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180-136
MEMORANDUM TO: Jim Regg� 7�� ✓�'� �� P.I. Supervisor FROM: Brian Bixby Petroleum Inspector Well Name PRUDHOE BAY UNIT 16-01 Insp Num: mitBDB220205154141 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, February 14, 2022 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 16-01 PRUDHOE BAY UNIT 16-01 Src: Inspector Reviewed By: P.I. Supry'= Comm API Well Number 50-029-20533-00-00 Inspector Name: Brian Bixby Permit Number: 180-136-0 Inspection Date: 2/4/2022 ' Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 16-01 ' Type Inj ' W ',TVD 8602 Tubing1502 1497 1502 1508 2150 IA 615 2418 2381 BBL Returned: psi _'1 -- p 2372 PTD p1801360 — Type Test SPT '� i BBL Pumped: 1 2.3 2.3 OA 4- 4 3 3 Interval 4YRTST PIF P ✓ Notes: Monday, February 14, 2022 Page 1 of I David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/15/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Please include current contact information if different from above. Received By: 07/15/2021 37' (6HW By Abby Bell at 2:06 pm, Jul 15, 2021 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:180-136 6.50-029-20533-00-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 13020 12806 9132 12000, 12175 None 12806 8462, 8601 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 35 - 115 35 - 115 1530 520 Surface 2661 13-3/8" 34 - 2695 34 - 2661 5380 2670 Intermediate 12428 9-5/8" 32 - 12460 32 - 8836 6870 4760 Production Perforation Depth: Measured depth: 12598 - 12795 feet True vertical depth:8953 - 9123 feet Tubing (size, grade, measured and true vertical depth)5-1/2" 17# L-80 30 - 12250 30 - 8663 12000 8462Packers and SSSV (type, measured and true vertical depth) 5-1/2" Baker S-3 Packer Liner 818 7" 12197 - 13015 8620 - 9315 7240 5410 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1 18868 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Richards, Meredyth Meredyth.Richards@bp.com Authorized Name:Richards, Meredyth Authorized Title: Authorized Signature with Date:Contact Phone:+1 9075644867 Treatment descriptions including volumes used and final pressure: 13. Petroleum Engineer Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ 5 WAG GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9319 Sundry Number or N/A if C.O. Exempt: N/A 5-1/2" Baker Hydro Set Packer 12175 8601 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028332 & 028346 PBU 16-01 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:46 am, May 28, 2020 Meredyth Richards Digitally signed by Meredyth Richards Date: 2020.05.27 15:00:29 -08'00' DSR-5/28/2020MGR28MAY20 RBDMS HEW 5/29/2020 ACTIVITYDATE SUMMARY 4/12/2020 ****WELL S/I UPON ARRIVAL**** (Perforating) DRIFTED TBG W/ 20' x 2-1/2" PJO DUMMY GUNS, TEL & 2-1/2" SAMPLE BAILER.(recovered thick shmoo sample) LOCATED TT @ 12,250' SLM/ 12,234 ELMD, TAGGED STICKY BTM @ 12,696' SLM/ 12,680' ELMD. NOTE: TARGET DEPTH FOR PERFORATING WAS NOT ACHIEVED - BOTTOM SHOT @ 12,870' WAS REQUESTED IN SoR. ****WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS**** 4/26/2020 T/I/O= 1200/750/0. Temp = Hot Assist CTU. Freeze protect flowline/Pump hot dsl. (PERFORATING/DIESEL XYLENE) Pumped 5 bbls 60/40, followed by 60 bbls crude, followed by 3 bbls 60/40 down flowline from manifold bldg. Close WV and pressure flowline to 1500 psi. *** Job continued to 04/27/2020*** 4/28/2020 CTU #9 - 1.75" Coil x 0.156" wt ***Cont. from WSR 4-27-20*** Job Objective- Jet Schmoo and Add Perf Make up Log/FCO BHA with 2.88" GR/CCL carrier and 3.0" JSN. Clean out down to 12797'. POOH logging for coil flag. POOH with good data, Corrected PBTD of 12796'. MU 31' x 2.5" Powerjet Omega Perf Gun, 6 spf, and RIH. Tie-in at PBTD and perforate 12764-12795' (interval adjusted per APE). POOH and FP well. RDMO CTU. ...Continued on WSR 4-29-20... 4/29/2020 CTU #9 - 1.75" Coil x 0.156" wt ***Cont. from WSR 4-28-20*** Job Objective- Jet Schmoo and Add Perf Complete Rig down ***Job Complete*** Daily Report of Well Operations PBU 16-01 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,February 21,2018 / P.I.Supervisor I Q�t Z-1 Z7 V't SUBJECT: Mechanical Integrity Tests / BP EXPLORATION(ALASKA)INC. 16-01 FROM: Bob Noble PRUDHOE BAY UNIT 16-01 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 16-01 API Well Number 50-029-20533-00-00 Inspector Name: Bob Noble Permit Number: 180-136-0 Inspection Date: 2/15/2018 V Insp Num: mitRCN180215140616 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Type 'TVD 8602 Tubing 1440 1433 1443 Well 16-01 'I' a Inj I W1 1443 ?; -Type Test psij 2150 IA 3 2500 - 2491 2486 PTD 1 so136o T e Test SPT BBL Pumped: 5 8 Returned: 5.3 OA -11_ 8 6 - 7 7 BBL Interval 1 4YRTST P/F P Notes: cUtuc W QLD SS r CT G j-itL", et4,�kw.„21-Wei10- dela J "�. iktAi reSrv"— r- C i G(ht L3 eavrided _til zol, BP)e4 SCANNED :. Wednesday,February 21,2018 Page 1 of 1 • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, February 9, 2018 7:31 AM To: AK, GWO Well Integrity Engineer;Wallace, Chris D (DOA);AK, OPS EOC Specialists;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL;AK, OPS FS2 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; G GPB FS2 Drillsites; Nottingham, Derek; Ohms, Danielle H Cc: Regg,James B (DOA);AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau;O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua; Worthington,Aras J;AK, GWO Well Integrity Well Information Subject: OPERABLE: Injector 16-01 (PTD#1801360) Ready to be brought online for AOGCC MIT- IA All, Injector 16-01 (PTD#1801360)was made not operable on 01/31/2018 for missing its 4 year AOGCC witnessed MIT- IA. The well is now ready to be brought back online and is reclassified as Operable. An AOGCC witnessed MIT-IA will be conducted once the well is on stable injection. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 ' � � ,o From: , WO Well Integrity Engineer Sent: Wednes•• •nuary 31, 2018 10:34 AM To: 'chris.wallace@alas-•.,•v'; AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK,OPS FS2 Field OTL; AK, OPS FS2 0 ' , RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; G GPB FS2 Drillsites; -•ingham, Derek; Ohms, Danielle H Cc: 'Regg, James B (DOA) (jim.regg@alaska.go' AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT We - -•rity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Da Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; 0 •• or, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel,Joshua; Worthington, Aras J Subject: NOT OPERABLE: Injector 16-01 (PTD #1801360)AOGCC MIT-IA wil =, e 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,January 31, 2018 10:34 AM To: Wallace, Chris D (DOA);AK, OPS EOC Specialists;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL;AK, OPS FS2 OSM;AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr;AKOp5ProdEOCTL;G GPB FS2 Drillsites; Nottingham, Derek; Ohms, Danielle H Cc: Regg,James B (DOA);AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine;'Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J Subject: NOT OPERABLE: Injector 16-01 (PTD#1801360)AOGCC MIT-IA will lapse All, Injector 16-01 (PTD#1801360) is due for its 4-year AOGCC witnessed MIT-IA by the end of January 2018.The well was shut in on 01/17/18 for Coil Tubing Drilling Activity on 16-21.The well is now classified as NOT OPERABLE until the rig has completed their drilling operation and the well can be brought online. Plan Forward: 1. Well Integrity Engineer: Return to OPERABLE status when ready to POI. 2. Operations: Put on injection 3. DHD: Perform AOGCC MIT-IA when thermally stable. Please respond if in conflict. Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 1 • MEMORANDUM To~ Jim Regg P.I. Supervisor ~J • ~~~ FROM: Lou Grimaldi Petroleum Inspector 4~~1,~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, April O1, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 16-01 PRUDHOE BAY UNIT 16-O1 Src: Inspector NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 16-01 API Well Number: 50-029-20533-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG1oo22111074o Permit Number: 180-136-0 Inspection Date: 2/21/2010 ~F Rel Insp Num: MITOP000002936 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 16-01 , Type Inj. N TVD 8454 IA 1600 1900 1875 P.T.D 1801360/ TypeTeSt SPT Test pSl ' 211.4 QA 0 0 0 Interval Post Workover Test ~ per, Pass Tubing , soo 4100 3450 Notes: post workover test performed on rig (Doy 16). 2nd test of tubing performed after successful IA test. Lack of IA pressure increase suggests leakage is not in tubing to IA area iw~i~- "~ Thursday, April O1, 2010 Page 1 of 1 • MEMORANDUM To: Jim Regg ~~ ~t-I ~ ~ i ~, P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, Apri101, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC I6-O1 PRUDHOE BAY UNIT 16-01 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv - Comm Well Name: PRUDHOE BAY UNIT 16-01 Insp Num: mitLG100314083848 Rel Insp Num: API Well Number: 50-029-20533-00-00 Permit Number: 180-136-0 Inspector Name: Lou Grimaldi Inspection Date: 3/14/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 16-01 Type Inj. w TVD 8454 ~ IA lsoo zslo ~ zsoo zsoo P.T.D 1801360 TypeTest SPT Test psi 2114 r QA 5 5 5 5 Interval wRxovR p~ P ~ Tubing lzoo lzoo 1200 lzoo Notes: 2.6 bbl's pumped, 2.5 bbl's returned. Good post RWO MIT. ,lV~i"~" ~ ~~VT-s~~ Thursday, Apri101, 2010 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, April O1, 2010 To~ Jim Regg ~j/` ~ +n SUBJECT: Mechanical Integrity Tests P.I. Supervisor 7 I BP EXPLORATION (ALASKA) INC ((( 16-O1 FROM: Lou Grimaldi PRUDHOE BAY UNIT 16-O1 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 16-01 API Well Number: 50-029-20533-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG100221103430 Permit Number: 180-136-0 Inspection Date: 2/21/2010 Rel Insp Num: Mrropooooo293s Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 16-O1 ~ Type Inj. N ~ TVD 8454 ~ IA 300 4100 4050 4025 P.T.D 1so136o TypeTest SPT Test psi zlla - pA o 0 0 0 0 0 Interval Post workover Test p~ Pags ~ Tubing llzs lsoo lsoo llzs Notes: preinjection MIT on Rig. Trouble with initi al attempt of tubing test. Test IA with better resul ts, bleed IA to 1500 and retested tubing. See subsequent test. F~~,;`~,..~;; ~..y apt{ '~ ~ ICJ Thursday, April O1, 2010 Page 1 of 1 AOGCC MITIA Forms for P1-12 (1910130}, P2-O1 (1970730) MPC-28A (2051630), MP... Page 1 of 1 • Maunder, Thomas E (DOA) From: WSU, ADW We11 Integrity Engineer [NSUADVVWelilntegrityEngneer~BP.earn] Sent: V1Ardnesday, March 31, 2010 8:35 PRA To: NSU, ADW Well Integrrrt~r Eru,Jineer; Regg, Jaynes B (DOA); Breaks, Phoebe L (DflA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Cc: MPU, OMS Facility Coordinator; MPU, OMS Field Coordinator Subject: AOGCC RA1T1A Forms for P1-12 (1910130), P2-01 (1970730) MPC-28A (2051630), MPF-82A (2091350), MPH-95 (2051590), 04-40 (191'1340), 13-31A(2051600), 16-01(1801360), AGI- 01A(2091640), L-213(2060530], M-29(2000990), P-14(1910070), V-212(2051500), W 217 (2091170) Attachments: March 2010 M1T Farms.zip Jim, Tom, and Phoebe, Please find the attached AOGCC MITIA forms far the following wells: 04-40 (PTD #1919340) 13-31A (PTD #2051600 -~ 15-01 (PTD #1801360 AGI-01A (PTD x'2091640) L-213 (PTD #2060530) M-29 (PTD #2000990) MPC-28A {PTD #2051530) RAPT-82A {PTD #2091350) MPH-15 PTD #2051590) P-14 (PTD x1910070} P1-12 (PTD #1910130] P2-01 {PTD #1970730] d-292 (PTD x2051500) 1N-217 (PTD #20919 70) «March 2010 GAIT Farms.zip» Thank you, Torn Rvschinger (alt. Anna Dube) Weil Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570=9630 Pager (907) 659-5100 Ext. 1154 ~~ ~~-~ 4/29/2410 f. J Email to:jim.regg~alaska.gov; phcebe.brooks~alaska.gov; tom.maunder~alaska.gov; doa.aogcc.prudhoe.bay~alaska.gov OPERATOR: BP F~cploration (Alaska), Inc_ MELD / UNIT i PAD: Prudhoe Bay / GPB / DS 16 DATE: 03/14/10 OPERATOR REP: Anna Dube AOGCC REP: Lou Grimaldi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIO(1~ Mechanical Integrity fies?. • Packer D Pretest Initial 15 Min. 30 Min. Well 16-01 T In'. W TVD 8,454 Tubi 1,200 1,200 1,200 1,200 Interval O P.T.D. 1801360 T test P Test 2113.5 Cali 1,400 2,510 2,500 2,500 P/F P Notes: MIT-IA to 2500 psi post RWO OA 5 5 5 5 Well T Iri . TVD Tut>i Interval P.T.D. T test Test P/F Notes: OA Well T In'. TVD Tubi Interval P.T.D. T test Test Cali P/F Notes: OA Well T Iri . TVD Tubi Interval P.T.D. T test Test Casi P/F Notes: OA Well T In'. TVD TutH Interval P.T.D. T test Test i Casi PIF Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Intemal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes} MIT Report Form BFL 11/27!07 MIT PBU 16-01 03-14-10.x1s 16-O1 (PTD #1801360) MITIA During Rig Workover Ntaunder, Thomas E (DUA) Page 1 of 1 From: NSU., ADW WeN Integrity Engineer (NSUADWWellntegrityEngineer~BP.cflm) Sent: Sunday, February 21, 2010 8:15 PM To: Regg, James B (DOA}; Maunder, Thomas E (DOAj; Snooks., Phoebe L (C}OA); DOA AOGCC Prudhoe Bay Cc: NSU, ADW brig Rig 16; NSU, ADW 1IVel1 Integrity Engineer Subject: 16-01 (PTD #1801360) MITIA During Rig Workover At#achrrten~: MIT P8U 16-01 RWO MITIA 02-21-10.x1s Jim, Torn, Phoebe., and Lou, Please find the attached MITIA form for Well 16-01 {PTD #1801360) for the MITIA conducted during the rig Workover. «MIT PBU 16-01 RWO MITIA 02-21-10.x1s» Please let me knout if you have any questions. Thank you, ,m`~itlttL ~ jaft Torin R ingerj Well integrity Coordinator GPB Wetly Group Pktone: (t~17} 659-5TE1Z Pager: (9t17j 65g-5'IE~ x~'f54 6 ~o ~~~ ~~ 4129/2010 Email to:jim.regg~alaska.gov; phcebe.brooks~a~lca.gov; tom.maunder~alaska.gov; doa.aogcc.prudhoe.bay~alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP F~cploration (Alaska), Inc. Prudhoe Bay /PBU / DS 16 21212414 Abbie Barker Lou Grimaldi Packer Pretest Initial 15 Min. 30 Min. Well 16-01 T In'. N TVD 8,455' Tubi 1,125 1,500 1,300 1,125 Interval T P.T.D. 1801360 T test P Test 2114 300 4,100 4,050 4,025 P!F P Notes: MITIA confirms packer and IA integrity. OA 0 0 0 0 Well 16-01 T In'. N TVD $455' Tubi 500 4,100 3,450 Interval T P.T.D. 1801360 T test P Test 2114 1,600 1,900 1,875 P/F P Notes: MIT-T confirms leak is not into the IA. OA 0 0 0 0 Well T In'. TVD Tubin Interval P.T.D. T test Test Gasi P!F Notes: OA Well T In'. TVD Tubi Interval P.T.D. T test Test Casi P/F Notes: OA Well T In'. TVD Tula Interval P.T.D. T test Test Cali P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A = Temperatrrre Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU 16-01 RWO MITIA 02-21-10.xts MEMORANDUM TO: Jim Regg ~ ~ ~ j~2~f'I / o P.I. Supervisor l FROM: Lou Grimal Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, March 16, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 16-O1 PRUDHOE BAY UNIT 16-01 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv '~/ Comm Well Name: PRUDHOE BAY UNIT 16-01 Insp Num: mitLG100314083848 Rel Insp Num: API Well Number: 50-029-20533-00-00 Permit Number: 180-136-0 Inspector Name: Lou Grimaldi Inspection Date: 3/14/2010 - Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 16-01 Type Inj. w TVD 86oz ~ IA lsoo zslo / zsoo zsoo ,. P.T.D tsols6o TypeTest SPT Test psi nso pA s s s s Interval wRKOVR ~ p~ P ,i Tubing lzoo lzoo lzoo 1200 NOtes: 2.6 bbl's pumped, 2.s bbl's returned. Good post RWO MIT. Tuesday, March 16, 2010 Page 1 of 1 STATE OF ALASKA ~~~~~~ ALAS IL AND GAS CONSERVATION COMMI N ~EPOR OF SUNDRY WELL OPERA~ONS MAR 3 2 2010 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspende~ ® Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: .Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 180-136 3. Address: ®Service ^ Stratigraphic API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20533-00-00 7. Property Designation: ~ 8. Well Name and Number: ADL 028332 & 028346 ~ PBU 16-01 9. Field /Pool(s): ~ Prudhoe Bay Field /prudhoe Bay Oil Pool 10. Present well condition summary ~ ~ ~ Total depth: measured . ~ ~ ZO t 0 0' feet 1 2 3 0 ~~ ppp ~~^ yyy ///~~~ true vertical ~ feet 1~ ~ Plugs (measured) 12806' Effective depth: measured 12806' feet Junk (measured) None true vertical 9132 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 2694' 13-3/8" 2694' 2659' 4930 2670 Intermediate 12460' 9-5/8" 12460' 8836' 6870 4760 Production Liner 818' 7" 12197' - 13015' 8619' - 9312' 8160 7020 Perforation Depth: Measured Depth: 12635' - 12725' True Vertical Depth: ggg5~ _ gp62~ Tubing (size, grade, measured and true vertical depth): 5-1/2", 17# x 4-1/2", 12.6# L-80 / N-80 12250' 8663' Packers and SSSV (type, measured and true vertical depth): ~ ~~ ~ ~~ ~~ 9-5/8' x 5-1/2 Baker'S-3' packer; 1199 8454' 9-5/8" x 5-1/2" Baker'SAB' packer 12175' 8602' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pulled tubing from 12124'. Cut and pull 9-5l8" casing from 2287'. Run 9-5/8" Tieback (47#, L-80) to 2290' and cement with 161 Bbls (Yield of 1.17). Run 5-1/2" (17#, L-80) tubing to 12141'. 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ^ Copies of Logs and Surveys run '~• Well Class after work: ^ Exploratory ^ Development ®Service ® Dail Re ort of Well O erations y p p ® Well Schematic Diagram '~• Well Status after work: ^ Oil ^ Gas ^ WDSPL ^ GSTOR ® WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A ff C.O. Exempt: Contact David Bjork, 564-5683 309-440 Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number Signature Phone 564-4628 Date ~ ~ Terrie Hubble, 564-4628 Form 10-404 Revised 07/200~CfDi.c MAR 2 2 2010 Subm'~ Ori/ginal Only GG?? 1I~~11aa77 sC~~a~i~ /' _ " ~ y•~ •/j1 ~ ~ :~ ~L-®"ffCi • • 16-01, Well History (Pre Rig Workover) Date Summary 1/3/2010 T/I/0=200/160/0+. Temp=S1. OART (eval high OAP). TBG FL C~3 surface. IA FL C~ surface. OA FL near surface. Pressured IA to 1640 psi, TP increased 1440 psi. OAP increased 30 psi. Monitor 1 hr, during monitor OAP increased 15 psi. Final WHPs=1640/1640/45. Job complete. 1/4/2010 T/I/O = 1570/1570/230. Temp = SI. OART day 1. WAG (water). TBG head adapter appears to be seeping fluid from 07:00 - 12:00 o'clock positions, wiped clean & marked w/ yellow paint marker (notified DSO). TP &IAP decreased 70 psi to 1570 psi. OAP increased 185 psi overnight. 1/5/2010 T/I/O = 1560/1560/320. Temp = SI. OART day 2 & moitor TBG head adapter. WAG (water). No fresh leaks on TBG head. TP &IAP decreased 10 psi to 1560 psi. OAP increased 90 psi to 320 psi overnight. 1/6/2010 T/I/O = 1560/1560/370. Temp = SI. OART day 3 & monitor TBG head adapter. WAG (water). No fresh leaks on TBG head. TP &IAP unchanged. OAP increased 50 psi to 370 psi overnight. 1/7/2010 T/I/0=1580/1560/360. Temp=S1. OART (day 4). TP increased 20 psi, IAP unchanged ,OAP decreased 10 psi. 1/7/2010 T/I/O = 1560/1560/390. Temp = SI. OART day 4 & monitor TBG head adapter. WAG (water). No fresh leaks on TBG head. TP &IAP unchanged. OAP increased 20 psi to 390 psi overnight. 1/8/2010 T/I/0= 1540/1510/320. Temp= SI. OART (day 5). TP decreased 40 psi, IAP decreased 50 psi, OAP decreased 40 psi overnight. 1/10/2010 T/IA/OA= 1500/1580/300 Temp=Sl PPPOT-T (Fail) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU 2 HP BT 0 psi. Cycled LDS "Standard" (5) pins need to be drilled. Attempted to pressure up void with Kroil to leave in void to assist freeing up stuck pins, found that THA x tubing is leaking, void bleds to 0 psi. RD test equipment. PPPOT-IC RU 2 HP BT onto IC test void 0 psi, flushed void until clean returns achieved. Pressured to 3500 psi for 30 min test, 3450/ 15 minutes, 3450/ 30 minutes. Bled void to 0 psi. Cycle and torqued LDS "Standard" (1) pin left in out position, all others were in good working condition. RD test equipment. ALL Pins should be replaced on this head prior to RWO. PPPOT-OC RU 1 HP BT onto OC test void 50 psi bled to 0 psi. Pressured to 1500 psi, gas and hydraulic fluid leaking from ring gasket, bled void to 0 psi RD test equipment All LDS cycled out 2" ran in and torqued. 1/10/2010 T/IA/OA= 1500/1580/300 Temp=Sl PPPOT-T (Fail) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU 2 HP BT 0 psi. Cycled LDS "Standard" (5) pins need to be drilled. Attempted to pressure up void with Kroil to leave in void to assist freeing up stuck pins, found that THA x tubing is leaking, spool pressure bleeds to 0 psi. PPPOT-IC RU 2 HP BT onto IC 0 psi. Flushed void until clean returns achieved 1/11/2010 T/I/O = 1580/1540/320. Temp = SI. Bleed WHP's to 0 psi (LDS drill out prep/RWO). WAG (water). Fresh leaks on TBG head adapter from 09:00 to 01:00 o'clock positions, wiped clean. TBG FL C~ surface. IA & OA FL's near surface. Bled IAP from 1540 psi to 0 psi (initialy gas, swapped to fluid) in 45 min (TP tracked IAP to 90 psi). During IA bleed OAP decreased 70 psi to 250 psi. Bled TP from 90 psi to 0 psi (fluid) in 1.5 hours (TBG went on Vac). During TBG bleed IAP went on Vac & OAP decreased 20 psi to 220 psi. Bled OAP from 220 psi to 0 psi in 1 min. Monitor for 30 min. TP &IAP unchanged. OAP increased to 0+. FWHP's Vac/Vac/0+. Page 1 of 3 16-01, Well History (Pre Rig Workover) Date Summary 1/14/2010 T/I/0=0/0/40 Temp=S/I. CMIT-TxIA PASSED to 3000 psi. MIT-OA PASSED to 1000 psi. (RWO Screen) Pumped 14.7 bbls diesel into IA to reach test pressure. CMIT TxIA lost 20/30 psi in 1st 15 mins and 10/0 psi in 2nd 15 mins for total loss of 30/30 psi in the 30 minute test. RD off of IA and up to OA. Pumped 0.9 bbls crude into OA to reach test pressure. MIT OA lost 20 psi in the 1st 15 min and 10 psi in the 2nd 15 min for a total loss of 30 psi in the 30 min test. Bled OAP back to 0 psi. Final W HP's = 100/50/0 1/17/2010 T/I/0=100/20/40. Temp=Sl. Assist w/LDS DO (RWO/LDS drillout prep). IA & OA FL C~3 Surface. Maintain 0 psi, open bleed on IA & OA for Cameron. 1/17/2010 T/IA/OA= 100/0/0 Temp=warm PPPOT-T (PASS) LDS Drill-out PPPOT-T : Test conducted between primary, control lines and "W" seal RU 1 HP BT onto Alemite 50 psi bled to 0 psi, pressured to 5000 psi for 30 min test, 5000/ 15 min, 4950/ 30 min. Bled void to 0 psi, RD test equipment. This test will allow RIG to get BOP test. (1) LDS drilled on tubing spool top flange, (1) blanking pin is installed ~ 2:00 and made up tight on G/N (Secure) Casing spool : All LDS removed and replaced with new equipment. (1) LDS at 5:00 still needs to be taped but new equipment is installed left in the out position, G/N is made up tight (Secure) 1/18/2010 T/IA/OA= 80/0/0 Temp=Sl warm Well Head repair (LDS Drill). Prep LDS, RU drill. Drilled out (1) pin on tubing spool ~ 2:00 replaced with blank. RD equipment, on hold for change out. Tapped out LDS profile on IC flange C~ 5:00 installed new equipment. Job not complete. 1/19/2010 T/I/O=VACNAC/15, Temp=Sl. LDS drill out (pre rig). Stung into test void to verify 0 psi. Prep LDS, RU Wachs drill. Drilled out (1) pin on tubing spool, upper flange C~3 7:00 position, replaced with blank. Rig back drill, will continue in AM. Well is secured, 2 LDS left to drill on same flange. 1/20/2010 T/I/O = VacNac/15. Temp = SI. Assist w/ LDS DO (RWO). Bled OAP from 15 psi to 0 psi in 20 min (gas) for valve crew. SI and monitor for 30 min. No change in OAP. Job in Progress. FW HPs = VacNac/0. 1/20/2010 T/I/0= 0/0/0 Installed new 3-1/8" FMC 120 I/A & O/A valves on backside of well. Pressure tested good to 4000 PSI, pulled V/R plugs. Installed V/R plugs & removed I/A & O/A valves on frontside of well. 1/21/2010 T/I/0=0NAC/2, Temp=Sl. LDS drill out (pre rig). DHD maintained open bleed on TBG. 2 stuck LDS on TBG head. Stung into test void to verify 0 psi. RU Wachs drill. Drilled both LDS, and retrieved nose. Installed 1 LDS assembly in the 3:00 position, and 1 blank assembly in the 5:00 position. Unable to get passing PPPOT-T due to ring gasket leak. Stung into void between neck seals, PT to 5000 psi, test good for 30 min. Stung into void between primary seal, control lines, and "W" seal. PT to 5000 psi for 30 min, lost 250 psi/15 min, lost 100 psi/30 min. Rig should be able to get BOP test. PPPOT-IC PASSED 1-10- 2010. Job complete. 1/23/2010 T/I/0=0/0/0; Attempted to pressure up on tubing for BPV test. Downhole barrier in place and fluid to surface, tree was fluid packed. Pumped 5 gal. of diesel and with no rise in pressure. Shut in MV and tested tree, noted build up of 1000psi almost immediately. Re-opened MV and pressure dropped to 0 psi. Pumped 80 gal. of diesel and noted no rise in pressure. Removed lubricator from tree and noted tree was still fluid packed, indicating that fluid did not "drop out". Discontinued test. Result: FAIL 1/25/2010 T/I/0=10/10/0+. Temp=Sl. Pressure up on IA to 500 psi to assist valve shop (PR BPV). Pressured TP & IAP to 500 psi. Set 2-way check, PT PASSED to 750 psi (decreased 30 psi in 10 mins). Note: S-riser pressure increased & decreased freely w/Tree pressure (wing is not holding). Final T/I/0=500/500/0+. Job Complete. 1/25/2010 WELL SHUT IN PRIOR TO ARRIVAL. ASSIST CH2/DHD IN SETTING, PRESSURE TESTING AND PULLING BPV. DRIFT W/4.60" GAUGE RING TO DSSSV ~ 2100'SLM. PULLED 5 1/2" DSSSV FROM 2100' SLM / 2127' SLM. CURRENTLY RIH W/ 4.40" G-RING. Page 2 of 3 i 16-01, Well History (Pre Rig Workover) Date Summary 1/26/2010 PULLED "P" PRONG FROM 4 1/2" PXN PLUG C~3 12,216' SLM. MADE SEVERAL ATTEMPTS TO PULL 4 1/2" PXN PLUG BODY Q 12,221' SLM. RAN HYD BAILER TO 12,222' SLM AND RECOVERED INJ SCHMOO. RAN 1.75" S-BAILER TO 12222' SLM, EMPTY W/ METAL MARKS. CURRENTLY RIH W/ 4 1/2" GS. 1/27/2010 PULLED 4 1/2" PXN PLUG BODY FROM 12248' MD / 12221' SLM. DRIFTED OUT TAIL W/ 3.65" CENTRALIZER TO 12260' SLM, NO PROBLEMS. RDMO -DSO WALKED THRU AND TOOK POSSESION OF W ELL. T/I/O = 0/0/0 1/31/2010 T/I/0=230NAC/30. Temp=S1. T & IA FL. (Pre E-line). TBG FL Q 1308' (31 bbl). IA FL Unknown, unable to get IA FL due to IA on hard Vac. 1/31/2010 T/I/0= 200/0-/20 ,Temp = SI, Assist E-line (RWO prep) CMIT-TxIA PASSED to 1000 psi. Pumped 65 bbls diesel down the tubing and 26 bbls down IA to reach test pressure. TxIA had no loss in a 30 min. test. Bled 4 bbls back to Final WHP = 380/200/100. 1/31/2010 WELL SHUT IN UPON ARRIVAL. INITIAL T/I/O: 100/0/0 PSI. SET HALLIBURTON FASDRILL PLUG WITH MID-ELEMENT AT 12231'. LRS RAN CMIT TO TEST THE PLUG TO 1000 PSI. T/I/O: 1160/1000/160 PSI DURING TEST. DIESEL LEAK WHILE UNSTABBING AFTER PT. 2/1/2010 SWAB WOULD NOT HOLD PRESSURE, SO OBTAINED PERMISSION TO USE THE MASTER AND SSV. CUT TUBING WITH 4.15" POWERCUTTER AT 12124' IN TOP THIRD OF FIRST FULL JOINT ABOVE PKR. JOB COMPLETE. WELL LEFT SI. 2/4/2010 T/IA/OA= 0/0/0 Temp=cold Replace LDS blanks with LDS. RU 1 HP BT onto THA test void 1000 psi bled to 0 psi. Removed (4) blanks on top tubing spool flange, replaced with FMC "Standard" LDS. LDS are not engaged onto top ring ran in enough for packing to be into profile and G/N to be installed and tightened. RD equipment re installed Alemite cap. 2/5/2010 T/I/0= 0/0/0 Temp= SI Circ-Out TxIA (PRE RWO). Pumped 6 bbls 60/40 meth, 1187 bbls 1% KCL down Tbg up IA taking returns to tiger tanks. Currently pumping down Tbg with 1 %KCL. 2/6/2010 Circ-Out TxIA, CMIT-TxIA PASSED to 1000 psi (Pre RWO). Pumped 298 (1486 total) bbls 1%KCL down g up taking returns to tiger tanks. Freeze protected TxIA with 140 bbls diesel, U-tubed TxIA for 1 hr. Freeze protected hard line with 10 bbls diesel. CMIT-TxIA: Pressured up TxIA with 3.1 bbls diesel. TxIA lost 0/20 psi in 1st 15 mins and 0/0 psi in 2nd 15 mins for a total loss of 0/20 psi in 30 min test. Bled pressure back, bled aprox 4.5 bbls diesel. Final WHPs 0/0/0 2/6/2010 T/I/0= 0/0/0 Set 5" FMC ISA #537 C«3 90", used 1-2' ext... Pre Doyon 16 pull over well. Page 3 of 3 • • BP EXPLORATION Page 1 of 22 Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date ~ Frorn - To ~ Hours Task Code NPT Phase I, Description of Operations 2/8/2010 06:00 - 19:00 13.00 MOB P PRE -RELEASE EXTERNAL POWER GENERATION MODULE AND MUD PUMP #2 MODULE. -SET TOPDRIVE ON TRAVEL STUMP IN ROTARY TABLE. -PREPARE RIG FLOOR FOR MOVE. -0700-Hrs--CALL AOGCC TO GIVE 24-Hrs NOTIFICATION OF IMPENDING INITIAL BOPE TEST FOR DOYON 16'S RWO ON 16-01 i. -0800-Hrs--WAIT ON 16-01 i PAD PREPARATION. -PERFORM RIG MAINTENANCE AND WORK ORDERS WHILE WAITING ON PAD PREPARATION. -1300-Hrs--JEFF JONES, AOGCC INSPECTOR, CALLED TO WAIVE STATE'S RIGHT TO WITNESS INITIAL BOPE TEST FOR DOYON 16 ON DS 16-01 i. -1430-Hrs--WSL MEET WITH DS 16 PAD OPERATOR TO DISCUSS POST-PAD RWO INSPECTION FOR 16-08a AND PRE-PAD INSPECTION FOR 16-01i. PAD OPERATOR GAVE GO-AHEAD TO MOVE RIG OFF 16-08A WITHOUT HIS PRESENCE. -1500-Hrs--PJSM FOR RIG MOVE WITH RIG CREW, TOOLPUSHER, AND WSL TO ENSURE SPECIAL EMPHASIS ON COLD WEATHER PROTECTION, LEAK PREVENTION AND DETECTION, AND STOPPING THE JOB IF SOMETHING DOESN'T LOOK OF FEEL RIGHT. -1600-Hrs--MOVE OFF WELL PAD. PEAK BEGIN MOVING MODULES NEAR TO 16-01 i. -1830-Hrs-- PJSM, SHIM RIG AND BURM AROUND RIG. 19:00 - 21:00 2.00 RIGU P PRE RU CIRCULATING MANIFOLD IN CELLAR, RU DOUBLEANNULUS VALVE, SPOT PUMP COMPLEX. -RU OA VALVES TO SLOP TANK. -IA PRESSURE = 0-PSI, OA PRESSURE = 0-PSI **********ACCEPT RIG AT 2100-Hrs ON 2/8/10********* 21:00 - 22:00 1.00 RIGU P PRE SPOT MOTOR COMPLEX. -DUE TO THE LACK OF SPACE ON THE OFF DRILLER SIDE OF THE RIG, UNABLE TO RU THE ARCTIC GRADE DIESEL TANK FOR THE BOILER. TOOL PUSHER IS ADDRESSING THE ISSUE OF A LONGER HOSE THAT WILL REACH THE TANK IN ANOTHER POSITION AROUND THE RIG.. -SPOT VAC TRUCKS AND FILL PITS. 22:00 - 00:00 2.00 WHSUR P DECOMP RU DSM. FILL TREE WITH DIESEL TO PRESSURE TEST. WHILE FILLING TREE HAD LEAK FROM NEEDLE VALVE (SEE REMARKS). -PRESSURE TEST TREE TO 500-PSI -PULL BPV. -TUBING PRESSURE = 0-PSI. -LD DSM, RU CIRCULATING LINES TO TOP OF TREE. 2/9/2010 00:00 - 05:00 5.00 WHSUR P DECOMP PJSM FOR CIRCULATING OUT FREEZE PROTECT WITH RIG CREW, CH2MHILL, TOOL PUSHER, WSL. -PRESSURE TEST RIG LINES TO 3500-PSI. -0100-Hrs-- WAIT ON WELL SUPPORT TO RU FLOW BACK TANK AND HARDLINE. -0145-Hrs-- PRESSURE TEST HARDLINE TO FLOWBACK TANK TO 2500-PSI. -0200-Hrs-- REVERSE CIRCULATE OUT 50-BBLS OF Printetl: 3/23/2010 10:4ti:1 t3 AM • ', BP EXPLORATION.... Page 2 of 22 I,, ~, Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 .Date From - To Hours Task Code: NPT 2/9/2010 00:00 - 05:00 5.00 WHSUR P 05:00 - 10:00 5.00 WHSUR P 10:00 - 10:30 0.50 WHSUR P Spud Date: 12/5/1980 Start: 2/2/2010 End: 2/10/2010 Rig Release: 2/22/2010 Rig Number: 16 Phase Description of Operations DECOMP DIESEL OUT THE TUBING AND CONTINUE TO PUMP I URN. CIRCULATE AT 6-BPM WITH 900-PSI PUMP PRESSURE. -0212-Hrs-- CIRCULATE THROUGH TUBING. CIRCULATE OUT 92-BBL DIESEL AND CONTINUE TO PUMP UNTIL RETURNS WERE CLEAN WITH FRESH SEAWATER. CIRCULATE AT 6-BPM WITH 720-PSI PUMP PRESSURE. -ALL DIESEL FROM FREEZE PROTECT TRANSFERRED TO THE FLOWBACK TANK TO USE FOR ARTIC PACK CLEANOUT OF 9-5/8 X 13-3/8 ANNULUS. -0440-Hrs --MONITOR WELL. NO FLOW DECOMP FMC DRY ROD IN BPV. --0615-Hrs--FMC CAN'T GET BPV PAST MASTER VALVE. CALL DSM TO RETURN TO THE RIG TO TROUBLESHOOT THE PROBLEM. --0800-Hrs--DSM DAY SHIFT ARRIVES ONSITE. RIH WITH DRIFT FOR THE ISA. STOP TO FUNCTION SURFACE SAFETY VALVE TO ALLOW LARGER PASSAGE. WORK DOWN THROUGH WITH ISA BPV. SEE A LTTLE DIFFICULTY GETTING AROUND THE MASTER VALVE, BUT BPV IS SET PROPERLY AND AT THE SAME DEPTH AS THE ORIGINAL BPV WAS LEFT PRIOR TO R/U OF DOYON 16. --0945-Hrs--TEST BPV TO 1000-psi FROM BELOW, RECORDED FOR 10-MINUTES ON CHART FOR SOLID TEST. DECOMP PJSM FOR N/D TREE. SPECIFICALLY DISCUSS THE SOURCE OF DROPPED OBJECTS AS WELL AS COMMUNICATION BETWEEN RIG FLOOR AND CELLAR SINCE THE TOP DRIVE WILL BE UTILIZED TO LIFT THE TREE WHEN IT HAS BEEN UNBOLTED. THE WEIGHT OF THE TREE IS 6-7000-LBS, THE LIFT RATING OF THE WEAKEST LINK IS 12-TONS FOR THE SHACKLES, BUT THE DRILLER SAID THAT HE WOULD NOT PULL OVER 12,000-LBS, AND THAT HE WOULD STOP TO RE-ASSESS THE SITUATION IF THIS WASN'T SUFFICIENT TO REMOVE THE TREE. 10:30 - 14:30 4.00 WHSUR P DECOMP N/D TREE. THE STUDS ON THE BOTTOM FLANGE OF THE TREE WERE RUSTED IN PLACE AND TOOK 10,000-LBS TO PULL THE TREE FREE FROM THE ADAPTOR SPOOL. --1330-Hrs--HOLD PJSM WITH FLOORHANDS, DERRICKMAN, TOOLPUSHER, FORKLIFT OPERATOR, AND WSL TO DISCUSS TAILING OUT THE TREE WITH THE FORKLIFT WHILE DRILLER CONTROLS THE TREE FROM THE RIG FLOOR USING THE TOPDRIVE. 1400-Hrs--R/U TO PULL THE ADAPTOR FLANGE AND FIND THE SAME RUST PROBLEM WITH THE STUDS ON THE BOTTOM OF THE ADAPTOR FLANGE. SLOWLY WORKED THE FLANGE WITH TUGGER LINE, AND IT CAME FREE WITHOUT INCIDENT. 14:30 - 18:00 3.50 BOPSU P DECOMP PJSM -INSTALL RISER, MOUSE HOLE, AND TURN BUCKLES. Printed: 3/23/2010 10:46:18 AM BP EXPLORATION Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours ~ Task Code NPT 2/9/2010 14:30 - 18:00 3.50 BOPSU P 18:00 - 23:30 5.50 BOPSU P 23:30 - 00:00 0.50 BOPSU P 2/10/2010 00:00 - 02:00 2.00 CLEAN P 02:00 - 03:00 1.00 CLEAN P 03:00 - 04:00 1.00 CLEAN P 04:00 - 07:00 3.00 CLEAN P 07:00 - 11:00 4.00 CLEAN P Page 3 of 22 Spud Date: 12/5/1980 Start: 2/2/2010 End: 2/10/2010 Rig Release: 2/22/2010 Rig Number: 16 Phase Description ofi Operations DECOMP -INSTALL PLYWOOD OVER CELLAR FOR A SOLID WORKING SURFACE -RKB OF 11.62' TO ANN., 15.41' TO BLINDS, 17.06' TO MUD CROSS, 19.26' TO PIPE RAMS, 21.72' TO UPPER LOCK DOWNS AND 23.81' TO LOWER LOCK DOWNS, 25.25' TO GROUND LEVEL. -FUNCTION BOP COMPONENTS. DECOMP HOLD PJSM WITH TOOLPUSHER, RIG CREW, AND WSL TO PERFORM BOP TESTS. TEST BOPE TO 250-PSI LOW, 4,000-PSI HIGH, USING 4" AND 5-1/2" TEST JOINTS. USE 4" ONLY FOR THE HYDRIL. HOLD AND CHART ALL TESTS FOR 5 MIN. AOGCC REP. JEFF JONES WAIVED WITNESS @ 1300-HRS ON 2/8/10. BP WSL JOHN WILLOUGHBY, DDI TOOLPUSHER GLENN HERMANN WITNESS TESTS. ALL TESTS HELD. DECOMP RIG DOWN TEST EQUIPMENT. -BLOW DOWN CHOKE AND KILL LINES. DECOMP PJSM, DRAIN STACK. -PICK UP DUTCH RISER AND TEST TO 500 PSI -GOOD TEST. -PULL BLANKING PLUG AND BPV. DECOMP PJSM. P/U AND M/U SPEAR BHA. -MAKE UP 5-1/2" SPEAR ASSY BHA: BULLNOSE, 5-1/2" SPEAR PACKOFF ASSEMBLY, BAKER/ ITCO SPEAR WITH 2-ea 4.805" GRAPPLES. DECOMP RIH WITH SPEAR -SPEAR WAS STACKING OUT HIGH, SO PICK UP SPEAR ASSY AND SEE THAT PACKOFF WAS DAMAGED. SUCK OUT STACK AND SEE A PIECE OF JUNK IN TOP OF -- HANGER. -RIH WITH T-BAR AND PUSH JUNK DOWN 1'. THEN P/U ROPE SPEAR AND GRAB JUNK. DRAG JUNK OUT OF TUBING AND THE JUNK FELL ON TOP OF TUBING HANGER TO THE SIDE OF THE HANGER THREAD PROFILE. TUBING WAS CLEAR. DECOMP RIH WITH SPEAR AND SET GRAPPLES. -BACK OUT LOCK DOWN SCREWS. SNAPPED ONE LOCK DOWN SCREW, BUT WORKED IT WITH A PIPE WRENCH. CONTINUE BOLDS. --0500-Hrs--START TO P/U ON SPEAR AND PULLS FREE WITH 240K-Ibs, CONTINUE POOH AND SEE DRAG OF 285K-Ibs. START RIG PUMP TO CLEAR IA AND ADD FORCE FROM BELOW. PULL HANGER INTO STACK AND S/D RIG PUMP. SEE DRAG FROM 275K AND DROPPING TO 245K AS PULLING HANGER TO FLOOR. --PULL HANGER ABOVE RIG FLOOR AND UD SPEAR ASSY. DECOMP CIRCULATE BOTTOMS UP, 7-BPM AT 500-psi. CLEAN SEAWATER RETURNS ACROSS THE SHAKERS WITH NO APPARENT DEBRIS. --0830-Hrs--MIX TWO DRUMS OF MI SAFE-TUBE IN PILL Printed: 3/23/2010 10:46:18 AM • • BP EXPLORATION Operations Summary Report -Page 4 of 22 Legal Well Name: 16-01 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date From. - To Hours Task... Code. NPT Phase Description of Operations 2/10/2010 07:00 - 11:00 4.00 CLEAN P DECOMP PIT AND PUMP INTO ACTIVE PIT. --0900-Hrs--PUMP SAFELUBE PILL AROUND, 10-BPM AT 1110-psi. 11:00 - 00:00 13.00 CLEAN P DECOMP PJSM TO POH AND UD 5-1/2" TUBING. --1115-Hrs--START POH WITH 5-1/2" TUBING, USING VARCO MYC 125-TON ELEVATORS. STRING PULLING AT 235K-Ibs TO 240K-Ibs, INCLUSIVE OF TOPDRIVE. --1145-Hrs--STOP TO PERFORM THA DUE TO LONG JOINT (44') BLOCKING THE SKATE CARRIAGE LIMIT SWITCH. THE TUGGER HAS TO BE USED AS A SAFETY LINE TO LAY DOWN EXCESSIVELY LONG JOINTS (IN EXCESS OF 43') IN ORDER FOR THE CARRIAGE TO BE RETRACTED. JOINTS APPEAR TO BE AVERAGING OVER 42'. --1240-Hrs--JOINT #14 IS ANOTHER EXCESSIVELY LONG JOINT. STOP AND USE TUGGER TO ASSIST. --1345-Hrs--JOINT #30 UD THROUGH THE PIPE SHED. --1415-Hrs--JOINT #45 IS OVER 45' LONG, REQUIRING IT TO BE REMOVED DIAGONALLY FROM THE PIPE SHED. --1445-Hrs--5-1/2" OTIS RQM SSSV. RECOVERED 25 SS-BANDS, BUT SCHLUMBERGER SPOOLER OPERATOR ESTIMATES THAT THERE MAY BE 2-3 ADDITIONAL SS-BANDS BASED ON THE SPACING OF THE RECOVERED BANDS. --1500-Hrs--PJSM TO REMOVE SPOOLER FROM RIG FLOOR AND ONTO BEAVALATOR. --1730-Hrs--UD JT #100. --2145-Hrs--UD JT #210. --2315-Hrs--UD JT #255. --0000-Hrs--UD JT #260. 4 GLMs, 1 SSSV AND 25 SS BANDS. 2/11/2010 00:00 - 01:30 1.50 CLEAN P DECOMP CONTINUE TO POH AND UD 5-1/2" TUBING. -FINISH POH WITH ALL 5-1/2" TUBING. -RECOVERED 289 JOINTS, 12 GLMs, 1 SSSV ASSEMBLY. -CUT JOINT RECOVERED IS 13.82' LONG, FLARED TO 6-5/16". CUT WAS A BIT RAGGED, BUT CUT CLEAN THROUGH. 01:30 - 03:00 1.50 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR. -UD TUBING EQUIPMENT. -INSPECT TOP DRIVE AND SKATE. -GATHER UP 9-5/8 SCRAPER BHA EQUIPMENT. -SET 8-3/4" ID WEAR RING. 03:00 - 04:30 1.50 CLEAN P DECOMP PJSM AND MAKE UP BHA -M/U 9-5/8" CSG SCRAPER BHA CONSISTING OF: 8-1/2" USED BIT, 9-5/8" CSG SCRAPER, BIT SUB, XOs, AND 6 EA DRILL COLLARS. 04:30 - 05:30 1.00 CLEAN P DECOMP A ROUSTABOUT USING TUGGER AND MOVED THE LEVER THE WRONG WAY, BREAKING THE HOLD BACK STRAP. THE RIG WAS SHUT DOWN TO DISCUSS THE INCIDENT WITH TOOLPUSHER, WSL AND RIG CREW. 05:30 - 08:30 3.00 CLEAN P DECOMP RIH P/U DRILL PIPE OUT OF PIPE SHED. --0610-Hrs--RIH JOINT #30 OUT OF PIPE SHED. --0635-Hrs--RIH JOINT #45. --0735-Hrs--RIH JOINT #75. Printed: 3/23/2010 10:46:18 AM s ~ BP EXPLORATION Page 5.of 22 Operations Summary-Report Legal Well Name: 16-01 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To .Hours Task Code NPT Phase Description of Operations 2/11/2010 108:30 - 09:30 I 1.001 CLEAN I P 09:30 - 10:00 I 0.501 CLEAN I P 10:00 - 10:30 0.50 CLEAN P 10:30 - 12:00 1.50 CLEAN P 12:00 - 13:30 1.50 CLEAN P 13:30 - 14:30 1.00 CLEAN P 14:30 - 15:00 0.50 CLEAN P 15:00 - 16:00 1.00 CLEAN P 16:00 - 18:30 ~ 2.501 CLEAN P 18:30 - 19:00 ~ 0.50 ~ CLEAN ~ P 19:00 - 20:00 I 1.001 CLEAN I P 20:00 - 21:30 I 1.501 CLEAN I P 21:30 - 22:30 I 1.00 I CLEAN I P 22:30 - 00:00 I 1.501 CLEAN P 2/12/2010 00:00 - 00:30 0.501 CLEAN P DECOMP GET PARAMETERS: PUMP #1--30-SPM, 20-psi; 40-SPM, 60-psi. PUMP #2--30-SPM, 40-psi; 40-SPM, 70-psi. P/U WT 95K-Ibs, S/O WT 95K-Ibs. CIRCULATE BOTTOMS UP, 10-BPM AT 950-psi. MONITOR WELL, WELL IS DEAD. DECOMP SAFETY S/D TO DISCUSS RECENT SAFETY INCIDENTS ON THE NORTH SLOPE AS WELL AS THE BROKEN HOLD BACK STRAP INCIDENT THIS MORNING. ATTENDEES: JIM WILLINGHAM-ADW RWO SUPERINTENDENT, TOOLPUSHER, RIG CREW, MI ENGINEER, AND WSL. DECOMP PJSM FOR SLIPPING AND CUTTING DRILLING LINE. DECOMP SLIP AND CUT DRILLING LINE. DECOMP PJSM -REVIEW PROCEDURE. -POH FROM 3000' TO 192' -STAND BACK DRILL COLLARS. -VD BHA, NO CHANGE IN BIT GRADE. DECOMP CLEAN AND CLEAR RIG FLOOR. -PJSM FOR RIGGING UP SCHLUMBERGER, DISCUSSING DROPPED OBJECTS WITH E-LINE CREW AND RIG CREWS. DECOMP R/U E-LINE EQUIPMENT. -FUNCTION TEST USIT LOG HEAD DECOMP SAFETY DISCUSSION WITH WSL, TOOL PUSHER AND CREWS, ABOUT STAYING FOCUSED AND IN THE MOMENT DURING ALL TASKS. DECOMP RIH TO 3,000' WITH E-LINE. -LOG UP AND FIND TOP OF CEMENT AT 2,314'. -REPEAT PASS ON SECTION TO CONFIRM TOC. -LOG OUT TO 34'. -DISCUSS WITH TOWN ENGINEER AFTER EMAILING IN THE PDS FILE AND AGREE THAT TOC IS 2,314' AND DETERMINED CUT POINT TO BE -2,285' AND ALLOWED TO ADJUST FOR PIPE TALLY. DECOMP REVIEW THA. -RIG DOWN E-LINE TOOLS. DECOMP PJSM AND M/U RBP BHA. -PICK UP 15' PUP TO MAKE UP RBP. DECOMP RIH WITH 4" DP OUT OF DERRICK. -RIH TO 2,400' AND SET RBP. -TOP OF RBP AT 2,391'. -CONFRIM SET OF RBP WITH 15K WEIGHT. -P/U 1 STAND AND RACK BACK. DECOMP R/U TEST EQUIPMENT TO TEST RBP. -PRESSURE UP TO 1000 PSI ON TOP OF RBP TAKING 9 STROKES OUT OF CALCUTATED 7 STROKES. -HOLD FOR 10 CHARTED MINUTES. ROCK SOLID TEST. -R/D TEST EQUIPMENT. DECOMP R/U PIPE HOPPER AND DUMP 20/40 SAND DOWN DP. -DUMP SAND AT ~2 MIN SACK. -DUMPED A TOTAL OF 44 SACKS BRINGING SAND UP A CALCULATED 50' ON TOP OF THE RBP. -TOP OF SAND AT 2,341'. DECOMP FINISH DUMPING THE LAST SACKS OF SAND. Printed: 3/23/2010 10:46:1 S AM • $P EXPLORATION Page 6 of 22 Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT 2/12/2010 00:30 - 01:30 1.00 CLEAN P 01:30 - 03:00 1.50 CLEAN P 03:00 - 03:30 0.50 CLEAN P 03:30 - 04:00 0.50 CLEAN P 04:00 - 07:30 3.50 CLEAN P 07:30 - 08:00 0.50 CLEAN P 08:00 - 09:00 1.00 CLEAN P 09:00 - 14:00 5.00 CLEAN P Spud Date: 12/5/1980 Start: 2/2/2010 End: 2/10/2010 Rig Release: 2/22/2010 Rig Number: 16 Phase Description of Operations DECOMP R/U TO CIRCULATE DOWN DRILL STRING. -PUMP DRILL STRING VOLUME OF SEAWATER AT 1 BPM. -0 PSI WHILE PUMPING AT 1 BPM. DECOMP PJSM -POH WITH RBP SETTING TOOL. -UD RBP SETTING TOOL. DECOMP CLEAR AND CLEAN RIG FLOOR. DECOMP PJSM -MAKE UP 9-5/8" CUTTER BHA: 8-1/4" M.S. CUTTER WITH 3-1/2" KNIVES, XO SUB, 8-1/2" STABILIZER, PUMP OUT SUB, XO SUB. DECOMP RIH WITH DRILL PIPE FROM DERRICK. -DIRTY VAC NUMBER 1 TAKE 30-BBLS OF DIESEL OUT OF FLOWBACK TANK FOR REDUCING ARCTIC PACK WHEN IT TIES UP TO EMPTY THE FLOWBACK TANK. -CONTINUE STRAPPING AND DRIFTING 9-5/8" HYDRIL 563 CASING IN PIPE SHED. -RIH AND TAG TOP OF SAND ~ 2339'. - ONFIRM CUT DEPTH WITH 9-5/8" TALLY OF 2287' -8' BELOW THE COLLAR. TOC IS AT -2314'. -SPOT LIL RED HOT OILER VAC TRUCKS. DECOMP PJSM WITH 5-CH2MHILL DRIVERS, 2 LIL RED DRIVERS, MI ENGINEER, BAKER FISHERMAN, RIG CREW, TOOLPUSHER, AND WSL. EVERYONE CONTRIBUTED. DECOMP PT LIL RED LINES TO 3000-psi. --GET PARAMETERS: #1 SLOW PUMP RATE 36-SPM (3-BPM) AT 165-psi; 90-SPM (7.6-BPM) AT 1000-psi. 85-RPM, 5K-ft-Ibs FREE TORQUE; ROTATING WEIGHT 75K-Ibs. --0815-Hrs--START ROTATING AND BRING UP TO 85-RPM, 5K-ft-Ibs. BRING PUMP UP: 25-SPM, 35-psi; 33-SPM, 135-psi; 40-SPM, 173-psi; 48-SPM, 280-psi; 60-SPM, 505-psi; --0820-Hrs--68-SPM, 620-psi. --0823-Hrs--PRESSURE DROPS TO 500-psi, TO INDICATE KNIVES PENETRATING 9-5/8". PRESSURE CONTINUES TO DROP TO 430-psi WHILE CONTINUING TO CUT WITH TORQUE KICKING TO 7-9K-ft-Ibs. FLOORHAND ON FLOWBACK TANK REPORTS THAT RETURNS ARE COMING TO FLOW BACK TANK. -0827-Hrs--TORQUE STALLED OUT. LET OFF TRAPPED TORQUE. P/U AND SEE 10K-20K OVERPULL, DROPPING BACK TO STRING WEIGHT OF 75K-Ibs (INCLUSIVE OF TOP DRIVE). 25K-LBS OVERPULL REQUIRED TO DISENGAGE KNIVES FROM CUT. P/U TO GET TOOL JOINT ABOVE RIG FLOOR TO BEGIN ARCTIC PACK CIRCULATION. --0830-Hrs--CLOSE HYDRIL AND IA VALVE FOR A CIRCULATION CHECK THROUGH THE 9-5/8" CUT; 2-BPM AT 425-psi. --0840-psi--CHECK LINES AND READY LIL RED TO PUMP 25-Bbls OF DIESEL DOWN DRILLPIPE. DECOMP --0900-Hrs--LIL RED PUMP 25-Bbls OF DIESEL, 2-BPM AT 550-psi WITH OA CLOSED AND IA OPEN, TAKING RETURNS TO THE CUTTINGS TANK. --0910-Hrs--CLOSE IA, HYDRIL REMAINS CLOSED, OPEN Printed: 3/23/2010 10:46:18 AM • • BP EXPLORATION Page 7 of 22' Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description ofi Operations 2/12/2010 09:00 - 14:00 5.00 CLEAN P DECOMP OA, TAKE RETURNS TO THE FLOW BACK TANK, LIL RED PUMP 25-Bbls DIESEL DOWN DRILLPIPE STARTING AT 2-BPM AT 1100-psi. PRESSURE DROPPED TO 800-psi WHEN A TOTAL 38-Bbls OF DIESEL IS PUMPED. FLOORHAND AT FLOWBACK TANK REPORTS HEAVY, BLACK FLUID IN THE RETURNS TO THE FLOWBACK TANK. --0930-Hrs--BRING ON RIG PUMP TO PUMP HOT 9.8-ppg BRINE FROM VAC TRUCK. CLOSE DOWN TO ~50% ON THE CHOKE AT THE FLOW BACK CIRCULATING MANIFOLD AND BRING PUMP UP TO 2-BPM AT 220-psi. PRESSURE DROPPED TO 40-psi BY THE TIME THE DRILLPIPE WAS CLEARED OF 25-Bbls OF DIESEL. --0945-Hrs--SHUT-IN AND LET DIESEL SOAK IN OA. --1045-Hrs--RESUME PUMPING HOT 9.8-ppg BRINE_TO_ SLOWLY DISPLACE THE DIESEL THROUGH THE OA AT 2-BPM AND 20-psi, TAKING RETURNS TO THE FLOWBACK TANK. FLOORHAND MONITORING FLOWBACK TANK SAYS "IT'S ARCTIC PACK". --1045-Hrs--PRESSURE INCREASED TO 65-PSI, AND FLOORHAND SAID THAT THE FLOW RATE INCREASED AT FLOWBACK TANK. --1100-Hrs--GETTING GRAY ARCTIC PACK AT THE FLOW BACK TANK. PUMP RATE 2-BPM, 80-psi. SEE NO "FREE" DIESEL IN THE RETURNS. --1140-Hrs--9.8-PPG BRINE AT THE FLOWBACK TANK. FULLY OPEN CHOKE AND OPEN THE CENTER VALVE IN THE FLOWBACK CIRCULATING MANIFOLD. INCREASE PUMP RATE TO 6-BPM AT 1830-psi. --1210-Hrs--PUMP 40-Bbls SAFE-SURF-O PILL DOWN DRILLPIPE AT 6-BPM AND 640-psi. AT 25-Bbls PUMPED, REDUCE RATE TO 2-BPM AND 480-psi AND CONTINUE TO CIRCULATE THE SAFE-SURF-O SWEEP THROUGH THE OA. --1230-Hrs--INCREASE PUMP RATE TO 6-BPM AT 1190-psi. --1300-Hrs--SEAWATER ALL THE WAY THROUGH THE OA. CLOSE THE OA, OPEN THE HYDRIL AND CIRCULATE -2-Bbls OF DIESEL OUT OF THE DRILLPIPE X 9-5/8" ANNULUS. 14:00 - 15:30 1.50 CLEAN P DECOMP PJSM WITH CREW TO POH AND S/B DP IN DERRICK. -POH AND S/B DP IN DERRICK. --1420-Hrs--MAKE CREW CHANGE. IT'S THE LONG DAY FOR THE NIGHT CREW IN ORDER TO FACILITATE THE DAY CREW HITCH CHANGEOUT. --CONTINUE POH AND S/B DP. --1500-Hrs--BREAK OUT AND UD CUTTER BHA. THE CUTTERS HAD WEAR MARKS ALL THE WAY UP TO THE SHOULDERS NEAR THE PERIPHERY OF THE BODY OF THE MULTI-CUTTER HOUSING, INDICATING THAT THE CLUTTERS. _ --1520-Hrs--PULL WEAR RING. Printed: aiz:uzuiu lU:4ti:1C AM • • BP EXPLORATION Page 8 of 22'' Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date .From.- To Hours Task Code NPT 2/12/2010 15:30 - 16:00 0.50 WHSUR P 16:00 - 20:30 4.50 BOPSU P 20:30 - 00:00 3.50 BOPSU P 2/13/2010 00:00 - 01:00 1.00 BOPSU P 01:00 - 01:30 0.50 BOPSU P 01:30 - 02:00 0.50 PULL P 02:00 - 04:00 2.00 PULL P Spud Date: 12/5/1980 Start: 2/2/2010 End: 2/10/2010 Rig Release: 2/22/2010 Rig Number: 16 Phase Description of Operations DECOMP PJSM TO PULL THE 9-5/8" CASING PACKOFF WITH THE TUBING SPOOL. DECOMP N/D BOP STACK AT THE TUBING FLANGE. -SET THE STACK BACK ON THE STUMP. -M/U PACK-OFF PULLER ON SINGLE JOINT AND PULL T .PLUS THE PORT-A-POWER, WHICH WAS USED TO ASSIST IN BREAKING THE SPOOL FREE. -BARRIERS ARE THE FAS-DRILL AT 12230' AND THE RBP ~AT 2391' DECOMP PULL OLD TUBING SPOOL FROM CELLAR. -BRING IN NEW TBG SPOOL. -CLEAN OFF CSG SPOOL FLANGE AND RING SEALING AREA. -PJSM AND N/U TUBING SPOOL AND ROPE STACK... DECOMP FINISH N/U BOPE. -RIG UP SHACKLES AND RISER. DECOMP PJSM PRESSURE TEST BOP STACK BREAK. -R/U TEST EQUIPMENT. -PRESSURE UP TO 500 PSI FOR 10 MIN. -GOOD TEST. DECOMP M/U 9-5/8" SPEAR BHA. -BULLNOSE, 9-5/8" SPEAR PACKOFF, ITCO TYPE SPEAR, SPEAR EXTENSION, STOP SUB, XO. DECOMP PJSM SPEAR 9-5/8" CSG. -RIH 23' AND ENGAGE SPEAR. -P/U 145k AND PULL 9-5/8" HANGER UP, BUMPING RISER AND MOVING THE RISER UP 3 INCHES. -RIH AND SET HANGER BACK DOWN AND RELEASE SPEAR, TO INSPECT RISER. -RESET RISER AND INFLATE AIR BOOTS. -RESET GRAPPLES ON SPEAR AND RIH 23'. -ENGAGE SPEAR. -P/U 145K AND PULL HANGER TO RIG FLOOR. 04:00 - 05:00 I 1.001 PULL I P 05:00 - 08:30 3.50 ~ PULL P DECOMP R/U CIRCULATING XO AND EQUIPMENT. -CIRCULATE 110 DEGREE SEAWATER AT 8 BPM AND 420 PSI, WHI E REGIPROGATING PIPE TO ASSIST IN CLEANING ARCTIC PAC.. CIRCULATED 300 BBLS BEFORE RETURNS BEGAN TO CLEAN UP. -LARGE AMOUNTS OF ARCTIC PAC IN RETURNS ON SHAKER. -R/U 9-5/8" CSG EQUIPMENT. DECOMP PJSM POH WITH 9-5/8" CSG FROM 2287', USING 9-5/8" VARCO SLX 150-TON SIDE DOOR ELEVATORS. --0720-Hrs--#20 POH AND L/D. AVERAGE BREAKOUT TORQUE IS 45K-ft-Ibs WITH SOME AS HIGH AS 50K-ft-Ibs. PIPE IS COMING OUT CLEAN, BUT PERIODICALLY SEE A THIN, TAN COLORED SHEEN WITH 1/4" TO 3/4" CONGEALED LUMPS OF ARCTIC PACK. --0810-Hrs--#25 POH. --0830-Hrs--#30 POH, BUT TONGS WOULD NOT RELEASE FROM THE JOINT. CALL DOYON CASING FOR TECHNICIAN. Printetl: 3/23/2010 10:46:18 AM • BP EXPLORATION. Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT 2/13/2010 108:30 - 10:30 2.00 PULL P 10:30 - 14:00 I 3.501 PULL I P 14:00 - 14:30 I 0.501 PULL I P 14:30 - 17:00 I 2.501 PULL I P 17:00 - 20:00 I 3.001 PULL I P 20:00 - 21:00 I 1.001 PULL I P Page 9 of 22 Spud Date: 12/5/1980 Start: 2/2/2010 End: 2/10/2010 Rig Release: 2/22/2010 Rig Number: 16 Phase Description of Operations DECOMP --DOYON TECHNICIANS TROUBLESHOOT PROBLEM AND GET THE TONGS TO RELEASE. POSSIBLE CAUSE MAY HAVE BEEN A TOO SHORT BITE WITH THE BACK-UP TONGS ON THE BOTTOM OF THE COLLAR. TECHNICIANS PERFORM A NORMAL MAINTENANCE SERVICE ON THE TONGS. --POH WITH NEXT JOINT AND TECHNICIAN RUNS THE TONGS TO GET THE CORRECT BITE, BUT THE TONGS LOCK ON AGAIN. RELEASE THE TONGS AND UD THE JOINT. INSPECT THE TONGS, BUT FIND NOTHING APPARENT. --P/U THE NEXT JOINT AND THE TONGS BREAK OUT AND RELEASE PROPERLY. --TECHNICIANS DEMONSTRATE PROPER METHOD TO ENGAGE AND OPERATE THE TONGS. DECOMP DRILLER PERFORMS THA WITH THE FLOORHANDS TO RESUME POH AND UD 9-5/8" CASING. --1045-Hrs--RESUME POH AND UD CASING. --1130-Hrs--PJSM WITH DAY CREW AND DOYON CASING TECHNICIAN TO DISCUSS THE CORRECT APPLICATION OF THE TONGS AS WELL AS BREAKING OUT AND LAYING DOWN THE CASING. --1245-Hrs--#45 POH. --1335-Hrs--#56 POH, FOLLOWED BY THE CUTOFF JOINT THAT IS 8.43' LONG AND FLARED TO 10" AT THE CUT. RECOVERED 14-CENTRALIZERS AND ALL BUT 3 FULL CENTRALIZER BLADES, BUT THEY ARE EACH LIKELY TO BE BROKEN IN TWO PIECES FOR A POSSIBLE 6 PIECES, EACH ABOUT 10" LONG. DECOMP CLEAR AND CLEAN RIG FLOOR AND PREPARE TO M/U 9-5/8" CASING STUB DRESS-OFF BHA... --SET TEST PLUG AND SUCK OUT STACK TO LOOK FOR BROKEN CENTRALIZER BOWS. FIND 3 HALF PIECES. PULL TEST PLUG. --SET 12-3/8" WEAR RING. DECOMP PJSM TO ASSEMBLE BHA. --M/U 9-5/8" DRESS-OFF BHA: 9-5/8" DRESS-OFF SHOE, WASHPIPE EXTENSION, BOOT BASKET, 9-5/8" DRESSING MILL WITH 8-1/2" STINGER, 13-3/8" CASING SCRAPER, 13-3/8" ULTRA CLEAN BRUSH, FLOAT SUB, OIL JARS, AND 6-EA, 6-1/4" DRILL COLLARS. DECOMP RIH 9-5/8" DRESS-OFF BHA ON DP FROM THE DERRICK. -RIH ABOVE 9-5/8" STUMP. ESTABLISH PARAMETERS OF 88k DOWN, 88k UP, 88k ROT WITH 3 K FREE TO. PUMP RATE 6 BPM WITH 200 PSI. -TAG TOP OF STUMP AT 2287' DECOMP DRESS OFF STUMP AT 2287' -P/U 40' OFF OF STUMP AND START ROTATING AT 60 RPM WITH 4K OF TO. PUMP RATE OF 4 BPM AND 100 PSI. WASH AND CLEAN DOWN TO STUMP. -SWALLOW 8' OF STUMP AND BEGIN DRESSING OFF STUMP WITH 5k WOB, MILLED 5" OFF STUMP. -RIH WITHOUT ROTATION 6 TIMES, SEEING TOP OF Printed: 3/23/2010 10:46:18 AM i • BP EXPLORATION Page 10 of 22 Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 2/13/2010 120:00 - 21:00 I 1.001 PULL I P 21:00 - 22:00 I 1.001 PULL I P 22:00 - 00:00 I 2.001 PULL I P 2/14/2010 100:00 - 01:30 I 1.501 CLEAN I P 01:30 - 02:30 1.00 CLEAN P 04:00 - 09:30 5.501 CASE P DECOMP STUMP, ROTATE 1/2 TURN EACH TIME AND SWALLOW 8'. EASILY GOING OVER STUMP. DECOMP PUMP 20 BBLS SAFE-SURF O SWEEP FOLLOWED BY 20 BBL HI-VIS SWEEP, FOLLOWED BY 20 BBLS SAFE-SURF O. -SCRAPE ECP SETTING DEPTH FROM 2221' DOWN TO 2287' SEVERAL TIMES. -CIRCULATED AT 8 BPM AND 310 PSI, WHILE ROTATING AND RECIPROCATING DRILL PIPE. -THE 1ST 20 BBL SAFE-SURF SWEEP SHOWED A MAJOR INCREASE IN ARCTIC PAC RETURNS. -THE 20 BBL HI-VIS SHOWED A SLIGHT AMOUNT OF ARCTIC PAC IN THE RETURNS. -THE 2ND 20 BBL SAFE SURF SWEEP SHOWED SLIGHT AMOUNT OF ARCTIC PAC IN THE RETURNS. DECOMP PJSM - POH FROM 2287'. -MONITOR WELL -STATIC. -POH RACKING BACK DRILL PIPE IN DERRICK. DECOMP PJSM -MONITOR WELL -STATIC. -UD 9-5/8" DRESS OFF BHA. -RACK DRILL COLLARS BACK. -GOOD DRESS OFF INDICATION ON MILL. -RECOVERED LESS THEN 1 GALLON OF METAL CUTTINGS. DECOMP CLEAR AND CLEAN RIG FLOOR OF ARCTIC PAC RESIDUE. DECOMP PJSM FOR RUNNING 9-5/8" 47#, L-80, HYD 563 CASING WITH WSL, TOOLPUSHER, HALIBURTON, BAKER REPS, AND RIG CREW. DISCUSSING HAZARDS OF DROP OBJECTS, STAY FOCUSED AND IN THE MOMENT. -BRING UP CENTALIZERS. -P/U CASING PATCH AND PACKER, BAKERLOK TO HES -P/U HES CEMENTER. -RIH 9-5/8" CASING. RUN ONE FREE-FLOATING CENTRALIZER PER JOINT; USING JET LUBE SEAL GUARD THREAD COMPOUND AND TORQUE TURNING ALL CONNECTIONS TO 15,200-Ib-ft OPTIMUM TORQUE. -JOINT #1 AT 0510-Hrs. --0645-Hrs--#20 RIH. 0715-Hrs--#30 RIH. 0745-Hrs--#40 RIH. 0820-Hrs--#50 RIH. --0825-Hrs--WSL OBSERVED HALLIBURTON TECH LOAD STAGE COLLAR CLOSING PLUG IN CEMENTING HEAD. --0830-Hrs--SCHLUMBERGER HOLDING PJSM OUTSIDE, THEN R/U THEIR EQUIPMENT FOR CEMENTING OPERATION. --0850-Hrs--#58 RIH. --0900-Hrs--P/U 4.87', 9-5/8" HYDRIL 563 PUP JOINT AND M/U TO STRING. --0905-Hrs--P/U #59, GET PARAMETERS: P/U WT 140K-Ibs, S/O WT 143K-Ibs. SLOWLY RIH AND 25' IN ON JOINT #59 BEGIN SLOW ROTATION TO THE RIGHT. SEE THE TOP OF Printed: 3/23/2010 10:46:18 AM BP EXPLORATION Page 11 of 22` Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 2/14/2010 04:00 - 09:30 5.50 CASE P DECOMP THE STUB AT 35' IN AND STOP AT 36' IN. SET MANUAL SLIPS. P/U AND M/U 9-5/8" BUTRESS BOX X 9-5/8" HYDRIL PIN XO PUP JOINT (2.87'). --0925-Hrs--P/U TO NEUTRAL WT OF 140-K-Ibs TO PULL SLIPS, CONTINUE TO SLOWLY RIH AND LET STUB TAKE 20K-Ibs. P/U TO 170K-Ibs TO CHECK FOR GRAPPLE SET. S/O TO PUT 20-K-Ibs ON STUB. P/U TO 250K-Ibs TO PULL TEST GRAPPLES. SET BACK DOWN TO 180K-Ibs, SET MANUAL SLIPS TO GET BALES OUT OF THE WAY FOR R/U THE CEMENTING HEAD. 09:30 - 10:30 1.00 CASE P DECOMP M/U HALLIBURTON CEMENTING HEAD TO XO PUP AND M/U ALL LINES TO THE HEAD. --0950-Hrs--P/U TO 240K-Ibs TO PULL MANUAL SLIPS AND TO PARK THE TOPDRIVE WITH 240K-Ibs ON THE WEIGHT INDICATOR AND 100K-Ibs OVERPULL ON THE 9-5/8" CASING PATCH. --1000-Hrs--HOLD PJSM TO INFLATE BAKER EXTERNAL CASING PACKER AND OPEN HALLIBURTON ES CEMENTER AND ALSO TO DISCUSS R/U TO SCHLUMBERGER LINE AND PRESSURE TEST ALL LINES. --1020-Hrs--PT LINES TO 4000-psi. 10:30 - 11:30 1.00 CASE P DECOMP --PRESSURE CASING TO 1000-psi FOR 10-mins, ~ RECORDED. INCREASE PRESSURE TO 1300-psi, LET STABILIZE. INCREASE PRESSURE TO 1450-psi, LET STABILIZE. INCREASE PRESSURE TO 2200-psi AND LET STABILIZE. SEE NO INDICATION OF ECP INFLATION. --BLEED OFF PRESSURE TO 0-psi. INCREASE PRFSSl1RF INDICATION OF ECP INFLATION. HOLD PRESSURE AT 2200-psi FOR 10-MINUTE, RECORDED CASING PRESSURE TEST. --BAKER COMPLETIONS TECH CALL BAKER SLOPE-BASED LEAD. WSL CALL ADW RWO ENGINEER. BAKER LEAD SAID THAT THE INFLATION INDICATION MAY NOT BE APPARENT. ADW ENGINEER AGREED TO GO AHEAD WITH THE INCREASE IN PRESSURE TO OPEN THE HALLIBURTON ES CEMENTER. --1115-Hrs--INCREASE PRESSURE TO OPEN ES CEMENTER. CEMENTER OPENS AT 2750-psi. 11:30 - 12:00 0.50 CASE P DECOMP CIRCULATE HOT SEAWATER AT 6-BPM, 250-psi TO HEAT UP THE WELLBORE. TEMPERATURE FROM PITS AT START -110-F DEGREES. --1155-Hrs--TEMPERATURE IN RETURNS 78F DEGREES. 12:00 - 12:30 0.50 CASE P DECOMP PJSM WITH RIG CREW, SCHLUMBERGER CREW, CH2MHILL DRIVERS AND PUSHER, HALLIBURTON TECHNICIAN, TOOLPUSHER, AND WSL. EVERYONE WAS ASKED TO CONTRIBUTE AND THE MOST REPEATED INPUTS WERE PRESSURED LINES, COMMUNICATION, PPE, AND COMMUNICATION. 12:30 - 14:30 2.00 CASE P DECOMP --SCHLUMBERGER LINE UP TO PUMP 5-Bbls OF FRESHWATER TO PT LINE TO 4500-psi. PUMP TRUCK POPOFF SET AT 4870-psi. GET RETURNS IMMEDIATELY. --1235-Hrs--CLOSE LINE TO CEMENTING HEAD TO LET Printed: 3/23/2010 10:46:1 S AM • BP EXPLORATION Page 12 of 22 Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 2/14/2010 112:30 - 14:30 I 2.001 CASE I P 14:30 - 15:00 I 0.501 WHSUB I P 15:00-18:30 I 3.501WHSUBIP 18:30 - 19:00 I 0.501 W HSUB I P 19:00 - 22:30 I 3.501 WHSUB I P DECOMP SCHLUMBERGER PRESSURE UP LINE TO 4500-psi. CHECK FOR LEAKS AT 700-psi, THEN EASE UP TO 4500-psi. --1240-Hrs--SCHLUMBERGER BATCH UP CEMENT AND PREPARE TO PUMP CEMENT. --1245-Hrs--START PUMPING 15.8-ppq, CLASS G WITH GASBLOK 1.17 ft3/ k YIELD• 5-BPM AT 2 5- si. --1320-Hrs--HALLIBURTON TECH DROPS CLOSING PLUG AND SCHLUMBERGER PUSHES IT OUT WITH 5-Bbls OF FRESHWATER. --1321-Hrs--SCHLUMBERGER TURN OVER TO RIG PUMP TO PUMP DISPLACEMENT WITH SEAWATER FROM PITS. SCHLUMBERGER BLOW DOWN LINE BACK TO THEIR PUMP TRUCK. --1322-Hrs--BRING RIG PUMP RATE UP TO 6-BPM AT 150-psi. CATCH UP TO FLUID AT 810-STROKES OR 69-Bbls. PRESSURE BEGINS TO INCREASE FROM 220-psi. 1000-STROKES, 380-psi. 1200-STROKES, 600-psi. AT 1300-STROKES, DIVERT RETURNS TO THE CUTTINGS TANK. --1350-Hrs, 1552-STROKES, 4.8-BPM, 980-psi, GET CEMENT RETURNS TO THE CUTTINGS TANK. --1355-Hrs--REDUCE PUMP RATE TO 2-BPM AT 850-psi WITH 1830-STROKES (155-Bbls) OF DISPLACEMENT PUMPED. --1358-Hrs--PLUG BUMPS AT 1866-STROKES. PRESSURE P AND E EME TER CLOSES AT 2000- si. --1400-Hrs--CEMENT IN PLACE AND FLOAT HOLDING. PUMPED 161-BBLS TOTAL --BREAK OFF CEMENT LINE FROM CEMENTING HEAD TO CHECK FOR FLOW UP CASING. NO FLOW. CUTTINGS TANK = (1866-STROKES - 1552-STROKES) / 11.8-SPB = 2_, 6.~Bbls.. DECOMP PJSM. SET MANUAL SLIPS. R/D HALLIBURTON's CEMENTING HEAD AND CROSSOVER. --SUCK OUT THE 9-5/8" CASING TO PREPARE FOR THE WACHS CASING CUTTING OPERATION. BREAK OFF XO PUP JOINT. --DEFLATE AIR BOOTS. DECOMP PJSM FOR N/D BOPE. -CENTER STRING AND SET EMERGENCY SLIPS WITH 100K-lBS TENSION IN 9-5/8" CSG. -CUT OFF REMAINDER OF 9-5/8" CSG WITH WACHS CUTTER. - 25.47' -L/D CUT 9-5/8" CSG. DECOMP M/U 9-5/8" PACK-OFF ON RUNNING TOOL. -LOWER PACK-OFF INTO PROFILE. -RILDS. -BRING DRILL PIPE INTO PIPE SHED TO STRAP AND TALLY. DECOMP PJSM - N/U BOPE. Printed: 3/23/2010 10:46:18 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 16-01 Page 13 of 22 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 2/14/2010 119:00 - 22:30 I 3.501 WHSUB I P 22:30 - 00:00 1.501 CLEAN P 2/15/2010 00:00 - 00:30 0.50 ~ CLEAN P 00:30 - 01:00 0.50 CLEAN ~ P 01:00 - 03:00 2.001 CLEAN P 03:00 - 09:30 I 6.501 CLEAN I P 09:30 - 10:30 ( 1.00 ~ CLEAN ~ P 10:30 - 13:00 I 2.501 CLEAN I P 13:00 - 13:30 0.50 CLEAN P 13:30 - 20:00 6.50 BOPSU P DECOMP -N/U BOPE STACK AND RISER. -INFLATE RISER BOOTS, R/U TURN BUCKLES. -TEST 9-5/8" PACK-OFF TO 3800 PSI FOR 30 MIN_ -GOOD TEST. -INSTALL SHORT BAILS WITH 4" ELEVATORS AND LINK TILT. -CLEAR AND CLEAN RIG FLOOR. DECOMP INSTALL WEAR RING WITH 8-15/16" ID. -PJSM FOR P/U BHA DECOMP PJSM - M/U DRILL OUT BHA -BHA CONSISTS OF: 8-1/2" BIT, BOOT BASKETS, BIT SUB,OIL JARS, PUMP OUT SUB, XOs, DRILL COLLARS. -RIH TO 219' DECOMP RIH WITH DP OUT OF DERRICK. -RIH 20 STANDS TO PARK ABOVE HES CEMENTER. -BREAK CIRCULATION. DECOMP CIRCULATE AT 4 BPM AND 105 PSI WITH 100 DEGREE SEAWATER WHILE WAITING ON 500 PSI COMPRESSIVE STRENGTH OF CEMENT. 13 HRS FOR 500 PSI COMPRESSIVE STRENGTH. DECOMP WASH DOWN FROM 2112' -PUMP AT 7 BPM AND 343 PSI. -85 UP WT, 85 DOWN WT. 1 RPM WITH 7k FREE TO. -RIH TO 2221' AND DRILL UP SMALL CEMENT STRINGERS DOWN TO 2243' TOP OF PLUG. --0345 Hrs--CONTINUE TO DRILL ON HES PLUG AT 100 RPM WITH 7 BPM AND 345 PSI, 3-4k WOB. --0635-Hrs--CHUCK SCHEVE, AOGCC NS INSPECTOR, WAIVED STATE'S RIGHT TO WITNESS WEEKLY BOP TEST. --0700-Hrs--DRILLING ON LANDING RING AT 2245'. --0720-Hrs--DRILLED THROUGH LANDING RING AND DRILLING ON HARD CEMENT. --0915-Hrs--DRILL THROUGH HARD CEMENT AND CONTINUE RIH TO SOFT TAG ON TOP OF SAND AT 2339'. CONTINUE TO DRY DRILL ON THE SAND FOR ONE FOOT OF PENETRATION. DECOMP CIRCULATE A 20-Bbls HI-VIS SWEEP AT 11.5-BPM AND 930-psi. SEE LOTS OF FINE CEMENT AND TAN-COLORED FLUID ACROSS THE SHAKERS JUST BEFORE THE SWEEP RETURNED. SEE SAND ACROSS THE SCREENS NEAR THE END OF THE SWEEP AND FOR A FEW MINUTES AFTERWARD. DECOMP POH AND S/B DP IN DERRICK. CLEAN OUT BOOT BASKETS AND GET 4-GALLONS OF CEMENT AND DEBRIS. BAKER FISHERMAN CHECKED BIT AND IT IS STILL IN GAUGE FOR 8.5". --M/U STACK WASHER AND RIH TO WASH CEMENT OUT OF BOP STACK. DECOMP CLEAR AND CLEAN RIG FLOOR. DECOMP PJSM FOR BOPE TESTING. TEST TO 250-psi LOW AND Printed: 3/23/2010 10:46:18 AM BP EXPLORATION Page 14 of 22 Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 2/15/2010 113:30 - 20:00 I 6.501 BOPSUR P 20:00 - 21:00 I 1.00 I CLEAN I P 21:00 - 22:30 I 1.50 I CLEAN I P 22:30 - 00:00 1.501 CLEAN P 2/16/2010 100:00 - 01:00 I 1.001 CLEAN I P 01:00 - 02:30 I 1.501 CLEAN I P 02:30 - 03:30 I 1.00 I CLEAN I P 03:30 - 04:30 I 1.00 CLEAN ~ P DECOMP 4000-psi. USE 4" AND 5-1/2" TEST JOINTS IN VBRs, BUT TEST THE HYDRIL WITH ONLY THE 4" TEST JOINT AND TO 250-psi LOW AND 3500-psi HIGH. ALL GOOD TESTS. -ROPE TEST WITNESSED BY WSLs, MIKE ROONEY ANO JOHN WILLOUGHBY, DOYON TOOLPUSHERs SAM DYE AND GLENN HERMANN. DECOMP PJSM - M/U RCJB BHA -BHA CONSISTS OF: RCJB, 4EA BOOT BASKETS, BIT SUB, OIL JAR, XO, 6 EA DRILL COLLARS, XO. -RIH TO 224' DECOMP RIH WITH 4" DP OUT OF DERRICK. -RIH AND KELLY UP ON STAND 23. -ESTABLISH PARAMETERS OF: 85K UP, 85K DOWN, 90K ROT. PUMP RATE OF 4 BPM. DROP BALL AND PUMP DOWN AT 4 BPM SHOWING BALL ON SEAT WITH AN INCREASE IN PSI TO 500. -ROTATING AT 30 RPM WITH 3K FREE TO. -SPR OF MP#1 = 30SPM @ 90 PSI, 40 SPM ~ 210 PSI, MP#2 = 30 SPM ~ 160 PSI, 40 SPM @ 290 PSI. DECOMP WASH DOWN FROM 2306' TO TOP OF SAND AT 2339' -CONTINUE TO WASH TO 2351' SEEING A BOBBLE ON THE WT INDICATOR, CONTINUE TO WASH DOWN TO 2360'. -CIRCULATE BOTTOMS UP SEEING VERY LITTLE SAND OVER SHAKER. -PUMP DRY JOB. POOH. DECOMP PJSM -POOH FROM 2360' TO 225'. DECOMP STAND BACK DRILL COLLARS. -BREAK OFF BHA AND INSPECT RCJB AND BOOT BASKETS. -RCJB CONTAINED 4 PIECES OF CENTRALIZES BLADES ABOUT 6 INCHES TO 4 INCHES LONG. IT SEEMS TO BE THE MAJORITY OF 3 CENTRALIZER BLADES. STILL MISSING 4 PIECES APPROXIMATELY 2 INCHES LONG. -INSPECT BOOT BASKETS. RECOVERING THE MAJORITY OF THE LANDING RING, CHUNKS RANGING IN SIZE OF APPROX. 1"SQUARE TO 2" SQUARE. -M/U BOOT BASKETS AND RCJB FOR A SECOND RUN. SAME BHA AS PRIOR RUN. -CLEAR AND CLEAN FLOOR. -PJSM FOR RIH. DECOMP RIH WITH DP FROM DERRICK TO 2306'. -ESTABLISH PARAMETERS: 85K UP, 85K DWN, 90K ROTATING WITH 3K TO. -PUMP RATE OF 6.6 BPM AND 2500 PSI. DECOMP WASH DOWN FROM 2306' TO TOP OF SAND AT -BEGIN ROTATING AND WASH DOWN TO 2367' AND SEE A BOBBLE ON WT INDICATOR AND AN INCREASE IN TO BY 1 K, PU AND STOP ROTATING AND WASH DOWN TO 2368', BEGIN ROTATING AND WASH DOWN TO 2376'. -PUMP 20 BBL HI-VIS SWEEP AND CIRCULATE OUT OF HOLE SEEING AN INCREASE IN SAND AT THE SHAKERS bye Printed: 3/23/2010 10:46:18 AM • BP EXPLORATION Page t5 of 22 Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 2/16/2010 03:30 - 04:30 1.00 CLEAN P DECOMP 04:30 - 07:00 2.50 CLEAN P DECOMP 07:00 - 09:00 2.00 CLEAN P DECOMP 09:00 - 11:00 2.00 CLEAN P DECOMP 11:00 - 13:30 2.50 CLEAN P DECOMP 13:30 - 14:30 1.00 CLEAN P DECOMP 14:30 - 15:00 0.50 CLEAN P DECOMP 15:00 - 18:30 3.50 CLEAN P DECOMP ALONG WITH CHUNKS OF RUBBER AND CEMENT. PJSM. -POH FROM 2376' TO RIG FLOOR. --0600-Hrs--FIND THE RCJB EMPTY. RECOVER 1-GALLON OF SAND IN THE BOOT BASKETS. --CLEAR AND CLEAN RIG FLOOR. PJSM. ly](U RBP RETRIEVAL TOOL ON CROSSOVER TO 4" DP, AND PREPARE TO RIH. --CLOSE BLINDS AND TEST CASING FROM RBP TO . SURFACE TO 4000-psi, AND RECORD ON CHART FOR 30-MINUTES. LOSE -30-psi IN FIRST 15-MINUTES AND -20-psi IN SECOND 15-MINUTES FOR A GOOD TEST. --PJSM WITH RIG CREW, HALLIBURTON TECH, AND WSL TO RIH TO CLEAN OFF AND RETRIEVE RBP AT 2391'. RIH WITH RBP RETRIEVAL TOOL; GET PARAMETERS AT 2302': P/U WT 75K-Ibs, S/O WT 75K-Ibs. --SLOWLY RIH AND TAG SAND AT 2380'. P/U AND PARK FOR PJSM TO R/U FOR REVERSE CIRCULATING. CLOSE HYDRIL BAG, START PUMP, AND REVERSE CIRCULATE 5-BPM, 330-psi. -20K DOWN WT., STRIPPING PIPE THRU ANNULAR. -WASH SAND OFF OF RBP DOWN TO 2391'. -SHUT DOWN PUMPS AND OPEN HYDRIL BAG. -SET DOWN 20K AND LATCH UP TO RBP, P/U 10K OVER TO CONFIRM LATCH UP. -PUMP 20 BBL HI-VIS SWEEP AROUND AT 7.7 BPM AND 820 PSI. -P/U SINGLE AND SET DOWN 20K ON RBP, ROTATE PIPE 3/4 TURN TO THE RIGHT AND P/U 10K OVER RELEASING RBP. -RIH PAST RBP SETTING DEPTH TO CONFIRM RELEASE. PJSM WITH CREW AND CH2MHILL DRIVERS. -DISPLACE TO CLEAN 120 DEGREE SEAWATER AT 4.1 BPM AND 250 PSI. -UD SINGLE AND MONITOR WELL. -WELL STATIC. -BLOW DOWN TOP DRIVE AND KILL LINE. POH FROM 2391' TO SURFACE. -L/D RBP AND RBP RUNNING TOOL. R/U TO TEST CASING FROM SURFACE DOWN TO FAS-DRILL PLUG AT 12230'. -LINE UP AND CLOSE BLINDS. -PRESSURE UP 9-5/8" CASING TO 4000 PSI. CASING BLED OFF 1000 PSI IN 10 MINUTES AND PRESSURE -CHECK ALL SURFACE EQUIPMENT FOR LEAKS. NONE SEEN. -ATTEMPT TO RETEST AND INSPECT EQUIPMENT 2 MORE TIMES WITH SAME RESULTS. -DISCUSS OPTIONS WITH TOWN ENGINEER. 18:30 - 20:00 1.50 CLEAN P DECOMP PJSM M/U 5-1/2" DRESS-OFF BHA WITH 9-5/8" SCRAPER. -BHA CONSISTS OF: SHOE, 3 EA WASH PIPE EXTENSIONS, WASHOVER BOOT BASKET, 5-1/2" DRESS-OFF MILL, DOUBLE PIN SUB, 9-5/8" CSG Printed: 3/23/2010 10:46:1 S AM BP EXPLORATION Operations Summary Report Page 16 of 22 Legal Well Name: 16-01 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 2/16/2010 18:30 - 20:00 1.501 CLEAN P 20:00 - 00:00 I 4.001 CLEAN I P 12/17/2010 100:00 - 05:00 I 5.001 CLEAN I P 05:00 - 06:00 1.00 CLEAN P 06:00 - 07:00 I 1.001 CLEAN I P 07:00 - 09:00 I 2.001 CLEAN I P 09:00 - 10:00 I 1.001 CLEAN I P DECOMP SCRAPER, BIT SUB, BUMPER SUB, XO, 6EA DRILL COLLARS, XO. -RIH TO 226'. DECOMP RIH WITH DRILL PIPE FROM DERRICK TO 3447', NO PROBLEMS NOTED GOING BY THE 9-5/8" CSG PATCH AT 2287' -RIH P/U DRILL PIPE FROM PIPE SHED TO 5341' DECOMP RIH PICKING UP 4" DRILL PIPE FROM PIPE SHED. -RIH FROM 5341'to 12,108'. -WORK 9-5/8" CASING SCRAPER 4-TIMES FROM 11886' TO 12021'. DECOMP OBTAIN PARAMETERS -PU WT = 225K-LBS, SO WT = 135K-LBS, ROT WT = 175K-LBS. -ROTATE AT 60-RPM WITH 10K-FTLBS FREE TORQUE. -OBTAIN SLOW PUMP RATES. -PUMP ON AT 5-BPM WITH 680-PSI. -RIH AND TAG STUMP AT 12,122'. DECOMP DRESS OFF 5-1/2" TUBING STUMP WITH PUMPS ON AT 5-BPM WITH 630-PSI, ROTATING AT 60-RPM WITH 13K-FTLBS OF TORQUE AND 3-4K-LBS WOB. -SLIDE OVER STUB WITHOUT RESTRICTION AND NO GO AT 12139' (17' OF SWALLOW). -WORK OVER STUMP 6-TIMES ROTATING TO GET OVER STUMP INITIALLY. TOOK -1-1/2 TURNS TO SLIDE OVER. -FINAL DRESSED STUMP DEPTH = 12,123'. DECOMP PUMP 20-BBL HI VIS SWEEP AND CHASE AT 10-BPM WITH 2470-PSI. -SEE SMALL PARTICLES OF OILY PARAFFIN, INCREASING AHEAD OF AND THROUGHOUT SWEEP. -METAL SEEN ON DITCH MAGNETS. -MONITOR WELL -STATIC. -STAND BACK 1-STD AND BLOW DOWN TOP DRIVE. DECOMP PJSM ON TESTING 9-5/8" CASING WITH RIG CREW, DOYON TOOLPUSHER AND BP WSL. DISCUSS HAZARDS OF HIGH PRESSURE TESTING AND THE IMPORTANCE OF GOOD COMMUNICATION WHILE TESTING. -RU JUMPER FROM MUD MANIFOLD TO DRILL PIPE AND LINE TO IA FROM THE CEMENT LINE. -PRESSURE TEST 9-5/8" CASING FROM SURFACE TO -TEST BLEEDS OFF AT 100-PSI PER MINUTE (IDENTICAL TO BLEED OFF OBSERVED YESTERDAY). -RD TEST EQUIPMENT. 10:00 - 10:30 0.50 CLEAN P DECOMP PJSM ON POH, STANDING BACK 4" DP IN DERRICK WITH RIG CREW AND BP WSL. EACH CREW MEMBER IDENTIFIES TASK SPECIFIC HAZARDS. -PUMP 10-BBL 9.8-PPG DRY JOB. -BLOW DOWN TOP DRIVE. 10:30 - 14:30 4.00 CLEAN P DECOMP POH FROM 12,076' TO 226', STANDING BACK 4" DP IN DERRICK. 14:30 - 16:00 1.50 CLEAN P DECOMP LD 6(EA) 6-1/4" DRILL COLLARS THROUGH PIPE SHED. -LD 5-1/2" DRESS OFF BHA. Printed: 3/23/2010 10:46:18 AM BP EXPLORATION Page 17 of 22 Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 2/17/2010 14:30 - 16:00 6:00 - 16:30 16:30 - 17:00 17:00 - 21:00 1.50 .50 0.50 4.00 CLEAN LEAN CLEAN CLEAN P P P P DECOMP ECOMP DECOMP DECOMP -RECOVERED 12 (EA) -2" LONG SECTIONS OF SS CONTROL LINE BANDS AND ONE CLASP IN BOOT BASKET. -INNER DRESS OFF MILL SHOWS GOOD INDICATION OF DRESSING OFF TUBING STUMP. CLEAN & CLEAR RIG FLOOR. -SEND OUT ALL UN-NEEDED BAKER FISHING TOOLS AND SUBS. INSPECT AND SERVICE TOP DRIVE. HOLD PJSM ON RIH WITH 9-5/8" RTTS ON 4" DP FROM DERRICK WITH RIG CREW, HES TOOL REP AND BP WSL. DISCUSS SETTING PROCEDURES AND OUTLINE TESTING SCHEME. -PU 9-5/8" HES RTTS FROM PIPE SHED AND MU. -RIH WITH 9-5/8" RTTS ON 4" DP FROM DERRICK TO 5980'._ -SET RTTS, WITH 120K UP WT, AND 100K DOWN WT. 21:00 - 22:00 1.00 CLEAN P DECOMP PJSM - R/U TEST EQUIPMENT. -CLOSE PIPE RAMS. -PRESSURE UP ON TOP OF RTTS FROM 5980' TO SURFACE TAKING 52 STROKES OF CALCULATED 50 STROKES TO ACHIEVE 4,000 PSI. ~LiART AND HOLD FOR 30 MIN. -GOOD TEST. -BLEED PRESSURE DOWN, UNSEAT RTTS. 22:00 - 00:00 2.00 CLEAN P DECOMP RIH WITH 4" DRILL PIPE FROM 5980' TO 10,441'. -CLEAR AND CLEAN RIG FLOOR. 2/18/2010 00:00 - 00:30 0.50 CLEAN P DECOMP RIH WITH 4" DP FROM DERRICK FROM 10,441' TO 12040'. 00:30 - 02:00 1.50 CLEAN P DECOMP PJSM. -SLIP AND CUT DRILLING LINE. 02:00 - 04:00 2.00 CLEAN P DECOMP SET RTTS WITH COE AT 12040', WITH 210K UP WT, AND 137K DOWN WT. -RU TO TEST FROM SURFACE TO 12040'. -CLOSE PIPE RAMS. -PRESSURE UP ANNULAR TO 4,000 PSI WITH 128 STROKES. -CHART AND HOLD FOR 30 MIN. -SOLID GOOD TEST. -BLEED OFF PRESSURE AND RU TO TEST BELOW RTTS FROM 12040' DOWN TO FAS-DRILL AT 12230' -PRESSURE UP UNDER RTTS TO 4000 PSI WIT 2,jl 8 ~ STROKES. \ ~ ~j. -CHART AND HOLD FOR 5 MIN. COST 600 PSI IN 5 MIN. -PRESSURE BACK UP TO 4000 PSI AND HOLD FOR 3 MIN. LOST 600 PSI IN 3 MIN. -BLEED PRESSURE OFF. 04:00 - 05:30 1.50 CLEAN P DECOMP UNSEAT RTTS FROM 12040'. -BREAK CIRCULATION AND CBU AT 10 BPM AT 1800 PSI. 05:30 - 11:00 5.50 CLEAN P DECOMP POH FROM 12040' TO SURFACE. -LD 9-5/8" RTTS TO PIPE SHED. RTTS IN GOOD CONDITION WITH NO CONDITION ISSUES. -WHILE POH, DOYON TOOLPUSHER, SUPPORT CREW AND PEAK CRANE CREW HOLD PJSM, REVIEW LIFTING PLAN AND CHANGE OUT DRILLING SPOOL ON ROOF. 11:00 - 11:30 0.50 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR. 11:30 - 12:00 0.50 CLEAN P DECOMP RU POWER TONGS AND ASSOCIATED EQUIPMENT FOR Printed: 3/23/2010 10:46:18 AM BP EXPLORATION ~ Page 18 of'22 Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 2/18/2010 111:30 - 12:00 I 0.501 CLEAN I P 12:00 - 14:30 I 2.501 CLEAN I P 14:30 - 21:30 I 7.001 CLEAN I P 21:30 - 22:00 I 0.501 CLEAN I P 22:00 - 00:00 I 2.001 CLEAN I P 2/19/2010 00:00 - 01:00 1.001 CLEAN P 01:00 - 03:30 I 2.50 I CLEAN I P 03:30 - 04:00 I 0.501 CLEAN I P DECOMP HANDLING 2-7/8" PAC HT DRILL PIPE. -BRING DRILL OUT BHA COMPONENTS TO RIG FLOOR. DECOMP MU FASDRILL DRILL OUT BHA. -BHA CONSISTS OF 3-5/8" CONVEX JUNK MILL IWTH 3(EA) 1/2" HOLES, SHEAR PIN GUIDE ASSY, 7-JTS OF 2-7/8" PAC HT DRILL PIPE, XO, XO, PUMP OUT SUB, AND XO TO 4" HT38 DP. -TOTAL BHA LENGTH AFTER SHEAR IS 234.45'. BEFORE SHEAR IS 236.96'. -MU BHA TO FIRST STAND OF DP AND PUMP A DRILL PIPE VOLUME TO ENSURE PIPE IS CLEAR. DECOMP RIH WITH DRILL OUT BHA ON 4" DP FROM DERRICK TO 12085'. -BREAK CIRCULATION AND PUMP 1-DP VOLUME EVERY 35-STDS TO ENSURE PIPE AND MILL ARE CLEAR. -ESTABLISH 8-BPM PUMP RATE WITH 2050-PSI IN PREPARATION FOR BULLHEADING AFTER PLUG IS MILLED. DECOMP HOLD PJSM WITH RIG CREW, DOYON TOOLPUSHER, BP WSL AND CH2MHILL TRUCK DRIVERS AND LEAD ON WELLBORE DISPLACEMENT. DISCUSS SPILL POTENTIALS, DISPLACMENT PROCEDURES AND TRUCK POSITIONS, AND HIGHLIGHT FOUL WEATHER CONDITION AWARENESS. DECOMP PUMP 20-BBL HI VIS SWEEP AND DISPLACE WELLBORE TO CLEAN SEAWATER AT 7.5-BPM WITH 2300-PSI. -WHILE DISPLACING, FINISH LOADING, STRAPPING & DRIFTING 5-1/2" 17# TCII TUBING, TRANSFERRING FROM ODS TO DS USING BRIDGE CRANE. -LOAD COMPLETION JEWELRY ON ODS. STRAP AND INSPECT SAME. PIN END OF PUP UNDERNEATH PACKER FOULED WITH OLD, DRIED BAKERLOK. SENT PACKER TO BAKER MACHINE TO HAVE PIN CLEANED OR POTENTIALLY RECUT. DECOMP CONTINUE TO DISPLACE WELL AT 7.5 BPM AND 2360 PSI. -MONITOR WELL. -STATIC. -BLOW DOWN CEMENT LINE. DECOMP OBTAIN PARAMETERS AT 12,084'. -PUW OF 205K, SOW OF 135K, ROT WT OF164K, 40 RPM WITH 8K FREE TO. -RIH AND TAG TOP OF 5-1/2" STUB AT 12123.5' WITH 3K WOB, CONTINUE TO RIH AND TAG JUNK AT 12,158' WITH 3K WOB, REAM DOWN TO 12176'. MAKE CONNECTION AND WASH DOWN TO 12,198' AND TAG JUNK WITH 5K WOB. REAM DOWN TO 12 228' AND TAG TOP OF FAS DRILL. DRILL FAS DRILL WITH 60 RPM AND 11 K TO, PUMPS AT 3 BPM AND 350 PSI, WOB OF 3-4K. DRILL FOR 1 HOUR ON PLUG WHEN PLUG LET LOSE. PUSH PLUG OUT TAIL PIPE A_T 12 250' AND CONTINUED DOWN TO 12,269'. -STAND BACK 2 STANDS TO CLEAR STUMP. DECOMP CLOSE BAG AND BRING PUMPS ONLINE AT 3.5 BPM BULLHEADING SEAWATER WITH 1050 PSI. INCREASE Printed: 3/23/2010 10:46:18 AM • BP EXPLORATION Page 19 of 22 Operations Summary Report. Legal Well Name: 16-01 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 2/19/2010 103:30 - 04:00 ( 0.501 CLEAN ~ P 04:00 - 09:30 5.501 CLEAN ~ P 09:30 - 10:30 I 1.001 CLEAN l P 10:30 - 22:00 I 11.501 CLEAN I P 22:00 - 23:30 1.501 CLEAN I P 23:30 - 00:00 I 0.50 I CLEAN I P 2/20/2010 ~ 00:00 - 02:30 ~ 2.50 ~ RUN 02:30 - 00:00 I 21.50 DECOMP RATE TO 8 BPM AND 1410 PSI CONTINUE AT SAME RATE AND PRESSURE FOR A TOTAL OF 134 BBLS OF SEAWATER BULLHEADED AWAY. -SHUT DOWN AND OPEN BAG. DECOMP BEGIN CIRCULATING BOTTOMS UP AT 8 BPM AND 2380 PSI. -INITIALLY, DYNAMIC LOSS RATE OF 2 BPH. -WITH 282-BBLS PUMPED, BEGIN GETTING GAS BACK AND THEN COMPLETELY LOSE RETURNS FOR 15-BBLS. -CONTINUE TO CIRCULATE AT 7-BPM AND RESTABLISH RETURNS. -ESTABLISH LOSS RATE OF 36-BPH WITH PUMPS ON AT 7-BPM WITH 1800-PSI. -WHEN NO MORE GAS SEEN AT SURFACE AND WITH LOSS RATE STABILIZED, CBU x2 AT 8-BPM 2320-PSI. DECOMP MONITOR WELL. -ESTABLISH DYNAMIC LOSS RATE OF 20 BPH, STATIC LOSS RATE F 12 BPH. -MONITOR WELL, WELL TAKING FLUID. -BLOW DOWN TOP DRIVE. DECOMP PJSM, POH UD 4" DRILL PIPE. -POH FROM 12084' TO SURFACE. -LOSS RATE OF 10 TO 13 BPH. DECOMP R/U TO UD 2-7/8" PAC DP. -LD MILL OUT BHA, ALL BHA COMPONENTS IN GOOD CONDITION. DECOMP CLEAR AND CLEAN RIG FLOOR. -MAINTAIN HOLE FILL SHOWING LOSSES AT 12 BPH. RUNCMP PJSM. RU TO RUN 5-1/2", 17#, L-80, TCII TUBING. -PULL WEAR RIN -RU TUBING EQUIPMENT. -LOAD AND STAGE TBG JEWELERY. -PU HANGER TO RIG FLOOR. -LOSS RATE OF 12 BPH WITH CONTINUOUS HOLE FILL. RUNCMP PJSM WITH CREW, BAKER COMPLETIONS, TOOL PUSHER AND WSL. DISCUSSED HAZARDS OF JOB, INCLUDING DROPPED OBJECTS, INSPECTING EQUIPMENT, PHASE 2 CONDITIONS. -RIH WITH OVERSHOT, XN NIPPLE, FULL JOINT, X NIPPLE, PACKER, AND X NIPPLE. BAKER LOCKING ALL JOINTS BELOW THE PACKER. -0340 Hrs--JOINT #1 RIH. -0400 Hrs--JOINT #5 RIH. -0405 Hrs-- CHANGE OUT COMPUTER BOX ON TONGS. -0415 Hrs--JOINT #6 RIH. -0430 Hrs--MAINTAINING CONTINOUS HOLE FILL AT A LOSS RATE OF 18 BPH. -1130 Hrs--JT #143 RIH. MAINTAIN CONTINUOUS HOLE FILL WITH A LOSS RATE OF 13-BPH. -2130Hrs--JT #286 RIH. 5 FT JOINT DOWN. P/U JOINT #287 5 FT JOINT DOWN AND SEE TOP OF TBG STUB 9-1/2' IN, SEE 1ST SHEAR AT 11-1/2' IN WITH 10K DOWN WT, SEE 2ND SHEAR 19-1/2' IN WITH 10K DOWN WT. BOTTOM OUT Printed: 3/23/2010 10:46:18 AM • $P EXPLORATION Page 20 of 22 Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 2/20/2010 ~ 02:30 - 00:00 ~ 21.50 ~ RUN 2/21/2010 100:00 - 05:30 I 5.501 RU 05:30 - 06:00 0.50 06:00 - 08:00 2.00 08:00 - 08:30 I 0.50 RUNCMP 23-1/2' DOWN WITH 15K DOWN WT. -THIS IS 9' DEEPER THEN PLANNED WITH GOOD SHEAR INDICATIONS, TOP OF STUB IS AT 12,132'. -CALCULATE SPACE OUT AT 31' LEAVING 4' OFF NO-GO. -BACK OUT JOINTS #287, 286, 285. PICK UP PUPS 20', 5', 6' M/U ON JOINT 284. -P/U JOINT 285, M/U HANGER. -M/U LANDING JOINT. -210K UP WT, 152K DOWN WT. -BOTTOM OF OVERSHOT AT 12,141'. NO-GO OF OVERSHOT AT 12,128'. -MAINTAIN CONTINOUS HOLE FILL AT 13 TO 18 BPH LOSS RATE. RUNCMP P/U HANGER ABOVE RIG FLOOR, CLOSE BAG. -R/U TO CIRCULATE. PRESSURE TEST LINES TO 4000 PSI. -GOOD TEST. -PJSM WITH TRUCK DRIVERS, CREW, TOOL PUSHER AND WSL. -REVERSE CIRCULATE 290 BBLS OF 120 DEGREE SEAWATER, FOLLOWED BY 540 BBLS OF 120-DEGREE SEAWATER TREATED WITH EC-1124A CORROSION INHIBITOR. -PUMP RATE OF 3 BPM AND 70 PSI. RECEIVING RETURNS AFTER 20 BBLS AWAY. LOBBING 9 BPH WHILE CIRCULATING. RUNCMP LAND TUBING HANGER AND FMC RILDS. RUNCMP HOLD PJSM ON LRS REVERSING 80-DEGREE DIESEL FREEZE PROTECTION WITH RIG CREW, LRS, AND BP WSL. DISCUSS SPILL POTENTIALS, HIGH PRESSURE LINES AND WEATHER CONDITIONS. -TEST LINES TO 4300-PSI. GOOD TEST. -REVERSE 97-BBLS OF 80-DEGREE DIESEL INTO IA AT 2-BPM WITH 500-PSI. -SHUT IN IA AND LINE UP TO PUMP DOWN TUBING. -PUMP 50-BBLS OF 80-DEGREE DIESEL DOWN TUBING AT 1-BPM WITH 725-PSI. RUNCMP PU LANDING JT AND CENTER ON HANGER. -ALLOW BALL & ROD TO FALL FOR 10-MINUTES. 08:30 - 12:00 3.50 BUNCO RUNCMP LRS BRING PUMP ONLINE AND PRESSURE UP TO SET PACKER. SEE SLIGHT BOBBLE IN PRESSURE TREND INDICATING PACKER BEGAN SETTING AT -1500-PSI. -CONTINUE TO PRESSURE UP AND ATTEMPT TO -UNABLE TO GET PRESSURE TO HOLD. TROUBLESHOOT ALL SURFACE EQUIPMENT WITHOUT FINDING LEAK SOURCE. -BLEED TUBING PRESSURE TO 1500-PSI AND SHUT IN. -PRESSURE UP ONJA_TO 4000-PSI AND HOLD FOR 30-CHARTED MINUTES. GOOD TEST INDICATES PACKER AND TUBING INTEGRITY ON IA SIDE. -WHILE TESTING IA, TUBING PRESSURE CONTINUED TO Printed: 3/23/2010 10:46:18 AM • BP EXPLORATION Page 21 of 22 Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 2/21/2010 08:30 - 12:00 3.50 BUNCO P RUNCMP DROP. -BLEED IA PRESSURE TO 1500-PSI AND SHUT IN. -PRESSURE UP ON TUBING TO 4000-PSI AND MONITOR IA PRESSURE. TUBING PRESSURE DROPS FROM 4100-PSI TO 3450-PSI OVER 15-MINUTE PERIOD. IA PRESSURE STARTS AT 1900-PSI AND DROPS TO 1875-PSI OVER THE SAME INTERVAL, INDICATING THAT LEAK IS AT THE RHC-M AND/OR BALL & ROD AND THAT TUBING INTEGRITY IS GOOD. -ALL TESTS WITNESSED BY AOGCC REP LOU GRIMALDI. 12:00 - 12:30 0.50 BUNCO P RUNCMP BLEED OFF ALL PRESSURE TO LRS AND THEN RD LRS. -DISCUSS SITUATION WITH RWO ENGINEERING TEAM AND BREAKING CONTAINMENT SUBJECT MATTER EXPERT AND DECIDE TO PROCEED BY MONITORING WELL TO CONFIRM THAT A FLUID COLUMN COULD BE MAINTAINED ABOVE THE LEAKING RHC-M /BALL & ROD, THUS CONFIRMING A COMPETENT MECHANICAL BARRIER. 12:30 - 13:30 1.00 BUNCO RUNCMP FILL BOP STACK USING CHARGE PUMP AND MEASURE FROM ROTARY TABLE TO TOP OF FLUID IN BOP STACK. -MONITOR WELL FOR 1-HR. -INITIALLY FLUID LEVEL AT 46" BELOW RIG FLOOR. -AFTER 1-HR, FLUID LEVE AT 48" BELOW RIG FLOOR. -CONFIRMS BALL & ROD WITH KILL WEIGHT FLUID ABOVE AS A COMPETENT MECHANICAL BARRIER. 13:30 - 14:00 0.50 WHSUR P RUNCMP FMC T-BAR IN TWC. -CLOSE BLINDS AND TEST TWC TO 4000-PSI FOR 10-CHARTED MINUTES. GOOD TEST. 14:00 - 16:30 2.50 BOPSU P RUNCMP DRAIN BOP STACK. -BLOW DOWN ALL LINES ON BOP STACK AND USED DURING TESTING. -RD SAME LINES AND CELLAR MANIFOLD. 16:30 - 20:30 4.00 BOPSU P RUNCMP HOLD PJSM ON CHANGING OUT 3-1/2" X 6" VBRS TO 2-7/8" X 5" VBRS AND THEN ND BOP STACK. DISCUSS WORKING AT HEIGHTS, PROPER PERMITTING AND HAZARD ASSESSMENT. -OPEN VBR DOORS AND RECOVER 1-PIECE OF CENTRALIZER BLADE AND A SIGNIFICANT AMOUNT OF CEMENT. -DECIDE TO OPEN BLIND RAM DOORS AS WELL AND CLEAN. -2 BARRIERS FOR NLZBOP STACK ARE 1) BALL & ROD ON SEAT WITH FULL FLUID COLUMN ABOVE AND 2) TESTED TWC IN TUBING HANGER. -N/D TURN BUCKLES, RISER, KOOMEY LINES. -STAND BOP STACK BACK. 20:30 - 00:00 3.50 WHSUR P RUNCMP PJSM N/U TREE. -REMOVE OLD RAMS AND SECONDARY ANNULUS VALVE FROM CELLAR. -BRING IN TREE, ADAPTOR FLANGE INTO CELLAR. -N/U ADAPTOR FLANGE AND TREE. 2/22/2010 00:00 - 01:00 1.00 WHSUR P RUNCMP CONTINUE TO N/U TREE. 01:00 - 02:00 1.00 WHSUR P RUNCMP TEST ADAPTOR FLANGE AND VOID TO 5000 PSI FOR 30 Printed: 3/23/2010 10:46:18 AM . ~ • BP EXPLORATION Page 22 of 22 Operations Summary Report Legal Well Name: 16-01 Common Well Name: 16-01 Spud Date: 12/5/1980 Event Name: WORKOVER Start: 2/2/2010 End: 2/10/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/22/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 2/22/2010 01:00 - 02:00 1.00 WHSUR P RUNCMP MIN. GOOD TEST. -TEST TREE TO 5000 PSI FOR 5 MIN. GOOD TEST. 02:00 - 03:00 1.00 WHSUR P RUNCMP SECURE WELL. -CLEAN IN CELLAR AND SECURE TREE. -TREE / IA / OA PRESSURE ALL = 0-PSI. -RELEASE RIG AT 0300 Hrs. Printed: 3/23/2010 10:46:1 S AM TREE = CMJ WELLHEAD = FMC AC'T'UATOR = AXELSON KB. ELEV...- 73' BF. ELEV - KOP = Max Angle = 2100' 61 ° @ 7900' Datum MD = 12504' Datum TV D = 8800' SS 16-01 20" CONDUCTOR, 110' ~I 5-1/2" TUBING STUB (02/19/10) 12124' 5-1/2" TBG, 17#, L-80 TCII, .0232 bpf, ID = 4.892" 12141 94#, H-40, ID = 19.124" 9-5/8" CSG, 47#, L-80 HYRRILL 563, ID = 80750" 2286 9-5/8" BOWEN CSG PATCH, ID = 9.740" 2290 13-3/8" CSG 72#, L-80, ID = 12.347" 2694' Minimum ID = 3.71" @ 12471' CEMENT COLLAR 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~ 12187' TOP OF 7" LNR --r 12197 4-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" ~~ 12250' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~~ 12460 PERFORATION SUMMARY REF LOG: BHCS ON 12/31/80 ANGLE AT TOP PERF: 49 @ 12536' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 12552 - 12582 S 11/18/98 12598 - 12628 S 11/18/98 3-1/8" 8 12606 - 12623 S 11/18/98 3-1/8" 2 12623 - 12628 S 11/18/98 2-7/8" 6 12635 - 12655 O 02/14/99 2-7/8" 6 12676 - 12696 O 02/14/99 2-7/8" 6 12705 - 12725 O 02/14/99 PBTD -1 12979 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 13015 ELM CMT PLUG DATE REV BY COMMENTS DATE REV BY COMMENTS 01/09/81 ORIGINAL COMPLETION 02/22/10 D-16 RWO 03/07/10 PJC DRLG DRAFT CORRECTIONS 03/08/10 DB/PJC FINAL DRLG CORRECTIONS PRUDHOE BAY UNIT WELL: 16-01 PERMff No: 1801360 API No: 50-029-20533-00 SEC 24, T10N, R15E, 2876.98' FEL & 1991.9' FNL BP Euploration (Alaska) 2124' I-15-1/2" HES X NIP, ID = 4.562" 2242' 9-5/8" HES ES CEMENTER 22T 6~ 9-5/8" BKR ISO ZONE EXTERNAL PKR 11960' I-~ 5-1/2" HES X NIP, ID = 4.562" 11990 9-5/8" X 5-12" BKR S-3 PKR, ID = 4.75" 12025 5-1/2" HES X NIP, ID = 4.562" 12096 5-1/2" HES XN NIP, ID = 4.455" 12141 -19-5/8" X 5-1/2" UNIQUEOVERSHOT - 12161 5-1/2"BKRPBRASSY 12175 9-5/8" X 5-1/2" BKR SAB PKR 12187' S-1 /2" X 4-1 /2" XO, ID = 3.958" ~ y~{r;G u.~\ ~ L~31 ~`~ 12248 4-1/2" OTIS XN NIP, ID = 3.725" 12249 4-1/2" BKR S/O SUB 12250 4-1/2" TUBING TAIL, ID = 3.958" 12234 ELMD TT LOGGED 07/10/81 - 12649' I-I CEMENT COLLAR Alaska Data & Consulting Services 2525 Gamball Street. Sufle 400 Anchorage, AK 99503-2838 - --~ ~ - ~,~~,; j, ~4~ ,I:. S~hlum6erger Alaska Date & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503.283a ATTN: Beth Well Job 8 NO. 5473 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD MPC-22A BAUJ-00007 MEM PROD PROFILE WlGLS - 2!11110 1 1 F-21 13-17 P2-48 i6-Ot MPC-24A V-224PB1 AYKP-00073 AYKP-00072 AWO-00057 BBSK-00006 BAUJ-00005 09AKA0147 PROD PROFILE ~ INJECTION PROFILE PROD PROFILE USIT MCNL OH MWD/LWD EDIT 02/16/10 02/14/10 02/11/10 02/11/10 01/09/10 11/28/09 1 1 1 1 2 1 1 1 1 1 1 1 YLtq~t AI:RNV WLCUVC rlCliC1Y 1 Or DlUrvmu Nrvu nc r unrvnr~a vrvc ~.vr ~ cn~.n , v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Bivd. o2~te~to V • • SEAN PARNELL, GOVERNOR ~LASSA OIL A11TD GAS COI~TSERQATIOI~T COl-II~iIS51O1Q Mr. David Reem Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~, ~3~ ~~ Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU 16-01 Sundry Number: 309-440 ~~~ JAS ' ' X01 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount Chair DATED this ~ day of January, 2010 Encl. (,Q'~~, ~~ STATE OF ALASKA 1° ALAS~IL AND GAS CONSERVATION COMMI~N APPLICATION FOR SUNDRY APPROVAL 20 AAC 25280 .2~G 1. Type of Request: ~lasfca Qip ~ G>y~ GAflS. Commis ^ Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Re-Enter SuspendedVl~4rs-;~,>.,nsz ® Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Other Speafy: ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Expbration (Alaska) Inc. ^ Development ^ Exploratory 180-136 - 3. ~~' ®Service ^ Stratigraphic 6. API Number. P.,O_ Box 196612, Anchorage, Alaska 99519612 50-029-20533-00-00 ~ 7. If perforating, cosest approach in pool(s) opened by this operation to nearest 8. Well Name and Number. property line where ownership or landownership changes: PBU 16-01 ~ Spacing Exception Required? ^ Yes ®No 9. Property Desgnation: 10. F~ki /Pool(s): ADL 028332 ~ 028346 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11 _ PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13020' ~ 9316' 12806' 9132' 12248' & 12806' None Cali Len Sine MD TVD Burst Colla Strkx3ural Conductor 11 11 11 1 Surface 2694' 1 265 4 267 Intermediate 12460' 9- " 12460' 8836' 6870 4760 Production Lim 818' 7" 12197" -13015' 19' - 312' 81 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft}: 12635" -12725' 8985' -9062' 5-12", 17# x 4-12", 12.6# L-80 / N~0 12250' Packers and SSSV Type: 9-5/8° x5-1/2° Baker'SAB' packer Packers and SSSV 12175' /8602' MD (ft) and TVD (ft): 12. Attachments: 13_ Well Class otter proposed work: ® Deskxiption Summary of Proposal ^ BOP Sketch ^ Expbratory ^ Development ®Senr~e ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Comrt~ncin9 Operations: January 20, 2010 ^ Oil ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: Date: ^ WINJ ^ GINJ ~® WAG ^ Plugged ^ SPLUG Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge_ Contact David Bjork, 564-5683 Printed Nam avid Reem Title Engineering Team Leader Bra Signature Phone 564-5743 Date fZ 3D Zero Terris Hubble, 564-4628 Commission Use On Conditions of approval: otify Commission that a representative may witness _ Sundry Number. ~ ^ Plug Integrity BOP Test ( Mechan~al Integrity Test ^ Location Clearance ~ O ' 7 F R i Subsequent arm red: equ APPROVED BY ~ ~ /O D t Approved By: COMMISSIONER THE COMMISSION a e tan I Form 10-403 ReviseQ 07!2000 ~ ~ ~. ~ ~ A L,~~MS fA u _ ~ j~~n'~~~ ~ ~ ~ ~0 Skbmit In Duplicate e7 dFU~ U~~'' Yv • 16-01 i Expense Rig Workover • Scope of Work: Repair T x IA x OA communication. Pull 5-'/z" L-80 completion, cut and pull 9-5/8" ~ casing, run and cement to 9-5/8" surface casing, test 9-5/8" casing, and run 5-1/2" L-80 completion. MASP: 2345psi Well Type: Injector Estimated Start Date: January 20, 2009 Production Engineer: Justin Nash Intervention Engineer: David Bjork Pre-Rig Work Request: S 1 Pull PX lu from 4-~h" tail i e at 12,248' MD. E 2 Seta 4-~/z" composite bridge plug in the middle of the first full joint above the XN nipple at 12,233'. reference tall 1/8/81 F/W 3 Set an ISA/BPV in the tubing hanger and CMIT-TxIA to 1,000 psi. Monitor the THA/tubing spool void for pressure during CMIT-TxIA. MIT-OA to 1,OOOpsi record LLR if necessa E 1 Power Jet cut 5-'/2" L-80 IPC tubing at 12,124' MD, in the top third of the first full joint above the acker Reference tubin tall dated 01-08-81 . F 2 CMIT-TxIA to 1,OOOpsi. Circulate well with 8.6ppg seawater and freeze protect to 2000'. W 3 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-IC. W 4 Set a BPV in the tubin han er. O 5 Verify that the well has a competent cellar. Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure -, 1. MIRU. ND tree. NU BOPE with 3-'/2" x 6" VBR pipe rams. Pressure test to 4,000 psi. Cfrculate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull. and LD 5-'h" tubing string to the cut. 3. Run USIT log to determine top of cement in 9-5/8" x 13-3/8" annulus. 4. Set retrievable bridge plug 100' below the top of cement and pressure test to 1,500 psi for 15 minutes. 5. Cut and pull 9-5/8" casing from above the top of cement. Note: Pipe rams will not be changed to 9-5/8" as the well has two tested barriers (composite plug at 12,233' and RBP) to the reservoir. 6. Run and fully cement new 9-5/8" casing to surface. Pressure test to 4,OOOpsi 7. Retrieve bridge plug. 8. Pressure test to 4,OOOpsi, drill out composite bridge plug in the tailpipe.. 9. Run 5-1/2" L-80 stacker packer completion. 10. Displace the IA to packer fluid, freeze protect to 2000' MD and set the packer. 11. Test tubing and IA to 4,000 psi. 12. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = FMC GE WELLHEAD = FMC ACTUATOR = AXEiSON KB. ELEV - ~3~ BF. E1EV = KOP = 2100' Max Angle = 61 @ 7900' Datum MD = 12504' Datum TV D = 8800' SS 13-3/8" CSG 72#, L-80, ID = 12.347" I-{ 2694' Minimum ID = 3.71" @ 12471' CEMENT COLLAR ', 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" I-i 12187• II TOP OF4-1/2"TBG-PC 12187 ', TOP OF 7" LNR 12197 4-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" ~ 12250' i I ~~, 9-5/8" CSG, 47#, L-80, ID = 8.681" 12460' PERFORATION SUMMARY REF LOG: BHCS ON 12/31/80 ANGLE AT TOP PERF: 49 @ 12536' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL O n/Sgz DATE 3-1/8" 4 12552 - 12582 S 11/18/98 12598 - 12628 S 11/18/98 3-1/8" 8 12606 - 12623 S 11/18/98 3-1/8" 2 12623 - 12628 S 11/18/98 2-7/8" 6 12635 - 12655 C 02/14/99 2-7/8" 6 12676 - 12696 C 02/14/99 2-7/8" 6 12705 - 12725 C 02/14/99 PBTD ~ 72979• 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 13015' SAFETY NOTES: 2127' S-1/2" OT ROM SSSV NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2996 2921 35 211RL552-4 RO-3 2 5922 4807 53 211RL552-4 RO-3 3 8289 6079 58 211RL552-4 RO-3 4 9914 7013 52 211RL552-4 RO-3 5 10715 7524 48 211RL552-4 RO-3 6 10786 7572 47 211RL552-4 RO-3 7 11264 7906 44 211RL552-4 RO-3 8 11338 7960 44 211RL552-4 RO-3 9 11654 8194 41 211RL552-4 RO-3 10 11728 8250 40 211RL552-4 RO-3 11 11930 8407 39 211RL552-4 RO-3 12 12005 8466 38 211RL552-4 RED 12161' ~5-1/2" BKR PBRASSY 12175' 9-5/8" X 5-1/2" BKR SAB PKR 12187' 5-1/2" X 4-1/2" XO ~ 12248' H 4-1 /2" OTfS XN NIP NO GO, ID = 3.725" 12248' 4-1/2" PXNTTP(01/03/09) 12249' 4-1/2" BKR S/O SUB 12250' 4-1/2" TUBING TAIL 122$4' E-lMD TT LOGGED 07/10/81 12471' ~~ TOP OF CETAENT COLLAR 12649 I-I BOTTOM OF CEMEM COLLAR 12806' I~ ELM CMT PLUG DATE REV BY COMMENTS DATE REV BY COMMENTS 01/09/81 ORIGINAL COMPLETION 07/08/01 RNltlh CORRECTIONS 10/06/03 BCH/TLP PERF CORRECTIONS 08/05/08 BSEJPJC SE7 CAT VALVE (07122/08) 03/29/09 JCM/ PJC PULL CAT STD VALVE (01/02/09) 03/29/09 JCM/ PJC SET PXN PLUG (01/03!09) PRUDHOE BAY UNfT WELL: 16-01 PERMfT No: 1801360 API No: 50-029-20533-00 SEC 24, T10N, R15E, 2876.98' FEL & 1991.9' BP Exploration (Alaska) TREE = FMC GEN 2 WELLHEAD = FMC ~4CTUATOR = AXELSON_ KB. ELEV = 73' BF. ELEV = KOP = 2100' Max Angle = 61 @ 7900' Datum MD = 12504' Datum TV D = 8800' SS 9-5/8" HES ES Cementer - 2 200` 9-5/8" BKR ECP 2 220` 9-5/8" Bowen Casing Patch - 2,250` -5/8" 47#, L-80, Hydril 563, ID=8.681" - 2200` 13-3/8" CSG 72#, L-80, ID = 12.347" 2694' 5-1/2" 17#, L-80, TC-II, ID=4.892" Minimum ID = 3.71" @ 12471' CEMENT COLLAR 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" I TOP OF 4-1 /2" TBG-PC TOP OF 7" LNR 16 -O ~ SAFETY NOTES: Proposed 2100' S-1/2" HES X NIP, ID = 4.562" 11,951' S-1/2" HES X NIP, ID = 4.562" - 11,938' 9-5/8"x 5-112" HES TNT PKR - 12,017' S-1/2" HES X NIP, ID = 4.562" 12,090' 5-1/2" HES XN NIP,ID = 4.455" ~~ ^ 2,122' 9-5/8" X 5-1 /2" UNIQUE OV ERSHOT 12187' I~ 5-1 /2" X 4-1 /2" XO 12161' --15-1/2"BKRPBRASSY 12175' 9-5/8" X 5-1/2" BKR SAB PKR 12187' 12187' I4-1/2" OTIS XN NIP NO GO, ID = 3.725" I 12249' ~4-1/2" BKRS/O SUB 4-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" 12250' 12250' 4-1/2" TUBING TAIL 12234' ELMD TT LOGGED 07/10/81 19-5/8" CSG, 47#, L-80, ID = 8.681" ~ PERFORATION SUMMARY REF LOG: BHCS ON 12/31/80 ANGLE AT TOP PERF: 49 @ 12536' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 12552 - 12582 S 11/18/98 12598 - 12628 S 11 / 18/98 3-1/8" 8 12606 - 12623 S 11/18/98 3-1/8" 2 12623 - 12628 S 11/18/98 2-7/8" 6 12635 - 12655 C 02/14/99 2-7/8" 6 12676 - 12696 C 02/14/99 2-7l8" 6 12705 - 12725 C 02/14/99 I PBTD 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" ~~ 13015' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/09/81 ORIGINAL COMPLETION 07/08/01 RN/tlh CORRECTIONS 10/06/03 BCH/TLP PERF CORRECTIONS 08/05/08 BSE/PJC SET CAT VALVE (07/22/08) 03/29/09 JCMI PJC PULL CAT STD VALVE (01/02!09) 03/29/09 JCMI PJC SET PXN PLUG (01/03/09) ELM CMT PLUG PRUDHOE BAY UNIT WELL: 16-01 PERMfr No: 1801360 API No: 50-029-20533-00 SEC 24, T10N, R15E, 2876.98' FEL & 1991.9' BP Exploration (Alaska) 12471' I-~ TOP OF CEMENT COLLA R BOTTOM OF CEMENT COLLAR I • Page 1 of 2 ~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, October 22, 2009 3:37 PM ~~~~~~ ~~~~~~~r~`~~ To: Regg, James B (DOA) ~~ Cc: NSU, ADW Well Integrity Engineer Subject: RE: PBU 16-01 (PTD 1801360) `" Hi Jim, ~ Here is a history on well 16-01 (PTD #1801360) since the failed MITIA. ~ - .~t~,% r ~> ~~~J ~ ~ ~,,;~~ ~~+ ~~- t : ~.. ~ > 07/09/08: AOGCC MITIA Failed > 07/14/08: Obtained a liquid leak rate of 0.26 gpm at 2400 psi > 07/15/08: PPPOT-T Passed, IC Failed to determine if the leak was through the wellhead. Although the inner caing packoff test failed, one of the tw > 07/18/08: MITIA Failed confirming that tightening the lockdown screws during the packoff testing did not mitigate the communication > 07/22/08: Set a cat standing valve @ 12248' securing the well; MIT-T Passed to 2400 psi > 07/23/08: CMIT-TxIA Passed to 2400 psi -~ > 07/24/08: MIT-IA Failed, L~R ~ 1.26 gpm @ 2400 psi ~ > 10/15/08: Tbe caliper, 275 jts 1-20%, 45 jts 20-40% > 10/16/08: MITIA Failed; LLR 1.26 gpm @ 2400 psi ~% > 11/21/08: Tecwell leak detection log confirms tubing leaks @ 8229' 8214' & 9807' > 01/03l09: Pulled cat stnd vlv from 12248', set TTP @ 12248' resuring well ~ ~/~~ ~~v~~ > 01/05/09: Wellhead crew re-torqued stud/pad bolts on all casing spools/head > 09/06/09: Set 5 1i18 FMC ISA BPV and test tree passed to 5000 psi. BPV in well until further evaluation ~~~''~~- > 09/09/09: Voidage test of packoffs confirms no leaks through the wellhead seals ,~ The well has been shut-in and secured since 7/22I08. Due to the confirmation of multiple tubinq leaks, the decision has been made to leave the well shut-in and secured until repaired by a rig workover. At this time a rig ~J workover is scheduled for February 2010. An AOGCC MITIA will be conducted once the well is returned to injection. .---------- Please let us know if there is any additional information you need. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Weli (ntegrity Coordinator GPB Wells Group Pharee: (907) 659-5102 Pager: (907) 659-5100 x1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, October 22, 2009 10:18 AM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: PBU 16-01 (PTD 1801360) Attached is last info in our files regarding injection well PBU 16-01 (PTD 1801360); records indicate no injection since 7/2008. Unknown to us if there was any diagnostics done as described in the attached email, and if the well 10/22/2009 ~ ~ Page 2 of 2 is just SI or secured with a plug? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 10/22/2009 Page 1 of 1 ~i Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, October 24, 2008 6:46 PM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: RE: PBU 16-01 (PTD 1801360) Hi Jim, Well 16-01 {PTD #1801360) remains shut-in and classified as Not Operable due to the tubing leak. The plan is to run a leak detection log and evaluate in the dummy gas lift valves or leaking ~or if the wail needs a tubing patch. If plans continue and a patch is set, an AOGCC witnessed MITIA will be conducted at that time for UIC compliance. Thank you, Anna 1~u6e, 2'.2. Well Integrity Coordinator GPB Wells Group Phone: {907} 659-5102 Pager: {907) 659-5100 x1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, October 24, 2008 12:59 PM To: NSU, ADW Well Integrity Engineer Subject: PBU 16-01 (PTD 1801360) Commission witnessed 2 failed MITIAs on July 9, 2008. Pressure would not stabilize. I cannot find a copy of notification of failed MITA; it appears the well was and remains shut in. Please review and confirm well status. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 11/28/2008 1!'IEl®'I® I~IDi.TM To: Jim Regg ~f ~; 1~~~fi~ U ~ P.I. Supervisor (( FROM: John Crisp Petroleum Inspector State ®f Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 31, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 16-O1 PRUDHOE BAY UNIT 16-01 Src: Inspector NON-CONFIDENTIAL Well Name• PRUDHOE BAY UNIT t6-O1 Insp Num mitJCr0807 1 40852 1 0 Rel Insp Num: MITOP000002314 API Well Number 50-029-20533-00-00 Permit Number: 180-136-0 Inspector Name: John Crisp Inspection Date 7/9/zoos Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! 16-01 Type Inj. W ~ TVD ~ 8602 ~ IA ~ s00 2400 2340 2300 2260 P T• 1801360 iTypeTest SPT Test psi zlso.s ~ OA I. Sao slo slo ' slo slo Interval Four Year Cycle per, Pail .~ Tubing laso i laso laso laso laso Notes• 4.7 bbl's pumped for test. Well did not stabilize & had average 40 psi loss for each 15 minute interval. Added block valve on IA to retest. ~~~~~~ AUG ~ eI ~~~~ Thursday, July 3l, 2008 Page 1 of t ~+ ®~~~ w Toy Jim Regg ~ ~? P.I. Supervisor ~~`~~ ~~ 1 ~~ FROM: John Crisp Petroleum Inspector State ®f Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 15, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 16-01 PRUDHOE BAY UNIT 16-01 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~'~ Comm Well Name: PRUDHOE BAY UNIT 16-01 API Well Number: 50-029-20533-00-00 Inspector Name: John Crisp Insp Num: mitJCr080714085640 Permit Number: 180-136-0 Inspection Date: 7/9/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 16-O1 Type InJ. w ~ TVD 8602 IA ~ 2240 ~ 2410 ~ 2370 2330 , 2290 P.T I laols6o TypeTest SPT Test psi ! zlsos pA ~ slo szo ~ szo szo I szo Interval 4YRTST P~ F / Tllbing j 14s0 1460 1450 1450 ~ 14s0 Notes' .4 bbl's pumped for retest with added block valve on IA. • ~ ~ ~ ~E'f't ~ ~ ~~ ~ (i2-E~ (~~V~~~ ~~d'7lIIlY~i.~ ~U q ~ ~ L~OD Tuesday, July 1 s, 2008 Page I of 1 ~® ~~~~ To: Jim Regg ~ ~ ~ , ~ ~ ~. P.I. Supervisor ~~ ~~% ~ °~~ ~~ FROM: John Crisp Petroleum Inspector State ®ff Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 1 s, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 16-01 PRUDHOE BAY UMT 16-O1 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~.J~~F~'-" Comm Well Name: PRUDHOE BAY UNIT 16-01 API Well Number: so-oz9-zos33-oo-0o Inspector Name: John Crisp Insp Num: mitJCr080714084632 Permit Number: 180-136-0 Inspection Date: 78/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 16-oI TYPe Inj. w TVD '' s6oz IA so so p T. i lsols6o ;TypeTest SPT Test psi usos pA uo ~ las , '~ ~ Interval 4YRTST per, t - Tubing' laso ; Iaso ! i NOtCS' umped 10 bbl's into IA with no pressure change on IA. OA had increased from 110 psi to I55 psi. Fluid level test was performed on IA & calculated another 20 bbl's needed to fill IA. The truck only had 14 bbl's left on board. Test was cancelled incomplete. ~ 33 ~~ . es,~~~' AIJC ~ ?008 Tuesday, July 15, 2008 Page 1 of l Schlum~erger RECEIVED NO. 3907 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth AUG 1 0 Z006 .,.' hlEn ,i\UG 1 t!x. S\.u"\N~. .. """ -" ~aska Oil & Gas Cons. Commission . ~nchoægl:r¡)_l3b ~ &;P(QS. lJ lŒ.. OL-- Field: Prudhoe Bay Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave. Suite 100 Anchorage, AK 99501 b L D C C Well Jo # o! escription Date BL olor D 02-166 11209601 MEM PRUD ,,_, .~~ 04/25/06 1 16-21 11221558 IU~C ...""...., 04/03/06 1 16-01 1105228 INJECTION PROFILE 07/21/05 1 16-01 10980601 INJECTION PROFILE 08/15/05 1 D.S 11-08 11223100 INJECTION PROFILE 02127/06 1 D.S. 02-26C 11223117 LDL 05/16/06 1 09-09 11211484 PROD PROFILE W/DEFT 04/28/06 1 18-33A 11258719 LDL 06/08/06 1 X-07 A 11217272 USIT 08/05/06 1 D-03A 11243918 SCMT 06/02/06 1 D-03A 11217271 US IT 08/04/06 1 Z-19 11217273 USIT 08/06/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 08/08/06 . . Schlumbel'ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well NK-20 P2-34 N-14A 4-38/K-34 B-19A 15-31 B MPF-89 , DS 16-01 DS 16-15 DS 09-10 M-30 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 10889223 11072853 10991753 10933591 11058502 10942223 11132060 10980601 10980599 11058237 11072877 Log Description Date 03/21/05 06/05/05 01/22/05 10/29/04 05/06/05 07/16/05 10/08/05 08/15/05 08/13/05 08/16/05 08/04/05 PPROF W/DEFT TEMPERATURE PRESSURE LOG LDL PPROF W/DEFTlGHOST RST MCNL SCMT (PDC-GR) INJECTION PROFILE PPROF W/DEFT INJECTION PROFILE INJECTION PROFILE §ÇANNED NOV 0 2 2005 , O~ ~~- NO. 3503 10/18/05 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 Color CD 1 1 1 1 "- '~. Alaska Data & Consulting Services 2525 Gambell Street, S te 400 Anchorage. AK 995 2838 A TTN: Beth Received by: l~·b-~c~,.~r .fL&1 h'_.f. Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SC!~NNEC SEP 0 6 2005 Well Job# Log Description Date BL VMPF-57A "0.) . ,6-7 10672349 CHANNEL DETECTION LOG 01/24/04 1 ;-- 02-28A J... '0l1'~ j {p Y 10928607 MCNL 12/11/04 j OS 18-23A \ c,\ 3 ,- Ie¡ I 10942206 MCNL 04/20/05 1 / OWDW-SE ì (:1 C·· 1.) q 10893097 RST-BORAX CHANNEL DETECTION LOG 03/25/05 1 1/ E-23B (2 (c i t -f J. """ 10889133 LEAK DETECTION LOG 07/16/04 1 v E-23B ...-t" 11039119 LEAK DETECTION LOG 05/08/05 1 L- P-06A ¡ q 7 -), J. t.-i N/A LEAK DETECTION LOG 06/04/05 1 J Y-09A t q 7 - ê .3) 10942222 MEM PPROF W/DEFT 07/14/05 1 !t-' P2-49 ¡ <1 J.. ... c)... ..../ 11062633 PRODUCTION PROFILE W/DEFT 07/02/05 1 ~. OS 04-23A 1 q 3-- )") 11051072 PRODUCTION LOG WIDEFT 07/13/05 1 v"o.S.16-01 130-"J(¡ 1105228 INJECTION PROFILE UTe.- 07/21/05 1 ./ 4-1 OA/L-28 .2~..)..J 3 10662991 RST 02/05/04 1 .;-' 01-49IP-21 !gg -~ ~ 73 11072870 PRODUCTION PROFILE W/GHOST 07111/05 1 ......-- -01-57IR-23 /JI :~ -, i/~1 11072871 PRODUCTION PROFILE WIGHOST 07/12/05 1 BP Exploration (Alaska) Inc_ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ,,2 J¡J JJ\T I" 08/04/05 NO. 3447 I ~'""> fD~' Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color CD 1 J3"'Cf : 1 IJ:2Jg 1 )J'7Clü _.-/ -~ Alaska Data & Consulting Services 2525 Gambe ( Street, Suite 400 Anchorage, AK 9~9~3~~38 I 'I! / ATTN- Beth _r I/'I' I~,! {I _I - -' ./ 1- í ¡¡I' Received by: ~ rv--r.~~;f( Ll t/~/?" /'..{' v II '/ - L-( MEMORANDUl\1 TO: Jim Regg K~:'/ 7( ? i CJt P.I. Supeni!!.or II. FROM: Chuck Scheve Pelroleum In~peclor Well Name: PRUDHOE SAY UNIT 16-01 Insp Num: mnCSO-W713210711 Rellnsp Num: Packer Well 16-01 IType Inj. TVD P.T. 1801360 ITypeTest SPT Test psi Inten/al 4YRTST P/F P State of Alaska Alaska Oil and Gas Consen:alion Commission DATE: Wednesda}. July 14.2004 SlIBJECT: ~1ech3nlcallmegrlt)' Tests BP EXPLOR..o\ TlON IALASK.:\'IINC 16-01 PRUDHOE SA Y UNIT 16-01 Src: Inspector NON-CONFIDENTIAL Re\'iewed By: Pol. Supr\' 5(Þ Comm API \Vell Number: 50-029-20533-00-00 Permit Number: 180-136-0 Inspector Name: Chuck Scheve Inspection Date: 7/13/2004 Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 9331 I IA 350 24ÜO ~3S0 ~370 ~ 150~:i ! OA I ~(I 150 150 150 Tubing 1400 14(10 1400 1400 Notes: Pretest pressures observed for 30+ minutes and found stable Well demonstrated good mechanical integrity. Wednesday, July 1-" 2004 Page I of I GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'FTN: Sherrie NO. 10177 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 5/7/96 Field: Prudhoe Bay Anadrill Anadrill Anadrill Floppy Well Job # Log~escription Date BL RF Sepia Survey Program Performance Disk Calculation Letter D.S. 15-9A (~J~- I ,~ Y PERF RECORD 951 222 I 1 D.S. 15-12 ~/-/~f(~ POGLM sETTING RECORD 951031 I 1 D.S. 1 6-1 ..~ PERF RECORD 9 51 21 I I 1 ... , , -- -- · , . ; , __ ,, /' SIGNED: DATE: r AY 0 7 'i990 AI.3.~k8 Oil & Gas Cons. Commission STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate_ SCHMOO-B-GONE Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development __ Exploratory_ Stratigraphic._ Service__X 4. Location of well at surface 1302' FNL, 4267' FEL, Sec. 24, T10N, R15E, UM At top of productive interval 1670' FNL, 3441' FEL, Sec. 18, T10N, R16E, UM At effective depth 2033' FNL, 2985' FEL, Sec. 18, T10N, R16E, UM At total depth 1985' FNL, 2888' FEL, Sec. 18, T10N, R16E, UM (asp's 719785, 5929642) (asp's 725529, 5934725) (asp's 725998, 5934376) (asp's 726093, 5934427) 12. Present well condition summary Total depth: measured true vertical 13020 feet Plugs (measured) 9316 feet Effective depth: measured true vertical 12799 feet Junk (measured) 9126 feet Casing Length Conductor 110' Surface 2664' Intermediate 12430' Liner 818' Size Cemented 20" 300 sx PF 13-3/8" 2882 sx PF 9-5/8" 500 sx Class 'G' 7" 375 sx Class 'G' 6. Datum elevation (DF or KB feet) RKB 73 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 16-01 9. Permitnumber/appmvalnumber 180-136 10. APInumber 50-029-20533-00 11. Field/Pool Prudhoe Bay Oil Pool Tagged PBTD @ 12799'(02/11/1999) Measured Depth True Vertical Depth 140' 140' 2694' 2659' 12460' 8836' 12197'-13015 8619'-9312' Perforation depth: measured Open Perfs 12635' - 12655', 12676' - 12696', 12705' - 12725' true vertical Open Perfs 8985' - 9002', 9020' - 9037', 9045' - 9062' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 5-1/2",17#, L-80, PC Tubing @12187'. 4-1/2",12.6# L-80 Tubi~~~.~~ 5-1/2" X 4-1/2" XO.I ~E,..,,~,/'~I V I.~,&./. 5-1/2" BKR PBR ASSY. 9-5/8" x 5-1/2" BKR SAB Packer @ 12175'. 5-1/2" OT RQM SSSV Nipple @ 2127'. MAR ~ 8 ZO0; 13. Stimulation or cement squeeze summary . Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 03/11/2002 Subsequent to operation 03/17/2002 OiI-Bbl Representative Daily Avera.qe Production or Iniection Data Gas-Mcf Water-Bbl 18078 25541 Casing Pressure Tubing Pressure 1919 2801 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended __ Service WAG INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · ORIGINAL Date March 18, 2002 Prepared by DeWayne R. $chnorr 564-5174 SUBMIT IN DUPLICATE 16-01 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/13/2002 SCHMO0 B GONE: SCMOO-B-GONE EVENT SUMMARY 03/13/02 PUMP 350 BBLS SCHMO-B-GONE 3 BPM@2200 PSI FROM SKID TO WELL, PUMP 10 BBLS MEOH FREEZE PROTECT,TURN WELL OVER TO PAD OPERATOR AT 1:00 PM. RDMO FLUIDS PUMPED BBLS 10 METHANOL WATER 350 SCHMOO-B-GONE 360 TOTAL Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown _ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_X (Cmt Sqz) 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchora~le, AK 99510-0360 4. Location of well at surface 1299' FNL, 4267' FEL, Sec. 24, T10N, R15E, UM At top of productive interval 1671' FNL, 1625' FWL, Sec. 18, T10N, R16E, UM At effective depth At total depth 1992' FNL, 2877' FEL, Sec. 18, T10N, R16E, UM 5. Type of Well: Development__ Expk)rato~__ StratigraphY__ Service__X 6. Datum elevation (DF or KB feet) RKB 73 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 16-01i 9. Permit number / approval number 80-136 10. APl number 50-029-20533 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured true vertical 13020 feet Plugs (measured) 9316 feet Effective depth: measured 12799 feet Junk (measured) true vertical 9126 feet PBTD tagged @ 12799' MD (2/11/1999) Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 300 Sx PF 110' 110' Surface 2621' 13-3/8" 2882 sx PF 2694' 2659' Production 12387, 9-5/8" 50o sx C~ass G 12460' 8836' Liner 818' 7' 375 sx C~ass G 13015' 9312' Perforation depth: measured 12635'- 12655'; 12676'- 12696'; 12705'- 12725'. I JII I L true vertical 8985' - 9002'; 9020' - 9037'; 9045' - 9062'. Tubing (size, grade, and measured depth) 5-1/2" 17#, L-80 PCT @ 12187' MD; 4-1/2" 12.6~, 13CR PCT ~ 12257' MD. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" Baker SAB Packer @ 12175' MD; 5-1/2" Otis RQM SSSV @ 2127' MD. 13. Stimulation or cement squeeze summary _ Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Avera.qe Production or Injection Data Gas-Md Water-Bbl 21098 12348 Casing Pressure . Tubing Pressure 1839 1829 15. Attachments Copies of Logs and Surveys run _ Dally Report of Well Operations __X 16. Status of well classification as: Oil ' Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ..~.~ ~. ~ Title Arco Engineering Supervisor Erin Oba Prepared by Paul Ra~f 263-4,g90 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 16-01i DESCRIPTION OF WORK COMPLETED PERFORATION I CEMENT SQUEEZE OPERATIONS Date Event Summar~ 1110111998: 11/1311998: 11/14/1998: 11/17/1998: 12/10/1998: 1/03/1999: 1/28/1999: 2/04/1999: 2/05/1999: 2/11/1999: 2/15/1999: MIRU CTU & PT'd BOPE. RIH & tagged PBTD @ 12804' MD. Pumped gelled sand slurry containing 7000 lbs of 20/40 mesh sand, to place an isolation sand plug across the open perforation intervals located @: 12645'-12655' (Zone2) RefLog: BHCS 12/31/1980. 12676' - 12696' (Zone 2) 12705' - 12725' (Zone 2) Tagged TOS @ 12640' MD. POOH w/CT. FP well. RD. RIH &tagged TOS @ 12494' MD. Reversed oUt sand to 12645' & POOH. RD. A CTU Cement Sqz for Injection Profile Modification was performed as follows: MIRU CTU. PT'd BOPE. RIH &tagged TOS @ 12645' MD. Pumped 10 bbls of Neat LARC, followed by 90 bbls of LARC w/Fiber into the open perforation intervals Ioasted @: 12606'-12628' (Zone2) RefLog: BHCS 12/31/1980. 12636' - 12645' (Zone 2) Did not develop squeeze pressure. Zone took all Cement. Contaminated Cement w/Biozan & cleaned out to 12645' MD. POOH w/nozzle. RD. FCO'd to hard BTM @ 12505' MD. Press well up to 3050 psi, bled off 230 psi in 15 min. MIRU CTU. PT'd BOPE. RIH & milled Cement to 12649' MD. PT'd to 1000 psi - passed. Cleaned out sand fill to 12770' MD. POOH. FP'd well. RD. Performed FCO f/12649' - 12840' MD. Reversed out sand to 12610' MD. RIH & milled to 11700' MD. Reversed out fill f/11772' to 11799' MD. RIH &tagged PBTD @ 12799' MD. RU ELU. PT'd BOPE. RIH w/2-7/8" guns & Reperforationed: 12635' - 12655' (Zone 2) 12676' - 12696' (Zone 2) All shots @ 6 SPF, 60° phasing, random orientation, & balanced pressue. POOH w/guns. ASF. RD. Returned well to produced water injection and obtained a valid injection rate. STATE OF ALASKA ALASK/.~' "_AND GAS CONSERVATION C(' MISSION REPORT F SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X o"~)__~ / 6. Datum o~ele/v~' r~l~,er I(B) 73' RK~ 7. Unit or Pro~ feet 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1302' FNL, 1013' FWL, Sec 24, T10N, R15E, UM. At top of productive interval 1671' FNL, 1625' FWL, Sec 18, T10N, R16E, UM. At effective depth At total depth 1565' FNL, 1843' FWL, Sec 18, T10N, R16E, UM. 5. Type of Well Development Exploratory Stratigraphic Service Prudhoe Bay Unit 8. Well number 16-01i 9. Permit number/approval number 80-136 10. APl number 50 - 029-20533 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2621' Production 12387' Liner 818' 13020 feet 9217 feet 12793 feet 9265 feet Junk(measured) Size Cemented 20" 300 Sx Permafrost 13-3/8" 2882 Sx Permafrost 9-5/8" 500 Sx CIG 7" 375 Sx CIG Plugs(measured) PBTD Tagged @ 12793' MD (12/11/95). Measured depth True vertical depth 110' 110' 2694' 2694' 12460' 8831' 13015' 9312' Perforation depth: measured 12606- 12628'; 12635- 12655'; 12676- 12684'; 12685- 12691 '; 12693 - 12696'; 12705 - 12725' true vertical 8884 - 8902'; 8984 - 9001'; 9019 - 9026'; 9027 - 9032'; 9034 - 9037'; 9044- 9061' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 12187' MD; 4-1/2", 12.6#, N-80, PCT@ 12250' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 12175' MD; Otis RQM SSSV @ 2127' MD. 13. Stimulation or cement squeeze summary ~~! V ~ 14. Intervals treated(measured) See Attached JAN 0 4 t J9,6 Treatment description including volumes used and final pressure Representative Daily Average Production or Iniection Data ~JIC~[~ OiI-Bbl Gas-M~ Water-Bbl Casing Pressure Tubing Pressure Prior to well operation .... 11362 -- 1485 Subsequent to operation 12102 -- 1489 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas__ Suspended__ Service Injector 17. I hereby certify that the forego~ct to the best of my knowledge. Signed~"'" ~) ' Title Engineering Supervisor Form 01~4 Rev 06/15/88 CC: KZ, JWP SUBMIT IN DUPLICATE 16-01i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 12/11/95: MIRU & PT equipment. 32' of reperforations as follows: Reperforated: RIH w/perforating guns & tagged PBTD at 12793' MD, then PU & shot 12635 - 12655' MD (Z2) 12708 - 12720' MD (Z2) Ref. Log: BHCS 12/31/80. Used 3-3/8" carriers & shot 4 spf at 60 degree phasing with well overbalanced. POOH w/perf guns. Noted all shots fired. Rigged down. Returned the well to produced water injection & obtained a valid injection rate. J STATE OF ALASKA ALASK)~ OIL AND GAS CONSERVATION C~' AMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory StraMgraphic Service X 4. Location of well at surface 1302' FNL, 1013' FWL, Sec. 24, T10N, R15E, UM At top of productive interval 1671'FNL, 1625'FWL, Sec. 18, T10N, R16E, UM RECEIVED At effective depth MAY 2 ;5 1995 At total depth 1565' FNL, 1843' FWL, Sec. 18, T1 ON, R16E, I)t~ 0ii & Gas Cons. Commission 12. Present well condition summary Total depth: measured 13020 feet Plugs(measured) true vertical 9217 feet 6. Datum of elevation(DF or KB) 73' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 16-01 i 9. Permit number/approval number 80-136 10. APl number 50 - 029-20533 11. Field/Pool Prudhoe Bay Oil Pool feet Effective depth: measured 12979 feet true vertical 9821 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 110' 20" 300 sx Permafrost 110' Sudace 2621' 13-3/8" 2882 sx Permafrost 2694' Production 12387' 9-5/8" 500 sx G 12460' Liner 818' 7" 375 sx G 13015' True ve~icalde~h 110' 2694' 8831' 9312' Perforation depth: measured 12606-12628'; 12635-12655'; 12676-12684'; 12685-12691 '; 12693-12696'; 12705-12725' true vertical 8884-8902'; 8984-9001'; 9019-9026'; 9027-9032'; 9034-9037'; 9044-9061' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 12187' MD; 4-1/2", 12.6g, N-80, PCT @ 12250' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 12175' MD; Otis RQM SSSV @ 2127' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 15294 18235 Tubing Pressure 1582 1612 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil ..... Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Injector Signed ""~~ '~1/2 · Form 10-404 Rev 06/15/88 Title Engineering SuPervisor Date 5- / 5: .,'~ 5 SUBMIT IN DUPLICA'Fr cc: KZ, JWP 16-01i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 4/7/95: RIH & tagged PBTD at 12680' MD. 4/1 3/95: RIH w/CT & performed a fill cleanout to 12803' MD. 4/23/95: MIRU & PT equipment. Added Perforations: Reperforated: RIH w/perforating gun & shot 40' of perforations as follows: 12635 - 12638' MD (Z2) 12648 - 12655' MD (Z2) 12705 - 12712' MD (Z2) 12722 - 12725' MD (Z2) Ref. Log: BHCS 12/30/80. 12638 - 12648' MD (Z2) 12712 - 12722' MD (Z2) Ref. Log: BHCS 12/30/80. Used 3-3/8" carriers & shot 4 spf at 180 degree phasing with well overbalanced. POOH w/perf guns. Noted all shots fired. Rigged down. Returned the well to produced water injection & obtained a valid injection rate. R£Crr. IV£g kl~kY 2, ~) 1995 Gas Cons. C0mmission Anchor~.!:,o I Schlumberger i GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9463 Company: 5/12/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log DesCription Date BL RF Sepia DIR MWD Disk D.S. 2-18 ~'(~-'c~ ~ CNT-D 042595 I I D.S. 3-19 ~'~--=]~... PERFRECORD 042095 I 1 D.S. 5-6 (31-6-10-15) _.. '~5-5(") PROD PROFILE 042095 I 1 D.S. 6-04 ~ ~--.~:~.. DUAL BURST TDT-P 042095 I 1 D.S. 7-3 ""~'-""/,/ GCT 042695 I 1 D.S. 9-30 ST1 ~5"[~_z~PERFREcORD 042495 I 1 D.S. 12-21 ~-~ IPERFRECORD ,, 042695 1 I ,,, D.S. 12-34 C~ ~ ~ ~ '~i PERF RECORD 042495 I 1 D.S. 16-1 ~)-/.~ ~PERFRECORD 042395 I 1 D.S. 17-15 (~-/~)Q PERFRECORD :. 042595 I 1 .;' .... , SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. MAY 'i,5 9.95.. Alaska 0il & Gas Co~s. L;omm~ss~on o.~3..,c b % ~'~.~: Commission Alaska 0il c. ,.,,~-. -. Ancr',orage GeoQuest r~0 w. Irdemational ~ Road ATTN: Sherrle NO. 8911 Company: Aiaaka Oil & Gc~ Cone Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 9/6/94 Field: Pmdhoe Bay Well Log Deacription BL RR Sepia RF Sepia Mylar · i~'~"' ~:~,D.S. 15-11 ~ - ~BRIDGE PLUG RECORD (8-14-94) 1 I ' 1 ~.~'('-ll- D.S. 16-~ [INJ~SU~Ey(8-!3'94) ' I 1 ~ i~Q D.S. 16-01 . INJ~ SURVEY (8-1~-94) .. 1 1 ~V- ~...[ D.S. 12-28 PERF R~RD (8-10-94) 1 1 · ~ -.~ D.S. 12-10A PROD PROFILE (8-13-94) . 1 1 -~-~ D.S.' i2-~A PROD L~ (8-12-94) . . I 1 ~Vi D.S. 12-3 PROD PROFILE (8'13-94) ,, , 1 . 1 ~'~-~ !D.S. 12-1 PERF R~RDT(8-10-94) I 1 '~ ' ~Y D.S. 6.19 PROD PROFILE (8-12-94) 1 1 7Tr ?~ D.S. 01-14 e~ S~NG RE.RD (8.11-94) 1 1 ~ ~' T~ D.S. 01 14 TUBING PUN~ER R~RD (8-1 !-94) ' 1 I ~{G D.S. 01-,~ P~ S~NG RE~ (8-14-94) ,, 1 1 ,, )~ _ ' · I I~ ~UG O, 1994 SIGN ~-. _. DATE: Please ~Ign and retum one copy ~ ~i~ ~n~al to S~ ~ ~e ~ve adding. ~k you. ARCO ALASKA, INC. F'.O. BOX i00S60 ~ ANCHORAGE, ALASKA 99~i0 -''DATE' 9-6-9i REFERENCE' ARCO CASED HOLE FINALS i-,q~' 8-i7-9i PROD F'ROFILE 2-5- 8-8-9i TEMPERATURE 2-26- 8-8-9i PROD PROFILE ~\ '~q) -'3-35- 8-3-9i GR-COLLAR 4-29- 8-i 0-9i PITS ,.~\ .o.,-~\--5-3 2- 8-i 0-9t JFWELRY v~ ,. 7-7A- 8-9-9t PROD PROFILE 7-i ~ 8--4-9i TEMPERATURE 7-2~'~' 8--t 8-9t F'ROD F'ROFILE 7-28' 8-i -9i TEMPERATURE 7-2?' 8-3-9i F'ERF BREAKDOWN/HPFM/I'EMP 9-6- 8-2-9i LEAK DEI'ECT 9-~ 8-i 9-9t PITS 9-i7~ 8-4-9i IN,J PROFILE i i-'"" 8-9-9i IN,J PROFILE ti-9" 8-4-9i LEAK DETECT i i-24-- 8-4-9i F']:TS/FIF'FM i2-3~ 8-t4-9i LEAK DETECT i2-8B'- 8-9-9i PROD PROFILE * t3-3- 8-it-9i PROD PROFILE t3-tt- 8-tt-9i PROD PROF'ILE ' !3-i2- 8-i5-9i PROD F'F(OFILE i ,-5-i 4- 8-i 6"9i PROD FR.)F ILE t 4-2,-5'- 8-i t-gl F'ROD PROFILE i5-25'--- 8-i4-9i PERF BREAKDOWN TREATMENT t6-i- 8-i6-9i INJ PROFILE i8-3-- 8-i6-9i LEAK DETECT RUN i RUN t RUN i RUN i RUN i RUN i RUN i RUN i RUN i RUN i RUN i RUN i RUN i RUN t RUN t RUN t RUN i RUN t RUN ~ RUN t RUN t RUN i RUN i RUN i RUN i RUN t RUN i PLEASE SIGN AND RETURN THE ATI'ACHED COF'Y HAVE A NICE DAY! SONYA WAL. LACE .. AT0-1529 AS RECEIF'[ OF DATA AF'F'ROVEI) 'I'RAN$~ 9 DISTRIBUTION ~-" CENTRAL FILES · ..'"' CHEVRON D & M '--,, EXTENSION EX~-LO~.ATION' '" ;.' -.-"EXXON MARATHON · "-,, MOB l L · .-F'HI'LLIF'$ F'B WELl_. FILES R & D $ BF:'X ~ STATE OF ALASKA TEXACO , 5 ' CAMCO ~' CAMCO , 5 ' CAMCO · 5' CAMCO , 5 ' CAMCO , 5' CAMCO ~' CAMCO , 5 ' CAMCO , 5" CAMCO , 5" CAMCO , 5" CAMCO , t · &5 · CAMCO , 5 ' CAMCO , 5 · CAMCO , 5 · CAMCO , 5 ' CAMCO , 5 · CAMCO ~' CAMCO , 5' ' CAMCO , 5 · CAMCO , 5 · CAMCO '--' · &5" CAMCO , .~. CAMCO ,. 5 · CAMCO , 5 · , 5 ' CAMCO , 5" CAMCO * TFIE CORRECTFD AF'I¢ FOR. i S-S IS 50-0'~9-"~03':.~5,,. ,_ .' · ARCO ALASKA, INC. F'.O. BOX i00S68 ANCHORAGE, ALASKA 995~e DATE' 8-22-89 REFERENCE' ARCO CASED HOLE FINALS 1-tA 8-t2-89 CET-THICKNE$$ RUN t-tA 8-t2-89 CORR. PROTECTION EVAL. RUN t-t 9 8-t 3-89 COLLAR/PERF RUN t , 4-6 8- t 8-89 COLLAR RUN 4-6 8-t 0-89 BRIDGE PLUG RUN 5-tt 8-t4-89 DIFF. TEMP RUN 5-tt 8-t4--89 CNL-'GAMMA RUN o5-t8 8-t8-89 CET RUN 9-t~. 8-2-89 INJECTION PROFILE RUN 9-t8 8-~-89 INJECTION PROFILE RUN 9-t9 8-4-89 INJECTION PROFILE RUN 9-25 8-4.-89 INJECTION PROFILE RUN --ii-2? 7-2-89 DUAL SPACED NEUTRON RtJN t6-1 8-7-89 INJECTION PROFILE RUN t?-~ 8-9-89 COLLAR/PERF RUN t8-te 8-5-89 I'EMP/WHUT SURVEY RUN F'LEASE SIGN AND RETURN THE ATTACHED COPY Al' RECEIF'T OF' DATA. · 2' 5' 5' 5' 5' 5" 5' 5 · 5' 5' 5' 5' 5' 5' 5" $CH $CH ATLAS' ATLA¢ ~' ATLAS A"FLA~ ATLAS' ~'CH CAMCO CAMCO CAMCO CAMCO HL$ CAMCO ATLAS CAMCO RECEIVED BY CENTRAL FILES ~ ~ PHILLIF'~ CHEVRON F'B WELL FILES D&M R&D EXTENSION EXPLORATION .~ BF'X EXXON '~ STATE OF ALASKA MARATHON ~ ~ TEXACO MOBIL THE CORRECTED AF'I~ FOR 5-tt I$ 50-n'~°-'>na~° THE CORRECTED AF'I~ FOR 9-t9 I$ 50-829-20268. DATE- 7-28-89 REFERENCE- ARCO PRESSURE DATA 3-i q' '7- 7-89 BHF'--Si'ATIC GRADIENT HLS 3-22 '?-9-89 8HF'--$i'AT lC GRADIENT 4-i 8-'28-8~ BHF'--SI'AT IC GRADIENT HLS 4-28 7-- t ~ ,~, BHF'--Si'A't'IC GRADIENT CA~CO 7-i6 ,5-~;~-89 BHF'--STAFIC GRADIENT FiLS 9-~:f:, 'F--5-87 BI4F'--S"FAT.[ C GRAD i EN F HL.S o-7 7'" ~'- 8° BHF ....STATIC GRADIENT HL~ 9--9 '7-'6-8!~ BHF'--~TATIC GRADIENT 9-- ")~1 ~ n c',c' ~-, ~-r-c,Z BHF .... STATIC GRADIENT HLS 9-28 7-6-89 BHF'--YT~TiC GRADIENT HL~ ~-25 7-~2-89 BHF'--STA'FIC GR~D].ENT CANCO ~6-~ 7-~-89 BHF'--~'i'ATIC GRADIENT HL~ ~6-6 7-8-89 BHF'--STATIC GRADIENT HLS i 6-8 T-8-89 BHP'--~'TA'/IC GRADZEN [' i 6-i 2 7--9-8~ BHP--STATIC. GRADIENT HL2' t 6-2(~ 7--8-8~ BHF'--STATIC GRADIENT HLS i6-24 7--6-8~ BHF'--STAI'IC GRADIENT .. HLS . . . .. F'WDW2-i 7-~-8~? 8HF'--STA'i"IC GRADIENT CAMCO HAVE A NICE DAY! SALLY HOFFECI<ER AT0-i529 PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. .. DISTRIBUTION ? ~ ' .-4: . . CENTRAL'.FI~E$-' L' CHEVRON'... -' D & M... EXTENSION EXF'LORAT~ON EXXON" NARATHON MOBIL F'H.[ LL I F'~, F'B WELL FILES R & D BF'X STATE OF ALASKA TEXACO I='. i-l. .p.R'× ~ O0.-4.~(.a. " 14r.%"."!z' 4; N '!",.-,: !:' l; !:' F:' f'.:. fl; Y i.-', 1:-7. i'-,! i,J I--- T T Alaska Oil & 8as Cons. ¢., T n - ~, ':~', '"..... '"'..-. Anchorage Comrnissiorl · rr.;..~.';,.'~.~ .:.~.::~:..c~:.;.-, .~/4 .'.~_...~_~.lS/t~ A P F' R' ri '...' i~' r, ,: ........ B T :"-7 T F;.< T T-: ! ! T T f"l i',J I:' ...FI.. ~.0×' ~ RFFF..RF]Nr'.F.' ~R.rt..O C¢~,~.F..I) HOLE 4--3~.':-~. 5.-2E~-,q,q F'D. K-t Go 9-?9 rS."- 27- E~ R F'DK-t Oo ~ t -'% s-27-R..p., F'DK-{ O0 i .'?- i r.'S-.'.~r~-F~,,°, F'.nl I...¢~F.'/F'I!-'F4.'FflFC.'AT 1' f')t,.J . ARCO AI_A£KA: T.N(;.. P..O, BOY ~GGM6G ANCHORAGF.-., AI...A2WA 99.5~ G · . DATE' ~-?-88 -... REFERENCE' AR~O CA~ED Hf')l.l= FTNA!_ .A.-2~/24-88 F-'F,'O !.)l ICT I r)N F'ROF II..F PF;:QDIIC...TTON F'Iq'flFTI. F F' r-;.' [i D ! ! c T T rit'.J F'[~'.FIF T. I..F PF,'[1Dt!r.T T fin F:'Iq'OT')~ !F:T'[ FiN F'F:f'IF TI F 1' N. I F. (.'t. T T f'l N I::' R.i') F' T I.. F:' F:'REIDI.IfZ'T' '[ f')N r.?r:.,f')F.:' 1:! F: F' F;.' [I 1') ! .ll"t.'T' 1' (~ N F:' R f'l F: 1' !i I: I. I!..". A K D ~ 'i" F.i: [.'. "f' T I'1N T N. I Ii' R T 1' [1N F' I:L' .0 !::' T I. !::' l::' I-~' i':] T)., r-:' F;.' I::'1 .. f.!: .--. I'i;, I;.' / "f' I!!: H P / Ixl ~ 'T' !:.." F-;.' .H I .. [') [.J I::' I::'I..EA2E 2!('.,N AN.I") R.F.:'I"III:,W 1'!--t1~: HT'I'Af'.I--IF.'D (..(.ll:..y A,., !.:.'_Fr.r.]P"f FIF' " R E! E ' ' (./' A[ P, 1 :.: · HAVE A NICF DAY! ..¢ Na$~G Oil & Gas Cons. Oommissjon F' r:: ~; f:; V l.:~ F. N N Il.!: T'T' Anchorage A'I" Fl- t ..... .' . l') T .% '1" F-;..' T R I I T l' ('11N RIIN R!IN RI.IN RI. IN RIIN RI.IN R'I. Ii'-J R',! IN RIIN R'l..IN D A'r n .. C. AHCF! C..AHF: f! F: A H C. f'! · . f': A H f": IT') EAHCf'i P. A H F: 1:! ~ C'. rE N 'f' !:;.' A !... F:' '[ !... I:E .R · ,-'"' [': H !!:' V !:;,' ('1 N r:T ~; T F!' N .'? T (] N F. ¥ F' I.. f'l R' A T T f'! N F" Y.. ,v, f.] N H A F;: A T H f'l DJ .,,.'"' M C) B I L. :,",: I::'!-t ]' I !. T F'.'? F:' R l.,J I:: I. I.. F T ! I::i 2 F;: :-": :,": STATE f')F AI.A,?I(A ~: '!" Fi .Y.. A 13: f') ARCO AI..A,.~KA., T. ANCHORAGE: 995i0 DATE' .A-t 0-88 REFERENCE. ARCO CAKED HOLE FTNAI_ t-t~ in ~-5-.7 t-J4 tt-25/2A-87 COI..[ AR/PERFORATTON 2-5 ti-SG-g7 CgI_I..AR/PERFORATTON 5-t t4-~-87 COl..EAR/PERFORATION 3-2 tt-5-87 C~I._I..AR/PERFORAT~QN 5-4 ~2-t6./tR-R7 C~I..I. AR/F'ERFORATT~N 5-4 tt-i'~-~7 COI. I..AR/PF~FRRATTRN 5=8 tt-26-87 C~I..I...AR/F'ERFBRATTRN ?-& . t~-?-~'7 CRI..L. AR./PERFRRATZON 7-t5 tt-&-R7 Cf]I._I.AR/PERFORAT~RN 7-t7 ti-A-R7 CRt.[..AR/PFRFORATTON 4~-~ 't4-2~-~7 ~,,. 44-20-R7 COI..[,AR/PF~F~RAT!RN t?-~ 42-A-R? £f]I_I..AR/F'ERFORAT~ON RUN t : RI. IN t. RllIN '~ . RllN t, RI.IN t , RUN t, RI.IN ~ : I;.'IINt, RI.IN i, RUN i. F,'!.INt: RI. IN i. RIlN t, R'I.J Nt. RUN i: ~ ~cnsrage .;.. PEr;gY ~ENNETT AT0-t52~ DATA., AF'F'R. OVEI) OT,~TRTRIITT. ON -,-'" CENTRAl. .......F'[I E,? -,.- PHII...l...'[P,.g' ¢ CHEVRON F'R WELl... FTt. F.,? D & M ~ E)~TEN,~ I ON FXF't..ORATT FIN ~ ..? A F' F: ~ EX"ON '""-~" ,.~TATE ' OF AI._ARKA .... -~ . MARATHON 5 TFYA,.P.R ~' NOR .T.I... · ~- .,. ARCO Alaska, Inc.( Prudhoe BaY ,-ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 10, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 16-1 Approval No. 7-31 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations formed on the above-referenced well. Very 'truly yours, D. F. Scheve DFS/TAB/jp Attachment CC: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 16-1)W1-3 detailing work per- RECE. I¥£.O · · ~l ,.:~ 0il & Gas Cons. Anchorage WELLS/25 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE Of ALASKA ALA , OIL AND GAS CONSERVATION CO $SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [~ 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 73' RKB Feet 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 1302' FRL, 1013' ~T~, Sec. 24, T10N, R15E, t~ At top of productive interval 1671' FNL, 1625' Fk~, Sec. 18, T10N, R16E, U~ At effective depth At total ~,~_~t,h 1565' 1843' FWL, Sec. 18, T10N, R16E, UM 7. Well number 16-] 8. Approval number 7-31 9. APl number 50-- 029-20533 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 13020 feet 9217 feet Plugs (measured) Effective depth: measured 12979 feet true vertical 9821 feet Junk (measured) Casing Length Size Cemented Structural Conductor 110' 20" 300 S× Surface 2694' 13-3/8" 2882 S× Intermediate Production 12460' 9-5/8" 500 S× Liner 818 ' 7" 375 SX Perforation depth: measured 12606-12628', 1"2712-12722' true vertical 8884-8902' , 8975-8983' Tubing (size, grade and measured depth) 5~", L-80, 17# o 12250' Packers and SSSV (type and measured depth) Baker SAB Packer @ 12175' MD, Otis RQY SSSV @ 2127' KD Measured depth 110' 2694' 12460' 13015' ~ue Verticaldepth 110' 2694' 8831' 9312' REEEIVED 12. Stimulation or cement squeeze summary Intervals treated (measured) Attached Treatment description including volumes used and final pressure k~-~ska 0il & Gas Cons. C0mmissi0~: Anchorage 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 10500 400 Tubing Pressure 450 2690 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 2~~7~ Form 10-404 Rev. 12-1-85 WELLS/25 Operations Engineering Manager Title Y. A. Biiiingsiey, ATO-15OO, 265-6871 Submit in Duplicate¢ 10/25- 11/1/87 Perforate: 12712-12722, 12606-12628, DS 16-1i COILED TUBING CEMENT SQUEEZE INJECTION PROFILE MODIFICATioN Pumped 70 bbls cement With additives through COiled tubing. Obtained Squeeze pressure of 1600 psi and held for 1 hour. Unable to contaminate due to premature set of cement in Wellbore. Drill out cement With underreamer on COiled tubing. Drill from 12420-12815,. 1/2 spf Well WOuld not take injection. Reperforate: Ref. BHCS 12/31/80 12606-12628, 12712-12722, Ref. BHCS 12/31/80 1/2 spf REC iYED: AIaslea 011 & Gas Cons; Commissic,~ A~chorage WELLS/25 ARCO AI..A~KA; INC. P.,[.I, ~DX ~ 00~60 ANCHORA[;E ~ AI...A~K A DATE' REFERENCE: ARCO CA,ED HOI_E FINAl... COI...I._AR/F'ERFORAT I ON I...0 [, COI...L AR/F'ERFORAT.T DN LOG COI...t..AR./F'ERFOR. AT I 0 N I...0~ ,RI.IN ~, 5' 'El. IN 'i-R, %" RUN t -8: 5' F'I..EAYE ~IGN AND RETURN THE ATTACHED COPY AY RECEIPT OF DATA.. REC;,EIVED BY HAVE; A NICE DAY! PEGGY BENNETT AT0-.t529 TRAN,.~ $88G48 AF'F'R.OVED___ .RI. IT I [iN GEAR'. CE. NTRAI... F I I...E,? C. HI:-. VRON D ~ M EXTENYTON [-:,XF'I...ORAT I ON EXXON MARATHON MC)B.. I L. F' H ]: I... I....T. F' ,.s,' F'R WE.I.. 1.. t.. ~ ~.AFC .,,-~'- ,.~TATE OF' AI...A,~I,/~ -,,--"' TFXACO.. ARCO ALASKA, INC. F'~O. BOX i88368 ANCHORAGE, ALASKA DATE: t2-24-87 REFERENCE' ARCO CA£ED HOLE FINAl... ._ · . q-t 8 i 2-7-87 LEAK DET./~.F'.TN/TEMP RUN t , .,... . t 2-t t 2-.5-87 PI.IMF'-IN/TEMF' R!JN i t 2-9 t 2-6-87 PUMF'-IN/TEMP RIIN j::~' i 2-t 4-87 C, AI...IF'ER RUN i, 5' F'L. EA,,.~E 5ION AND R'ETI..IRN THE ATTACHED COPY A,~ RECEIPT OF DATA., D HAVE A NICE DAY! ~,~aska Oil & Gas Cons. Oommis$lo,~ Anchorage PEGGY BENNETT ATO-i .5.29 TRAN~ ~877(~5 APF ROV~:..D DISTRIBUTION CAMCO CAMCO CAMCO CAMCO $ C, ENTRAI... F I LE,~ · ,,-'"' CHEVRON D & M · ,,-~EXTEN,~ION EXFi...ORATION ~~ EXXON MARATHON ~~ MOBIl.. PI..I I t..I... I F' S PB WEt..[.. R & D £AF'C STATE. OF ALASKA TEXACO ARCO Alaska, In~~ Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager January 12, 1987 C. V. "Chat" Chatterton Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 16-1 Permit No. 80-136 Dear Mr. Chatterton: Attached is the "Intention" Sundry Notice the above-referenced well. Very truly yours, D. F. Scheve DFS/TAB/jp Attachment cc: Standard Alaska Production Company PI(DS 16-1)W1-3 detailing work performed on WELLS/25 ARCO A~aska, Inc. is a Subsidiary o! AflanticRichfie~dCompany APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 73' RKB feet 3. Address 6, Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 1302' FNL, 1013' FWL, Sec. 24, TION, R15E, UM 7. Well number 16-1 At top of productive interval 1671' FNL, 1625' FWL, Sec. At effective depth At total depth 1565' FN[, 1843' FWL, Sec. 18, TION, R16E, UM 18, TION, R16E, UM 8. Permit number 80-136 9. APl number 50- 029-20533 10. Pool Prudhoe Ba~v 0i] Poe] 11. Present well condition summary Total depth: measured true vertical 13020 feet 9217 feet Plugs (measured) Effective depth: measured 12979 feet true vertical 9821 feet Junk (measured) Casing Length Size Cemented Structural Conductor 110' 20" 300 SX Surface 2694' 13-3/8" 2882 SX Measured depth True Vertical depth 110' 110' 2694' 2694' Intermediate Production 12460' 9-5/8" 500 SX Liner 818' 7" 375 SX 12460' 8831' 13015' 9312' Perforation depth: measured 12551-12722' true vertical 8910-9056' Tubing (size, grade and measured depth) 5½", L-80, 17# o 12250' Packers and SSSV (type and measured depth) Baker SAD Packer @ 12175' MD, Otis RQY SSSV @ 2127' MD 12.Attachments Description summary of proposal [] Detailed operations program 13. Estimated date for commencing operation 5/1/87 14. If proposal was verbally approved Name of approver Date approved 15. I hereb~ certify/t~a~)the/~oregoing is true and correct to the best of my knowledge Signed ~,'~,,~t~/~ Title Operations Engineering Manager Date Conditions of approval Commission Use Only Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI q Approved by ~eturn~ld .~ Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 WELLS/25 T. A. Billingsley, AT0-1506, 265-6871 Submit in triplicate DS 16-1 PRELIMINARY PROCEDURE CTU CEMENT SQUEEZE FOR INJ. PROFILE MODIFICATION me 2. 3. 4. 5. e 7, 8, Pull SSSV. Tag PBTD. Last PBTD was 12928 on 3/6/86. Load tubing with diesel so positive pressure can be seen at surface. RIH w/CT, Tag and flag TT. Move nozzle to within 10' of PBTD. Lay in 14 bbls normal fluid loss cement (50 cc +_20 cc after 30 minutes) to cover perfs. Rathole volume 12928-12722 = 7.7 bbls 26.92 ft/bbl Perf volume 12722-12552 = 6.3 bbls 26.92 ft/bbl 14.0 bbls With nozzle at 12550', pump 10 bbls of high fluid loss cement (100 cc +_20 cc after 30 minutes), m Follow with 10 bbls normal fluid loss cement to push high fluid loss cement into formation. Hesitate as necessary to obtain squeeze pressure of 5200 psi BHP. Shut down. Pick up nozzle to safety point of 11750'. Hold squeeze pressure for 45 minutes. 9. GIH contaminating cement to PBTD. Leave positive pressure on well. 10. WOC 12 hours. 11. Reverse out contaminated cement. 12. Wait one week. Test for injectivity. 13. If perfs are still taking fluid, pump second squeeze. 14. Reperforate: 12598-12628' 4 SPF 12638-121~48' 4 SPF 12676-12696' 4 SPF 12712-12722' 4 SPF 15. Return Well t~ in'ec~. 16. Run injection profile log. Ref: BHCS 12/31/86 TAB/45 3 2 ! ,I 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSi 4 1/6" FLOW TUBE PACK-OFF HIRELINE BOP EOUIPHENT I I iii 6 5 4 2 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSi 4 1/16" PIPE RAMS ,%. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PS1 4 1/6" BLIND RAMS 6. 5000 PS1 4 1/16" STUFFING BOX CO ! LEO TUB ! NI3 UN ! 1' BOP EOU ! PMENT ARCO Alaska, Inc.( Prudhoe Bag ,~ngineering Post Office Box .100360 Anchorage, Alaska 995'10-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June 9, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: DS 16-1 Permit No. 80-136 Attached is the "Subsequent" Sundry Notice detailing work performed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/WWP/plt Attachment cc: Standard Alaska Production Company File Pi(DS 16-1)W5-4 RECEIVED ,Alaska Oil & Gas Cons. Commission Anchorage WWP2/136 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ ALAb--(i~.., OIL AND GAS CONSERVATION COJ...SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 73'RKB Feet 3. Address 6. Unit or Property name PO Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 1302'FNL, 1013'FWL, Sec. 24, T10N, R15E, UM At top of productive interval 1671'FNL, 1625'FWL, Sec. 18, T10N, R16E, UM At effective depth At total depth 1565'FNL, 1843'FWL, Sec. 18, T10N, R16E, UM 7. Well number 16-1 8. Approval number 80-136 9. APl number 50_029-20533 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 13020 feet Plugs (measured) 9217 feet Effective depth: .measured 12979 feet Junk (measured) true vertical 9821 feet Casing Length Size Cemented Measured depth Structural True Vertical depth Conductor 110' 20" 300 SX 110' S u rface 'r'. ~7~ ' Intermediate 2694' 13 3/8" 2882 SX 2694' Production 12460' 9 5/8" 500 SX 12450' Liner 818' 7" 375 SX 12197-13015' 110' 2661' 8839' 8633-9326' Perforation depth: measured 12552-12582'; 12598-12628'; 12638-12648'; 12676-12696'; 12712-12722' true vertical 8925-8951'; 8964-8990'; 8998-9007'; 9031-9048'; 9062-9070' Tubing(size, grade and measured depth) 5½", 17~, L-80 PCT Packers and SSSV(type and measured depth) Otis RQY SSSV @ 2127'MD, Baker SAB Packer @ 12175'MD 12. Stimulation or cement squeeze summary RECEIVED Alaska Oil & G,~s Cons. Comtniss[on 13. Intervals treated (measured) 12598-12628'; 1.2638-12648'; 12676-12696'; 12712-12722' Treatment description including volumes used and final pressure 3000 9al of 15% HCl & 4000 9al of 12% HC1 - 3% HF; Final Pressure 3490 psig Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (Injection Well)' 5784 BWPD -- 447 psig Subsequent to operation (Injection Well) 8279 BWPD -- 230 ~3sig... 14. Attachments DailyReportofWellOperationsl~ CopiesofLogsandSur~ ©.,:,.3 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ' /_O- '- Signed Form 10-464 Rev. 12-1-85 Titleoperations Engineering Manager Submit in Duplicate Drill Site 16-1 Selective Stimulation Summary 3-6-86 MI & RU Camco slickline unit. WIH w/3.500" gauge ring and tubing tail locator. Tagged 12,928' PBTD. POH & RD. 3-16-86 MI & RU FracMaster CTU. WIH w/tubing tail locator on 1%" CT. Located tubing tail at 12,288 CTMD. Corrected CTMD & flagged CT. WIH to 12,800'CTMD, no obstructions. POH. PU & RIH w/3 3/8" inflatable coiled tubing packer with hydraulic disconnect and equalizing sub. RIH to 12,590'CTMD (corrected with CT flags). Dropped 5/8" aluminum setting ball. Pumped 20 bbls of diesel behind ball, shut down 30 min. to allow ball to seat in shear pin assembly. Pressured up CT to inflate packer, shear pin assembly sheared at 2400 psig surface pressure, 1600 psi differential BHP. Tested packer with 3000 lbf weight set down -- no movement. 3-17-86 MI & RU Dowell-Schlumberger. Tested acid as follows: HCl: 13.8% HCl w/24 ppm Fe HF-HCI: 3.3% HF, 8.8% HC1 (no iron measurement performed) Re-blended HF-HC1 and re-titrated. HF-HCl: 2.6% HF-11.1% HC1 w/43 ppm Fe Pressure tested all surface lines and stimulated well while pumping SW down CT-5%" annulus ARO 4.28 BPM as follows: 2000 gals of 15% HCl w/0.4% A250 and 20#/M gal L-58 4000 gals of 12% HCl - 3% HF w/0.4% A250 and 20#/Mgal L-58 1000 gals of 15% HCl 2/0.4% A250 and 20#/Mgal L-58 35 bbls of diesel Attempted to shear set pins and open equalizing sub with straight pick up. Unable to shear pins. Unable to release packer. Dropped 7/8" aluminum ball to activate hydraulic disconnect. POH w/CT, release CTU. 3-20-86 MI & RU slickline unit. WIH w/overshot & grapple. Latched cutter bar. POH. WIH w/spear, punctured bladder of inflatable packer. POH WIH w/overshot & grapple. POH w/packer. WWP2/136 ARCO A-"-a~ska, Ir, c. Anchorage: .A ~' er-ka DATE' Apl- i k 2! . i'.7--'8& REFERENCE' ARCO Ce:smd Hole cin.:::L DS ?-7A I 2-27-86 DS 7-8 ! ?-28-86 D.S-.7-'.--.--' i 7:-27-~:6 DS 7--i 4 a..- ~.. : ,~ , .,-- ,-- CN!_ Mu i-I'i-Sp_=..ce C'i"..:h Ntt L CNi_ :.e.~u :. "~' i -Space E:NL Mui.{ i Space F'_=,.'.,- !"c.,i- .~ ± i ¥'..,g Run i 5' ,5..'ch ~ u-.-". , ' Ft.-'--; Rk:i', 'i, ...; Camco DS ~6-{ 5-50-E;6 l,-~'. F'rcfi Le ¥-~.~,'~p Run i 5' :":.:.-.~.':.c:. '-.3A Pi¢.:,.=.=:,= ---:.i.-:.-,-, ;,~",d ',-ei'urr~ ~.~ ai:i'ached c.c:,py a:-.':. ',-ec~ipt c.,i:" data.. HAVE A N I,_.,_r'c' T',Ay... '. i. r ,,'r~a Carl ATO-i 429F TRAN$ ¢86242 U':T ?TC,? .'.-i C:en±ra [ F ;.=-- Ch ev~:- o'n &... :_? ~ L:il × "t.. e n s i o ':-.~ I!!' x ? [ c.- '.-- a ~. :, c.:,'n ~ ....... ~ Stata of A[ms-J<a .-.- i E" X .3 C ARCO Alaska, Inc( Prudhoe B~y r_:ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager February 24, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 16-1 Permit No. 80-136 AttacheJis the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D F. Scheve DFS/WWP/plt Attachment CC: Sohio Alaska Petroleum Co. File Pi(DS 16-1)W5-4 ARCO Alaska, inc. is a Subsidiary of AflanticRichfieidCompany STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-136 3. Address 8. APINumber P.O. Box 100360, Anchorage, AK 99510 50-029-20533 4. Location of Well 1302'FNL, 1013'FWL, Sec. 24, T10N, R15E, UM (Surface) 1671'FNL, 1625'FWL, Sec. 18, T10N, R16E, UM (Top Prod) 1565'FNL,' 1843'FWL, Sec. 18, T10N, R16E, UM (TD) 5. Elevationinfeet(indicateKB, DF, etc.) 73' RKB 6. Lease Designation and Serial No. ADL 28346 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 16-1 11. Field and Pool prUdhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate E~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. intends to perform a selective 'stimulation to improve the injection profile of the Well. The treatment'will be performed as follows: 1) GIH w/inflatable coiled tUbing packer on ~ CT and set at 12,590'MD. 2.).i Stimulate well down CT with: 2000 gal of 15% HC1 W/additives ~4000 gal of 12% HC1-3% HF W/additives 1000 gal of 15% HCl W/additives displace from CT with diesel 3) POH & return well to SWI 4) Obtain new injection prOfile. RECEIVED FEB28Lq Oil & Gas Con~. (Jmmntssion A. oc~rage 14'' herebycertifythatthe~°'~ngistrueandCOrrectt°thebestOfmykn°wledge'~~~ ~ _ . Signed Title Operations ~nc~n~r~nc _r The space below for Commission use Conditions of APproval, if any: ' By Order of ~ ...... ~ ~ ~ ~ ~ '~ COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.{f'' Post Office~b,.,x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 24, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 16-1 Permit No. 80-136 Attached is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS:JEB:dp Attachment cc: SOHIO Alaska Petroleum Co. File Pi(DS 16-1)Wl-3 '~ChorCa°g~~' Cor~/~is~io~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATIONCOMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~× OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 1302' FNL, 1013' FWL, Sec. 24, T10N, R15E, OM Producing Interval: 1671' FNL, 1625' FWL, Sec. 18, T10N, R16E, UM (Top Prod) Total Depth: 1565' FNL, 1843' FWL, Sec. 18, T10N, R16E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 73' RKB ADL 28346 12. 7. Permit No. 80-136 8. APl Number 50-- 029-20533 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 16-1 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska Inc. intends to selectively stimulate DS 16-1 to improve the injection profile of the well. The operation will be performed in the following manner: 1) MI and RU CTU. GIH with inflatable treating packer and set packer at 12,590' MD. 2) Stimulate the well with the following solutions: - 2000 gallons of 15% HCL with additives, - 4000 gallons of 12% HCL - 3% HF with additives, - 1000 gallons of 15% HCL with additives. All displaced to the formation. 3) ~ POH and RD. 4) Obtain injectivity profile; if unsatisfactory continue with stimulation. 5) MI and RU CTU. GIH with inflatable treating packer and set packer at 12662' MD. 6) Stimulate the well with the following solutions: ~ :i'~ C ~ I V ED - 1500 gallons of 15% HCL with additives - 3000 gallons of 12% HCL - 3% HF with additives - 1000 gallons of 15% HCL with additives. All displaced to the formation. 7) POH and RD. 14. I hereby,qertify that the,,~oregoing is true and correct to the best of my knowledge. Signed , ,, .. w Title Operations Engr. Manager The space below for Commission use Date Conditions of Approval, if any: Approved by Form 10-403 COMMISSIONER By Order of - -1- 1'01~'~/~ the Commission Date ~ Submit "intentions" in Triplicate Rev. 7.1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. -;-' :.. Post Office E,,._/100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: October 17, 1985 Reference: ARCO CH Finals 9-16 Spinner Run 1 5%' 'Camco 9-28-85 '~ ~" 11-9 Temp 1 5" Camco 10-8/9-85 ~6lI:::'. ?,Sp ~nner 1 5 Camco 9-29-85 ~ "-/ 16-14 'Spinner 1 5" Camco 9-29-85 Pam Lambert ATo 1429C Trans 359 ~,~vron. -Phillips- D & M PB Well Files ~xpl. Services R & D -Ext. Exploration S~hio Exxon :: $~a:e. of Alaska Marathon .~mx. aco ARCO Alaska, Inc.(~ Prudhoe Bay ~-ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer August 22, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: DS 16-1 Permit No. 80-136 Dear Mr. Chatterton: Attached is the "Subsequent" Sundry Notice for work completed on the above-mentioned well. Very truly yours, D. F. Scheve DFS:JEB:pr Attachments cc: SOHIO Alaska Petroleum Co. File Pl (DS 16-1) Wl-3 RECEIVED 2 9 ~:;~,~ c,, b~s Cons, Commission ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATIONCO,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-136 3. Address 8. APl Number P.O. BOX 100360, Anchorage, Alaska 99510 5o- 029-20533 4. Location of Well 1302' FNL, 1013' FWL, Sec. 24, T10N, R15E, UM OTHER [] 1671' FNL, 1625' FWL, Sec. 18, T10N, R16E, UM (Top Prod) 1565' FNL, 1843' FWL, Sec. 18, T10N, R16E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 73' RKB I ADL 28346 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 16-1 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 08/12/85. RU perforating unit and pressure tested equipment. RIH with gun #1, shot interval 12712' - 12722' MD (4SPF). Shut in well, POOH, all shots fired. RIH with gun #2, shot interval 12676' - 12696' MD (4SPF). Shut in well, POOH, all shots fired. RIH with gun #3, shot select-fire interval 12638' - 12648' MD (4SPF); pulled up and shot select-fire interval 12618' - 12628' MD (4SPF). Shut in well, POOH, all shots fired. RIH with gun #4, shot interval 12598' - 12618' MD (4SPF). Shut in well, POOH, all shots fired. Secured well, RD. Ref: BHCS 12/31/80 RECEIVED ~.~aska 0ii & Gas Cons. C0mmissior Anchorage 14. I hereby_certify that the foregoing is true and correct to the best of my knowledge. Signed 2~'~~ ,~~ TitleRegiOnal OperatiOns Engineer Date ~;'/~-~/~'~" The space below for Commission use ~ c~" ~ '- %~ Conditions of Approval, if any: _ ~..-.~,___~~_...~ Approved by By Order of COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~,,, Prudhoe BayEli teering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 22, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil'and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-6 DS 3-7 DS 3-10 DS 3-18 DS 4-6 DS 4-8 DS 4-11 DS 4-14 DS 4-15 DS 9-8 DS 9-10 DS 9-12 DS 9-14 DS 9-15 DS 9-16 Permit # 76-60 Permit # 76-53 Permit # 79-21 Permit # 79-103 Permit # 76-42 Permit # 76-10 Permit # 78-6 Permit # 78-36 Permit # 78-37 Permit # 76-70 Permit # 76-82 Permit # 77-7 Permit # 77-25 Permit # 77-36 Permit # 77-37 DS 9-18 DS 9-17 DS 9-19 DS 9-20 DS 11-2 DS 16-1 DS 16-2 DS 16-3 DS 16-5 Permit f! 77-39 Permit # 77-38 Permit # 77-40 Permit # 77-41 Permit # 81-128 Permit # 80-136 Permit # 80-150 Permit # 76-83 Permit # 81-37 DS 16-10 Permit # 80-04 DS 16-11 .Permit # 80-118 DS 16-16 Permit # 80-127 DS 17-6 Permit # 80-132 DS 17-8 Permit # 81-74 DS 17-10 Permit # 81-97 Dear Hr. Chatterton: Attached are Subsequent Sundry Notices for work completed on the above-mentioned wells. Very truly yours, D. F. S cheve DFS/JEB/mjb R ECE I VED At t achment s JAN 2 !985 cc: Sohio Alaska Petroleum Company Alaska 0il & Gas Cons. commission Anchorage ARCO Alaska, Inc, Is a Subsidiary of AtlantlcRIchfieldCompany ALASKA IL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] Name of Operator ARCO Alaska, Inc. 3. Address P.O. :Box 100360, ~chorage, kl.aska 99510 COMPLETED WELL]~ OTHER [] 4. Location of Well 1302' FNL, 1013' FWL, Sec. 24, T10N, R15E, UM 1671' FNL, 1625' FWL, Sec. 18, T10N, R16E, UM (Top Prod) 1565' FNL, 1843' FWL, Sec. 18, T10N, R16E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 73' RKB ADL 28346 7. Permit No. 80-136 8. APl Number 50- 029-20533 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 16-1 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. has converted DS 16-1 to water injection service. The well is part of the Flow Station 2 waterflood project. The well began receiving water on June 24, 1984. RECEIVED J A N 2 Alaska Oil & Gas Cons, C0mm!ssi0. 14' I hereb~tify ~~~~rect tO the best Of my knOWledge' Regiorlla]. Engineer Signed 4J~' ~ _ . _ Title The space below for Commission use Conditions of Approval, if any: ! Approved by By Order of COMMISSIONER the Commission Date Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate · .. A?.en A[--:k-- Inc~ F:'..O. Box 1,9,,93;6¢:, Anchorage, A i.a£ka '..) 9 c't ¢, DATE' December 2t, 1984 REFERENCE' ARCO F'ressure Data I). S . 9-6. t 6.:,- I t _ .c.,,,_,_.. F'BU P.....*"I 2-4 I I -26-84 3-. 1. I), £ . I 2-8, B I i --'~6-84.:. .'-";1' a f:,. $ .i 2-2,3 i i -~6-84,:. S'f D :-;' I"~--'-'i i i-Sr.; 84 D 3 i 2-~n I "'~-I-84 3t'a D. S , t 2-23: i '">- t --84. ...":'"" D £ I"~ "~: ''- -' o 3-.1. D.. ,..,<". t-..n-- n":,:. , t ,..~--=-8~,., ,; D, 3 i -'-,_ ~ o t .,..':'-"i -84 £,4. D '"' t R-: i 1:-i ,'-,..,~. . · . ,.:. .... -- o ,, ¢' f D,3,., 13-4 1t-i?'-84 ' D,S;, I3;-6 1i-t9-84 D.Z. i2;-7' tt-!7 84 Y't'a I) <'. .... ,. ¢..i ¢,-t x,... i I -i 9--°,*,.,-,. ,..:¢' t .,,.:., ';~,-t4. ~, i i-I°-84.. !-."!'a D ,S' I 4-t '"' i I -f 6-84 $ t6-t o.-I '"'/' . . , -o'* F'DD D. £'. i 6-6 9'-22-84 F:'P,U D.$. f6-9 3-! 9-84. .?.1'a I:'. 5' . t 6-' i i ?::-" i c;,,_ ?, 4 2 t: 'r, :'7 i-" = 9-26-84 Pt:.:LI .t..' ... ¢. ~' ~ ,..,,.~ . , _ i) .'.. i ~'- =' . . , '.;. i:;-'i ,,-c>4,-, P[eas'e sign a:~d re1.ur'n ~, Ltl- t: i c f,-rad i el"11. o t'ic 6radien't: · t'ic E. radien1. t.' i c C_,-rCd i e'nt t'ic 6, radie'nt 'tic Gradien't' tic rJrad i en't' l'ic E. radien1. 1.lc E.r ad i er~'t' · i:. i c Grad i eh't: ±ic Gradien't' l'ic Graclien~. ~,:ic bradier, t 1.'ic Graciient t i c brad i en'l' t'ic Grad ien't' ,r', 'v'e · ". ti i- ',,: :.:/u.'r' v e'y 1'lc Gradien1' 4.,. ic [.:radier~* ,%'ur vey 1. i c [-.'~ad i enl. the a1.'t'ached copy as receip1. of da 1.a., F;.:ecei red By £EAYONZ E,-REET ]: NC:':?; I<e[ [¥ Mc:F:ar La'nd "' .-"n- i ', '""OF TRA~'<' ~I: ,":,~ . 422 Alaska Oii & Gas Cons. C0mmiss!0n Anchorage I) ]: 3 T R I B U T ]: 0 N C h E, v l- 0 !'i i) & ~ E::..-..'p i. ora't' ior~ 3err i ce:_--. E x '~: =,'-, '" i c:. :-~ E x ¢. I, .=. t:-:' [ 0 i' a ,. i 0 ii Ex G e i: t y Pi a r a 1. h o Mob i [ Hr-,bi ~. E ;;:, 'F' Phi !. ':. i p '--.: F'rudhc, e Bay We[[ R & D 3oh i c, ~' 4- 4- .... a ,.e (:.','f' Rl.a.-..~l.::a F'i Le~: ARCO ALas'ka, Inc. I:'~0. Box ~0036~ Anchorage, ALaska 9951~) DATE:' October 4, t984 REF:'EF,:I!.-'.NC;,E' ARCO F're:s.sure Da 't: a D., 3', i 4.-.. 8 '/ 9-.- t S---. 84 ,'.'.;: t: a 't' i c 3' ti r v e y D., ,:,, i 6- t '" 9 - f .... '::::.... -.,. '* ,:'i: -t.. e r.:' R a -i.. e D a -t-. a D 6 .... 'i 6 -'"" 9 .... 'i 2---. 84 e. x :~: u. r ,?. F:'a I.I. 0 '1"' "~ · (~l-"' i. e a ~: e :.'-:; i g i',. a 'nd r e t: t.t r l"~ t: h e a t: -f a c h e d (:: o p y a f-..' i" e .r.: e i p 't' I.-IAVE A NICF DAY! Kel. t.y HcF:'ar I. and Aiaska O;l & 8~s Co;Is, Comrnissiort ATO .... t 429F A,nchoreo~ · · T'-; '*' "~ :* ::: .'7 ' r,, ~--,,'..,' .:. ,. ;5 8 C· ¢.:t fil C: 0 Ca mc o DA C a f~l C 0 ['-:a ¢~1 c: o Ca f~(:: o C ....'.1 i'll (] 0 C;O c, f d a +. a ~ D I g'l' R I B LJ T I 0 N Ch err on D &M Exp I.c, ra~: ion ~¢erv i,'.::e.'..z E x t e n.'._.: i o n E x p L o r a t: i o ~"~ "E x x on Getty M a r a 't' h c, n ARCO ALaska, Inc· P.O. Box i00360 Anchorage, Alaska 995; i 0 DATE:' C)ct.'ober:..':', i 9q4. ,~ kEFI=REN(.'.E · ARC(] Ca.s'ed HoLe l"emper a t.. u. re l...og C: I.':' .?.." / ;!.:.' p i 'nner a.l: J'nner Log (.; t:;.'. E I::' i t. c, g / S 1:'-' a ~:.'...~' o v e r t. a y C:: (.';I... f,:::, ;" .s e t' '~' i 'n,.;l t3 ;'- i d g e D J 'F 'f T e ~','~ p 1.. c, g F:' I. u. g 5;" I:.T II ,...- I::.' I! · ") II I::,' ti t:' Il ,.,;- C: @ m c: o C: a m c c, DA DA G C) I I~ , I ]'n a'nd r e 't' u':" 'n 1.- h e a i: -~- a ,.':: h e d ,:: c-., p y d a t' a. i< e I. I. y H,::: I::' a r I. ¢'..', 'nd AT'C] .... i ,-'l. 29F' Alaska Oil & Gas Cons. Commission Anchorage 'T' t:;,' A N .'.":,' '"' ':" ' ,. 'ir,.; ~ ~) D ]: ~'~: T R :t: B U 't" t C) N Chevron I) & H ExpLor'a't'ion Services Ext'en.~f. ion Expi. oraf. ion Exxon Get'fy H a ;" ,::', t h o n Mobi L Hc.',bi I. E & I::' Phi L L i p.s' I::'ru. dhoe Bay WeLt. R & D 3'oh i o t::' i I. e s' ARCO Alaska, Inc. F'. O. Box t Anchorage, Alaska DATE' Oc:tober 4, t784 REF=E:RFNCE' ARCO I='ressure Data I),$, t2-4 / 9-t3--84 $'tatic Survey Camco D, 3' , ' 1 2--9 ~ 9-.t 3--84 Static Survey Camco D.$. t3-.t3,X 9--i2-'84 .~" 3-' D ~. ~.. t4 9-.t2--84 Static Survey $'ta'tic Survey C m m c o GO t4-8 / 9-t3-84 Static Survey Camco D, $, t 4 .... t :..~ ?..- t 3.... 84 $ 't a ~ i c: S u r v e y C a m c o .. D.S~ t4'-26,/' 9-"t 4-.84 5"tatic 5'urvey Cam(:o . C a m c o t6-.t '" 9-..t-.F~4 Step I:;,'ate Data ~.~6 .... t 6 '"' 9..- i '".-.Iii 4 PI. ease '.;ign and ret'urn · the attac:hed copy as rec:eipt of da'tm, .., D R eceive(:l B~ ........... HAVE: A NICE I)AY! L,',..~ :.J. ~. KeI. Ly HcF'arLand ATO .... t ,129F:' · v' 6 z,J ~,] ,~ :,".' 3 '? 8' Alaska U;I &,:.'~o Cons. D I S 1' R I B U T I 0 N Chevron D&M Expl. oration Servi,.-e.s Extension ExpLoration E x x on Getty H a r a 't h o n Les'"' ARCO Alaska, Inc(' Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 21, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 16-1 DS 16-5 DS 16-11 DS 16-16 Permit No. 80-136 Permit No. 81-37 Permit No. 80-118 Permit No. 80-127 Attached are "Subsequent Report" Sundry Notices for work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/lmh Attachments cc: Sohio Petroleum File Pi(DS 16-1)W1-3 File P1 (DS 16-5)W1-3 File Pi(DS 16-11)W1-3 File Pl (DS 16-16)W1-3 ARCO Alaska, Inc. Is a Subsidiary of AllanllcRIchfleldCompany STATE OF ALASKA ALASKA(' L AND GAS CONSERVATION C~ MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELI3~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-136 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20533 OTHER [] 4. Location of Well (Surface) 1302' FNL, 1013' FWL, Sec. 24, T10N, R15E, UM (Producing Interval) 1671' FNL, 1625' FWL, Sec. 18, T10N, R16E, UM (Top Prod) (Total Depth) 1565' FNL, 1843' FWL, Sec. 18, T10N, R16E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 73' RKB I ADL 28346 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 16-1 12. 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [-'] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 3/9/84. RU perforating unit, pressure tested equipment. RIH with gun #1, shot interval 12712 - 12722' MD (4spf), flowed well to clean up. Shut in well, POOH, all shots fired. RIH with gun #2, shot interval 12552 - 12582' MD (4spf), flowed well to clean up. Shut in well, POOH, all shots fired. Ran SSSV, secured well, RD. Ref: BHCS 12/31/80 RECEIVED JUN2 8 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereb~rtify~/f///~that th,,e for~go~/~_ is t~e and/correct to the best of my knowledge. Signed. _~,¢~_,~~~ Title Regional l~.ngineer The space below for Commission use Conditions of Approval, if any: Approved by COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~" Prudhoe Bay ,dineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 13, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 16-1 DS 16-2 DS 16-3 DS 16-5 DS 16-10 DS 16-11 DS 16-16 Permit No. 80-136 Permit No. 80-150 Permit No. 81-11 Permit No. 81-37 Permit No. 80-04 Permit No. 80-118 Permit No. 80-127 Enclosed are the Sundry Notices for Change of Well Status for the proposed Drill Site 16 Water Injectors. Ve~ truly yours, D. F. Scheve DFS:WT:kg Enclosures cc: SOHIO Alaska Petroleum Co. File P1 (DS 16-1)Wl-3 .File P1 (DS 16-2)Wl-3 File Pl (DS 16-3)Wl-3 File P1 (DS 16-5)Wl-3 File P1 (DS 16-10)W1-3 File P1 (DS 16-11)Wl-3 File P1 (DS 16-16)Wl-3 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASKA'[' _ AND GAS CONSERVATION CC~-- ,41SSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-136 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20533 OTHER [] 4. Location of Well 1302' FNL, 1013' FWL, Sec. 24, T10N, R15E, UN 1671' FNL, 1625' FWL, Sec. 18, T10N, R16E, UM (Top Prod)' 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 16-1 1565' FNL, 1843' FWL, Sec. 18, T10N, R16E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 73' RKB I ADL 28346 12. Check Appropriate Box Tolndicate NatureofNoti~e, Report, orOtherData 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool [] [] [] NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF', (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate ['-] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Puff Tubing [] Other E~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to change Well 16-1 status from oil producer to water injector. It will be operated as part of the Prudhoe Bay Waterflood Project. Subsequent Work Reported RECEIVED JUN 1 8198 Alaska Oil & Gas Cons, Commission Anchorage 14. I herebyp~rtify that the foregoing is true and correct to the best of my knowledge. ~,/~~~~j Regional Engineer Signed Title The space below for Commission use Date Conditions of Approval, if any: Approved by ORIGINAl $1il[ll BY [ONNIE C. SILT! Approved Copy Returned ~r- ---'-- .k, _ , . ,~ BV Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" i n Duplicate WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [~ Water Injector , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 80-136 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20533 4. Location of well at surface 9. Unit or Lease Name 1302' FNL, 1013' FWL, Sec. 24, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1671' FNL, 1625' FWL, Sec. 18, T10N, R16E, UM DS 16-1 At Total Depth 11. Field and Pool 1565' FNL, 1843' FWL, Sec. 18, T10N, R16E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 73' RKBI ADL 28346 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 12/5/80 1/1/81 1/9/81 -- feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 13020' MD, 9217'TVD 12979' MD, 9821'TVD YES iX-I NO [] 2127 feet MDI 3_975' 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR, CBL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surf. 110' 32" 300 sx Permafrost to s~rface 13-3/8" 72# L-80 Surf. 2694' 17~" 2882 sx. Permafrost 9-5/8" 47# L-80 Surf. 12460' 12~" 500 sx. Class G 7" 29# N-80 12197' 13015' 8%" 375 sx. Class G 24. Perforations open to Production'(MD+TVD of Top and Bottom and 25. TUBING RECORD . interval, size and number) - SIZE DEPTH SET (MD) PACKER SET (MD) * New Perfs shot w/4spf 5½" 12250' 12175' 12598-12618' MD 8949-9033' TVD . 12618-12628' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12638-12648' MD. DEPTH ~NTERVAL(MD) AMOUNT& KIND OF MATER~ALUSED 12676-12696' MD , N/A · *12712-12722' MD (10') 8910-8936' TVD *12552-12582' MD (30') 9048,9056' TVD 27. PRODUCTION TEST Date First Production ' ~1 Method of Operation (F~owin§, gas ~!ft, etc.) Injecting . , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OILRATIO N/A I · TEST PERIOD I~ Flow Tubing Casing Pressure ' · .CALCULATED. I~ OIL-BBL: GAS-MCF WATER-BBL OILGRAVITY-API (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. · Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Sadlerochit O/W Contact Base Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH 12536'MD 12760'MD 12800'MD TRUE VERT. DEPTH 8896 ' TVD 9089'TVD 9193'TVD 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. None 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state ink, item 16, and in item 24 show the producing intervals for on!y the interval reported in item 27. Submit a separate form for each additional interval to be separately p¢oduced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- . lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 Biff Sheffield, Governor ALASKA OIL AND 8AS CONSERVATION COMMISSION March 29, 1984 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501;.3192 TELEPHONE(907) 279.--1433 A D M I N I S T R A T I V E A P P R O V A L NO. 192.1 Re: The application.of ARCO Alaska, Inc. to substitute static bottomhole pressure surveys for transient pressure surveys in Prudhoe:.Bay Unit wells DS 3-10, DS 3-15, DS 3-18, DS 4-1, DS 4-5, DS'4-11, DS 9-1, DS 9-6, DS 9-10, DS 1.6'-1 and DS 16-9.. Mr. D. F. Scheve Regional Operations Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Dear Mr. Scheve: Application for exceptions to Rule 6 of CO 165 was received March 23, 1984. Exception to CO 165 Rule 6(c) for PBU wells DS 4-5 and DS 9-6 and exception to CO 165 Rule 6(d) was requested for PBU wells DS 3-10, DS 3-15, DS 3-18, D'S 4-1, DS 4-11, DS 9-1, DS 9-10, DS 16-1 and DS 16-9. ARCO Alaska, Inc.'s application requests substitution of static bottomhole pressure surveys for the transient surveys required in Rule 6(c) and (d) of CO 165. These static pressure measurements were taken during the scheduled FS2 shutdown (March 12-19) after a shut-in of approximately seven days. Pursuant to CO 188 and 192 it has been determined that static bottomhole pressure surveys serve the intent and purpose of Rule 6 of CO 165 and may be substituted for the transient survey. The Alaska Oil and 'Gas Conservation Commission hereby authorizes substitution of static bottomhole pressure surveys for transient surveys in PBU wells DS 3-10, DS 3-15, DS 3-18, DS 4-1, DS 4-5, DS 4-11, DS 9-1, DS 9,6, DS 9-10, DS 16-1 and DS 16-9 pursuant to' Rule 2 of CO 192. '~.' '~ ~Your/j~ very Lonnie C. Sfnith Commis s ioner BY ORDER OF THE COM}~_ISSION lc STATE OF ALASKA ALASK( JIL AND GAS CONSERVATION (( ,VIMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-136 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20533 9. Unit or Lease Name Prudhoe Bay Unit 4. Location of Well 1302' FNL, 1013' FWL, Sec. 24, T10N, R15E, UM 1671' FNL, 1625' FWL, Sec. 18, T10N, R16E, UM 1565' FNL, 1843' FWL, Sec. 18, T10N, R16E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 73' RKB ADL 28346 12. 10. Well Number DS 16-1 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska Inc. requests permission to run a static bottomhole pressure survey on section well 16-1 in lieu of a pressure transient test for 1984. Conservation Order 165, Rule 6(d) requires an annual transient survey on one well in each governmental section producing. A static pressure survey will be run while the well is shut-in during the flow station shutdown (March 12-19) to fulfill the State's requirements. The static pressure survey should provide accurate reservoir pressure data. REC VJ D MAR 2 '~ ]984 ~0il & Gas Cons, C0mmis$i01i 14. I hereby g,ertify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Date Conditions of APproval, if any: Approved by BY LONNIE Ii, SMIT! Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1.80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Offic~.~. '~ox 360 Anchora~ ,laska99510 Telephone 907 277 5637 March 19, 1984 Reference: ARCO Cased Hole Finals D.S. 4-1 12-5-83 D.S. 4-10 '"' 12-9-83 D.S. 4-11~ 12-5-83 D.S. 4-13~ 12-9-83 D.S. 5-2'~ 1-13-84 D.S. 6-8~ 12-9-83 D S 6-11/' 12-21-83 D S 7-15 / 12-18-83 D.S. 9-7 ~,z 12-4-83 D.S 9-16 2-20-84 D.S. 9-17/~ 12-4-83 D.S 14-5~/ 3-4-84 D.S. I6-1~/ 3-9-84 D.S. 16-11,~ 3-10-84 D.S. 16-16 -'" 3-10-84 MS/CNL/GR EPL MS/CNL/GR CET Log Collar Log CH CNL CH CNL Perforating Record MS/CNL/GR Collar and Perforating Log MS/CNL/GR Collar & Perforating Log Collar & Perforating Log Collar & Perforating Log Collar & Perforating Log Run 1 5" DA Run 1 5" Sch Run 3 5" DA Run 1 5" Sch Run 1 5" Camco Run 2 5" Sch Run 3 5" Sch Run 1 5" Sch Run 1 5" DA Run l&2 5" GO Run 1 5" DA Run 1 5" GO 5" GO Ru-n 1 5" GO Run 1 5" GO Please' sign/ and return the attached copy as receipt of data. HAVE A NICE DAY Kelly McFarland ATO-1429F Trans. # 101 DISTRIBUTION Chevron Mob i 1 D & M Mobil E & P Dallas Phillips Drilling Prudhoe Bay Well Files Ext. Exploration R&D Exxon Getty Marathon Carolyn Smith Sohio --. ' "~-f~; ": .-' ~!.~ ~ State of ~q,~,i:'( 2 2 15~4 ARCO Alaska, Ir~ .... Prudhoe R;.~, Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer March 15, 1984 C. V. Chatterton STATE OF ALASKA Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: Prudhoe Bay Unit DS 3-10 DS 3-15 DS 3-18 DS 4-1 DS 4-5 DS 4-11 DS 9-1 DS 9-6 DS 9-10 DS 16-I DS 16-9 Permit No. 79-21 Permit No. 79-92 Permit No. 79-103 Permit No. 70-42 Permit No. 71-25 Permit No. 78-6 Permit No. 75-76 Permit No. 76-48 Permit NO. 76-82 Permit N6. 80-136 Permit No. 81-19 Enclosed are Sundry Notices requesting permission to substitute static bottomhole pressure surveys in place of transient pressure test prescribed in Conservation Order 165, Rule 6, on key wells 4-5 and 9-6, and section wells 3-10, 3-15, 3-18, 4-1, 4-11, 9-1, 9-10, 16-1 and 16-9. The static pressure measurements on these eleven wells are part of a package being planned to obtain a baseline reservoir pressure in the FS2 waterflood area prior to the start of water injection. Each well will be shut-in for approximately seven days prior to its survey. We believe that these static pressure surveys will provide a better interpretation of reservoir pressure in the FS2 area than transient pressure surveys .and will satisfy the intent of Conservation Order 165, Rules 6(c) and 6(d). If you have any questions concerning this request, please contact Dan Cavin at 263-4268. Very truly yours, D. F. Scheve DFS/DLL/STATE/lmh cc: SOHIO Petroleum Company File Pi(DS)Wi-3 ARCO Alaska, Inc. is a Subsidiary of AtlanllcRIchfleldCompany STATE OF ALASKA ALAS~', OIL AND GAS CONSERVATION',.OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 7. Permit No. 80-136 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20533 4. Location of Well 1302' FNL, 1013' FWL, Sec. 24, T10N, R15E, UM 1671' FNL, 1625' FWL, Sec. 18, T10N, R16E, UM (Top Prod) 1565' FNL, 1843' FWL, Sec. 18, T10N, R16E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ADL 28346 _ 73' RKB 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 16-1 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~ Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations on DS 16-1 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 12552-12582' MD 12712-12722' MD Ref: BHCS 12/31/80 MAR 0 5 i984 A1~sk~ 0~I & Gas Cons. Commission 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Date Conditions of Approval, if any: 8RIGINA[ SIGNED BY [OH~!E C. $1~ITIt B¥Orderof Approved by, COMMISSIONER the Commission Approved Copy Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Prudhoe Ba~' Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer March 1, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 16-I DS 16-2 DS 16-5 DS 16-11 DS 16-16 DS 17-6 DS 17-8 Permit No. 80-136 Permit No. 80-150 Permit No. 81-37 Permit No. 80-118 Permit No. 80-127 Permit No. 80-132 Permit No. 81-74 Attached are "Notice of Intention" Sundry Notices for work ' proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: Sohio Petroleum File 100.0 ARCO Alaska, Inc. Is a Subsidiary of AtlanllcRIchfleldCompany ARCO Alaska, Inc. '.~ Post Office B 360 Anchorage. Alaska 99510 Telephone 907 277 5637 March 24, 1983 Reference: Arco Pressure Data D.S. 2-lA~ 2-21-83 2-21-83 D.S. 2-5 / 2-3-83 2-3-83 Pressure Build-up Camco Pressure Build-up Survey Report Pressure Build-up Camco Pressure Build-up Survey Report D.S. 4-13 2-25-83 2-25-83 Pressure Build-up camco Pressure Build-up Survey Report D.S. 13-8 ' 3-3-83 3-3-83 :.',., D. $ ~..'. l~-i 2-26-83 ~, 2-26-83 Pressure Build-up Camco Pressure Build-up 'Survey Report Pressure Build-up Camco Pressure Build-up Survey Report Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 ~.~ Trans. # 229 DISTRIBUTION NORTH GEOLOGY ~~N.//~f~~.,.,~'~ R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON MOBIL GETTY D&M STATE OF ALAS~KA DALLAS CAROLINE SMITH Post Otfice Box Anchorage. Alaska 99510 Telephone 907 277 5637 May 11, 1982 Hr. C. V. ChatLerton Commissioner State of Alaska Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUB3ECT: Well Completion Reports · Dear Mr. Chat[ertbn: Enclosed are revised completion reports and gyroscopic surveys for the ¢ollowing wells: DS 13-6 DS 13-9 DS 14-13 DS 15-11 ~ DS 16'1 The original completion reports indicated that certain items would be submitted at a later date° These items are now included in the attached completion reports. Sincerely, P.A. VanDusen District Drilling Engineer PAV:JG/llm Enclosures GRUS/A13 STATE OF ALASKA£~f '" .tVl ALAS .- AND GAS CONSERVATION ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, :]:nc. 80-136 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50-029-20533 4. Location of well at surface 9. Unit or Lease Name 1302' FNL, 1013' FWL, Sec 2z;, T10N, R15E, UH LO¢/~T'IONS-- Prudhoe Bay Unif. At Top Producing Interval VERIFIED 10. Well Number 1671' FNL, 1625' FWL, Sec 18, T10N, R16E, UN Surf. E DS 16-1 At Total Depth j B. H.. ~-~ 11. Field and Pool 1565' FNL, 18Z;3' FWL, Sec 18, T10N, R16E, UM Prudhoe Bay Fieid 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0ti PooI 73' RKBI ADL 283Z;6 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if offshore 116. No. of Completions 12-05-80 01-01-81 03-06-82I .... feetMSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 13020'HD 9331'TVD 12979'HD 9296'TVD YESJ~] NoE-] 2127' feetMD 1975' 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR, CBL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE! WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 110' 32" 300sx Permafrosf. t:o surface 13-3/8" 72# L-80 Surface 2.69Z;' 17-1/2" 2882sx Permafrost: 9-5/8" 47# L-80 Surface 12.z;60' 12-1/z~" 500sx Class G 7" 29# N-80 12,197' 13,015' 8-1/2" 375sx Class G 8-RD 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A Date of Test Hours'Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ ~ . . Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-A, PI (corr) Press. 24-HOUR RATE "I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ECEIVED MAY 1 3 i982 AL~.ska Oil & Gas Cons. Commission ^nch0rag-. Form 10-407 GRU/4/B9/1 u/n/11 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Sadlerochit O/W Contact Base Sadlerochit GEOLOGIC MARKERS TRUE VERT. DEPTH 8913' 9104' 9209' MEAS. DEPTH 12,536' 12,759' 12,880' FORMATION TESTS Include interval tes~e.z,i~:e~s,~:,: ,3: ';,~,, ','iu,~:s recu~t;~ ~r. ,:. ~.~,~., GOR, and time of each phase. None 31. LIST OF ATTACHMENTS iGyroscopic Survey (2 copies) I hereby certify that the foregoing is true and correct to the best of my knoWledge Signed Title Area Drlq. Enqr.,, Date /~' 32. INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate-which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in itb'm 16, and in item 24 show the producing intervals for only t'~e 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 (G L) or other elevation (DF, KB, etc.). Item 23: A~tached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Post Office _,ox_~ 360 Anchorage. J i:ka 99510 Telephone 907 277 5637 '7-- April 12, 1982 Reference: ARCO PRESSURE DATA D.S.16-16 _D.S.'16-1 ' D.S.7-2 D.S.2-1 D.S.2-6 D.S.6-1 D.S.6-9 D.S.2-15 D.S.17-9 D.S.2-15 D.S.17-6 'D.S.2-14 DS..6-4 DS..5-11 D.So5-17 D.S. I7-7 D.S. 17-8 3/10/82 Pressure Survey 3-12/13-82" " 3/4/82 " " 2/10/82 '" " 2-7/8-82 " " 1/24/82 " " 2/5/82 " " 1/23/81 " " 3/14/82 " " 1/24/81 " " 6/26/81 " " 11/9/80 " " · 3/8/82 " " 2/7/82 " " ~2/26/82 " " 3t~/8~ " " 3/15/82 " " ~/PPlease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #92 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA cHEVRON ARCO Alaska i.q¢. I$ a Suo.,,J.ary o! A:lanllCrR~cbt~eiclCompar~¥ ARCO Alaska, Inc. Post Office 80× 3~0 Anchorage. ,~ ,] 99510 Tele.ohone S0~ ~77 5637 March 30, 1982 Reference: ARCO DIRECTIONAL SURVEY DATA D.S.15-3 D.S.14-29 D.S.13-6 D.S.11-7 D.S.16-1 3/9/82 to 3/21/82 Single-Shot 3/13/82 Gyroscopic·~ 3/2/82 .' Gyroscopic 2/27/82 Gyroscopic 3/6/82 Gyroscopic Job No. 0382-021 Job No. A0382G0416 Job No. A0382G0404 Job No. A0382G0407 Job No. A0382G0408 Multi-Shot Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 75 DISTRIBUTION NORTH~GEOLOGY~ EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Alaska, Inc. Post Office-~ '360 Anchorage,[ .~ka 99510 Telephone 907 277 5637 January 21, 1982 Reference: ARCO PRESSURE DATA ~['S.9-3 11.~0/81 Pressure Surve~ D.S.3-4 11/20/81 " " D.S.17-6 11/15/81 " " D.S.3-2 11/19/81 " " D.S.17-1 11/15/81 " " D.S.9-1 11/21/81 " " D.S.16-16 11/15/81 " " D.S.16-1 11/14/81 " " D.S.4-7 12/2/81 " " D.S.9-8 11/15/81 " " D.s.16-11 11/14/81 " " D.S.9-5 11/22/81 " " D.S.9-15 11/24/81 " " D.S.4-6 11/25/81 " " D,S.9-6 11/16/81 " " D.S.3-18 11/19/81 " " D.S.9-4 11/21/81 " " D.S.9-12 11/20/81 " " D.S.9-10 11/20/81 " " D.S.3-6 11/18/81 " " D.S.3-7 11/18/81 " " DISTRIBUTION /.~.~'se sign and return the attachedNORTH GEOLOGY R&D copy as receipt of DRILLING data. PHILLIPS D.S.9-6' 12/9/81 D.S.9-6 1/1/81 D.S.9-17 12/10/81 D.S.9-6 12/23/81 ~D.S.9-6 11/30/81 D.S.12-9 1/4/82 D.S.12-10 1/3/82 9.s.12-12 1/2/82 D.S.12-11 1/2/82 D.S.16-9 1/8/82 Pressure Survey I! II II !1 !! II Il I1 l! Il II l! II !I II II EXXON MOBIL GETTY D&M Mary F. Kellis North Engineering SOHIO MARATHON CHEVRON GEOLOGY STATE OF ALASKA Transmittal #902 ARCO Alaska. inc. is a sac..~d,ary Of A:lan,cRichhe~dCo.'~pany ARCO Oil and Gas Company North Alask(~ 'istrict Post Office% ~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 10, 1981 Reference: ARCO Pres~.Te Data D.S. 16-1 9/27/81 Pressure Survey Please sign and return the attached copy as receipt of data. Mary F. Ke{lis North Engineering Transmittal f~733- ? ~ .~ DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA MOB I L Alaska Oil GETTY &.Gas Cons. anchorage C°mmi$~ion PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and Gas Company ~s a O~ws,(~n of AtlanlicRichf eldCornpany ARCO Oil and Gas Company North Alaska' ~trict .. · Post Off;ce E,-~ 560 Anchorege, Alaska ~9510 Telephone 907 277 5637 Jerry A. Hochon District Operaiions Engineer October 27, 1981 Reference: ARCO Magnetic Tapes & Lists D-S.16-1 9/27/81 Tape #62215 D.S.17-1 10/4/81 Tape #62223 CORRECTED COPY Please sign ans return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #699 DISTRIBUTION NORi'H GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA .. EXXON MOB I L ' GETTY PHILLIPS · 50H I 0 ~ -'" ~'" _..¥'L,~'; r L", ;~ ,-. ,,, CHEVRON . ARCO Oil and Gas~nmpany North Alask[f ,strict Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 22, 1981 Reference:'ARCO Cased Hole Finals D.S.16-1 9/27/81 TDT Ru~.l 5" D.$o 16-1 9/27/81 EPL Run 1 5" e sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #686 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILL I NG GETTY GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oil and Gas Company ~s a OivisiQ, n Ot AtlanticR~chfielc~Company ARCO Alaska, Inc.("' North Slope~.,strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 12, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: D S. 16-1 Permit No. 80-136 D.S. 16-2 Permit No. 80-150 D.S. 16-8 Permit No. 80-02 D.S. 16-9 Permit No. 81-19 D.S. 16-10 Permit No. 80-04 D.S. 16-11 Permit No. 80-118 D.S. 16-16 Permit No. 80-127 D.S. 17-1 Permit No. 80-55 D.S. 17-2 Permit No. 80-70 D.S. 17-3 Permit No. 80-77 D.S. 17-5 Permit No. 80-96 D.S. 17-6 Permit No. 80-132 Dear Mr. Hamilton: Enclosed are our Completion Reports for the above-mentioned wells. Very truly YoU~ '~. A. Rochon JAR: DAH: adri Attachments R ECEIV.ED OCT 2 0 1981 Alaska Oil & Gas Cons. Comrnis$io . Anchorage ri ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Company North Alaska..,' ,q rict Post Otlice Bux'360 Anchorage. Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 19, 1981 Reference: ARCO MAGNETIC TAPES & LISTS / D.S.1142" 9/25/81 Tape #62204 D.S.12-13 / 8/31/81 Tape f/62160 D.S 13-7~ 9/27/81 Tape #62206 D.S.15-11/ 10/3/81 Tape #62222 ? D.S.16-1~ 9/27/81 Tape #62215 / D S.16-11j 9/24/81 Tape #62202 D.So16-16 -~ 9/25/81 Tape #62203 D.S.17-7 J 6/4/81 Tape #61671 CORRECTED TAPE ase sign and returm the attached copy as receipt of data. Mary F. Kellis North-Engineering Transmittal #676 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D & M ,. GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY ps?, ' SOHIO OCT 2 0 198] MARATHON CHEVRON AI~sX~ 0il & Gas Cons, Commission Anchorage ARCO 011 and (]as Company ~s a O~vis~on of AtlanhcR~chf~clclCompany · A ,,S A C WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL][~ GAS [] SUSPENDED [] ,. ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 80-136 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 50_029-20533 4. Location of well at surface 9. Unit or Lease Name 1302' SNL, 1013' FWL, Sec. 24, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number To be submitted D.S. 16-1 At Total Depth 11. Field and Pool To be submitted Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KB 73'I ADL 28346 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., SusP. or Aband. 115. Water Depth, if offshore 16. No. of Completions '12-5~80 1-1-81 1-9-81I -- feet MSL 1 .17. Total Depth (MD+TVD)18.PlugBack Depth (MD+TVD)19. Directional SurveY13020 MD 12979 MD YES~x NO [] I20' Depth where sSSV set2127 feet MD I21' Thickness °f Permafr°st1975 ' . 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR, CBL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94~ H-40 Surface 110' 32" 300 sx Permafrost tc surface 13-3/8" 72# L-80 Surface 2694' 17 1/2" 2882 sx Permafrost 9-5/8" 47# L-80 Surface· 12,460J, 12 1/4" 500 sx.Class G 7" 29# N-80 12,197 13,015 8 1/2" 375 sx Class G 8RD .24. Perforatio.ns open' to Production (MD+TVD of Top and Bottom and . 25. TUBING RECORD ,. interval,size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 12598-12618' M.D. 5 1/2" 12,250' 12,175' 12608-12618' M.D. 12638-12648 ' M.D. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 1267'6-1269~' M.D'., ". ' ' :r:" ~ ' .... , 8949' T.V.D.-9033' T.V.D. 'n/a , · . 27. '~: PR'ODUCT,ON T'EST '. Date Fisst..Production. .: I Met. l~od of OPeration (F..!owing, gas !ift,.etc.). ~ . I · 7-10-81 Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OILRATIO 9-16:-8t. 12.05 . .. TESTPERIOD I~. 4445. .. 5122~, 0 52I 1152.4 Flow~Tul~ing; Casing Press. ure ' ' CA'LC~LATED" I~ OIL-BBL . GAS-MCF WATER-BBL. OIL GRAVITY-APl (corr) :Press-1038 N/A ' 24-HOUR RATE "~. 88~ . . ' .,. ' 3. 1,0202 Q 24.2 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .. . , · AIa.[~ 0il' & Gas Coils Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. '" .... 30. ' ' GEOLOGIC MARKERS FORMATI©~. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR. and time of each_ phase. T. Sadlerochit To be submitted None B. Salderochit , . · · 31. LIST OF ATTACHMENTS , . , · 32 I hereby certify that the foregoing is trde and corre~:t to the best of my knowledge Signed ~~~..Z/~ ~~''~""'''""~ Title District Engineer 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-sil~u 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 i~!6 and 24: If ~his well is completed for separate productio~i~ from more than one interval' (multiple comPilation), so state in item 16; and in item 24 ~how the producing intervals for only the ir~'~erval 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 P. A. Van Duser(,:~, September 2, I981 Incomplete Completion Reports Well Name and Number Prudhoe Bay Unit~ Prudhoe Bay Unit DS 14-9A Prudhoe Bay Unit DS 16-4 West Sak 18 Prudhoe Bay Unit DS 16-5 Kuparuk C-8 Prudhoe Bay Unit DS 14-19 Prudhoe Bay Unit DS 17-7 · Prudhoe Bay Unit DS 14-20 Prudhoe Bay Unit DS 12-11 Kuparuk A-2 Prudhoe Bay Unit DS 17-8 _Comp 1 e ti on / Aba ndonme nt Sp~pension Date 1-9-81 3-21-81 3-27-81 4-17-81 4-21-81 5-15-81 6-6-81 6-10-81 6-30-81 7-1-81 7-2-81 7-2-81 Overdue (?) Completion Repor_t_s Prudhoe Bay Unit DS 16-14 Kuparuk B-4 Kuparuk A-3 Prudhoe Bay Unit DS 17-9 Prudhoe Bay Unit DS 12-12 7-9-81 7-14-81 7-24-81 7-25-81 7-26-81 Sept~ber 2, 1981 Mr. P. A. Van Dusen District Drilling Engineer Arco Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99501 Re~ Overdue Data Submission Dear Mr. Van Dusen: Wells on the attached lists are those for 'which Completion Reports (form 10-407) are either incomplete or apparently overdue, with completion, abandonment, or suspension dates prior to August 1, !981. The first list is of those wells for which an incomplete Completion Report was filed, with the comment that the locations at the top of the prod~ucing interval and at the total depth were "to be submitted" or "N/A." The completion dates go back to January 9. The second list is of those wells for which available info~ation indicates the wells have been completed, but the 30 day filing period, has passed without a Completion Report having been submitted. We need to be brought up-to-date on directional survey problems that may be responsible for these late filings, or hav'e the r~.ired directional surveys and reports submitted to us. We would appreciate a response at your earliest convenience. Sincerely yours, Ear~-y Kug Commissioner ~%:K/JAL/g lh ARCO Alaska, Inc. North Slope I~,=,[rict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer August 26, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: .Permit No. 80-136 D.S. Permit No. 80-150 D.S. 16-3 Permit No. 81-11 D.S. 16-4 Permit No. 81-20 D.S. 16-8 Permit No. 80-02 D.S. 16-9 Permit No. 80-91 D.S. 16-10 Permit No. 80-04 D.S. 16-11 Permit No. 80-118 D.S. 16-16 Permit No. 80-127 Dear Mr. Hamilton: Enclosed are our Sundry Notices of work completed on the above- mentioned wells. Very truly you. rs, · ~.---'"J. A. Rochon JAR:DAH:mlc Attachments ARCO Alaska, Inc, is a subsidiary of AllanticRichfieldCompany A~r STATE OF ALASKA ~ ALASK -,L AND GAS CONSERVATION C...iMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska 80-136 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50- 029-20533 4, Location of Well 1302' SNL, 1013' FWL, Sec. 24, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) KB75' 12. I 6 . Lease Designatio. n and Serial No. ADL 28346 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 16-1 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting anv proposed work, for Abandonment see 20 AAC 25.105-170). 16-1 Began perforating operation 7/10/81. Tested tubing and annulus-tested tree. N. U. and tested perforating equipment. N. U. and tested wireline BOP and lubri- cator. Perforated 12676-96'M.D. with 4 spf. Unloaded to tanks. Flowed torfIbw%'7 station. Perforated 12638-48'M.D., 12608-618'M.D. and 12618-598'M.D. with-4 spf. Reperforated 12676-96'M.D., 12638-48'M.D., 12608-618'M.D. and 12618-598'M.D. with 4 spf. Recorded BHP. Rigged down perforating equipment. Secured well 7/12/81. RECEIVED AUG ~ 1 ]98I Alaska Oil & Gas Cons. Commission A. chorage 14. I hereby certify that the foregoing is, true and correct to the best of my knowledge. . Signed ,~/_,_~/~-~- Title District Operations Engineer Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and Gas.,,' .... mpany North Alaska, ,J'istrict Post Ollice Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer Aug 11, 1981 Reference: ARCO Cased H~le Finals D.S.14-11 6/30/81 :D,s.tG-t ,- 7/10/8t D.~.16-2 7/12/81 Co.!lar'Log Collar & Perf Log Collar & Perf Log Run 1 Run 1 Run 1 1! 2"/5': 2"/5" D.S.16-4 L/ 7/20/81 Diff Temp Log Run 1 5" D.So16-4 D.S.16-4 7/17/81 7/20/81 Collar & Perf Log Fluid Density Log Run 1,2,3,4 Run i 5" 11 D.S.16-4 7/20/81 I).S.16-6 7/25i81 Continuous Flow Survey Collar Log Run 1 5" Run 1 2"/5" D.S.16-8 7/22/81 Collar'Log Run i 2"/5" D.S.16-10 8/5/81 Collar & Perf Log Run 1 D.Sol6-10 7/25/81 .Collar Log Run 1 ~~Please sign and return the attached copy as receipt of data. 1! 2,,/5,! Mary F. Kellis North Engineering Transmittal #503 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY ...:-/ .,,.-" SOHIO MARATHON A!aska Oil & Gas Cons. Colnr~lission CHEVRON Anchorage ARCO 0il and Ggs Company is a Division ol AllanlicR~¢hlieldCompany ARCO Oil and Gas, :npany North Alaska district Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer July 27, 1981 Reference: ARCO Pressure Data ~[~~ 7/12/81 D. S. 4-5 5~7/8-81 ,. D.S.3ql3-'. Pressure Survey (Printout only) Pres sure Survey .. 7/11/81 Pressure Survey /~lease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #460 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG, MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON JUL 3 0 ltt81; ARCO OH and Gas Company is a Division 0! AllanlicRichfieldCompany ARCO Oil and Gas~' mpany North Alask.,,~, ,strict Post Office Box 360 -Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer May 28, 1981 Reference: ARCO CASED HOLE FINAL PRINT D.S.16-1 4-12/13/14-81 CCL/Gyro Run 1-6 2" Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmitf~l DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG~ MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON RECEIVED JUN - 1 1981 Alaska 0il & Gas Cons. Commission Anchorage ARCO Oil and Gas Company is a Division of AtlanticRichfietdCompany · ARCO Oil and Ga,~" mpany North AlaskL ,Jistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer May 20, 1981 Reference: ARCO Cased Hole Final D.S. 16-1 3-20-81 CCL run 2 2/5" ~~please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 294 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO Oil and Gas Company is a Division c)! AtlanticRichfieldCompany EXXON MOB I L GETTY .~ ~/~'~ MARATHOn's_ ~ ARCO Alaska, Inc. ( North Slope~,..~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer May 19, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Hamilton: RE: D,S, 16-1 Permit No. 80-136 D.S. 16-2 Permit No. 80-150 D.S. 16-3 Permit No. 81-11 D.S. 16-4 Permit No. 81-20 D.S. 16-8 Permit No. 81-02 D.S. 16-9 Permit No. 81-19 D.S. 16-10 Permit No. 80-04 D.S. 16-11 Permit No. 80-118 D.S. 16-16 Permit No. 80-127 Enclosed are our Sundry Notices detailing the work to be done on the above-mentioned wells. ~u~Y~~~/~. A. Richon JAR/BBB/mi s Enclosures ARCO Alaska, Inc, is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA (~i~ AND GAS CONSERVATION CO(' .VlISSION SUNDRY' NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] OTHER I-I 2. Name of Operator 7. Permit No. ARCO Alaska 80-136 3. Address P. O. Box 360, Anchorage, Alaska 4. Location of Well 99510 1302' SNL, lO13' FWL, Sec. 24, TION, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) KB 73' 12. I 6 . Lease Designation and Serial No. ADL 28346 8. APl Number s0-029-20533 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 16-1 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To IndiCate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to the flow station for cleanup and production. The perforated intervals will be given in a subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the perforating and cleanup operation. t E£EIVED MAy e 1 1981 Alaska 0il & Gas Cons. A~Chorage C°m~ission 14. I hereby ~ that the/~oing ~,~and correct to Signed :ho:;~)t~ ~3~el~ ,Os_of Apprro~a~,~SnS~n use the best of my knowledge. Title District Operations Engineer Date Approved by ORIGINAl. SIGNED BY LOfl~JiE C. SMITH i Approval Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and Gas Company North Alas~,,3 District Post olt;c(r )x 360 AnchorageS. Alaska'~ 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer March 31, 1981 Reference: ARCO Magnetic Tapes & Listings D.S.9-18 3/6/81 ,,.~ '3/10/81 D.S.13-12 3/9/81 Tape #DDNLL 8800-9320 Dresser Atlas Tape #CNL/MS 11800-12990 Dresser Tape #CN/MS 9796-10836 Dresser D.S.3-10 3/20/81 Tape #CN/MS 8950-9650 Dresser D.S.14-7 3/20/81 Ta~e #SP 10560-11~60 Dresser ase sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #153 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and Gas Company ~s a Division o! AtlanticRichfieldCompany ARCO Oil and Gas Company North~ ska District Post r,~ e Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer March 20, 1981 Reference: ARCO Cased Hole Finals D.S.2-16 D.S.3-5 D.S.5-16 D.S.9-14 D.S. 12-2 D.S.16-2 D.S.16-2 2/3/81 Collar Log 3/10/81 CCL/Gyro 3/11/81 COL/Gyro 3/12/81 Perf & CCL 3/8/81 CCL/Gyro 3/7/81 CCL/Gyro 3/7/81 CCL/Gyro 2/6/81 CCL Run 2 Run 1 Run 4 -- Run 2 2"/5" sam~ log 2"/5" sane log 2"/5" same log 2"/5" same log 2"/5" same log 2"/5" same, log P~lease sign and return the attached 'copy as receipt of data. Mary F. Kellis North Engineering Transmittal #136 DISTRIBUTION r~ORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO 0~1 and G,]s Company is a IDiws~on Of AllanticRichl~eldCornpany EXXON MOBIL GETTY ' PHILLIPS;~? /F '.'~, ./ ' , ,,.,'; .~ ,, SOHIO "[-.~,.'~..~-./~...j%,,..,. ,~ .~ /,,,~,,, CHEVRON ARCO Alaska, Inc. Post Office'"' x 360 ,,Anc,"iorage,'~-~aska 99510 ]Telephone 907 277 5637 March 16, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 14-9A DS 16-1 DS 16-10 DS 16-11 B-2 Dear Sir' Enclosed please find the Monthly Reports of Drilling Operations for DS 14-9A, DS 16-1, DS 16-10, DS 16-11 & B-2. Sincerely, P. A. VanDusen District Drilling Engineer PAV/KJG'sp Enclosures .i ECEIVED MAR 1 ? 1981 ~Jaska 011 & Gas Cons. Commission Anchorage ARCO AIr.~si,,a. Inc, is a ~L:!),:,,,'Ji;~r ~t &th;nticRichfic:dC')rr,;t;~n'~' STATE OF ALASKA , ' ALASK~? IL AND GAS CONSERVATION C( ~MISSION I NTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. Atlantic Richfield Company 80-155 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50- 029-20533 4. Location of Well , 9. Unit or Lease Name atsurface Prudhoe Bay Unit 10. Well No. 1302'SNL, IO13'FWL, Sec 24, TION, R15E, UM DS 16-1 11. Field and Pool Prudhoe [lay Unit 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe 0tl Pool 73' RKB ADL 28346 For the Month of. December ,19 88 . 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well 12/5/80. Drld 8~," hole' to 12,996' (12/31/80) 2 · {See attached Drilling History) 13. Casing or linar run and quantities of cement, results of pressure tests 20", 94#/ft, H-40 conductor to 110' Cmtd w/300 sx Permafrost. 13-3/8" 72#/ft, L-80 csg w/shoe @ 2~64'. Cmtd w/2882 sx Permafrost. 9-5/8", 47#/ft, L-80 csg w/shoe @ 12,460'. Cmtd w/500 sx Class G. (See attached Drilling History) , 14. Coring resume and brief description n/a 15. Logs run and depth where run "' DIL/SP/BHCS/GR, FDC/CNL/GR, CBL/CCL/GR ;16. DST data, perforating data, shoves of H2S, miscellaneous data n/a 17' I hereby certify that the f° Ii°lng is true and c°rrect t° the best °f mY kn°wledge'D~I' J~ ~J~/~/~ / ' "~/b' '"t~/5, ,~~ 1 ~SIGNE ~' ~l~..~'~'d. TITLE Dist. Drlg. Engineer DATE NOTE--Report on this form ,s required for each calendar month, regardless of the status of operations, and must be (ded in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in dupliCate Rev. 7-1 DS 16-1 DRILLING HISTORY Spud @ 0730, 12/5/80. Drld 17½" hole 2704' RU & ran 68 its 72# L-80 13-3/8" csg w/shoe @ 2694'. Cmt w/2882 sx ~ondu & 400 sx Permafrost cmt. NU & tst BOPE. Tstd csg to 1.500 psi - ok~~ Drld cmt, FC, shoe & foi~mation to 2714'. Tstd form to 12.5 ppg EMW - ok. Drld 12¼" hole to 3298'. Pipe was sticking @ 3248' & packing off. Circ & cond hole & lost 100 bbls fluid in 30 min. PUmped 15 sx nut plug pill. Drld f/3298-3635' - lost 35 bbls/hr for 3 hrs. Pumped 30 bbls nut plug pill across 3200-3400'. Drld 12¼" hole to 4926' w/precautionary washes & reams. No further fluid loss. Drld 12¼" hole to 12,475'~ RU & ran 307 its 47# L-80 & S00-95 9-5/8" csg w/shoe @ 12,460'. Tstd form to 12~5 ppg EMW - ok. Drld 8½" hole to 12,996' as of 12/31/80. AI~.~O Alaska, Inc.( Post Office i~..~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 4, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 16-1 Dear Sir- Enclosed p,l.ease find the Completion Report and Drilling History for DS 16-1. The Gyroscopic Survey is presently being rerun. An updated Completion Report will be submitted as soon as data becomes available. ~~,Sincerely' ~ P. A. VanDusen 'District Drilling Engineer PAV: KJG- sp ~Encl osures RECEIVED MAR - 5 1981 Alaska Oil & Gas Cons. Commission A~horage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ALASK ,~_ AND GAS CONSERVATION C,. ,,. ,vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE 2. Name of Operator 7. Permit Number ARCo Alaska, :[nc. 80-136 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50-029-20533 .- 4. Location of well at surface 1302'SNL, 1013'FWL, Sec 24, T10N, R15E, UM At Top Producing Interval To be submitted At Total Depth· , 5. Elevationin~(indicate KB, DF, etc., 16. Lease DesignationandSeria. No. .KB~3~ ~ ADL 28346 12. Date Spudd~ ~ 13. Date T.D. Reached 12/5/80 I 1/1/81 17. Total Depth (MD+TVD) ~18..Plug Back Depth (M~D) 13020MD'~:~7~ 12979 MD 9. Unit or Lease Name Prudhoe Bay Unit 10. weu N~~ D~ 16-1 ': 11. Field and.~9ol Prudhoe Bay Field Prudhoe 0il Pool 14' Date C°mp" Susp' °r Aband' J 15' Water Depth' if °ffsh°re I !6' N°' °f C°mpleti°ns'1/9/81 feet MSL' 1 19. Directional Surve 20. Depth where SSSV set 21. Thickness of Permafrost YES ]~X NOr-] 2127 feet MD 1975' 22. Type Electric 6r Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR, CBL/CCL/GR 23. CASING, LINER AND CEMENTIN( CASING SIZE WT. PER FT. GRADE HOLE SIZE 20" 94# H-40 32" 13-3/8" 72# SETTING DEPTH MD TOP BOTTOM Surface 110' Surface 2694' Surface 12,460' 47# 9-5/8 L-80 L-80 7" 29# N-80 12,197 13,015' 8 RD 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) n/a 17½" 12¼" RECORD I CEMENTING RECORD IAMOUNT PULLED 300 Sx Permafrost to' surface 2882 sx Permafrost 500 sx Class G 8½" 375 sx Class G 25. SIZE 5½" 26. TUBING RECORD DEPTH SET (MD) I PACKER SET (MD) 12,250' I 12,175' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) n/a 27. PRODUCTION TEST AMOUNT & KIND OF MATERIAL USED Date Ei.rst Production n/a .... Method of Operation (Flow, ing,.gas lift, etc.) · Date of Test ~, . Flow Tubing. 'Press. : . ' 28: Hours Tested Casing Pressure PRODUCTION FOR IOI L-BBL GAS-MCF TEST PERIOD I~ CALCULATED OIL-BBL GAS-MCF 24-HOUR RATE CO R E DA'TA WATER-BBL WATER-BBL ICHOKESIZE ]GAS-OILRATtO OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chip~,. _. ,ECEIVED none ~,q~ -- .5 ]98] '.Alaska 0il &~_a~ Cons. C°mrnis$ior~ nct~orage 'Form 10-407 ,. 'r}~: ...... ...'' ?:~:1. Rev. 7-1-80 " CONTINUED ON R 29. 30. GEOLOGIC MARKERS FORMATION Tr NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T. Sadlerochit To be submitted None B. Sadlerochit ., , 31. LIST OF ATTACHMENTS Dri 11 ing Hi story '32. , hereby certify that the foregoingTe and;orrect to the best of my kn"owledge . . 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 producti.on from more than one interval (multiple com~etion), so state-.in item 16, and in item 24 show the producing intervals for only the interval reported' in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any'multiple stage cement- lng and the location of the cementing tool. Item 27: Method of .Operation: Flowing, Gas Lift, -Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". .......... . ~'~ ........... ~ ........ ~.. ........... Form 10-407 DS 16-1 DRILLING HISTORY Spud @ 0730, 12/5/80. Drld 17½" hole 2704'. RU & ran 68 jts 72# L-80 13-3/8" csg w/shoe @ 2694'. Cmt w/2882 sx Fondu & 400 sx Permafrost cmt. NU & tst BOPE. Tstd csg to 1500 psi - ok. Drld cmt, FC, shoe & formation to 2714'. Tstd form to 12.5 ppg EMW- ok. Drld 12¼" hole to 3298'~ Pipe was sticking @ 3248' & packing off. Circ &Lcond hole&lost 100 bbls . fluid in 30 min. Pumped 15 sx nut plug pi~. °Drl~i' f/3298-3635' lo§'t 35 bbls/hr for 3 hrs. Pumped 30 bbls nut plug pill across 3200-3400'. Drld 12¼" hole to 4926' w/precautionary washes & reams. No further fluid loss. Drld 12¼" hole to 12,475'. RU & ran 307 its 47# L-80 & S00-95 9-5/8" csg w/shoe @ 12,460'. Tstd form to 12.5 ppg EMW - ok. Drld ~" hole to 13,020' TD. Circ & cond for logs. Ran DIL/SP/BHCS/GR f/13,000- 12,460'. Performed Arctic Pak downsqueeze while logging by pumping 300 bbls water, 300 sx Howco Permafrost "C" cmt & 133 bbls Arctic Pack. Had hole prob, made trip w/bit. Tstd Arctic Pack to 1000 psi - ok. Ran FDC/ CNL/GR f/12,996-2690'. Ran 27 jts 29# N-80 8RD liner f/12,197-13,015'. Cmtd by pumping 25 bbls Sepiolite & 375 sx Class "G" cmt. Reciprocated liner while cmt§. Drld cmt to FC @ 12,979 PBTD. Displaced well w/9.6-9.7 ppg NaC1. Tstd csg and liner lap to -3000 psi - ok. Ran CBL/CCL/GR f/12,982-10,990' Ran 5½" completion assy w/pkr @ 12,175' and tail @ 12,250' Tstd p~off to 5000 psi - ok. ND BOPE. NU & tstd tree to 5000 psi - o~. Displaced NaCl w/treated diesel. Dropped ball, set & tstd pkr - ok. Tstd compl assy - ok. Secured well. Conducting long term tbg test. Rig released @ 1930 hrs, 1/19/81. ~Jaska Oil &~as. Cons. Comrnismo~ nChorage Eastman / ,~ Whipstock A PETROLANE COMPANY REPORT of SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, INC. COMPANY DS 16, Well ~umber: 1 WELLNAME Prudhoe Bay, North Slope, Alaska hOCAT~ON JOB NUMBER TYPE OF SURVEY DATE RECEIVED A0382G0408 Gyro Hu!ti Shot 06-Mar-82 APR 0 ? 1982 Alaska Oil & Gas Cons. Commission Anchorage SURVEY BY OFFICE Pef f erkorn/Lund Alaska Eastman ' Whipstock APE TROLAt, JE CC¢~PA;~Y P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-4617 March 25, 1982 ARCO ALASKA, INC. P.O. Box 360 Anchorage, Alaska 99503 Well Number: 16-1 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Gyro Multi Shot Date: 06-Mar-82 Method of Computation: Radius of Curvature Surveyor: Pefferkorn/Lund Job Number: A0382G0408 Attn: Bob Hines Dear Mr. Hines, We are enclosing the original and sixteen copies of the Gyro Multi Shot Survey run on the above mentioned well. To date, the following distribution has been accomplished: A. 1 copy telecopied to E/W North Slope office for delivery to ARCO field representives. B. 16 copies delivered to drilling for in-house distribution. C. 3 copies for E/W permanent well files. We wish to take this opportunity to thank you for calling on our services and we trust that we may continue to serve your needs in the future. Sincerely, Distr~ct Operations Manager ST/bb cc .. file enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide .._ ARCO ALASKA IN, C, PRUDHOE BAY, NORTH SLOPE, ALAS~<A GMS, 0-12~00 ~lD, ,SURVEYOR~' PEFFERKORN/LUND, DATE RUN: 06-~1AR-82 GYRO NO; 627, ~0 DEG A/U NO: 15~5, CAMERA NO: ~287, ................. FORESIGHT~ .... N6E (BENCHMARK) VERTICAl_ S~'CTION CALCULA ~ ' '~ ..... ~ ....... ~ ............. RECORD OF SURVEY RADI~JS OF CURVATURE METHOD 16, WELL NO,~ .1 . GMS .JOB NO~ AO382--G0408 TIME DATE F'RUDHOE"BAY', .... NORTH 'SL'OPE, AI:ASKA 1-4'.~ 4~. ** 58 ...... 25;HAR-~82 TRUE '4EASURED-DRI-FT ............. DR'I'FT ............ COURSE--VERTICAI:"VERTICAI: ..... SUBSEA ........ R' E-C'"'T'-A'-N--G--U-E'"A R' C I,.'"0 S-U R 'E ........ DOGL-EG-~ DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/.100FT: · , _ O. 0 0 0 0 O, 0,00 0o00 -7S,00 0,00 0,00 0,00 0 0 0,00 100, 0 15 S 34 0 E 100, 100,00 -0,03 27,00 0,18 S 0,12 E 0,22 S ~4 0 E 0.25 ..... 200; ................ 0 ]5"-N""59 ........ O'--E .............. ~0-0"'; ........ 200-;00 ................. 0;20 ........... I27'~"00 SO0, 0 15 S 29 0 W 100, ~00,00 0,22 227,00 0,49 S 0,74 E 0,89 S 56 ~0 E 400, 0 15 N 27 0 W 100, 400,00 -0,04 S27,00 0,48 S 0,~8 E 0,62 S S8 26 E 500, 0 15 S 71 0 E JO0, 500,00 0,~0 427,00 0,2~ S 0,6.1 E 0,65 S 69 ~5 E ,~,=6 99 0.64 S ].09 E 1.27 600. 0 ~0 S 28 0 E ]00. ~ 0 ~8 ~ .99,99 · , S 59 S6 E 700. O' 30S'""53 O-E .......... 100'; ........... 699;99 0~36 ....... 626'¥99 ~-;30-'-S ........ :I;-'66'-E -"2.11 S 5.1 ~..~ E 800. 0 ]5 N S8 0 E 100. 799.99 0.85 726.99 1.~ S ,_.? 24 E ~9.55 S 61 24 E 900. 0 0 0 0 ]00, 899,99 '.1o06 826,99 1,05 S 2,38 E 2,60 S 66 8 E .1000. 0 0 0 0 1001 1100, 0 0 0 0 1 1200'~ 0 1'5 'N-'-27 ........ O"'E 1 1300, 0 0 0 0 J 1400, 0 ~0 S 27 0 W I .1500, 1600. 1700. 1800, 1900, 999.991111 1.06 926.99 1.05 S 2.38 E · 99:: .... : :: 06 ':: :1110.~611'. ~9- ::: I · Oo ~ ,~ · ~.~8 E 1299,99 11 ':4rS::: 11226"99 0.667:'S '~'~72~,57 E 2,60 S 66 8 E 2,60 S 66 8 E 2,62 S 70 5S E 2,66 S 75 SJ E 2,60 S 66 5 E 0 ~0 S 8 0 W 100, 1499,98 0.S1 1426,98:: ::::::::::::::::::::: 2,11E 0 SO S 2S 0 W 100, 1599,98 -0,42 1526.98 2,72 S 1,88 E 0 S0'"'S"6I O-'E ..... 100; :'1'699;97 -0.7S 1626,97 3.47-'-S ......... 2-;'14'E 2 0 N 77 0 E 100, 1799,95 0,64 1726.95 S,77 S 4,25 E 2 45 N 5S 0 E 100, 1899,86 4,57 1826,86 2.0S S 7,98 E 2,8S S 48 20 E S,S1 S S4 40 E 4,08 S SJ ~9 E 5,68 S 48 27 E 8,24 S 75 4S E 2000, 6 0 N 4S 0 E 100. 1999,56 12~19 1926.56 S.07 N 1~.64 E 1S.98 N 77 20 E 2100, 9 45 N 46 0 E 100, 2098,60 25.86 2025°60 ~2o8S N 2S,24 E 26,55 N 61 6 E 2200, 12 SO N '47 ....... O""'E ............... I'00~ .......... 2196,71- 45,15 2'12S~7-J 26-~"1-.1 ..... N ............. S7~24'--E .... 45.48 N 54 57 E 2S00. 15 15 N 44 0 E 100, 229S,78 2400, 18 0 N 40 0 E 100, 2S89,59 2500, 21 15 N S9 0 E 100, 248S,77 2600, 24 15 N ~7 0 E 100, 2575.98 2700. 26 15 N'37 .... O'E .... 100C '2666.42 2800. 28 0 N S8 0 E JO0. 2755.42 2900, ¥1 0 N 40 0 E 100, 2842,44 69,10 2220,78 42,92 N 54,~4 E 69°24 N 51 42 E 97,55 2S16,59 64,18 N 7S,48 E 97,56 N 48 52 E 130,76 2410,77 90,09 N 94,84 E la0,80 N 46 28 E 168.8S 2502,98 120°56 N tl. 8.64 E 169,14 N 44 S2 g 210.7.~ 259~.'42 .... 154~62-"N .144,~1 'E 211,50 N 4S 1 E 255,5~ 2682'.42 J90°79 N 172.06 E 256.92 N 42 S E 304,J6 2769,44 229,05 N 203,05 E 306,10 N 41 33 E 0.48 : 0.44 0.S6 0.22 .... 0.56 0.25 0.00 0.00 0'.25 0.25 0.50 0,17 0.13 0.67 3.33 3.77 2.76 2,84 2.98 2.00 1.81 3,16 i6, WELL NQ; I GMS .]OB NO.' AO382-G0408 TIME lrlATE F'RUDHOE--'BAY',~ ....... NORTH· SI.:OPE-, .... Al,ASEA '1:4 .~ 41158 .... 25-MAR-'82 ......................................... TRUE HEA'SURE'KI---DR~t FT ............ DRIFT ............... COURSE-VERTICAl=" VERTICAL ..... SUBSEA ..... R -E- C-T--A- N-O-U-L--A DEPTH ANGLE DIRECTION l. ENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANC~ DIRECTION SEVERITY FEET D H D M FEET FEET FEET FEET .FEET FEET D H DG/100FT 3000. ~4 0 N 39 0 E 100. 2926.77 357.29 2853.77 270.51N 237.22 E 359.79 N 4] 15 E 3.05 3100. 37 0 N 39 0 E ~00. ~008,17 414.64 ~e~q~,_~,~,.17 315.63 N 273.76 E 417.8~ N 40 56 E .......... ~200'~ ............. 39-S0-N-'4'1 O--E ...... 100~ ......... ~086'~--70 ............. 475~·94 ....... ~0t3~-70 .......... S6~',-05-N ..... 31..3~-55-E--- 479,7] 3300. 41 ~5 N 4~ 0 E 100. 3]62,88 540,36 3089.88 411,19 N 356,8? E 544,47 N 40 57 E 2,18 3400. 45 15 N 44 0 E 100, 3235.70 608,65 ~)62.70 460,88 N 404,05 E 6~2,91 N 41 14 E 4,06 3500, 48 0 N 44 0 E ~00. ~304.~7 681,16 ~231,37 513.16 N 454 54 E 685,='~ N 41 ~2 E 2 3600, 50 35 N 46 0 E 100, ~369,8] 756,66 3296.81 566,62 N 508,00 E 761,00 N 41 5~ E 2,71 ......... 3900i ......... 52 .....O"N '46 0 E 100~' ~432~57 .... 834'i46 ....... 3~59~57 620i'70~'N ...........564+'00"E ~800, 51 30 N 46 0 E 100. ~494,48 '912,94 3421,48 675.25 N 620.49 E 917,04 N 42 35 E 0,50 3900. 52 0 N 46 0 E 100, ~556,~9 991,42 3483,39 729,80 N 676,98 E 995,44 N 42 51 E 0.50 4000, 51 45 N 46 0 E 4100, 51 45 N 45 0 E ....... 42'00~ .......... 5t ..... ~5~"N'--46 0 E 4300. 51 15 N 46 0 E 4400. 51 15 N 46 0 E 4500, 51 0 N 46 0 E 4600. 51 0 N 46 0 E ...... ~-?00"~ 50"~0 N'46 0 E 4800, 50 0 N 46 0 E 4900. 50 15 N 47 0 E 5000, 50 0 N 46 5100. 51 0 N 46 ........ 5200': ...... 51 ...... 15 N'45 5300. 51 15 N 45 5400. 52 0 N 46 5500. 52 30 N 45 5600, 52 30 N 46 ...... 5700~ ...... 52~-45'N'46 5800, 53 0 N 47 5900, 5~ 0 N 47 0 E 0 E 0 E 0 E 0 E 100, 3618.12 ............ 1070,04 loo': :: 3680, ~ O0 J 3742. ! 00' ' .~804.88 130.4 .1.00' ?~867· 47 1 100. 100. 100, 100. 100· S930.23 1460.36 S993.16 1538.03 3545,12 784.44 N 733 839.49 N 789 894-;'34 ;:N :::845 37:~J,88 :,948,52 N .901 7~:4~94 1002 ~69 N · ~857.23 1056.77 N 3920,16 1110.75 N 4056 · 43 1615.42 ~983 · 43 1.t64.55 N 4120.38 1692.26 4047, ~8 1217.96 N .56 .39 .49 957.59 : ~0~S.59 1069.50 1.1.25.20 1.180.5.1 E .1074. E 1152. E 1308. E 1386. E E E E 4184.49 ~768.98 4Jllo49 1270,79 N 1236.18 E 1464, 1541, 1619, 1696. 1772, O0 N 43 5 E 0.25 46 N 43 15 E 0.79 66- N-43 23 E -- 0,9~- 58 N 43 33 E 0.00 50 N 43 41E 0,00 29 N 43 48 E 0.25 95 N 43 55 E 0,00 34 N 44 .1. E 0,50 - 18 N 44 & E 86 N 44 13 E~ 100, J00o 100. J00. 100. 4248,60 1845,70 4175 60 1~..3,61 N 129.1. 85 E 4312.21 1922,81 4239.21 1377,2.~.. N 1347,3~, E 4374~97 2000,59 4'30:1:.~97 1431-78 "N "'1402.88 E 4437.56 2078,47 4364.56 1486·93 N 1458.02 E 4499,64 21~ · ~6 79 4426,64 1541,87 N 1513.94 E 1849. 1926, 2004, 2082· 2160, 55 N 44 18 E 0.81 68 N 44 22 E 1.00 51 N-44- 25- E 0.82 49 N 44 26 E 0.00 88 N 44 29 E 1,08 100. .100. 100. JO0~ 100, . . M 29 2239 4560,87 2235 78 4487 87 1~97, N 1570·33 E ,93 N 44 31 E 0.94 4621.74 2315.04 4548,74 1652·90 N .1.626.92 E 2319.25 N 44 33 E 0,79 4682.44 .2394,46 .~4609,-44 1708,10 N .... 1684,08 E 2398,70 -N 44 36 E 0,25 4742.80 2474.17 4669.80 .1762.99 N 1741.92 E 2478.39 N 44 39 E 0.84 4802,98 ~sSa .~ .... ,02 4729,98 1817,45 N ~800,33 E 2558,19 N 44 44 E 0,00 Lo 16, WELL N¢._!** 1 · GMS JOB NO.* A0;]82-G0408 Tilde [.lATE PRtIDFIOE~'BAY~ IqORTH SL'OPE, ..... AIZASKA 14 ~ 4~; 58 25-MAR~82 TRUE . ~E~SURE~ [RIFT DRIFT COURSE' VERTICA'IZ'V~RTI'CA;, ....... SUBSEA ........ R'E-'C~'T-'A-N-G"-U~L A R C L 0 S II R DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY. FEET D H D H FEET FEET FEET FEET FEET FEET D M DG/IOOFT~ 6000. 5~ 15 N 48 0 E JO0, 4862.~9 2634.01 4789.9~ 1871.50 N 185~.~J. E 2638.09 N 44 49 E 0,84 6100. 53 30 N 47 0 E 100, 4~22,65 27~4,2& 484~.65 1~25,72 N 1~8.48 E 2718,26 N 44 54 E 0,84 ........... '6200; ........ 5'4 ........... O-'N '-50 .......... O'""E ............... 1'00 ¥ .... 4~8~ * 78 27~4'~0 ...... 4~08';-'78 ..... 1-~7~TIS-N ....... 1~78'~ 87' 'E -27~8,-74 ' N ' 45 ......0 E .......... 2;'~7 ...... 6300. 53 0 N 52 0 E 100. 504J.26 2875,J6 4~&8,2& 202~,73 N 2041,~4 E 2878.&V N 45 10 E 6400. 53 30 N 52 0 E 100. 5101 0~ ~. · 2J 2~58 26 . ~ .... O~ 5028 O~ 207~.06 N 04.48 E . N 45 21 E 0,50 6500 55 0 N 52 0 E 100, 5~.~,52 30~&,05 5086.52 212~.02 N 2168,4~ E ~038,88 N 45 55 30 N 52 0 E ~00, .,~16,52 ~1J8,02 5143,52 217~ &l N ~3~ J7 E 3120 54 N 45 42 E 0 50 ' .,4 .~199,6~ ~30,00 N ~98,8., E ~3 O' E ........J'O0', , ~200~ '75' N 45 52 E ...... 6700'~ ........... 5272 62 ~ ~ ..... o ....oo ...................o~ --~ .... 6800, 57 0 N 53 0 E 100, .~3~7,63 3283,73 5254,63 2280 26 N 2365.54 E 3285,63 N 46 3 E 0,75 6900. 58 0 N 53 0 E 100. 5381.36 ~67.75 5Z<08,~6 23~1,02 N 24~2,90 E 3~69.37 N 46 14 E 1,00 7000, 58 45 N 52 0 E JO0, ~,43~.79 3452,64 5360,79 ~38~,85 N 2500.45 E ~454 02 N 46 23 E J.13 ,48::: 3~37~97 2434,96 N 2568 36 E 7100, 59 0 N 5~ 0 E ~00; 5485 ~ ~:: , 3539,14 N 46 .......... 7200T .......... 58'-45'"N-"-5~ ...... O' E 10O~ 5577,17 S623;25' 2 ,7~ E ~624'21 N 46 4 7300 58 45 N 54 0 E 100': 5589 Oz, 3708,3.: ~55~6,05 ~2537,33 N 2705'~45 E ;f709 11 N 46 50 E 0,85 7400, 59 45 N 54 0 E 100' 5640,18 2774,98 E 3794,39 N 47 0 E 1,00 , ~ , . N 47 9 E 0.25 7500, 60 0 N 54 0 E 100 ~690 ~7 ~87~,84 2844 ~5 E 3880,26 7600 5~ 15 N 5~ 0 E J00 ._740 94 ~965.7J 5667.94 26~0.00 N 2~14,30 E 3966,01 N 47 18 E J,14 ......... 7700~ ....... 59~'30-N-'54 O'~'E' ~00~ 5791.88 4051~37 5718-,88 ' 274I-;19'N .... 2~8~.48 E 4051.57 N 47 25 E 7800~ 60 0 N ~ . ~..., 4J37 ~5 5769 25 ,57 N .91 E 4~7,48 N 47 .~. 0 E 100. ~842 ~ · . 2792 ~052 7~00. 60 45 N 52 0 E 100~ 5891.69 4224,01 5818.6~ 2845,49 N 31~1.88 E 4~.~4 09 N 47 ~ E 5 : 8000, 60 0 N 4~ 0 E 100. 594~.~2 4~10.85 5868,12 2~00,77 N ~J88.95 E 4~10.90 N 47 4~ E 8100, 59 0 N 4~ 0 E 100, 5991.87 4~97.00 5918.87 2~57,30 N ~25~.97 E 4~97.04 N 47 44 E ~ ~ N 47 46 E .......... 8200'¥ 58 0 N'~O 0 E ~00. 6044.12 4482'i2~ 59-7'J~"~J:2 301-2-'i6'8~'N ..... ~'18.81 E 4482 26 8300, 57 15 iq 51 0 E 8400. 57 0 N 51 0 E 8500. 57 0 N 51 0 E F~600. 56 15 N 51 0 E ......... 8?00'¥ .......... 56 O"N 52 0 E 8800. 56 0 N 51 0 E 8900, 56 0 N 51 0 E 2.71 1.00 1',31'- 1,13 0.25 ~00, 6097~67 4566.60 6024.67 3066,40 N 3383.98 E 4566,63 N 47 49 E 100, 6151.95 4650,47 6078°95 3119025 N 3449,24 E 4650°48 N 47 53 E 100. 6206.41 4734°22 6~33,41 S172,03 N 3514,42 E 4734,23 N 47 56 E 0,00 ~ ~ . ~' 32 . N 47 .,9 E 0,75 100. 6~6104o 4817.62 6188.42 ~224 58 N 3.79. E 4817 62 1000 6317.16 4900~48' 6244.'-16 ....... 3276~26-'N ~ 3644.29 E 4900°49 N 48 3 E 0.87' 100. 6~73.08 4983.23 6300.08 3327.87 N 3709.~7 E 4983.24 N 48 6 E 0.83 100. 6429~00 5066,02 6356o00 ~380,04 N S777,60 E 5066,04 N 48 9 E 0,00 WELL NO.* 1' GMS JOB NO; AO382-G0408 TIHE DATE F'RUDHOE--BAY, ...... NORTH SEOF'E~ .... AI~'ASKA 1'4;41;58" 25'"MAR~82 TRUE -HEASURED-~'-DR~-F~T ................. DRIFT ................. COURSE-~-VERTICAI,'VERT-I'CAI: .... SUBSEA R E'~C'-~--T--A-~N---G--U~--L--A-R C'-L O-S U'-RE .............. DOGLEG-- DEF'TH ANGLE DIRECTION LENGTH DEPTH SECTTON TVD C 0 0 R D I N A T E S D~STANCE DIRECTTON SEVERIT' FEET D H D H FEET FEET FEET FEET FEET FEET D M DG/IOOF' ?000. 55 15 N 52 0 E JO0. 6485.46 5148.40 6412.46 34.-fJ042 N ~8J8.19 E 514804~ N 48 12 E 1.12 91 O0, 55 0 N "'"' ,..,. .,~ 0 E 100. 6542.64 5230.-~F; 6469 64 3481.94 N 5902.84 E 5230.30 N 48 16 E 0.25 .......... 9200'~ ........ 5'4 "-~0'" N'"'52 ........... O"E ............. t00, ......... 6600 ~:35 ........53':t'1"~'7't ........ 6527'~'35 3532', 21' N 3967, ] 9 E 5:311 ',79 ..... N "' 48 9:300, 54:30 N 52 0 E .1.00, 6658,42 5:392,92 6585,42 ~582,3:3 N 40:31,:35 E 5:393,04 N 48 2:3 E 0,00 9400. 53 30 N 52 0 E 100. 6717.20 547:3.63 6644.20 :3632.14 N 4095.10 E 5473.78 N 48 26 E 1.00 9500~ 53 15 N 52 0 E 100. 6776.86 5553.69 670:3.86 J681.55 N 4~58.~4 E 5555088 N 48 <7600. 53 0 N 52 0 E .100. 68:36.87 56:33.4<2 67<53.87 57:30.80 N 4221.37 E 56:3:3.7:3 N 48 ~2 E 0.25 ........... ~7'00~ ........... 52 45' N 5~ O-E - 100,' 68~7'~ 57J'2-~8 ...... ~ ..... ,~ 68~4,~ 3779,34 N 4284.6~ E 57J3,27 N"'48"35' E '0~84 9800. 52 45 N 52 0 E 100. 6957.75 5792.33 6884.75 3827.80 N 4347.79 E 5792.69 N 48 38 E 0.80 ?~00. 52 45 N 52 0 E J. 00. 7018.28 5871.74 &945.28 ~876.80 N 4410.51 E 5872.16 N 48 41 E 0.00 10000, 52 15 N .,0 0 E 100, ............ 7079 16 ..... ..~9.~0,96 7 06,16 3926,73 N 4472 J6 E 5951.42 N 48 43 E 1,66 10100, 52 15 N 49 0 E N 4532,29 E 6030,48 N 48 44 E 0,79 ~'0200~ ...... 50' 45 N 49 "0 'E -~' ~ ~.63'-::::6:~08::25~ :4029~42 N 459J ~5 E 6108,74 N' 48'-'44:" E i 50 100, 7 ~ 0 .~ . · 10300, 50 15 N 47 0 E 6J85,:40:: 71:93~24 4080,04 N 4647,58 E 6J85,90 N 48 44 E 0,50 10400. 50 15 N 49 0 E 100; :':>::~330.18 N 4707,61 E 6262.79 N 48 44 E 0.00 10500. 49 15 N 50 0 E 100. 7394.79 6338.56 7321:.79:' 4180.05 N 4765.64 E 6339.10 N 48 45 E 1.26 10600. 48 50 N 50 0 E 100. 7460.56 &4iS.84 7J87.5.6 4228.47 N 482~.~5 E 6414.41 N 48 4& E 0.75 ~ 5 42 I'0700. 48 0 N 52 0 E 100, 7527,15 &488,~4 74o4.1. 4275. N 4881 E 6488.~5 N 48'47 E 1.57 J0800 47 15 N ='~ · o~ 0 E JO0. 7594.55 6562.04 7521.55 4320.90 N 4939.54 E 6562.71 N 48 49 E 75 10~00. 46 ~0 N 55 0 E 100. 7682.?~ 86~4.80 7589.91 4~65.~ N 4997.44 E 6835.55 N 48 52 E ' ~05 11000. 4& 0 N 5~ 0 E 100. 7'752.06 6706.76 7659.06 4408.80 N 5055~5 E 6707.60 N 48 54 E 0.50 ~1100. 45 0 N 54 0 E 100. 7802.J5 8777.78 7729.15 4451.2~ N 5112.47 E 8778.70 N 48 57 E 1.23 J'1"200" 44 30 N ~o 0 E 100 7873,17 ...... &847,'70 7800,17 4492 11 N ,.,..~? 78 E &848.77 N 4~ i E 11300, 43 30 N 57 0 E JO0. 7~45.10 6916.49 7872.J0 4530.95 N 5227.37 E 6917.72 N 49 5 E 1.71 11400. 43 0 N 59 0 E 100. 8017.94 6~8~.~6 7944.94 45~7.26 N 5285.47 E 6985.42 N 4~ 10 E 1.46 11500. 42 0 N 58 0 E JO0. 8091.66 7050.39 8018.66 4602.56 N 5343.07 E 7052.09 N 49 15 E ~.21 11600. 41 15 N 59 0 E 100. 8J66.41 7115.70 8093.41 4637.26 N 5~?~.71 E 7117.66 N 49 21 E J1700, 40 30 N Fl , ~ 0 E 100 8242~0~' 717~+94 816~,'0~' 4670.~7 N .~.~ 80 E 7182~18 N 4~ 26 E '0.75 11800. ~ 0 N &O 0 E: 100. 8~18.~1 7242.60 8245.~1 470~.42 N 5510.8~ E 7245.15 N 11900. 39 15 N 59 0 E 100. 8396,48 7304,4~ 8323,48 473~..45 N ...,o~. ~.;S 16, WELL NP; i. GHS JOB NO; AO382-G04C"8 TIME DATE PRUDHOE"-'BAY'~ ..... NORTH'-SL'OPE~ ....... AL-ASEA 14; 4'1'I 58- 25'MAR'82 TRUE ME'~SURED'"~IIRI'FT ....... DRIFT ......... T;O[IRSE'-'VERT I CAIZ"' VERT I CAll' ........ SUBSEA .........R-' E-'C--T-A-N--G-'U'--I"-- ~A"-R ..... C- L ' 0" S" U ~ R ' E ..............DOGLEG-- DEF'TH ANGLE DIRECTION LENGTH DEPTH .SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D H D H FEET FEET FEET FEET FEET FEET D H DG/100FT 12000~ 58 0 N 5~ 0 E 100, 8474,61 7~65,70 840~,61 4767,60 N 5618,77 E 7~68,8~ N 4~ 41 E 1,25 12100, J7 0 N 6~ 0 E 100, 855J,~4 7425,01 8480,~4 47~7,10 N 5672,00 E 7428,58 N 12200'~ ........S5'-"4'5-N'-"~2 ........ O'-E ......... IO0'i' ............ 86'3'4'~"45 ......7482~'4'2 ...... 8561"~-'45 ........... q82'A'~"~'?'-N~-5724'~'~O'"E' --7486-, 44 ' N' 49 53 E ......... ]-~-~8---- 12300, 55 0 N &3 O'E 100, 8715~ 7558,47 8642,~ 4851,~ N 5775,~& E 7542,~4 N 4~ 58 E 0,~5 12400, J4 0 N 62 0 E ~00, 87~8,40 75~5~0 8725,40 4877,57 N 5826,1~ E 75~8,24 N 50 4 E 1,15 12500, ~2 45 N &4 0 E 100~ 8881,~] 7646,44 8808,~] 4~02,~4 N 5875,21 E 7651,87 N 50 12600. 50 45 N &5 0 E 100, 8~6&,~4 76~6,8~ 88~5,~4 4~25~00 N 5~22,70 E 7702,86 N 50 15 E 2,07 ' '12700-; ......... ~0'-~0-'N'-'-6-4 ........O-'E .......... I'00-;~ ....... ~052'"~' 7745,75 8~7~'~ ~ ....... 4~467'~--N ..... 57&8~--6'8-E 7752,24 .... N- 50 2 12800, JO 0 N 64 0 E 100, ~15~,58 77~4,16 ~066,58 4~6~,01 N &0].5,~6 E 7801,20 N 50 26 E 0,50 12900, 29 0 N 6~ 0 E 100, 9226,4] 7841,61 915~,4] 4990,98 N 6058,02 E 7849,]7 N 50 ~ E 1,11 PROJECTED TO TD ~7897~80 9.,.,8,37 ::~J~¥~.~,~ .0~,86 E 7905,99 N 50 36 E 0,00 13020';- ............ 29 .....O'-'N-'-'-6'~ ....... 0-- E ~ ~ "~ ~'~'";~"? ~ ~'~' ~'~?~'~ ~ "~ ARCO AI.ASKA IN, C, ' [iS - it 6 ,~-'Wi'"f~L: - NO ,* 1 ........ GMS ;:lOB -" NO ~ AO..7.82"G0408 PRUDHOE BAY, NORTH SLOPE, AI.ASKA GMS, 0-12~'00 HD, SLIRVEYOR,* F'EF'FERKORN/LLIND, Ir'lATE RUN,* O,4-HAR-82 GYRO NO,' 627, c)'O ~'IEG A/U NO,* :15:~5, CAHERA NO;. ~287, ~&9 .................... FOREStGHT~ N6E' (BENCHMARK) :, ':~:'"~ DS 1~, WELL. NOI-1 GMS JOB ~ >.. , , ........................ ~RKER- TRLIE SUgSE~ CODE ~E~S~R'E[i'-'-'VERTTCAI/'--' H[i~-TVD---VERTI C'AI/"R "E-'-C'-T'--'-A"-N'"--G""-U---E'-"A-- R ......... C" L"O - S' [ R E 'VERT ~'C'~'IS NAME DEPTH DEPTH DIFF DEPTH C 00 R D I N A T E S DISTANCE DIRECTION THICKNESE FEET FEET FEET FEET FEET FEET D M ~: TOP OF SADLEROCH1T 12538.00 8912.52 3823.5 8839,52 4910.50 N 5892,3~ E 7870.22 N 50 12 E OIL/WATER CONTACT 1275~,00 ~0~,~6 3655,0 ~030,~6 4~5~,~ N 5~5,~ E 7781,12 N 50 24 E BAS~"'~OF"S'~'~;E"EROCH IT ......... 1-'2880'~-00 ............ ~20~-~"00"""~671-~'0 .......... ~'~-'~'~"'~'00 ........ ~'~8'6--~-5~--N--6'0-4'~ ¥'21 .... E 783~, 58 ' N' 50 "~0" E ............................... PBTD 12~7~,00 ~2~5,5~ ~68S,5 ~222,51 5008,~7 N 60~2,~5 E 7886,57 N 50 ~5 E TD 13020,00 ~331,37 3688,6 ~258,37 5017,~ N 610~,86 E 7~05,~ N 50 ~6 E . I IN., t~ FEET Eastman/ tl ipstocl{ A PETROLANE COMPANY REPORT of SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, INC. COMPANY DS 16, Well Number: 1 WELLNAME Prudhoe Bay, North Slope, Alaska LOCATION JOB NUMBER A0382G0408 SURVEY BY Pefferkorn/Lund TYPE OF SURVEY Gyro Multi Shot APR 0 0 1982 A!aska Oil & Gas Cons. CommJssJor~ /mchara§~, OFFICE Alaska DATE 06-Mar-82 Eastman Whipstock A PETROLANE COMPANY March 25, 1982 P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 34~4617 ARCO ALASKA, INC. P.O. BOX 360 Anchorage, Alaska 99503 Well Number: 16-1 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Gyro Multi Shot Date: 06-Mar-82 Method of Computation: Radius of Curvature Surveyor: Pefferkorn/Lund Job Number: A0382G0408 Attn: Bob Hines Dear Mr. Hines, We are enclosing the original and sixteen copies of the Gyro Multi Shot Survey run on the above mentioned well. To date, the following distribution has been accomplished: A 1 copy telecopied to E/W North Slope office for delivery to ARCO field representives. B. 16 copies delivered to drilling for in-house distribution. C. 3 copies for E/W permanent well files. We wish to take this opportunity to thank you for calling on our services and we trust that we may continue to serve your needs in the future. Sincerely, SHYAMi?ALWAR j..~'?'!i'? Distr~ct Operations Mana~e~ ST/bb cc: file enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ARCO ALASKA INC, ........ EPS ....... I"6~~ ....... WELI~'-NO: ....... I ........ GMS JOB"~NO;-A'O~82~G0~08 F'RUDHOE BAY, NORTH SI_OPE, AI_ASKA GMS, 0-12900 HE;, SURVEYOR; PEFFERKORN/L. UND, DATE RUN: 06-MAR-82 GYRO NO: &27, ~70 DEG A/U NO; 1535, CAMERA NO: 3287, ~,$69 ................ FORESIGHT~ N6E (BENCHMARK) VERTICAl. SECTION CALCULAT N PLANE.?~OF~ ?!~!~i' :~ , %,'-'%'"' ,. EGo 0 MIN. E RECORD OF SURVEY RADIllJS OF' CURVATURE METHOD 16, WELL NO; 1' GM~ dOB NO: AO382-G0408 TIME DATE PRUDHOE-BAY~ ..... NORTH 'SI:OPE'~ ..... At~ASKA 1'4:4I:58 .... 25-MAR-82 TRUE H~[A-SURED-DR[FT ........ DR[-FT .......... COURSE-VERT[CAi.'VERTICAI, SLIBSEA ..... R'E-'~'C-T---A--N-G-U--L-A-R .... CL OS LI-R.E ....... DOGLEG--- DEF'TH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D H D M FEET FEET FEET FEET FEET FEET D M DG/100FT 3000. 34 0 N 39 0 E 100. 2926.77 357.29 2853.77 270.51 N 237.22 E 359.79 N 4] 15 E 3.05 3100. 37 0 N 39 0 E ]00. 3008.17 414.64 2935.]7 315,63 N 273.76 E 417.8] 3200~ .......... S9'"'S0-N~'4t ........ O-E .......... ~00~ ..... 3086~70 ......... 475+94 .... 3013,'70 .......... S6-3~'05--N ...........3~'~55 E- - '479.7] 3300. 41 ]5 N 43 0 E 100. ~]62.88 540.36 ~089,88 411.19 N 356.89 E 544,47 3400. 45 15 N 44 0 E 100. 3235.70 608.65 3]62.70 460.88 N 404.05 E 612.91 3500. 48 0 N 44 0 E ]00. 3304.~7 681.16 52 3600. 50 ~5 N 46 0 E 100. 3369.8] 756.66 00 '3700~ ........52 ...... 0""'N'46 .......O"E ........100~ .... 3432,57 ' 834,46 66 SSO0. 51 ~0 N 46 0 E 100. 3494.48 912.94 04 3900. 52 0 N 46 0 E 100. 3556.39 ~91.42 44 4000, 51 45 N 46 0 E 4100. 51 45 N 45 0 E 4200, ..... 4300. 51 15 N 46 0 E 4400. 51 ].5 N 46 0 E 4500. 51 0 4600, 51 0 N 46 0 E 4700, 4800. 4900, 100. ....... S618.12 1070.04 100~::~'3680.03 1148.49 ]00:~:,'~3742,28 1226.68 100.'::3804.88 1~04.62'- 100,. ~867.47 1382,56 100. 3930.23 1460.36 . 538 03 100 3993.16 I · 50 30'"N'"46 O-E ]:00'~ 4056.43 1615~42 50 0 N 46 0 E 100, 4120.38 1692.26 50 15 N 47 0 E 100. 4184.49 ]768.98 40 56 E 3.00 40 49 E .... 2,79 40 57 E 2.18 41 14 E 4.06 3231.37 513.16 N 454.54 E 685, 41 3296.81 566.62 N 508.00 E 761. 41 3359:57 ...... 620'~70'--N ....... 564-~00 E -'838. 42 3421.48 675.25 N 620.49 E 917. 42 3483.39 729.80 N 676.98 E 995. 42 E ]074, E 1152. E ]230. E 1308. E 1386. 5000. 50 0 N 46 0 E 100. 4248.60 1845.70 5100. 51 0 N 46 0 E ]00. 4312.21 1922.8] 5200~ 51 .... t'5-N-~'45 ..... O-'~E .... t00~ 4374.97 2000~59 5~00, 51 15 N 45 0 E ]00. 4437.56 2078.47 5400. 52 0 N 46 0 E 100. 4499.64 2156,79 3545.12 784.44 N 733.56 3607~03 839.49 N 789.57 373].88 .. 948.J~:N ~0'I.49 3857:.23 .... 1056,:YT':N ]0]3.59 3920.16 1110.75 N 1069.50 3983.43 't]64',55-N .... 1125'.20 4047.38 1217.96 N 1180.5] 4111.49 1270.79 N 1236.18 E 1464. E 1541. E 1619. E 1696. E 1772. 5500, 52 30 N 45 0 E 100. 4560.87 2235.78 4487.87 1597.29 N 1570.33 5600. 52 S0 N 46 0 E ]00. 4621.74 2315.04 4548,74 1652,90 N 1626.92 5700. ~"52'45"N 46 O'E " 100. '4682.44 2394,46 4609~44 ..... t708+t0~"N ....... t684,08' 5800. 53 0 N 47 0 E ]00. 4742.80 2474.17 4669.80 ]762.99 N 1741.92 5900. 53 0 N 47 0 E 100, 4802.98 2554~02 4729,98 1817.45 N ]800.33 O0 N 43 46 N 43 66 N 43 58 N 43 50 N 43 29 N 43 95 N 43 34 N 44 18 N 44 86 N 44 55 N 44 68 N 44 51 N 44 49 N 44 88 N 44 93 N 44 25 N 44 70 N 44 S9 N 44 19 N 44 4175.60 1323.61 N ]29]..85 E 1849. 4239.21 1377.2~,_ N 1347.3 4'30] ,97 1431 ¥'78-N ....... 1-402,88' E 2004. 4364.56 1486.93 N ]458.02 E 2082. 4426.64 1541,87 N 151~.94 E 2160. E 2239. E 2~19 · E 2398. E 2478. 2558. 32 E 2.,u 5S E 2.71 16 E ~-1.,-75 ........ S5 E 0.50 51E 0.50 5 E 0.25 15 E 0.79 23 E 0.93 33 E 0.00 41E 0.00 48 E 0.25 55 E 0.00 ] E 0.50- 6 E 13 E (. '1 18 E' 0.81 22 E 1.00 25 E 0,82 ~6 E 0.00 29 E 1.08 31E 0.94 33 E 0.79 36 E 0,25- 39 E 0.84 44 E 0.00 DS 16, WELL NO~' ~ GMS JOB NO~' AO382-~G0408 TIME DATE ' PRUDHOE'-~ BAY' ~'NORTH SUOPE' ALASKA 14141 l ~ ..... ~-~ '~" ~ TRUE MEASURED DRIFT [RIFT COURSE VERTICAl_ VERTiCAl: SLIBSEA ....... R E-CT"~'"N-'"G--IJ'-L"A R C [."0 S U R E '"'DOGEEG-' DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D ~ N A T ~ S D~STANCE DIRECTION SEVERITY FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/~OOFT O. 0 0 0 0 O. 0.00 0.00 -73.00 0.00 0.00 0.00 0 0 0.00 100. 0 15 S 34 0 E 100. 100.00 -0.03 27.00 0.18 S 0.12 E 0.22 S ~4 0 E 0.25 ........... 200"; .......... 0 ~'5'-'N'59 ........ O"E ........... I'00~ ............ 200TO0 ................ 0;'20 ....... 127,00 ......... 0;'27-S ..............0¥5I E ........... 0~"57 ....... S-62 ~2~ E- ' 0o~4 -' SO0. 0 15 S 29 0 W 100. 300.00 0.22 227.00 0.49 S 0.74 E 0.89 S 56 30 E 0.48 400. 0 15 N 27 0 W 100. 400.00 -0.04 ~27.00 0.48 S 0.~8 E 0.62 S ~8 26 E 0.44 500. 0 15 S 71 0 E ]00. 500.00 0.30 427.00 600. 0 30 S 28 0 E ~00. 599.99 0+38 526.99 ...... 700; ..... 0 30'S 53 O'-E .......... I-OOY ............ 6'99';"99 ...... 0;36 626.99 800. 0 ~5 N 38 0 E 100. 799.99 0.85 726.99 900. 0 0 0 0 JO0. 899.99 '~.06 826.99 0.23 S 0.61 E 0.65 S 69 35 E 0.64 S ~.09 E 1.27 S 59 36 E 0.3~ 1~30""S .................I-';6&-'E ....... 2;11 .... S' 51 -52 E 0,22 1.0~ S 9.24 E 2.55 S 61 24 E O. 1.05 S 2.38 E 2.60 S 66 8 E 0.25 JO00. 0 0 0 0 100 1100. 0 0 0 0 1 ........ 1200', ....... 0 ..... 15 N 27 ...... O"E 1 1300. 0 0 0 0 ~ 1400. 0 30 S 27 0 W 1500. 1600. 0 30 S 8 OW 0 30 S 23 0 W 100. 1499.98 100. 1599.98 999. t .06 926.99 099.9 ::: 102 99 199.99.:::::::::::::::: : J '2.7.: 1126.99 1299.99 I ,42:1226.99 · 99 :1 '.06 99 0.31 1426.98 -0.4'~ 1526.98. 1'700, 0 30 S 61 O-'E .... 100-~ ..... I699';97 -0.73 1626.97 1800. 2 0 N 77 0 E 100. 1799.9,5 0.64 1726.95 1900. 2 45 N 53 0 E 100. 1899.86 4.57 1826.86 1.05 S 2.S8 E 1.05 S 2.38 E 0'86 s. 48 E 1 .88 S 2.11 E 2.72 S 1.88 E 2.60 S 66 8 E 2.60 S 66 8 E 2"+'62 .... S"70' 53 E 2.66 S 75 31E 2.60 S 66 5 E 2.83 S 48 20 E 3.31 S 34 40 E 3.47 S 2~I4"E 4',-08 S 31 39 E 3.77 S 4.25 E 5.68 S 48 27 E 2.03 S 7.98 E 8.24 S 75 43 E 0.00 0.00 0.25 0.25 0.50 0.17 0.13 0.67 _3 . .M 2 2000 6 0 N 43 0 E 100. 1999 ~6 ! .19 1926.56 2100. 9 45 N 46 0 E 100. 2098.60 25.86 2025°60 ~.~:.00~ 12 SO'N 47 0 E ............. I00~ .......... 2'196~7! 45,'15 2123.7] 2300. 15 15 N 44 0 E 100, 2293.78 69.10 2220.78 2400. 18 0 N 40 0 E 100. 2389°~9 97.~='.,,~ 2316.59 2500. 21 15 N 39 0 E 100. 2483.77 130.76 2410.77 2600. 24 15 N 37 0 E 100° 2575.98 168.83 ~.,-~°qn?.98 2700~ 26 15 N 37 0 E lO0, 2666.42 210.7] 2593,42 2800. 28 0 N S8 0 E ]00. ~=-~,,~?qm.42 ~.~55.53 ~68~..42 ~842. 2900. S1 0 N 40 0 E 100, ,. 44 304~]6 2769,44 3.07 N 13.64 E 13.98 N 77 20 E J2.83 N 23.24 E 26,55 N 61 6 E 26.1J N ....... S7~'24"E .......... 45~'48 N 54 57 E 42.92 N 54.34 E 69.24 N 51 42 E 64.18 N 73.48 E 97.56 N 48 52 E 90.09 N 94.84 E 1~0.80 N 46 28 E 120.56 N 118.64 E 169.14 N 44 32 E 154.62 N ~44.31 .... E ....... 2t1.'50 N 43 1 E ~90.79 N 172,06 E 256.92 N 42 S E ~9,°° 05 N 203,05 E 306.10 N 41 33 E 3.33 3.77 2.76 2.84 2.98 3.27 2.00 1.81 3,16 16, WELL NO; I GM~ .JOB NO~ A0382=60408 TIME DATE ' ~ ' . · .q · ........... ; 14:4]';58 .... 25'MAR=82 PRUDHOE"BAY, NORTH ~LOFE, AI_ASKA TRUE '~EASURED-~PRI~FT ............... [iRIFT ............... C'OURSE-'VERTICAI:"Y-VERTICAI, .... SUBSEA ....... R'E"C"'T--A"--N-G-'Li-'~E'"-A"'R' C'L-'O'SU R E DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D H D M FEET FEET FEET FEET FEET FEET D H DG/100FT 6000, 5~ 15 N 48 0 E ~00, 4882,99 28~4,01 4789,99 1871,50 N 1859,31 E 2638,09 N 44 6100. 5~ ~0 N 47 0 E 100, 4922,6=~, ._-~7~4,26 4849,65 1925,72 N 19_~_8,48 E 2718,26 N 44 6200; ..... 54 ........... 0'~' N"50 ............. O-E ...... 100:~- ......... 498':1"';78 ..... 2794 :,.'90 4908.,: 78 1979;15-'N .... 1-978-,~ 87'-'E ..... 2798 ;74' N'- 45 6300... 53 0 N 52 0 E 100. 504:1.26 287...%.:18 4968.26 2029.7~ N 2041.~4 E 2878.89 N 45 6400. 53 ;0 N 52 0 El 100. 5101.09 2955.09 5028.09 2079.08 N 2:104.48 E 2958..26 N 45 6500, 55 0 N 52 0 E 100, 5:15~,52 3038.05 5086,52 2129,02 N 2188,43 E ~038,88 N 45 6600, 55 ~0 N 52 0 E :100, 5216,52 31~8,02 5143,52 2179,61N 22~,J7 E ~120,54 N 45 6700; 56' 1~ N ~3 0 E ........... ]'00'~ ......... 5272~62 S200~.4 5199 62 6800. 57 0 N 5~ 0 E 100. 5327.63. 3~83~ .73 ..~_~:~a.6~ ...:80.26 N 2365.54 E ~285.63 N 46 6900 .8 0 N 5~ 0 E 100, .~81,~6 3387,75 .,~.08 38 2331 02 N 24~2o90 E ~&9,~7 N 48 . 49 E 0.84 54 E 0,84 0 E 2,47 10 E 1,89 21E 0,50 32 E 42 E 0,50 52 E 1,12 ~ E 0.75 14 E 1,00 7000. 58 45 N 52 0 E 7100. 59 0 N 53 0 E ' 7200; 58'-45"N~"5~ ......... 0" E 7300, 58 45 N 54 0 E 7400, 59 45 N 54 0 E 7500 7800 7700 7800 7900 , 60 0 N 54 0 E 100, 5690,37 J879.84 . 59 15 N 53 0 E :100, 5740,94 3965,7:1 . 59 30"N 54 O~'E ..... :1~00'~ 5791~88 4051,37 , 80 0 N 53 0 E 100, 5842,25 4}~7,35 , 60 45 N 52 0 E 100, 5891,69 4224,01 :100~ .......... .¢ 3~,79.. ~452,64 .~60,79 --38.-,8~ N ~00,4~ E ~00.::,::,~48~ 48.:~u~7,97 5412,48 24~4,96 N 2568,~6 E 17 ..3623' 25 5484' 17 248~;;48~;;~ · 7~ E i 5589.05 ~708.~5 E 5667.94 5718.88 5769 · 25 46 46 46 46 47 ~,~4.09 N 47 5818~69 2845,49 N S121,88 E 4~ S454,02 N 3624~21' ~709,11 N ~794,39 N ~880,28 N 47 9 E 2690,00 N 2914,30 E 3986,01 N 47 18 E 2741;'19 N 2983'¥'48'-'E 4051',57 N 47 25 E 2792,57 N ~052,91E 4:1~7,48 N 47 3~ E 39 E 23 E :1,13 32 E 0.89 4:1 E 0,25 50 E 0,85 0 E 1,00 0,,25 J .14 0.90 ~5 8000 8100 8200 8300 8400 · 60 0 N 49 0 E 100, 594:1.:12 4~10,85 5868,12 2900,77 N 3:188,95 E 4310,90 N 47 43 E . 59 0 N 49 0 E 100. 5991.87 4397.00 5918.87 2957.30 N S253.97 E 4397.04 N 47 44 E ~ ~ S012,'68'---N ...... S'~8'"~'81 .....E ..... 4482'~26 · ~8 0 N 50 ...... 0 E ..... :100~ ....... 6044'.12 4482~23 597~ :1_2 N'47 46 E , 57 15 N 51 0 E :100. 8097°67 4568.80 6024.67 3066.40 N ~83.98 E 4586.63 N 47 49 E · 57 0 N 5:1. 0 E 100. 6151.95 4650,47 8078.95 3119o25 N ~449.24 E 4850.48 N 47 53 E 2~71 1.00 1~31 1,13 0,25 8500~ 57 0 N 51 0 E 100, 6206,41 4734,22 6.133,41 3172,03 N 3514,42 E 4734,23 N 47 56 E 8600, 56 15 N 51 0 E 100, 6261.42 4817.62 6188.42 S224,58 N 3579,32 E 4817,62 N 47 59 E 8700 56 0 N ,.,.- 0 E 100, 6~17,16 4900 48 6244 16 S276~26'N ..... S644~29-E '4900 49 N 48 S E 8800. 56 0 N 51 0 E 100, 6373.08 4983.23 6300~08 3327.87 N 3709.~7 E 4983.24 N 48 6 E % 00 3380~04 N 3773,60 E 5066.04 N 48 9 E 8900~ 56 0 N 51 0 E 100~ 6429,00 5066.02 63~6~ 0.00 0.75 0,87 0.83 0.00 '~.~S 16., WELL NO: ~ GM~ JOB NO: A0382-'G0408 TIME DATE F'RUDHOE-'BAY~ NORTH SL"OF'E"~ .... AI/ASKA 14:'4! :58 '25'~MAR~'82 TRUE HEASUREEr-DRI-FT .............. DRIFT ............. COURSE-VERTICAl_VERTICAl, SUBSEA R E~-C--~T-A--N----G----~U--U---A-R C'L"O'S"-U-R--E'- ...... DOGL'EG- DEPTH ANGLE DIRECI'ION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET B H D H FEET FEET FEET FEET FEET FEET D H DG/IOOFT 9000, 55 15 N 52 0 E ]000 6485,46 5148,40 6412,46 34~1,42 N 38~8,19 E 5148043 N 48 12 E 1,12 9100, 55 0 N 5~ 0 E 100, 654~ 64 ~ ~, .~.~0,25 6469,64 ~481,94 N ~02,84 E 5230,~0 N 48 16 E 0,25 ...... 9200~ .....54 ~0 N~52 .... O-'E .......... 100~ ......... 6600~75 ..... 5~J'1-~7-1 6527,~5 ~532~'21~-N ..... S967-~--]9 'E ..... 5~t1--,'79 N----48.-~19 E 0,50 9300, 54 30 N 52 0 E 100, 6658,42 5392,92 6585,42 3582.3~ N 40~1,35 E 5~93o04 N 48 2~ E 9400, 53 30 N 52 0 E 100, 6717,20 547~,63 6644°20 ~6~2,14 N 4095,10 E 5473,78 N 48 26 E 1o00 9500, 53 15 N 52 0 E 100, 6776,86 5553,69 670~,86 3681,55 N 4~.58,~4 E 5553°88 N 48 29 E 9600, 53 0 N 52 0 E JO0, '6836,87 5633,49 676~,87 37~0,80 N 4221,~7 E 563~o7~ N 48 32 E 0,25 ..... 9700i .~ 45 N 53 0 E 100~ ........ 6897~22 57J2',98 6824,22 "~779~4-"N ...... 4284-'~'6~-"~E ..... 57~'3,27 '~N'"48'~5 E 0.84 9800, 52 45 N 52 0 E 100, 6957,75 5792,~ 6884,75 ~827,80 N 4~47,79 E 5792,69 N 48 ~8 E 9900, 52 45 N 52 0 E 100, 70~8,28 5871,74 6945,28 ~876,80 N 4410,51 E 5872,16 N 48 41 E 10000, .52 15 N 50 0 E 100,,..~_~¢.7079,16 ~5950,96 7006,16 3926,73 N 4472,~6 E 5951,42 N 48 43 10100, 52 15 N 49 0 5 J.O 3978,08 N 45~2o29 E 60~0,48 N 48 44 E ....... t0200,' 50 45 N 49 0 E 67 .6108,~ 71~9,6~ 40~9,4~ N :4~91,~5 E 6108,'74 N 48 44 E 10~00, 50 15 N 49 0 E 100~77266,24 ....... 6~8~;"4d' 7197'24 4080'04 N 4649,58 E 6185,90 N 48 44 E 10400, ~OS 15 N 49 0 E 1007~;;::~:~7~S0,18 6262~27" 4707",61 E 6~6~,_ _ 79 N 48 44 E 10500, 49 15 N 50 0 E 100, 7~94,79 67~8,56 7~21,79 4180~05 N 4765,64 E 6~79,10 N 48 45 E 10600~ 48 S0 N 50 0 E 100~ 7460,56 64JS,84 7787,56 4228,47 N 4827,~5 E 6414,41 N 48 46 E 10700+ 48 0 N 52 0 E 1-00-,-"' 7:527','15 6488, S4 7454,15 4275~42 N -4881,"72 E 6488,95 N 48 47 E J0800 47 15 N 52 0 E J00 7594~55 6562 04 7521 * , · ,~ 4720 90 N 4979,54 E 6562~71 N 48 49 E 10900, 46 S0 N .S 0 E 100~ 766~,9J 6674,80 7589~91 4~65~SS N 4997~44 E 6675,55 N 48 52 E lj000, 46 0 N 57 0 E 100, 77~2~06 6706+76 7659,06 4408,80 N 5055~JS E 6707~60 N 48 54 E J. 1100, 45 0 N 54 0 E 100~ 7802,J5 6777,76 7729,15 4451,27 N 5112,47 E 6778~70 N 48 57 E J'1200~- 44 ~0 N 55 0 E 100'~ ............ 78'77"~'17 ..... 6847~70 7800,17 4492~'11 'N ....... 5J69~'78- E -6848~77 N 49 i E lJ~00~ 47 ~0 N 57 0 E J00, 7945,10 6916,49 7872~J0 4570,95 N 5227,77 E 6917,72 N 49 5 E 11400, 4~ 0 N 59 0 E 100~ 8017~94 6987,96 7944~94 4567,26 N q~o5.,..o.,47 E 6985,42 N 49 10 E 11500, 42 0 N 58 0 E J00, 8091~66 7050~79 8018,66 4602,56 N 5747,07 E 7052~09 N 49 15 E 11600~ 41 15 N 59 0 E 100~ 8J66,41 7115,70 8097,41 4677,26 N 5799,71 E 7117~66 N 49 21 E J1700, 40 S0 N 59 0 E 100, ..... 8242~07 7179,94 8169,07 4670,97 -N 5455,-80.E 7182,18 N 49 26 E 11800 ~9 0 N 60 0 E 100, 8S18 91 7~4~ 60 8245 , · .... · ~ ~.~0 89 E 7245 15 N 49 S1 E 11900, S9 15 N 59 0 E 100~ 8796,48 7~04~47 8727,48 47~5,45 N 5565,26 E 7~07,S0 N 49 ~6 E 0,80 0,00 1,66 0,79 1,50 0,50 0,00 J ,26 0,75 1,57 0,50 1,27 0,86 1,71 1,46 ~,21 J,O0 0,75 1.63 0,68 WELL NO,* 1' Gt4~ .JOB NO** A0382-'60408 TIHE Ir;ATE PRUDHOE'""'BAY' NORTH"SLOPE~ A~'A'SK'A 14,* 4.1."** 58 25~MAR~82 TRUE MEC~SURED'""'DRIFT ............... DRIFT ............. 'COURSE°-VERTICAi-~'"-VERTICAI-- ....... SUBSEA ..... R E' C"'"'T'~'A "'N-G--U--E-A"- R C-k.-"O""S -U 'R E ..... DOGLEG-' DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/IOOFT 12000, ~8 0 N 5~ 0 E 100, 8474,61 7~65,70 840J,61 4767 GO N 5618,77 E 7~68,8~ N 12100, ~7 0 N &~ 0 E 100, 855~,~4 7425,01 8480,~4 47~7,10 N 5672~00 E 7428,58 N ' 1'2200~ ....... ~5 '45'-N '~62 ....... O'-E ........ IO'O; ........... 8'6S'4~-45 ........ 7482~42 ......... 8561 ;'45 ........4824-';"49-'N ........5724;~60--E 12~00, ~5 0 N 6~ 0 E 100, 8715,~ 75~8,47 864~,9~ 4851,~n N 5775,~& E 7542,~4 N 4~ 58 E ~_2400, ~4 0 N 62 0 E ~00~ 87~8~40 759~0 8725 40 4877,~7 N 5826,1~ E 75~8~24 N 50 4 E 1,15 12500~ ~2 45 N &4 0 E 100~ 8881,~ 7646,44 8808,9~ 4902,~4 N 5875~21 E 7651,87 N 50 12600, ~0 45 N 65 0 E 100, 896&,94 7696,8~ 889~,94 4~25,00 N 5922~70 E 7702,86 N 50 15 E 2,07 '12700~ ~0 ~0 N &4 O"-E .......... 100";- ...... ~0'5'2,"~9' '7745',7~ 8~79,99 '4946~'~--"N .......... 5~&8~68'-E'~ 7752,24' ' N 50 2~ E 0,57 12800~ ~0 0 N 64 0 E 100~ 91~,~8 7794~16 9066,~8 4969~01 N &01~6 E 7801,20 N 50 12900, 29 0 N &~ 0 E 100, 9.,~6,4J 7841 61 9~5~ 4J 49~0 98 N &058,02 E 784~ J7 N 50 ~ E i 11 ......................................................... PROJECTED TO TD FINAl_ CLOSURE -DIRECTION'. '~";/'v '"Tc~v;::'~'~;:vq~'GS'-S&- .,,,,. ,,.,.~,,.,.*.~ ~,.-.~ ~ MINS 2& SECS E .... DISTANCE; 7905,99 FEET ARCO At. ASI~A I'NC:, ' ............. DS .... 1'6¥ ......... WEIL'L-'i~O~ .....1 .......... GMS ........................................................................ ~JOB"NO: .......AO382-G0408 PRUDHOE BAY, NORTH SLOPE, Al. ASEA GMS, 0-12900 MD, SURVEYOR; F'F:FFERKORN/LIlND, DATE RUN: 06-MAR-82 GYRO NO: 627, 90 DEG A/ll NO: ~535, CAMERA NO; ~287, 3369 FORESIGHT: N6E (BENCHMARk') ~S 16, WELL NO; ~ GMS JOB '"'I~FRD[HOE .................. BAY, NORTH S[.OFE,' Al. ASEA 14:47;37 NAME DEF'TH DEPTH DIFF DEPTH C 0 0 R D I N A T E S DISTANCE DIRECTION THICKNESS FEET FEET FEET FEET FEET FEET D M TOP OF SADLEROCH1T 12536°00 8912,5~ ~62305 88~9,52 4910,50 N o89,.,3J E 7670 22 N 50 12 E OIL/WATER CONTACT 12759°00 9~03~96 3655,0 90~0,~6 4959°96 N 5995,39 E 7781012 N 50 24 E PBTD J2979000 9295,5J ~6830~. 9~,.1~_~ ~ 5008,37 N &O92,J5 E 7886,57 N 50 ~5 E TD 13020,00 93~1o37 3688°6 9258°37 5017,~9 N 6109,86 E 7905°99 N 50 36 E J Eastman / ~ Whipstock l A PETROLANE COMPANY REPORT of SUB-SURFaCE D~REC TiOJV~ £ SURVEY Arco 0il & Gas COMPANY D.S. 16, Well No: 1 WELL NAME Prudhoe Bay, North.. Slope, Alaska LOCATION JOB NUMBER A1280D01 29 TYPE OF SURVEY Directional Single Shot DATE 1-20-8'1 SURVEY BY Jerry Cook/Lynn Hensley ....... :;~..._'~--.,-_~... - .... ...... OFFICE Alaska Eastman Wh p s t o,£ P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-4617 TWX 910-881-5066~Cable: EASTCO January 20, 1981 ARCO 0il & Gas ?. O. Box 1479 Anchorage, Alaska 99510 Well Number: D.S. 16, Well No: 1 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Directional Single Shot Date: January 20, 1981 Method of Computation: Radius o£ Curvature Surveyor: Jerry Cook, Lynn Hensley Job Number: A1280D0129 Attn: Bob Hines Dear Mr. Hines I am enclosing the original and one copy of the Directional Single Shot Survey run on the above men- tioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, J~m Turnage District Operations Manager Alaska District JT/cfw cc: file eno. Oirec'tioa,a.i Dflllers/Su~dace SurVeyors/Instrument & Tool Rentals/Sales/Worldwide 32;;!8., "-:;4 4 ......... ¥290: ,-"i. S42., 85 N '"'"'-' '~" ,., ',. :'. · '.~ i ~..c' 73,7, "7.;' 7 ;i~47'7, .%4 206,60 N 6,53 · 66 ~ ";'6<;:', ,40 · .:', o c> .; . 1 0 1 0 5 3,, 7 4 J'~ ~. "" i 0 · 8 0 f' ! 4 o 0,1. ,' -,'<'" I o ."z-. ......... Gg, .- .. N 43 4"}' E O, N 44 '"" '"' 6079 ~ 19 £347 · 87 66,t=)~, 37 ,:!i, -i:-' 7~ o 7283,79 4,57 ~ --,.., 7 .=-~, ~ ...'~:: 4,:":'":?.;932 · 75 · .~._,3, 84000 0 .... '-='70 ~ 09 ..... .:, : -. .~.i. , ._ ..-~ .,) , d .0..', .:', "Z "" '"''"-' -- ::, .~, ,: o ~, c., -...., :",.'~,/ ,.:- 52 · U,3 ..: A "] .~. ' -,,,.. ,-..c.' 8800,25 .:-<::'SO0, ,'6<!, ...... 2!L::, · 2!2 .... ,."',. ='~, 79"4~64 4..56::it,78 t-~ .47 L, 6 [:' i i,C, 2 ,-."~. 5-' 78 ,~ O 0 ;'~ 47:15 i ,r'i: 0 ~. 3 ':5 r,E 4 ~...:: ........ ._,--, ...... q. 6 N 4 ;'s 2 El 0,,-..' .... ,. S837,7j. t'4 -4di; :i.O iE 0~4]. 624:.5.67 t-4 48 i;;: E 0,40 , .-~.:,-... !'lEGS Si t-{lNg 26 SE,i;S E. 7 ? 18 · '.'.-' 9 F' '.7.;; El T' ARCO :~L D$:-"~I 6!.,"Y t, IEUL?iN8:! i--.;-P R UDHC! E: -BFI¥~-~N D R TH ~---NORTH'iSLO.P. Ei ARCO ALASKA !N'C. I)S lc'>, WELL-NO; 1 .... GMS ' .JOB NO: AO382-G0408 .......... PRUr_;HOE BAY, NORTH SI_OPE, AI.ASIc,'A GMS, 0-12c~00 MD, ,~URVEYOR; PEFFERKORN/L..UND, DATE RUN: 06-MAR-82 GYRO NO; &27, c/O I)EG A/U NO; 1535, CAMERA N(]; 3287, . FORESIGHT: N6E (BENCHMARK) VERTICAl_ SE'CTION CALCULATED IN F'I. ANE OF PROPOSAl_ DIRECTION; N 48 DEGo 0 MIN. E RECORD OF SURVEY RAD]'IJS OF' CURVAI'LIRE METHOD 16, WELL NO~ I Gf4S !'RUDHOE BAY, NORTH SLOPE, AI_ASKA ,JOB NO: A0382-~0408 · T I ME DATE 14: 41; 58 25-MAR-8? TRUE IEASURED DRIFT ' DRIFT COURSE VERTICAl_ VERTICAl, SLIBSEA R E C T A N G U L A R C I... 0 S'U R'E -DOGLEr: DEF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI] FEET Ir; M D M FEET FEET FEET FEET FEET FEET D H lqG/l 00F O. 0 0 0 0 100. 0 15 S 34 0 E 200. .... 0 15 N 59 0 E 300. 400. 500. 600. 700. 800. 900, 0 15329 OW 0 15 N 27 O W 0 15 S 71 0 E 0 30 S 28 0 E 0 30 S 53 0 E 0 15 N 38 0 E 0 0 0 0 O, 0,00 0.00 -73,00 0,00 0.00 100, 100,00 -0,03 27,00 0,18 S 0.12 E 100' 200.00' 0.20 ~127"00 0~27 S 0.51E 100. 300.00 0.22 227.00 0.49 S 0.74 E 100. 400.00 -0.04 327.00 0.48 S 0.38 E 100. 500,00 0.30 427,00 0,23 S 0,61 E 100. 599,99 0,38 526.99 0.84 S 1,09 E 100. 699,99 0,36 626',99 1,30 S 1,66 E 1.00, 799.99 0.85 726.99 1.22 $ 2.24 E 100. 899.99 '1.06 826.99 1.05 S 2.38 E · 0.00 0 0 0.22 S 34 0 E 0.57 S 62 23 E 0.89 S 56 30 E 0.62 S 38 26 E 0.65 S 69 35 E 1.27 S 59 36 E 2.11 S 51 52 E 2.55 S 61 24 E 2,60 S 66 8 E 0.00 0.25 0.34 0.48 0.44 0.36 0.22 0.56 0.25 1000, 0 0 0 0 1100, 0 0 0 0 1200. 0 15 N 27 0 E 1300. 0 0 0 0 1400. 0 30 S 27 0 W 1500, 1600, 1700, 1800. 1900, 0 30 S 8 0 W 0 30 S 23 0 W 0 30'S 61 0 E 2 0 N 77 0 E 2 45 N 53 0 E 100, 999,99 100, 1099.99 1.00, 1199,99 100, 1299,99 100, 1399.99 100. 1499.98 100. 1599.98 100, 1699.97 100. 1.799.95 100, !899.86 1,06: 926,99 1.05 S 2.38 1o06 ,,1026:;99 1.05 $ 2,38 1,27. 1126:'99 0,86 S 2.48 1.47 1226,99 0,66 S 2,57 ~,06 '1326~:~99' 1,05 $ 2.38 0.31 1426.98' 1.88 S 2.11 -0.42 1526.98 2.72 S 1.88 -0.73 1626.97 3.47 O. 64 1726.95 4,57 1826.86 2.03 S 7,98 .... 2,60 S 66 8 E 2.60 S 66 8 E 2,62 S 70 53 E 2,66 S 75 31E 2.60 S 66 5 E 0.00 0,00 0.25 Oe~~' 0.50 '~ 83 S 48 20 E 3,31 S 34 40 E: 0.13 4.08 S 31 39 E 0.67 5.68 S 48 27 E .~66 8.24 ,q 75 43 E 23 2000. 6 0 N 43 0 E 2100. 9 45 N 46 0 E' 2200. 12 30 N 47 0 E 2300. 15 15 N 44 0 E' 2400. 18 0 N 40 0 E 100. 1999.56 !00, 2098.60 !00, 2196.71 100. 2293,78 100. 2389.59 12,19 1926,56 25.86 2025,60 45,15 2123,71 69.10 2220.78 97,55 2316.59 3.07 N 13.64 E: 12.83 N 23.24 E 26.11 N 37.24 E: 42.92 N 54.34 E 64,18 N 73.48 E 13.98 N 77 20 E: 26.55 N 61 6 E 45.48 N 54 57 E 69.24 'N 51 42 E 97.56 N 48 52 E 3.33 3,77 2.76 2.84 2.98 2500. 21 15 N 39 0 E 2600, -~4,., 1~'., N 37 0 E '~700.,: 26 15 N 37. 0 E 2800. 28 0 N S8 0 E' 2900. 31. 0 iq 40 (', E 100. 2483.77 100. 2575.98 !00. 2666.42 JO0. 2755.42 100. 2842.44 130.76 2410.77 168.83 2502.98 210.71 2593.42 255.5~ 2682.42 304.16 2769.44 90.09 N 94.84 E 120.56 N !1.8.64 E 154.62 N 144.31 E 190.79 N 172.06 E 229,05 N 203.05 E 130.80 N 46 28 E 169.14 N 44 32 E 211.50 N 43 1E 256.92 N 42 3 E 306,10 N 41 33 £ 3,27 2,00 1,81 3,16 WELL Nf~; 1 GHS ~'RUlr~HOE' BAY, NORTH SLOPE, AI,ASKA JOB NO; A0782-G0408 · T I HE DATE 1.4;41;58 ' 25-MAR-82 TRUE 4EASURED-I)RIFT DRIFT-' COURSE ·VERTICAl_ VERI'ICAI. SUBSEA R E C T A~-N~B---U L A R DEF'TH ANGLE DTRECTION LENGTH DEPTH FEET D H D H FEET FEET 7000. 34 0 N 79 0 E 100. 2926.77 3100. 77 0 N 39 0 E ]00. 3008.17 3200.' 39 30 N 41' 0 E' 100. .... 3086.70 3300. 41 ]5 N 43 0 E 100. 3]62.88 3400. 45 15 N 44 O E 100. 3235.70 . 3500. 48 0 N 44 0 E ]00. 3304.37 3600. ~ ~.0 ]5 N 46 0 E 100. 3369.8] 3700. 52 0 N 46 '0 E 100.' 34~2.57 3800. 51 30 N 46 0 E 100. 3494.48 3900. 52 0 N 46 0 E 100. 3556.39 4000. 51 45 N 46 0 E 4100. 51 45 N 45 0 E 4200. 51 ]5 N 46 0 E 4300. 51 15 N 46 O E 4400. 51 15 N 46 0 E · 4500. 51 0 N 46 0 E SECTION TVD FEET FEET 357.29 2853.77 414.64 475.94 3013.70 540.36 3089.88 608.65 3]62.70 681,~6 3231.37 756,66 3296,81 874.46 3~59,57 912.94 3421,48 991,42 100. 3618.12 1070.04 3545.12 100' 3680.03 1148.49 3607.03 ]00. 3742.28 !226,68 3669'28 · 100. 3804.88 1704.62 773].88 C L 0 S II R E _ DOGLEF. C O 0 R D I N A T E $ DISTANCE DIRECTION SEVERI] FEET FEET D M DG/100F 270.51 N 2~7.22 E 359.79 N 4] 15 E 315.63 N 273.76 E 417.8] N 40 56 E 363.'05~N .... 313.55 E '479.7] N 40 49 E 544.47 N 40 57 E 612.91 N 41 14 E 685.52 N 41 32 E 761.00 N 41 53 E 838.66 N 42 16 E 917.04 N 42 35 E 995,44 N 42 51 E 411.19 N 356.89 E 460.88 N 404.05 E 513.16 N 454.54 E 566.62 N 508.00 E 620.'70'N ...... 564.'00 E 675.25 N 620.49 E 729.80 N 676.98 E 784.44 N 733.56 E ]074.00 N 433 5 E 839.49 N 789.57 E 1152.46 N 4,7 15 E 894~(34'~iN.i(,78'45.39 E ]230.66 N 43 23 E 948.52 N 901.49 E 1308.58 N 43 33 E 100. ~867.47 13~2.56 3794.47 1002'69 N" ~9 E 1386 50 N 43 41 E 100. 3930.23 1460.36 3857.27 1056.77 N ]013.59 E 1464.29 N 43 48 E 4600~ 51 0 N 46 0 E 100. 3993.16 1538.03 3920.16 1110.75 N 1069.50 E 1541.95 N 47 ..~:"~,_, F. 4700, 50 30 N 46 0 E 100. 4056.4,7 !615.42 3983.43 1164.55 N 1125.20 E 1619.34 N 44 .1 E' 3.05 3.00 2.79 2.18 4.06 ~../5 2.71 0.50 0.50 0.2%~. 0.79 0.9S 0,00 0,00 0. 0. ,%0 4800. 50 0 N 46 0 E 4900. 50 15 N 47 0 E ,5;000. 50 0 N 46 0 E 5100. 51 0 N 46 0 E 5200. 51 15 N 45 0 E 5300. 51 1.5 N 45 0 E 5400. 52 0 N 46 0 E 5500. 52 30 N 45 0 E 5600. 52 30 N 46 0 E 5700. 52 45 N 46 0 E 5800. 5S 0 N 47 0 E 5900. 53. 0 N 47 0 E 100 4120,38 1 'oo o ,.. -. · ..o,,: .... 6 4047.38 1917.96 N 1180.51 E 1696.18 N 44 6 g ~5:,0 100. 4184.49 ]768.98 4111.49 1270.79 N 1236.18 E 1772.86 N 44 1.3 E 100. 4248.60 ~845.70 4~75.60 1323.61 N 1291.85 E 1849.55 N 4,1 18 E' 100. 4712.21 1922.8] 4239.21 1377.22 N 1347.35 E 1926.68 N 44 22 E 100. 4374.97 2000.59 430].97 1431.78 N- 1-402.88 E 2004.5.1 N 44 25 E ]00. 4437.56 2078.47 4764.56 1486.93 N 1458.02 E 2082.49 N 44 26 El 100. 4499.64 2156.79 4426.64 1541.87 N 1513.94 E 2160.88 N 44 29 E _. 100. 4560.87 2235.78 4487.87 1597.29 N 1570.33 E 2239.93 N 44 31 E ]00. 4621.74 2315.04 4548.74 1652.90 N 1626.92 E 2319.25 N 44 33 E' 100. 4682.44 2394.46 4609.44 1708.10 N -t684o08 E 2398°70 N 44 S6 E ]00. 4742.80 2474.17 4669.80 1762.99 N 1741.92 E 2478.39 N 44 39 E 100. 4802.98 2554.02 4729.98 1817.45 N ]800.33 £ 2558.19 N 4,1 44 E .8t 0.8i 1..00 0.82 0.00 1 · 08 0,94 O. 7':.," 0.2 ,'5 O. 8,1 0,0o 16, WELL NO: 1 GMS F'RUDHOE BAY, NORTH SLOPE, ALASKA .JOB MO: AO382-G0408' I'IME DATE 14~41:58 25-MAR-82 TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G [; L A R C L 0 S U R E BOGLE DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVB C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/100 6000. 5~ 15 N 48 0 E 6100. 5G 30 N 47 0 E 6200. 54 0 N 50 0 E 6~00. 53 0 N 52 0 E 6400. 53 30 N 52 0 E: 6500. 55 0 N 52 0 E 6600. 55 30 N 52 0 E 6700. 56 15 N 53 0 E 6800. 57 0 N 5~ 0 E 6900. 58 0 N 53 0 E ]00. 4862.99 26~4.01 4789.99 ].871.50 N 1859.~] E 2638.09 N 44 49 E 100. 4922.65 27]4.26 4849.65 1925.72 N 19~8.48 E 27].8.26 N 44 54 E 100. 498].78 2794.90 4908.78 1979.15 N 1978.87 E 2798.74 N 45 0 E 100. 504~.26 2875.~6 4968.26 2029o7~ N 2041.~4 E 2878.69 N 45 10 E 100. 5101.09 2955.09 5028.09 2079.06 N 2]04o48 E 2958.26 N 45 21 E 100. 5159.52 3036.05 5086°52 2129.02 N 2168.4~ E ~0~8.88 N 45 ~2 E 100. 5216.52 ~1~8~02 5143.52 2179.61 N 22~0~7 E 3120.54 N 45 42 E 100. 5272.62 ~200o54 5199.62 2230.00 N 2298.85 E ~202.75 N 45 52 E 100. 5~27.6~ ~283o7~ 5254.6~ 2280.26 N 2~65o54 E ~285.6~ N 46 ~ E 100. 5~81.36 3367.75 5~08o36 2331.02 N 24~2.90 E 3369.37 N 46 14 E 0.84 0.84 0.5(- · 1.1F O. 75 7000. 58 45 N 52 0 E 7100. 59 0 N 5¥ 0 E 7200. 58 45 N 53 0 E 7300. 58 45 N 54 0 E 7400. 59 45 N 54 0 E 7500. 60 0 N 54 0 E 7600. 59 15 N 5: o E 7700. 59 30 ~ 54 0 E 7800. 60 0 ~ 53 0 E 7900, 60 45 N 5~! 0 E' 8000. 60 0 N 49 0 E 8100. 59 0 N 49 0 E 8200. 58 0 N 50 o E 8300. 57 15 N 51 0 F: 8400. 57 0 N 51 0 E ~00, 5433,79 3452,64 5360,79 2382,85 N 2500.45 E 3454,02 N 46 23 E 100. 5485.48 3537,97 :5412.48 2434.96 N 2568.36 E 3539.14 N 46 32 E 100. 5537.17 ~623.2~ 5464.17 2486.48 N 2636.73 E 3624.21 N 46 4J E · 100. 5589.05 ~708,35 5516.05 2537.33 N 2705.45 E ~709.11 N 46 50 E 100. 5640.18 ~793~8~ 5567.18 2587.84 N 2774~98 E 3794.39 N 47 0 E 1.:i:.. 0.8< 0.'")r 0.8:' 100. 5690.37 S879.84 5617.37 2638.69 N 2844,95 E 3880.26 N 47 9 E O.?r 100. 5740.94 3965.7] 5667.94 2690.00 N 2914.30 E 3966.01 N 47 18 E 1.1/ ~00. 5791.88 4051.37 5718.88 2741.19 N 2983..48 E 4051.57 N 47 25 E 0.9; 100, 5842,25 4137,35 5769,25 2792,57 N ~052.9! [:: 4137,48 N 47 33 E 100. 5891,69 4224,01 5818,69 2845,49 N 3121.88 E 4224.09 1.00. 5941.12 4310.85 5868.12 2900.77 N 3~88.95 E 4310.90 N 47 43 E 100. 5991.87 4397.00 5918.87 2957.30 N 375~o97 E 4397.04 N 47 44 E ]00. 6044.12 4482.23 5971.1.2 3012.68 N 3318°~]. E 4482.26 N 47 46 E ~00. 6097.67 4566°60 6024,67 3066,40 N 3383~9~ E 4566.63 N 47 49 E !00. 6151.95 4650.47 6078.95 3119.25 N 3449~24 E 4650.48 N 47 53 E 1. 0.2.."' 8500. 57 0 N 51. 0 F: 8600. 56 1.5 N 51 0 E 8700. 56 0 N 52 0 E 8800. 56 0 N 51 0 E 8900. 56 0 N 51 0 E 100. 6206,41 4734,22 6133,41 31.72,03 N 35:14,42 E 4734,23 N 47 56 E 100. 6261.42 4817.62 6188.42 3224.58 N 3579.32 E 4817.62 N 47 59 E 100. 6317.16 4900.48 6244,16 3276.26 N 3644.29 E -4900.49 N 48 S E 100. 6373.08 4983.23 6300,08 3327.87 N 3'709.17 E 4983.24 N 48 6 E 100. 6429,00 5066,02 6S56.00 SS80.04 N S77~.60 E 5066.04 N 48 9 £ 0.7! 0,0:' }.;S i6, WELL 'NO: 1 GMS PRUDHOE BAY, NORTH SLOPE, AI.ASKA JOB.NO~ AO38Ef-60408 MEASURED DRIFT DEPTH ANGLE FEET I) Pi TRUE 7DRIFT COURSE VERTICAl_ DIRECTION LENGTH DEPTH D M FEET FEET VERTICAl_ SUBSEA SECTION TVD FEET FEET 9000. 55 15 9100. 55 0 9200. 54 30 9300, 54 30 9400. 53 30 9500. 53 ?600. 53 9700. 52 9800, 52 9900. 52 10000. 52 10100. 52 10200. 50 10300. 50 10400. 50 N 52 0 E 100. 6485.46 N 52 0 E 100, 6542,64 N'52' 0 E ......100, 6600.35 N 52 0 E 100, 6658.42 N 52 0 E 100, 6717,20 · 15 N 52 0 E 100. 6776.86 0 N 52 0 E 100, 6836.87 45 N 53 0 E ' 100, 6897.22 45 N 52 0 E 1.00. 6957.75 45'N 52 0 E 100. 7018.28 15 N 50 0 E 100, 7077.16 15 N 49 0 E 100o 7140,38 45 N 4? 0 E 100, 7202.63 15 N 49 0 E 100, 7266.24 15 N 49 0 E 100, 7330.18 5148.40 6412.46 5230.25 6469.64 5311,71 6527.35 5392.72 6585.42 5473.63 6644.20 5553.69 6703.86 5633.49 6763.87 5712.98 6824.22 5792.33 6884.75 5871,74 6?45.28 5950,96 7006.16 6030,00 7067.38 6108.25 7129.63 6185.40 7193.24 6262,27 7257.18 TIME DATE 14~41:58 25-MAR-82 R E C T'A--N'G"U L A R COORDINATES FEET 343]..42 N 3838.17 E 3481,94 N 3902.84 E 3532.21-N 3967.19 E 3582.33 N 4031.35 E 3632,14 N 4075.10 E 3681.55 N 4158.34 E 3730.80 N 4221,37 E 377?.34 N '4284.&3 E 3827,80 N 4347,7? E 3876,80 N 4410,51E 3?26,73 N 4472,16 E 3?78,08 N 4532,2? E 402~,42 N 4571,35 E 4080,04.N 464?.58 E 4130,48 N 4707,61 E C L 0 S U R E' DOGt: DISTANCE DIRECTION SEVER FEET D M DG/I .c., 5148.43 N 48 12 E ]..~ 5230,30 N 48 16 E 0.2 5311.79 N 48 19 E 0,5 5393.04 N 48 23 E 0.0 5473.78 N 48 26 E 1,0 5553.88 N 48 29 E ~.2 5633.73 N 48 32 E 0.2 5713.27 N 48 35 E 0,~ 5792.69 N 48 38 E 0.~i; 5872.16 N 48 41E 0.0 5951,42 N 48 43 E 1.6 6030.48 N 48 44 E 6108.74 N 48 44 E 1,5 6~85,90 N 48 44 E 6262.79 N 48 44 E 10500. 49 10600. 48 10700. 48 ]0800. 47 10900. 46 11000. 46 11100. 45 ~1200. 44 11300. 43 11400, 43 15 N 50 0 E 100. 7394.79 30 N 50 0 E 100. 7460.56 0 N 52 0 E 1.00. 7527.15 1.5 N 52 0 E 100, 7594.55 30 N 53 0 E 100. 7662.91 0 N 53 0 E 100. 7732.06 0 N 54 0 E 100. 7802,15 30 N 55 0 E 100. 7873.17 30 N 57 0 E ~00. 7745.10 0 N 59 0 E 100, 8017.94 6338.56 64~3.84 6488.34 6562.04 6634.80 6706.76 6777.76 6847.70 6916.49 6983~96 7321.79 4180.05 N 4765,64 E 7387.56 4228.47 N 4823.35 E 7454.15 4275,42 N 4881.32 E 7521.55 4320.?0 N 4937.54 E 7589.91 4365.33 N 4997.44 E 7659.06 4408.80 N 5055.13 E 7729.15 4451.23 N 5112.47 E 7800.17 4492.11 N 5169,78 E 7872.10 4530.95 N 5227.37 E 7944.94 4567.26 N 5285.47 E 6339.10 N 48 45 E 6414.41 N 48 46 E 6488.95 N 48 47 E 1 6562,71 N 48 49 E~0,7 6635.o~ N 48 52 E 1 6707.60 N 48 54 E 6778.70 N 48 57 E 1.,'-' 6848.77 6917.72 N 49 5 E 6985,42 N 49 10 E 1.-:', 11500. 42 11600. 41 11700. 40 11800. 39 11900. ~9 0 N 58 0 E 100, 8091.66 15 N 59 0 E 100. 8166,41. 30 N 59 0 E 100. 8242.03 0 N 60 0 E 100. 8318,91 15 N ~9 0 E ~00 8396 48 7050.39 71t5.70 7!79~94 7242.60 7304~43 8018.66 4602.56 N 5343.07 E 8093.41 4637,26 N 5399.71 E 8169.03 4670.97 N '5455.80 E 8245.91 4703.42 N 5510.89 E 8323.48 4735.45 N 5565.26 E 7052.09 N 49 15 E 7117,66 N 49 21E 7182.18 N 49 26 E 0.7 7245.15 N 49 31 E 7307,30 N 49 36 E 0,~. i:~S 16, WELL NO: I GMS ~'RUI)HOE BAY, NORTH SLOPE, AI_ASKA JOB NO; 'A0382-60408' TIME DATE 1.4;4!t58 25-MAR-82 '~IEASURED DRIFT DEPTH FEET DRIFT TRUE COLIRSE VERTICAl_ VERTICAl. SUBSEA R E C T A N G U L A R i ..,..,. * . - - C L. 0 S IJ R E DOGLE~ C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI~ FEET FEET D M [IG/lO~ · ANGLE DIRECI'ION LENGTH DEPTH D M D M FEET FEET SECTION TVD FEET FEET 12000, 38 0 N 59 0 E' 12100. 37 0 N 63 0 E 12200, 35 45 N 62 0 E 12300. 35 0 N 63 0 E ~400. 34 0 N 62 0 E 12500, 32 45 N 64 0 E 12600. 30 45 N 65 0 E 12700. $0 30 N 64 0 E 12800. ~0 0 N 64 0 E 12900. 29 0 N 63 0 E 100. 8474.61 7365,70 840~,61 4767.60 N 5618,77 E 7368,89 N 49 41 E 100. 855~.94 7425.01 8480.94 4797.10 N 5672,00 E 7428,58 N 49 47 E 100. 8634.45 7482,42 8561.45 4824';4~ N 5724,60 E 7486,44 N 49 55 E 100, 8715.99 7538°47 8642,99 4851,22 N 5775,96 E 7542,94 N 49 58 E ]00. 8798.40 7593,30 8725.40 4877,37 N 5826,19 E 7598,24 N 50 4 E 100, 8881,9] 7646.44 8808.9] 4902,34 N 5875,21 E 7651,87 N 50 9 E 100. 8966.94 7696.89 8893.94 4925.00 N 5922.70 E 7702,86 N 50 15 E 100. 9052.99 7745,73 8979.99 4946,93 N 5968,68 E 7752,24 N 50 2] E 100. 9139,38 7794.16 9066.38 4969.01 N 6013.96 E 7801.20 N 50 26 E 100. 9226.4] 7841,61 9]53.4] 4990,98 N 6058,02 E 7849,]7 N 50 3] E 2.6._'5; 1 0.95 1,,15 0.5 '7 O. 5;', 1.1~i F'ROJECTED TO TD 13020. 29 0 N 63 0 E 120. 9331.37 7897.80 9258.37 5017,39 N 6109.86 E 7905°'99 N 50 36 E FINAl. CLOSURE - PlRECTION; DISTANCE; '-.. ..,0 DEGS 36 MINS 26 SECS E 7905.99 FEET ARCO Ai. AS~A DS 16, 'WELL NO; I -'GMS ' ' ,JOB PRUDHOE BAY, NORTH SLOPE, ALASKA GMS, 0-12900 MD, SI~RVEYOR; P~FFERKORN/LUND, DATE RUNI 06-MAR-82 GYRO NO; 627, 90 DEG A/LI NO; ]535, CAMERA NO; ~287, ~69 FORESIGHTI N6E <BENCHMARK) RECORD OF INTERPOLATED~'SURVEY ........ US 16, WELL NO: 1 GMS .lOB NO; A0382-60408- TIME DATE ' ' F'RUDHOE BAY, NORTH S[.OF'E, AI.ASKA ................. 14:47:37 25'MA~-82 ..... , · MARKER- TRUE SUBSEA ..................... CODE .... MEASURED VERTTCAI. MD-TVD VERTICAl. R E C T A N G II ~L A R C L 0 S II R E' VER. TICAI. NAME TOP OF SADLEROCHII' OIL/WATER CONTACT DEPTH DEF'TH DIFF FEET FEET FEET DEPTH C 0 0 R D I N A T E S DISTANCE DIRECTION THICKNESS FEET FEET FEET D M 12536°00 8912.52 ~623.5 8839°52 4710.50 N 5872.3~ E 12759.00 9]03,96 oo~.O ?O~O,?& 4?5?°?6 N 5??5.3? E 7670,22 N 50 12 E 7781.12' N 50 24 E BASE"~-OF 'SADLEROCHIT 12880'*'00 920~*00"3671'-00 '-9S'36;00 .... 4986;'59"-N' 60'49.'21"E "'7839.58-"N'50'"'30'E- ' F'BTD ].2979.00 9295,5] 3683.5 ,~,=~eom~.51 5008.37 N 60920]5 E 7886.57 N 50 35 E T[I 13020.00 9331.37 3688.6 9258,3'7 5017.39 N 6109.86 E 7905.99 N 50 36 E N 513. 36 . . [ . : l !000 !3020' - Check Form for timely compliance with our regulations. Operator, Well Name and Number Reports and Materials to be received by: , ~- ~ Date Required Completion Report Date Received Well History Samples Mud Log Registered Survey Plat InClination Survey Directional Survey Drill Stem Test Reports Production Test Reports Logs Run Digitized Log Data Yes Yes Yes -fl Remarks ARCO O~1 and Gas Company North Al?.ka District Post O~"'~ , Box 360 Anchoragu, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer February 25, 1981 Reference: ARCO CASED HOLE FINALS D.S.2-17 2/18/81 D.S.4-8 2/7/81 D.S.4-8 '2/19/81 D.S.14-5 1/23/81 D.S. 14-7 1/16/81 8 / 8 D.S.16-1 1/18/81 D.S.16-1 1/18/81 ]),S./~-12 21'4181 Continuous Flow Survey Collar Log Collar Log Diff Temp Log Continuous Flow Survey · Diff Temp Log/Dynamic Run Diff Temp Log/Static Run Borehole Audio Tracer Survey Collar Log ~Please sign and return the attached copy as receipt of data. · Mary Kellis North Engineering Run 1 5" Run 1 5" Run 1 5" Run 1 5" Run 1 5" Run 1 2" Run 1 2" Run 1 5" Run 1 5" Transmittal (J85 DISTRIBUTION' NORTH GEOLOGY R & D DRILLING ENG. MANAGER D & M GEOLOGY STATE OF ALASKA EXXON MOB I L GETTY ARCO OH and Gas Company is a Division of AllanlicRichfieldCompany February 24, 1981 Mr. P. A. VanDusen District Drilling Engineer Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99510 Dear Mr. VanDusen: A random sampling of Atlantic Richfield Company well files indicates a severe shortage of 10-404 Forms which are required to b~ filed monthly for each drilling well. The data on the following wells indicates the reason for this letter: ¥~ELL PERTINENT DATA PBU 9DS 14-9A Reportedly spudded on December 31, 1980. NO Form' 10-404 for December. NO Form 10-404 for January. PBU 9DS 14-10 Spudded on November 10, 1980. Have received Form 10-404 for November. NO Form 10-404 for December. __ NO Form 10-407 for well. Reportedly spudded on December 5, 1980. Reportedly completed on January 9, 1981. NO Form 10-404 for December. NO Form 10-404 for January. NO Form 10-407. PBU #DS 16-16 Reportedly spudded on December 12, 1980. NO Form 10-404 for December. -- NO Form 10-404 for January. NO Form 10-407. Kuparuk 25648 #B-2 Spudded on December 22, 1980. Temporarily suspended on January 11, 1981. ~O Form 10-404 for December. NO Form 10-404 for January. Mr. P. A. VanDusen Page 2 February 24, 1981 The random sampling of these and a few other well files indicates that Form 10-404 is almost a forgotten item at ARCO. The Commission would like to remind your company that the submission of a Form 10-404 is required by 20 AAC 25.030(e)(2) and 20 AAC 25.070(a)(2) of the regulations. Yours very truly, Harry W. Kug ler Commi ssi one r HWK=be ARCO Oil and Gas Company North Alasl<~ '")istrict Post Office~ x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A, Rochon District Operations Engineer Feb 4, 1981 Reference: ARCO Magnetic Tapes & Listings D.S.7-2 12/21/80 D.S.7-8 10/5/80 1/2/81 ..... I Tape #61272 J ST..%T TEC_'] Tape #61055 ~-~ F~ Tape #61307 (Corrected copy) D.S.16-2 1/26/81 Tape '#61363 Pleasesign and return the attached copy as receipt of data. Mary Kellis North Engineering Transmittal #47 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS<.,, PE£E'iVED SOHIO ~ ,:-' ~/~'~i ..... ?z,. ~_ MARATHON t:- b, t:~ - ~ J S ~J ~ ~ CHEVRON Al~sk~ 0il &~,~ Cons. Commission Anchorag~ ., ARCO Oil and (;as Company is a Division of AllanticRichfieldCompany Feb 3, 1981 ARCO Oil and Gas Company North Ala~ District Post Oflic~ ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer Reference: ARCO DIRECTIONAL SURVEYS D.S.16-11 1/7/81 Gyroscopic Job #4414 D.S.15-21 12/31/80 D.S. 17-1 1/19/81 Gyroscopic (Multi-Shot) Job # Boss-1672 Gyroscopic (Single-Shot) Job # A780D0392 D.S.16-16 1/20/81 Gyroscopic (Single-Shot) Job # A1280DO154 1/20/81 Gyroscopic (Single-Shot) Job # A1280DO129 ~Please sign and return the attached copy as receipt of data. Mary Kellis North Engineering Transmittal #36 DISTRIBUTI ON NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY SOHIO MARATHON CHEVRON ARCO Oil and Gas Company is a Division of AllanticR~chfieldCompany Oil and Gas North Alaska District Post Offi~f'' "ox 360 Anchorag-~..! Alaska 99510 Telephone 907 277 51537 Jerry A. Rochon District Operations Engineer January 26, 1981 Referenc'e: ARCO Cased Hole Finals D.S.2-17 1/5/81 Collar Log/Gyro Corr 2"/5" (same log) D.S. 14-1'0 12/20/80 " " " " Run 1 5" D.S.15-21 12/20/80 " " " " 1/6/81 CBL/VDL Pass NO. 1 Run 1 5" 2" / 5" (same ~~Please sign and return the attached copy'~s receipt of data. Mary Kellis North Engineering Transmittal #12 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE, OF ALASKA ARCO Oil and Gas Company is a Division of AllanhcR~chlieldCompany EXXON MOBIL GETTY "" PHILLIPS::];..../5. . SOHIO JAN ? 1981 MARATHON CHEVRON N~ Oil & (~,~;; ~:.',,;, ~,~ .....,~ .... ~ ,. ARCO Oil and Gas Company North AI~ District Post OIIA ox 350 Anchorage. Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer January 27, 1981 Reference: ARCO Cased Hole Finals D.S.I-17 1/9/81 .' D.S.3-8 1/8/81 D.S.3-13 1/17/81 D.S.6-11 1/18/81 D.S.6-12 1/15/81 D.S.6-15 1/12/81 D.S.14-5 8/22/80 D.S.15-10 l/il/S1 D.S.15-10 1/11/81 ........... 51S.16- ~ 1/12/81 D.S.16-1 1/12/81 DDNLL Run 1 5" DDNLL Run 2 5" Collar log Run 1 5" Spinner Run 1 5" Spinner Run 1 5" Collar log Run 1 DDNLL Run 1 5" Collar log/Gyro correlation Collar log/Gyro correlation CNL/Multi-Spaced Run 1 5" Collar log/Gyro correlation Please sign and return the attached copy as receipt of data. 11 1! 2"/5" (same log) Mary Kellis North Engineering Transmittal #17 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO ARCO Oil and Gas Company is a Division of AllantlcR~chlieldCompany ARCO Oil and Gas Company North Alaskn District Post Otfic( ~x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer January 13, 1981 Reference: ARCO Magnetic Tapes D.S.i-15 ~P] ease sign 10/4/80 Tape #61060 12/31/80 Tape #61307 and return the attached Run l&2 Run 2 copy as receipt of data. Mary F. Kellis North Engineering transmittal #971 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO Oil and Gas Company is a Division of AtlanticRichlieldCompany EXXON MOBIL GETTY PHILLIPS SOHIO CHEVRON ~,~ ,,, ~ :' ~--. ,.,,' January 8, Reference: D.S.16-1. D/S. 16-1 D.S.16-1 D.S.16-1 D.S.16-1 ARCO Oil and Gas Company North Ala~ District Post Offic~~ ,.ox 360 Anchorage, Alaska. 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer 9181 ARCO Open Hole Finals 1/2/81 1/2/81 12/31/80 12/31/80 1/2/81 FDC Run 1 5" FDC/CNL Run 1 5" DIL/SFL Run 1 2" BHCS Run 1 2" & 5" Cyberlook Run 1 5" D.S.15-10 (N-l) ,r ~~Please sign and 12/16/80 return the HDT/w listing Run 3 2" & 5" attached copy as receipt of data. (same log) Mary F. Kellis North Engineering Transmittal #958 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG: MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL MA RAT H 0 N . ~,~m~°~ CHEVRON lk~~\ ~ ~a~ ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany ALASKA OIL AND GAS CONSERVATION COMMISSION Roy le H. Hamilton/~ Chairman IV,' Thru: Lonnie C. Smith Commissioner ~,~ ~.~' Retold R. ~awkins Petroleum Inspector December 22, 1980 Witness BOPE test on ARCO'S Well No. 16-1 Sec. 18, T10N, R16E, UM Permit 980-136. ~ondaY.....December 8., 1980: I left Anchorage at 8:45 am, by Wien to Prudhoe Bay arriving at 9:30 ~ and at DS 16-1 at 10:30 am. Conditioning of hole was in progress. ~9esday December. 9., 1980: 13 3/8 casing being run. Wednesday..pecember 10, 1980: I witnessed the BOPE test. I filled out an A.O.G.C.C. report (attached). Also attached is an ARCO Field Report on the cement job done on the well. In summary, I witnessed the BOPE test on 16-1 that Rowan Drill- ing performed for ARCO. BOPE tests were satisfactory. ~RH:mm O&G #4 4/s0 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector .~..+ [l,)/.~/-/~-5 Operator ~ .~. L"~ Well / ~.' -- / · Location: Sec / ~/ T/Z~/R/~, M Dr il ling Contractor/?~A._~,~ Representative Permit # ~ /,?£ casing Set Rig #,-3_~- Representativ~FgJ~-~ Location, General /3)~t~)/~3~ Well Sign General Housekeeping d/~~ Reserve pit .. . ~/~' Rig ~/f ACCUMULATOR SYSTEM Full Charge Pressure ~p~(~ psig Pressure After Closure /~ W ~ psig 200 psig Above Precharge Attained: / miL .--- se, Full Charge Pressure Attained: '~ min~(~ se ~ - j -- ) Controls: Master ~ 1]~' Remote ~/~' Blinds switch cover Kelly and Floor Safety Valves Upper Kelly. Test Pressure Lower Kelly Test Pressure Ball Type ~/i~ Test Pressure Inside BOP . ~'/{ Test Pressure / Choke Manifold Test Pressure No. Valves / ~ No flanges 3 nd3 ustable Chokes / ~/~ Hydrauically operated choke. ?/~ BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Failures Test Pres sure 3 Test Time ~' hrs. Repair or Replacement of failed equipment to be made within ~ ~ days and Inspector/Commission office notified. Remarks :.ff 2~, ~/j~ ~: ' I Distribution orig. - LO&GCC cc - Operator cc - Supervisor Inspector AtlanticRichfieldCompa~,f ~, Well ISize & Deoth Last CSG ! Days Drilling Report -- Dail o'ta/,,2-/0- ~" ~ ~~er I I ~ I ~ I , ,~v! Bit No. Size MaKe Ty~e. SN ~t ~ · RPM ~.-~ IFormation IAccum. Mud Cost SIo~v Pump Rata '" 'iConclition ~,ot, Hfs, BOTTOM HOLE ASSEMBLY: (INCLUDING DRILL PIPE SIZE & GRADE) AN GLE DI RECTI ON T.V.D. TOTAL COORDINATES NORT, H/$OUTH,, E, AST/WE~ST, VERT., SEC. , , , , ~ , OPERATIONS FROM 0600 TO 0600 C, IC-, , ,. ANGLE/DI RECTI 0 FROM LAST SURVEY POINT ITO TARGET Di r~:tion . Diesel on Loc. Taml~,3 ~ i NORTH ALASKA THIS BLOCK IF SUMMARY CONTINUED ON BACK TIME /~/~--/~ ~/oo - ,u,-~. /d - / OPERATIONS L/:L,~T 24 C ,,,t+ , Tt~,~, g o td n mo' l:. ; ll ~, d / ~ ~,d b r y ~ 0o o'"' et( IESCRIPTION OF KICK DRILL: WHILE PULLING PIPE MORNING TOUR ~ WELL CLOSED IN [] EVENING TOUR --WELL CLOSED IN [] WHILE RUNNING PIPE D WHILE DRILLING SECONDS, ON STATION SECON DS SEC ON DS, ON STATI ON SECON DS IESC RIPTI ON OF ACCI DENT: lAME OF INJURED EMPLOYER ,,, rATE REPORT FILED November 25, 1980 Mr. P. A. VanDusen District Drilling Engineer ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 Re: Prudhoe Bay Unit DS 16-1 Atlantic Richfield Company Permit No. 80-136 Sur. Loc.: 1302'FNL, 1013'FWL, Sec 24, T10N, Ri5E, UM. Bottomhole Loc.~ 1469'FNL, 1413'FWL, Sec 18, T10N, R16E, UM. Dear Mr. VanDusen: Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental .logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any water's of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70} and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Prudhoe Bay Unit DS 16-1 -2- November 25, 1980 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to dril 1. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commiss..ion may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness pre. sent. Very truly yours, H. Hamilton Alaska Oil & Gas Conservation Commission Enclosure. cc= Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation W/o/encl. Department of Labors Supervisor, Labor Law Compliance Division w/o encl. ARCO Oil and Gas ~ pany North Slope U...,trict Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 November 19, 1980 Mr. Hoyl e Hamilton State of Alaska Alaska Oil & Gas Co nserva ti on, Commi ss i on 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 16-1 Dear Sir: Enclosed please find our Application for Permit to Drill DS 16-1 and the required $100.00 filing fee. Attachments to the appli- cation include a conductor as-built survey plat, a plat detailing the section and plan views of the proposed wellbore, and a drawing and description of the BOP equipment including anticipated pressures. As confirmed in previous correspondence from your office, the requirement of using a surface hole diverter system on this well has been waived. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:jh Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10.-~,O1 REV. 9-1-78 SUBMIT IN TRI rE (Other instructi& ;a reverse side) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL OR DEEPEN DEEPEN [--~ SINGLE IVKILTIPU~ la. TYPE OF WORK DRILL ['~ b. TYPE OF WELL OIL GAS r-1 WELL [~] WELL I~ OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface aPI #50-029-20533 6. LEASE DESIGNATION AND SERIAL NO. ADL 28346 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit : 9. WELL NO. DS 16-1 10. FIELD AND POOL, OR WILDCAT ~rudhoe Bay Field, Prudhoe Oi 1302'FNL, 1013' FWL, Sec 24, TION, R15E;'IDI~aOil&~'~"~ Gas Cons. CommissJo Anchorage At proposed prod. zone 1469'FNL, 1413'FWL, Sec 18, T10N, R16E, UM (-8800'SS) 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 5 Miles NE of Deadhorse, Alaska 11. SEC., T., R., M., (BOTTOM Pool HOLE OBJECTIVE) Sec 18, TION, R16E 14. BOND INFORMATION: ~E Statewides.retya.d/orNo. Federal Insurance Co. #8011-38-40 mo.n, $500,000 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT, (Also to nearest drig, unit, ii' any) 1413' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING,COMPLETED, 2625I SSF OR APPLIED FOR, FT. of DS 9-13 16. No. OF ACRES IN LEASE 2512 .--- 19. PROPOSED DEPTH 13250'MD 17. NO. ACRES ASSIGNED TO THIS WELLibm 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX. DATE WORK WILL START Tundra 34',. Pad 39', RKB 73' (Datum MSL) 12/5/80 23. PROPOSED CASIN( AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 32" 20" 94# H-40 1lO'MD 300 SX Permafrost II to surface 17½" 13-3/8" 72# L-80 2700'MD 2300 SX Fondu + 400 SX PF II to 12%" 9-5/8" 47# L-80& 12435'MD 500 SX Class G cmt - 1st Stage SOO 95 300 SX Permafrost II - 2nd Stage ...... 8%" 7" 29# L-80 12135-13250 450 SX Class G cmt surfac Atlantic Richfield Company proposes to directionally drill this well to 13250'MD 9364'TVD to produce the Sadlerochit zone. Logs will be run across selected intervals. The Sadlerochit will be conventionally cored. A 13-5/8" 5000 psi RSRRA BOP stack will be in- stalled and tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5½" 17# L-80 tubing, packer and necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. Selection intervals within the Sadlerochit to be perforated and reported on a subsequent report, a 5000 psi WP wireline lubricator, test to 'working pressure, will be used on all wireline work. The packer will be set above the Sadlerochit. The down hole safety valve will be tested and installed upon conclusion of ~NAB~VESPACEDESCR~BEPR~P~SEDPR~GRAM:~fpr~p~sa~ist~deepe~giveda~a~npresen~pr~duc~ivez~neandp~~posed job. new productive zone. If proposal is to drill or deepen dixectionaUy, give pertinent data on subs'tttface locations and measured and true vertical depths. Give blowout preventer program. SIGNED f ~]~~-24' I hereby certify that the FoFing is Tr~'~nd Correct TITLE District Drilling Eng. (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] YES ~.NO DIRECTIONAL SURVEY REQUIRED MUD LOG [] YES CONDITIONS OF APPROVAL, IF ANY: ~.NO OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE PERMIT NO. (~ O - /3 $ ~PROVAL DATE APPROVED BY TITLE BY O~,~D:R ~- = ~ ~a~..-,~ .... , *See Instruction On Reverse Side November 25, 1980 DATE 11/25/80 !¢ i~ T/OM, RI5£, U.I~. ~ Z¢ . ~* --r---,'--::----:'" ~ ~ / / ~ ~ ~ ~ ~.~ ' -/ %- , :%. 1. Y = 5 929 642,O~ 5. Y = 5,929,172.41 - 0 ~ T o 1 LONG = 148°~3~39,055,, LONG = 14~ ~3'36,51~" 2. Y = 5,929,524,77 6. Y = 5,929~055.05 X = 7~9,81,0,53 X = 719,911,44 ~AT = 70°12 ~35`782'' LAT = 70°12 ~31 .135" - LONG = 348°13:38.425,, 'LONG = 148°13~35.893'' 3. Y = .5,929,407.32 I HEREBY CERTIFY THAT ! AM X = 719',835~80 PROPERLY REGISTERED AND LICENSED LAT = 70°12~34.620,, TO PRACTICE LAND SURVEYING IN x = 719,861.18 ~ ~M~NS~ONS AND ~~ LAT = 70o12,33,~60,, DETAILS~RE~ORRECT, AS~/49~ DATE ~/~ ~ ~'~' ~ ~ ~ ~ ~--'~ ....... ~ ~, · ~ '~ ........ ~-~ I I I I I lll I _ AtlanticRichfiel~Compan ~ DATE- ]DRAWING No: NORTH AMERICAN PRODUCING DIVISION /~A~ ALASKA DIST~iC'T-PRUdHOE baY ...... Iii. I Iiil i~ I I . 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'='=':: ...... ~ ...... ?"=-' -"~ ..... :~"- '~"::?"='":':::'::' ':':~:::" '=':':": :=::× ~-- ,.-::..~.: ~ :.=~:::.=.:: :x: ..... .......... ...~.~ ,= :: ............. ................ ~ ..,-, ............................................... ,...... ~:.,: .......... ..... ,., :.,.,:'~' ............. ~: .......... ,~: .~ :-,-.:.~,.," ...... ,_.,.. ..,-.~;+"":- ..... .--~.=":'~= ..... -..i :??':"'-..,--.-.,.-'~-~ i ~--~:.?-:-:-= :=.~:=:?:-==: ~_'=:=_~ -:::-=-- ::-i:~-::. ......:,.~ - i-~-,-:.:.~ :. -.--,-.,..:~ .:=::--" .... ..: :-: ..--"~ .... ...... :-..::'"": ....... .... :, :-. :--' .... :-:..-4`-'~ ....... ,-.-,., q56'/ IRNNULRR PREVENTOR BL!ND RRHS P!PE RRHS k 2. .. 13-518" BOP STACK DIAGRAM Accumulator Capaci.~y Test Check and fill accumulator reservoir to proper level with hydraulic fluid. Assure that aCcumulator pressure is 3000 psi with 1500 psi downstream of the regulator. Observe time,then close all units simultaneously and record the time and pressure remaining after all units are closed with charging pump off. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1~J30 psi remaining pressure.) 13-5/8" BOP STACK TEST 1. Fill BOP stack and manifold with Arctic Diesel or Calcium Chloride Solution. DRILLING SPOOL 2. Check that all hold down screws are fully retracted. Predetermine depth plug will seat & mark running joint. Run test plug on drill pipe and seat in wellhead. Run.An.'lock down screws in head. PIPE RRHS . Close annular preventer and chokes and bypass valves on manifold. Test all components to 250 psi and hold for 10 minutes. 5. Increase pressure to 3000 psi and hold for 10 minutes. Bleed pressure to 500 psi. 6. Close top set of pipe rams and open annular preventer,. 8. Increase pressure to 5000 psi and hold for 10 · minutes. Bleed pressure to 500 psi. Close bottom set of pipe rams and valves directly upstream of chokes, then open top set of pipe rams and chokes. Increase pressure to 5000 psi and hold for 10 minutes. Test remaining untested manifold valves(if any) with 5000 psi upstream of valve and zero pressure downstream. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for 10 min. Bleed pressure off all equipment open blm~ Make sure manifold & lines are full o~ Arctic Diesel and all valves are set in ~ b~Ro. COili~il.~S~lilling position. psi - Max, anticipated Bottom 12, Test standpipe valves to 5000 psi. Hole Pressure psi - Max. pressure to which BOP's could be subjected. Calculated by allowing a gas bubble at reser- voir pressure to rise w/o expanding but cooling to 80OF. 13. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 14. ~ Check operation of De Gasser. 15. Record test information on Blowout preventer test form. Sign and send to Drilling Supervisor. 16. Perform cOmplete BOPE test once a week and functional, operate BOPE daily. Item Approve Date Yes No (1) Fee ~~__ /,/.,-~L;~,~, 1. Is the permit fee attaChed ....................................... 2 Is well to be located in a def pool ...... 3. Is a registered survey plat attached .................... ............ _ / (2) Loc. ,~/"'-~/-~, .~,,_ ~4. Is well 1 ~ocated proper distance frcm property line ..... ............ ~'~ Is well located proper distance frcm other ~lls ...... 6. Is sufficient undedicated acreage available in this pool ............ Lease &Well No. /~.&~ Remarks (3) ktmin /,:- (4') Cas, cj~ Is well to be deviated ~ ' :: ~ 8. Is o~ra~r ~e only affect~ ~t7 ................................. ~ 9. C~ ~mit ~ appr~ ~foro t~ay mit .......................... ~ __ 10. ~s o~rator ham a ~nd ~ force ........... · ............ ........... ~ 11 -- . Is a co~e~ae~on order ne~ ...................................... ~ 12. Is administrative approval needed .................................. 13. Is conductor string provided ....................................... 14. Is enough cement used to circulate on conductor and surface ........ 15. Will c~nent tie in surface and intermediate or production strings .. >~6. Will c~t cover all known productive horizons .................. ( 5 ) BOPE 17. Will surface casing protect fresh water zones ...................... 18. Will all casing give adequate safety in collapse, tension and burst. . . ~i9. Does BOPE have sufficient pressure rating- Test to ~ psig . ~%pproval Recked: Additional Requirements: Geology: Engingerin~.- JgJ.~ rev: 03/05/80 Well Histow 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, LIBRARY TAPE CURVE SPECIFICATIONS Company Arco Oil ~ Gas Well DS 16- 1 Field PrudhOe Bay County,State North Slope, Alaska Date 5-10-81 Curve Name (Abbreviated) Standard Curve Name Logs Used Scale GR Gamma Ray CNL/MS 0- ] 00 SS Short Space CNL/MS 0-2000 LS Long Space CNL/MS 0-2000 , ,,NEU Compensated Neutron C'NL/MS 60-0 ,, ... . .. _ -- );;\GE ,l /\RCO OIL ~ GAS ..... .~.S. 16-1 ...................... ] A I. ~,... _. EWE RY_ ................... ~..__S A.MRLES 1~1,t5 50 60.53 825 97 797 $0 ~6 1.2 180~, 50 61 q-5 82~ 5q- 7BB qB ~6 15 1BO? 50 62.~5 812 777, 11 ~5.B8 l~Og.50 59.&9 786 2S 60 67 ~5.5~ 11B!0.50 111%11.50 1817 50 62.92 781.77 756.69 1815 50 I 1~1~ 50 181.5 50 55 k.lB17.50 59.57 782,6~+ 766,~23 q5.09 ~ 1, B!.9 50 59 57 773 65 753 29 ~5.50 50 5 '~0 789 51 ~ 72 ,1,821.50 SO 801 80 757 ~e ~+:5 55 50 58 23 821 771 55 ~l.B5 182~.50 56 97 800 1~ 77'6 71 ~2 B1 ARCO OIL ~ GAS ..... 3.$. BAY .... N. $LOPE,AL'AgKA -~LAC 6711 183] O0 57.95 809 23 75~ 05 ~t 96 1832 O0 60.39 826 74 770 1~ ~i 18 33 O0 58 '?7 8qO 31 77B lB ~1 98 1~3qo00 54.08 11835.00 53.20 838,95 78~,03 1153~.00 54.03 828 67 800 34 ~3 99 !~57 O0 183~ O0 i1~39.00 61. 11840 11843. O0 65 11542.00 62.29 814.71 77q..78 44.59 1184~.00 65.05 809.72 785.19 44.60 11~q4.00 65.50 805.37 794.91 q~4,40 1~4%.00 66.28 796,83 7B3.~4 ~5.97 llB~a. O0 60.33 79~,99 7~3.83 ..1.~84~. O0 61.94 792.19 767.11 46.93 1~849.00 61.20 785.53 755,~3~ q5.~ 11850.00 67.45 78~,18 7~7~30 45.00 . PAGE'_ .~ ARCO OIL .~ GAS ..... 3,$, 16-1 PRLI3HOF BAY .... N, SLOPE,AL~ASKA -~LAC 6711 ................... _3_A T.&__EV_EP,_Y ........................... ............................................... Gg .................... S_S ................. __LS ~J ............ 1!.~.9]_~, 50 65 ,.56 ......... 7__Y_.3_,_9__1____7 ~3_~.40 ........ _~:3._,05 ............. 1.!_.~. 5.2..,._.~_Q ........... _6_3_,~A6_ ......... 7 7_0_..6_~__ 7:59,4 8 ...... ....... ii..~_,.:2_..: _0. ........ ..6_2__,__0__6 ......... _7__6 ~_~,.!8 _ 7 ~__~ 81 ...... ~_~__~ 2 8 ............. 1.!..~_53_,_5 o. .......... _66_~.:3 ........ _7_5. .. 9~,_9. . _% .... 7_5_.!_~_1~ .................. ~.5.,__0_9.. 1B5~.50 70.59 756 I ~ 16 1. B55 50 66 03 760 67 BO 1856 50 67 79 751 96 7~4 44 50 32 1. B57 50 67 16 742 O0 732 60 53 70 1858 50 61 20 750 38 729 75 51 14 1.859 50 54.05 75B 90 719 93 47 29 1B61.,50 5,~.24 796 36 715 85 ~6 3~ 1864.50 56 50 ~_ {: 858 37 827 16 ~4, ARCO OIL g GfiS ..... J.S, 16-1 .... N. SLOPE,fiL~SKR ~LfiC 6711 1.._._S~LE.S ~I,B~U,O0 61.78 76~.22 765.9~ ~5.B5 11865.00 59.~9 766.9~ 759.19 ~6.29 I1BS~.O0 56.10 76~.78 7~9.2~, ~:~.99 118~7.00 56.~9 755.25 7~1.2~ ~2.91 11888.00 56 11889 1~B90.00 61. 11892 O0 67 I~.89~.00 69.05 11895.00 70.55 7,58.60 766.28 g9.87 1896 O0 6~.27 72~ 6~ 797 99 51.60 1,897 O0 8 31 708 )3 720 05 50 O0 55 S7 709 70 700 O$ ~6 Bg ¥¥ V¥ EEEEEEEEEE RRRRRRRR YV YV EEEEEEEEEE RBRRRRRR VV VV EE RR RR VV VV EE RR RR VV VV EE RR RR ~'EE'' VV VV EEE E.EE RRRRRRRR V¥ ¥¥ EEEEEEEE ~RRRRRR VV VV EE R~ RR VV VV EE R~ RR VV VV EE R~ R~ VV VV EE R~ RR iIllII IIIIII I1 II II II II II II II 1I II IIIII IIIII FFFFf'FFf FF FFf'FFFf [FF FF FF FF FF EF.~f'FFFFF~' f'F~FFFf FF FF FF YY YY YY Y¥ YY YY YY YY YY YY YY YY YY Y¥ YY YY YY YY YY 000000 000000 666.666 000000 000000 666666 O0 O0 O0 O0 66 00 O0 O0 O0 66 00 0000 00 000.0 66 O0 0000 00 0000 66 00 00 00 00 00 00 66666666 00 00 00 00 00 00 66666666 0000 O0 0000 O0 66 0000 O0 0000 00. 66 O0 O0 O0 O0 66 00 O0 00 O0 66 000000 000000 666666 000000 000000 666666 66 66 *START* US~R PCAL [10707,61307] JOB SHIP SEQ. 445:4 DATE 28-dAN-8! MONIT[]R SWS KLIOE40 NOV-80. *START* FILE: DSKH:VE~IfY-O06<057>[I07~7.61307] CREATED: 28-JAN-8! 16~43. 5 PRINTED: 28-JAN'8! 16:49:40 QUEUE SWITCHES: /FILE:FORT /COPIE8:I /SPACING:I /LIMiT:138 /FORMS:NORMAL 16:49:06 SCHLUMBERGER COMPUTING CENTER 10707,61307 REEL HEADER LENGTH. 1.32 BYTES REEL NAME: ~.C.A.L. SERVICE NAME. EDIT REEL CONTINUATION NUMBER: O! PREVIOUS REELL~AME. COMMENTS: S FORMAT CUSTOMER TAPE TAPE HEADER LENGTH 132 BYTES TAPE MIME: 61307 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: O! 'REVIGUTAPE NAME: OMMENT~: TAPE COMMENTS . DIL RUN # 1, LOGGED 02-JAN-80 CASING DRILLER = 13.36 IN. 8 2694' 9.625" 12460i' TO 12435" FT. BIT SIZE = 12.25" 12460' / FLUID _IN THE HOLE DENS VISC PH FLUID LOSS RM ~ SEAS TEMP. RMF " " RMC " " RM ~ BHT LIGNOSULFGNATE 10.2 44 0 14,6. NL .35 ,a 57 F 1.10 ~ 157 F 1.57 @ '57 F 0.43 @ 177 F DATE: 81/ 1/ ~ DATE: 81/ l/ 6 TO O' 8 5" 12999' ., Et3F FILE HEADER LENGTD: 62 BYTES FILE NAME: EDIT ,001 MAXIMUM PHYSICAL R~CORD LENGTH: 1024 BYTES PREVIOUS FILE NAME: FILE CONM~NT~ · OPEN HOLE .~ CASED HOLE MERGE AT 12400' ,WELL SITE INF.ORMATION RECORD LENGTH: COMPANY: WELL: F~ELD. COUNTX: STATE: 138 BYTES ATLANTI~ RICHf'IELD CU. D.S' 16 l PRUDH~OE BAY N. SLOPE ALASKA DATA ~ORMAT SPECIFICATION 'LENGTH: 610 BYTES ENTRY BLOCKS: TYPE 0 SIZE REP CODE ENTRY ! 66 0 0 I 0 DEPTH 13035.000 13000.000 12900.000 12800.000 12700,000 12600.000 12500,000 124OO.0O0 12300.000 12200.000 12100.000 MNEMONIC P R HOB R SP GR RHOB GR SP GR HOB VALUE MNEMONIC VALUE -12.109 ILD 103.813 GR 1,474 NRAT 103,813 DT -32,656 ILD 10~.813 GR .935 NRAT 103.813 DT ~.I56 ILD .125 GR , 625 NRAT 9 .125 DT SP -41.906 ILD GR 21~ 266 GR RHOB .: ~201 NRAT GR 21 · 266 DT SP GR RHOB GR SP HOB SP GR RHOB GR -1,359 ILD 60'969 GR 2,527 NRAT 60.969 DT MNEMONIC -68.438 ILD 21,672 GR 2.322 NRAT 21'672 DT VALUE '4.656 ILD 151.125 GR 2.385 NRAT 151,125 DT 7,31;3 ILM 7. 559 1 1 ,250 CALl 2.559 6.ooo SP 5,125 ILD GR 79,438 GR RHOB 2,359 NRAT GR 79.438 DT 7,324 ILM 11~ 9250 CALl 79i 39 NCNL 188 4,359 105.563 CALl 873 NCNL 8 .'75o SP R 1,867 3 406 -CALl 2 : 393 NCNL 96. 000 SP R G~OB GR 4.3454 ILM 9.12 CALl 217 t CML 78 : 7s SP GR RHOB GR 23.891 24,391 CALl 2;471 NCNL 91.000 7.250 7.875 2236.000 - .250 i ,99~,307 NRAT ,250 DT 4.422 11.359 2368.000 '999.250 250 -999.250 1.962 8.422 3330.000 9.625 9.469 2466.000 -999,250 -999'250 ,99~ '412 .250 16.703 8.547 3540.000 MNEMONIC SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL 996 iLM 6. 810 SFLU 15 ;625 CALl 11.503 NPHI 3,697 NCNL 1904.000 FCNL 101 '750 2000.000 8.750 1577.000 -999.250 2.740 1473.000 -999.250 =16.000 2.418 -999.250 2.750 1.577.000 5.145 ILM · 854 CNL 132.500 -999.250 105.625 AL1 910 NCNL -99 :25o CALl NCNL ILD -999.250 -0 012 DT -999 250 ILO -999 250 GR 87:375 ~RAT 99~.834 T ' .250 ILM CALl NCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHi FCNb SFLU NPH1 FCNL VALU~ 7.969 40,088 729.500 7.969 34.326 729.500 5.094 29.834 776.000 3.660 25.537 1383.000 20.203 20.947 1268.000 26.891 25,781 1334.000 11.023 42.871 460.750 2000.000 49.463 394.250 -999.250 0.457 349.500 -999.250 397.750 2.734 -999.250 0.443 ~72.000 DEPTH 12000.000 11900.000 11800.000 11700.000 11600.000 11500.000 11400.000 11300.000 11200.000 11100.000 11000.000 R RHOB GR SP GR RHOB GR VALUE MNEMONIC VALUE MNEMONIC 2~99-250 lSD -999.250 , 4,.ooo -999.250 GR 71.688 CahI 2.359 NRAI' ,172 NCNL -999.250 DT -999.250 P R GR SP GR RHOB GR 999.250 'ILD '999.250 999.250 GR 73.313 CALl 99~-035 NRAT - .250 DT -99~'008 NCNL .250 -999.250 ILD -999.250 -99~. 250 GR 5~ 344 CALl .965 NRAT :670 NCNL -999.250 DX -999.250 -~P -999.2__50 ~ILD -999.250 GR -999.250 GR ~i.250 RHOB 93,,-523 GR 9991 · 665 NRAT - .250 DT -99 1250 CALl NCNL .SP -999.250 ILD -999.250 ILM GR GR 50.781 CALl RHQB NRAT . 3.598 NCNL GR DT "999.250 250 HOB 2.361 R -999.250 CA,, NRAT 000 NCNL DT -9994:250 SP RGR HOB GR '99i.250 ILD -999.250 -99 ,250 : GR 74.188 . 459 NRAT z~. 047 -999 '250 DT '999.250 ILM CALl NCNL SP GR RHOB GR -9~.250 ILD -99 -9 .250 GR ~.250 .563 99~.414 NRAT - .250 DT -99~'738 .250 SP -999. 250 ILD -999. 250 GR -9 ~ 250 GR 9 5~.906 RHOB ~420 NRAT .094 GR -999.250 DT -999.250 CALl NCNL ILM CALl NCNL SP '999.250 I~D -999.250 GR -999.~50 O ~5,250 RHOB GR -99~ NRAT DT -99~'891 .250 ILM CALl NCNL VALUE -999.250 48.000 416.000 -999.250 2.721 1417.000 -999.250 2.725 1657.000 -999.250 2.729 1611.000 -999.250 2.7]8 1683.000 -999.250 2.758 1724.000 -999.250 2.762 1585.000 -999.250 2.754 1679.000 -999.250 2.764 1679.000 -999.250 2.775 1637.000 -999.250 2.814 1547.000 MNEMONIC Sf'LU NPHI FCNL SFLU NPHI FCNL Sf'L,U NPHI FCNL SFLU NPHI FCNL SFbU NPHI FCNb SFbU NPHI FCNL SFDU NPHI FCN~ NPHi FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL VAbUE -999.250 ].664 -0.001 -999.250 0.505 354.250 -999.250 0.475 402.000 -999.250 0.413 431.750 -999.250 0.386 458.250 -999.250 0.400 455.750 -999.250 0.474 35~.750 -999.250 0.482 397.000 -999.250 0.426 438.750 -999.250 0.490 379.500 '999.250 0.454 365.500 DEPTH 10900.000 10800,000 10700,000 t0600.O00 10500.000 10400.000 10300,000 10200.000 10100.000 10000.000 9900.000 MNEMONIC SP GR RHOB GR SP RHOB GR SP GR RHOB GR GR RHOB GR SP GR RHOB GR SP GR RHOB GR SP GR RHOB SP RHOB GR R RHOB SP GR RHOB SP GR RHOB GR :299 250 ~ IhD '999 .250 DT -99~:250 .387 NRAT .719 -999.250 DT -999-250 '999,250 ILD '999,250 -999.250 GR 53:031 'gg~:385 NRAT .,g20 -999.250 DT -999. 250 ~999.250 ILD -99925:0 999.250 GR 64:625 CALl ,99~,359 NRAT ~ 785 NCNb ,250 DT -99 ~250 :999,250 ILD -999 250 999.250 GR 48~656 CALl .99~.~48 NRAT NCNL , 250 DT -99w .25'0 -999,250 ILD -999,250 -999,250 GR 45,375 CALl 2 .355 NRAT 31820 NCNb -999,250 DT -999-250 . :99 ,250 ILD -999 250 iBM 99 .250 GR 53.78'1 CALl DT .352 ~AT 4] 781 CALl 328 NCNb -999-250 DT -999 250 -999.250 iLD -999,250 ILM -999.250 GR 33,969 CALl -992'4069 NRAT 3,684 NCNL "250 DT -999'250 MNEMONIC ALI NCNb ibm ALI CML CALl NCNb CALl NCNb VALUE -999,250 2.797 1610.000 -999.250 000 -999,250 2,805 1509.000 -999.250 2.834 1531.000 -999.250 2.859 1593.000 -999.250 2.891 1671.000 -999.250 2.861 1608.000 -999.250 2.848 1504.000 5O -99 1589.000 -999.250 2.818 1757,000 -999.250 2,826 1589.000 MNEMONIC SFLU NPHI FCNL SFLU NPHI FCNh SFLU NPHI SFLU NPHI FCNL SFUU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPH£ FCNL VALUE -999.250 0.401 406.750 -999.250 0.422 429,750 -999,250 0,429 368.750 -999.250 0,459 368.000 -999.250 0,434 379.250 -999,250 0,445 390.000 -999.250 0.423 434,750 -999.250 0.440 408,500 -999,250 0.491 366,750 -999.250 0.351 528,000 -999.250 0.416 427.750 DEPTH 9800.000 9700.000 9600.000 9500.000 9400.000 9300.000 9200.000 9100.000 9000,000 8900,000 8800.000 MNEMONIC SP GR SP RHOB GR GR ~HOB GR SP GR RHOB GR SP GR GR SP GR RHOB GR GR RHOB GR SP HOB SP GR HOB R SP GR [~HOB GR RHOB GR ALUE MNEMONIC ·VALUE · MNEMONIC 'VALUE ~99,250 ILD - -999.25'0 ~ILM -999.250 999.250 GR 38,18~ CALl 2.816 2.258 NRAT 3'6~1 'NCNb- 1591'000 -999.250 DT -99~i~6 ' -999,250 99,250 GR 39,~3 CALl 2.816 2,342 NRAT 3.85'9 NCNb 1460.000 999,250 DT 999,250 ~99,~50 ILD 999,250 IbM -999.250 -999.250 GR 35.281 CALl 2.852 2,'371 NRAT~ ; . 4.273 NCNb 1415-000 -999,250 DT 99~.2~'0 ' -999.250 ILD -999'250 ILM -999.250 [ ~ALi 2-840 CML 1562.000 ~.~50 ILD 999,250 ibm -999 250 -999.250 GR 33,813 ·CALl 2,834 2-365 NRAT 3,490 NCNb 1489 000 -999.250 DT -99~'2~-0 ' ° '9 99,250 GR 3~,~50 CALl 2,828 2.311 NRAT 3.881 NCNL 1290.000 999,250 ILD 999,250 I -M - 9 .. . L. 9 9 250 -999.250 GR 35.969 CALl 2;830 2,307 NRAT 3,426 NCNb 1019.000 -999.250 DT -99~.~56 iLM -999.250 CALl 2.836 NCNL 1633.000 -999.250 ILD -999-250 ~lLM' -999.250 -999;250 GR '39;2~6 daLI 2.836 2,393 ~ NCNb 1605.000 -999.250 . 2999.250 ....... -gg . so 2.855 . 2.361 NRAT 3.695 NCNb 1755.000 "999.250 DT -999.250 '999.250 ILD -999.250 1bM -999.250 -999,250 - GR 29i32~ CALl 2.855 2,402 NRAT 3.45I NCNb 1676 000 -999.250 DT -999.250 ' _ · MNEMONIC SFLU NPHI FCND' S~'LU NPHI FCNL SFLU FCNL SFbU NPHI FCNL SFLU NPHI FCNL SFbU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL VASUE -999.250 0.402 432.250 -999.250 0.448 358.250 -999.250 0.523 336.500 -999,250 0.554 3]0.250 -999.250 0.380 434.500 -999.250 0.452 320.250 -999.250 0..~69 402.500 -999.250 0.382 443.750 -999.250 0.444 419.000 -999.250 0.418 447.750 -999.250 0.373 490.500 DEPTH 8700.000 8600.000 8500.000 8400.000 8300.000 8200.000 8100.000 8000.000 7900.000 7800.000 7700.000 MNEMONIC VALUE ~99 250 99.250 RHOB 92.367 Glq -99 .250 SP -999.250 GR -9929 250 GR -999.250 MNEMONIC VALUE ILD -999.250 GR 36.000 NRAT 3.697 DT -999.250 ILD -999.250 GR 3~.969 NRAT .871 DT -999.250 SP 999 2250 ILD RHOB 357 NRAT SP -999.250 ILD G~ --99~.250 GR RHOB .379 NRAT GR -999.250 ~ DT SP -999. 250 GR -999.250 RHOB 301 GR RHOB GR SP GR RHOB GR SP GR RHOB -999.250 -9 .250 '9~.322 -999.250 -999.250 -999i250 .99~ '365 .250 -999.250 -99~.250 '355 -999.250 SP G~ RHOB GR .-~99.250 99.250' : SP .HOB GR -999 250 33271'9 615 GR RHOB -999.250 3~ 625 680 '999 250 ILD '9~ .250 GR ~,344 NRAT 9~.525 DT -9 .250 ILD -999.250 GR 2~.766 NRAT 1813 DT -999.250 NRAT ~ t52 DT -99:250 ILD -999.250 GR 3~.781 NRAT .791 DT -999.250 ILD -999.250 GR 441500 NRAT 039 -999.250 ILD -99~.250 GR '855 .NRAT -999.250 DT -999.250 iLD -999.250 GR .99~.254 NRAT .250 DT -999.250 781 -999.250 '999.250 3b.156 896 -99 : so MNEMONIC ILM CALl NCNL IbM CALl NCNL CALl NCNL ILM CALl NCNL CALl NCNL CALl NCNL ALI NCNL ILM CALl NCNL b~ AL1 NCNL CNAL I CNL ILM CALl NCNL VALUE -999.250 2.881 1410.000 -999.250 2.885 1494.000 -999.250 2.871 1541.000 -999.250 2.867 1798.000 -999.250 2.900 1722.000 -999.250 2.904 1673.000 -999.250 2.867 1760.000 -999.250 2.863 1511.000 -999.250 2.86] 1239.000 -999.250 2.871 1516.000 -999.250 2.867 1331.000 MNEMONIC SFLU NPHI FCNL Sf'bU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFBU NPHI FCNL SFLU NPHI FCNb SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI SFLU NPHI FCNL SFLU NPHI FCNL VALUE -999.250 0.418 357.000 -999.250 0.450 382.000 -999.250 0.403 410.250 -999.250 0.415 449.500 -999.250 0.38'7 470.500 -999.250 0.439 435.250 -999.250 0.355 48'7.000 -999.250 0.436 401.250 -999.250 0.480 299.000 -999.250 0.528 342.500 -999.250 0.455 304.500 DEPTH 7600,000 7500.000 7400.000 7300.000 7200.000 7100.000 7000.000 6900.000 6800.000 6'700.000 6600.000 MNEMONIC VALUE MNEMONIC R -999'250 -RHOB GR -994'949 ,250 VALUE SP -999.250 ILD -999.2~0 IbM HOB .24 NRAT .0i2 NCNL GR '999.250 DT '999-2'50 SP - -999.250 GR -999.250 HOB SP HOB GR SP GR HOB R MNEMONIC CALI NCNb -999.250 ILD -99~.250 GR .000 NRAT -999.250 DT 99..250 GR 47~g38 .250 DT -99~'156 .250 NRAT 336 ILD '~999 N GR 34 99~,055 NRAT ' .250 DT -99~ '999.250 33.281 CALl 1504'000 ' NCNb -999.290 SP -999.250 GR -99~,2520 RHOB .26 GR -999 · 250 ILD '999. 250 OR 38.656 NRAT DT -9993,988 1250 '9999.250 GR '99 ' 2'50 R H OB GR -994 ' 387 ·250 ILM CALl NCNb NCALI CNL ,$P -999.250 ILD GR -9 ? GR ..99'25 RHOB 2,45 NRAT GR -999·250 DT LN ALI NCNb -999.250 4~.219 CALl ' 867 NCNb -999-250 ILD '999.250~ GR 41.969 CALl 402 NRA T -99~:250 DT 99~,855 NCNb - .250 GR 999.250 RHOB GR SP -999.250 ILD -999. 250 ILM GR -9 RR 4~i344 CALl 99.250 RHOB 2'398 NG AT 086 NCNb GR -999.250 DT -999 250 SP OR 29999-250 ILD -999 250 99.250 OR 39;594 CALl ~G~® 2.307 NRAT -4.305 NCNb -999.250 DT -999.250 VALUE -999.250 2.895 I301.000 -999.250 -16.000 1.844 -999.250 2.900 1654.000 -999.250 448.000 336.250 -999.250 2.908 1306.000 -999.250 2.896 1390.000 -999.250' 2.900 1484.000 -999.250 2.889 1390.000 -999.250 2.924 1352.000 -999.250 2.959 1395.000 -999.250 2.973 1427.000 NNEMONIC VALUE SFLU -999.250 NPHI 0·472 FCNL 313.500 SFLU -999.250 NPH1 25{.875 FCNL 2.885 SFLU -999.250 NPHI 0.434 FCNL 433.500 SFLU -999.250 NPH/ 3.959 FCNL -0.676 SFLU -999.250 NPHI 0.502 FCNL 291.250 SFLU -999.250 NPHi 0.535 FCNL 327.750 SFLU -999.250 NPHI 0.471 FCNL 355.500 SFLU -999.250 NPHI 0.449 FCNL 363.000 Sf'bU -999.250 NPHI 0.447 FCNL 3.33.500 SFLU -999.250 NPHI 0.490 FCNL 335.500 SFLO -999.250 NPHI 0.529 FCNL 299.500 DEPTH 6500,000 6400,000 6300.000 6200,000 6100.000 6000.000 5900,000 5800.000 5700,000 5600,000 5500.000 MNEMONIC SP GR RHOB GR VALUE MNEMONIC VALUE -999,250 ILO -999,250 GR 2,391 NRAT -999,250 DT SP -999.250 ILD R -999,250 GR HOB 2.021 NRAT GR -999,250 DT $P GR RHOB GR SP GR RHOB GR GP SP RHOB P R SP HOB GR 8P GR RHOB GR SP GR RHOB GR SP GR RHOB GR -999 ILD 50 GR 1,981 NRAT -999,250 DT -999,250 ILD -99~,250 GR ,361 NRAT -999,250 DT ,250 iLD 99 GR .250 99~,201 NRAT - ,250 DT -999,250 ILD -99],250 GR ,277 NRAT -999,250 DT ,250 GR 355 . NRAT -999,250 ILD -999,250 GR 2,414 NRAT -999,250 DT Z99~,250 ILD 99 ,250 GR .99~,289 NRAT ,250 DT -999,250 ILO -99~,250 GR '375 NRAT -999,250 DT -999.250 ILO -999,250 GR .99~,340 NRAT ,250 DT -999,250 461031 99~-896 - .250 -999,250 I09 -999.250 -999.250 28,203 5,273 -999,250 -999,250 2~.484 ,822 -999,250 -999,250 39,844 .99~ '379 .250 -999.250 448,563 .371 -999,250 502 -999.250 000 -999 · 250 -999,250 43,281 4,414 -999,250 -9q9,250 094 -999 25-0 -999.250 42.000 2 I:5 - 99 : 5o MNEMONIC ILM CALl NCNL ILM CALl NCNL CALl NCNL CALl NCNL CALl NCNL ILM CALl NCNL CALl NCNL ALi CML CALl NCNL ILM CALl NCNL CALl NCNL VALUE -999,250 2,9]9 1409,000 -999,250 2.969 1766,000 -999,250 2,939 1080.000 -999,250 2,979 1610.000 -999.250 3,002 I165.000 -999,250 2,97] 1264,000 -999,250 2,969 1814.000 -999,250 2,959 1485.000 -999,250 2.969 1547,000 -999,250 2,969 1500.000 -999,250 3.016 1517.000 MNEMONIC SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU SPSi FCNL SFLU NPHi FCNb SFLU NPHI FCNL SFLU NPHI FCNL VALUE -999.250 0,455 352,250 -999,250 0,]93 482,250 -999,250 0.706 1~0,000 -999.250 0,441 396,750 -999.250 0,725 226.750 -999.250 0,542 288.750 -999~50 0 82 489,000 -999,250 0,499 349,500 -999,250 0,549 32],750 -999,250 0,491 339,500 -999.250 0.513 332,000 D5 P TH MN.~ MDN I C 5400.000 SP GR (~HOB 5300.000 SP GR SP GR ~HOB GR SP GR RHOB GR GR GR 5200.000 5100.000 5000,000 4900.000 4800.000 4700.000 4600.000 45O0.000 4400.000 VALUE MNEMONIC VALUE MNEMONiC VALUE -~9~.~o ~ -~.~o .~,~ -~g~.~o 99 .2 0 GR 43.9)d CALl 3.002 -99~'420.250 DTNRAT '999.2504"2~0 NCNb 1463.000 -999.250 iLD ILM -999.250 049 ,. 8 :ooo -999'250 -99~ ILM -99~:250 -99 CALI 012 99~'-36'3 NRAT' 4'1~2 NCNb 1565.000 - .250 DT -9991250 -vgg. ~o ~u .ggg. zSo z~ -gv~. ~o -99~. ~5o o~ 4$..5~.a cA~ o2u .396 NRAT . '4,3~=4 N~N~ 151~]000 999Z250 UALi 012 2.041 N~AT 4.]O1 -NCNb I~86[000 999,250 DT -990.256 ~ .000 -9 ,_9 -999.250 '99 2.979 99~.359 NRAT NCNL 1340000 - .250 DT -99~,25~ ' 9 .250 _ OR ' '42'500 ~AL/ .988 .355 NRAT 4.066 N~N~ 1395.000 -999.2.50 DT -999-250 '~ -999.250 ' ~I 2.996 SP HOB P HOB -99~'396,250 DTNRAT .99912~64.148 NCNb 1453.000 -999 .~o ~ ~--~ ~c~ a.ol~ .99~'250 ILD 'gg9.250 ILM '9gg.250 '359 NRAT . 4.305 NCNL 1408.000 -999.250 ~DT ..999.~50 99,250 G~ 40278i CA~I 035 1366.000 MNEMONIC SFLU NPH1 SFLU NPHI FCNL SFbU NPHI FCNL SFI.,U NPHI FCNb 8FLU NPH! FCND SFLU NPH1 FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL VALUE -999.250 0.523 332.250 -999.250 0.514 325-000 '999.250 O.5O5 355.500 '999.250 0.536 331.250 -999.250 0.529 310.500 -999.250 0.506 307.500 -999.250 0.495 335.000 -999.250 0.474 3]1.750 -999.250 0.501 323.000 -999.250 0.529 298.750 -999.250 0.551 27 ~. 000 · DEPTH 4300.000 4200.000 4100.000 4O00,O0O 3900.000 3800.000 3700.000 3600.000 3500,000 3400.000 3300.000 MNEMONIC P R RHOB GR SP GR RHOB GR SP GR RHOB GR SP GR RHOB GR SP RHOB GR SP HOB GR SP GR RHOB GR SP HOB GR SP RHOB GR VALUE -999 250 .99~ '465 .25O -999.250 -99~.250 .313 -999.250 -999.250 -999.250 .99~ '790 .250 MNEMONIC VALUE MNEMONIC ILD -999.250 iLM GR 35.7i9 CALl NRAT 9~.785 NCNL DT -9 .250 ILD -999.250 [~R 41.8163 CALl RAT 4.24 NCNL DT -999.250 1LD -999.250 GR 46.688 CALf URAT 4.668 NCNL T -999.250 -999.250 ILD . -999 250 ILM '99~.250 NG~ T 45'1 76 NCNL .434 A 4 063 CALl -999.250 DT -999~250 -999.250 iLD -999.250 - ILM -999.250 GR 50,188 CALl .99~.314 NRAT .250 DT 99~'422 NCNL - .250 -999.250 25O '9919:869 '999.250 ILD -999.250 GR 5}.250 CALl NRAT .215 NCNL DT -999.25<0 -999.250 ILD -999.250 GR .99~-301 NRAT .250 DT 250 I LM '949~:094 CALl .25'0 -999.250 ILD '999.250 -999-250 GR 34-219 2.184 NRAT ~i512 -999.250 DT '999 250 999-250 ILD -999 250 999,250 GR 39:969 994'563 NRAT .250 DT 99~'48-4 - .250 SP -999. 250 ILD -999. 250 890 NRAT 320 GR -999. 250 OT -999. 250 -9999.250 ILD -999.250 -99 .250 G~ 28.891 19.118 NRAT 94.676 -99 .250 DT -99 .250 SP IbM CALl NCNL iLM CALl NCNL CALl NCNL CALl NCNL VALUE -999.250 ].045 1387.000 -999.250 3.045 1418.000 -999.250 3.016 1482.000 -999.250 3.021 1390.000 -999.250 3.021 1439.000 -999.250 3.021 1454.000 -999.250 3.021 1463.000 -999.250 3.016 1215.000 -999.250 3.045 1270.000 -999.250 3.049 1411.000 -999.250 3.049 1151.000 MNEMONIC SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI f'CNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPH1 FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPH1 FCNL VALUE -999.250 0.434 365.750 -999.250 0.518 316.000 -999.250 0.596 289.500 -999.250 0.505 332.000 -999.250 0.550 305.250 -999.250 0.513 324.000 -999.250 0.477 350.750 -999.250 0.507 293.250 -999.250 0.562 263.750 -999.250 0.532 280.500 -999.250 0.597 230.125 3200.000 3100.000 300O°00O 2qO0,O00 2800,000 2700.000 2000.000 2500.000 2490.000 MNEMONIC SP GR RHOB GR SP GR RHOB GR SP GR RHOB GR SP GR GR 8P GR GR SP GR RHOB SP GR HOB R SP GR RHOB GR GR RHOB GR VALUE MNEMUNiC VALUf' -999 250 999;250 1,8go -ggg.250 250 - o :ooo NRAT 4 324 ST -999."250 '999.250 -99~.250 .463 -999.250 ILD -999.250 DT -999'250 -999. 250 -999,250 808 -994: so ILO -999.250 GR 22.469 NRAT .410 DT -99~.250 -999.250 -99~.250 .995 -999.250 ILD -999.250 NRAT .2 DT -999-250 -999 250 '999."250 GR - 1 406 NRAT -99 2 so -999.250 31.719 -0.709-999,250 -999.250 iLO 21 NRAT -999 250 DT -999.250 4~5 -999 250 :9999.250 99.250 ILD -999 250 GR 24:750 204 ooo DX -999".250 -999.250 '99~.250 .486 -999.250 ILO -999.250 GR 25.016 NRAT 4 "766 DT -999.250 -999 250 -9992250 -999 250 -9992250 ILO -999.250 GR -999.250 NRAT -999.25:0 DT -999.250 MNEMONIC ILM CALl NCNL ILM CALl NCNL ILM CALf NCNL ILM CALl NCNL IbM CALl NCNL iLM CALl NCNL CALl NCNL 1LM CALl NCNL CALf NCNL VALUE -999.250 3.055 1160.000 -999.250 3.055 1235.000 -999.250 3.045 1317.000 -999.250 3.045 1486.000 -999.250 -16.000 1.939 -999.250 3.045 1485.000 -999.250 848.000 232.500 -999.250 3.045 1181.000 -999.250 -999.250 -999.250 MNEMONIC SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPHI FCNL SFLU NPH1 FCNL 8FLU NPHI FCNb SFLU NPHi FCNL SFLU NPHI FCNb VAbUE -999.250 0.533 271.500 -999.250 0.500 263.500 -999.250 0.548 285.250 -999.250 0.523 317.250 -999.250 327.250 3.045 -999.250 0.555 335.750 -999.250 5.047 -0.499 -999.250 0.613 226.125 -999.250 -999.250 -999.250 SUMMARY OF DATA RECORD,.S · NUMBER O~ ,RECORDS: 1318 LENGTH OF RECORDS: 966 BYTES LENGTH DF LAST RECORD: 426 BY~ES FILE TRAILER LENGTH: 62 BYTES FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECORD LENGTH: NEXT FILE NAME: 1024 BYTES EOF TAPE TRAILER LENGTH: 132 BYTES TAPE NAME: 61307 SERVICE NAME: .EDIT TAPE CONTINUATION NUMBER: 01 NEXT TAP~ NAME: COMMENTS: DATE: 81/ l/ 6 LIS TAPE VERIFiCAI')..ON LISTING 5VF 009,H05 VERiFICATlO~ LISTING PAGE DATE :~1t10/ 6 CO~TISUATION # PRE¥IOUS REEL : DAT£ :gl/~O/ ORIGI~ :~070 TAPE NA~E ~622~5 CONTiNUATiON PREVIO(iS ~APE CO~ENTS ~TAPE FiLE NA~E :SEHVIC.O0i SERVICE VERSiO~ # MAXIN~ LENGTH : 1024 PREVIOUS FILE : MNE~ COMTENT$ CN : AHCO ALASKA I~C. FN : PRUDMDE BAY SEC:Y: I~ COU,~: ~. SbOPE STAT: ALASKA CTRY: U.S,A. MNE~! CUNT~]NTS ** RECORD TYPE 047 ** U~IT TYPE CATE SIZE CODE 000 000 016 065 000 000 OOB 065 000 000 012 065 OOO 000 004 065 000 000 004 065 000 000 002 065 000 000 008 065 000 000 006 065 000 000 006 065 UNI% IYPE CATE SIZE CODE 000 000 011 065 L~P 009.H05 VERiFiCATiON LISTfNG ~* RECO. D IYFE 047 *~ JOB 10707,62215 TDT HUN #I, 27-6EP-S~ BT~. h~.!G INTERVAL = 12950 TOP LOG INTERVA~ = !2400 TYPE FLUIO IN ~OLE = CRUDE FLUID L~VEL : FLOWING PAG~ ** DA~A FORMAT HECORO ** ENTRY SHOCKS ~YPg SIZE REPR CODE ENTRY 4 i 66 8 4 73 60 9 4 65 .lin 0 1 66 0 DATOM ~3PECIFICATION SHOCKS MNEM SERVICE SERVICE ONIT API APl APl AP1 FILE SIZE PROCESS SAMPLE REPR I'0 ORDER # LOG TYPE .bA~ ~OD N bEVEL CODE DEPT FT 0 0 0 0 4 0 1 68 GA '~D~ ,~API 0 3 0 0 0 1 68 BACK ~ $ 0 0 0 1 68 TRAT YD~ 0 42 I 0 0 A 0 ! 68 FTDT TOM CPS 0 0 0 0 0 4 0 I 68 hVP 00')."i05 VYRIFiCATIOf~ b.iSI'iNG FBAC TDi:4 CPS 0 SIG,~4 'r~3'~ CU 0 NTDT '£D?~ CPS 0 GSF TD~ 0 SGR T~q GAP£ 0 0 0 0 0 4O i 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ** DATA DEPY 12990,000 GR FTD:~ -999.250 FBAC FSIG -999.250 GSF DEP~ 12900,000 GR FTDT 277,7i4 FBAC F$IG 40,364 GSF DEPT ~2800.000 GR FTDT 228.461 FBAC F$iG 14 970 DCPT 12700.000 GR FTDT 322.71~ F~AC FSIG R7.854 GSP DEPT 12600,000 FTD~Y 299 ~65 FSI~ 13.805 GSF DEPT 12500,000 G~ FTDT 314.216 ~BAC FSIG 35,031 GSF DEPT 12400.000 GR FTD~ -999.250 FDA(] FSIG -999.250 GSF DEPT 12399.000 GR FTDT -9~9,250 FBAC F$IG -999.250 GSF -999,250 =999.250 -999'250 5b.404 -34 267 0~997 14.I01 -48.~74 1' 31 53.704 5,' 997 2§.802 -67.409 1.73i ~61,463 -8 ~ 95 -999.250 :999.250 999.250 -999.250 -999.250 -999.250 Fib~ ~A~E :SERVIC,O01 SERV1C~ ~AME VERSiO~ ~ DATE ; NEXT FILE NA~E EOF B~CK SIGM SGR BACK SIG~ SGR BACK SIC~! SGR BACK SiG~ BACK Slm~q SGR MACK SIG~ BACK SiGM SGR BACK SGR -999. 250 999,250 15~.Z56 43,767 -22,000 235.759 7,26~ !5.500 291.261 40.979 -!7.375 337.263 i~.487 -i0.125 383.265 34.6B3 -999.250 '~99 ' ' -999.250 -99g TRAT N T D T TRAT NTDT TRAT NTDT TRAT TRAT TRAT NTDY TRAT TRAT £: T D T PAGE 1 68 1 68 1 68 1 68 i 68 i 68 -999.250 -999.250 3.877 787.477 2.390 487.562 3.516 796,47~ 2.352 6~.512 4,340 941,933 -999.250 -999.250 -999.250 -9~9.250 FILE NAM£ :SERVIC.O02 SE~vIC~ ~AME DATE : MAXI~U:4 bENGTH : 1024 FILE: TfPE : PREVIO~ FILE ** INF<~R~ATION RECORDS PRES: TOTOO1E RECO~D TYPE 047 ~ RECORD TYPL 047 ~* UalT TYPE CATE SIZE CODE 000 000 011 ** DAT~ FORAAT RECORD *~ ENTRY ~LOCKS TYPE SIZE REPR CODE ~ I 66 8 4 73 9 4 65 0 i 66 ENTRY 1 60 ,lin 0 DATUM SPECIFICATION 8DOCKS MNEM SE~V£CE SERVICE UNiT API ~PI APl IO ORDER ~ ~OG TYPE CLASS ~OD DEPT FT 0 0 0 0 GR TOM GAPI 0 31 32 0 BACK TDq CPS 0 0 0 0 TRAT TD~ 0 42 1 0 FTDT TD~ CPS 0 0 0 0 F~AC TD~ CPS 0 0 0 0 SIG~i '~D~ CO 0 40 ~ 0 NTDT TD~ CPS 0 0 0 0 FSIG TD~ 0 0 0 0 GSF TDM 0 0 0 0 SGR TD~ GAPI 0 0 0 0 FiDE SIZE PROCESS SA.MPLE REPR N O. ~EVEL CODE 0 4 0 i 68 0 4 0 1 68 0 4 0 I 68 o 4 0 1 68 0 4 0 1 08 0 4 0 i 68 0 4 0 1 68 0 4 0 1 68 0 4 o 1 68 0 4 0 1 68 0 4 0 I 68 DATA DEPT iF qt F T ,) l FSIG 2.,99~:000 GR 99 250 FBAC -999,250 GSF -999.250 B~CK 99:250 SGR -999.250 TkAT -99~ ~ -999.250 -999.250 DEPT 12900.000 GR 79.856 BACK 341.013 TRAT 3.802 LVP 009.H05 VERIFICATION Li:STING FTDT 265,463 FSiG 40,961 -71.651 3IGM 0.997 DEPT 12800,000 GR FTDT 218,7%% FBAC FSIG 14,~4% GSF -71,286 1,731 DEPT 12700.000 FTDT 271 , 7 ~ 4 FBAC FSIG ~7 79~ -7~, $iG~ 0.997 SGR DEPT 12o00,000 GR FTDT 303,465 FBAC FSIG 13,656 GSF 4~ 604 ~ACK 1,731 DEPT 12500.000 GR FTDT 286,464 F6AC FSI~ 36,898 ~'"SF ~85,664 BACK 99,~25 SIGM 0,9g9 DEPT 12gO0.O00 GR FTDT 275,964 FBAC FS!G 33,911 GSF 85,107 BACK '90,795 SI 0.997 DEPT 12399,000 GR FTOT 281 464 FSI(; 36.151 88,707 ~hCK 87,794 $IG.~ 0,997 SGR ** FILE T~AILER ** FIL~ NA~E :SERVIC.O02 SERVICE NAME VER~IO~ ~ DAT~ : MAXIbiU~ L~NGT~ : 1024 FiLE TYPE : NEXT FILS NAME ** FILE Ht;ADER ** FILE NA~E :8ERVIC,O03 SERVICE NAME : VERSIO~-~ # : DATE : MAXIMU~ LENGTH : 102~ FILE TYPE : PREVIOUS FIL~ : RECDRDS 62,763 NTDT -29,750 392 51 5 TRAT -!4,500 40~,766 T~AT 4 ,009 NTDT -2~,250 43S.267 TRAT 16.637 NTDT -I7.500 463,~18 T~AT 3g, 74 NTDT -6~,750 440,017 TRAT 33,155 -34,000 471.01~ TRAT 34,324 NTDT -30,250 P~GE 719,996 2,230 490,5bi 3,78~ 730'493 2.295 658.513 4,459 880.451 4.356 914.941 4,715 928,437 UNIT TYPE CAT~ SIZE CODE PRES: ** RECORD TYPE 047 ** RECORD"Yi' PF 047 ** RECORD TYPE 047 ** 000 000 011 065 ** DATA FORMAT RECORO *~ ENTRY BLOCKS TYPE $IZ~ REPR CODE ~ 1 66 ~ 4 73 9 4 65 o i 66 OCKS UNIT API API AP1 APl FILE LOG TYPE CLASS ~OD NO. FT 0 O 0 0 0 GAPi 0 31 32 0 0 CPS 0 0 0 0 0 0 42 i 0 0 CPS 0 0 0 0 0 CP~ 0 0 0 0 0 CO 0 40 1 0 0 CPS 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 GAPI 0 0 0 0 0 ENTRY 1 60 .lin 0 SIZE PROC bEV 4 4 4 4 4 4 4 ESS SAMPLE REPR Eb CODE 0 I 68 0 ! 68 0 1 68 0 1 68 0 ! 68 " ! 68 0 1 68 0 I 58 0 i 68 0 1 68 0 I 68 ** DATA DEPT FTDT FSIG DEPT FTDT FSIG DEPT FTDT FSIG DEPT FTDT FSIG DEPT FTDT FSIG 12990.000 G~ -999.250 FBAC -999.250 GSF 12900.000 GE 262.713 F~AC 41. 110 ,,"~'FS 12800.000 GR 225,211 FBAC 14.70i GSF 12700.000 GR 325.966 FBAC 38,840 GSF 12~00,000 G~ 258,963 F~AC !6.193 GSF -999. $1GM -999.250 SGR 8 ~ 91 SiGM 0,997 $GR 52,554 '83,917 1,731 90 ~57 ~ACK Q,997 06.~f}5 ~ACK -95, 73 SIGH ~.731 -~99.250 -999.250 -999,250 427 7 -~0.500 472.518 17,476 -20.500 ~7b,018 42.223 -34.750 493,0i9 16.637 -25.125 THAT NTDT TRAT NTDT THAT NTDT THAT NTDT THAT NTDT -999.250 -999.250 ~.054 768.985 2,219 502.558 3.682 883.450 2 504 577~536 LVP 0i)9.;-{05 VERIFICATIr~ DEPT 12500,000 GR FTDT 302,715 F~AC F$IG 35,165 GSF DEPT 12400.000 GR FTDT 256.7i3 FSAC FSIG 33.149 GSF DEPT 12399.000 FTDT 249.213 FSIG 35.135 LISTING 199.916 0,9~7 103,458 -99,425 0.997 114.259 -99.800 0.997 BACm $IGm SGR 502.520 YRAT 35.148 NYDT -72.250 492.019 TRAT 33,439 NTDT -40.750 492,269 TRAT 33.185 NTDT -43.250 PAGE 4.560 982,421 4.297 880.45! 4,496 ~44,460 ** FiLS '~RAILER FILE NAgE :$ERViC.O03 SERVIC~ ,~AME ; DAT~ ; MAXI~g~ LENGTH ; 1024 FiL~ T'fP< NE×T FiLE NAME EOF ** FILE H~]ADER FILE sAMS :SERVIC.004 SERVICE VERSIO~ DATE : MAXIgi]i'~ L~GTH ; i024 PRES: TO?OOiE RECORD RECORD TYPE 047 TYPE 047 TYPE 047 U~IT TYPE CATE SIZE CODE 000 000 011 O65 ENTh~Y BLO. C145 4 8 9 i 4 REP~ CODE 73 65 1 60 PAGE 8 DATUN SPECiFiCATION B6OCKS IO ORDER ~ DEP'~ FT 0 GR TDM GAPi 0 31 8AC~ ?0~ CPS 0 o TRAT Ti)hi 0 FTDT TD~ CPS 0 0 FBAC TDI CPS 0 $%G~ TD~ Cd 0 40 NTDT '~£)~ CPS 0 0 FSI(; TD~i 0 0 GSF TD~ 0 0 SGR ~?D~ GAPI 0 0 AP1 CDASS 0 32 1 0 0 0 0 0 o AP1 ~OD 0 0 0 9 0 0 0 0 0 FiLE SIZE 0 4 0 4. 0 4 0 4 0 4 0 t 0 4 0 4 0 4 0 4 0 .4 MEPR CODE 08 68 68 68 68 68 DATA ** DEPT 12990.000 GA -999.250 FTD~i -999,250 FBAC -999,250 F$IG -999,250 GSF -999,250 DEPT 12900,000 Ga 107,508 FTDT 24~,~2 FBAC -92.921 FSIG 40,573 GSF 0.997 DEPT 12800.000 GR 68,605 FTDT 221,2ii FBAC -qO.Oa5 FSIG 15,0%5 GSF 1.731 DEPT 12700.000 GR 126.860 FTDT 275.964 FBAC -96.548 FSIG 38,153 GSF 0.997 DEPT 12600.000 GR 81.456 FTDT 294,21b FbAC -101,551 FSIG 13.984 GSF 1.731 DEPT 12500,000 Gk i99.916 FTDT 279.464 F.~AC -109,305 FSIG 36,973 GSF 0.997 DEPT 12400.000 GR 144,$61 FTDT 290,465 F~AC -99,300 FSIG 34.672 GSF 0,995 DEPT 12399,000 GR 129,910 FTDT 294,465 FbaC -100.675 FSiG 33~104 G~F 0.997 ** FihE TMAILER ** FIbE DAaE :SERVIC.004 BACK ,-~ ~ 8GR BACK BACK SiGM SGR SACK 8IGM SGR BACK SIG~ SGR BACK SiGA SGR BACK 8GR -999.250 TRAT -999.250 NTDT -999.250 465.768 TRAT 43,032 NT~)T -40.750 ~9i.519 TRAT. 656 NTDT ~:000 482.769 TRAT ~2,178 NTDT -44.000 500.519 TRAT la.667 NTDT -31.000 513.520 TRAT 34,399 NYOT -79,750 495.769 TRAT 35.103 NTOT -53.500 503.520 34.564 -47.625 -999,250 -999,250 3.842 718.497 2,264 505. 557 3.746 72q.495 2.505 6bO.Ul3 4.467 859.954 5.037 925,438 4.634 916.440 LVP Oo',~.H05 VERIFICATIOm LISTING PAGE 9 SER~'iCE MAHE : DAT~: : MAXIMU~ L~NGT~ : 1024 FIL~ T?PE NEXT F~LE NAME EOF *********~ FIL~ NAME :SERVIC.O05 SERVICE NA~E VERSIU~ ~ : DATE : MAXIhU~q b£NGTH : 1024 FILE TYPE : PREVIOUS F~bE ** INF~'}RMATION RECORDS ** PRES: TDTOO1E ** RECu~D TYPE 047 ,~ RECORD TYPE 047 ** RECORD TYPE 047 ** UNIT TYPE CAT~ SIZE CODE 000 000 011 065 ** DATA FORMAT RECORD ** ENTRY BbOCK~ TYPE SIZE ~ 1 9 ~ 0 1 REPR CODE ~NTRY 66 1 73 60 65 ,lin 66 0 DATUN SPECIFICATION BL3CKS MNE~i~ ....... C P!$ o~:~R~! E SERVICE UNIT AP1 API A iD ORDER # LOG TYPE CLA8.. MOD NO, APl FILE SIZE PROClaSS SAMPLE REPR bEVEL CODE DEPT FT 0 0 0 0 0 GR TO~ GAP~ 0 3i ~2 0 0 BACK TD:~ CPS 0 0 0 0 0 TRAT TD~ 0 42 I 0 0 FTDT 779~ CPS 0 0 0 0 0 FBAC ?O~ CPS 0 0 0 0 0 BIG~ TO~ CU 0 40 i 0 0 NTDT 'fDq CPS 0 0 0 0 0 FSIG TD~ 0 0 0 0 0 GSF TO~ 0 0 0 0 0 SGR 'i]p~ GAPI 0 O 0 0 0 4 0 i 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 1 68 4 O 1 68 4 0 1 68 4 .o 1 68 VERiFICATiO~i LISTING DEPT 12990.000 GR FTDT -999.250 FBAC FSlG -999,250 GSF -999.250 99"250 BACK SiGM DEPT J2900,000 GR FTDT 270.464 FBAC F$IG 40.B42 GSF t31.310 -99,675 0.997 BACK $IG~ SGR DEPT 12800.000 GR FTDT 223.961 F6AC FSiG 14,806 G~F -92.79e i.731 BACK SiGN DEPT 12700,000 Gg FTDT 302.7t5 FBAC FSIG 37.585 GSF -10~,301 ,997 BACK $iGM DEPY 12~00,000 GR FTDT 254.463 FSAC FSIG 14.044 GSF 94.707 -I04.552 ~,731 BACK $iG~ DEPT !2500.000 GR FTDT 300,7!5 FBAC F$IG 35.464 GSF I99.9~6 -t16.683 0,997 BACK $1GM SGR DEPT 12400,000 GR FTDT -999.250 FB~C FSIG -999.250 GSF ~999,250 999,250 -999~250 SACK SIGN DEPT 12399.000 GR FTDT -999.250 FMAC F$IG -999.250 GSF -999.250 2999.~, S 0 999 ~ z ~0 BACK SIGN SGR ** FII~< TRAILER ** FILE NAME :SERVIC,O05 DATE : MAXIMU~ hENGTH: 102~ FILE TYPE ; NEXT F~LE NAME ; ** TAP~;i TRAILER *~ SERVICE NAME :SERVIC DATE :8i/!0/ 6 ORIGIN :i070 TAP~ PA~E :62215 -999,250 999. 5O 476.018 44.261 -49.250 500.019 17. 51 - 50 51~.020 42.118 -44,750 5i~.270 i6,697 -3~.500 519.270 34.623 -81.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999'250 TRaY TRAY NTDI TRAY NTDT TRAY NTDT TRAY NTDI THAT NTDT THAT NTDT TRAY PAGE -999.250 -999.250 3,835 797,974 2.220 510.055 3,a71 799.474 2.360 ~24.023 4.594 907,443 -999,250 -999.250 -999,250 -999.250 i0 bVF 0~.-~5 V~RIFiCATI!J~'~ bIST£NG DATE : ~i/10/ 6 OR ~ Gl r"~ : REEL ~.~AME :PEEL ID CONTI,~.~,jATIO~ ~ :0I NEXT ~EEf, NAME : CO~4HE~TS :[~EEL COMMENTS
