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Home My WebLink About185-2241. 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 7120'feet 6532', 6541'feet true vertical 6320' feet None feet Effective Depth measured 6532'feet 6408', 6523', 6684'feet true vertical 5895' feet 5806', 5888', 6005'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80/J-55 6711' MD 6024' TVD Packers and SSSV (type, measured and true vertical depth) 6408' MD 6523' MD 6684' MD N/A 5806' TVD 5888' TVD 6005' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: 322-649 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: MFT HAL Packer Packer: Baker FHL Packer Packer: Baker FB-1 Packer SSSV: None Adam Klem adam.klem@conocophillips.com (907) 263-4529Senior RWO/CTD Engineer 6602-6642', 6752-6772', 6786-6842', 6882-6888' 5946-5974', 6053-6068', 6078-6118', 6147-6151' 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) ~ Gas-Mcf MD ~ Size 88' ~ ~~ Well Remains Shut-In ~~ ~ measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-224 50-029-21445-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025631, ADL0025632 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3A-08 Plugs Junk measured Length Production Liner 7073' Casing 6308'7102' 3130' 88'Conductor Surface Intermediate 16" 9-5/8" 57' 3161' 3160' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Carlisle at 2:48 pm, Feb 09, 2023 DTTMSTART JOBTYP SUMMARYOPS 11/24/2022 ACQUIRE DATA DRIFT W/ 5' x 1.875" WB & 2.52'' GAUGE RING TO 6504'RKB. GOT DEPTH CORRECTION W/ KOT TO STATION 5# @ 6461'RKB. READY FOR ELINE 11/27/2022 ACQUIRE DATA CUT 3.5" TUBING @ 6485' RKB W/ WELLTEC MECHANICAL CUTTER. CCL TO CUTTER=18'. CCL STOP DEPTH=6467' RKB. GOOD INDICATION OF CUT (TATTLE-TAIL INDICATED ~3.70" CUTTER EXTENSTION). JOB IS READY FOR SL 12/25/2022 RECOMPLETION Mob Rig, camp, pits and support equipment to 3A-Pad 12/26/2022 RECOMPLETION Spot pits to sub. Berm in rig. Hook up interconnect and electrical to pits. Turn on steam and air. Spot cuttings tank. Raise derrick. Bridal down. Rig up circ manifold in cellar. Complete acceptance checklist. Get measurements for riser height from tubing spool height. Take initial pressures T/IA/OA. Offload 14.9 PPG KWF. PT circ manifold & tiger tank T/ 4500 PSI. Bleed free gas off TBG/IA. Kill Well. 12/27/2022 RECOMPLETION ND Wellhead and NU DSA and BOPE. PT BOPE. RU pull completion. 12/28/2022 RECOMPLETION Lay down completion from 6460' to surface. Process remaining tubing for new completion. 12/29/2022 RECOMPLETION Finished strapping tubing and completion equipment. started RIH with new 3-1/2" completion. 12/30/2022 RECOMPLETION TOOH with completion from obstruction at 6841'. Unable to get over the cut joint at 6485'. Rack back completion laying down jewelry. Overshot tattle tale pins showed no indication of getting over stump. PU clean out BHA on DP and RIH to 3100' at midnight. 12/31/2022 RECOMPLETION RIH with clean out BHA and string mill to 6481' unable to swallow cut joint. TOOH W/DP changed out shoe on BHA to 5.125" ID TIH to top of tubing stump at 6481' wash down to 6485' TOOH. 1/1/2023 RECOMPLETION PU test packer and TIH to 6460' test 7" casing. POOH with test packer L/D DP and test packer. Rerun 3-1/2" completion out of derrick to 5469' at midnight 1/2/2023 RECOMPLETION Land completion. ND BOP NU adapter and tree. Reverse circulate well to corrosion inhibited 10.3# NaCl/NaBr. Drop ball and rod, set packer and test tubing and IA. Attempted to shear SOV mutiple times pressured up IA to 2800 PSI 3 times unable to shear. Called out Slick line to pull SOV. 1/2/2023 SUPPORT OTHER OPERATIONS PULLED 1.5''SOV FROM ST#3 @6352'RKB,SET 1.5''HFCV W/FLOW THRU LATCH ST#3@6352'RKB JOB COMPLETE 1/3/2023 RECOMPLETION RU slickline pull SOV in station 3 replace with CV. RD slickline. Freeze protect tubing and IA using 75 BBL's diesel at 2 BPM. U-tube tubing and IA. RDMO. Moved rig off well at 1:30 PM 1/16/2023 PUMPING TRACKING ONLY PRESSURE TEST & FREEZE PROTECT FL PUMPED 7 BBLS DSL DWN FL PRESSURE TEST FL TO 3000 PSI PASSED PRESSURE TEST 1/18/2023 ACQUIRE DATA SHAKE OFF BAITED BALL & ROD PULLING TOOL @ 6400' RKB; PULLED CV @ 6352' RKB & SET OV; PULLED DMY'S @ 5485', 2733' RKB & SET GLV'S; TESTED TBG TO 2500; PULLED BAITED PT W/ BALL & ROD @ 6459' RKB; PULLED RHC @ 6466' RKB; BAILED DEBRIS & SAND FROM 6505' ~ 6514' RKB. IN PROGRESS. 1/19/2023 ACQUIRE DATA BAILED FROM 6516' ~ 6527' RKB; MADE SEVERAL ATTEMPTS TO PULL CATCHER @ 6528' RKB; WHILE RUNNING 3.5'' GR & 1.75'' SAMPLE BAILER INADVERTENTLY SAT DOWN ON OV IN GLM#3 @ 6352' RKB & MOVED OFF SEAT CREATING TBG x IA COMMUNICATION **OV NEEDS TO BE REPLACED**. RDMO FOR OPS TO PLACE WELL HOUSES. 1/21/2023 ACQUIRE DATA ATTEMPT TO PULL OV & UNABLE TO LATCH @ 6352' RKB; RAN 1.70'' LIB TO CONFIRM EMPTY POCKET; SET OV (.25'' PORT) @ 6352' RKB & OBTAIN GOOD DDT. IN PROGRESS. 1/22/2023 ACQUIRE DATA RECOVER DROPPED OV W/ 2.68'' BELL GUIDE & 1.625'' JD @ 6526' RKB; BAILED FILL & PULLED 3.5'' CATCHER @ 6528' RKB; EQUALIZE RBP @ 6531' RKB & MAKE SEVERAL ATTEMPTS TO PULL. IN PROGRESS. 1/23/2023 ACQUIRE DATA PART WIRE WHILE BAILING ON RBP @ 6531' RKB (APPEARS TO BE A BAD SPOT); RECOVER ALL WIRE & TOOLSTRING @ 6496' RKB; BAILED FILL ON TOP & INSIDE RBP @ 6531' RKB; LATCHED RBP @ 6531' RKB & JARRED FOR 1 HOUR. IN PROGRESS. 1/24/2023 ACQUIRE DATA ATTEMPT TO PULL 2.72''QUADCO RBP @6531'RKB. JOB IN PROGRESS 3A-08 RWO Summary of Operations 1/25/2023 ACQUIRE DATA ATTEMPT TO PULL 2.72''QUADCO RBP @6531'RKB. READY FOR COIL **LEFT BAITED TTS PULLING TOOL IN TOP OF RBP** Page 1/6 3A-08 Report Printed: 1/26/2023 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) 12/25/2022 12:00 12/25/2022 16:00 4.00 MIRU, MOVE DMOB P Finish cleaning Pits. Pull pits away from sub. Load shop and office. 12/25/2022 16:00 12/25/2022 19:00 3.00 MIRU, MOVE DMOB P Move pits, Taylor camp and shop to 3A pad. Spot shop and Taylor camp. 12/25/2022 19:00 12/26/2022 00:00 5.00 MIRU, MOVE MOB P Transport sub T/ 3A-Pad 12/26/2022 00:00 12/26/2022 01:30 1.50 MIRU, MOVE MOB P Spot sub over well, lay mats and herculite. Spot pits to sub, lay mats and herculite. 12/26/2022 01:30 12/26/2022 03:00 1.50 MIRU, MOVE RURD P Spot Pits. Set Rig Mats. Set Herculite. Release Trucks from Pits. 12/26/2022 03:00 12/26/2022 04:30 1.50 MIRU, MOVE RURD P Perform Derrick Inspection. Raise Pin Derrick. 12/26/2022 04:30 12/26/2022 12:00 7.50 MIRU, MOVE RURD P Safeout Landing on Rig. RU Interconnect service lines. Spot cuttings tank. Bridal down. Work on Rig Up Acceptance checklist. 12/26/2022 12:00 12/26/2022 15:30 3.50 MIRU, WELCTL COND P Unload hot water to the Pits to wash and remove mud solids from KWF . Accept Rig at 12:00 Noon. ITP: 2200 psi IIAP: 1920 psi IOAP: 40 psi 12/26/2022 15:30 12/26/2022 15:45 0.25 MIRU, WELCTL SFTY P Safety Meeting for testing and killing well. 12/26/2022 15:45 12/26/2022 16:15 0.50 MIRU, WELCTL PRTS P Fluid pack to Tiger Tank and PT Manifold to 4200 psi. 12/26/2022 16:15 12/26/2022 21:00 4.75 MIRU, WELCTL KLWL P Start Circulating 14.9 ppg down Tubing while taking returns up the IA until KWF is return to surface at 2 bpm, 850 psi. 14.9 ppg fluid seen at surface after Pumping 408 bbls 12/26/2022 21:00 12/27/2022 00:00 3.00 MIRU, WELCTL OWFF T Observe well for flow While waiting on more KWF from MI. 12/27/2022 00:00 12/27/2022 01:00 1.00 MIRU, WELCTL OWFF T Observe well for flow While waiting on more KWF from MI. 12/27/2022 01:00 12/27/2022 02:30 1.50 MIRU, WELCTL KLWL P Start Circulating 14.9 ppg down Tubing while taking returns up the IA until KWF is return to surface at 2 bpm, 850 psi.Pumped 250 bbls 12/27/2022 02:30 12/27/2022 03:00 0.50 MIRU, WELCTL OWFF P Observe well for flow 12/27/2022 03:00 12/27/2022 04:00 1.00 MIRU, WELCTL RURD P Blow down Service Lines. Grease Choke. 12/27/2022 04:00 12/27/2022 05:00 1.00 MIRU, WELCTL MPSP P Rig Up T-Bar and Install BPV.Perform Rolling Test on BPV. Threads Looked Bad. 9 turns on the blanking plug. 12/27/2022 05:00 12/27/2022 11:00 6.00 MIRU, WHDBOP NUND P RD Wellhead and RU DSA & BOPE for testing, install riser, Etc. 12/27/2022 11:00 12/27/2022 12:30 1.50 MIRU, WHDBOP RURD P Fill stack and surface lines with fresh water and purge air from system. Performed shell test to 250/4200 PSI. Rig: NABORS 7ES RIG RELEASE DATE 1/3/2023 Page 2/6 3A-08 Report Printed: 1/26/2023 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) 12/27/2022 12:30 12/27/2022 18:00 5.50 MIRU, WHDBOP BOPE P Tested BOPS. Initial BOPE test, Tested BOPE at 250/4200 PSI for 5 Min each, UVBR's, LVBR's w/ 3 1/2" test joint. Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3 1/2" HT-38 FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test annular to 250/2500 PSI, Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1500 PSI, 200 PSI attained =21 sec, full recovery attained = 109 sec. UVBR's= 6 sec, Annular= 30 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 1945 PSI. Test gas detectors, PVT and flow show.Test Witness Waived by AOGCC rep Sean Sullivan. 12/27/2022 18:00 12/27/2022 20:00 2.00 MIRU, WHDBOP RURD P LD test joint and blanking plug. Blow down BOPS and surface equipment choke and kill lines needed thawed. Fill stack with 14.9# LSND. Set up floor to pull completion. Move spooler to floor function test, move double stack tongs to floor and function test. RU to circulate. 12/27/2022 20:00 12/27/2022 22:15 2.25 MIRU, WHDBOP CIRC P Circulate down the tubing taking returns up the IA through the secondary choke to pit 14.9# in 14.7# out. 3 BPM 1000 PSI pump pressure. 12/27/2022 22:15 12/27/2022 23:30 1.25 COMPZN, RPCOMP RURD P Blow down RD circulating equipment. PU MU spear to DP. Drain stack. Spear hanger. BOLDS. 12/27/2022 23:30 12/28/2022 00:00 0.50 COMPZN, RPCOMP PULL P Pull hanger to floor. LD spear and hanger. 6,485.0 6,460.0 12/28/2022 00:00 12/28/2022 04:00 4.00 COMPZN, RPCOMP PULL P Pull completion F/6460' PUW=75K T/4637' lay down SSSV. 6,460.0 4,637.0 12/28/2022 04:00 12/28/2022 05:30 1.50 COMPZN, RPCOMP CIRC P Circulate BUS 4 BPM 675 PSI blow down top drive 4,637.0 4,637.0 12/28/2022 05:30 12/28/2022 20:30 15.00 COMPZN, RPCOMP PULL P Continue POOH W/3-1/2" completion F/4637' T/surface. Recovered 206 joints 5 GLM's 1 SSSV and 13.65' of cut joint. 4,637.0 0.0 12/28/2022 20:30 12/29/2022 00:00 3.50 COMPZN, RPCOMP RURD P RU to run casing continue strapping and drifting remaining 125 joints of 3-1/2" 9.3# L-80 EUE tubing for completion. 0.0 0.0 12/29/2022 00:00 12/29/2022 07:00 7.00 COMPZN, RPCOMP RURD P Continue processing 3-1/2" Tubing // Halliburton on location 03:00 confirm completion tally and prep running order for picking up tubing // 0.0 0.0 12/29/2022 07:00 12/29/2022 14:15 7.25 COMPZN, RPCOMP PUTB P RIH with completion per tally circulating every 1500' 0.0 3,000.0 12/29/2022 14:15 12/29/2022 14:45 0.50 COMPZN, RPCOMP SVRG P Service elevators and draw works. 3,000.0 3,000.0 12/29/2022 14:45 12/29/2022 17:15 2.50 COMPZN, RPCOMP PUTB P Continue RIH F/3000' T/4300' 3,000.0 4,300.0 12/29/2022 17:15 12/29/2022 17:45 0.50 COMPZN, RPCOMP CIRC P Circulate BUS 14.9# in and out. Blow down top drive 4,300.0 4,300.0 12/29/2022 17:45 12/29/2022 20:30 2.75 COMPZN, RPCOMP PUTB P Cont' RIH F/4300' T/ 5708' 4,300.0 5,708.0 Rig: NABORS 7ES RIG RELEASE DATE 1/3/2023 Page 3/6 3A-08 Report Printed: 1/26/2023 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) 12/29/2022 20:30 12/29/2022 22:00 1.50 COMPZN, RPCOMP CIRC P Circulate BUS at 2 BPM 800 PSI. Blow down top drive. 5,708.0 5,708.0 12/29/2022 22:00 12/29/2022 23:30 1.50 COMPZN, RPCOMP PUTB P Continue to RIH with completion F/5708' T/6457' 5,708.0 6,457.0 12/29/2022 23:30 12/30/2022 00:00 0.50 COMPZN, RPCOMP CIRC P Circulate SxS with 14.9# 6,457.0 6,457.0 12/30/2022 00:00 12/30/2022 01:30 1.50 COMPZN, RPCOMP CIRC P Cont. circulate SxS 14.9# 2BPM 680 PSI PUW=75K SOW=65K 6,457.0 6,457.0 12/30/2022 01:30 12/30/2022 03:00 1.50 COMPZN, RPCOMP PUTB P Continue RIH F/6457 T/6481' Set down up to 30K unable to get shear on overshot. Work completion attempt to overshot tubing stump. set down 30K 3 more times PUW=90K weight broke back to 75K unable to overshot. Discussed options with town. decided to POOH and make scraper run. 6,457.0 6,459.0 12/30/2022 03:00 12/30/2022 03:30 0.50 COMPZN, RPCOMP SFTY P Discussed plan forward and scope change hazards and mitigations with new crew. 6,459.0 6,459.0 12/30/2022 03:30 12/30/2022 04:30 1.00 COMPZN, RPCOMP RURD T Rig up to TOOH with completion. Mix dry job. 15 BBL 15.4# 6,459.0 6,459.0 12/30/2022 04:30 12/30/2022 05:00 0.50 COMPZN, RPCOMP CIRC T Pump 10 BBL dry job 6,459.0 6,459.0 12/30/2022 05:00 12/30/2022 11:30 6.50 COMPZN, RPCOMP TRIP T Start TOOH F/6459' PUW=75K T/ 65' 6,459.0 65.0 12/30/2022 11:30 12/30/2022 12:00 0.50 COMPZN, RPCOMP SVRG P Service rig 65.0 65.0 12/30/2022 12:00 12/30/2022 12:30 0.50 COMPZN, RPCOMP TRIP T Continue to rack back completion to surface 65.0 0.0 12/30/2022 12:30 12/30/2022 13:00 0.50 COMPZN, RPCOMP RURD T RD tubing handling equipment RU to PU DP. 0.0 0.0 12/30/2022 13:00 12/30/2022 14:00 1.00 COMPZN, RPCOMP RURD T Install tubing head bowl protector. 6-3/8" ID 0.0 0.0 12/30/2022 14:00 12/30/2022 15:30 1.50 COMPZN, RPCOMP RURD T Continue processing DP while clean out BHA is on the way from shop. Trucking delayed due to lack of vehicle resources. 0.0 0.0 12/30/2022 15:30 12/30/2022 17:00 1.50 COMPZN, RPCOMP RURD T Offload truck with BHA and stage in shed thaw BHA strap and put in order to pick up. 0.0 0.0 12/30/2022 17:00 12/30/2022 20:00 3.00 COMPZN, RPCOMP BHAH T PU and MU cleaout BHA 0.0 340.4 12/30/2022 20:00 12/30/2022 22:00 2.00 COMPZN, RPCOMP PULD T PU 3-1/2" DP RIH F/340.37' T/1650' 340.4 1,650.0 12/30/2022 22:00 12/30/2022 22:30 0.50 COMPZN, RPCOMP CIRC T Circulate 14.9# LSND SxS strokes 5 BPM 700 PSI Blow down top drive 1,650.0 1,650.0 12/30/2022 22:30 12/31/2022 00:00 1.50 COMPZN, RPCOMP PULD T Continue RIH F/1650 T/3100' 1,650.0 3,100.0 12/31/2022 00:00 12/31/2022 00:30 0.50 COMPZN, RPCOMP CIRC T Circulate 14.9# LSND SxS 5BPM 800 PSI blow down top drive 3,100.0 3,100.0 12/31/2022 00:30 12/31/2022 01:45 1.25 COMPZN, RPCOMP PULD T Continue to RIH W/3-1/2" DP and clean out BHA F/3100' T/4600' 3,100.0 4,600.0 12/31/2022 01:45 12/31/2022 02:15 0.50 COMPZN, RPCOMP CIRC T Circulate 14.9# LSND BUS 5 BPM = 1400 PSI 4,600.0 4,600.0 12/31/2022 02:15 12/31/2022 04:15 2.00 COMPZN, RPCOMP PULD T Continue to RIH to 6380' PUW=120K 4,600.0 6,380.0 12/31/2022 04:15 12/31/2022 05:45 1.50 COMPZN, RPCOMP SLPC T Slip and cut drilling line 6,380.0 6,380.0 12/31/2022 05:45 12/31/2022 06:15 0.50 COMPZN, RPCOMP PULD T Con't RIH to 6461' RU blower hose 6,380.0 6,461.0 Rig: NABORS 7ES RIG RELEASE DATE 1/3/2023 Page 4/6 3A-08 Report Printed: 1/26/2023 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) 12/31/2022 06:15 12/31/2022 08:30 2.25 COMPZN, RPCOMP MILL T Establish milling parameters PUW=120K SOW=100K PR=2BPM 900 PSI RPM=50 ROT=100K Con't RIH to tag at 6481' Pressure increased 1400' TQ=3.4 - 3.8K Wash and ream work down to 6483.95' adjust pump rate to 1 BPM unable to get deeper Tq=3K Shut pump off unable to get deeper set down 10K TQ=3.5K Start pumping again PR-2 BPM set down 10K = 2100 PSI unable to make any hole. PUH and ream through packer setting area from 6450' to 6350'. At bottoms up strokes sand back at shakers. RPM=47 6BPM=2100PSI TQ=2700 work across area. OA pressure increased from 200 To 750 PSI. 6,461.0 6,300.0 12/31/2022 08:30 12/31/2022 11:00 2.50 COMPZN, RPCOMP TRIP T Start TOOH F/6300' PUW=120K. Start bleeding off OA From 750 PSI mixed gas and fluid. less than 1 BBL bled off OA=200 PSI. 6,300.0 247.4 12/31/2022 11:00 12/31/2022 12:30 1.50 COMPZN, RPCOMP BHAH T C/O BHA to larger ID 5-1/2" ID Drag tooth shoe 247.4 247.4 12/31/2022 12:30 12/31/2022 17:00 4.50 COMPZN, RPCOMP TRIP T TIH F/234.22 T/6481' tagged. Conditioned hole every 1500' while TIH. to light tag at 6476'. PUW=120K SOW=100K Establish millling parameters. ROT 50 RPM=100K 3 BPM = 1000 PSI increase to 5BPM=1500 PSI. Torque=2K off 3K- 4K on top of tubing stump. 247.4 6,481.0 12/31/2022 17:00 12/31/2022 19:45 2.75 COMPZN, RPCOMP WASH T Set down 5k start washing down reciprocate DP washing down T/6484'. Adjust RPM pump rates and weight on bit several attempts made at various WOB and pump rates. unable to make torque in drill string. Unable to make it deeper. Discussed options W/town engineer decision made to TOOH and inspect BHA for wear remove string mill from BHA to get full swallow over tubing stump. made 3' of hole out of potential 11' to inner dress off mill. 6,481.0 6,484.0 12/31/2022 19:45 12/31/2022 22:15 2.50 COMPZN, RPCOMP TRIP T TOOH F/6484' PUW=120K rack back 3 stands, pump dry job, blow down top drive. Continue TOOH F/6484' T/234.2 6,484.0 234.2 12/31/2022 22:15 1/1/2023 00:00 1.75 COMPZN, RPCOMP BHAH T LD BHA to inspect inner dress off mill 234.2 0.0 1/1/2023 00:00 1/1/2023 00:30 0.50 COMPZN, RPCOMP BHAH T Inspect Drag tooth overshot/dress off BHA inner dress off mill showed signs of wear drag tooth bent over on shoe inner diameter at drag tooth 3.5" 0.0 0.0 1/1/2023 00:30 1/1/2023 01:00 0.50 COMPZN, RPCOMP SVRG T Service top drive 0.0 0.0 1/1/2023 01:00 1/1/2023 01:30 0.50 COMPZN, RPCOMP BHAH T PU/MU test packer BHA 0.0 16.5 1/1/2023 01:30 1/1/2023 03:30 2.00 COMPZN, RPCOMP RURD T Clear rig floor of all BHA tools and handling subs for BHA 16.5 16.5 1/1/2023 03:30 1/1/2023 04:00 0.50 COMPZN, RPCOMP BHAH T Inspect test packer set in running position. 0.0 16.5 Rig: NABORS 7ES RIG RELEASE DATE 1/3/2023 Page 5/6 3A-08 Report Printed: 1/26/2023 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) 1/1/2023 04:00 1/1/2023 08:00 4.00 COMPZN, RPCOMP TRIP T RIH W/ Test packer BHA F/16.5' T/6470' PUW=120K SOW=198K 16.5 6,470.0 1/1/2023 08:00 1/1/2023 09:30 1.50 COMPZN, RPCOMP PRTS T Set test packer at 6470' close annular. Pressure test 7" casing to 1000 PSI for 30 minutes. 6,470.0 6,470.0 1/1/2023 09:30 1/1/2023 15:15 5.75 COMPZN, RPCOMP PULL T Pump dry job blow down top drive. lay down D.P. F/6470 T/ 6,470.0 16.5 1/1/2023 15:15 1/1/2023 16:00 0.75 COMPZN, RPCOMP BHAH T LD Test packer 16.5 0.0 1/1/2023 16:00 1/1/2023 16:30 0.50 COMPZN, RPCOMP PULL T Pull wear ring 0.0 0.0 1/1/2023 16:30 1/1/2023 17:00 0.50 COMPZN, RPCOMP RURD P RU to run completion out of the derrick. 0.0 0.0 1/1/2023 17:00 1/1/2023 17:30 0.50 COMPZN, RPCOMP SVRG P Service top drive, draw works and roughneck. 0.0 0.0 1/1/2023 17:30 1/2/2023 00:00 6.50 COMPZN, RPCOMP RCST P Start RIH with 3-1/2" EUE 8rd completion F/surface T/5469' 0.0 5,469.0 1/2/2023 00:00 1/2/2023 01:00 1.00 COMPZN, RPCOMP RCST P Cont RIH with completion to tag at 6481.17' PUW=75K SOW=65K Set down 13K saw tattle tale pins shear bottomed out at 6484.61' 7ES RKB. PU 3' and verify travel. 5,469.0 6,484.6 1/2/2023 01:00 1/2/2023 02:15 1.25 COMPZN, RPCOMP HOSO P Space out completion laid down joint 203 and 202 PU 26.74' of pup joints; (10.21, 10.24, 6.29), PU joint 202 6,484.6 6,484.6 1/2/2023 02:15 1/2/2023 03:00 0.75 COMPZN, RPCOMP THGR P PU tubing hanger and MU to landing joint. MU to string. drain BOP stack. Land tubing hanger C/O LDS and torque to 450 Ft/Lbs. 6,484.6 6,484.6 1/2/2023 03:00 1/2/2023 03:45 0.75 COMPZN, RPCOMP PRTS P RU secondary kill to IA. Pressure up on IA under HP-BPV to 1000 PSI rolling test at 1 BPM 5 minutes. 6,484.6 6,484.6 1/2/2023 03:45 1/2/2023 10:00 6.25 COMPZN, RPCOMP RURD P Flush mud out of circulating system, jet stack, clear all choke and kill lines and gas buster of mud. Wash down floor, 6,484.6 6,484.6 1/2/2023 10:00 1/2/2023 13:30 3.50 COMPZN, WHDBOP NUND P ND BOP's NU adapter and tree. Pressrue test adapter to 5000 PSI for 10 minutes. 6,484.6 6,484.6 1/2/2023 13:30 1/2/2023 15:30 2.00 COMPZN, WHDBOP RURD P RU LRS to cement manifold in cellar RU to pump down the IA taking returns up the tubing. LRS pressure test surface lines to 5000 PSI in cellar. Pressure test tree to 5000 PSI for 10 minutes. LRS pressure test lines to kill tank to 1500 PSI for 10 minutes, pre-heat lines with warm diesel. 6,484.6 6,484.6 1/2/2023 15:30 1/2/2023 16:15 0.75 COMPZN, WHDBOP RURD P Pull HP BPV dart and plug. 6,484.6 6,484.6 1/2/2023 16:15 1/2/2023 16:30 0.25 COMPZN, WHDBOP SFTY P PJSM fro pumping CI with ASRC LRS Halliburton and Nabors. discussed procedure, hazards and mitigations. 6,484.6 6,484.6 1/2/2023 16:30 1/2/2023 16:45 0.25 COMPZN, WHDBOP RURD P RU to pump down the IA taking returns up the tubing 6,484.6 6,484.6 1/2/2023 16:45 1/2/2023 19:30 2.75 COMPZN, WHDBOP CIRC P Pump 40 BBL high vis 9.1# sweep followed with 275 BBL's 10.3# corrosion inhibited NaCl/NaBr at 2 BPM SxS. 6,484.6 6,484.6 1/2/2023 19:30 1/2/2023 20:00 0.50 COMPZN, WHDBOP RURD P Blow down secondary kill and surface lines to kill tank. 6,484.6 6,484.6 1/2/2023 20:00 1/2/2023 20:15 0.25 COMPZN, WHDBOP RURD P Set ball and rod on master valve. RU Slick line lubricator extension to tree cap. Open master valve and drop ball and rod. Close in master, blow down lubricator extension and remove from tree, install tree cap. 6,484.6 6,484.6 Rig: NABORS 7ES RIG RELEASE DATE 1/3/2023 Page 6/6 3A-08 Report Printed: 1/26/2023 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) 1/2/2023 20:15 1/2/2023 20:30 0.25 COMPZN, WHDBOP SFTY P PRE job safety meeting W/LRS, Nabors discussed setting packer, operation, hazards and mitigations. 6,484.6 6,484.6 1/2/2023 20:30 1/2/2023 22:30 2.00 COMPZN, WHDBOP PRTS P Open tubing, IA and OA Tubing=1300, IA=1000 OA=250 PSI. LRS Pressure up on tubing to1200 PSI. open up to tubing. Pressure up on tubing to 4800 PSI. Set packer and test tubing for 30 minutes. Bleed tubing back to 1500 PSI. Pressure up on IA to 2500 PSI for 30 minutes. 6,484.6 6,484.6 1/2/2023 22:30 1/3/2023 00:00 1.50 COMPZN, WHDBOP RURD P Continue cleaning pits and floor while waiting on Slick line. Secure well, move LRS off well to stage Slick-line. 6,484.6 6,484.6 1/3/2023 00:00 1/3/2023 01:15 1.25 COMPZN, WHDBOP SLKL T Continue cleaning pits and floor while waiting on Slick line. Secure well, move LRS off well to stage Slick-line. 6,484.6 6,484.6 1/3/2023 01:15 1/3/2023 01:45 0.50 COMPZN, WHDBOP SLKL T Slick line on location Held ops meeting with crew to discuss plan forward. 6,484.6 6,484.6 1/3/2023 01:45 1/3/2023 02:15 0.50 COMPZN, WHDBOP SFTY T Hold prejob safety meeting W/Nabors and Halliburton for rigging up. 6,484.6 6,484.6 1/3/2023 02:15 1/3/2023 05:30 3.25 COMPZN, WHDBOP SLKL T MIRU Slickline 6,484.6 6,484.6 1/3/2023 05:30 1/3/2023 08:30 3.00 COMPZN, WHDBOP SLKL T RIH with KOT to GLM 3 at Pull SOV @ 6347' SLM. POOH with SOV. RIH W/CV to GLM 3 set CV @ 6347' 6,484.6 6,484.6 1/3/2023 08:30 1/3/2023 10:00 1.50 COMPZN, WHDBOP SLKL T RD Slick-line 6,484.6 6,484.0 1/3/2023 10:00 1/3/2023 10:15 0.25 COMPZN, WHDBOP SFTY P PJSM LRS for FP TxIA operations, hazards and mitigations. 6,484.0 6,484.0 1/3/2023 10:15 1/3/2023 12:00 1.75 COMPZN, WHDBOP FRZP P 2BPM. LRS to pump down the IA taking returns up the tubing. Maintain1:1 returns from the tubing while circualting diesel. Isolate LRS evacuate lines and release LRS. U-Tube well for 1 hour. released rig at 12:00PM 6,484.0 6,484.0 1/3/2023 12:00 1/3/2023 13:30 1.50 DEMOB, MOVE DMOB P Cruz on location hold prejob for moving pit mod. back sow under pit. at 12:30. pulled sub off weell at 1330. Rig released @ 12:00 Hrs 6,484.0 Rig: NABORS 7ES RIG RELEASE DATE 1/3/2023 3A-08 Actual RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 88 88 16 15.06 62.5 H40 Welded Welded Surface 3161 3160 9.625 8.92 36 J55 BTC BTC Production/ Intermediate 7102 6308 7 6.28 26 J55 BTC BTC Tubing 6711 6023 3.5 2.992 9.3 L80 EUEM 8rd EUEM 8rd New COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ 2733, 5485, 6352' 3.5" x 7.0" Packer @ 6408' RKB (4" ID) 3-½" X landing nipple at 6466' RKB (2.813" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE 3.5" x 7.0" Retrievable Packer @ 6523' RKB (4" ID) 3-½" GLM at 6561' RKB Blast Rings 3-½" Sliding Sleeve at 6671' RKB (2.75") 3-1/2" x 2-7/8" Crossover 2.875" x 7.0" Permanent Packer @ 6684' RKB (4" ID) Nipple @ 6701' RKB (2.25" ID) SOS @ 6711' RKB Surface Casing Production/Intermediate Casing Conductor A-sand perfs 6752'-6888' RKB C-sand perfs 6602'-6642' RKB STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:7ES DATE:12/27/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1852240 Sundry #322-649 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/4200 Annular:250/2500 Valves:250/4200 MASP:3778 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T90 P Pit Level Indicators P P #1 Rams 1 2 7/8' x 5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 3 1/2" x 5 1/2"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)3000 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1500 P Check Valve 0 NA 200 psi Attained (sec)18 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)110 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5@1950 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 29 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0 NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/26/22 2:51am Waived By Test Start Date/Time:12/27/2022 12:30 (date)(time)Witness Test Finish Date/Time:12/27/2022 17:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Sully Sullivan Nabors Tested with 3 1/2" Test joint. Tony Morales/ Paul Yearout ConocoPhillips Mark Adams KRU 3A-08 Test Pressure (psi): tony.morales@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2022-1227_BOP_Nabors7ES_KRU_3A-08        J. Regg; 5/24/2023 RBDMS JSB 120222 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Well Integrity Specialist CPF1 & CPF3 To:Loepp, Victoria T (OGC) Cc:Earhart, Will C Subject:KRU 3A-08 (PTD 185-224) Report of IA Sustained Casing Pressure Date:Monday, June 6, 2022 12:00:52 PM Attachments:AnnComm Surveillance TIO for 3A-08.pdf Victoria, KRU 3A-08 (PTD 185-224) was reported by Operations to have exceeded the DNE on the IA on 6/4/22 and is currently at 2200 psi. The 7”, 26 lb/ft, J-55 has a burst rating of 4980 psi (45% of the burst rating= 2241 psi). CPAI plans to pump fluids down the IA to lower the IA pressure while working toward securing the well. A wellbore schematic and 90 day TIO trend are attached. Please let me know if you disagree or have any questions with the plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 3A-08 90-Day Bleed HistoryWELL DATE STR-PRES END-PRES DIF-PRES CASING Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod ByLast Tag: CTMD (Est. 113' of Rathole) 7,001.0 5/11/2020 3A-08 rogerbaLast Rev Reason Annotation End Date Wellbore Last Mod ByRev Reason: Pulled D&D Plugs 6/4/2022 3A-08 zembaejCasing StringsCasing DescriptionCONDUCTOR OD (in)16 ID (in)15.06 Top (ftKB)31.0 Set Depth (ftKB)88.0 Set Depth (TVD) …88.0 Wt/Len (lb…62.50 GradeH-40 Top ConnectionWELDEDCasing DescriptionSURFACE OD (in)9 5/8 ID (in)8.92 Top (ftKB)30.7 Set Depth (ftKB)3,160.7 Set Depth (TVD) …3,160.1 Wt/Len (lb…36.00 GradeJ-55 Top ConnectionBUTTCasing DescriptionPRODUCTION OD (in)7 ID (in)6.28 Top (ftKB)28.7 Set Depth (ftKB)7,101.8 Set Depth (TVD) …6,307.7 Wt/Len (lb…26.00 GradeJ-55 Top ConnectionBTCTubing Strings: string max indicates LONGEST segment of stringTubing DescriptionTUBING 3.5"x2.875" @ 6679'String …3 1/2 ID (in)2.99 Top (ftKB)28.7 Set Depth (ft…6,711.3 Set Depth (TVD…6,024.1 Wt (lb/ft)9.30 GradeJ-55 Top ConnectionEUE 8RDCompletion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model 28.7 28.7 0.03 HANGER 3.500 8.000 1,821.9 1,821.6 1.94 SAFETY VLV 2.810 5.937 2,268.2 2,267.8 1.34 GAS LIFT 2.920 5.312 CAMCO KBUG 3,857.1 3,847.8 15.72 GAS LIFT 2.920 5.312 CAMCO KBUG 5,162.7 4,926.0 45.01 GAS LIFT 2.920 5.312 CAMCO KBUG 6,116.2 5,598.1 45.23 GAS LIFT 2.920 5.312 CAMCO KBUG 6,461.6 5,844.3 43.86 GAS LIFT 2.875 5.960 MERLA TPDX 6,508.9 5,878.5 43.78 PBR 3.000 5.125 6,522.6 5,888.4 43.81 PACKER 3.000 6.078 6,598.2 5,942.8 43.98 BLAST RINGS 3.867 4.500 6,670.6 5,994.8 44.12 NIPPLE 2.750 4.520 6,683.6 6,004.2 44.15 LOCATOR 2.437 5.000 6,684.4 6,004.7 44.15 PACKER 3.000 6.151 6,701.2 6,016.8 44.18 NIPPLE 2.250 3.668 6,710.6 6,023.6 44.17 SOS 2.441 3.750 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,476.0 5,854.7 43.82 TUBING LEAK Relay Identified Tubing Leak @ 6476' RKB 12/20/2020 0.000 6,670.6 5,994.9 44.12 SLEEVE-C AVA 2.75" BPI set 1/4/2007 1/4/2007 2.310 Mandrel Inserts : excludes pulled inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,268.2 2,267.8 1.34 1 GAS LIFT GLV BK 0.156 1,294.0 10/4/2014 2 3,857.1 3,847.8 15.72 1 GAS LIFT GLV BK 0.156 1,274.0 10/4/2014 3 5,162.7 4,926.0 45.01 1 GAS LIFT GLV BK 0.188 1,254.0 10/4/2014 4 6,116.2 5,598.1 45.23 1 GAS LIFT OV BK 0.188 0.0 5/12/2019 5 6,461.6 5,844.3 43.86 1 1/2 GAS LIFT DMY RM 0.000 0.0 9/15/2015 6 6,561.1 5,916.1 43.89 1 PROD DMY BK 0.000 0.0 4/28/1997 Close d Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,602.0 6,642.0 5,945.6 5,974.3 C-4, C-3, C-1, UNIT B, 3A-08 11/24/1985 12.0 IPERF 120 deg phase; 5" Csg Gun 6,752.0 6,772.0 6,053.3 6,067.6 A-3, 3A-08 11/24/1985 4.0 IPERF 90 deg phase; 4" Csg Gun 6,786.0 6,842.0 6,077.7 6,118.0 A-2, 3A-08 11/24/1985 4.0 IPERF 90 deg phase; 4" Csg Gun 6,882.0 6,888.0 6,146.9 6,151.2 A-1, 3A-08 11/24/1985 4.0 IPERF 90 deg phase; 4" Csg Gun Notes: General & Safety End Date Annotation 12/30/2003 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 3A-08, 6/5/2022 7:01:57 AMVertical schematic (actual) PRODUCTION; 28.6-7,101.8 IPERF; 6,882.0-6,888.0 IPERF; 6,786.0-6,842.0 IPERF; 6,752.0-6,772.0 SOS; 6,710.6 NIPPLE; 6,701.1 PACKER; 6,684.3 LOCATOR; 6,683.5 SLEEVE-C; 6,670.6 NIPPLE; 6,670.6 IPERF; 6,602.0-6,642.0 PRODUCTION; 6,561.1 PACKER; 6,522.6 PBR; 6,508.9 TUBING LEAK; 6,476.0 GAS LIFT; 6,461.6 GAS LIFT; 6,116.2 GAS LIFT; 5,162.7 GAS LIFT; 3,857.1 SURFACE; 30.7-3,160.7 GAS LIFT; 2,268.2 SAFETY VLV; 1,821.9CONDUCTOR; 31.0-88.0HANGER; 28.7 KUP PROD KB-Grd (ft)36.62 RR Date11/1/1985 Other Elev…3A-08...TDAct Btm (ftKB)7,120.0Well AttributesField NameKUPARUK RIVER UNIT Wellbore API/UWI500292144500 Wellbore StatusPROD Max Angle & MDIncl (°)45.53 MD (ftKB)5,000.00WELLNAME WELLBORE3A-08 AnnotationLast WO:End DateH2S (ppm)235 Date1/9/2015CommentSSSV: LOCKED OUT C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-27_22026_KRU_3A-08_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22026 KRU 3A-08 50-029-21445-00 LeakPoint Survey 27-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 185-224 T36685 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.03 15:01:08 -08'00' Originated: Delivered to:23-Nov-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1F-17 50-029-22657-00 907483748 Kuparuk River Leak Detect Log Field- Final 1-Nov-21 0 12 1F-17 50-029-22657-00 907483748 Kuparuk River Multi Finger Caliper Field & Processed 2-Nov-21 0 13 3A-08 50-029-21445-00 907479053 Kuparuk River Packer Setting Record Field- Final 29-Oct-21 0 14 3C-17 50-029-23389-00 n/a Kuparuk River Packer Setting Record Field- Final 20-Nov-21 0 15 3F-13 50-029-21499-01 907473188 Kuparuk River Leak Detect Log Field- Final 28-Oct-21 0 16 3F-13 50-029-21499-01 907473188 Kuparuk River Plug Setting Record Field- Final 28-Oct-21 0 17 3H-08 50-103-20080-00 907467555 Kuparuk River Packer Setting Record Field- Final 22-Oct-21 0 18 3H-08 50-103-20080-00 907467555 Kuparuk River Packer Setting Record Field- Final 25-Oct-21 0 1910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:11/23/2021Wd͗ϭϴϱϮϮϰϬͲ^Ğƚ͗ϯϱϵϳϭBy Abby Bell at 3:04 pm, Nov 23, 2021 Originated: Delivered to:22-Sep-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 2V-11 50-029-21311-00 907365411 Kuparuk River Leak Detect Log Field- Final 3-Sep-21 0 12 2V-11 50-029-21311-00 907373122 Kuparuk River Multi Finger Caliper Field & Processed 4-Sep-21 0 13 2V-11 50-029-21311-00 907365411 Kuparuk River Plug Setting Record Field- Final 2-Sep-21 0 14 2V-13 50-029-21293-00 907373111 Kuparuk River Plug Setting Record Field- Final 7-Sep-21 0 15 3A-08 50-029-21445-00 907327765 Kuparuk River Packer Setting Record Field- Final 13-Aug-21 0 16 3C-17 50-029-23389-00 907330662 Kuparuk River Multi Finger Caliper Field & Processed 15-Aug-21 0 17 3H-01 50-103-20084-00 907344061 Kuparuk River Plug Setting Record Field- Final 24-Aug-21 0 18 3H-01 50-103-20084-00 907344061 Kuparuk River String Shot Record Field- Final 24-Aug-21 0 19 3H-01 50-103-20084-00 907344061 Kuparuk River Tubing Punch Record Field- Final 24-Aug-21 0 110 3H-14B 50-103-20092-02 907358282 Kuparuk River Multi Finger Caliper Field & Processed 29-Aug-21 0 111 3Q-09 50-029-21674-00 907349862 Kuparuk River Multi Finger Caliper Field & Processed 25-Aug-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:09/23/2021Wd͗ϭϴϱϮϮϰϬͲ^Ğƚ͗ϯϱϳϭϯBy Abby Bell at 10:25 am, Sep 23, 2021 Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1J-170 50-029-23310-00 906951584 West Sak Injection Profile Field & Processed 30-Jan-21 0 1 2 1J-176 50-029-23364-00 906948912 West Sak Injection Profile with TMD3D Field & Processed 29-Jan-21 0 1 3 1J-180 50-029-23329-00 906811709 West Sak Injection Profile with TMD3D Field & Processed 27-Jan-21 0 1 4 1Y-19 50-029-22391-00 906880907 Kuparuk River Packer Setting Record Field- Final 3-Jan-21 0 1 5 2H-09 50-103-20050-00 906910408 Kuparuk River Multi Finger Caliper Field & Processed 8-Jan-21 0 1 6 2H-09 50-103-20050-00 906960677 Kuparuk River Packer Setting Record Field- Final 3-Feb-21 0 1 7 2N-333 50-103-20525-00 906882125 Kuparuk River Multi Finger Caliper Field & Processed 21-Dec-20 0 1 8 3A-08 50-029-21445-00 906879883 Kuparuk River Leak Detect Log Field- Final 20-Dec-20 0 1 9 3B-06 50-029-21336-00 906905927 Kuparuk River Leak Detect Log Field- Final 5-Jan-21 0 1 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 1852240 E-Set: 34734 Originated:Delivered to:19-Aug-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Sari 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 Leak Detect Log 2 Plug Setting Record 3 2L-310 50-103-20616-00 906449149 Tarn Packer Setting Record Field-Final 13-Apr-20 0 1 4 2T-37 50-103-20227-00 906480199 Kuparuk Plug Setting Record Field-Final 30-Apr-20 0 1 5 3A-08 50-029-21445-00 906499970 Kuparuk Plug Setting Record Field-Final 17-May-20 0 1 6 Multi Finger Caliper Field-Processed 26-May-20 7 Packer Setting Record Field-Final 27-May-20 8 3H-14B 50-103-20092-02 906486722 Kuparuk Packer Setting Record Field-Final 7-May-20 0 1 9 3K-03 50-029-21602-00 906531280 Kuparuk Plug Setting Record Field-Final 29-May-20 0 1 10 3A-08 50-029-21445-00 906499689 Kuparuk Multi Finger Caliper Field-Processed 16-May-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: 1 3H-03 50-103-20085-00 n/a Kuparuk 0 1 Transmittal Date: 2H-09 50-103-20050-00 906426492 Kuparuk Field-Final 5-Apr-20 0 08/26/2020 Abby Bell Received by the AOGCC 08/26/2020 PTD: 1852240 E-Set: 33691 Originated:Delivered to:19-Aug-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Sari 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 Leak Detect Log 2 Plug Setting Record 3 2L-310 50-103-20616-00 906449149 Tarn Packer Setting Record Field-Final 13-Apr-20 0 1 4 2T-37 50-103-20227-00 906480199 Kuparuk Plug Setting Record Field-Final 30-Apr-20 0 1 5 3A-08 50-029-21445-00 906499970 Kuparuk Plug Setting Record Field-Final 17-May-20 0 1 6 Multi Finger Caliper Field-Processed 26-May-20 7 Packer Setting Record Field-Final 27-May-20 8 3H-14B 50-103-20092-02 906486722 Kuparuk Packer Setting Record Field-Final 7-May-20 0 1 9 3K-03 50-029-21602-00 906531280 Kuparuk Plug Setting Record Field-Final 29-May-20 0 1 10 3A-08 50-029-21445-00 906499689 Kuparuk Multi Finger Caliper Field-Processed 16-May-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: 1 3H-03 50-103-20085-00 n/a Kuparuk 0 1 Transmittal Date: 2H-09 50-103-20050-00 906426492 Kuparuk Field-Final 5-Apr-20 0 08/26/2020 Abby Bell Received by the AOGCC 08/26/2020 PTD: 1852240 E-Set: 33690 Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: RECEIVE® APR 2 3 2020 A®GCC 188224 32803 23 -Apr -20 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date: Signed: L.. WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # CD # 1 3A-08 50-029-21445-00 Kuparuk Multi Finger Caliper Final -Field 15 -Feb -20 0 1 2 3K-23 50-029-22771-00 906323212 Kuparuk p Radial Cement Bond Log Final -Field 18 -Feb -20 0 1 3 SBHP and Plug Setting Record 21 -Jan -20 4 906290370 String Shot Record 2 -Feb -20 5 906290370 Tubing Punch Record 3 -Feb -20 6 3K-27 50-029-22751-00 Kuparuk Packer Set Record Final -Field 30 -Dec -19 0 1 3N-09 50-029-21541-00 905268412 Kuparuk Packer Set Record Final -Field 4 -Feb -20 0 1 8 10 -Feb -20 9 3N-15 50-029-21592-00 906251137 IKuparuk Packer Set Record Final -Field 18 -Jan -20 0 1 10 3M-17 50-029-21729-00 906236139 IKuparuk I Packer Set Record Final -Field 19 -Feb -20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date: Signed: L.. u ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~~~~ ~- <~~ ^ QI~ ~0~~, acs:: t. p`,~.~ ~CliO~~~~ APR ~ gip. E~:;~ ~~V` ~~~ ~~ ~~, Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 27~' and 30~', 2009. The corrosion inhibitor/sealant was pumped April 6~' and 15~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Kv leinr ConocoPhillips Well Integrity Projects Supervisor r~ u ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off .~-- ~ Report of Sundry Operations (10-404) Kuparuk Field Date 411 712 0 0 9 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-01 185-186 28" NA 28" NA 3.50 4/15/2009 3A-03B 207-131 11' 1.50 25" 3/27/2009 4.80 4/15/2009 3A-05 185-221 30' 4.10 26" 3/27/2009 7.70 4/15/2009 3A-06 185-222 12' 2.00 19" 3/27/2009 2.60 4/15/2009 3A-08 185-224 22" NA 22" NA 3.10 4/15/2009 3A-09 181-194 SF NA 13" NA 2.55 4/6/2009 3A-10 185-237 16' 2.50 25" 3/27/2009 5.95 4/6/2009 3A-11 185-238 SF NA 20" NA 2.55 4/6/2009 3A-12 185-239 SF NA 13" NA 1.00 4/6/2009 3A-13 185-281 18'8" 1.00 32" 3/30/2009 7.70 4/6/2009 3A-14 185-282 13' 3.00 20" 3/30/2009 9.35 4/6/2009 3A-15 185-283 NA NA 2.60 4/15/2009 3A-17 196-132 3'6" NA 3'6" NA 12.75 4/6/2009 3A-18 196-133 11'10" 2.00 9" 3/30/2009 2.55 4/6/2009 RECE\VED A,U~ () ~ 2006 08/01/06 Scblumberger ~ Oil & Gas Cons. Comm~n ,A,nchorage NO. 3899 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth " ~/ .:(-- !:; ::)(,(" OJ-00 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 SCl\,N¡..¡r':!J. -."-'-" "¡'-' ..,~- C J. I.:: 2005 ~.A "_ ~ Kuparuk Field: Well Job # Color Log Description Date BL CD 1J-101 (REDO) 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 1 D-125A (REDO) 11213778 INJECTION PROFILE 07ì1i/06 1 2K-24 (REDO) 11213781 INJECTION PROFILE 07/20/06 1 1 G-05 11249932 INJECTION PROFILE 07/28/06 1 3A-08 11249933 PROD PROFILE W/DEFT 07/29/06 1 1 D-117 11216305 INJECTION PROFILE 07/08/06 1 3F-18 11235384 SBHP SURVEY 07/25/06 1 3F-17 11235383 BHP SURVEY 07/25/06 1 1Y-32 11213707 SBHP LOG 07/25/06 1 3G-25X 11216313 PROD PROFILE W/DEFT 07/31/06 1 1 Y -24A 11216315 GLS/FBHP SURVEY 08/01/06 1 1 R-36 11249931 LDL 07/27/06 1 2V-10 11216311 SBHP SURVEY 07/28/06 1 1 D-1 07 11216309 INJECTION PROFILE 07/12/06 1 1 D-130 11249928 INJECTION PROFILE 07/09/06 1 31-03 11213788 PROD PROFILE W/DEFT 07/26/06 1 1 Y -05 11216310 LDL 07/27/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission- TO: Julie Heusser, Commissioner DATE: January 7, 2001 THRU: FROM: Tom Maunder, P. I. Supervisor ~j o~.,- o \ Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 3A & 3B Pads Sunday, January 7, 2001: I traveled to the Kuparuk River Field and witnessed the semi-annual safety valve system testing on 3A & 3B Pads. As the attached AOGCC Safety valve sYstem Test Reports indicat® I witnessed the testing of 8 wells and 16 components on 3A Pad and 6 wells and 12 components on 3B Pad with 1 failure observed. The surface safety valve on well 3A-08 had a slow leak when pressure tested. This valve will be serviced and retested by the operator. John Arend conducted the testing today he demonstrated good test procedure and was a pleasure to work with The wellhouses on these two pads were very clean and all related equipment appeared to be in good condition..' Summary: I witnessed the semi annual SVS testing at 3A & 3B Pads in the Kuparuk River Field. KRU 3A Pad, 8 wells, 16 components, KRU 3B Pad, 6 wells, 12 components, 19 wellhouse inspections 1 failure 0 failures Attachment: SVS KRU 3A Pad 1-7-01 CS SVS KRU 3B Pad: 1-7-01 CS X Unclassified Confidential (Unclassified if doc. Removed) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: John Arend AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: FieldfUnit~ad: KUparuk / KRU / 3A Pad Separator psi: LPS 64 HPS 1/7/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GlNJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 3A-01 1851860 64 70 50 p P OIL 3A-03 1852060 ,3A-05 1852210 64 70 50 P P OIL 3A-08 1852240 64 70 60 P 4 OIL 3A-09 1811940 64 70 60 P P OIL 3A-12 1852390 64 70 60 P P OIL 3A-13 1852810 64 70 40 P P OIL 3A-16 1852840 64 70 70 p P OIL . 3A-17 1961320 3A-18 1961330 64 70 50 p P OIL . Wells: 8 Components: 16 Failures: 1 Failure Rate: 6.3% [] 90 oar Remarks: Surface Safety Valve on well 3A-08 had a slow leak when tested, vzlve to be service retested by operator. 1/9/01 Page 1 of 1 SVS KRU 3A Pad 1-7-01 CS.xlS Alaska Oil and Gas ConserVation CommiSsion Safety Valve System Test Report Operator: Phillips Operator Rep: John Arend AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupamk / KRU / 3B Pad Separator psi: LPS 64 HPS 1/7/01 Well Permit Separ Set LfP Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLe. 3B-03 1850600 64 70 60, P P OIL · 3B-04 1850610 64 70 50 : P P OIL 3B-06 1850760 64! 70 50 P P OIL , , 3B-08 1850870 3B-09 1851130 64 70 70 P P OIL 3B-11 1851150 64 70 50 P P OIL! 3B-13 1850230 · 3B-14 1850240 Wells: 6 Components: 12 Failures: 0 Failure Rate: [] oo Day Remarks: Good Test - 1/9/01 Page 1 of 1 SVS KRU 3B Pad 1-7-01 CS.xls STATE OF ALASKA ~SKA OIL AND GAS CONSERVATION COMMiSsION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate X Plugging Perforate -- Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _~X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 647' FSL, 781' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1156' FNL, 1182' FEL, Sec. 18, T12N, R9E, UM At effective depth 1441' FNL, 1225' FEL, Sec. 18, T12N, R9E, UM At total depth 1513' FNL, 1239' FEL, Sec. 18, T12N, R9E, UM 12. 6. Datum elevation (DF or KB) RKB 73 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-08 9. Permit number/approval number 85-224 10. APl number 50-029-21445-00 11. Field/Pool feet Present well condition summary Total Depth: measured 71 2 0 feet true vertical 6320 feet Effective depth: measured 7 01 2 feet true vertical 6241 feet Casing Length Size Structural Conductor 8 0' 1 6" Surface 31 0 0' 9 - 5 / 8" Intermediate Production 7073' 7" Liner Perforation depth: measured 6602'-6642', true vertical 5945'-5974', Plugs (measured) Kuparuk River Field/Oil Pool None R ~C E ~ V ~ i~.-~ JU{'.-,J I 1997 Junk (measured) None 4!aS~ QJ_! .& Gas GoDs. Cemented Measured depth True 195 Sx AS II 85' 880SxASIII& 3161' 270 Sx Class G w/100 Sx AS II top job 325 Sx Class G & 71 0 2' 175 Sx AS I 85' 3161' 6307' 6757'-6772', 6786'-6827', 6882'-6888' 6056'-6067', 6077'-6106', 6146'-6150' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 6702' Packers and SSSV (type and measured depth) Pkr's: Baker FHL @ 6513' & Baker FB-1 @ 6674'; SSSV: Baker FVL @ 1812', Otis FXE WRDP (Out of well) ORI61NA 13. Stimulation or cement squeeze summary Fracture stimulate "C" sand on 4/11/97. Intervals treated (measured) 6602'-6642' Treatment description including volumes used and final pressure Pumped 47.9 M lbs 20/40, 12/18, & 10/14 ceramic proppant into formation, fp was 4300 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 809 639 59 1252 176 Subsequent to operation 956 360 0 1271 129 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. F° rm,~1~4/'l~ey'/067¢'5/'~8 / I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent Date 0/~ ~'-('~ ~ /~ SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~ K1(3A-08(W4-6)) WELL JOB SCOPE JOB NUMBER 3A-08 FRAC, FRAC SUPPORT 0113970937.8 DATE DAILY WORK UNIT NUMBER 04/11/97 "C" SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~ Yes O NoI (~) Yes O No DS-YOAKUM CHANEY FIELD AFC_~ CCff DALLY COST ACCUM COST S~ned ESTIMATE KD1763 23ODS36AL $76,999 $84,796 Initial Tb_q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Out~r-Anri I-"Fi'nal Outer Ann 50 PSI 1 500 PSI 600 PSI 500 PSII 425 PSI~ 60,..015Sl DAILY SUMMARY "C" SAND FRAC COMPLETED THRU FLUSH. INJECTED 47894 LBS IN THE FORMATION. W/6# PPA OF #10/14 @ PERF'S. MAX PRESSURE 4300 PSI. F.G. (.67). FREEZE PROTECTED W/DIESEL DOWN TO 4600'. TIME 06:30 08:00 08:45 09:45 10:45 LOG ENTRY MIRU FRAC EQUIP, APC VAC TRK, AND LRS HOT OIL TRK. HELD SAFETY MEETING (16 ON LOCATION) PT'D BACKSIDE LINES TO 4000 PSI AND PRESSURED UP INNER CSG AS NEEDED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 8200 PI. PUMP BREAKDOWN W/ 50# DELAYED XL GW @ 20 TO 10 BPM. VOLUME PUMPED 192 BBLS. MAXIMUM PRESSURE 4300 PSI AND ENDING PRESSURE 1930 PSI. S/D AND OBTAINED ISlP OF 1395 PSI AND F.G. @ (.68). STOOD-BY AND MONITORED WHTP FOR CLOSURE. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 10 BPM. VOLUME PUMPED 145 BBLS. MAXIMUM PRESSURE 3062 PSI AND ENDING PRESSURE 1876 PSI. S/D AND OBTAINED ISlP OF 1267 PSI AND F.G. @ (.66) PUMP FRAC W/50# DELAYED XL GW @ 5 TO 10 BPM. COMPLETED THRU FLUSH. VOLUME PUMPED 467 BBLS. MAXIMUM PRESSURE 3400 PSI AND ENDING PRESSURE 2900 PSI. S/D AND MONITORED WHTP FOR 10 MINS. PUMPED 48294 LBS (4600 LBS OF #20/40, 37900 LBS OF #12/18, 5794 LBS OF #10/14). INJECTED 47894 LBS IN THE FORMATION, W/6# PPA OF #10/14 @ PERF'S. LEFT 400 LBS OF PROP IN THE WELLBORE. FREEZE PROTECTED W/DIESEL DOWN TO 4600°. 12:00 STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D LRS HOT OIL TRK. 12:30 13:30 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. R/D COMPLETE AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $252.00 APC $4,700.00 $4,700.00 DIES EL $400.00 $400.00 DOWELL $70,360.00 $70,360.00 HALLIBURTON $0.00 $5,500.00 LITTLE RED $1,540.00 $3,585.00 TOTAL FIELD ESTIMATE $77,000.00 $84,797.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 647' FSL, 781' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1156' FNL, 1182' FEL, Sec. 18, T12N, At effective depth 1441' FNL, 1225' FEL, Sec. 18, T12N, At total depth 1513' FNL, 1239' FEL, Sec. 18, T12N, 12. Present well condition summary Total Depth: measured 71 true vertical 6 3 R9E, UM R9E, UM 6. Datum elevation (DF or KB) RKB 73 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-08 9. Permit number/approval number 85-224 10. APl number 5o-029-21445-00 11. Field/Pool Kuparuk River Field/Oil Pool R9E, UM 20 feet 20 feet Plugs (measured) None Effective depth: measured 7 0 1 2 true vertical 6 2 41 feet Junk (measured) None feet Casing Length Structural Conductor 8 0' Surface 31 0 0' Intermediate Production 7073' Liner Pedoration depth: measured 6602'-6642', true vertical 5945'-5974', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 6702' Packers and SSSV (type and measured depth) Size 16" 9-5/8" 7" Cemented Measured depth True vertical depth 195 Sx AS II 85' 85' 880SxAS III& 3161' 3161' 270Sx Class G w/100 Sx AS Iltopjob 325 Sx Class G & 71 0 2' 6 3 0 7' 175 Sx AS I ~ ',-~ .... 6757'-6772', 6786'-6827', 6882'-6888' 6056'-6067', 6077'-6106', 6146'-6150' ,,_t' 1997 Pkr's: Baker FHL @ 6513' & Baker FB-1 @ 6674'; SSSV: Baker FVL @ 1812', Otis FXE WRDP (Out of well) 13. Stimulation or cement squeeze summary Refracture "A" sands on 7/16/96 Intervals treated (measured) ORIGINAL 6757'-6772', 6786'-6827', 6882'-6888' Treatment description including volumes used and final pressure Pumped 48.5 M lbs 20/40, 12/18, & 10/14 ceramic proppant into formation, fp was 1735 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 728 526 923 779 198 Subsequent to operation 1188 873 760 798 195 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned .~:2..¢~'~ ~ ~ ,,,,T~ Form 10-404 Lit:lev 06/15/88 Title Wells Superintendent Date 4-9-97 SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(3A-0.8(W4-6)) WELL JOB SCOPE JOB NUMBER 3A-08 FRAC, FRAC SUPPORT 0708961559.4 DATE DAILY WORK UNIT NUMBER 07/1 6/96 A-SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISC):R. ×- ,. 4 (~) Yes q'~ No, (~) Yes O No DS-GALLEGOS PEN,,P~,~,/,.// ESTIMATE KM1307 23ODS36AL $76,852 $95,645 Initial Tb~ Press Final Tbq Press Initial tnner Ann Final Inner Ann I Initial Out . r Ann 0 PSI 900 PSI 500 PSI 500 PSI 330 PSI 71 0 PSI DAILY SUMMARY IFRAC'D 'C' SAND AS DESIGNED. PLACED 48,455 LBS SAND BEHIND PIPE, LEFT 400 LBS IN WELLBORE. TOP 3,700' OF TBG IS DIESEL-FILLED. USED 4,076 LBS 20/40, 38,107 LBS 12/18, AND 6,672 LBS 10/14 PROPPANT. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP & APC SUPPORT EQUIP. 08:30 HOLD PRE-JOB SAFETY MEETING, WORK UP AND QC FLUIDS, PRIME PUMPING EQUIP. 09:15 TREE SAVER WILL NOT STROKE OUT. TEAR DOWN AND SERVICE. RE-INSTALL ON TREE AND PRESSURE UP - SET OK. 11:15 RE-PRIME PUMPING EQUIP AND PRESSURE TEST TO 9,200 PSI. 11:30 START PUMPING BREAKDOWN/CONDITIONING STAGE. PUMPED PER PROGRAM. 11:45 END BREAKDOWN/CONDITIONING STAGE, S/D. FFP = 2,110 PSI, ISIP = 1,414 PSI. CONDUCT PULSE TESTING, MONITOR WHP. 12:40 START DATAFRAC. PUMPED PER PROGRAM. 12:55 END DATAFRAC, S/D. FFP = 2,101 PSI, ISIP = 1,410 PSI. MONITOR WHP, CALCULATE PAD. 14:00 START FRAC - PUMP PAD. PUMP 37 BBLS @ 5 BPM. 14:05 END PAD, START ADDING 20/40 PROPPANT @ 2 PPA. PUMP 29 BBLS @ 5 BPM. 14:10 INCREASE RATE TO 10 BPM, PUMP 21 ADDITIONAL BBLS. 14:15 SWITCH TO 12/18 PROPPANT. PUMP 273 BBLS @ 10 BPM WHILE RAMPING PROPPANT CONCENTRATION FROM 2 PPA TO 6 PPA. 14:40 SWITCH TO 10/14 PROPPANT. PUMP 39 BBLS @ 6 PPA, 10 BPM. 14:45 SWITCH TO FLUSH. PUMP 11 BBLS XL GEL H20 @ 10 BPM. 14:46 SWITCH TO NON-XL GEL H20. PUMP 7 BBLS @ 10 BPM. 14:47 SWITCH TO DIESEL. PUMP 39 BBLS @ 10 BPM. 4:50 END DIESEL FLUSH, S/D. FFP = 2,939 PSI, ISlP = 2,009 PSI. MONITOR WHP. 15:05 END PRESSURE MONITORINfG?i Fi'¢ L:. i,735 PSI. RDMO DOWEL & APC. 17:00 WELL SECURE AND EVERYBODY OFF LOCATION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $381.00 APC $6,060.00 $9,660.00 APC-PUMPING $0.00 $450.00 ARCO $249.00 $249.00 DOWELL $70,543.00 $79,565.00 HALLIBURTON $0.00 $4,575.00 LITTLE RED $0.00 $765.00 TOTAL FIELD ESTIMATE $76,852.00 $95,645.00 ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 12, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Report of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. WELL ACTION 3 A- 0 8 Stimulate 3A- 1 6 Stimulate 3 H- 0 8 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer CC: KOE Manager ATe 1120 KeEl .4-9 w/o attachments ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company AIR3B-6003-C STATE OF ALA,SKA ~ OIL AND GAS ~RVATION ~MI~iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 647' FSL, 781' FEL Sec 7, T12N, R9E, UM At top of productive interval 1156' FNL, 1182' FEL, Sec 18, T12N, R9E, UM At effective depth 5. Type of Well: Development Exploratory Stratigraphic Service At total depth 1513' FNL~ 1239' FEL, Sec. 18, T12N, R9E~ UM 12. Present well condition summary Total Depth: measured 7120 feet true vertical 6320 feet Plugs (measured) None 6. Datum elevation (DF or KB) RKB 73 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-08 9. Permit number/approval number 85-224 10. APl number 5o-029-2144,5 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7012 feet true vertical 6241 feet Junk (measured) None Casing Length Size Structural Conductor 8 5 1 6" Surface 31 61 9 5/8" Intermediate Production 71 0 2 7 Liner Perforation depth: measured 6602-6642, true vertical 5946-5974, Tubing (size, grade, and measured depth) 3 1/2', 9 3# J-55 EUE @ 6702' Packers and SSSV (type and measured depth) Cemented 195 Sx AS II 880 Sx AS III & 270 Sx Class G 100 Sx AS II Top Job 325 Sx Class G & 175 Sx AS I 6752-6772, 6053-6068, 6786-6842, 6078-6118, Baker FHL Packer @ 6513'/Baker FB-1 @ 6674'/Baker FVL SSSV @ 1812' Measured depth 85' 3161' 7102' 6882-6888 6147-6151 True vertical depth 85' 3160' 63O8 13. Stimulation or cement squeeze summary A Sand refracture treatment. See attached well service report Intervals treated (measured) 6752-6772, 6786-6842, 6882-6888 Treatment description including volumes used and final pressure 64.8 Mlbs 12/18 Carbo-lite in formation w/550 bbl GW pad & 383 bbl treatment, FP=5800 psi 14. Reoresentative Daily Averaoe Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 4 0 0 3 0 0 4 7 5 0 Subsequent to operation 21 0 0 2 8 7 5 2 9 0 0 .... t~a.. C,.~,o. Co~nmissioo ch0raga Tubing Pressure 100 20O 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector m Oil ...X Gas Suspended Service hereb rtify that the foregoing is true and correct to the best of my knowledge. Signed - Title Senior Operations Engineer Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, Inc~ ~ WELL SERVICE REPORT ~C~lb,sjdiary of Atlantic Richfield Compan'; WEL~' -- / /~/ ~-:PBDT-' / FIELD-DISTRICT-STATE .-~,,~-- IDAYS ~DATE/ 'ONTRACTOR' ~ ~ /OPERATION AT REPORT TIME [-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL CAMCO , , OTIS · SCHLUMBERGER = , DRESSER-ATLAS DOWELL /~~ ' HALLIBURTON' ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts .'+', ~ ~-~-..~.~&~v-~/~.....-- Supe~ision .. Pr~Job Safety M~ting AFE STATE OF ALASKA AI_Ab--r,:A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ Other ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _~X Exploratory _ Stratigraphic _ Service i 4. Location of well at surface 647' FSL, 781' FEL Sec 7, T12N, R9E, UM At top of productive interval 1156' FNL, 1182' FEL, Sec. 18, T12N, R9E, UM At effective depth At total depth 1513' FNL, 1239' FEL, Sec. 18, T12N, R9E, UM Present well condition summary Total Depth: measured 71 2 0 true vertical 6 3 2 0 Effective depth: measured 7 0 1 2 true vertical 624 1 ' Casing Leng'~h Size Structural Conductor 8 5 I 6" Surface 31 61 9 5/8" Intermediate 7102 7" measured 6602'-6642, feet Plugs (measured) feet Cement: feet Junk (measured) feet None . Cemented 195 Sx AS II 880 Sx AS III & 270 Sx Class G 100 Sx AS II Top Job 325 Sx Class G 175 Sx AS I 6. Datum elevation (DF or KB) RKB 7,3 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3A-08 9. Permit number/A~¢,r¢~,.~t ~ ,/ 85-224 10. APl number 5o-020-21 44,5 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 85' 85' 3161' 3160' 7102' 63O8' 6752'-6772, 6786'-6827, 6882'-6888' Production Liner Perforation depth: 12. true vertical 5946'-5974', 6053'-6068, 6078'-6107, 6147'-6151' Tubing (size, grade, and measured depth 3 1/2", 9.3# J-55 EUE @ 6702' Packers and SSSV (type and measured depth) Baker FHL Packer @ 6513'/Baker FB-1 packer @ 6674'/Baker FVL SSSV @ 1812' 13. Stimulation or cement squeeze summary Intervals treated (measured) 6602-6642 Treatment description including volumes used and final pressure See attached stimulation summary Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 535 329 0 614 526 376 0 587 Tubing Pressure 111 126 16. Status of well classification as: Oil X Gas Suspended Service 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date /~///~/~ 5 SUBMIT IN DUPLICATE Form 10-404 ~'Rev 06/15/88 Title Sr. Operations Engineer ARCO Alaska, Inc ~ WELL SERVICE REPORT · Subsidiary of Atlantic Richfield Coml3any - [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather IT®mP'Re,ort 'F ChlllFactor.Vi$lbilitY. F. miles Iwind vel' kllOt$~:~ - ARCO Alaska, Inc Post Office ~,~,.,× 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 8, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 .Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells: WsII Action Anticipated Start Date 3 A- 0 8 Acidize 1 A-1 3 Conversion September, 1 989 October, 1989 If you have any questions, please call me at 265-6840. Sincerely, G. B. Sma'llwood Senior Operations Engineer co: J. Gruber ATO 1478 J. R. Brandstetter ATO 1120 L. Perini ATO 1130 KOE1.4-9 w/o attachments ARCO Alaska, Inc. is a Subsidiary ct AtlanticRichfieldCompany STATE OF ALASKA AI.:.~,-dKA OIL AND GAS CONSERVATION COMtvii~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 647' FSL, 781' FEL Sec 7, T12N, R9E, UM At top of productive interval 1156' FNL, 1182' FEL, Sec. 18, T12N, R9E, UM At effective depth At total depth 1513' FNL, 1239' FEL, Sec. 18, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 71 20 feet Plugs (measured) 6 3 2 0 feet Cement: 6. Datum elevation (DF or KB) RKB 7,3 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3A-08 9. Permit number 85-224 10. APl number 50-02cj-21 445 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 701 2 feet Junk (measured) 6 2 41 ' feet None Casing Length Size Structural Conductor 8 5 2 4" Surface 31 61 12 Intermediate 1/4" Production Liner Perforation depth: 7102 measured 6602'-6642, 8 1/2" true vertical 5946'-5974', Tubing (size, grade, and measured depth 3 1/2", 9.3# J-55 EUE @ 6702' Packers and SSSV (type and measured depth) 6752'-6772, 6053'-6068, Cemented Measured depth 195 Sx AS II 880 Sx AS III & 270 Sx Class CT 100 Sx AS II Top Job 325 Sx Class G 175 Sx AS I 85' 3161' 7102' 6786'-6827, 6078'-6107, True vertical depth 85' 3160' 6308' 6882'-6888' Baker FHL Packer @ 6513'/Baker FB-1 packer @ 6674'/Baker FVL SSSV @ 1812' 13. Attachments HCL Acid Stimulation of C Sand. Expected BHTP equals 2,500 psi. No workover fluids required. 14. Estimated date for commencing operation 115. Status of well classification as: I Oil X Gas __ Name of approver Date approved Service ~ Description summary of proposal X Detailed operation program _ BOP sketch ~X September 5, 1989 16. If proposal was verbally approved Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~_.m_ ~7 /~ ~~~,-a'~ '~itleSr.FOR COMMISSIoNOperati°nSuSEEngineeroNLY Conditions of approval' Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIE O. SMITH [IAppr°val 10- ~'~/~ Approved Copy Returned ~ Commissioner Date ~/' SUBMIT IN TRIPLICATE HCL ACID STIMULATION , . . . . , MIRU CTU, Nitrogen, and Acidizing equipment. Pressure Test Equipment. Titrate 12% HCI. RIH with CT to approximately 6650' (just above AVA ports). Pump the following matrix stimulation treatment via CT. Maintain pressures below that needed to fracture the formation (BHTP < 3930 psi @ 5870' TVD, CT/Tbg annulus pressure < 1900 psi assuming diesel in CT/Tbg annulus ): 1. Displacement: 2. Preflush: 3. Acid Stage #1: 4. Overflush: 5. Divert: 6. Acid Stage #2: (*) 7. Overflush: 8. Purge: Approx 40 bbls diesel, circulated while RIH until diesel returns seen @ surface 15 bbls xylene 15 bbls of 12% HCI (including additives) energized with 400 SCF/bbl of N2 10 bbls of N2 (equiv reservoir volume) 20 bbls of Diversion Fluid A (batch mixed) 45 bbls of 12% HCI (including additives) energized with 400 SCF/bbl of N2 with 5 gal/1000 gal of Diverting Agent B (on fly) 20 bbls of hot diesel w/5% Mutual Solvent energized with 400 SCF/bbl of N2 Purge coiled tubing with N2 If no pressure response is seen after Divert Stage hits the formation, interrupt Acid Stage #2, pump a 5 bbl N2 spacer followed by an additional 10 bbls of Diversion Fluid A, then continue w/ remainder of Acid Stage #2. Open well to flowback spent acid immediately. Continue lifting with N2 or gaslift to ensure that all spent acid flows back. Collect three fiowback samples of spent acid (from beginning, middle, and end of time period in which spent acid from Acid stage #2 passes sample point) and analyze for % HCI and Fe content. RD Acidizing Equipment. NH4CI water (base fluid for diversion fluid A) and HCI are to be filtered with a 2 p. nominal filter Additive sheet attached. Adjustments may be made to surfactants and/or other additives as necessary in order to pass sludge/compatibility tests. Monitor CT/tbg annulus pressure to maintain below C Sand frac pressure (BHTP < 3930 psi @ 5870' TVD, CT/Tbg annulus pressure < 1900 psi assuming diesel in CT/Tbg annulus ) Monitor formation pressure response to initial Diverter stage and adjust or add subsequent diverter volumes as indicated If well will not flowback, overflush all treating fluids w/ 60 additional bbls of diesel and/or N2 rather than leave spent acid near wellbore ~ !~ ~ ~ 't~ !~ [~ Anchorage 6 5 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 4 , . 2 CO I LEDTUB l NI3 UN l TBOP EOU I PMENT I i i~ · i ~ ~1 ARCO Alaska, Inc. Date: May 12, 1989 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal Ct: 7470 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-18 . .'~3A-03 ~"3A-08 '~'""3 O- 11 ~'"'30-13 '~"'30-17 .,~ B - 14 D 08 ~3H-1 0 '~'3A-08 '~ 30-12 '~30 18 2B 14 ~1 R -.02 ~,3F-'1 6 ~ 3F-16 ~1 R-02 ~1Y-06 '~' 2T-07 ~'~1 E-25 Sub-Surface Pressure Survey 2- 1 5 - 8 9 Kuparuk Fluid Level Report 4 - 2 3 - 8 9 Kuparuk Fluid Level Report 4 - 2 3 - 8 9 Kuparuk Fluid Level Report 4 - 2 2 - 8 9 Kuparuk Fluid Level Report 4 - 2 2- 8 9 Kuparuk Fluid Level Report 4 - 2 2- 8 9 Kuparuk Fluid Level Report 4 - 2 4 - 8 9 Kuparuk Fluid Level Report 4 - 2 4- 8 9 Kuparuk Fluid Level Report 4 - 2 4 - 8 9 Kuparuk Fluid Level Report 4 - 2 4- 8 9 Kuparuk Fluid Level Report 4 - 2 9 - 8 9 Kuparuk Fluid Level Report 4 - 2 9 - 8 9 Kuparuk Fluid Level Report 4 - 2 9 - 8 9 Kuparuk Fluid 'Level Report 4 - 3 0 - 8 9 Kuparuk Fluid Level Report 4- 2 9 - 8 9 Kuparuk Fluid Level Report 5-03-89 Kuparuk Fluid Level Report 5 - 0 4- 8 9 Kuparuk Fluid Level Report 5 - 0 3- 8 9 Kuparuk Fluid Level Report 5 - 0 8- 8 9 Kuparuk Fluid Level Report 5 - 0 7- 8 9 Kuparuk Well Presure Report 1 1 - 0 7- 8 #64613 Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Casing Casing Casing Amerada Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M ~ SAPC Chevron Mobil Unocal ARCO Alaska. Ir Post Offic~-8ox 100360 Anchorage. Alaska 99510-0360 Tetept~one 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 04-03-86 TRANSMI~"~EAL ~ 5622 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: S~hl: CET's or CBL's: One * of each 12-03-85 Run #2 7050-7732 02-21-85 Run #1 6390-6964 02-23-85 Run #2 6400-7000 04-16-85 Run #1 0695-4476 01-28-85 Run #1 5346-7359 01-14-85 Run #1 4710-6500 01-13-85 Run -#! 6050-8250 01-13-85 Run #1 5390-7522 12-06-85 Run #1 6000-8016 02-11-85 Run #2 6488-8062 11-03-85 Run #! 6771-8518 11-03-85 Run #1 6086-7545 11-04-85 Run #1 5186-7006 11-14-85 Run #1 5410-6885 STATE OF ALASKA ALASKA 0j~L AND GAS CONSERVATION COI~'MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number . ARCO Alaska, Inc. 85-224 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-214#5 4. Location of well at surface 647' FSL, 781' FEL, 5ec.7, T12N, RgE, UN At Top Producing Interval 1156' FNL, 1182' FEL, Sec.18, T12N, R9E, UM At Total Depth 1513' FNL~ 1239' FEL~ Sec.18, T12N~ RgE~ UN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 73' RKB ADL 25632 ALK 2565 12. Date Spudded 113. Date T.D. Reached 14. Date Comp., Susp. or Aband. 10/26/85 I 10/31/85 11/01/85* 17. Total Depth (MD+TVD) 18.PIugBackDepth(MDH-TVD) 19. DirectionaISurvey 71 20 'MD ,6320 'TVD 701 2 'MD ,6241 'TVD YES [Z}(X NO [] 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3A-8 11. Field and Pool Kuparuk River Fi eld Kuparuk River 0il Pool 15. Water Depth, if offshore 116- No' of Completions N/A feet MSLt 1 20. Depth where SSSV set 21. Thickness of Permafrost 1822 feet MD 1550' (Approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Ca1, CET, (::;CT 23. CASING, LINER AND CEMENTING RECORD CASING SIZE 16" 9-5/8" WT. PER FT. 62.5# 36.0# GRADE H-40 J-55 HOLE SIZE SETTING DEPTH MD TOP BOTTOM Surf 85' Surf 3161 ' Surf 7102' 24" 12-1/4" CEMENTING RECORD 195 sx AS I I 880 sx AS III & 270 s> Performed top job w/1 7" 26.0# J-55 8-1/2" 325 sx Class G & 175 x AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, sizeand number) 6882' - 6888' w/4 spf 6786' - 6827' 6757' - 6772' 6602' - 6642' w/12 spf AMOUNT PULLED Cl ass G 0 sxAS 11 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 6711' 6523' & 6684' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) / NT AMOU & KIND OF MATERIAL USED / See attached Addendum, dated 2/27/86. / 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL TEST PERIOD I~ CALCULATED 24-HOUR RATE GAS-MCF Flow Tubing Casing Pressure OIL-BBL GAS-MCF Press. 28. CORE DATA WATER-BBL CHOKE SIZE GAS-OIL RATIO WATER-BBL OILGRAV TY-AP (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED APRO $198 ~ Oil & 6as Con~. U~mmi~s.~o~ Form 10-407 * NOTE: Tubing was run and the well p_erforated 11/26/85. GRU1/WC07 Submit induplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGICM/~RKERS ' ~ ? ..... :' ~FORMATIONTESTS 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 6596' 5941' N/A Base Kuparuk C 6640-' 5972' .... ' ~' ~:' Top Kuparuk A 6729' 6036' Base Kuparuk A 6904' 6162' ,' .. ' ' . '~:-' ! "-: : F- ' _ : · . . . 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) 32. I hereby certify that the f0regoi:ng is true'and COrrect to the b.est of my knowledge Signed v~ ~ u ~.~,' Title 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.). Itemt~3~/~tt~ched '~upplemental records for this well should show the details of any multiple stage cement- lng and the.,~¢locati,0.~;. , .'::~f the cementing tool. Item 27: Method of Oper~a,tion: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jeC-ti.o. ~: Gas I~r~je'dt~ot~, i'.- ,~,~,..~:" · .......... Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 11/o5/85 11/12/85 2/09/86 3A-8 Rn CET log f/7012'-5186'. Rn GCT gyro f/6956'-surf. Arctic Pak w/175 bbls AS I. Begin frac work @ 1353 hrs, 2/9/86. AFE: AK0316 Frac'd Kuparuk "A" sand perfs 6752'-6772'; 6786'-6842' & 6882'-6888' in 7 stages per 12/9/85 procedure using gelled diesel w/Musol, 100# mesh & 20/40 mesh. Press'd ann to 1500 psi w/diesel. Tst ins to 7910 psi; OK. Stage 1: Pmp'd 44 bbls 5% Musol/diesel @ 4.4 BPM w/final press of 2760 psi. Stage 2: 22 bbls gelled diesel pad @ 7.5 BPM w/final press of 2550 psi. Stage 3: 19 bbls gelled diesel w/lO0 mesh @ 21.7 BPM w/final press of 4670 psi. Stage 4: 22 bbls gelled diesel @ 21.5 BPM w/final press of 3920 psi. Stage 5: 8 bbls gelled diesel w/20/40 @ 21.4 BPM w/final pressure of 3900 psi. Stage 6: 19 bbls gelled diesel w/20/40 sand @ 21BPM w/final pressure of 4000 psi. Stage 7: 58 bbls gelled diesel flush @ 20.1BPM w/final pressure of 3300 psi. Pmp'd 800# 100 mesh + 896# 20/40, 3 ppg & 4227# 20/40, 8 ppg sand in 7" csg. Load to recover 184 bbls of diesel. Job complete @ 1412 hrs, 2/9/86. Dr ill ing/Sup er int end ent / Da~e ' ARCO Alaska, Inc. Post Office B(.,..-.t00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 11, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3A-8 Dear Mr. Chatterton' Enclosed is an addendum to the 3A-8 Well the Well Completion Report, dated 12/18/85. questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU13/L98 Enclosure Hi story to include wi th If you have any ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ADDENDUM WELL: 11/o5/s5 11/12/85 3A-8 Rn CET log f/7012'-5186'. Rn GCT gyro f/6956'-surf. Arctic Pak w/175 bbls AS I. Drilling ~Superintendent f I~ate ARCO Alaska, Inc. Post Office B~,..--~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 11, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3A-8 Dear Mr. Chatterton- Enclosed is a copy of the 3A-8 Well History (completion details) to include with the Well Completion Report, dated 01/22/86. If you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU13/L90 Enclosure cc' 3A-8 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany ARCO Oil and Gas ComPany Daily Well History-Final Report Illatruclione; 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. I Accounting cost center code District I Count~-~-r Parish I S'tate Alaska North Slope Borough Alaska Field ILease or Unit 'l Well no. Kuparuk River ADL 25632 3A-8 Auth, or W.O. no. JTitle AFE AK0316 I Completion Nordic 1 API 50-029-21445 Operator I A.R.Co. W.h rTotal number of wells (active or inactive)on this, ARCO Alaska, Inc, I 56 24% Icost center prior to plugging and I · Jabandonment of this well Spudded or W.O. begun IDate IHour I Prior status if a W.O. Complete 11/24/85 1145 hrs. Date and depth as of 8:00 a.m. Complete record for each day reported Old TD Released rig 11/25/85 11/26/85 0230 hrs. Classifications (oil, gas, etc.) Oil Flowing 7" @ 7101' 7012' PBTD, RIH w/3½" CA Accept rig @ 1145 hrs, 11/24/85. NU & tst BOPE. RU Schl, perf w/4" gun, 4 SPF f/6882'-6888', 6827'-6842', 6806'-6827', 6786'-6806', 6757'-6772'. Perf w/5" gun, 12 S?F f/6642'-6627' & 6622'-6602'. Make gage ring/JB rn. RIH w/FB-1 pkr, set @ 6674' WLM, RD Schl. RIH w/3½" CA. 7" @ 7101' 7012' ?BTD, RR Lnd tbg, set top pkr, no press tst on tbg. Shear PBR. Drop 2nd ball; no press tst on tbg. RIH w/WL kick over tl, tst tbg to 2500 psi; no tst on ann. RIH w/std'g vlv, tst tbg & ann; OK. Tst SSSV. Shear ball, ND BOPE, NU & tst tree to 5000 psi. Displ well to crude· RR @ 0230 hrs, 11/26/85· Moving rig to DS 3F-1. (Note: All 3½" tbg 9.3#, EUE, 8RD, J-55 IPC. Ail 2-7/8" tbg 6.5#, EUE, 8RD, J-55 IPC. Ran 2 jts, 3½" BTC, J-55 IPC w/blast rings· SSSV @ 1822', FHL Pkr @ 6523', FB-1 pkr @ 6684', "D" Nipple @ 6703' TT @ 6711') Producing method New TD Date /'~:l¢~ 5~;'~;~i(~ 7012' PBTD I Kind of rig Rotary 11/26/85 IType completion (single, dual, etc.) Single Official rese~oir name(s) Kuparuk Sands Potential test data 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 Signature I Date I Title ~/~z~ ~.~,~,~) Drilling Superintendent For ,o~m-p-reparation an~ distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 23, 1986 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3A-8 Dear Mr. Chatterton- Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not yet received the Well Hi story (completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU13/L23 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany STATE OF ALASKA ALASKA (~ AND GAS CONSERVATION COi..~ IlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85'224 3. Address. 8. APl Number r . P. 0. Box 100360, Anchorage, AK 99510 50- 029-21445 4. Location of well at surface 9. Unit or Lease Name 647' FSL, 781' FEL, Sec.7, T12N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1156' FNL, 1182' FEL, Sec.18, T12N, R9E, UN : :~ ~:~ . :! ='i.. ~. ' 3A-8 At Total Depth ' : 11. Field and Po°l 1513' FNL, 1239' FEL, Sec.18, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 73' RKB ADL 25632 ALK 2565 12. Date Spudded 13. Date T.~). Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1 0/26/85 1 0/31/85 11/01/85* 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 21. Thickness of Permafrost 7120 'MD ,6320 'TVD 7012'MD,6241 'TVD YES [~X NO []I 1822 feet MD 1550' (Approx) , 22. TyPe Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET, GCT 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 85' 24" 195 sx AS II 9-5/8" 36.0# J-55 Surf 3161' 12-1/4" 880 sx AS Ill & 270 sx Class G Performed top job w/10,) sx AS II 7" 26.0# J-55 Surf 7102' 8-1/2" 325 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) 6882' - 6888' w/4 spf 3-1/2" 6711' 6523' & 6684' 6786' - 6827' 6757' - 6772' 26. ACID, FRACTURE, CEMENTSOUEEzE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6602' - 6642' W/12 spf N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.~ 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 LOCATIONS 1 i Surf.~j Form 10-407 * NOTE: Tubing was run and the well perforated 11/26/85. TEMP3/WC62 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · .' ;', "' GEOI'OGI~ M'/~,i~KER's'' !'~i": :''':i'il ' '" ii'::" '":i ...... "; ;,:,i .:'!! ;i:':: ' ~:--Fo:RM~,-TION:TESTS- . NAME Include interval tested, pressure data, all fluids recovered and gravi;y, MEAS. DEPTH TRUE VERT. DEPTH GQR, and time of each phase. Top Kuparuk C 6596' 5941' N/A Base Kuparuk C 6640' 5972' Top Kuparuk A .6729' 6036' Base Kuparuk A 6904' 6162' 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~0~ ~L~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 ARCO Alaska, inc. Post Office Bo~.O0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 12-19-85 TRANSMITTAL # 5481 B Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OPen Hole Finals/ Schl/ One * of each 3A-10 ~-~ 5" DIL/SFL /'~ ~ 2" DIL/SFL - ~5" Den/Neu ~ ~2" Den/Neu ~ ~5" Den/Neu ~ ~2" Den/Neu ~ ~JCyb e rlook 2A-8 /~ ~ 5~' DIL/SFL-gr ~ -- 2" DIL/SFL-gr 11-09-85 Run#1 11-09-85 Run#1 (poro) 11-09-85 Run#1 (poro) 11-09-85 Run#1 (raw) 11-09-85 Run#1 (raw) 11-09-85 rUn#1 11-09-85 Run#1 10-30-85 Run#1 10-30-85 Run#l -.5" Den/Neu-gr (poro) 10-30-85 Run#1 2" Den/Neu-gr (poro) 10-30-85 Run#1' 5" Den/Neu-gr (raw) 10-30-85 Run#~ 2" Den/Neu-gr (raw) 10-30-85 Run#l ~ ~Cyberlook 10-30-85 Run#1 · ~ 5." DIL/SFL-gr ~ -- 2" DIL/SFL-gr - --5" Den/Neu ~- 2" Den/Neu 5" Den/Neu \ ~ 2" Den/Neu ~ ~ Cyberlook 10-24-85 Run#l 10-24-85 Run#1 (poro) 10-24-85 Run#l (poro) 10-24-85 Run#t (raw) 10-24-85 Run#1 (raw) 10-24-85 Run#1 10-24-85 Run#1 3211-6988 3211-6988 6180-6962 6180-6962 6180-6962 6180-6962 6400-6800 3161-7080 3161-7080 6390-7055 6390-7055 6390-7055 6390-7055 6490-7030 1950-7238 1950-7238 4750-7212 4750-7212 4750-7212 4750-7212 6650-7189 Receipt Acknowledged: STATE OF AK*BL&SE RATHMELL*BL NSK CLERK*BL DRILLING*BL VAULT*FILMS DEGLOYER & ~CNAUGHTON*BL Date: ARCO Alaska, Inc. ~s · Subsidiary of AtlanticRtc~l~eldCompart)' ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 19, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3A-8 Dear Mr. Chatterton- Enclosed is the Well Completion Report for 3A-8. The bottomhole location, TVDs, and geologic markers will be submitted when the gyroscopic survey is run. Also, I have not yet received the Well History (completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L149 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ;;-:~ AND GAS CONSERVATION CC~_.._~.VIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~x GAS I-I SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7, Permit Number ARCO Alaska, Inc. 85-224 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 5O- 029-21445 4. Location of well at surface 9. Unit or Lease Name 647' FSL, 781' FEL, Sec.7, T12N, RgE, UM Kuparuk River Unit , At Top Producing Interval 10. Well Number To be submitted when gyro is received. 3A-8 At Total Depth 11. Field and Pool To be submitted when gyro is received. Kuparuk River Field . 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 73' RKBJ ADL 25632 ALK 2565 12. Date Spudded 13. Date ~.D. Reached 14. Date comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 10/26/85 10/31/85 11/01/85* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I'VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 71 20 'MD 701 2'MD YES I-~X NO []I 1 822 feet MD 1550' (Approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET, GCT 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 85' 24" 195 sx AS !1 9-5/8" 36.0# J-55 Surf 3161' 12-1/4" 880 sx AS III & 270 sx Class G Performed top ,iob w/10( sx AS !! 7" 26.0# J-55 Surf 7102' 8-1/2" 325 sx Class G & 175 s; AS ! 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) 6882' - 6888' w/4 spf 3-1/2" 6711' 6523' & 6684' 6786' - 6827' 6757' - 6772' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6602' - 6642' w/12 spf N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I ' Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow T~bing 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 ,-~.-'a~a Oil .,:~ Form 10-407 * NOTE: Tubing was run and the well perforated 11/26/85. TEHP3/WC22 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. . 30. ' . GEOLOGIC'M~,RKERS FORMATION TES~s~' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be submitted w~)n gyro is rece~ ged. N/A 31. LIST OF ATTACHMENTS Well Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~. __~/ ~~j Title Associ ate 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. ARCO Oil and Gas Company Well History- Initial Report - Daily Instructione: 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. Alaska JState Alaska District Field Kuparuk River Auth. or W.O. no. AFE AK0316 County, parish or borough North Slope Borough Lease or Unit ADL 25632 Tte Drill IWell no. 3A-8 Parker 141 API 50-029-21445 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth. as of 8:00 a.m. IDate IHour 10/26/85 The above is correct 10/26/85 thru 1o128/85 10/29/85 10/30/85 10/31/85 Complete record for each day reported 0245 hrs. ARCO W.I. IPr or status if a W,O. 56.24% 9-5/8" @ 3161' 3180', (2680'), DO cmt Wt. 9.2, PV 8, YP 6, PH 9, WL 18, Sol 6 Accept rig @ 1900 hfs, 10/25/85. NU diverter sys. Spud well @ 0245 hfs, 10/26/85. 16" @ 88 Drl 12½" hole to 3180', 21 std short trip. RU & rn 9-5/8", 36# BTC csg w/FC @ 3081', FS @ 3161'. Cmt w/880 sx AS III w/lO#/sx Gilsonite & 270 sx Cl "G" w/2% S-1 & .2% D-46. Perform 100 sx AS I top job. ND diverter sys. NU & tst BOPE. RIH, tst csg to 1500 psi. DO cmt + 10' new hole. 9-5/8" @ 3161' 4860', (1680'), Turbo drl Wt. 9.0, PV 11, YP 10, PH 10, WL 18.2, Sol 5 Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 4860'. 3524', 8.8°, S37W, 3523 TVD, 15.66 VS, 13.71S, 10.33W 3872', 15.7°, S21W, 3863 TVD, 86.59 VS, 78.02S, 43.99W 4208', 26.4°, S23.5W, 4176 TVD, 206.48 VS, 192.11S, 86.49W 4557', 35.5°, S19.7W, 4475 TVD, 383.00 VS, 357.90S, 153.58W 9-5/8" @ 3161' 6970', (2110'), Drlg Wt. 10.1, PV 16, YP 15, PH 9.5, WL 6.3, Sol 11 Turbo drl to 6511', rotary drl to 6970'. 4872', 42.8°, S16.4W, 4721TVD, 577 VS, 543S, 215W 5440', 45.4°, S14.7W, 5124 TVD, 977 VS, 929S, 321W 6436', 44°, S 7.7W, 5827 TVD, 1681VS, 1625S, 437W 6827', 43.9°, S10.5W, 6108 TVD, 1952 VS, 1893S, 480W 9-5/8" @ 3161' 7120', (150'), LD HWDP Wt. 10.0+, PV 5, YP 7, PH 9.0, WL 6.2, Sol 11 Drl to 7100', 10 std short trip, C&C, POOH. RU Schl, rn DIL/GR/SP/SFL f/7088'-3160', FDC/CNL f/7088'-6400', CAL f/7088'-5500'. RIH, drl & surv 8½" hole to 7120', short trip, POOH, LD DP & HWDP. 7070', 42.8°, S17.9W, 6285 TVD, 2119.34 VS, 2054.90S, 521.40W Signature For form preparation and distrR~tion. see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate 12-4 ITitle Drilling Superintendent ARCO Oil and Gas ComP~iny Daily Weli~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 Reporl" should be submitted also when operations are suspended ~'or 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 District IState Alaska North Slope Borough Field Kuparuk River Auth. or W.O. no. AFE AK0316 Parker 141 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded County or Parish Le ..... Unit ADL 25632 ITit e Drill API 50-029-21445 A.R.Co. W.I. Date cost center code Alaska IWell no. 3A-8 56.24% I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prior status if a W.O, 0245 hrs. 10/26/85 Date and depth as of 8:00 a.m. Old TD Released rig Complete record for each day reported 11/01/85 7" @ 7102' 7120', (0'), RR Wt. 10.1, PV 6, YP 6, PH 9.0, WL 6.8, Sol 11 Chg rams to 7" & tst to 3000 psi. RU & rn 163 its, 7", 26#, J-55 BTC csg w/FS @ 7102', FC @ 7012'. Cmt w/125 sx C1 "G" w/8% D-10, .5% D-65, .5% D-112 & .2% D-46, followed by 200 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ w/brine, bump plug. CIP @ 2005 hrs, 10/31/85. ND BOPE. Set pack-off & tst. RR @ 0100 hfs, 11/1/85. Moving to 3A-10. 7012' PBTD I New TD PB Depth 7120' TF (10/30/85) Date K nd of r g 0100 hrs. 11/1/85 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 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 , Signature /J-~.~ ~'J-~~ Drilling Superintendeat For form preparation and distJ~bution,-. see Procedures Manual, Section Drilling, Pages 86 and 87. ~]UIDANCE [~]ONTINUOUS [~]OOL SUB. SURFACE DIRECI'IONAI. SURVEY ARCO ALASKA INCORPORATED Company Well N~me ~A-S' (647' FSL, 781' FEL, S7, T12N, RgE, UM) Fleld/I.~atlon ~A~, NORTH SLOPE, ALASKA Jel~ .Rif .at. ce No. 71105 HALFACRE 19-DECEMBER-85 Comguted CUDNEY .]CT ]iTECTi]NiL SURV-Y ' dST "MF- R LISTINg 4RC] ALAXSK~ 'INC. KUPA~UK NORTrt SLDPE,AL.4SKA DATE: 3~-NOV-85 ZNGI!'4:: ER: HALFACRE T3OL L3C&T!]N: TANjENTI&L- VErTiCAL ~CT.ICN: dr]qlZ. !3IST. DEVIATION AND PRC.,JECTFO ONTO 4 TARGET AZIMUTH AZIMUTH OF SOUTH 12 MIN dEST ARC3 ALASKA, i;tC. 36-8 N3RTH SLOPE, ALi~SKA C Z'.I ~UT & T Z 3 D&T=: 19-D 'C-85 iNTERPOLATED VALUES FCE =VEN 100 FEET DF TRUE ME&SUR=O VERTICAL V~RTi'-6L DEPTH D~PT~ DEPTH 0.00 O.O0 -73.00 100.00 lO0.OO 27.00 200.OO 200.00 127.00 300,00 300.00 227.30 400.OJ ~O0.O0 32'7.00 500.00 4}9.99 500.00 599.)~ 525.99 700.00 699.')'~ 525.33 800.00 79~.9~ 900.00 899.35 ~25.:33 lOOO.O0 99'9.97 92m.)7 1100.00 1093.97 1025.9'7 1ZO0.O0 11'39.95 i125.95 1300.00 129:3.9~ 1225.~4 1400.00 1399.92 132~.92 1509.00 1~99.90 1~25.9j 1600.00 15'99.$$ 1525.86 1700.00 1699.~1 1525.~t 1~00.00 1799.77 1725.77 1900.00 1~99.71 1325.71 2OO0.OO 1999.55 1925.~5 2100.00 !099.60 2026.50 2200.00 2199.56 2126.55 2300.00 2299,53 2225.53 2~00,00 2399,50 i326.50 2500.00 1493.~5 2~25.4o 2600.00 259~.42 Z52~.~Z 2'700.00 269:~.39 2525.39 2300,00 27,29.38 2725.38 2900.03 2899.37 2825.37 COURSE V-RTIC&L DOGL;G DEVIATIJN AZ?MOT~ 5=CTION SEVERITY DEG MIN 0=:3 ?~l'q FEET DES/IOO 0 0 N C O Z 0.00 0,00 0 5 N ,!3 51 W -0.11 0.20 0 5 ~ 2~ 39 W -0.12 0.27 0 17 S 5 10 N 0.23 0.21 0 ~4 S ~ -~ = O. 0 29 S 11 ~5 W !.56 0.29 0 ~B S ~ 10 W ~ 5~ 0 23 -- -,: .- -- · ~ · 0,.°5 S ~']. 33 N 3.24 0.10 0 29 S 43 17 N 3.94 O.1Z 0 i9 ~ 41 39 N 4.71 0.06 3 35 S 32 0 W 5.57 0.13 O 50 S :]3 14 W 6.68 0.12 '3 57 S 34 57 W 3.13 0.12 i 1 S 45 15 W 9.65 0.27 1 5 S 23 ~S W 11.44 0.30 1 ]30 S 7 49 W 13.63 0.60 i 38 S 2 55 W 15.39 0.22 I $3 ~ 3 ig W 19.26 0.35 1 ~l S 4 j5 E 22.45 0.81 1 55 S 14 17 ~ 25.48 3.25 i 5,3 S oj 57 ; 2'~ ~ - ~.48 0.23 I ~5 S 24 45 E 3!.07 0.10 I 23 S 24 ~ £ 33.37 0.56 1 18 :5 14 55 : 35.25 0.2'9 1 32 S ~ 5 Z 3'7.56 0.10 I 3') S '9 5~ = 40.~1 0.12 1 !'2 S ~ il ~ 4.2.33 0.27 i i0 ,S 7 3~ = ~4.96 0.48 J 43 S i 52 ~ 47.31 0,56 0 3 7 10 1£ ~4 1 5 Z~ S 27 21 W 43.58 0.78 25 S 35 J W 49.55 0.11 25 S 22 29 ~ 50,2~ 0.10 51 S 27 58 N 51.19 1.62 ~4 S 4°~ =°;5 ~ 54.27 3.97 ~,I $ ?7 0 w 63.54 3,09 35 S 33 !56 ~ 73.48 2.25 37 S ':Z4 35 J 97.95 1.80 26 S 23 25 W !20.B3 2.26 ~1 S 1~ I~ W !47.19 2.91 3000.00 2999.3~ 2)25.36 3100.00 30)9.36 3025.35 3200.00 31919.36 3125.35 3300.00 3299.35 322a.35 3400.00 3399.23 3325.25 3500.00 3438.72 3~25.72 3500.00 3597.3~ 352~.3) 3700.00 3g95.3! 3422.31 3800.00 3792.54 3719.54 3~00.00 3888.93 3315.93 PAGE 1 DATE 9= SURVEY: 04-NDV-85 KELLY 6USHING ELEVATION: 73,00 ;NGINEER: HALFACRE FT MEASURE RECTAN NDRTm/ FEE . O. O. O. O. 1, 2. 3. 3, 4. 6. 7. 8. 10. 12. 13. 21. 24. 27. 30. 33. 35. 38. 40. 43. 43. 47. 48. 49. 50. 51. 52. 54. 62. 75. 93 · 114. 139. D DEPTH GULAR SOdTq T COOROINAT=S EAST/WEST FEE T O0 12 15 19 55 44 08 31 05 06 35 65 25 37 '15 05 32 58 0.00 0.05 0.15 O.ZO 0.20 0.25 0.51 1.09 1,53 2,27 2.85 W 3,49 W 4.37 W 5.53 W 6.53 W 7.09 W 7,31 W 7.44 W 7.49 W 6.8,4 W 89 83 46 56 O4 91 53 87 5.77 4.54 3.37 2.60 2.08 !. 64 1.19 0.'~3 0.73 0.66 93 52 13 O3 69 73 92 70 96 90 0.86 W 1.29 W 1.58 W 2,01 W 4,24 W 10.6~ W 20.05 W 29.74 W 39,42 W 48.64 W O.Zl' 0.28 0.86 1.67 2.52 3,27 4.02 4.87 0 E 52 W N 44 21 W S 46 5 W S 13 39 Wi' $ 8 41 ~ S 13 56 W S 19 33 W S 23 56 W S 27 46 W 5.81 6.99 8.53 10.26 12.16 14..:'6 16.83 1'9.54 22.60 25.51 S Z~) 22 W S 29 58 W S 30 43 W S 32 35 W S 32 29 W S 29 49 W S 25 45 W S ZZ 23 W S 19 21 N S 1.5 32 W 28.48 31.16 33.62 35.55 38.10 40.89 43.66 45.92 47.53 48.88 S 11 41 W S $ Z2 W S 5 45 N S 4 10 N S 3 7 s z i7 S 1 33 N s 1 1 w S 0 52 W S 0 46 N 4'9,93 50.53 51,16 52,07 54,85 63,53 78,53 98.30 121.53 148,12 S 0 59 W S 1 27 W S 1 52 W S Z 1Z W S 4 26 W S 9 39 W S 1~ 47,W S 17 36 W S 18 55 W S 19 10 W ':2M~UTAT'' IN ARCO ALASKA, !NC. 3A-8 DATE: 19-DEC-Bi INTERPOL&T=D VALUES F3R =VEN 100 F=ET OF TRUE ME~SURE3 VERTICAL VERTI'AL 3EPT'~ DEPT~ DEPTH 4000.00 3933.57 4100.00 4076.)1 4200.00 4167.95 4300.00 4256.52 4400.00 4342.75 4500.00 4426.75 4690.00 4508.54 4700.00 4~00.00 5000.00 4810.99 5100.00 4881.32 5200.00 4"951.~6 5300.00 5022.53 5~00.00 5093.1) 5500.0~ 5163.~2 5500.00 5233.96 5700.00 5304.,33 5500.00 53~4.53 5900.00 5445.21 6000.90 5515.S0 . 6100.00 55B5.9~ o200.00 5656.~ 6300.00 5727.52 6400.00 5799.22 6500.00 5871.97 6600.00 5943.50 6700.00 5015.1~ 6000.00 5035.99 6900.09 5158.99 4003.91 4096.95 ~133.52 ~26'9.75 ~353.78 %455.54 4515.70 ~593.42 ~667.39 4737.99 ~608.31 4873.86 4949.63 50Z3.19 SO'~O. 52 516~ . 90 5231.35 5301 .63 5372.21 5442.60 5512.:93 5583.4~ 57:)3.27 5370.50 5942.1~ ~013.':)'9 6055.99 COJRS~ DEVI~TI%N ~ZI~UTq 3EG ~IN DEG ~159.04 42 47 $ 11 7 w 5232.41 42 47 S 11 I w ~247.09 42 47 S I1 7 '~ 7000.00 5232.04 7100.00 6305. ~+1 7120.00 5320.09 V=RTIC~L DOGLSG S~CTION SEV:RITY ~:~:~T OEGtlO0 17:g.~2 3.39 ~14.98 ~ 91 256.20 3.89 30'2.13 2.94 35°~..75 _P.74 40,5.21 2.52 46.3.51 1.30 523.16 2.20 5~.5.94 3.80 653.17 3.12 MEASURE PAGE DATE Om SURVEY: 04-NOV-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE D D=PT"~ RECTANGULAR NORTH/SOUTH _AS FEST FE 169.79 S 58 205.02 S 68 244.52 S 80.20 287.83 S 96.88 335.18 ~ 114.74 386.59 S 131.59 441.67 S 148.66 498.63 S 156.77 558.99 S 184.47 624.10 S 201.,39 2 73.00 FT 723.93 0.65 592. 795.05 0.71 761. 365.92 3.73 830. 936.56 0.85 899. 1307.4Z 0.6~ ~68. 1078.51 0.79 1037. iI~9.49 0.21 1107. 1220.44 1.15 ' 1176. 1291.50 1.38 1247. 1~62.12 0.44 1317. 143'2.81 0.5'3 1387. 1503.40 0.25 1458. !573.80 0.36 1528. 1543.60 0.64 1598. 1712.71 0.32 1668. 17~1.46 0.60. 1737. 1~50.15 1.41 1806. 1917.59 3.67 1375. 19~38.89 0.12 1944. 2058.07 1.63 2012. 2126.29 O.OO 2080. 2194.21 0.00 2146. 2207.79 O.O0 2160. 57 S 213.31 89 S 235.28 59 S 252.34 33 S 269.07 32 S 255.27 59 S 300.82 18 S 315.30 87 S 328. B~ 03 S 340 · 7 5 15 S 350.,87 W 257.33"::,!:S 18 9 W W 303,70 'S, 13 36 w w 354.28, :'S',' 18 53: W 408.46 S 18 47 '. W ~66.02 S lB 36 N W 525.78 S lB 29 W W 588.64 S 18 15 W W 655.79 S 17 53 W 725.45 S 17 29 W 797.39 S 17 9 ~ 868.17 S 15 53 W 938.72 S 15 39 W 1009,46 S 15 24 W 1080.41 S 15 10 W 1151.20 S 15 53 W 1221.95 S 15 36 W 1292.74 S 15 16 W 1363.08 S 14 54 ~ 61 S 359.78 W 22 S 367.59 W 79 S 374.73 W 84 S 381.44 W 24 S 387.86 W 30 S 394.20 W 06 S 401.59 W 28 S 410.33 W 18 S 419.80 W 85 S 429.84 W O1 S 442.1 3 W 68 S 455.25 W O1 S 457.87 W 1433.49 S 14 32 1503.84 S 14 8 1574.04 S 13 46 1543.71 S 13 25 1712.74 S 1 3 5 1781.46 S 1Z 47 1~50.17 S 12 32 1919.54 S 12 20 198~.99 S 12 11 2058.23 S 1 2 3 2126.49 S 12 0 W 2194.42 S 11 58 W 2208.01 S 11 58 W C 3"4 :~U T A 1' Z ] 3A-;3 KUPARUK N'gRTH SLOPE,ALaSkA Z,%TJ: 19-~'mC~,_ -35 ZNTERP,3L~,T=3 V.ALJES :'3F< ",/'.=N 1003 F-EET TqUE SjS-S~A !'qEASURE3 V:RTiC~L V=qTI'~&L D:PTH O-~Td DEPTH ~,U.~,S V RTl :iL DO'3L=G DEVI~TI ]'~ & Z-',i.d T ~ S-CTiQN SEVERITY 'DEG MIN 3'-:5 HI'~ ~:~ET DES/100 O. O0 O. OO -7~- O0 lOOO.O0 999.~7 925.97 2000.00 19'99.55 t925.55 3000.00 ~999. 3.5 _~9~6~ .36 4030.00 39B3.:B7 3910.87 5000.00 4810, ~ 4737.99 6000.00 5515.60 5442.60 7000.00 5232.34 6!59.0~ 7120.00 5320.0~ 5247.09 0.03 5.57 23.4~ 1.7~.42 723.9~ _, i432.'~1 !126.29 2!07.79 P&GE DATE OF SURVEY: 04-N3V-85 KELLY BUSHING ELEVATION: ENGZNEER: H~L~ACRE MEASUR 3 73,00 FT ED :3EPT R'=CTANSULAR C30RDINATES NO~TH/SOUTH EAST/WEST FE=T FE=T O.CO O.O0 N 0.00 E 3.13 5.06 S Z.85 W 0.23 27.89 S 5.77 W 3.75 49.~3 S 0.85 W 3.39 169.79 S 58.08 W 3.65 592.87 S 218.31 W 3.53 1387.~1 S 359.78 W 0.00 2080.01 S ~42.13 W O.O0 2160.01 S 457.87 W HDRIZ,... DEPARTURE OI $ Y ~:',: ' :,'AZ I MUTM F E E ~ ;:i i' ii:. ,' .: ~-'D E G MIN 0.00' N 0 0 E 5,81' ,S. 29 ZZ W 28.48 ' $ 11 41 W 49,93. S 0 59 W 179,45 S 18 53 72~.45 S 17 29 1433.49 S 14 32 'W- 212,5.49 S 1Z 0 W 2208.01 S 11 55 N .3~-8 KJPARdK N3RTH SLSPE,ALASKA C 3MPUT '-~TI ;3'4 DATE: 19-C, cC-S5 ZNTEROOLATUS, :_ VALU=S F]R =V~=N_ 100 =EET Ow, TRUE SdS-SEA CJURSc qEASUR=J VERTICAL VERTICAL DEVIATION AZiqUTt 3~PTH. OEPTd D:PTH~ D.EG MIN DES ~'4~=N O,OO 0,00 -73.00 73,00 73,00 0.00 173.00 173.00 100,00 273.33 273.00 203.00 373.33 373.00 300.00 ~73,01 ~73.00 573.01 S73.00 ~JO.O0 573,01 673,00 500,00 77~,02 773,00 700.00 873.02 873.00 800.00 973.02 973.00 '900.00 10Z3.03 1073.00 I000.00 1173.04 1173.00 i103.00 1273.0~ 1273.00 1200.00 1373.07 1373.00 i303.00 1473.10 1473.00 1400.00 1573.13 1573.00 1503.0J 1573.17 1673,00 l$O~.OO 1773.23 1773,00 1700.00 1~73.28 1873.00 1973,3~ 1973.00 120J.OJ 2073,39 2073.00 ZOOJ.O0 2173,4~ 2173,00 2100,30 2273,46 2273,00 2203.30 2373,49 2373.00 2300.00 2473.53 2473.00 2405.00 2573.57 2573.00 2500.00 2573,60 2673.00 .26.33.03 2773,62 2773.00 2703.30 2873,63 2873,00 2503.00 2973,6~ 2973.00 2900.00 3073.64 3073.00 3000.03 3173.64 3173.00 3130.03 3'273.65 3273.00 3200.00 3373,68 3373,00 3303,00 3~74.05 3473,00 3403.00 3575,21 3573.00 350~,00 3677,15 3673.00 3500.J0 3779,$~ 3773.00 37JJ,00 3883.39 3873.00 3800.00 V"RTIC,~L DO'SL:G SE:STIgN S:V:RITY FEET DES/lO0 O.O0 0.00 -0.07 3.22 -0.15 0.27 O.11 O.IB 0.68 0.09 !. 43 0.0'3 2.30 0.15 3.06 0.13 3.75 O.OB 4.50 0.15 5.31 0. ~6 6.32 0 · 45 7.72 0.11 ~.26 0.19 10.93 0.35 12. ')4 O. 65 15.64 0.14 18.48 0.30 ~1 56, O. 44 ;. . 2¢ .59 3.15 27.70 3.33 30.42 0.21 32.82 1,25 34.74 0.38 35.90 0.32 39.4'9 O. 14 ~2.19 0.83 44.44 0.2~ 46.17 0.53 47.46 0.19 4;3.63 0.25 49.38 0,05 50.05 0.20 50.87 0.53 52.98 4.4~ 60.47 3.96 74.36 2.31 93.14 2, 53 115.95 1-82 142.53 2.93 PAGE DATE OF SURVEY: O~-NDV-85 KELLY BUSHING ELEVATIDN: ENGIqEER: HALFACRE SdS-SEA DEPTH RESTANSULAR C03ROINATES NDRTH/SDUTH EAST/NEST FEET FEET 0,00 N 0,00 E 0,08 N '0.03 W 0.18 N 0.13 W 0,06 S 0,19 W 0.65 S 0.21 W 1.42 S 0.22 W 2.24 S 0.49 W 2,92 S 0,95 W 3.51 S 1.48 W 4.14 S Z.11, W 4.83 S 2.71 W 5.74 S 3.28 W 6.99 S 4.12 W 8.32 S 5.18 W 9.78 S 6.30 W 11.69 S 6.96 W 14.39 S 7.27 w 17.27 S 7.41 W 20.40 S 7.54 W 23.72 S 7.05 W 27,03 S 6,09 W 30,0'9 S 4.87 W 32,83 S 3,54 W 34,99 S 2,76 W 37.34 S 2.19 W 40.09 S 1.76 W 42.96 S 1.30 W 45.36 S 0.92 W 47.18 S 0.73 W 48.51 $ 0.68 W 49.59 S 0.77 W 50.36 S 1.17 W 50.96 S 1.60 W 51.74 S 1.89 W 53.59 S 3.24 W 60.05 S 8.64 W 72.26 S 17.55 W 89,23 S 27.57 W 110.42 S 37.39 W 135.45 S 47.15 W 73. O0 FT 5.54 S 29 6.51 S 29 8.11 S 30 9.81 S 31 11.64 S 32 13.60 S 33 16.12 S 26 1'5.79 S 23 21.75 S 20 24.74 S 15 14 W 46 W 30 W 54 W 47 W 47 W 47 ~ 12 W 16 W 32 W 27.70 S 12 41 W 30.48 S 9 12 W 33.03 S 6 19 35.10 $ 37.~1 S 3 21 W, 40.13 S 2 31 42.98 S 1 43 W 43.37 S 1 9 W 47.13 S 3 53 N' 48.52 S 0 48 W 49.70 S 0 53 W 50.38 S 1 19 50.98 S 1 47 W 51,77 S 2 5 W 53.69 S 3 27 W 60.57 S 74.36 S 13 38 93.42 S 17 13 W 116.58 S 18 42 143.4~ S 19 11 ARCO .ALASKA, 3A-S KJPARJK NORTH SLOPE,ALASKA CO',.lmdT&T-]N ZNTERPOL~T:J VALUES F3R TRUE SdS-SEA ME~SURED VERTICAL VERTI"&L DEPTH DzPTM O~FTH 3968.4~ 3973.00 3gO0.O0 4095.75 4073.00 ~OOJ.O0 ~205.5~ 4173.00 ~100.00 4318.94 4273.0~ 4200.00 4~35.62 4373.00 ~300.00 4556.31 4475.00 4400.00 ~5B0.21 4573.0J ~808.63 ~673.00 ~5JO.30 4'945.83 ~773.00 4700.00 5035.21 4B73.00 ~O0.JO 5229.85 4973.30 ~900.00 5371.38 5073.00 5513.49 3173.00 510J.O0 5655.39 3273.00 5797.6~ 5373.00 5939,51 5473,J0 6081.57 5573.00 5530.0.J 6223.36 5673.00 3500.00 6353.49 57715.30 6502.40 5873.0J ~SO0,OJ 6541.14 5973.00 5900.03 6780.53 5073.00 5003.Og 6919.33 5i73.00 5100.30 7055.83 6273.00 ~2OO.JO 7120.00 5320.3~ C 3 ,.J q S '- OEVI&Ti$N ~ZZMUTH DEG":.MIN D:G ~qlN 44 !7 S 7 1~ ;t ~3 25 S ~ 42 ~7 ~ i 1 7 W 42 47 ~ I1 7 W ,3~,T ~-: 1'9-D'-C-35 ~V=N_ 100 F""=T~_~_ OF V-RTICAL DOGLEG SECTION .S:VERiTY F~ET gEG/100 174.50 3.28 Z1B.34 2.B9 258.63 3.85 ~i!.32 2.71 370.96 2.86 43~.27 1.01 511.16 2.19 5')1.57 3.71 5:35.37 1.72 7~6.70 0.Sa B85.99 0.40 987.13 0.60 108B.lO O.B2 11.~.76 1.15 1209.~5 1.38 1390.0~ 0.86 1490.40 0.45 !5~0.17 0.39 16~7.53 0.35 17~3.11 0.59 137~.69 0.40 !g75.40 0.68 2371.30 2.70 2154.21 0.00 2207.79 0.00 DATE OF SURVEY: O~-NDV-8$ KELLY 5USHING ELEVATION: ~NGINEER: ~ALFACRE 73.00 FT SUB-SEA DEPTH - , RECTANGULAR COORDINATES HIRe'Z,', D. EP~RTURE NORTH/SOUT,i EAST/WEST F ~ ~ r F E E T F ~ E,~<~"i''''..,:~,:_,,I~'E G M: N 1,56.02 S 56.9~ ~ 175.5Z':".S:""i~8 55 W 203.43 S '87.60 W 214.37 "S :18 22 ~ 246.37 S 81.05 W 259,84 S 18 10 W 296.~8 5 100.32 ~ 312.99 $ 18 41 N 353.00 S 120.77 W 373.08 S 18 53 W 417.~0 S 141.13 W 4~0.6! S 18 40 ~ 487.14 $ 163.17 W 513.74 S 13 31 W 564.42 S 185.98 w 594.28 S 18 14 ~ 655.36 S 209.12 W 687.91 $ 1T 41 W 753.79 5 233.~7 W 789.06 S 17 11 W B51.16 S 257.33 W 889.22 S 16 49 W 948.56 S 280.69 W 939.22 S 16 29 W 1047.06 S 302.85 W 1089.98 $ 16 7 W 1145.71 S 322.97 W 1190.36 S 15 44 W 1245'~0 $ 340.49 N 12~1.11 $ 15 17 W 1344.99 S 354.55 W 1390.94 S 14 46 W 1445.20 S 366.22 W 1490.88 S IZ, 13 W 1545.22 S 37.5.32 W 1590.38 S 13 41 W 1.542.95 S 385.53 W 1687.58 S 13 12 W 1738.95 S 394,35 ;4 1783.11 S 12 46 ~ 1834.51 S 403.18 W 1378,72 S !2 2'7 ~ 1930.7'9 S 417.87 W 1973.49 S 1Z 12 W 2026.00 S 431.94 W 20'71.53 S 12 2 W 2117.23 S 449.45 W 2154.41 S 11 59 N 2160.01 S 457.87 ~ 2228.01 S 11 58 / ARCO ~LA3KA, iNC. 3%-~ KJPaRO~ NBRTH SLBPE,ALAS~A C 3'~Pd l' ~T i "2~ PAGE DATE DF SURVEY: 04-NDV-85 KELLY BUSHING ELEVATION: ;NGINEER: HALEACRE 73.00 FT TOP KdP&RdK - ]AS= KU°ARUK C TOP KUPARUK ~ 5~SE KUPARU~ A PBTD TD INTERPOLATED V&LdES FOR MEASjREO 2~TH 5729.00 5304.00 731~.00 71ZO.O0 CHOSEN H3RIZDNS FROH KB 5972.13 5035.95 5151.89 5320,09 OqlGlN= 647' TVD SJB-SE& 5867.51 5~99.18 5962.95 5088.89 5167.84 6267.09 FSL,781' F R~ N 1803. 31 S 401.24 1833.72 S ~+05.0 B 1895.31 S' 412.92 2015.57 S 430oZ7 2088.01 S 443.70 2160.01 S 457.8? W W W W W C]M~T~TE]~ D~ !9-£,EC-~5 P~GE 7 ARCO ALASKA, INC. 3~-8 KJP~RUK NORTH SLOPE,hLASKA D~TE OF SURVEY: 04-N]V-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE 73.00 TOP 3ASE TOP P~TO TO MAR~£R KUPARUK & KUnARUK C KUPARUR ,~ 5 ..595. ,.,, 0 ,554 0.0 C, ,572 9.00 5 ::9 ,.3/-,,.. ,30 7312.30 7120.00 ORIGIN: 547' TVD FROM KB SUB-SEA $940.61 5367.51 5972.18 5B99.18 5335.95 5962.95 6151.59 6085.89 5240,84 5167.84 5320.09 5247.09 FSL,?81' RE~' NO SU L, T~ RT 83 89 O1 O8 RFA SEC NSU' H/S 3.3 3.7 5.3 5.5 8.0 0.0 1 S 601.2~ 2 S, 1 S ~12.92 7 S 430.27 1 S ~63.70 1 S 457.87 W W ' W W FINAL MEASJR~D DEPTH W6LL LCCATZDN &T TD: TRJ:£ SJR-SE~ V:RTZCAL V:RTiShL DEPTH DEPTH HORIZONTAL D=°&RTUR~ 31ST&NCE AZIMJTd ~EET 3EG MIN FT 7120.00 5320.0'9 5247.39 220:B.01 S 11 58 W SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3A-8 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO REFERENCE O000?]]OS WELL NAME: 3A-8 SURFACE LOCATION: 647' FSL, 781' FEL, S7, T12N, R9E, UM 12. PROJECTION ON vERTICAL PLANE 192. - 12. SCALED IN VERTICAL OEPTHS HORIZ SCALE = 1/SO0 IN/FT WELL NAME: 3A-8 SURFACE LOCATION: 647' FSL, 781' FEL, S7, T12N, R9ET~UM HORIZONTAL PROJECTION NO~TH !000 R£F 000071 lOS SCALE = I/B00 IN/FY SOO 0 -BOO ..~...~...~...~...~...~...~..~... -1000 -lBO0 --H--'? T"T"~'"F' -ZOO0 , -2BO0 :-. ............ 7';'~ ....... ' i ' ' ' ..... ...... ' ~ · ..... ? ?'?"'; ? / . , ...... +'"~"+"+"~.'"~'".~"'~'"+ ........ ~'~ ;;, !'"i"i'"'i"f'"i, if ....... ~'"~ ...... r.-;-.-:-..~_.;.. .. :, ;i: ', i ::'i ;.~..i....: .~;; ..-?..~..~...r.t...r.r.~....~ .... ';'"i'--i--'~'4'-~-'~''-L-;- '~' ~ .... ~ : : . : ; . : : : ; : : i ~ - ~ : ' .... ~'"¢'"'~' ~'"~'"'~' ....... ?'"? .... SOUTH -~1000 -2000 - 1 SO0 - ] 000 -SO0 0 SO0 1000 1 SO0 2000 WEST EAST Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WEL~' NAME AND N~Ej . Reports and Materials to be received by. ,:'~.;~ ~--(:/' Date Required Date Received Remarks Completion Report / Well History Core Chips_ . :. ~: .: . , C6r~' DescrSpt~on , Registered Survey Plat Inclination Survey . ,.~ ~_ ~." .. . , Drill Stem Test Reports ~t~epor-s ~:" ~ ~ ::- Production Test Digitized Data ""/-~' :':" : ~ ' i':: ~.. f L.FJ.04 MEMORANr'UM TO: TH R U: FROM: State of Alaska ALASKA OIL A~vD GAS CONSERVATION COFR~ISSzON C. V ~~'~t t~er ton Chai~a~-~' Lonnie C. Smith Commissioner Doug Amo ~- Petroleum Inspector DATE: December 9, 1985 FI LE NO.: TELEPHONE NO.: D.ADA. 57 SUBJECT: BOP Test ARCO K.R.U. 3A-8 Well Permit No. 85-224 Kuparuk Ry. Field Sunday, October 27, 1985: After witnessing the Sohio Safety Valve Retest, I travel&d to Kuparuk to witness the BOP test at ARCO's KRU 34-8 well. The testing commenced at 9:45· PM and was concluded at !1:30 There were no failures and I filled out an A.O.G.C.C. BOP Inspection Report which is attached. In summary, I witnessed the successful BOP test at ARCO's KRU 3A-8 well. Attachment 32-001 A ( Rev 10-84) O&G #4 4/80 . STATE OF ALASKA ~-~ ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator Location: Dril ling Contracto Rig # i4~ Date ~] g/~asing Set @ Representativm' ~, Location, General Well Sign General Housekeeping Reserve pit Rig ACCUMULATOR SYSTEM BOPE stack Annular Preventer Pipe Rams (~ ~ Blind Rams Choke Line Valves H.C.R. Valve ~ Kill Line Valves Check Valve Test Pres sure ,~ Full Charge Pressure '~)~.~ psig Pressure After Closure l ~P~ psig 200 psig Above Precharge Attained: Full Charge Pressure Attained: ~ ~ r '~ ~ '~2 ~-~--~ ps ig Controls: Master Remote ~ Blinds switch cover Kelly and Floor safety Valves ~Tes t Pressure ~Test Pressure Test Pressure ~'~Tes t Pressure 1 ~Test Pressure Upper Kelly Lower Kelly Bal 1 Type Ins ide BOP Choke Manifold No. Valves No. flanges ~O Adjustable Chokes Hydrauically operated choke Test Time j hrs. 4'6 ,, min ~ sec min ~ sec Test Results: Failures Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. days and Remarks: Dis tribut ion orig. - LO&GCC~ cc - Operator cc - Supervisor InsPector RETURN TO: ARCO Alaska, Inc. Post Office B~-~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 .... .* -..:.:~-..~:..- :.. .' . -. :~ · '-*- -' -::i;~- . .... : . .-. ARCO! ALASKA, INC. KUPARUK OPERATIONS ENGINEERING R~ECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 DATE:Il-19-85 TRANSMITTAL N0:5453 TRANSMITTED HERE~ I RECEIPT AND ttETURN OPEN HOLE LIS TAPES PLUS 3F-7 11-03-85 RUN $1 3F-6 . 10-27-~.5 RUN 3C-13 10-26-85 RUN 3A-8 10-30-85 RUN 3A-1 09-30-85 RUN 2A-8 10-29-85 RDN TH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE ONE SIGNED COPY OF THIS TRANS~IITT~. LI~TING/ SCHL/ ONE COPY OF EACH 3456.0-8045.0~% ~'-~ --~--~/~e/~ ~ ~--F~ 4793 0-9420.0~O~~j-5-~e~-~,~j- 3392 5-8527. ~~ -'33f - RECEIPT ACKNOWLEDGED: BPAE B. CURRIER CHEVRON D & M DISTKIBUTION: D~{ILLING W. PASHER L. JOHNbTON EXXON MOBIL PHILLIPS OIL NSK CLERK J. RAThMELL UNION VAULT/ANO ARCO Alas~<a. Inc. Js a Subsidiary of AtlanticRichtielclCom!oany ARCO Alaska, Inc. Post Office B~O0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- State Reports Dear Mr. Chatterton' Enclosed are the October monthly reports for the following wells' 1B-1 (workover) 3A-7 3C-15 3J-6 9-24 L2-3 2A-8 3A-8 3F-3 3J-7 9-36 L2-13 2D-12 (workover) 3C-6 3F-4 3J-8 16-17 L3-5 3A-5 3C-13 3F-5 4-21 16-18 L3-11 3A-6 3C-14 3F-6 4-22 18-6 (workover) If you have any questions, please call me at 263-4944. Sincerely, d. ~ruber ^ssoc~ate [n§ineer JG/tw GRU12/L80 Enclosures RECEIVED Alaska Oil & Gas Cons. Comm!ssJon Anchoress ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA O~:=,.AN D GAS CONSERVATION CO -N~.¢ISSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wel~(~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-224 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 647' FSL, 781' FEL, Sec.7, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 73 ' RKB I 6. Lease Designation and Serial No. ADL 25632 ALK 2565 8. APl Number 50-- 029-21 #45 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3A-8 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. October ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0245 hfs, 10/26/85. Drilled 12~1/4'' hole to 3180'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 7100'. Ran logs. Cont'd drlg 8-1/2" hole 'co 7120'TD (10/31/85). Ran, cmtd, & tstd 7" csg. PBTD = 7012'. Secured well & RR 0100 hfs, 11/01/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40 weld conductor set ~ 88'. Cmtd w/195 sx AS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3161'. Cmtd w/880 sx AS III & 270 sx Class G. Top job performed w/lO0 sx AS I. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 7101'. Cmtd w/325 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/7088' - 3160' FDC/CNL f/7088' - 6400' Cal f/7088' - 5500' 1 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~ ~ ~~ TITLE Associate Engineer DATE //-/4-~__,~" NOTE--Repot n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEHP2/MR56 Rev. 7-1-80 Submit in duplicate ARCO Alaska, Inc. Post Office ?0'x 100360 AF.,chomge,~ _-:,~[~sl:_a 99510-0360 Te!epho.*-~e ;~)7 276 1215 October 25, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3A-8 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to change the KOP from 3300'TVD to 2800'TVD. Since we expect to spud on October 28, 1985, your earliest approval will be appreciated. Verbal approval was received from M. Minder, AOGCC, today. If you have any questions, please call John Bell at 263-4715. Sincerely, · Gruber Associate Engineer JG/tw GRU12/L41 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA Oi'L AND GAS CONSERVATION CO'r~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. NaArr~ec~f Operator 7. Permit No. Alaska, Inc. 85-224 3. Addre~ 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21#45 4. Location of Well Surface: 647' FSL, 781' FEL, Sec. 7, T12N, RgE, UM 5. Elevationinfeet(indicate KB, DF, etc.) 73' RKB, PAD 40.9' 6. Lease Designation and Serial No. ADL 25632 ALK 2565 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3A-8 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation [] Change Plans ~ Repairs Made Repair Well Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to change the KOP from 3300'TVD to 2800'TVD. 3A-8 will still be 26' away from 3A-7 at the surface. There are no closer wellbores anywhere downhole. Diagrams showing the revised horizontal and vertical projections of the wellbore are attached. Estimated Spud: October 28, 1985 Verbal approval was received from M. Minder, AOGCC, October 25, 1985. Alaska 0ii & Gas 0ohs, Con'~mission Anchoress 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~1 (/'~,/~ .~~-, Title Associate Engineer The space below r Commission use Date /~)- ~ ~5 Conditions of Approval, if any: Approved by COMM ISS ION ER By Order of the Commission Form 10-403 Rev. 7-1-80 (JF8) SN/100 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - : f .~URE~O[ - t -i TnnO_~ . - --_~: _~-_ ......... ,---TOP-W-SAk-SNDS -TVD=2s6-3 ....... ...... -<::: Z-Z .......... ,~L- KOP ;_ 7_LT VD .=.2 800;_ T.I'ID ~2800 -3--K-12 .... TVD=2943-'H'ID=2943-DEP=5 , L.:33_:--EOCZ -T_VD=3899`'-/HD~-39?OIZ1)EP,;~48 - - - '1 - LD ~TVD '5 g 48. :-%_TI~ID=64767OEP ~_i?_8 9 - _ ,~---T'VD',,5955-Tl'tD,,6488?DEP~t~"96 ~ '" : ~._~__T VD= 6040.2THD= 6588LOEp~-~853~ : }-CflTR~--TVD~'6ogg ~-Tt1D,-6660-DEP~895 .... ~ '-- · = TD ~LOO-P T)--.-TV D-6322--TflD,-6933-fDEP~2051 i × September 18, 1985 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 3A-8 ARCO Alaska, Inc. Permit No. 85-224 Sur. Loc. 647;FSL, 781'FEL, Sec. 7, T12N, R9E, Btmhole Loc. 1386'Fb~, 1242'FE~.~-, Sec. 18, T12N, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify 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. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Com~ission may witness testing before drilling below the shoe of the conductor pipe. V~ tr~12~-~,o.urs ,.~ .:-- ,.,..:-' /. x,:,; Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF ~H.E COM~4I$SION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ' ARCO Alaska, Inc. Post Office Bo .... J0360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 4, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3A-8 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 3A-8, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment We estimate spudding this well on October 10, 1985. any questions, please call me at 263-4970. Sincerely, ~a Dri ing Engineer JBK/JFB/tw PD/L170 Enclosures If you have ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA O-~_ AND GAS CONSERVATION cOIv~ISSION PERMIT TO DRILL 20 AAC 25.005 lb. Type of well EXPLORATORY [] SERVICE I--}~ DEVELOPMENT OIL ~X SINGLEZONF% DEVELOPMENT GAS ~ MULTIPLE la. Type of work. DRILL FXlX REDRILL [] DEEPEN [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 647' FSL, 781' FEL, Sec.7, T12N, RgE, UN At top of proposed producing interval 1118' FNL, 1171' FEL, Sec.18, T12N, RgE, UM At total depth 1386' FNL, 1242' FEL, Sec,18, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 73' PAD 40.9' I ADL 25632 ALK 2565 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name Kuparuk River Unit 10. Well number 3A-8 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount .$500,000 15. Distance to nearest drilling or completed 3A-7 well 26' (~ surface feet 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi, NW of Deadhorse miles 3894 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7050' MD, 6304' TVD feP. t 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 3:300 feet. MAXIMUM HOLE ANGLE 43 Ol (see 20 AAC 25.035 (c) (2) 18. Approximate spud date 10/10/85 2686 psig@ 80OF Surface 3066 psig@. 5957 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT _ ~ole-- Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 32' I 32' 112~ 112' + 200 cf 12-1/4"I 9-5/8" 36.0# .-55/HF-EF'.W BTC 3110' 32' 32' 3142'I~ 3142' 700 sx AS III & I ~ I 270 sx Class G 8-1/2" 7" 26.0# .-55/HF-EF:W BTC 7019' 31' II 31' 7050'1 6304' 300 sx Class G , I I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7050' MD (6304' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA DOPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2686 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3A-8 will be 26' away from 3A-7 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby cer/~,f~hat the foregoing is true and correct to the best of my knowledge SIGNED .4 TITLE Regional Drilling Engr. The space~Z~w'f iss~on u CONDITIONS OF APPROVAL DATE Samplesrequired~iXiO ] Mud Iogrequiredl ! Directional Survey required []YES i []YES ~40 [~ES []NO ~ 1~/Y~¢~'~ Permit number I Approval date ,~- ~_~ ff ,,,~/Q.9/1~8/85 ' SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY -~/~, ,COMMISSIONER DATE September IR, 1 985 ~ ~ /, ~_~'/~/~/~ by order of the Commission Form 10-401 (JFB) PD/PD170 / Rev. 7-1-80 Submit in triplicate PERHIT TO DRILL 3A-8 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. ARCO ALASKA, -INC. '- ~- ' ~- ...... PAD 3A. WECL' 'NO~'-:8 PROPOSED .... -KUPARUK FIELD. - NoRTH ~ SLOPE, ALASKA SOUTH 1848 - : .. ', ........... :__' _., ;-.; _- _ ~--_: .... -.:: .:~ _. :_:. .... :_ : ............. : ............... · ~-. · . ......... .,,. _:. , -- ......... _ ~ ........... ~_ ,. . .~ '. . ~ - , : .-___ ,_ ...... -._2. _: ...... --_~_. _:.- _ ~ . 2: .... '_ : _.-_ ....................... ~ .................. ~ .... -... - .... · , ..:_-__~ ~, :~ :_~: .......... :;_ . . . ; : ....... ; . : ..... . .... . : . : . ,- i . . 400 _ . ........... I . ~ ...... : - ~ - , ~ : - · I - - · .... ---:~_~.>; J .... :_?: - .---i' :- .--:-7 ': : . .. ;-5 :': -- ';; ----F ............ : ........... ~-~ ......... . _: -- . ; ;~~.J ~:~t-~ :--:-~:m ......... --~CO 'ALASKA., ' ~ NC-- ........... ' ~':::: ~ =-~=~-~ ~ ~-. =--,, ~--=~---'=-:--:P~D-3A.--UELL NO, 5-6-7-8 PRDPOSED ] ":_~ ';~ -~.~ ~ ,;~ ~- ]--_]~ ".'~_; ~ :--_[~: : ..... ~KUFARUK-EZEL~ ;--NORTH ~PE;-AKa: '; : . ; ~ ; - :'.']~-~-F~:-'-' [ ......... ;'-~ .... i ~-'~ :- --' i'. .... ; ..... ; '" . ', ....... ~ . , . , ; : .. . . . . . , ~ ~ .... . . .-~ ; ~ ~~ ~: ?~_l~-~:~;] ~%~:~' ;' ]NOTE[-LS-WELL~PATHS EXTEND BEYOND.~22 ........ ~. .... T--~., .~:. . . -: - T~,u~~~x-THIS'VIEwING UINDOU ....... ' ' "; ' ' __ i ...... i ~ t:' , -~~'";-: ........... ,-'-: ' .'- ~7-~ ; ' , ...... ~ ~ - ~ / i ..... ' _ ~: ' ' ~ - ' ' ~ --' , ~~~ ...... T ,. ....... i i i , i, ..... _-- KUPARUK RI VER UNIT 20" -DI VE~TER SCHEMAT I C DE S CR I PT I ON I. 16 · C6~DUCT 2. TANI,(O STARTER HEAD. 3. TA~,(O SAVER SUB. ,4. TA~,(O LO~R QU I CK-CO~t~CT ASSY. 5. TAhI<O UPPEr QUICK-COf,,t~CT ASSY. 6. 20" 2000 PSI DRILLING SPOOL W/I O" OUTLETS. ?. I0" HCR BALL VALVES W/lO" DIVERTER LINES, VALVES OPEN AUTOf4ATICALLY UPON CLOSURE OF A~AR PREVENTER. 8. 20" 2000 PSI A~LAR PI::~VENTER. 3 I MAINTENANCE & OPERATION I. UPON INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES -- HAVE OPEh, ED PROPERLY. 2. CLOSE AI',a',iJLAR PREVENTER At,l) BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE Af',I',,MLAR PREVENTER I N THE EVENT 'THAT AN I I'~LUX CF FLUIDS OR GAS IS DETECTED. IF NECESSARY,. ~t~,JALLY OVERRIDE Ah,E) CLOSE APPROPR ~ ATE VAL YE TO ACHIEVE DOWNWIND DIVERSION, DO NOT SHUT IN UNE>ER ANY CIRCUMSTANCES. i i i i i ii i ii i i i 6 DIAGRAM #1 13-5/8" .... ,SCX~ PS~ RSRRA ~OR STACK I. 16' - 2000 PSI TAN<C~ STARTING FO_AD 2. II' - 3000 PSI CASING ~E, N2 3. I1' - 3000 PSI X 13-5/8' - 5000 PSI S~AC~R SF~OL 4. 13-5/8' - 5000 PSI PIPE RAt~ 5. 13-5/8' - 5000 PSI DRILLING SF~OL W/Q4CKE AN:) KILL LI~r.S 6. 13-5/8" - 5000 PSI EZ:tJEN_E RA~ W/PIPE RN~ ON TOP° 7. 13-5/8' - 5000 PSI ~ · ACQ.tCULATOR CAPACITY TEST I. Q-,ECK AN;) FILL A~TCR RESERVOIR TO PRCPE~ LEVEL WITH FfYDRAL~IC FLUID. 2. ~ THAT A~TC~ F~ESSURE IS ~ ~ WI~ I~ ~I ~~ ~ ~ ~~T~, 3. ~ TI~, T~ ~ ~ ~ITS SIXThlY 4. ~~ ~ ~ ~T, ~ A~T~ L~ LIMIT IS 45 ~~ ~~ T~ ~ I~ ~I ~~ 5 4 3 2 . I 13-5/8" BOP STACK TEST 1. FILL BOP STACK AN3 ~ MANIF~ WITH ARCTIC DIESEL. 2. Q-ECK 'R4AT ALL LOCK ~ SC~ IN WE]_L~ A~ F1J_LY RETRACTED. SEAT TEST PLUG IN ~LPE. AD WITH RULING JT AhD RLt~ IN LO~ S~. 3, CLOSE AN~ F~ AhD MAhtJAL KILL AAD GNOKE LIhE VALVES ABJA~ TO BOP STACK, ALL OT~ VALVES AND C~ S~ BE OPEN. 4. PRES~ UP TO 2_.50~ FOR I0 MIN. IN- CREASE PRES~ TO(,_3OOO_~P_SIJA~ HOLD FOR I0 MIN. BL~'mr~ PRES~ TO 5. OPEN AJ~ P,~ENTER AhD MAh~JAL KILL AbE) 040KE LIh~ VALVES. CLOSE TOP PIRE RA~ ARID HCR VALVES ON KILL AbE) CHOKE LI~ 6. TEST TO 250 RSI Ah~)~3OOO~,P~I~AS IN STEP 4. 7. CC~INUE TESTING ALL"-VC~ES, LIhF_S, AhD C~ES WITH A 250 RSI LC~ AhO 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT F~E~ TEST ANY .040<E THAT ~S .N~T A FULL CLOSING POSIT~V~ SEAL 04CK~ ONlY RJNCTZON TES~ 04O<ES THAT CO NOT FU_L¥ CLOSE. 8. C~ TOP PIPE RA~ AhO CLOSE BOTTC~ PIPE RA~. TEST BOTTC~ PZPE RA~S TO 25O PSl AND 3COO PSI. 9. OPEN Byrro~ PI~E RA~S, 8ACK OCrT RUNNING JT AND . I0. CLOSE BLIND RA~ Ah~ TEST TO 250 PSI AND 3000 OPeN B-I O --mIEVE TEST .Ue. SUrE 'N~ANIFOLD AN) LIN~S ARE FULL- CF NON-FREE:ZING FLUIB. SET ALL VALVES ZN DRILLING POSITION. '12: TEST STAh/)PIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, AN3 INSIDE BOP TO 250 PSI AN3 13. REOQ~ TEST INc'ORI~TI~ ON BL~ PRg-VENTER TEST FOI~, SIGN, AN3 SEN:) TO DRILLING' SUPERVISOR. 14. PF_RF~ CQVPLETE BOPE TEST AF-FER NIPPLING UP A~D ~¢_EKLY THER~~ ~IONALLY OPERATE BOPE DAILY. I~AY 1 5,, I ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plats - 3A Pad Wells 1-16 Dear Mr. 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 GRU11/L22 Enclosure If RECEIVED AUG ~ 0 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfleldCompany ' i ? 8 NOTES :. CJCROINATES 4, RE A.S.R,ZONE 4 2. SECTION ~_,NE DISTANCES ARE TRUE. 3. HOR!ZONTAL POSITIONS BASED CN THE D.S.-SA WEST & 3AMID PER LH0 6 ASSOC. 4. VERTICAL POSITION BASED CN 3A EAST ~ 3A MID PER LHD ~ ASSOC. 5.OG. ELEVATIONS iNTERPOLATED FROM S/C D~G, CED- RlXX- 3020 rev.~ 5'g:~- F ROBERT ~ELL ~ ~ ~ HEREBY CERTIFY THATI AM PROPE~LY REGISTERED L~SCENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF AUGUST 14,1985 LOCATED IN PROTRACTED SEC. 7,T. I,?. N. F~.9~.~ Et 12 Oil & 9, AS BUILT ~__~ CONDUCTORS I- 16 _ Y=5,996,860.05 LAT= 70°24 X= 507,712.01 LONG= 14g° . 478' FSL, 736' FEL, 36.8 0G ' 09. 520"' 56' I~.020" . 40.8 PA0 2- Y=5,gg6,884.17 LA X= 507,705.57 L0N 503' FSL, 743' FEL, 3- Y=5,996,908.32 LA X: 507,699.06 L0N 527' ;SL, 749'FEL, 3 ~- Y=$,996,g32. 72 LA X: 507,692.55 LON 551' FSL, 756' FEL, 5- Y=5,ggG,g56.61 LA X: 507,686.21 LON 575';SL, 762'~EL, 36 6- Y=5,996,980.84 LA X= 507,679.66 LON 5go' FSL, 768' FEL, 7- Y=5,gg7,004.90 LA X= 507,673.26 LON 623' FSL, 774'FEL, 3 8- Y:s,gg7,02g.03 LA[ X: 507,666.81 LON 647' FSL, 781' 9- Y=$,997,101.24 X= 507,647.70 720' FSL, 800' 10- Y:5,g97,[25.66 X= 5d ,640.89 144' ~}L, 806! Il- Y=5,997,149.84 X= $07,§34.44 768' FSL, 813 12- Y:5,997,173.97 X= 507,627.96 792' FSL, 81g 13- Y=5,997,198.08 x= 507,621.48 817' ;SL, 825 14- Y=5,ggT,222.2g 15- [EIVED S o 1985 Gas Cons. CommtssJ~h mchorage x= 507,615.0 841' FSL, 832 Y=5,997,2~6.44 ×: 507,608.55 865' FSL, 838 Y:5,gg/,270.55 5n~,b02.10 ; L, 344 G FEL, 3 LAT: LONG FEL, 3 LAT: LONG FEL, 3 LAT= LONG FEL, 3 LAT= LONG FEL, 3 LAT= LONG FEL, 3 LAT: LONG FEL, 3 LAT: LONG FEL, 3 LAT= LONG ;EL, 35 = 70074 G: 149° 3 = G G 3 G · : G 3 G ' 09. 758" 56' !4. 207" 6.8 O'S, :,0.9 70o24'0,~. 14g°56' [4. j97" 7 0G, 40. 8 PAD 70°24' 10.235" 149056, 14.587" .70G, 40.8 PaD 70024' i0.470" 149°56' 14. 773" OG, 40.9 P~D 70°24' 10. 709" = 149°56' 14.963" 6.5 OG, 40.8 PAD 70°24' lO.gqS" : 14g°56' 15 15~" · 5 0'], '-,l. I P,~9 7002~' Il. ig3" = 149°56' 15 33::i" 6.4 OG, 40.9 PAD 70024' 11.893" = 149°56'15 896" 6.3 OG, 41.7 PA.r_` 70°24' i2. 134" = 149°56' 16 095" 6.30G, al.6 PAD 70o24' 12.371" = 149°56' 16 283" 6.20G, 41.2 PAD 70°24' 12.509" : 149°56' i6 ,,; ':" 6. 1 0 G, 70°2'~' i2. 846" = 1~9°56' 15. ~-<- " 6.0 OG, ~l.O 70o24' = 1~9°55' 5.8 CG, ~l.O 70o24' 13.322" = 14g°56' 17.03'.'}" 5.6 0G, al.3 70°24 = I~,9°55' !7. -'" .5 0G, ~I. ~- : ,.. , ~,,.,,-~ ,~, ARCO Alaska, Inc. CONDUCTOR AS- B UI LT LOCATIONS 8SSD& ""t '": Drafted by:~ Owg. no.: NSK 85-16 !1~1111 ~ Jill I~ I Ir ~ CHECK LIST FOR NEW WELL PERMITS Company / ~ '?'"" '~ Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc / ?, ~' . ('2 thru 8) (8). ,' J " 9 · (3) Admin ,~ .' ' ( thru 12) : 10. (10 and 12) 12. YES NO th "',- 1. Is e permit fee attached ........................................... :,,,. .... : 2 Is well to be located in a defined pool . . · · · e e. e · e . e · e e e. · e e e e e e e e · · · ~1,~ 3. Is well located proper distance from property line ................... -.",~' 4. Is well located proper distance from other wells .................... · ... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is wel. 1 to be deviated and is wellbore plat included ................ 7 Is operator the only affected party ..................... . . · e e . · · · . e · · .~. 8. Can permit be approved before ten-day wait .............................. '\ Does operator have a bond in force .................................. Is a conservation order needed ....... eeeeeee ee.e eeeeee,ee.leeee. ·lee Is,administrative approval needed ................................... Is the lease number appropriate ..................................... REMARKS (4) Ca s g ~~,~, ~ -)f-~,~' (13 thru 21) (22 thru 26) 13. 14. 15. 16. 17. 18. 19. 20. 21. '22. 23. 24. 25. 26. 27. Is conductor string provided ............................. ........... 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 surface casing protect fresh water zones ....................... 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 ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ,,~OO~ psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) ....... ' ........... Is the presence of H2S gas probable ................................. ~ Additional requirements ............................................. Additional Remarks: o ~-] H 0 Geology: Engi~..e.ring: HWK~ LCS WVA';~ MTM~//' HJH,~. JAL ~h ........ .,~ ' rev: 03/13/85 6.011 INITIAL GEo. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE / .' t - /, ? ,,//" ' Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. 2' ,,,' Dk . I T i,,,~ C 0 L' F; 68 68 68 6a PROCESS O000t~OOOOOOnO0 0000000 O00O(;nO0000000 0000000 O0000oO000000n 0000000 000000000 0000000 0000000 O 000000 68 0000(',,0000000()0 68 00000o00000000 68 O000C,,O00000000 68 O000POt) OOOO000 6,9 00000000000000 f,~ O000OO00000000 ¢, itl', ! u r'.'. b' [.~ t; ~432.2 ! 25 FCt~RA 4 1 9 6 0 l 0.1 4 0 ? 3 ~, 9~°$ 4,J, 921 .~108 6.9336 7854 r-, 9 q ,,, ? % ('r~ Li' r',r ',,"i ~' i .... r.,. a 50 t r" ,q .r: 1~ 73. ? 773 ~'. 31.39,65 '? 67. r! l ? b r.! ;i: P A '/33.,~125 r.~ · 7129 r, ? p 1' 4 0.8 2 n 3 6' P 6.~453 88.8398 3.1370 17.1397 27.3955 78.0273 3.ngOl 25.39O6 5.2703 93.4023 3.0198 ln,9375 7.~164 3]1252 -2.2949 2,2190 112.6523 3.~834 ? 5,452 .~, 27 5898 3 7209 13 5742 2,99,.9.,4 1.46.6~75 -,q9c~. 2bO0 2,8577 229 4375 -999 2500 -r)99 2500 3.5608 !76.1875 -o9~,2500 -g99.2i~oo -g99,, 2500 -- 0'9 c~. 2bPO . ,'" '.) o, "b {" ~ ,-, ~ '"..,) 9 ,, 2500 - '.~ 9 C,'. '> S n <! 0273 22?7 ii .... 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'750 u C, R .,n rl~ O. ,, ? 5 O ~} r),~N'~ .4.o242 -099.2500 -099,2500 -ggq,2500 !.765'7 -q99.2500 -q99.~500 -o99,~5n0 2.0530 -999.~500 -q99,2500 -999.2500 2.64~b -q99.2500 -~99'~500 ,-qgg.2500 2" ]71 3 ~99 2500 i0{ 9: soo -099.2500 2,7151 -~)90. 2500 -g9:}, 25 0 -q90.2500 ".q99. 2500 -g99,2.,.500 ,-999,2500 3,2639 .2 , 6663 ~ n,2500 999,, 9.500 2,351~ -~99,2500 -999,2500 -99~,~500 2. :'1~71 3 - 999 · 2500 -,o99 ~500 -'2 '} ,.:t 7 ;~ 7 ', ~ C 4 f, .i C A f _l - ¢. 9 q ,, '7 5 0 ,.) D ? b{ I 2,. '? 7 % (¢ ]' [.~ '¢ ' 999. '250 (~, C q .. ,-'" '4 q ~ !) a ,','. t'~ P t4 1 -990. 7500 dR -o, r4o.. ? 500 f.~PH i . o 9 0 ,, ? f:,;, 0 ,) r') P ~-~ 1 2,7268 -q99.2500 -099.2500 -o99,~500 3.2053 -099.2500 -q99,2500 -999.2500 3.6506 -99g.9500 4,;~539 -099.:.500 -999.~500 -99o,2500 ,3.017 2 5 '499 :)500 -q99,2500 -!.)99. ~500 4.. 48 5 1 - o g 9 ,7500 -999,7500 nO0,6875 99~, 250O 99' 2500 -099.~500