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Home My WebLink About197-206Originated: Delivered to:18-Jun-25Halliburton 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 # E SET#1 1B-20 50-029-23164-00 910026681 Kuparuk River Packer Setting Record Field- Final 7-May-25 0 12 1D-117 50-029-22844-00 910027101 Kuparuk River Plug Setting Record Field- Final 8-May-25 0 13 1D-133 50-029-22827-00 910010225 Kuparuk River Multi Finger Caliper Field & Processed 25-May-25 0 14 1G-02 50-029-20813-00 910036496 Kuparuk River Multi Finger Caliper Field & Processed 21-May-25 0 15 1H-08 50-029-20763-00 910080713 Kuparuk River Multi Finger Caliper Field & Processed 22-May-25 0 16 1H-08 50-029-20763-00 910080713 Kuparuk River Plug Setting Record Field- Final 22-May-25 0 17 1Q-04 50-029-21250-00 910027200 Kuparuk River Tubing Cut Record Field- Final 14-May-25 0 18 1Q-04 50-029-21250-00 910027200 Kuparuk River Tubing Cut Record Field- Final 15-May-25 0 19 1Q-22 50-029-22595-00 910027102 Kuparuk River Plug Setting Record Field- Final 16-May-25 0 110 2B-02A 50-029-21154-01 910106459 Kuparuk River Leak Detect Log Field- Final 14-Jun-25 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:203-115197-237197-206182-138182-093184-234195-140216-087T40582T40583T40584T40585T40586T40586T40587T40587T40588T405896/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:37:34 -08'00'197-2061D-13350-029-22827-00 910010225Kuparuk RiverMulti Finger CaliperField & Processed25-May-2501 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP Repair 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 5265'feet 2237'feet true vertical 4239'feet None feet Effective Depth measured 5122'feet 2154', 4565', 4671', 4740', 4845', 4928' feet true vertical 4105'feet 1961', 3584', 3683', 3748', 3846', 3923'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" 5.1" L-80 L-80 4430' 4960' 3460' 3953' Packers and SSSV (type, measured and true vertical depth)2154' 4565' 4671' 4740' 4845' 4928' 1961' 3584' 3683' 3748' 3846' 3923' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:West Sak Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 5249'4225' Burst CollapseCasing 5208' 121'Conductor Surface 16" 7-5/8" 80' measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-206 50-029-22827-00-00 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: ADL0025650 Kuparuk River Field/ West Sak Oil Pool KRU 1D-133 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MDSize 121' Well Shut-In 4628-4664', 4696-4732', 4786-4828', 4866-4922' 3643-3677', 3706-3740', 3791-3830', 3865-3918' 324-712 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. Packer: D&L Feed Through Packer: SC-1 Gravel Pack Packer: Baker SC-1 Isolation Packer: Baker SC-1 Isolation Packer: Baker SC-1 Isolation Packer: Baker SC-1 Isolation SSSV: None Elliott Tuttle elliott.tuttle@conocophillips.com (907) 263-4742CTD Engineer Fra O s 6. A PG , r Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:03 am, Mar 28, 2025 Digitally signed by Elliott Tuttle Reason: I am approving this document Location: Anchorage Tower, CoP Date: 2025.03.28 07:09:29-08'00' Elliott Tuttle RBDMS JSB 040325 JJL 4/9/25 DSR-4/2/25 Page 1/10 1D-133 Report Printed: 2/27/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/13/2025 02:00 2/13/2025 11:30 9.50 MIRU, MOVE RURD P RDMO 1B-09. 0.0 0.0 2/13/2025 11:30 2/13/2025 12:30 1.00 MIRU, MOVE RURD P LD derrick Load out shop and camp clean cellar 0.0 0.0 2/13/2025 12:30 2/13/2025 14:00 1.50 MIRU, MOVE RURD P Move camp shop and pits dowm road from 1B to 1D pad. 0.0 0.0 2/13/2025 14:00 2/13/2025 17:00 3.00 MIRU, MOVE RURD P Move sub from 1B to 1D pad. 0.0 0.0 2/13/2025 17:00 2/13/2025 18:30 1.50 MIRU, MOVE RURD P Raise and pin derrick. 0.0 0.0 2/13/2025 18:30 2/13/2025 21:00 2.50 MIRU, MOVE RURD P Safe out cellar, spread herculite, and stage wellhead equipment. 0.0 0.0 2/13/2025 21:00 2/13/2025 23:30 2.50 MIRU, MOVE RURD P Spot pits, set mats and herculite. 0.0 0.0 2/13/2025 23:30 2/14/2025 00:00 0.50 MIRU, MOVE RURD P Spot pits, set mats and release trucks. (two flat tires on truck) 0.0 0.0 2/14/2025 00:00 2/14/2025 01:00 1.00 MIRU, MOVE RURD P Spot pits, set mats and release trucks. (two flat tires on truck) 0.0 0.0 2/14/2025 01:00 2/14/2025 11:00 10.00 MIRU, MOVE RURD P Perform derrick up inspection checklist. Spot pits. 0.0 0.0 2/14/2025 11:00 2/14/2025 14:30 3.50 MIRU, WELCTL RURD P Rig Accept at 11:00 when rig was ready to take on fluids. 650 TGB/150 IA initial pressures 0.0 0.0 2/14/2025 14:30 2/14/2025 17:30 3.00 MIRU, WELCTL KLWL P Circulate filtered 9.6 ppg NaCl down IA up TBG. Then Bullhead 1.5 volumes KWF at 3.5+ BPM down TBG and out perfs. Tubing still flowing. 0.0 0.0 2/14/2025 17:30 2/14/2025 18:00 0.50 MIRU, WELCTL KLWL P Line up and bull head 120 BBLS @4 BBL/Min @ 880 PSI 0.0 0.0 2/14/2025 18:00 2/14/2025 19:00 1.00 MIRU, WELCTL OWFF P Shut in and montior tubing pressure. ITP: 550 PSI FTP: 200 PSI 0.0 0.0 2/14/2025 19:00 2/14/2025 20:30 1.50 MIRU, WELCTL OWFF P Line tubing up to tiger tank, and observe flow. Observe initial decreasing trend every 5 min. Started @ 9 BBL/ 5 min, slowed to 1 BBL/ 15 min. Shut in tuibng put gauge on read 30 PSI. 0.0 0.0 2/14/2025 20:30 2/14/2025 22:30 2.00 MIRU, WELCTL OWFF P Hook up hose in cellar to choke manifold. Line up and continue to monitor flow back through rig choke to trip tank. Observe flow drop to 0. Open tubing valve in cellar, observe crude oil flowing back. Check IA, at wellhead, IA dead. 0.0 0.0 2/14/2025 22:30 2/14/2025 23:30 1.00 MIRU, WELCTL KLWL P Line up on tubing, and bullhead 210 BBLS brine down tubing. 5 BBL/Min @ 923 PSI. 0.0 0.0 2/14/2025 23:30 2/15/2025 00:00 0.50 MIRU, WELCTL OWFF P Shut in tubing, and montior tubing pressure. ITP: 600 PSI, FTP: 300 PSI. 0.0 0.0 2/15/2025 00:00 2/15/2025 00:30 0.50 MIRU, WELCTL OWFF P Line up and bleed pressure through rig choke. 0.0 0.0 2/15/2025 00:30 2/15/2025 12:00 11.50 MIRU, WELCTL OWFF P Relax well, and flow check through rig choke, and poor boy degasser. Rcord diminishing TBG flow from 40 second per 5 gallon bucket to no flow. Bleed back 103 BBLS total. 0.0 0.0 2/15/2025 12:00 2/15/2025 13:00 1.00 MIRU, WELCTL MPSP T Vault Wellhead tried to set BPV. The 4" and 3.5" brought to location were too large. Trip to valve shop and retrieved 3" BPV. 0.0 0.0 2/15/2025 13:00 2/15/2025 14:00 1.00 MIRU, WELCTL MPSP P Installed 3" BPV/test plug and PT from above 1400 PSI for 10 min. Good test. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 2/26/2025 Page 2/10 1D-133 Report Printed: 2/27/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/15/2025 14:00 2/15/2025 17:00 3.00 MIRU, WHDBOP NUND P ND tree/NU BOPE TQ bolts on flange/Kill line. 0.0 0.0 2/15/2025 17:00 2/15/2025 18:30 1.50 MIRU, WHDBOP RURD P R/U test equipment. Fill stack and purge lines. Shell test BOP. 0.0 0.0 2/15/2025 18:30 2/16/2025 00:00 5.50 MIRU, WHDBOP BOPE P Test BOPS. Test Annular, Upper pipe rams, lower pipe rams, to 250 low/ 2500 PSI high 5 min each w/ 3.5" Test joint. Test Blind rams to 250 Low 2500 High. Perform Koomey draw down test. Test gas alarms, and flow paddles. Test witnessed by Austin McCleod. 0.0 0.0 2/16/2025 00:00 2/16/2025 00:30 0.50 MIRU, WHDBOP BOPE P Test BOPs 250 low 2500 PSI high 5min each w/ 3.5" test joint. 0.0 0.0 2/16/2025 00:30 2/16/2025 01:00 0.50 MIRU, WHDBOP RURD P R/D BOP test equipment, drain stack, blow down lines. 0.0 0.0 2/16/2025 01:00 2/16/2025 01:30 0.50 COMPZN, RPCOMP MPSP P Pull test dart and BPV. Install isolation sleeve in tubing hanger. 0.0 0.0 2/16/2025 01:30 2/16/2025 03:00 1.50 COMPZN, RPCOMP THGR P R/U handling equipment. M/U landing joint to tubing hanger. Kelly up top drive to landing joint BOLDS. 0.0 0.0 2/16/2025 03:00 2/16/2025 04:00 1.00 COMPZN, RPCOMP PULL P Attempt to pull hanger, Pull up to 100K HKLD. Slack off and check LDS and B/O Hanger alignement pint. Attempt to pull hanger, work up to 175K. Pull up to 160K, Wrap wellhead in herculite, and steam. After 20 min hanger popped free. Continue to pick up to 140K, observe packer shear, and weight drop to 70K. 0.0 0.0 2/16/2025 04:00 2/16/2025 04:15 0.25 COMPZN, RPCOMP OWFF P OWFF. Fluid level dropped in annulus. 0.0 0.0 2/16/2025 04:15 2/16/2025 04:45 0.50 COMPZN, RPCOMP CIRC P Line up and start to CBU @ 3 BBL/min @ 440 PSI. Observe packer gas back at surface. 0.0 0.0 2/16/2025 04:45 2/16/2025 05:30 0.75 COMPZN, RPCOMP OTHR P Close annular, and line up to poor boy degasser. Fill poor boy degasser. 0.0 0.0 2/16/2025 05:30 2/16/2025 05:45 0.25 COMPZN, RPCOMP OTHR P Rig crews crew change. PJSM w/ oncomming crew. 0.0 0.0 2/16/2025 05:45 2/16/2025 06:45 1.00 COMPZN, RPCOMP CIRC P Circulate 3 BPM/380psi. shut in annular circ through gas buster at 3 BPM/630 psi with no returns. Pumped 66 bbls total. Open tubing and IA and bleed back 13 bbls. 0.0 0.0 2/16/2025 06:45 2/16/2025 07:15 0.50 COMPZN, RPCOMP CIRC P Line up to bullhead down IA. Pump 15 bbls before catching fluid. PSI climbed from 150psi to 2400 psi FCP at 3BPM. Pumped 35 bbls total. 0.0 0.0 2/16/2025 07:15 2/16/2025 14:00 6.75 COMPZN, RPCOMP CIRC P Discus with town and pump 210 bbls down tubing at 3 bpm, then up rate to 5 bpm/950 psi for last 57 bbls. Only got 6 bbls back to gas buster everything else bullheaded away. Bleed back 93 bbls. OWFF = No flow 0.0 0.0 2/16/2025 14:00 2/16/2025 14:30 0.50 COMPZN, RPCOMP PULL P Move packer up and down 3 times and within 5 minutes packer gas to surface. 0.0 0.0 2/16/2025 14:30 2/16/2025 17:00 2.50 COMPZN, RPCOMP P Circulated 230 bbls down down IA at 3BPM 2300 ps taking returns up tubing. Got 229 bbls returned to surface and sent to cuttings box. Bled back 9.3 bbls. 0.0 0.0 2/16/2025 17:00 2/16/2025 17:30 0.50 COMPZN, RPCOMP P Observe well for flow. Observe gas, and oil back to surface. 0.0 Rig: NABORS 7ES RIG RELEASE DATE 2/26/2025 Page 3/10 1D-133 Report Printed: 2/27/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/16/2025 17:30 2/16/2025 17:30 COMPZN, RPCOMP P Consult town for plan forward. Call out fluid, and load pits. Monitor IA and tubing pressures. Tubing: 29 PSI IA: 20 PSI. Pressures tabilized after 1 hour. 2/17/2025 00:00 2/17/2025 00:30 0.50 COMPZN, RPCOMP WAIT P Wait on fluids. 0.0 0.0 2/17/2025 00:30 2/17/2025 01:00 0.50 COMPZN, RPCOMP SFTY P PJSM w/ Crew to circulate out packer gas. Line up to circulate. 0.0 0.0 2/17/2025 01:00 2/17/2025 02:30 1.50 COMPZN, RPCOMP CIRC P Line up and Reverse circulate 250 BBLS @ 2000 PSI @ 126 GPM. Taking retuns out of the gas buster. 205 BBLS returned to surface. 0.0 0.0 2/17/2025 02:30 2/17/2025 04:00 1.50 COMPZN, RPCOMP CIRC P Line up on tubing and IA. Bullhead 350 BBLS @ 6 BBL/Min @ 1176 PSI. 0.0 0.0 2/17/2025 04:00 2/17/2025 05:00 1.00 COMPZN, RPCOMP OWFF P Monitor pressures for 30 min. 0.0 0.0 2/17/2025 05:00 2/17/2025 11:00 6.00 COMPZN, RPCOMP OWFF P Line up tubing and IA to MGS and relax well. Bleed back 130 BBLS. 0.0 0.0 2/17/2025 11:00 2/17/2025 12:00 1.00 COMPZN, RPCOMP RURD P RD head pin and circulating equipment. 0.0 0.0 2/17/2025 12:00 2/17/2025 16:00 4.00 COMPZN, RPCOMP OWFF P OWFF and reciprocate pipe to relax packer. 0.0 0.0 2/17/2025 16:00 2/17/2025 19:00 3.00 COMPZN, RPCOMP CIRC P Pump down tubing and up IA at 1 bpm then 2 bpm at 100 psi. Gas returns are persistantly comeing to surface but cleaning up. 0.0 0.0 2/17/2025 19:00 2/17/2025 20:30 1.50 COMPZN, RPCOMP CIRC P Pump at 1 BBL/min to keep fluid moving, no gas to surface. 0.0 0.0 2/17/2025 20:30 2/17/2025 21:30 1.00 COMPZN, RPCOMP CIRC P Pump @ 3 BBL/Min @ 260 PSI, observe some crude back to surface, no gas to surface. Lost 17 BBLS during circulation. 0.0 0.0 2/17/2025 21:30 2/18/2025 00:00 2.50 COMPZN, RPCOMP OWFF P Relaxed well, bled back 11.86 BBLS for 17 BBLs lost on last circulation. 0.0 0.0 2/18/2025 00:00 2/18/2025 01:30 1.50 COMPZN, RPCOMP OWFF P OWFF 30 min: Fluid level dropping in stack. Line up to trip tank and establish loss rate for 30 min: 3.5 BBL/HR loss rate. PJSM w/ crew on laying down landing joint and tubing hanger. 0.0 4,544.0 2/18/2025 01:30 2/18/2025 02:00 0.50 COMPZN, RPCOMP PULL P Reciprocate pipe in the stack. Observe fluid level drop while pipe being pulled. Pull tubing hanger to rig floor. Cut ESP cable, L/D tubing hanger, and landing joint. 4,544.0 4,520.0 2/18/2025 02:00 2/18/2025 18:00 16.00 COMPZN, RPCOMP PULL P POOH w/ 3.5" ESP completion. F/ 4520' work through tight spot with packer at 500' from surface continue to pull tubing to 99' 4,520.0 99.0 2/18/2025 18:00 2/18/2025 20:00 2.00 COMPZN, RPCOMP PULL P OWFF while disconnecting ESP cable from motor. LD ESP cable, clear floor. LD motor and pump assembly. 99.0 0.0 2/18/2025 20:00 2/18/2025 20:30 0.50 COMPZN, RPCOMP P Pull ESP cable back to spooler. String rope through ESP sheave. Clean and clear rig floor. 0.0 2/18/2025 20:30 2/18/2025 21:00 0.50 COMPZN, WELLPR OTHR P Install wear bushing in well head. 0.0 0.0 2/18/2025 21:00 2/18/2025 23:00 2.00 COMPZN, WELLPR BHAH P P/U Clean out BHA F/ Surface to 228' 0.0 228.0 2/18/2025 23:00 2/18/2025 23:30 0.50 COMPZN, WELLPR PULD P Single in the hole w/ clean out BHA F/ 228' To 449.82' 228.0 452.0 Rig: NABORS 7ES RIG RELEASE DATE 2/26/2025 Page 4/10 1D-133 Report Printed: 2/27/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/18/2025 23:30 2/19/2025 00:00 0.50 COMPZN, WELLPR PULD P Set down 10 K @ 452'. P/U and break over to P/U WT. Slack off, and set down 10K. P/U turn string Turn 1/4 Turn slack off, st down 15K, Observe weigh come back up, run down to 453. Repeat same steps same results. 452.0 452.0 2/19/2025 00:00 2/19/2025 02:00 2.00 COMPZN, WELLPR BHAH P POOH racking back 2 stands of drill pipe, and drill collars. Remove 6 3/4" Flat bottom mill, and 5" Boot baskets. M/U Mule shoe to bottom of BHA. Run back in to 443'. 443.0 443.0 2/19/2025 02:00 2/19/2025 02:30 0.50 COMPZN, WELLPR PULD P Attempt to work through tight spot from 443' to 445'. Set down up to 15K, index tring a quarter turn at a time. Unable to pass 445'. 452.0 2/19/2025 02:30 2/19/2025 03:30 1.00 COMPZN, WELLPR BHAH P POOH F/ 443' to surface reconfigure BHA. Drop one string mill. Run back in to tight spot @ 443'. 2/19/2025 03:30 2/19/2025 04:00 0.50 COMPZN, WELLPR PULD P Work string from tight spot @ 443'- 449' to 454'. Max set down 15K 443.0 454.0 2/19/2025 04:00 2/19/2025 04:30 0.50 COMPZN, WELLPR PULD P Circulate around 3% Safe lube. Let lube soak. Orient string mill and work past tight spots @ 443/-449' w/ 5-10K Drag. 454.0 454.0 2/19/2025 04:30 2/19/2025 08:30 4.00 COMPZN, WELLPR PULD P Continue RIH with string mill tag top of liner at 4547.67' set down 5K 454.0 4,547.7 2/19/2025 08:30 2/19/2025 11:00 2.50 COMPZN, WELLPR CIRC P Pump 40 BBL deep clean pill. Circulate 9.6# at 2 BPM 150 PSI SxS. 25 BBL loss to formation 4,547.7 4,547.7 2/19/2025 11:00 2/19/2025 11:30 0.50 COMPZN, WELLPR OWFF P OWFF for 30 minutes. No flow 4,547.7 4,547.7 2/19/2025 11:30 2/19/2025 13:00 1.50 COMPZN, WELLPR TRIP P TOOH With stringmill and mule shoe BHA F/4547.7' PUW=102K. T/10' 4,547.7 219.5 2/19/2025 13:00 2/19/2025 13:30 0.50 COMPZN, WELLPR BHAH P LD BHA 219.5 0.0 2/19/2025 13:30 2/19/2025 14:30 1.00 COMPZN, WELLPR SVRG P Install derrick camera service 0.0 0.0 2/19/2025 14:30 2/19/2025 15:00 0.50 COMPZN, WELLPR BHAH P MU 6.75" Swage and 6.69" string mill BHA. 222.1 215.8 2/19/2025 15:00 2/19/2025 16:30 1.50 COMPZN, WELLPR TRIP P TIH T/453' to 456' continue down to 449' set 30K PUW=45K pulled 105K sticky 215.8 449.0 2/19/2025 16:30 2/19/2025 18:00 1.50 COMPZN, WELLPR TRIP P TOOH C/O BHA. L/D String mill, Run back in hole w/ CSG swedge to 443'. 449.0 449.0 2/19/2025 18:00 2/19/2025 19:00 1.00 COMPZN, WELLPR TRIP P Work 7.75" swedge through tight spots F/ 443' to 449'. 5-10K Going through upper tight spot @ 443'. 15-20K going though tight spot @ 449'. Spot in 3% Lube 776, let soak for 30 min, and work through tight spots. Consistent 5-8K through upper tight spot. 10-15K going through tight spot @ 449' for the first 3 passes. Drag increased to 15-20K through lower tight spot after first 3 passes. 449.0 449.0 2/19/2025 19:00 2/19/2025 21:00 2.00 COMPZN, WELLPR BHAH P POOH F/ 449 to surface, L/D CSG swedge, P/U RCJB, and 5" Boot baskets. 449.0 225.0 2/19/2025 21:00 2/19/2025 23:30 2.50 COMPZN, WELLPR TRIP P RIH w/ BHA F/ 225' to 4300'. Observe 3 -5K drag going though bad spot in CSG @ 449'. 225.0 4,300.0 2/19/2025 23:30 2/20/2025 00:00 0.50 COMPZN, WELLPR SLPC P Cut and slip drilling line. 4,300.0 4,300.0 2/20/2025 00:00 2/20/2025 02:00 2.00 COMPZN, WELLPR SLPC P Cut and slip drilling line. 4,300.0 4,300.0 Rig: NABORS 7ES RIG RELEASE DATE 2/26/2025 Page 5/10 1D-133 Report Printed: 2/27/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/20/2025 02:00 2/20/2025 03:30 1.50 COMPZN, WELLPR CIRC P Run in and tag top of gravel pack liner @ 4548'. Set down 5K, P/U and establish parameters. Start pumps and circulate @ 294 GPM @ 1600 PSI work string 30', turn string 1/4 turn every reciprocation. PUWT: 95 K SOWT: 80 K ROTWT: 85 K Free torque 3 K @ 30 RPM. 4,300.0 4,548.0 2/20/2025 03:30 2/20/2025 04:30 1.00 COMPZN, WELLPR CIRC P Pump around High vis sweep @ 5 BBL/ min @ 800 PSI. 4,548.0 4,548.0 2/20/2025 04:30 2/20/2025 05:00 0.50 COMPZN, WELLPR OWFF P OWFF: Slight losses. 3.5 BBL/Hr. Blow down top drive. 4,548.0 4,548.0 2/20/2025 05:00 2/20/2025 06:30 1.50 COMPZN, WELLPR TRIP P POOH F/ 4548' to 225'. 4,548.0 225.0 2/20/2025 06:30 2/20/2025 07:00 0.50 COMPZN, WELLPR BHAH P LD RCJB and boot baskets. nothing recovered in either boot basket or RCJB. 225.0 0.0 2/20/2025 07:00 2/20/2025 07:30 0.50 COMPZN, WELLPR BHAH P MU 6.69" OD string mill BHA. 0.0 0.0 2/20/2025 07:30 2/20/2025 07:45 0.25 COMPZN, WELLPR TRIP P TIH to 443' drift through restriction with 15K down weight down. Con't T/449' 0.0 449.0 2/20/2025 07:45 2/20/2025 09:00 1.25 COMPZN, WELLPR SWDG P Drift through restriction 12 times 2-4K down. Turn string in small increments and continue to work through restrictions 4-5K down initially reducing to 2-3K after mutiple passes. 449.0 480.0 2/20/2025 09:00 2/20/2025 09:45 0.75 COMPZN, WELLPR TRIP P TOOH C/O Bull nose on bottom of string mill for 6.75" swedge TIH to 449' 480.0 449.0 2/20/2025 09:45 2/20/2025 10:00 0.25 COMPZN, WELLPR SWDG P Attempt to swedge through restriction at 449' set down 20K unable to pass restriction. Attempt 3 times no gains. 449.0 449.0 2/20/2025 10:00 2/20/2025 10:15 0.25 COMPZN, WELLPR TRIP P TOOH F/449' T/222' PUW=40K 449.0 222.0 2/20/2025 10:15 2/20/2025 11:15 1.00 COMPZN, WELLPR BHAH P LD collars, and remaining BHA. 222.0 0.0 2/20/2025 11:15 2/20/2025 11:45 0.50 COMPZN, WELLPR OWFF P OWFF calculated 5.6 BPH loss rate. 0.0 0.0 2/20/2025 11:45 2/20/2025 12:00 0.25 COMPZN, WELLPR BHAH P MU test packer 0.0 9.2 2/20/2025 12:00 2/20/2025 14:30 2.50 COMPZN, WELLPR TRIP P TIH F/9.21' T/4465' 9.2 4,465.0 2/20/2025 14:30 2/20/2025 14:45 0.25 COMPZN, WELLPR MPSP P Set AS-1Test packer at 4465' 4,465.0 4,465.0 2/20/2025 14:45 2/20/2025 17:30 2.75 COMPZN, WELLPR PRTS P Attempt to pressure test casing to 2200 PSI for 30 minutes. unable to get casing to test. Verified surface equipment was not leaking. casing pressure bleeding off surface equipment not leaking on chart. Released Test packer LD 5 stands of DP. Set test packer at 3996' COE. 4,465.0 3,996.0 2/20/2025 17:30 2/20/2025 18:00 0.50 COMPZN, WELLPR PRTS P Attempt to test CSG @ 3996' to 2200 PSI, observe pressure drop off consistently on 3 attempts. Find minor leak from stem of inner annulus valve. Release test packer, and allow to relax 15 min. OWFF: Losses 3.5 BBL/hr. 3,996.0 3,996.0 Rig: NABORS 7ES RIG RELEASE DATE 2/26/2025 Page 6/10 1D-133 Report Printed: 2/27/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/20/2025 18:00 2/20/2025 19:00 1.00 COMPZN, WELLPR TRIP P POOH L/D singles F/ 3996' to 3519'. PUWT: 75 K SOWT: 65 K 3,996.0 3,519.0 2/20/2025 19:00 2/20/2025 20:30 1.50 COMPZN, WELLPR PRTS P Set test packer per YJOS COE: 3510'. R/U and pressure test CSG F/ 3510 to surface to 2500 PSI. Attempt 3 times. Same trend. 3,519.0 3,510.0 2/20/2025 20:30 2/20/2025 22:00 1.50 COMPZN, WELLPR TRIP P POOH F/ 3510' to 2194' L/D Singles of drill pipe. 3,510.0 2,192.0 2/20/2025 22:00 2/20/2025 23:00 1.00 COMPZN, WELLPR PRTS P Set test packer @ 2184 COE. Flush lines, and R/U to test. Pressure up to 2500 PSI. Would not test. Attempt 4 times. Release test packer. 2,192.0 2,184.0 2/20/2025 23:00 2/21/2025 00:00 1.00 COMPZN, WELLPR TRIP P POOH F/ 2192' to 1500' racking back drill pipe. 2,184.0 1,500.0 2/21/2025 00:00 2/21/2025 01:30 1.50 COMPZN, WELLPR TRIP P POOH w/ Test packer F/ 1500' to surface. Observe 3-5K over pull coming through 449' with test packer. 1,500.0 0.0 2/21/2025 01:30 2/21/2025 02:00 0.50 COMPZN, WELLPR BHAH P Inspect test packer. Run back in the hole. 0.0 15.0 2/21/2025 02:00 2/21/2025 02:00 COMPZN, WELLPR TRIP P RIH to 420' (COE). 15.0 420.0 2/21/2025 02:00 2/21/2025 03:30 1.50 COMPZN, WELLPR MPSP P Set test packer per YJOS rep. Rig up, and fill lines. Close upper pipe rams, and test F/420' to surface to 2500 PSI for 15 min: . Release test packer. 420.0 420.0 2/21/2025 03:30 2/21/2025 04:45 1.25 COMPZN, WELLPR MPSP P RIH F/ 420' to 512', set test packer per YJOS rep. Pressure test F/ 510' to surface to 2500 PSI for 15 minutes, good test. 420.0 510.0 2/21/2025 04:45 2/21/2025 06:00 1.25 COMPZN, WELLPR TRIP P TIH to 2220' 510.0 2,200.0 2/21/2025 06:00 2/21/2025 11:45 5.75 COMPZN, WELLPR MPSP P Set test packer attempt to test casing to 2500 PSI unable to achieve passing test. Move test packer to 2123' Attempted to test casing to 2500 PSI. Unable to achieve passing test. Move test packer to 2030' Attempted to test casing to 2500 PSI. Unable to achieve passing test. Move test packer to 2003' Attempted to test casing to 2500 PSI. Unable to achieve passing test. Move test packer to 1085' Pressure tested casing to 2500 PSI. Lost 100 PSI, pressure stabilized at 2400 PSI Move test packer to 1556' Pressure tested casing to 2500 PSI for 15 minutes. Moved test packer to 1842' Attempted pressure test to 2500 PSI. Unable to achieve passing test. 2,200.0 1,842.0 2/21/2025 11:45 2/21/2025 12:45 1.00 COMPZN, WELLPR TRIP P TOOH F/1842 T/surface LD test packer. 1,842.0 0.0 2/21/2025 12:45 2/21/2025 13:15 0.50 COMPZN, WELLPR CLEN P Clear rig floor from fishing and swedging operations. 0.0 0.0 2/21/2025 13:15 2/21/2025 13:45 0.50 COMPZN, WELLPR OWFF P OWFF for 30 minutes. monitor losses. 0.0 0.0 2/21/2025 13:45 2/21/2025 14:00 0.25 COMPZN, WELLPR BHAH P MU RBP and running tool. 0.0 17.0 Rig: NABORS 7ES RIG RELEASE DATE 2/26/2025 Page 7/10 1D-133 Report Printed: 2/27/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/21/2025 14:00 2/21/2025 15:30 1.50 COMPZN, WELLPR TRIP P TIH F/16.98' T/2300 17.0 2,100.0 2/21/2025 15:30 2/21/2025 19:30 4.00 COMPZN, WELLPR PULD P RIH F/2100' T/4500' Hang up @ 2678'. Able to pull free and continue in the hole. 2,100.0 4,500.0 2/21/2025 19:30 2/21/2025 21:00 1.50 COMPZN, WELLPR MPSP P Attempt to set RVP @ 4500', unable to set RBP. Wash down to TOL @ 3 BBL/ min @ 330 PSI and Tag @ 4551' to verify plug was not lost when encountering tight spot. No indications plug had been dropped. PUWT: 90 K SOWT: 80 K 4,500.0 4,500.0 2/21/2025 21:00 2/21/2025 22:00 1.00 COMPZN, WELLPR CIRC P CBU @ 4 BBL/ MIN working pipe 40' to attempt to clean setting area for RBP. 4,500.0 4,500.0 2/21/2025 22:00 2/21/2025 23:00 1.00 COMPZN, WELLPR MPSP P Attempt to set RBP. Would not set. 4,500.0 4,500.0 2/21/2025 23:00 2/21/2025 23:15 0.25 COMPZN, WELLPR OWFF P OWFF: Slight losses. 4,500.0 4,500.0 2/21/2025 23:15 2/22/2025 00:00 0.75 COMPZN, WELLPR TRIP P POOH F/ 4500' to 3800' 4,500.0 3,800.0 2/22/2025 00:00 2/22/2025 02:00 2.00 COMPZN, WELLPR TRIP P Cont. to POOH F/ 3800' to surface. 3,800.0 0.0 2/22/2025 02:00 2/22/2025 02:30 0.50 COMPZN, WELLPR BHAH P No RBP on bottom of running tool. Break down running tool, and inspect for signs of damage. No obvious signs of damage on the running tool. M/U. 0.0 10.0 2/22/2025 02:30 2/22/2025 04:30 2.00 COMPZN, WELLPR TRIP P RIH w/ RBP retrieval tool F/ surface to 4543' Engage RBP 10.0 4,543.0 2/22/2025 04:30 2/22/2025 05:15 0.75 COMPZN, WELLPR CIRC P Circulate 4BPM 3800 PSI 4,543.0 4,543.0 2/22/2025 05:15 2/22/2025 05:30 0.25 COMPZN, WELLPR MPSP P Set RBP at 4521' top of plug. 4525' COE 4,543.0 4,521.0 2/22/2025 05:30 2/22/2025 07:00 1.50 COMPZN, WELLPR TRIP P TOOH W/ setting tool F/4521' PUW=90K SOW=75K T/10' 4,521.0 10.0 2/22/2025 07:00 2/22/2025 07:30 0.50 COMPZN, WELLPR BHAH P LD RBP setting tool MU Test packer 10.0 11.0 2/22/2025 07:30 2/22/2025 10:00 2.50 COMPZN, WELLPR TRIP P TIH F/16' T/4490' PUW=90K SOW=75K 11.0 4,490.0 2/22/2025 10:00 2/22/2025 10:30 0.50 COMPZN, WELLPR MPSP P Set Test packer at 4490' 4,490.0 4,490.0 2/22/2025 10:30 2/22/2025 11:15 0.75 COMPZN, WELLPR PRTS P Test RBP Attempt to test RBP to 2500 PSI for 30 minutes. Unable top attain passing test. Difficulties releasing test packer pulled 50K over to release Moved up 30' reset test packer at 4460' Attempt to test RBP to 2500 PSI for 30 minutes. Unable top attain passing test. 4,490.0 4,460.0 2/22/2025 11:15 2/22/2025 11:45 0.50 COMPZN, WELLPR MPSP P Release Test packer. PUW=90K 4,460.0 4,460.0 2/22/2025 11:45 2/22/2025 15:00 3.25 COMPZN, WELLPR TRIP P TOOH F/4460 T/16' 4,460.0 16.0 2/22/2025 15:00 2/22/2025 15:30 0.50 COMPZN, WELLPR BHAH P LD Test packer 1 MU test packer #2 16.0 14.6 2/22/2025 15:30 2/22/2025 19:30 4.00 COMPZN, WELLPR TRIP P TIH F/14.62' T/4490' PUW=90K 14.6 4,490.0 Rig: NABORS 7ES RIG RELEASE DATE 2/26/2025 Page 8/10 1D-133 Report Printed: 2/27/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/22/2025 19:30 2/22/2025 21:30 2.00 COMPZN, WELLPR PRTS P Close pipe rams and test against RBP set @ 4521'. Stage up in 500 PSI incraments to 2000 PSI, holding for 5 min each. All pressures held. Bleed off pressure, and kelly down top drive, and blow down kelly hose.. R/U test equipment, and test CSG to 2500 PSI for 30 min. 4,490.0 4,490.0 2/22/2025 21:30 2/22/2025 22:00 0.50 COMPZN, WELLPR OTHR P Blow down lines and rig down test equipment. Contact town for plan forward. 4,490.0 4,490.0 2/22/2025 22:00 2/23/2025 00:00 2.00 COMPZN, WELLPR TRIP P POOH w/ Test packer F/ 4490' to 3310' 4,490.0 3,310.0 2/23/2025 00:00 2/23/2025 01:00 1.00 COMPZN, WELLPR TRIP P POOH F/ 3310' to 2180'. 3,310.0 2,180.0 2/23/2025 01:00 2/23/2025 01:30 0.50 COMPZN, WELLPR CIRC P CBU @ 100 GPM @ 100 PSI. Work pipe 30'. 2,180.0 2,180.0 2/23/2025 01:30 2/23/2025 03:30 2.00 COMPZN, WELLPR PRTS P Blow down top drive, L/D 1 joint of drill pipe P/U Space out pups, P/U joint of drill pipe, and Set test packer @ 2171' (C.O.E.)R/U test equipment and test CSG F/ 2171' to surface. Observed flow up drill pipe. 2,180.0 2,171.0 2/23/2025 03:30 2/23/2025 04:00 0.50 COMPZN, WELLPR MPSP P Rig down test equipment, and release test packer. 2,171.0 2,171.0 2/23/2025 04:00 2/23/2025 05:30 1.50 COMPZN, WELLPR TRIP P POOH F/ 2171' to surface. L/D test packer. 2,171.0 16.0 2/23/2025 05:30 2/23/2025 06:00 0.50 COMPZN, WELLPR BHAH P LD test packer and MU retrieval head. 16.0 10.0 2/23/2025 06:00 2/23/2025 08:30 2.50 COMPZN, WELLPR TRIP P TIH F/10' T/4521' 10.0 4,521.0 2/23/2025 08:30 2/23/2025 09:00 0.50 COMPZN, WELLPR MPSP P Release test packer allow element to relax monitor well. 4,521.0 4,521.0 2/23/2025 09:00 2/23/2025 09:15 0.25 COMPZN, WELLPR OWFF P OWFF for 15 minutes. Well started U- Tube 4,521.0 4,481.0 2/23/2025 09:15 2/23/2025 10:30 1.25 COMPZN, WELLPR CIRC P Circulate BUS 2 BPM 130 PSI. Monitor losses while circulating. 4,481.0 4,481.0 2/23/2025 10:30 2/23/2025 11:00 0.50 COMPZN, WELLPR OWFF P OWFF 30 minutes establish 7BPH loss rate. Blow down surface lines after circulating. 4,481.0 4,481.0 2/23/2025 11:00 2/23/2025 12:00 1.00 COMPZN, WELLPR TRIP P TOOH with RBP F/4481' T/2200' 4,481.0 2,200.0 2/23/2025 12:00 2/23/2025 13:00 1.00 COMPZN, WELLPR MPSP P Set RBP at 2200' RU and test casing to 2500 PSI for 15 minutes good test. Blow down surface lines. 2,200.0 2,200.0 2/23/2025 13:00 2/23/2025 14:00 1.00 COMPZN, WELLPR TRIP P TOOH F/2200' T/22' 2,200.0 22.0 2/23/2025 14:00 2/23/2025 14:30 0.50 COMPZN, WELLPR BHAH P LD RBP and running tool. 22.0 0.0 2/23/2025 14:30 2/23/2025 22:00 7.50 COMPZN, WELLPR ELOG P RU and spot in E-Line unit. Perform continuity checks W/Gyro. RIH W/Gyro to 4400' POOH. 0.0 0.0 2/23/2025 22:00 2/23/2025 22:30 0.50 COMPZN, WELLPR ELNE P L/D scientific gyro. R/U Reed Caliper tool. 0.0 0.0 2/23/2025 22:30 2/24/2025 00:00 1.50 COMPZN, WELLPR ELOG P RIH to 4551' w/ Caliper logging tools. POOH logging from bottom to 3375'. 0.0 0.0 2/24/2025 00:00 2/24/2025 01:00 1.00 COMPZN, WELLPR ELOG P POOH w/ Reed caliper on E-line. F/ 3375' to surface. 0.0 0.0 2/24/2025 01:00 2/24/2025 02:00 1.00 COMPZN, WELLPR ELOG P AK E-line, and R/D tools. R/D AK E-line equipment on the rig floor. 0.0 0.0 2/24/2025 02:00 2/24/2025 03:30 1.50 COMPZN, WELLPR TRIP P M/U Mule shoe on drill pipe, RIH w/ Drill pipe from the derrick. 0.0 4,500.0 Rig: NABORS 7ES RIG RELEASE DATE 2/26/2025 Page 9/10 1D-133 Report Printed: 2/27/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/24/2025 03:30 2/24/2025 07:30 4.00 COMPZN, WELLPR PULD P POOH L/D Drill pipe. 4,500.0 0.0 2/24/2025 07:30 2/24/2025 09:00 1.50 COMPZN, WELLPR OTHR P Pull wear bushing, rig up to run completion on the rig floor. 0.0 0.0 2/24/2025 09:00 2/24/2025 09:30 0.50 COMPZN, RPCOMP SFTY P Prejob safety meeting with Summit Nabors Halliburton and CPAI. Discussed hazards and mitigations. Emphasized SWA for all parties. Red zones pinch points and roles and resposibilities for each team member. 0.0 0.0 2/24/2025 09:30 2/24/2025 13:00 3.50 COMPZN, RPCOMP PUTB P Verify completion tally and running order in pipe shed. Start PU ESP componenets fill motor housing. stack up ESP to recieving base. 0.0 60.0 2/24/2025 13:00 2/24/2025 14:15 1.25 COMPZN, RPCOMP PUTB P MU dicharge gauge to tec wire. 60.0 132.0 2/24/2025 14:15 2/24/2025 18:30 4.25 COMPZN, RPCOMP PUTB P MU MLE to motor splice cable to ESP spool 132.0 132.0 2/24/2025 18:30 2/24/2025 20:00 1.50 COMPZN, RPCOMP PUTB P Cont. to RIH to Gauge mandrel. HAL install gauge and M/U Tech wire. 132.0 183.0 2/24/2025 20:00 2/25/2025 00:00 4.00 COMPZN, RPCOMP PUTB P Cont. To RIH w/ Completion 183.0 800.0 2/25/2025 00:00 2/25/2025 03:30 3.50 COMPZN, RPCOMP PUTB P Cont. RIH w/ ESP completion F/ 800' to 2000'. Check ESP cable and HAL Tec wire every 1000'. 800.0 2,276.0 2/25/2025 03:30 2/25/2025 11:30 8.00 COMPZN, RPCOMP PUTB P P/U Packer and inspect. Cut and feed through ESP cable, and Tec wire. Make splice. Test continuity. 2,276.0 2,276.0 2/25/2025 11:30 2/25/2025 19:30 8.00 COMPZN, RPCOMP PUTB P RIH W/Completion F/2276' T/2714' packer at restriction. worked through restrictions from 463'-468' set down 12K worked past and continued in hole to 2776'. Good continuity check. Continue RIH with completion *** Note: 159 clamps w/315 pins 2,276.0 4,395.4 2/25/2025 19:30 2/25/2025 22:00 2.50 COMPZN, RPCOMP PUTB P Terminate ESP and gauge control line through hanger. Trouble with epoxy and gun, call for replacement. Deadhorse. 4,395.4 4,395.4 2/25/2025 22:00 2/25/2025 23:30 1.50 COMPZN, RPCOMP PUTB P RD Summit and Haliburton equipment to ground 4,395.4 4,395.4 2/25/2025 23:30 2/26/2025 00:00 0.50 COMPZN, RPCOMP PUTB P Continue to terminate ESP Cable 4,395.4 4,395.4 2/26/2025 00:00 2/26/2025 00:30 0.50 COMPZN, RPCOMP PUTB P Continue to terminate ESP cable & feed through hanger install cap. Test ESP cable (good test) 4,395.4 4,395.4 2/26/2025 00:30 2/26/2025 01:00 0.50 COMPZN, RPCOMP PUTB P RD equipment Land hanger 4,395.4 4,430.4 2/26/2025 01:00 2/26/2025 01:30 0.50 COMPZN, RPCOMP PUTB P RILDS and torque Test hanger pack offs to 5,000 psi 15 mins (good test) 4,430.4 4,430.4 2/26/2025 01:30 2/26/2025 02:00 0.50 COMPZN, RPCOMP PUTB P Back out Landing Joint, pull Isolation Sleeve, MU landing joint 4,430.4 4,430.4 2/26/2025 02:00 2/26/2025 02:45 0.75 COMPZN, RPCOMP CIRC P RU surface lines Circluate 146 bbls w/8.0 bbl chased 3.0 bpm @ 270 psi 4,430.4 4,430.4 2/26/2025 02:45 2/26/2025 03:45 1.00 COMPZN, RPCOMP OWFF P Observe well for flow 4,430.4 4,430.4 Rig: NABORS 7ES RIG RELEASE DATE 2/26/2025 Page 10/10 1D-133 Report Printed: 2/27/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/26/2025 03:45 2/26/2025 05:45 2.00 COMPZN, RPCOMP PRTS P Drop ball and rod allow to fall 10 min's Open up IA to sensator monitoring pressure Bring pump online 8 stks away 3,100 psi, block tubing in at RF, chart on IA reading 0 pressure Hesitate 30 min's to allow packer to set. Bleed pressure to 1050 psi on tubing, Line up down the IA bring pressure up to 2,500 psi/30mins Shear SOV *** Note: Tri Point Feed Through packer - COE @ 2,155.93' 4,430.4 4,430.4 2/26/2025 05:45 2/26/2025 06:15 0.50 COMPZN, RPCOMP MPSP P Set BPV Pressure test BPV through casing to 1000 PSI for 10 minutes. 4,430.4 0.0 2/26/2025 06:15 2/26/2025 08:00 1.75 COMPZN, RPCOMP RURD P Remove tec wire spooler unit from floor, RD ESP sheaves, and tubing tongs. clear floor 0.0 0.0 2/26/2025 08:00 2/26/2025 10:30 2.50 COMPZN, RPCOMP NUND P Change upper rams to 2-7/8" x 5" inserts. ND BOP's N/D DSA. prep wellhead for adapter and tree. 0.0 0.0 2/26/2025 10:30 2/26/2025 14:00 3.50 COMPZN, RPCOMP NUND P NU adapter and tree. Test adapter to 5000 PSI for 10 minutes. test tree to 5000 PSI. 0.0 0.0 2/26/2025 14:00 2/26/2025 15:00 1.00 COMPZN, RPCOMP MPSP P Pull BPV and test dart. 0.0 0.0 2/26/2025 15:00 2/26/2025 16:00 1.00 COMPZN, RPCOMP FRZP P Freeze protect well with 85 BBL's Diesel down 7-5/8" casing taking returns up TBG to kill tank. Shut in LRS suck back line. U-Tube well for 1 hour. 0.0 0.0 2/26/2025 16:00 2/26/2025 16:30 0.50 COMPZN, RPCOMP RURD P RD rig floor RU bridal lines to derrick. Trucks on location at 4:00 PM Spot trucks at pits shop and camp. Note: Rig Released 1630 2/26/25 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 2/26/2025 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:5,122.0 1D-133 1/2/1998 triplwj Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set DV 1D-133 12/26/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By Note: Motor spline broke off & was stuck in the pump.8/29/2023 fergusp Rev Reason: Pull slip stop pack off & ESP. Note: spline was broke off in pump. 8/29/2023 fergusp NOTE: WORKOVER 7/1/2008 osborl Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 41.0 121.0 121.062.58 H-40 SURFACE 7 5/8 6.87 40.7 5,249.3 4,224.8 29.70 L-80 ABM-BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth… 4,430.4 String Max No… 3 1/2 Set Depth… 3,459.7 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.836.80.00 Hanger 11.000 Vault tubing hanger Vault 2.900 1,973.6 1,833.6 44.21 Mandrel – GAS LIFT 5.425GLM 3.5"x 1" KBMG SOV 2000 PSI shear. SN: 25166-06 SLB KBMG 2.920 2,154.21,961.0 49.19 Packer 6.690 3.5"x 7 5/8" D&L Feed through packer. Pinned to shear at 40K. D&LDL ESP FEEDTH ROUGH 2.992 2,237.6 2,013.9 52.07 2.81" X Nipple 4.501 2.813" X-nipple HES X 2.813 2,416.32,116.6 57.81 Mandrel – GAS LIFT 5.425 GLM 3.5"x 1" KBMG SOV. 2400 PSI shear SN: 25166-09 SLB KBMG2.920 4,191.6 3,244.2 28.41 Sleeve - Sliding 5.800 Nexa sliding sleeve. SLB NEXA 2.808 4,246.7 3,293.026.70Sensor - Discharge Gauge 4.846Gauge mandrel 2.981 4,297.6 3,338.8 25.43 Pump - Discharge head 5.500 Discharge adapter SUMMIT 2.970 4,371.5 3,405.9 24.39 Recieving Base 3.500 Receiving base SUMMIT 2.978 4,376.0 3,410.0 24.36 Seal Assembly 5.130 Tandem seal section SUMMIT 3.500 4,393.9 3,426.3 24.25 Motor - Adapter 4.500 Motor adapter SUMMIT 4,394.3 3,426.7 24.24 Motor 4.540 ESP motor SUMMIT 4,425.6 3,455.3 23.98 Sensor - Suction Gauge 4.560 Sensor adapter SUMMIT 4,425.9 3,455.5 23.97 Sensor - Suction Gauge 4.560 Intake sensor SUMMIT 4,427.9 3,457.4 23.92 Centralizer 5.380 Motor centralizer SUMMIT Top (ftKB) 4,564.9 Set Depth… 4,960.2 String Max No… 5.1 Set Depth… 3,953.4 Tubing Description Tubing – Production Wt (lb/ft)Grade Top Connection ID (in) 4.00 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,564.93,584.021.32 PACKER 6.680 SC-1 GRAVEL PACK PACKER Baker 4.000 4,568.7 3,587.5 21.29 MILLOUT 5.540 MILLOUT EXTENSION Baker 4.990 4,574.7 3,593.2 21.24 SBR 6.080 SEAL BORE RECEPTACLE Baker 3.250 4,579.9 3,598.0 21.20 SLEEVE 6.050 GRAVEL PACK SLIDING SLEEVE Baker 3.480 4,581.6 3,599.6 21.19 SEAL BORE 5.010 SEAL BORE Baker 3.250 4,623.5 3,638.7 20.95 SCREEN 5.100 BAKERWELD GRAVEL PACK SCREEN 4.000 4,668.7 3,680.9 20.92 SBR 5.020 SEAL BORE RECEPTACLE Baker 3.250 4,670.93,683.020.91 PACKER 6.490 SC-1L ISOLATION PACKER Baker 3.875 4,674.3 3,686.1 20.91 SBR 6.080 SEAL BORE RECEPTACLE Baker 3.250 4,679.4 3,690.920.91 SLEEVE 6.050GRAVEL PACK SLIDING SLEEVE Baker 3.480 4,681.1 3,692.5 20.91 SEAL BORE 5.010 SEAL BORE Baker 3.250 4,692.9 3,703.5 20.90 SCREEN 5.100 BAKERWELD GRAVEL PACK SCREEN 4.000 4,738.1 3,745.8 20.86 SBR 5.020 SEAL BORE RECEPTACLE Baker 3.250 4,740.3 3,747.8 20.86 PACKER 6.490 SC-1L ISOLATION PACKER Baker 3.875 4,743.6 3,750.9 20.86 SBR 6.080 SEAL BORE RECEPTACLE Baker 3.250 4,748.8 3,755.8 20.85 SLEEVE 6.050 GRAVEL PACK SLIDING SLEEVE Baker 3.480 4,750.5 3,757.4 20.85 SEAL BORE 5.010 SEAL BORE Baker 3.250 4,782.6 3,787.4 20.83 SCREEN 5.100 BAKERWELD GRAVEL PACK SCREEN 4.000 4,842.8 3,843.6 20.75 SBR 6.080 SEAL BORE RECEPTACLE Baker 3.250 4,845.0 3,845.7 20.74 PACKER 6.490 SC-1L ISOLATION PACKER Baker 3.875 4,848.3 3,848.8 20.74 SBR 6.080 SEAL BORE RECEPTACLE Baker 3.250 1D-133, 2/27/2025 10:37:20 AM Vertical schematic (actual) SURFACE; 40.7-5,249.3 PACKER; 4,928.0 SCREEN; 4,866.8 IPERF; 4,866.0-4,922.0 PACKER; 4,845.0 SCREEN; 4,782.6 IPERF; 4,786.0-4,828.0 PACKER; 4,740.3 SCREEN; 4,692.9 IPERF; 4,696.0-4,732.0 PACKER; 4,670.9 SCREEN; 4,623.5 IPERF; 4,628.0-4,664.0 PACKER; 4,564.9 Sensor - Suction Gauge; 4,425.9 Seal Assembly; 4,376.0 Sensor - Discharge Gauge; 4,246.7 Sleeve - Sliding; 4,191.6 Mandrel – GAS LIFT; 2,416.3 2.81" X Nipple; 2,237.6 TUBING PLUG; 2,237.0 BALL & ROD; 2,229.0 Packer; 2,154.2 Mandrel – GAS LIFT; 1,973.6 CONDUCTOR; 41.0-121.0 Hanger; 36.8 Casing 1; 0.0 KUP PROD KB-Grd (ft) 42.97 RR Date 11/22/199 7 Other Elev… 1D-133 ... TD Act Btm (ftKB) 5,265.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292282700 Wellbore Status PROD Max Angle & MD Incl (°) 59.00 MD (ftKB) 2,811.45 WELLNAME WELLBORE Annotation Last WO: End Date 5/22/2012 H2S (ppm) 0 Date 12/29/2016 Comment SSSV: NONE Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,853.5 3,853.6 20.73 SLEEVE 6.060 GRAVEL PACK SLIDING SLEEVE Baker 3.480 4,855.2 3,855.2 20.73 SEAL BORE 5.010 SEAL BORE Baker 3.250 4,866.8 3,866.1 20.71 SCREEN 5.100 BAKERWELD GRAVEL PACK SCREEN 4.000 4,926.9 3,922.3 20.62 SEAL ASSY 5.010 S-22 ANCHOR LATCH SEAL ASSEMBLY Baker 3.821 4,928.0 3,923.3 20.62 PACKER 6.490 FB-1 RETAINER PRODUCTION PACKER Baker4.000 4,930.4 3,925.6 20.61 NIPPLE 5.020 CASING NIPPLE 4.410 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,229.0 2,008.6 51.77 BALL & ROD 2/26/2025 0.000 2,237.0 2,013.5 52.05 TUBING PLUG 2/26/20250.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 1,973.6 1,833.6 44.21 1 SOVBEK 1 2/24/2025JMI 2000 PSI IA to tbg 2,416.3 2,116.6 57.81 2 ESP SOV BEK 1 2/24/2025JMI 2400 TUBING to IA Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 4,628.0 4,664.0 3,642.9 3,676.5 WS D, 1D-133 1/2/1998 12.0 IPERF RDX Charge; SOS 4 1/2" Ultrapak 4,696.0 4,732.0 3,706.4 3,740.1 WS B, 1D-133 1/2/1998 12.0 IPERF RDX Charge; SOS 4 1/2" Ultrapak 4,786.0 4,828.0 3,790.5 3,829.8 WS A4,WS A3, 1D-133 1/2/1998 12.0 IPERF RDX Charge; SOS 4 1/2" Ultrapak 4,866.0 4,922.0 3,865.3 3,917.7 WS A2, 1D-133 1/2/1998 12.0 IPERF RDX Charge; SOS 4 1/2" Ultrapak 1D-133, 2/27/2025 10:37:23 AM Vertical schematic (actual) SURFACE; 40.7-5,249.3 PACKER; 4,928.0 SCREEN; 4,866.8 IPERF; 4,866.0-4,922.0 PACKER; 4,845.0 SCREEN; 4,782.6 IPERF; 4,786.0-4,828.0 PACKER; 4,740.3 SCREEN; 4,692.9 IPERF; 4,696.0-4,732.0 PACKER; 4,670.9 SCREEN; 4,623.5 IPERF; 4,628.0-4,664.0 PACKER; 4,564.9 Sensor - Suction Gauge; 4,425.9 Seal Assembly; 4,376.0 Sensor - Discharge Gauge; 4,246.7 Sleeve - Sliding; 4,191.6 Mandrel – GAS LIFT; 2,416.3 2.81" X Nipple; 2,237.6 TUBING PLUG; 2,237.0 BALL & ROD; 2,229.0 Packer; 2,154.2 Mandrel – GAS LIFT; 1,973.6 CONDUCTOR; 41.0-121.0 Hanger; 36.8 Casing 1; 0.0 KUP PROD 1D-133 ... WELLNAME WELLBORE C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-02-23_23065_KRU_1D-133_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23065 KRU 1D-133 50-029-22827-00 Caliper Survey w/ Log Data 23-Feb-25 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 ______________________________ _____________________________________ 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 197-206 T40157 2/28/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.28 08:26:54 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV U WSAK 1D-133 JBR 03/26/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 3-1/2" joint. Test Results TEST DATA Rig Rep:Morales/LanghamOperator:ConocoPhillips Alaska, Inc.Operator Rep:Phillips/Burson Rig Owner/Rig No.:Nabors 7ES PTD#:1972060 DATE:2/16/2025 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopSAM250217183747 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6 MASP: 1411 Sundry No: 324-712 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 3-1/2"x5-1/2"P #2 Rams 1 Blinds P #3 Rams 1 2-7/8"x5"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"P HCR Valves 2 3-1/8"P Kill Line Valves 2 3-1/8"&2"P Check Valve 0 NA BOP Misc 2 2-1/16"P System Pressure P3000 Pressure After Closure P1600 200 PSI Attained P15 Full Pressure Attained P117 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P5@2075 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P22 #1 Rams P6 #2 Rams P6 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9 9999 9 1 Gluyas, Gavin R (OGC) From:Lau, Jack J (OGC) Sent:Monday, December 30, 2024 3:27 PM To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL]KRU 1D-133 (197-206) From: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Sent: Monday, December 30, 2024 2:57 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL]KRU 1D-133 (197-206) Jack,  The gauge is still on line and we plan to get a reading closer to RWO. But current plan is: 5/3/2024 (Gauge reading) 1767 psi @ 3558' TVD = 9.6ppg EMW, 9.8ppg KWF 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. 2  Let me know if there are any questions or concerns, thank you and happy new year. Elliott Tuttle 3 C: 907.252.3347 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, December 30, 2024 9:56 AM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Subject: [EXTERNAL]KRU 1D-133 (197-206) CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Good Morning Elliott – I am reviewing your sundry application for KRU 1D-133.  What is the planned KWF and density?  Please send a cement summary for the 7-5/8” Thanks! Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 OƯice (907) 227-2760 Cell 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: West Sak Oil Pool West Sak Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 5265'1411'None Casing Collapse Conductor Surface Gravel Packed Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-263-4742 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Elliott Tuttle elliott.tuttle@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Tubing Grade:Tubing MD (ft): 2190'MD/1984'TVD 4565'MD/3584'TVD 4671'MD/3683'TVD 4740'MD/3748'TVD 4845'MD/3846'TVD 4928'MD/3923'TVD Other: ESP Repair Kuparuk River Field Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size AOGCC USE ONLY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650 197-206 P.O. Box 100360, Anchorage, AK 99510 50-029-22827-00-00 ConocoPhillips Alaska, Inc Will perfs require a spacing exception due to property boundaries? 4540' MD 121' TVD 16' 4-1/2" 80' Proposed Pools: Burst Current Pools: MPSP (psi):Plugs (MD): 3953' 121' 4960' 1/15/2025 3-1/2" Viking ESP Feed Thru Baker SC-1 Gravel Pack Baker SC-1L Isolation Baker SC-1L Isolation Baker SC-1L Isolation Baker FB-1 SSSV: None Perforation Depth MD (ft):Perforation Depth TVD (ft): KRU 1D-133 4628-4664' 4696-4732' 4786-4828' 4866-4922' 3643-3677' 3706-3740' 3791-3830' 3865-3918' 395' 5208'7-5/8"5249'4225' 4239'5122'4105'None m n P s 1 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov X 'HF 324-712 By Grace Christianson at 10:27 am, Dec 19, 2024 AOGCC witnessed BOP and Annular Test to 2500 psi. A.Dewhurst 23DEC24 X 10-404 DSR-12/20/24JJL 12/30/24 MEUIRUMOF Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.12.31 10:15:07 -09'00'12/31/24 RBDMS JSB 010225 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 18, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Elliott Tuttle Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 1D-133 (PTD# 197-206). Well 1D-133 is currently shut-in. The well uses a thru-tubing conveyed (TTC) electric submersible progressing cavity pump (ESPCP) for artificial lift. This well has received four RWO's for various reasons, but mostly due to broken motor shafts. The current completion is two years old and a broken motor output shaft was found on the bottom of the retreivable pump the first time the pump was changed out in 2023. We are requesting a RWO to replace the ESP completion, where we will run a gyro that will give us one foot data to determine the best place to space out the pump assembly in the well. The RWO scope is like-kind replacement of the TTC-ESPCP completion which includes a feed- through packer to provide a barrier to formation as this is a single casing well. If you have any questions or require any further information, please contact me at 907-252-3347 The TTC-ESPCP completion will be pulled and recompleted in like-kind fashion although the production packer will be set deeper so that gas lift is a viable alternative form of artificial lift. 1D-133 RWO Procedure West Sak Producer PTD #197-206 Page 1 of 2 Completed Pre-Rig Work 1. T-PPPOT (Passed) and T-POT tests (passed). Function LD’s – 12/9/24 2. MIT-IA to 2500psi, (passed) – 12/11/24 Remaining Pre-Rig Work 3. Pull GLV from Station #1, GLM @ 2006.7’ RKB and install large port OV. 4. Pull OV from station #2 @ 2295.6’ RKB, let packer gas migrate to surface, 24hrs. 5. Bleed gas, install DV in station #2, pull SOV @ 4367’ RKB, pull catcher 6. Prepare for rig arrival 48-72 hrs before rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 1D-133. (No BPV set for MIRU due to internal risk assessment for Nabors 7ES.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF down IA as needed through OV followed by bullhead kill. 3. Set HP BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing, Packers, and TTC-ESPCP Completion 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing and release pull-to-release packer. Close BOPE and circulate out remaining packer gas. 6. Retrieve completion down through TTC-ESPCP at ~4539’ RKB. Perform Cleanout and Test Packer run 7. MU Cleanout BHA and TIH down to top of gravel pack liner. Rotate and reciprocate scraper at 4319’ RKB or new packer set depth. 8. MU Test Packer BHA, TIH to 4319’ RKB test backside or packer to surface and confirm casing down past new packer set depth. RU E-Line, Run Gyro 9. RU Eline and deploy Gyro over a dead well, follow hole fill schedule established a. Determine optimum pump location using 1’ data provided Install new TTC-ESPCP 3-½” Completion with Feed-through Packer 10. MU 3 ½” completion with TTC-ESPCP, mandrels, packer, and nipples. RIH to depth. 11. Once on depth, space out, land tubing, terminate ESP cable, RILDS. Test void to 5000psi for 5 minutes. 12. Circ in CI down IA to below TTC-ESPCP Assy. 13. Drop ball and Rod, pressure up and set Packer. 14. Pressure test tubing to 1500 psi, 5 minutes bleed to 1000psi. 15. Pressure test inner annulus to 2500 psi for 30 minutes and chart. 16. Dump tubing pressure and shear SOV. ND BOP, NU Tree 17. Install BPV. PT BPV. 18. ND BOPE. NU tree. Test tree. 1D-133 RWO Procedure West Sak Producer PTD #197-206 Page 2 of 2 19. Pull BPV, freeze protect well. 20. RDMO. Post-Rig Work 21. Pull Ball/Rod and any plugs or RHC plugs as needed to set pump. 22. Set Catcher above pump intake. Pull SOV, install DV. Install SOV (T-> IA) in station below packer. 23. Set pump. 24. Turn over to operations. General Well info: Wellhead type/pressure rating: Vetco Gray Horizontal, 5M psi top flange Production Engineer: Natalie Dye Berryman Reservoir Development Engineer: Carolyn Kirchner Estimated Start Date: 1/15/25 Workover Engineer: Elliott Tuttle (907-252-3347, elliott.tuttle@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion with feed through packer and TTC-ESPCP. Replace in-kind with deeper packer set depth. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-IA to 2500psi Passed, 12/11/24 MIT-OA N/A IC POT &PPPOT PASSED – N/A TBG POT &PPPOT PASSED – 12/9/24 MPSP: 1411 psi using 0.1 psi/ft gradient Static BHP: Gauge Reading, 1767psi @ 3558’ RKB (5/3/24) 1D-133 Current Schematic Description Depth MD Depth TVD OD ID Weight Length Grade Top Conn Run Date Conductor 121 121 16 15.062 62.58 H-40 11/19/1997 Surface 5249.3 4224.8 7 5/8 6.875 29.7 L-80 ABM-BTC 11/20/1997 Tubing – Production 4540 3560 3 1/2 2.992 9.3 L-80 EUE 5/16/2022 Gravel Packed Liner 4960 3953 4 1/2 N/A 13.5 L-80 SL-HT 12/31/1997 ESP COMPLETION - 2022 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 2.813" X Nipple @ 507.5' RKB 3-1/2" x 1" Camco KBMG gas lift mandrel @ 2006.7' RKB 4.5" x 7 5/8" Viking Feed Through ESP Packer @ 2189.6' RKB (4 1/2" Vam Top Conn) 2.812" X landing nipple at 2242.8' RKB (2.813" min ID) 3-1/2" x 1" Camco KBMG gas lift mandrels @ 2295.6' RKB 4367' RKB TTC-ESPCP Assembly - Discharge Adapter/ Gauge Unit @ 4421.4' RKB - TTC Perforated Intake @ 4505.4' RKB - Tandem Seal Section @ 4509.9' RKB - Gear Reduction Unit @ 4527.8' RKB - ESP Motor @ 4530.4' RKB - Pressure Sensor @ 4536.7' RKB End of Assembly @ 4540' RKB Gravel Pack Liner 5 1/2" x 7 5/8" Baker SC-1 Packer @ 4565' RKB Upper Millout Extension @ 4569' RKB 2 Joints of 4 1/2" Bakerweld Gravel Pack Screen @ 4623.5' RKB 76B2-38 Model SC-1L Packer @ 4670.9' RKB 2 Joints of 4 1/2" Bakerweld Gravel Pack Screen @ 4692.9' RKB 76B2-38 Model SC-1L Packer @ 4740.3' RKB 2 Joints of 4 1/2" Bakerweld Gravel Pack Screen @ 4782.6' RKB 76B2-38 Model SC-1L Packer @ 4845' RKB 2 Joints of 4 1/2" Bakerweld Gravel Pack Screen @ 4866.8' RKB 91-40 Baker Model FB-1 REtainer Production Packer @ 4928' RKB End of Gravel Pack Liner @ 4960.16' RKB Production Casing Conductor Gravel Pack Liner #4 Flat ESP Cable 1D-133 Proposed RWO Completion Description Depth MD Depth TVD OD ID Weight Length Grade Top Conn Run Date Conductor 121 121 16 15.062 62.58 H-40 11/19/1997 Surface 5249.3 4224.8 7.625 6.875 29.7 L-80 ABM-BTC 11/20/1997 Tubing – Production 4540 3560 3.5 2.992 9.3 L-80 EUE 5/16/2022 Gravel Packed Liner 4960 3953 5.1 4 12/31/1997 New Tubing 4545 3562 3.5 2.992 9.3 L-80 EUE8rdMOD PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" x 1" Camco KBMG gas lift mandrel(s) @ TBD 3.5" x 7 5/8" D&L Feed Through ESP Packer @ ~4319' RKB 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3 1/2" NEXA-2 (Up to Open) 5.5" OD with cable bypass - 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Phone:670-6130 Rep.: E-Mail Well Name: PTD #11972060 Sundry #322-141 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1255 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 2P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" T 90 P Pit Level Indicators PP #1 Rams 1 2 7/8"x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 3 1/2" x 5 1/2"NT H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8" Gate P Inside Reel valves 0NA HCR Valves 2 3 1/8" Gate P Kill Line Valves 2 3 1/8" & 2"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 2 2 1/16 Gate P Time/Pressure Test Result System Pressure (psi)2950 P CHOKE MANIFOLD:Pressure After Closure (psi)1550 P Quantity Test Result 200 psi Attained (sec)22 P No. Valves 16 FP Full Pressure Attained (sec)110 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 5@2006 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:1 Test Time:6.0 Hours Repair or replacement of equipment will be made within 0 days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 5-12-22/ 12:00 Waived By Test Start Date/Time:5/14/2022 1:30 (date) (time)Witness Test Finish Date/Time:5/14/2022 7:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Nabors Tested with 3 1/2" test jnt. CMV #13 FP grease valve, retest, passed. Kelly Cozby / Paul Yearout ConocoPhillips Kevin Barr/Lenward Toussant KRU 1D-133 Test Pressure (psi): nskrwo.cm@conocophillips.com Form 10-424 (Revised 02/2022) BOP Nabors7ES 5-14-22 revised MASP:1255 5/14/22 1 FP ! " # $! % " & '$ ("" )*$ &+ *# , # -.$ /. 0$$ " ## ! 1 +1 2 $ 3* 45 $6 784 6 * 9*4 6 * :*4 6 & #* 9* & #* :* 94 6 49*6 ;<49*6 )'-)=$ " . < : < :9*4 6:*4 6 ' ," !< * >< &+ *# # (& * ) !< " .5 .$; *5 -:# * ? ? ? 5@? ?"" #?.$; ! "$ "& " A " #$ ?"" #! $ . > 9 . 5" ..B9. =12 $ &+ 12 $ :&*>2 # "99..$& C&?"" * " " & ? & /. # !# ! !# A$ *! * <#& * !D 437/6'-)%-), ? 9*4 6 '',0=9*'7(=:* ()-)=9*,)0(=:* (-/=9*,-0,=:* (/(7=9*,/(0=:* (0()=9*,0(-=:* (3'0=9*,3',=:* $8 * :*4 6 A &5E 5E.5$*?"$& :.$"99..$ '7"')'07 ! "#$%! >+77,-7F FE33)7 %#%&$%% " <F. 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Operations Performed: Abandon r Repair w ell r Plug Ferforations fl Perforate r Other r Alter Casing f Rill Tubing Stimulate - Frac r Waiver f Time Extension r Change Approved Program I- Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 197 - 206 3. Address: 6. API Number: Stratigraphic I� ' Service r �� P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 22827 -00 r° 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 1 D - 133 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): . none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5265 feet Plugs (measured) none true vertical 4239 feet Junk (measured) None Effective Depth measured 5122 feet Packer (measured) see schematic true vertical 4071 feet (true vertucal) see schematic Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 SURFACE 5209 7.625 5249 4225 RECEIVED JUN 13 2012 Perforation depth: Measured depth: 4626- 4664', 4696'- 4732', 4786- 4826, 4866-4922' AOGCC True Vertical Depth: 3646- 3677', 3707'- 3740', 3791'- 3830', 3865' -3918' Tubing (size, grade, MD, and TVD) 3.5, L - 80, 4548 MD, 3568 TVD Packers & SSSV (type, MD, and TVD) PACKER - ESP FEED - THRU PACKER WEATHERFORD HYDROW II DUAL - STRING PACKER @ 2238 MD and 2014 TVD PACKER - BAKER SC -1 GRAVEL PACK PACKER @ 4565 MD and 3584 TVD 3 PACKERS - BAKER SC -1L ISOLATION PACKERS @ 4671, 4740, 4845 MD and 3683, 3748, 3846 TVD PACKER - BAKER FB-1 RETAINER PRODUCTION PACKER © 4928 MD and 3923 TVD NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: �� II ryy 13. Representative Daily Av�`ilt�orll Attic t Ul Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 153 43 97 -- 233 Subsequent to operation shut - _ 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory I Development 17. Service r Stratigraphic f 16. Well Status after work: -0011 ;► Gas r WDSPL l" Daily Report of Well Operations XXX GSTOR I — WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Ian Toomey a 263 -4773 Printed Name Ian Toomey Title Wells Engineer Signature Phone: Ian Toomey @ 263 - 4773 Date Form 10-404 Revised 11/2011 VMS JUN 13 2012 V IMP 1 Only KUP 1 D -133 ConocoPhdllps m Well Attributes Max Angle & MD TD Alaska, Inc Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB OMB) ) Act Btm KB) Conoco/1109s 500292282700 WEST SAK PROD 59.00 2,811.45 5,265.0 Comment H2S (ppm) Date Annotation End Date KB -(3rd (ft) Rig Release Date ." _ SSSV: NONE 0 9/26/2011 Last WO: 5/22/2012 42.97 11/22/1997 Well Confiq -1 - D 133, 2312012 0.11'.52 AM Schematic51- Actua 1 l Annotation Depth (ftKB) End Date Annotation Last Mod By End Date __ �_ __. Last Tag: 5,122.0 1/2/1998 Rev Reason WORKOVER/WELL REVIEW osborl 5/23/2012 =JMNGHR. z___it __ _ s _ Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String String Top Thrd CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H CONDUCTOR, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 41 - 121 SURFACE 75/8 6.750 40.7 5,249.3 , 4,224.9 29.70 L -80 ABM -BTC II Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd MANDREL. 1 1 TUBING 31/2 2.992 36.8 4,548.0 3,568.4 9.30 L -80 EUE 2.114 Completion Details VW Top Depth (TVD) Top Inc! Nomi... PACKER. 2.238 _ Top (ftKB) (ftKB) C Item Description Comment ID (in) Mb 36.8 36.8 -1.89 HANGER VETCO GRAY TUBING HANGER 2.950 ESP Cable. 37 Allt ESP ' SE 2,238.2 2,014.4 52.09 PACKER ESP FEED -THRU PACKER Weatherford Hydrow II Dual- string packer 3.250 MANDREL, NC- 4,458.6 3,485.5 22.10 DISCHARGE WeIILiftDISCHARGE GAUGE UNIT 2.992 2,357 CATCHER, � 1 '.. - "' 4,515.8 3,538.5 21.68 INTAKE TTC PERFORATED INTAKE 2.992 P,J / s 2,3 ' .-- , 4,520.3 3,542.6 21.65 SEAL TANDEM SEAL SECTION L PLUG, 2, 4,534.1 3,555.4 21.54 GEAR GEAR REDUCTION UNIT SP MR MANDREL, ltd: 4,535.9 3,557.1 21.53 MOTOR ESP MOTOR 562MSP1, 60 hp/1240V/29 (S/N: 12057565 ) S 4 4,544.2 3,564.9 21.47 GAUGE WeIUL'rft MOTOR GAUGE N M 4,546.0 3,566.6 21.46 Centralizer MOTOR CENTRALIZER DISCHARGE. Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 4.459 GRAVEL PACK 5.1 4.000 4,564.9 4,960.2 3,953.6 Completion Details Top Depth MO) Top Inc! Nomi... t Top (ftKB) (ftKB) ( °) kern Description Comment ID (in) INTAKE. 4.516 4,564.9 3,584.2 21.32 PACKER BAKER SC -1 GRAVEL PACK PACKER 4.000 SEAL, 4,520 4,568.7 3,587.7 21.29 MILLOUT BAKER MILLOUT EXTENSION 4.990 GEAR, 4,534 4,574.7 3,593.3 21.24 SBR BAKER SEAL BORE RECEPTACLE 3.250 MOTOR, 4,536 4,579.9 3598.1 21.20 SLEEVE BAKER GRAVEL PACK SLIDING SLEEVE 3.480 GAUGE. 4.544 ,a 4,581.6 3,599.7 21.19 SEAL BORE BAKER SEAL BORE 3.250 Ceisrafaer, 4,546 .1 4,623.5 3639.1 21.09 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.000 PACKER, 4565 4,668.7 3,681.2 21.02 SBR BAKER SEAL BORE RECEPTACLE 3.250 MILLOUT. 4,569 4,670.9 3,683.2 21.01 PACKER BAKER SC -1L ISOLATION PACKER 3.875 568, 4,575 tIIIII 4,674.3 3,686.3 21.01 SBR BAKER SEAL BORE RECEPTACLE 3.250 SLEEVE, 4,580 4, 64 SLEEVE BAKER GRAVEL PACK EVE 3.480 SEAL BORE, 4,681.1 3,692.7 21.00 SEAL BORE BAKER SEAL BORE 3.250 4,582 1 4, 692.9 33,691.1 ,703.7 2222200001.....9900909811 SCREEN BAKERWELD GRAVEL PACK SCREEN SLIDING 4.000 4 ,738.1 3,745.9 SBR BAKER SEAL BORE RECEPTACLE 3 4 ,740.3 79. 3,747.9 PACKER BAKER SC -1L )SOLAT)ON PACKER SLE 3.875 4 ,743.6 3,751.1 SBR BAKER SEAL BORE RECEPTACLE 3.250 IPERF, 04%44 4,748.8 3,755.9 20.89 SLEEVE BAKER GRAVEL PACK SLIDING SLEEVE 3.480 4,E 4 .624 SCREEN, 4.624 rIlli El + 4,750.5 3,757.51 20.89 SEAL BORE BAKER SEAL BORE 3.250 SBR, 4.669 4,782.6 3,787.5 20.84 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.000 PACKER. 4,671 r - 4,842.8 3,843.7 20.75 SBR BAKER SEAL BORE RECEPTACLE 3.250 SBR, 4,674 4,845.0 3,845.8 20.74 PACKER BAKER SC -1L ISOLATION PACKER 3.875 SLEEVE, 4,679 SEAL BORE. 4,848.3 3,848.9 20.74 SBR BAKER SEAL BORE RECEPTACLE 3.250 4,681 4,853.5 3,853.7 20.73 SLEEVE BAKER GRAVEL PACK SLIDING SLEEVE 3.480 4,855.2 3,855.3 20.73 SEAL BORE BAKER SEAL BORE 3.250 4,866.8 - 3,866.2 20.71 SCREEN BAKERWELD GRAVEL PACK SCREEN 4.000 4,926.9 3,922.4 20.62 SEAL ASSY BAKER S-22 ANCHOR LATCH SEAL ASSEMBLY 3.821 IPERF, 4,6964.732 : 141, ' .4 4,928.0 3,923.5 20.62 PACKER BAKER FB-1 RETAINER PRODUCTION PACKER 4.000 SCREEN, 4,693 ' V 4,930.4 3,925.7 20.61 NIPPLE CASING NIPPLE 4.410 PACKER, 4,740 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) SBR, 4,744 Top Depth (TVD) Top lnc! SLEEVE, 4,749 Top (ftKB) MKS) (') Description Comment Run Date ID(in) SEAL BORE, 36.8 36.8 -1.89 ESP Cable 5/20/2012 0.000 4,751 • ��. 2,378.0 2,095.5 56.53 CATCHER CATCHER SET ON TOP OF WRP @ WORKOVER 5/21/2012 0.000 2,381.0 2,097.1 56.63 PLUG WRP SET @ WORKOVER 5/21 /2012 0.000 S , Perforations & Slots Shot IPERF, _ Top (TVD) Btm (TVD) Dens 4,786 -4,828 p .q Top (ftKB) Btm (MKS) (ftKB) i (81813) Zone 1 Date , (oh... Type Comment SCREEN, 4,783 - OPP 1 . OBin n 4,628.0 4,664.0 3,643.2 3,676.8 WS D, 1D -133 1/2/1998 12.0 IPERF RDX Charge; SOS 4 1/2' Ultrapak SBR, 4,843„' 4,696.0 4,732.0 3,706.6 3,740.2 WS B, 1D -133 1/2/1998 12.0 IPERF RDX Charge; SOS 41/2" Ultrapak PACKER, 4.845 4,786.0 4,828.0 3,790.6 3,829.9 WS A4,WS A3, 1/2/1998 12.0 IPERF RDX Charge; SOS 4 1/2" Ultrapak SBR, 4,848 �1j 10-133 SEAL BOORE, RE, r SLEEVE, - 4,866.0 4,922.0 3,865.4 3,917.8 WS A2, 1D - 133 112/1998 12.0 IPERF RDX Charge; SOS 4 1/2' Ultrapak 4.855 Notes: General & Safety End Date Annotation 7/1/2008 NOTE: View Schematic w/ Alaska Schematic9.0 7/1/2008 NOTE: WORKOVER IPERF. 4,9864,4.922 2 , . SCREEN, 4,867 SEAL ASSY, ' Mandrel Details 4,927 �' ° - Top Depth Top Port PACKER. 4,928 (TVD) Inc! OD Valve Latch Size IRO Run NIPPLE, 4,930 111'. Stn Top (ftKB) (ftKB) 11 Make Model (In) Sery Type Type ( (psi) Run Date Com... 1 2,114.1 1,934.3 47.80 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 5/22/2012 SURFACE, 41 -5,249 2 2,350.8 2,080.7 55.62 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 5/22/2012 TO (15-133), 4a. 3 4,406.6 3,438.0 24.17 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 5/22/2012 5,265 • 1 D -133 Well Work Summary DATE SUMMARY 2/25/12 PRE RWO T -POT BONNET( PASSED ), T -PPPOT BONNET ( FAILED ), T- UPPER BODY PASSED ), T -PPPOT UPPER BODY ( PASSED ), T -POT LOWER BODY ( PASSED ), T -PPPOT LOWER BODY ( PASSED ), UNABLE TO TEST GRAYLOC, FT -LDS ALL NORMAL. 5/12/12 PULLED 3 1/2 TBG STOP @ 4485' RKB, PULLED 3 1/2 PACKOFF @ 4486' RKB. IN PROGRESS 5/13/12 PULLED APART 3 1/2 ESP PUMP 2' BELOW FISHING NECK WHERE PUMP WAS WELDED TOGETHER. 32' OF PUMP LEFT IN HOLE, ATTEMPTED TO FISH. PULLED 1" SOV @ 4449' RKB. COMPLETE. Note: Displaced tbg w/ 40 bbls hot diesel and IA w/ 155 once HES was rigged out of the way.per procedure 5/21/12 * ** RIG JOB * ** DRIFTED TBG & CORRELATE DEPTH. SET 2.78" WRP @ 2382' RKB ON DPU. STAND BY FOR RIG. IN PROGRESS. 5/22/12 * ** RIG JOB * ** DEPLOYED CATCHER FROM SURFACE. PULLED DV @ 2114' RKB. REVERSE CIRCULATED 35 BBL DSL FOLLOWED BY 65 BBL GELLED DSL. RE- INSTALL DV @ 2114' RKB. TESTED TBG 3000 PSI, PASSED. COMPLETE. 5/28/12 PULLED CATCHER & WRP @ 2382' RKB. COMPLETE. • S ConocoPhitlips Time Log & Summary Wellview Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 5/17/2012 7:00:00 PM Rig Release: 5/22/2012 3:00:00 PM Time Logs Date F From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/17/2012 24 hr Summary Completed Well 1D-108 Program. RDMO. MIRU at Well Slot 1D-133. PJSM. Pull BPV. Begin Well Kill. 17:00 21:30 4.50 MIRU MOVE MOB P RDMO Well 1D-108. MIRU on 1D-133. Accept rig at 19:00 hrs. Spot equipment and Cutting Box and Load Pits with Filtered 3% KCL Sea Water. RU kill lines. 21:30 23:00 1.50 MIRU WELCTL KLWL P PJSM. Pick -up Lubricator. Pull BPV. Lay down same. Tbg /30 psi. IA/660 psi. Pressure test lines at 250/3,000 psi. Good. 23:00 00:00 1.00 MIRU WELCTL KLWL P PJSM. Notify DSO and Security that we will be venting gas. Bleed IA to 100 psi. Reverse in at 3.0 bpm /170 psi. with Hot Filtered 3% KCL Fresh Water to recover the Diesel Freeze Protect in the Tubing and to "wash" the ESP /HT Cable. 05/18/2012 Complete Well Kill. Install BPV. NU Tree. Install Blanking Plug. NU BOP Stack w/ STA and Dutch Riser. Perform Initial BOPE Test. Pull Blanking Plug and BPV. Install Side Port Isolation Sleeve. Circulate Well. Pull Tbg Hanger to Rig floor. 00:00 03:00 3.00 MIRU WELCTL KLWL P Contine to reverse in at 3.0 bpm /170 psi. with Hot Filtered 3% KCL Sea Water to recover the Diesel Freeze Protect in the Tubing and to "wash" the ESP /HT Cable. 200 bbls away with gas /fluid to surface. Shut in TBG /IA= 20/30 psi. 90 bbls return to kill tank. Swap lines and begin the Well Kill pumping the long way at 5.0 bpm /600 psi, holding 170 psi back pressure on the Choke, routing returns to the Kill Tank (45% returns). Total volume pumped = 420 bbls. Returns = 8.5 lb /gal. Monitor Well, on vacuum. 03:00 03:30 0.50 MIRU WHDBO MPSP P PJSM- Install BPV. 03:30 05:00 1.50 MIRU WHDBO NUND P PJSM- Nipple down Tree. Inspect threads, good. Install blanking plug. 05:00 08:00 3.00 MIRU WHDBO NUND P Nipple Up BOPE w/ STA and Install Dutch Riser. Page 1 of 6 • S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 17:00 9.00 MIRU WHDBO BOPE P PJSM. Start Initial BOP Test. Function & PT rams, choke manifold and annular w/ 2 -7/8" and 3 -12" test joints to 250/3000 psi. Koomy draw down, Start 3000 psi, End 1850 psi, 200 psi recovery 12 seconds, full recovery 94 seconds. RD test equipment States right to witness initial BOPE test waived by AOGCC field rep. Bob Noble at 08:00 on 05/17/2012. 17:00 18:00 1.00 MIRU WELLPF SVRG P Service Rig. Filled Ducth Riser and had small leak, drain riser, re -seal riser and flange and tested good.. 18:00 18:30 0.50 COMPZ WELLPF OTHR P DHD crew shoot IA fluid level at 650 -ft. 18:30 19:30 1.00 COMPZ WELLPF OTHR P PJSM- Load, rack and tally 511 Hydrill Tbg. Load heat trace spool and install in spooler. 19:30 21:00 1.50 COMPZ WHDBO MPSP P PJSM w/ Vetco -Gray and Nordic 3 crews. Pull blanking plug and BPV. Monitor well, static. Install Side Port Isolation sleeve and MU landing joint. 21:00 22:45 1.75 COMPZ WELCTICIRC P Rig up lines. Circulate and condition Well, 1.5 times with Filtered 3% KCL Sea Water at 5.0 bpm /400 psi. Returns clean 8.5 lb /gal. (40% returns) Monitor Well, on vacuum. Blow down and Rig down circ. lines. 22:45 23:00 0.25 COMPZ RPCOM SFTY P PJSM w/ Centralift, Vetco Gray and Nordic 3 crews. Discussed procedures and hazards for pulling tubing hanger to floor with ESP de- completion. 23:00 00:00 1.00 COMPZ RPCOM THGR P Make -up Top Drive to the Landing Joint. BOLDS. Pull Tubing Hanger free at 150K. Pull Tubing Hanger to the floor at 90K. Remove penetrators and lay down same. 05/19/2012 Prep to pull Completion. Single down the 3 -1/2" ESP /HT Completion. RIH with RCJB. POOH. RIH with th_ e Clean -out String., 00:00 00:30 0.50 COMPZ RPCOM RURD P Rig up to single down the 3 1/2" ESP /HT Completion. 00:30 07:00 6.50 4,666 24 COMPZ RPCOM PULL P PJSM. Begin to single down the 3 1/2" ESP /HT Completion. Spooling ESP and HT Cables. Kick -out 3 1/2" Tubing from the Pipe Shed as needed. Up Wt. 90K. Down Wt. 65K. No signs of trouble thru tight areas from 2008 WO (2,880 -ft to 2,220 -ft) Page 2 of 6 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 08:30 1.50 24 0 COMPZ RPCOM PULD P Lay Down Lower ESP Assembly. Count all bands and clamps removed from completion. Called Corrosion Team and Talk to Tom. He said no need to inspect if there was no sign of corrosion. Tubing showed no sign of corrosion. Recover (2) Protectorizer (5) SS Bands (30) 2' Cross Coupling Clamps (94) 2' Dual - Channel Clamps (5) 4' Cannon Clamps (1) 2' End Shoe (428) 5' Cannon Clamps, missing 3. 08:30 10:30 2.00 0 0 COMPZ RPCOM PULD P Kick -out Used Clamps + ESP Motor assembly. Prep + secure spools for swap out. Change out floor equipment. Clean and Clear floor. 10:30 12:00 1.50 0 0 COMPZ RPCOM OTHR P PJSM. Remove Ice from Derrick. Move DP in Derrick. 12:00 12:45 0.75 0 27 COMPZ RPCOM PULD P PJSM. PU & MU BHA #1. 5 3/4" RCJB, 4 3/4" Bumper Sub and Oil Jars. 12:45 17:30 4.75 27 4,565 COMPZ RPCOM TRIP P TIH with BHA #1 on Drill Pipe down to 1 stand above SC -1 packer and circulate down to 4565' RKB. Up wt 100k, Dn wt 75k. 17:30 19:00 1.50 4,565 4,565 COMPZ RPCOM OTHR P PJSM- Hazards of Off loading and Loading ESP spools to Rig. Swap out ESP cable spools, Off load recovered Heat Trace spool. 19:00 20:30 1.50 4,565 0 COMPZ RPCOM TRIP P TOOH and Inspect RCJB. 3" x 1.5" x .25" piece of pack -off rubber and 3/4 of 1 Band recovered. no marks or signs of other junk, confer w/ town engineer. 20:30 22:00 1.50 0 0 COMPZ RPCOM PULD P Lay down RCJB assembly and MU Hydrill 511 clean out assembly with 7 5/8" casing scraper. 22:00 00:00 2.00 0 4,960 COMPZ RPCOM TRIP P TIH with C/O and scraper assembly on drill pipe down to 4960' RKB, no fill encountered, no problem thru SC -1 liner top packer at 4,565 -ft. Up wt 100k Dn wt 75k. 05/20/2012 Reverse Circulate Well. POOH. RIH and Set Retrievable Bridge Plug. Test Casing. Slip -n -Cut Drill Line. Release RBP. Circulate Well. TOOH with Pkr and RBP. Rig up to handle the Completion. Single in 3 -1/2" ESP Completion to Weatherford Packer. 00:00 01:30 1.50 4,526 4,526 COMPZ RPCOM CIRC P PUH to above liner top packer at 4,565 -ft. Up wt 100k. Reverse circulated well clean Two DP volumes 5 bpm, ICP 150 psi, FCP 270 psi. 01:30 03:30 2.00 4,526 0 COMPZ RPCOM TRIP P TOOH standing back DP, splitting in derrick. Up Wt 100k / Dn Wt 75k. Lay down clean out assembly. Page3 • Time Logs Date From To Our S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:00 0.50 0 34 COMPZ RPCOM PULD P Make up Baker Model "G" Retrievable Bridge Plug and the Baker Retrievamatic Packer. 04:00 05:30 1.50 34 4,510 COMPZ RPCOM TRIP P TIH with Test Packer assembly to 4,520 -ft. Up Wt 100k / Dn Wt 75k and set center element at 4510' RKB. PUH 1 stand. 05:30 06:30 1.00 4,479 4,479 COMPZ RPCOM PRTS P RU Testing Equipment. Pressure test 7 5/8" Casing to 1500 psi x 30 minutes and Record on pressure Good Test. 06:30 10:30 4.00 4,479 4,479 COMPZ RIGMNT SLPC P PJSM. Kick out Hydrill 511 tubing. Secure Blocks. Slip -n -Cut Drilling line and inspect cable drum. 10:30 11:00 0.50 4,479 4,510 COMPZ RPCOM PULL P RIH and retrieve RBP._ 11:00 11:45 0.75 4,510 4,510 COMPZ RPCOM CIRC P Line Up Mud pump and circulate and condition well at 5 bpm, 500 psi. 11:45 15:30 3.75 4,510 4,510 COMPZ RPCOM TRIP P CBU until returns are clean. PJSM. TOOH standing back drill pipe. Up Wt 100k 15:30 17:30 2.00 4,510 0 COMPZ RPCOM PULD P OOH. lay down RBP and Test Packer. Clean and CLear Floor and K/O Tools from Pipe Shed. Pull Wear Bushing and Wash BOP Stack. Change over floor equipment to run completion. 17:30 22:15 4.75 0 78 COMPZ RPCOM PULD P PJSM- Check Cable Integrity. PU Motor centralizer, MGU, ESP Motor, check rotation, MU GRU and tandem seal section, check rotation, MU TTC assembly to seal section, Pup joint, Full joint and DGU assembly. Install TEC wire to MGU, RU cable sheave and motor cable, Lower assembly into well, installing MLE, Protectolizers and Clamps per program, MU TEC wire from motor gauge to the discharge gauge. Check cable integrity. 22:15 00:00 1.75 78 2,300 COMPZ RPCOM RCST P Continue to RIH w/ remainder of ESP completion as designed to Weatherford Hydrow II Feed -thru Packer checking power cable every 1000 -ft. Up wt 60k, Dn wt 56k 05/21/2012 Splice cable thru packer. Run 3 -1/2" completion as designed. Splice cable at tubing hanger. Land completion. RILDS. PT hanger pack -offs. Check Cable integrity. Prep for S -Line ops. Drift and Correlate for WRP. Set WRP. Pump Corr Inhib SW down IA. Set Pkr. Test IA. Use decompression sch to bleed IA pressure. 00:00 05:15 5.25 2,300 2,300 COMPZ RPCOM PACK P MU Weatherford Hydrow II Feed -thru packer, Make splice thru packer. Check cable integrity. 05:15 08:15 3.00 2,300 4,500 COMPZ RPCOM RCST P Continue to RIH w/ remainder of ESP completion as designed checking power cable every 1000 -ft. Call Out Vetco Gray at 0735 hrs. Ready to MU Tubing Hanger. Page 4 of 6 • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 08:15 09:45 1.50 4,500 4,500 COMPZ RPCOM THGR T Waiting On Personal to Arrive. Check ESP Cable. Had to sent one of the centrilift reps in to get him? 09:45 10:00 0.25 4,500 4,500 COMPZ RPCOM PULD P Vetco Gray on Location at 0945 hours. PU TBG Hanger and Inspect. 10:00 12:00 2.00 4,500 4,500 COMPZ RPCOM THGR P MU Tubing hanger w/ side port isolation sleeve installed. Make final splice of cable to penetrator. Check Electrical Integrity. 12:00 12:30 0.50 4,500 4,548 COMPZ RPCOM THGR P PJSM. MU landing joint and land tubing hanger and RILDS. 12:30 13:00 0.50 4,548 4,548 COMPZ RPCOM PRTS P PT Hanger packoffs to 5000 psi for 15 minutes. 13:00 13:30 0.50 4,548 4,548 COMPZ RPCOM THGR P Remove landing joint and side port isolation sleeve from hanger and re- install landing joint. Call out Slick -line 13:30 13:45 0.25 4,548 4,548 COMPZ RPCOM NUND P NU Dutch Riser. Unable to Used the Dutch Riser. The Last Lubricator section needed is Pin x Pin, we need a female to male. 13:45 16:15 2.50 4,548 4,548 COMPZ RPCOM SLKL P PJSM- MIRU Slickline. PIT Lub, RIH w/ 2.78" Drift to 2,400' SLMD. RIH w/ KOT to 2,392' SLMD Flag wire - POOH stand back Slickline 16:15 17:00 0.75 4,548 4,548 COMPZ RPCOM CIRC P Bullhead 40 bbls Corrosion Inhibited KWF follewed by 5 bbls 3% KCI KWF down Tubing. 17:00 18:30 1.50 4,548 4,548 COMPZ RPCOM SLKL P RIH w/ WRP on 1- 11/16" DPU and set @ 2,382 -ft' RKB, PT same to 300 psi for 5 minutes. 18:30 19:30 1.00 4,548 4,548 COMPZ RPCOM CIRC P Bullhead 50 bbls Corrosion Inhibited KWF follewed by 35 bbls 3% KCI KWF down IA 2 bpm at 80 psi. 19:30 20:30 1.00 4,548 4,548 COMPZ RPCOM PACK P Pressure up on TBG and Set Hydrow I I Packer per Weatherford Rep. Packer set at 3,250 psi. 20:30 23:00 2.50 4,548 4,548 COMPZ RPCOM PRTS P Rig up lines, fill IA and bleed air from system. Pressure IA up to 1550 psi, Failed first 2 tests, lost more than 10% on each 30 minute test. RU chart sensor direct to Tee at IA valve P I to bypass choke /manifold system. pressure IA uo to 1500 psi. good. 23:00 00:00 1.00 4,548 4,548 COMPZ RPCOM OTHR P Bleed IA down per decompression schedule. 05/22/2012 Continue decompression sch to bleed IA pressure. Pull DV. FP Well. Set DV. PT Tbg. RD S -Line. Install TWC. ND BOPE. NU Tree. Test Tree. Make final cable checks. Pull TWC. Install BPV. Secure Cellar. Release Nordic Rig 3 at 15:00 hrs on 5- 22 -12. 00:00 02:15 2.25 4,548 4,548 COMPZ RPCOM PRTS P Continue to bleed IA down per decompression schedule. 02:15 03:30 1.25 4,548 COMPZ RPCOM SLKL P PJSM- RU Slickline, MU Catcher and RIH w/ KOT, chase catcher to 2,200 -ft, PUH and latch DV at 2,114 -ft RKB, POOH w/ DV on BK latch. Redress KOT to run while pumping freeze protect. Page 5 of 6 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 03:45 0.25 COMPZ RPCOM SFTY P MI LRS and spot equipment. PJSM- discussed pump procedure and hazards. RU LRS and transport. Pressure test lines. 03:45 06:00 2.25 COMPZ RPCOM CIRC P Reverse circulate 30 bbls diesel (neat) followed by 65 bbls Gelled Diesel followed by 5 bbls neat diesel 2 bpm. 06:00 08:00 2.00 COMPZ RPCOM SLKL P PJSM- RU Slickline and RIH w/ KOT and set DV in upper GLM at 2,114 -ft, pressure TBG to 200 psi, POOH, DV set. Bleed TBG to 0 psi. PJSM- RDMO Slickline. .- 08:00 09:30 1.50 COMPZ RPCOM PRTS P Pressure test TBG at 3,000 psi and 121- • chart for 30 minutes, Good Test - S IP Bleed TBG to 0 psi. RD Test equipment. Nordic Rig 3 went off High line at 09:00 hrs 09:30 10:30 1.00 COMPZ RPCOM OTHR P Drain BOP stack and Back out landing joint. Lay down landing joint. 10:30 11:30 1.00 COMPZ WHDBO NUND P ND BOPE w/ WFT Safety Tension Adapter and set back on stump. 11:30 13:00 1.50 COMPZ WHDBO NUND P NU Tree and PT at 250 / 5,000 psi - good test 13:00 13:30 0.50 COMPZ RPCOM SEQP P Make final electrical test on ESP cable with Centrilift 13:30 15:00 1.50 COMPZ RPCOM MPSP P Pull Two way check and install BPV, Clean and dress tree. Release Nordic Rig 3 at 15:00 hrs on 5 -22 -12 Page 6 of 6 • • ~~~ L~ ~~~~~~~ Id' PROAcme DiAgnosric SeevicES, INC. To: AOGCC Christine A~Aa~leer~ 51~~'fze~ 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing (nspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt. by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Anchorage, AK 99518 ~~-,~ ~;° , . +~. 1 Fax: (907j 245-8952 1 j MTT Report 25,1un-10 10-129 1 Report 50-029-22830-00 2J MTT Report 25-Jan-10 1 D-133 1 Report 50-029-22827-00 j~~ -ark I ~''~~~ ~ Signed Print Name: RECEI ~ ~u~ ~sao~o Da PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : pdsanchoraaeCa memorvlog.com WEBSITE : www.memoryloa.com C:\Documents and Settings\Diane Willisms\Desktop\Transnrit_Conoco.docx • Memory Magnetic Thickness Toot Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1D-133 Log Date: June 25, 2010 Field: West Sak Log No.: 7417 State: Alaska Run No.: 2 (1 ~` MTT) API No.: 50-029-22827-00 Pipet Desc.: 3.5" 9.3 Ib L-80 EUE 8RD Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 222 Ft. (MD) Pipet Desc.: 7.625° 29.7 Ib L-80 ABM-BTC Top Log Intvl.: Surface Pipet Use: Surface Casing Bot. Log Intvl.: 222 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total metal thickness of the 3.5" tubing, 7.625" surface casing, with some influence from the 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20 fpm. INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from surface to 222'. Changes in metal volume are relative to the calibration points at 66' and 161', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which indude influences from the 3.5" tubing, 7.625'` casing and 16" conductor pipe. A log plot overlay of the average overall metal thickness recorded by the 5Hz, 8Hz and 10Hz passes is included in this report. This plot indicates an area of up to 13% relative metal loss over the interval (21' - 41') in the 5Hz pass. Over the same interval, the 8Hz pass indicates up to 7% relative metal loss and the 10Hz pass indicates up to 4% relative metal loss. A log plot of the entire 5Hz pass and an expanded log plot of top 30' of the 5Hz pass are included in this report. A maximum -13% circumferential metal loss is indicated in the interval between 21' and 41' in the 5Hz pass. (A tubing joint collar may mask some potential casing damage in this interval.) The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" surface casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. Field Engineer: Wm. McCrossan Analyst: HY. Yang & J. Burton Witness: J. Condio ~'f "-~Cti'., r C~;! f'=,^c~-'.C ~°I'VlCvir T r+~,r ~' ' .~FC} ~~~~^.~f'C~ T~,t 7 q.C- gip- ' -_ _ `~ ~ " ~ _ i~ i_ -_ _ t ~'sc=, - c`l ~! Y.C7Q.CC7rC~ r. ~i~!d ~?~ _~~~ ;:~E,r :e; rc, . ;~i? ~~ :: '~ 7 f:~~3-231 T~ ~~~ A o`E"'"~E"S SHz, and 10Hz Delta Metal Thi ess Passes Overlay Q~ Fc1 ~~ N 1 D-133 June 25, 2010 Po°Acrivc Dinyhosric Scaviccs Database File: d:Iwarriorldatal1d-133loverlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Wed Jun 30 10:18:34 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2010 (10Hz) (%) 50 -50 Delta Metal Thickness 2010 (8Hz} (%) 50 -50 Delta Metal Thickness 2010 {5Hz) {%) 50 0 Delta Metal 20 Delta Metal Thicknes 40 Col 60 Delta Metal Thickness 80 Bottom of 16" 10D • 120 140 160 180 OHz Delta Metal Thic Delta Metal 200 220 Delta Metal Thickness -50 Delta Metal Thickness 2010 (10Hz) {%) 50 -50 Delta Metal Thickness 2D1D {8Hz) (%) 50 -50 Delta Metal Thickness 2010 {5Hz) {%) 50 o`~"`WE"sA~ R rded Magnetic Thickness Data - 5Hz Pass Q~ c''~ ~ ~ ~ '" 1 D-133 June 25, 2010 Pn°Acriv[ DL.\C~N°Si1C SCRYICCS Database File: d:lwarriorldatal1d-13315hzpass.db Dataset Pathname: 5HzPass ' Presentation Format: 18 Dataset Creation: Wed Jun 30 11:09:26 2010 Charted by: Depth in Feet scaled 1:150 ' -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 0 Line Speed (ftlmin) -200 -7 MTTP12 (rad) 3 ' Tree ~Hanger~ ' 7.625" Collar _ Delta Metal Thickness Line Speed Tubing Jt. 1 ' 20 -- 3.5" Collar _ ~ ' 13% Metal Loss ~ - 7.625" Collar Tubing Jt. 2 -- 60 3.5" Collar 1 - Tubing Jt. 3 ' 80 7.625" Collar ' 3.5" Collar ' ~~ ii A o`~"`"~F"s E nded 5Hz Pass Magnetic ~ckness Log Data Q~ F~~y N 1 D-133 June 25, 2010 Pn°Acrivc Dinc n°sric Suviccs Database File: d:lwarriorldatal1d-1331expanded 5hzpass.db Dataset Pathname: 5HzPass Presentation Format: 18 Dataset Creation: Wed Jun 30 11:09:26 2010 Charted by: Depth in Feet scaled 1:60 -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 0 Line Speed (ftlmin} -200 -7 MTTP12 (rad) 3 Tree - - -- - -- ~--- ~-J-= ~Hanger~ -- - - - ~ i ~ ~ i I ~ " 1- I ~ ~ i j '~ 7. 625 Co llar y 7 Delta Metal Th ickness 10 ~ ~, - Line S peed ~ r ~ ~ Tubin Jt 1 g . 20 5 :' 30 3.5" Co llar ~ 13% Metal Loss L -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 0 Line Speed (ft/min} -200 -7 MTTP12 (rad) 3 1 1 1 1 ConocoPhillips .\I. r;n,: lit:. ... ~ CammaR Well Confp' -10.133 1272010 12 5]'17 PM NONE Scnematic-Adual Afltlet~1011 Last Tag: x.8510 _ Casing Des, HANGER. 37 CONDUCT Casng Des _____________ ________ SURFACE - - - -- -_ Tu6ina. 1 D-133 K weir stains hn puts) Aa Btrn pll®) PROD 59.00 2,811.45 5,265.0 ITS Ippm) Date Annottion End Date IBL1'd pp Rig Release Date 0 8/712009 Last WO: 7/1/2008 42.97 11!22/1997 M Date Ama[ation Last plo d ... End Date 1/2/1998 Rev Reason: GLV C/O Imosbor 1/27/2010 ... ~ Top pnto) Set DeptOp... Set Depm (7V D) ... Stritg gL.. Shi .. Strlrg Top 7hd 1 062 ~O ... ITap pDB) Sa Zepth3 ... Set Depth49 DJ ... Sm .. S°Li .. Sm ~ 6.750 9.70 -80 ABM-B EUE 8rd Top Intl (°) CONDUCTOR. 41-121 ESP MANDREL, 3 060 ESP SLIP STOP. 4 485 PACKOFF, 4 486 GAUGE, 4 495 PUMP, 4 493 INTAKE.4527 SEAL, 4,542 GEARBOX, 4 555 MOTOR, 4 5S/ Centralizer. 4564 IPERF, 4 ]B6d 828 IPERF, 4,8664 922 SURFACE, di-5 2d9 TD (1D-1331, 5 265 Comment Top ptlo;) 1nnn1 (°) Descdptian t:pnmeM R1n Date ID IiN 4,485 3,509.9 21.91 SLIP STOP 3.5' SLIPSTOP 11127!2009 1.500 4,486 3,510.8 21.90 PACKOFF 3.5" D&D PACKOFF wISTINGER 11/2712009 1.620 4.493 3.517.3 21.85 PUMP 3.5" TTC PCP 44T250 ESP PUMP - OAL =34.5625' 11/26/2009 0 000 lop ITYD) etm ITVD) Dins lop ptKB) Bbn ptl®) pg18) pBCe) Zane DMe (~° Tvpe canment Make Model IIN Serv type Type lin) TROMRUn 1D-133 (PTD 197-206) • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, October 20, 2008 1:14 PM To: 'Ennis, J J' Cc: Allsup-Drake, Sharon K Subject: RE: 1 D-133 (PTD 197-206) Jim and Sharon, 1 can make ahand-correction. No need to send any new paper. Tom Maunder, PE AOGCC • Page 1 of 1 From: Ennis, J J [mailto:J.J.Ennis@conocophiltips.com] Sent: Monday, October 20, 2008 12:58 PM To: Maunder, Thomas E (DOA) Cr. Allsup-Drake, Sharon K Subject: iD-133 (PTD 197-206) Hi Tom, You are correct, the tbg in 1 D-133 is 3.5". It was upsized during the workover from 2.875". I apologize for the typo. Please let me know if we need to re-submit the 404 or if this wi11 suffice. Jim Ennis j j.ennis@conocophiiiips.com (907)265-1544 (VV) (907)632-7289 (C) ~u 10!20/2008 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~ ~~~ ~` '~ 1. Operations Pertormed: Abandon ^ Repair Well ~ Plug Perforations ^ Stimulate ^ Other ^, Alter Casing ^ Pull Tubing Q Perforate New Pool ^ Waiver ^ Times Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConOCOPhillipS Alaska, InC. Development 0 Exploratory ^ ~ 197-206 / . 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22827-00 • 7. KB Elevation (ft): 9. Well Name an Number: KB 41', Pad 71' 1 D-133 8. Property Designation: 10. Field/Pool(s): 'r ADL 25650 Kuparuk River Field /West Sak Oil Pool ` 11. Present Well Condition Summary: Total Depth measured 5265' feet true vertical 4239' feet Plugs (measured) Effective Depth measured 5122' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 5208' 7-5/8" 5249' 4224' Perforation depth: Measured depth: 4628'-4664', 4696'-4732', 4786'-4828', 4866'-4922' true vertical depth: 3643'-3677', 3706'-3740', 3791'-3830', 3865'-3918' 3i~}i ~0~ Tubing (size, grade, and measured depth) L-80, 4565.5' MD . Packers &SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 155 4 143 -- 168 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact ~' Enn' @ 265-1544 Printed Name nnis Title Wells Engineer ~ ( ~C, U Signature Phone: 265-1544 Date to Pre a d r n Allsu Drake 263-4612 Form 10-404 Re ed 04/2006 ~~~` .~ ' a, A L Submit Original Only , ~ ~5'~~` • i Cor~o~oPhilips Time Log & Summary Wp,~~~ ~Q~ ~~pfl,-~,~9 Report Well Name: 1 D-133 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 6/27/2008 7:00:00 PM Rig Release: 7/1/2008 9:00:00 PM - -- ---- Time Logs Date From To __ Dur___S,_ D~th E Depth Phase Code Subcode T __Comment 6/27/2©08 24 hr Summary RDMO 1A-12, moved rig to 1 D-133, spotted rig, kill tank and filter unit, RU hardline and circ lines. 07:00 18:00 11.00 MIRU MOVE MOB P Move rig off 1A-12. Remove rig mats. Move ri from 1A ad to 1 D ad. 18:00 19:00 1.00 MIRU RPCOM RURD P Set rig mats. Spot rig and center over well. 19:00 20:00 1.00 COMPZ RPCOM RURD P Accept rig at 19:00 hrs, spot mud shack, cuttings box, and rig e ui ment. 20:00 20:30 0.50 COMPZ RPCOM RURD P RU Vetco lubricator and pull BPV, LD lubricator. 300 psi on tbg, 600 psi on IA. 20:30 21:30 1.00 COMPZ RPCOM RURD P RU 2" hardline to kill tank, RU circ lines in cellar, test hard line at 120 psi w/air, fluid pack lines and test to 500 psi to kill tank, RU filter unit and com lete berm of tank farm and unit. 21:30 00:00 2.50 COMPZ RPCOM RURD P Load vac truck with 285 bbls sea water and 6% KCL, start filtering fluid (65 microns in, 1 micron out). Spot LRS to heat seawater when done filterin . 6/28/2008 RU and killed well, ND tree, NU BOP. 00:00 04:30 4.50 COMPZ RPCOM OTHR P Cont filtering and heating seawater, prep 2 7/8" rams and floor equipment, hang heat trace sheave, pull and clean out under piperack, re test lu . 04:30 06:00 1.50 COMPZ WELCTL CIRC P Spot vac truck, RU, PJSM, break circ at 3 bpm 470 psi dwn tubing, staged rate up to 5 bpm 890 psi, pumped total of 270 bbls, 160 deg, 8.5 ppg, 6% KCL seawater. Shut dwn and shut in well. 06:00 12:00 6.00 COMPZ WELCTI COND P Observe shut in pressures. SITP =60 psi SICP = 60 psi, KWF (100 # overbalance 9.6 # load vac truck with 280 bbls 9.6# kill weight fluid, filter to <2 microns. Load ESP s ooler w/crane. RU LRS Hot Oil. 12:00 14:30 2.50 COMPZ WELCTL CIRC P Pump 265 bbls 9.6# Filtered brine with 6% KCL heated to 160 degrees 2 BPM @ 775 psi. MW out 9.5# 110 degrees. SD monitor well, static. RD LRS. 14:30 15:30 1.00 COMPZ WELCTL NUND P B/D & R!D circ.lines. Install BPV. ~ ~ t F~e~~ 't of 4 Time Loys _ _ _ _ Date From To Dur S. De th E De th Phase Code Subcode T Comment 15:30 00:00 8.50 COMPZ WELCTL BOPE P ND tree. Install POT in lift threads. NUBOP. Function & PT BOP rams and choke manifold to 250/2500 psi, annular 250/2500 psi. Witnessing of test waived by AOGCC (Chuck Scheve . 6/29/2008 Test BOP equip, R & T 3 1/2" tbg, unseat hanger, POOH LD 2 7/8" 00:00 03:00 3.00 COMPZ WELCTL BOPE P Cont testing BOP equipment at 250 and 2500 psi., load heat trace spool, clamp containers, pipe handing equipment. Witnessing of test waived b AOGCC Chuck Scheve . 03:00 06:00 3.00 COMPZ RPCOM RURD P R & T 3 1/2" tbg in shed, install isolation sleeve, fill hole (22 bbls), MU landing jnt extension and MU on han er. BOLDS 06:00 06:30 0.50 COMPZ RPCOM PULD P Pull hanger to rig floor, 150K to unseat hanger. Up wt 70K dwn. Monitor well loosin a rox. 30 hr. Chan a MW from 9.6 # to 9.3#. 06:30 07:30 1.00 COMPZ RPCOM PULD P LD hanger & landing jt. Remove Penetrators. 07:30 10:00 2.50 COMP2 WELCTL CIRC P RU & circulate 9.3# brine @ 2 BPM, 150 psi 100 bbls. Closed annular and bullhead 35 bbls 9.3# brine to bottom perfs. @ 4 BPM w/900 psi. SD, open annular, circ. annulus vol from open GLM to surf 165 bbls 9.3# brine @ 4 BPM w/500 psi. SD, monitor well, losin small amount of fluid 10:00 23:00 13.00 4,512 0 COMPZ RPCOM PULD P Thread ESP & Heat Trace cables over sheaves and POOH laying down 2 7/8" tubing ,spooling up cables, removing clamps & bands. Obtained oil samples from pump assembly and broke down pump. LD total 142 jnts 2 7/8" tbg, 458 - 5' dual channels, 1 - 2' channel, 1 - 3' channel, 1 - 4' channel, 1 shoe, 92 - dual cross couplers, and 30 single cross couplers. Heat Trace had bad spot on bottom, needs to be replaced.Total fluid lost = 264 bbls for last 24 hrs. 23:00 00:00 1.00 0 0 COMPZ RPCOM RURD P PJSM with crane operator, RU and CO both spools, emptied pipeshed, re-loaded shed with new pump parts, start cleanin ri floor. 6/30/2008 RIH to 3,735' with ESP completion. 00:00 02:00 2.00 0 0 COMPZ RPCOM OTHR P Cont cleaning rig floor and e ui ment. 02:00 05:00 3.00 0 71 COMPZ RPCOM PULD P PU and MU ESP pump and service. ~n an s np ech wire for au e. ~~~ 2 ~t ~ 1 Time Logs Date From T_o _ _Dur S Depth E. De th Phase_ Code _ Subcode T Comment _ ----- 05:00 06:00 1.00 71 71 COMPZ RPCOM RURD T Wrong connections for Guardian Guage. Wait for tech and correct arts. 06:00 07:00 1.00 71 71 COMPZ RPCOM RURD P Install Guardian Guage. 07:00 09:00 2.00 71 71 COMPZ RPCOM RURD T Wrong Cannon Clamps on location. Wait for correct single cross coupling Cannon Clam s. 09:00 11:30 2.50 71 1,596 COMPZ RPCOM RURD P Continue running in hole with completion. Installing Cannon Cross Coupling clamps on 1st six tbg collars above GLM and every other collar until reaching heat trace. Start Heat Trace 19' in on jt # 47 (3000'). Testing ESP cable and Heat Trace continui eve 1000'. 11:30 23:00 11.50 1,596 3,735 COMPZ RPCOM RURD P Continue RIH w/ESP completion. Hit tight spot @ 2220', worked thru. Retest cables OK. Continue RIH, hit ti ht s ots @ 2290', 2322', 2380' 2411', 2600', 2638', & 2880'. 23:00 00:00 1.00 3,735 3,750 COMPZ RPCOM RURD T Ran out of dual cross couplers at 3,735'. Wait for more dual cross coupling Cannon Clamps from wharehouse. 7/01 /2008 Continue to Rih w/ 3 1/2 ESP Comaletion. Make final splices. Land hanger. Set TWC and ND BOPE. NU Tree and ull TWC. Freeze rotect. Set HBPV. Release Nordic Ri 3 21:00 hrs. 00:00 00:30 0.50 3,750 3,750 COMPZ RPCOM RCST T Wait for more dual cross coupling Cannon Clam s from wharehouse. 00:30 04:00 3.50 3,750 4,565 COMPZ RPCOM RCST P Continue RIH w/ESP completion, testing ESP cable and Heat Trace continuity every 1000' to 4495'. MU hanger and landing jnt. Up wt 80K, down wt 70K. 04:00 09:00 5.00 4,565 COMPZ RPCOM DHEQ P Splice esp and heat trace cables for penetrators and test same. Final clamp count: 2 -Flat Guards, 5 - SS bands, 30 Single Xcouplings clamps, 94 Dual Channel Xcouplings, 431 - 5' Mid jt couplings, 5 - 4' Mid jt couplings, 1 end shoe (for heat trace . 09:00 10:30 1.50 COMPZ RPCOM RURD P Lower hanger to wellhead and land. Up wt 80K, dwn wt 65K. RILDS. Test hanger void to 5000 psi. Remove landing jt. Remove side port iso. sleeve. Install two-wa check. 10:30 13:00 2.50 COMPZ RPCOM NUND P ND BOPE. Change bottom rams to 3-1l2" from 2-7/8". 13:00 13:30 0.50 COMPZ RPCOM DHEQ P Re-test ESP cable and heat trace after ND. 13:30 17:30 4.00 COMPZ RPCOM NUND P NU tubing adapter and 5M tree. Trouble establishing seal at penetrators. Test tree to 5000 psi. Pulltwo-wa check. 17:30 18:00 0.50 COMPZ RPCOM SFTY P Held PJSM w/ LRS and Rig crew. Faye 3 of d Time Logs __ __ _ _ _ __ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 18:00 20:00 2.00 COMPZ RPCOM FRZP P RU Cirvc lines and PT to 2,500 psi. Freeze protect well. 100 bbls diesel down IA @ 2 bpm @ 500 psi and 30 bbls down tb 2 b m 1,000 si. 20:00 21:00 1.00 COMPZ RPCOM OTHR P RD Lines and secure tree. Set HBPV w! lubricator. Release Nordic Ri 3 21:00 hrs. ~ e F~age ~ ca# d (~,, } L Q~~~~1`i 1~i~~prJ ~ - ' 1 ~ KUP ~ 1 D-133 W ll Att ib t .. ~ , r u e es {?i~eL-.a HFI / U~+/I Field Name Well Jtaaus ;Maalmum Inclmadon (-) total lxplh (hNCi) " 5002922827 WEST SAK PROD j _ 59.00 _ 5,265.0 ... onfg 10133 su,emai. , J .SAM _ _ Comment H33 Ippm( Date ~Annotati... End Date S 1/1/2008 ~LastWO: 7/1/2 ;Amotation Depth (RKB( End Dah Annotation KB-Ground Distance tM1) Rig Release Date _008 42.97 11/2211997 ;End Date . - ~LastTag: 5,122.0 1/2/1998 Rev Reason: ADD ZONES Casing Strings 7/13Y2008 j giie~ piio~ L ~„ IC I IAN nre s,.lr 1 nln .. c I nlr:o n I it i- ~~I CONDUCTOR ~ ! III ,,I Ir I ~ Invrl sm r 1 I ICasl aG~~ ton [ , i~ sir 1 n r .~ol n n u s i.- rol r_a OF ~. ~E .,~ ~ 1 l ; ~ Tubing Stnngs ~ .. T L r _. F ,n GD I 1 ID 1 n t L,. h nM art Ilnl I,;~~ a ~~~,~~ C~c h IT, C~) llih Ci , Ins'RI I - li. tlr IoF I ~~n ,. ~~~ ~~ Com letron Detalts ~ ~~LL ~ 3 V e Too Ittl( l i Item c,ea~.~m~on ~ommem IL d..l xover 4,563.SjCENTRALIZER (Motor Centralizer ~_ ,~~„ ~ Perforations GAS LIFT, ~ iaP bun ~sna ~~ Top Btm (TVD) (TVD( ; Dens 3'~ ~ (RKB) (RKB( (RKB) I (RKB) Type Zone ilsho...l Date Comment ' ' ~ 4,628.0 4,664.0 3,643.2' 3,676.8iIPERf WS D, 10.133 ~ 12.0( 1/2(1998 RDX Charge; SOS 41/2" Ultrapak ., ~ j, 4,696.0 4,732.0 3,706.6' 3,740.2'1 IPERF I WS B, 10.133 ! 12.0 1/2/1998 RDX Charge; SOS 4 1Y2" Ultrapak~ ~, 4,786.0 4,828.0 3,790.6 3,8299 IPERf WS A4,WS A3 - 12.0 11211998 RDX Charge; SOS41/2"Ultrapak ', ~ , ~, 10.133 ~ ( ~, 4,866.0( 4,922.0 3,865.4 3,9178';IPERF WS A2, 1D-133 1/2/1998 (RDX Charge; SOS41/2"Ultrapak ; 72.0 Notes: General $, Safety cGAS uFr, 4,44s GAUGE CARRIER, 4,495 XO INTAKE, _ 4,527 ~~ NN?? f . . SEAL, 4,542 ~ r tt GEARBOX, - 4,555 MOTOR, 4,557- [[ `E. ~~... I :ENTRAUZER, 4,5$4 IPERF, _ , 4,62&4,fiW IPERF, 4,896-0,732 IPERF, 4,785-4,828 IPERF, 4,868-4,922 TD (t D-1 Set Depth , Vert ' Top ~! ITVDI ', Valve I Latch Size TRO Run I, Stn I (RKB( (RKB) I, Make ~! Motlel : OD Iin1 TYPe ! TYPe IIN Iwil ', Run Date Comment 1 D-133 Post Rig Well Work DATE SUMMARY 7/13/08 SET 3 1/2 TTC PCP T1800 ESP (32.06' OAL) @ 4527' RKB. SET 3 1/2 D&D PACKOFF ASSEMBLY W/ STINGER IN TOP OF PUMP @ 4496' RKB. (TESTED PACKOFF TO 1000 PSI ). SET 3 1/2 SLIP STOP IN TOP OF PACKOFF @ 4488' RKB. PULLED DGLV @ 4449' RKB AND SET 2000 PSI STS SOV. JOB COMPLETE. • • VV~LL•~ L ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ~~~E~ JUN `~ ~ 2048 Suite C Anchorage, AK 9951 S Fa~c (907j 245-8952 1) Caliper Report 2) 12zJun-08 1 D~133 1~~~26~ Signed Print Name r 1~,c;~ F, ~~~ r, Y Ia.~,~.~e~ 1 Report / EDE ~~C'D ~/~vc7 50-029-22827-00 Date __ .. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~'~ 7 ~_; ~~.,,_ ~ ,...: ,:r, WEBSITE ...:#,:~° :?~ ~~ ::_~ 6 C:\Docmnents and Settings\Ownec\Desktop\Tian+zcdt_Conoco.doc • • Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1D-133 Log Date: June 12, 2008 Field: Kuparuk Log No.: 8685 State: Alaska Run No.: 1 APt No.: 50-029-22827-00 Pipet Desc.: 2.875" 6.5 Ib. L-80 EUE 8rd Mod Top Log Intvl1.: Surface Pipet Use: Tubing $ot. Log Intvl1.: 4,485 Ft. (MD) Inspection Type : Pre- Rig Work Over Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the CAMCO SOV GLM @ 3,063' (Drlller's Depth). This log was run to assess the condition of the 2.875" tubing with respect to internal corrosive and mechanical damage to determine if tubing will be replaced during workover. The caliper recordings indicate that the majority of the 2.875" tubing is in good condition, with the exception of a 20% wall penetration in joint 138 (4,344'). The damage recorded appears in the form of Isolated Pitting. No areas of significant cross- sectional wall loss (> 10°~) or I.D. restrictions are recorded. A known leak in the tubing at GLM 2 (3,063') is indicated in the notes on the wellbore schematic. Critical analysis of the caliper data recorded through this GLM shows no internal features indicating a leak point MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting (20%) Jt. 138 @ 4,344 Ft. (MD) No other significant watt penetrations (>16%) are recorded. MAXIMUM RECORDED CROSS-SEC710NAL METAL LOSS No areas of significant cross-sectional wall loss (> 10%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded. ~~~ JUN ~ ~ ~a08 Field Engineer: K. Miller Analyst: HY. Yang Witness: C. Kennedy ProActive Diagnostic Services, Inc. / P.O. Bnx 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~umemorylog.com Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907) 659-2314 I cj ~ ~j(o ~6 ~/l0~ • • Correlation of Recorded Damage to Borehole Profile Pipe 1 2.875 in (-1.6' -4484.6') Well: 1 D-133 Field: Kuparuk Company: ConocoPhi9ips Alaska, lnc. Country: USA Survey Date: June 12, 2008 ^ A pprox. Tool De viation . A pprox. Borehol e Profil e 1 10 -2 286 20 602 30 918 40 ~ 1235 50 1552 6U 1868 ~ v -° 70 ~ '-' 2179 ~ c Z Y ~ 80 ~ 2490 v o p 90 2806 GLM 1 100 3139 110 3452 120 3768 130 4087 GLM 2 r- 140 4422 142 4485 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 142 • • PDS Report Overview 1 s. Body Region Analysis Well: 1D-133 Survey Date: June 12, 2008 Field: Kuparuk Tool Type: UW MFC 24 No.212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: HY. Yang Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 2.875 ins 6.5 f L-t30 EUE 8rd Mod 2.438 ins 2.875 ins 6.0 ins 6.0 ins Penetration and Metal loss (% wall) ~ penetration body ,-: metal loss body 100 80 60 40 20 0 0 to 1 to 10 to 1% 1t)% 20% 20 ro 40 ro over 40% 85% 85% Number of "oints anal se d rotal = 146 pene. 0 52 94 loss 56 90 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 7 7 0 0 0 0 Damage Profile (% wall) ~ penetration body o metal loss body 0 50 100 1 GLM 1 GLM 2 bottom of Survey= 142 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf L-80 EUE 8rd Mod Web: 1 D-133 Body Wall: 0.218 in Field: Kuparuk Upset Wall: 0.218 in Company. ConocoPhiiips Alaska, Inc. Nominal I.D.: 2.438 in Country: USA Survey Date: June 12, 2008 Joint No. Jt. Depth (Ft.) I'~~n. IllrsE~l (lnti.) Pen. Body (Ins.) Pen. % Vlcl.+I I~~ss `;~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 -2 (I 0.02 11 (~ 2.37 2 0 u 0.01 V 1 2.38 3 63 (1 0.03 I3 1 2.36 4 95 U 0.0 1 1 1 2.38 5 126 a 0.03 I _' I 2.36 6 159 U 0.02 & I 2.37 7 190 ll 0.03 1 Z i 2.37 8 222 tl 0.03 14 s 2.37 9 254 (I 0.0 10 2.37 10 286 (I 0.02 9 1 2.37 11 317 I~ 0.02 IU 1 7 12 349 I I 0.03 14 .39 13 380 ~ 0.02 11 ' 2.37 14 412 11 0.01 5 2.38 15 444 a 0.01 .5 ~ 2.38 16 475 tt 0.03 I2 t> 2.37 17 507 tl 0.02 t3 I 2.37 18 539 a 0.03 14 I tl 2.39 19 570 (I 0.03 12 _' 2.37 20 602 I> 0.01 1 .38 21 634 a 0.01 t> 2.38 22 666 a 0.03 1 ~ 2.38 23 698 U 0.03 14 1 2.37 24 729 tl 0.02 11 5 2.40 25 761 U 0.03 12 Z 2.37 26 792 U 0.01 1 2.39 27 823 U 0.03 1.1 ~1 .39 28 855 t) 0.02 11 I 2.36 29 887 l) 0.02 11 5 2.38 30 918 11 0.02 1 1 l 2.39 31 950 (I 0.02 8 1 2.38 32 982 (~ 0.02 11 1 2.38 33 1013 tl 0.03 11 5 2.39 34 1045 U 0.02 11 2 2.38 35 1076 (~ 0.03 14 1 2.37 36 1108 ~ ~ 0.03 14 ~1 2.39 37 1140 ~~ 0.02 11 ~ .39 38 1171 n 0.03 14 _' 2.37 39 1203 U 0.01 ~ I 2.39 40 1235 U 0.03 12 1 2.39 41 1267 () 0.02 11 ' 2.37 42 1298 tl 0.03 12 ~ 2.39 3 1331 U 0.01 4 I 2.39 44 1362 t) 0.02 1O I 2.38 45 1394 U 0.01 4 1 2.40 46 1426 tl 0.02 Ill I 2.38 47 1457 tl 0.03 14 tl 2.37 48 1488 (I 0.02 1 1 2.38 49 1520 (I 0.01 ~ 2.38 50 1552 tl 0.03 14 2.36 Penetration Body Metal Loss Body Page 1 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf L-80 EUE 8rd Mod Wel: 1 D-133 Body Wall: 0.218 in Field: Kuparuk Upset Wall: 0.218 in Company. ConocoPhilips Alaska, Inc. Nominal I.D.: 2.438 in Country: USA Survey Date: June 12, 2008 Joint No. Jt. Depth (Ft.) I'en. t_Jlse~t (Ins.) Pen. Body (Ins.) I'c~n. °i~ Me6il Luss "',~ Min. LD• (Ins.) Comments Damage Profile ~%wall) 0 50 100 51 1584 (~ 0.03 1 Z ? 2.38 52 161 t) 0.02 11 I 2.38 53 1647 U 0.03 14 t .37 54 1679 U 0.03 13 s 2.38 55 1711 !) 0.03 1 3 ! 2.37 56 1742 t) 0.03 14 2.37 57 1774 U 0.01 i I 2.38 58 180 U 0.01 4 1 2.3 59 1836 O 0.03 14 I 2.39 60 1868 U 0.03 14 1 2.37 61 1900 U 0.03 14 ~ .38 62 1932 U 0.03 I4 2.36 63 1960 i) 0.03 14 ~ .35 64 1991 (? 0.03 1 ' I 2.35 65 2022 c) 0.02 I I I 2. 5 66 2054 a 0.02 11 a 2.39 67 2086 t> 0.03 13 I 2.37 68 2117 a 0.0 1 t) _' 2.36 69 2149 t) 0.03 I4 ~ 2.37 70 2179 t) 0.03 14 I 2.37 71 211 a 0.02 1 1 1 2.35 72 2242 U 0.03 14 1 2.37 73 2273 fl 0.02 ~) 1 2.38 74 2305 a 0.02 11 ? 2.38 75 2336 U 0.02 11 1 2.37 76 2368 U 0.02 ti 1 2.38 77 2398 t) 0.02 11 1 2.36 78 2428 ~) 0.01 4 ~' 2.35 79 2460 ! ~ 0.01 5 1 2.36 80 2490 it 0.03 12 ! 2.37 81 2522 ~) 0.02 6 2.38 82 2554 i~ 0.02 1(1 I 2.38 83 2585 U 0.02 1 U I 2.37 84 2616 a 0.02 It) 2.39 85 2 648 t t 0.02 1 t) I 2.38 86 2680 t) 0.02 I I Z 2.39 87 2712 t) 0.01 5 I 2.35 88 2743 O 0.01 7 ~' 2.37 89 2775 U 0.02 11 2.37 90 2806 tt 0.02 11 t 2.38 91 2837 t) 0.02 I I I 2.39 92 2869 U 0.01 r~ _' 2.38 93 2901 i ~ 0.03 14 I 2.36 94 2932 c) 0.02 ~) E~ 2.38 95 296 U 0.03 13 ~~ .36 96 2994 t1 0.02 11 ! 2.38 97 3026 t) 0.03 16 ~ 2.38 Shallow itfin . 97.1 3057 t) 0.03 12 2.37 PUP 97.2 3063 11 0 (1 t) N A GLM 1 Latch 4:30 97.3 3071 i) 0.02 ~) [> 2.39 PUP Penetration Body Metal Loss Body Page 2 • PDS REPORT JOI NT TABULATION SHEET Pipe: 2.875 in 6.5 ppf L-80 EUE 8rd Mod Wel: 1 D-133 Body Wall: 0.218 in field: Kuparuk Upset WaU: 0.218 in Company. ConocoPhilips Alaska, Inc. Nominal I.D.: 2.438 in Country: USA Survey Date: June 12, 2008 Joint No. Jt. Depth (Ft) I'c•n. 111„ei (Ins.) Pen. Body (Ins.) Pen. %~ Me~~l I~» °~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 98 3077 O 0.02 1t) I 2.38 99 3108 t) 0.02 1 U I 236 100 3139 t) 0.01 4 ~' 2.38 101 3171 l~ 0.01 5 ! 2.39 102 3202 U 0.01 4 3 2.35 103 3232 U 0.03 I Z ) 2.38 104 3263 U 0.03 14 ~ 2.37 Shallow itU 105 3295 O 0.03 12 Z .36 106 3326 t) 0.01 5 1 2.38 107 3358 C) 0.01 5 1 2.38 108 3389 0 0.03 13 1 2.39 109 3421 0 0.02 11) _' 2.37 110 3452 U 0.02 1 t1 2.37 111 3483 O 0.02 11 2.37 112 3515 a 0.01 I .39 113 3547 U 0.03 12 2.29 Lt. De sits. 114 3578 O 0.04 I6 ~ 2.33 Shallow ~ttin Lt. De sits. 115 3610 U 0.03 14 t9 2.38 Lt. De sits. 116 3642 t) 0.03 14 i 2.38 117 3674 t) 0.03 12 ~ 2.36 118 3706 a 0.02 10 2.3 119 3737 i) 0.03 13 -l 2.37 120 3768 ~? 0.03 11 5 2.37 121 3800 U 0.03 1.5 -1 2.37 Shallow itUn Lt. De sits. 122 832 U 0.03 15 ~ Shallo i Un 123 3864 t) 0.04 16 Z 2.38 Shallow ittin . 124 389 O 0.03 12 1 2.36 125 3928 t) 0.01 4 I 2.39 126 3960 U 0.03 11 ( .37 127 3992 (? 0.03 I ~ 2.36 Lt. De sits. 128 4024 t? 0.03 I Z 2.35 129 4055 (? 0.03 I.1 -t 2.37 130 4087 O 0.02 1 1 -4 2. 7 131 4119 ~ ? 0.02 ~~ t 2.36 13 4151 a 0. 2 f3 5 2.37 133 4183 t? 0.02 11 I 2.35 134 4214 U 0.02 t l I .36 135 4245 t? 0.02 IO ! 2.35 136 4277 t) 0.03 14 <4 2.38 137 4308 O 0.03 13 -1 2.37 138 4340 U 0.04 ZU 5 2.36 Isolated "ttin 139 4371 O 0.03 12 1 2.37 Lt De sits. 139.1 4403 (? 0.02 1 U 3 5 PUP 139.2 4409 U 0 O O N A GLM 2 Latch ~ 2:30 13 .3 4416 ~) 0.02 1 1 I 2.37 PUP 140 4422 ~? 0.03 1-1 2.29 Lt. De sits. 141 4454 U 0.02 I 1 2.29 Lt. De its. 142 4485 U 0.02 s3 237 _ Penetration Body Metal Loss Body Page 3 ~~ S PDS Report Cross Sections b'Vell: 1D-133 Survey Date: June 12, 2008 Field: Kuparuk Tool Type: UW MFC 24 No.212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 2.875 ins 6.5 f L-80 EUE Srd Mod Anal st: HY. Yan Cross Section for Joint 138 at depth 4344.333 ft Tool speed = 43 Nominal ID = 2.438 Nominal OD = 2.875 Remaining wall area = 99 Tool deviation = 23 ° Finger 2 Penetration = 0.044 ins Isolated Pitting 0.04 ins. = 20% Wall Penetration HIGH SIDE = UP • • Cross Sections page 1 . ~. ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 29,2006 NIr. Tom Maunder SCANNED JAN 1 6 2007 Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 1./'J..o(P \C\ Dear NIr. Maunder: 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 by surface casing annulus. The voids were fIrst filled with cement to a level of approximately 1.0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG2401 that was 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 top-fill operation was completed on December 16, 2006 and the sealant top was completed on December 27,2006 for IH-Pad and December 28, 2006 for 1D-Pad. Schlumberger Well Services mixed 15.7 ppg Expando cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The 2401 sealant was pumped in a similar manner. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~-/cO~ Jerry Dethlefs ConocoPhillips Problem vVells Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 12/29/2006 Initial Top Cement Final Top Sealant Well Name PTD# of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date 1 H-O 1 193-006 12" na 12" na 7.4 12/27/2006 1 H-02 193-008 21'4" 2.9 14' 6" 12/16/2006 na na 1 H-1 0 193-030 4' na 4' na 29 12/27/2006 1 H-11 193-036 Surface na Surface na 1 12/28/2006 1H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1 H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1 H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1 H-18 193-020 14'4" 2.7 12" 12/16/2006 7.4 12/27/2006 1 H-21 193-046 4" na 4" na 2.4 12/27/2006 1 H-401 198-101 45' 4.4 18" 12/16/2006 20.1 12/27/2006 1 0-1 09 197-235 10'9" 2.1 12" 12/16/2006 10.8 12/28/2006 10-110 200-039 8'6" 1.4 10" 12/16/2006 9 12/28/2006 10-111 198-166 17' 7" 3.4 25" 12/16/2006 21 12/28/2006 1 0-120 197-221 13'6" 2.9 18" 12/16/2006 16 12/28/2006 10-121 197-181 13' 2.2 20" 12/16/2006 16.2 12/28/2006 10-132 198-121 10'8" 2.0 14" 12/16/2006 11 12/28/2006 10-133 197-206 6' 1.0 6" 12/16/2006 4.6 12/28/2006 10-136 200-046 10'2" 2.0 10" 12/16/2006 6.4 12/28/2006 10-137 200-047 11 ' 2.00 24" 12/16/2006 13.2 12/28/2006 1 0-138 200-048 11'7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 1 0-139 200-049 11'2" 2.2 18" 12/16/2006 9.9 12/28/2006 1 0-140 200-136 29'9" 3.4 12" 12/16/2006 na na 1. Operations Peñormed: Abandon 0 Repair Well 0 f~.(J'# Plug Peñorations 0 Stimulate 0 Oth~\íl.o"'" TI Alter Casing 0 Pull Tubing 0 \,. Peñorate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownD Peñorate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development _ 0 Exploratory 0 1972060 . 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360 50-029-22827-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 111' 10-133 8. Property Designation: ,/J> /1. 7'0tø 10. Field/Pool(s): Kuparuk River Unit AI> <- ¡. 'S"" S" 0 Kuparuk River Field 1 West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5265' feet true vertical 4239' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical 6276' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' PROD. CASING 5138' 7-5/8" 5249' (::-~K:,. U(,F' C} ¿, (:. ~ Perforation depth: Measured depth: 4628-4664,4696-4732,4786-4828,4866-4922 v""',, true vertical depth: 3643-3677,3706-3740,3790-3830,3865-3918 Tubing (size, grade, and measured depth) 2-7/8", L-80, 4462' MD. , Packers & SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation n/a n/a n/a n/a n/a Subsequent to operation n/a n/a n/a n/a n/a 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 306-327 Contact Jerry Dethlefs/MJ Loveland @ 659-7043 Printed Name MJ LOV~ Title Well Integrity Supervisor Signature ~ ~ Phone 907-659-7224 Date 10/26/06 Pr",nared bv Sharon Al/slln-Drake 263-4612 /' /t'.7·Ob RECE\VED OCT 3 1 2006 ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TICä&6 Oil & Gas Gons. . STATE OF ALASKA . Form 10-404 Revised 04/2004 RBOMS 8B {.j .~ 2006 OR\G\NAL .t-\t(~ ~þ Subm~inal ~n!x ",,¿::;.- /1 /? /t?ð . 1 D-133 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 10/17/2006 Cut & removed 3'2" of conductor for inspection of SC. Found conductor full of gravel, gravel at cut depth. Top of cement unknown. 10/22/2006IWrap SC w/denso after UT results confirm pipe is still in working pressure spec. 10/25/2006 Weld patch on Conductor total patch length was 71 1/4" production casing has been wrapped with dense I tape also landing joint hanger to conductor top has had carboline paper wrapped. Repaired piece of 16" 6.25# AP.I. 5L Gr.B Conductor. ,/ 11/02/2006 15:52 9076597~ .. NSK WELLS GROUP PAGE 02 -..-...-~. ~~ @~,Ã=! @ _ fl, '- b ~ F !A~1~~~1 FRANK H. MURKOWSI(I. GOVERNOR ~ AT,ASRA OR AlQ) GAS CONSERVATION COMMISSION aaa w. f1'" AVENU5, sun!: 100 ANCHORAGE, ALASKA 99501-3589 ÞI-IONe (907) 279-1-1S3 FAX (907) 276-7542 Roger Winter Problem Well Supervisor ConocoPhillips A1aska~ Inc. PO Box 100360 Anchorage~ AK 99510 ~o NO\! () 2 ,DUB Re: Kuparuk River Field, West Sale Oil Pool, ID-133 Sundry Nwnber: 306-327 '\010 C~:'( 0- \ . Dear Mr. Winter: Enclosed is the approved Application for Sundry Approval relating to the a.bove referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission~s petroleum. field inspector a.t (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decisionj or such further time as the Comnússion grants for good cause shown, a person ,affected by it may file with the Commission an application , for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day 'if the 23rd day falls on a holiday or weekend. A person may not appeal a Comnússion decision to Superior Court unless . rehearing has been requested. Sincerely, EncJ.. ~~9/25/2006 12:43 9076597. ~EL~ Z~ ~t, PAGE 03 IV' J '/~, RECEIVED .~ STATE OF ALASKA '-:f{ SEP 2 5 2006 ALASKA OIL AND GAS CONSERVATION COMMiSSiON APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons. Commission 20 MC 25.280 Anchorage 1. Type of Request: Abandon 0 SUS)~nd 0 Operation Shutdown 0 Porfol'8\e 0 Waivér 0 Annl.lb¡¡r Olap. 0 Alter CIIslng 0 Repair weU 0 Plug PerfclBtions 0 Stlml.llate 0 Time Extension 0 Other 0 cnango approved progn¡¡m 0 Pull Tubing D Perforate New Pool D ~e-enwr Sl.Ispended Well 0 2. Operator Name: 4. CUrrent Well Cl3Œ(' õ. Permit to Drill Number: ConocoPhilli~ Alaska, Inç.. Development _ Explol'8lòry 0 1972060 3. Address: Sttali;~phÎÇ 0 Servlœ ~. 6. API Number: P. O. Box 100360 50-029-22827-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 111' 1D-133 8. Property DeslgnátiOn: ,P> c:r'~.o, 10. i=leld/PooI(s): Kuparuk River Unit AI:> c... ~S'"~'ò Kuparuk River Field I West Sak 011 Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD {II}: Effective Depth TVD (ft): Plugs (measured): JUnk (meeeured): 5265' . 4239' . Casing Lengttt saz:ø MD TVO Burst CoJlepse CONDUCTOR 121' 16~ 121' PROD. CASING 5138' 7.sIB" 5249' PerforatlOfl oeptl'l MD (ft): Perforation Depth TVO (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 462S-4ee4.4age-473:õ1,47B8..4ð:;¡a,4SSS..4922 3643-3677.3706-3740.3790-38JO,3865-391 B 2-7/8" L·80 4462' Par;l<el'$ S"d SSSV Type: Packers and SSSV MD (ft) no packer no SSSV no SSSV 12. Attachmenls: Description Summary of Proposal 0 13. Well Class after pl'Oøosed work: Þ q.z.g,o(. Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development [?( Service ~ 14. Estimated Date for 15. Well Status after proposed work; Commencing Operations: 011 0- Gas 0 Plugged 0 Al;)a.,doned 0 16. Verbal Approval: Dale: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Represe"tative: 17. I !'Iere\)Y certify that the foregoing Is true and correct to the best of my knowledge_ Contact: MJ Loveland/Jerry Dethlefs Printed Name ß. Roaer Wint.!r Title: Problem Well Supervisor Signature EZ., X r ~ phone 659-1043 Date 9120/06 Commission Use Onlv 5und~ ~~r: ConditIons of approl/al: Notify Commi$SÎon so that a representative may witness r"." g~Î Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 LocaUon Clearance 0 Other: y\.'\(.~ ~ÖC~\M..Jè.d'-....~o..\\ a '" 0 (¿\\ b ~~ \<C s;:- Ck. ~ ~ tr \-<t.~' t ~~ ~\\Q,? \JC>....~0 ~5Ibl.' s.......~ RBDMS 8Ft SEP 2 9 2006 ""'''1'''''' F.... ....',...., U 0 CZ..l1 rÐ' A,,,",,"d '" ~ 'fi ~OMM'SSlONeR BY ORDER OF THE COMMISSION Date: Form 10-403 Revised 1212!J RilS'N!, ~~T::$ ON REVERSE .4> f·¿S06 Submit In Duplicate ~ 16zs¡b6 11/02/2006 15:52 9076597~ . NSK WELLS GROUP B9/25/2EJÐ6 12:43' 907659·13i4 NSK WELLS GRû , ,-,' ! PAGE 04 PAGE 02 Conocc;J:PhiUips Alaska, Ine. Kuparok We)) ID-133 (pTD 1.97-206) ST]NDRY NOTICE 1. 0-403 APPROVAL RBQU£ST Sept.e-mbet 20, 2006 This 8:pptication for Sundry approva.l for Kuparuk wel11.D-133 is to extMd the conductor to .... ____. . . (¡n.i:gil1~-height"'sQ-as-tQ-pt'@.v~¡t-an.y-futtb.$t'-¢ogos.io.n-tO-SC..-This-we.lWs..a..si:ngle-casing :produc.er_ .~- It was completed in November 1997 and is cucrently on line. At so,mc point during nonnaI operations the conductor. subside~ about 4~ to 5~. Wit1:! a.pproval, the cond.uctor extension will requirc the fo1J.owi.ng general steps: 1. Ren1oV'e land,ng ring from conducto:r. ;2. ~1(amine SC below where landing ring was for auy cot,TOsion. da1nage. 3. T.osta11 anti.-corrosion coating o:n se as specified by CPAI Corrosion Engineer. 4. Extc:nd tbe conductor to braden head and .fi.n the void 'With cement and top off With sealant. S. :PUe 1 O~404 with the A OGCC post repair. NSK Problan WI;I1 Sup~rvi~or 05/0 7/05 11/02/2006 15:52 09/25/2Ð06 12:43 I, 9076597?" <1 9lõ7659-(;--1, ( NSK WELLS GROUP NSK WELLS GiRO' PAGE 05 PAGE 131 1-"" r" . "'\ .......... ...~~ ÞO ratóx 100380. N$S<: 00 AMi'1orage\ AI( 99510 ConocoPhilljps Alaska, Incpt Fax .F~ECEiVfEÜ ~:E? ,~; t~: ~008 frcnm ·:~J[t$P.~ (;;1 ç. f':! ,., ,-~3~ r.:! :~~r......,... '~" . _.___...___----"-'--"'~- ~."~~.¡.....,;¡~<-..,-~- ... ~'J". .~ ,,~ . .' ~<', . :, ~ ¡lp1s~,:r~f.m .J'~:8;q1 jj]f.'tiq¡Jj _, ~_ _________.............J~..- ..__--'-----.__ _.___ _..__ .---------..... ".- ~-- Tac Tom Maunder Roger Winter Pax~ 276--7542 ~gen= 2 __' .._I.AI. ,. a., ...,...- -.. Ph£Jne=' 793-01250 Date: 912012Q06 .. I. ".._1" _.N· '1/__0 Re~ 1 D"133 Conductor Extension çc= ,..... ,~..~-' ..r....v'J o UIVent o For Rm.ri8'W f:I PIe89ê CaM~nt X Please Reply o PlftaM 'kH:ycle .. .-.. -- ..... - .. ~-_. --.', VWWUIfl' Tom: Attached is a 10-403 for West Sak well 1 D~ 133. The request is for approval to extend conductor back to oríginal tJefght. tn January 2000 PWS Supv (MJ Loverand) contacted you by e--mail about the conductor subsiding. We would nke to extend the conductor & fill w/œment to provide well héad suøøort ~nd protect the surface casing from the efements. With approval it is our intent to work in OctOber. which could be within the next couple of weeks. ExPediting your approvalls appreciated. Plaasa note I am faxl ng one copy Of th~ package. Please let me know rf you have any questions. Roger Winter ConocoPhiflips Alaska, Inc. Office# 659..7506 CeU# 943-1055 ) ) Jim Ennis Wells Group Engineer Drilling & Wells ConocóPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1544 January 19, 2006 R~C 'E/~D JAN 2 0 'OlaQ · 2006 II Cons P ,lIft_,iI . bGr~' 'r"!IfqOlBfe "It 1 ì1SSiof Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Reports of Sundry Well Operations for 10-133 /I / <JO(P \0\ \ Dear Commissioner:' ConocoPhillips Alaska, Inc. submits the attached Reports of Sundry Well Operations for the recent workover on the West Sak well 1 0-133. If you have any questions regarding this matter, please contact me at 265-1544. Sin~erel .. ,.. ~ --' ,......~"" J. Jln's W~~ Group Engineer CPAI Drilling and Wells A~'11 (2;~ '1\ 'In(~h ~ f~~ !\:,;;;,',,' tf, 'J 1\ , ". 1'\1 ,\..; f_,., , ~ ~CA\Nß~t£:;.t!)J ,~þ h ~," JE/skad RECEIVED -) ) JAN 2 0 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERA TIO~~ Anchorage Abandon D Repair Well 0 Plug Perforations D Stimulate D Other D Alter Casing D Pull Tubing 0 Perforate New Pool D Waiver 0 Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 197-2061 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22827-00 7. KB Elevation (ft): 9. Well Name and Number: RKB41', Pad 71' 10-133 8. Property Designation: 10. Field/Pool(s): AOL 25650, ALK 468 Kuparuk River Field 1 West Sak Oil Pool 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR PROD. CASING Perforation depth: measured 5265' feet true vertical 4239' feet measured 5122' feet true vertical feet Length Size MD 80' 16" 121' 5208' 7-5/8" 5249' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 4224' Measured depth: 4628'-4664',4696'-4732',4786'-4828',4866'-4922' true vertical depth: 3643'-3677',3706'-3740',3791'-3830',3865'-3918' Tubing (size, grade, and measured depth) 2-7/8", L-80, 4475' MD. Packers & SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable R8DMS 8Ft .IAN 2 0 2006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation SI Subsequentto operation 416 41 449 231 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Printed Name Signature Jim Ennis @ 265-1544 ~iS Title Phone Wells Engineer C~ 071 J ~ 5' - I)' ~ I 1-\ r;:::md b, L; l~:ke 263-4'" o~\G\~f\l Form 10-404 Revised 04/2004 Submit Original Only ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/28/2005 00:00 - 02:00 02:00 - 04:00 04:00 - 05:00 05:00 - 11 :00 11 :00 - 14:00 14:00 - 16:00 16:00 - 18:00 18:00 - 20:00 20:00 - 21 :00 21 :00 - 21 :30 21 :30 - 22:30 22:30 - 00:00 11/29/2005 00:00 - 05:30 05:30 - 10:00 10:00 - 14:00 WEST SAK 1 0-133 10-133 WORKOVER/RECOMP Start: 11/28/2005 Rig Release: 12/5/2005 Rig Number: Spud Date: 11/14/1997 End: Group: Nabors 3S '···Suþ' Hours . COde 'Cod~ Spot rig over 1 D-133 and rigging up Raise Derrick continue to rig up Pull BPV and rig up to Kill Well. Accept rig @ 04:00 AM on 11/28/2005 Kill well pumping down the IA and up the tubing. Well had 700 psi on IA and 400 psi on tubing. Pumping hot sea water with 3% KCL @ 2.5 bpm holding 500 psi on tubing. Filling pits with 240 bbls of SW with 3% KCL 3.00 WELCTL OBSV DECOMP Well is holding 225 psi tubing and IA monitoring well 2.00 WELCTL OBSV DECOMP Continue to monitor well pressure dispose of sea water and ordered 450 bbls of 9.8 ppg Sodium Chloride brine. Rig up ESP and heat-trace spoolers. 2.00 WELCTL KILL DECOMP Kill well with 9.8 ppg brine down the tubing up the IA @ 4 bpm. 2.00 WELCTL CIRC DECOMP Shut down, blow down kill line to tanks, monitor pressures. DP=70 psi, cp=70 psi. Begin circulating a hole volume at 4 bpm, holding 70 psi backpressure at the choke. Brine inlout is 9.7# hvy. 1.00 WELCTL OBSV DECOMP Shut down; 100 psi csg and dp, 15 bblloss. Pressures slowly falling. Confer wi Mud Engineer I Wells Engineer regarding options if we weigh up. 0.50 WELCTL OBSV DECOMP Pressure has fallen to 20 psi on csg, 10 psi on dp. Open up and bleed off. Well appears dead. Proceed forward wi installing BPV. Begin nippling down tree, install test plug, and NU BOPE stack. Cont. NU BOPE. Begin BOPE testing, function and PT BOP rams and choke manifold to (250/3000) psi annular to 25012500 psi. AOGCC Chuck Sheave waved witnessing test. 4.00 WELLSR RURD DECOMP Dig mouse hole with SS set mouse hole in place. LD test jt, blow down all lines. Pull test dart, & BPV, well on small vacum. Installed isolation sleeve & MU landing jt. RU sheaves for ESP cable and heat trace. BOLDS. DECOMP PJSM with all involved in pulling ESP. DECOMP Attempted to pull hanger w/2-7/8" landing jt. Pulled 125K with no movement. DECOMP LD 2-7/8" landing jt. PU 3-1/2" landing jt and elevators. Pulled hanger free @ 152K. Pullled to rig floor. Removed penetrators from hanger. Filled hole with 14 bbls. DECOMP Begin pulling pipe, standing back in the derrick. DECOMP 6 stands out, slow going spooling heat tracelpower cable & cutting bandslremoving channel. DECOMP Well drinking approx. 15-20 bblslhr. Discuss lightening mud wgt. wi Wells Engineer. Decide to lighten up from 9.7 to 9.6. Call out fluids. DECOMP Fluid in truck I pits cut to 9.6#; begin circulating in at 4 bpm. Note: 70 bbls total brine lost to formation. DECOMP ¡Well Continue out of hole with old completion. Well losing 4-5 bbls I hr. DECOMP : Spooled up all of heat trace, removed spooler, cable guards and bands i from rig floor. Continued to pull out of hole, strapping and drifting with : remainder of completion to ESP pump. . DECOMP Disconnected ESP cable at motor, spooled up to end on spooler. Broke down ESP equipment and LD. Collected and counted all bands, flat cable guards and clamps. Cleaned rig floor. Preped to run RBP & packer. Well losing 5-6 bbls/hr. WRKOVR Install wear ring. MU and RIH with RBP and test packer. WRKOVR . Continue in hole with test packer and RBP. . WRKOVR Set RBP at 4526' orig. RKB. Fluid loss 3-4 bbfs/hr. 2.00 MOVE RURD MOVE 2.00 MOVE RURD MOVE 1.00 WELLSR PLGP DECOMP 6.00 WELCTL KILL DECOMP 1.00 WELLSR PLGM DECOMP 1.50 WELCTL NUND DECOMP 5.50 WELCTL NUND DECOMP 4.50 WELCTL BOPE DECOMP 14:00 - 14:30 0.50 WELLSR SFTY 14:30 - 15:00 0.50 FISH PULL 15:00 - 16:00 1.00 FISH PULL 16:00 - 18:00 2.00 FISH PULL 18:00 - 21 :00 3.00 FISH PULL 21 :00 - 23:00 2.00 WELCTL COND i 23:00 - 00:00 1.00 WELCTLJ CIRC I I 1 11/30/2005 100:00 - 07:00 7.00 FISH !PULL : 07:00 - 12:00 5.00 FISH ¡PULL '12:00 - 16:00 4.00 FISH ·PULL I 16:00 - 18:00 2.00 WELLSR PULD 18:00 - 23:00 5.00 WELLSR TRIP 23:00 - 00:00 I 1.00 WELLSR PLGM I Printed: 1/6/2006 2:39:51 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WEST SAK 1 0-133 10-133 WORKOVER/RECOMP Nabors 3S Date .:, ,.,., 'F',','ro· m', ',,"': "T" 0' " H;, .,'ou" ,'rs ""~,',·o.','"d"e' ,Sub Pha 'e' v ¢ode ,;:. ',"g' ',: 12/1/2005 00:00 - 02:00 2.00 WELLSR DEQT WRKOVR 02:00 - 03:30 1.50 WELLSR TRIP WRKOVR 03:30 - 06:00 2.50 RIGMNT RGRP WRKOVR 06:00 - 09:30 3.50 WELLSR TRIP WRKOVR 09:30 - 10:00 0.50 WELLSR TRIP WRKOVR 10:00 - 13:30 3.50 WELLSR TRIP WRKOVR 13:30 - 19:00 5.50 WELLSR TRIP WRKOVR 19:00 - 21 :30 2.50 WELLSR PULD WRKOVR 21 :30 - 22:30 1.00 CMPL TN SFTY CMPL TN 22:30 - 00:00 1.50 CMPL TN PULD CMPL TN 12/2/2005 00:00 - 01 :30 1.50 CMPL TN RUNT CMPL TN 01 :30 - 02:15 0.75 CMPL TN RUNT CMPL TN 02:15 - 05:30 3.25 CMPL TN RUNT CMPL TN 05:30 - 10:00 4.50 CMPL TN RUNT CMPL TN 10:00 - 13:30 13:30 - 18:00 3.50 CMPL TN[ TRIP 4.50 CMPL TN OTHR i CMPL TN CMPL TN 118:00 - 20:00 2.00 CMPL TN: RUNT CMPL TN 12/3/2005 : 20:00 - 22:00 ; 22:00 - 00:00 00:00 - 03:30 2.00 I CMPL TNi RUNT CMPL TN 2.00 I CMPL TN RUNT CMPL TN 3.50 CMPL TN RUNT CMPL TN 103:30 - 04:00 0.50: CMPL TN RUNT CMPL TN Start: 11/28/2005 Rig Release: 12/5/2005 Rig Number: Spud Date: 11/14/1997 End: G rou p: ;:p~scti ption: pf' pperatio hs RBP set at 4526' orig. RKB wI 2000 ftllbs torque (30k up wgt, 25k dn). Test and chart 7-5/8" csg to 2500 psi, hold for 30 mins. Good test- 30 psi drop 30 mins. Release RBP with 1600 ftllbs torque and rand down 10' past where plug was set. Fluid loss 3 - 4 bbls/hr. Pull out of hole with test packer and RBP. Cut I slip drill line. Resume pulling out of the hole with test packer and RBP. Landed test packer but DID NOT retrieve RBP. Monitor well fluid losses 3-4 bblslhr LD test packer, broke out retrieving head. MU on 2-718" tubing to RIH and retriev the Model"G" Lock-Set RBP. Run back in hole, Up wt =30K Dwn wt = 25K, did not see RBP until top of screen @ 4565'. Latched onto RBP picked up 30' with small increase in wt. Up wt = 32K Dwn wt = 25K. Set RBP to confirm we were latched on. Unset RBP and lowered back down. All indications are we have latched onto RBP. Turn all tools around start pulling out of hole drifting tubing and standing back in derrick. At surface; break out RBP and retrieving tools; lay down. Pull wear ring. Prep to run new 2-7/8" ESP completion. Rig up cable from spooler over sheave to rig floor, clean up rig floor. Conduct prejob safety meeting Begin making up motor; find Centrilift doesn't have a cross-over to get from centralizer back to motor. Swap new bottom coupling with that of old completion in order to make up to centralizer. Make up motor and begin servicing same. (1.5 hrs lost time due to Centraliftlthread issue making up centralizer). Running new 2-7/8" completion; making up motor and pump. Centrilift missing other crossover from pump discharge to tubing (3-1/2" 8rd x 2-718 8rd EUE). Shut down again while Centrilift Rep goes to Milne Point to look for one. Resume making up motor I pump. Begin servicing same. Offload 100 bbls more 9.6# brine. Make upGuardian Double BHP gauge on top of first full jt. above pump, one jt and GLM. RIH to 1250' stop, check electrical continuity on ESP cable and Guardian BHP Guage. ESP cable test good, Guadian BHP guage showed short. Pull out of hole up to Guardian BHP Guage. Disconnect 'Y' Splice to guage and found top 'O-ring' leaked had water inside. Disconnect 'Y' splice and double Guardian Guages. Install single Guardian Guage and re-splice. Re-spliced 3 times before guages I checked out good. I Resume running in hole with ESP completion. Installing ¡ clampslbandslchannel per procedure. Torquing same to 1600#. I Checking gauge every 500', meg'ing heat trace and power cable every l1000'. Heat trace started at 2935' between stands #23 and #24. . Continue in the hole with completion Continue running in the hole with new completion. Attaching channel, clamps, bands per procedure. 97 bbls fluid lost to formation in last 24 , hrs. Tag up 10' in on stand #34, set down 4k# over. Possibly have a clamp hanging up in the stack. Drain stack to get visual. Everything looks clear/centered. Begin working pipe in attempt to clear Printed: 1/6/2006 2:39:51 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WEST SAK 1 0-133 10-133 WORKOVER/RECOMP Nabors 3S Hours Code SUb ., .' Phase: Code 12/3/2005 03:30 - 04:00 0.50 CMPL TN RUNT CMPL TN 04:00 - 05:00 1.00 CMPL TN RUNT CMPL TN 05:00 - 07:00 2.00 CMPL TN RUNT CMPL TN 07:00 - 08:30 1.50 CMPL TN RUNT CMPL TN 08:30 - 10:00 1.50 CMPL TN NUND CMPL TN 10:00 - 00:00 14.00 CMPLTN NUND CMPL TN 12/4/2005 00:00 - 03:00 3.00 CMPL TN NUND CMPL TN 03:00 - 07:00 4.00 CMPL TN DEQT CMPL TN 07:00 - 09:00 2.00 WELLSR NUND CMPL TN 09:00 - 14:30 5.50 WELLSR NUND CMPL TN 14:30 - 15:00 0.50 WELLSR NUND CMPL TN 15:00 - 18:00 18:00 - 21 :00 3.00 WELLSR NUND CMPL TN 3.00 CMPL TN SEQT CMPL TN 21 :00 - 23:00 , 2.00 i WELLSR PLGM CMPL TN 23:00 - 00:00 1 1.00 WELLSR PLGM CMPL TN 12/5/2005 , 00:00 - 02:00 ' 2.00! WELLSR PLGM ,CMPL TN '02:00 - 06:00 4.00 MOVE DMOB MOVE Start: 11/28/2005 Rig Release: 12/5/2005 Rig Number: Spud Date: 11/14/1997 End: Group: ··D~scriþ~ionof pp~ratior1s shoulder/whatever is hanging us up. Pop past with 7K over. Whatever is hanging us appeard close shallow. Run stand in hole and meg cable, check gauge. Everything ok. Discuss. Repeat with stand #35, same results, popped through with 8-10k DN. However see slight overpull (5K) while working up/down. Offload 110 more bbls 9.6# brine (wi 3%KCL) into pits. Pick up next stand and begin in hole, offset clamps 30 deg from previous running position. Tag up roughly same place on this stand as last. "Drop" past again. Discuss further. Unable to spin clamps further due to I-Wire. Cont. in hole. Tag up in roughly same spot on this stand as previous two (20' in on stand #36). Meg cables, test gauge again- verify good. Drain stack and look again...everything is centered as well as possible. Discuss with Wells Engineer. Review drilling records and find they had to rotate to get through suspected problem areas in 5 deg doglegs. Rotate pipe 1/4 turn to get past tight spot. Continues to bobble at same place on each stand but not as bad. LaSalle clamps hanging at dogleg at approx. 2146'. Same as original completion. Meg cable and check BHP gauge, OK. Continue to run in hole slow stopping to check cable and BHP guage every 500'. Install side port iso sleeve. Pick up hanger, orient, install penetrators. Test cables I BHP gauge- good. Cut cables and spool over sheaves; rig out of way. Begin making splices. Continued. Making up ESP I heat trace spices. Fluid losses last 24 hrs = 82 bbls. Splices complete; test; heat tracelpower tested. Gauge not functioning. Begin troubleshooting; pull apart splice and re-examine. Centrilift hand going to look for another splice kit. Re-spliced BHP guage. Rechecked all connections, good to go. Up wt.= 42K Dwn wt = 34K, Land tubing. Check orientation of hanger in wellhead. RILDS. Back out landing jt. Remove side port isolation sleeve. Install BPV. Pressure test hanger voidlpackoff to 5000 psi. RD cable spooler, sheaves, LD 1 stand from derrick. Pulled mouse hole. Change pipe rams from 2-7/8" to 3-1/2". ND BOPE. Checked ESP cable and Heat Trace cable electrical integrity. Re-check BHP guage, everything checked out good. I NU tubing adapter and 5M tree. Having difficulties getting tree to test. Order heater and warm up cellar I tree. Re-tighten bolts with sweeney...its having problems due to cold as I well. Tighten up with hammer wrenches. Perform void test to 5000 psi; I initial drop to 4950 psi, then held solid for 30 mins. Pull BPV, install 2-way check. Test tree to 5000 psi- good. 1 Attempt to pull 2-way check with lubricator, appear to be tagging up 6" high with running tool. Get visual through side port...everything appears ,clear. Dump 1 gal tanner gas on top of 2-way check. Put heater back on hanger profile. Discuss options. Vetco hand called to DOY 141 to run completion. Call AES valve shop foreman and ask for assistance. Ongoing. Call out AES Valve Shop to pull 2-way check and install BPV. Rig up lubricator, pull 2-way check, install BPV. Rig down their equipment. Release rig at 02:00 am, 12/05/05. 1 Prep rig to move; begin moving to 1 D-131. Printed: 1/6/2006 2:39:51 PM Co'nocoPhillips AlasJa, Inc. t[)":133 TUBING (0-4475, 00:2.875, 10:2.438) Discharge Head (4475-4476, 00:5.130) Pump Intake (4485-4486, 00:4.500) LOWER ESP (4476-4499, 00:4.000) SEAL (4486-4500, 00:5.125) ESP MOTOR (4500-4512, 00:5.625) GRAVEL PACK (4564-4930, 00:6.490) Perf (4628-4664) Perf (4696-4732) Perf (4786-4828) Perf (4866-4922) ]',I[ I.", ' ,,::I.,' ) KRU 1)·133 API: 500292282700 SSSV Type: NONE Well Type: PROD Orig 11/22/1997 Completion: Last W/O: 12/4/2005 Ref Log Date: TD: 5265 ftKB Max Hole Angle: 59 deg @ 2811 Angle @ TS: deg @ Angle @ rD: 20 deg @ 5265 Annular Fluid: Reference Log: 36.8' RKB Last Tag: 5122 Last Tag Date: 1/2/1998 OåsiOgiStfing·...:iCØN·[)UCT0a Description I Size CONDUCTOR 16.000 eá$ihgSfring .·.....·PRC)[)l.JCT ION Description I Size PROD. CASING 7.625 ml.lbing$tr·ihg"'~·,TLlBING Size I Top 2.875 0 RerfOråtiôns.Summåry Interval TVD 4628 - 4664 3643 - 3677 Rev Reason: WORKOVER Last Update: 12/15/2005 Top o Zone WSD Status Ft SPF Date Type Comment 36 12 1/2/1998 IPERF RDX Charge; SOS 41/2" Ultrapak 36 12 1/2/1998 IPERF RDX Charge; SOS 41/2" Ultrapak 42 12 1/2/1998 IPERF RDX Charge; SOS 41/2" Ultrapak 56 12 1/2/1998 IPERF RDX Charge; SOS 41/2" Ultrapak 4696 - 4732 3706 - 3740 WS B 4786 - 4828 3791 - 3830 WS A4,WS A3 4866 - 4922 3865 - 3918 WS A2 Gas ",Lift...Mandrels/VåIVes St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date M~ Run 3063 2457 Camco KBMG-2 SOV 1.0 BEK 0.000 2000 12/4/2005 2 4393 3426 CAMCO KBMG-2 DMY 1.0 BK-5 0.000 0 12/4/2005 Other'':pIÙgs,''',åqLiip., .étc.) '··.JEWELRY Depth TVD Type Description 4436 3465 GAUGE BAKER GUARDIAN/PM925 PRESSURE GAUGE 4475 3501 Discharge CENTRILlFT ESP DISCHARGE HEAD Head 4476 3502 LOWER LOWER Tandom Pump wi Intake 142FC925 (OAL 23') ESP 4485 3510 Pump CENTRILlFT PUMP INTAKE SE64491A Intake 4486 3511 SEAL TANDEM Seal Section GSFT DB HL PFS 4500 3524 ESP ESP Motor 57 HP 1315/26 KMH MOTOR 4512 3535 Centralizer CENTRILlFT MOTOR CENTRALIZER 4564 3583 GRAVEL BAKER GRAVEL PACK ASSEMBL Yw/SCREEN PACK Vlv Cmnt ID 3.875 0.000 0.000 0.000 0.000 0.000 0.000 3.250 ') ) ~~7~ ~~¡::D "I I 'I ".. I I ',"""\ ',' ,~'"' ! :.1 i :\. J ~~~ '¡';¡..! ;,1 ~,·r~ 'j' I , ,,,,",,,, FRANK H. MURKOWSKI, GOVERNOR AI~ASIiA OIL AlÐ) GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 n(1,'" -'\:",V,·., \<\.,.:.~... ;II:~~ 'i' t',," ,,¡. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska s··.. C.., A ,\oj ~\ li E-· i-·~ PI.n 1\ 'I ~ r: ,<:, I J~LI 't! . ".' !VI.!;" &; 10' Re: Kuparuk 1D-133 Sundry Number: 305-126 Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd y following the date of this letter, or the next working day if the 23rd day falls on oliday or weekend. A person may not appeal a Commission decision to Superio, Co unless rehearing has been requested. DATED thisA day of May, 2005 Encl. ,,~ ) ConocJPhillips Alaska ) P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED MAY 1 7 2005 Alaska Oil & GlIS Cons. Commission Anchorage May 12, 2005 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well1D-133 (PTD 1972060). The variance request is for approval to temporarily use gaslift to produce the ESP-completed well. Also attached is a discussion and well schematic. Please call Marie McConnell at 659-7224 or myself if you have any questions. Sincerely, / / /ø/~r· MJZ Problem Well Supervisor ....',....,"".,'" ~~..-, ,.., ......., Attachments "\~\,"\s Of\~ ð~<:'(b)I(:~\ ~<è\\~ -\"o...\-c)"'E:~\'C)ð~~~ \r.J I ~c..", ~\~~ o..~, <J..~ eS~ ~<>~\ \<è~, ~ ~~~\-.. ~~ ~Q::.~' ~\-\-,\,->(è 0l~1ù0!..-ö...~,1.Lo~'1 c.V'~1: ~-\ \\ "",^~'1é ~o.~ ~"-::.'O~ro.\-\:c>K..,\ 4-~~c, c;:.~ ""~t<.'~Áo\'~\"CS ~~,~~((:~, hr?V1S¡'ì 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 111' 8. Property Designation: Kuparuk River Unit ) STATE OF ALASKA ') ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 o o o Suspend 0 o o Stimulate Perforate 0 o Repair well Pull Tubing 4. Current Well Class: Development _ 0 Stratigraphic 0 C1,IfR~'VErt MAY 1 7 Z005 Ala~ka Oil & f.ì14S Cons. r.ommi~~irm Waiver Amlli1rag\Imu'ar Disp. 0 Time Extension 0 Other 0 Re-enter Suspended Well o 5. Permit to Drill Number: 1972060 6. API Number: 50-029-22827 -00 9. Well Name and Number: 1 D-133 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): Exploratory D Service D 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 5265' 4239' Casing Length Size CONDUCTOR 1211 16" PROD. CASING 51381 7-5/8" Perforation Depth MD (ft): 4628-4664,4696-4732,4786-4828,4866-4922 Packers and SSSV Type: no packer no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. /' Printed Name MJ ~~d / ./ Signature ~ ~¿:J'?~.~ / ' - Commission Use Only MD TVD 121' 52491 Perforation Depth TVD (ft): 3643-3677,3706-3740,3790-3830,3865-3918 Packers and SSSV MD (ft) Tubing Size: 2-7/8" Date: no SSSV 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D Contact: Title: Burst Collapse Tubing Grade: L-80 Tubing MD (ft): 44621 Service 0 Plugged D WINJ D Abandoned D WDSPL D MJ Loveland/Marie McConnell Problem Well Supervisor Phone6sf- 7~~¢ Date/:;/?1I'1f'~:S- Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D Sundry Number: Mechanical Integrity Test D Location Clearance 0 3oS::-¡ ~ Other: þ.. p~ro\;)~",IT. ':> :J I?> \ -t) ~ sUbse~ff ~Q\\~~ <-~ot~ IT;¡ NAt~ ( (r¡ )../ BY ORDER OF Approved bY~ ~ COMMISSIONER THE COMMISSION Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE RBDMS BFl MA:' ? ~ 7nns Date: 1~$ Submit in Duplicate ) ') <" - .'. :;'1 ConocoPhillips Alaska, Inc. West Sak W elllD-133 (PTD 1972060) SUNDRY NOTICE 10-403 VARIANCE REQUEST May 12, 2005 The purpose of this Sundry Notice is for approval to produce ConocoPhillips' West Sak well1D- 133 on gaslift. The well is completed as an ESP (electric submersible pump) producer and does not have a production packer. 1D~133 produced via ES~until 04/30/05, at which time it was shut-in due to a grounding problem downhole. At this time no more re~start~'will be attempted, the problem will need to be fixed bya rig workover. ' The tubing is configured with one gaslift mandrel at 4410' RKB (3441' TVD). Gaslift will be applied in the "standard" configuration; i.e., gas will be injected down the annulus and enter the tubing through the gaslift valve. All production .from the well will be through the tubing to surface facilities. Since there will not be annular flow with this configuration, supplemental corrosion/erosion inspections will not be undertaken., The last production test on 04/26/05 (ESP production) recorded 250 BOPD, 156 BWPD (38%WC), and 47 MSCF of gas. Attached is a wellbore diagram of the well. ConocoPhillips proposes that: 1. The AOGCC approve this request for a time period not to exceed 24 months from the approval date; 2. Should aworkover not be completed within the approved time period the AOGCC will be contacted for a review and discussion of the plan forward. NSK Problem Well Supervisor ) ARCO..Alaska,lnc.A 1ð":133 Kuparuk API: 500292282700 SSSV Type: Annular Fluid: Last Tag: 5122 Rev Reason: New Schem Elevations Grd I Casing String - CONDUCTOR Item 16.000 in CONDUCTOR Casing String - PRODUCTION Item 7.625 in PROD. CASING ITublng'String . tUBING Item I Top 12.875 in TUBING , Perforations ! Interval 4,628 - 4,664 Well Type: PROD Orig Completion: 11/22/97 Last W /0: Last Tag Date: 1/2/98 Last Update: 2/15/98 I Original Rig RKB 1211 Btm Jnts Btm 5,2491 Jnts 371 Len I Jnts I Wt I Grd 4,425 141 6.50 L-80 Status Feet SPF Date 36 12 1/2/98 36 12 1/2/98 42 12 1/2/98 56 12 1/2/98 Zone 4,696 - 4,732 4,786 - 4,828 4,866 - 4,922 ) PBTD: 5,265 ftKB TO: 5,265 ftKB Max Hole Angle: 59 deg @ 2811 Angle ~ TS: deg @ Angle @ TO: 20 deg @ 5265 Wt I 62.58 Wt I 29.70 Type SOS 4 1/2" Ultrapak SOS 41/2" Ultrapak SOS 4 1/2" Ultrapak SOS 41/2" Ultrapak r 37 ft Grd H-40 Grd L-80 Thd EUE 8rd Mod Comment RDX Charge RDX Charge RDX Charge RDX Charge GáSHLiffMåndt~lšJ"åIVé!;':,,:,;; ,i; ;,\,,:<;:, .'. ' , ',. :,;i ..' ..". ; .'.. .. , ., ~:J¡(~!ij~~~Jij~.~~~I~;¡:~J~~~;~~~MM ··1 In!;·. ··1 i~;I~tchl 6.~~ , Depth Type Description 37 WIRE #2 ESP Electric Cable W/I Wire Cable; Run to 4492' 37 WIRE #1 Heat Trace (Raychem) Run to 2261' 4,422 SAP Baker Sensor Gauge attached to Top of Joint 1 4,453 HANDLING PUP EUE 8rd Mod 4,462 UPPER ESP UPPER Tandom Pump 142FC925 4,475 LOWER ESP LOWER Tandom Pump w/lntake 142FC925 4,482 SEAL Seal Section GSFT DB HL PFS 4,492 ESP MOTOR ESP Motor 57 HP 1315/26 KMH '·"···TRO]' 3000.0 Thd Thd ;...., Run 1/13/98 ID 0.000 0.000 2.438 2.438 0.000 0.000 0.000 0.000 1 D-133 WIRE #1 L TUBING -----# WIRE #2 t:' PROD. CASING -r .. r ¡ JL \ " ' ) I ,i, Gas Lift MandreVValve 1 SAP ," HANDLING PUP .. ../ r \ I I ;¡I, 1 '1' 5. ¡ I, ¡¡ ii '.W:~ ,,\ UPPER ESP LOWER ESP SEAL .... - IIIiI ESP MOTOR : l a,~"." 'r ( ,¡ Perf j ,¡ Perf =t =t .-L + t 4= -L. I =r. Perf /" + T 1" -t =} ~ :t Perf ] ± ~ ,- i J FW: ID-133 ESP failed last week. ') ) SuÞject: J:....W: 1D-133 ESP failed last week. FrJm': NSK Problem Well Supv <n1617@conocophillips.com> Date: Thu, 05 May 2005 17:04:57 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> cc: NSK Problem Well Supv <n1617@conocophillips.com> <1\ / ~~ \fI\ \ The ESP on 10-133 (PTO 197-206) failed April 30th and will require a workover to repair, The well is currently 81, however we will pursue a 10-403 for gas lift in the near future. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: NSK West Sak Prod Engr Sent: Thursday, May 05, 2005 4:40 PM To: NSK Problem Well Supv Cc: Hunt, Hai L Subject: 1D-133 ESP failed last week. MJ, Please notify AOGCC that 10-133 ESP has failed - see Pete's c/o note below for details. We'd like to gas lift this well, conventionally. Please submit a 10-403 for gas lift until the well is worked over. It is on this year's RWO schedule, but a 2 yr request would be nice incase if falls off the schedule for a while. Thanks, Marie . ID-133: ESP failed 4/30 will require RWO. The unit shut down on overload. DSO made one re-start attempt that failed on Low Speed. Centrilift made two re-start attempts after seeing that the current was un-balanced Centrilift tested the do\yn hole unit at the transformer. Centrilifts diagnostics indicate the system is grounded downhole requiring a workover. 1 of 1 5/17/2005 3 :41 PM Well Report L~fmp. 01 ~15 / 1998 KUPARUK RIV U WSAK 1D-133 Completion Status: 1-OIL Current Status 029-22827-00 197-206-0 ARCO MD 0526~-TVD 04239 Name Interval Sent Received BO 8203 ~ 1,2 SPERRY MPT/GR/EWR4 12/17/97 12/17/97 8204 /~1 SPERRY M?T/GR/EWR4 PB1 12/17/97 12/17/97 DGR/EWR4-MD ~/~INAL 121-5265 12/23/97 12/24/97 DGR/EWR4-MD ~//FINAL 121-3252 PB1 12/23/97 12/24/97 DGR/EWR4-TVD d~/FF~AL 121-4241 12/23/97 12/24/97 DGR/EWR4-TVD .J//FINAL 121-2560 PB 1 12/23/97 12/24/97 FLOW-TEM/PRES tJ/FINAL 40-4415 ~/2/4/~ ~ 7/9/98 7/13/98 MWD SRVY t..~/' SPERRY 1862.-5265. 12/19/97 12/24/97 MWD SRVY t~ SPERRY 0-3260. PB1 12/19/97 12/24/97 MWD SRVY ~ SPERRY 1861.66-5265. 2/18/98 2/20/98 Daily Well Ops /!~ ~/,/c~?__ Was the well cored? yes Are Dry Ditch Samples Required? yes ~_____~And Receivod¢-yes--m~ Analysis Description Received?.~Aes_~_n_o_~Sa~ e' e Comments: Monday, January 10, 2000 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL E~] GAS [~] SUSPENDED [~ ABANDONED~ SERVICE E~] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 97-206 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22827 · . r 9 Unit or Lease Name At Top Producing Interval i . 110 Well Number At Total Depth 2256' FSL, 594' FEL, Sec. 23, T11N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. West Sak Oil Pool RKB 41', Pad 71' ADL 25650 ALK 468 12 Date14-Nov-97Spudded 13 1Date8-Nov-97T'D' Reached 14 1Date5-Jan-98Comp', Susp. or Aband. 15 WaterNADepth, if offshorefeet MSL 16 1Nc' of Completions 7 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 5265' MD & 4239' TVD 5122' MD & 4071' TVD YES X~ NO U NA feet MD 1690' APPROX 22 Type Electric or Other Logs Run GR/Res 23 CASING, LINER AND CEMENTING RECORD SEI-I-ING DEPTH MD I CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT I~ECORD 16" 62.58# H-40 SURF. 121' 24" 9 cu yds High Eady 7.625" 29.7# L-80 SURF. 5249' 9.875" 465 sx AS III LW, 400 sx Class G, 60 ASI 24 Pedorations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET'MD) 2.875" 4498' 4928', 4845', 4740', 4671', 4565' 4628'-4664' MD 3643'-3677' TVD 12 spt 4696'-4732' MD 3706'-3740' TVD 12 spt 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4786'-4828' MD 3791'-3830' TVD 12 spt DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4866'-4922' MD 3865'-3918' TVD 12 spt 4628'-4664' MD D: 1276# 16/20 proppant in reservoir SWS 4.5" HSD TCP w/ultra-pock 24 GM RDX charges 4~596'-~732' MD B: 9534# 16/20 proppant in reservoir 4786'-4828' MD A-3: 51,257# 16/20 proppant in reservoir 4866'-4922' MD A-2: 150,424# 16/20 proppant in reservoir 27 PRODUCTION TEST ¢hDI C'_lkl A i Date First Production01/19/1998 Method of OperatiOnEsp(FIowing, gas lift, etc.) U I '~ I U i I ~1~ ~ Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBI CHOKE SIZE I GAS-OIL RATIO o2/o9/1998 12 TEST PERIOI: ]86 133 2 0I 717 Flow Tubing Casing Pressure CALCULATED OIL-BBL :GAS-MCF WATER-BBI OIL GRAVITY-APl (corr) Press. 195 -]5 24-HOUR RATE: 372 267 5 0° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. !30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 4622' 3637' Base West Sak Sand 5094' 4079' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Doily Drillincj Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title DATE Prepared by Name/Number Sharon Allsup-Drake/263-4612 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- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form10-407 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA, INC. WS / 1D-133 500292282700 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 111897 MWD SURVEY JOB NUMBER: AKMMS0011 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES 'DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 1861.66 1754.22 1642.72 43 10 S .18 W .00 419.03S 83.92W 1930.00 1802.88 1691.38 46 1 S .26 W 4.17 467.01S 84.11W 1956.91 1821.77 1710.27 44 47 S .80 W 4.75 486.17S 84.28W 1998.00 1851.29 1739.79 43 20 S 1.08 W 3.58 514.74S 84.75W 2051.02 1889.84 1778.34 43 22 S 1.52 W .57 551.13S 85.58W 418.49 466.47 485.63 514.20 55O.58 2145.71 1955.44 1843.94 48 53 S 1.58 W 5.83 619.34S 87.42W 2241.61 2016.37 1904.87 52 12 S 3.02 W 3.65 693.32S 90.42W 2335.20 2071.83 1960.33 55 5 S 1.22 W 3.45 768.64S 93.18W 2430.14 2123.97 2012.47 58 16 S .74 W 3.37 847.95S 94.53W 2621.28 2225.50 2114.00 57 33 S 1.14 E .91 1009.87S 93.98W 618.78 692.74 768.04 847.34 1009.26 2811.46 2325.48 2213.98 59 0 S 1.32 E .76 1171.60S 90.50W 3002.17 2424.95 2313.45 58 7 S 1.72 E .49 1334.24S 86.19W 3095.87 2474.75 2363.25 57 40 S 1.24 E .65 1413.59S 84.14W 3191.86 2526.53 2415.03 57 2 S .67 E .83 1494.40S 82.79W 3287.71 2579.93 2468.43 55 15 S 3.55 E 3.12 1573.93S 79.88W 1171.00 1333.68 1413.03 1493.85 1573.40 3383.68 2636.88 2525.38 51 57 S 5.55 E 3.83 1650.92S 73.78W 3478.89 2697.54 2586.04 48 52 S 5.03 E 3.25 1723.97S 67.01W 3574.92 2761.88 2650.38 46 58 S 3.10 E 2.48 1795.06S 61.94W 3669.87 2827.96 2716.46 44 46 S 4.82 E 2.66 1863.04S 57.26W 3763.11 2895.54 2784.04 42 17 S 5.40 E 2.69 i927.00S 51.54W 1650.42 1723.52 1794.63 1862.64 1926.63 3857.02 2966.89 2855.39 38 47 S 5.40 E 3.74 1987.76S 45.80W 3951.53 3041.79 2930.29 36 19 S 5.66 E 2.61 2045.09S 40.25W 4047.03 3120.12 3008.62 33 26 S 5.55 E 3.03 2099.45S 34.92W 4136.11 3195.78 3084.28 30 15 S 5.67 E 3.58 2146.22S 30.32W 4232.33 3280.21 3168.71 27 3 S 6.97 E 3.38 2192.07S 25.27W 1987.43 2044.80 2099.18 2145.98 2191.87 4328.39 3366.65 3255.15 24 39 S 3.46 E 2.96 2233.77S 21.41W 4421.99 3451.91 3340.41 24 4 S 2.54 E .75 2272.33S 19.39W 4518.47 3540.81 3429.31 21 39 S 5.50 E 2.77 2309.72S 16.81W 4612.96 3628.83 3517.33 20 57 S 4.53 E .83 2343.92S 13.80W 4802.23 3805.67 3694.17 20 48 S ,5.04 E .12 2411.16S 8.17W 2233.59 2272.16 2309.56 2343.79 2411.06 4989.63 3981.01 3869.51 20 31 S 5.16 E .16 2477.03S 2.30W 5201.70 4179.96 4068.46 20 0 S 6.28 E .31 2550.10S 5.01E 5265.00 4239.44 4127.94 20 0 S 6.28 E .00 2571.62S 7.38E 2476.97 2550.08 2571.61 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2571.63 FEET AT SOUTH 0 DEG. 9 MIN. EAST AT MD = 5265 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 179.64 DEG. TIE-IN SURVEY AT 1,861.66' MD WINDOW POINT AT 1,930.00' MD PROJECTED SURVEY AT 5,265.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, INC. WS / 1D-133 500292282700 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 111897 JOB NUMBER: AKMM80011 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORtH/SOUTH EAST/WEST DIFFERENCE CORRECTION 1861.66 1754.22 1642.72 2861.66 2351.33 2239.83 3861.66 2970.50 2859.00 4861.66 3861.22 3749.72 5265.00 4239.44 4127.94 419.03 S 83.92 W 107.44 1214.62 S 89.51 W 510.33 402.89 1990.66 S 45.53 W 891.16 380.83 2432.19 S 6.32 W 1000.44 109.28 2571.62 S 7.38 E 1025.56 25.12 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. WS / 1D-133 500292282700 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 111897 JOB NUMBER: AKMM80011 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 1861.66 1754.22 1642.72 419.03 S 83.92 W 107.44 1942.40 1811.50 1700.00 475.92 S 84.'15 W 130.90 23.46 2081.26 1911.50 1800.00 572.23 S 86.14 W 169.76 38.86 2233.73 2011.50 1900.00 687.13 S 90.10 W 222.23 52.47 2406.72 2111.50 2000.00 828.14 S 94.25 W 295.22 73.00 2595.19 2211.50 2100.00 987.86 S 94.42 W 383.69 88.46 2784.32 2311.50 2200.00 1148.34 S 91.04 W 472.82 89.13 2976.70 2411.50 2300.00 1312.63 S 86.84 W 565.20 92.38 3164.24 2511.50 2400.00 1471.23 S 83.06 W 652.74 87.54 3341.83 2611.50 2500.00 1617.77 S 76.74 W 730.33 77.59 3500.12 2711.50 2600.00 1739.90 S 65.61 W 788.62 58.29 3646.68 2811.50 2700.00 1846.76 S 58.63 W 835.18 46.56 3784.54 2911.50 2800.00 1941.23 S 50.20 W 873.04 37.87 3913.90 3011.50 2900.00 2022.87 S 42.45 W 902.40 29.36 4036.67 3111.50 3000.00 2093.72 S 35.47 W 925.17 22.77 4154.23 3211.50 3100.00 2155.19 S 29.41 W 942.73 17.57 4267.32 3311.50 3200.00 2207.64 S 23.54 W 955.82 13.09 4377.72 3411.50 3300.00 2254.27 S 20.21 W 966.22 10.40 4486.84 3511.50 3400.00 2297.87 S 17.83 W. 975.34 9.13 4594.40 3611.50 3500.00 2337.30 S 14.33 W 982.90 7.55 4701.48 3711.50 3600.00 2375.49 S 11.30 W 989.98 7.09 4808.47 3811.50 3700.00 2413.37 S 7.98 W 996.97 6.98 4915.41 3911.50 3800.00 2451.12 S 4.64 W 1003.91 6.94 5022.19 4011.50 3900.00 2488.40 S 1.27 W 1010.69 6.77 5128.85 4111.50 4000.00 2525.33 S 2.29 E 1017.35 6.66 5235.27 4211.50 4100.00 2561.51 S 6.27 E 1023.77 6.42 5265.00 4239.44 4127.94 2571.62 S 7.38 E 1025.56 1.79 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA INC WS / 1D-133PB1 500292282770 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 111397 MWD SURVEY JOB NUMBER: AKMM80011 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -111.50 0 0 N .00 E .00 121.00 121.00 9.50 0 0 N .00 E .00 199.76 199.74 88.24 1 46 N 31.93 W 2.25 289.83 289.78 178.28 1 0 N 56.11 W 1.05 379.37 379.31 267.81 0 25 S 17.15 W 1.34 .00N .00E .00 .00N .00E .00 1.03N .64W -1.04 2.66N 2.04W -2.67 2.78N 2.79W -2.80 467.07 467.00 355.50 1 12 S 8.62 E .97 559.71 559.60 448.10 2 5 S 24.16 W 1.36 649.24 648.98 537.48 4 28 S 53.23 W 3.17 740.42 739.72 628.22 6 49 S 64.83 W 2.84 832.02 830.48 718.98 8 37 S 53.90 W 2.53 1.56N 2.75W -1.58 .95S 3.29W .93 4.53S 6.76W 4.49 8.97S 14.51W 8.88 15.33S 24.98W 15.17 922.45 919.51 808.01 11 36 S 36.99 W 4.63 1012.99 1007.91 896.41 13 16 S 29.48 W 2.56 1103.96 1096.23 984.73 14 26 S 21.88 W 2.38 1194.73 1183.44 1071.94 17 42 S 15.18 W 4.12 1289.99 1273.20 1161.70 21 24 S 12.28 W 4.02 26.59S 35.94W 26.36 42.92S 46.54W 42.63 62.55S 55.91W 62.20 86.38S 63.75W 85.98 117.36S 71.24W 116.91 1383.83 1359.37 1247.87 25 12 S 8.54 W 4.33 1479.58 1444.74 1333.24 28 40 S 2.23 W 4.69 1574.77 1527.20 1415.70 31 15 S 1.55 W 2.73 1670.68 1607.40 1495.90 35 14 S .53 W 4.20 1766.27 1682.96 1571.46 40 15 S .65 E 5.30 1861.66 1754.17 1642.67 43 10 S .18 W 3.12 1956.91 1821.32 1709.82 47 8 S .29 W 4.17 2051.39 1883.72 1772.22 50 11 S .81 E 3.34 2146.58 1942.52 1831.02 53 30 S 2.03 E 3.62 2242.74 1999.63 1888.13 53 37 S 2.55 E .45 153.87S 197.00S 244.51S 297.07S 355.56S 419.02S 486.54S 557.47S 632.29S 709.58S 77.85W 153.38 81.77W 196.48 83.33W 243.98 84.26W 296.53 84.16W 355.02 83.92W 418.48 84.20W 486.00 83.86W 556.93 81.99W 631.76 78.89W 709.07 2430.41 2107.33 1995.83 56 19 S 3.19 E 1.47 863.06S 2525.41 2160.38 2048.88 55 46 S 3.39 E .60 941.73S 2717.27 2267.53 2156.03 56 19 S 3.80 E .33 1100.57S 2904.94 2370.24 2258.74 57 18 S 2.79 E .69 1257.36S 3095.30 2474.36 2362.86 56 22 S 1.31 E .82 1416.60S 71.19W 862.59 66.66W 941.30 56.68W 1100.19 47.66W 1257.04 41.95W 1416.31 3184.97 2523.41 2411.91 57 18 S 2.36 E 1.44 1491.62S 3260.00 2563.93 2452.43 57 18 S 2.36 E .00 1554.71S 39.55W 1491.34 36.94W 1554.45 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1555.15 FEET AT SOUTH 1 DEG. 21 MIN. WEST AT MD = 3260 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 179.64 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 3,260.00' MD ORI¢INAL SPERRY-SUN DRILLING sERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC WS / 1D-133PB1 500292282770 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 111397 JOB NUMBER: AKMM80011 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -111.50 1000.00 995.27 883.77 2000.00 1850.25 1738.75 3000.00 2421.59 2310.09 3260.00 2563.93 2452.43 .00 N .00 E .00 40.32 S 45.07 W 4.73 4.73 518.48 S 84.21 W 149.75 145.02 1337.27 S 43.77 W 578.41 428.66 1554.71 S 36.94 W 696.07 117.65 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC WS / 1D-133PB1 500292282770 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 111397 JOB NUMBER: AKMM80011 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH' EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -111.50 .00 N .00 E .00 111.50 111.50 .00 .00 N .00 E .00 .00 211.52 211.50 100.00 1.34 N .84 W .02 .02 311.55 311.50 200.00 2.87 N 2.36 W .05 .03 411.56 411.50 300.00 2.56 N 2.86 W .06 .01 511.58 511.50 400.00 .58 N 2.67 W .08 .02 611.67 611.50 500.00 2.89 S 4.81 W .17 -.09 712.03 711.50 600.00 7.55 S 11.68 W .53 .36 812.83 811.50 700.00 13.63 S 22.66 W 1.33 .80 914.28 911.50 800.~00 25.34 S 34.95 W 2.78 1.45 1016.68 1011.50 900.00 43.66 S 46.95 W 5.18 2.39 1119.75 1111.50 1000.00 66.29 S 57.36 W 8.25 3.08 1224.28 1211.50 1100.00 95.37 S 66.09 W 12.78 4.53 1331.39 1311.50 1200.00 132.75 S 74.31 W 19.89 7.10 1441.95 1411.50 1300.00 179.39 S 80.73 W 30.45 10.57 1556.46 1511.50 1400.00 235.09 S 83.06 W 44.96 14.51 1675.73 1611.50 1500.00 300.01 S 84.28 W 64.23 19.27 1804.00 1711.'50 1600.00 380.24 S 83.96 W 92.50 28.27 1942.57 1811.50 1700.00 476.09 S 84.14 W 131.07 38.57 2095.53 1911.50 1800.00 591.75 S 83.19 W 184.03 52.96 2262.82 2011.50 1900.00 725.77 S 78.16 W 251.32 67.30 2437.93 2111.50 2000.00 869.30 S 70.84 W 326.43 75.10 2616.31 2211.50 2100.00 1016.76 S 62.22 W 404.81 78.38 2796.56 2311.50 2200.00 1166.41 S 52.31 W 485.06 80.25 2981.33 2411.50 2300.00 1321.57 S 44.53 W 569.83 84.76 3162.92 2511.50 2400.00 1473.08 S 40.31 W 651.42 81.59 3260.00 2563.93 2452.43 1554.71 S 36.94 W 696.07 44.65 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11326 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 7/9/98 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1 A- 20 PRODUCTION PROFILE 9 8 0 5 31 I 1 1D-10 ~ CBT 98051 8 I 1 1 D-124 FLOWING TEMP/PRESS 980524 I 1 1 D- 130 ~, \ ~ - INJECTION PROFILE 980423 I 1 1 D- 133 FLOWING TEMP/PRESS 980524 I I -- 1 E-23 ~\~, L.~- - INJECTION PROFILE 980523 I 1 2 A- 17 PRODUCTION PROFILE 980522 I 1 2 A- 19 PRODUCTION PROFILE 98051 0 I 1 2 D- 14 L~,\ (, . WATER INJECTION PROFILE 980531 I 1 2 D- 16 t~, ~ ~. - WATER INJECTION PROFILE 980530 I I _ 2 F- 02 i._t,. ~ (- ..- WATER INJECTION PROFILE 980528 I 1 '2 F- 03 ~. ~ (... - .WATER INJECTION PROFILE 980529 I 1 2 M- 23 TEMPERATURE SURVEY 980507 I 1 3 C- 04 PRODUCTION PROFILE 980505 I 1 3 C- 04 GAS LIFT SURVEY 980505 I 1 3F-06 GAS LIFT SURVEY 980512 I 1 3 F- 06 PRODUCTION PROFILE 980512 I 1 3 F- 14 PRODUCTION PROFILE 980514 I 1 3K-27 GAS LIFT SURVEY 980504 I 1 1D-09 ~ CBT 980517 I I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 17, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-133 (Permit No. 97-206) Well Completion Report Dear Mr. Commissioner: Enclosed is a corrected well completion report for the completion on West Sak 1D-133. The location at bottomhole has been corrected. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Senior Drilling Engineer Kuparuk Development TWM/skad ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 18, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-133 (Permit No. 97-206) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-133. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Senior Drilling Engineer Kuparuk Development TWM/skad ri !:t I l_l_l N G S I:: F:I~I C I:: S 19-Dec-97 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-133 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 1,862.00' MD 1,930.00' MD 5,265.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, ~~ William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company 19-Dec-97 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-133PB1 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD n/a' MD 3,260.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~ December 23, 1997 RE: MWD Formation Evaluation Logs 1D-133 & 1D-133 PB1, AK-MM-80011 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention o12 Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1D-133: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22827-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22827-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1D-133 PBI: 2"x 5"MD Resistivity & Gamma Ray Logs: 50-029-22827-70 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22827-70 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I~ I L-I--I IM I~ WELL LOG TRANSMITTAL To.' State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs December 17, 1997 I 1D-133 & 1D-133 PB1, AK-MM-80011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2 LDWG formatted Disks with verification listings. API#: 50-029-22827-00 & 50-029-22827-70 5631 Silverado Way, Suite G · Anchorage, Alaska99518 · (907)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVE/~NOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 7. 1997 Tom Mc Kav Senior Drilling Engineer ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit West Sak 1D-133 (J5) ARCO Alaska. Inc. Permit No 97-206 Sur. Loc ' 451'FNL. 600'FEL. Sec 23, TllN, R10E? UM Btmhole Loc' 2260'FSL. 578'FEL, Sec 23, T11N. R10E. UM Dear Mr. Mc Kay: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may ~vitness the test. Notice mav be given by contacting the Commission petroleum field inspector on the North .. Chairman BY ORDER OF THE COMMISSION dlf/enclosures cc~ Department of Fish & Game, Habitat Section w/o encl. Department of Environment Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMi'S%ION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill _ Re-Entry __ Deepen lb. Type of Well Service __ Exploratow.__ Development Gas __ Stratigraphic Test __ Single Zone __x Development Oil ~ Multiple Zone __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 451' FNL, 600' FEL, Sec. 23, T11N, R10E, UM At top of productive interval 2430' FSL, 585' FEL, Sec. 23, T11 N, R10E, UM At total depth 2260' FSL, 578' FEL, Sec 23, T11N, R10E, UM 12. Distance to nearest I 13. Distance to nearest well propert~ line i 1D-07 2260' @ TD feet i 24' @ 875' feet 5.Datum Elevation (DF or KB) RKB 41', Pad 71 6. Property Designation ADL 25650 ALK 468 7. Unit or property Name Kuparuk River Unit 8. Well number West Sak 1 D-133 (J5) 9. Approximate spud date 11/5/97 14. Number of acres in property 2560 feet 10. Field and Pool Kuparuk River Field West Sak Oil Pool · 11. Type Bond (see 20 AAC 25.025) i Statewide ~ Number #U630610 Amount $2OO,OOO 15. Proposed depth (MD and TVD) 5154'MD 4234' TVD feet 16. To be completed for deviated wells j 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 300 feet Maximum hole angle 47.0°, Maximum surface 1416 psig At total depth (TVD) 1861 psig 18. Casing program size Hole I Casing 24" 16" 9.875" 7.625" Weight 62.5# Specification Grade H-40 Coupling :~ Length Weld 77' BTC 5113' Setting Depth Top Bottom MD ! TVD! MD 41' i 41' i 118' , TVD 118' Quantity of cement (include staqe data) 200 CF 29.7# L-80 41' 41' 5154' 4234' 580 sx AS III & 330 sx Class G : 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet true vertical feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented Measured depth True Vertical depth Perforation depth: measured true vertical 20. Attachments Filing fee __x Property plat __ BOP Sketch __x Diverter Sketch ~ Drilling program __x Drilling fluid program __x Time vs depth plot__ Refraction analysis __ Seabed report __20 AAC 25.050 requirements __x 21. ' hereby certify that the foregoing is true and correct to the best of my knowledge ~(~~~~Signed.,...~/ ~j~'' /~'""/~ Title ~"~;'"~'~///"~! /~2/3~/y7 ~. I Commission Use Only Permit Number _ i APl n~'nber ... _ ,-.__ i Approval date ! 1 i ,-. '~c~ ,,,, i See cover letter for I ! lllqlq) ] otherrequirements Conditions of approval Samples required '._Yes ,~No Mud Icg required _~Ye¢ ,~'No Hydrogen sulfide measures _ Yes z_,~'No Directional survey required ~'Yes _ No Required working pressure for BOPE ~'2M;' _ 3M; _ 5M; _ 10M; _ 15M Other: Original Signed By by order of Approved by Oared W. J0hrlst0r[ Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor October 29, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak Phase lA Development Well, Kuparuk River Unit;:~:~'-?':?:~ Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1 D pad. The well is designed as a producer well using a frac-pack completion technique for reservoir stimulation and sand control purposes. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements detailed in ARCO's testimony for West Sak Pool Rules governing the West Sak development project. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D- 133 (JS), such as shallow gas. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 6) There have been eight (8) Kuparuk wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APB per 20 AAC 25.035 (d)(2). A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is November 5, 1997. If you have any questions or require further information, please contact Tom McKay at (907) 265- 6890. Sincerely, Thomas W. McKay, P.E. Senior Drilling Engineer Attachments: cc: West Sak 1D-133 (J5) Well File Tom Brockway ATO-1207 Mike Zanghi ATO-1276 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK6 Drill and Case Plan for West Sak 1D-133 (JS) Frac-Packed Producer General Procedure: o Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. , Spud and directionally drill 9-7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. o Run and cement 7-5/8" 29.7# L80 BTC-MOD casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. , Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3,000 psi. , Pick up 6-3/4" mill tooth bit, 4-3/4" drill collars, and 3-1/2" drill pipe. Trip in and drill out stage collar. Clean out to PBTD. , Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. , Swap well over to non-freezing completion brine. Filter brine to desired level. Trip out. 10. Nipple down BOP stack. Install production tree and pressure test same. Set back pressure valve. 11. Secure well and release rig. TAB, 9/25/97 Page 1 Completion Plan for West Sak 1D-133 (J5) Four-Sta.qe, Single-Trip Frac-Pack Job, Frac-Packed Producer General Procedure: Well Preparation 1. Move in / rig up completion rig. , Pull back pressure valve, nipple down tree and install 11" 5M WP BOP stack and pressure test same. , Trip in with 6-3/4" bit and scraper on 3-1/2" workstring, and RIH to to PBTD. Pressure test 7-5/8" 29.7# L80 BTC-MOD casing. Perform casing wash and displace well to filtered brine. Pickle workstring as required. Filter brine to desired level. Trip out. . Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. , Make up Baker sump packer on E-line. RIH and set same below A2 sands (bottom pay sands). Space out and set sump packer to position TCP guns accurately on next trip in. POOH with E-line. , Pick up TCP perforating gun string to perforate all West Sak intervals in one trip. Trip in with 3-1/2" workstring, and sting into sump packer seal bore. Locate TCP guns on depth. Set TCP packer above West Sak. , Use diesel cap and/or void tubing to achieve desired underbalance. Drop bar and fire guns. , Release packer and reverse out to clean brine. Kill well as required. TOH with TCP gun string. o Pick up gravel pack assembly, including wire-wrapped screens, gravel pack and isolation packers, blank pipe, frac-pack crossover tool, and other jewelry and trip in hole on 3-1/2" workstring. Screens and packers should be spaced out to allow for isolated frac-packs on the following four West Sak intervals in one trip: Stage 1: A2 Stage 2: A3 Stage 3: A4 + B Stage 4: D Page 2 Stage 1 10. Locate gravel pack string into seal bore of sump packer. Sting lower screen seal assembly and snap-latch into sump packer. Set all isolation packers. Rig up and pressure test frac equipment at surface. 11. Position frac-pack crossover tool as required. Perform data frac for Stage 1. 12. Using 16-20 mesh carbolite proppant, proceed to frac Stage 1 with the specified volume of proppant. 13. Shift crossover tool, and gravel pack Stage 1. 14. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Stage 2 15. Re-position frac-pack tools to frac-pack Stage 2 interval. Rig up and pressure test frac equipment at surface. 16. Position frac-pack crossover tool as required. Perform data frac for Stage 2. 17. Using 16-20 mesh carbolite proppant, proceed to frac Stage 2 with the specified volume of proppant. 18. Shift crossover tool, and gravel pack Stage 2. 19. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Stage 3 20. Re-position frac-pack tools to frac-pack Stage 3 interval. Rig up and pressure test frac equipment at surface. 21. Position frac-pack crossover tool as required. Perform data frac for Stage 3. 22. Using 16-20 mesh carbolite proppant, proceed to frac Stage 3 with the specified volume of proppant. 23. Shift crossover tool, and gravel pack Stage 3. 24. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Page 3 Stage 4 25. Re-position frac-pack tools to frac-pack Stage 4 interval. Rig up and pressure test frac equipment at surface. 26. Position frac-pack crossover tool as required. Perform data frac for Stage 4. 27. Using 16-20 mesh carbolite proppant, proceed to frac Stage 4 with the specified volume of proppant. 28. Shift crossover tool, and gravel pack Stage 4. 29. Shift gravel pack tools, and reverse out excess proppant and frac fluids. 30. Release frac-pack running tools and trip out of well. At this point, the flow conduit inside the screens from the sump packer to the upper packer should be free of sand and any plugs. Rathole should be available below sump packer. 31. Circulate well to clean brine. TOH with workstring. Change rams to 2-7/8" and pressure test same unless VBR's are available. 32. Pick up Centrilift ESP on 2-7/8" production tubing. 33. Run in well with ESP pump with power cable and data gathering information wire attached to tubing. 34. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 35. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. 36. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 37. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. 38. Release rig and turn well over to production. TAB, 9/25/97 Page 4 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1 D-133 (J5) Drillinq Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 8-15 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.6-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12% Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 50-100 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A combination surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately.. 200. feet TVD below the base of the permafrost interval. :" F ~ ' ~ ~' ~ ~:' '~ ~ : ~ Page 1 MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-133 (J5) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. Based on actual well test data from the nearby WSl-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.6 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,626' MDFFVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base in the West Sak 1D-133 (J5) well to surface, the following MASP can be computed: MASP = (4,046 ft)(0.46 - O. 11 psi/fi) = 1416 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7-5/8" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 7-5/8" 29.7# L80 BTC-MOD casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. Following the clean out operation with the completion rig, a frac-pack completion will be installed, after which the ESP pump, power cable, heat trace and production tubing would be installed. Page 2 Drilling Area Risks: Drilling risks in the West Sak 1D-133 (J5) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-133 (J5). Well Proximity Risks: The nearest existing well to West Sak 1D-133 (J5) is KRU 1D-07. As designed, the minimum distance between the two wells would be 24' at 875' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of an existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-133 (J5) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 2-7/8" production tubing and prior to the completion rig moving off of the well. TAB, 10/16/97 Page 3 C~eoted ~/~nch For: T McKAY Date p~a~ted: 2~-0ci-§7 Plot ~e~erence is WS 1D-153/d5 Vernon ~. Cao~;notes ore in feet reference s~o~ ~153. r~= Verticai Dep~s ~re ref~ence ~B (P=rker ~24~ 3OO 6OO 9O0 1200 1500 1800 2i00 2400 27OO 3000 3300 3600 3900 4200 4500 AlPC 0 A1 --' aska, Inc. Structure : Pod 1D Well : J5 I Ffeld : Kuparuk River Unit Location : North Slope, Alaska RKB ELEVATION: 112' 1 ?9.64 AZIMUTH E399' (TO TARGET) ***Plane of Proposal*** I<OP rlWD=300 TMD=300 DEP=0 4.00 BEGIN TURN TO TARGET TVD=499 TMD=500 DEP=5 9.54 12.25 15.50 1 1.04 22.73 DLS: 4.00 deg per 100 ft 26.51 30.34 34.20 38.09 42.00 45.92EOC TVD=1494 TMD=1628 DEP=4-68 B/ PERMAFROST TVB=1652 TMD=1850 DEP=615 MAXIMUM ANGLE 47.02 DEG 45.72 42 DLS: 3.00 deg per 100 ft TARGET ANGLE 20 DEG SURFACE LOCATION: 451' FNL, 600' FEL SEC. 23, T11N, R10E 200 0 Begin Turn to TargetS)~) :ac Base Permafrost ITARGET LOCATION: 2430' FSL, 585' FEL SEC. 23, TllN, RIOE TARGET TVD=3767 TMD=4-657 DEP=2399 SOUTH 2399 8~gi. A~g[e O,op EAST 15 Top Ugnu Sands TD LOCATION: 2260' FSL, 578' FEL SEC. 23, T11N, TIOE 200 I I 200 o 200 400 600 8OO lOOO 12o0 1400 ~ 16oo 180o 2ooo 2200 Top West Sok Sands/ T~CET - 'w~ so~ .~, ~, , 2400 BEGIN ANGLE DROP TVD=2741 TMD=3457 DEP=1804 Base we~t Pt ~ - Casing 2600 u ~z T/ UGNU SNDS ~D=2947 TMD=3738 DEP=1995 30.72 ~ 27.72 ~ ..... END ANGLE DROP WD=3485 TMD=4357 DEP=2297 ~T/ W SAK SNDS ~D=3626 TMD=4507 DEP=2348 TARGET ~ SA~ A3 TVD=3?6? T~D=~657 OgP=g399 B/ W SAK SNDS ~D=4046 TMD=4954 DEP=2501 TD - CSG ~ ~D=4234 ~MD=St54 DgP=256g i I i i i i ii i i ii i i i ii i i 0 300 600 900 1200 1500 1800 21 O0 2400 2700 Verficol Section (feet) -> Azimuth 179.64 with reference 0.00 N, 0.00 E from slot #1.3.3 Craated by finch For: T McKAY Dote pletted : 25-0ct-97 Flor Reference ie W$ 10-133/d§ Vernon 44. CaardMates ere ;n[eet reference sial. ~155, True Vertical Depths are reference RKB (Parker ~._ A lask In Field : Kuparuk River Unit Location : North Slope, a 8o 4o 4o 8o 120 16O 2OO 240 (D (- 280 0 {.Fl 320 I V 400 44O 48O 520 560 600 640 <- West (feet) 520 280 240 200 1 60 120 80 40 0 40 80 120 160 200 240 280 I I I I I I I I I I I I t I I I I I I I I I I I I I I I 80 300 1400 " 600 //" 2600/' '"' '--~ 1500 ,, 700 ./ .,,/1'000 " //'/ ./i'1 O0 1 600 / 2700;/' 800../ ...-' 600.F.--'~00 ,,,' ..../ .?-'1200 700."' ,,,/ ../' ..." /? ~,~-300 2800 ,/,,,~ 00/,~'300 800/ ~7000 /' ,,," i/4oo e %oo 1000 '''''/' 2g ,0,~ 1100// /// / ~ 1 ~"" / I [~-~/2800 ~ ?7 ~oo -~oo ~oo .: 1600~r~O0 / .... ,.," ,,,,'~/ ~1200 ./~oo / 1500 1600 t40 o 1700 40 1800 8o 1500 1400 ....... 1600 ....... ~ .... 1700 2 ~1 i I i I i i i i i I i I i i i I i I i i i i i i I i i I i 520 280 240 200 160 120 80 40 0 40 80 120 160 200 240 280 <- West (feet) 12O 160 200 240 0 280 320 v I 600 640 480 I520 - 560 440 400 360 ARCO Alaska, Inc. Pad 1D J5 slot #133 Kuparu~ River t~nit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE Baker Hughes II~TEQ REPORT Your ref : WS 1D-133/J5 Version #4 Our ref : prop2189 License : Date printed : 23-Oct-97 Date created : 16-Apr-97 Last revised : 22-Oct-97 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 17 56.880,w149 30 36.399 Slot Grid coordinates are N 5959213.711, E 560490.627 Slot local coordinates are 451.00 S 600.00 W Projection ty~e: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PGMS <0-8365'>,,1,Pad 1D TOTCO Survey,,WS-8,Pad 1D PGMS <0-8930'>,,5,Pad 1D PGMS <O-7502'>,,4,Pad 1D PGMS <O-8070'>,,3,Pad 1D MSS <3311-8200'>,,7,Pad 1D PGMS <O-8610'>,,6,Pad 1D PGMS <O-9783'>,,2,Pad 1D WS 1D-135/G7 Version #4,,G7,Pad 1D WS 1D-121/G5 Version #3,,G5,Pad 1D WS 1D-130/H4 Version #4,,H4,Pad 1D WS 1D-124/G3 Version #3,,G3,Pad 1D WS 1D-129/J3 Version #3,,J3,Pad 1D WS 1D-106/D6 Vers.#3,,D6,Pad 1D WS 1D-109/D4 Vets. #2,,D4,Pad 1D WS 1D-119/F4 Vers.#3,,F4,Pad 1D WS 1D-120/F6 Vets. #3,,F6,Pad 1D WS 1D-118/E5 Version #4,,ES,Pad 1D WS 1D-105/C7 Version #4,,C7,Pad 1D WS 1D-115/E3 Version #4,,E3,Pad 1D WS 1D-117/E7 Version #4,,ET,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 4-Aug-92 16-Oct-96 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 22-Oct-97 22-0ct-97 9-Oct-97 22-0ct-97 22-Oct-97 8-Oct-97 8-Oct-97 6-0ct-97 6-0ct-97 22-0ct-97 22-0ct-97 22-Oct-97 22-0ct-97 688.0 69.9 207.5 327.8 448.0 24.1 87.2 567.9 51.4 270.0 45.0 180.0 59.4 555 0 510 0 300 0 285 0 345 0 585 0 390 0 360 0 3O0 1050 300 300 20 875 325 3OO 825 300 300 30O 650 30O 30O 3O0 300 30O 3O0 300 300 0 300.0 0 1050.0 0 300.0 0 300.0 0 300.0 0 875.0 0 325.0 0 300.0 0 825.0 0 300.0 0 300.0 0 300.0 0 650.0 0 300.0 0 300.0 0 300.0 0 300.0 0 300.0 0 300.0 0 300.0 0 300.0 Wes~Sak 1 D-133 (J5) Injector Well Four (4) Stage Frac-Pack 16" Conductor Casing @ 80' 2-7/8" Production Tubing Heat Trace Through Permafrost 7-5/8" DV Stage Collar set +/- 200' TVD below permafrost Power Cable for ESP MandrelNalve to circulate well for freeze protection purposes ESP Pump Section .......... ESP Gearbox ESP Motor Section D Sand Frac-Pack Assembly with Screen B + A4 Sands Frac-Pack Assembly with Screen A3 Sand Frac-Pack Assembly with Screen 7-5/8" Combination Surface/Production Casing, Cemented to Surface A2 Sand Frac-Pack with Scree ARCO Alaska, Inc. TAB, 10/27/97, Rev.2 KUPARUK RIVER UNIT- WEST SAK OPERATIONS 20" DIVERTER SCHEMATIC · .. I 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVEAND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"cONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3.' DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"- 2000 PSI ANNULAR PREVENTER. TWM, 9/15/97 'h I I 8 6 5 4 3 2 13 5/8" 5000 PS BOP STACK West Sak Operations - Producer Wells ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2 CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOq-rOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN TIlE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 6" OR 4-1/2" TO 7" PIPE ODS AS APPROPRIATE. 1. 16"- STARTING HEAD 2. 11" - 5000 PSI HORIZONTAL TUBING HEAD 3. 11" 5000 PSI X 13-5/8" 5000 PSI DOUBLE STUDDED ADAPTER/SPACER SPOOL 4. 13-5/8" - 5000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 5. 13-5/8"- 5000 PSI PIPE RAMS 6. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 7. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 8. 13-5/8" -5000 PSIANNULAR TWM, 9/22/97 i AK ~ I , '~ SURLY ~ 14.13 , ~ * ,,~ ~ ~CINI TY MAP ~ , 117 ~ i SCALE: 1" = I MILE I 119 ~ I ii 1201121 _ ~ 124 i ~T 129 i ~ i 1~5 I I .... I 68 I NO S~ ~ o LEGEND o ~s~a co~cro~s ~ LOUNSBURY · NEW CONDUCTOR LOCAnON~'~/~ k ASSOCIATES, INC. ~--E~NEE. P~NE. SUR~O. ~EA' 1D W~ULE XX UNIT' D1 ~ DRILL SI[ 1-D A R C O A la s k a, In c. ~r ~sm SAK PHASE I - ~ CONDUCTORS AS-BUILT CADD FILE NO. J J DRA. NG NO: I~T= m~v= LK610410 9/02/97 CEA-D1DX-6104D10 1 ~ 2 2 REV I -'.ATE i i3Y i CK I APID I DESCRIPTION N 0 TES . 1. COORDINATES SHOWN ARE A.S,P. ZONE 4, N.A.D. 27. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN Z£A LEVEL. ALL DISTANCES SHOWN ARE TRUE. REV I2 !o/ 7/o7! AoR, / , D.S.18 2. £ASIS OF LOCATIONS AND ELEVATIONS ARE D.S. 1-D MONUMENTS PER LHD AND ASSOCIA ]"ES. DESCRIPTION AS-BUILT PER KSBI KgT082ACS / \ \ 4. . CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS ~4 & 23, TOWNSHIP 11 NORTH. RANGE 10 EAST, U,M. DATE OF SURVEYS: 8/25, 29 & 50/97, FIELD BK L97-24, pp. 32 - 45. 68 - 73. DRILL SITE 1-0 GRID NORTH IS ROTATED 00' 01' 05~ 'WEST FROM A.S.P. ZONE 4 GRID NORTH. SEE DRAWING NSK-J. 5-1 FOR AS-BUILT LOCATIONS OF CONDUCTORS titl THROUGH 1~t8. ~-c~', ,," "4 . :.: WEST SAK- 1 THIS SURVEY 22 VICINITY MAP SCALE: I~ = i:: MILE 'i: ; Well SEC.' SEC.-' PAD O.G. No. ,y, A.S.P. s 'X' LA TI TUDE LONGITUDE ~J~ L~/~ ELEV. ELEV. S~.c. 14, T. 11 N.,R. IO £. F.S.L.F.£.L. 105 5,959,798.99 560,490.57 70' 18' 02.637' 149' 30' `76.263' I,74' 595' 70.5' 62.0' 106 5,959,768.9,1 560,490.67 70' 18' 02.341' 149' 30' ,76,268' 104' 595' 70.4' 62.3' 109 5,959,72,.7.89 560,490.60 70' 18' 01,898' 149' 30' ,76,280' 59' 596' 70.4' S,~.c. 23, T. 11 N., R. 10 E. F.N.L. F.£.L. 115 5,959,603.93 560,490,68 70' 18' .00.718' 149' 30' 36.306' 61' 597' 70.4' 6`7.4'I 117 5,959,57,7.95 5~0,490.65 70' 18' 00.42`7' 149' `70' `76..t14' 91' 597' 70.4' 6`7.4' 118 5,959,558.95 560,490.68 70' 18' 00.276' I49' $0' 36,316' 106' 597' 70.4' 63.4' 119 5,959,513.86 560,490.72 70' 17' 59,832' 149' 30' `76.$26' I51' 598' 70,6' 66.0' 120 5,959,499.01 560,490.77 70' 17' 59.686' 149' 30' ,36.327' 166' 598' 70.6" 66.0' 12i 5,959,483.89 560,490.67 70' 17' 59.5,78' 149' ,SO' `76.`7`75' 181' 598' 70.5' 66.0 124 5,959,393.96 560,490.70 70' 17' 58.65,7' I49' ,70' `76.,155' 271' 599' 70.`7' 65.0' 129 5,959,27,7.92 560,490. 79 70' 17' 57.472' 149' ,70' ,76.380' $91' 600' 70,$' 68.2' l JO 5,959,259.09 560,490.81 70' 17' 57.,726' I49' ,70' ,76.38,7" 406' 600' 70.5' 68,2' 1.73 5,959.21.7.89 560,490.68 70' 17' 56,882' 149' .70' 36,397" 451' 600' 70.4' 69.0' 1J5 5,959,139.02 560,490.80 70' 17' 56.146' 149' ,70' ,76.412' 526' 60I' 70.5' 69,4' SURVEYOR'S CER TIFICA T~ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLA T REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION ANO THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AUGUST 30, 1997. ARCO Alaska, LK610410 9//02/97 LOUNSBURY & ASSOCIATES, INC. E~NEERS PLANNERS SURVEYORS AREA' 1D MOOULE' XX DRILL SITE 1-D WEST SAK PHASE I - WELL CONDUCTORS AS-BUILT CEA-D1DX-6104.D10 ISHEET:2 ~2 I~EV:' UNIT' D1 2 · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~2/ ~O,}So INIT CLASS · WELL NAME ~'~.PE.t/. //""C_-2,,~ ¢/ GEOL AREA PROGRAM: exp [] dev./~redrll [] serv [] wellbore seg D ann. disposal para req [] P~C:~ UNIT# /,/,'/~',¢ ON/OFF SHORE ~ ADMINISTRATION , 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. APRR DAT,,,E / 12. _---k~z~' ~~' 13. ENGINEERING GEOLOGY APPR DATE Permit fee attached ....................... N Lease number appropriate ................... N Unique well name and number .................. N Well located in a defined pool .................. N Well located proper distance from drilling unit boundary .... N Well located proper distance from other wells .......... N Sufficient acreage available in drilling unit ............ N If deviated, is wellbore plat included ............... N Operator only affected party ................... N Operator has appropriate bond in force ............. N Permit can be issued without conservation order ........ N Permit can be issued without administrative approval ...... N Can permit be approved before 15-day wait ........... N 14. Conductor string provided ................... N 15. Surface casing protects all known USDWs ........... N 16. CMT vol adequate to circulate on conductor & surf csg ..... N 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C. T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. N 23. If diverter required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ...... 26. BOPE press rating appropriate; test to ~' ' ' 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y 30. Permit can be issued w/o hydrogen sulfide measures ..... YY N,,/ ,, ,,~ 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. "' 33. Seabed condition survey (if off-shore) ............. /Y N 34. Contact name/phone for we_eklyprogress reports ...... ,,X. Y N lexploratory only] REMARKS GEOLOGY: ENGINEERING: COMMISSION.;,.., R P C~,~C_, BEV~-_ hl~' DWJ~ JDH ~ ' RNC~ co ~ HOW/lit- A:\FORMS\cheklist rev 09/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon Dec 15 17:17:44 1997 Reel Header Service name ............. LISTPE Date ..................... 97/12/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/12/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION D~TE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 1 AK-MM-80011 S. BURKHARDT D. BREEDEN ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: Dato~{ 1D-133 ?B1 500292282??0 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 15-DEC-97 23 llN 10E 451 600 .0O 111.40 70.40 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9. 875 3252.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WkVE RESISTIVITY PHASE-4 (EWR4) 3. MWD RUN 1 REPRESENTS WELL 1D-133 PB1 WITH API #: 50-029-22827-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 3252'MD, 2560'TVD. - SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP S PACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE RPD RPM RPS RPX GR FET ROP $ START DEPTH STOP DEPTH 77.0 3207.0 77.0 3207.0 77.0 3207.0 77.0 3207.0 85.5 3215.0 122.0 3207.0 122.0 3252.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH - BIT RUN NO MERGE TOP MERGE BASE 1 121.0 3252.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 RPX MWD OHM- 4 1 68 8 3 RPS MWD OHM- 4 1 68 12 4 RPM MWD OHM- 4 1 68 16 5 RPD MWD OHM- 4 1 68 20 6 ROP MWD FT/H 4 1 68 24 7 FET MWD FT 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 121 3252 1686.5 6263 121 GR 9.5394 106.523 52.6069 6189 121 RPX 0.8816 2000 60.8648 6173 121 RPS 0.8182 1409.65 64.583 6173 121 RPM 0.3799 2000 95.9874 6173 121 RPD 0.4249 2000 161.269 6173 121 ROP 9.0352 1863.66 236.891 6261 122 FET 0.1142 8.714 0.525405 6171 122 Last Reading 3252 3215 3207 3207 3207 3207 3252 3207 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 3252 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH R?D 77.0 RPM 77.0 RPS 77.0 RPX 77.0 GR 85.5 FET 122.0 ROP 122.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 3207.0 3207.0 3207.0 3207.0 3215.0 3207.0 3252.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 16-NOV- 97 ISC 5.06 CIM 5.46 MEMORY · · 3252.0 121.0 3252.0 1.8 57.3 TOOL NUMBER P0863CRG6 P0863CRG6 9.880 9.9 SPUD MUD 180.80 MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 400.0 8.0 55O 6.8 4.200 4.015 5.000 2.800 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 RPX MWD 1 OHM~ 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 28.9 First Name Min Max Mean Nsam Reading DEPT 121 3252 1686.5 6263 121 GR 9.5394 106.523 52.6069 6189 121 RPX 0.8816 2000 60.8648 6173 121 RPS 0.8182 1409.65 64.583 6173 121 RPM 0.3799 2000 95.9874 6173 121 RPD 0.4249 2000 161.269 6173 121 ROP 9.0352 1863.66 236.891 6261 122 FET 0.1142 8.714 0.525405 6171 122 Last Reading 3252 3215 3207 3207 3207 3207 3252 3207 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 3252 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/12/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/12/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF PhysiCal EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Tue Dec 16 13:54:30 1997 Reel Header Service name ............. LISTPE Date ..................... 97/12/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN. Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/12/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 1 AK-MM-80011 S. BURKHARDT D. BREEDEN Date~l 1D-133 500292282700 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 16-DEC-97 MWD RUN 2 AK-MM-80011 P. SMITH D. BREEDEN 23 liN 10E 451 600 .00 111.40 70.40 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE 'CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 5265.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) 'UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) 3. THE WELL WAS SIDETRACKED (INADVERTANTLY) AT 1930'MD, 1804'TVD. THE SIDE- TRACK WAS NOT DISCOVERED UNTIL 2082 'MD. LOGGING WAS STARTED AT A DEPTH OF 2050'MD, 1890'TVD (DGR SENSOR DEPTH). 4. DEPTH SHIFT/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN MIKE WERNER OF ARCO ALASKA, INC. AND MARSHALL MUNYAK OF SPERRY-SUN DRILLING SERVICES ON 12/12/97. 5. MWD RUNS 1 AND 2 REPRESENT WELL 1D-133 WITH API#: 50-029-22827-00. THIS WELL REACHED A TOTAL DEPTH OF 5265'MD, 4241'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comraent Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FET 121.0 5220.5 RFD 121.0 5220.5 RPM 121.0 5220.5 RPS 121.0 5220.5 RPX 121.0 5220.5 GR 121.0 5228 . 5 ROP 122.0 5265.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 121.0 3252.0 2 1930.0 5265.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OH/V~ 4 1 68 RPS MWD OH/V~ 4 1 68 RPM I~rWD OITMM 4 1 68 RPD MWD OHF94 4 1 68 FET MWD HOUR 4 1 68 ROP MWD FT/H 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 121 5265 2693 10289 GR 6.4254 110.918 55.0528 9908 RPX 0.8816 637.102 37.804 9894 RPS 0.9318 700.903 41.4124 9894 RPM 0.7506 2000 60.9856 9894 RPD 0.4249 2000 98.7748 9894 FET 0.0714 8.8927 0.514374 9894 ROP 15.2097 1878.88 261.704 9981 First Reading 121 121 121 121 121 121 121 122 Last Reading 5265 5228.5 5220.5 5220.5 5220.5 5220.5 5220.5 5265 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 5265 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ....... - .... 1.0.0 Date of Generation ....... 97/12/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 121.0 1885.0 RPD 121.0 1885.0 RPM 121.0 1885.0 RPS 121.0 1885.0 RPX 121.0 1885.0 GR 121.0 1893.0 ROP 122.0 1930.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ~GLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY 16-NOV-97 ISC 5.06 CIM 5.46 MEMORY 3252.0 121.0 3252.0 1.8 57.3 TOOL NUMBER P0863CRG6 EWR4 $ ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 P0863CRG6 9.880 9,9 S PUD MUD 180.80 400.0 8.0 550 6.8 4.200 4.015 5.000 2.800 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP I~D 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 28.9 First Name Min Max Mean Nsam Reading DEPT 121 1930 1025.5 3619 121 GR 10.2933 106.523 52.1999 3545 121 RPX 0.8816 637.102 79.6937 3529 121 Last Reading 1930 1893 1885 RPS 0.9318 700.903 88.3044 3529 RPM 0.7506 2000 135.991 3529 RPD 0.4249 2000 222.632 3529 ROP 32.4379 1863.66 225.012 3617 FET 0.1459 1.5732 0.422988 3529 121 121 121 122 121 1885 1885 1885 1930 1885 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 1930 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD 2038.0 RPM 2038.0 RPS 2038.0 FET 2038.5 RPX 2038.5 GR 2047.5 ROP 2083.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): STOP DEPTH 5220 5 5220 5 5220 5 5220 5 5220 5 5228 5 5265 0 18-NOV-97 ISC 5.06 CIM 5.46 MEMORY 5265.0 2082.0 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: ~AXIMUMANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEJtSURED TEMPERATURE (MT): MUD AT MT~ CIRCULATING TERMPER~TURE: MUD FILTRATE AT MT: MUD CTkKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ............... i.Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 52 65.0 20.0 59.0 TOOL NIIMBER P0863CRG6 P0863CRG6 9.880 9.9 S PUD MUD 184.60 600.0 8.5 5OO 6.6 4.250 3.390 4.400 5.500 40.4 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 RPX MWD 2 OHM>4 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMS4 4 1 68 20 6 FET I~D 2 HOUR 4 1 68 24 7 ROP MWD 2 FT/H 4 1 68 28 Name Min Max Mean DEPT 2038 5265 3651.5 GR 6.4254 110.918 56.6422 RPX 1.5944 398.051 14.5788 RPS 1.589 407.75 15.4174 RPM 1.7445 2000 19.4027 RPD 1.8621 2000 30.106 FET 0.0714 8.8927 0.565042 ROP 15.2097 1878.88 282.707 Nsam 6455 6363 6365 6366 6366 6366 6365 6347 First Reading 2038 2047.5 2038.5 2'038 2038 2038 2038.5 2083.5 Last Reading 5265 5228.5 5220.5 5220.5 5220.5 5220.5 5220.5 5265 First Reading For Entire File .......... 2038 Last Reading For Entire File ........... 5265 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/12/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/12/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File