74 S 49 8 W 1097.75 S 1268.43 W 1677.20 S 49 8 W 1149.65 S 1329.98 W 1758.00 S 49 10 W 1202.07 S 1391.63 W 1838.91 S 49 11 W 1254.42 S 1453.37 W 1919.qj6 S 49 12 W 1307.14 S 1515.38 W 2001.25 S 49 13 W C3MPUTATION DRT~: 4-JAN-90 PAGE Z ARCO ALASKA, INC. DATE OF SURVEY: Z4-DEC-lgB9 2K - 20 KE'LLY BUSHING ELEVATION: 154.00 F~ KUPARUK NORTH SLOPEr ALASKA ENGINEER: M.MCBRiDE INTERPOLATED VALUES FOR EVEN 100 FEET OF 'MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH'EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 4000.00 3065.07 2911.07 5¢ 29 4100.00 3123.44 2969.44 54 16 4200.00 3181.7,3 3027.78 54 24 4300.00 3239.60 3085.60 54 56 4400.00 3296.69 3142.69 55 27 4500.00 3353.03 3199.03 55 54 4600.00 3410.32 3256.32 53 41 4700.00 3469.7,5 3315.76 53 38 4800.00 3528.51 3374.51 54 22 4900.00 3586.26 3432.26 55 0 5000.00 3643.15 3489.15 55 21 5100.00 3700.82 3546.~2 54 28 5200.00 3758.83 3604.83 54 40 5300.00 3816.35 3662.35 55 7 5400.00 3873.39 3719.39 55 23 5500.00 3930.38 3776.38 54 36 5600.00 3989.98 3835.98 52 48 5700.00 4050.13 3896.13 53 15 5800.00 4109.74 3955.74 53 35 5900.00 4168.95 4014.95 53 47 6000.00 4227.76 4073.76 54 6 6100o00 4286.25 4132.25 54 20 6200.00 4344.50 4190.50 54 10 6300.00 4404.25 4250.25 52 47 6400.00 4454.69 4310.59 52 51 6500.00 4524.8~ 4370.32 53 12 6600.00 45~4.48 4430.48 53 26 6700.00 4644.12 4490.12 53 25 6800.00 4703.51 4549.51 53 47 6900.00 4762.42 460~.42 54 0 7000.00 4820.96 4666.96 54 7 7100.00 4879.55 4725.55 54 19 7200.00 4937.54 4783.54 54 42 7300.00 4996.12 4842.12 53 41 7400.00 5055.44 4901.44 53 43 7500.00 5115.27 4961.27 52 13 7600.00 5177.37 5023.37 51 30 7700.00 5241.32 5087.32 48 10 7800.00 5308.85 5154.~5 47 31 7900.00 5375.78 5221.78 48 19 DEG M'IN FEET DEG/IO0 FEET FEET FEET DEG MIN S ,49 16 W 2081.73 S ~9 1 W 2162.90 S 48 52 W 2244.09 S 48 50' W 2325.66 S 48 50 W 2407.74 S 48 49 W 2490.34 S 48 52 W 2572.27 S 48 47 W 2652..66 S 48 41 W 2733.57 S 48 35 W 2815.19 S 48 41 W 2897.42 S 49 8 W 2979.08 S 49 10 W 3060.50 S 49 1Z W 3142.27 S 49 15 W 3224.37 S 49 Zl W 3306.51 S 49 19 W 3386.76 S 49 25 W 3466.60 S 49 30 W 3546.85 S 49 35 W 3627.38 S 49 41 W 3708.21 S 49 49 W 3789.26 S 49 48 W 3879.47 S 49 34 W 3950.60 S 49 33 W 4030.22 S 49 30 W 4110.07 S 49 21 W 4190.29 S 49 1~, W 4270.51 S 48 2'7 W 4350.95 S 48 22 W 4431.74 S 48 13 W 4512.81 S ~8 11 W 4593.84 S 48 ~ W 4675.31 S 46 21 W 4756.34 S 44 56 W 4835.80 S 43 14 W 4916.78 S 42 27 W 4994.88 S 41 ~6 W 5071.40 S 40 38 W 5144.64 S 40 34 W 5218.39 0.09 0.58 0.40 0.42 0.88 0.23 1.43 1.00 0.82 0.56 1.06 0.25 0.14 0.2.1 0.11 2.63 0.16 0.22 0 0.26 0.24 0.34 1.32 0.25 0.37 0.32 0.12 0.62 0.73 0.98 0.20 0.52 0.58 1.91 0.73 3.22 0.59 3.70 0.94 0.58 1360.14 S 1577.17 W 2082.65 S 49 14 W 1413.30 S 1638.55 W 2163.85 S 49 13 W 1466.64 S 1699.80 W 22.45.07 S 49 13 W I520.35 S 1761.21 W 2326.66 S 49 12 W 15'74.39 S 1823.02 W 2408.76 S 49 11 W 16.28.79 S 1885.20 W 2491.37 S 49 10 W 1682.72 S 1946.91 W 2573.33 S z~9 10 W 1735.65 S 2007.45 W 2653.74 S 49 9 W 1789.04 S 2068.27 W 2734.66 S 49 8 W 1842.98 S 2129.55 W 2816.3.0 S 49 8 W 1897.38 S 2191.23 W 3898.54 S 49 7 W 1951.02 S 2252.83 W 2980.22 S 49 6 W 2004.30 S 2314.44 W 3061.68 S 49 6 W 2057.78 S 2376.34 W 3143.48 S 49 7 W 2111.44 S 2438.5.3 W 3225.62 S 49 7 W 2165.05 S 2500.81 W 3307.79 S 4'9 7 W 2217.37 S 2561.71 W 3388.08 S 49 7 W 2269.33 S 2622.35 W 3467.97 S 49 8 W Z321.57 S 2683.3,,6 W 3548.26 S 49 8 W 2373.86 S 2744.68 W 3628.84 S 49 9 W 2426.27 S 2806.28 W 3709.72 S 49 9 W 2478.67 S 2868.19 W 3790.82 S 4) 10 W 2531.12 S 2930.29 W 3872.10 S 49 11 W 2583.05 S 2991.38 W 3952.28 S 4':J 11 W 2634.76 S 3051.99 W 4031.94 S 4::} 12 W 2686.62 S 3112.78 W 4111.85 S 49 12 W 2738.81 S 3173.74 W 4192.10 S 49 12 W 2791.15 S 3234.60 W 4.272.37 S 49 13 W 2844.1~ S 3295.14. W 4352.$2 S 49 12 W 2897.79 S 3355.55 W 4433.62 S 49 11 W 2951.72 S 3416.10 W 4514.613 S 49 10 W 3005.76 S 3476.49 W 4595.71 S 49 9 W 3060.11 S 3537.18 W 4677.17 S 49 8 W 3115.07 S 3596.73 W 4758.16 S 49 6 W 3171.50 S 3654.13 W 4.83,3.51 S 49 3 W 3228.92 S 3710.02 W 4918.)5 S 48 58 W 32'36.58 S 3763.11 W 4996.26 S 48 52 w 3343.53 S 3814.71 W 5072.60 S 48 46 W 3399.38 S 3862.88 w 5145.64 S 4)3 39 W 3455.81 S 3911.20 W 5219.21 S 48 32 W COMPUTATI3N DATE: 4-JAN-g0 PAGE ARCO ALASKA, INC. 2K - 20 KUPARUK NORTH SLOPEm ALASKA DATE OF SURVEY: 24-0EC-1989 KELLY BUSHING ELEVATION: 154.00 F~ ENGINEER: M.MC~RIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SE& COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/.IO0 FEET FEET FEET DEG MIN 8000.00 5441.83 5287.83 48 55 8100.00 5507.07 5353.07 49 43 8200.00 5571.23 5417.23 50 27 8300.00 5634.70 5480.70 50 41 8400.00 5698.01 5544.01 50 47 8500.00 5760.74 5606.74 51 33 8600.00 582.2.47 5668.47 52 5 8700.00 5883.5.3 5?29.53 52 43 8800.00 5943.73 5789.73 53 16 8900.00 6004.55 5850.55 51 23 S 40 35 W 5292.92 S 40 31 W 5368.14 S 40 29 W 544~,.27 S 40 22 W 5520.96 S 40 0 W 5597.?3 S 39 48 W 5674.91 S 39 24 W 5752.84 S 39 4 W 5831.20 S 38 47 W 5910.16 S 38 39 W 5988.58 0.5,6 0.88 0.61 0.56 0.74 1.06 0.53 0.43 0.82 1.95 3512.84 S 3960.04 W 52'93.58 S 48 25 W 3570.44 S .4009.30 W 5.368.66 S 48 19 W 3628.78 S 4059.10 W 5444.66 S 49 12 W 3687.58 S 4109.23 W 5521.24 S 48 6 W 3746.74 S 4159.15 W 55'97.91 S 47 59 W 3806.49 S 4209.10 W 5675.02 S 47 53, W / 3867.11 S 4259.25 W 5752.89 S 4'7 46 W 3928.45 S 4309.34 W 5831.22 S 47 39 W 3990.56 S 4359.51 W 5910.16 S 47 32 W 4052.55 S 4409.09 W 5988.59 S 47 25 W 9000°00 6067.57 5913.57 50 43 9100.00 6130.37 5976.37 51 17 9200.00 6193.72 6039.72 50 12 9300.00 6257.98 6103.98 49 58 9400.00 6322.01 6168.01 50 15 9500.00 6386.45 6232.45 49 21 9600.00 6452.13 6298.13 48 43 9700.00 6518.10 6364.10 48 23 9800.00 6584.51 6430.51 48 23 9808.00 6589.83 6435.83 48 23 S 38 1W 6065.25 S 37 25 W 6141.90 S 37 39 W 6R18.09 S 37 2'7 W 6293.57 S 36 50 W 6369.11 S 36 55 W 6444.24 S 38 10 W 6518.46 S 39 0 W 6598.00 S 39 0 W 6671.93 S 39 0 W 6677.85 1.0'9 1.07 0.62 0.72 0.54 0.94 1 0.00 0.00 0.00 4113.36 S 4457.36 W 6065.29 S 47 18 W 4175.02 S 4504.84 W 6142.01 S ~l 11 W 4236.41 S 4551.93 W 6218.30 S 47 3 W 4297.09 S 4598.70 W 6293.89 S 46 ST W 4358.3~ S 4645.01 W 6369.59 S 46 49 W 4419.65 S 4690.7'7 W 5444.89 S 46 42 W 44?9.56 S 4]'36.56 W 6519.31 S 46 36 W 4541.79 S ~,787.41 W 6599.02 S 46 30 W 4599.90 S 4834.45 W 6673.15 S 46 25 W 4604.55 S 4838.21 W 6679.08 S 46 25 W 'COMPUTATION BATE: 4-JAN-90 PA~E ~ ARCO ALASKA, !NC. 2K - ZO KUP~RUK NORTH SLOPE., ALASKA TRUE SUS-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH BEG MIN BEG MIN DATE OF SURVEY: .24-DEC-1989 KELLY 5USHING ELEVATION: 154.00 F~ ENGINEER: M.MCBR~DE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. ,AZIMUTH FEET DEG/IO0 ~EET FEET ~EET DEG MIN N 0 0 E 0.00 S 62 37 W 38.12 S 50 3 W 478.74 S 45 19 W 1261.94 S 49 16 W 2081.73 S 48 41 W 2897.42 S 48 13 W 4512.81 S 40 35 W 5292.92 S 38 1 W 6065.Z5 0.00 0.00 -154.00 0 0 1000.00 997.40 843.40 10 18 2000.00 1876.09 1722.00 43 33 3000.00 2493.89 2339.89 58 33 4000.00 3065.07 2911.0~ 54 29 5000°00 364~.15 3489.15 55 21 6000.00 4227.76 4073.76 54 6 7000.00 ~8Z0.96 4666.96 54 7 8000.00 5441.83 5287.83 48 55 9OOO.O0 6067.57 5913.57 50 43 9808.00 6589.83 6435.83 48 23 S 39 0 W 6677.85 0.00 2.18 6.94 0.40 0.09 1.06 0.24 0.20 0.56 1.09 0.00 0.00 N 0.00 E 0.00 N 0 0 E !1.18 S 32.30 W 33.6Z S 56 45 W 272.95 S 399.19 W 483.58 S 55 38 W 814.75 S 965.02 W 1262.96 S 49 50 W 1360.14 S 15'77.17 W Z082.65 S 49 14 W ) 1897.38 'S 2191.23 W Z898.54 S 49 7 W 24Z6.27 S Z806.28 W 3709.72 S 49 9 W 2951.72 S 3416.10 W ~514.68 S 49 10 W 3512.84 S 3960.04 W 5293.55 S 48 25 W 4113.36 S 4457.36 W 6065.29 S 47 18 W 4604.55 S 4838.21 W 6679.08 S 46 25 W COMPUTATION D~TE: 4-JAN-g0 PAGE ARCO ALASKA, INC. 2K - ZO KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 24-DEC-1989 KELLY BUSHING ELEVATION: 154.00 FT ENGINEER: M. MC6R~OE INTERPOLATED VALUES FOR EVEN 100 FEET DF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATIQN AZIMUTH DEPTH DEPTH DEPTH DEG MIN D~G MIN VERTICAL DOGLEG RECTANGULAR COORDINaTeS HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -154.00 0 0 N 0 0 E 154.00 154.00 0.00 0 5 S 36 46 W 254.00 254.00 100.00 0 1 N 67 22 W 354.00 354.00 200.00 0 7 S 37 11 W 454.00 454.00 300.00 0 14 S 19 21 W 554.00 554.00 400.00 0 25 S 12 36 W 654.01 654.00 500.00 0 50 S 25 53 W 754.06 754.00 6OD.OD 3 15 S 55 41 W 854.67 854.00 700.00 8 22 S 58 8 W 955.93 954.00 800.00 9 40 S 61 26 W 0.00 0.00 0.00 N 0.00 E 0.10 0.24 0.06 S 0.08 W 0.13 0.00 0.10 S 0.09 W 0.22 0.01 0.12 S 0.19 W 0.46 0.36 0.35 S 0.30 W 0.95 0.11 0.92 S 0.45 W 1.80 0.67 1.86 S 0.75 W 4.61 5.84 3.83 S 2.75 W 15.t9 1.35 9.54 S 11.86 W 30.75 1.54 17.62 S 25.57 W 0.00 N 0 0 E 0.10 S 52 29 W 0.13 S 44 37 W 0.22 S 57 3 W 0.47 S 40 25 W 1.OZ S 25 52 W 2.00 S 21 52 W 4.71 S 35 41 W 15.22 S 51 11 W 31.05 S 55 26 W 1057.65 1054.00 900.00 11 46 1160.66 1154.00 1000.00 15 59 1265.56 1254.00 1100.00 18 59 1372.32 1354.00 1ZO0.O0 22 4 1481.97 1454.00 ltO0.O0 26 29 1595,.31 1554.00 1400.00 29 26 1713.82 1654.00 1500.00 34 34 1837.42 1754.00 1600.00 38 52 1970.01 1854.00 1700.00 42 13 2111.68 1954.00 1800.00 46 26 S 64 0 W 48.68 3.55 S 66 7 W 72.09 3.73 S 61 19 W 102.45 3.11 S 57 47 W 139.00 3.53 S 52 51 W 183.45 4.49 S 52 O W 336.62 4.02 S 55 50 W 299.66 1.1.Z S 53 22 W 371.61 6.73 S 51 1 W 458.39 3.32 S 48 37 W 558.62 0.83 26.11 S 42.10 W 49.54 S 58 12 W 36.32 S 64.50 W 74.02 S 60 37 W 50.29 S 92.86 W 105.61 S 61 34 W 69.29 S 125.02 W 142.94 S 61 0 W 94.76 S 161.97 W 187.65 S 59 40 W 127.68 S 203.91 W 240.59 S 57 57 W 164.75 S 255.45 W 303.97 S 57 11 W 206.26 S 315.00 W 376.52 S 56 47 W 260.01 S 383.45 W 463.29 S 55 52 W 325.43 S 459.44 W 563.02 S 54 41 W 2263.43 2054.00 1900.00 52 24 2428.49 2154.00 2000.00 52 36 2590.63 2254.00 2100.00 50 52 2747.71 2354.00 ZZO0.O0 50 41 2923.41 2454.00 2300.00 58 40 3114.39 2554.00 2400.00 58 4 3299. !37 2654.00 2500.00 54 45 3468.72 2754.00 2600.00 53 40 3638.53 2854.00 2700.00 54 10 3808.77 2954.00 2800.00 54 25 S 4,5 40 W 672.59 S 46 0 W 803.35 S 46 2 w 931.43 S 45 56 w 1052.52 S 45 12 w 1196.61 S 45 26 w 1359.19 S 47 59 W 1515.32 S 49 17 W 1651.33 S 49 3~3 W 1788.48 S 49 43 W 1)26.16 2.63 0.69 1.21 I .93 0.33 0.57 4.96 0.72 0.36 0.16 402.78 S 543.15 W 676.20 S 53 26 W 494.49 S 637.16 W 806.53 S 52 11 W 583.14 S 728.96 W 933.51 S 51 ZO W 667.26 S 816.12 W 1054.17 S 50 44 W 768.73 S 918.58 W 1197.80 S 50 4 W 883.18 S 1034.22 W 1360.01 S 49 30 W 991.45 S 1146.78 W 1515.94 S 49 9 W 1080.$2 S 1249.35 W 1651.99 S 49 8 W 1169.86 S 1353.79 W 1789.22 S 49 10 W 1259.03 S 1458.81 W 1926.99 S 49 12 W 3980.94 3054.00 2900.00 54 28 4152,.35 3154.00 3000.00 54 17 4325.11 3254.00 3100.00 55 5 4501.73 3354.00 3ZOO.OD 55 55 4673.46 3454.00 3300.00 53 29 4843.94 3554.00 3400.00 54 44 5019.06 3654.00 3500.00 55 8 5191.65 3754.00 3600.00 54 39 5365.92 3854.00 3700.00 55 16 5540.17 3954.00 3800.00 53 28 S 49 18 W 2066.22 S 48 58 W 2205.40 S 48 51 W 2346.22 S 48 49 W 2491.77 S 48 50 W 2631.32 S 48 40 W 2769.35 S 48 48 W 2913.08 S 49 lO W 305).69 S 49 14 W 3196.36 S 49 21 W 3338.98 0.36 0.04 0.67 0.20 0.64 0.72 1.92 0.12 0.51 2.66 1350.01 S 1565.42 W 2067.14 S 49 14 W 1441.20 S 1670.62 W 2206.36 S 49 13 W 1533.89 S 1776.70 W 2347.23 S 49 12 W 1629.74 S 1986.28 W 2492.81 S 49 10 W 1721.58 S 1991.39 W 2632.39 S 49 9 W 1812.67 S 2095.14 W 2770.45 S 49 8 W 1907.71 S 2203.00 W 2914.20 S 49 7 W 1999.85 S 2309.29 W 3054.87 S 49 6 W 2093.14 S 2417.30 W 3197.59 S 49 7 W 2186.21 S 2525.46 W 3340.28 S 49 7 W COMPUTATION DATE: 4-JAN-90 PA3E 6 ARCO ALASKA, INC. 2K - 20 KUP~RUK NORTH SLOPE, ALASKA DATE OF SURVEY: 24-DEC-1989 KELLY 5USHING ELEVATION: 154.00 FL ENGINEER: M.MCBR~DE INTERPOLATED VALUES FOR EVEN 100 FEET DF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH D~PTH DEPTH BEG MIN DEG MIN VERTZC&L DOGLEG REC'TANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET OEG MIN 5706.47 4054.00 3900.00 53 16 5874.71 4154.00 4000.00 53 45 6044.80 4254.00 4100.00 54 11 6216.12 4354.00 4200.00 53 52 6382.30 4454.00 4300.00 52 48 6548.83 4554.00 4400.00 53 25 6716.58 4654°00 ~500.00 53 26 6885.68 4754.00 4600.00 53 57 7056.31 4854.00 4700.00 54 5 7228.37 4954.00 4800.00 54 24 S 49 25 w 3471.78 S 49 35 W 3507.00 S 49 45 w 3744.49 S 49 45 W 3883.49 S 49 32 W 4016.12 S 49 27 W 4149.21 S 49 ~ W 4283.82 S.48 23 W 4420.17 S 48 10 W 4558.41 S 47 44 W 4698.42 0.17 0.06 0.14 1.91 0.46 0.50 0.90 0.62 0.58 2.23 2272.76 S 2626.28 W 3473.15 S 49 8 W 2360.63 S 2729.16 W 3608.44 S 49 8 W 2449.75 S 2833.98 W 3746.03 S 49 10 W 2539.54 $ 2940.23 W 3885.13 S 49 11 W 2625.60 S 3041.25 W 4017.83 S 49 12 W ) 2'712.06 S '3142.54 W 4151.00 S 49 12 W 2799.85 S 3244.68 W 4285.68 S 49 13 W 1890.10 S 3346.90 W 4%22.04 S 49 11 W 2982.13 S 3450.08 W 4560.2~9 S 49 10 W 3075.61 S 3554.32 W 4700.27 S 49 8 W 7397.57 5054.00 4900.00 53 43 7562.51 5154.00 5000.00 51 26 7718.94 5254.00 5100.00 47 40 7867.29 5354.00 5200.00 48 9 8018.53 5454.00 5300.00 49 l 8172.99 5554.00 5400.00 50 16 8330.48 5654.00 5500.00 50 45 8489.15 5754.00 5600.00 51 26 8651.44 5854.00 5700.00 52 22 8817.17 5954.00 5800.00 53 15 S 44 57 W 4834.84 S 42 28 W 4965.68 S 40 53 W 5085.38 S 40 34 W 5194.17 S 40 34 W 5306.79 S 40 29 W 5423.63 $ 40 14 W 5544.37 5 39 50 W 5666.50 S 39 1~, W 5793.07 S 38 42 W 5923.75 0.72 0.50 2.07 0.47 0.49 0.71 0.45 1.37 I .10 0.92 3170.11 S 3652.76 W 4836.55 S 49 3 W 3264.95 S 3743.32 W 4967.13 S 48 54 W 3354.13 S 3823.96 W 5086.54 S 4'~ 45 W 3437.27 S 3895.34 W 5195.05 S 48 34 W 3523.46 $ 3969.13 W 5307.43 S 4~ 24 W 3612.96 S 4045.60 W 5424.05 S 48 14 W 3705.58 S 4124.4'9 W 5544.62 S 48 4 W 3799.96 S 4203.67 W 5666.61 S 47 53 W 3898.56 S 4285.00 W 5793.10 S 47 42 W 4001.29 S 4368.12 W 5923.75 S 47 31 W 8978.55 6054.00 5900.00 50 45 9137.57 6154.00 6000.00 50 50 9293.81 6254.00 6100.00 49 57 9449.91 6354.00 6Z00.00 49 57 9602.84 6454.00 6300.00 48 42 9754.05 6554.00 6400.00 48 23 9808.00.v/ 6589.83j 6435.H3 48 23 S 38 17 W 6049.86 S 37 26 W 6170.67 S 37 29 W 6288.91 S 36 41 W 6406.75 S 38 13 W 6520.57 S 39 0 W 6637.96 S 39 0 W 6677.85 0.87 1.34 0.63 1.61 1.44 0.00 0.00 4100.30 S 4447.10 W 60~8.90 S 47 19 W 4198.22 S 4522.59 W 6170.81 S 47 8 W 4293.33 S 4595.82 W 6289.22 S 45 57 W 4389.08 S 4667.93 W 6407.31 S 45 46 W 4481.24 S 4737.87 W 6521.42 S 46 36 W 4573.20 S 4812.83 W 6639.09 S 45 28 W } 4604.55 S 4838.2l W 6679.09 S 46 25 W COMPUTATI3N DATE: 4-JAN-g0 PA~E 7 ARCO ALASKA, INC. 2K - 20 KUPARUK NORTH SLOPE, ALASKA MARKER 9 5/8" CSG TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A GCT LAST READING PSTD TD 7" CSG DATE DF SURVEY: 24-DEC-1989 KELLY 5USH[NG ELEVATION: 15'~.00 FI ENGINEER: M.MCSRiDE INTERPOLATEO VALUES FOR CHOSEN HORIZONS SURFACE LOCATION : 244' FNL & 9,4' FELt SECll TION RSE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3723.00 9259.00 9269.00 9299.00 9502.00 9642.25 9700.00 9808.00 9808.00 2903.78 2749.73 6231.60 6077.60 6238.03 6084.03 6257.34 6103.34 6387.75 6233.75 6479.75 6325.'75 6518.10 6364.10 6589.83 6435.83 6589.B3 6435.83 1214.09 S 4272. Z1 S 4,278.28 S 4296.49 S 4420..~6 S 4508.23 S 4541.79 S 4604.55 S 4604.55 S 1405.76 W 4579.57 W 4584.25 W 4598.24 W 4691.68 W 4760.25 W 4787.41 -W 4838. Z1 W 4838.21 W C~MPUT~TI3N DATE: 4-JAN-90 ARCO ALASKA, INC. 2K - 20 KUPARUK NORTH SLOPE, ALASKA BATE OF SURVEY: Z4-DEC-lgS9 KELLY ~USHING ELEVATION: I54.00 FT, ENGINEER: M.McsRiDE SURFACE LOCATION : 244' FNL & 94' FEL, SEC!I TION RSE MARKER MEASUREO DEPTH TVO BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 9 5/8" CSS TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUP~RUK A PBTD TD ?" C SG 3723o0D 290].78 2749o7B 121~.09 S 9259.00 6231..60 6077.60 4272.21 S 9269.00 6238°03 6084.03 4275.28 S 9299.00 6257.34 6103.34 4296.49 S 9502.00 6387.75 6233.75 4420.8f S 9700.00 651~oI0 6~64.10 4541.79 S 9808.00 6589.~3 64135.83 4604.55 S 9808.00 6589.83 6435.83 4604.55 S 1405.T6 W 4579.57 W 4584.25 W 4598.24 W 4691.68 W 4787.41 W 4838.21 W 4838.21 W FINAL WELL LOC~TION ~kT TO: TRUE SUS-SE~ MEASURED VERTIC,aL VERTIC&L DEPTH DEPTH DEPTH HORIZ3NTAL DEPARTURE DISTANCE &ZIMUTH mEET DEG MIN 9808.00 6589.83 6435.83 6679.08 S 46 25 W SCHLUMBERGER O I REC T I ONAL SURV E Y COMPANY ARCO ALASKA. INC. WELL 2K- 20 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOED 24 - DEC - 89 REFERENCE ?3622 WELL" '(244' '-'ORIZTONAL PROJECTION ,2K-20 FNL, 94' FEL, SEC ~l, TION, R8E, UM) NORTH 2000 REF ?9622 SCALE: = 1/1DO0 IN/FT .1_~ ..... , -.' ..-,.-..~.-~-..-~..-~ -~~,-4....,....~ .... ~..4-..~-.-;, ....... ;..-b-..~,.4..-.~.-..p.-~...-,.-~.- ..-~..-~..4...4 ....... ~ ..... ~..-,...- ...4..-~.-;...,p...~..-~....~...~... ~..-~..,.~..4..-; ...... ~,..~...;....~ ........ ~..-~....;..-~.. · --i--4..4-4..~.--1--.}.-4..4.-4.-4,-4.-4.4.-~.-4---t-4-4 ....... F-F4,--k-4..4-~..-V.-4.--.-4-:-F-F-b-.{.--~-4-.-F4 ...... ;-4..4-4-.-~.-t--F.;...l...'.4...i..-F4 ..... 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SCALEO IN VERTICi:~. OEPT~ HORIZ SCALE = 1/2000 IN/FT PERMIT # ~' - · bUM~LC i IUI~ U~I C /'/O0 WELL NAME ,~ j /'/ I ,~o co. Co,%rrAcT I '" ^o~cc GEoLoGi'C'~L MATERIALS INVENTORY LIST [ check off or list data as it is received ~ 4(17 i ~,,~/"?' drilling h~o~ ,~? ~,r~y I,/i ~,,,~***, ! rare d,~sriptian cored i~tewals, core analysis ......... d~ ditch inte~als , di~ita~ data ............ .~~ , , I ,, , ,, , h , LOG TYPE RUN INTERVALS SCALE NO, RI' c.O T / ?poop/- p~poo' , , .... , I,, , , , , ....... , ..... , ARCO Alaska, Inc. Date: January 5, 1990 Transmittal #: 7640 RERJRN 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 - 03 ' Acoustic Cement Bond Log 9 - 26 - 89 6894 - 8742 2 K - 04 Acoustic Cement Bond Log 11 - 04 - 89 9000 - 10703 2 K - 14 AcoUstic Cement Bond Log 11 - 05 - 89 5019 - 8042 2K-1 7 CBT I 2-25-89 7245-9018 2K-20 CBT I 2-24-89 7889-9698 2K-22 CBT I 2-24-89 7923-9708 Receipt Acknowledged: ..... ~;- Date' DISTRIBUTION: NSK Drilling RECEIVED JAN ! 21 00 Anch0rag~ The following were received without a transmittal: 2K-20 Kuparuk API 50-103-20120-00 Dual Induction SFL 2" Sepia/Blueline Dual Induction SFL 5" Sepia/Blueline Compensated Neutron Formation Density Raw Data Sepia/Blueline Compensated Neutron Formation, Density Porosity Sepia/Blueline Cyberlock Sepia/Bluel ine ARCO Alaska, Inc. Date: December 21, 1989 Transmittal #: 7632 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- 2 0 OH Edit Tape and Listing (.t(,~ 1 2- 1 0- 8 9 # 7 3 5 8 8 Receipt Acknowledged: ............................. Date' DISTRIBUTION: Lynn Goettinger · State of Alaska 1. Type of Request: Abandon _ Suspend Alter casing _ Change approved program _ 2. Name of Operator ' STATE OF ALASKA ~ AL.A,sc, A OIL AND GAS CONSERVATION COMMIS,51ON APPLICATION FOR SUNDRY APPROVALS Repair well _ Plugging _ Pull tubing _ 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Operation Shutdown ~ Re-enter suspended well _ Time extension _ Stimulate _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) Plugs (measured) None RKB 154' 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-20 feet 9. Permit number 89-118 10. APl number ~0-103-20120 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool 4. Location of well at surface 244' FNL, 94' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 734' FSL,510' FWL, Sec. 11, T10N, R8E, UM (approx) At effective depth 537' FSL, 349' FWL, Sec. 11, T10N, R8E, UM (approx) At total depth 472' FSL, 295' FWL, Sec. 11,T10N, R8E, UM (approx) 12. Present well condition summary Total Depth: measured 9808' feet (approx) true vertical 6586' feet 9700' feet Junk (measured) 651 9' feet None Effective depth: measured (approx) true vertical Size Cemented Measured depth True vertical depth 16" 115' 115' 9 5/8" 1200 Sx AS III & 3723' 2907' (approx) 450 Sx Class G 7" 300 Sx Class G 9808' 6586' (approx) None Casing Length Structural 8 0' Conductor Surface 3 6 8 8' Intermediate Production 9 7 75' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Description summary of proposal Detailed operation program BOP sketch 13. Attachments Status of well classification as: Gas ~ Suspended IApproval No. I 14. Estimated date for commencing operation 15. February, 1990 Oil X 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned '~) ~' (~'~ C~FoRTitle COMMISSIoNArea DrillingUSEEn~]ineerONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test~ Location clearance ~ Mechanical Integrity Test_ Subsequent form require u~i~IGiNAL SIGNED ~Y LOHNIE C. SMITH Commissioner SUBMIT IN TRIPLICATE Approved by the order of the Commission Form 10-403 Rev 06/15/88 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial ReDort" 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. Field County. parish or borough J NORTH SLOPE ILease or Unit J ADL: 25588 ALK: 2674 Title · ~ DRILLING IState Well no, KUPARUK RIVER UNIT Auth. or W.O. no. AK4354 KRU 2K-20 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. Date Hour 12/03/89 00:30 J Complete record for each day reported DOYON 14 DRLG 12.25" HOLE MW: 8.9 VIS: 97 MOVE RIG IN,NU 20"DIVERTER, PU BHA, DRLG F/l15 T/924' IARCO WI. 55 ,8533 Prior status il a W.O. 12/03/89 (1) TD: 924'( 924 SUPV:CD 12/04/89 ( 2) TD: 3745'( 2821 SUPV:CD 12/05/89 (3) TD: 3745'( 01 SUPV:CD 12/06/89 (4) TD: 5823'( 2078 SUPV:CD 12/07/89 (5) TD: 9049'( 3226 SUPV:CD 12/08/89 (6) TD: 9264'( 215 SUPV:SC 12/09/89 (7) TD: 9575'( 311 SUPV:SC DAILY:S58,708 CUM:$58,708 ETD:S58,708 RFC:S1,200,000 CIRC MW: 9.2 VIS: 98 DRLG F/924 T/3745, CIRC HOLE PRIOR TO SHORT TRIP. DAILY:S52,933 CUM:$111,641 ETD:S111,641 EFC:$1,200,000 C.I.P. 9-5/8" CSG NU BOP MW: 9.4 VIS: 54 SHORT TRIP TO HWT-TITE @ 1500-POOH F/HOLE OPENER. CHANGE BHA. PU 12-1/4 OH TIH WORK TITE SECTION 1500-1700. DID NOT REAM. CIRC HOLE CLEAN. DROP SINGLE SHOT. POOH-TITE. REAM AND WASH. CIRC HOLE CLEAN. POOH RU & RUN 9-5/8" 36~ J-55 BTC. SET @ 3723. CMT W/1200 SX ASIII & 450 SX CLASS G. C.I.P @ 0330. L/D LANDING JOINT, ND DIVERTER, MU FMC BRADENHEAD, BAKER LOK IN PLACE, NU BOP STACK. DAILY:S236,285 CUM:$347,926 ETD:S111,641 RFC:S1,200,000 DRLG 3755 TO 5823 MW: 9.0 VIS: 32 CONTINUE NU BOP. TEST BOPE, TEST ALL.RAMS, LINES, VALVES, HYDRILL, & KELLY INSTALL WEAR BUSHING. PU BHA, ORIENTATE MWD, FUNCTION TEST MWD, TIH, TAG CMT @ 3580', TEST CSG TO 2000 PSI DRLG CMT, FLT/EQUIP & 10' NEW HOLE TO 3755' DISPLACE W/8.4 PPG MUD, TEST FORM TO 625 @ 2926'TVD W/8.4 MUD, 12.5 EMW BLED TO 425 PSI IN 10 MIN~3TES - DID NOT PUMP INTO FORMATION - TEST OK. DRLG 3755' TO 5823. DAILY:S72,330 CUM:$420,256 ETD:S111,641 RFC:S1,200,000 DRILLING MW: 9.4 VIS: 36 DAILY:S52,309 CUM:$472,565 ETD:S111,641 RFC:S1,200,000 DRLG MW:10.0 VIS: 36 WT UP, POOH TO SHOE, TEST FORMATION, 10.6 EMW OK, RIH, DRLG. DAILY:S61,666 CUM:$534,231 ETD:S534,231 EFC:$1,200,000 DRLG 8.5" HOLE DRLG, POOH, CHANGE BHA, RIH, DRLG. MW:10.0 VIS: 37 DAILY:S56,351 CUM:$590,582 ETD:S590,582 EFC:$1,200,000 The above is correct Drilling, Pages 86 and 87. AR3B-459-1-D [Number all daily well hi~to~ forms consecutively iPage no. ARCO Oil an~ ,~as 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 perlormed. Number aH drill stem tests sequentially. Attach description of all cores Work performed by Producing Section will be reported on "lnlerim" sheets unlit final completion. Report official Or representative test on "Final" form ~) Submit "Interim" sheets when filled out but not less lrequenHy than r;very 30 (Jay:;, o¢ (2) on Wednesday of the week in which oil string is set. Submit weeldy for workovers and following setting of od string untd cornpletion. District Field ARCO ALASKA INC. County or Parish NORTH SLOPE JLease or Unit ADL: 25588 ALK: 2674 JState [RU 2[4-2O Well no. KUPARUK RIVER UNIT Date and depth as of 8:00 a.m. 12/10/89 ( 8 TD: 9808'( 23 SUPV:SC 12/11/89 ( TD: 9808'( SUPV:SC Complete record for each day while drilling or workover in progress DOYON 14 RIH AFTER LOGS MW:10.0 VIS: 36 TD WELL, CIRC, SHORT TRIP, POOH, LOG, RIH. DAILY:S80,676 CUM:$671,258 ETD:S671,258 EFC:$1,200,000 RUN 7" CASING MW:10.0 VIS: 42 RIH, CIRC, POOH, RIH, CIRC., POOH, LDDP, RUN 7" CASING. DAILY:S95,081 CUM:$766,339 ETD:S766,339 EFC:$0 The above is correct Signatur~_~ ~ For form preparatioi~ a~d distribution see Procedures MaCro. aC Section 10, Drilling. Pages 86 and 87 AR3B-459-2-B I N umber all daily well hislory Iorms consoculively as they are prepared for each well. Page no ARCO 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 worl~overs when an olficial test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the antire operation if space is avadabJe. IAccounting cost center code ARCO ALASKA INC. KUPARUK RIVER UNIT NORTH SLOPE Lease or Unit TiteADL: 25588 ALK: 2674 KRU 2K-20 IWell no, Auth. or W.O. no. Operator A.R,Co. W.I ARCO 55. 8533 Spudded or W.O. begun Date SPUD 12/03/89 Date and depth Complete record for each day reported as of 8:00 a.m. DOYON 14 Iotal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well our IPrior status if a W,O. I 00:30 Old TD Released rig 12/12/89 (10) TD: 9808 SUPV:SC PB: 9728 RIG RELEASED 7"@ 9805' MW:10.0 NaCl RUN AND CMT 7" CSG W/ 300 SX CL G, SET SLIPS, INSTALL PACKOFF, MOVE TO 2K-10. RIG RELEASED AT 0230HOURS, 12/12/89 DAILY:S196,529 CUM:$962,868 ETD:S962,868 EFC:$1,200,000 New TD PB Depth Kind o r g Classifications (oil, gas, etc.) Type completion (single. dual, etc.) Producing method Official reservoir name(s) Potential test data 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 Sign~~.~ ~ Date T,~ seeP d ~ .... .... ~ .... ,, Section 1'0'~, For form prepa__n and distribution, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively I Page no. as they are prepared for each we . I Division of AtlantlcRIchfleldCompany Noveraber 9, 1989 Telecopy: (907)276-7542 P. J. Archey Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage,. Alaska 99510-0360 Re: Kuparuk R~iver Unit 2K-20 ARCO Alaska, Inc. Pemit No. 89-118 Sur. Loc. 244'FNL, 94'FEL, Sec. 11, Ti0N, RSE, UM. Btn~ole Loc. 534'FSL, 268'FWL, Sec. 11, T10N, RSE, UM. Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced wall. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to comencing 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 driliad. Where a diverter system is required, please also notiiy 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. Ver~y~. truly yours, Chairman of Alaska Oil and Gas Conservation Commis~ion BY ORDER OF THE CO~R~ISSION dlf Enclosure cc~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmeiltal Conservation w/o enci. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,5,ON PERMIT TO DRILL 20 AAC 25.0O5 ! la. Type of Work Drill X Redrill m I lb. Type of Well Exploratorym Stratigraphic Test _ Development Oil .~X Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone ~". Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 154, P~.d 118' GL, feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25588 ALK 2674 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 244' FNL, 94' FEL, Sec. 11 , T10N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 700' FSL, 450' FWL, Sec. 11, T10N, R8E, UM 2K-20 #U630610 At total depth 9. Approximate spud date Amount 534' FSL, 268' FWL, Sec 11, T10N, R8E, UM 1 1-20-89 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2K-1 9 9806 MD 534' @ TD feet 25' at SURFACE feet 2560 6581 TVD feet 1~. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 700 feet Maximum holeangle 53° Maximum surface 1733 psig At totaldepth (TVD) 6581' 3490 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length IVD TVD IVD TVD linclude stage datat 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 CF 12.25 9.625 36.0# J-55 BTC 3651 35' 35' 3651 2928' 1100 Sx AS III & HF-ERV 450 Sx Class G 8.5 7" 26.0# J-55 BTC 9806' 35' 35' 9806' 6581 250 Sx Class G & HF-ERV Top 500' above Kuj:)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 Length Size Cemented Measured depth True Vertical depth Structural sCu°rr;da~:'° r Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X~ Property plat Drilling fluid program ~ Time vs depth plot ~ Refraction analysis _ Seabed repod _20 AAC 25.050 requirements X~ ~1. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~-,¢'~.-, ~~ Title Area Drillincj Engineer Date /t / c,~/~ c/ Commission Use Only Permit Number I AP, number [ Approval date [ See cover letter for ??-//~' 50-/©~,- ;~,~;,,...'.~d ].'I/09/89 other recluirements Conditions of approval Samples required ~Yes .~ N o Mud log required ~ Yes ~'N o Hydrogen sulfide measures~ Yes ~ N o Directional survey required ~-,~Yes __ N o Required working pressure for BOPE ~2M; .~ 3 M'~ 5M' ~ 10M' ~ 1 5 M Other: ~~, ~~~ /~~ by order of Approved by Commissioner the commission Date Form 10-401 Re '-24-89 mit in triplicate HOR ;ONTAL PROJECT ION SCALE 1 IN. = 1000 FEET ARCO ALASKA. !ne. Pad 2K, Well No~ 20 Propoeed Kuperuk FI eld, North SI ope, Alaeke 1000 1000 2000 3000 4000 5000 WEST-EAST 5000 4000 3000 2000 I I 1000 I SURFACE LOCAT [ ON' 244' FNL, 94' FEL SEC. 11. TI ON. RSE t TARGET CENTER fVD=S3g~) THD=9500 ~ DEP-642! SOUTH 4336 WEST 4?36 RECEIVED TAROET LOCAT[ONt ?00' FSL. 450' FWL SEC. II. TION. RgE S 47 DEO 6421 ' (TO 31 MIN W TARGET) TD LOCATION' 534' FSL. 268' FWL SEC. 11. TION. RgE ,CE 1000 I ARCO ALASKA, Ino, Pad 2K, Well No, 20 Proposed Kuparuk Field, North Slope, Alaska 0 . RKB ELEVAT[ON~ 154' 1000_ 2000 _ 3000_ 4000_ 5000 _ 6000_ 7000 KOP TVD=700 TI'ID=700 DEP=O BUILD 3 DEO g PER 100 FT 15 21 B/ PERHAFROST TVD=1424 THD--144;3 DEP=143 T/ UGNU SNDS TVD=1543 THD=1573 DEP=196 33 39 45 T/ t4 SAK SNDS TVD=2154 TIED=2353 DEP=672 $1 EOC TVD=2237 TIED=2487 DEP=776 B/ W SAK SNDS TVD=2728 TMD=3314 DEP=1442 9 5/8' CSO PT TVD=2928 TIED=3651 DEP=171;3 K-lO TVD=3170 TIID=4058 DEP=2042 K-5 TVD=4552 THD=6387 DEP=3916 AVERAGE ANGLE 53 DEO 36 T/ ZONE C TVD=6314 TI'ID=9356 DE?=6306 T/ ZONE A TVD=6335 TI'ID=9392 DEP=6334 TARGET CNTR TVD=6399 THD=9500 DEP=6421 B/ KUP SNDS TVD=6462 THD=9606 DEP=6507 TD (LOG PT) TVD=6581 TIED=9806 DEP=6668 VERTICAL SECTION I I I I I I I 1 000 2000 ;3000 4000 5000 6000 7000 150 I 100 I 50 0 50 100 150 I I I I 2O0 150 100 50 0 50 100 150 20O I 150 2700 ?00 29OO 1 500 1 9~0 / 1500 700 / -~ 1 300 :300 I 100 O0 300 O0 r"7oo -'<--%~ 300 '""'-,~oo - '11'00 ' x ~ /~7, oo ' 1~5,,oo ~-'~'~ J Xo, j 700 J I IG~O , 1 500 700 I I j' 900 I I 1700 t 1 O0 I I 00650 S08038j SO 0 I I I 50 1 O0 1 50 _ 200 _ 150 100 50 50 100 150 200 DRILLING FLUID PROGRAM (2K-20) 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 10.2 PV 15-30 5-15 1 1 -1 6 YP 20-40 8-1 2 8-1 2 Viscosity 70-80' 35-40 35-50 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 APl Filtrate 10-15 10-20 5 pH 9- 1 0 9.5-10.5 8.5-10.0 % Solids 10 +/- 4-7 <12-15% 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 13.5 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. The nearest well to 2K-20 is 2K-19. As designed, the minimum distance between the two wells would be 25' at the surface. The wells would diverge from that point. 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. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. 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" casing. 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. SHALE SHAKERS DEGASSER ------ MUD CLEANER STIR STIR MUD CLEANER CENTRIFUGI TYPICAL MUD SYSTEM SCHEMATIC KUPARUK RIVER UNIT 20 DIVERTER SCHEMATIC DESCRIPTION 1. 16' CONDUCTOR 2. FMC SLIP~3N 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 WI10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTEI~ VALVES CAN BE REMOTELY CZ::)N3R(~ I ;n TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC2S.035(b) MAINTENANCE & OPERATION 2 I ! 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. 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 · ,,.. JG 4/26/88 13 5/8" 5000 F,.,I BOP STACK 7 6 5 4 ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MIN UTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'FI'OM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" -2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 ARCO Alaska, Inc. Post Office Box ;00360 ^ncllora.qe, ^laska 99510-0360 Telephone 907 27'6 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 ~(~] (Wells I - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for the any questions, please call me at 263-4618. Sincerely, subject wells. If you have D. Martin Engineering Aide DM'hf Enclosure RECEIVED DEC 1 3 ]988 Alaska 0il & Gas Cons. C0mmissJ01] Anchorage GRU13/010 ARCO Alaska, I11C. is a Subsidiary of AtlanlicRichfield¢;~,np,any ca ~ WELLS 1-12 ARE LOCATED IN ~' SECT)ON 2, T. lO N., R. B E., $~ ~i. UMIAT MERIDIAN. WELLS 15-24 ARE LOCATED IN ~ SECTION II,T. ION., R. 8 E., TION ,~ ]' UMIAT MERIDIAN. . EY N.TS. 2:3 ,:, , /, ...... ~RACTED ~tes: , Vici ~ITY UAP I": Imi. ~ te:ts ~SECTION CORNER ~ ~ I. CO0~INATES ARE ASP ZONE 4. SECTION II 18:t9 SECTION ~a ?. ALL DISTANC~ SHOWN ARE TRUE. . ~:z~ 3. ELEVATIONS ARE B.P.M.S.L. ~ ~ g~C 5. HORIZONTAL POSITION BASED ON 2-K CONTROL MONUMENTS PER ~NSBURY ~ A~OClATES. ~ - ~: 6. REFERENCE FIELD BOOK: L88-~,D~.55,56, i ~ 58,59, 65 6 66. z DEC 1 1988 . ~ ~ ,.- A~ m)~*;~n '~ell ,y ASP's ~la¢~a Ull ~. ~L~s ~t,,,~, ~, ........... Dist. DiSt. O.G. ~d ~. ' 'X' m ~;~ ~NGITUDE F.S.L. EEL. Elev. Elev. I i 5,9~8,600.18 i 498J~10.17 7°°14'~6.519" 150600'49.i5~" 296' 94' !14.0 mme.5 ) " ' ~0" 2 5,958,575.14 498,~10.~8 70° 14' ~6.~75 150°00 49.1 Z71' 11~.9 ~ 5,9~8,550.50 498,510.~5 70Ol4'~6.029" 150°00'49.128" 246' ~ 11).8 ' 4 5,9~8,5~5.46 498,~10.06 70o14. 55.784" 150°00'49.1~6'' 22~' I ~ 11~.8 ) ' II I I ~ 5 6~38~00.1~ 4~8,310.1~ lO~l~' ]~.63~ I~O~O0 ~.l~" I~' 113.8 6 B,~38,4T5.1~ 4~8,310.~ lO~l~'35.~" 160~O0'~.l~e" Ill' I I II~.~ I , 4' 35.04~" 150°00' 49.127 I ,46' II 3.8 7 5~938,450.36I 498 ~310.36 70° 14, 8 5,938,425.30 498,310.18 ~ 70Ol4,34.799" ~ 150o00' 49.132'' 121' 1t3.8 I0 5,9~8,375.19 498,~10.14 i 70°~j34.30~'' 150°00'49.153,,$'' 71'~ 113.~ I I 5,938,350.22 ~ 498,310.14 70°1 34.061 " 150°00'49.13 46' i 113.9 12 5,938,325.20 ~ 498,310.17 i 70°14'33.815'' 150°00'49.131" 21' 94' 113.9 118.5 EN.L 13 5,938,235.31 ~ 498,310.37 70° 14' 32.930" 150°00'49.125" 69' 94' 113.7 118.5 I ' = 14 5,938,210.14 498,310. t6 70014'32.683" 150°00'49.131" 94, i 113.7 : ' '9 i ' 15 5,938,185.12 498,310.16 70°14'32.43~'' 150o00 49.131" ; 114, I 113.8 16 5,938, 160.11 [ 498,310.20 70°14' 32. 191" 150°00'49.130" 14 113.8 4' 46" , 17 5,9~8,1~5.21 498,~10.18 70°14, ~1.9 150°00 49.1~0" 169' 115.9 18 5,9~8, I I0.1~ 498,~10.~9 70°1 ~ 1.700" 150°00' 49.197'' 194' 114.0 19 5,9~8,085.~0 ~ 498,~10.g7 70°14' ~1.454'' 150 °00' 49. I~?'' ~1~' 114.0 i 20 5,9~8,060.14 ~ 498,~10.22 70°14'~1.207" : 150°00'49.128'' 244' ~ 1'14.1 ~21 5,9 38,035.1G 498,310.16 70014'30.962" 150°00'49.130" 269' ,r 114.0 22 5,938,010.40 498,310.19 70°14'30.718'' 150° 00'49. 129" 294' 94' ~ 114.0 123 5,937,985.32 498,310.1~ 70°14'30.471" 150°00'49.130" i 319' ~ 95' 114.0 i. ~4 5 ~937~960.29 498,310.08 70 °14' 30.2~5" 150°00'49.132" 344' 95' I 113.9 118.5 OF. I HEREBY CERTIFY THAT I AM ~~..'' PROPERLY REGISTERED AND LICENSED ~." ~ '"~& ~,.. o. ......... ...... BY ME OR UNDER UY DIRECT SUPER- ~. ~. ~.e DRILL SITE 2. K vISION AND THAT ALL DIMENSIONS ~' ~m ~ CONDUCTOR AS-BUILTS :.....: i ax I oo,. "' ~,,~,.~, i r } ~ ~ ,,.~ , .,,' ~, ~ ~ ~ ..~ ~ , , ' ' "' ' . Ala¢[a Ull m. t,.:~s w.,,,.'_,. ,,,,, ........... Dist DiSt. O.G. Pod .I 'Y ' ' X ' I_,aA'~t;l~dl[~ LONGITUDE F.S.L. EEL. Elev. Elev. ASP's I 5,938,600.18 4981510.17 70° 14'36.519'' 150° 00'49.155" 296' 94' !14.0 118.5 2 5,93,8,575.14 498,310.28 70o14' 36.273" 150°00'49.13,0" 271' 11:5.9 , 3, 5,93,8,550.50 498,;510.3,5 70° 14' 36.029" 150°00'49.128" 246' 113.8 4 5,93,8,525.46 498,310.06 70°14' 35.784" 150°00'49. I 3,6'' 22?-' I 115.8 5 5,93,8,500.19 49 8,3,10.12 70°14' .55.536" 150°00'49.13,4" 196' 113,.8 6 5,938,475.14 498,:510.33 70°14' 35.289" 150°00'49.128'' 171' I I 1.5.8 j 4' ~55.04~" 1,~0 °00' 49.127 ,46' 113,.8 7 5,93,8,450.36J 498'3,10"36 70° 14, 8 5,93,8,425.:30 498,$10.18 70° 14, 3,4.799" 150o00'49.13,2" 121' 1t3.8 I0 5,938,$75.19 498,510.14 70°144j34.306" 150°00'49.133.~ 71'I 113.9 I I 5,938,350.22 ! 498,.310.14 70°1 3,4.061 " 150°00'49.13 46' 113,.9 12 5,93,8,325.20 i 498,3,10.17 70°14'3,3.815'' 150 °00' 49.151'' 21' 94' 113,.9 118.5 EN.L I$ 5,938,23,5.3,1 i 498,3,10.$7 70° 14' 32.93,0" 150000'49.125" 69' 94' 113.7 118.5 14 5,938,210.14 498,310. t6 70°!4' 32.683'' 150° 00' 49.151'' 94, 11.3.7 15 5,93,8,185.12 498,$10.16 70Ol4' 32.437'' 150o 00' 49. 13,1" 114,9 11;5.8 16 5,9.58, 160.11 [ 498,3,10.20 70°14' 32. 191" 150°00'49.13,0" 14 113,.8 4' 46" , 17 5,93,8, 135.21 498,3,10.18 70°14, 3,1.9 150°00 49.130" 169' 113.9 18 5,93,8, 110.19 498,310.29 70°1 3,1.700" 150°00'49.127'. 194' 114.0 19 5,93,8,085.20 ! 498,310.27 70°14'$1.454" 150 °00' 49. 127'' 219' 114.0 20 5,938,060.14 i 498,310.22 70°14'31.207" 150 ° 00'49.128" 244' 1'14. I 21 5,9 38,035.16 498,310.16 70014'3,0.962" 150°00'49.130" 269' ,r 114.0 22 5,938,010.40 498,.510.19 70°14'$0,718'' 150° 00'49. 129" 294' 94' 114.0 23, 5,937,985.32 498,310.1:3 70 °14' 30.471'' 150° 00'49. I$0" $19' 95' 114.0 24 5~937,960.29 498,$10.08 70°14'30.225" 150°00'49.132'' 344' 95' I 113.9 118.5 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) Loc (~/Pt~ru 8) ~//~/~/~? (8) (9 ~h~ru 1'3) ' (i0 and 13) (14 t:hru 22) (23 thru 28) Company 1. Is the permit fee attached .............. ............................ e 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. Is well to be located in a defined pool ............................. Is we~] located proper distance from property line .................. Is we-~l_located proper distance from other wells .................... Is suffiCient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number .................. ' ...... Lease & Well No. YES NO Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to 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 wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... .~ Is the drilling fluid program schematic and list of equipment adequate z~.. Are necessary diagrams and descriptions of diverter and BOPE attached.~9,~ ~oes BOPE have sufficient pressure rating - Test to ~~ psig .. ~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. .... (6) OTHER thr~ ~1) ' (6) Add: ~~'/ Geology.: Engineering: pw~ ~LCS ~.w rev: 01/30/89 6.011 For 29. 30. 31. 32. 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 ............................................. ~ Additional Remarks: INITIAL GEO. UNIT 'ON/OFF POOL CLASS STATUS AREA NO. SHORE 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. CO,PA,NY ~A~E { ARCO ALASKAt FIELD ~A~: : K~PARUA BOROUGH : NORTH SLOPE STATE ~ ALASKA API NUMBER ~ 50'103'20120'00 REFERENCE NO { 73588 MICROFILMED IB ~'ape Verification blEtlnq =hlumDetges AlasKa ¢omputln~ Center lg-D~¢-1989 **** REEL HEADER $~iRVICE NAME : EDIT DATF : 89/12/19 ORIGIN : FLIC REEl, NA~E I 73588 CONTINUATION S ~ PREVIOU6 REEL COMMENT I ARCO ALASKA, INC,,KUPARb~,2K **** TAPE HEADER **** SlaV!CE NAME ~ EDIT DATE ~ 89/12/19 TAPE NAME I 73588 CONTINUATION # ~ 1 PREVIOUB TAPE : COMMENT : ARCO ALASKA, INC,,KUPARUK.~K - 20,50-103-20120-00 **** FILE HEADER **** F~LE NA~E ~ EDIT ,001 S~RVICE I FLIC ION I 00lA04 D.TE ~ 89/!2/19 FILE TYPE ~ ~0 ~AST Flb~ ~ PAGE: COMPANY NAME: ARCO ALASKA, INC, IE,~DI KUPARUK BOROUGH~ NORTH SLOPE STATEI ALASKA API HUMBERt LOCATION~ 244' FNL & 94' FEL SECTION~ 11 TOWNSHIP~ 10N PERMANENT DATUMI MSL ELEVATION', 0 LOG MEASURED FROM RK~ 154 ABOVE PERNANENT DATO~ IS Tape Verification Listing :hlumberger Alaska ComPuting Center 19-DEC-~.959 10108 PAGE: ELEVATIONS DATE LOGGED: RUN NUMBERS TD LOGGER: CASING KB: 154 153 1t3 09-DEC-1989 ONE 9809 9806 9 5/8" 36 bB ~ DRILLER DEPTH OF -- TO 3723 BIT SIZE 1{ 8 1/2" @ 9809 TYPE FLUID IN MOLE: WEIGHTED POLYMER DENSITY: 10 VISCOSITY: 36 P}~ 9.5 FLUID LOSS: 3.8 MUD ~ES!STIVlTY: 3,79 ~ 80 FILTRATE RESISTIVITY: ~.9t ~ 78 MUD CAKE RESISTIVITY: ~.86 ~ 75 TX~E CIRCULATION ENDED: %6:45 12/9 TI~E LOGGER ON BOTTOm: 23:45 12/9 ~AXIHU~ TE~P RECORDED~ 147 LOGGING DISTRICT: PRUDHOE BAY INKHAM LOGGING ENGINEER: ~'EAL/CAMER~ TOOl., NUMBERS: .DIS 2140 DIC 2191 PGS 508' CNC !238 SGC 3533 IE~ 1348 NLM 1329 FOUR I" TEFLON STANDOFF~ RUN ON TOOL ST~ING, 2 FOOT HOLE FINDER USED AS BOTTOM NOSE- . ~ATRIX DENSITY =~2.65 G/C3 . [~[tID DENSITY- 1.00 G/C3 NL MATRIX = SAND , HOLE CORR.ECTX. O~ = CALIPER D~TE JOB STAR'TED: 15,,DEC"'89 JOB REFERENCE, NO:73588 LDP/ANA: R,~ SI~E8 ******************************************************************************** FILE" ED'IT,O01 I8 TaDe Verification Listing chlumberqer AlasKa Computing Center 19-D£C-lg89 10:08 ARCO ALASKA, INC, KUPARUK 2K - 20 50-103-20120-00 MAIN PASS LOG DATA DATA SANPbED EVERY ",5000 FEET DATA INCLUDED TOOL EXTENSION 300L TYPE USED NANE DIT-D ,nIL DUAL INDUC~ION FDC ,FDC FORMATION DENSITY ,CSG GAM~A RAY PAGE: TABLE TYPE I CONS TUNI. VALU FN RANG COUN :STAT NATI .bO NC W!.TN PDAT EPD L~F APD EDF TDD TtAB FT FT FT FT FT FT FT DEF! ARCO ALASKA, iNC, 2K- 20 50'I03'20120 244' FNL & 94,0 ~0 10~ NORTH SbOPE ALASgA USA' Ab/CAMfRON ~9:13B 0 ' 154 54' 5~' t7gB' .6:4~ 12/9 23:45 12/9 Company Name Field Name Well Name API Serial Number Field Location Section Township Range County State or Provlnce Nat~on ~at rude bongItud, e W!t~ess' Name erv'lce~Order Number ermanent,.datum bog Measured From Bottom boo Interval Time ctrcOlatlon StoPped Time Logger At Verification Listing =hlumberger Alaska Computing Center !0{08 TUNI VALU DEFI STE~ DEGF 70, TABLE TYPE : CURV DEFI DFPT Dept~ C~annel Name ILD Deep Induction Standard Processed Resistivity IL~ Medium ]nduction Standard Processed Resistivity SFLU SFL Resistivity (unaveraged) SP' Spontaneous Potential GR Gamma Ray TENS Tension DPHI Density Porosity RHOB BUlk Density D~BO Delta RHO FFDf Far FDC Count Rate NFDC Near FDC Count Rate CAL! Caliper GR Gamma. Ray T£N$ Tension NPH! Neutron Porosity_ TNPN Thermal Neutron ~orosit¥ T~RA Cal~brate~ ~herma! Neutro~ Ratio NPOR Neutron Porosity Qutput from an Application Program RCN~ RCNT ~CFT RCFT CNTC CNTC CFTC CFTC GR Gamma Ray CALI Caliper TENS Tension G~ Gamma Ray TENS Tension DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ~ TYPE REPR CODE VALUe] .~ 66 0 . 66 0 73 t.12 5 66 Tape verification Llst. ino chlummerger Alaska Computl. C~ Center 19-DEC-IQSg 10)08 PAGEI e~m~m~e~mlme~mm(~mmmem#mm~me~mmlmmm~mm#mem ? 65 9 65 68 13 66 0 14 65 !5 66 68 16 66 0 66 0 ** $~ TYPE - CHAN ** NAME: SERV UNIT SERVICE APl AP1 AP1 API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 549138 ILD DIL OHM, 549138 IL~ DIL 0.,, 549138 SFLU D!b OH.~ 549138 SP DIb MV 549138 GR DIL GAP! 5491 8 TENS DIL L~ 54913 38 DPH! ,DC PU 549138 RHOB FDC G/C] 549138 'DPHO FDC G/C3 ~49138 FFDC FDC CPS 549138 .FDC FDC CPS 549138 C~LI FDC IN 549138 GR FDC GAP! 549138 ~s ~DC L~ 5491_38 NPH! CN~ PU 5491~8 TNpH CNL PU 549i~8 TNRA CNL 549 38 NPOR CNL PO 549 38 RCNT CNL CPS 549 38 RCFT CNL CPS 549 38 CNTC CNL CPs 549 38 C~'TCF C~L CPS 549 38 GP CNL GAP! 5.49~38 ca~I c~ ZN' 549138 GR CSG GAP, 549138 oo ooo ooo ~ , , , ~. oooooooooo o~ ~o 40 o ~ ~ ~ 4 ~ oooooooooo o~ ~o ~4 o ~ ~ ~ ~ o~ oooooooooo o~ ~o o~ o , , ~ ~ ~. oooooooooo o, o~o o~o ~ ~ ~ ~ ~, oooooooooo o~ ~o o, o ~ , ~ 4 ~, oooooooooo o~ ~ ~ o ~ ~ ~ 4 ~ oooooooooo o~ ~ ~ o ~ ~ ~ ~ ~ oooooooooo O? 350 020 1 1 1 4 6~ 0000000000 07 356 010 ~ 1 1 4 65 0000000000 07~4 o~ o, ~ ~ .4o~oooooooooo o,o, o, , , , oooooooooo o,,,o o, o, , , oooooooooooo o? 6 · ' 00000000 2I 0 I I 1 4 68 O0 8 0 O0 0 1 1 .4 68 0000000000 o~ ~o oo o :~ , , ~ oooooooooo O1 ~ ol o I } 1 4 68 0000000000 o~ .9~ oo o ~ :, ~ ~ ~ oooooooooo o~ 4~o o~ o ~ ~ <~ 4 o~ oooooooooo O? 420 Oi 0 I 1 ! 4 68 0000000000 07 420 Ol 0 I I I 4 68 000'0000000 O? 420 01 0 ! ! 1 4 68 0000000000 07 310 O1 O 1 1 1 4 68 O0000000OO 07 280 O! 0 I 1. 1 4 68 0000000000 07 635 21 0 I ! I 4 68 0000000000 07 3!0 Oii 0 I I 1 4 68 0000000000 Z:ENS CSG LB 549138 07 635 21 0 ! 1 ! .4 65 0000000000 rape Verification Listing :hlumberger Alaska ComPutiDg Center SP R~OB FDC C~bI FDC T.PH D~PT, SP,DIb RHO~,FDC CA~,FDC RCFT'CNL SP,DIL RHOB,FDC CALi,FDC TNPH,CNL RCFT,CNL CALI,CNL DEPT TNPH~CNL RCFT,CNL CALI'CNL ~HOB,FDC C~LI*FDC ~CFT,.CNL CAL~;CN~ DEPT L!;:FDC TNPH*iCNb RCF~ CALl DEPT ~P ~HOBFDC .CAbI:EDC RCF~ CN~ CALl CN~b 9821 500 -27~891 1,859 6,824 36,521 571,710 6,~24 9800,000 -27,125 1,859 6 824 36 521 571 710 6 824 9700,000 '29,094 39,623 49~,503 ,047 9600 000 -31 266 445 ~ 74 40 0~1 520 ~35 8 34 ;484 38.922 68! ;802 ~,626 .'g22 9400.000 :'35'125 407 898 '898 9300,000 -40;063 2,478 9,984 5;653 9'984 DRHO.FDC GR.FDC TNRA.CN5 CNTC.CNL TENS.CNL ILO OIL GR:DIL DRHO,FDC GR,FDC TNRA.CNL CNTC.CNL TENS.CNL ILD DRHO FDC GR FDC TNRR CNL CNTC CNL TENS CNL ILD.DIL GR,DIL DRHO,FDC GR,FDC TNRA'C~.b CNTC*C~L TENS,C~b ILD'DIL DRHO,FDC 6R'fDC TN~A~CNL CN~C,CNL TEN$,CN~ ILD,DIb 'GR,DiL DRBO'FDC CN~C,CNb ~ENS*CNb ILD,D!L D~HO,FDC 6R~FDC TNRA,CNG C~TC~CN~ 'TENS,CNb 19-DEC-!gB~ 10:08 3 165 tL~.DIL 124i563 TENS'OIL 0 102 FFDC.FDC 124 563 TENS.FDC 3.162 MPCR.CNL 2034.915 CFTC,CNL 1930,000 GR,CSG ,1 70 IbC,DIG 12 ,563 TENS DIL 0.102 FFDC:FDC 124,563 TENS,FDC 3 162 NPOR,CNL 2034i915 CFTC,CN~ 6304 000 GR.CSG 3,043 IbM,Din 114,125 0 048 FFDC,FDC 114:125 3 335 NPOR,CNb 2004:94! CFTC"CNL 6150,000 GP.CSG 3,781 ILM, 100.750 TENS 0'077 FFDC 101,750 IENS ,31~ NPOR 1950,21 C.F~C 6168,000 GR 5.179 97,7~0 750 TENS i57 CFTC 6~04,000 OR ;750 TENS' 0;017 FFDC, 77'750 TENSe · 580 NPOR, ,829 CFIC, 3, 6.4 IbM 00'~ 5 FFDC 1.1, 88 TENS 3' 51 NPO~ 1999,~09 C:FI~C 6248'000 Ga OIL OIL FDC FDC CNG OIL DIL FDC FDC CNb CSG DIL FDC FDC tnb CNG DIG DIL FDC FDC CSG 3 388 1930 000 2522 000 1930 000 36 521 654,704 -999.250 3.387 6304.000 2522.000 6304,000 36'521 654,704 -999'250 3,061 6180,000 528,000 i180,000 40,412 602.,~59 999, 50 ooo 6168 000 5~1 035 .4,972 6104;000 '573,000 6104,000 7 ,833 .9 9.~50 531 500 58.44 0 lo I 445 -9~9 250 3'921 6248,:000 515,000 6248,000 37.,085 .626,974 999.~50 SFLU.DIL DPHI.FDC NFDC.FDC NPHI,CNL RCNT,CNL GR.CNL TENS.CSG SFLU.DIL DPHI,FDC NFDC.FDC NPHI.CNL RCNT,CNL GR,~NL TENS, SG SFLU,DIL DPHX,FDC NFDC,FDC NPH!:.CNL TENS',CSG S~LU DPH! FDC ,:FDC NFDC ~PH~ NL RCN~ ~NL TENS ~NLsG DPHI,FDC NFD¢'FDC RCNT~CNL NFDC;FDC RCNT.'CN~ GB.'CNL SFLU,D~L ~PH~,FDC NFDC,FD¢ NPHI,CNL RCN~,CNL GR,CNL TEN'S,CSG PAGE: :868 4 962 1063,000 39,159 1977'397 124'563 -999,250 3,871 47,962 1063,000 391159 '63 9 50 0 9'363 1915,1!5 999,2 i 1~ ® .,446 664~000 39,.424 1854;519 · 00,750 -~99'250 ~,52 7!4,500 . ,7 50 '999'250 2525,1..~ .:77'750 3.762 10,453' 638.257 iS ?ape Verification bisttno :hlumberger Alaska Computina Center DEPT SP OIL PHOB FDC CALI FDC TNpH CNL RCFT CNL C~L! CNL SP,DIL RHOB,FDC CA~I,FDC TNPH, DZPT SP PI5 RMOB FDC C~bI FDC TNP~ ~CFT CNL C~LI CNL DEPT,D RHOB.,FDC CALI;FDC TNPH,CNb CALI'CNL SP,DIL R~OB,FDC 'TNP~,CN5 DFP?, CALI'FDC TNP~,CNL RCFT~CNL CALI,CNL ~OB FDC ClL! FDC 9200 000 -35 063 2 348 9 891 43 418 404 759 9 891 9100,000 '34 000 ~ 464 43 966 424 9000,000 '37,313 1:4 o 273 _39,779 438,870 8900 .00~ '31 18 2 260 8 898 40 810 457 411 8: 898 8800 000 -9~9 844 25O -999 250 -999 -999 250 87~0,000 ~'094 -~9 ,250 '-999,250 -999,250 -999'250 -999;250 8600 000 · -33 188 -999 250 -999 250 -999 250 -999 250 ILD,DIL GR.DIL DRHO.FDC GR;FDC TNRA.CNL C~TC,CNL TEN$,CNL ILD,DIL GR,DIL DRHO.FDC GR,FDC TNRA,CNL CNTC,CNL TEN$,CNL I~D.DI~ GR,DIL DRHO,FDC GR'FDC TNRA,CNL CNTC;CNL TENS'CNL ILD,DIL GR;Di5 DRHO'FDC GR~FDC TNRA'CNL CN?C;C TENS,CN~ IbD.DIL GR~DIL DRHO~FDC GR~;FDC. TNRA!~CNL C C,CN TEN$,C~L ILD'DI5 ~ GR;DIb DRHO,FD¢ GR,~DC ?NRA~NL CNTC~CNL TENS,CNL GR,D,IL DRHO,FD¢ GR.,FDC TNRA;CNL 19-DEC-1989 10{08 1'3~ 990 0 ~25 15 131 125 3 559 1678 157 6188 000 110, 5 0 2 3 773 1784 4~5 6228 0~0 3 463 140 625 0 043 ~40 625 560 1761 709 6028 000 0 !63 287 500 !75~ 428 942 5960 000 4,155 625 25~'259 '99 '250 '99'99~'2~0 '99 ,20 -999,250 4, 8 -999' 50 -999,~0 -999, 0 "999;~0 '999,2 0 3 '999 50 '999 ~50 '999 0 -999 ~0 IL~,DIL T~N$.DIL FFDC,FDC TEN$,FDC NPOR.CNL CF~'C,CNL GR.CSG ILM.DIL TEN$'DIL FFDC.FDC TENS.FDC NPOR.CNL CF~C.CNL GR,CSG TENS,DIL FFDC,FDC TEN$,FDC NPOR,CNL CFTC~CNb GR,CSG ILM,D!L TENS,DXL TEN$'FDC NPOR,CNb CF?C-,CN ~ENS,DIb FFDC*FD fEN$,FD~ NP~.CN5 FFDC,FDC TENS,FDC NPOR,CNL CFTC,CNL ~ENS,DiL FFDC,FDC TEN$'FDC NPO'R,CNL CFTC,CNL 2 O38 6188 000 611 500 6188 000 42 176 466 092 -999 250 SFLU ~IL up. : Dc NFDC,FDC NPH~,CNL RC~,CNL GR,CNL TENS,C~G 2 399 SFbD,DIL 6228 000 DPHI,FDC 455 750 NFDC,FDC 6228 000 ~PHI,CNL 43 363 RCN~.CNL 070 -999 250 TENS 3,489 oo §°° ,000 ' 9 .50 1090, -999,250 ~88~:370 000 999' § -999,] 0 -999.; ~0 -999'250 4, .~ '999,~50 '999' 50 "999,.250 SFLU DIL DPH! FDC NFDC FDC RCN TENS, DPHI NFDC.FDC NPHI~CNL RCNT,CNL TENS,CSG SFLU..DIL DPHI'FDC NFDC-FDC NPMI*CNL RC.NT.CNL OR,CNL TENS,C$:G SFLU.DIL DPHI'FD¢ NFDC'FD¢ NPHI'CN~ RCNT.CNL GR,CNL TEN$,CSG 3'924 SFDU,DIL ~85~,000 D~HI,'~DC ;999,250 .~DC,FDC :999,259 ~PBiI.:CNL ~999,250 RCN~'CNL 999'250 GR'CNL ~AGE: 2.196 tB.309 624 000 42 214 2.237 11,256 °°. , 0 : 39,783 701.' 794 40, 60 -999,250 6.,~20 999,250 -999;250 '999'250 Z999'250 ,g99,250 999~250 4~904 i~999;250 :2999'250 '.999~250 .999,250 999,250 '999,250 5,355 '999~;250 '999,'250 '999~250 -999'250 1-999~250 IS Tape Verification bisting :blumberger Alaska Compqting Center CALI.CNL DE:PT, SP,DIL RHOB,FDC CALI,FDC T P".CNU RCFT'CNL PEPT SP RBOB FDC CAL! FDC RCFT CNL CALl CNL DEP~, ~0~ DC C~L! DC DEPT, R~OB,FDC C~bI,FDC RCFT,CNb C L!,C L TNP CNb ~EPT ~SP R..~OB FDC Ab! FDC RCFT CNL CALl CNL RHOB,FDC TNP~,C~L -999.250 8500.000 '38 844 '999:250 '999.250 '999'250 '999,250 '999,250 400,000 -37.031 999.250 'Egg 250 '999:250 '999.250 '999,250 8300 000 '32 125 '999 ~50 '999 250 '999 250 '999 250 '999 250 8200,000 ; ,ooo - ,250 -999,250 -999.250 -9 .9~'250 · ,250 8 00,000 -999.50 -999'~56 '999.'250 -999;250 :~000,000 ~26,313 99,250 -999,250 -999,250 -999'250 ~-999;250 . 999,250 ' 999,25 0 -999,250 TEN$,CNb ILO.OIL D GR,DIL RHO,FDC GR,FDC TNRA,CNb CNTC,CNL TEN$,C~L ILO,OIL GR,DIL DRMO,FDC GR,FDC TNRA,CNL CNTC,CNL TENS,CNb ILO'OIL GR,DIL DRHO,FDC GR,FDC TNRA'CNL CNTC,CNL TEN$,CNL ILO OIL OR DRHO FDC GR FDC TN~A CNL CNTC CNb TENS CNb ILO.OIL GR,DIL DRHO,FDC GR'FDC TNRA,CNL CNTC;CNb TEN$,CNL ILD..D!L GR.DIL G.R;FDC TNRA,CN~ C TCgC L TENS,C~G I~D*DIb ~R,DI~ DRBO~FDC GR'F.DC TNRA'CNG 1 9,,DEC-1989 10:08 '999.250 GR,CSG 4 595 115 375 -999 250 -999 250 -999 250 -999 250 -999 250 3 771 105 063 -999 250 -999 250 -999 250 -999 250 -999 250 !24' -999'250 -999'~50 -999' 50 -999.~0 -999, 0 _4,351 bO,O00 :999,250 ~999,250 ;999.;250 -999'250 ..999,250 ~999'25~ 999;250 -999,250 -999'250 1' 62 !21;~25 -999.~50 -999' 50 '999, 0 -999. ~0 2,527 i 24; 500 ' 999,250 -999;250 ,'999.250 ILM,DIL TENS,OIL FFDC FDC TENS:FDC NPOR,CNL CFTC,CNL GR,CSG ILM,DIL TENS,OIL FFDC,FDC TEN$,FDC NPOR,CNL CFTC,CNL GR'CSG ILM.DIL TENS OIL FFDC:FDC TENS.FDC NPOR,CNb CFTC,CNL GR,CSG TEN$,DIL TE!$,FDC NPOR,CNL GR;CSG ILM,DIL TEN$'DI5 FFDC,FDC TEN$,FDC NPOR,CNL CF~C,CNL G~,CSG ILM,D!~ TENS;OIL FFDC,FDC TENS;FDC ~POR:,CNL CFTC,CNb CR;CSG FFDC DC ~ESFDC NPOR CNb -999.250 TENS.CSG 4 452 SFLU.DIL 5768 000 D?HI.FDC -999 250 NFDC.FDC -999 250 NPH~,CNL -999 250 RCNT.CNL -999 250 -999 ~50 3 711 SFbU.DIL 5784 000 DPHI..FDC -999 250 NFDC.FDC -999 250 NPHI CNL 3,302 SFLU.DIL 5612.000 DPHI,FDC -999.250 NFD¢.FD¢ -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 ,GR*CNL -999,250 TEN$.CSG 000 DPHI..FDC .999,. 50 NPHI,,CN~ .999,~50 NFDC'FDC -999,250 RCNT'CNL -999,250 GR.CNL -999,250 TEN$',CSG 3,196 BFLU.DIL 5460;000 DPHI*FD¢ -999,250 NFDC,,FDC -999:~0 NPHI.~CN5 .-~99 0 RCNT'CNb - 99,~50 ,GR'CN~ -999'~50 TENS'CSG !,~65 55.40,000 '999,i250 '999,250 '99~.250 -999~250 -999,250 SF'bU,D!L DPHI;FDC NFDC'FDC NPHI'CN5 RCNT.CNL GR,CNL TENS'CSG' 5392 -999 ..999 -999 DPHI;::FD¢ 2~8 NFDC,FDC N :P H !, C N L 2:50 I~CNT,CN~ PAGE~ -999,250 5,556 '999.250 '999.250 '999,250 '999,250 '999,250 -999,250 '999.250 -999.250 -999,250 -999i.~50 -999'250 4.264 '999,,250 '999,250 '99~.250 '99'.250 '999,2150 '999.250 4,73! 999,250 999,250 999,250 999;250 -999,250 '999;'250 3,4i3 :999.;250 999.;250 --999~250 :'999'250 '999.~:250 '999,250 1:,967 '999'250 '999,250 ::999.,250 ~999'250 :.999~250 999,250 · -9 3'524 '999'250 '999'250 Tape Verification Listing chlumberqer AlasKa Co~putinq Center RCF~,CNL CALI,CNL D~PT SP ~PO~ FD¢ CILI FDC TNPH CNL RCF~ CNL CALI,CNL SF DIL RHO~ FDC ¢~L FD¢ TNPH CNL pCFT CNL CAbI CN6 DEPT, _$P~DIL RHOB,FDC ClLI,FDC TNPP,CNL RCFT,CN[. CALI'C D~PT sp RHO~ FDC CALl FDC CAt,! C~L SP~DI:L .oe,foc CAL!,fDC TNPH~CNL RCF 'CNL DEPT, ~HOB,FDC CALI'FDC TNPH,CNL RCFT,CNL CAbi,C.NL DEPT' HSP'DI~ R OB,FDC CAbI,FDC '999,250 '999,250 7800,000 '47,781 '999,250 '999,250 '999,250 '999,250 '999,250 7700 000 -42 188 -99~ 250 -99 250 -999 250 -999 250 -999,250 7600 000 -51 813 -999 250 -999 250 -999 250 °999 250 -999 250 7~00,000 -42,000 ~999,250 999,250 -999,250 -999;250 -999,250 7400 000 -50 563 -999 ~50 -999 250 -999 250 -999 250 -999 250 7300,000 -53,313 -999,250 -999,250 -999'250 "999,250 '999'250 72.00,000 50;875 5O '999'~50 '999, CNT~:CNL TEN CNL ILO GR:DIL DRHO FDC G~' ,FDC TNRA,CN5 CNTC,CNL TENS,CNL ILD,DIL GR,DI~ DRMO,FDC GR,FDC TC,CNL TENS,CNb ILD,DIL GR,DIL DRHO,FDC GR,FDC TNRA,CNL CNTC,CNL TENS,CNL ,, ILD GR DRHO FDC GR FDC CNTC CNL TENS CNL ILD,DIL GR,DIL DRHO'FDC GR'FDC TN~A'CNL CNTC'CNL TENS,C~L LD,D!L GR~DIL DRHO,,FDC G ,F C TNRA~CNb CNTC,CNL TEN$~CNL ILD,DIL GR,DIL DRt!O,FDC 19'DEC-1989 10:08 ~999,250 CFTC,CNL 999,250 GR,CSG ] 7~9 111 185 '999 250 '999 250 "999 250 '999 250 '999 250 3 lb7 86 500 -999 250 -999 250 -999 250 -999 250 -999 250 9~ 497 -999 ~iO - 9 20 '99 ~50 '999 50 3,594 93'750 :999'250 .999,250 "999'250 "999'250 '999,250 4 379 119 750 'gg9 250 '999 250 '999 2~0 "999 2~0 -999 20 '99~ 0 "99 250 ~999 "99~ 20 ~99 250 '999,~50 ILM,DIL TENS,DIL FFDC,FDC NPOR,CNL CFIC,CNL GR,CSG TENS,DIL FFDC,FDC TENS,FDC NFOR,CNL CFTC,CNL GR,CSG ILM D!L TENS DIL FFDC FDC TENS FDC ~POR C~L CFTC CNL GR CSG TEN$,DIL FFDC,FDC TEN$,FDC NPOR,CNL CFTC;CNL 'ILM,OIL FFDC,FDC TENS'FDC NPOR'CNL c mc,;c G~,CSG iLM,D1L T~N$,DIL FFDC'FDC TENS'FDC NPOR,CNL CFTC'CNL G~,CSG IL~,DIL TEN&'DIL FFDC,FDC TENS,FDC -999,250 TENS SG 3 796 SFLU,DIL 5300 000 DPHI,FDC -999 250 NFDC,FDC -999 250 NPHI,CNL -999 250 RCNT,CNL -999 250 T GR,CNL -999 250 ENS,CSG 3,233 SFEU.DIL 5044,000 DPHI,FDC -999,250 NFDC,FDC -999'250 NPHI,CNL -999,250 RCNT,CNL :999,250 GR'CNL 999'250 TENS,CSG 3 558 SFbU, 5040 000 DPH~,~ILDC -999 250 -999 250 NPHI.,[DC -999 250 RCNT,CNL -999 250 _ -999 250 3 619 SFLU,D'!L 5060 000 DPHi,FDC -999 250 NFDC;FDC .999 250 NPRI;CN~ -999 250 RCNT'CN[ -999 250 GR'CNL -999 250 TEN$,.CSG 47!,2:I O0 DPH]; DC -99 50 NFDC~':FDC -999i.!50 ~CNT'CNL -99950 GReC~L 3 898 'SFLU'.DIL 4620 000 D~HI.FDC 1999 !50 NfDC;'FDC , 999 50 NPHI~CNL .999 i 50 RCNT.;CNL -999 250 GR!;CNL '999 250 TENS'CSG 4 sr u':vz .999,250 NFDC'FDC -999.250 NPHt,CNL FAGEI '999,250 '999,250 4,904 '999.250 '999,250 '999,250 '999,250 -999.250 -999.250 3 229 -999 250 -999 250 -999 250 -999 250 -999 250 -999,250 3.475 -999!~50 -999 ~0 -999 0 -999,250 25O -99!!250 -99 2'50 -99 250 -99 ,250 '99 ~:250 · 4,t47 '999'250 '999.,250 '999'250 '999,250 "999'250 '999,250 ~,095 '999,250 '999,250 :999,250 .-999'250 -999~250 '999'250 3,992 999'250 :999,250 999,250 Tape Verification Listing :h. lOmt-erger Alaska Computing Center CAL1,CNL -ggg,250 TENS,C~L DEPT SPDIL RHOR FDC CALl FDC TNPH CNL RCFT CNL ChL! CNL DEpT RMOB FDC CALl FDC RCFI CNL SP D!L RHOB FDC CAb! FDC TNPH CNL RCFT CNb CAb! D~PT RHOB,FDC CA~'FDC TN&'CNb RCFT'CNb CAbX.CNL DEPT C~L!.FDC TN~H CNb SP,,DIb RHOB,FDC T~PH'CNb RCFT'CML C~L!.CN~ 7100 000 -]8 188 -999 250 -999 250 -999 250 -999,~50 -999,250 7000,000 '32.813 -999,250 -999,250 -999,250 -999,250 -999,250 6900,000 -37,031 '999,250 '999,250 "999.~0 -999, 0 "999,250 ooo -999 250 -999 250 -999 ~50 67:00,000 -34,2~0 -999'2 0 -999,250 -999,250 -999;250 -999'250 6600 000 -999'250 -999'250 -999'250 -999'250 ~-999,250 ILO.OIL GR.DIL ORHO.FDC GR.FDC TNRA.CNL CNTC.CNL TENS,CNL GR.DIL DRHO,FDC GR.FDC TNRA,CNL CNTC,CNL TENS,CNL ILD OIL GR OIL DRHO FDC OR FDC TNRA CNL CNTC CNb TENS CNL ILD,DIL GR,DIb .DRMO'FDC GR,FDC TNRA,CNL C~TC;CN~ IbD,DI5 O~O,~"OC TNRA,CNL CNTC;CNL TEN$;CNb ILO,OIL GR;DI.L DRHO'FDC GR,FDC CNTC;C~ TENS,CN~ 19-DEC-1989 !0:08 '999,250 NPOR,CNL -999,250 CFTC,CNL -999'250 GR,CSG 3,~55 ILM,OIL 132, 25 TENS'DIL -999,250 FFDC,FDC -999,250 TE~$,FDC '999'250 NPOR,CNb -999,250 CF~C,CNL '999,250 ' GR,CSG 2 480 166 250 -999 250 -99~ 250 -99 2bO 99 5 25O 18 '999 250 "999 250 "999 ~50 '999 50 "999 250 2 045 114 813 -g99 2~0 -999 20 -999 250 -999 250 "999 250 2,507 130;500 -9~9'.2~0 -999'250 -999,250 '999;250 -999,250 ,903 ;250 -999'250 -999'2~0 ,2~0 .,250 IbM,OIL TENS,OIL FFDC,FDC TENS'FDC NPOR'CNL CF~C,CNL GR.CSG TENS FFDC FDC TENS FDC NPOR CNb CFTC CML GR CSG ,iL~,.D1L TENS,OIL FFDC;FDC ~EN$,FDC NPOR'CNb CFTC,CNL · GR,CSG IL~,DIb TENS,OIL FFDC,FDC TEN$,FDC NPOR,CN5 CFTC'CNL 'GR,,CSG ~ENSDIb FFDC FDC TENS FDC NPOR CNL CFTC CNL G~ CSO · .999,250 RCNT,CNL -999,250 TENS SG 3 091 SFbU,DIL 4728 000 DPHI,FDC -999 250 NFDC,FDC :999 250 NPHI,CNL 999 250 RCNT'CNL -999 250 GR,~NL -999 250 TEN$,CSG 48 SFLU,DIL 000 DPHt,FDC 250 NFDC,FPC -999,250 NPMI,CNL -999,250 RCN 'CNL -999, 50 G~,CNL -999,~50 TEN 3 698 4580 000 DPHI,FDC .999 250 NFDC,FDC .99~ 250 NpH~..iNL -999 250 RCNT' NL -999 250 -999 250 , 999 SFLO..DiL 454 .999'250 NFDC'FDC -999;250 ~PHI,CNL -999,250 RCNT,~NL -999.'250 GR';~NL -999;250 TEN~,CSG 2,498 4540i000 DPHI,FDC .-999~' 50 NFDC,FDC -999,250 RCN~, -999,250 "999,250 2 968 999, 0 -999, 0 "999.~ 0 -999250 .999 250 DPM~'FDC NFD¢'FDC NPH{~:CN~ RCNJ'~NL E~,CSG PAGE: 10 "999,250 '999.250 '999,250 '99 250 .,999,250 -99 250 2 548 -999 250 -999 250 -999 250 -999 250 -999 250 '999 250 4 203 '999 250 '999 250 - 250 ,,999 '999 2 0 i'.~ '999' 20 "999'2 '999' 20 · 4,482 '999 '250 · 'gg 9.' 250 999' 250 :-999~; 250 -999,250 ~999" 250 ~ 999'250 :999,,250 999' 250 .'999~250 X8 Ta e Verification Llstino chlum~erger Alaska ComputtnO Center DEPT SP D!L RHOB FDC CALl FDC RCFT CNL CALl CNL DEPT SP DIL RHOB FDC CALl FDC TNPH CNL RCFT CNb CALX CNL DEpT, SP,DIL RHOB,FDC CALX,FDC TNPP,CNL PCFT~CN5 D~PT, ~OB,FDC CALX'FDC CF ,Cmb D~PT' SP FDC CAb! FDC TNPM CN5 R~FT CNL C~! CNL RMOB,FDC CALI'FDC TNPH'CNb RCFT,CN~ DEPT RMOB~FDC CALI;FDC RCFT,CNL CALI,CNL 6500.000 ' ,250 '999 250 '999:250 '999,250 '999,250 b400,O00 "36,78! '999,250 '999,250 '999"250 "999,250 "999,250 6300,000 '36 563 -999 250 -999250 -999 250 -999 250 -999 250 6200 000 - 250 -999 250 "999 250 -999 250 -999 250 6i00 000 '36 031 '9 ~ 250 -999 250 "999 250 6~00',000 .37' 3! '999' 50 '999'~50 '999, 50 -999, 50 ~999~250 oo'ooo '999'~5050 "999~ 50 '999'~50 "999,250 ILD.DIL GR.DIL DRHO'FDC GR.FDC TNRA.CNb CNTC.CNL TEN$,CNL ILD,DIb GR,DIL DRMO.FDC GR,FDC TN~A,CNL CNTC,CNL TENS'CNL ILD,DIL GR,DIL DRMO,FDC GR.FDC TNRA'CNb CNTC,CNL TENS'CNL ILD,DIL GR,DIb DRHO,FDC GR,FDC TNRA,CNL CNTC;CNL TENM;CNL iLD,DIL GR,DIL QRMO,FDC .GR,FDC TMRA'CNL TENS,CNL ILD DiL GR DIL DRHO FDC GR FDC TNRA CNL CNTC CNL TENS CNL GR,DIL DRHOeFDC GR,FDC TNRR,CNL C TC.;C L TENS,CNL 19-DEC-1089 !0:08 3079 100 188 -999250 -999 250 -999250 -999250 -999250 ILN,DIL TFN$.DIL FFDC,FDC TENS,FDC NPOR,CNL CFTC.CNL GR,CSG 3 399 -999 -999 250 -999250 -999 ~50 -999 50 IL~,DIL TENS,DIL FFDC,FDC TENS,FDC NPOR.CNL CFTCCNb GP:CSG 3 071 '999 ~50 :9 '999 250 XLM,DIL TEN$,DZL FFDC,FDC TEN$,FDC NPOR,CNL CFTC,CNL GR,CMG :4499 ~25 '999, ~0 '999,~ 0 "999, 50 "999,~50 '999;~50 ~ENS FFDC FDC ~EN$ FDC NPOR CNL CFTC CNL OR CSG 2,~!4 IL~,DIL 99,i~5 TENS,DIL "999, 0 FFDC'FDC '999, 50 TEN$;FDC '999' 50 NPOR;CNL "999~50 CFTC,CNL '999~' 50 GR'CSG 3.414 ILM,D!L 95;4~8 -999'250 FFDC'FDC -999;250 TENS'FDC -999,250 N -999'250 ,CSG -999;250 FFDC:~DC -999'250 TENS, DC -999,250 NPOR,CNL CFTC'C b -999,2~0 N -999'20 G~,CSG 3 034 SFLU 4360 000 DPHI' ,FDC -999250 NFDC,FQC -999250 NPHI,CNL -999250 RCNT,CkL -999 250 GR,CNL -999 250 TEN$.CSG 3344 SFLU'D!L ~504'000 PH -99~,250 NP~ -99 ,250 RCN{'cNL -999 GR'CNL 50 TENS,CSG 2995 SFLU,DIL ~260000 DPHX'[DC -999250 NFDC,FDC -999 250 NPH~,CNL -999250 RCNT,CNL -999250 GR,CNL -999250 T~NS,CSG 000 DPH{,FDC 999.250 NFDC'FDC -999;250 NPBX-*CNL -999,250 RCN~.'CNL :999;.250 999'250 ~EN$~iCSG 2,560 SFLU'DIL ~192,000 DPHX'FDC 999~:250 NFDC,,FDC -999 250 NPH!,CNL -999 ".50 RCN~.CNL -999 ~50 ' 3'350 SFLU,DXL 4020'000 DPH{,~DC -,999,250 NF~C,FDC -999;250 NPHi'{,CNL -999,~50 RCN~;CNL -999,~50 GR'CNL -999'~50 3,236 SFLU-'DIL ~960'000 ~999'250 NFDC,FDC ~999i250 NP~i.CNL ,999,250 PAGE: .99~ '485 .250 '999.250 "999,250 '999,250 '999,250 '999.250 5 450 '999 250 '99 2 50 ° , 0 9, 0 999,250 -', -99~, 5,298 "'999 250 ,250 ,2~ 0 4 2!! -~99 25 ~-999 250 5, I3 -9 ,2 4J, 626 -999.;250 '-99~,i250 -99 '250 -999~.250 TaPe V'erification Listing ChlUmberger Alaska Computing Center D~PT, SP,DIL PHOB,FDC CAL!,FDC TNPH'CN6 RCFT,CNL CALI,CNL DEPT. SP p.OB FDC CAt,! C~L DEPT, SP,DIL R~GB,FDC C~L~,FDC TNP~'CNL ~CF~,CN~ C~LI,CNL ~EPT, SP,D!L RMOM,FDC TNPM,~b ~CFT,CNL RHOB,FDC CILt'FDC Ti~PM,CNL RCFT,CNL D~PT ,FDC C~bl,FPC RCFT~CNb C~tilgC~L ~OB,FDC C X.F C ~CF~,CNL 5800,000 '39,625 -999.250 -999,250 -999.250 -999.250 -999.250 5700,000 =38.438 -999.250 -999.250 -999,250 -999,250 -999,250 5~0,000 9,250 -999 250 ~99 ,250 -999,250 -999,250 5500 000 -40 406 -999 250 -999 250 -999 250 ~999 250 -999 250 5400 000 -4 ,688 -999 0 '999 ~50 '999 50 '999 ~50 5~00,000 .38,:031 999,250 ~999'250 ~999~250 .999;250 -999,~50 o.ooo 0,750 '999,~50 "999,250 '999,250 '999,250 ILD.DIL GR.DIL DRMO,FDC GR,FDC TNRA,CNL CNTC.CNL TENS.CNL ILD.DIL GR"DIL DRHO.FDC GR'FDC TNRA.CNL CNTC,CNL TENS.CNL ILD,DIL GR,DIL DNHO,FDC GR'FDC TNRA'CN~ CNTC,CN5 TENS,CNL ILD,DIL GR,DIL DRMO"FDC GR,FDC TNRA~CNL CNTC,CNL IhD'DIL GR,DIL DRHO,FDC GR,FDC TNRA,CNL CNTC'CNL TENS~CNL I~D DIL GR DIL DRHO FDC GR FDC TNRA CNL CNTC CNL TENS CNL I~D,DIL GR,DIL DRMO'FDC GR'FDC TNRA;CN5 CNTC'CNb 19-DEC-1989 lO:OB 3 076 124 6B8 999 250 -999 250 "999 250 '999.250 3,086 1!4,125 '999,~50 '999, 50 '99~,250 '99 .~50 '999. 50 3 591 115:250 '999,2~0 '999,2 0 "999,250 '999,250 -999,250 3 624 11.5 125 -999 250 ~999 250 -999 250 ~999 250 ~999 25O 4,084 116,250 -999,~50 -999, 50 -999' 50 -999;;~50 ~999'50 -999,250 '99g; 250 '999,250 '9 ,250 ~9 , 0 ~999,250 IL~.DIL TENS.DIL FFDC.FDC TE~S,FDC NPOR,CNL CFTC.CNL GR,CSG IbM. TENS' FFDC, TENS, NPOR, CFTC, Ib~, TENS, FFDC, TENS, NPOR, CFTC, IL~, FFDC, TENS, NPOR, CFTC' G~' TENS; FFDC NPOR CFT~ G FFDC NPO~ CFTC TENS FFDC TEN8 NPO~ CFTC OIL FDC FDC CNL CSG DIL FDC FDC CNL CSG DIL FDC FDC CNb CNL CSG O IL FDC FDC CNL CSG D I b FD¢ F DC D Ib DiL FDC FDC CNh 2 973 4014 000 -999 250 -999 250 -999 250 -999 250 -999 250 3,019 3954,000 -999.250 -999.250 '999,250 -999'250 '999.250 3 450 4084 000 -999 250 -999 250 -999 250 -999 250 -999 250 3.460 ~834,000 999..250 -999.~250 -999,!50 3850,000 '999,250 -999;250 -999'250 -999'250 '999;250 347 99.~50 -999;250 -999,250 .999~250 -999;250 2999; 999,~5~ .999,250 SFLU,~IL DPHI,FDC NFDC.FDC NPHI.CNL RCNT,CNL GR.CNL TENS,CSG SFLU.OIL DPHI,'FDC NFDC.FDC NPHI.CN~ GR NL TENS,CSG SFLU.DXL DPHI DC RCNT.CNL GR.CNL TENS'CSG SFLU,DIL DPHI,FDC NFDC,FDC NPHi.'CNL RCNT'CNL GR'.CNL TENS,CSG ~LU,DIL ~PHI;'FDC NFDC,FDC NPHI',CN.~ RCN'T,.CNL TEN$,C$~ SFLU,DIL DPMiI'FDC NFDC~FDC NP~I"CNL RCNT,CN~ 'G~CNL SFbU~DX~ DPHI"FDC NFDC'FD~ NPH!'CN~ RCN~'CN~ GR'CNL EAGE; !2 4 75O -999:250 -999.250 -999.250 -999 250 -999:250 -999.250 4 836 -999!250 -999 250 -999.250 -999.250 -999.250 -999,250 5,288 -999.~50 -999, 50 -999,2.50 -999.250 -999,250 -999,250 5.255 999'250 .999.250 999;250 -999'250 -999;250 -999,250 , 6,675 999;250 :~999'250 999;250 -999,25 -999':'0 -999,250 999~250 4'9~0 '999,250 '-999,.250 ~999;2.50 -999,250 Tape Verification Listinq ChlumDerger AlaSRa ComPuting Center CILI,CNL SP,DIL RMO~,FDC C~LI,F~C TNPH,CNL ~CFT,CNL CALI.CNL DEPT, SP,DI5 PHO~.FDC CAL! FDC T~PHiCNL RCF~' CNL CAL! CNL DEFT, R~OB,FDC TNP~ CNL DEPT, DEPT, ~O.B~FDC C~LI,FDC RCFT,CNL CAL[ CN5 RHOB~'FD¢ C~LI'FDC TNP~'CN~ DfPT SP RNOB FDC PFDC ~P C~ '999,250 TEN$.CNL 100 000 ILD.DIL 999.250 DRHO,FDC -999,250 GR.FDC -999,250 TNRA.CNL -999,250 CNTC,CNL -999,250 TENS,CNL 00OOO 39:781 999.250 -999,250 -999,250 '999,250 -999,250 4900 000 -41 063 -999 250 -999 250 -999 250 -999,250 '999,250 4800,000 .'42~563 '999,250 '999,250 -~99'250 - 99,250 '-999,250 .4100,000 4~,06~ '99 ,~50 '99~.~50 '99 · 50 -999;250 '999,250 4600,~00 -48, 13 -999'.50 5O '999; 5 -999,0 -999,250 -999i250 4500,000 "39,188 -999 '250 -999'250 -999,250 ILD OIL GR DIL DRHO FDC GR FDC TNRA CNL CNTC CNL TENS CNL ILD,DIL ~R,DIL DRMO,FDC GR,FDC TN~A,CN5 CNTC'CNb TENS.CNL IbD,Plb GR~DIL DRMO,FDC G ,FUC TN~A,CNL CNTC,C~ TENS~CNL ILD GR DRHO FDC GR FDC TNRA CN5 CNTC CN5 TENS CNL !LD,DIL DRNO,FDC GR'FDC NRA;C~ ~NTC'CNI, TENS,CNb ILD'DIL GR,DIL DRHO'FDC GR,FDC TNRA,CNL 19-DEC-1989 !0:08 -999,250 GR,CSG -999.250 3 659 96i188 -999 250 -999 250 '999i250 -999250 -999,250 90, 5 -999.250 -999'250 -999,250 -999.250 -999,250 3 940 111 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999' 5 -999;]0 -99 2 0 0 '-999~250 108 ., '999 250 ~999 250 3.761 ,,!05;750 999'250 -999;250 ,'999,250 ILg DIL TENS DIL FFDC FDC TENS FDC NPOR CNL CFTC CNL GR CSG XLM,DIL TENS,DIL FFDC,FDC TEN$,FDC NPOR,CNb CFTC,CNb GR,CSG IL~,DXb TEN$,DIL FFDC'FDC TENS,FOC NPOR.CNb CFTC.CNL GR,CSG IL~ TENS DIL FFDC FDC TENS FDC NPOR CNL CFTC CNL G~ T.~NS,D!·L FFDC,FDC TENS,FD~ NPORiCNL CFTC.C~b GR'CSG Ib~,Olb ~ENS,DIb FFDCgFDC TENS,FDC NPO~,CNL CFTC'CNL GR,CSG IL~,.DIL, FFDC;FDC NPOR,CN[~ 3 490 3564 000 -999 250 -999 250 -999 250 -999 250 -999 250 2 985 ~!90 000 999 250 -999 250 -999 250 -999 250 -999 250 3 688 3384 000 -999 250 -999 250 -999 250 -999 250 -999 250 TENS,CS6 SFLU DIL DPHI:FD¢ NFDC.FDC NPH! CNL RCNT:CN~ GR.CNL TENS,CSG DPHI FDC NFDC FDC NPhI CNL RCNT CNL GR,CNL TE~$.CSG 6FLU.DIL DPHI,FDC NFDC.'FDC NPHI.CNL RCNT'CNL GR.CN~ TEN$,CSG 2.898 SFLU'DXL ..99'250 NFDC.,'FDC .999'250 NPHX:,CNL 999'250 RCNT.CNL -999.;250 GR'CNL -999,250 TENS'C$O ,3.080 :$FI..,U,DI5 3224,000 DPHI'FDC :999,250 NFDC,FD¢ ,999; 50 RCNT'.NL · 999,250 GR,'¢~ -999;250 TENS,:C~G DPHI.'FDC 999;250 NFDC,FDC -9991,250 NP~I~,CN.~ -999'250 RCNT,C~L :999.;250 GR,CML 999;250 TEN:$'CSG 3,33~ SF~U,D.IL ~010,000 DPHI,'FDC i999,250 NFDC,FDC -99g,250 NP~I;CN·~ -999'250 RCNT~CNL '999,250 4.221 '999i250 -999 250 '999,250 '999.250 '999.250 '999,250 4.438 '999,250 '999,250 '999,250 '999.250 '999'250 '999,250 5,805 '999,250 -999.,250 -999.250 -999'250 -999'250 -999'250 4,824 '999;250 '999;250 '999'250 :999'250 .999'250 999:,250 5i, 026 -999 250 ~-999 250 -999 250 -999 250 -999 250 '999 250 .9,424 -999."250 -999.~250 -999.;250 :-999,250 ';'999,250 -999,250 ,,,999,2 "999,2~0 '99 IS 7'ape verifi, cation Listing chlumberqer AlasKa ComPuting Center g99 250 ~C~'~,CN~ ~. , CA[.I.CNL 999,250 DEPT SP DIL RPOB FDC CALl FDC TNPH CNL CALl CNL DEPT. SP'DIU RHO~.FDC CALI,FDC TNPM'CNL CALl NL SP D!L CALl FDC RCFT CNL CALl CNL DEP? SP:DIL ~HOB,FDC C~LI,FDC TNPM,CNL RCF?;CNL DEPT, RH~B.,FDC R~OB}FDC DEPT, SP;D~t~ RHOB'FDC C~bI'FDC 4400,000 '45.500 '~99,250 '999.250 '999.250 '999.250 '999'~50 4]00 000 '41 000 '999 250 '999 250 '999 250 '999 250 '999 250 4200 000 ;4 469 '.9~ 250 ~999 250 ~999 250 '999 250 '999 250 4!00,000 999.250 -999,250 -999;250 -999'250 -999,250 4000 000 -99 ,250 -999,250 -9 '2SO '999"250 3900,000 '45'688 '999~50 '999'~6 '999,250 '999~250 '999,250 3800,000 -46'031 -999,250 -999,250 CNTC TENS:CNL ILD,DIL GR.DIL DRMO FDC GR FDC TNRA CNL CNTC CNL TEN8 CNL ILD,DIL GR,DIL GR DC TNR.A,CNb CNTC.CNL TENS,CNL ILD DIL GR DIS DRHO FDC GR FDC TNRA CNL CNTC CNL TENS CNL ILD,DIL DRHO,FD¢ GR;FDC TNRA;CNL TE'NS,CNL GR,DIL DRHO~FDC GR'FDC TNRA~;CNb CNTC.CNb TENS'CNh 'ID R,DIL ,DI~ DR~O,FDC GR.FDC ~N~A,CN[i NTC'CNL TEN$,CNb ILD'D!L GR;DI.b DR.HO~FDC 19-DEc-IgBg 10:08 '999.250 CFI~C,CNL -999,250 GR,CSG 6 066 93 750 -999 250 -999 250 -999 250 -999 250 -999 250 11 88 -99 250 -99 ~ 0 '999, 0 "999.250 9~ 692 688 250 999 999 250 -999 250 -999 250 -999 250 5,~26 96. 13 '999 50 -9 50 '9 50 3, 05 ~6,~00 '999': 0 -999;~50 -999; 50 -999,1250 4 40 117 -999 2~0 "999 2~'iiO 'ggg 250 "g99 "999 250 4'793 99, ! 88 ,.999,~50 -999, 50 IL~.DIL TENS.DIL FFDC.FDC TENS'FDC NPOR'CNL CFTC.CNb GR,CSG IL~,DIL TEN$,DIL F[DC,FDC TENS,FDC NPOR,CNL CFTC,CNL GR,CSG ILM,DIL TENS~DIL FFDC,FDC TENS,FDC NPOR,CNL CFTC,CNL G~'CSG TEN$.DIL FFDC FDC TENS FDC NPOR CNL CFtC CNL GR CSG TENS DI~ FFDC FDC TENS FDC NPOR CNL CFTC CNL GR CSG ILM,DIL FFDC,FDC TENS,FD~ NPOR,CN[ CFTC;CNL GR,CSG ! L M, D I L FFDC; FDC TENS, FDC -999, '999, 5 2980 '999 -999 -999 '999 '999 3 2930 -999 -999 -999 -999 -999 3 2764 -999 -999 -999 250 250 719 000 250 250 250 250 250 95O 000 25O 25O 25O 25O 25O 517 000 o GR CNL TEN$:CSQ SFLU,DIL DPHI,FDC NFDC,FDC NPHI.CNL RCNT CNL GR:CNL TENS.CSG SFLU.DIL NFDC DC GR,~NL TENS, SG DPHI FDC NFDC FDC NPH~ CNL RCNT CNL G~ C~L TgMS CSG ~99g,25~ .999,25 RCNT'CN~ ~999;:~5 GR'CNL .999,250 T'EN$,C.$G 000 -g99'250 -999,250 ~999. 999;250 s 4;ooo ~999,250 .999~250 999'250 .-999;.250 .-999.250 4'~85 57o: oo -99g'2:50 .999,250 DPMI'FDC NFDC.FDC ~PHI.,CN~ RCNT'CNL ::GR'CNL TEN'$,CSG DP~I'F'DC N~DC'FDC RCNT'CNL :GR,CN~ TENS..C$~ SFLU,.DIL DPHI.~:FDC MFDC.'FDC NPHI"CN~ PAGE: 14 '999.~50 '999. 50 8.056 '999.250 '999'250 '999,250 '999.250 '999.250 "999,250 6 767 '999 250 '999 250 -999 250 '999 250 -g99 250 -999 250 . 6;.056 .999.250 -999,250 -999.250 -999.250 -999'250 -999,250 7.,137 :999:;250 .999;,250 '~999:,250 999,:250 -999'250 999,250 ~-999~,250 '999~250 :'999,250 :-999~250 6.190 -999~250 :999%25:0 ,999.,250 ~999,250 999'250 8,012 ~-999:;250 ~-999'25.0 ChlUm erger AlasKa Comput ng Center NPH,CNL CFT,CNL CALI,CNL DEP?, SP,DIL RPOB,f'DC CALI,FDC TNPH,CNL ~FT.CNL L! .CNL DEPT SP RFOB FDC CALl FDC RCFT CNL CALl CNL DEPT. _HSP'DIL ~ OB;FDC CAL! FDC TNPH CNL RCFT CNL DEPT, CALI;:FDC ?~PH..CNL RCFT;CNL DEPT, RHO DC D~PT~ CA~I,;~DC TNPH~CNL CALI~¢NL '999 250 TNRA,CNb '999:250 CNTC.CNL =999,250 TENS.CNL 19-DEC-1989 10:08 -999 250 NPOR,CNL =999!250 CFTC,CNL '999 250 GR,CSG ]700.000 ILD,DIL 2 -999,250 DRH FDC -99 -999,250 GR,FDC '999,250 TNRi!CNL '999 -999,250 CNT CNL -999 -999,2~0 TEN CNL -999 3600,000 ILD '999,250 GR -999,250 DRHO -999,250 GR -999,250 TNRA -999,250 CNTC -999,250 TENS 3500,000 .ILD '999'250 OR -999'250 DRHO '999'250 GR · -999,250 TNRA '999,250 CNTC '999,250 TENS ~400,000 .999,250 GR, ::~999;250 DRHO' .-999'250 1999,250 CN?C, ~.999;250 TENS; DIL DIL FDC FDC CNL CNL CNL DIL D!L FDC FDC CNL DIL DI~ FDC FDC CNL CNL CNG DIL DIL FDC FDC CNG C N b CN L DIL FDC FDC CNL CN b CNG 3300,000 -999,250 '999,250 DRHO' 999~,250 TNRA' -999~R50 CNTC, -999;250 TENS1 ~200,000 ILD. 999;' 0 GR, -999.~0 DRHO, -999;250 GR; -999,250 TNRA~ 1999,250 CNTC, 999,250 TENS, 4 258 1 500 9 250 9 250 250 250 250 -999 -999 -999 -999 -999 -999 -999 -999 99 -999 -999 2999 -999 -999 -999 -999 -999 -999 -999 -999 250 25O $0 250 250 250 25O 25O 25O 25O 25O 250 ,250 ,250 ,250 ,250 ;250 ;250 ,250 50 50 50 0 2 5 0 ,250 0 0 ~0 ;250 ILM,DIL TENS,DIL FFDC.FDC TEN$.FDC NPOR,CNL CFTC,CNb GR.CSG ILM,DIL TENS,DIL FFDC,FDC TENS,FDC NPOR,CNL CFTC.CNL GR'CSG ILM,DIL TENS.DIL FFDC.FDC TENS"FDC NPOR"CNb CFTC;CNL GR,CSG FFDC FDC TENS FDC NPOR CNL CFTC .u 'ILM,DIL ~FDC,FDC T~NS.FDC N~OR,CNb C~C,CNG GR'CSG iLM,DIL TEN$,DIL FFDC,FDC TENS,FDC NPOR'CNG CFTC,CNb -999 '999i 87 2000. 2444 -999 -999 -999 -999 6O -999 -999 -999 -999 -999 -999 5~ -999 -99 -999 -999 -999 5! 250 250 063 000 000 25O 25O 25O 25O 250 250 250 250 250 250 625 ,250 50 250 50 ,~44 -999. -999, ~999, ~999, 999, 5.1; -999, -999. .99 ; .999. 999, -999, -999; 2999, .999, .999; 250 5O 250 250 25 o 250 250 250 063, 250 250 250 250 250 250 375 RCNT.CNL GR.CNL TEN$.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR,CNL TEMS.CSG DPMI.FDC Nf'DC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI-FDC NFDC.FDC NPHI. CNL RCNT~C.NL :GR,CNL SFLO,DIL DP.MI.FDC NFDC,FD¢ NPH~'~NL RCN.~'CNL GR.CN5 ?EN. SOCSG SFLO..DIL DPHI..FDC NFDC,'FDC NPMI~:CNL RCNT,CN~ GR,CNL T'ENS, CSG SFLU. DIL DPHI'FDC NFDC'FDC NPHi"CNL RCNT.CNL GR,:~NL TENS, SG PAGE: 15 -999 250 '999i250 2530 000 2000,000 '999,250 -999,250 '999,250 '999.250 '999 250 2424:000 '999.250 '999,250 '999,250 '999,250 '999;250 '999,250 2420.000 '999, -999'250 '999,250 ~999.250 .999,250 23~4;O00 :999,250 999:;250 .999,.250 9V9;250 2294,000 'Z999;250 ~;999'250 ;999'250 i;999'250 ,999'250 2220'000 :'999,250 -999'250 -999;2:50 .-999~250 :999,250 999'250 2144;000 ~S ~'~e Verification Listinc ~hlum~erger ~las~e Co~putin~ Center DFPT SP DIE ~PO~ FDC RCF~' CNL DEFT, SP,DIL RHO~,FDC TNPH,CNL ~CFT,CN~ CILI,CNL DEPT SP DIS RMOB FDC CAL! FDC TNP~ SP DID ~MOB FDC fpc T~PH CNL CILI DEPT,D CAL!'FD¢ T~PH'CNL ~CFT,CNL D[P'? SP DIL CA:L! FDC T~P~ RCFT C~ CAbi CNL DEPT, C~.L~,FDC RCFT'CNL CALI,CNb 3100 000 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 3000,000 -999.250 -999,250 -999.250 -999,250 -999,250 -999,250 2900 000 -999 250 -999 250 '999 250 '999 250 '999 250 '999 25O ~800,000 'i999'250 -999~250 -999'250 -999'250 -9~9,250 -999;250 2700,000 '999,25'0 '999;:~50 :999'250 999'250 "999.250 '999'250 2600 000 -999 250 -999 ~50 -999 50 -999 250 -999 250 -999 250 2500 o0o '999 250 '999 250 '999 250 '999 250 -9 250 ILD.DIL DRHO.FDC GR,FDC T~RA,CNL CNTC,CN5 TENS,CNL ILD DIL GR DID DRHO FDC G~ FDC TNRA CNL CNTC, CNL TENS:CNL ILD DID GR DID DRHO FDC ~R FDC TiaRA CNL CNTC CN5 TENS CNL ILD,DIL GR.DI!~ DRHO'FDC ~n;tDC T~.C~ C~TC'C~5 TENS,CNL ILD,DIL GR,D/L DRHO'FDC GR'FDC c~?c,cN[~ TENS,CNL ILD DID GR DIL DRHO FDC GR FDC TNRA CNL C~TC CNb TENS CNb ILD,DIL GR'DIL DRHO,FDC GR;FDC TNRA,CNb C~TC;C~b TENS,CN'b 19-DEC-198g 10:08 -Egg 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 "999.250 '999;250 '999'250 "999.250 '999'250 '999'250 '99~,250 '99 .250 '99~,2~0 '99 ,2.'0 -99~.2 0 -999.2 0 -999,2 0 -999 250 '99 0 "99~ 25 25O '999 250 '999 250 '999 250 '999.250 '999,250 '999.250 '999'250 -9~,250 '9 '250 ILM.DIL TENS.DIL FFDC.FDC TEN$.FDC NPO~.CNL CFTC.CNL GR.CSG ILM.D!L TEN$.DIL FFDC.FDC TENS.FDC NPOR.CNL CFTC.CNb GR.CSG TENS IL FFDC,[DC TENS,FDC NPOR:~NL CFTC .Nb GR,CSG ILS DIL TENS DIL FFDC FOC TENS FDC NPOR tnb CFTC CNL O~ CSO ILM.DIL TENS;D!b FFDC'FDC NPOR'CN~ CFTC.CNL GR.CSG I5~.DIL TE~S.DIL FFCC'FDC TENS.FDC CF~'C;CNL GR,CSG TEN6~DIL FFDC,FDC TENS,FDC CF~:C;CNb GR.C6G -999 250 SFbU.DIL -999 250 DPMI.FDC -999 250 NFDC,FDC -999 250 NPMI.CNL -999 250 RCNT'CNL -999 250 GR.C~L 52 344 TEN$.CSG -999.250 SFLU,DIL -999,250 DPMI.FDC -999,250 NFDC.FDC -999.250 RCNT NL -999 250 GR.CNL 54:000 TEN$.CSG -999 250 8FbU.DIL -999 250 DPHI,FDC '999 250 NFDC.FDC -999 250 NPHX,C~L -999 250 RCNT.C~L -999 250 GR.CNL 48 375 TENS,CSG 999 250 SFLU.DIL -9 0 ~.PHI,CNL -999' '0 RCNT,CNL ~999,250 SF~U,DI~ ~999, ~0 DPHI,FDC 999.~ ~ NFDC'FDC -999,~5 NPMI.CNL -999,250 RCNT,CNL -999.~50 GR,CNL 55.188 TEN$~CSG .999 250 SFLU'DIL -999 250 DPHI,FDC -999 250 NFDC,FDC -999 250 'NPB!,C~L -999 0 GR,C~ -999 :~!0 RCNT,C~b 53 3 TE~$;CSG ~999,250 .999, 2999,250 .997, SFLU,DI~ .DPHI,FDC NFDC~FDC RCNI.CNL PAGE: 16 '999,250 '99 250 '99 250 '999,250 10 000 '999,250 '999,250 '999"250 '999'250 '999,250 '999.250 2045.000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 1970 000 '999,250 -999'250 '999'250 -999,250 -999;250 "999'250 2054;000 '999,250 '999~250 '999,250 "999',250 '999,250 '999,250 1945~=000 '999,250 '999,250 '999,250 '999,250 "999,~50 -999,250 i945,000 ~999 250 -999 250 -999 250 25' '999 25~ "999 ~'999 250 1875 000 IS Tape Verification Listing ~blU~.berger Alaska Computing Center SP T~PB ReFT CNL SP~DIL RBDB.FDC TNP~CNb RCFT'C~L CALI.CNL DEPT R.OB FDC C~L! FDC RCFT CNL C~L! CN5 DfPT, SP,D!b R.,OB,FDC C~AL!-.FDC TNPH:'CNL RCFT,CNL CALI,.CNL DEPT, R. OB,FDC C~L~FDC TNPH,C~L RCFT,CNL C~LI,CN5 D~PT. _SP'~!L C~LI;FDC 400,000 999,250 '999,250 -999,250 -999,250 -999,250 -999,250 2]00 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ! o.ooo 250 99 : so -99:250 -99~ 250 -99 250 ~loo 0oo ~999 250 '999 250 '999 250 "999 ~50 '999 250 '999 250 2o00,o00 '999,250 -~99'~50 - 99:50 -999'250 -999'250 -999,250 ~900,000 ~999'250 999-250 -999~250 -999;:250 -999'250 -999,~50 999 50 -999 250 ~999 250 "999 250 ILD DIL GR DIL DRHO FDC GR FDC TNRA CNL CNTC CkL TENS CNL ILD DIL GR!DIL DRHO FDC GR.F~C TNRA,CNL CNTC.CNL TENS.CNL ILD,DIL DRBO,FDC ~Dc TN~A,CNL CN~C,C~L TENS'CNL ILD,DtL ~R'DiL DRHO,FDC CR'FDC TNRA'C~L CNTC'CNL TENS;CNL GR,DI'b DRHO,FDC GR;~DC CNTC'CN~ TENS.CNL ILD,DIL DRHO,FDC GR,FDC ~TNRA~CN5 CN~C;C~h TENS,CNB I~D,DIL CNTC'CNL 19-DEC-1989 10:08 2999.250 999.250 '999 250 "999 250 '999 250 '999 250 "999 250 ~999 250 ~ 999: 250 -999.250 -999.250 ,,999 250 "999 25 "999 250 ..999:250 -999 250 -999 2§0 -999 250 ..999 250 -999 250 -9 50 '999 250 "999 250 '999 250 '999 ,,,9~9 50 "999,250 -999. 250 -999,2550 -999'250 -999,2~ 0 -999.2~0 -999,250 · '999,250 '999'250 '999.250 '999'250 '999;250 '999.~50 '999 ' 250 ' 999, 29 9, so ~ 999'~50 .-99 250 TENS.DIL FFDC.FDC TENS.FDC NPOR,CNL CFTC,CNL GR,CSG ~EmS:DIL FFDC FDC TENS:FDC NPOR.CNL CFTC,C~L GR,CSG ]L~,DIL TENS,DIL FFDC,FDC TENS,FDC NPOR'CNL CFTC,CNL GR,CSG !L~ DIL ~ENS DIL FFDCFDC TENS FDC NPOR CNL C~'TC GR TENS FFDC FDC TENS FDC NPOR CNL CFTC CNb GR CSG TE'D!L FFDC,FDC TENS,FDC NPOR'CN5 CFTC,CN5 GR'CSG IL~,DIL TEN5 DIL FFDC FDC TENS FDC NPOR CNb CFTC CNL -999 250 SFLU.DIL -999 250 DPH! FDC -999 250 NFDC FDC -999 250 NPHI CNL -999 250 RCNT CNL -999 250 GR CNL 44 719 TENS CSG -999 250 SFLU,~IL -999 250 DPHI. DC -999 250 NFDC,FDC -999 250 NPHI,~NL -999 ~50 RCNT NL -999 250 GR:CNL 55 063 TENS,CSG -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 38 125 SFLU.,DIL NFDC,FDC NPHI'CNL RCNT,CNL GR,CNL TENM.CSG -999,250 SFL~,DIL -999.250 DPH ,FDC -999.250 NFDC.FDC -999'250 NPHI.CNL -999.250 RCNT.CNL -999'250 GR.~CNL 25,594 TgN$*CSG :999,25 DPHI,FDC ~999,250 NFDC;FDC .999'250 NPMI'CNL 999~250 RCNT,CNL -999'250 ~GR,CNL 37;000 Tf~NS'CSG -999 250 SFLU,DIL -.999 ~0 DPH~,FD¢ -999 0 NFDC'FDC -999 250 NPHI..CNL -999 ~50 RCNT'CNL .999 50 GR,~NL 4! 988 TENS.CSG '999,~250 SF}~U,D~L :999.250 DPh.I.FDC 1999,250 NFDC,FDC .999,250 NPHI'CNb 1999;250 RCNT;~CNL 999,250 !~R,CNL PAGE: 17 ~999 250 999:250 -999.250 -999'250 -999.250 -999 250 i o:ooo -999 250 '999i250 -999 250 -999 250 -999.250 -999.250 1750,000 -999.250 -999,250 -999,'250 -999'250 -999 ~50 -999:250 t795.000 -999.250 -999'250 -999'250 -999'250 :9.99,250 999;:250 .i685,000 '999,250 -999,,~50 '999, 50 ~-999'250 -999,250 -999,250 1740'000 -999,250 -999,250 -999,250 -999,250 '999,250 -999'250 1650'000 "999,250 '999,250 "999;250 '999'250 :'999'250 ~'999'250 IS Tape verification Listing chlumberger Alaska Computing Center C!LI,CNL TEN&,CNL DEPT. SP DIL R~OF FDC CALl FDC TNPH CNL RCFT CNL CALl CNL DEPT, ~HOB~FDC CA~.FDC TN ,CNb RCFT,CNL CALI,CNL DEPT EP DIL CAb[ FDC TNPH CNL RCFT CNL DEPT, RHOB,FDC AL! FDC ~NpH CNL RCFT CNL DEP?. L s ,uI CALI,FDC RCFT~CNL CA~I,:CNL EP DIL R~O~ FDC T~PM CNb ~EPT I~MOB FDC CNAbI FDC '999,250 1700,000 :999,250 .999,250 -999,~50 -999.250 -999.250 -999,250 1600 000 -999~250 -999.250 -999.250 =999,250 -999,250 =999,250 1500 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 [400,000 999'250 '..999,250 -999,250 '999,250 1300,000 "999'250 "999,250 -999'' 0 -99',250 -99~,250 1200,000 "999,250 :999'250 .999,250 ~999,250 ~999;250 999,250 [100,000 .999,250 ~999;.~50 999,;250 -999'250 i9-DEC-1989 !0:08 -999.250 GR,CSG 42 ILD.DIL -999 250 IL~,DIL -999 GR DIL -999~250 TENS,DIL -999 DRHO:FDC -999.250 FFDC,FDC -999 GR,FDC -999,250 TENS,FDC 999 TERA,CNL -999.250 NPOR,CNL ~999 CNTC,CNL -999.250 CFTC.CNL -999 TENS.CNL =999'250 GR.CSG 48 ILD,DIL GR.DIL DRHO,FDC GR.FDC TNRA.CNL CNTC.CNL TENS,C~L ILD OIL GR DIL DRHO FDC GR FDC TNRA CNL CNTC C~L TENS CNL ILD,DIL GR,D!L DRHO,.FDC GR,FDC TNRA,CNb CNTC,CNL TEN$,CNL .ILD,DIL GR.;DIL DRHO'FDC GR,FDC TNRA,CN6 CNTC'CNL TEN$,CN5 DRHO;FDC TNRA,CNL c?c.c I~,DIL , :DR~O ' FDC TNRA,CNb -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 '999 -999 -999 -999 -999 -999 -99g '999 "999 -99 '999 "999 "999 "999 "999 '999 "999 "999 "999 -999 ,,999 "999 '999 "999 250 ILM,DIb 250 TENS.DiL 250 FFDC.FDC 250 TEN$,FDC 250 NPOR,CN~ 50 CF2C,CNL ~50 GR,CSG 50 IL~,DIL 50 TEN$.DIL 250 FFDC.FDC 250 TENS,FDC 250 NPOR,CNL 250 CFT'C'~b 250 GR, SG 250 IL~,DIL 250 TENS,DIL 250 FFDC,FDC 250 TENS,FDC 250 NPOR'CNL 250 CFTC,CNL 250 GR,CSG 250 2 0 TEN~'DIL 0 FFDC,FDC 50 T.E~S,FDC 250 250 CF'.C,CNb 250 GR,CSG ,250 ,250 ,250 ,250 ;250 .250 ,250 250 250 25O 25 O: !bM TENS FFDC FDC TENS FDC ~PO~ CNh CFTC'CNL GR,CSG ! L ~, D I L t E N~5; D I L FFDC. FDC TENS, FDC NpOR ;CNL ,250 25O 250 250 ,250 .250 .250 ,656 -999 -999 .-999 -999 -999 -999 -999 -999 -.999 -999 -999 -999 3! -999, -999, · -999, -999. -999, -999, 28, -999, -,999, - 999, -999, -999' '"99~, -999 -999 -999 -999 -999 -999 34 -999 -999 -999 -999 -999 250 250 250 250 250 250 344 250 250 25O 000 250 250 250 250 250 250 250 266 250 250 25O 25O 250 250 531 250 25 25:0 ,250 TENS,CSG SFLU,DIL DPHI FDC . DC: DC NPHI,CNL RCNT.CNL GR,CNL TENS.CSG SFLU.DIL DPH! FDC ~FDC:FDC NPH! CNL RCNT[CNL GR CNL TENS,CSG SFDU DIL DPHI FD~ NFDC NP'HI,CNL RCNT,CNL "GR,~NL TEN:S.~G SFLU,DXL DPH~,,FDC NFDC~FDC ~P~X,CNL RCNT,~NL G~CNL TENS;CEG SFbU'DIL DPH{,FDC NFDC,FDC RCN~,CN~ GR,C~L TEN$'CSG DPHI,FDC NFDC'FDC NPHi.'CNL RCh~':CNL GR,CNL ,TEN$.CSG SFLO,DIL DPHI.FDC NFDC'FDC NPHX,CNL RCNT,CNL PAGE: 18 1670,000 -999,250 .-999.250 '999,250 '999,250 '999,250 '999,250 1645.000 ~99.250 99.250 -999,250 -999,250 -999,250 -999,250 1610,000 -999 250 -999 250 -999 250 -999 250 -999 .250 -999 250 1520 000 '999,250 -999,250 '-999;250 -999'250 :-999,250 -999'250 ~495,000 -999,250 .-999.'250 -999,250 '999~250 -999.;250 -999'250 1405'000 '999,250 "999,250 "999'250 "99 ~50 ; g: so '999,250 -999,250 -999,250 .-999'250 -999,250 IS Tspe Yerlflcatl. on ListI Q :hlumberger AlasKa Comput ~q Center [~CFT,CNL .-999 250 CNTC.CNL CALI,CNL 999:250 TENS,CNL BEPT !000,000 ILO.DIL SP~DIL 999,250 GR.DI5 RHOP.FDC 999.250 DRHO'FDC CALI'FD¢ -999.250 G~,FDC T~PH CNL -999.250 TNRA.CNL RCFTiCNL -999,250 CNTC,CNL CALl CNL -999,250 TENS,C~L SP TNP~ CALl 992,500 ILD,DIL DIL -999,250 GR,DIL FDC -999,250 ORHO,FDC FDC -999,250 GR.EQC CNL -999.250 TNRA,CNL CNL -999,250 CNTC,CNL CNL -999,250 TENS,CNL END OF DATA 19-DEC-~989 10:08 -999 250 CFTC.CNL -999,250 -999:250 GR,CSG 30.859 -9q9 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 50 -999.250 !L~.DI5 TEN$,DIL FFDC,FDC TENS,FDC NPOR,CNL CFTC.CNL GR'C6G ILM,DI5 IEN$,DIL FFDC,FDC TENS.FDC NPOR'CNL TC,C~L CFGR,CSG -999,250 -999.250 -999.250 -999.250 .99 250 ]4 ]44 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 42 GR.CNL TENS.CSG SFLU.DIL DPHI.FD¢ NFDC.FDC RC~T,CNL GR,CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC,FDC NPHI,CNL RCNT.CNL GR,CNL TEN$,CSG PAGE: 19 -999,250 1320,000 -999.250 -999.250 -999,250 -999,250 -999.250 -999,250 1285,000 -999 250 -999:250 -999 250 -999!250 -999 250 ~999'250 240,000 ~ F.ILF TRAILER **~ FILE NA~E : ED!T ,001 S~VlC~ : FLI C YERS!ON : O0!AO.4 DATE : 89/12/19 ~AX REC $iZ~ : !096 F!L~ TYPE ~ LO L~ST FIL~ : PREVIOUS TAPE : COM~E.NT :.ARCO ALASKA, INC, ,KUPARUK, 2~ $~RV.tCE NA,E : EDIT TE : 89t12/!9 O~IGIN : FLIC REEL'NAME : 7~588 CONTINUATION # : p~E¥IOUS REEL : COMMENT' : ARCO ALASKA, INC,,KUPARUK,2K - 20,50',!0.]'20!20"00 - 20,50-!03-20t20-00
