Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
186-139
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9038'feet None feet true vertical 6843' feet 8799 feet Effective Depth measured 8737'feet 8400', 8553'feet true vertical 6646'feet 6404', 6516'feet Perforation depth:Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" 2-7/8" L-80 L-80 8515' 8579' 6489' 6535' Packers and SSSV (type, measured and true vertical depth)8400' 8553' 6404' 6516' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 325-202 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: SLB Blue Max Packer: CAMCO HRP-1-SP SSSV: None Adam Klem adam.klem@conocophillips.com (907) 263-4529RWO/CTD Engineer 8684-8716', 8738-8760', 8778-8779', 8782-8783' 8786-8787', 8790-8791', 8799-8804' measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MDSize 115' Well Shut-In 76' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 186-139 50-029-21633-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025629 Kuparuk River Field/ Kuparuk Oil Pool KRU 3K-16 Plugs Junk Burst Collapse 8976' Casing 6823'9007' 4846' 115'Conductor Surface Production 6609-6631', 6646-6661', 6673-6674', 6676-6677', 6679-6679', 6681-6682', 6687-6691' 4883'3842' 16" 9-5/8" Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:21 pm, Jun 23, 2025 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: I am approving this document Location: Date: 2025.06.23 09:55:59-08'00' Foxit PDF Editor Version: 13.1.6 Adam Klem RBDMS JSB 062725 JJL 6/30/25 Page 1/4 3K-16 Report Printed: 6/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/20/2025 04:00 5/20/2025 10:00 6.00 MIRU, MOVE DMOB P Disconnect interconnect. Remove berming around rig Bridle up derrick. Work move checklist. Rig trucks on location at 0400 0500 shop loaded. 0530 office loaded. 0700 halfway house loaded. Sub base off well at 0830. 5/20/2025 10:00 5/20/2025 12:00 2.00 MIRU, MOVE MOB P All convoy pieces to travel to 3K-16. On location at 1030 AM Sub base left location 3R pad traveled to 3K-16 5/20/2025 12:00 5/20/2025 17:00 5.00 MIRU, MOVE MOB P Mobilize sub to 3K-16 5/20/2025 17:00 5/20/2025 18:00 1.00 MIRU, MOVE MOB P Spread pit liner around well head, hang tree in cellar, spot wellhead equipment in cellar. 5/20/2025 18:00 5/20/2025 19:00 1.00 MIRU, MOVE MOB P Spot sub base over well 5/20/2025 19:00 5/20/2025 20:00 1.00 MIRU, MOVE MOB P spot in pit module. 5/20/2025 20:00 5/20/2025 23:30 3.50 MIRU, WELCTL RURD P RU interconnect, raise derrick berm in rig, Rig down bridle lines. Work pre accecptance checklist. RU kill tank and hardline. Spot in cuttings box 5/20/2025 23:30 5/21/2025 00:00 0.50 MIRU, WELCTL RURD P Accept rig at 2330. Loading pits with seawater at 2330. 5/21/2025 00:00 5/21/2025 02:30 2.50 MIRU, WELCTL RURD P Build deep clean pill. RU to pump in the cellar Blow air to kill tanks. Pressure test lines to 3000 PSI Bleed pressure off tubing and IA 5/21/2025 02:30 5/21/2025 04:30 2.00 MIRU, WELCTL KLWL P Pump 35 BBL Deep Clean pill, followed with 387 BBL's seawater. 5BPM at 1100 PSI. 422 BBL's total. Shut down pump. Blow down lines 5/21/2025 04:30 5/21/2025 05:00 0.50 MIRU, WELCTL OWFF P OWFF starting at 430 5/21/2025 05:00 5/21/2025 06:00 1.00 MIRU, WHDBOP MPSP P Set BPV. Test under valve to 1000 PSI for 10 minutes. 5/21/2025 06:00 5/21/2025 07:30 1.50 MIRU, WHDBOP NUND P Bleed off tubing hanger void and SSSV. ND tree and adapter. FT LDS, Function X-O in hanger neck threads, X rotations in neck. record RKB measurments. 5/21/2025 07:30 5/21/2025 11:30 4.00 MIRU, WHDBOP NUND P NU BOP, tighten kill line swivel, set riser, fill stack perform shell test. Rig: NABORS 7ES RIG RELEASE DATE 5/25/2025 Page 2/4 3K-16 Report Printed: 6/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/21/2025 11:30 5/21/2025 17:00 5.50 MIRU, WHDBOP BOPE P Start testing BOPE, Initial BOP Test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular on 2-7/8" and 4" test joints, UVBR's, LVBR's w/2-7/8" and 4" test joint. Test 1.) Blind rams, CMV 1,2,3, and 16, rig floor kill, and outer test spool valve, and IBOP, Test 2.) Blind rams, CMV 4,5, and 6, HCR Kill, inner test spool valve, and Manual IBOP, (Open CMV 2, inner test spool valve, rig floor kill, upper IBOP), B/D TD, move test hose T/cellar test spool valve, P/U 2- 7/8" Dounut test joint w/3.5" FOSV, Test 3.) LPR, 3.5" FOSV, Test 4.) Annular, CMV 7, 8, 9, manual kill. (open CMV 4,5,6, HCR Kill, and outer test spool valve), Test 5.) Hydraulic super choke and manual adjustbale choke (1,500 psi test), (Open CMV 7-9), Test 6.) UPR, CMV 10-11 (8), Manual Kill, (Open super and manual adjustable choke), Test 7.) LPR, TIW, Test 8.) Annular, CMV 12,13, 15 (8), Dart, (Open CMV 10, 11) TIW, Test 9.) UPR, CMV 14, (Open CMV 15), Test 10.) UPR, HCR Choke, (Open CMV 14), Test 11.) Manual Choke, (Open HCR Choke), Perform accumulator test. Initial pressure=3100 PSI, after closure=1500 PSI, 200 PSI attained =12 sec, full recovery attained = 130 sec. UVBR's= 6 sec, Annular= 26 sec. Simulated blinds= 6 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2200 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Guy Cook. 5/21/2025 17:00 5/21/2025 18:00 1.00 COMPZN, WHDBOP RURD P LD all test equipment and BD surface lines. 5/21/2025 18:00 5/21/2025 21:30 3.50 COMPZN, WHDBOP RURD P Move spooler to rig floor Rig up floor to pull completion. Load and tally DP in pipe shed. 5/21/2025 21:30 5/21/2025 22:00 0.50 COMPZN, WHDBOP SFTY P Prejob safety meeting to LD tubing. 5/21/2025 22:00 5/21/2025 22:30 0.50 COMPZN, WHDBOP PULL P MU landing joint to hanger BOLDS. Pull hanger to floor. PU WT=98K weight broke back to 80K Terminated Control line below hanger. L/D hanger and landing joint. 8,510.0 8,478.0 5/21/2025 22:30 5/21/2025 23:00 0.50 COMPZN, WHDBOP OWFF P OWFF for 30 minutes no flow 8,478.0 8,478.0 5/21/2025 23:00 5/22/2025 00:00 1.00 COMPZN, WHDBOP PULL P MU control line to spooler open SSSV start LD 2-7/8" tubing F/8510' T/8247' 8,478.0 8,247.0 5/22/2025 00:00 5/22/2025 01:00 1.00 COMPZN, WHDBOP CIRC P Well out of balance Circulate SxS 5BPM 1000 PSI . 8,247.0 8,247.0 5/22/2025 01:00 5/22/2025 01:30 0.50 COMPZN, WHDBOP OWFF P OWFF for 15 minutes 8,247.0 8,247.0 5/22/2025 01:30 5/22/2025 04:30 3.00 COMPZN, WHDBOP PULL P LD 2-7/8" Tubing F/8247' T/ SSSV at floor. Move spooler off floor. Break out SSSV. No pup joint under SSSV. Fought to LD SSSV for 45 minutes. 8,247.0 6,726.0 Rig: NABORS 7ES RIG RELEASE DATE 5/25/2025 Page 3/4 3K-16 Report Printed: 6/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/22/2025 04:30 5/22/2025 10:30 6.00 COMPZN, WHDBOP PULL P Continue to LD 2-7/8" Completion to cut joint. 266 jts and a cut joint. Corrosion/holes/damage on jts 226, 227, 239, and 266. Pictures taken and uploaded into MW. *** Note: Cut joint length 14.39' 6,726.0 0.0 5/22/2025 10:30 5/22/2025 11:00 0.50 COMPZN, WHDBOP BHAH P MU 2-7/8" joint, set wear bushing 0.0 5/22/2025 11:00 5/22/2025 11:45 0.75 COMPZN, WHDBOP CLEN P RD tongs and clean rig floor Load and tally DC's x 6 Load cart and bring tools to RF 0.0 0.0 5/22/2025 11:45 5/22/2025 14:00 2.25 COMPZN, WHDBOP BHAH P MU Cleanout BHA #1 w/6 4-3/4" Drill collars 0.0 237.0 5/22/2025 14:00 5/22/2025 21:00 7.00 COMPZN, WHDBOP TRIP P RIH W/Clean out BHA and 4" XT 39 F/surface T/8489' PU X-O to HT-38 and single joint KU PUW=1650 SOW-105K 237.0 5/22/2025 21:00 5/22/2025 22:00 1.00 COMPZN, WHDBOP REAM P Establish Milling parameters Rot at 55 RPM ROT WT =130K Free tq= 6K PR=3 BPM at 300PSI Engage TOF at 8496' (7ES RKB) Dress off and clean out down to 8502' (7ES RKB) Set down 10K WOB PU clean off fish RIH to 8503' 5/22/2025 22:00 5/22/2025 22:30 0.50 COMPZN, WHDBOP RURD P LD single C/O elevators PU single MU to top drive to ream and circulate. 5/22/2025 22:30 5/23/2025 00:00 1.50 COMPZN, WHDBOP CIRC P Circulate sweep off bottom chase with seawater. 5 BPM 800 PSI. till clean 5/23/2025 00:00 5/23/2025 01:30 1.50 COMPZN, WHDBOP PRTS P RU and attempted to test 7" casing to 2500 PSI for 30 minutes. Pressured up to 2200 PSI. OA increased to 1000 PSI. Bled OA down to 525 PSI. Pressured up 7" from 2200 PSI to 2500 PSI for 30 minutes. 46 STK's total to pressure up. 5/23/2025 01:30 5/23/2025 02:00 0.50 COMPZN, WHDBOP RURD P RD testing equipment and blow down lines. LD HT-38 joint. 8,503.0 8,503.0 5/23/2025 02:00 5/23/2025 08:30 6.50 COMPZN, WHDBOP PULD P Pull out of hole LD DP F/8502' (7ES RKB) 8,503.0 237.0 5/23/2025 08:30 5/23/2025 10:00 1.50 COMPZN, WHDBOP BHAH P LD Dress off assembly BHA #2 237.0 0.0 5/23/2025 10:00 5/23/2025 10:30 0.50 COMPZN, WHDBOP CLEN P Clean RF and prep to run tubing 0.0 0.0 5/23/2025 10:30 5/23/2025 11:00 0.50 COMPZN, WHDBOP PUTB P Pull wear ring 0.0 0.0 5/23/2025 11:00 5/23/2025 12:00 1.00 COMPZN, WHDBOP PUTB P Load and tally 2 joints of 3-1/2" Tubing Load all jewelry into pipe shed and verify order. Confirm joint count and thread cap placement. 0.0 0.0 5/23/2025 12:00 5/24/2025 00:00 12.00 COMPZN, WHDBOP PUTB P Run 2-7/8" completion as per approved tally F/surface T/6166' PUW=60K 60-80 fpm max running speed per SLB rep. 0.0 5/24/2025 00:00 5/24/2025 03:30 3.50 COMPZN, WHDBOP PUTB P Coninute RIH W/2-7/8" EUE completion F/6610' T/8499' shear pins at 12K down. No go at 8502' 6,610.0 8,502.0 5/24/2025 03:30 5/24/2025 04:15 0.75 COMPZN, WHDBOP HOSO P Spaced out off tag 1.97' MU 10.14' of pups under joint 252. 8,502.0 8,502.0 5/24/2025 04:15 5/24/2025 05:00 0.75 COMPZN, WHDBOP THGR P MU Hanger to landing joint and hanger to string. 8,502.0 8,502.0 Rig: NABORS 7ES RIG RELEASE DATE 5/25/2025 Page 4/4 3K-16 Report Printed: 6/17/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/24/2025 05:00 5/24/2025 07:00 2.00 COMPZN, WHDBOP RURD P RU, Reverse circulate corrosion inhibited seawater down IA taking returns up tbg. Pumping 880 psi @ 3 bpm, 290 bbls 8,502.0 8,502.0 5/24/2025 07:00 5/24/2025 07:30 0.50 COMPZN, WHDBOP RURD P Land hanger RILDS and torque to spec via Cameron WH hand. (150 ft/lbs) 8,502.0 8,502.0 5/24/2025 07:30 5/24/2025 08:00 0.50 COMPZN, WHDBOP CIRC P RD circulating equipment on RF, 0.0 0.0 5/24/2025 08:00 5/24/2025 09:45 1.75 COMPZN, WHDBOP PRTS P Drop ball and rod pressure up to 3,800 PSI set packer and test 30 mins (good test) Bleed tubing pressure to 1,500 psi, Pressure IA 2,500 psi 30 mins (good test) Dumped tubing pressure SOV sheared. Pump 1.5 bpm / 40 psi to confirm good shear. Shut down pump 0.0 0.0 5/24/2025 09:45 5/24/2025 10:45 1.00 DEMOB, MOVE PRTS P RD testing equipmenrt Set BPV, and test 1000 psi 10 mins. (good test) 0.0 0.0 5/24/2025 10:45 5/24/2025 14:45 4.00 DEMOB, MOVE SVRG P Start BWM Swapping VBR's to 3.5" x 5.5" top and bottom Inspecting and taking pictures of all rams and annular ND BOP *** Note: Sim-ops Bridle up to lower derrick. 0.0 0.0 5/24/2025 14:45 5/24/2025 17:00 2.25 DEMOB, MOVE NUND P Install test plug into BPV NU Tree and adaptor spool P/T Void to 5,000 psi for 15 mins (confirmed) P/T Tree to 5,000 psi with LRS for 10 mins (good test) 5/24/2025 17:00 5/24/2025 20:00 3.00 DEMOB, MOVE FRZP P PT LRS 3,000 psi Freeze protect well to 2,100' with 78 bbl of diesel Hook up to U-Tube well. at 2000 Sim Ops>>>> Move bridle line to floor RD cattle chute 1830 trucks on location. Pull pits off sub Load shop on trucks. 5/24/2025 20:00 5/24/2025 21:00 1.00 DEMOB, MOVE FRZP P Blow down lines and start to U-tube at 2000 hours. for 1 hour. RD hard line to kill tanks empty out kill tank 5/24/2025 21:00 5/24/2025 22:00 1.00 DEMOB, MOVE DMOB P Hook truck up to halfway house. Hook truck up to office trailer. 2030 Half way house king pin went into recessed position. 2115 waiting on rig mats to get loaded on bed truck from under half way house and office. 2200 convoy left 3K. 5/24/2025 22:00 5/25/2025 00:00 2.00 DEMOB, MOVE DMOB P RD cellar blow down lines Pull pins out of derrick 2230 lay derrick over. 2330 Jack up rig pull mats out from under sub base. 0000 Rig off 3K-16 Rig: NABORS 7ES RIG RELEASE DATE 5/25/2025 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,737.0 3K-16 6/11/2025 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Post rig GLD, tag 3K-16 6/11/2025 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL: IA x OA COMMUNICATION 7/22/2003 raineg NOTE: TUBING TAIL @ 8588' DIL Based on Perf Tie-In Log 12/21/1986 raineg Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 39.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.76 37.0 4,882.9 3,841.7 36.00 J-55 BTC PRODUCTION 7 6.28 30.7 9,006.7 6,823.1 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 8,515.0 String Max No… 2 7/8 Set Depth … 6,488.5 Tubing Description Tubing – Completion Upper Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.0 35.0 0.30 Hanger 7.000 CIW CXS tubing hanger 7" X 3-1/2" EUE T x B 5K Camero n CXS 2.400 3,470.4 2,832.2 47.81 Mandrel – GAS LIFT 5.395 2-7/8" MMG mandrel W/SOV installed S#25343-01 Camero n MMG 2.366 6,514.8 5,026.9 41.37 Mandrel – GAS LIFT 5.395 2-7/8" MMG mandrel W/DMY installed S#25343-02 Camero n MMG 2.366 8,338.2 6,358.5 42.32 Mandrel – GAS LIFT 5.395 2-7/8" MMG mandrel W/DMY installed S#25343-06 Camero n MMG 2.366 8,399.8 6,404.0 42.47 Packer 6.276 3-1/2" SLB Blue Max Packer SLB Blue max 2.992 8,456.6 6,445.8 42.78 Nipple - X 3.688 2.313" HES X Nipple HES 2.313" X 2.313 8,506.9 6,482.7 43.13 Overshot 6.000 2-7/8" Northern Solutions overshot 7' Swallow 4' to shear screws No. Solution s 3.000 Top (ftKB) 8,510.0 Set Depth … 8,579.4 String Max No… 4 3/4 Set Depth … 6,535.1 Tubing Description Tubing – Completion Lower Wt (lb/ft) Grade Top Connection ID (in) 2.35 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,534.9 6,503.0 43.55 SBR 4.750 CAMCO OEJ SBR 2.347 8,552.5 6,515.7 43.82 PACKER 5.937 CAMCO HRP-1-SP PACKER 2.347 8,568.5 6,527.3 44.07 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 8,578.7 6,534.6 44.22 SOS 3.750 CAMCO SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,510.0 6,484.9 43.17 CUT RCT TBG CUT AT 8510' RKB 5/1/2025 2.441 8,799.0 6,687.4 48.06 FISH 47th Charge & Pieces of Bullnose Left in Hole 8/9/1988 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,470.4 2,832.2 47.81 1 GAS LIFT GLV RK 1 1/2 1,197.0 6/6/2025 SLB 0.188 6,514.8 5,026.9 41.37 2 GAS LIFT GLV RK 1 1/2 1,192.0 6/7/2025 SLB 0.188 8,338.2 6,358.5 42.32 3 GAS LIFT OV RK 1 1/2 0.0 6/6/2025 SLB 0.250 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,684.0 8,716.0 6,608.9 6,631.1 A-3, 3K-16 8/11/1988 8.0 RPERF 2 1/8" EnerJet, 60 deg ph 8,702.0 8,703.0 6,621.4 6,622.1 A-3, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,706.0 8,707.0 6,624.2 6,624.9 A-3, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,710.0 8,709.0 6,627.0 6,626.3 A-3, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,713.0 8,714.0 6,629.0 6,629.7 A-3, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,738.0 8,760.0 6,646.2 6,661.2 A-2, 3K-16 8/11/1988 8.0 RPERF 2 1/8" EnerJet, 60 deg ph 8,741.0 8,742.0 6,648.2 6,648.9 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,745.0 8,746.0 6,651.0 6,651.6 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,755.0 8,756.0 6,657.8 6,658.4 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,759.0 8,760.0 6,660.5 6,661.2 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,778.0 8,779.0 6,673.3 6,674.0 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,782.0 8,783.0 6,676.0 6,676.7 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,786.0 8,787.0 6,678.7 6,679.4 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,790.0 8,791.0 6,681.4 6,682.1 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,799.0 8,804.0 6,687.4 6,690.8 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 3K-16, 6/17/2025 12:47:42 PM Vertical schematic (actual) PRODUCTION; 30.7-9,006.7 IPERF; 8,799.0-8,804.0 FISH; 8,799.0 IPERF; 8,790.0-8,791.0 IPERF; 8,786.0-8,787.0 IPERF; 8,782.0-8,783.0 IPERF; 8,778.0-8,779.0 IPERF; 8,759.0-8,760.0 IPERF; 8,755.0-8,756.0 RPERF; 8,738.0-8,760.0 IPERF; 8,745.0-8,746.0 IPERF; 8,741.0-8,742.0 IPERF; 8,713.0-8,714.0 IPERF; 8,710.0-8,709.0 IPERF; 8,706.0-8,707.0 IPERF; 8,702.0-8,703.0 RPERF; 8,684.0-8,716.0 PACKER; 8,552.5 CUT; 8,510.0 Nipple - X; 8,456.6 Packer; 8,399.8 Mandrel – GAS LIFT; 8,338.2 Mandrel – GAS LIFT; 6,514.8 SURFACE; 37.0-4,882.9 Mandrel – GAS LIFT; 3,470.4 CONDUCTOR; 39.0-115.0 Hanger; 35.0 KUP PROD KB-Grd (ft) 39.01 RR Date 8/20/1986 Other Elev… 3K-16 ... TD Act Btm (ftKB) 9,052.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292163300 Wellbore Status PROD Max Angle & MD Incl (°) 50.02 MD (ftKB) 2,600.00 WELLNAME WELLBORE3K-16 Annotation Last WO: End DateH2S (ppm) 160 Date 2/20/2016 Comment SSSV: TRDP ORIGINATED TRANSMITTAL DATE: 5/8/2020 ALASKA E-LINE SERVICES TRANSMITTAL #: 5423 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5423 3K-16 50029216330000 Tubing Cut Record 1-May-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 186-139 T40396 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.08 13:14:30 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9052'3146 8799' Casing Collapse Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-263-4529 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8569' 9-5/8" 76'115' CAMCO HRP-1-SP SSSV: CAMCO TRDP-1A-SSA 6852'8569'6528' 7" 16" KRU 3K-16 8684-8716' 8738-8760' 8778-8779' 8782-8783' 8786-8787' 8790-8791' 8799-8804' 8976' 6609-6631' 6646-6661' 6673-6674' 6676-6677' 6679-6679' 6681-6682' 6687-6691' 4846' 9007' Perforation Depth MD (ft): 2-7/8" 115' 4883' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025629 186-139 P.O. Box 100360, Anchorage, AK 99510 50-029-21633-00-00 ConocoPhillips Alaska, Inc Will perfs require a spacing exception due to property boundaries? AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 8553MD/6516'TVD 1786'MD/1688'TVD 8579' Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Proposed Pools: 3842' Burst 5/10/2025 Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 6823' Adam Klem adam.klem@conocophillips.com RWO/CTD Engineer Subsequent Form Required: Suspension Expiration Date: L-80 m n P 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:34 pm, Apr 03, 2025 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: I am approving this documentLocation: Date: 2025.04.03 12:58:10-08'00' Foxit PDF Editor Version: 13.1.6 Adam Klem 325-202 X DSR-4/7/25JJL 4/14/25 10-404 9038' * SFD *AOGCC witnessed BOP and Annular test to 2500 psi. *If a production casing leak is discovered, contact the AOGCC to gain approval before proceeding with the operation. * Per Well Completion Report of 4/3/87 SFD SFD 4/4/2025 6843' SFD *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.14 16:42:35 -08'00'04/14/25 RBDMS JSB 041725 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 24, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 3K-16 (PTD# 186-139). Well 3K-16 was drilled and frac’d in 1986 as a Kuparuk A sand producer. It was subsequently re-frac’d in 1993. It has never been worked over and has the original tubing, which developed multiple tubing leaks. The tubing has been patched and continued to produce for a period time, however more tubing leaks have developed. In July of 2023 a plug was installed in the tubing tail to secure the well, and both a CMIT and DDT were performed in 10/23. Therefore, a workover is planned to replace the tubing. To bring the well back online, we request approval to proceed with a pre rig tubing cut above the packer and then rig workover to pull and replace the tubing and stack a packer above a pre rig tubing cut stub. The 2 7/8” tubing will be pulled from a pre-rig cut above the packer, and a new 2 7/8” completion including a non-sealing overshot, gas lift mandrels, and a stacked packer will be installed. If you have any questions or require any further information, please contact me at 907-263-4529. Adam Klem Rig Workover Engineer CPAI Drilling and Wells Digitally signed by Adam Klem DN: CN=Adam Klem, E= adam.klem@conocophillips.com , C=US Reason: I am approving this document Location: Date: 2025.04.03 12:58:28 -08'00' Foxit PDF Editor Version: 13.1.6 Adam Klem 3K-16 Kuparuk Producer Pull and Replace Tubing with Stacked Packer RWO PTD: 186-139 Page 1 of 2 PPre-Rig Work Remaining 1. Dummy off all GLM, leaving lowest GLV open for circulation 2. T-POT/PPPOT and IC-POT/PPPOT. 3. Cut tubing at ~8,510’ RKB 4. Combo pressure test tubing and casing to 2500psi 5. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3K-16. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Circulate seawater. Record shut-in pressures on the T & IA. Circulate KWF as needed and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/3,500psi. Test annular 250/3,500psi. Retrieve 2 7/8” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 2 7/8” tubing down to the pre-rig cut at ~8,510’ RKB. Cleanout to Tubing Stub 6. PU DP. RIH with casing scraper and dress off mill to tubing stub and dress off stub as needed. POOH LD DP. 7. RIH with RBP/G-Plug to set at 1,000psi. 8. PT plug to 1,000psi to confirm it as barrier Perform C-Bowl Conversion 1. ND BOPE 2. Swap WH to C-bowl 3. NU BOP and test break Install 2 7/8” Completion with Stacked Packer 4. MU new 2 7/8” completion with non-sealing overshot, packer, nipple profile, and GLMs. RIH to tubing stub. 5. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 6. Land tubing hanger, RILDS, drop ball/rod, and set packer. 7. Pressure test tubing to 3,000 PSI. 8. Pressure test IA to 2,500 PSI. ND BOP, NU Tree 9. Shear out SOV with pressure differential. 10. Install BPV and test. ND BOPE. NU tree. PT Tree and packoffs. 11. Pull BPV and freeze protect well. 12. RDMO. 3K-16 Kuparuk Producer Pull and Replace Tubing with Stacked Packer RWO PTD: 186-139 Page 2 of 2 PPost-Rig Work 1. Pull DVs and SOV. Install GLD. 2. Pull ball/rod used for setting packer. 3. Pull RBP and catcher. General Well Information: Estimated Start Date: 5/10/25 Current Operations: Shut-In Well Type: Producer Wellhead Type: Cameron Gen 4 casing head top flange. 7-1/16”- 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Static BHP: 3,814psi / 6681 TVD measured on 9/7/17 MPSP: 3,146psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 2 7/8” completion to a pre-rig cut, perform cleanout run, install a new 2 7/8” completion with a stacked packer. Personnel: Workover Engineer: Adam Klem (907-263-4529 / adam.klem@conocophillips.com) Production Engineer: Marina Krysinski Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,804.0 3K-16 9/1/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set CA-2 plug, Pulled DMY valve 3K-16 7/31/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL: IA x OA COMMUNICATION 7/22/2003 WV5.3 Conversio n NOTE: TUBING TAIL @ 8588' DIL Based on Perf Tie-In Log. 12/21/1986 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 39.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.76 37.0 4,882.9 3,841.7 36.00 J-55 BTC PRODUCTION 7 6.28 30.7 9,006.7 6,823.1 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 35.0 Set Depth … 8,579.4 Set Depth … 6,535.1 String Ma… 2 7/8 Tubing Description TUBING Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE8rdABMO D ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.0 35.0 0.30 HANGER 6.000 CIW TUBING HANGER 2.875 1,785.8 1,687.8 38.68 SAFETY VLV 5.125 CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 3,055.7 2,555.7 47.35 GAS LIFT 4.750 Merla TMPD 2.375 5,332.7 4,149.9 43.97 GAS LIFT 4.750 Merla TMPD 2.375 6,536.5 5,043.2 41.34 GAS LIFT 4.750 Merla TMPD 2.375 7,174.0 5,510.8 43.39 GAS LIFT 4.750 Merla TMPD 2.375 7,621.9 5,835.2 43.66 GAS LIFT 4.750 Merla TMPD 2.375 8,069.3 6,161.1 43.14 GAS LIFT 4.750 Merla TMPD 2.375 8,485.2 6,466.8 42.94 GAS LIFT 5.460 Merla TGPD 2.375 8,535.0 6,503.1 43.56 SBR 4.750 CAMCO OEJ SBR 2.347 8,552.5 6,515.7 43.82 PACKER 5.937 CAMCO HRP-1-SP PACKER 2.347 8,568.6 6,527.3 44.07 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 8,578.7 6,534.6 44.22 SOS 3.750 CAMCO SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,710.0 5,172.6 42.62 TIGHT SPOTS TIGHT SPOTS - TIGHT SPOTS STARTING @ 6,710 ' RKB DOWN 10/5/2017 0.000 7,190.0 5,522.5 43.41 LEAK TBG LEAK(S) @ 7190, 7214', 7230' RKB, HES LDL DATED 25-MAR-2018 3/25/2018 2.441 7,595.0 5,815.7 43.73 LEAK TBG LEAK(S) @ 7595' - 7597' RKB, HES LDL DATED 25- MAR-2018 3/25/2018 2.441 7,640.0 5,848.3 43.61 LEAK TBG LEAK(S) BETWEEN 7640 & 7650', INDENTIFIED BY HOLEFINDER ON 29- JUNE-2018 6/29/2018 2.441 8,566.0 6,525.5 44.03 CATCHER Set 2.23" AVA catcher on top of plug (OAL 33") 7/31/2023 0.000 8,569.0 6,527.6 44.08 PLUG Set 2.25" CA-2 plug 7/31/2023 0.000 8,799.0 6,687.4 48.06 FISH Pieces of 47th bullnose & Body of 1 Charge Pulled 46 of the 47 charges Out; Last Charge & Pieces of Bullnose Left in Hole 8/9/1988 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,055.7 2,555.7 47.35 1 GAS LIFT GLV BK 1 1,294.0 10/5/2018 0.156 5,332.7 4,149.9 43.97 2 GAS LIFT GLV BK 1 1,327.0 10/4/2018 0.188 7,174.0 5,510.8 43.39 4 GAS LIFT DMY BK 1 0.0 7/11/2017 0.000 7,621.9 5,835.2 43.66 5 GAS LIFT DMY BK 1 0.0 12/21/1986 0.000 8,069.3 6,161.1 43.14 6 GAS LIFT DMY BK 1 0.0 12/21/1986 0.000 8,485.2 6,466.8 42.94 7 GAS LIFT OPEN 1 1/2 7/31/2023 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,684.0 8,716.0 6,608.9 6,631.1 A-3, 3K-16 8/11/1988 8.0 RPERF 2 1/8" EnerJet, 60 deg ph 8,702.0 8,703.0 6,621.4 6,622.1 A-3, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,706.0 8,707.0 6,624.2 6,624.9 A-3, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,710.0 8,709.0 6,627.0 6,626.3 A-3, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,713.0 8,714.0 6,629.0 6,629.7 A-3, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,738.0 8,760.0 6,646.2 6,661.2 A-2, 3K-16 8/11/1988 8.0 RPERF 2 1/8" EnerJet, 60 deg ph 8,741.0 8,742.0 6,648.2 6,648.9 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 3K-16, 8/1/2023 7:21:56 AM Vertical schematic (actual) PRODUCTION; 30.7-9,006.7 IPERF; 8,799.0-8,804.0 FISH; 8,799.0 IPERF; 8,790.0-8,791.0 IPERF; 8,786.0-8,787.0 IPERF; 8,782.0-8,783.0 IPERF; 8,778.0-8,779.0 IPERF; 8,759.0-8,760.0 IPERF; 8,755.0-8,756.0 RPERF; 8,738.0-8,760.0 IPERF; 8,745.0-8,746.0 IPERF; 8,741.0-8,742.0 IPERF; 8,713.0-8,714.0 IPERF; 8,710.0-8,709.0 IPERF; 8,706.0-8,707.0 IPERF; 8,702.0-8,703.0 RPERF; 8,684.0-8,716.0 PLUG; 8,569.0 CATCHER; 8,566.0 PACKER; 8,552.5 GAS LIFT; 8,485.2 GAS LIFT; 8,069.3 LEAK; 7,640.0 GAS LIFT; 7,621.9 LEAK; 7,595.0 LEAK; 7,190.0 GAS LIFT; 7,173.9 TIGHT SPOTS; 6,710.0 GAS LIFT; 6,536.5 GAS LIFT; 5,332.7 SURFACE; 37.0-4,882.9 GAS LIFT; 3,055.7 SAFETY VLV; 1,785.8 CONDUCTOR; 39.0-115.0 KUP PROD KB-Grd (ft) 39.01 RR Date 8/20/1986 Other Elev… 3K-16 ... TD Act Btm (ftKB) 9,052.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292163300 Wellbore Status PROD Max Angle & MD Incl (°) 50.02 MD (ftKB) 2,600.00 WELLNAME WELLBORE3K-16 Annotation Last WO: End DateH2S (ppm) 160 Date 2/20/2016 Comment SSSV: TRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,745.0 8,746.0 6,651.0 6,651.6 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,755.0 8,756.0 6,657.8 6,658.4 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,759.0 8,760.0 6,660.5 6,661.2 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,778.0 8,779.0 6,673.3 6,674.0 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,782.0 8,783.0 6,676.0 6,676.7 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,786.0 8,787.0 6,678.7 6,679.4 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,790.0 8,791.0 6,681.4 6,682.1 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,799.0 8,804.0 6,687.4 6,690.8 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 3K-16, 8/1/2023 7:21:57 AM Vertical schematic (actual) PRODUCTION; 30.7-9,006.7 IPERF; 8,799.0-8,804.0 FISH; 8,799.0 IPERF; 8,790.0-8,791.0 IPERF; 8,786.0-8,787.0 IPERF; 8,782.0-8,783.0 IPERF; 8,778.0-8,779.0 IPERF; 8,759.0-8,760.0 IPERF; 8,755.0-8,756.0 RPERF; 8,738.0-8,760.0 IPERF; 8,745.0-8,746.0 IPERF; 8,741.0-8,742.0 IPERF; 8,713.0-8,714.0 IPERF; 8,710.0-8,709.0 IPERF; 8,706.0-8,707.0 IPERF; 8,702.0-8,703.0 RPERF; 8,684.0-8,716.0 PLUG; 8,569.0 CATCHER; 8,566.0 PACKER; 8,552.5 GAS LIFT; 8,485.2 GAS LIFT; 8,069.3 LEAK; 7,640.0 GAS LIFT; 7,621.9 LEAK; 7,595.0 LEAK; 7,190.0 GAS LIFT; 7,173.9 TIGHT SPOTS; 6,710.0 GAS LIFT; 6,536.5 GAS LIFT; 5,332.7 SURFACE; 37.0-4,882.9 GAS LIFT; 3,055.7 SAFETY VLV; 1,785.8 CONDUCTOR; 39.0-115.0 KUP PROD 3K-16 ... WELLNAME WELLBORE3K-16 3K-16 Proposed RWO Completion PROPOSED COMPLETION 2-7/8" 6.5 # L-80 EUE-M 8rd Tubing to surface 2-7/8" Camco MMG gas lift mandrels @ TBD 2-7/8" by 7" Packer @ ~8,450' RKB 2-7/8" X landing nipple (2.313" min ID) 2-7/8"" Non-sealing Overshot @ ~8,510' RKB REMAINING COMPLETION LEFT IN HOLE Camco HRP-1 Retreivable Packer @ 8,550' RKB Camco D nipple @ 8,568' RKB (2.25" ID) TOC: 6750'MD per CBL 29bbl arctic pack 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9052'3146 8799' Casing Collapse Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-263-4529 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8569' 9-5/8" 76'115' CAMCO HRP-1-SP SSSV: CAMCO TRDP-1A-SSA 6852'8569'6528' 7" 16" KRU 3K-16 8684-8716' 8738-8760' 8778-8779' 8782-8783' 8786-8787' 8790-8791' 8799-8804' 8976' 6609-6631' 6646-6661' 6673-6674' 6676-6677' 6679-6679' 6681-6682' 6687-6691' 4846' 9007' Perforation Depth MD (ft): 2-7/8" 115' 4883' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025629 186-139 P.O. Box 100360, Anchorage, AK 99510 50-029-21633-00-00 ConocoPhillips Alaska, Inc Will perfs require a spacing exception due to property boundaries? AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 8553MD/6516'TVD 1786'MD/1688'TVD 8579' Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Proposed Pools: 3842' Burst 5/10/2025 Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 6823' Adam Klem adam.klem@conocophillips.com RWO/CTD Engineer Subsequent Form Required: Suspension Expiration Date: L-80 m n P 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:34 pm, Apr 03, 2025 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: I am approving this documentLocation: Date: 2025.04.03 12:58:10-08'00' Foxit PDF Editor Version: 13.1.6 Adam Klem 325-202 DSR-4/7/25 9038' * SFD * Per Well Completion Report of 4/3/87 SFD SFD 4/4/2025 6843' SFD X *AOGCC witnessed BOP and Annular test to 2500 psi. *If a production casing leak is discovered, contact the AOGCC before proceeding with the operation. 10-404 *&:4/10/25 4/10/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.10 09:31:48 -08'00' RBDMS JSB 041025 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 24, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 3K-16 (PTD# 186-139). Well 3K-16 was drilled and frac’d in 1986 as a Kuparuk A sand producer. It was subsequently re-frac’d in 1993. It has never been worked over and has the original tubing, which developed multiple tubing leaks. The tubing has been patched and continued to produce for a period time, however more tubing leaks have developed. In July of 2023 a plug was installed in the tubing tail to secure the well, and both a CMIT and DDT were performed in 10/23. Therefore, a workover is planned to replace the tubing. To bring the well back online, we request approval to proceed with a pre rig tubing cut above the packer and then rig workover to pull and replace the tubing and stack a packer above a pre rig tubing cut stub. The 2 7/8” tubing will be pulled from a pre-rig cut above the packer, and a new 2 7/8” completion including a non-sealing overshot, gas lift mandrels, and a stacked packer will be installed. If you have any questions or require any further information, please contact me at 907-263-4529. Adam Klem Rig Workover Engineer CPAI Drilling and Wells Digitally signed by Adam Klem DN: CN=Adam Klem, E= adam.klem@conocophillips.com , C=US Reason: I am approving this document Location: Date: 2025.04.03 12:58:28 -08'00' Foxit PDF Editor Version: 13.1.6 Adam Klem 3K-16 Kuparuk Producer Pull and Replace Tubing with Stacked Packer RWO PTD: 186-139 Page 1 of 2 PPre-Rig Work Remaining 1. Dummy off all GLM, leaving lowest GLV open for circulation 2. T-POT/PPPOT and IC-POT/PPPOT. 3. Cut tubing at ~8,510’ RKB 4. Combo pressure test tubing and casing to 2500psi 5. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3K-16. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Circulate seawater. Record shut-in pressures on the T & IA. Circulate KWF as needed and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/3,500psi. Test annular 250/3,500psi. Retrieve 2 7/8” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 2 7/8” tubing down to the pre-rig cut at ~8,510’ RKB. Cleanout to Tubing Stub 6. PU DP. RIH with casing scraper and dress off mill to tubing stub and dress off stub as needed. POOH LD DP. 7. RIH with RBP/G-Plug to set at 1,000psi. 8. PT plug to 1,000psi to confirm it as barrier Perform C-Bowl Conversion 1. ND BOPE 2. Swap WH to C-bowl 3. NU BOP and test break Install 2 7/8” Completion with Stacked Packer 4. MU new 2 7/8” completion with non-sealing overshot, packer, nipple profile, and GLMs. RIH to tubing stub. 5. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 6. Land tubing hanger, RILDS, drop ball/rod, and set packer. 7. Pressure test tubing to 3,000 PSI. 8. Pressure test IA to 2,500 PSI. ND BOP, NU Tree 9. Shear out SOV with pressure differential. 10. Install BPV and test. ND BOPE. NU tree. PT Tree and packoffs. 11. Pull BPV and freeze protect well. 12. RDMO. 3K-16 Kuparuk Producer Pull and Replace Tubing with Stacked Packer RWO PTD: 186-139 Page 2 of 2 PPost-Rig Work 1. Pull DVs and SOV. Install GLD. 2. Pull ball/rod used for setting packer. 3. Pull RBP and catcher. General Well Information: Estimated Start Date: 5/10/25 Current Operations: Shut-In Well Type: Producer Wellhead Type: Cameron Gen 4 casing head top flange. 7-1/16”- 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Static BHP: 3,814psi / 6681 TVD measured on 9/7/17 MPSP: 3,146psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 2 7/8” completion to a pre-rig cut, perform cleanout run, install a new 2 7/8” completion with a stacked packer. Personnel: Workover Engineer: Adam Klem (907-263-4529 / adam.klem@conocophillips.com) Production Engineer: Marina Krysinski Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,804.0 3K-16 9/1/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set CA-2 plug, Pulled DMY valve 3K-16 7/31/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL: IA x OA COMMUNICATION 7/22/2003 WV5.3 Conversio n NOTE: TUBING TAIL @ 8588' DIL Based on Perf Tie-In Log. 12/21/1986 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 39.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.76 37.0 4,882.9 3,841.7 36.00 J-55 BTC PRODUCTION 7 6.28 30.7 9,006.7 6,823.1 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 35.0 Set Depth … 8,579.4 Set Depth … 6,535.1 String Ma… 2 7/8 Tubing Description TUBING Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE8rdABMO D ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.0 35.0 0.30 HANGER 6.000 CIW TUBING HANGER 2.875 1,785.8 1,687.8 38.68 SAFETY VLV 5.125 CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 3,055.7 2,555.7 47.35 GAS LIFT 4.750 Merla TMPD 2.375 5,332.7 4,149.9 43.97 GAS LIFT 4.750 Merla TMPD 2.375 6,536.5 5,043.2 41.34 GAS LIFT 4.750 Merla TMPD 2.375 7,174.0 5,510.8 43.39 GAS LIFT 4.750 Merla TMPD 2.375 7,621.9 5,835.2 43.66 GAS LIFT 4.750 Merla TMPD 2.375 8,069.3 6,161.1 43.14 GAS LIFT 4.750 Merla TMPD 2.375 8,485.2 6,466.8 42.94 GAS LIFT 5.460 Merla TGPD 2.375 8,535.0 6,503.1 43.56 SBR 4.750 CAMCO OEJ SBR 2.347 8,552.5 6,515.7 43.82 PACKER 5.937 CAMCO HRP-1-SP PACKER 2.347 8,568.6 6,527.3 44.07 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 8,578.7 6,534.6 44.22 SOS 3.750 CAMCO SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,710.0 5,172.6 42.62 TIGHT SPOTS TIGHT SPOTS - TIGHT SPOTS STARTING @ 6,710 ' RKB DOWN 10/5/2017 0.000 7,190.0 5,522.5 43.41 LEAK TBG LEAK(S) @ 7190, 7214', 7230' RKB, HES LDL DATED 25-MAR-2018 3/25/2018 2.441 7,595.0 5,815.7 43.73 LEAK TBG LEAK(S) @ 7595' - 7597' RKB, HES LDL DATED 25- MAR-2018 3/25/2018 2.441 7,640.0 5,848.3 43.61 LEAK TBG LEAK(S) BETWEEN 7640 & 7650', INDENTIFIED BY HOLEFINDER ON 29- JUNE-2018 6/29/2018 2.441 8,566.0 6,525.5 44.03 CATCHER Set 2.23" AVA catcher on top of plug (OAL 33") 7/31/2023 0.000 8,569.0 6,527.6 44.08 PLUG Set 2.25" CA-2 plug 7/31/2023 0.000 8,799.0 6,687.4 48.06 FISH Pieces of 47th bullnose & Body of 1 Charge Pulled 46 of the 47 charges Out; Last Charge & Pieces of Bullnose Left in Hole 8/9/1988 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,055.7 2,555.7 47.35 1 GAS LIFT GLV BK 1 1,294.0 10/5/2018 0.156 5,332.7 4,149.9 43.97 2 GAS LIFT GLV BK 1 1,327.0 10/4/2018 0.188 7,174.0 5,510.8 43.39 4 GAS LIFT DMY BK 1 0.0 7/11/2017 0.000 7,621.9 5,835.2 43.66 5 GAS LIFT DMY BK 1 0.0 12/21/1986 0.000 8,069.3 6,161.1 43.14 6 GAS LIFT DMY BK 1 0.0 12/21/1986 0.000 8,485.2 6,466.8 42.94 7 GAS LIFT OPEN 1 1/2 7/31/2023 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,684.0 8,716.0 6,608.9 6,631.1 A-3, 3K-16 8/11/1988 8.0 RPERF 2 1/8" EnerJet, 60 deg ph 8,702.0 8,703.0 6,621.4 6,622.1 A-3, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,706.0 8,707.0 6,624.2 6,624.9 A-3, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,710.0 8,709.0 6,627.0 6,626.3 A-3, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,713.0 8,714.0 6,629.0 6,629.7 A-3, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,738.0 8,760.0 6,646.2 6,661.2 A-2, 3K-16 8/11/1988 8.0 RPERF 2 1/8" EnerJet, 60 deg ph 8,741.0 8,742.0 6,648.2 6,648.9 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 3K-16, 8/1/2023 7:21:56 AM Vertical schematic (actual) PRODUCTION; 30.7-9,006.7 IPERF; 8,799.0-8,804.0 FISH; 8,799.0 IPERF; 8,790.0-8,791.0 IPERF; 8,786.0-8,787.0 IPERF; 8,782.0-8,783.0 IPERF; 8,778.0-8,779.0 IPERF; 8,759.0-8,760.0 IPERF; 8,755.0-8,756.0 RPERF; 8,738.0-8,760.0 IPERF; 8,745.0-8,746.0 IPERF; 8,741.0-8,742.0 IPERF; 8,713.0-8,714.0 IPERF; 8,710.0-8,709.0 IPERF; 8,706.0-8,707.0 IPERF; 8,702.0-8,703.0 RPERF; 8,684.0-8,716.0 PLUG; 8,569.0 CATCHER; 8,566.0 PACKER; 8,552.5 GAS LIFT; 8,485.2 GAS LIFT; 8,069.3 LEAK; 7,640.0 GAS LIFT; 7,621.9 LEAK; 7,595.0 LEAK; 7,190.0 GAS LIFT; 7,173.9 TIGHT SPOTS; 6,710.0 GAS LIFT; 6,536.5 GAS LIFT; 5,332.7 SURFACE; 37.0-4,882.9 GAS LIFT; 3,055.7 SAFETY VLV; 1,785.8 CONDUCTOR; 39.0-115.0 KUP PROD KB-Grd (ft) 39.01 RR Date 8/20/1986 Other Elev… 3K-16 ... TD Act Btm (ftKB) 9,052.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292163300 Wellbore Status PROD Max Angle & MD Incl (°) 50.02 MD (ftKB) 2,600.00 WELLNAME WELLBORE3K-16 Annotation Last WO: End DateH2S (ppm) 160 Date 2/20/2016 Comment SSSV: TRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,745.0 8,746.0 6,651.0 6,651.6 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,755.0 8,756.0 6,657.8 6,658.4 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,759.0 8,760.0 6,660.5 6,661.2 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,778.0 8,779.0 6,673.3 6,674.0 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,782.0 8,783.0 6,676.0 6,676.7 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,786.0 8,787.0 6,678.7 6,679.4 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,790.0 8,791.0 6,681.4 6,682.1 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 8,799.0 8,804.0 6,687.4 6,690.8 A-2, 3K-16 12/21/1986 1.0 IPERF 2 1/8 EnerJet, 0 deg. ph 3K-16, 8/1/2023 7:21:57 AM Vertical schematic (actual) PRODUCTION; 30.7-9,006.7 IPERF; 8,799.0-8,804.0 FISH; 8,799.0 IPERF; 8,790.0-8,791.0 IPERF; 8,786.0-8,787.0 IPERF; 8,782.0-8,783.0 IPERF; 8,778.0-8,779.0 IPERF; 8,759.0-8,760.0 IPERF; 8,755.0-8,756.0 RPERF; 8,738.0-8,760.0 IPERF; 8,745.0-8,746.0 IPERF; 8,741.0-8,742.0 IPERF; 8,713.0-8,714.0 IPERF; 8,710.0-8,709.0 IPERF; 8,706.0-8,707.0 IPERF; 8,702.0-8,703.0 RPERF; 8,684.0-8,716.0 PLUG; 8,569.0 CATCHER; 8,566.0 PACKER; 8,552.5 GAS LIFT; 8,485.2 GAS LIFT; 8,069.3 LEAK; 7,640.0 GAS LIFT; 7,621.9 LEAK; 7,595.0 LEAK; 7,190.0 GAS LIFT; 7,173.9 TIGHT SPOTS; 6,710.0 GAS LIFT; 6,536.5 GAS LIFT; 5,332.7 SURFACE; 37.0-4,882.9 GAS LIFT; 3,055.7 SAFETY VLV; 1,785.8 CONDUCTOR; 39.0-115.0 KUP PROD 3K-16 ... WELLNAME WELLBORE3K-16 3K-16 Proposed RWO Completion PROPOSED COMPLETION 2-7/8" 6.5 # L-80 EUE-M 8rd Tubing to surface 2-7/8" Camco MMG gas lift mandrels @ TBD 2-7/8" by 7" Packer @ ~8,450' RKB 2-7/8" X landing nipple (2.313" min ID) 2-7/8"" Non-sealing Overshot @ ~8,510' RKB REMAINING COMPLETION LEFT IN HOLE Camco HRP-1 Retreivable Packer @ 8,550' RKB Camco D nipple @ 8,568' RKB (2.25" ID) TOC: 6750'MD per CBL 29bbl arctic pack • • PTD 184 —R9 Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday, May 27, 2018 8:59 AM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler Subject: KRU 3K-16 (PTD#186-139) Follow Up Flag: Follow up Flag Status: Flagged Hello Victoria— Kuparuk producer 3K-16(PTD 186-139) has developed sustained casing pressure exceeding 2000 psi in the IA. The well has known TxIA communication and had been secured with a downhole plug while we were conducting diagnostics. In order to set a tubing patch,the plug was removed and the IA pressure increased,stabilizing at 2,150 psi. The well has 7", 26 lb/ft,J-55 grade production casing which has a burst pressure rating of 4,980 psi. We are continuing wellwork that will restore TxIA integrity as soon as possible—once this work is complete we will submit a 10-404 Sundry form. We will continue to monitor the well in the meantime. Please let us know if you have any questions or disagree with this plan. Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED JUN 5 2018 My0 0111- > L9 0 , s _o o O LL CIO Y Co > co Ill rIL CO 4- 'd 10 h COz Oc CO U o +, > J r co V 4. a c O N o f- w Qd N C -6 a - 0 < o C) s U al > n Q Q J to n t, r r r n n 4'' v 0 Cr crn -1 Q W r r T r T vl _C a) O L J h- O Q a a a a C. �' 0 N Q J d d d y 0) w d 'd '6 .i.-. N W co N fn N fn V) V) fn C V v V) F- 00 6 o - N 6 r� 6 O Y L C VI z u z 4 0 41 >• E v O c F- vN U• 0 (0 v p Cc - OWaWWWWWWW vi v C N LL LL LL LL LL LL LL LL +-' O) C C Q CU J J J J J J J J - >> 4-' - C ` OG a Z Z Z Z Z Z Z Z CU U L (1-, N '. LL LL LL LL LL LL LL LL 1Y .fl ' > .. r0 Y > ..-' N r U 0 I• Z a v > noV .. ro O c o • e - L v v -c c > V O1 4--.O , a ~ c c0 a O 0 Z C 2 < a) a v, c a G U Li Sr O 01 a O a Oa, a a a y N . U U Cl. U U U -) g U L N O .r.. W W ca, co : > 1J is es ca 019 Et co ▪ x p h z \ W x RI i—r 0 to v a J J J J J J J J o zapN� 4 m ir WWWWWW � � E 0 W W W W W W W W W > > > > > > > > .c...c." W z Y Y Y Y Y Y Y Y 0 w a a a a a a a a v > in a O QY Y Y MDDMM Y Y Y Y tv, Co LU Ucc colii N CD l0 O N N `_Nco Q a: 0 0 0 0 0 0 N ♦ , O O O 0 0 0 O o O d v o O o O O O 00 W 07 0 In fn (n to n r c 0 0 0 o O = o o > rn N 2n to co 2 2 to I ` O W 00000000 C V co . X N ^ V . ui V' O 0 0 O 0 0 O O O c 0 0 0 0 0 0 0 0 ooCC c n O O M t0 f0 IA O II') V) C h n M N N h. 00 N y O M n 10 N t0 r V h N 0 0 0 0 0 r N a N N N N N N N N L > R < th 8 O M M M 8 cd N N N O O O N NL 01 0 0 0 0 0 0 0 0 0 0 0 0 0 ++ O Co °�0 C l[) 1() 1() U) In N N M) Q U C Id °) tan I- u >L z ° cu c c w �acu 0 • Cr CD CD CD 4D N 03 3 a Z N a N O N N N N- O +▪+ E v v, = a: � N z -1 i Y Y Y < < O E z a a, C a < O N J M N N N N y1 N Y .r r t W C a'' Co vt C., N r-1 c N E U to O '�i a 13 .:x I- a a Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Organization (done') ~Two-Sided RESCAN Color items: Corayscale items: Poor Quality Originals: DIGITAL DATA [] Diskettes, No. [] Other, No/Type Other TOTAL PAGES: ~ '~ ORGANIZED BY; NOT E S: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Is~ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ Scanned {done) Illllllllllllllll[I PAGES: ~~(atthetimeofscanning) SCANNED BY; BEVERLY BREN VINC~RIA LOWELL ReScanned(done) RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~SI General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned.wpd i .__.-~7 V c~' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well ~~}} ~+, t ~) n Pt k': Job # Log Description JUN 1 9 2009 Kaska ~?il ~ Gas COrts. C~rnmissi0~ NO.5284 ~,-iChOf8g0 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 06/17/09 1B-19 ANHY-00091 PRODUCTION PROFILE ~ - < 05/27/09 1 1 3K-16 ANHY-00094 GLS ~ 05/29/09 1 1 3G-10 B04C-00058 INJECTION PROFILE ~ 05/31/09 1 1 1J-160 62WY-00006 MEMORY INJECTION PROFILE ~ - - 05/31/09 1 1 iJ-164 B2WY-00009 MEMORY INJECTION PROFILE 06/01/09 1 1 iJ-160L2 AXBD-00028 MEMORY INJECTION PROFILED - t 06/07/09 1 1 1 A-04A 604C-00040 RST ~ ~ 05/05/09 1 1 3M-03A AZJZ-00011 CH EDIT SFRT ~ 01/11/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • . . ~ ConocoPhillips Alaska JUL 3 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 t, (:J July 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 sCANNE.D AU G 0 1 2007 fó\ô9 \CO Dear Mr. Maunder: Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ') 1 ~~<_... \ Perry KI . ConocoPhillips Well Integrity Supervisor / 7 ('Lillo? . . JUL 1ì) ~ ,j) .u. 2007 {) 1~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/28/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft na gal 3K-1 186-101 19' 2.6 19" 7/7/2007 7 7/27/2007 3K-2 186-102 53' 7.2 9" 7/7/2007 3.7 7/22/2007 3K-3 186-103 43' 5.8 11" 7/7/2007 4.2 7/27/2007 3K-5 186-123 66' 9.0 26" 7/7/2,007 9.6 7/22/2007 3K-6 186-124 58' 7.9 13" 7/10/2007 4.8 7/22/2007 3K-7 186-125 70' 10.5 35" 7/7/2007 13.2 7/22/2007 3K-8 186-126 54' 4.0 9" 7/10/2007 3.6 7/22/2007 3K-9 186-174 26' 9.0 16" 7/10/2007 6 7/22/2007 3K:·11 186-164 43' 6.5 21" ... 7/10/2007····· 7.8 7/16/2007 3K-13 186-136 8" none 8" 7/10/2007 3.1 7/16/2007 3K-14 186-137 8" none 8" 7/10/2007 3.1 7/16/2007 3K-15 186-138 50' 6.0 22" 7/10/2007 8.4 7/22/2007 3K-16 186-139 46' 7.0 27" 7/10/2007 9.6 7/22/2007 3K-17 186-152 56' 8.0 30" 7/10/2007 10.7 7/22/2007 3K-18 186-151 38' 5.5 23" 7/10/2007 8.4 7/22/2007 MEMORANDUM- State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor DATE: May 18, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 3K Pad May 18. 2001' I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, SSV on 3K-27 would not pass the DP test. The valve was serviced & passed the re-test The AOGCC test report is attached for reference. I inspected 14 well houses on lQ Pad w/no problems witnessed. 'SUMMARY: i Witnessed SVS testing in Kuparuk River Field. 14 wells, 28 components tested. 1 failure witnessed. 3.57% failure rate. 14 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc cc; NON-CONFIDENTIAL SVS KRU 3K 5-18-01jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Ernie Barndt AOGCC Rep: John Crisp Submitted By: Date: Field/Unit/Pad: Kuparuk River Unit 3K Pad Separator psi: LPS 65 HPS 5/18/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE '3K-01 1861010 65 70 50 P P OIL 3K-03 1861030 65 70 55 P P OIL i3K-06 1861240 65 70 50 P P OIL 3K-09A 1861740 65 60 54 P P OIL! 3K-10 1861630, 65~ 70 52 P P OIL1 3K-11 18616401 65i 70 50 P P OIL , 3K-14 1861370 65 60 58 P P OIL 3K-t6 -- '-' 1861390 65 7'0 70 P P OIL , , 3K-i7 1861520 65 60 35 P P OIL , , i 3K-23 1970970 65 70 58 P- P OIL 3K-24 1982490 65 70 50 P P OIL 3K-27 1970460 65 70 52 P 4 OIL 3K'32 1970760 65 70 55 P P OIL 3K-35 1971090 65 70 50 P P OIL · , Wells: 14 Components: 28 Failures: 1 Failure Rate: 3.57% Remarks: RJF 1/16/01 Page 1 ofl SVS KRU 3K 5-18-01jc MICROFILMED 9/~ ~/00 DO NOT PLACE ANY' NEW MATERIAL UN ER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Stimulate X Plugging ~ Perforate Alter casing Repair well Pull tubing 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 R9E, UM R9E, UM R9E, UM R9E, UM 4. Location of well at surface 1009' FSL, 315' FWL, SEC.35, T13N, At top of productive interval 1521' FSL, 1514' FWL, SEC.1, T12N, At effective depth 1187' FSL, 1575' FWL, SEC.1, T12N, At total depth 1107' FSL, 1597' FWL, SEC.1, T12N, feet Plugs (measured) feet Other 6. Datum elevation (DF or KB) feet 6~)' RKB 7. Unit or Property name Kuparuk River Unit 12. Present well condition summary Total Depth: measured 9 0 3 8' true vertical 6 8 4 2' 8. Well number 9. Permit number/approval number 86-13cJ / ADDrv. N/A lO. APl number 5o-02cj-2163300 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 9 2 0' true vertical 6766' feet Junk (measured) feet Casing Length Structural Conductor 80' Surface 4 8 4 8' Intermediate Production 89 7 2' Liner Perforation depth: measured 8684'-8716', 8738'-8760', true vertical 6548'-6630', 6645'-6660, Size Cemented 1 6" 1540# POLESET 9-5/8" 1340 SX AS III& 350 SX CLASS G 7" 350 SX CLASS G& 175 SX AS I Measured depth True vertical depth 115' 115' 4883' 3841 ' 9007' 6823' 8778', 8782', 8786', 8790', 8799'-8804' 6672', 6675', 6677', 6680', 6686'-6690' Tubing (size, grade, and measured depth) 2 7/8" 6.5# J-55 ABM @ 8579' MD Packers and SSSV (type and measured depth) CAMCO HRP-1-SP @ 8553', CAMCO TRDP-1A-SSA @ 1786' , 8790' 13. stimulation or cement squeeze summary A SAND FRACTURE STIMULATION Intervals treated (measured) 8684'-8716', 8738'-8760', 8778', 8782', 8786' Treatment description including volumes used and final pressure SEE A'F1-ACHED WELL SERVICE REPORT SUMMARY MD Alaska 0il & Gas Cons. Corr~rnission Anchorage 8799 '-8804' ¸14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Rearesentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 411 177 -0- 1099 1905 1606 -0- 1329 16. Status of well classification as; Oil X Gas __ Suspended __ Service Tubing Pressure 114 140 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned '~~v4'~ "'~ ,, ~V"~--------~ Title Sr. Petroleum Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE MORNING REPORT SUMMARY 05/20/93 TO 05/20/93 CPF-3 DS-3K 3K-16 05/20/93 GAUGED TREE WITH 2.8" SWAGE TO 10' WLM, GAUGED TUBING WITH 2.3" SWAGE TO D NIPPLE @ 8533' WLM -- NO OBSTRUCTIONS. (MCINNIS) PUMPED A SAND DATAFRAC/REFRAC WITH DS YF140D. DATAFRAC CONSISTED OF FOUR PUMP-INS WITH 20g/1000 GAL NON XL GW, ONE PUMP-IN WITH 40~/1000 GAL NON XL GW & TWO DATAFRACS WITH XL GW FLUSHED WITH 50 BBLS NON XL GW. STAGE VOLUME RATE FWHTP ISIP FG XS FRIC CLOS P CLOS T EFF. PI gl 150 12-30 7350 1990 .74 640 1870 .5 -- PI g2 25 25 6150 2 TURBINES KEPT ROLLING PI g3 25 25 5950 1900 .73 450 1820 .5 -- PI g4 25 25 6050 1850 .72 600 1820 .5 -- PI g5 50 25 5900 1890 .73 400 1920 .5 -- DF gl 250 23 7630 2020 .75 1320 1850 5.7 31% DF g2 125 23 7800 2000 .75 1500 1850 8.1 48% PUMPED 80 BBLS PAD @ 20 BPM FOLLOWED BY 7.7 MLBS 16/20 CARBOLITE IN 2 PPA STAGE & 146.8 MLBS 12/18 CARBOLITE IN 4 TO 14 PPA STAGES. CUT RATE FROM 20 BPM TO 17 BPM BY THE END OF THE 14 PPA STAGE TO STAY WITHIN MAX WHTP LIMITS. CUT RATE INTENTIONALLY DURING FLUSH FROM 17 BPM TO 1 BPM IN AN ATTEMPT TO ATTAIN TIP SCREEN OUT. FLUSHED JOB TO COMPLETION 3.8 BBLS SHORT OF TOP PERF. EFFECTIVE PAD/SLURRY RATIO WAS 10%. TOT PROPPANT: DESIGN 156.5 MLBS,.IN FORM 153.0 MLBS WITH 14.4 PPA @ PERFS. TOT FLUIDS: WATER 1202 BBLS, DIESEL 60 BBLS (FAA & FLUSH), ADDITIVES 18 BBLS. (HARVEY/CORBELL/ZERNELL/GRIFFIN) ARCO Alaska, inc. Date: July 22, 1988 Transmittal #: 7232 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 K - 1 I Kuparuk Well Pressure Report 5 - 1 6 - 8 8 PBU 3 K- 1 6 Bottom-Hole Pressure Survey 8- 2 7 - 8 7 PBU Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska Chevron Mobil SAPC Unocal STATE OF ALASKA ALAa..A OIL AND GAS CONSERVATION CON .... ~SSION 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 Fl, Amend order [] Perforate iT] Other , . 11. Name of Operator ARCO Alaska, Inc Address PO Box 100360, Anchoraqe, AK 99510-0360 Location of well at surface 1009' FSL, 315' FWL, Sec.35 T13N R9E UM At top of pro~luctive interval ' ' ' 1521' FSL, 1514' FWL, Sec. 1, T12N, R9E, UM At effective dep. th 1196 FSL, 1583' FWL, Sec. 1, T12N, R9E, UM At total depth 1107' FSL, 1597' FWL, Sec. 1, T12N, R9E. UM Present well condition summary Total depth: measured 9038' MD 5. Datum elevation (DF or KB) RKB 69 6. Unit or Property name Kup~ruk River Unit 7. Well number 3K-16 8. Permit number Permit #86-139 9. APl number 50-- 029-21633 10. Pool KuDaruk River Oil Ponl feet feet true vertical6842, TVD feet Effective depth: measured 8920' MD feet truevertica16766, TVD feet Casing Length Size Structural 80' 16" Conductor Surface 4846' 9-5/8" XX XX~(~Xr;ml~C;i~te Production xx x%~Cxe/xx xx 9007' 7" 350 SX Class G & 9007' MD Plugs(measured) None Junk (measured) None Cemented Measured dep~s~[[ ~ ~~al depth 1540¢ Po]eset 115' HD 115' TVD 1340 SX ASZ~ & 4883' HD 3841' TVD 350 SX 6]ass G 6822' TVB & 175 SX ASI Perforation depth: measured 8702', 8706', 8710', 8713', 8741', 8745', 8755' MD 8759', 8778', 8782', 8786', 8790', 8799'-8804' MD true vertical6621, , 6624', 6627', 6628', 6647', 6650', 6657' TVD 6659', 6672', 6675', 6678', 6681', 6686' -6689' TVD Tubing (size, grade and measured depth) 2-7/8", L-80, tbg w/tail @ 8579' Packers and SSSV (type and measured depth) HRP-1-SP pkr (a gR53' ~ TRDP-IA-RRA SSSV @ 1786' 12.Attachments Description summary of proposal I~ Detailed operations program [] Convert well from oil producer to water injector 13. Estimated date for commencing operation October 1, 1987 BOP sketch 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the ~oregoing is true and correct to the best of my knowledge Signed_.-'*' ''/'-ti/4L¢~.,~¢-.¢ ,. _/~/ .>fi'r/½'~,-~;j¢~.c~..~,./'~¢ ..... .¢¢.',¢"¢"'z~" Title Sr. Operations Engineer Date9/16/87 Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by Form 10-403 Rev 12-1-85 Approval No. ¢ "" ~/~/"-~ ]''' Commissioner by order of the commission Date Submit in triplicate ADDENDUM WELL: 10/24/86 2/23/87 2/24/87 3K-16 Rn GR/JB to 8925'. Rn CBL & gyro. Perform data frac: RU WL, RIH to 8650' w/dnhole press monitor. RU Dowell, tst to 8000 psi. Pmp 50 bbls diesel w/9% Musol @ 3 BPM, 4350 psi. Displ w/50 bbls gel diesel @ 5 BPM, 4925 psi. Spot Musol across perfs, shut dn & allow to soak f/30 min. Pmp 100 bbls gel diesel w/no FLA @ 6800 psi, 20 BPM. Shut dn. ISIP = 2874 psi. Press stablizied @ 2086 psi. Step rate inject as follows: Pmp 1.25 bbls gel diesel @ 1.25 BPM, 2740 psi. Pmp 2.5 bbls gel diesel @ .5 BPM, 2825 psi. Pmp 3.75 bbls gel diesel @ .75 BPM, 2855 psi. Pmp 5 bbls gel diesel @ 1BPM, 2904 psi. Pmp 7.5 bbls gel diesel @ 1.5 BPM, 3020 psi. Pmp 10 bbls gel diesel @ 2 BPM, 3154 psi. Pmp 20 bbls gel diesel @ 4 BPM, 3685 psi. Pmp 18 bbls gel diesel @ 6 BPM, 4040 psi. Shut dn. ISIP = 2660 psi, flowback 2 BPM f/3 min. SI well. Press stabilized @ 1763 psi. Pmp 50 bbls gel diesel w/40#/1000 gal Silica flour @ 20 BPM, 6400 psi. Shut dn. ISIP = 2654 psi. Flowback @ 1BPM f/5 min. Press stabilized @ 1885 psi. Pmp 400 bbls gel diesel w/40#/1000 gal Silica flour @ 20 BPM, 5950-5780 psi. Shut dn. ISIP = 2977 psi - after 5 min = 2605 psi - after I0 min = 2350 psi - after 15 min = 2320 psi - after 30 min = 2050 psi. POOH w/WL pressure recorder, RD WL. Load to recover = 818 bbls diesel/gel diesel. Frac Kuparuk "A" sand perfs 8702', 8706', 8710', 8713', 8741', 8745', 8755', 8759', 8778', 8782', 8786', 8790' & 8799' - 8804' in 11 stages per 1/19/87 procedure as follows: Stage 1: 50 bbls gel diesel @ 20 BPM, 5740-5550 psi Stage 2: 47 bbls gel diesel 1 ppg 100 mesh @ 20 BPM, 5550-5470 psi Stage 3: 360 bbls gel diesel @ 20 BPM, 5470-5425 psi Stage 4: 33 bbls gel diesel @ 2 ppg 20/40 mesh @ 20 BPM, 5425-5406 psi Stage 5: 34 bbls gel diesel @ 3 ppg 20/40 mesh @ 20 BPM, 5406-5500 psi Stage 6: 35 bbls gel diesel w/4 ppg 20/40 mesh @ 20 BPM, 5500-5490 psi Stage 7: 37 bbls gel diesel w/5 ppg 20/40 mesh @ 20 BPM, 5490-5440 psi ADDENDUM WELL: 3K-16 (cont'd) 2/24/87 Stage 8: 38 bbls gel diesel w/6 ppg 20/40 mesh @ 20 BPM, 5440-5516 psi Stage 9: 20 bbls gel diesel w/7 ppg 20/40 mesh @ 20 BPM, 5516-5486 psi Stage 10:25 bbls gel diesel w/8 ppg 20/40 mesh @ 20 BPM, 5486-5547 psi Stage 11:52 bbls gel diesel @ 20 BPM, 5547-5450 psi Fluid to Recover: Sand in Csg: Sand in Zone: Average Pressure: 668 bbls 1427# 1900# 100 mesh & 34,449# 20/40 mesh 5500 psi RU WL, press tst lubr to 2500 psi. RIH w/CCL/Temp TI, tag @ 8730' (hole sticky @ 8730'). Rn CCL/Temp log f/8720'-8200', POOH, RD WL. Turn well over to Production. ~~ate~ STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-1 39 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21633 4. Location of well at surface 9. Unit or Lease Name 1009' FSL, 315' FWL, Sec.35, T13N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1521' FSL, 1514' FWL, Sec. 1, T12N, R9E, UM 3K-16 At Total Depth 11. Field and Pool 1107' FSL, 1597' FWL, Sec. 1, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 69' ADL 25629 ALK 2562 12. Date Spudded 13. Date T.D. Reached 14. Date comp., susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/14/86 08/19/86 02/24/87* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 9038'MD 6842'TVD 8920'MD 8766'TVD YES ~.. NO []I 1786 feet MDI 1700' (Approx) 22. TVpe Electric or Other Logs Run DLL/GR/SP/SFL, FDC/CNL, Cal, CBL/Gyro, CCL/Temp. Log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE! WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 20" 1540# Poleset 9-5/8" 36.0# J-55 Surf 4883' 12-1/4" 1340 sx AS Ill & 350 s; Class C 7" 26.0# J-55 Surf 9007' 8-1/2" 350 sx Class G & 175 s~ AS I ._ 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) 2-7/8" 8579' 8702'MD 6620'TVD 8759 'MD 6659'TVD 8706'MD 6623'TVD 8778'MD 6672'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 8710'MD 6626'TVD 8782'MD 6675'TVD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8713'MD 6628'TVD 8786'MD 6677'TVD See attached Addem um. dated 03/2b,/R7_ for Fra~_t-..r~ 8741 'MD 6647'TVD 8790'MD 6680'TVD 8745 'MD 6650'TVD 8799'-8804'MD 6686'-6690'TVD 8755'MD 6656'TVD Perforated w/1 spf_, 0° phasing 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I ' Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None *NOTE: Drilled RR 08/20/86. Tubing ran 12/08/86. Perforated well 12/21/86. .- Form 10-407 WC2:33:DANI Submit in duplicate , ,/ .,~ ~¢~ Rev. 7-1-80 CONTINUED ON REVERSE SIDE -J : 30. 29. ~;. ' GEOLOGIC MARKERS FORMATION TESTS I · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8459' 6447' N/A Base Kupaurk C 8511' 6485' Top Kuparuk A 8658' 6590' Base Kuparuk A 8860' 6727' 31. LIST OF ATTACHMENTS Addendum, (dated 03/24/87). 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'zZ, (,,~')~'~.,_- . ~LJ,,L~/~,..., Title Associate 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-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 November 18, 1986 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-60081 Well: 3K-16 Field: Kuparuk Alaska Survey Date: October 25, 1986 Mr. Ruedrich: ~ Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures RE£EIVED JAN 2 1987 Alaska Oil & Gas Cons, Commission Anchorage NL Sperry.$un/NL Industries, Inc. P.O. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 A N C I"-I 'il::;: A 7-i Fi' A I_ A S K A ARC:O AL~.i.:,k.A" '"".', I HI.Z' ' -" ............... "" ......... ' ................. .......... "'-""' ................. . .......... .._ ............. ___,? DATE OF" .................................. ..=,~.,-.i il-:tlr, vl[--it[::.'--'"l f3CTOBE:.R ............................... ,-'":'",, , 1 q;";:~/, ...... :31<-.- 1 ,'.'=, COMPIJ'I"AT]J ON F.~A"FE BOSS r3YRO'.BCOF' I C SIJRVEY K IJ F'A R IJ K : :: ClI'": T I') B E R ,..: ,..=.:, 1 ':' ':' .... '"' ..,',-,6 JOB NUHBER AI<-.BO-6()()L=)i v~l....¢.4.:,l.'..A KEI_LY BI...I(.::;HIN(:; EL..EV, : ..../:,'i;).0,:::~ l::"r'. 0 F,' Iii!': R A T 0 R...,. S E: I.... L.. E R S VI.'i.:.I::~T I CAL.. SI:CT ]: iN CAL. C.. I...A]::'[.~D'""AiUTqxI(:; c L..OS... RE' ..... ' ..... .......... ====================== :¢:x:! ;:::'""'*' ........................ '"'' .................................................................................................................................... ' .............................................................................. ~----"--"~*":"' ........... TRUE: 8t:I;~:~S:E~ COURSE C 0 t.[F:~ S F 0 0 C:~- L E 0 TOT Al_, " ....' .... I ..... ' ' .... ' -I MEA'.'3UF:;~Ii=; D VIERT I :::::Al... VERTi e'AL I NCI_. I NAT I ON D I RECTI OI',1 SEVER I TV REU I AN .,UL. AR I._.LJUI.~L INA T'E:'S VERT I CAf OEF:'TH D[-.'i:PTH ][::~FF:'T'H ..... i]'[i15:5 ......... Jq]:iq 'i:.:~iii'iSii!il::~[ii:}~i:i.=J; ........ i5'[~i!;/!ii'(5'i5 ....... ]-q',::-[?:i=i:FZ,'_?..ir=/i:i:'r=l.] ...... ............ [i-~A-~.:.-iT:i:'7-kiiiii:'ii-':ii"l=: ..................... :iiiit-i: ,":"i' r, '~l..i 1 ()() 1 1 00 1. 2 ("~ () 1 :B 0 0 140 () 1 ':-" ._[ 1 e, O 0 1 7 C:, () "'1 2000 2100 :2200 ::it :B O () :2400 2500 :27 ('~ 0 2 ',3 (.') 0 2'i:'O() 6'? 9. '75) 799..1. 5 897 "::;":' '99 4.., ':.;'5 .1. ()'i;;' () ,, 70 1 I ',3 q.. ',!ii','7 12:7/_:,. 8'.7: 1 =',/=,6. 4-2 14 5 :B. 5 c":, r'" ,"', '" .1. ::,.:..7'. ':iCi 1 61 'P. 6 4. 1. 6 9:3. '2' 1 ':a")... 9o. ,.., :1 '7 '2 :'::() 96, I '=' :3:3o' Oq ...... i:i !3"4. ........ 4 :'::O '::;'=' 1 5 ::ii', O. 'P 1 1 1:2 6:3(), 79 ..... 4-' ..... S :':i:("~ ...... :1.':'.. Ii:i: ::: . .::.'"",:, ',::',C)_. . .76 :iii; 4.1. ,, '.:.':,"il;' S "::"::/ () E:. :}?,. '": .... 1 :[ ()() :ii!; ......... ........ :, 7 C). ':::",iii',. ':::'"':' :~; --, .-, ,.::...) ..:.:: ..... ,t 'E' .....':':43 ........ i'-~:4'L"~.~4 'S ..... //. 4:;... '..'-.'; :3:t .... "-,':;' [.-i: 3. o4 182.79 'S 99 '76 :=; :2::=:. 10 b" ...,':'. 10 22:4 . 17 S 1 :.3 A .0.. 5 :34 .?"; S :7.: 0 ,, 69 [=.': :::. 4,'.':, 2 (':, 9. '7:3 '.iii; .1 .'.'54 ,, :3 :!ii: :'::~ ...../-, 1/-, :.:i; 27 . 1 ':','.. E 2 , ,:;...,v :'::: ...... :2 (") . ':"'. O. :'_=.;1 :i.]: 2 .2 :;..it :39 !15 ::i 25. :i:30 E '.';:, 95 ' '74, '? c) S 20'!;;'. 4 7 1846. :36 1777. :2:,"_-, 45 28 S 27. 10 El 3.01 495.72 S :269. :::0 i915.41 184/=,.41 4.7 10 S 25.80 E 1.94 560.4:3 S 30]...5() '1'":;8':3, :3:-_:: ....... '.Ii~'P ~'2i~":3::.'-~- ....... 47 15 ~..--.; 24.69 E (:). 81 /-,26. ',::5 '.:; .... !:','::-?,~!i i:':!i::,:'') (). :'='.': 4 /::, 9 4. 1 1S :::':,'.5, ::ii:. :3:1. · i-.)~' 91 ':76.::!:. 47:i:_'; :..:.:'.:.;'::ii:. :2,::f 1.00 8:31.29 S 4-2::2,. 6,0 1 · 12 900. :=:8 '.=; 45 !5, :5.:8 .:,, 14 967, 84 c; 4:3 :=:. ':;'~ ." .......................................... SI:::'E]::;tI::;:Y'"-':i.~;LII'"..I Wl..Z.;I....I .... :iii;LIl:::.:Vlii!:'flNC:i I:":OMF'AIqY r:'A':i.i.:; ::" ARF:O-ALAF;I<f~, ]:NIi~i" ......................................................................................................................................................................................................................................... '"~ATE OF F';LIRVE"Y OCTOBEF:;t :25., .... ' ........ ' i ....... -' · .:,K- 1. 6 L. UMF L ]' A r I i']N DATE Bo~.:, GVROSC:OP l: C: '-' "- I....I.. I.- ARIJl,., OCTOBER.,..'":":',,., 1 '-:/,:, 6'"" dOB NI_ MBER AI<'-BO-6()08. .1 AL..AE;I<A I<E:I..I....Y 1.31.. I .:.i H ]: lq Fii lii..:'l...EV.. : ..../.,':;-'.,(>~'~ I:""1 ,, 0 F:' E R A T 0 R- S I!i..':. L I.... [.'.:.':. R :iii: .......................... VEI::;t"I" I CA/_ E!;E!:C"f' ]: (]1'..I C AL.. :7111....~TED AI_.OI',I(3 CI....O'.i.:.';I.JF:;:Ii-E 'T' R i_i E '"" ME A.:,I.. F",E L~ VERT I r':Al_ VERT I C:AL ][::l E I::' 'T' I'-'!:(::t [ii: F::' 'T' I-'.1 D E F' T' H C: Cl IJ R :"':'; E C: 0 LI R S E D 0 G -l... E G T 0 T A L. I Nli:[... I NAT I ON D I F?ECT I ON .:,E. VI::-R I ]'Y RECTANC. ilJLAF~ I..]:OEIF;:D INA] E.::., VEI::;~' 't '' :1: ~:::' ~::~',t D [ii: G M I Iq D I!i:: G R E-i: [!".:' !:'!; I]E ':ii / .1. ()0 I',10 R "1" !--'1 ../S 0 IJ T H E A '.~i; "I"/' W E (ii; T tiii; Ei' ('.. '1 ]' ( I I',.i E Ii:i: E E E Ii:i: Ii:: I.".".'. E E. E E I:i: E' i'~!: 4. 400 4.500 4-'7 C-:, 0 4 :?, 0 C.) 5000 f--] "::' c) 5:2: () 5 40 () .............. .57Ac) ..... !:; :::l (') 5 '.::? 0 () ::::4:}: 1.8o 3.'2:6,2. E:/:, ."',l~." .'", · .:: ..... (.).:,. ::::':.2 :?': 4:34 ''"' "" :.3 5 7 5.2--'::3 3 5 0 6.2 8 ::ii: 6 4 (5. :/4 :3 5'7 '7 ,, .1. 4 ::ii: 7 J./:,. C)9 3 6 4. '7 ,. O'il;' :3'7 :!3 4. :3'7 3'7.1. 5.8 · > 1.~'~ /-,C) E 0.10 '.::; 1 .=, 6,9 E I O. '-" '.:;16. 19 E c).:::8 4272, 6'~~ .......... 4 ~'6~:-.-i5i.5 ................ ~-5 ..... Ei'2.T., ................ ~:.'i-'i-z~"~' 'Ei 5'- 'E 4.:,4 ....'71 4276 71 42 .:, .... 4 15. =" E .J 441'-?....'2:4 4:350 . :_::4 42 o'-'~._, '.:; 1.~. 69.. E 4.4'?::-,,. (2? 4h!?T::'i::i7 ........ 4::;i,. 24 .......:iii'"--T~.'~': :?,(::i' Zl 5 ~, 7.04 zt 4'.'--';' 8.04 42 11 '.~i; ]. 6. 1 ('-~ Ii!i: O. 27 : Q~ 41 ;" d'; 14 C). 19 C). :_::0 2424.6:5: E; 106, C). :.'-.': 2: 2495.41 S 108C).64 ~._,6e,. 14 S .1. 100. 35 5:'(':,:2: 6.4'il) :E; 11:21..'!:.'i;:" 5:' 7 C, 5. :5: ]. E:; ]. :i 4 2 ,, ():ii:: :2771. ::30 S 1:1. (':., O. :36 ................. 2:8:2:7.26 S 1177.5:':: 2902.57 S 11 'i:';5.2'7 2967·74 E; 121:3.47 .......... :5:C) ::ii: :2. '7 & S 1 ::ii::':: .1. ,, :!.:.': t :'.30'F' 7.4 '7:5; :1. 25 (). :3 C, A N (.'.: I-"10 R A '3 E A L. A :::i; I":; A :3 K-- 16 " .....' I I"" '" R F',-',' .....' '" ""l" - ' '-' I '" "' UUMF_ IAFION [)ATE ~: _, o .:, t..~ Y R u.: ~, u F I C ;-., L R V E t K IJ F'~ i~ I..I K 0 C: '1' 0 B IF.: R ":' ':~ 19 ::~/-, J 0 B N U Pi B E R /4 K- B 0- 6 ()0 81 _ ................................ :t".:.S:L.? ........... '___:-_':_ ......................................... ........... _,._ AL.A:F.i;KA KEI....I....Y BLI'.:".i;H I NI-..i EI....IEV,, = 4:,'!? ,, 0,.~ 1.: t' ,, 0 I:::' E I:R A T 0 R - '.!':; E L I.... I!!.': R :i:'; VIEF;:'T' I C:AI... '.BEC'T' I ()N CALF':I. L ATED AL. OIqF} Ci....OSl...II-:,:I::: ::': ;: ::::: : TRI._IEi: ~ ':~ '"-' ' . ........ <;,UB ~'~,,EA F':nl IR.':;E COLIRSE DOG-.L..EC~ TOTAL MEASLIREI] VERT I CAI_ VERT I C~t.. I NCL I N~"I' f ON D I REC:T :[ ON E;E:UER I TY REC:TANCdJL. AF~ C OORD T IxlA ]'EE; VE:.F:~'T' :1: CAi.. [:,E:F'TH 'c~r..i:P-r'H "]:.Ti.'~'P'Wf.'i .................... i:-i"iiii:i! Fi :iii:,i ............. ~'::ii~i: :'"ii::i[?~i::~i; ....... ii!'ili!iii!i:;'!l' ti6 ............ [G!ili??:h:iTi!!i'~i~:.~ ....... ~il;~i-.:.:i'":i:Ti~iiiii'~: i~: t:~ :': 'r' '~ ,'.5 4. 0 ('-~ 6 F:!', () 0 6 6 0 0 6700 6800 6?CK) '7 C~ 0 0 '7:1. ()0 7 2 () 7:3 0 :'~ '7 4 0 0 7500 '7 ./::, ('-) 0 7 7 ('~ () '7'F, O0 80c) 0 810 0 ............ E 200 :::: :3 c)0 8 ,-I-0 () :.~:'50'b 87 c) C) :--_', :?i', 00 :3'.:::' 0 () '::'.._, 1'=..., . .5(-)_ _ E c...., 15.....'::':;... E ,:")_ . .... :5; 15..5C) Eli 0.15 S 15.50 E 0.00 4467.20 S 164,:],.7',F: E L=; 15.50 E 0.00 4533.11 '._:; 165'F.'.06 E ..... 654'.-.?. (]:` 1 6480.01 44 :3:3 S 12.8'F.~ E 1.. 57 4862.52 S 1744.2 /-,/-. 1 ':.:' 2 !=:; '-'"- - . . 7"-"; ""' 4 8 Ei' ~.._,._,C) ""= · _ . ........ · .' ..., 46 11 S 11 :::9 E 1 80 49':32 02.-': S ] ..... .-:,. ,,:., :'., :s:: 7,. ::~:!!s ;'_:",,'-:]. ~!~.:, ::::' Ls 4:.:_': 5 i~Y-"'~['~: -:i 'i:?' ii!-- t. '.-.-,o .... ~!-:!;'i.-.-;-,~;i?:'~-i:-F':): ........... ]77':;'4. ?'.i;, ,:'{:,75:;i: ,, 0,':::, 66:34 ,, 0,(:, ,':I.'F~ :::i',6 r:3 :3. :{;{:'!? IE 2:. '? :l. F]()'77. '7:1. '..:.'i; J. '7 :~i: :.:.';', ,, 55 . 'l"f:~l IE' :=,UB~EA E: O U F:;,' ::':; E:: F::i.':ILIR::!;E I:)OO-"I_.EEi 'T U I"AI. P'IEASI...II:'~IED VE:I:";:"I" ]: E:C,L. VERT I C:AL ]: I',.It'::i... I NAT I I:)N D :[ RE:E: T I ON .::,EVER I TY REL. I ANUL I_AR E:OC. iIRD l IxlATE'.E; Vii:l:::: 'T' 'i: E'i'.'.'~t.. ................................................. · ........ "7:.,.7 ........ '? ...................... :";_-_'..: ....... :'.._! I'-~E:l:z"J"k'l l::~li:::l:::' T H DE F:' TI-J IJJIE (':; PI :1: Iq Ij:lEl:::i F:;~l::::l:.:."'.ii:; I:)1:.'::: ':i~ / 1 ('_')(7.) IxlOl::;~"l" H / '.J:i;l:':~l...l'T' H ~::: ¢.'.~ :.'::;'T'/' k~ E :~:;'T' :~:;ti::' ~7' "t' 'J' 15 · ~....... ,~ ,J ....... ARC:O AL..A::,I,..A, I NC:, DATE OF 'SLIRVEY OC:"FOBEIR '"=', ].9:::::A 3K- 16 6:OMF'I...ITAT I lIN [lATE KI...IF'~RUK Or]Tr]BER 2~q, 19F~A ,JOB NUMBER .................................................... . ............................................................. ~:,~ ...... :L .... ::. ............. :..~ ......... ~...~.,..~_~ ............................................. , .~.~_- - _ ....... ALASKA KIEL..I....Y BLISHING EL..EV., : ....65:'. ,::.,('~ I::'~. ...... (] F, E R A T () R ..--S E I.... I.... E R . ..... INTE~Ri~!L~'g~ED VAI....I...IES F'I'"IR EVEN iOC)C). FLEET CIF ME, A.:d.,REr:~, DEF'I]'q "I"RUE M E A S I..Ij::;~ E [) V Ei:l:.-( "1" :[ (_-: A I .... V E R T I f_': Al .... ii:) E F::' '1' I"'1 .D E I:':' ]" I"'1 D E i:::' T H 0 (), ()0 1 () 0 0 9 94.7 5 2 ()0 0 :I. 8 4 6. ::--::/..:, :':: .............. c") (") (', '2 f::i .1. '7. "", ,::.'-" 4. 0 C:, (:;, :3:2 :l. ::ii', ,, 2',;ii', 5 ()() 0 :ii '!)20. :iii: .1. 6 00 0 4 (!:. 41. :32 70 0 () 5:38 :':~ ,, 6 6 8 ()0 () 610'F'. 76 9 () () () 6',iii: .1. '7. 9 0:3 :::: 6:34 2 ,, 4 :!ii', ..... 7 .... 5/-,, 95 :i:.'; 27 ()..., Iii!; .'.5 ;-'.% .... : ...... .'1. 7 7 7 ,, :3.6 4 '? 5.7:2: :::5.; 2 6 '.:::'. 3,r':~ Ii-': 15:3.6 4 1. 4:5. :7-.: 9 244:-:.:.':;; :?'!? !i.'!i. ~,~;i!i~i!!!; i" :ii:; "":;~ · .,..:' 1 ,, 6:1. tE 4 :iii', 2 , ':;i: :.".-.': :'3, .2::-':: ,, .1. :iii: .1. 9 ,, .1. ::ii: :iii; :!ii','77 ,, '7 ('.:, E '7:56. '72 :3 () 4 ,, 4:7ii: 2"I. 9 F:; ,, 4 .'1. :i!i;1 (') :i () ,, ,':, 4 liii: :1. () 7'ii:' ,, 19 :;lit 9 2 ,, Zl :iii', :3 t (':i.1. ,'76 t::; 1268.98 E .1. :':;I!-'::.',, ~:::.:.::i 279 ,, 4.'!? 3804 5:5 S .t z ~'",-, ..... -"',, ...... , ... . .I...::,,::, (') J E :I, 616. :}) 4 .~:...::, 7 44 ./:,'7, "::'("~ '..5 1640, '78 E 'l 8 9 0, '24. :2'7:3.90 5 .1. 5 2, ':;? F, :5 18 ()(). :3:}.': I!!i: 2:1. 8 2, :[ 4 '::' 5 5 ............ : ...... .... .1. :F: 71., :iii; 1 ',iii: ('),-1. :i?, 1 I:.'.-~. 2 .t '::~ 5 =''''' .1. :3 "::', '7 'r'HE" C:ALC:L.ILA'r'iC~N F'ROCE_"'Ef'URE?.; AR[.]; BA:3E'D" t3N' THE I.)L:;E OF: TFIREE I]IMEN::i;ICfNAI.]]' R~'D]:'I')F; C)F:: CLIRVA'I"LIF;:E: M[!!:"I"t--IO.F~,, AF:,'CO AL..AF~I<A ~ 3K .... 16 KLIPAF;~I..IK ALASKA M E A :iii; U F,,' E.] D I) E P '1" I..] '769 :370 '? '73 1 ()'7'7 .1. 18:2 1 ,.'1-o 2 :l 6:3 '7 ...... 18'!P 2 I iq C. :.":;I:::'[!!:RF:,'Y'"'SIJN WEI...I .... :.:.';I...tF:(VEYII',I(':i C:C!MF:'ANY l:::'Al:iil::i ,:,LIR V E.'Y CI C'T' 0 B .E': R '":":; ELATE: OF '" -' "' ]..':/',::',/"', COMF::'L.ITAT I ON I.'.IAT'E OC'I'C~BEIR "'"'" .,::.,=,, '1'i;'86 JOB I",.IIJMBER AK-BCI-6()C~:'31 ................... I<E'L.L.Y BUSHII",I[]i E[...EV, ..... ,'i,'i;:',, ,:':,0 F::'"!',, 0 F:' E R A "1' 3 R - !:i; E I... I.... IF.: R S ·.. 'T'R IJ E =,UB-oE A "l' Cl T {-..':i L. V I!!!: F:;.: 'I" :[ CAI .... VFR"r I C:AI .... F-,,[: ... I j..~lql.':!il..ll_ AR C f_] (':l F;.: ][.:l I I',.hq"l'liE'.E; MI]----.'I-V][i VE:'RT I r..::AI .... D E F::' 'l" I..-I [) E F:'-I" H Iq i~.)IR ]" I--I/:iii; 0 I...I 'l" I.--I [ii: A S 'T' / W E :!ii; 'T' ][':l I I:::' f::' .F.'." R I.=E I,,I C E C :::1R I::( [![ i:::: T I 0 ~"..I , . A R C fi A I.... A S K A: :'%:i .... 1 6 KL.~F'AF;;UK ,~-~ --.., e- AI.~.~-.~.-, I--.. ~.~ M E.". A '.!ii: I_1 I::;,' Ii.::: lO BEi:PTH :':I (.) '7 "::' .."! _1 ,~:~.....I :']/-,/- '7; :'::8C) 4 4076 4. 21 :.7.: 4:3 !51 44.'il;' 1 46:32' ' E;F'E:I::~I::;;'~ ...... E;I...IN b,lEI,...I .... SI...IF~VE'V I NCi C:OMF:'ANV I:':'AC'[.i}!' A hi C I'-I 0 I-'( A G E A I.... A E; I< A ...... ~ v ~. :1. '? :5: e, C:OMPLITA'I'[ON DATE r,":TnBEFi .......... ~;c,~ ~98~ .... lOB NUMBER ~K-BO-60C)81 I<EI....LV BUSH ]: I~C]i IE:I....EV. ::::: E,'~;>.O() ............. 0 P E R A '1" 0 R- E; E I.... L E R S ............. TRUE SUB-~SEA I::('T' I Il': A t .... V E"'R'I' I C Al.. E f::' T F'I D E I:::' '1" H ]"OT~I .... Rliii: f:: "l" (.'./ N (31...l l.... AR Clil)([If:~[t I NAT'ES MIl----- T'?I'I Vl3.':R"r' I CAL N 0 R 'T' H ./E; (::1 I...I "Il' I..-I I:i:: A E: 'l" / W E: 5 'T' D I I:::' F:' E: I::;: E N C E C 0 R R E: i:.".: T' I 0 N :1. ':.~/-,':~. _ ... C)O ....... 19(')(') .00.. ,'.':, 1'"'.::. 7'7 :ii!; ::ii:;:'/'_-,.. . :%-_-: E 209.89 46.6(') . . "" -'"" '-':= 4 8:3 6 20 r'-, ............... 9. C)(] '? C)(")(") . O. C) '712 . .... ,.,,~ c, '.!ii; :3'71 !5 '7 E .,: 5,:: .... :._, . .. . 'd 1 ;:,. 4 ..... :: ...... E :.::a.)'.-;. :3,'_, ...... 5 :t.",,"l"Jl ..... 2 '26 9 ,, ()0 '7-' 9 ('),:'). C)C) 9 '::, 9 ,"-.'", . 5 :!i P,/.. ........................... - :i.-'.: 4 E, !:.!.';, 9 4 E :36:3 2 2 ........ :2 :q /:, ,il;, (")(")';::' :'i:: (") (") (")(')1 (")9 (') ',:::(') '...E; .... ' t 7. 1 7 E 41 2 .=; (') 4'::; '":":::' 2469 (')(:') ' '::' 4 (') (') (")(') ....... i'1'1'-'"'"~' '"" .~'" .... ' ............... · ::,. x ..:, .::: ..... e, 7. F.V:)E 4 ........................... 5 9 ,, :32 4.6.82 .,~: ..... 6, :,~. ()0 ........... 2F ('fi). O0 ! 21 '":'..... ()L:::. E; 616 .69 ........ rc Fsc~/. ./-,.. 1 4.7 ~ ~.....'.~'c:' · 26/-,'9 ,, o ............... () '?/., ~"~ () o o .l :31 ('~ .83 '.i:'; e:,' e,' ..., '= . 4 '? E ._,=._l~._,,-". -'~, o 48 .77 ............· .::,-76 o ()0 '" 27 O0. ()0 :l 412" :21 8 7' 1 !5 i, ':1. 9 E: ~i:i'i:5,'..~i ii !} ![ ............................. 50. 2',::: ~'-'-, 9 () ('~'2 ::.:: ('~ c~ ()c~ 1 '.-'"i :t :3..'"'-',.,"" Ei; '7/...::, :l :3 Ii!il ' '''~ · ,, 1:7:!: 49 92 '29/:, 9 (') (") 9':? (')(') (") (") J. ,E, 0 7 f':', 9:5; :::', (") :1. (")(")[ii: /-, 9 :::~ '""':::' 4 ::ii: ,, 7 J. "::'l/-'r:~ ()0 :L-':i(')O.C)C) 1780 47 ::!; 8/,4 :::9 E 770 72 ":'q :37 · ,2, I ,.£, ,.-. E: 94 5:3 E 807 12 :2:6,. 41 :2::526, 9. (')0 :3200. (:)(") 1 ,-, r.,-,. 21.z, . . 5::!::; ~:, 9.0 0 ::ii', 5 C)0.0 0 214 i. 9 E '.:3 '.:):30. '(2).5 E 9 2 2. 18 ' 5:9.74 :::.:,'_-.;;:;'?'. oo _~_-':,'_:,00, 06 'J_'2::~'7] 7b'" i:_-4 ......... ~'-6i5[~:'. (:.)'? E 96:_~. 45 4 Z ."2',':.' ~ ...................................................................................... ......... . 4776 50'7 I 5218 I;;;' .'% 122 .... .,,.I ..;)....I '7 1::7 ," I:::' ..,ZI. ::; .j 56, :3 .l .:: / .:, '7 5 9 0 2: ,?i. 0 :.i.!: 7 61 7' 1 6:3 0 4 ..... 6 4:3 8 ,5.~'7.1. ,':_.. '7' () 5 /4. ,-'" ! '- .:, c:, 4 6 9 '7 i;> 71 ;I 7 ............. '7'~75 ::'~ i~ F'liii;RF;:Y""".iii;I. IN WELl .... :~,I...IF;,'VEY I NG COMF:'AIqY I:::'AI.: i.": :'3 ",./' i"'- ,.' ' DATE OF oURVE. Y OC]"OBER '-'=' 1<~:::,''<'. C:O~F'I_IT~T I ON I]~TE O C: T O BE R ":'° 1 c ,-, · ..... ,-,, ~ ........=4=,6 dOB NLI~BER ~K---~'6OOol KELI_Y BUSHING EI....EV, = 4:,':? , ':} () I':'T'., O F' E R A "1' 0 R- S E I.... I.... E R S ............................... ....I N1 EB=~.B~i~ED~ ...... :~:?'"""=:~'~?'::"?"'~¢}' ....... : ........................ V~LI_IEc,=;::: ........ F l_l~':"::'"~ ........ EVEN: ....... = ............ Itt);"[5"': ........ F EET:::~": .................. UF::"":-T:-i,:,I_ B-oE~<::~:7 .......... BEEE:~FH TRLIE. . SLIB:,~SE:~ ....................................... :[.!~l.]" VE:I:~<"I::'i' CAI .... VER]' I C:AI .... RIEC"f'AN(}I...II_hI::~ COORI] I NAT'IES MD-"I"V E{ VEl:;:'l" I ('3~l .... .... DiE I:::' '1" H D E P l" FI N 0 R T I--I /E; O I...I T H E A E: 'T'/W E S 'T' D I I:::' F E R E N C E C O R R E C T I O N .......... :37 E, 9. :3,.::;' .r::,,p ,, zl O 6'il;'. ()() 4.1 <'.':,'.?, (.'." () 4 ";i: ,:'.::, '.:.':", ()0 /~::i?,69, O0 4. 4 6'.-:;', O0 4. 5 6 9.0 0 /.I. ,5 6'.:;' ~ (5 0 4 '7 ,'.'i:, '.-7, ,, (),:"~ :36.5:3 :5': 7. :39 :.':': 7.4 :.3 3 7.68 A N C H Et I::~ A G E:'. A I.... A Ei: I'::] I:';.~ ARC:O ALAE;KA, Z NC, DATE OF:' oLIRVEY EfC:TCIBEF~ """::'., :3K'- 1 6 C:OPIF'LITAT I ON I-::.'11PARI IK CIIE:TI]'IEIF.'_"I:;~ 2El: .t 9,~3/:, , ,lOB NI II"IBE'R ~I-::'-BCI-.6C~C~F: 1 .... Z %' ............................................................................................................................... "'..~Z"_ "'. .......... '.LC ....................................................... ': .....' ~ ° L~ AI....AE;I<A I'::]E:'LL.Y BI...I(3HING EL.E]V. :::.'./.-.,'i;). () () F:"l' ., .......... 0 F:"E R A "1" 0 ............. I N'¥EIRR~TED VAL. UE$ F:OR EVEN 10(3 FEE'T OF' :BI. lB-SEA DEPTH TRLIE hi E A '.i'-'; I_1R E D V I""!; I't "F ]; C A I... g E R '1' ;[ C A I... D E I:::' 'T' H D I.E F' ]"H /.:1E F::"I" H 7:3'?::::: '7':=i"::' 1 7 6 6'P '7' ', 3 0 '7 '7 9 4 4 :iii', 0 8 ]. E: 2 :l 7 :3:35:3 :.:J: _/.':, 2 :~i: :"-'i:'? 72 "I"HE C:ALI.E:I...IL..AT I ON F::'RC'fCF.'::EtLIF~:EL:.; USE A L.. I NEAR I NTEF;;F'f")L. AT i AI',i BETWEEN ]'HE I',lli.:.EAF:;:liJi:'.3"l" 2C)"' i.:-:' :30"1" 1"1][:) ( F'l::;:Oi'-'l F;tAI')I LI'.:-'; Ell:: C:I..IF;:VA]"IJF:~E/) F'f:'l I N'T".3 ;:':.~ N C H OI:R ~'.':'~"il:::' '" '" ...... (,,~RC:O (.~I._ASK(..~., INC DATE OF .:,L!RVEY OC'I"C~BEFt :"::'"':.'~ ::::[::: .... 1/_', C O MI'~ U T A T I ON DA T E -"! ' ' .... .-.~o/::, ,JOB NUMBER Al _BCI f ..... IF ARUk OC:T(.'~BEF~ ';!:E~, 1 '-'-' (.~I_..{-/G;I-:::A KELLY BUE;H:[NC~ I!.::I....E:~J. :;: ,":,'il),, ,:.').'~ t:::T. ............ ................................. O F::' [ii' Fi: (~ 'T' L-.~ F;: -" :.'.-'.'; E: L.. I... [ii: R S ............................. TRUE b'l liE: ¢':t '.iF; I...I J::i [![ ][.'.1 \/Iii: F:;; ']" :[ I:: (2i L D E: F:' '1" I-'1 JD Iii: I:':' T H SLIB-~SEA TOTAL V E:: IR 'T ]; (';: A I .... F:;,: li:i C 'T' rr::~ Ixl 1'.3 I..,I L [--'~ I::i: I.':; F~ '.".~ I::;: D ]; BI ~.:'~ 'T' I.: t:ii; DET. F"I'T-I NOI::;tTH/!i:.;OI...ITH Ii:: (~ :i.:.'; T / [4 E: E;'T' ................. ~ ............ . ............ ., ,., ................ , ......................................... ., .,,, .~,,, ,1,~ .......... .~; .......................... ,~; ............................................... ...... ~ ........ . · ,:,k-16 STRATI GRAPH I C SUMMARY "' ! '"1 [IERI VED I_lt~;IN(} DI L DEPTHS AND SPERRY ,:,L N .:,JRVE. Y DATA .............................................. .... C 00 R D I Itl A 'T' F~' ............................... MARKIE:F:~ ................................ "ME~sui::;:i~D DE:F:' I"1'"1 ................................... "I"~D ............................... "I"I"]ICKNESt3 WI TI'-I REF',, TO WF~'L.t...i.' " :'-::~'::;":'" B~::.B Bk.B ::;I_.IB--~::;E.A VERT I CAL ( UR I ~5 .[ N- 10C)':~F ~;L. ] 5F.: WI.. ) · :, E L. '-' ~' 3 N R" ''' © F::' · .::,..., T ~ .......... '7'?0 ,, 1 ) FF;tF~M I....Ilxtr:i:_'AF;: I!.?. X'I"RAF'F~I.. AT I ON BErl..CW I)[-~E:F'EST S'TATI ]DRTA CALCULATZON AI',ID INTERF'OLATIC~N BY RADILI$ OF CLIRVATORE---- C 0 I'1F:' I...I T A T I i.-j N L] A 'r'E OCTOBE:R '::':::, 1'786 ][]A'I"E: I-:iF:' SURVEY r_-.~C'I"(.'.~BER ',.?5:, :l. '.:.';' :_:.': d:, , . I<ELLY BUSHING EI.._EV. = 6':.-,'.00 F'T. I -iOOO. '30 000.00 JAN 2 3 1987 Alaska Oil & Gas Cons. Gommission Anchorage qK-eC-6CCSi 5aCC.~3C 4SCC. CC ~Ooo. oo -!, 8 ~5CG. CC / i 5CO. C :::lqC:" ::tl qs:';q ' hZ 8CTOBE8 2ff., i985 'N RECEIVEI} JAN 2 Abska Oil & Gas Coas. Commission 'X,,,. Anchorage .......... t i i 1 .... STATE OF ALASKA ALASK~ ,. AND GAS CONSERVATION COMMI, JN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutOown ~ Stimulate ~ Plugging ~- Perforate -- Pull tubing - Alter Casing ~ Other [~ CCHPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 69' Feet 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1009' FSL, 315' FWL, Sec.35, T13N, R9E, At top of productive interval 1521' FSL, 1514' FWL, Sec. 1, T12N, R9E, LH At effective depth 1196' FSL, 1583' FWL, Sec. 1, T12N, R9E, LH At total depth 1107' FSL, 1597~ FWL, Sec. 1, T12N, R9E, 6. Unit or Property name Kuparuk River Unit 7. Well number 3K-16 8. Approval number 379 9. APl number 50--. 029-21633 10. Pool Kuparuk River Oi 1 Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 80' 4846' 9007' Production 9038'MD 6842'TVD 8920'MD 6766 'TVD feet Plugs (measured) feet feet Junk (measured) feet None Size Cemented Measured depth 16" 1540~ Poleset 115 'MD 9-5/8" 1340 sx AS III & 4883'MD 350 sx Class G 7" 350 sx Class G & 9007'lvD 175 sx AS I True Vertical depth 115'TVD 3841'TVD 6822'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) 2-7/8", L-80, tbg w/tail @ 8579' Packers and SSSV (type and measured depth) HRP-I-SP pkr @ 8553' & TRDP-1A-SSA SSSV @ 1786' 12. Stimulation or cement squeeze summary ~N/A Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED JAN 2 3 1987 Alaska Oil & Gas Cons. Commission Anchorage 13, N/A Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Subsequent to operation 14. Attachments Daily Report of Well Operations (Completion Well History w/Addend~, dated 11/15/86) Copies of Logs and Surveys Run X~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Tubing Pressure Gyro Signed Form 10-404 Rev. 12-1-85 Associate Enqineer (DAM) SW0/145 Date Nq- 7 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District Alaska Field North Slope Borough State Alaska County or Parish Lease or Unit I Well no. Kuparuk River ADL 25629 I 3K-16 Auth. or W.O. no. T t e AFE AK1487 Completion Nordic 1 Operator A.R.Co. ARCO Alaska, Inc. Spudded or w.O.complet ebegun Date Date and depth Complete record for each day reported as of 8:00 a.m. 12/08/86 12/09/86 API 50-029-21633 W.I. ~otal number of wells (active or inactive) on this tcost center prior to plugging and 56.24% Jabandonment of this well IH°ur I Prior status if a W.O, 12/8/86 / 0045 hrs. I 7" @ 9007' 8920' PBTD, Rn'g 2-7/8" CA 10.0 ppg NaC1 Accept ri~ @ 0045 hfs, 12/8/86. rn'g 2-7/8" CA. NU & tst BOPE. RU & begin 7" @ 9007' 8920' PBTD, RR 6.8 ppg Diesel Rn 267 jts, 2-7/8", 6.5#, L-80, EUE 8rd AB-mod w/SSSV @ 1786' HRP-1-SP 8553' & tbg. tail @ 8579'. Tst tbg & annulus to 2500 psi. ND BOPE, NU tree & tst to 5000 psi, disp well with diesel. RR @ 1845, 12/08/86. RE£EIVED JAN 2 3 1987 Alask~ Oil & Gas Cons. Commission Anchorage Old TD Released rig 1845 hrs. Classifications (oil, gas, etc.) 0±1 Producing method Flowing Potential test data J New 8920 ' PBTD ID P8 Depth Date Kind of rig 12/8/86 Rotary Type completion (single, dual, etc.) Single J Official reservoir name(s) J Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct J~/~/~ Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ADDENDUM 10/24/86 3K-16 Rn GR/JB to 8925'. Rn CBL & gyro. 11 7~- ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO' ARCO ALASKA, INC. ATTN' Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5854 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Finals (blueline unless specified otherwise)' 3K-I~' 5" DIL 8-27-86 4761-9572 "~5" FDC Porosity 8-27-86 4761-9548 '"""2" FDC Raw 8-27-86 4761-9548 ~~ '2" FDC Porosity 8-27-86 4761-9548 '~5" FDC Raw 8-27-86 4761-9548 ~'2" DIL 8-27-86 4761-9548 ~Cyberlook 8-27-86 4761-9548 3K-14~Cyberlook 8-4-86 8300-8900 '"' 2" DIL 8-4-86 4752-8948 ~2" FDC Porosity~ 8-4-86 8000-8922 ~- 5" FDC Raw 8-4-86 8000-8922 %' ~ "-2" FDC Raw 8-4-86 4752-8922 -~ 5" FDC Porosity 8-4-86 8000-8922 --~ 5" DIL 8-4-86 4752-8948 3K- 6'~ 5" DIL 8-19-86 4893-9046 '"~2" DIL 8-19-86 4893-9046 "'"5" FDC Porosity 8-19-86 8275-9021 ~- ~ "~5" FDC Raw 8-19-86 8120-9021 ~2" FDC Porosity 8-19-86 8275-9021 "'J2" FDC Raw 8-19-86 8120-9021 ~ Cyberlook 8-19-86 4893-9006 Receipt Acknowledged' (" .~' Alaska 0ii & Gas Cons. Commissi ~ -- Anchorage Date'" Distribution' NSK Drilling Rathmell Vault (film) D&M Johnston (ven. pkg) ........... ,-^ .'- ~ m,,~..i~i=,,, n! AllanticRichfieldCompany ALASKA A~, c c TO: STATE OF ALASKA -~ .L AND GAS CONSERVATION CC 'ISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 the following material which was transmitted via is hereby acknowledged: DESCRIPTION RECEIVED: Copy YES sent to sender N0 . , ??~ ~:-~::::~-:-.' :~' AnchOrage,: Alaska 99510-0360 "::::~':~:'-; *::-: -:. '': ' ~ :' ' === === = ===== ======== =? :: Telephone 907 276 1215 '~: ~::~; ~ 1~ :1:-.. ::: .- :: .- :t AT~: Kupa~::Rec°rds/Clerk ::~:'--] .::(:: :( ::~:~ :: - :> :: -.- ~r~smi~ea- nerewi~:l::-ar~' ~ ~e:-~o~0wing one Signed Cop~i_ s .tr~sm~tta~: :t: .'~. :-. ..... .. . ~3K:17:/: ;':::_:: 08-27-86 Run:': ~I:- :~3K-Ze~:: ::.:: 0S. Zg-Se ~un ~Z- oosg.o-9o~z.o{~3/~0-~-~en-~-~/ 3K-15: ..:. 08-12-8~ Run ~1 09~8.0-9302.0~/~/ ,2T-6 . 08-21-86 Run ~1 0987.5-8235. ~2T-4 - 08-12-86 Run ~1 0924.0-8067. ~O~I~-S-O~U-~2' ~' -~~ , :-_ . : . :: - : ., : ' . : .: : : :_ . .' - : : : .: . -'. : : - . ::: . :: :;: : =: :-: , ARCO AIlskl. Inc. ,s · SuOs;diary ol AtlanticRIchfieldComp·ny STATE Of ALASKA ALASh,,-, OIL AND GAS CONSERVATION COM~,,.sSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon -- Suspend - Operation Shutdown/'~' Re-enter suspended well - Alter casing - Time extension .Z Change approved program-' Plugging- Stimulate-- Pull tubing- Amend order-- Perforate "- Other 2. Name of Operator ARCO Alaska, Inc. 3. Address . P. O. Box 100360 Anchorage~ AK 99510 4. Location of well at surface 1009' FSL, 315' FWL, Sec 35, T13N, R9E, UM At top of productive interval 1776' FSL, 1536' FWL, Sec. 1, T12N, RgE, UM (Approx) At elf:~t'iV¢s~ePlt~36' FWL, Sec. 1, T12N, RgE, UM (Approx) At t¢lt~,Clel~, 1656' FWL, Sec. 1, T12N, RgE, UM (Approx) 5. Datum elevation (DF or KB) 69 ' RKB 6. Unit or Property name K.vparuk River Unii; 7. Well number 3K-16 8. Permit number 86-139 g. APl number 50-- 029-21633 10. Pool · Kuparuk River 0il Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 80' 4846' 9007' Production 9038 'MD feet 6852 'TVD feet 8920 'MD 6771 'TVD feet feet Size 16" 9-5/8" 7" Plugs (measured) None Junk (measured) None Cemented Measured depth 1540# Poleset 115'MD 1340 sx AS III & 350 sx Class G 4883 'MD 350 sx C1 ass G 9007'MD True Vertical depth 115 'TVD 3853 'TVD 6831 ' TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) None None 12.Attachments Description summary of proposal F'] Detailed operations program .m. BOP sketch ."-' Well Hi story 13. Estimated date for commencing operation November, 1986 14. If proposal was verbally approved Name of approver Date approved 15, I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /' ~/';¢~/'}(.....- ;~--.)~}/Z/l-L/\_. Title Associate Engineer Commission Use Only (DAM) 5A/106 Conditions of approval Notify commission so representative may witness Date I Approval No:,._j .~ 2 Plug integrity ~ BOP Test ~ Location clearance Approved by Commissioner by order of the commission Date Form 10-403 Rev 12-1.85 Submit in triplicate ARCO 011 and Gas Company Well History - Initial Report- Daily Instructlonl: Prepare and submit the "Initial Report" on the first Wednesday after a Well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District -Alaska ICounty, parish or borough North Slope Borough Lea~ or Unit ADL 25629 Title Drill State Field Alaska Kuparuk River Well no. 3K-16 Auth. or W.O. no. AFE AK1487 Doyon 9 API 50-029-21633 Operator ARCO Alaska, Inc. Spudded or W.O. begun jDate JHour Spudded 8/14/86 Date and depth as of 8:00 a.m. 8/14/86 Complete record for each day reported 0230 hrs. ARCO W.I. Prior status if a W.O. 56.24% 8/15/86 8/16/86 thru 8118/86 -- 8/19/86 16" @ 115' 551', (436'), Drlg Wt. 9.2, PV 21, YP 20, PH 9.0, WL 11.6, Sol 6 Accept ri~ @ 2400 hfs, 8/13/86. NU diverter sys. 0230 hfs, 8/14/86. Drl 12¼" hole to 551'. Spud well @ 16" @ 115' 3520', (2969'), Drlg Wt. 9.6, PV 21, YP 18, PH 8.5, WL 13.6, Sol 10 DD & surv 12¼" hole to 3520'. 556', Assumed vertical 707', 3.7°, S28.4E, 706.92 TVD, 4.84 VS, 1170', 20.0°, S30.2E, 1158.04 TVD, 100.92 VS, 16~8' 1954' 4.29S, 2.32E 86.38S, 56.37E , 34.6°, S29.9E, 1571.81TVD, 314.28 VS, 272.35S, 166.95E , 44.0°, S27.8E, 1817.03 TVD, 512.05 VS, 449.17S, 257.98E 9-5/8" @ 4883' 8435', (4915'), Drlg Wt. 10.0, PV 20, YP 10, PH 9.0, WL 3.8, Sol 12 Drl & surv 12¼" hole to 4903', short trip, C&C, POH. RU'& rn 122 jts, 9-5/8", 36#, J-55 BTC csg w/FC @ 4802', FS @ 4883'. Cmt w/1340 sx AS III w/10#/sx Gilsonite & 350 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. CIP @ 1330 hfs, 8/16/86. 2000 psi. DO formation tst to 12.5 ppg EMW 2388', 48.7°, S24.6E, 2116.60 3548', 45.9°, S24.0E, 2904.24 4459', 44.3°, S17.0E, 3556.50 4838', 47.3°, S16.5E, 3820.73 5336', 42.9°, S15.3E, 4172.25 5902', 42.3°, S17.6E, 4588.88 6977', 43.5°, S15.4E, 5385.47 8078', 43.3°, S15.8E, 6182.14 ND diverter. NU & tst BOPE. TIH, tst csg to cmt & flt equip + 10' new hole. Conduct . Drl & surv 8½" hole to 8435' . TVD, 824.87 VS, 730.93S, 396.63E TVD, 1673.70 VS, 1498.20S, 765.85E TVD, 2309.39 VS, 2092.23S, 992.20E TVD, 2580.29 VS, 2352.41S, 1070.51E TVD, 2931.55 VS, 2691.67S, 1167.15E TVD, 3313.36 VS, 3059.10S, 1275.64E TVD, 4033.82 VS, 3746.81S, 1494.85E TVD, 4789.97 VS, 4479.28S, 1697.33E 9-5/8" @ 4883' 9038', (603'), POOH f/logs Wt. 10.0, PV 18, YP 10, PH 9.0, WL 3.8, Sol 12 Drl 8½" hole to 9038', 10 std short trip, C&C, spot diesel pill, POOH f/logs. 8328', 42.6°, S16.6E, 6365.13 TVD, 4959.67 VS, 4642.86S, 1744.85E The above is correct For form prep. al~t)o'n and distril:6,~h~, see Procedud~..4~anual, Section 10, Drilling, Pages 86 and 87, Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when oDerations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative lest data in blocks provided. The "Final Repolff" form may be used for reporting the entire operation ii' space is available. District ~ICoun'~Y or Parish Alaska I Field Lease or Unit Kuparuk River ADL 25629 Auth. or W~O. no. Title AFE AK1487 Drill Accounting cost center code State North Slope Borough Alaska IWell no. 3K-16 Doyon 9 Operator ARCO Alaska, Inc. API 50-029-21633 A.R. Co. W.I. 56.24% Spudded or W.O. begun Date Spudded 8 / 14/86 Date and depth Complete record for each day reportecl as of 8:00 a.m. 8/20/86 8/21/86 Iotal number of Wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our I Prior status If a W.O. 0230 hrs. I 9-5/8" @ 4883' 9038', (0'), LD BHA Wt. 10.0, PV 20, YP 12, PH 9.0, WL 4.2, So1 12 RU Schl, log DIL/GR/SP/SFL/CAL f/9052'-4892'; cont w/GR to surf. Rn FDC/CNL f/9052'-8300', RD Schl. Make cond'g rn, spot 50 bbls diesel pill, POOH, LD DP. 9038', 50.75°, S10E, 6852.29 TVD, 5471.30 VS, 5145.51S, 1863.67E 7" @ 9007' 9038' TD, 8920' PBTD, RR 10.0 ppg Brine RU & rn 219 its, 7", 26# BTC csg + 1 ~kr jt w/FC @ 8922', FS @ 9007'. Cmt w/100 sx 50/50 Pozz w/4% D-20, .2% D-46 & .5% D-65 & 250 sx Cl "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ w/10.0 ppg brine, bump plug. ND BOPE. Instl upper packoff & tbg head, tst to 3000 psi. RR @ 2000 hfs, 8/20/86. SEP 0 9 1986 Aiaska Oi~ & Gas Anchor'-3.gB Old TO INew TD PB Depth I 9038' TD 8920' PBTD Released rig J Date J Kind of r g 0200 hrs. I 8/20/86 I Rotary Classifications (oil, gas, etc.) 0il Producing method Flowing Potential test data IType completion (single, dual, etc.) Single Official rese~oir name(s) Kuparuk Sands Welt no. : Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected TSe-above is correct Drilling,~Pages 86 and 87. IDate JTitle Drilling Supervisor July 18, 1986 Mr. J. B. Kewin Regional Drilling Engineer ;~.CO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 .Telecopy: (907) 276-7542 Re: Kuparuk River Unit 3K-16 ARCO Alaska, Inc. Permit No. 86-139 Sur. Loc. !009'FSL, 3tS'FWL, Sec. 35, T13N, R9E, !~. Btmhole Loc. 1413'FSL, 1677'~, Sec. !, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The pe~nnit to drill does not indem~nify you from the probable need to obtain additional permits required by law from other governmental agencies prior to co~encing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~Cmere a diverter system is required, please also notify this office 24 hours prior to'co~encing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. 7~ trqly C. V. ~atterton~' Chai~an of Alaska Oil and Gas Conservation Co~ission BY OPd)ER OF ~E CObR,~ISSION d!f Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lower7 .... STATE OF ALASKA ALASKA ~.,L AND GAS CONSERVATION CC,¢~'MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill Fit lb. Type of well. Exploratory D Stratigraphic Test [] Development Oil Re-Entry [] Deepen ~1 Service [] Developement Gas ~ Single Zone ~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 69', PAD 35' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25629 ALK 2562 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20AAC 25.025) IO09'FSL, 315'FWL, Sec.35, T13N, RgE, UN Kuparuk River Unit Statewide At top of productive interval 8. Well nu ,tuber Number 1776'FSL, 1536'FWL, Sec.1, T12N, R9E, UN 3K-16 #8088-26-27 At total depth 9. Approximate spud date Amount 1413'FSL, 1677'FWL, Sec.1, T12N, RgE, UM 08/08/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 8701 'MD 1009' ¢. surface feet 3K-15 25'¢ surface feet 2560 (66,51 'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 600 feet Maximum hole angle 45 0 Maximum surface 2288 psig At total depth (TVD) 3300 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD 'i (include stage data) ,- ................. ....... " '...... l?-l/b."q-r-,/R" ~¢, ~.~ l-r-,c, RTr ,' ' ,~r~, ~.r~, '~RC, b., b. Rf~R~ 1~/+0 HF-ERW ~,sO s× C. 1 ass 6 bl end 8-1/2" 7" 26.0# J-55 BTC 8667' :34' $4' 8701 ' 66,51 ' 200 ~x (;::la~ G(minimum HF-ERW TOC 50'' above top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface qECEIVED I nte rmed i ate Production JUL 3986 Liner Alaska Oil & [~as Cons. Com~ic,t, ior, Perforation depth: measured true vertical ..... 20. Attachments Filing. fee ,:~ Property plat I~ BOP Sketch ,~, Diverter Sketch ,~ Drilling program Drilling fluid program 3(~ Time vs depth plot [] Refraction analysis ,'~ Seabed report [] 20 AAC 25.050 requirements 21. I hereby cert' at the foregoing is true and correct to the best of my knowledge ~/~-/~~ //~/¢' ' Regional Dril ling Engineer Signed ¢ .~',.,4~ Title Date (~/ "-~// (,/,/ ~ ~' ~'-- - Commission Use Only (HRE) PD/PD295 APl number J Approval date J see cover letter Permit Num6er 5~/_7~' 50-- ¢%9 - ~/L, 3,3 07/18/86 for other requirements I I Conditions of approval Samples required ~ Yes F~ No Mud Icg required ~ Yes ~ No Hydrogen sulfide measures tq Yes [] No Directional survey required ~ Yes lq No R equiredwor~4~,~~SM; lq 5M; [] l OM; © 15M Other: by order of Approved by ~ ,,--/. k,,...././/~'~/.~'¢~ Commissioner the commission Date · Form 10-401 Rev. 12-1-85 Su n triplicate .~ ': PAD 3K. 14ELL NO, 16 PROPOSED . ......... i ..... _'_:. _KUPARU~_K. F_I_E_L_D'L_NORTH_ ; EASTHAN t,q.IIPSTOCK~ I#C- - ._. · : , /-KOFF~L~6OO-THDi61~O,DEF'O · ; _ . ' .~._tOO0_ 9 .... P_O~_oo FI- i ; .... ~ ' I$- - ' 33 SASE PERM^F]ROST : TVD"IZ21 TMD"I 3. 'EoC TVD=_l,951 TMD=210i DEP-560 ri1 r98. DEp-36-4. : 45 DEG 2 MINi ~ ,---,- .......... - ............. sooo ............................ : ...... . ..... :_ ...... - ............... ,:_~. R [ ~_ c IV E D . T/ ZONE C TVD=622Z THD-8151 DEP-4840 T/ ZONE T~ET CNTR- TVD-6412 T~-8~3-DEP-~6 "~ B/ KUP SNDS TVD=64Z4 T~-8501 ~P-5088 TD (LO~ PT) TVD=6615 T~-SZ0I DEP-5229 ......... : .......... ZOO0 0 1 000 2000 3000 4000 5000 6000 ...... TOP UGNU SNDS TVDm2694 TI"ID':3152. DEP" 1 304 ~ TOP 14 SAK SND~--TVD~:.3~24 THD'2t043 DEP-I9334 . . K-12 ~"TVD-36~4 TMD-4525 DEP-22Z5 9 5/8" CS13 PT I¥~ 6r4---IHD--=--4808. DEP'-'.24Z5 ............ PAD- 3K; - NO~ 16 . PR~OSED EASTHAN ~IPSTO~, ~I~C. - .cCEIVcD J U L ! ! Alaska Oil & fi~m Cons. Commis.~i:;:~ TD LOCAT!ON ~ 1413' FSI... 187r' FR SEC- 1. T12N. Rc:JE TAROET OENTER TVD-64t2 DEP-~026 SOUTH 4686 Jill_. .1816 S21 5026' DEG (TO 11 MINE TAROET) '~:-:-?-t-~ {.~ ~: !i~l: :' ~! ..... .b-;-'?' :'~ 17.&~t~--?..~-: -.-- : ~ ~-I..?'-' .--~~-- ~': - --~--"~' .'~',~ ',"; ~' ~. ' ; ~-', ~' ',~" , '.. · :~ ~.~.:.~: ~ ~. ~ ~ .... ~-~ -~. ~ ' ~:: ~--~.~ ~ ~' . : ~:~ ..... ~h~ ~ ~ .... ~ - · .... · ~ ~' .~, ~ ~' ~ Ff ' ~ - ~ .t-~ ~ - --~ . ~. ' · ~ ~ : _~-.~ ~ . ~ ~ - ' . ~ - ~ ~ · ~ ~ ~ ~~-~-~ ..... ~-- ~ T , ~--. ' ' · ~ '~ ~ - '[ , .~ .. , , ....., , .... ~ ; ; . . , , . . ; .r. "~ . -- ..... j ~ . ~ .... t ' . ~ . ~ : . : :- -:' .... · :, /--.-~-:~-.~ ' ' ' ' ' ' ~' : : ' ' ~ .... ' '-':' ' " '"'": .... - ' . _ ~ .... :& .... ___~.-. :_ __-_-_~ ..... : ..... -__~ ....... ~ .......... ~ ............ ~ _- ~- --:~- ..... ~ ---~---~- - ~-' ' 2~/~--~:-~ - - - ~--~:- i -~--' :'~ .... ~ .......... : ........ ~- ' ' ' .................................. . : ~ ; _~-__~.: ---~~~~--~.~ ...... ~_ : ....... : .... : ~ ........ ; ....... ~ ....... ;. .._ ~. _ Z~~ ' ' ' ~ ~ ~ - ' ' ~ ! ' ' ~ .......... :. ~- · . ~ ~ ' ..I ~ ' i ....... _- . ~ -- . ~ . . -~--~-~ ....... :. ..... :.-3-~i~ .... ~ ....... : : .... ~ ..... ~ ...... r .... ~ ............. :_~ .... . ~__ _ ~~ ---~-~ ____ ~ .......... ~-~: -~ ...... ; ...... ~ ...... ~ .......... ~ .... ~ ................... ' ~ ~ I ~ : - - - ' , . - '"""T,I[~[] .... i -- ~-~ ~ -' '~3[~-:- ..... ~ ....................................... 1 _~ ~:_: : ~:~ ..... ~~_ ~. ..~ ..... :___~~~~_~p_~_/~___: ..... ~ .......... ~ ................. --~--:.~ .~ i-~--~ -~-- ~::-q ...... ~.~ ..... ~f~~~~._J_~___:~__~ ..... : ....... ~ .............. ~ , , ' J ' ~ ~ . ; - . : ~' '~~~~~ - - ~ i '-~ - ~- ,. ~ ~ ' ~- ~ ...... ~ ...... 1 - '~ - ~ .... ~--': ...... -- .,-'-~ ~: .... ~ ................. ~ ............. , .... ..... [ ,. : : ,~ ~ --. . ..... .... ~ .... 4 --~ ~----~--- ~ ~ ;' -$ ................ ~ . -- ~ ........... ~ ......... ~ ............... ~. ..... _~ .... , . __ ~_ · _ __l___~ ..... : ..... ~_.~_~~~-_ ..... ~__~ .... ~ ....... ~ .............. ~___ mnr~: ~.-'1T:-:~~--~--~ ~--:-~88~--: -n-~~~--~_ ~--:- :~-' :' '~; .... , ...... T'~-nnn~- ---~-' : : ' ~ -~: i- ~----~ ........ [~--' -~~~- E ..... ~ ~- ........... ~ ........... : ......... * ............. i .... ~ ' ; ' · - . ' ~ ~ I ~i~ ' ~ ' ~ ..... ~ ~ ; ~ · I --~ -~ ~ ...... A ~ .... ~~~ ......... ~ ........... ~--.:-~--~ .................. ~- ................. ~ .... ' : : ~ [ - , i ~ /~ ~ i ~ I · ~ . ' '~ ~ ~ . ' ~ ~71 i · - . ' : - ' ' '' ~ : ! ' ~ i -.. I , ''~-" i , .... ~ : , . . ..... , ......... ; ............... ~_ - . ~-~ ....... :~ ....... ~_ _ ~p-~ ~ ........................ . . _~_ ' I ~&~ :~ . T :~Z_.~__. ~ ...... ~-- : '~ _ _ :~- ~ '_ ~ . ~ -~ ]. ~ ..F..-_}__~_ - t . - . . ~ - ~ :-~-- ~ .... ~ ..... --~- ~ ....... '- :~--~ ...... ~ ........... ~ ......... : ............... ' .............. F--- - ~ - : ~ ' ~ -~-- : - --:~: .... ~ ....... l-~-~ ....... ~ .... ~ ............. ~ ......... '. ...... ~ ................. F - ~ .... : .... __~_.2 -- ~ - - ~ .................. ~ ...... ' ........................ *'-' .2-;- - ' - ~ : : : · . . -~ ~ I ~ .... ~ ~ ~ -; ............. f ..... ~- -- ~ ........ ~ ' ..... ' _ ~' - ~---; .... ~ ....... ~- - _ ~ ..... ~ - ~.'. . ~ ..................... ~: ..... ~ ...... ~ ........ ~ ....... ~ ...... : ~ ~- ~--~---: .......... ~ ........ ~ .... ?- -~ .... ...... t -~ ....... r ~_ ':_:__: :_'_::::':_; :'/-:-.:.: ..... : .... x !--:_ :_.:: :/-_:-_:-f:- - RI c_ ......... [ D , -- ~ .... ~ -I ....... ~ ...... ,- :'.:-:;:::-:::.--- t: ..... :.'c.: I ~ ............. ' .... / ..... '" i JUL 1 1 1986 _5~0-'7~ ....... ]' '/ '~' ' ~ ~ 50E .... ~ , , , ~. ,.~,~ I ........ 40~.~ .... ~ ............. ~ ;- . --. ~ ....... ~ ....... ~ - __ --,--~ J J , I , , ...... ~ .................. : .... I I i i i ~ .__ ; ,- : --;- ::-'3-: 100 200 3'00 400 500 600 . KUP~RUK R I VER UN I T 20" O I VERTER SCHEM~T I C DE SCA I PT I ON 1. 16" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. 6. 20" 2000 PSI DRILLINQ SPOOL W/lO" OUTLETS. 7. 10" HCR 8ALL VALVES W/lO~ DIVERTER LINES, A SINQLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REHOTELY CONTROLLED TO ACHIEVE DOHNWINO DIVERSION. 8. 20" 2000 PSI ANNULAR PREVENTER. 6 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S . 03S (b) 4 3' HR I NTEN/~NCE & OPER/tT I ON 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DI VERTER L I NES EVERY 12 HOURS, 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR ~AS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOI, fl~INO DIVERSION. DO NOT SHUT IN HELL UNDER /~NY C I RCUHSTP~NCES. Si 00~4002 R1 I 7 6 31AOI:~AM ~! 13-5/8' 5CX)O PSI RSRRA BCP ~TAOK ACCt~TQR CAPACITY TEST I. (I-ECl( ~ FILL A~TOR RF_,,qI~OIR TO PRCIMER LEVEL. WITH HYC]a, AU. IC FLUID. A,~ THAT A~TC~ PR~~ IS ~ PSI WITH 3. ~ TI~, T~ CLOSE ALL LINITS SIM. LTAFECIJSLY ALL ~TS ~ ~ NI~ ~I~ ~ ~. 4. ~ ~ ~ ~, ~ A~~ L~ LIMIT IS 45 ~~ ~I~ TI~ ~ 12~ ~I ~INI~ 5 4 3 2 ir BOP STACX TEST I. FILL B(]a STACX N~) ~ MN~IFCI.D WITH ARCTIC DIESEL. C~C)( THAT ALL LCX]( ~ ~ IN ~i. LFEAD FiJ. LY RETRACTED. SEAT TEST PLUG IN ~ WITH RLI~ING JT ~ ~ IN LOCKI:O~ LI~E VALVES ADJA(2D~ TO ~ 5TACX. ALL 4. P~ ~ TO ~ PSI ADO HOLD FOR I0 MIN. IN-- C~ PRES~[.I~ TO ~ PS! AFO HCLD FOR I0 MIN. Bi rlmn PRESSI.I~ TO 0 PSI. L[~I[ VALVES. CL_c?_l!'___ TC~ PIPE RNv~ AI~) H(~ VALVES CN KILL AI~ Q.EI<E LI~ES. 6. TEST TO 250 PSI AI~) ~300 PSI AS IN STE~ 4. 7. CCNTI~LE TESTING ALL VALVES, LII~r.s. ~ O-K](ES WITH A 250 PSI LC~ ~ ~ PSI HIGH. TEST AS iN STEP 4. DO N~T Pt:~'~,ciR~ TE.~T AN~ OqCI(E .TI-iAT N~T A FULL CLOSING POSITIVE SEAL CH(](E. CI~.Y F~I~ TEST C~D(E5 TI-JAT J20 h,12T FULLY 8. ~ TCP PIPE RAMS ~ CLC~E BOTTCM PIPE P-Jr, IS. TEST BOTTC~ PIPE R/kMS TO 250 PSI AI~ ~ PSI. 9. CPEN SOTTC~ PIPE RAMS, BACX OUT Rt.X~IING jT AbO I0. CLCE~ BLI~I) RAM~ AI~ TEST TO 2,50 PSI AI~ 3000 PSI. I1. ~ Bl. Ihi:) PNd~ At4:) RETRIEVE 'TEST PLUG. MAKE SURE MAN[F~ AhD LIt~ES ARE FLt..L CF FLUID. SET ALL VALVES IN DRILLING PC~ITICN. 12.' TEST STA, I~[~IPE VALVES, KF1 fY, KE].LY 033<S, SRILL PIPE SAFETY VALVE, ~ Ih~IDE ~ TO 2.50 PSI 5000 PSI. 15. RECCRD TEST [r'~CI~VATICN CN BLO/K1J'I' PREVENTER TEST FCIC, SIGN, Af~) SEh~ TO DRILLING SLI:~ISC~. 14. PERF~ COW~ETE BCI:~ TEST AFTE~ NIPPLI~ UP '/E_B<LY THEREAFTER ~IClqALLY (]3EI~ATE BCPE '3AIL~, 510084001 ~[V. MAY 15,1~ GENERAL DRILLING PROCEDUR]~ KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psis. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole loss. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. -~ DEt~LS,SER I' ,SHRL'E sHRKER~"' TYPICAL I'IUD SYSTEM SCHEMATIC LWK4/ih DRILLING FLUID PROGRAM Density PV YP Spud to 9-5/8" Surface Casing 9.6-9.8 15-30 20-40 Viscosity 50-100 Initial Gel 5-15 10 Minute Gel 15-30 Filtrate API 20 pH 9-10 % Solids 10± Drill out to Weight Up 8.7-9.2 5-15 8-12 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. LWK5/ih ARCO Alaska, inc.; Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 7, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas ConServation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor'As-Built Location Plat - 3K Pad (~/ells 1 - 18) Dear Hr. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU!/12 Enclosure Z,]T__- -- . . If ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany .... I I ~ ~ ~ I · ~ I ii ~ ~ II I I r[.,r I t ,/ LOCAT~O IN P~OT~CTE~ LOC~T~O IN P~OT~ACTE~ SECTION ~5, T.I~H.~ ~.~E.~U.M. S~CTION ~ T.I~H.~ I - Y - 6,~,~.74 ~T. 70'~'02.7~" ~0 - Y - ~,~,~53.7g ~T. 70'~'~.07~ ~' ~, 3~' ~ ~- ~.4 P~- ~.5 ~35' F~, 3~' ~ ~- ~.0 P~- ~.5 3 - ~ - &,~,~l.~ ~T. 70'~'02.~79" t2 - ~ - 6,~,~03.~3 ~T. ~" ~, 3~' ~ ~" ~.5 ~- ~.5 ~' ~, 3~5' ~ ~- ~.0 e~- ~.5 4 - ~ - ~,~,~3.~ ~T. 7~'02.~)4" ~3 - Y - 6,~,078.~7 ~T. ;359' ~, 3~" ~ ~" ~.7 ~- ~.S ;~" ~, 3~' ~ ~- ~.0 e~ - ~.5 ~3~' ~, 3~' ~ ~" ~.8 P~ ~.5 ~' ~, 3~' ~ ~- ~.0 P~ - ~.5 ~' ~, 3~7' ~ ~ - ~.~ P~' ~.5 ~0~' ~L, 3~' ~ ~ - ~.0 P~ - ~.5 8 - T - 5,~,~3.70 ~T. 70'~'0~.0~ ~7 - ~ - 6,007,978.8~ ~T. 70"25'~.355~" X - 5~,~5.~ L~. ~49'45'~.~" ~" 5~,~5.77 L~. ~ - T - 6,~,~.~5 ~T. 7~'~.8~24" ~8 - ~ - 6,~7,953.69 ~T. 70'25'~.~ ~2~' FSL, 3~7' ~ ~ - ~.] ~ - ~.5 959' FSL, 3~5' _ - NOTES -. . I. ALL COORDINATES AR~ A.S.R, ZONE4. ~ALL DISTANCES SHOWN ARE TRUE. ~.HORIZONTAL POSITIONS BASED ON ~K CONTROL MONUUENTS PER LHD & ASSOC. 4. VERTICAL POSITIONS BASED ON ~K TBM No. 4 S TBM No. 5 PER LHD ' 5.0.G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED-RIXX-3070 rev.~ CER~FICA~ OF SURVEYOR: : HEREBY C~l~ THAT I ~M PROPERLY ~mST~[D ~ND L,C~NSED ~ P~CT~CE C~D '~' / THIS PLAT REPRESENT5 A LOCATION SURVEY . MADE BY ME OR UN~R MY SUPERVISION, AND ~ , .- ~. THAT ALL DIMENSIONS AND OTHER D[TAICS ~ ~ .,'..~ -:. ,, , - SURVEYED FOR: ~ ARCO Alaska, Inc. :'~o-----~ ~~ I 11 ~ KUPARUK PROJECT ":, '. -- "' ~ CONDUCTOR " "" ~ECKED ~T. 8SSO& -' '- ' .... I AS-BUILT. LOCATIONS '~ ....... ~IDWG. NO. NSK 86-31 ~ A~ ~va~, Suke 201, A~ge, A~a 99503 IIs~LE NOT T0 SCALE il~Oe ~. , i i i ~ ITEM APPROVE DATE (1) Fee,. 7 -F~-/( 1. (2) Loc, ')'-/' ~"'~ ~ 2. (2 thru 8) 3. 4. 5, 6. 7. 8. (3) Admtn~(9~/hru~ 1~/~/~ 10. n 11. '(iO d 1'~) '/ 12. 13. (4) Casg ~.~.~ (14 thru 22) (23 thru 28) Company 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. YES Is the permit fee attached ~ Is well to be located in a defined pool .............. ~ ........ Is well located proper distance from property line ...... i oi i}iiii.i i IS well located proper distance from other wells .......... Is s~fficient undedicated acreage available in this pool . Is well to be deviated and is wellbore plat included .... Is operator the only affected party ........... , ......... Can permit be approved before ten-daywait .......................... Lease & Well No. NO Does operator have a bond in force ................ ' ................. ~. Is a conservation order needed ' eeeee®ee eeeeeeeee®eeeeeeeeeee®eeeelee Is.administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production, strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ...................................... ~ Is the drilling fluid program schematic and list.of equmpment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to .~OCyp psig .. Does the choke manifold .comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. ( 6 ) OTHER ~,~. (29 thru 31) (6) Add: ~.~ ?-/.5'-~( Geology: Engineering: ~ LCS ~ I~EW ~ WVA ~ MTM ~ HJH ~f rev: 04/03/86 6.011 For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ....... ~ ......... 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented__ 32. Additional requirements ............................................. POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Additional Remarks / Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. · ... ;'7. 2' ['.~ :,,( CT :: {. '¥ L :' u: .: L '? , _ } ,, :'-' 7 :' i :,.:' "::~ ':. ? 7 :.: 0 -" i: ., : ':, .:,' .:., ,': " . '2. C. _'2. _-. >'-, :. :..:.: "-' .!_. _- -1, '.. ,1 ' :, "'" :i i' 2. 7622 - 9 ?'~. 250 {} · . . ;': :::, 3 ,::::,. c..., ,,, .i .::~ :.-.: (:: ::.: i::,' ;'-: ~ ~": i '::, :~ .:, ,, .:. :..: ,.,, i:.. C :.., ' ;:" T :,- ?' 0 ::, ,. ":::.' :'3 '3 ' ::' L. . :.:': -..3 ,,, 4 ? :: ?:-.., ,"t :_q :::: -:?, '9 ::., 2.-' 3 ': ..... -..-'" ::' "~ 2 -::,:': ? :: ,, ".:: ',} '3 :'.,, · :': ::' 'F ' .<, :3' "O' ,,. ':. ::' C'; ',:, :: :;:: L ,j :3, ::,j. ",':;~ - ,"' "' ,: ,,,. --.~ ,,., :...'.,,, :.~ ,.,' _,, :~ '-': .... ")" .,, :: :: :.:::' :J .iL: .:,:..-"" F t'"~ '2 '-..? ":.." ':;' ,,, ..:: :.: ..':: ':; :',.:: (: ": :::' T 4 :;' ~: ;i? ,, 8 ,.: 3 :: ,;::: c:' -:? :? :).,,,: '- 3.3 'Lt. ,~ '2 :' '-".:,; ::~ :-'? ,., Z ' ':3 ') :' ::.': '-': :' ,-:' i-: .: _ ,.:: ,.:, .5 ,, ~ :. :} :.) ).,: .... .:. ,~ - :? ':':., ':::.,, ,,, 2 ::' .:; ::.- ix: f: :.;' ~:.'. '-'.:': ':.;1" ,,, ..t ::: 3 .::; :::. :'.:" ;'." :.~ -'i '-'::: ",, .... ::: '" :.; .3 :.; L · : ? 'i' ' :: :3:3 ,,, "' ?; (.':: '.:'.' ' ::: L. ,.., P -":: 3 ":: ,, :: :.:, ,.} ' .'.: :.': -..:: .:: ._:..:.:., ::.- .::, ,} _. ':: ..... ;.: ~ T --:::.: :.' '~ ,,, "' .:.: 2 i'~ ...... :' L ' ::::' ::' '"" .:.: ::-3' ':', "' 5 :..' ,:,: : -: ' ~ ~ - :. ':~ '.:' ,,, ,:.: 9 ',:, .:' · : ,-" _.:S ' · -: ?:' :;::_ ..: :::' 'X," -.:' :: :.; ,-., .:: ": '"' ', :.: ..,: . .... j,; ~ r .3" z , -- -- ' .' .' ~ .. :.. '.,' __' ;~, '-- · ,: -:- :; '.-: .- ,:: ..:..::, : :: .... . . -...::-.: _. ?: · .,, .. - ._-.,. _ -., ... "-: z - .:, _': ::.,, _': :: .::; ', .:: ',. ..: .:..j .? :..:. .... ,": ,3 iL:. -:::~ :; ~',, .:,;. '.E) '.-:: ';'"' "-F T' .7. ,:: 'J; ~.:;, ':.;;" .'~ .'~ .... :;;) ';'.' :t:3 '"'~ -.....:. ..... ::.~., ?~: ,:,': ..... ,.~ ~ ,,:. ,. ,; ~.:.;. :' x ... ,? ~: ,';. , '.:....)'" ~7. :.; ~ ? " .... '.' ': '.: t. . .... ,, . . n .. L'. ,::. :;;, ' ·." ,' ,.. ..... ., -, ~ ~ ~ ~ ~ .._ ¢ . · ,-- -i::, :. ? -'~ ".;, '?. - ?; ? ,y. :.. :::: :,:: ;2, ,-, ;:,, . . ~ '~ ':7 ~ .., ..... '~ .... - ~ :~: . .:~ .:, :' '? : t_ "'" _ .'~, :, ~ -'~r ? ~. ' ~':: -'~r ' _ ,:: '~. :,: ;.,., ::._ ~'~" - ~ ~ '~', ~ f, ': .-. ..... .. -* *il ~.:, ~ ~ ~ !!: C i.~ ';) ~ ..... ~ ~, .., ........ , ..r ;.:.,..., ~"., i" ,--,:: ':~,,, ':~ ~ ?: ;~,~ ,"~ :,:, L:' ,..~ ,::: ,::~ ..... '-' ' ......... :' '~ C: ',: .-~' _ . ?~ ~ . '~ ~.:~ ..... .~l ~.~.'. · ~ :, ~, '~ ~"~ ~,- ~ · -7 '~' ~' . :'" : '.. .... ~., '~ - L ~. - ,. ... -~.:'~,L.~O::'. -~v. .. -':, :,' ~'~ ,.~ .: (:.'. C .... L .:. - ? '!~.:' '~i .,, '?' !~ .:.) ,~ .- "ii~ ::~'::.., .? .:5 (.'! '.'? -'C. (::'. 9 .,, '~ ~ 3 :? ..::. ,.~ .,....'"' .~ ~: ,.... "..:.,,, ?. ":..,. S O. -":' '-:;' ':.,'.., ~ 7 :":....~ ,, ,~, "~ ~,~ -'7'".: ': .~ ..'.'5: _ ~: ,: :: '? .: ,,". ,,h. ?,!'~.7' :)3 . . .: .-- ..... :!:. -, .. --7 ~ ~.. ~t !~ .~ -.,' ....
