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Home My WebLink About205-0211. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8450' None Casing Collapse Structural Conductor Surface Intermediate Production Scab 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: 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 (907) 265-6362 Staff Well Interventions Engineer KRU 3H-14B 6409' 5593' 4530' 5593' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Anne.Claudel@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): Packer: 6039' MD and 4848' TVD Packer: 7696' MD and 5866' TVD Packer: 7726' MD and 5884' TVD Packer: 7780' MD and 5916' TVD SSSV: N/A Anne Claudel STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025531 205-021 P.O. Box 100360, Anchorage, AK 99510 50-103-20092-02-00 Kuparuk River Field Kuparuk River Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst 8450' MD MD 115' 3002' 115' 3456' 6221'8220' 16" 9-5/8" 79' 3421' 7884-7888', 8147-8157', 8172-8187', 8212-8222' 8187' 5-1/2" 5981-5984', 6165-6172', 6184- 6195', 6214-6223' 7" Perforation Depth TVD (ft): 10/20/2025 7925'1886' 3-1/2" 6007' Packer: Baker CPH Liner Top Packer Packer: Paragon II Patch Packer Packer: Paragon II Patch Packer Packer: Baker HR ZXP Liner Top Packer SSSV:None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 7:35 am, Oct 09, 2025 325-614 DSR-10/15/25 A.Dewhurst 10OCT25 A.Dewhurst 23OCT25 AOGCC witnessed Tag TOC. AOGCC witnessed cement plug MIT-T to 1500 psi. J.Lau 11/14/25 X 10-407 X 11/17/2030 11/17/25 3H-14 Anne Claudel (281-556-3517) Background & Objec ve Wellview well schematics is believed to show wrong cement tops. 3H-14B is a multilateral well, completed with 5½ scab liner (sidetracked from 7 motherbore at ~6,227ft KB), 3½ tubing/liner, and 2-3/8 slotted liner (sidetracked from 3½ liner at ~8,025ft KB). A rig workover in 2021 failed to meet the objective of pulling and replacing tubing. With rig options exhausted, it had been determined that the best path forward was to suspend the well and access the stranded resource with a redrill. During the rig workover, the 3½ tubing was cut and pulled from 7,645ft KB, leaving behind a 3-1/2 tubing stub, with stuck tubing patch packer inside. Before moving off, the rig set a kill string (3½ tubing, rerun) at 2,519ft KB. Suspension operations were performed in 2022: CT pumped 55bbls of 15.8ppg class G cement down the 3.5 tubing and laid in 3bbls above the tubing cut at 7,645. Top of cement reported by CT is 7,519 RKB. 8 days later, SL tagged top of cement at 5,593 SLM. Due to the ~2,000 of discrepancy between ToC reported by CT and SL tag, it is suspected that SL tagged cement stringers on the low side. No cement retainer was used. It is not clear where the top of good quality cement is; it could be below the scab liner packer on the high side. Deviation at scab liner packer is 44deg. It is also not clear which set of perforations were squeezed with cement. Surface pressure shows 1600psi. This procedure outlines the steps for another suspension attempt. Per this procedure, suspended operations will be performed by circulating 90 bbls of 15.8 ppg Class G cement to place on top of the existing cement in the 3.5 tubing possibly and in the 7 casing to cover the scab liner packer at 6,039 up to 4,000. No expandable cement retainer can be used as they are not millable. Well Data The well is currently shut in, with 3 ½ kill string installed to 2,519ft KB. 3.5 Tubing cut at 7,645ft KB. Stuck patch at 7,695ft KB (min ID = 1.59) 5.5 liner packer at 6,039. 3.5 liner cut at 7,645. 5/25/25: CMIT T X IA (PASS) @ 2300 PSI. T X IA CDDT (FAIL) : Bled T x IA down simultaneously to 0 psi. Left open to breathe for 3 hrs. SI for 60 min monitor. Initial T/I/O= 0+/0+/3 15 min T/I/O= 4/4/3 (+4/+4) 30 min T/I/O= 7/7/3 (+3/+3) 45 min T/I/O= 10/10/3 (+3/+3) 60 min T/I/O= 14/14/3 (+4/+4) Final T/I/O= SI 14/14/3 6/20/22: T/I/O = SI 1600/1600/10 1/31/22: TAG TOP OF CEMENT @ 5593' SLM. PERFORM PASSING CMIT (TXIA) TO 1500 PSI. 1/23/22: CT calculated ToC @ 7,519RKB. CT pumped slick diesel after pumping cement. Calcs/Fluids 7 capacity (6.28 ID) = 0.038 bbl/ft 3.5 capacity (2.99 ID) = 0.0087 bbl/ft Worst case assuming no cement from 7,519 up = 90 bbls: o 7,519- 6,039= 1,480 in 3.5 = 13bbls o 6,039- 4,000 = 2,039 in 7 = 77 bbls If there is cement from SL tag at 5,593 up, 90 bbls in 7 casing = 2,349. Procedure Coil 1. Rig up Coiled Tubing with 2 pipe and Cementers. Pressure test surface equipment as required. 2. Fluid pack the well. Gas in the well will result in a poor cement job. 3. RIH with the CT cementing BHA as deep as possible. SL tagged at 5,593. If CT can go deeper, keep RIH. Record tag depth. 4. With BHA positioned 1ft above obstruction, begin pumping the following keeping back pressure at surface to avoid gas migrating and creating channels: a. 10 bbl FW spacer b. 90 bbls of cement c. 10 bbl FW spacer d. Displace with diesel 5. With approximately 50 of cement out of the nozzle, begin to pull out of hole, laying in cement, taking 1 for 1 returns up the coil tubing backside. 6. Continue to lay in cement, placing 90 bbls of cement in 7 production casing from tag depth. 7. Freeze protect well with diesel. Slickline 1. WOC for minimum 48 hours or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. RIH and tag TOC (AOGCC witness) 3. Pressure test plug (MIT-T) to 1500 psi (AOGCC witness) and perform a TxIA CDDT. Monitor surface pressure for 30 days for build up to proper suspension. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM, TOC 5,593.0 3H-14B 1/31/2022 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Tag TOC - Added Cement Icons 3H-14B 2/28/2022 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: **TUBING COMPONENT DEPTHS QUESTIONABLE** TALLY/DETAIL SHEETS VARY 3/1/2011 lmosbor NOTE: CHEMICAL CUT 3H-14BL4 LINER TOP DOWN TO 8040' CLEAR 3H-14B LINER 2/28/2006 lmosbor NOTE: MULTI-LATERAL WELL: 3H-14B/3H-14BL1/3H-14BL2/3H-14BL3/ 3H-14BL4 1/22/2006 lmosbor NOTE: 3H-14BL1(OPEN HOLE PILOT HOLE - PLUGGED OFF) 1/22/2006 lmosbor NOTE: 3H-14BL4 **ONLY ACCESSIBLE LEG** 1/22/2006 lmosbor NOTE: WELL SIDETRACKED FOR SECOND TIME 4/21/2005 lmosbor NOTE: WAIVERED WELL: IA x 0A COMMUNICATION 9/16/1999 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.2 3,455.6 3,002.4 36.00 J-55 BTC PRODUCTION 7 6.28 33.0 8,220.2 6,221.2 26.00 J-55 BTC Window L4 7 6.00 8,016.0 8,026.0 6,075.2 9.30 SCAB LINER 5 1/2 4.95 6,038.9 7,925.0 6,007.4 15.50 L-80 HYDRIL511 LINER 3 1/2 3 1/2 2.99 7,780.3 8,450.0 6,408.6 9.30 L-80 HYDRIL 511 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.3 Set Depth 2,519.2 Set Depth 2,345.9 String Max No 3 1/2 Tubing Description Tubing Kill String 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) 35.3 35.2 0.08 Hanger 3.500 Hanger/Pup 2.992 Top (ftKB) 7,645.0 Set Depth 7,801.1 Set Depth 5,928.9 String Max No 3 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD 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) 7,705.7 5,871.5 53.45 GAS LIFT 4.725 CAMCO KBG-2-9 2.900 7,747.8 5,896.7 53.14 NIPPLE 4.520 CAMCO D NIPPLE W/ NO GO PROFILE 2.750 7,789.1 5,921.6 52.82 SEAL ASSY 4.125 BAKER SEAL ASSEMBLY (3 SETS) 2.990 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) 7,695.0 5,865.2 53.52 PATCH - UPR PKR (ME) P2P UPR PKR, OAL 4' CPP3 5243 3/1/2020 1.625 7,699.0 5,867.6 53.50 ANCHOR LATCH 33' SPACER PIPE w/ ANCHOR LATCH CPAL 35147 3/1/2020 1.590 7,714.0 5,876.5 53.39 LEAK LARGE LEAK FOUND @ ST#4 GLM 2/18/2015 0.000 7,728.0 5,884.9 53.28 PATCH - LWR PKR (ME) P2P LWR PKR, OAL 4' CPP3 5244 3/1/2020 1.625 8,025.0 6,074.4 43.02 Whipstock Weatherford Whipstock (Could not be Pulled) 4/18/2005 8,223.0 6,223.4 37.45 RETAINER B LINER HES EZ-DRILL SVB RETAINER 5/13/2005 2.690 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,038.9 4,848.1 44.44 PACKER 6.070 BAKER CPH LINER TOP PACKER-7 x 5.5" 4.830 7,780.3 5,916.3 52.89 PACKER 5.500 BAKER HR ZXP LINER TOP PACKER 5-1/2" x 3-1/2" (Comm #H296-28-00579) 3.500 7,813.8 5,936.6 52.11 XO Threads 3.500 Crossover 3-1/2" SLHT box X 3- 1/2" Hydril 511 pin 2.992 8,383.2 6,353.3 34.43 LANDING COLLAR 3.500 LANDING COLLAR 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,884.0 7,886.0 5,981.0 5,982.3 5/18/2005 4.0 IPERF Shot TBG punch holes (9) 7,886.0 7,888.0 5,982.3 5,983.5 5/13/2005 4.0 IPERF Shot TBG punch holes (9) 8,147.0 8,157.0 6,164.5 6,172.0 A-3, 3H-14B 10/7/2005 6.0 APERF 2.5" PJ 2506, 60° phase 8,172.0 8,182.0 6,183.5 6,191.2 A-2, 3H-14B 8/9/2005 6.0 APERF 2.5" HSD, 60° phase 8,182.0 8,187.0 6,191.2 6,195.1 A-2, 3H-14B 8/9/2005 6.0 APERF 2.5" HSD, 60° phase 8,212.0 8,222.0 6,214.7 6,222.6 A-1, 3H-14B 10/7/2005 6.0 APERF 2.5" PJ 2506, 60° phase 3H-14B, 9/29/2025 5:58:55 PM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Primary Full Bore; 3,450.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 Squeeze Behind Casing Squeeze; 1,852.0 ftKB Primary Full Bore; 42.0 ftKB CONDUCTOR; 36.0-115.0 Tubing Pup; 36.4 Hanger; 35.3 KUP PROD KB-Grd (ft) 42.01 RR Date 12/14/198 7 Other Elev 3H-14B ... TD Act Btm (ftKB) 8,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009202 Wellbore Status PROD Max Angle & MD Incl (°) 55.50 MD (ftKB) 7,048.39 WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 H2S (ppm) 160 Date 2/23/2019 Comment SSSV: TRDP Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 8,172.0 8,187.0 1 FRAC 8/28/2005 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,593.0 9,535.0 4,530.0 Cement Plug 5,593.0 9,535.0 4,530.0 Cement Plug 1/23/2022 3H-14B, 9/29/2025 5:58:55 PM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Primary Full Bore; 3,450.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 Squeeze Behind Casing Squeeze; 1,852.0 ftKB Primary Full Bore; 42.0 ftKB CONDUCTOR; 36.0-115.0 Tubing Pup; 36.4 Hanger; 35.3 KUP PROD 3H-14B ... WELLNAME WELLBORE3H-14B Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,975.0 3H-14BL1 3/16/2015 hipshkf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: SET PACKER 3H-14BL1 12/30/2015 lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread OPEN HOLE L1 4 3/8 8,285.0 9,200.0 6,169.7 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,720.0 6,110.4 89.57 PLUG IBP SET IN OPEN HOLE FOR PLUG BACK 1/11/2006 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,285.0 6,105.9 93.28 OPEN HOLE L1 4.375 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,593.0 10,133.0 4,530.0 Cement Plug 1/23/2022 3H-14BL1, 9/29/2025 5:58:56 PM Vertical schematic (actual) OPEN HOLE L1; 8,285.0- 9,200.0 PLUG; 8,720.0 PRODUCTION; 33.0-8,220.2 LINER 3 1/2; 7,780.3-8,450.0 Window L4; 8,016.0-8,026.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Primary Full Bore; 3,450.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 Squeeze Behind Casing Squeeze; 1,852.0 ftKB Primary Full Bore; 42.0 ftKB CONDUCTOR; 36.0-115.0 Tubing Pup; 36.4 Hanger; 35.3 KUP PROD KB-Grd (ft) 42.01 RR Date 12/14/198 7 Other Elev 3H-14BL1 ... TD Act Btm (ftKB) 9,200.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009260 Wellbore Status PROD Max Angle & MD Incl (°) 94.66 MD (ftKB) 8,240.72 WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 H2S (ppm) 160 Date 2/23/2019 Comment SSSV: TRDP Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,975.0 3H-14BL2 3/16/2015 hipshkf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: SET PACKER 3H-14BL2 12/30/2015 lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Liner L2 2 3/8 1.99 9,123.2 10,133.0 6,114.9 4.44 L-80 STL 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) 9,122.0 6,110.8 87.95 SPEAR L2 LINER WEATHERFORD GS ANTI-TURN SPEAR CONNECTING SECTION 1 & 2 OF LINER 1/11/2006 0.750 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,123.2 6,110.9 87.95 DEPLOY 2.375 BTT SEAL BORE DEPLOYMENT SLEEVE 1.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,870.0 9,122.0 6,112.5 6,110.8 A-2, 3H-14BL2 1/11/2006 40.0 SLOTS Alternating slotted/solid pipe 9,124.0 9,257.0 6,110.9 6,116.9 A-2, 3H-14BL2 1/11/2006 40.0 SLOTS Alternating slotted/solid pipe 9,667.0 10,132.0 6,115.8 6,114.8 A-3, A-4, UNIT D, 3H-14BL2 1/11/2006 40.0 SLOTS Alternating slotted/solid pipe 3H-14BL2, 9/29/2025 5:58:57 PM Vertical schematic (actual) Liner L2; 9,123.2-10,133.0 SLOTS; 9,667.0-10,132.0 SLOTS; 9,124.0-9,257.0 SPEAR; 9,122.0 SLOTS; 8,870.0-9,122.0 LINER 3 1/2; 7,780.3-8,450.0 Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Primary Full Bore; 3,450.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 Squeeze Behind Casing Squeeze; 1,852.0 ftKB Primary Full Bore; 42.0 ftKB CONDUCTOR; 36.0-115.0 Tubing Pup; 36.4 Hanger; 35.3 KUP PROD KB-Grd (ft) 42.01 RR Date 12/14/198 7 Other Elev 3H-14BL2 ... TD Act Btm (ftKB) 10,774.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009261 Wellbore Status PROD Max Angle & MD Incl (°) 94.66 MD (ftKB) 8,240.72 WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 H2S (ppm) 160 Date 2/23/2019 Comment SSSV: TRDP Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,975.0 3H-14BL3 3/16/2015 hipshkf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: SET PACKER 3H-14BL3 12/30/2015 lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Liner L3 2 3/8 1.99 9,179.0 10,106.0 6,113.0 4.44 L-80 STL Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,203.0 10,105.0 6,086.6 6,113.0 A-3, A-4, A-3, A- 4, UNIT D, 3H- 14BL3 1/14/2006 40.0 SLOTS Slotted Tubing 3H-14BL3, 9/29/2025 5:58:57 PM Vertical schematic (actual) Liner L3; 9,179.0-10,106.0 SLOTS; 9,203.0-10,105.0 Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Primary Full Bore; 3,450.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 Squeeze Behind Casing Squeeze; 1,852.0 ftKB Primary Full Bore; 42.0 ftKB CONDUCTOR; 36.0-115.0 Tubing Pup; 36.4 Hanger; 35.3 KUP PROD KB-Grd (ft) 42.01 RR Date 12/14/198 7 Other Elev 3H-14BL3 ... TD Act Btm (ftKB) 10,106.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009262 Wellbore Status PROD Max Angle & MD Incl (°) 95.55 MD (ftKB) 9,122.80 WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 H2S (ppm) 160 Date 2/23/2019 Comment SSSV: TRDP 3H-14BL3, 9/29/2025 5:58:58 PM Vertical schematic (actual) Liner L3; 9,179.0-10,106.0 SLOTS; 9,203.0-10,105.0 Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Primary Full Bore; 3,450.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 Squeeze Behind Casing Squeeze; 1,852.0 ftKB Primary Full Bore; 42.0 ftKB CONDUCTOR; 36.0-115.0 Tubing Pup; 36.4 Hanger; 35.3 KUP PROD 3H-14BL3 ... WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,975.0 3H-14BL4 3/16/2015 hipshkf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FOUND NEW TUBING LEAK 3H-14BL4 9/21/2020 condijw Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Liner L4 2 3/8 1.99 8,040.0 9,532.0 6,093.5 4.40 L-80 STL Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,498.9 6,094.1 90.10 O-RING 2.392 L4 LINER BTT O-RING SUB 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,243.0 9,499.0 6,108.7 6,094.1 A-3, A-4, A-3, 3H -14BL4 1/19/2006 40.0 SLOTS Slotted Tubing 3H-14BL4, 9/29/2025 5:58:59 PM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Primary Full Bore; 3,450.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 Squeeze Behind Casing Squeeze; 1,852.0 ftKB Primary Full Bore; 42.0 ftKB CONDUCTOR; 36.0-115.0 Tubing Pup; 36.4 Hanger; 35.3 KUP PROD KB-Grd (ft) 42.01 RR Date 12/14/198 7 Other Elev 3H-14BL4 ... TD Act Btm (ftKB) 10,070.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009263 Wellbore Status PROD Max Angle & MD Incl (°) 96.94 MD (ftKB) 9,621.95 WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 H2S (ppm) 160 Date 2/23/2019 Comment SSSV: TRDP 3H-14BL4, 9/29/2025 5:58:59 PM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Primary Full Bore; 3,450.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 Squeeze Behind Casing Squeeze; 1,852.0 ftKB Primary Full Bore; 42.0 ftKB CONDUCTOR; 36.0-115.0 Tubing Pup; 36.4 Hanger; 35.3 KUP PROD 3H-14BL4 ... WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the Abandon box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer A.Dewhurst 10OCT25 325-614 A.Dewhurst 10OCT25 205-021 KRU 3H-14B 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: 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 8450'feet 5593'feet true vertical 6409' feet None feet Effective Depth measured 5593'feet 6039', 7695', 7728', 7780' feet true vertical 4530'feet 4848', 5865', 5885', 5916' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7801' MD 5929' TVD Packers and SSSV (type, measured and true vertical depth) 6039' MD 7695' MD 7728' MD 7780' MD N/A 4848' TVD 5865' TVD 5885' TVD 5916' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool- SUSPENDED 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: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker CPH Liner Top Packer Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: Baker HR ZXP Liner Top Packer SSSV: None Dusty Freeborn Dusty.Freeborn@conocophillips.com 907-659-7224Staff Well Integrity Engineer 7884-7888', 8147-8157', 8172-8187', 8212-8222' 5981-5984', 6165-6172', 6184-6195', 6215-6223' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 115' ~~~ SUSPENDED ~~ ~ measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-021 50-103-20092-02-00 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: ADL0025531 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3H-14B Plugs Junk measured Length Production Liner 8187' 1886' Casing 6221' 5-1/2" 8220' 7925' 6007' 3421' 115'Conductor Surface Intermediate 16" 9-5/8" 79' 3455' 3002' Burst Collapse 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 10:59 am, Sep 26, 2025 Digitally signed by Dusty Freeborn DN: CN=Dusty Freeborn, O=ConocoPhillips Alaska, OU=Well Integrity and Intervention, E= Dusty.Freeborn@conocophillips.com, C=US Reason: I am the author of this document Location: Anchorage, Alaska Date: 2025.09.24 11:16:59-08'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn J.Lau 11/5/25 RBDMS JSB 100225 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 8, 2025 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry KRU 3H-14B (PTD 205-021) Dear Commissioner Chmielowski: Enclosed please find the suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 3H-14B (PTD 205-021). The following documents are attached: - 10-404 Sundry - Suspended Well Inspection - Wellbore Schematic - Location Plot Plan - Photographs Please call me at 265-6218 if you have any questions. Sincerely, Dusty Freeborn Well Integrity Engineer ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: CN=Dusty Freeborn, O=ConocoPhillips Alaska, OU =Well Integrity and Intervention, E=Dusty.Freeborn@ conocophillips.com, C=US Reason: I am the author of this document Location: Anchorage, Alaska Date: 2025.09.24 11:18:34-08'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM, TOC 5,593.0 1/31/2022 3H-14B fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Tag TOC - Added Cement Icons 2/28/2022 3H-14B pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.2 Set Depth (ftKB) 3,455.6 Set Depth (TVD) … 3,002.4 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 8,220.2 Set Depth (TVD) … 6,221.2 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Casing Description Window L4 OD (in) 7 ID (in) 6.00 Top (ftKB) 8,016.0 Set Depth (ftKB) 8,026.0 Set Depth (TVD) … 6,075.2 Wt/Len (l… 9.30 Grade Top Thread Casing Description SCAB LINER OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 6,038.9 Set Depth (ftKB) 7,925.0 Set Depth (TVD) … 6,007.4 Wt/Len (l… 15.50 Grade L-80 Top Thread HYDRIL511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,038.9 4,848.1 44.44 PACKER BAKER CPH LINER TOP PACKER-7 x 5.5" 4.830 6,049.3 4,855.5 44.45 HANGER BAKER HMC LINER HANGER 4.920 Casing Description LINER 3 1/2 OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 7,780.3 Set Depth (ftKB) 8,450.0 Set Depth (TVD) … 6,408.6 Wt/Len (l… 9.30 Grade L-80 Top Thread HYDRIL 511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,780.3 5,916.3 52.89 PACKER BAKER HR ZXP LINER TOP PACKER 5-1/2" x 3- 1/2" (Comm #H296-28-00579) 3.500 7,807.1 5,932.5 52.36 HANGER BAKER HMC LINER HANGER 5-1/2" x 3-1/2" Comm #H292-23-0212) 3.500 Tubing Strings Tubing Description Tubing – Kill String String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 35.3 Set Depth (ft… 2,519.2 Set Depth (TVD) (… 2,345.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in) Make Model 35.3 35.2 0.08 Hanger 2.992 3.500 Tubing Description Tubing – Completion Lower String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,645.0 Set Depth (ft… 7,801.1 Set Depth (TVD) (… 5,928.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in) Make Model 7,705.7 5,871.5 53.45 GAS LIFT 2.900 4.725 CAMCO KBG-2-9 7,747.8 5,896.7 53.14 NIPPLE 2.750 4.520 7,789.1 5,921.6 52.82 SEAL ASSY 2.990 4.125 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,695.0 5,865.2 53.52 PATCH - UPR PKR (ME) P2P UPR PKR, OAL 4' 3/1/2020 1.625 CPP35243 7,699.0 5,867.6 53.50 ANCHOR LATCH 33' SPACER PIPE w/ ANCHOR LATCH 3/1/2020 1.590 CPAL 35147 7,714.0 5,876.5 53.39 LEAK LARGE LEAK FOUND @ ST#4 GLM 2/18/2015 0.000 7,728.0 5,884.9 53.28 PATCH - LWR PKR (ME) P2P LWR PKR, OAL 4' 3/1/2020 1.625 CPP35244 8,025.0 6,074.4 43.02 Whipstock Weatherford Whipstock (Could not be Pulled) 4/18/2005 8,223.0 6,223.4 37.45 RETAINER B LINER HES EZ-DRILL SVB RETAINER 5/13/2005 2.690 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,884.0 7,886.0 5,981.0 5,982.3 5/18/2005 4.0 IPERF Shot TBG punch holes (9) 7,886.0 7,888.0 5,982.3 5,983.5 5/13/2005 4.0 IPERF Shot TBG punch holes (9) 8,147.0 8,157.0 6,164.5 6,172.0 A-3, 3H-14B 10/7/2005 6.0 APERF 2.5" PJ 2506, 60° phase 8,172.0 8,182.0 6,183.5 6,191.2 A-2, 3H-14B 8/9/2005 6.0 APERF 2.5" HSD, 60° phase 8,182.0 8,187.0 6,191.2 6,195.1 A-2, 3H-14B 8/9/2005 6.0 APERF 2.5" HSD, 60° phase 8,212.0 8,222.0 6,214.7 6,222.6 A-1, 3H-14B 10/7/2005 6.0 APERF 2.5" PJ 2506, 60° phase Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 8/28/2005 8,172.0 8,187.0 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,593.0 9,535.0 4,530.0 Cement Plug Notes: General & Safety End Date Annotation 3/1/2011 NOTE: **TUBING COMPONENT DEPTHS QUESTIONABLE** TALLY/DETAIL SHEETS VARY 2/28/2006 NOTE: CHEMICAL CUT 3H-14BL4 LINER TOP DOWN TO 8040' CLEAR 3H-14B LINER 1/22/2006 NOTE: MULTI-LATERAL WELL: 3H-14B/3H-14BL1/3H-14BL2/3H-14BL3/ 3H-14BL4 1/22/2006 NOTE: 3H-14BL1(OPEN HOLE PILOT HOLE - PLUGGED OFF) 1/22/2006 NOTE: 3H-14BL4 **ONLY ACCESSIBLE LEG** 3H-14B, 2/28/2022 2:45:13 PM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 SEAL ASSY; 7,789.1 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 CONDUCTOR; 36.0-115.0 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 12/14/1987 3H-14B ... TD Act Btm (ftKB) 8,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009202 Wellbore Status PROD Max Angle & MD Incl (°) 55.50 MD (ftKB) 7,048.39 WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 H2S (ppm) 160 Date 2/23/2019 Comment SSSV: TRDP Notes: General & Safety End Date Annotation 4/21/2005 NOTE: WELL SIDETRACKED FOR SECOND TIME 9/16/1999 NOTE: WAIVERED WELL: IA x 0A COMMUNICATION 3H-14B, 2/28/2022 2:45:14 PM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 SEAL ASSY; 7,789.1 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 CONDUCTOR; 36.0-115.0 KUP PROD 3H-14B ... WELLNAME WELLBORE3H-14B “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 11/03/2025 InspectNo:susSTS250908135921 Well Pressures (psi): Date Inspected:9/6/2025 Inspector:Sully Sullivan If Verified, How?Other (specify in comments) Suspension Date:3/1/2022 #321-490 Tubing:1643 IA:1646 OA:0 Operator:ConocoPhillips Alaska, Inc. Operator Rep:Matt Miller Date AOGCC Notified:9/3/2025 Type of Inspection:Subsequent Well Name:KUPARUK RIV UNIT 3H-14B Permit Number:2050210 Wellhead Condition minor corrosion and chipping paint, wellhead is in a well house, no signs of leaks, detached from flowline, valves turn easily Surrounding Surface Condition clean, no subsidence Condition of Cellar dry gravel, no rubbish in cellar Comments Gauges were accurate and verified by calibrated digital gauge. Location was verified by plot map. Supervisor Comments Photos (5) attached. Failed suspension plug suspected; CPAI submitted a new Sundry Application to re-suspend the well, received by AOGCC 10/9/2025. Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, November 3, 2025              See Supevisor Comments re: equalized pressures in Tubing and IA - jbr 2025-0906_Suspend_KRU_3H-14B_photos_ss Page 1 of 3 Suspended Well Inspection – KRU 3H-14B PTD 2050210 AOGCC Inspection Rpt # susSTS250908135921 Photos by AOGCC Inspector S. Sullivan 9/6/2025 2025-0906_Suspend_KRU_3H-14B_photos_ss Page 2 of 3 2025-0906_Suspend_KRU_3H-14B_photos_ss Page 3 of 3 From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL]RE: CPAI 3H-14B (PTD #205-021) Suspended well with elevated pressure. Date:Wednesday, June 4, 2025 12:44:59 PM Attachments:image001.png 3H-14B CMIT & DDT 25 May 25.xlsx 3H-14B.pdf From: Freeborn, Dusty <Dusty.Freeborn@conocophillips.com> Sent: Wednesday, June 4, 2025 12:03 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; NSK Wells Integrity Eng CPF1 & CPF3 <n1617@conocophillips.com> Subject: RE: [EXTERNAL]RE: CPAI 3H-14B (PTD #205-021) Suspended well with elevated pressure. Victoria and Jack- CPAI has completed the initial diagnostics on 3H-14B (PTD #205-021). The well passed a CMIT-TxIA (kill string and IA) to 2300 psi but failed the kill string/IA draw down test (refer to attached 10-426 form for detailed results). The well has since stabilized at ~1600 psi on the kill string and IA and will be monitored for any changes. Currently the Well Interventions Engineer is evaluating the well for remediation options and once a plan is developed the proper notifications will be submitted as required. Please feel free to give me a call with any questions or concerns. Dusty Freeborn Well Integrity Engineer ConocoPhillips Alaska, Inc. Office phone: (907) 265-6218 Cell phone: (907) 830-9777 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Wednesday, May 14, 2025 1:25 PM To: Freeborn, Dusty <Dusty.Freeborn@conocophillips.com>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; NSK Wells Integrity Eng CPF1 & CPF3 <n1617@conocophillips.com> Subject: [EXTERNAL]RE: CPAI 3H-14B (PTD #205-021) Suspended well with elevated pressure. 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. 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. Thanks Dusty. Please keep us in the loop. Jack From: Freeborn, Dusty <Dusty.Freeborn@conocophillips.com> Sent: Wednesday, May 14, 2025 1:01 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; NSK Wells Integrity Eng CPF1 & CPF3 <n1617@conocophillips.com> Subject: CPAI 3H-14B (PTD #205-021) Suspended well with elevated pressure. Victoria & Jack, KUP 3H-14B (PTD# 205-021) was suspended 31 Jan 2022 by removing the tubing, placing cement top at 5593’ and installing a kill string. The well passed a CMIT-TxIA to 1500 psi and the subsequent suspended well inspection was completed on 20 June 2022. The T/I/O pressure was noted at 1600/1600/10 psi during the suspended well inspection. During a recent monitor of the well it was noted that the 1600/1600 psi was not intentionally installed and that the well potentially no longer meets the criteria of 20 AAC 25.110 (2)(A)(i). CPAI intends to conduct diagnostics to investigate the source of the elevated pressure. Depending on the results of the diagnostics, the proper notifications will be submitted as required. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Engineer ConocoPhillips Alaska, Inc. Office phone: (907) 265-6218 Cell phone: (907) 830-9777 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 205-021 Type Inj N Tubing 1678 2300 2220 2190 Type Test O Packer TVD 5593 BBL Pump 0.8 IA 1670 2300 2220 2190 Interval O Test psi 1500 BBL Return OA 5 5 5 5 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 205-021 Type Inj N Tubing 2190 0 4 7 10 14 Type Test O Packer TVD 5593 BBL Pump IA 2190 0 4 7 10 14 Interval O Test psi 1500 BBL Return OA 5 3 3 3 3 3 Result F Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 3H Pad G.Arend 05/25/25 Notes:Non-witnessed CMIT-TxIA of kill string/IA. Cement top is at 5593' Notes: 3H-14B 3H-14B Notes:Non-witnessed CDDT-TxIA of kill string/IA. Cement top is at 5593' Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)3H-14B CMIT DDT 25 May 25 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM, TOC 5,593.0 1/31/2022 3H-14B fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Tag TOC - Added Cement Icons 2/28/2022 3H-14B pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.2 Set Depth (ftKB) 3,455.6 Set Depth (TVD) … 3,002.4 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 8,220.2 Set Depth (TVD) … 6,221.2 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Casing Description Window L4 OD (in) 7 ID (in) 6.00 Top (ftKB) 8,016.0 Set Depth (ftKB) 8,026.0 Set Depth (TVD) … 6,075.2 Wt/Len (l… 9.30 Grade Top Thread Casing Description SCAB LINER OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 6,038.9 Set Depth (ftKB) 7,925.0 Set Depth (TVD) … 6,007.4 Wt/Len (l… 15.50 Grade L-80 Top Thread HYDRIL511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,038.9 4,848.1 44.44 PACKER BAKER CPH LINER TOP PACKER-7 x 5.5" 4.830 6,049.3 4,855.5 44.45 HANGER BAKER HMC LINER HANGER 4.920 Casing Description LINER 3 1/2 OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 7,780.3 Set Depth (ftKB) 8,450.0 Set Depth (TVD) … 6,408.6 Wt/Len (l… 9.30 Grade L-80 Top Thread HYDRIL 511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,780.3 5,916.3 52.89 PACKER BAKER HR ZXP LINER TOP PACKER 5-1/2" x 3- 1/2" (Comm #H296-28-00579) 3.500 7,807.1 5,932.5 52.36 HANGER BAKER HMC LINER HANGER 5-1/2" x 3-1/2" Comm #H292-23-0212) 3.500 Tubing Strings Tubing Description Tubing – Kill String String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 35.3 Set Depth (ft… 2,519.2 Set Depth (TVD) (… 2,345.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in) Make Model 35.3 35.2 0.08 Hanger 2.992 3.500 Tubing Description Tubing – Completion Lower String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,645.0 Set Depth (ft… 7,801.1 Set Depth (TVD) (… 5,928.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in) Make Model 7,705.7 5,871.5 53.45 GAS LIFT 2.900 4.725 CAMCO KBG-2-9 7,747.8 5,896.7 53.14 NIPPLE 2.750 4.520 7,789.1 5,921.6 52.82 SEAL ASSY 2.990 4.125 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,695.0 5,865.2 53.52 PATCH - UPR PKR (ME) P2P UPR PKR, OAL 4' 3/1/2020 1.625 CPP35243 7,699.0 5,867.6 53.50 ANCHOR LATCH 33' SPACER PIPE w/ ANCHOR LATCH 3/1/2020 1.590 CPAL 35147 7,714.0 5,876.5 53.39 LEAK LARGE LEAK FOUND @ ST#4 GLM 2/18/2015 0.000 7,728.0 5,884.9 53.28 PATCH - LWR PKR (ME) P2P LWR PKR, OAL 4' 3/1/2020 1.625 CPP35244 8,025.0 6,074.4 43.02 Whipstock Weatherford Whipstock (Could not be Pulled) 4/18/2005 8,223.0 6,223.4 37.45 RETAINER B LINER HES EZ-DRILL SVB RETAINER 5/13/2005 2.690 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,884.0 7,886.0 5,981.0 5,982.3 5/18/2005 4.0 IPERF Shot TBG punch holes (9) 7,886.0 7,888.0 5,982.3 5,983.5 5/13/2005 4.0 IPERF Shot TBG punch holes (9) 8,147.0 8,157.0 6,164.5 6,172.0 A-3, 3H-14B 10/7/2005 6.0 APERF 2.5" PJ 2506, 60° phase 8,172.0 8,182.0 6,183.5 6,191.2 A-2, 3H-14B 8/9/2005 6.0 APERF 2.5" HSD, 60° phase 8,182.0 8,187.0 6,191.2 6,195.1 A-2, 3H-14B 8/9/2005 6.0 APERF 2.5" HSD, 60° phase 8,212.0 8,222.0 6,214.7 6,222.6 A-1, 3H-14B 10/7/2005 6.0 APERF 2.5" PJ 2506, 60° phase Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 8/28/2005 8,172.0 8,187.0 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,593.0 9,535.0 4,530.0 Cement Plug Notes: General & Safety End Date Annotation 3/1/2011 NOTE: **TUBING COMPONENT DEPTHS QUESTIONABLE** TALLY/DETAIL SHEETS VARY 2/28/2006 NOTE: CHEMICAL CUT 3H-14BL4 LINER TOP DOWN TO 8040' CLEAR 3H-14B LINER 1/22/2006 NOTE: MULTI-LATERAL WELL: 3H-14B/3H-14BL1/3H-14BL2/3H-14BL3/ 3H-14BL4 1/22/2006 NOTE: 3H-14BL1(OPEN HOLE PILOT HOLE - PLUGGED OFF) 1/22/2006 NOTE: 3H-14BL4 **ONLY ACCESSIBLE LEG** 3H-14B, 2/28/2022 2:45:13 PM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 SEAL ASSY; 7,789.1 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 CONDUCTOR; 36.0-115.0 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 12/14/1987 3H-14B ... TD Act Btm (ftKB) 8,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009202 Wellbore Status PROD Max Angle & MD Incl (°) 55.50 MD (ftKB) 7,048.39 WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 H2S (ppm) 160 Date 2/23/2019 Comment SSSV: TRDP Notes: General & Safety End Date Annotation 4/21/2005 NOTE: WELL SIDETRACKED FOR SECOND TIME 9/16/1999 NOTE: WAIVERED WELL: IA x 0A COMMUNICATION 3H-14B, 2/28/2022 2:45:14 PM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 SEAL ASSY; 7,789.1 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 CONDUCTOR; 36.0-115.0 KUP PROD 3H-14B ... WELLNAME WELLBORE3H-14B CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CPAI 3H-14B (PTD #205-021) Suspended well with elevated pressure. Date:Wednesday, May 14, 2025 1:23:19 PM Attachments:image001.png AnnComm Surveillance TIO for 3H-14B.pdf From: Freeborn, Dusty <Dusty.Freeborn@conocophillips.com> Sent: Wednesday, May 14, 2025 1:01 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; NSK Wells Integrity Eng CPF1 & CPF3 <n1617@conocophillips.com> Subject: CPAI 3H-14B (PTD #205-021) Suspended well with elevated pressure. Victoria & Jack, KUP 3H-14B (PTD# 205-021) was suspended 31 Jan 2022 by removing the tubing, placing cement top at 5593’ and installing a kill string. The well passed a CMIT-TxIA to 1500 psi and the subsequent suspended well inspection was completed on 20 June 2022. The T/I/O pressure was noted at 1600/1600/10 psi during the suspended well inspection. During a recent monitor of the well it was noted that the 1600/1600 psi was not intentionally installed and that the well potentially no longer meets the criteria of 20 AAC 25.110 (2)(A)(i). CPAI intends to conduct diagnostics to investigate the source of the elevated pressure. Depending on the results of the diagnostics, the proper notifications will be submitted as required. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Engineer ConocoPhillips Alaska, Inc. Office phone: (907) 265-6218 Cell phone: (907) 830-9777 3H-14B 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM, TOC 5,593.0 1/31/2022 3H-14B fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Tag TOC - Added Cement Icons 2/28/2022 3H-14B pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.2 Set Depth (ftKB) 3,455.6 Set Depth (TVD) … 3,002.4 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 8,220.2 Set Depth (TVD) … 6,221.2 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Casing Description Window L4 OD (in) 7 ID (in) 6.00 Top (ftKB) 8,016.0 Set Depth (ftKB) 8,026.0 Set Depth (TVD) … 6,075.2 Wt/Len (l… 9.30 Grade Top Thread Casing Description SCAB LINER OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 6,038.9 Set Depth (ftKB) 7,925.0 Set Depth (TVD) … 6,007.4 Wt/Len (l… 15.50 Grade L-80 Top Thread HYDRIL511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,038.9 4,848.1 44.44 PACKER BAKER CPH LINER TOP PACKER-7 x 5.5" 4.830 6,049.3 4,855.5 44.45 HANGER BAKER HMC LINER HANGER 4.920 Casing Description LINER 3 1/2 OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 7,780.3 Set Depth (ftKB) 8,450.0 Set Depth (TVD) … 6,408.6 Wt/Len (l… 9.30 Grade L-80 Top Thread HYDRIL 511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,780.3 5,916.3 52.89 PACKER BAKER HR ZXP LINER TOP PACKER 5-1/2" x 3- 1/2" (Comm #H296-28-00579) 3.500 7,807.1 5,932.5 52.36 HANGER BAKER HMC LINER HANGER 5-1/2" x 3-1/2" Comm #H292-23-0212) 3.500 Tubing Strings Tubing Description Tubing – Kill String String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 35.3 Set Depth (ft… 2,519.2 Set Depth (TVD) (… 2,345.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in) Make Model 35.3 35.2 0.08 Hanger 2.992 3.500 Tubing Description Tubing – Completion Lower String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,645.0 Set Depth (ft… 7,801.1 Set Depth (TVD) (… 5,928.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in) Make Model 7,705.7 5,871.5 53.45 GAS LIFT 2.900 4.725 CAMCO KBG-2-9 7,747.8 5,896.7 53.14 NIPPLE 2.750 4.520 7,789.1 5,921.6 52.82 SEAL ASSY 2.990 4.125 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,695.0 5,865.2 53.52 PATCH - UPR PKR (ME) P2P UPR PKR, OAL 4' 3/1/2020 1.625 CPP35243 7,699.0 5,867.6 53.50 ANCHOR LATCH 33' SPACER PIPE w/ ANCHOR LATCH 3/1/2020 1.590 CPAL 35147 7,714.0 5,876.5 53.39 LEAK LARGE LEAK FOUND @ ST#4 GLM 2/18/2015 0.000 7,728.0 5,884.9 53.28 PATCH - LWR PKR (ME) P2P LWR PKR, OAL 4' 3/1/2020 1.625 CPP35244 8,025.0 6,074.4 43.02 Whipstock Weatherford Whipstock (Could not be Pulled) 4/18/2005 8,223.0 6,223.4 37.45 RETAINER B LINER HES EZ-DRILL SVB RETAINER 5/13/2005 2.690 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,884.0 7,886.0 5,981.0 5,982.3 5/18/2005 4.0 IPERF Shot TBG punch holes (9) 7,886.0 7,888.0 5,982.3 5,983.5 5/13/2005 4.0 IPERF Shot TBG punch holes (9) 8,147.0 8,157.0 6,164.5 6,172.0 A-3, 3H-14B 10/7/2005 6.0 APERF 2.5" PJ 2506, 60° phase 8,172.0 8,182.0 6,183.5 6,191.2 A-2, 3H-14B 8/9/2005 6.0 APERF 2.5" HSD, 60° phase 8,182.0 8,187.0 6,191.2 6,195.1 A-2, 3H-14B 8/9/2005 6.0 APERF 2.5" HSD, 60° phase 8,212.0 8,222.0 6,214.7 6,222.6 A-1, 3H-14B 10/7/2005 6.0 APERF 2.5" PJ 2506, 60° phase Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 8/28/2005 8,172.0 8,187.0 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,593.0 9,535.0 4,530.0 Cement Plug Notes: General & Safety End Date Annotation 3/1/2011 NOTE: **TUBING COMPONENT DEPTHS QUESTIONABLE** TALLY/DETAIL SHEETS VARY 2/28/2006 NOTE: CHEMICAL CUT 3H-14BL4 LINER TOP DOWN TO 8040' CLEAR 3H-14B LINER 1/22/2006 NOTE: MULTI-LATERAL WELL: 3H-14B/3H-14BL1/3H-14BL2/3H-14BL3/ 3H-14BL4 1/22/2006 NOTE: 3H-14BL1(OPEN HOLE PILOT HOLE - PLUGGED OFF) 1/22/2006 NOTE: 3H-14BL4 **ONLY ACCESSIBLE LEG** 3H-14B, 2/28/2022 2:45:13 PM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 SEAL ASSY; 7,789.1 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 CONDUCTOR; 36.0-115.0 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 12/14/1987 3H-14B ... TD Act Btm (ftKB) 8,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009202 Wellbore Status PROD Max Angle & MD Incl (°) 55.50 MD (ftKB) 7,048.39 WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 H2S (ppm) 160 Date 2/23/2019 Comment SSSV: TRDP Notes: General & Safety End Date Annotation 4/21/2005 NOTE: WELL SIDETRACKED FOR SECOND TIME 9/16/1999 NOTE: WAIVERED WELL: IA x 0A COMMUNICATION 3H-14B, 2/28/2022 2:45:14 PM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 SEAL ASSY; 7,789.1 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 CONDUCTOR; 36.0-115.0 KUP PROD 3H-14B ... WELLNAME WELLBORE3H-14B Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2022 InspectNo:susAGE220622074808 Well Pressures (psi): Date Inspected:6/20/2022 Inspector:Adam Earl If Verified, How?Other (specify in comments) Suspension Date:3/1/2022 #321-490 Tubing:1600 IA:1600 OA:10 Operator:ConocoPhillips Alaska, Inc. Operator Rep:Roger Mouser Date AOGCC Notified:6/10/2022 Type of Inspection:Initial Well Name:KUPARUK RIV UNIT 3H-14B Permit Number:2050210 Wellhead Condition Good working condition. Surrounding Surface Condition good. No visible trash or sheens. Flow lines removed and wellhead blinds installed. Condition of Cellar water in cellar, below casing valves. De-watering will have pad free from water in a few weeks. Still a lot of snow under flowlines and mods. Comments Well verified by pad map, operator to submit photos. Supervisor Comments Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? 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ill Simek Digitally signed by Jill Simek Date: 2022.03.01 11:21:43 -09'00' Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM, TOC 5,593.0 1/31/2022 3H-14B fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Tag TOC - Added Cement Icons 2/28/2022 3H-14B pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.2 Set Depth (ftKB) 3,455.6 Set Depth (TVD) … 3,002.4 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 8,220.2 Set Depth (TVD) … 6,221.2 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Casing Description Window L4 OD (in) 7 ID (in) 6.00 Top (ftKB) 8,016.0 Set Depth (ftKB) 8,026.0 Set Depth (TVD) … 6,075.2 Wt/Len (l… 9.30 Grade Top Thread Casing Description SCAB LINER OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 6,038.9 Set Depth (ftKB) 7,925.0 Set Depth (TVD) … 6,007.4 Wt/Len (l… 15.50 Grade L-80 Top Thread HYDRIL511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,038.9 4,848.1 44.44 PACKER BAKER CPH LINER TOP PACKER-7 x 5.5" 4.830 6,049.3 4,855.5 44.45 HANGER BAKER HMC LINER HANGER 4.920 Casing Description LINER 3 1/2 OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 7,780.3 Set Depth (ftKB) 8,450.0 Set Depth (TVD) … 6,408.6 Wt/Len (l… 9.30 Grade L-80 Top Thread HYDRIL 511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,780.3 5,916.3 52.89 PACKER BAKER HR ZXP LINER TOP PACKER 5-1/2" x 3- 1/2" (Comm #H296-28-00579) 3.500 7,807.1 5,932.5 52.36 HANGER BAKER HMC LINER HANGER 5-1/2" x 3-1/2" Comm #H292-23-0212) 3.500 Tubing Strings Tubing Description Tubing – Kill String String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 35.3 Set Depth (ft… 2,519.2 Set Depth (TVD) (… 2,345.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in) Make Model 35.3 35.2 0.08 Hanger 2.992 3.500 Tubing Description Tubing – Completion Lower String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,645.0 Set Depth (ft… 7,801.1 Set Depth (TVD) (… 5,928.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in) Make Model 7,705.7 5,871.5 53.45 GAS LIFT 2.900 4.725 CAMCO KBG-2-9 7,747.8 5,896.7 53.14 NIPPLE 2.750 4.520 7,789.1 5,921.6 52.82 SEAL ASSY 2.990 4.125 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,695.0 5,865.2 53.52 PATCH - UPR PKR (ME) P2P UPR PKR, OAL 4' 3/1/2020 1.625 CPP35243 7,699.0 5,867.6 53.50 ANCHOR LATCH 33' SPACER PIPE w/ ANCHOR LATCH 3/1/2020 1.590 CPAL 35147 7,714.0 5,876.5 53.39 LEAK LARGE LEAK FOUND @ ST#4 GLM 2/18/2015 0.000 7,728.0 5,884.9 53.28 PATCH - LWR PKR (ME) P2P LWR PKR, OAL 4' 3/1/2020 1.625 CPP35244 8,025.0 6,074.4 43.02 Whipstock Weatherford Whipstock (Could not be Pulled) 4/18/2005 8,223.0 6,223.4 37.45 RETAINER B LINER HES EZ-DRILL SVB RETAINER 5/13/2005 2.690 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,884.0 7,886.0 5,981.0 5,982.3 5/18/2005 4.0 IPERF Shot TBG punch holes (9) 7,886.0 7,888.0 5,982.3 5,983.5 5/13/2005 4.0 IPERF Shot TBG punch holes (9) 8,147.0 8,157.0 6,164.5 6,172.0 A-3, 3H-14B 10/7/2005 6.0 APERF 2.5" PJ 2506, 60° phase 8,172.0 8,182.0 6,183.5 6,191.2 A-2, 3H-14B 8/9/2005 6.0 APERF 2.5" HSD, 60° phase 8,182.0 8,187.0 6,191.2 6,195.1 A-2, 3H-14B 8/9/2005 6.0 APERF 2.5" HSD, 60° phase 8,212.0 8,222.0 6,214.7 6,222.6 A-1, 3H-14B 10/7/2005 6.0 APERF 2.5" PJ 2506, 60° phase Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 8/28/2005 8,172.0 8,187.0 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,593.0 9,535.0 4,530.0 Cement Plug Notes: General & Safety End Date Annotation 3/1/2011 NOTE: **TUBING COMPONENT DEPTHS QUESTIONABLE** TALLY/DETAIL SHEETS VARY 2/28/2006 NOTE: CHEMICAL CUT 3H-14BL4 LINER TOP DOWN TO 8040' CLEAR 3H-14B LINER 1/22/2006 NOTE: MULTI-LATERAL WELL: 3H-14B/3H-14BL1/3H-14BL2/3H-14BL3/ 3H-14BL4 1/22/2006 NOTE: 3H-14BL1(OPEN HOLE PILOT HOLE - PLUGGED OFF) 1/22/2006 NOTE: 3H-14BL4 **ONLY ACCESSIBLE LEG** 3H-14B, 2/28/2022 2:29:21 PM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 CONDUCTOR; 36.0-115.0 Tubing Pup; 36.4 Hanger; 35.3 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 12/14/1987 3H-14B ... TD Act Btm (ftKB) 8,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009202 Wellbore Status PROD Max Angle & MD Incl (°) 55.50 MD (ftKB) 7,048.39 WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 H2S (ppm) 160 Date 2/23/2019 Comment SSSV: TRDP Notes: General & Safety End Date Annotation 4/21/2005 NOTE: WELL SIDETRACKED FOR SECOND TIME 9/16/1999 NOTE: WAIVERED WELL: IA x 0A COMMUNICATION 3H-14B, 2/28/2022 2:29:22 PM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 CONDUCTOR; 36.0-115.0 Tubing Pup; 36.4 Hanger; 35.3 KUP PROD 3H-14B ... WELLNAME WELLBORE3H-14B Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,975.0 3/16/2015 3H-14BL1 hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SET PACKER 12/30/2015 3H-14BL1 lehallf Casing Strings Casing Description OPEN HOLE L1 OD (in) 4 3/8 ID (in) Top (ftKB) 8,285.0 Set Depth (ftKB) 9,200.0 Set Depth (TVD) … 6,169.7 Wt/Len (l…Grade Top Thread Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 8,720.0 6,110.4 89.57 PLUG IBP SET IN OPEN HOLE FOR PLUG BACK 1/11/2006 0.000 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,593.0 10,133.0 4,530.0 Cement Plug 1/23/2022 3H-14BL1, 2/28/2022 2:29:23 PM Vertical schematic (actual) OPEN HOLE L1; 8,285.0- 9,200.0 PLUG; 8,720.0 PRODUCTION; 33.0-8,220.2 LINER 3 1/2; 7,780.3-8,450.0 Window L4; 8,016.0-8,026.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 CONDUCTOR; 36.0-115.0 Tubing Pup; 36.4 Hanger; 35.3 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 12/14/1987 3H-14BL1 ... TD Act Btm (ftKB) 9,200.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009260 Wellbore Status PROD Max Angle & MD Incl (°) 94.66 MD (ftKB) 8,240.72 WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 H2S (ppm) 160 Date 2/23/2019 Comment SSSV: TRDP Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,975.0 3/16/2015 3H-14BL2 hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SET PACKER 12/30/2015 3H-14BL2 lehallf Casing Strings Casing Description Liner L2 OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 9,123.2 Set Depth (ftKB) 10,133.0 Set Depth (TVD) … 6,114.9 Wt/Len (l… 4.44 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,123.2 6,110.9 87.95 DEPLOY BTT SEAL BORE DEPLOYMENT SLEEVE 1.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 9,122.0 6,110.8 87.95 SPEAR L2 LINER WEATHERFORD GS ANTI-TURN SPEAR CONNECTING SECTION 1 & 2 OF LINER 1/11/2006 0.750 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,870.0 9,122.0 6,112.5 6,110.8 A-2, 3H-14BL2 1/11/2006 40.0 SLOTS Alternating slotted/solid pipe 9,124.0 9,257.0 6,110.9 6,116.9 A-2, 3H-14BL2 1/11/2006 40.0 SLOTS Alternating slotted/solid pipe 9,667.0 10,132.0 6,115.8 6,114.8 A-3, A-4, UNIT D, 3H-14BL2 1/11/2006 40.0 SLOTS Alternating slotted/solid pipe 3H-14BL2, 2/28/2022 2:29:23 PM Vertical schematic (actual) Liner L2; 9,123.2-10,133.0 SLOTS; 9,667.0-10,132.0 SLOTS; 9,124.0-9,257.0 SPEAR; 9,122.0 SLOTS; 8,870.0-9,122.0 LINER 3 1/2; 7,780.3-8,450.0 Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 CONDUCTOR; 36.0-115.0 Tubing Pup; 36.4 Hanger; 35.3 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 12/14/1987 3H-14BL2 ... TD Act Btm (ftKB) 10,774.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009261 Wellbore Status PROD Max Angle & MD Incl (°) 94.66 MD (ftKB) 8,240.72 WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 H2S (ppm) 160 Date 2/23/2019 Comment SSSV: TRDP Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,975.0 3/16/2015 3H-14BL3 hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SET PACKER 12/30/2015 3H-14BL3 lehallf Casing Strings Casing Description Liner L3 OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 9,179.0 Set Depth (ftKB) 10,106.0 Set Depth (TVD) … 6,113.0 Wt/Len (l… 4.44 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,179.0 6,087.9 93.26 HANGER L3 LINER WEATHERFORD ALUMINUM BILLET LINER HANGER 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,203.0 10,105.0 6,086.6 6,113.0 A-3, A-4, A-3, A- 4, UNIT D, 3H- 14BL3 1/14/2006 40.0 SLOTS Slotted Tubing 3H-14BL3, 2/28/2022 2:29:24 PM Vertical schematic (actual) Liner L3; 9,179.0-10,106.0 SLOTS; 9,203.0-10,105.0 Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 CONDUCTOR; 36.0-115.0 Tubing Pup; 36.4 Hanger; 35.3 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 12/14/1987 3H-14BL3 ... TD Act Btm (ftKB) 10,106.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009262 Wellbore Status PROD Max Angle & MD Incl (°) 95.55 MD (ftKB) 9,122.80 WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 H2S (ppm) 160 Date 2/23/2019 Comment SSSV: TRDP Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,975.0 3/16/2015 3H-14BL4 hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: FOUND NEW TUBING LEAK 9/21/2020 3H-14BL4 condijw Casing Strings Casing Description Liner L4 OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 8,040.0 Set Depth (ftKB) 9,532.0 Set Depth (TVD) … 6,093.5 Wt/Len (l… 4.40 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,498.9 6,094.1 90.10 O-RING L4 LINER BTT O-RING SUB 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,243.0 9,499.0 6,108.7 6,094.1 A-3, A-4, A-3, 3H-14BL4 1/19/2006 40.0 SLOTS Slotted Tubing 3H-14BL4, 2/28/2022 2:29:26 PM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB Cement Plug; 5,593.0 ftKB SURFACE; 35.2-3,455.6 CONDUCTOR; 36.0-115.0 Tubing Pup; 36.4 Hanger; 35.3 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 12/14/1987 3H-14BL4 ... TD Act Btm (ftKB) 10,070.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009263 Wellbore Status PROD Max Angle & MD Incl (°) 96.94 MD (ftKB) 9,621.95 WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 H2S (ppm) 160 Date 2/23/2019 Comment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tate of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:12 Township:12N Range:8E Meridian:Umiat Drilling Rig:NA Rig Elevation:NA Total Depth:8450 ft MD Lease No.:ADL 0025531 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 115 Feet Csg Cut@ Feet Surface:9-5/8"O.D. Shoe@ 3455 Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 8220 Feet Csg Cut@ Feet Scab Liner:5-1/2"O.D. Shoe@ 7925 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3.5"O.D. Tail@ 8450 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bottom 8025 ft MD 5593 ft MD Wireline tag Initial 15 min 30 min 45 min Result Tubing 1520 1440 1425 IA 1520 1440 1425 OA 0 20 20 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: I witnessed the tag and pressure test on plug #1 for the suspension operator on KRU 3H-14B. Top of cement (TOC) was found to be @ 5593 ft MD using a wireline unit equipped with a 160lb tool string and a bailer. A good cement sample was produced after retrieving the bailer after the tag. A combo MIT-TxIA pressure test to 1500 psi was completed with passing results. January 31, 2022 Lou Laubenstein Well Bore Plug & Suspension KRU 3H-14B ConocoPhillips Alaska Inc PTD 2050210; Sundry 321-490 none Plugging Data: Test Data: P Casing Removal:Casing/Tubing Data (depths are Sid Ferguson rev. 11-28-18 2022-0131_Plug_Verification_KRU_3H-14B_ll              ! " # " $$$$$$$$$$$$$$$$$$$$$$ % &' ( )*! + (% ,- !. /"!! 0- ,- 12132+.2 4, . " ( % /5326 ! )5206 ! & % /5326 )27068+)0368 ++1/68++/26 )5206 5/5/683/)368 3//36830)6 9 : , ;88 .-#/2 -#/2 13069% +)5369% 175)6:% +/26:% < :, (8 . )27069% +)0369% ++1/69% ++/269% !4 5/5/6:% 3/)36:% 3//36:% 30)6:% !4 1 =; ( * , . !4 7 = 3" < % ( " &' ( % - ( )" < > "%- & % > >*!? @ -@> (!!4 &' ! & ; A 7#41B - 7#41B 71#720 & > & ;! % % "*!?"> " #C #C +*( ( (< % (" (D ,02+.1)3#)37 "<& <C<E- < <1 < <1 < <C<FG- < :! +//5#+///68/5+#/3+8/+1#//+68/11#/1126 < % ( *H % #* 5 ,= 12132+28132+8I131/7. #* > #9 36 753)6 &-A -A*-!%>!& :*!99**! 3 % !1 ! ! 5" C"< !"# !#$% !"# !$ &&$ <8* C'227)2 8A0032 7 '() ?< !4 #*+,- +06 75126 !.# * )B 0#34/B - //+6 //)6 /0!*+ 30/#30/568))5#)+168)/7#)0368/11#/1116 )0, /&$$0# 36 72216 )116 3#41B /1126 +0136 )22+6 +B 2#525 24121 " 72( By Samantha Carlisle at 7:40 am, Oct 19, 2021 SFD 10/20/2021VTL 01/24/2022 DSR-10/19/21 RBDMS HEW 10/19/2021 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,975.0 3/16/2015 3H-14B hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pre-RWO chem cut 7/13/2021 3H-14B spilch Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.2 Set Depth (ftKB) 3,455.6 Set Depth (TVD) … 3,002.4 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 8,220.2 Set Depth (TVD) … 6,221.2 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Casing Description Window L4 OD (in) 7 ID (in) 6.00 Top (ftKB) 8,016.0 Set Depth (ftKB) 8,026.0 Set Depth (TVD) … 6,075.2 Wt/Len (l… 9.30 Grade Top Thread Casing Description SCAB LINER OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 6,038.9 Set Depth (ftKB) 7,925.0 Set Depth (TVD) … 6,007.4 Wt/Len (l… 15.50 Grade L-80 Top Thread HYDRIL511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,038.9 4,848.1 44.44 PACKER BAKER CPH LINER TOP PACKER-7 x 5.5" 4.830 6,049.3 4,855.5 44.45 HANGER BAKER HMC LINER HANGER 4.920 Casing Description LINER 3 1/2 OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 7,780.3 Set Depth (ftKB) 8,450.0 Set Depth (TVD) … 6,408.6 Wt/Len (l… 9.30 Grade L-80 Top Thread HYDRIL 511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,780.3 5,916.3 52.89 PACKER BAKER HR ZXP LINER TOP PACKER 5-1/2" x 3- 1/2" (Comm #H296-28-00579) 3.500 7,807.1 5,932.5 52.36 HANGER BAKER HMC LINER HANGER 5-1/2" x 3-1/2" Comm #H292-23-0212) 3.500 Tubing Strings Tubing Description Tubing – Kill String String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 35.3 Set Depth (ft… 2,519.2 Set Depth (TVD) (… 2,345.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 35.3 35.2 0.08 Hanger Hanger/Pup 2.992 Tubing Description Tubing – Completion Lower String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7,645.0 Set Depth (ft… 7,801.1 Set Depth (TVD) (… 5,928.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,747.8 5,896.7 53.14 NIPPLE CAMCO D NIPPLE W/ NO GO PROFILE 2.750 7,789.1 5,921.6 52.82 SEAL ASSY BAKER SEAL ASSEMBLY (3 SETS) 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,695.0 5,865.2 53.52 PATCH - UPR PKR (ME) P2P UPR PKR, OAL 4' 3/1/2020 1.625 CPP35243 7,699.0 5,867.6 53.50 ANCHOR LATCH 33' SPACER PIPE w/ ANCHOR LATCH 3/1/2020 1.590 CPAL 35147 7,714.0 5,876.5 53.39 LEAK LARGE LEAK FOUND @ ST#4 GLM 2/18/2015 0.000 7,728.0 5,884.9 53.28 PATCH - LWR PKR (ME) P2P LWR PKR, OAL 4' 3/1/2020 1.625 CPP35244 8,025.0 6,074.4 43.02 Whipstock Weatherford Whipstock (Could not be Pulled) 4/18/2005 8,223.0 6,223.4 37.45 RETAINER B LINER HES EZ-DRILL SVB RETAINER 5/13/2005 2.690 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,884.0 7,886.0 5,981.0 5,982.3 5/18/2005 4.0 IPERF Shot TBG punch holes (9) 7,886.0 7,888.0 5,982.3 5,983.5 5/13/2005 4.0 IPERF Shot TBG punch holes (9) 8,147.0 8,157.0 6,164.5 6,172.0 A-3, 3H-14B 10/7/2005 6.0 APERF 2.5" PJ 2506, 60° phase 8,172.0 8,182.0 6,183.5 6,191.2 A-2, 3H-14B 8/9/2005 6.0 APERF 2.5" HSD, 60° phase 8,182.0 8,187.0 6,191.2 6,195.1 A-2, 3H-14B 8/9/2005 6.0 APERF 2.5" HSD, 60° phase 8,212.0 8,222.0 6,214.7 6,222.6 A-1, 3H-14B 10/7/2005 6.0 APERF 2.5" PJ 2506, 60° phase Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 8/28/2005 8,172.0 8,187.0 0.0 0.00 0.00 Notes: General & Safety End Date Annotation 3/1/2011 NOTE: **TUBING COMPONENT DEPTHS QUESTIONABLE** TALLY/DETAIL SHEETS VARY 2/28/2006 NOTE: CHEMICAL CUT 3H-14BL4 LINER TOP DOWN TO 8040' CLEAR 3H-14B LINER 1/22/2006 NOTE: MULTI-LATERAL WELL: 3H-14B/3H-14BL1/3H-14BL2/3H-14BL3/ 3H-14BL4 1/22/2006 NOTE: 3H-14BL1(OPEN HOLE PILOT HOLE - PLUGGED OFF) 1/22/2006 NOTE: 3H-14BL4 **ONLY ACCESSIBLE LEG** 4/21/2005 NOTE: WELL SIDETRACKED FOR SECOND TIME 9/16/1999 NOTE: WAIVERED WELL: IA x 0A COMMUNICATION 3H-14B, 10/18/2021 11:19:15 AM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 SEAL ASSY; 7,789.1 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 ANCHOR LATCH; 7,699.0 GAS LIFT; 7,705.7 PATCH - UPR PKR (ME); 7,695.0 SURFACE; 35.2-3,455.6 CONDUCTOR; 36.0-115.0 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 12/14/1987 3H-14B ... TD Act Btm (ftKB) 8,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009202 Wellbore Status PROD Max Angle & MD Incl (°) 55.50 MD (ftKB) 7,048.39 WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 H2S (ppm) 160 Date 2/23/2019 Comment SSSV: TRDP Page 1/12 3H-14 Report Printed: 10/13/2021 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) 9/3/2021 00:00 9/3/2021 15:00 15.00 MIRU, MOVE MOB P Pull pits away from sub. Move sub F/ 3H-01 T/ 3H-14. Spot pits. Move in auxiliary equipment. Berm in equipment. RU companion valve and manifold for circulating. PU / RU Lubricator and Test same to 1500 psi. Pull BPV. Take on 11.7 PPG KWF for circulating and conditioning well bore. INITIAL T/I/O 375/250/500 9/3/2021 15:00 9/3/2021 18:30 3.50 MIRU, WELCTL KLWL P PT circulating lines T/ 3500 PSI - good test. Pumped 284 Bbls 11.7 PPG NaBr down tubing, out IA T/ tiger tank @ 2 BPM, 250 PSI. Shut in. 9/3/2021 18:30 9/4/2021 00:00 5.50 MIRU, WELCTL OWFF P Monitor pressures in cellar. Recording every 5 min. Stabilized @ T/IA 25/55 PSI. Consult w/ town. Call out for load of 12.0 PPG NaBr F/ 1B. Offload 250 Bbls into pits. Truck went back T/ 1B for additional 40 Bbls. Dust system up T/ 12.1 PPG w/ sack product on rig. 9/4/2021 00:00 9/4/2021 00:30 0.50 MIRU, WELCTL OWFF P Call out for load of 12.0 PPG NaBr F/ 1B. Offload 250 Bbls into pits. Truck went back T/ 1B for additional 40 Bbls. Dust system up T/ 12.1 PPG w/ sack product on rig. 9/4/2021 00:30 9/4/2021 03:30 3.00 MIRU, WELCTL KLWL P Circulated 305 bbls of 12.1 PPG @ 2 BPM down Tbg taking returns up the IA. while holding pump psi @ 300 psi for 56 bbls then slowly step down circulating psi to avg. 250 psi. Shut down after 305 bbls and bled off trapped pressure. No flow TBG & IA. Start monitoring well. 9/4/2021 03:30 9/4/2021 04:00 0.50 MIRU, WELCTL OWFF P Observed well for flow for 30 minutes. "GOOD" no flow. 9/4/2021 04:00 9/4/2021 05:00 1.00 MIRU, WELCTL RURD P Secure well, blow down surface lines. RD high pressure lines and secure same. 9/4/2021 05:00 9/4/2021 06:00 1.00 MIRU, WELCTL MPSP P Install BPV and PT same down IA to test in the direction of flow. Seen well taking fluid at 750 psi. Confirmed no pressure above BPV. Stack above BPV was still dry after test. Attempted to perform rolling test with pump for testing, well taking fluid at 750 psi. 9/4/2021 06:00 9/4/2021 14:00 8.00 MIRU, WHDBOP NUND P PJSM. ND tree and inspect hanger lift threads. Install Cameron test dart into BPV. NU BOPE. 9/4/2021 14:00 9/4/2021 15:00 1.00 MIRU, WHDBOP BOPE P Initial BOPE test All test at 250/3500 PSI for 5 Min each. Test blinds rams. Choke valves #1 to #3, & 16, Test 2" rig floor Demco kill valves. Waived to witness Test by Matthew Herrera with AOGCC. 9/4/2021 15:00 9/4/2021 15:15 0.25 MIRU, WHDBOP BOPE T Fail/Pass on manual kill valve. Greased, functioned and passed retest. Rig: NABORS 7ES RIG RELEASE DATE 9/21/2021 Page 2/12 3H-14 Report Printed: 10/13/2021 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) 9/4/2021 15:15 9/4/2021 18:30 3.25 MIRU, WHDBOP BOPE P Initial BOPE test All test at 250/3500 PSI for 5 Min each. Tested annular, VBR's, LPR w/ 3 1/2" test joint. Choke valves #4 to #15, upper and lower top drive well control valves. Test 3 1/2" HT- 38 FOSV and IBOP. Test manual and HCR kill valves and manual and HCR choke valves. Test hydraulic and manual test valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2900 PSI, after closure=1500 PSI, 200 PSI attained =20 sec, full recovery attained =120 sec. 5 bake up nitrogen bottles average =2050 PSI. Test gas detectors, PVT and flow show. Waived to witness Test by Matthew Herrera with AOGCC. 9/4/2021 18:30 9/4/2021 19:30 1.00 MIRU, WHDBOP RURD P B/D, R/D testing equipment. 9/4/2021 19:30 9/4/2021 20:30 1.00 MIRU, WHDBOP MPSP P Pull test dart and BPV. R/U SLB spooling unit. 9/4/2021 20:30 9/4/2021 22:00 1.50 COMPZN, RPCOMP PULL P Install landing joint. M/U TD. BOLDS. Pull hanger T/ RF. Hanger came of seat @ 75k. Tubing pulled free @ 100K. L/D hanger, joints 1 &2 and space out pup T/ 5932' PUW=70K. Excessive oil on completion and control line. 6,006.0 5,932.0 9/4/2021 22:00 9/5/2021 00:00 2.00 COMPZN, RPCOMP CIRC P M/U TD. Circ 42 Bbls 12.1 PPG NaBr citric acid pill @ 5 BPM, 500 PSI. T/ attempt to clean up pipe. Pill dropped PH F/ 6 T/ 2. R/D, B/D TD 5,932.0 5,893.0 9/5/2021 00:00 9/5/2021 08:00 8.00 COMPZN, RPCOMP CIRC P Continue pumping 42 bbls of Citric Acid pill to clean 3.5" TBG. Pipe still dirty. R/U and pump 30 bbls of hot diesel with LRS. Flushed 164 bbls of dirty fluid to kill tank. Stop and Build pit volume. Circulated surface to surface volume with 12.1 ppg brine. Well clean and still dead. 5,893.0 5,893.0 9/5/2021 08:00 9/5/2021 08:30 0.50 COMPZN, RPCOMP OWFF P Observed well for flow for 30 minutes. "No Flow" 5,893.0 5,893.0 9/5/2021 08:30 9/5/2021 09:30 1.00 COMPZN, RPCOMP PULL P Pull 3 1/2" completion while spooling up SSSV control line. Stand back 20 joints of TBG in derrick. 5,893.0 4,033.0 9/5/2021 09:30 9/5/2021 10:30 1.00 COMPZN, RPCOMP PULL P Continue POOH with 3-1/2" TBG laying down same to SSSV. "Pulled 73 Joints total to reach SSSV" "Recovered 80 bands from the SS 1/4" control line" 4,033.0 3,668.0 9/5/2021 10:30 9/5/2021 10:45 0.25 COMPZN, RPCOMP RURD P Secure well. RD/LD spooler from rig floor. 3,668.0 3,668.0 9/5/2021 10:45 9/5/2021 15:30 4.75 COMPZN, RPCOMP PULL P Continue POOH with 3-1/2" TBG laying down same maintaining proper hole fill. OD of cut tubing was 3.51' Cut joint was 22.72' feet long. 190 total Joints pulled 3,668.0 0.0 9/5/2021 15:30 9/5/2021 16:45 1.25 COMPZN, RPCOMP BHAH P Clean and Clear Rig Floor. Install wear ring. ID: 6.375" 0.0 0.0 9/5/2021 16:45 9/5/2021 18:45 2.00 COMPZN, RPCOMP RURD P Load Baker Fishing tools to RF, and pipe shed. Verify straps and running order 0.0 0.0 9/5/2021 18:45 9/5/2021 20:30 1.75 COMPZN, RPCOMP BHAH P M/U & RIH BHA #1 Overshot T/ 130', PUW=40, SOW=40K 0.0 130.0 Rig: NABORS 7ES RIG RELEASE DATE 9/21/2021 Page 3/12 3H-14 Report Printed: 10/13/2021 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) 9/5/2021 20:30 9/6/2021 00:00 3.50 COMPZN, RPCOMP TRIP P RIH w/ BHA #1 on 3 1/2" DP F/ pipe shed T/ 2829', SOW=69K 130.0 2,829.0 9/6/2021 00:00 9/6/2021 02:30 2.50 COMPZN, RPCOMP TRIP P Continue to TIH w/ BHA #1 on 3 1/2" DP F/2829' T/4,862. 2,829.0 4,862.0 9/6/2021 02:30 9/6/2021 04:00 1.50 COMPZN, RPCOMP SLPC P Slip/Cut 82' of Drill Line 4,862.0 4,862.0 9/6/2021 04:00 9/6/2021 06:00 2.00 COMPZN, RPCOMP TRIP P Continue to TIH w/ BHA #1 on 3 1/2" DP F/ 4862' To top fish @ 5,999' DN WT 90K UP WT 115k. 4,862.0 5,999.0 9/6/2021 06:00 9/6/2021 09:30 3.50 COMPZN, RPCOMP FISH P Tagged an latched fish at 5999' Up Wt 115k / Dn Wt 90k. Pulled Up to 200k,225k & 250k. Start Jarring on fish, after 3 hours of jarring and 100 jar hits at 200k and max pull at 325, decided to release from fish and TOOH to change out BHA. 5,999.0 5,999.0 9/6/2021 09:30 9/6/2021 10:30 1.00 COMPZN, RPCOMP CIRC P Circulate a Bottoms Up 56 SPM, 430 Pump Psi. 5,999.0 5,999.0 9/6/2021 10:30 9/6/2021 11:00 0.50 COMPZN, RPCOMP OWFF P Observed well for flow. 0.0 9/6/2021 11:00 9/6/2021 14:15 3.25 COMPZN, RPCOMP TRIP P TOOH F/5999' T/Baker BHA on trip tank. 5,999.0 130.0 9/6/2021 14:15 9/6/2021 15:00 0.75 COMPZN, RPCOMP PULD P L/D Fishing BHA #1. 130.0 0.0 9/6/2021 15:00 9/6/2021 15:45 0.75 COMPZN, RPCOMP PULD P P/U BHA #2 Overshot w/ Rattler T/ 156', PUW=40K, SOW=40K 0.0 156.0 9/6/2021 15:45 9/6/2021 19:00 3.25 COMPZN, RPCOMP TRIP P RIH on DP w/ BHA #2 T/ 5959', PUW=115K, SOW=90K. 156.0 5,959.0 9/6/2021 19:00 9/7/2021 00:00 5.00 COMPZN, RPCOMP FISH P Tagged fish @ 5999' swallowed T/ 5996'. Circ @ 2.5 BPM, 1340 PSI activating rattler. Pulled T/ 250K, 275K, 300K. Start Jarring on fish at 75K over string weight working up T/ 100K over. Total of 40 jar hits w/ straight pull T/ 325K, Consult w/ town. Release from fish, P/U T/ 5979'. 5,959.0 5,979.0 9/7/2021 00:00 9/7/2021 01:00 1.00 COMPZN, RPCOMP CIRC P Circ BU @ 2.4 BPM, 1250 PSI 5,979.0 5,979.0 9/7/2021 01:00 9/7/2021 01:15 0.25 COMPZN, RPCOMP OWFF P OWFF - no flow. 5,979.0 5,976.0 9/7/2021 01:15 9/7/2021 02:15 1.00 COMPZN, RPCOMP SVRG P Post jarring derrick and top drive inspection. 5,976.0 5,976.0 9/7/2021 02:15 9/7/2021 06:00 3.75 COMPZN, RPCOMP TRIP P POOH, F/ 5956' T/ 158', PUW=115K, SOW=85K 5,976.0 158.0 9/7/2021 06:00 9/7/2021 07:00 1.00 COMPZN, RPCOMP BHAH P Rack back DC's and L/D BHA #2 F/ 158' to surface. 158.0 0.0 9/7/2021 07:00 9/7/2021 08:00 1.00 COMPZN, RPCOMP BHAH P M/U BHA #3 Overshot RIH T/ 129', PUW=50K, SOW=40K 0.0 129.0 9/7/2021 08:00 9/7/2021 11:00 3.00 COMPZN, RPCOMP TRIP P RIH engage fish F/ 129' Tag fish @ 5992', swallow T/ 5994'. PUW=115K, SOW=85K. P/U 30 K over 15.5" of stretch. P/U 100K over 58" of stretch. 129.0 5,994.0 9/7/2021 11:00 9/7/2021 12:30 1.50 COMPZN, RPCOMP RURD P E-line on location, pre job w co rep, spot unit, Pre Job on rig floor 5,994.0 5,994.0 9/7/2021 12:30 9/7/2021 15:00 2.50 COMPZN, RPCOMP RURD P Mobilize e-line equipment to the rig floor. Rig up and RIH with Radial Cutting Torch tool string. 5,994.0 5,994.0 9/7/2021 15:00 9/7/2021 19:30 4.50 COMPZN, RPCOMP ELNE P RIH w/ 2" RCT, T/ 5890. Ran into obstruction and could not pass through. POOH w/ E-Line 5,994.0 5,994.0 Rig: NABORS 7ES RIG RELEASE DATE 9/21/2021 Page 4/12 3H-14 Report Printed: 10/13/2021 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) 9/7/2021 19:30 9/7/2021 20:00 0.50 COMPZN, RPCOMP RURD P R/D E-line pack off and pump in sub. R/D tool string. Found debris (plastic coating from drill pipe) in second centralizer on E-line string. R/U T/ circ 5,994.0 5,994.0 9/7/2021 20:00 9/7/2021 22:00 2.00 COMPZN, RPCOMP CIRC P Release F/ fish. P/U T/ 5985'. Circ 10 Bbls hi vis pill followed by 280 Bbls12.1 NaBr @ 6 BPM, 1240 PSI. Saw some plastic debris at shakes when hi-vis pill returned to surface. 5,994.0 5,985.0 9/7/2021 22:00 9/7/2021 23:00 1.00 COMPZN, RPCOMP RURD P RIH engage spear T/ 5994'. R/U TD, R/U 2.15" E-line swedge drift. R/U pump in sub and pack off on surface. 5,985.0 5,994.0 9/7/2021 23:00 9/8/2021 00:00 1.00 COMPZN, RPCOMP ELNE P RIH w/ 2.15" drift on E-line. Had trouble passing through DC's @ 5924' and 5964'. Worked through entered tubing and tagged spear @ 7694'. 5,994.0 5,994.0 9/8/2021 00:00 9/8/2021 01:30 1.50 COMPZN, RPCOMP ELNE P POOH w/ E-Line. Attempt T/ clean up tight spots @ 5924' and 5964'. Unsuccessful. POOH. 5,994.0 5,994.0 9/8/2021 01:30 9/8/2021 02:30 1.00 COMPZN, RPCOMP RURD P R/D E-line pack off and pump in sub. R/D tool string. R/D long bails. R/U short bails. 5,994.0 5,994.0 9/8/2021 02:30 9/8/2021 03:00 0.50 COMPZN, RPCOMP OWFF P Release F/ fish. OWFF - no flow. 5,994.0 5,985.0 9/8/2021 03:00 9/8/2021 06:15 3.25 COMPZN, RPCOMP TRIP P POOH F/ 5985' T/ 129', PUW=115K, SOW=85K 5,985.0 129.0 9/8/2021 06:15 9/8/2021 06:45 0.50 COMPZN, RPCOMP BHAH P L/D BHA #3 F/ 129' T/ 25' 129.0 25.0 9/8/2021 06:45 9/8/2021 07:15 0.50 COMPZN, RPCOMP BHAH P M/U BHA #4 F/ 25' T/ 37' 25.0 9/8/2021 07:15 9/8/2021 11:00 3.75 COMPZN, RPCOMP TRIP P RIH F/ 37' T/ 5994'. PUW=120 klbs, SOW = 85 k lbs, tag fish and set 10 K lbs down to confirm. PU to 150 k lbs, slack off to neutral and set slips. 37.0 5,994.0 9/8/2021 11:00 9/8/2021 12:00 1.00 COMPZN, RPCOMP RURD P Swap to long bails while rigging up Alaska E-line simops. Install YT 3.5" elevators. 37.0 5,994.0 9/8/2021 12:00 9/8/2021 13:00 1.00 COMPZN, RPCOMP RURD P Complete rig up of Alaska E-line, Hang sheave, MU tool string, 2" Radial cutting torch. Latch onto string, PU 150k lbs and set in slips 37.0 5,994.0 9/8/2021 13:00 9/8/2021 18:15 5.25 COMPZN, RPCOMP ELNE P RIH with E-line @ 200 ft/min. Set down at jars. Make attempts to pass, unsuccessful. PU String, stack weight to compress jars and attempt to RIH with no success. Line up to pump down drill string. Successfully RIH past BHA and into completion. Park below GLM @ 7004'. Latch onto string, PU 30 k lbs over string weight and set in slips. Trouble falling in completion, stacking out on suspect plastic coating or other debris, pumping did not help. Decide to shoot as deep as we can. Tie in, park CCL @ 7419', engage anchors, PUH to latch collar. Indication of anchors holding. Attempt to fire cutting torch @ 7428' =, top of joint #9. No indication at surface. POOH T/ 50'. 37.0 5,994.0 9/8/2021 18:15 9/8/2021 18:30 0.25 COMPZN, RPCOMP OWFF P OWFF - No flow 5,994.0 5,994.0 Rig: NABORS 7ES RIG RELEASE DATE 9/21/2021 Page 5/12 3H-14 Report Printed: 10/13/2021 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) 9/8/2021 18:30 9/8/2021 19:30 1.00 COMPZN, RPCOMP RURD P R/D pack off and pump in sub, pull tools to rig floor. RCT did not fire. Disassemble, inspected no visual indication of failure mechanism. Replace tool string. M/U new 2" RCT with magnetic anchor. RIH. R/U pump in sub and pack off. 5,994.0 5,994.0 9/8/2021 19:30 9/8/2021 22:00 2.50 COMPZN, RPCOMP ELNE P RIH with E-line @ 200 ft/min. Set down at tubing top. Line up to pump @ 2 BPM, 210 PSI . Tag top of spear @ 7694' Tie in, park CCL @ 7633'', engage anchors, P/U to latch collar. Indication of anchors holding. Fire RCT @ 7645' w/ 30K over on string set in slips. Cut at top of joint #4. Good indication at surface of cut. POOH, tubing collars move up hole 3' on CCL. Pull T/ 50'. 5,994.0 5,994.0 9/8/2021 22:00 9/8/2021 22:15 0.25 COMPZN, RPCOMP OWFF P OWFF - no flow 5,994.0 5,994.0 9/8/2021 22:15 9/9/2021 00:00 1.75 COMPZN, RPCOMP RURD P R/D pack off and pump in sub, pull tools to rig floor. RCT fired. R/D E-line. P/U on string verify pipe is free - good cut PUW=140K. Changing elevators and bails. 5,994.0 7,645.0 9/9/2021 00:00 9/9/2021 01:00 1.00 COMPZN, RPCOMP RURD P Swap long bails back to short bails. Fix safety wire on top drive bail ear ODS. Install drill pipe elevators. 7,645.0 7,645.0 9/9/2021 01:00 9/9/2021 02:30 1.50 COMPZN, RPCOMP CIRC P Circulate and condition hole post cut. Verify line up, start pumping @ 6 bpm & 1220 psi. Stage down to 3 bpm & 380 psi as bottoms approached surface. FCP 365 psi. Total bbls circulated 288, monitor well 10 minutes - 2.4 bbl/h losses. 7,645.0 7,645.0 9/9/2021 02:30 9/9/2021 06:00 3.50 COMPZN, RPCOMP TRIP P Completion -trip tubing/DP, blow down top drive, TOH, set back in derrick from 7645' to top of fish @ 1640' 7,645.0 1,678.0 9/9/2021 06:00 9/9/2021 06:30 0.50 COMPZN, RPCOMP BHAH P Completion PU / LD, make up tools, BHA, LD BHA as per baker rep. 1,678.0 1,640.0 9/9/2021 06:30 9/9/2021 09:30 3.00 COMPZN, RPCOMP PULL P Completion - trip tubing / DP POOH with fish. UPW=40 k lbs t / Cut joint/ total L/D 1,601.22'. 1,640.0 0.0 9/9/2021 09:30 9/9/2021 11:30 2.00 COMPZN, RPCOMP TRIP P Completion - trip tubing/DP, RIH with 3.5" tubing out of derrick, 20 stands PU Wt = 45k lbs 0.0 1,860.0 9/9/2021 11:30 9/9/2021 13:30 2.00 COMPZN, RPCOMP PULD P Completion - trip tubing/DP, POOH and L/D 60 joints of 3.5 " tubing. 1,860.0 0.0 9/9/2021 13:30 9/9/2021 14:30 1.00 COMPZN, RPCOMP RURD P Clear and clean floor and prep to run 2- 7/8 PAC DP, change elevators, bring BHA to rig floor, PJSM 0.0 0.0 9/9/2021 14:30 9/9/2021 19:00 4.50 COMPZN, RPCOMP BHAH P M/U BHA #5 Overshot on 2 7/8" work string followed by jar package T/ 2030' PUW=50K 0.0 2,030.0 9/9/2021 19:00 9/9/2021 22:00 3.00 COMPZN, RPCOMP TRIP P RIH w/ BHA #5 on 3 1/2" DP F/ 2030' T/ 7584', PUW=145, SOW=45 2,030.0 7,584.0 9/9/2021 22:00 9/9/2021 23:00 1.00 COMPZN, RPCOMP FISH P RIH tag fish @ 7626', swallow T/ 7631'. P/U T/ 290K, hit jars, P/U T/ 310K. Hit jars 5x @ 245K, P/U T/ 310K. Hit jars 5x @ 245K, P/U T/ 315K. Hit jars 5x @ 245K, P/U T/ 310K, fish came free, P/U one more over pull 180K, fish came free. P/U T/ 7778' end of fish depth ORKB 7,584.0 7,778.0 Rig: NABORS 7ES RIG RELEASE DATE 9/21/2021 Page 6/12 3H-14 Report Printed: 10/13/2021 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) 9/9/2021 23:00 9/9/2021 23:45 0.75 COMPZN, RPCOMP CIRC P Circt STS @ 6 BPM, 2550 PSI. Stage down to 3 BPM, 760 PSI as bottoms approached surface. Total bbls circulated 260, 7,778.0 7,778.0 9/9/2021 23:45 9/10/2021 00:00 0.25 COMPZN, RPCOMP OWFF P OWFF - No flow 7,778.0 7,778.0 9/10/2021 00:00 9/10/2021 00:30 0.50 COMPZN, RPCOMP SVRG P Derrick inspection post jarring. 7,778.0 7,778.0 9/10/2021 00:30 9/10/2021 01:00 0.50 COMPZN, RPCOMP SVRG P Service rig - top drive and draw works. 7,778.0 7,778.0 9/10/2021 01:00 9/10/2021 05:00 4.00 COMPZN, RPCOMP TRIP P PU single to stand 59, TOH setting back in derrick from 7,770' to 2,030' 7,778.0 2,030.0 9/10/2021 05:00 9/10/2021 05:30 0.50 COMPZN, RPCOMP BHAH P Lay down 4-3/4 drill collars, jars, bumper sub and intensifier to pipe shed - change elevators. 2,030.0 2,030.0 9/10/2021 05:30 9/10/2021 07:30 2.00 COMPZN, RPCOMP PULL P POOH with 2-7/8" PAC standing back in the derrick. PU Wt = 46 k lbs, LD 3 joints to the pipe shed, pull overshot to the floor. No fish recovered. Grapple broke, small amount of grapple left in hole. 2,030.0 0.0 9/10/2021 07:30 9/10/2021 08:30 1.00 COMPZN, RPCOMP CLEN P Organize and clean rig floor, clear fishing equip. 0.0 0.0 9/10/2021 08:30 9/10/2021 10:30 2.00 COMPZN, RPCOMP RURD P Prep cellar and well head for BOP test. Remove wear ring, install test plug, make up all testing equipment for 250/3500 psi weekly BOP test 0.0 0.0 9/10/2021 10:30 9/10/2021 17:00 6.50 COMPZN, RPCOMP BOPE P Weeklyl BOPE test All test at 250/3500 PSI for 5 Min each, Tested VBR's, LPR w/ 3 1/2" test joint. Tested annular and VBR's w/ 2 7/8" test joint. Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3 1/2" HT-38 FOSV and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves and manual and HCR choke valves. Test hydraulic and manual test valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1650 PSI, 200 PSI attained =17 sec, full recovery attained =102 sec. 5 bake up nitrogen bottles average =2045 PSI. Test gas detectors, PVT and flow show. Witnessed waived by AOGCC rep Bob Knoble. All testes passed. 0.0 0.0 9/10/2021 17:00 9/10/2021 18:15 1.25 COMPZN, RPCOMP RURD P R/D, B/D testing equipment. Pull test plug, run 7 1/16" wear ring. 0.0 0.0 9/10/2021 18:15 9/10/2021 18:30 0.25 COMPZN, RPCOMP OWFF P OWFF - No Flow 0.0 0.0 9/10/2021 18:30 9/10/2021 19:00 0.50 COMPZN, RPCOMP BHAH P M/U BHA #6 Overshot w/ barrel extension T/ 10' 0.0 10.0 9/10/2021 19:00 9/10/2021 20:15 1.25 COMPZN, RPCOMP TRIP P RIH w/ BHA #6 on 2 7/8" work string T/ 1900' 10.0 1,900.0 9/10/2021 20:15 9/10/2021 21:45 1.50 COMPZN, RPCOMP BHAH P M/U jar packacge XO F/ 2 7/8" T/ 3 1/2" DPT/ 2032', PUW=52K, SOW=50K 1,900.0 2,032.0 9/10/2021 21:45 9/11/2021 00:00 2.25 COMPZN, RPCOMP TRIP P RIH w/ BHA #6 on DP F/ 2032' T/ 4000', SOW=70K 2,032.0 4,000.0 9/11/2021 00:00 9/11/2021 03:00 3.00 COMPZN, RPCOMP TRIP P RIH w/ BHA #6 on DP F/ 2032', took 10K weight @ 6095' and fell off, tag fish top @ 7626', swallow T/ 7631'. PUW=147K, SOW=85K 4,000.0 7,626.0 Rig: NABORS 7ES RIG RELEASE DATE 9/21/2021 Page 7/12 3H-14 Report Printed: 10/13/2021 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) 9/11/2021 03:00 9/11/2021 05:30 2.50 COMPZN, RPCOMP FISH P P/U T/ 145K over, 5 hits w/ jars @ 100K over, continue cycle raising over pull every 5 hits 5K at a time up T/ 205K over. Continue jarring @ 100K over and pulling T/ 205K over, total of 95 jar hits no movement. 7,626.0 7,626.0 9/11/2021 05:30 9/11/2021 06:00 0.50 COMPZN, RPCOMP SVRG P Derrick inspection, allow draw works brake bands T/ cool off. 7,626.0 7,626.0 9/11/2021 06:00 9/11/2021 07:00 1.00 COMPZN, RPCOMP FISH P Continue to jar on fish. Pulling to 140 k jar 5 times then straight pull 355k. After jar hit 56 pulled to 355 k lbs and weight released. RIH tagged ~2' high, slight over pull of 5-10k lbs while picking up. 7,626.0 7,576.0 9/11/2021 07:00 9/11/2021 09:00 2.00 COMPZN, RPCOMP CIRC P Circulate 12.1 brine @ 6 bpm and 2620 psi. 100 bbls away. Some gas observed in returns, rate to 4 bpm and 1230 psi, 3 bpm and 760 psi until returns clean up. total pumped 320 bbls, monitor well - loss rate 1.8 bbl/hr 7,576.0 7,576.0 9/11/2021 09:00 9/11/2021 13:00 4.00 COMPZN, RPCOMP TRIP P Start setting back stands, well out of balance with heavier fluid on the back side. Pump 40 bbls 12.1+ down DP - good. POOH from 7,576 to 2,032' racking to derrick. 7,576.0 2,032.0 9/11/2021 13:00 9/11/2021 13:30 0.50 COMPZN, RPCOMP BHAH P Lay down BHA, collars, jars and crossovers. 2,032.0 1,890.0 9/11/2021 13:30 9/11/2021 15:30 2.00 COMPZN, RPCOMP TRIP P set back 2-7/8" HT PAC DP from 1,890' to overshot. - No fish! 1,890.0 0.0 9/11/2021 15:30 9/11/2021 16:30 1.00 COMPZN, RPCOMP CLEN P Clean and clear rig floor. 0.0 0.0 9/11/2021 16:30 9/11/2021 17:00 0.50 COMPZN, RPCOMP PULD P L/D 2 stand of 2 7/8 work string from derrick T/ pipe shed to reduce footage of excess 2 7/8" 0.0 0.0 9/11/2021 17:00 9/11/2021 17:30 0.50 COMPZN, RPCOMP SVRG P Service rig grease blocks, TD and wash pipe. 0.0 0.0 9/11/2021 17:30 9/11/2021 18:45 1.25 COMPZN, RPCOMP WAIT P Consult with town about plan forward, ordered fishing tools from Baker. 0.0 0.0 9/11/2021 18:45 9/11/2021 19:15 0.50 COMPZN, RPCOMP RURD P Mobilize tools T/ RF. 0.0 0.0 9/11/2021 19:15 9/11/2021 20:15 1.00 COMPZN, RPCOMP BHAH P M/U BHA #7 spear as per Baker rep. T/ 37' PUW=30K, SOW=30K 0.0 37.0 9/11/2021 20:15 9/11/2021 21:30 1.25 COMPZN, RPCOMP TRIP P RIH w/ BHA #7 on 2 7/8" WS F/ 37' T/ 1646' 37.0 1,646.0 9/11/2021 21:30 9/11/2021 23:00 1.50 COMPZN, RPCOMP BHAH P M/U jar package and one DC F/ 1646' T/ 1722' PUW=48K, SOW=48K 1,646.0 1,722.0 9/11/2021 23:00 9/11/2021 23:15 0.25 COMPZN, RPCOMP SFTY P Kick while tripping drill. AAR 1,722.0 1,817.0 9/11/2021 23:15 9/12/2021 00:00 0.75 COMPZN, RPCOMP TRIP P RIH w/ BHA #7 on DP F/ 1722' T/ 3200', SOW=62K 1,817.0 3,200.0 9/12/2021 00:00 9/12/2021 02:30 2.50 COMPZN, RPCOMP TRIP P RIH w/ BHA #7 on DP F/ 3200' T/ 7600'. L/D single of DP. PUW=145K, SOW=85K 3,200.0 7,600.0 9/12/2021 02:30 9/12/2021 03:00 0.50 COMPZN, RPCOMP SFTY P PJSM w/ rig crew and Baker rep. Discuss jarring operation and barrier zones. 7,600.0 7,600.0 9/12/2021 03:00 9/12/2021 03:30 0.50 COMPZN, RPCOMP FISH P RIH w/ BHA #7 on DP F/ 7600' tag fish top @ 7626', sink spear T/ 7630'. P/U fire jars once @ 55K over P/U and lost weight @ 142K. S/O retag same spot. P/U and lost weight 65K over. PUW=145K, SOW=85K 7,600.0 7,620.0 9/12/2021 03:30 9/12/2021 03:45 0.25 COMPZN, RPCOMP OWFF P OWFF - no flow. 7,620.0 7,620.0 Rig: NABORS 7ES RIG RELEASE DATE 9/21/2021 Page 8/12 3H-14 Report Printed: 10/13/2021 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) 9/12/2021 03:45 9/12/2021 05:30 1.75 COMPZN, RPCOMP TRIP P Trip out of hole racking back to derrick from 7623 to 5124' UWt=102 k lbs SOWt= 72 k lbs 7,620.0 5,124.0 9/12/2021 05:30 9/12/2021 06:00 0.50 COMPZN, RPCOMP SVRG P Service rig, grease iron roughneck, draw works, and blocks 5,124.0 5,124.0 9/12/2021 06:00 9/12/2021 11:30 5.50 COMPZN, RPCOMP TRIP P Continue to trip out of hole from 5,124' to 1,715' UWt = 102 k lbs, SOWt= 72 k lbs, 63 stands 5,124.0 1,715.0 9/12/2021 11:30 9/12/2021 12:00 0.50 COMPZN, RPCOMP BHAH P Lay down BHA #7, collars, jars & XO. Note one third of the grapple broken off and left in hole. See Pictures in Maxwell, BHA7 1,715.0 0.0 9/12/2021 12:00 9/12/2021 12:30 0.50 COMPZN, RPCOMP BHAH P Pick up BHA #8 - 3.5" overshot with additional barrel to bit ~ 9' down on stub. 0.0 10.0 9/12/2021 12:30 9/12/2021 13:00 0.50 COMPZN, RPCOMP SVRG P Service top drive, mechanic inspected all instruments, gauges, hose connections and brackets. 10.0 10.0 9/12/2021 13:00 9/12/2021 14:30 1.50 COMPZN, RPCOMP BHAH P Continue picking up BHA #8 - RIH with 52 joints 2-7/8" PAC pipe PU jars, bumper sub and collar from pipe shed to 1729' 10.0 1,729.0 9/12/2021 14:30 9/12/2021 19:00 4.50 COMPZN, RPCOMP TRIP P RIH with 3-1/2" DP F/ 1,729' T/ 6095', took weight, had to kelly up and rotate off to get past obstruction. Continue RIH T/ 7585'. L/D single and kelly up RIH T/ fish top @ 7626' 1,729.0 7,626.0 9/12/2021 19:00 9/12/2021 20:00 1.00 COMPZN, RPCOMP FISH P Engage fish & swallow T/ 7635'. S/O 35K string weight on fish. P/U fire jars 75K over, hit jars 4x @ 100K over, P/U T/ 215K over. Hit jars 5x @ 125K over P/U T/ 222K over, lost weight. S/O retag @ 7635' P/U clean no over pull. P/U T/ 7614' 7,626.0 7,614.0 9/12/2021 20:00 9/12/2021 21:00 1.00 COMPZN, RPCOMP CIRC P Circ well w/ 289 Bbls stating @ 6 BPM, 2500 PSI, staging pump down T/ 3 BPM 790 PSI as BU came back. Slight gas returns seen at surface. 7,614.0 7,614.0 9/12/2021 21:00 9/12/2021 21:15 0.25 COMPZN, RPCOMP OWFF P OWFF - no flow. Static loss rate 1.6 BPH 7,614.0 7,614.0 9/12/2021 21:15 9/12/2021 21:45 0.50 COMPZN, RPCOMP SVRG P Post jarring inspection of top drive and derrick 7,614.0 7,614.0 9/12/2021 21:45 9/13/2021 00:00 2.25 COMPZN, RPCOMP TRIP P POOH F/ 7614' T/ 4325', PUW=145K, SOW=85K 7,614.0 4,325.0 9/13/2021 00:00 9/13/2021 03:30 3.50 COMPZN, RPCOMP TRIP P POOH F/ 4320' T/ 1729', PUW=45K, LD Baker equipment, jars and bumper sub. Racked back 17 stands of 2-7/8 PAC DP. 4,325.0 46.0 9/13/2021 03:30 9/13/2021 04:00 0.50 COMPZN, RPCOMP BHAH P Lay down BHA #8 - LD 1 joint of 2-7/8" DP and overshot - no fish. 46.0 0.0 9/13/2021 04:00 9/13/2021 04:30 0.50 COMPZN, RPCOMP SVRG P Service top drive, crown and iron roughneck 0.0 0.0 9/13/2021 04:30 9/13/2021 05:00 0.50 COMPZN, RPCOMP RURD P Prepare rig floor to run 3.5" EUE tubing as work string 0.0 0.0 9/13/2021 05:00 9/13/2021 05:30 0.50 COMPZN, RPCOMP RURD P Remove wear bushing 0.0 0.0 9/13/2021 05:30 9/13/2021 06:00 0.50 COMPZN, RPCOMP CLEN P Make up XO to TIW. Clean clear rig floor 0.0 0.0 9/13/2021 06:00 9/13/2021 06:30 0.50 COMPZN, RPCOMP BHAH P Pick up BHA #9 - overshot. ID 3" OD 4.6875", L = 2.68', F/N 0.750 and 4.5" OD 0.0 33.0 9/13/2021 06:30 9/13/2021 12:00 5.50 COMPZN, RPCOMP PULD P Trip in hole with 3.5" EUE tubing W seal rings, torque 2240 psi, T/ 4057", SOW = 50 UWT 56 33.0 4,057.0 Rig: NABORS 7ES RIG RELEASE DATE 9/21/2021 Page 9/12 3H-14 Report Printed: 10/13/2021 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) 9/13/2021 12:00 9/13/2021 15:00 3.00 COMPZN, RPCOMP SLPC P Cut an slip drill line, 11 wraps, inspect draw works, break pads, reset derrick block height. adjust CM. 4,057.0 4,057.0 9/13/2021 15:00 9/13/2021 18:00 3.00 COMPZN, RPCOMP PACK P M/U L Storm Packer T/ EUE tubing string and RIH on 1 stand of DP. Set packer COE @ 98.89'. Rack back stand of DP. 4,057.0 4,156.0 9/13/2021 18:00 9/13/2021 18:30 0.50 COMPZN, RPCOMP PRTS P Test packer from above T/ 1000 PSI for 10 Min - good test. 4,156.0 4,156.0 9/13/2021 18:30 9/14/2021 00:00 5.50 COMPZN, RPCOMP NUND P N/D stack and move to back of cellar on cranes. Attempt T/ N/D tubing spool, 7" began to grow. Called out hydra tight. Strip IA and LDS off of tubing spool. R/U hydra tight equipment. 4,156.0 4,156.0 9/14/2021 00:00 9/14/2021 11:00 11.00 COMPZN, RPCOMP WWSP P Relax 7" casing with Hydro Tight tool - 20 k lbs psi to release the growth and a total of 24"s growth. RD Hydro Tight and make up Baker spear. Remove tubing spool. Pick up on casing with 206 k lbs for a lift of 75 k lbs. Reset 7" csg in emergency slips, additional growth of 24" - total 48". LD baker spear. Change out pack offs, note old pack offs broke when removing, some of the assembly bolts seemed to have been broken previously and were corroded. RU Wacks saw and cut casing. 4,156.0 4,156.0 9/14/2021 11:00 9/14/2021 14:00 3.00 COMPZN, RPCOMP WWSP P Install C-bowl as per the Carmon rep. Test at 3000 psi for 20 minutes - good. Installed secondary valve onto IA rigged IA back to the tiger tank line. 4,156.0 4,156.0 9/14/2021 14:00 9/14/2021 17:00 3.00 COMPZN, RPCOMP BOPE P Test BOPs to 250/3500 low / high - note test only at break and 3.5 EUE FOSV. 4,156.0 4,156.0 9/14/2021 17:00 9/14/2021 18:00 1.00 COMPZN, RPCOMP RURD P laydown testing tools, pull test plug, blow down lines. 4,156.0 4,156.0 9/14/2021 18:00 9/14/2021 18:30 0.50 COMPZN, RPCOMP RURD P Install wear bushing ID 6 3/8" 4,156.0 4,156.0 9/14/2021 18:30 9/14/2021 20:30 2.00 COMPZN, RPCOMP MPSP P Run in the hole and engage storm packer, unseat storm packer and attempt to circ. (equalizing valve did not open). Reset storm packer, make up the stand with the retrieving tool with the top drive, screw into storm packer with top drive. (Valve opened) No Gas 4,156.0 4,156.0 9/14/2021 20:30 9/14/2021 21:30 1.00 COMPZN, RPCOMP CIRC P CIrc. B/U @ 140 gpm 187 psi. 4,156.0 4,156.0 9/14/2021 21:30 9/14/2021 23:00 1.50 COMPZN, RPCOMP TRIP P Pull storm packer to the floor and L/D 4,156.0 4,089.0 9/14/2021 23:00 9/15/2021 00:00 1.00 COMPZN, RPCOMP PUTB P Rig up and run 3 ½ EUE 9.3# tubing F/ 4,089’ - T/ 4,323' 4,089.0 4,323.0 9/15/2021 00:00 9/15/2021 05:30 5.50 COMPZN, RPCOMP PUTB P Rig up and run 3 ½ EUE 9.3# tubing F/ 4,323' - T/ 7,606' 4,323.0 7,606.0 9/15/2021 05:30 9/15/2021 07:00 1.50 COMPZN, RPCOMP PUTB P Pick up jnt. 247 RIH and tagged cut off jnt, @ 7,631', L/D Jnts 247 & 246, pick up space-out pups and jnt. 246. S/O onto the top of the cut off jnt. setting 5k of compression before setting slips. 7,606.0 7,631.0 9/15/2021 07:00 9/15/2021 09:30 2.50 COMPZN, RPCOMP RURD P Install FOSV and rig up Haliburton Slck line. 7,631.0 7,631.0 9/15/2021 09:30 9/15/2021 12:00 2.50 COMPZN, RPCOMP SLKL P RIH with 2.76” LIB down to 7,629’, pull out of the hole with not a clear imprint. 7,631.0 7,629.0 9/15/2021 12:00 9/15/2021 13:30 1.50 COMPZN, RPCOMP SLKL P RIH with 2.5” LIB came back with perfect/clean picture of FN 7,673’ 7,629.0 7,673.0 Rig: NABORS 7ES RIG RELEASE DATE 9/21/2021 Page 10/12 3H-14 Report Printed: 10/13/2021 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) 9/15/2021 13:30 9/15/2021 16:30 3.00 COMPZN, RPCOMP SLKL P RIH with 1.85” LIB came back with picture of FN 7,670’ 7,673.0 7,670.0 9/15/2021 16:30 9/15/2021 17:30 1.00 COMPZN, RPCOMP RURD P Rig down slick-lne 7,670.0 7,630.0 9/15/2021 17:30 9/15/2021 18:00 0.50 COMPZN, RPCOMP OWFF P Monitor well (No Flow) losing 1.8 bph 7,630.0 7,630.0 9/15/2021 18:00 9/15/2021 21:30 3.50 COMPZN, RPCOMP TRIP P Trip out of the hole l/d down jnt 247 and 3 pups, continue out with 3 1/2 EUE, stood back in the derrick F/7,630' - T/2,798' . 7,630.0 2,798.0 9/15/2021 21:30 9/15/2021 22:30 1.00 COMPZN, RPCOMP CIRC P Monitor well no flow but, brine was out of balance. Circ. B/U 168 gpm 170 psi. 2,798.0 2,798.0 9/15/2021 22:30 9/16/2021 00:00 1.50 COMPZN, RPCOMP TRIP P Continue POOH F/2,798 - T/ surface. 2,798.0 0.0 9/16/2021 00:00 9/16/2021 03:30 3.50 COMPZN, RPCOMP BHAH P Pick up BHA : 3'' GS Spear with 17 stands of 2 7/8 work string. 0.0 2,798.0 9/16/2021 03:30 9/16/2021 09:00 5.50 COMPZN, RPCOMP TRIP P RIH with 3- ½” DP. F/2,798' - T/7,629' 2,798.0 7,629.0 9/16/2021 09:00 9/16/2021 10:00 1.00 COMPZN, RPCOMP TRIP P Discussed w/town limitations of fishing assembly. @ 7,629’ - Work pipe pass through cut off 3-1/2” joint T/7,662’ - Pickup Weight 132k 7,629.0 7,662.0 9/16/2021 10:00 9/16/2021 10:30 0.50 COMPZN, RPCOMP TRIP P 7,673’ - Latched up to fish (P2P), bled jars, then straight pulled to 149k, popped free, continued up hole seeing 8 -10k weight bobbles, increase loss rate from 1.8 bph to 2.5 bph 7,662.0 7,666.0 9/16/2021 10:30 9/16/2021 11:30 1.00 COMPZN, RPCOMP OWFF P POOH T/ 7,666’ - Park and monitored well for flow. Loss rate = 1.8 bph 7,666.0 7,673.0 9/16/2021 11:30 9/16/2021 12:00 0.50 COMPZN, RPCOMP TRIP P Continue POOH F/7,666' - T/7,649’ 7,673.0 7,649.0 9/16/2021 12:00 9/16/2021 13:00 1.00 COMPZN, RPCOMP TRIP P @ 7,649’ - hung up at top of pup joint, worked pipe past, Continue POOH 7,649.0 7,629.0 9/16/2021 13:00 9/16/2021 14:00 1.00 COMPZN, RPCOMP TRIP P @ 7,629’ - then hung up at top of cut joint (might be bottle necked, jar 13 times, freely moving up hole, continue POOH 7,629.0 7,585.0 9/16/2021 14:00 9/16/2021 14:30 0.50 COMPZN, RPCOMP SVRG P Monitor well for flow, inspect derrick (post jarring) (Loss rate = 1.9bph 7,585.0 7,585.0 9/16/2021 14:30 9/16/2021 19:30 5.00 COMPZN, RPCOMP TRIP P Continue POOH F/ 7,585' - T/1,813' 7,585.01,813.0 9/16/2021 19:30 9/16/2021 22:00 2.50 COMPZN, RPCOMP BHAH P L/B BHA : Jars, Bumper Sub, & Stand back 17 stands r2 7/8 work string. RETRERIVED A BAITED SUB 1,813.0 0.0 9/16/2021 22:00 9/16/2021 23:00 1.00 COMPZN, RPCOMP WAIT P Discussed with town on next step. 0.0 0.0 9/16/2021 23:00 9/17/2021 00:00 1.00 COMPZN, RPCOMP BHAH P Pick up New bait sub & RIH W/ BHA 0.0 500.0 9/17/2021 00:00 9/17/2021 04:30 4.50 COMPZN, RPCOMP TRIP P Tripping in with New bait sub/GS spear on 3 joints of 2 1/16” CS Hydril crossed over T/ 2 7/8” WS T/ 3 ½” . 500.0 5,880.0 9/17/2021 04:30 9/17/2021 07:30 3.00 COMPZN, RPCOMP MPSP P M/U L Storm Packer T/ EUE tubing string and RIH on 1 stand of DP. Set packer COE @ 98'. Rack back stand of DP. 5,880.0 5,978.0 9/17/2021 07:30 9/17/2021 09:30 2.00 COMPZN, RPCOMP RURD P Rig up to test BOPE 5,978.0 5,978.0 Rig: NABORS 7ES RIG RELEASE DATE 9/21/2021 Page 11/12 3H-14 Report Printed: 10/13/2021 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) 9/17/2021 09:30 9/17/2021 16:30 7.00 COMPZN, RPCOMP BOPE P Weeklyl BOPE test All test at 250/3500 PSI for 5 Min each, Tested VBR's, LPR w/ 3 1/2" test joint. Tested annular and VBR's w/ 2 7/8" test joint. Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3 1/2" HT-38 FOSV and IBOP. Test 2" rig floor Demco kill valves. Test manual kill valve fail/pass. HCR kill valves Pass. Manual Choke Fail/pass HCR choke valve passed. Test hydraulic and manual test valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1650 PSI, 200 PSI attained =17 sec, full recovery attained =102 sec. 5 bake up nitrogen bottles average =2045 PSI. Test gas detectors, PVT and flow show. Witnessed by AOGCC rep Guy Cook. All testes passed. 5,978.0 5,978.0 9/17/2021 16:30 9/17/2021 16:45 0.25 COMPZN, RPCOMP BOPE T Manual Choke & Kill (Failed) greased and retest Pass 5,978.0 5,978.0 9/17/2021 16:45 9/17/2021 19:00 2.25 COMPZN, RPCOMP RURD P Pull Test plug, L/D Tesst joint. Drain stack and stall wear bushing. 5,978.0 5,978.0 9/17/2021 19:00 9/17/2021 20:00 1.00 COMPZN, RPCOMP MPSP P Unseat storm packer and monitor well (well losing 1.9bph) 5,978.0 5,978.0 9/17/2021 20:00 9/17/2021 20:30 0.50 COMPZN, RPCOMP WAIT P Discussed with town on next step. 5,978.0 5,978.0 9/17/2021 20:30 9/18/2021 00:00 3.50 COMPZN, RPCOMP TRIP P POOH L/D pipe F/5,978' - T/3,895' P/U= 102k S/O= 80k 5,978.0 3,895.0 9/18/2021 00:00 9/18/2021 02:30 2.50 COMPZN, RPCOMP TRIP P Trip out of the hole laying down 3 ½ Drill pipe f/3,895’ – T/1,876’ 3,895.0 1,875.0 9/18/2021 02:30 9/18/2021 04:00 1.50 COMPZN, RPCOMP TRIP P Trip in the hole withstands out of the derrick 3 ½ Drill pipe F/1,876’ – T/3,705’ 1,875.0 3,705.0 9/18/2021 04:00 9/18/2021 06:00 2.00 COMPZN, RPCOMP TRIP P Trip out of the hole laying down 3 ½ Drill pipe f/3,705’ – T/1,813’ 3,705.0 1,813.0 9/18/2021 06:00 9/18/2021 07:00 1.00 COMPZN, RPCOMP SVRG P Adjust draw works break. 1,813.0 1,813.0 9/18/2021 07:00 9/18/2021 08:00 1.00 COMPZN, RPCOMP BHAH P L/D down jar assemble with Baker Rep. 1,813.0 1,800.0 9/18/2021 08:00 9/18/2021 10:30 2.50 COMPZN, RPCOMP RURD P Swap out handling equipment.L/D 2 7/8 work string 1,800.0 1,800.0 9/18/2021 10:30 9/18/2021 12:00 1.50 COMPZN, RPCOMP BHAH P L/D down jar assemble with Baker Rep. 500.0 0.0 9/18/2021 12:00 9/18/2021 13:00 1.00 COMPZN, RPCOMP RURD P Swap out weatherford casing equipment to nabors equipment 0.0 0.0 9/18/2021 13:00 9/18/2021 20:30 7.50 COMPZN, RPCOMP TRIP P Run 3 ½ tubing form out of the derrick T/5,576’ 0.0 5,576.0 9/18/2021 20:30 9/19/2021 00:00 3.50 COMPZN, RPCOMP TRIP P L/D 3 ½ tubing form 5,576’ – 4,200’ 5,576.0 4,200.0 9/19/2021 00:00 9/19/2021 01:30 1.50 COMPZN, RPCOMP TRIP P L/D 3 ½ tubing form 4,200’ - T/ 3,186' replace seal rings 4,200.0 3,186.0 9/19/2021 01:30 9/19/2021 04:30 3.00 COMPZN, RPCOMP TRIP P Trip in the hole with 3.5" tubing F/3,186' - T/ 5,237' 3,186.0 5,237.0 9/19/2021 04:30 9/19/2021 15:00 10.50 COMPZN, RPCOMP PULD P L/D 3 ½ tubing form 5,237' - to surface. replace seal rings 5,237.0 0.0 9/19/2021 15:00 9/19/2021 15:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA, clear equipment off the floor. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 9/21/2021 Page 12/12 3H-14 Report Printed: 10/13/2021 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) 9/19/2021 15:30 9/19/2021 16:00 0.50 COMPZN, RPCOMP OTHR P Pull wear bushing 0.0 0.0 9/19/2021 16:00 9/19/2021 18:30 2.50 COMPZN, RPCOMP RURD P Load pipeshed with OLD 3 1/2" 9,3# L- 80 tubing. and tally 0.0 0.0 9/19/2021 18:30 9/19/2021 23:30 5.00 COMPZN, RPCOMP PUTB P M/U & RIH with 80 jnts of old 3 1/2" 10.4# L-80 tubing. New seal rings. 0.0 2,519.2 9/19/2021 23:30 9/20/2021 00:00 0.50 COMPZN, RPCOMP THGR P Make up hanger & landing jnt. Land kill string. P/U47k S/O 47k install BPV 0.0 0.0 9/20/2021 00:00 9/20/2021 08:00 8.00 COMPZN, RPCOMP SVRG P CHANGE RAMS, PERFORM BETWEEN WELL BOP INSPECTION 0.0 0.0 9/20/2021 08:00 9/20/2021 11:00 3.00 COMPZN, RPCOMP NUND P NIPPLE DOWN BOPS REMOVE RISER, REMOVE TURN BUCKLES, PULL KILL LINE, REMOVE STACK AND SET ON PEDISTAL AND SECURE, REMOVE ADAPATOR FLANGE 0.0 0.0 9/20/2021 11:00 9/20/2021 15:00 4.00 COMPZN, WHDBOP NUND P NU/ND TREE INSTALL ADAPTOR AND TEST, 5000 PSI 15 MIN TEST-GOOD, MAKE UP DRYHOLE TREE AND TQ 0.0 0.0 9/20/2021 15:00 9/20/2021 16:30 1.50 COMPZN, WHDBOP MPSP P PULL/SET BPV PULL BPV, SET TWC, RIG UP LINES FOR FREEZE PROTECT, TEST LINES AND TREE 5000 PSI-GOOD TEST 0.0 0.0 9/20/2021 16:30 9/20/2021 19:00 2.50 COMPZN, WHDBOP FRZP P TEST LRHOS LINES 4000 PSI, PUMP 180 BBLS DIESEL DOWN IA TAKING RETURNS TO TIGER TANK, 1000 PSI MAX PRESSURE OBSERVED, B/D LINE TO TIGER TANK, 0.0 0.0 9/20/2021 19:00 9/20/2021 20:00 1.00 COMPZN, WHDBOP FRZP P U-TUBE, SURFACE PRESSURE TBG. 300 PSI, IA 300 PSI, 0.0 0.0 9/20/2021 20:00 9/20/2021 23:00 3.00 COMPZN, WHDBOP MPSP P PULL/SET BPV R/U LUBRICATOR & LUBRICATE IN BPV, L/D SAME 0.0 0.0 9/20/2021 23:00 9/21/2021 00:00 1.00 DEMOB, MOVE RURD P REMOVE SECONDARY WORKING VALVE ON IA & 1502/ FLANG OFF WING VALVE, SECURE WELL & CELLAR *** RIG RELEASED FROM WELL 3H- 14B @ 24:00 HRS.*** 0.0 Rig: NABORS 7ES RIG RELEASE DATE 9/21/2021 From:Simek, Jill To:Loepp, Victoria T (OGC) Cc:Ward, Dusty K; Phillips, Ron L; Senden, R. Tyler Subject:RE: [EXTERNAL]KRU 3H-14B (PTD 205-021, Sundry 321-490) Suspension sundry Date:Wednesday, September 29, 2021 3:39:25 PM Hi Victoria, I’m back from vacation, and understand you have some questions about the status of 3H-14B and future plans for the well’s suspension. Below is information requested. Let me know if you need more details. 1. The spear was recovered by the rig, which should allow the suspension cement plug to be pumped to the laterals. The suspension procedure submitted with the application for sundry approval includes steps to: run in hole with coil tubing, to just above the tubing stub, then pump cement down the tubing, into the laterals, bringing top of cement to 5,900ft KB. This top of cement can be made deeper, if desired. Please advise. 2. We did not set the plug at 7,600ft. With the spear out of the patch, we plan to pump through the fish to place cement as described above. 3. 7” and 5 ½” cementing records (from rig reports) and calculations are below. 7” Cement Info: 12/14/1987 Rig Report: Mix and pump 500 sxs 50/50 poz with 4.0% D-20, .2% D-46, .5% D-65 @ 12ppg. Tail with 300 sxs Class “G” with 3% KCL, .9% D-127, .3% P-13, .2% D-46 @ 15.8ppg. Used three plug system. Displaced with 10.0 brine. Bump plug to 3500psi... Full returns entire job. Calculations: Lead: (500 sxs)*(1.85 ft3/sx)*(0.1781 bbls/ft3) = 165 bbls Tail: (300 sxs)*(1.16 ft3/sx)*(0.1781 bbls/ft3) = 62 bbls Total cement = 165 + 62 = 227 bbls BS = 8 ½” Production Casing = 7” 26# Production Casing set at 8,220 ft KB Annular Capacity, with 40% excess assumed = 1.4*(0.0225857 bbls/ft) = 0.03162 bbls/ft Top of cement 8 ½”open hole x 7” annulus = 8,220 ft – (227 bbls)/(0.03162 bbls/ft) = ~1,041 ft KB 5 ½” Cement Info: 4/12/2005 Rig Report: Turned Over to Cementers, Fill Lines and Pressure Test Lines to 3500psi, Pumped 20BBL of CW 100. Mix & Pump 20 BBL of Mud Push II Spacer @ 13ppg, Mix and Pump 40BBL of Tail @ 15.8ppg Drip Plug, Pump 20 BBL of Water & Turned over to Rig Pump 3BPM (350psi) Bumped @ 863 strokes & Pressure up to 3500psi Calculations: BS (below window) = 7” Liner = 5.5” 15.5# Liner set at 7,925ft KB Window at 6,227ft KB Annular Capacity, with 40% excess assumed = 1.4*(0.0182142 bbls/ft) = 0.02550 bbls/ft Top of cement in 7” open hole x 5 ½” annulus = 7,925 ft – (40 bbls)/(0.02550 bbls/ft) = ~6,356ft KB Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-4131 | Cell: 907-980-7503 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, September 23, 2021 3:09 PM To: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: [EXTERNAL]KRU 3H-14B (PTD 205-021, Sundry 321-490) Suspension sundry Ty, I was looking at this sundry and questioning why the TOC for the reservoir plug couldn’t be deeper. The plan calls for the TOC for the reservoir plug at 5900’ MD which is ~2200’ above the laterals. Would also like to see the TOC outside the 5.5” liner and 7” casing. Victoria From: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Sent: Thursday, September 23, 2021 2:20 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: FW: [EXTERNAL]KRU 3H-14B (PTD 205-021, Sundry 321-490) Suspension sundry Victoria, I’m not sure exactly what conversations were had during the week (and a miserable one it was……). We in fact did not recover the spear but did recover the bait sub attached to the top of the spear. The description of our recovered fish was not communicated clear enough to our town staff over the weekend. The rig personnel were under the impression that the plug and cement were to be set post rig via slickline and coiled tubing. From your questions below I gather this was not your understanding? We are in a position to complete those tasks once the rig is moved off of the 3H pad (~7-10 days) assuming this plan is acceptable to you. Please advise. Thank you, Ty Senden Director, Coiled Tubing Drilling / Rig Workovers ATO-676 O: 907-265-1544 C: 907-982-3996 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, September 22, 2021 8:57 AM To: Simek, Jill <Jill.Simek@conocophillips.com> Cc: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Subject: [EXTERNAL]KRU 3H-14B (PTD 205-021, Sundry 321-490) Suspension sundry 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. Jill, Ron, 1. Was the spear recovered? Was the plug set at 7600” MD? 2. What was the reason that a plug and cement plug could not be placed at ~7600, pressure tested and tagged? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Loepp, Victoria T (CED) Sent: Friday, September 17, 2021 3:02 PM To: Simek, Jill <Jill.Simek@conocophillips.com> Cc: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Subject: KRU 3H-14B APPROVAL Jill, Ron, Verbal approval is granted to release the rig with the requirement that a suspension sundry will be submitted by Tuesday, September 21, 2021. Approval of the suspension sundry will include time requirements for the plugging operations. Victoria Loepp Sent from my iPhone On Sep 17, 2021, at 12:36 PM, Simek, Jill <Jill.Simek@conocophillips.com> wrote: Victoria, Since our conversation, the rig has not been able to recover the tubing stub from the cut depth at 7,645ft KB, and plans to abandon efforts for the planned workover. Currently we are attempting to fish the wireline spear at 7,694ft KB, which is stuck in the tubing patch packer at 7,695ft KB. If successful, we may be able to establish injectvity to the formation, which would allow us to pump cement for well suspension. If we are not successful recovering the spear, we will be asking the AOGCC for permission to suspend the well from a plug set above the spear, at ~7,600ft KB, as previously discussed (and outlined below). With either outcome, we plan to release the rig from the well this weekend and would like to get “verbal” approval for the suspension options described, which would be performed rigless at a later date. We expect to know our path forward tonight after the rig gets to surface with/without the spear. Thanks, Jill From: Simek, Jill Sent: Monday, September 13, 2021 3:16 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: 3H-14B Victoria, Attached are slides showing a contingency plan for suspension of KRU 3H-14B. We are currently performing a rig workover and evaluating options should we be unable to pull tubing from the well. Since a suspension would require AOGCC variance to cement from “top of fish”, I’d like to discuss this contingency with you should it become necessary. Summary of Proposed Suspension Steps: 1. Set 5.5” plug at 7,600ft KB (Rig) 2. Run kill string to 2,500ft KB (Rig) 3. Place ~42 bbls Class “G” cement from 7,600ft – 5900ft KB (Rigless w/ Coiled Tubing & Pumping Services) 4. Pressure test/tag, freeze protect well (Rigless w/ Slickline) I will give you a call to discuss. Thanks, Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-4131 | Cell: 907-980-7503 Originated: Delivered to:22-Sep-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 2V-11 50-029-21311-00 907365411 Kuparuk River Leak Detect Log Field- Final 3-Sep-21 0 12 2V-11 50-029-21311-00 907373122 Kuparuk River Multi Finger Caliper Field & Processed 4-Sep-21 0 13 2V-11 50-029-21311-00 907365411 Kuparuk River Plug Setting Record Field- Final 2-Sep-21 0 14 2V-13 50-029-21293-00 907373111 Kuparuk River Plug Setting Record Field- Final 7-Sep-21 0 15 3A-08 50-029-21445-00 907327765 Kuparuk River Packer Setting Record Field- Final 13-Aug-21 0 16 3C-17 50-029-23389-00 907330662 Kuparuk River Multi Finger Caliper Field & Processed 15-Aug-21 0 17 3H-01 50-103-20084-00 907344061 Kuparuk River Plug Setting Record Field- Final 24-Aug-21 0 18 3H-01 50-103-20084-00 907344061 Kuparuk River String Shot Record Field- Final 24-Aug-21 0 19 3H-01 50-103-20084-00 907344061 Kuparuk River Tubing Punch Record Field- Final 24-Aug-21 0 110 3H-14B 50-103-20092-02 907358282 Kuparuk River Multi Finger Caliper Field & Processed 29-Aug-21 0 111 3Q-09 50-029-21674-00 907349862 Kuparuk River Multi Finger Caliper Field & Processed 25-Aug-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:09/23/2021Wd͗ϮϬϱϬϮϭϬͲ^Ğƚ͗ϯϱϳϭϴBy Abby Bell at 10:25 am, Sep 23, 2021 X X VTL 10/6/21 X NO Suspension operations to be completed by 12/31/21 X DLB 09/20/2021 DSR-9/20/21 10-407 dts 10/6/2021 JLC 10/6/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.06 15:17:56 -08'00' RBDMS HEW 10/7/2021 JS 3H-14B Suspend Procedure (Revised: 10/4/2021) Permit to Drill #: 205-021 On 3H-14B, a recent rig workover failed to meet the objective of pulling and replacing tubing. With rig options exhausted, it has been determined that the best path forward is to suspend the well and access the stranded resource with a redrill. Per this procedure, suspended operations will be performed by pumping 69 bbls of 15.8 ppg Class “G” cement to place cement in the 2-3/8” laterals, the 3 ½” liner and tubing, and 5 ½” liner. A tag and pressure test will confirm planned Top of Cement at ~7,519ft KB. Proposed Procedure: Little Red Services: Objective: Perform injectivity test to confirm adequate rates for cementing operations 1. Inspect pad and work area for Hazards. Complete Pre-Job Safety Meeting. RU Slickline unit and support equipment. PT lubricator and surface lines as required. 2. Using diesel, perform step rate injectivity test to ensure adequate rates for cementing operations. Record Results. 3. RDMO. Coiled Tubing/Cementing: Objective: Pump cement into laterals and squeeze some cement into formation. Place cement in 3 ½” & 5 ½” liners. NOTE: Confirm pressure, volume, and rate for squeeze prior to starting cement job (based on injectivity test results). Cement Volume Calculations (TOC in 5 ½” to be at approximately 7,519ft KB): x L2 lateral (3” hole): (10,774’ – 8,857’) x 0.008743 bbls/ft = 16.8 bbls x L3 lateral (3” hole): (10,106’ – 9,175’) x 0.008743 bbls/ft = 8.1 bbls x L4 lateral (3” hole): (10,070’ – 8,025’) x 0.008743 bbls/ft = 17.9 bbls x 3 ½” liner/tubing volume from 2-3/8” window to tubing cut: (8,025’-7,645’) x 0.008697 bbls/ft = 3.3 bbls x 5 ½” liner from tubing cut to ~7,519ft KB: (7,645’ – 7,519’) x 0.02380 = 3 bbls x Squeeze volume: 19.9 bbls x Total volume: 16.8 + 8.1 + 17.9 + 3.3 + 3 + 19.9 = 69 bbls 1. Ensure an approved sundry has been received from AOGCC. 2. Contact cementers before the scheduled Suspend date, to allow adequate time for pilot testing of the cement design. The job is designed for 69 bbls of 15.8# Class “G” cement. a recent rig workover failed to meet the objective of pulling and replacing tubing. With rig options exhausted, it has been determined that the best path forward is to suspend the well and access the stranded resource with a redrill. . A tag and pressure test will confirm planned Top of Cement at ~7,519ft KB. JS 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Coil Tubing Unit and PT Surface Equipment as required. 5. RIH to above tubing cut, at 7,645ft KB. Close in the CT x Tubing annulus, and line up to pump down the coil tubing. 6. Pump 30 bbls of diesel to verify injectivity required for cementing operations. 7. RU Cement Equipment and Cementers. PT surface lines as required. 8. Pump 10 bbls freshwater spacer 9. Pump 69 bbls of 15.8 ppg Class “G” Cement a. This calculation assumes 19.9 bbl of squeeze volume b. Volume could change based on injectivity test results 10. Pump 10 bbls freshwater spacer behind 11. After 66 bbls cement has left the coil, or squeeze pressure achieved, start to pull out of hole. Lay in remaining 3 bbls cement, to 7,519ft KB. 12. When bottom of coil tubing is at 7,519ft KB, circulate excess cement out of hole. 13. Once returns are clean, POOH and wait on cement as per UCA data Slickline / Little Red Objective: Tag TOC, State Witnessed CMIT-TxIA 1. WOC per UCA data (minimum 24 hours). Notify the AOGCC Inspector of the timing of the cement plug tag and pressure testing. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU SL and PT Equipment as required. 4. RIH and tag TOC @ approximately 7,519ft KB. Record Results. TAG MUST BE AOGCC WITNESSED 5. RU LRS and PT Surface Equipment as required. 6. Perform MIT-TxIA to 1,500 psi. Record Results. 7. RDMO 3UHVVXUHWHVWPXVWDOVREH$2*&&ZLWQHVVHG 97/ JS Current Schematic: JS Suspended Schematic: superceded superceded superceded From:Simek, Jill To:Loepp, Victoria T (OGC) Cc:Phillips, Ron L Subject:RE: 3H-14B Date:Friday, September 17, 2021 12:36:39 PM Victoria, Since our conversation, the rig has not been able to recover the tubing stub from the cut depth at 7,645ft KB, and plans to abandon efforts for the planned workover. Currently we are attempting to fish the wireline spear at 7,694ft KB, which is stuck in the tubing patch packer at 7,695ft KB. If successful, we may be able to establish injectvity to the formation, which would allow us to pump cement for well suspension. If we are not successful recovering the spear, we will be asking the AOGCC for permission to suspend the well from a plug set above the spear, at ~7,600ft KB, as previously discussed (and outlined below). With either outcome, we plan to release the rig from the well this weekend and would like to get “verbal” approval for the suspension options described, which would be performed rigless at a later date. We expect to know our path forward tonight after the rig gets to surface with/without the spear. Thanks, Jill From: Simek, Jill Sent: Monday, September 13, 2021 3:16 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: 3H-14B Victoria, Attached are slides showing a contingency plan for suspension of KRU 3H-14B. We are currently performing a rig workover and evaluating options should we be unable to pull tubing from the well. Since a suspension would require AOGCC variance to cement from “top of fish”, I’d like to discuss this contingency with you should it become necessary. Summary of Proposed Suspension Steps: 1. Set 5.5” plug at 7,600ft KB (Rig) 2. Run kill string to 2,500ft KB (Rig) 3. Place ~42 bbls Class “G” cement from 7,600ft – 5900ft KB (Rigless w/ Coiled Tubing & Pumping Services) 4. Pressure test/tag, freeze protect well (Rigless w/ Slickline) I will give you a call to discuss. Thanks, Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-4131 | Cell: 907-980-7503 From:Loepp, Victoria T (CED) To:Simek, Jill Cc:Ward, Dusty K; Phillips, Ron L; Senden, R. Tyler Subject:KRU 3H-14B (PTD 205-021, Sundry 321-490) Suspension sundry Date:Monday, October 4, 2021 11:05:00 AM Jill, The top of cement for the reservoir plug needs to be about 100’ to 150’ above the tubing stub, State Witnessed tagged and pressure tested. Please modify procedure and email the revised sundry pages to me. Victoria From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Wednesday, September 29, 2021 3:39 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Ward, Dusty K <Dusty.Ward@conocophillips.com>; Phillips, Ron L <Ron.L.Phillips@conocophillips.com>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: RE: [EXTERNAL]KRU 3H-14B (PTD 205-021, Sundry 321-490) Suspension sundry Hi Victoria, I’m back from vacation, and understand you have some questions about the status of 3H-14B and future plans for the well’s suspension. Below is information requested. Let me know if you need more details. 1. The spear was recovered by the rig, which should allow the suspension cement plug to be pumped to the laterals. The suspension procedure submitted with the application for sundry approval includes steps to: run in hole with coil tubing, to just above the tubing stub, then pump cement down the tubing, into the laterals, bringing top of cement to 5,900ft KB. This top of cement can be made deeper, if desired. Please advise. 2. We did not set the plug at 7,600ft. With the spear out of the patch, we plan to pump through the fish to place cement as described above. 3. 7” and 5 ½” cementing records (from rig reports) and calculations are below. 7” Cement Info: 12/14/1987 Rig Report: Mix and pump 500 sxs 50/50 poz with 4.0% D-20, .2% D-46, .5% D-65 @ 12ppg. Tail with 300 sxs Class “G” with 3% KCL, .9% D-127, .3% P-13, .2% D-46 @ 15.8ppg. Used three plug system. Displaced with 10.0 brine. Bump plug to 3500psi... Full returns entire job. Calculations: Lead: (500 sxs)*(1.85 ft3/sx)*(0.1781 bbls/ft3) = 165 bbls Tail: (300 sxs)*(1.16 ft3/sx)*(0.1781 bbls/ft3) = 62 bbls Total cement = 165 + 62 = 227 bbls BS = 8 ½” Production Casing = 7” 26# Production Casing set at 8,220 ft KB Annular Capacity, with 40% excess assumed = 1.4*(0.0225857 bbls/ft) = 0.03162 bbls/ft Top of cement 8 ½”open hole x 7” annulus = 8,220 ft – (227 bbls)/(0.03162 bbls/ft) = ~1,041 ft KB 5 ½” Cement Info: 4/12/2005 Rig Report: Turned Over to Cementers, Fill Lines and Pressure Test Lines to 3500psi, Pumped 20BBL of CW 100. Mix & Pump 20 BBL of Mud Push II Spacer @ 13ppg, Mix and Pump 40BBL of Tail @ 15.8ppg Drip Plug, Pump 20 BBL of Water & Turned over to Rig Pump 3BPM (350psi) Bumped @ 863 strokes & Pressure up to 3500psi Calculations: BS (below window) = 7” Liner = 5.5” 15.5# Liner set at 7,925ft KB Window at 6,227ft KB Annular Capacity, with 40% excess assumed = 1.4*(0.0182142 bbls/ft) = 0.02550 bbls/ft Top of cement in 7” open hole x 5 ½” annulus = 7,925 ft – (40 bbls)/(0.02550 bbls/ft) = ~6,356ft KB Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-4131 | Cell: 907-980-7503 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, September 23, 2021 3:09 PM To: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: [EXTERNAL]KRU 3H-14B (PTD 205-021, Sundry 321-490) Suspension sundry Ty, I was looking at this sundry and questioning why the TOC for the reservoir plug couldn’t be deeper. The plan calls for the TOC for the reservoir plug at 5900’ MD which is ~2200’ above the laterals. Would also like to see the TOC outside the 5.5” liner and 7” casing. Victoria From: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Sent: Thursday, September 23, 2021 2:20 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: FW: [EXTERNAL]KRU 3H-14B (PTD 205-021, Sundry 321-490) Suspension sundry Victoria, I’m not sure exactly what conversations were had during the week (and a miserable one it was……). We in fact did not recover the spear but did recover the bait sub attached to the top of the spear. The description of our recovered fish was not communicated clear enough to our town staff over the weekend. The rig personnel were under the impression that the plug and cement were to be set post rig via slickline and coiled tubing. From your questions below I gather this was not your understanding? We are in a position to complete those tasks once the rig is moved off of the 3H pad (~7-10 days) assuming this plan is acceptable to you. Please advise. Thank you, Ty Senden Director, Coiled Tubing Drilling / Rig Workovers ATO-676 O: 907-265-1544 C: 907-982-3996 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, September 22, 2021 8:57 AM To: Simek, Jill <Jill.Simek@conocophillips.com> Cc: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Subject: [EXTERNAL]KRU 3H-14B (PTD 205-021, Sundry 321-490) Suspension sundry 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. Jill, Ron, 1. Was the spear recovered? Was the plug set at 7600” MD? 2. What was the reason that a plug and cement plug could not be placed at ~7600, pressure tested and tagged? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Loepp, Victoria T (CED) Sent: Friday, September 17, 2021 3:02 PM To: Simek, Jill <Jill.Simek@conocophillips.com> Cc: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Subject: KRU 3H-14B APPROVAL Jill, Ron, Verbal approval is granted to release the rig with the requirement that a suspension sundry will be submitted by Tuesday, September 21, 2021. Approval of the suspension sundry will include time requirements for the plugging operations. Victoria Loepp Sent from my iPhone On Sep 17, 2021, at 12:36 PM, Simek, Jill <Jill.Simek@conocophillips.com> wrote: Victoria, Since our conversation, the rig has not been able to recover the tubing stub from the cut depth at 7,645ft KB, and plans to abandon efforts for the planned workover. Currently we are attempting to fish the wireline spear at 7,694ft KB, which is stuck in the tubing patch packer at 7,695ft KB. If successful, we may be able to establish injectvity to the formation, which would allow us to pump cement for well suspension. If we are not successful recovering the spear, we will be asking the AOGCC for permission to suspend the well from a plug set above the spear, at ~7,600ft KB, as previously discussed (and outlined below). With either outcome, we plan to release the rig from the well this weekend and would like to get “verbal” approval for the suspension options described, which would be performed rigless at a later date. We expect to know our path forward tonight after the rig gets to surface with/without the spear. Thanks, Jill From: Simek, Jill Sent: Monday, September 13, 2021 3:16 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: 3H-14B Victoria, Attached are slides showing a contingency plan for suspension of KRU 3H-14B. We are currently performing a rig workover and evaluating options should we be unable to pull tubing from the well. Since a suspension would require AOGCC variance to cement from “top of fish”, I’d like to discuss this contingency with you should it become necessary. Summary of Proposed Suspension Steps: 1. Set 5.5” plug at 7,600ft KB (Rig) 2. Run kill string to 2,500ft KB (Rig) 3. Place ~42 bbls Class “G” cement from 7,600ft – 5900ft KB (Rigless w/ Coiled Tubing & Pumping Services) 4. Pressure test/tag, freeze protect well (Rigless w/ Slickline) I will give you a call to discuss. Thanks, Jill Simek ConocoPhillips Alaska STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed BI P.I. Supry BOPE Test Report for: KUPARUK RIV UNIT 3H -14B Comm Contractor/Rig No.: Nabors 7ES PTD#: 2050210 - DATE: 9/17/2021 Inspector Guy Cook Insp Source Operator: ConocoPhillips Alaska, Inc. Operator Rep: Scott Kiser Rig Rep: Tony Morales Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopGDC210917184331 Rams: Annular: Valves: MASP: 321-309 — -- — — Related Insp No: Type Test: WKLY 250/3500 ' 250/2500 20/3500 3060 MISC. INSPECTIONS: FLOOR SAFTY VALVES: P/F Location Gen.: P Housekeeping: _ P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P - Hazard Sec. P Misc NA FLOOR SAFTY VALVES: TEST DATA MUD SYSTEM: Quantity P/F Upper Kelly 1 P Lower Kelly I P " Ball Type 1 P Inside BOP 1 P ' FSV Misc 0 NA TEST DATA MUD SYSTEM: ACCUMULATOR SYSTEM: Visual Alarm Time/Pressure P/F Trip Tank P - P System Pressure 3000_ P ` Pit Level Indicators _ P P Pressure After Closure _ 1500 P Flow Indicator P P _' 200 PSI Attained 23 P " Meth Gas Detector P P Full Pressure Attained 122 P ' H2S Gas Detector P P Blind Switch Covers: All Stations ' P MS Misc NA - NA_ Nitgn. Bottles (avg): 5(a�2000 P ACC Misc 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 0 NA No. Valves 16 - P Annular Preventer 1 ' 13 5/8" 5000 P Manual Chokes 1 - FP #1 Rams 1 ' 2 7/8"x5" VB P Hydraulic Chokes 1 P #2 Rams I ' Blinds P CH Misc 0 NA #3 Rams 1'15"x5.5" 3.5"x5.5" VB_ P #4 Rams 0 NA 45 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 3 1/8" 5000 Quantity P/F _ HCR Valves 2 3 1/8" 5000 _P P Inside Reel Valves 0 NA Kill Line Valves 2 '3 1/8"&2" 50 FP ✓ Check Valve 0 _ _ _ _ NA BOP Misc 0 NA Number of Failures: 2 ' Test Results Test Time 7.25 Remarks: 3.5" and 2 7/8" test joints used for testing. Test #3 the manual kill failed. Serviced valve anp retested for a pasg' Test #4 the grease zerk leaked on the manual choke for a fail. Serviced choke and retested for a pass. The accumulator has a small drip of hydraulic fluid off of the annular pressure adjustment device. Also the accumulator system pressure had to be adjusted to pressure up to 3000psi. The made the adjustment and the pressure would reach 3000psi from 2850psi where I found it. I spoke to the Tool Pusher Tony Morales about both issues and he is going to address both issues during the next rig move since they did not want to tear apart the accumulator system while they were over the hole. They plan to fix the small drip and replace the pressure switch for the accumulator with a new one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y Samantha Carlisle at 8:10 am, Jun 24, 2021 321-309 10-404X SFD 6/24/2021 BOP test to 3500 psig Annular preventer test to 2500 psig X VTL 7/26/21 DSR-6/24/21 dts 7/26/2021 JLC 7/26/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.26 14:38:41 -08'00' RBDMS HEW 7/28/2021 June !"# $$"%& ' & '&( ! "#)$! ! *" $+$,)"!-"-$" !.,#/"& ' 0"# !"#1 !.,&&4 & '3!.,"#"5 -5$ !44&.$!%#-!2#44#)&$6#')"#7#2-."# 8 9:0;< *"&& 86 2#&&"2!=+ -4#-' !24#2-."#3!&$"$,"! !2 6"#"4&-//"2!2 5!2!"26,4 $.'6 "$!2$,"6"&&5"." 85-$$6 &#/"&%&"2.!)"# !:,"!$,"#"6 #$# 2"$#.'$$"4$$,"!6#')"#$,"! :0 2"$#.'!!2$,"6"&&5"." 8> .""!$"2 .5&!"#6 ! $&&"2$,"&4 ,-$%%&2!"#5#"%&6:,"6"&&6 $,"!-4#-'!2 !2 4#2-."#-!$&#.,6,"!$-5!/4$.," %&"2$ $4$-5!/&"' !2$,"6"&&5"."*.!22$" :," >$-5!/6&&5"4-&&"2!2#"4&."26$,!"6$-5!/!2-42$"/ &%$2" /! 3%-,)"!?-" $! ##"?-#"!%-#$,"#!%#$!4&" ".!$.$"$@ 8+ 0- $*#2 "!#*"&& !/!""# 30#&&!/!2*"&& :," >$-5!/6&&5"4-&&"2!2#"4&."26$,!"6$-5!/!2-42$"/ &%$2" /!2 ! "#$%&'( ) &&*+(,-..-/0(1 - ""!2 !" %/34*56 ! &''& /'&& 78 & *89&*&'( .(&4: " '&0;: '(* 4< 436).9 ).. &).9 ).. #$% ! & %31$< ) & )=&*"'& - /&&* 5 /&&* &' # 2 (&&'*&*'"&5='" *() )='* !(#'')*% > %3 )='(" #$% . / ""'( '(('?('? 4<6" &"(*( 436 *? &('?&'( ' '&*/ &&*...)(& ! &&&)...(&' + ,+" ) (& &"& - 5 4<6 43 2 & @'" > /<% (# . &/ #$< &/ & VTL 7/26/2130 min Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,975.0 3/16/2015 3H-14B hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replaced OV and identified Tbg Leak 6/6/2019 3H-14B zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.2 Set Depth (ftKB) 3,455.6 Set Depth (TVD) … 3,002.4 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 8,220.2 Set Depth (TVD) … 6,221.2 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Casing Description Window L4 OD (in) 7 ID (in) 6.00 Top (ftKB) 8,016.0 Set Depth (ftKB) 8,026.0 Set Depth (TVD) … 6,075.2 Wt/Len (l… 9.30 Grade Top Thread Casing Description SCAB LINER OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 6,038.9 Set Depth (ftKB) 7,925.0 Set Depth (TVD) … 6,007.4 Wt/Len (l… 15.50 Grade L-80 Top Thread HYDRIL511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,038.9 4,848.1 44.44 PACKER BAKER CPH LINER TOP PACKER-7 x 5.5" 4.830 6,049.3 4,855.5 44.45 HANGER BAKER HMC LINER HANGER 4.920 Casing Description LINER 3 1/2 OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 7,780.3 Set Depth (ftKB) 8,450.0 Set Depth (TVD) … 6,408.6 Wt/Len (l… 9.30 Grade L-80 Top Thread HYDRIL 511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,780.3 5,916.3 52.89 PACKER BAKER HR ZXP LINER TOP PACKER 5-1/2" x 3- 1/2" (Comm #H296-28-00579) 3.500 7,807.1 5,932.5 52.36 HANGER BAKER HMC LINER HANGER 5-1/2" x 3-1/2" Comm #H292-23-0212) 3.500 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 37.5 Set Depth (ft… 7,801.1 Set Depth (TVD) (… 5,928.8 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 37.5 37.5 0.08 HANGER CIW GEN 3 TUBING HANGER 3.500 2,328.6 2,207.9 43.04 SAFETY VLV CAMCO TRMAXX-10E SAFETY VALVE (HWS-573) 2.810 6,781.0 5,326.4 52.64 SEAL ASSY BAKER SEAL ASSEMBLY 2.990 7,747.8 5,896.7 53.14 NIPPLE CAMCO D NIPPLE W/ NO GO PROFILE 2.750 7,789.1 5,921.6 52.83 SEAL ASSY BAKER SEAL ASSEMBLY (3 SETS) 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,696.0 5,865.8 53.52 UPR PKR (ME) P2P UPR PKR, OAL 4' (SN# CPP35194) 3/2/2019 1.625 7,698.0 5,867.0 53.50 SPACER PIPE 30' SPACER PIPE w/ ANCHOR LATCH ASSEMBLY (SN# CPAL 35072) 3/2/2019 1.600 7,714.0 5,876.5 53.39 LEAK LARGE LEAK FOUND @ ST#4 GLM 2/18/2015 0.000 7,726.0 5,883.7 53.30 LWR PKR (ME) P2P LWR PKR, OAL 4' (SN# CPP35026) 3/1/2019 1.625 8,025.0 6,074.4 43.02 Whipstock WEATHERFORD WHIPSTOCK (COULD NOT BE PULLED) 4/18/2005 8,223.0 6,223.4 37.45 RETAINER B LINER HES EZ-DRILL SVB RETAINER 5/13/2005 2.690 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,884.0 7,886.0 5,981.0 5,982.3 5/18/2005 4.0 IPERF Shot TBG punch holes (9) 7,886.0 7,888.0 5,982.3 5,983.5 5/13/2005 4.0 IPERF Shot TBG punch holes (9) 8,147.0 8,157.0 6,164.5 6,172.0 A-3, 3H-14B 10/7/2005 6.0 APERF 2.5" PJ 2506, 60 deg phase 8,172.0 8,182.0 6,183.5 6,191.2 A-2, 3H-14B 8/9/2005 6.0 APERF 2.5" HSD, 60 deg phase 8,182.0 8,187.0 6,191.2 6,195.1 A-2, 3H-14B 8/9/2005 6.0 APERF 2.5" HSD, 60 deg phase 8,212.0 8,222.0 6,214.7 6,222.6 A-1, 3H-14B 10/7/2005 6.0 APERF 2.5" PJ 2506, 60 deg phase Frac Summary Start Date 8/28/2005 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 8/28/2005 Top Depth (ftKB) 8,172.0 Btm (ftKB) 8,187.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,966.7 2,661.2 CAMCO KBUG- M 1 GAS LIFT GLV BK 0.156 1,279.0 3/3/2019 7:30 2 4,824.4 3,976.8 CAMCO KBUG- M 1 GAS LIFT GLV BK 0.156 1,278.0 2/25/2015 4:00 3 6,021.6 4,835.8 CAMCO KBUG- M 1 GAS LIFT OV BK 0.250 0.0 6/6/2019 6:00 4 7,004.4 5,460.7 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 2/19/2015 12:30, EXT PKG 5 7,705.6 5,871.5 CAMCO KBG-2- 9 1 GAS LIFT OPEN 12/26/2015 COVE RED BY PATC H Notes: General & Safety End Date Annotation 9/16/1999 NOTE: WAIVERED WELL: IA x 0A COMMUNICATION 4/21/2005 NOTE: WELL SIDETRACKED FOR SECOND TIME Comment SSSV: TRDP 3H-14B, 6/7/2019 7:24:27 AM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 SEAL ASSY; 7,789.1 NIPPLE; 7,747.8 LWR PKR (ME); 7,726.0 LEAK; 7,714.0 SPACER PIPE; 7,698.0 GAS LIFT; 7,705.6 UPR PKR (ME); 7,696.0 GAS LIFT; 7,004.4 SEAL ASSY; 6,781.0 GAS LIFT; 6,021.6 GAS LIFT; 4,824.4 SURFACE; 35.2-3,455.6 GAS LIFT; 2,966.7 SAFETY VLV; 2,328.6 CONDUCTOR; 36.0-115.0 HANGER; 37.5 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 12/14/1987 Annotation Last WO: End Date 6/26/2005 3H-14B H2S (ppm) 150 Date 2/3/2018... TD Act Btm (ftKB) 8,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009202 Wellbore Status PROD Max Angle & MD Incl (°) 55.50 MD (ftKB) 7,048.39 WELLNAME WELLBORE3H-14B Notes: General & Safety End Date Annotation 1/22/2006 NOTE: MULTI-LATERAL WELL: 3H-14B/3H-14BL1/3H-14BL2/3H-14BL3/ 3H-14BL4 1/22/2006 NOTE: 3H-14BL1(OPEN HOLE PILOT HOLE - PLUGGED OFF) 1/22/2006 NOTE: 3H-14BL4 **ONLY ACCESSIBLE LEG** 2/28/2006 NOTE: CHEMICAL CUT 3H-14BL4 LINER TOP DOWN TO 8040' CLEAR 3H-14B LINER 1/4/2011 NOTE: View Schematic w/ Alaska Schematic9.0 3/1/2011 NOTE: **TUBING COMPONENT DEPTHS QUESTIONABLE** TALLY/DETAIL SHEETS VARY 6/6/2019 NOTE: Slickline Identified Tbg Leak Between 7329'-7696' 3H-14B, 6/7/2019 7:24:27 AM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 SEAL ASSY; 7,789.1 NIPPLE; 7,747.8 LWR PKR (ME); 7,726.0 LEAK; 7,714.0 SPACER PIPE; 7,698.0 GAS LIFT; 7,705.6 UPR PKR (ME); 7,696.0 GAS LIFT; 7,004.4 SEAL ASSY; 6,781.0 GAS LIFT; 6,021.6 GAS LIFT; 4,824.4 SURFACE; 35.2-3,455.6 GAS LIFT; 2,966.7 SAFETY VLV; 2,328.6 CONDUCTOR; 36.0-115.0 HANGER; 37.5 KUP PROD 3H-14B ... WELLNAME WELLBORE3H-14B !"# $ !"# # % # &' ()!#* + ' + # ' + (# ,- ., !+- ,- ) + ,(& !" # $ %&"'""" "()*+,"-".(/01 %&"021"3",0."*/-"20+ ."4" %&"021"53",0."*/-"20+ ."*+.* "&" 2+- "!10)"*+"4" %&"'""" "()*+,"-".(/01 6&"7"0+ *+,"+*88"0-"9999:"5";&"2*+"#< %&"!0. =#$#$3" # $">"#$" &"2+-"!10)"*+"4":" : &"9"&"01?"4"::"5";&"#< &"!"4":"5 @*8.-1?"4":"5 &"*+" "4" :" : !(/01"0.*+, &" (1-*+"0.*+, + (1- &"!10)"*+ "0-0 ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTED©DATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE From:Loepp, Victoria T (OGC) To:Well Integrity Specialist CPF1 & CPF3 Subject:KRU 3H-14B (PTD 205-021) APPROVAL to flow temporarily with TxIA communication Date:Monday, May 10, 2021 11:13:00 AM Jan, Approval is granted to flow KRU 3H-14B for a period of 30 days to lower the high reservoir pressure prior to the RWO. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, May 4, 2021 9:06 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3H-14B (PTD 205-021) Request to flow temporarily with TxIA communication Victoria, Gas lifted producer KRU 3H-14B (PTD 205-021) has known TxIA communication along with a stuck tubing patch that has been unretrievable. Due to the unrepairable tubing leaks the well has moved onto the RWO list and is scheduled for Q3, 2021. As the tubing patch has been unretrievable the well is not able to be secured conventionally with a plug and will require a heavy KWF for the RWO due to the high SBHP (3643 psi at 5657’ TVD on 3/14/21). The RWO Engineer is requesting that the BHP be lowered as much as possible for the upcoming RWO. All offset injectors have already been shut in. CPAI is requesting a 30-day flow period with known TxIA communication to facilitate lowering the BHP for the upcoming RWO. Lift gas is not planned to be used during the flow period. The well passed a CMIT TxIA to 2500 psi on 5/8/2020 proving integrity of the production casing and passed an MITOA to 1800 psi on 11/21/19 proving integrity of the surface casing. The well has been shut in since 9/12/2020 so a TIO trend is not attached, but is available if needed. A wellbore schematic is attached. Please advise if the flow period is acceptable. Please let me know if you have any questions or would like further information. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 ORIGINATED TRANSMITTAL DATE:10/2/2020 ALASKA E-LINE SERVICES TRANSMITTAL #:3165 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET #WELL #API #LOG DESCRIPTION DATE OF LOG 3165 3H-14B 50-103-20092-02 LDL 9/21/2020 DELIVERED TO DIGITAL FILE PRINTS CD's Company & Address # of Copies # of Prints # of Copies BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc.1 0 0 Attn: NSK-69 700 G Street Anchorage, Alaska 99501 AOGCC 1 0 0 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 1 0 0 Attn: Adam Manzer-Natural Resource Tech II DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 RECEIVED BY Print Name Signature Date Please return via e-mail a copy to both Alaska E-Line Services and Conoco Phillips Alaska: tom.osterkamp@conocophillips.com reception@ake-line.com Received by the AOGCC 10/02/2020 PTD:2050210 E-Set: 34021 Abby Bell Abby Bell 10/02/2020 Originated:Delivered to:19-Aug-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Sari 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 Leak Detect Log 2 Plug Setting Record 3 2L-310 50-103-20616-00 906449149 Tarn Packer Setting Record Field-Final 13-Apr-20 0 1 4 2T-37 50-103-20227-00 906480199 Kuparuk Plug Setting Record Field-Final 30-Apr-20 0 1 5 3A-08 50-029-21445-00 906499970 Kuparuk Plug Setting Record Field-Final 17-May-20 0 1 6 Multi Finger Caliper Field-Processed 26-May-20 7 Packer Setting Record Field-Final 27-May-20 8 3H-14B 50-103-20092-02 906486722 Kuparuk Packer Setting Record Field-Final 7-May-20 0 1 9 3K-03 50-029-21602-00 906531280 Kuparuk Plug Setting Record Field-Final 29-May-20 0 1 10 3A-08 50-029-21445-00 906499689 Kuparuk Multi Finger Caliper Field-Processed 16-May-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: 1 3H-03 50-103-20085-00 n/a Kuparuk 0 1 Transmittal Date: 2H-09 50-103-20050-00 906426492 Kuparuk Field-Final 5-Apr-20 0 08/26/2020 Abby Bell Received by the AOGCC 08/26/2020 PTD: 2050210 E-Set: 33694 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ 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 feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Authorized Title: Contact Email: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD 15. Well Class after work: Exploratory Development Service Stratigraphic 16. Well Status after work: Oil Gas W DSPL a GSTOR GINJ SUSP SPLUG 5.070, 25.071, & 25.283) J G Plug Perforations Fracture Stimulate Pull TubingOperations shutdown Perforate Other Stimulate Alter Casing Change Approved Program Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory StratigraphicService 6. API Number: mber): 8. Well Name and Number: onic data per 20AAC25.071): 10. Field/Pool(s): ry: ured feet feet ticalfeet feet ured feet feet ticalfeet feet epth feet epth feet true vertical depth) d and true vertical depth) summary: lumes used and final pressure: tion: ion: CollapseBurstTVD 5. Permit to Drill Number: Size Gas-Mcf g Ju easu ed 4. W ell Class Before W ork: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl ue e ca W ater-Bbl MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations ConocoPhillips Alaska, Inc PO Box 100360 Anchorage, AK 99510 205-021 50-103-20092-02-00 ADL 0025531 KRU 3H-14B N/A Kuparuk River Field/Kuparuk River Oil Pool 8450 6409 N/A N/A 8450 6409 6039' & 7780' 4848' & 5916' Conductor 79' 16" 115 115 Surface 3421' 9-5/8" 3456 3002 Production 8187' 7" 8220 6221 Scab Liner 1886' 5-1/2" 7925 6007 8147-8222 6165-6223 3-1/2" L-80 7801' MD 5929' TVD Baker CPH Liner Top Packer 6039' MD 4848' TVD N/A N/A N/A N/A N/AStephanie Pilch Well Integrity & Compliance Specialist Stephanie Pilch/Sara Carlisle n2549@conocophillips.com (907) 659-7126 Tubing patches ✔ ✔ ✔✔ ✔ Digitally signed by Stephanie Pilch DN: C=US, O=CPAI, CN=Stephanie Pilch, E=stephanie.r.pilch@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-05-11 12:04:42 Foxit PhantomPDF Version: 9.7.0 Stephanie Pilch By Samantha Carlisle at 12:18 pm, May 11, 2020 VTL 5/26/20 DSR-5/11/2020 RBDMS HEW 5/12/2020 SFD 5/11/2020 ! 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ast Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,975.0 3/16/2015 3H-14B hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SET PATCHES 3/3/2020 3H-14B condijw Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.2 Set Depth (ftKB) 3,455.6 Set Depth (TVD) … 3,002.4 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 8,220.2 Set Depth (TVD) … 6,221.2 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Casing Description Window L4 OD (in) 7 ID (in) 6.00 Top (ftKB) 8,016.0 Set Depth (ftKB) 8,026.0 Set Depth (TVD) … 6,075.2 Wt/Len (l… 9.30 Grade Top Thread Casing Description SCAB LINER OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 6,038.9 Set Depth (ftKB) 7,925.0 Set Depth (TVD) … 6,007.4 Wt/Len (l… 15.50 Grade L-80 Top Thread HYDRIL511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,038.9 4,848.1 44.44 PACKER BAKER CPH LINER TOP PACKER-7 x 5.5" 4.830 6,049.3 4,855.5 44.45 HANGER BAKER HMC LINER HANGER 4.920 Casing Description LINER 3 1/2 OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 7,780.3 Set Depth (ftKB) 8,450.0 Set Depth (TVD) … 6,408.6 Wt/Len (l… 9.30 Grade L-80 Top Thread HYDRIL 511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,780.3 5,916.3 52.89 PACKER BAKER HR ZXP LINER TOP PACKER 5-1/2" x 3- 1/2" (Comm #H296-28-00579) 3.500 7,807.1 5,932.5 52.36 HANGER BAKER HMC LINER HANGER 5-1/2" x 3-1/2" Comm #H292-23-0212) 3.500 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 37.5 Set Depth (ft… 7,801.1 Set Depth (TVD) (… 5,928.8 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 37.5 37.5 0.08 HANGER CIW GEN 3 TUBING HANGER 3.500 2,328.6 2,207.9 43.04 SAFETY VLV CAMCO TRMAXX-10E SAFETY VALVE (HWS-573) 2.810 6,781.0 5,326.4 52.64 SEAL ASSY BAKER SEAL ASSEMBLY 2.990 7,747.8 5,896.7 53.14 NIPPLE CAMCO D NIPPLE W/ NO GO PROFILE 2.750 7,789.1 5,921.6 52.83 SEAL ASSY BAKER SEAL ASSEMBLY (3 SETS) 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,013.0 4,829.6 44.42 PATCH - UPR PKR (ME) P2P PKR (CPP35212) W/ 20.5' OF SPACER PIPE AND ANCHOR LATCH (CPAL35144) OAL 25' MAX OD 2.72" 5/8/2020 1.625 6,017.0 4,832.4 44.42 SPACER PIPE 20.5' OF 2 1/16" P-110 SPACER PIPE. 5/8/2020 1.600 6,022.0 4,836.0 44.43 TUBING LEAK LEAKING OV, DAMAGE TO OV FROM FLOW CUTTING ON LATCH AND ON NOSECONE, SET EXT PACKING DUMMY, MITT FAILED 3/5/2020 2.990 6,038.0 4,847.4 44.44 PATCH - LWR PKR (ME) P2P PKR (CPP35250) OAL 4' 5/7/2020 1.625 7,611.0 5,815.5 54.04 PATCH - UPR PKR (ME) 2.72" P2P PATCH ASSEMBLY, OAL 23.84' , SN: CPP35245 3/3/2020 1.625 7,615.0 5,817.9 54.02 SPACER PIPE 18' SPACER PIPE w/ ANCHOR LATCH ASSEMBLY (SN# CPAL 351135) 3/3/2020 1.590 7,622.0 5,822.0 53.97 LEAK Leak at 7622' 7/3/2019 0.000 7,634.0 5,829.1 53.90 PATCH - LWR PKR (ME) P2P LWR PKR, OAL 4' (SN# CPP35246) 3/2/2020 1.625 7,695.0 5,865.2 53.52 PATCH - UPR PKR (ME) P2P UPR PKR, OAL 4' (SN# CPP35243) 3/1/2020 1.625 7,699.0 5,867.6 53.50 SPACER PIPE 33' SPACER PIPE w/ ANCHOR LATCH ASSEMBLY (SN# CPAL 35147) 3/1/2020 1.590 7,714.0 5,876.5 53.39 LEAK LARGE LEAK FOUND @ ST#4 GLM 2/18/2015 0.000 7,728.0 5,884.9 53.28 PATCH - LWR PKR (ME) P2P LWR PKR, OAL 4' (SN# CPP35244) 3/1/2020 1.625 8,025.0 6,074.4 43.02 Whipstock WEATHERFORD WHIPSTOCK (COULD NOT BE PULLED) 4/18/2005 8,223.0 6,223.4 37.45 RETAINER B LINER HES EZ-DRILL SVB RETAINER 5/13/2005 2.690 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,884.0 7,886.0 5,981.0 5,982.3 5/18/2005 4.0 IPERF Shot TBG punch holes (9) 7,886.0 7,888.0 5,982.3 5,983.5 5/13/2005 4.0 IPERF Shot TBG punch holes (9) 8,147.0 8,157.0 6,164.5 6,172.0 A-3, 3H-14B 10/7/2005 6.0 APERF 2.5" PJ 2506, 60 deg phase 8,172.0 8,182.0 6,183.5 6,191.2 A-2, 3H-14B 8/9/2005 6.0 APERF 2.5" HSD, 60 deg phase 8,182.0 8,187.0 6,191.2 6,195.1 A-2, 3H-14B 8/9/2005 6.0 APERF 2.5" HSD, 60 deg phase 8,212.0 8,222.0 6,214.7 6,222.6 A-1, 3H-14B 10/7/2005 6.0 APERF 2.5" PJ 2506, 60 deg phase Frac Summary Start Date 8/28/2005 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 8/28/2005 Top Depth (ftKB) 8,172.0 Btm (ftKB) 8,187.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 3H-14B, 5/10/2020 5:13:17 PM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 SEAL ASSY; 7,789.1 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 SPACER PIPE; 7,699.0 GAS LIFT; 7,705.6 PATCH - UPR PKR (ME); 7,695.0 PATCH - LWR PKR (ME); 7,634.0 SPACER PIPE; 7,615.0 LEAK; 7,622.0 PATCH - UPR PKR (ME); 7,611.0 GAS LIFT; 7,004.4 SEAL ASSY; 6,781.0 PATCH - LWR PKR (ME); 6,038.0 SPACER PIPE; 6,017.0 GAS LIFT; 6,021.6 TUBING LEAK; 6,022.0 PATCH - UPR PKR (ME); 6,013.0 GAS LIFT; 4,824.4 SURFACE; 35.2-3,455.6 GAS LIFT; 2,966.7 SAFETY VLV; 2,328.6 CONDUCTOR; 36.0-115.0 HANGER; 37.5 KUP PROD KB-Grd (ft) 42.01 Rig Release Date 12/14/1987 3H-14B ... TD Act Btm (ftKB) 8,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009202 Wellbore Status PROD Max Angle & MD Incl (°) 55.50 MD (ftKB) 7,048.39 WELLNAME WELLBORE3H-14B Annotation Last WO: End Date 6/26/2005 H2S (ppm) 150 Date 2/3/2018 Comment SSSV: TRDP Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,966.7 2,661.2 CAMCO KBUG- M 1 GAS LIFT GLV BK 0.188 1,307.0 5/8/2020 7:30 2 4,824.4 3,976.8 CAMCO KBUG- M 1 GAS LIFT OV BK 0.188 0.0 5/8/2020 4:00 3 6,021.6 4,835.8 CAMCO KBUG- M 1 GAS LIFT OPEN BK 5/6/2020 6:00 4 7,004.4 5,460.7 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 6/25/2019 12:30 EXT PKG 4 7,004.4 5,460.7 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 7/21/2019 12:30 5 7,705.6 5,871.5 CAMCO KBG-2- 9 1 GAS LIFT OPEN 12/26/2015 COVE RED BY PATC H Notes: General & Safety End Date Annotation 3/1/2011 NOTE: **TUBING COMPONENT DEPTHS QUESTIONABLE** TALLY/DETAIL SHEETS VARY 1/22/2006 NOTE: MULTI-LATERAL WELL: 3H-14B/3H-14BL1/3H-14BL2/3H-14BL3/ 3H-14BL4 9/16/1999 NOTE: WAIVERED WELL: IA x 0A COMMUNICATION 3H-14B, 5/10/2020 5:13:18 PM Vertical schematic (actual) Liner L4; 8,040.0-9,532.0 SLOTS; 8,243.0-9,499.0 LINER 3 1/2; 7,780.3-8,450.0 RETAINER; 8,223.0 PRODUCTION; 33.0-8,220.2 APERF; 8,212.0-8,222.0 APERF; 8,182.0-8,187.0 FRAC; 8,172.0 APERF; 8,172.0-8,182.0 APERF; 8,147.0-8,157.0 Window L4; 8,016.0-8,026.0 Whipstock; 8,025.0 SCAB LINER; 6,038.9-7,925.0 IPERF; 7,886.0-7,888.0 IPERF; 7,884.0-7,886.0 SEAL ASSY; 7,789.1 NIPPLE; 7,747.8 PATCH - LWR PKR (ME); 7,728.0 LEAK; 7,714.0 SPACER PIPE; 7,699.0 GAS LIFT; 7,705.6 PATCH - UPR PKR (ME); 7,695.0 PATCH - LWR PKR (ME); 7,634.0 SPACER PIPE; 7,615.0 LEAK; 7,622.0 PATCH - UPR PKR (ME); 7,611.0 GAS LIFT; 7,004.4 SEAL ASSY; 6,781.0 PATCH - LWR PKR (ME); 6,038.0 SPACER PIPE; 6,017.0 GAS LIFT; 6,021.6 TUBING LEAK; 6,022.0 PATCH - UPR PKR (ME); 6,013.0 GAS LIFT; 4,824.4 SURFACE; 35.2-3,455.6 GAS LIFT; 2,966.7 SAFETY VLV; 2,328.6 CONDUCTOR; 36.0-115.0 HANGER; 37.5 KUP PROD 3H-14B ... WELLNAME WELLBORE3H-14B Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: APR 2 3 220^20 AVVCC 205021 32802 23 -Apr -20 WELL NAME API # CE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # CD # 12N-309 2 2W-12 3 3H-146 4 3H-26 5 3H-35 6 3H-146 7 50-103-20293-00 50-029-21240-00 50-103-20092-02 50-103-20208-00 -103-2O805-006363845 j9062893 841 305 906340306 6349140 Tarn Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Packer Setting Record Final -Field Packer Setting Record Final -Field Packer Setting Record Final -Field Leak Detect Log Final -Field Radial Cement Bond Log Final -Field Multi Finger Caliper Final -Field 28 -Dec -19 2 -Jan -20 1 -Mar -20 28 -Feb -20 4 -Mar -20 29 -Feb -20 0 1 0 0 1 1 0 0 0 1 1 1 8 M50 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date: ; i ✓. Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: RECEIVES APR � 2 3 102-^0 A°GCC 205021 32799 23 -Apr -20 WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # CD # 1 2N-309 2 2W-12 3 3H -14B 4 3H-26 5 3H-35 6 3H -14B 7 50-103-20293-00 50-029-21240-00 50-103-20092-02 50-103-20208-00 50-103-20805-00 50-103-20092-02 906207893 906212841 906340305 906340306 906363845 906349140 Tarn Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Packer Setting Record Final -Field Packer Setting Record Final -Field Packer Setting Record Final -Field Leak Detect Log Final -Field Radial Cement Bond Log Final -Field Multi Finger Caliper Final -Field 28 -Dec -19 2 -Jan -20 1 -Mar -20 28 -Feb -20 4 -Mar -20 29 -Feb -20 0 0 0 0 0 0 1 1 1 1 1 1 8 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date: J� WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Records: 3H -14B Run Date: 7/21/2019 205021 31203 September 9, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC @hal liburton. com 311-1411 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20092-02 RECEIVED SEP 12 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: eyw/� Signed: 205021 31148 CASED HOLE Well Log Transmittal To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 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 attention of : 1) Caliper Report 2) Signed Print Name: READ Cased Hole, Inc. Attn: Diane Williams RECEIVE> 130 West International Airport Road Suite C AUG 2 9 2019 Anchorage, AK 99518 n O Dianw.Williams@readcasedhole.com A 03 -Jul -19 3H -14B 1 Report / CD 50-029-20092-02 Date : _(VRO PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAG EOWEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM haps Wreadcasedhole-my, sharepointxom/personal/diane_williams_readcasedhole_com/Documents/Desk-top/ConowPhillips—Transmit.docx Company: ConocoPhillips Alaska, Inc. Log Date: July 3, 2019 Log No.: 14389 Run No.: 2 Pipe Description: 3.5 inch 9.3 Ib. L-80 EUE 8RD MOD 205021 31148 Memory Multi -Finger Caliper Log Results Summary Well: Field: State: API No. Top Log Interval: tom Log Interval: Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the top of GLM 4 at 7,004.4 feet (Driller's Depth). 3H-1413 Kuparuk Alaska 50-103-20092-02 Surface 7,694 Ft. (MD) This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. A 3-D log plot of the caliper recordings from 7,300 feet to 7,694 feet (end of log), where a suspected leak is located is included in this report. The caliper recordings indicate the 3.5 inch tubing logged appears to range from good to fair condition, with a maximum recorded wall penetration of 39% at an isolated pit in joint 241 (7,623 ft). Recorded damage appears as isolated pitting, a line of pits, and line corrosion. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. This is the second time a READ caliper has been run in this well, and the 3.5 inch tubing has been logged from 5,170 feet to 7,694 feet. A comparison of the current and previous log (December 19, 2005) indicates an increase in corrosive damage during the time between logs. A graph illustrating the difference in maximum recorded wall penetrations on a joint -by -joint basis between logs is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting 39 241 7,623 Ft. (MD) Line of Pits 37 201 6,360 Ft. (MD) Line of Pits 35 225 7,129 Ft. (MD) Line of Pits 34 223 7,069 Ft. (MD) Line of Pits 34 199 6,307 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 9%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. C. Goerdt & A. Power C. Waldrop J. Fama READ Cased Hole Inc. j P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmerica(&readcasedhole.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-231 1 CASED-Multifinger Caliper 3D Log Plot Company: ConocoPhillips Alaska, Inc. Field : Kuparuk Well: 31i-1413 Date: July 3, 2019 Description : Detail of Caliper Recordings From 7,300 feet to 7,694 feet (end of log). Comments Depth Maximum Penetration Nominal I.D. 3-D Log Image Map .................................................... 111:240ft 0 % 100 2.5 inches 3.5 321° 0° 90° 180° 270° 0° Maximum I.D. 2.5 inches 3.5 Minimum I.D. 2.5 inches 3.5 Joint 231 7310 Line of Pits - 29% Wall - Penetration 7320 7330 Joint 232 7340 lour Line of Pits 26% Wall Penetration 7350 7360 _- Joint 233 - 7370 Isolated Pitting _s 29% Wall Penetration 7380 _ 7t 7390 Joint 234 7400 i r' r Line of Pits i 28% Wall 7410 - Penetration 74207430 i �, _ a Line of Pits 25% Wall 7440 Penetration 7450 7460 Joint 236 i Line of Pits -- -- 21"/o Wall - - Penetration Penetration 7480 7490 Joint 237 Isolated Pitting 7500 24% Wall Penetration 7510 7520 " Joint 238 Line of Pits -- - _ 7530 22% Wall Penetration 7540 7550 Joint 239 Line of Pits 7560 24% Wall �a Penetration 7570 I 7580 - Joint 240 Isolated Pitting 7590 24% Wall - — Penetration 7600 7610 1 - Joint 241 Isolated Pitting 7620 39% Wall Penetration - 7630 - • i 7640 Joint 242 7650 i Line of Pits i N. 22% Wall Penetration 7660 7670__ - Joint 243 WOW Line Corrosion 7680 _ N 29% Wall Penetration 7690 u Minimum I.D. 2.5 inches 3.5 Maximum I.D. 2.5 inches 3.5 Comments Depth Maximum Penetration Nominal I.D. 3-D Log Image Map ....................................................— _ 1ft:240ft 0 % 100'2.5 inches 3.5 321° 0° 90° 180° 270° 0° Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (39.3'- 7,693.7') Well: 31-1-1413 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: July 3, 2019 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 44 25 795 50 1,571 75 2,372 GLM 1 11 3,164E p 1 :3 125 LL 3,942 • L 1 J Q N 1! 0 GLM 215 MM 4,723 175 5,520 GLM 3 6,312 GLM 4 7,110 243 7,668 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 243 1 • 1 _ 1 J 1! _ CASE:_: HOLE Well: 31-1-1413 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA 0 164 169 174 179 184 189 GLM 3 191 196 201 206 211 216 221 GLM 4 223 228 233 238 Overlay Maximum Recorded Penetration (mils) 50 100 150 200 250 E July 3, 2019 E December 19, 2005 Maximum Recorded Penetration Comparison To Previous Survey Date: July 3, 2019 Previous Date: December 19, 2005 Tool Type: UW MFC 24 No. 218527 Tubing: 3.5" 9.3 Ib L-80 EUE 8RD MOD Difference d E Z .E- 0 0 Difference in Maximum Penetration (mils) -100 -50 0 50 100 -7 -4 0 4 7 Approximate Corrosion Rate (mpy) Corrosion Rate (mpy) Top 101ts. Overall Average 4 2 Median 3 1 -= - CASES. HOLE Body Region Analysis it i Well: 31-1-146 Survey Date: July 3, 2019 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: Pipe USA 3.5 in. 9.3 ppf L-80 EUE 8RD MOD No. of Fingers: 24 Analyst_ Waldrop Pipe Nom OD Weight Grade & Thread —5i Nom ID Top Depth Bottom Depth 3 9.3 ppf L-80 EUE 8RD MOD 2.992 in. 39 ft. 7,694 ft. 200 150 100 50 0 0 to 20% Numl 189 10C 80 60 40 20 0 Penetration (% wall) 20 to 40 to over 40% 85% 85% �ints_anazed-ft-otal_= 255)_ 66 0 0 Damage Configuration (body) Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole Number of joints_ da-m-aged(.total_=. 151 68 0 83 0 0 Damage Profile (% wall) Penetration body Metal loss body 0 50 100 GLM 1 (7:00) GLM 2 (3:00) GLM 3 (6:00) GLM 4 (12:30) Bottom of Survey = 243 H®L Well: 31-1-146 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: July 3, 2019 Analyst: Waldrop Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. 39 ft 7,694 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 0.1 39 0 0.02 8 2 2.92 Pu Lt. Deposits. 1 44 0 0.03 13 6 2.92 Lt . De osits. 1.1 76 0 0.02 8 5 2.93 PuD Lt. Deposits. 2 82 0 0.03 12 5 2.94 3 113 0 0.03 11 5 2.93 Lt. Deposits. 4 144 0 0.03 11 6 2.93 5 176 0 0.03 12 5 2.92 Lt. Deposits. 6 207 0 0.03 10 4 2.93 Lt. De osits. 7 237 0 0.02 9 4 2.92 Lt. Deposits. 8 269 0 0.03 11 4 2.94 9 1 300 0 0.03 12 5 2.92 Lt. Deposits. 10 329 0 0.04 1 16 5 2.92 Shallow Line of Pits. Lt. Deposits. 11 360 0 0.03 12 5 2.92 Lt. De osits. 12 391 0 0.03 13 4 2.93 13 422 0 0.04 15 5 2.92 Shallow Line of Pits. Lt Deposits. 14 452 0 0.03 11' 4 2.93 Lt. Del2osits. 15 483 0 0.03 12 5 2.93 16 514 0 0.03 11 7 2.93 Lt. Deposits. 17 545 0 0.03 12 6 2.93 Lt. Deposits. 18 577 0 0.03 12 5 2.92 Lt. De osits. 19 1 608 0 0.04 14 1 4 2.94 20 639 0 0.03 10 4 2.93 Lt. Deposits. 21 670 0 0.04 14 6 2.94 22 702 0 0.04 14 6 2.93 Lt. De osits. 23 733 0 0.04 14 9 2.93 Lt. De osits. 24 764 0 0.03 12 5 2.92 Lt. Deposits. 25 795 0 0.03 13 5 2.94 26 826 0 0.03 11 1 5 2.93 Lt. Deposits. 27 1 856 0 0.04 16 5 2.93 Shallow Line of Pits. Lt Deposits. 28 887 0 0.04 16 7 2.93 Shallow Line of Pits. 29 918 0 0.04 15 6 2.93 Shallow Pitting, Lt. De osits. 30 949 0 0.03 12 4 2.94 31 980 0 0.04 15 6 2.94 Shallow Pitting. 32 1010 0 0.04 15 6 2.92 Shallow Pitting. Lt. Deposits. 33 1042 0 0.04 17 6 2.93 Shallow Pitting. Lt. Deposits. 34 1072 0 0.03 13 7 2.94 35 1103 0 0.04 15 5 2.91 Shallow Line of Pits. Lt. De osits. 36 1134 0 0.03 12 6 2.94 37 1165 0.06 0.04 15 6 2.92 Shallow Pitting. Lt. Deposits. 38 1197 0.05 0.04 15 5 2.92 Shallow Pitting. Lt. Deposits. 39 1228 0 0.04 16 7 2.93 1 Shallow Line of Pits. Lt. Deposits. 40 1259 0 0.04 15 1 5 2.93 1 Shallow Pitting. Lt. Deposits. 41 1291 0 0.04 15 5 2.92 Shallow Line of Pits. Lt. D osits. 42 1322 0.04 0.04 17 6 2.90 Shallow Line of Pits. Lt. Deposits. 43 1353 0 0.03 11 4 2.92 Lt. Deposits. 44 1384 0 0.02 9 4 2.94 45 1416 0.04 0.05 19 7 2.90 Shallow Line of Pits. Lt. Devosits. 46 1446 1 0 0.04 17 6 2.93 Shallow Line of Pits. 47 1477 0 0.03 12 4 2.90 Lt. Deposits. 48 1508 0 0.03 11 6 2. Lt. Deposits. Penetration Body E Metal Loss Body Page 1 CASED Joint Tabulation Sheet HOLE Well: 3H -14B Survey Date: July 3, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. 39 ft 7,694 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 49 1540 0 0.03 12 4 2.93 50 1571 0.05 0.05 18 5 2.93 Shallow Pitting. Lt. Deposits. 51 1602 0 0.04 14 4 2.93 Lt. Deposits. 52 1633 0 0.04 14 4 2.94 53 1665 0.05 0.04 15 6 2.93 Shallow Line of Pits. Lt. Deposits. 54 1 1696 0 0.03 10 4 2.94 55 1727 0 0.03 10 4 2.93 Lt. Deposits. 56 1758 0 0.03 11 4 2.94 57 1789 0 0.03 13 4 2.94 58 1820 0.04 0.04 15 5 2.92 Shallow Pitting. Lt. Deposits. 59 1851 0 0.04 15 4 2.93 Shallow Pitting. Lt. Deposits. 60 1883 0 0.03 11 6 2,94 61 1914 0 1 0.04 16 4 2.95 Shallow Line of Pits. 62 1946 0.05 0.05 18 4 2.91 Shallow Line of Pits. Lt. Deoosits. 63 1977 0 0.03 10 6 2.94 64 2008 0 0.04 14 4 2.93 65 2040 0 0.03 12 5 2.93 Lt. Deposits. 66 2071 0 0.03 12 4 2.94 67 2102 0.04 0.04 15 5 2.94 Shallow Line of Pits. 68 2134 0 0.03 11 5 2.94 69 2165 0 0.04 14 6 2,94 70 2196 0 0.03 13 6 2.93 Lt. Deposits. 71 2227 0 0.04 16 6 2.92 Shallow Pitting. Lt. Deposits. 72 2259 0.04 0.03 11 1 4 2.93 73 2288 0 0.03 13 1 4 2.93 Lt. Deposits. 73.1 2320 0 0.02 9 1 3 2.93 Pu 73.2 1 2328 0 1 0 0 0 2.80 Camco TRMAXX-t0E SSSV 73.3 2333 0 0.02 9 4 2.90 Pu Lt. De osits. 74 2341 0 0.03 13 5 2.93 Lt. Deposits. 75 2372 0 0.04 17 5 2.93 1 Shallow Pitting. Lt. Deposits. 76 2402 0 0.02 9 5 2.93 1 Lt. De osits. 77 2433 0 0.03 11 4 2.93 Lt. De osits. 78 2464 0 0.04 14 6 2.94 79 2496 0 0.03 13 5 2.94 80 2527 0 0.04 15 6 2.94 Shallow Line of Pits. 81 2558 0 0.04 17 5 2.93 Shallow Pitting. 82 2589 0 0.03 12 6 2.92 Lt. Deposit . 83 2620 0 0.04 16 5 2.92 Shallow Line of Pits. Lt. Deposits. 84 2650 0 0.03 11 3 2.93 85 2682 0 0.03 12 6 2.88 Lt. Deposits. 86 2713 0 0.03 12 6 2.93 1 Lt. Deposits. 87 2742 0 1 0.03 13 5 2.92 Lt. Deo its. 88 2773 0 0.04 16 4 2.92 Shallow Line of Pits. Lt. Deposits. 89 1 2804 0 0.05 20 4 2.92 Line of Pits. Lt. Deposits. 90 2836 0.05 0.05 19 7 2.92 Shallow Pitting. Lt. Deposits. 91 2866 0 0.03 11 6 2.94 92 2898 0 0.03 13 4 2.93 Lt. Deposits. 93 2929 0 0.02 9 5 2.94 93.1 2960 0.04 0.05 19 6 2.92 Pup Shallow Line of Pits. Lt. Deposits. 93.2 2966 0 0 0 0 2.85 GLM 1 Latch CEJ 7:00 Penetration Body Metal Loss Body Page 2 Well: 31-1-14B Field: Kuparuk Company: ConocoPhillips Alaska, Inc Joint Tabulation Sheet Survey Date: July 3, 2019 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE BIRD MOD Tubing Nom. ID Body Wall 2.992 in. 0.254 in. Top Depth Bottom Depth 39 ft 7,694 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 93.3 2972 0 0.03 11 6 2.91 Pup Lt. Deposits. 94 2978 0.05 0.03 13 5 2.93 Lt. Del2osits. 95 1 3009 0 0.03 13 6 2.93 Lt. Deposits. 96 3040 0 0.04 14 5 2.93 Lt. Deposits. 97 3071 0 0.05 19 6 2.93 Shallow Line of Pits. Lt. Deposits. 98 3103 0 0.03 13 5 2.93 99 3133 0 0.05 18 6 2.92 Shallow Pitting. Lt. Deposits. 100 3164 0.04 0.03 13 6 2.93 101 3196 0 0.03 13 4 2.94 102 3226 0 0.03 13 6 2.93 103 3258 0 0.04 15 5 2.93 Shallow Line of Pits. Lt. Deposits. 104 3289 0 0.03 12 5 2.93 Lt. Deposits. 105 3320 0 0.03 13 6 2.93 106 3351 0 0.03 13 6 2.92 Lt. Deposits. 107 3382 0 0.03 12 6 2.93 Lt. Deposits. 108 3412 0 0.04 15 6 2.92 Shallow Pitting. Lt. Deposits. 109 3443 0 0.04 15 6 2.93 Shallow Pitting. Lt. De osits. 110 3475 0 0.04 15 4 2.92 Shallow Line of Pits. Lt. Degosits. 111 3506 0.05 0.04 17 5 2.93 Shallow Pitting. Lt. Deposits. 112 3537 0 0.04 14 4 2.94 113 3568 0.05 0.03 12 6 1 2.93 Lt. Deposits. 114 3600 0 0.03 13 6 2.93 Lt. Deposits. 115 3631 0 0.03 13 5 2.93 Lt. De osits. 116 3662 0.05 0.04 16 6 2.94 Shallow Line of Pits. 117 3693 0 0.03 12 5 2.94 118 3724 0 0.03 13 6 2.92 Lt. Deposits. 119 3755 0.05 005 20 7 2.92 Isolated Pi tin Lt. Deposits. 120 3786 0 1 0.04 17 6 2.92 Shallow Pitting. Lt. De osits. 121 3817 0 0.03 13 5 2.93 Lt. Deposits. 122 3848 0 0.04 15 1 6 2.92 Shallow Pitting. Lt. Deposits. 123 3880 0 0.04 15 1 6 2.92 Shallow Pitting. Lt. Deposits. 124 3911 0 0.03 11 4 2.92 Lt. De osits. 125 1 3942 0 0.03 12 4 2.93 126 3973 0 0.03 11 5 2.94 127 4004 0 0.03 12 4 2.91 Lt. De osits. 128 4036 0 0.05 18 7 2.93 1 Shallow Pitting. Lt. Deposits. 129 4067 0 0.03 13 6 2.94 130 4098 0 0.04 15 1 5 2.93 Shallow Pitting. Lt. Deposits. 131 1 4130 0 0.03 12 5 2.92 Lt. Deposits. 132 4161 0 0.05 19 3 2.91 Shallow Line of Pits. Lt. Deposits. 133 4192 0 0.03 13 4 2.93 Lt. De osits. 134 4223 0 0.05 18 4 2.92 Shallow Pitting. Lt. Deposits. 135 4254 0 0.03 13 5 2.94 136 4286 0 0.05 19 6 2.93 Shallow Pitting. Lt. Deposits. 137 4317 0 0.04 17 1 6 2.94 Shallow Pitting. 138 4349 0 0.03 13 4 2.92 Lt. Deposits, 139 4380 0 0.04 17 5 2.94 Shallow Pitting. 140 4411 0.04 0.04 15 7 2.93 Shallow Pitting. Lt. De osits. 141 4442 0 0.04 15 5 2.93 Shallow Pitting. Lt. De osits. 142 4474 0 0.0 13 6 2.89 Lt. De osits. Penetration Body Metal Loss Body Page 3 Well: Field: Company: �a 31-1-1413 Kuparuk ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: July 3, 2019 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. 39 ft Bottom Depth 7,694 ft. Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 143 4504 0 0.03 11 5 2.91 Lt. Deposits. 144 4535 0 0.04 15 6 2.92 Shallow Pitting. Lt. Deposits. 145 1 4566 0 0.04 14 4 2.90 1 Lt. Deposits. 146 4598 0 0.04 15 6 2.88 Shallow Pitting. Lt. Deposits. 147 4629 0.05 0.05 21 6 2.93 Line of Pits. Lt. Deposits. 148 4660 0 0.04 15 3 2.91 Shallow Pitting. Lt. Deposits. 149 4691 0 0.03 13 5 2.92 Lt. Deposits. 150 4723 0 0.04 15 5 2.90 Shallow Pitting. Lt. Deposits. 151 4754 0 0.04 15 5 2.92 Shallow Pitting. Lt. Deposits. 152 4785 0 0.04 15 5 1 2.91 Shallow Pitting. Lt. De osits. 152.1 4816 0 0.03 11 3 2.89 Puv Lt. D osits. 152.2 1 4822 0 0 0 0 2.83 GLM 2 Latch @ 3:00 152.3 4829 0 0.03 10 2 2.90 1 Pu Lt. Detaosits. 153 4835 0.04 0.04 16 5 2.91 1 Shallow Line of Pits. Lt. De sits. 154 4867 0.05 0.04 16 8 2.91 1 Shallow Pitting. Lt. De sits. 155 4898 0.06 0.05 20 6 2.92 Line of Pits. Lt. Deposits, 156 4929 0.06 0.06 23 6 2.92 Line of Pits. Lt. Deposits. 157 4961 0.05 0.04 17 7 2.92 Shallow Pitting. Lt. Deposits. 158 4992 0.05 0.05 20 7 2.90 Line of Pits. Lt. Deposits. 159 5024 0 0.03 13 4 2.90 Lt. Deposits. 160 5055 0 0.03 13 4 2.91 Lt. Deposits. 161 5086 0 0.03 13 4 2.91 Lt. Deposits. 162 5115 0 0.04 17 5 2.92 Shallow Pitting. Lt. Deposits. 163 5146 0.05 0.06 22 4 2.91 Line of Pits. Lt. Deposits. 164 1 5177 0 1 0.04 17 1 4 2.91 1 Shallow Pitting. Lt. Deposits. 165 5208 0.05 0.06 22 5 2.91 Line of Pits. Lt. Deposits. 166 5239 0.05 0.05 20 7 2.90 Line of Pits. Lt. De osits. 167 5270 0 0.04 16 5 2.92 Shallow Pitting. Lt. Deposits. 168 5301 0 0.04 16 4 2.90 Shallow Pitting. Lt. De osits. 169 5332 0.06 0.06 22 6 2.92 Line of Pits. Lt. Deposits. 170 5363 0 005 20 6 1 2.90 Isolated Pitting Lt. De osits. 171 5395 0 0.05 18 4 2.91 Shallow Pitting, Lt. Deposits. 172 5426 0.04 0.04 17 6 2.92 Shallow Line of Pits. Lt. Deposits. 173 5457 0 0.05 18 6 2.89 Shallow Pitting. Lt. De osits. 174 5489 0 0.05 19 4 2.92 Shallow Pitting. Lt. Deposits. 175 5520 0 0.03 12 4 2.91 LL Deposits, 176 5551 0.05 0.04 16 6 2.91 Shallow Pitting. Lt. Deposits. 177 5582 0.04 0.04 15 5 2.90 Shallow Line of Pits. Lt. Deposits. 178 5611 0 0.05 20 6 2.91 Line of Pits. Lt. Deposits. 179 5642 0 0.06 22 6 2.90 Isolated Pittin Lt. De osits. 180 5674 0.06 1 0.05 18 6 2.92 Shallow Pitting. Lt. Deposits. 181 1 5705 0.05 1 0.05 19 6 2.92 Shallow Pitting. Lt. Deposits. 182 5736 0.04 0.04 17 4 2.91 Shallow Pitting. Lt. Deposits. 183 5768 0.05 0.04 17 6 2.92 Shallow Pitting. Lt. Deposits. 184 5799 0.05 0.04 17 4 2.89 Shallow Line of Pits. Lt. D osits. 185 5829 0 0.06 24 4 2.92 Isolated Pittiny, Lt. Deposits. 186 5861 0.04 0.05 20 5 2.92 Isolated Pittin Lt. De osits. 187 5890 0.05 0.05 19 8 2. 1 Shallow Pitting. Lt. De osits. 188 5921 0 0.05 21 6 2.90 Isolated Pittiny, Lt. Deposits. 189 5953 0 0.05 21 6 2.92 Line of Pits. Lt. Deposits. Penetration Body Metal Loss Body Page 4 CASED point Tabulation Sheet HOLE Well: 31-1-1413 Survey Date: July 3, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc Pipe Description 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. 39 ft Bottom Depth 7,694 ft. Joint No. 190 Jt. Depth (Ft.) 5984 Pen. Upset (in.) 0.04 Pen. Body (in.) 0.05 Pen. % 18 Metal Loss % 6 Min. I.D. (in.) 2.92 Comments Shallow Line of Pits. Lt. De osits. Damage Profile (% wall) 0 50 100 190.1 6015 0 0.04 15 3 2.88 Pu Shallow Pittin Lt. Deposits. 190.2 6022 0 1 0 0 0 2.90 GLM 3 Latch @ 6:00 190.3 6028 0 0.03 12 2 2.93 Pup Lt. Deposits. 191 6034 0.06 0.05 19 7 2.91 Shallow Line of Pits. Lt. Deposits. 192 6065 0.05 0.05 21 6 2.91 Line of Pits. Lt. Deposits. 193 6096 0.06 0.06 23 7 2.91 Line of Pits. Lt. Deposits. 194 6126 0.06 0.06 23 7 2.88 Line of Pits. Lt. Deposits. 195 6158 0 0.05 21 4 1 2.91 Isolated Pittin Lt. Deposits. 196 1 6189 0 1 0.05 20 5 2.89 Isolated Pittin Lt. Deposits. 197 6218 0.04 0.05 19 7 2.90 1 Shallow Pitting. Lt. Deposits. 198 6250 0.04 0.07 26 7 2.92 1 Line of Pits. Lt. Deposits. 199 6281 0.05 0.09 34 6 2.91 Line of Pits. Lt. Deposits. 200 6312 0 0.08 31 7 2.92 Line of Pits. Lt. De osits. 201 6343 0 0.10 37 6 2.89 Line of Pits. Lt. Deposits. 202 6374 0 0.08 30 4 2.90 Line of Pits. Lt. Deposits. 203 6406 0.07 0.08 33 7 2.92 Lin losits. 204 6437 0.04 0.08 30 5 2.90 Line of Pits. Lt. Deposits. 205 6468 0.04 0.08 31 4 2.88 Line of Pits. Lt. Deposits. 206 6499 0.05 0.06 23 6 2.90 _ Line of Pits. Lt. Deposits. 207 6530 0.07 0.06 25 7 2.90 Isolated Pitting, Lt. Deposits. 208 6561 0.04 0.06 24 6 2.89 Line of Pits. Lt Deposits. 209 6593 0.04 0.05 19 4 2.91 Shallow Line of Pits. Lt. Deposits. 210 6624 0 0.08 30 5 2.91 Line Corrosion. Lt. Deposits. 211 6655 0.05 1 0.05 21 1 5 2.90 Line of Pits. Lt. Deposits. 212 6687 0.05 0.07 28 8 2.90 Line of Pits. Lt. Deposits. 213 6718 0.05 0.08 31 8 2.91 Line of Pits. Lt. Deposits. 214 1 6749 0 0.06 22 6 2.90 Line of Pits. Lt. De sit . 215 6781 0 0.06 25 7 2.91 Line of Pits. Lt. Deposits. 216 6812 0 0.08 33 7 2.90 Line of Pits. Lt. De osits. 217 6841 0.05 0.06 22 7 2.90 Line of Pits. Lt. Deposits. 218 6873 0 0.07 27 4 2.92 Line of Pits. Lt. Deposits. 219 6904 0 0.06 22 6 2.91 Line of Pits. Lt. Deposits. 220 6935 0.04 0.06 22 5 2.91 Line of Pits. Lt. Deposits. 221 6967 0 0.04 17 4 2.91 Shallow Pitting. Lt. Deposits. 221.1 6998 0 0.04 17 2 2.90 Pup Shallow Pitting, Lt. Deposits. 221.2 221.3 221.3 7004 7010 0 0 0 0.05 0 18 0 6 2.87 2.92 GLM 4 Latch@ 12:30)___ -- Pu Shallow Pitting. Lt. Deposits. 222 7016 0 0.07 28 5 2,90 Line of Pits. Lt. Deposits. 223 7047 0.10 0.09 34 4 2.91 Line of Pits. Lt. Deposits. 224 7079 0.05 0.07 26 1 5 2.89 Line of Pits. Lt. Deposits. 225 1 7110 0.04 0.09 35 1 7 2.91 Line of Pits. Lt. De osits. 226 7142 0.07 1 0.07 29 1 5 1 2.90 Line of Pits. Lt De osi s. 227 7172 0.04 1 0.07 27 5 2.91 Line of Pits. Lt. Deposits. 28 7204 0 0.08 31 4 2.92 Line of Pits, Lt. Deposits. 229 7235 0.07 0.08 30 8 2.92 Line of Pits. Lt. Deposits. 230 7267 0.04 0.08 30 5 2.91 Line of Pits. Lt Deposits. 231 7296 0 0.07 29 7 2.92 Line of Pits. Lt. De sits. 232 7327 0.05 0.07 26 6 2.92 Line of Pits. Lt. Deposits. 233 7358 0.05 0.07 29 6 2.92 Isolated Pittin Lt. Deposits. Penetration Body Metal Loss Body Page 5 Joint Tabulation Sheet Well: 31-1-1413 Survey Date: July 3, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. 39 ft 7,694 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 234 7390 0 0.07 28 4 2.91 Line of Pits. Lt. De osits. 235 7421 0.08 0.06 25 6 2.92 Line of Pits. Lt. Deposits. 236 7453 0.07 0.05 21 6 2.92 _ Line of Pits. Lt. De osits. 237 7483 0.06 0.06 24 5 2.93 Isolated Pittin% Lt. Deposits. 238 7514 0.04 0.06 22 6 2.93 Line of Pits. Lt. Deposits. 239 7544 0.04 0.06 24 5 2.93 Line of Pits. Lt. De osits. 240 7575 0.05 0.06 24 9 2.93 Isolated Pitting, Lt. Deposits. 241 7606 0.05 0.10 39 6 2.92 Isolated Pittiniz. Lt. Deposits. 242 7638 0.04 0.06 22 5 2.94 Line of Pits. 243 7668 0.05 0.07 29 3 2.92 Line Corrosion. Lt. Deposits. Penetration Body Metal Loss Body Page 6 CASED HOLE Cross-sectional Illustration Well: 3H -14B Survey Date: Field: Kuparuk Tool Type: Company: ConocoPhillips Alaska, Inc. Tool Size: Country: USA No. of Fingers: Tubing 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Analyst: Cross Section for Joint 241 at depth 7,622.960 ft. Tool speed = 51 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 94% Tool deviation = 59° July 3, 2019 UW MFC 24 No. 218527 1.69 inches 24 Waldrop — - — Finger = 22 Penetration = 0.099 in. Isolated Pitting 0.10 in. = 39% Wall Penetration HIGH SIDE = UP Well: 3H -14B Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing_ 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Cross-sectional Illustration Survey Date: July 3, 2019 Tool Type: UW MFC 24 No. 218527 Tool Size: 1.69 inches No. of Fingers: 24 Analyst: Waldrop Cross Section for Joint 201 at depth 6,359.580 ft. Tool speed = 50 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 97% Tool deviation = 55° / E Finger = 18 Penetration = 0.095 in. Isolated Pitting 0.10 in. = 37% Wall Penetration HIGH SIDE = UP -�\ ConocoPhillips KUP PROD AW47 lI Ir WELLNAME 3H -14B WELLBORE 3H -14B 3H -14B, 'JYA197.48s7 AM Notes: General S Safety Vesical scfemmic (act�0 End Date Annotation 4/21/2005 NOTE: WELL SIDETRACKED FOR SECOND TIME 1/22/20% NOTE: MULTI -LATERAL WELL: 3H-14B/3H-14BL1/3H-14BL2/3H-14BL3/3H-14BL4 1/2212006 NOTE: 3H-14BL1(OPEN HOLE PILOT HOLE - PLUGGED OFF) HANGER; 375 1!22/2006 NOTE: 3H-`14BL4—ONLY ACCESSIBLE LEO" 2/28/2006 NOTE: CHEMICAL CUT 31-1-1481-4 LINER TOP DOWN TO 8040' CLEAR 3H -14B LINER 1/4/2011 NOTE: View Schematic w/ Alaska Schematic9.0 3/1/2011 NOTE: —TUBING COMPONENT DEPTHS QUESTIONABLE" TALLY/DETAIL SHEETS VARY CONDUCTOR; 36 P715.0 SAFETY VLV; 2,328.6 GAS LIFT; 2,966.7 SURFACE, 35.23,455.6 GAS LIFT', 4,8244 GAS LIFT, 6,021.6 SEAL ASSY; 6,781.0 GAS LIFT; 7,004.4 UPR PKR (ME); 7,696.0 GAS LIFT; 7,705.6 SPACER PIPE; 7,61380 LEAK; 7,714.0 LWR PKR (ME); 7,726.0 NIPPLE; 7,747.8 SEAL ASSY; 7,789.1 (PERF; 7,8840-7,886.0 (PERF; 7,886.0.7,888.0 SCAB LINER; 6,038.47,925.0 whWock 8,025 0 V49rcWw L4; 8,016.0$026.0 APERF; 8,147.M,157.0 APERF; 8,172.041.182.0 FRAC; 8,172.0 APERF; 8,182.08,187.0 APERF; 8,2120-8,222.0 PRODUCTION; 33 ".2202 RETAINER; 6.223.0 LINER 31/2; 7,780.38,450.0 SLOTS; 8,2430-90 Lifer 1-4; 8,040.0.9,532.0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon 0 Plug Perforations LJ Fracture StimulateLJ Pull Tubing Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casin 1 t"" g ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑✓ Re-enter Susp Well ❑ Other: _Tubing Patch 2. Operator4. Well Class Before Work: 5. Permit to Drill Number: Name: ConcocoPhillips Alaska Inc Development ❑✓ Stratigraphic ❑ Exploratory ❑ Service ❑ 205-021 3. Address: 6. API Number: P.O. Box 100360, Anchorage Alaska 99510 50-103-20092-02-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025531 3H -14B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NA Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8450 feet Plugs measured NA feet true vertical 6409 feet Junk measured NA feet Effective Depth measured 8450 feet Packer measured 6039'& 7780' feet true vertical 6409 feet true vertical 4848'& 5916' feet Casing Length Size MO TVD Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 3420' 9.625" 3456' 3002' Production 8187' 7" 8220' 6221' Scab Liner 1886' 5.5" 7925' 6007' Perforation depth Measured depth 7884'- 7888', 8147'- 8157', 8172'- 8187', 8212'- 8222' True Vertical depth 5981'- 5984', 6164'- 6172', 6184' - 6195', 6215'- 6223' Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7801' 5929' Packers and SSSV (type, measured and true vertical depth) SSSV CAMCO TRMAXX 2329' 2208' Upper Patch Packer Paragon II 7612' 5816' Lower Patch Packer Paragon II 7632 5828' Upper Patch Packer Paragon II 7696' 5866' Lower Patch Packer Paragon II 7726' 5884' 5.5" x 7" Liner Top Packer Baker CPH 6039' 4848' 3.5" x 5.5" Liner Top Packer Baker HR ZXP 7780' 5916' 12. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: NA NA NA NA NA Subsequent to operation: INA NA NA NA NA 14. Attachments (required per20 A C 25.070, 25.o7l, s 25.283) 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 Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Authorized Name: Jan Byrne (covering for Sara/Rachel) Contact Name: Sara Carlisle/Rachel Kautz Authorized Title: Well Integrity Supervisor Contact Email: "2549aconocoohilllos.com Authorized Signature: a Date: 7/30/19 Contact Phone: 659-7126 Form 10-404 Revised 4/2017 �Z 9��9�//,rJ RBDMS.1✓AUG 0 12019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 30, 2019 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 71h Avenue, Suite 100 Anchorage, AK 99501 Commissioner French, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch installed across a known tubing leak in producer KRU 3H -14B (PTD 205-021). Please contact Rachel Kautz or Sara Carlisle at 659-7126 if you have any questions. Sincerely, Jan Byr e Well Integrity Supervisor ConocoPhillips Alaska, Inc. Date Executive Summary Kuparuk well 3H -14B had a leak at 7,622' MD identified above the existing tubing patch installed in March 2019. A second tubing patch was installed over the leak at 7,622' MD with a passing CMIT TxIA to 2500 psi on the lower patch packer and passing MIT -T to 2500 psi on the upper patch packer. A passing TIFL was acheived 7/25/2019 confirming the patch integrity. 05/26/19 IPE REPORTED TXIA COMMUNICATION DURING SCALE SQUEEZE. 05/27/19 07/03/19 07/21/19 07/22/19 EVAL) TIFL (FAIL) DUE TO PRESSURE INCREASE AND INFLOW Initial T/I/O = 220/1100/1050. IA FL @ 6021' (St.43 OV). Stacked WHP's to 1025/1025/1050 psi in 60 min. IA FL @ 4934' (1086' inflow). T FL @ 4304'. Bled IA from 1025 psi to 480 psi in 50 min. IA FL @ 3911' (1023' inflow). T FL @ 4722' (418' outflow) Monitor for 1 hour. T/I/O = 1000/480/790. 15 min T/I/O = 1000/515/790 (+35 psi) IA FL @ 3720' (191' inflow). T FL @ 4782' (60' outflow) 30 min T/I/O = 1000/525/760 (+10 psi). IA FL @ 3540' (180' inflow). T FL @ 4782'. Final T/I/0= 1000/525/760 RUN 1: PERFROM LDL, LEAK FOUND AT 7622'. RUN 2: LOG 24 ARM CALIPER FROM PLUG @ 7696 TO SURFACE. SET 1" DV @ 7004' RKB, PULLED 3 1/2 TTS TEST TOOL @ 7695' RKB, SET 2.72" ER PACKER @ 7632' RKB (ME) (DAL 2.87'/ SN: CP350115), SET TEST TOOL IN LOWER ER PACKER @ 7632' RKB CMIT TBG x IA PASS, SET UPPER 2.72" ER PACKER SPACER ANCHOR @ 7612' RKB (ME) (DAL 20.36'/ SN:CP3500112 / CPS350052). IN PROGRESS. CMIT TxIA AGAINST LOWER PACKER TO 2500 PSI (PASS) Test T/I/O = 1075/1150/690 Pumped 1.2 bbls diesel to achieve test pressure Initial T/I/O = 2525/2600/700 15 min T/I/O = 2475/2550/700 30 min T/I/O = 2475/2550/700 ATTEMPT DRAW DOWN TEST ON IA FAILED, SET 3 1/2 ER TEST TOOL IN UPPER 2.72 ER PACKER @ 7612' RKB, MIT TBG 2500 PASS, ATTEMPT TO PRESSURE IA UP W/ LRS LLR @ .25 @ 2450 PSI 1.25 BBPS PUMPED, PULLED 3 1/2 ER TEST TOOL @ 7612' RKB, PULLED 2.72 ER PACKER PATCH ASSEMBLY @ 7612' RKB ANCHOR LATCH WAS NOT SHEARED, SET NEW UPPER 2.72" ER PACKER PATCH ASSEMBLY @ 7612' RKB (DAL 20.36' / SN: CP350031 / CPS350059), TEST UPPER 2.72" ER PACKER W/ 3 1/2 ER TEST TOOL MIT 2500 PASS DRAW DOWN IA TEST PASS. COMPLETE. MIT -T TO 2500 PSI AGAINST RE -SET UPPER PACKER (PASS) & IA BLED TO 500 psi. Pre-test T/I/O = 1200/500/650 Pump 0.3 bbls to achieve test pressure Initial T/I/O = 2575/550/650 15 min T/I/O = 2525/550/650 30 min T/I/O = 2515/550/650 07/25/18 (AC EVAL) RE-TIFL (PASS) Initial T/1/0= 225/1300/995. IA FL @ 6021' (St.#3 OV) SI wellhead @ WV & double block AL Stacked WHP's to 1160/1160/884 in 30 min. IA FL @ 6021' (same location) Bled AL line to 250 psi Bled IA from 1160 psi to 600 psi in 45 min. IA FL @ 6021' (same location) Monitor for 1 hour Initial T/I/O = 1160/600/660. 15 min T/I/O = 1180/600/660 30 min T/I/O = 1200/600/660. IA FL @ 6021' (same location) 45 min T/I/O = 1220/600/695 60 min T/I/O = 1220/600/695. IA FL @ 6021' (same location) Final T/I/O = 1220/60n/6" KUP PROD WELLNAME 31-1-1413 WELLBORE 3H -14B ConociPhillips Well Attributes Max Angle B MD TD Alaska, l00 w.....e Annrw Wellbore SlaNs KUPARUK RIVE UNIT 501032009202 PROD cl P MOIIINO) FCI Bfm mNB) 5550 ]04839 84500 Careen] Xx6(Few) Dab UMElon EnE Dab K.Gid IRI Wp ReImY Dab SSSV:TROP 150 2/3/2018 Last WO: 6262005 42.01 12/1411987 .Nd.. Toomir. z14AM Last Tag vwatlaWrwY(wm3 ArvwlWm Daps" ream WYMwe I L•d Yne _.... Last L9: SLIM ].9,501162.5 jhipahkr Last Rev Reason MnoeabnI seems wNlbm uY Ye4 a) Rev Reason: Sol Paltle IIII.Illa 3H-148 RANDER.115 Casing Ships fdn9UwJLpaan mon) mIM) Top aU®) as lea, (Me) aYDeps"O'sDF.. WVL•n O... OrW Top. CONDUCTOR 16 1508 we 115.0 115.0 62.50 H-40 WELDED so eoxoualoR: w.wesb dome ASNptbn 00 0-1 Io On) To pass) ad 1YPD11aRa) ad DaYel lrVD1... Vx6Leel n... O,M• fop mlYe SURFACE 959 8.92 352 3.455.6 3,002.4 38.00 155 BTG Cbina D•aulPNon com roMl TOP MKaI Sa DNN11YLa) ser D•qa Fred).. M" P... areae Tap Tlme PRODUCTION ] 528 330 8.220.2 8,221.2 2fi.0o 155 BTC saFETYvly. ]0x0.6 dam goetvl0. do 01"1 TOP paxpal ser DaPIn OYLa) sd Be na'DI... Lv1Axn 6...OM• Top ]nrw Window L4 ) 6.Be 11..6.0 .,026.0 50)52 930 ces, o•ss'. mMl IDllp TOP 014]1 aw onu meal sa D•Pm flvDl... wuLan ll... Dewe Top Th. Das LIFT', 2w%7 SCAB LINER 512 4.95 6,038.9 ],9250 6,OOJA 1550 L-06 HYDRIL511 Wer Details; Ynmma Io ,as 41®1 I Top"le"ss" To,ftr rl ded dew Dam M) 0,038.9 1.846.1 4444 1 PACKER BAKE CPH LINER TOP 111ER-7n55' 4830 MJFIACe..xa,4sse 8.0493 4,Ihit, aa.45 MANGER IBMER HMC LINER HANGER 4920 GMIUFTl4044 hats, Dasorlp6M mllnl maul TWp ) aa0.pmmsa) Sal Da(M IND/... WNLan n... O1Ka TYp Ta1W LWER312 312 2.99 ],]803 54500 6.408.6 930 L-00 HYDRA 511 Liner Detach xomma m Ws LiFi9pz?a Top laRel Top (rv0 1) Topblar) Ibm o.a can M) >.71103 5.918.3 5289 PgCKER BAKER HR DIP LINER TOP PACKER 5.12'x3- 3500 12' (CommaH298-2 5]9) ]180]1 5.932. 5238H0NGER BAKER HMCLWERHANGERS-12'x11I2'Comm 3.500 ##1292.23-02121 Tubing Strings *omng onealprlon and Y• ID IIsi *op meal parD•P1n m"aa oePm fxVD)4.. MY 6bm1 oleee Top eonnectlon TUBING 312 2.99 3].5 7.11..1 5.9288 9.30 Lb0 EUEBRDMOD aFwLAssr:eRe➢ Completion Details Top FVo1 Torew NomIn. Tap 41®1 "Baal fl nem va can mane A.B LIFi:I,D]aa 375 37.5 ON HANGER CM1Y OEs" 3TUBING HANGER 3500 UPR PACNER (MEI: ],012F LEAK?anal 3.38. 2.2..8 43.01 SAFEtt VLV CalACO ]RMAX%-10E SAFEtt VALVE (HVY"3>3) 2810 ii.dEp vIP6 Zeu0 8,701.0 5.326.4 5264 SEALASSY BAKER SEAL ASSEMBLY 2.990 LV9 PACKER WE). 7,65;6 1,]47.8 5.898.] 53.14 NIPPLE CAMCO D NIPPLE WINO GO PROFILE 2.750 UPRPKRYE)O.MD ),]09.1 5.921.6 5203 SEAL ASSY BAKER SEAL ASSEMBLY IS SETS) 2990 Other In Hole (Wirefine retrievable plugs, valves, pumps, fish, etc.) Wa uFr:7.7M9 s PACER PIF,;1. Top mo) Top ua Too flew (Nfa) r) DH cmm Fe.o. OIn LEAKT214p 7,812.0 5,616.1 54.03 UPR PACKER XiO' Upper ER Padwrw/Ancor Ldch IOAL 19.52' 7/228019 1.750 (ME) SN: CP350031 I CPS350059) 1978 pew MFF7.12d. 7,613.0 5,816.7 54.03 SPACER PIPE 24318' Spacer Pipe ]22!2019 1.750 7,622.0 5,822.0 53.97 LEAK LaakI47622' 7112019 0.000 -7 NIPPLE:].TOH 7,032.0 51827.9 53.91 LMR PACKER 3-18' Laver ER Pa &. (DAL 2.8r, SN: CP350115) / 1l 19 75-0 (ME) ssaLassv: )7Y'e ),898.0 5.885.8 53.52 UPR PKR (ME) P2P UPR PKR.OAL4'[SNa CPP35194) 322019 1 825 7,898.0 5.867.0 53.50 SPACERPIPE 30' SPACER PIPE wl ANCHOR LATCH ASSEMBLY 322019 1.600 (SNP CPAL 35072) 7.714.0 5.8)6.5 53.39 LEAK LARGE LEAK FOUND 0 STa4 GLM 2/102015 OOm 7,726.0 5,803.7 53.3D LWR PKR(ME) P2P LWR PKR. DAL 4'(SNe CPP35026) 112019 1.625 8,0250 6,074.4 43.02 Whipmlock WEATHERFORD WHIPSTOCK (COULD NOT BE 4118200 PULLED) IPERFI LaY.aTa99.o� 8.223.0 6.223.4 3715 RETAINER BLINER HES EZ -DRILL SVa RETAINER 5/132005 2.890 perforations 8 Slots .1 SCAB U.Ma0N972250 Top(rvol aM OVOI veno IMas41 Tap mm) ranmKe IKK•I Me) Yew gena Dads I Txw Com 7,884.0 7,606.0 5,981.0 59823 5/182005 40 IPERF Shot TBG PUFO Mies (9) ).8060 ,880.0 5,982.3 5,983.5 T13/2008 4.01PERF of TBGWnch MI95(B) vYlp4o[ksp ,ori m4o0.Oxsesad 8,1Q0 8,15].0 6,1M.5 8,172.0 s,3.31414B 10,78005 50 APERF 2s' PJ 2506, Be Deg DBau 8,92.0 51B2.0 6,183.5 6,191.2 A2,3HA4B MCK105 50 APERF 2.5-HSO 60 deg phase 8,182.0 8.187.0 8.1912 8,195.1 A4,3H-14B &92005 6.0 APERF 2.5' HSD. 60 deg 0. 0.212.0 8.222.0 6214.] 6,222.6 A-1,314148 10`7245 6.0 APERF 25' PJ 2508, W deg phew Frac Summary 6YIIDeM1 hopead awards (b) ProppenH. lo..Vb) 1212005 APERF.414708,15]A APERF: BFRAC51@➢ :arn.p SL9a 51efl . To' d0111 pass) sad (7.0 Ynka FlYle ayelMn VeI CIW ms") Vd 81YM 406 1 6282005 8.920 8,18).0 Mandrel Inserts APERRIAro.o'snod 61 a APERF.82120$SII➢ up lord) o Good poa6ae TRO pIM PflODVCiION: ]3.Od,Ltl.2 se Tnpmsal 00") YW mom ODM) Type T)Ps MI "Pep ass' as cal, l 2.986.] 2,6813 CAMCO KBUG- 1 BK BASS 1,278.0 3132019 7:30dB24A 3.976.8 CAMLO KBUG 1 BK 0158 1,2)80 2852015 490M I 3 6,021.6 4,035.8 CAMCO KBUR 1 BK 0.350 0.0 Bm2.9 890 M 4 ],004.4 5,460.7 CAMCO Keel- 1 BTM 0.000 8252019 12:309 EXTPRO 4 7,004A 5.480.7 CAMCO KB(F2� 1 BTM 0.000 1212019 12:30 9 LINER J I/G ],]903�,�50➢- sams: aza➢a.aY.p�_ rw.Lc 4➢xP.ea.al2p \ KUP PROD WELLNAME 3H -14B WELLBORE 3H -14B ConocoPhillips \ Aleske.Inc. x.®,]mamaeRlsua Mandrel Inserts v.n®Imin.ulawl a a K TOp nUO) IDKI) I YW Me OD1MI Nn YYw TRI IaW Tvw Mn Yn (in) TIORun Mvl Sun O01 can 1.)05.8 5,8)1.5 GM(:O KBCr2- 1 GAS LIFT OPEN 12UOrzerz015 COVE 9 RED NAHGER, 111—R0Y PATC H Notes: General & Safety COHDUCTOR:MAU50 EMMN MMYVan w1w1889 NOTE: WANEREDWELL: WKOACOMMUNICA330N SAFETY VLN, 2AYe 4212005 NOTE: WELL SIDETRACKED FOR SECOND TIME 12ffi008 NOTE: MULTFLATERAL WEll:3H-14813H.1 QLIMH-14132 14BLV 3H-14111.4 V1Ntlgf NOTE:3H-14BLHOPEN HOLE PIL0T HOLE -PLWGED OFF) GAS LIFT: 2.966.] 1R]2008 NOTE: 3H-14BL4-'ONLYACCESSIBLELEO" )R82008 NOTE: CHEMKC CL1T 3H-1481.4 LINER TOP DOWT3 TO804V CLEAR 3H -14B LINER 1142011 NOTE: View StllenYec wl Aleske SCb..U8.0 NOTE: "TUBING COMPONENT DEPTHS QUESTBL IONAE^ TA LYNEI'AIL SHEETS VARY SUFFACE.35�34668-A3112011 BVRFPCE:%}8,0.55.8 WBLIR:6.SMA GAS LIR: EA218 SEAL ASSY; 47811 GAELIFT:7A014 UPR PACNER WE): 7.8120 LEAK;].C6A SPACER PIPE; 7,,613.0 LWR PACKER WE) ,?N20 VPR P. WE)', ].366.0 GB LIFT;],]%8 SPACERLEAK71140 LNA PKR WE)', ],]280 NIP11E:1.14]S SF LASSY;).)89,1 IPERF;761H 7851.0— SCAB LIHER;B.Pb9�.ES WiµloM eA25➢ ldrtlow L<: BOIRO-0.O3&0 APERF,e,14]08,18].0 APERF; B.1R08, 133.0 FRAC; nT22.0 APERF;8,132.DS181.0 APERF;3,2120424.0 PRODUCTION, SIOS,]A2 R ETAI NER: 6 R3.0 UNER 3ITO 7, 66,38,4WA� SLOTB.i4J.O9,4%.0�� LIa1L9, S.N0.08.592.0 Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760fax Delivered to: n -,,4/ AOGCC ATTN: Natural Resources Technician It Alaska Oil & Gas Conservation Commision \y} 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 205021 I.. TRANSMITTAL DATE TRANSMITTAL#0' . .; ORDER NAME DESCRIPTIONFIELD • DATA DATELOGGED Prints CD's —ENL 1A-25 30-11 31K-23 50.029-22116.00 50-029-21676-00 50-029-22771-00 -00028 EBNL-00029 EBNL-00030 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL PPROF LDL LDL FINAL FIELD FINAL FIELD FINAL FIELD 21 -Jun -191 22 -Jun -19 23 -Jun -19 1 1 2V-02 1Y-14 1H-109 1H-113 1H-117 31-1-148 50-029-21037-00 50-029-20910-00 50-029.23595.00 50-029-23588-00 50-029-23602-00 50-103-20092-02 EBNL-00034 EBNL-00035 EBNL-00036 EBNL-00037 EBNL-00038 EOSH-00062 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL1 WL WL WL IPROF IPROF (PROF (PROF IPROF LDL FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 27 -Jun -19 28 -Jun -19 29 -Jun -19 30 -Jun -19 1Ju1-19 3 -Jul -19 1 1 1 1 1 2G -14A 1B-06 -09 3G 3G-03 1R -22A 50-029-21161-01 50-029-20603.00 50.029-20655-00 50-103-20245-00 50-029-22206-01 EOSH-00064 EOSH-00065 EOSH-00066 EOSH-00067 EOSH-00048 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL LDL PPROF (PROF PPROF LDL r. 11k FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 5•Jul-19 6 -Jul -19 7 -Jul -19 8 -Jul -19 8 -Jul -19 1 1 1 1 1 AL 12 Rig AGGGG 14 !'- 1 ! /�////// / -� // A Transmittal Receipt signature confirms that a package (box, J ..(�/ l Ll ��envelope, etc.) has been received and the contents of the X (f / 111 !!! package have been verified to match the media noted above. The Name Signature Date specific content of the CDs and/or hardcopy py prints may or may not have been verified for correctness or quality level at this e return via courier or sign/scan and email a copy Schlumberger and CPAI. point. a PTSPrintCenter(n)slb Com Tom Osns com SLB Auditor- l Schlumberger -Private WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Set Record: 31-1-1413 Run Date: 3/1/2019 205021 30 750 April 12, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3H -14B Digital Data in LAS format, Digital Log Image file 50-103-20092-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY 01, 1 H TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS ANC@halliburton.com ,te: O�Loq Signed: RECEIVED MAY 0 8 2019 AOGCC IV STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 L 2019 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Plug Perforations Lj Fracture StimulateT7 Pull Tubing LJ OpePaBons shutdown J Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Re-enter Susp Well ❑ Other: _Tubing Patch 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConcocoPhillips Alaska Inc Development ❑' Stratigraphic ❑ Exploratory ❑ Service El6. 1 205-021 3. Address: API Number: P.O. Box 100360, Anchorage Alaska 99510 50-103-20092-02-00 7. Property Designation (Lease Number):8. WeII Name and Number: ADL0025531 3H -14B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NA Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8450 feet Plugs measured NA feet true vertical 6409 feet Junk measured NA feet Effective Depth measured 8450 feet Packer measured 6039'& 7780' feet true vertical 6409 feet true vertical 4848'& 5916' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 3420' 9.625" 3456' 3002' Production 8187' 7" 8220' 6221' Scab Liner 1886' 5.5" 7925' 6007' Perforation depth Measured depth 7884'- 7888', 8147'- 8157', 8172'- 8187', 8212'- 8222' True Vertical depth 5981'- 5984', 6164'- 6172', 6184'- 6195', 6215'- 6223' Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7801' 5929' Packers and SSSV (type, measured and true vertical depth) SSSV CAMCO TRMAXX 2329' 2208' Upper Patch Packer Paragon II 7696' 5866' Lower Patch Packer Paragon II 7726' 5884' 5.5" x 7" Liner Top Packer Baker CPH 6039' 4848' 3.5" x 5.5" Liner Top Packer Baker HR ZXP 7780' 5916' 12. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil-ebl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: NA NA NA NA NA Subsequent to operation: NA NA NA NA NA 14. Attachments (required per 20 MG 25.070, 25.o71, & 252as) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory ❑ Development 71 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 21 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Authorized Name: Sara Carlisle Contact Name: Sara Carlisle/Rachel Kautz Authorized Title: Well Integrity Supervisor Contact Email: n25490conocoohillios.com Authorized Signature: �SWDate. 3-(0- 11 Contact Phone: 659-7126 Form 10-404 Revised 4/2017 31J-7119 Submit Original Only 1 RBDMSgv MAR 0 8 2019 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 06, 2019 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 71h Avenue, Suite 100 Anchorage, AK 99501 Commissioner French, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch removed and reset across a known tubing leak in producer KRU 31-1-14B (PTD 205-021). Please contact Rachel Kautz or me at 659-7126 if you have any questions. Sincerely, ��C6�b YQ'� Sara Carlisle Well Integrity Supervisor ConocoPhillips Alaska, Inc. Date Event Summary Executive Summary 03/01/19 03/02/19 03/03/19 03/06/19 Kuparuk well 31-1-146 required a coiled tubing jet -blast fill clean out. The previously existing tubing patch over the leak at 7,714' MD was pulled to allow coiled tubing access. Following the clean out, AOGCC permission was granted for a 7 -day flowback prior to re -patching to determine the job success. A tubing patch was re -installed over the leak at 7,714' MD after the flowback period with a passing CMIT TxIA to 2500 psi on the lower patch packer and passing MIT -T to 2500 psi on the up patch packer. A passing TIFL was acheived 3/6/2019 confirming the patch integrity. BRUSH n' FLUSH TBG FROM 7747' RKB TO 7650' RKB, SET 3 1/2 P2P PACKER @ 7726' RKB ME (CAL 4.01 / SN :CPP35026), SET 3 1/2 TTS TEST TOOL IN LOWER P2P PACKER @ 7726' RKB. IN PROGRESS. CMIT TBG x IA 2500 PASS, PULLED 3 1/2 TTS TEST TOOL FROM LOWER 2.72 P21P PACKER @ 7726' RKB, SET UPPER 2.72" P2P PACKER SPACER ANCHOR ASSEMBLY @ 7696' RKB ME (OAL 30.86' / SN: CPP35194 / CPAL 35072), SET 3 1/2 TTS TESTTOOL IN UPPER P2P PACKER @ 7696' RKB, MITTBG FAILED, GOOD DRAW DOWN ON IA. IN PROGRESS. RAN 3 1/2 F-STOP HOLE FINDER, GOOD TBG TEST ABOVE STA #1 @ 2966' RKB, REPLACED GLV INKIND, MITTBG PASSED AFTER SEVERAL ATTEMPTS, PULLED 3 1/2 TTS TESTTOOL FROM 2.72" P2P PACKER PATCH ASSEMBLY @ 7696' RKB. COMPLETE. (PASS) it T/I/O = 200/1060/600. IA FL @ 6021' (St.#3 OV). wellhead @ WV & double block AL. acked WHP's to 990/990/725 in 25 min. IA FL @ 6021' (same location). �d AL line to 240 psi. Bled IA from 990 psi to 520 psi in 50 min. IA FL @ 6021' (same location) onitor for 1 hour. rting T/I/O = 1070/520/700. min T/I/O = 1120/520/700. 30 min T/I/O = 1140/520/700. IA FL @ 6021' (same location) 45 min T/I/O = 1155/520/700. 60 min T/I/O = 1180/520/700. IA FL @ 6021' (same location) Final T/I/O = 1180/520/700. KUP PROD WELLNAME 311-14B WELLBORE 3H -14B ConoccPhillips Well Attibutds Ma:ARgie&610 TO Field Name wdWarc OPIN'M usawm3lMus nalr) M,pum, Rether Kel Alaska.Im. KUPARUK RIVER UNIT 5010MOTN112 PROD .50 7,04839 8.4504 Cam- HS IFPm1 DMe MnMallon End Date KBGNIXI RIB Rdeau Ogle SSSV: TRDP 150 DWO18 Iasi WO: 6262005 42.01 1211411987 S.14%3.. ILastTag VemlcelxMmn¢pnuall Anndtllon ===FEEEM Data weNve Las[MM By "M Tag: SUA I713]5-0 I 3'162015 1 spsnld I Last Rev Reason A. -ML -1 end Dae de"I"e Last MM By Rev Reason'. SET P2P se Patch Assembly and Reduce Station#1 GLV wiin 'SB'uH9 3H-1413 bwonni RANUE , aa5 Il An and At Casing Strings Grimy DescaPlion :DMI /Oehl TWMKBI BADveth M1Kal Bd Depth RVIS...WALen ll... Grade Top TImMA1 CONDUCTOR 16 15.06 36.0 115.0 115.0 6250 H-40 WELDED canning DRADIptlon ODUm ID lml Tap(M1Kte Sa DeptheK81 Set Depth(TVDI... WLLen(I... Geede Top Thea] COND,ICTOR:36.0-11Bo SURFACE 95111 8.92 35.2 3,455.6 3,002.4 36,00 E55 BTC Coring Deacrlpllon ODIN) Dan, Tap(XKBI Set DepP(M1KB) Set Depth(MIL. WN.en I. State Top Thread SAFETY Inv 2336e PRODUCTION 7 6.28 330 8,2202 6,221.2 2600 ESS BTC Casing Dexrlplion OO (in) ID (in) To i(KKB) Sel OeplI (tKB) Sd OepiI NIWm-- M. Chad. Top Thread Window L4 7 6.00 8.016.0 8,028.0 6.0]5.2 930 CaamE Description OOlinl ID lin Top IXKBj SN Dep+h (RKB) Set Depllr OV01.. .,,an p... Grade Top Named GAS BFT: 2966.7 SCAB LINER 512 495 6,038.9 7.925.0 6,007d 15.50 L-80 HYDRIL511 Liner Details .AsAad lO TW IM1KB) I Top OVER MIKE) Top Incl l') 1.Oea Com (inn 4. .1 44.44 PACKER BAKER CPN LINER TOp PACKER -]x5.5" 4A30 SURFACE:M.SK34ES8 6.dai) Ji artUbBI 4445 HANGER BAKER HMC LINER HANGER 4.920 easing Descietum OD In IDlih iap1M1KB1 Se, Dep,h(XKaI Bel Depth livor, W.n//..Grade TYCl GASLIFT:4.824.4 LINER 3112 3112 2.99 77803 84500 6,4086 9,30 L-80 HYDRIL 511 Liner Details nemmaND Top0,KB1 I Tapl WIPPIKB Topinclr) M1em Des coin lib GAS UFT. e.oa,e 71803 5916.3 5289 PACKER BAKER HR ZXP LINER TOP PACKER a -112-x 3- 3.500 I 112" (Comm#1129428-005]9) ],80].1 5,932.5 52.36 HANGER BAKER HAULm1RHANGER1I4-x3-10Comm 3.500 I #11292-23-0212) Tubing Strings Tame oesenpnon song Ma... ID lnl Top lnKBl Se10¢plh M.. se+De'in �VDll... wgmml Grade Top Connection SEALAssv; 67810 LURING 3112 2.99 37.5 ].801.1 5.928.8 9.30 L430 EUEBRDM00 Completion Details rpe'Tom Topma Nominal GAS LIFi:]WiA Top 11,KB nKBj 1.1 I,em Des Com ID 6,n) 5 37.5 006 HANGER CIW GEN 3 TUBING HANGER 3.500 37.1 UPR MR (ME), 7.53e.0 2.328.6 2,207.9 4304 SAF ELY VLV CAMCO TRMAXX-10E SAFETY VALVE (HAS -573) 2810 8,]814 5,3264 52.64 SEAL ASSY BAKER SEAL ASSEMBLY 2.990 GAS LIFT 7, me" ],]47.8 5,89fi] 53,14 NIPPLE CAMCO B NIPPLE W1 NO GO PROFILE 2.]50 SPACER PIPE. ],aM.O 7,]89,1 5,921.6 5283 SEALASSY BAKER SEAL ASSEMBLY (3 SETS) 2,990 LEAK nuo Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc:) roKno, TaP incl iop 1696, (IKB1 1.1 Des Com RimDateI1.in) PAR PKR (ME): T]$GO ],696.0 5.865.8 5352 HER PKR (ME) P2P UPR PKR,OAL 4'(SN#CPP35194) 3/22019 1.625 NIPPLE,77478 716980 $867.0 53.50 SPACER PIPE wI ANCHOR LATCH ASSEMBLY 3YL3019 1.600 (She GRAIL (SN# CPAL 3508) SE LASSY 7,.1 ],]14,0 5,876.5 53.39 LEAK LARGE LEAK FOUND @ ST44 GIM 21182015 0.000 ],726.0 5, .7 5330 LW P R(ME) P2P -WR PKR, GAL 4'(SNk CPMW26) 12019 1.625 8,060 .074.4 4302 WniDstack WEATHERFORD WHIPSTOCK (COULD NOT BE 4/182005 PULLED) 82230 62234 37.45 RETAINER BLINER HES EZ -DRILL SVS RETAINER 5/132005 2.690 Perforations & Slots Shut INERT: 7.8467.5860 One Den IPERF20.9° A].Bi6o- T Bim m0) Ienol:m (MB) TopVdKG) him SAKE!886.0 15981 1598 Llnkal2one Dale 1 Type Corn 7884.0 J, 086.0 5,9814 5,9823 51182005 4.01PERF Shot TOG punch holes (9) 7,8860 7,888.0 5,9823 5.983.5 5,132005 4A IPERF S6d TBG punts hdes(9) sue LINER 6058.a7 SG.0 8,147.0 8,15].0 8,1645 5.1720 A -3. 3H-140 100/2005 6A APERF 2.T PJ 2506, 60 deg phase 8,172.0 8,182.0 6,183.5 6.191.2 A-2,311-1413 8/912005 6.0 APERF 2.T HSD, 60 deg phase ,1 ---878-7o 6.191.2 6,195.1 A-4,311-140 8/94005 60 APERF 2.5- HBO, 60 deg phase wnpnocK Goan 8. 1 .0 2220 6,214.7 6,2226 Al. 3H -14B 10012005 ED APERF 25' PJ 2503,60 deg phase on. L4; Bp16Ga.016.0 Frac Summary SUXDae pnppe„IDeslgnM gel PMppniNFOrmalm (lb) "WDOs SRH# sad0are Top Oeplh Me) deal Ilnkto Fluid Byslem Vd CWn(htn Vd3lun(maj 1 8128noo5 81nA 8,187.0 Mandrel Inserts APERF;8.147.08.157.0 SI Mi APERF, 8+]2:8.+820 an Top 0"1 N TAR2,966L (89131 Make 00(Inl Value 18th P0(in) TRO Run Type (in) Run Data Com FRAC: e,trz0 2,9fifiJ 2.661.2 CAMCO BUG -Metal KBUG- 1 LIF GAS LIFT UJ GLV ,SRI)279 TK 0.1 E. 1,279.0 3131 9 :30 APERF 1318$4$1870 M 2 4,824.4 3,9]6.8 CAMCO KBUG- 1 GAS LIFT GLV Be 0.156 1,2]8.0 212512015 400 M AFERIF 821208.P120 3 6,021.6 4,035.8 CADDO KBUG- 1 GAS LIFT OV Be 0.250 DO 5120/2018 0:00 PROWCTbN', 37.0-0,242 M 4 ],004.4 5,460.7 CAMCO KBG - 1 A LIFT UM TTM OA00 0.0 211 015 1 RETAINER:89i0 9 EXT PKG 5 7,705.6 5,875 fAMC0 KBG-2- 1 GAS LIFT OPEN 12262015 COVE 9 RED BY PATO H Notes: General & Safety Fie Dae Anno,anon 9'1 611999NOTE WAIVFRED WELL: IA x OA COMMUNICATION LINER 312 7 m d.Sa.e5D0- SLOTS'SNSG8.493e Lner L4; soped.Men KUP PROD WELLNAME 31-1-1413 WELLBORE 3H -14B conocokillips Alaeka.Inc. s --aa. SP40191 m. 16 PIM Notes: General B Safety v<moa:N:n,am ).oi=mi E.4 Gae Ann.Gma _. __... 412112005 NOTE'. WELL SIDETRACKED FOR SECOND TIME TM -nm NOTE: MULTI4ATERAL WELL:3H-1dBr3H-14BL1I3H-14BL2I3H-148LY 3H -148L4 11222006NTE'. 3H- 4BL1(OPEN HOLE PILOT HOLE -PLU EO OFF) 10NGEN.3]s 11222006 NOTE :3H-14BL4"ONLY ACCESSIBLE LEG' 21282006 NOTE: CHEMICAL CUT 311-14BL4 LINER T0P DOWN T08040 CLEAR 311-14B LINER 1142011 NOTE: View SOhemalk Al Alaska Shcemali .0 S1/mil NOTE:"TUBING COMPONENT DEPTHS OUESTIONABLE" TALLYMETAIL SHEETS VARY CONWCTOR', 366uS0 SAFETYKV 3,32Ae GAS LIFT, 3.9Pa.7 SURFACE: 35 ]3455.6 GAS LIFT: 4a34a GAS LIFT. 6031.6 6EALA66Y.679T0 GAAUFT:],Na.a UPR WR (MEI; 70A6.0 GISUFT: T.T56 6PACER PWE;1d190 LEN(: ]]140 LWR We IME): ].]S.0 NIPPLE;],]4].B GEALASSY;].]&AI El /PERF',]884.0-738SO- IPERIF 1.0-1..� ACAS U.S.', 60NP.1.1 WNplrck, 9,0!5,0 Wk bw U'. RM8.O6,OM0 APERIF 614]68,15].0 APERIF 817!.08,1820 FRAC:61R0 APER, ', 8,183.08,10].0 APERF', 8, 313.Od,2120 PRO.T.R....2 RETAINER: 6 Ztl0 LINER 3IR, ],M.SSA.0� SLOTS.8N80-94 0� .., L4', 8,010.69.5 -- PT -D 2b5_ --o21 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, February 20, 2019 9:19 AM To: 'NSK Well Integrity Supv CPF3 and WNS' Subject: RE: 3H -14B (PTD 205-021) Request to Flow Temporarily Follow Up Flag: Follow up Flag Status: Completed Rachel, Approval is granted for a production flow test for no more than 7 days with known TxIA communication. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria Loepp(&alaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or V cloria.Loepore alaska.aov From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Wednesday, February 20, 2019 8:07 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: 3H -14B (PTD 205-021) Request to Flow Temporarily Victoria, Kuparuk producer 3H -14B (PTD 205-021) recently had a tubing patch removed which exposed a tubing leak to the inner annulus. Prior to resetting the tubing patch, CPAI would like to flow the producer in its current condition (with known TxIA communication) for no more than 7 days to determine if additional fill cleanout work is necessary before the patch is set. Please let us know if you approve. Thanks, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 STATE OF ALASKA ALO OIL AND GAS CONSERVATION COMMI SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing LI Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well 2 Re-enter Susp Wet ❑ Other: Tubing Patch Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 205-021 3.Address: Stratigraphic❑ Service ❑ 6.API Number: RECEIVED P7.Property Designation tiox 100360, 50-103-20092-02 (Lease Number):rage,Alaska 99510 8.Well Name and Number: JAN 1 1 2016 ADL0025531 KRU 3H-14B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): OGC N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8450 feet Plugs measured N/A feet true vertical 6409 feet Junk measured N/A feet Effective Depth measured 8223 feet Packer measured 6781 &7789 feet true vertical 6224 feet true vertical 5326&5922 feet Casing Length Size MD TVD Burst Collapse Conductor 79' 16" 115' 115' 0 0 Surface 3420' 9.625" 3456' 3002' 0 0 Intermediate 1886' 5.5" 7925' 6007' 0 0 Production 8187' 7" 8220' 6221' 0 0 Liner 670' 3.5" 8450' 6408' 0 0 Perforation depth Measured depth: 7884-7888,8147-8157,8172-8187,8212-8222 e�el I i#„ : ; . M iL True Vertical depth: 5,981-5,984,6,165-6,172,6,184-6,195,6,215-6,223 Tubing(size,grade,measured and true vertical depth):3.5"L-80;7789'MD&5922'TVD Packers and SSSV(type,measured and true vertical depth) Seal assy:Baker Seal Assembly;6781 MD and 5326 TVD Patch:3.5"Paragon II Upper Packer;7695 MD and 5865 TVD Patch:3.5"Paragon II Lower Packer;7725 MD and 5883 TVD Seal assy:Baker Seal Assembly;7789 MD and 5922 TVD Safety Valve:CAMCO TRMAXX-10E;2239 MD and 2208 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured):N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact:Dusty Freeborn/Jan Byrne Email:N1617@cop.com Printed Name:Dusty Freeborn Title:Well Integrity Supervisor Signature: L Phone:(907)659-7126 Date:4 Jan 16 Fnrm 1n-ane.Pavica c 9n15 Submit(lrir�inal Only /0 VI/ Lb v rz //i 7 i(t� RBDMS JAN 1 1 2016 . • • ConocoPhiI• hps RECEIVED Alaska JAN 11 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC The 4th of January, 2016 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 3H-14B PTD 205-021 tubing patch repair. Please call Jan Byrne or myself at 659-7126 if you have any questions. Regards, "(a — Dusty Freeborn Well Integrity Supervisor • S Date Event Summary 01/11/15 Tubing leak identified at 7710'. 02/17/15 Set upper and lower Paragon II packers for tubing patch from 7695' and 7724'. 02/20/15 MIT-T passed to 2500 psi. 05/15/15 Pulled upper section of tubing patch to diagnose tubing obstruction. 05/17/15 Reset upper Paragon II packer for tubing patch. Tubing appears to still be obstructed. 08/16/15 Pulled upper and lower Paragone II packers from 7695'and 7724'. 12/13/15 Started AOGCC approved production test with known TxIA communication. 12/28/15 Set lower Paragon II packer at 7725'. CMIT-TxIA passed. 12/29/15 Set upper Paragon II packer at 7695'. MIT-T passed. 01/03/16 TIFL passed confirming integrity of tubing patch. :, h. KUP PROD 3H-14B ConocoPhii.- hips �='S Well Attributes Max Angle&MD TD Alaska,IBC, Wellbore API/UWI Held Name Wellbore Status lind(°) MD(ftKB) Act Btm(ftKB) cvnv rttnlh o 501032009202 KUPAR UK RIVER UNIT PROD 55.50 7048.39 8,450.0 ..- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) •'Rig Release Date 311-148.12/3020154;05,53 PM SSSV:TRDP 140 11/12/2013 Last WO: 6/26/2005 42.01 12/14/1987 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date -- ------ ---- ----- ----"--"Last Tag:SLM 7,975.0 3/16/2015 Rev Reason:SET PACKER lehallf 12/30/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I Grade Top Thread HANGER,37 5 9, CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ' • '' ' ' ' ...SURFACE 9 5/8 8.921 35.2 3,455.6 3,002.4 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen p...Grade Top Thread 01 '"PRODUCTION 7 6.276 33.0 8,220.2 6,221.2 26.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 360-115.01 . Window L4 7 6.000 8,016.0 8,026.0 6,075.2 9.30 al Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread SCAB LINER 51/2 4.950 6,038.9 7,925.0 6,007.4 15.50 L-80 HYDRIL5p11 SAFETY VLV;2,328.6 ,IF-r-,,,^ Liner.Details �Jllle i,l;uN Nominal ID 11, Top(ftKB) Top(ND)(ftKB) Top Inc!(°) Item Des Com OW W. 6,038.9 4,848.1 44.44 PACKER BAKER CPH LINER TOP PACKER 4.830 GAS LIFT;2,966.7 "<"' 6,049.3 4,855.5 44.45 HANGER BAKER HMC LINER HANGER 4.920 II Casing Description OD(in) ID(in) -Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread I LINER 31/2 31/2 2.992 7,780.3 8,450.0 6,408.6 9.30 L-80 HYDRIL 511 Liner Details , Nominal ID" SURFACE;35.2-3,4556 to Top(069) Top(ND)(ftKB) Top Incl I') Item Des Com (in) 7,780.3 5,916.3 52.89 PACKER BAKER HR ZXP LINER TOP PACKER 5-1/2"x 3- 3.500 12"(Comm#H296-28-00579) GAS LIFT;4824 4Iii- 7,807.1' 5,932.5 52.36 HANGER BAKER HMC LINER HANGER 5-1/2"x 3-1/2"Comm 3.500 IF #H292-23-0212) it Tubing Strings ale ' g Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TUG)(...Wt(Ib/ft) Grade Top Connection GAS LIFT;6,021.6 TUBING 31/2 2992 37.5 7,801.1 5,928.8 9.30 L-80 EUE8RDMOD 11/ I Completion Details U r, ) E, Nominal ID :... Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 37.5 37.5 0.08 HANGER CIW GEN 3 TUBING HANGER 3.500 2,328.6 2,207.9 43.04 SAFETY VLV CAMCO TRMAXX-10E SAFETY VALVE(HWS-573) 2.810 6,781.0 5,326.4 52.64 SEAL ASSY BAKER SEAL ASSEMBLY 2.990 SEAL ASSY;6,781.0 7,747.8 5,896.7 53.14 NIPPLE CAMCO D NIPPLE W/NO GO PROFILE 2.750 , 1 7,789.1 5,921.6 52.83 SEAL ASSY BAKER SEAL ASSEMBLY(3 SETS) 2.990 GAS LIFT;7,004.4 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) _,, ,,,,,'..,,:,,g1t,,;,Niiili,11 Ill)ii Top(ND) Top Incl ®', Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,695.0 5,865.2 53.52 Packer SOS UPPER PARAGON II PACKER W 25.7' 12/29/2015 _ SPACER PIPE W SNAP LATCH GAS LIFT;7,705 6, 0- -0 Packer;7,695.0 7,725.0 5,883.1 53.31 Packer SOS LOWER PARAGON II PACKER 12/28/2015 il-, 8,025.0 6,074.4 43.02 Whipstock WEATHERFORD WHIPSTOCK(COULD NOT BE 4/18/2005 E PULLED) Packer;7,725.0 ;" 8,223.0 6,223.4 37.45 RETAINER B LINER HES EZ-DRILL SVB RETAINER 5/132005 2.690 NIPPLE;7,747.8 Perforations&Slots Shot Den SEAL ASSY;7,789.1 - Top(ND) Btm(TVD) (shots/f Top(ftKB) etm(ftKB) (ftKB) (ftKB) Zone Date 0 Type Com 'l 7,884.0 7,886.0 5,981.0 5,982.3 5/18/2005 4.0 (PERF Shot TBG punch holes r �,I (9) ` 7,886.0 7,888.0 5,982.3 5,983.5 5/13/2005 4.0 (PERF Shot TBG punch holes (9) 8,147.0 8,157.0 6,164.5 6,172.0 A-3,3H-14B 10/7/2005 6.0 APERF 2.5"PJ 2506,60 deg phase 8,172.0 8,182.0 6,183.5 6,191.2 A-2,3H-14B 8/9/2005 6.0 APERF 2.5"HSD,60 deg phase IPERF;7,884.0-7,886.0 I 8,182.0 8,187.0 6,191.2 6,195.1 A-2,3H-14B 8/9/2005 6.0 APERF 2.5"HSD,60 deg phase IPERF;7,886.0-7,888.0 ' 8,212.0 8,222.0 6,214.7 6,222.6 A-1,3H-14B 10/7/2005 6.0 APERF 2.5"PJ 2506,60 deg phase ' Stimulations&Treatments ,, I;i lii1 III" I,.. SCAB LINER;6,0389-7,925.0 Min Top Max Btm Depth Depth Top(TVD) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com ' 8,172.0 8,187.0 6,183.5 6,195.1 FRAC 8/28/2005 A-SAND FRAC-132,000#16/20 CARBOLITE Whipstock;8,025.0, Mandrel Inserts Window L4;8,016.08.026.0 l . St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com 1' 2,966.7 2,661.2 CAMCO KBUG- 1 GAS LIFT GLV BK 0.156 1,279.0 2/25/2015 7:30 APERF;8,147.0-8,157.0 = M APERF;8,172.08,182.0, 2 4,824.4 3,976.8 CAMCO KBUG- 1 GAS LIFT GLV BK 0.156 1,278.0 2/252015 4:00 FRAC;8,172.0 APERF;8,182.08,187.0 ' 3 6,021.6 4,835.8 CAMCO KBUG- 1 GAS LIFT OV BK 0.250 0.0 2/25/2015 6:00 M APERF;8,212.08,222.0 4 7,004.4 5,460.7 CAMCO KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 12/20/2015 12:30, 9 EXT PRODUCTION;330-8220.2 4k- s PKG 5 7,705.6 5,871.5 CAMCO KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 1/11/2015 Ext Pkg RETAINER;8.223.0 9 4:30 0 I-I Notes:General&Safety (i lfl .,,d,,,,',!1: / P *'l End Date Annotation { h 9/16/1999 NOTE:WAIVERED WELL:IA x OA COMMUNICATION I.. 4/21/2005 NOTE:WELL SIDETRACKED FOR SECOND TIME '1 I 1/22/2006 NOTE:3H-14BL4*'ONLY ACCESSIBLE LEG" LINER 3 1/2;7,780.38.450.0 SLOTS;8,243.0-9,499.0 1 Liner L4;8,040.0-9,532.0 M KUP PROD 3H-14B C - 1llionocc) ps Y Alaska,inc. C(rncol'hdli, ...•• 3H-148,12/30/2015 4.05.55 PM Vertical schematic(actual) i' Notes:General&Safety t End Date Annotation HANGER;37.511'x.` 1/22)2006 NOTE 3H-14BL1(OPEN HOLE PILOT HOLE-PLUGGED OFF) ,, 1/22/2006 NOTE:MULTI-LATERAL WELL:3H-14B/3H-14BL1/3H-14BL2/3H-14BL3/31-1-14BL4 2/28/2006 NOTE:CHEMICAL CUT 3H-14BL4 LINER TOP DOWN TO 8040'CLEAR 31-1-14B LINER 4 1/4/2011 NOTE:View Schematic w/Alaska Schematic9.0 CONDUCTOR,360-1150 1 3/1/2011 NOTE:"TUBING COMPONENT DEPTHS QUESTIONABLE**TALLY/DETAIL SHEETS VARY SAFETY VLV;2328.6p!` II GAS LIFT;2,966.7 1:-.. ISURFACE;35.2-3,455.6 ' R GAS LIFT;4,824.4 .x ; II 1 GAS LIFT;6,021.6 ', " SEAL ASSY;6,781.0 Z. GAS LIFT;7,004.4 'It',,a it I m'ii ist GAS LIFT;7,705.6, `V Packer;7,695.0 I'4i �-1[ajj1 '1I Packer;7,725.0 - NIPPLE;7,747.8 - SEAL ASSY,7,789.1 l 11....."'' ;11 (PERF;7,884.0-7,886.0 IPERF;7,886.0.7,888.0 I SCAB LINER;6,038.9-7,925.0 Whipstock;8,025.0.,. Window L4;8,016.0-8,026.0 APERF;8,147.0-8,157.0 APERF;8,172.08,18201 E 3 FRAC;8,172.0 APERF;8,182.0.8,1870 APERF;8,212.08,222.0 — PRODUCTION;33.0.8,220.2 44— d RETAINER;8,223.0 Mm 11u LINER 31/2;7,780.38,450.0 SLOTS;8,243.09,499.0 Liner L4,8,040.0-9,532.0 P-TZ7 2-o5 —b Z / • • Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, December 09, 2015 4:03 PM To: 'NSK Problem Well Supv' Subject: RE: 3H-14B Production Test (PTD 205-021) Update 5 Dec 15 Dusty, 10 day production test is approved as outlined below. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission AUGscONEQ 1 9 2016 U 6 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepoaa.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepo@alaska.gov From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, December 07, 2015 8:33 AM To: Loepp, Victoria T(DOA) Subject: RE: 3H-14B Production Test(PTD 205-021) Update 5 Dec 15 Victoria, Thank you for the quick reply, attached is the well bore schematic for 3H-14B. Cheers, Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 AWELLS TEAM comaphiips From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, December 07, 2015 8:29 AM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: 3H-14B Production Test(PTD 205-021) Update 5 Dec 15 • • Dusty, Please send a wellbore schematic. Thanx, Victoria From: NSK Problem Well Supv [mailto:n1617@conocophillips.con ] Sent: Saturday, December 05, 2015 12:50 PM To: Loepp, Victoria T(DOA) Cc: Senden, R. Tyler Subject: RE: 3H-14B Production Test(PTD 205-021) Update 5 Dec 15 Victoria- This email is to serve as an update on the production test in which was proposed and approved for 3H-14B (PTD 205- 021). Originally CPAI's intentions were to pull the whip stock to investigate the production capabilities of the isolated A sand perforations to provide information for the future use of this well. Most recently the attempts to pull the whipstock have proven unsuccessful. However,after the tubing patch,which was set over the existing TxIA communication,was pulled, CPAI was informed that the lower shear out sub had not properly sheared and was still intact within the patch's lower packer assembly. This type of failure would cause an obstruction within the production tubing and is potentially the cause of the inability to produce from the laterals above the whipstock. CPAI is proposing to continue with a 10 day production test with known TxIA communication to verify that failed shear out sub was indeed the obstruction causing the failure to produce from the exposed perforations. If production capabilities from the laterals above the whipstock are re-confirmed, a tubing patch will be re-set over the known TxIA communication and the proper follow up procedure for continued production will ensue. If the production test proves the inability of production from the exposed perforations the well will be further reviewed for future use. Please feel free to contact Jan or myself if you have any questions or would like to discuss the change in the production period plans. Cheers, Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 iipWELLS TEAM CAnocat,;flip s From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@>alaska.gov] Sent: Wednesday, September 16, 2015 4:02 PM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: 3H-14B Production Test (PTD 205-021) Jan, Approval is granted to conduct no more than a 10 day production test of the A Sands with existing leaks in the tubing. Thanx, Victoria 2 • S Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCia laska.qov CONFIDENTIALITY NOTICE: [his e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoa@alaska.gov From: NSK Problem Well Supv [mailto:n16170conocophillips.com] Sent: Tuesday, September 15, 2015 4:48 PM To: Loepp, Victoria T(DOA) Subject: FW: 3H-14B Production Test. Victoria, Below is a forwarded email with synopsis from the wells engineer regarding 3H-14B which we discussed earlier today. As per our conversation CPAI request the AOGCC allow the said well to be produced for testing purposes for a maximum of 10 days with known TxIA communication to facilitate evaluation of the plan forward for this well. Please let me know if you have any questions or need further information. Attached is a copy of the wellbore schematic. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7126 Pager(907)659-7000 pgr. 123 4IVELLS TEAM Oanocalhillips From: Brown, H Marshall Sent: Tuesday, September 15, 2015 3:20 PM To: Byrne, Jan (ASRC Energy Services) Subject: 3H-14B Production Test. Jan, Well 3H-14B was originally drilled in 1987. In 2005, 3H-14B was worked over by coiled tubing adding 3 laterals. In the process of coiled tubing drilling the 3H-14B well, a whipstock and packer were set inside our production casing to engage a kick off point. The whipstock was set above our A sand perforations isolating the A sands from our production tubing. At the time of this isolation,the A sand perforations were producing+/- 150 BOPD. 3 • S In 2014, 3H-14B was shut in for a fill clean out job. Once the clean out was complete,we were unable to bring the well back online.After many unsuccessful attempts to get the well to flow,the well was shut in. While attempting to get the well online,we found leaks in our production tubing. In February of 2015 we attempted to fix the leaking production tubing with a patch, our attempt was unsuccessful and the patch was pulled in August of 2015. Our new path forward is to attempt to regain the production lost by the isolation of the A sand perforations during the installation of the whipstock in 2000. We expect the A sand perforations to give us the capability to flow this well and bring it back online, as it is currently incapable. We are requesting a production test for 3H-14B through our leaking tubing. We believe the leaks are able to be fixed, however; we cannot justify spending more money to fix this well/tubing without knowing if the A sands are still capable of flowing. Since the A sand perforations have been shut in since 2000,we do not know if the current production capabilities are economically viable. Please let me know if you have any other questions. Regards, H. Marshall Brown Wells Engineer ConocoPhillips Alaska, Inc. ATO-1842 Office: 907.265.6218 Mobile: 281.732.5844 H.Marshall.Brown@ConocoPhillips.com 4 Pro 2e — oz/ • Loepp, Victoria T (DOA) From: Loepp, Victoria T(DOA) Sent: Wednesday, September 16, 2015 4:02 PM To: NSK Problem Well Supv Subject: RE: 3H-14B Production Test (PTD 205-021) Follow Up Flag: Follow up Flag Status: Flagged Jan, Approval is granted to conduct no more than a 10 day production test of the A Sands with existing leaks in the tubing. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 SCAMtiED AUG 1 61016 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppt alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: NSK Problem Well Supv [nailto:n1617(aconocophillips.com] Sent:Tuesday, September 15, 2015 4:48 PM To: Loepp, Victoria T(DOA) Subject: FW: 3H-14B Production Test. Victoria, Below is a forwarded email with synopsis from the wells engineer regarding 3H-14B which we discussed earlier today. As per our conversation CPAI request the AOGCC allow the said well to be produced for testing purposes for a maximum of 10 days with known TxIA communication to facilitate evaluation of the plan forward for this well. Please let me know if you have any questions or need further information. Attached is a copy of the wellbore schematic. Regards, Jan Byrne/Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7126 1 41110 • Pager(907) 659-7000 pgr. 123 WELLS TEAM ConocoPhillips From: Brown, H Marshall Sent: Tuesday, September 15, 2015 3:20 PM To: Byrne, Jan (ASRC Energy Services) Subject: 3H-14B Production Test. Jan, Well 3H-14B was originally drilled in 1987. In 2005, 3H-14B was worked over by coiled tubing adding 3 laterals. In the process of coiled tubing drilling the 3H-14B well, a whipstock and packer were set inside our production casing to engage a kick off point. The whipstock was set above our A sand perforations isolating the A sands from our production tubing. At the time of this isolation,the A sand perforations were producing+/- 150 BOPD. In 2014, 3H-14B was shut in for a fill clean out job. Once the clean out was complete,we were unable to bring the well back online. After many unsuccessful attempts to get the well to flow,the well was shut in. While attempting to get the well online,we found leaks in our production tubing. In February of 2015 we attempted to fix the leaking production tubing with a patch, our attempt was unsuccessful and the patch was pulled in August of 2015. Our new path forward is to attempt to regain the production lost by the isolation of the A sand perforations during the installation of the whipstock in 2000. We expect the A sand perforations to give us the capability to flow this well and bring it back online, as it is currently incapable. We are requesting a production test for 3H-14B through our leaking tubing. We believe the leaks are able to be fixed, however; we cannot justify spending more money to fix this well/tubing without knowing if the A sands are still capable of flowing. Since the A sand perforations have been shut in since 2000,we do not know if the current production capabilities are economically viable. Please let me know if you have any other questions. Regards, H. Marshall Brown Wells Engineer ConocoPhillips Alaska, Inc. ATO-1842 Office: 907.265.6218 Mobile: 281.732.5844 H.Marsnall.Brown@ConocoPhillips.com ConocoPhillips.com 2 STATE OF ALASKA - , AL __KA OIL AND GAS CONSERVATION COIb,. SSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate r Other IF kip '7 Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r.% Exploratory r 205-021 3.Address 6 API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20092-02 7.Property Designation(Lease Number) 8.Well Name and Number: ADL0025531 14,17...V 3H-14B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8450 feet Plugs(measured) None true vertical 6409 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 6781, 7694,7748,7789 true vertical 0 feet (true vertical) 5326, 5865, 5897, 5922 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 0 0 0 SURFACE 3420 12 3456 0 0 0 SCAB LINER 1886 6.12 7925 0 0 0 PRODUCTION 8187 7 8220 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 7884'-8222' True Vertical Depth: 5981'-6223' scANNED v','- t 4 RECEIVED Tubing(size,grade,MD,and ND) 3.5, L-80, 7789 MD, 5922 TVD MAR 0 9 2015 Packers&SSSV(type,MD,and TVD) SEAL ASSY-BAKER SEAL ASSEMBLY @ 6781 MD and 5326 TVD AOGCC PATCH-3.5"PARAGON II PATCH WITH SHEAR OUT SUB @ 7694 MD and 5865 TVD NIPPLE-CAMCO D NIPPLE W/NO GO PROFILE @ 7748 MD and 5897 TVD SEAL ASSY-BAKER SEAL ASSEMBLY(3 SETS)@ 7789 MD and 5922 TVD SAFETY VLV-CAMCO TRMAXX-10E SAFETY VALVE (HWS-573)@ 2329 MD and 2208 TVD 12.Stimulation or cement squeeze summary. Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - Subsequent to operation 14.Attachments 15.Well Class after work. Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil IF Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND 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 N/A or Sundry Number required here Contact Jan Byrne/Dusty Freeborn Email n1617@cop.com Printed Name Jan Byrne Title Problem Wells Supervisor Signature y,_ Phone:659-7126 Date: 3- s- I Form 10-404 Revised 10/2012 VTL 3//'1 /-s Submit ininal Only /,t it// 3-. RBDMS<A1 MAR 1 1 2015 RECEIVED ConocoPhillips MAR 0 9 2015 Alaska /40 GCC BOX 100360 OG C ANCHORAGE,ALASKA 99510-0360 March 5th, 2015 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 3H-14B PTD 205-021 tubing patch repair. Please call Dusty Freeborn or myself at 659-7126 or Brent Rogers/Kelly Lyons at 659- 7224 if you have any questions. Sincerely, Jan Byrne Problem Wells Supervisor Attachments Name of Recipient Page 2 of 2 03/05/15 Delete the section break above to remove the second page • 3H-14B DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary A leak was located in GLM#5 at 7706'. A patch was set to repair the TxIA communication. Attached below is the work completed to set and test the patch. 02/17/15 CONT FROM 2/14/15 SET LOWER 3 1/2" PARAGON II PACKER W/SHEAR SUB (5' OAL) @ 7724' RKB. LRS PERFORMED CMIT-TxIA TO 2500#. PASSED. SET UPPER 3 1/2" PARAGON II PACKER AND SPACER PIPE (32' OAL) @ 7694' RKB. (PATCH IS 30' MID ELEMENT TO MID ELEMENT, 1.63" ID, 2.72"OD) 02/20/15 PULLED ST#4 GLV& SET DMY GLV W/EXT PACKING. LRS PERFORMED MIT-T TO 2500#. FAILED. PULLED ST#4 DMY GLV& SET DMY GLV W/HIGH SEAL-ABILITY PACKING. LRS PERFORMED MIT-T TO 2500#. PASSED. MITT pass after set high seal-ability pkg: preT10=0/0/112, initial=2500/150/111, 15min=2400/150/110, 30min=2360/150/110"* 3H-14B • DESCRIPTION OF WORK COMPLETED SUMMARY KUP PROD 3H-14B ConocoPhillips " Well Attributes Max Angle&MD TD Alaska,Inc. Wel!boreAPuuWI Field Name Wellbore Status Incl(") MD(ftKB) Act Btm(ftKB) ,,eo'ei„g,p, 501032009202 KUPARUK RIVER UNIT PROD 55.50 7,048.39 8,450.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) "Rig Release Date 39-148,1/18/20157.49.18 AM SSSV:TRDP 140 11/12/2013 Last WO: 6/262005 42.01 12/14/1987 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ------------- ---- -Last Tag:SLM 7,990.0 1/25/2014 Rev Reason:SET WRP 8 CATCHER,GLV C/O hipshkf 1/18/2015 7 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread HANGER.3,s CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ItallffillIBLAIMMILIMILLIIIMIIMLLIMUMI oosurkia _ruumuu tlar SURFACE 9 5/8 8.921 35.2 3,455.6 3,002.4 36.00 J-55 BTC Casing Description SOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WULen(L..Grade Top Thread - ^^2"'^PRODUCTION 7 6.276 33.0 8,220.2 6,221.2 26.00 J-55 BTC I-- Casing Description OD(in) ID(in) Top(ftKB) ,Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;36.0-115.0 A Window L4 7 6.000 8,016.0 8,026.0 6,075.2 9.30 ,_j Casing Description OD(in) -ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SCAB LINER 5 1/2 4.950 6,038.9 7,925.0 6,007.4 15.50 L-80 HYDRIL511 SAFETY VLV;2.328.13-11M Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) "- 6,038.9 4,848.1 44.44 PACKER BAKER CPH LINER TOP PACKER ' 4.830 GAS LIFT;2,966.7.--ILA 6049.3' 4,855.5 44.45 HANGER BAKER HMC LINER HANGER 4.920 I-_ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WULen(I...Grade rep Thread LINER 31/2 I 31/21 2.992 7,780.31 8450.01 6408.61 9.301 L-80 I HYDRIL511 Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Corn (in) SURFACE;3.5.23,455.6 rk' 7,780.3 5,916.3 52.89 PACKER BAKER HR ZXP LINER TOP PACKER 5-1/2"x 3- 3.500 ,_ 12"(Comm#H296-28-00579) GAS LIFT;4,824.4 7,807.1 5,932.5 52.36 HANGER "BAKER HMC LINER HANGER 5-1/2"x 3-12"Comm 3.500 #H292-23-0212) i__ Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Iblft) Grade Top Connection GAS LIFT;6,021.6 TUBING 31/2 2.992 37.5 7,801.1 5,928.8 9.30 L-80 EUE8RDMOD Completion Details Nominal ID ® Top(fa(B) Top(TVD)(ftKB) Top net(") Item Des Com lin) 1 37.5 37.5 0.08 HANGER CIW GEN 3 TUBING HANGER 3.500 2,328.6 2,207.9 43.04 SAFETY VLV CAMCO TRMAXX-10E SAFETY VALVE(HWS-573) 2.810 6,781.0 5,326.4 52.64 SEAL ASSY BAKER SEAL ASSEMBLY 2.990 SEAL ASSY;6,791.0 _ 7,747.8 5,896.7 53.14 NIPPLE CAMCO D NIPPLE W/NO GO PROFILE 2.750 7,789.1 5,921.6 52.83 SEA) ASSY BAKER SEAL ASSEMBLY(3 SETS) 2.990 GAS LIFT:7.004.4 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) _.1 Top(ND) Top Inc) Top(ttKB) (ftKB) I') Des Com Run Date ID;in) '-'1..i 7,813.6 5,936.5 52.12 CATCHER 2.70"JUNK CATCHER 1/11/2015 GAS LIFT;7,7056 7,818.0 • 5,939.2 51.95 PLUG 2.69"WEATHERFORD WRP 1/102015 0.000 8,025.0 6,074.4 4302'Whipstock WEATHERFORD WHIPSTOCK(COULD NOT BE 4/182005 PULLED) NIPPLE;7,74.7.8 8223.0 6,223.4 37.45 RETAINER B LINER HES EZ-DRILL SVB RETAINER 5/13/2005 2.690 Perforations&Slots SEAL ASSY.7789.1 I Shot Dens Top(TVD) Bim(TVD) (shots/I Top IftKB) Btm(ftKB) I (Po(B) (ftKB) Zone Date t) Type Com 7.884.0 7,886.0 5,981.0 5,982.3 5/18/2005 4.0 IPERF Shot TBG punch holes CATCHER;7.813.6 (9) 7,886.0 7,888.0' 5,982.3 5,983.5" 5/132005 4.0 IPERF Shot TBG punch holes PLUG;7,818.0 (9) 8,147.0 8,157.0 6,164.5 6,172.0'A-3,3H-14B 10/7/2005 6.0 APERF 2.5"PJ 2506,60 deg phase 8,172.0 8,182.0 6,183.5 6,191.2 A-2,3H-14B 8/92005 6.0 APERF 2.5"HSD,60 deg phase IPERF,7,884 0-7886 o 8,182.0 8,187.0 6,191.2 6,195.1 A-2,3H-14B 8/92005 6.0 APERF 2.5"HSD,60 deg phase IPERF,7,886.0-7.888 0 8,212.0 8,222.0 6,214.7 6,222.6 A-1,3H-14B 10/7/2005 6.0 APERF 2.5"PJ 2506,60 deg phase Stimulations&Treatments Min Top Max Btm SCAB LINER.6.0389-7,925.0 Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 8,172.0' 8,187.0 6,183.5 6,195.1 FRAC 8/28/2005 A-SAND FRAC-132,000816/20 CARBOLITE Whlpstk;8,0250 -' Mandrel Inserts Window L4;8.016.oc08,0260 St crit on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model 01)(In) Sew Type Type (In) (psi) Run Date Com 1' 2,966.7 2,661.2 CAMCO KBUG- 1 GAS LIFT GLV BK 0.156 1,328.0 1/28/2006 7:30 _ M APERF;e.147.08.157.0 - - 2 4,824.4 3,9768 CAMCO KBUG- 1 GAS LIFT GLV BK 0.188 1,353.0 1/28/2006 4:00 APERF;8,172.08,182.0, �I M FRAC;8.172.0 J 3 6,021.6 4,835.8 CAMCO KBUG- 1 GAS LIFT GLV BK 0.188 1,338.0 1/28/2006 6:00 APERF;8.182.08,1878 M 4 7,004.4 5,460.7 CAMCO KBG-2- 1 GAS LIFT GLV BTM 0250 1,429.0 128/2006 12:30 APERF;8,212.682220 _ _ 9 PRODUCTION;33.0-8220.2 a.- _. 5 7,705.6 5,871.5 CAMCO KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 1/11/2015 Ext • 9 Pkg 4:30 1 RETAINER;8,223.0illi ?Otes:General&Safety End Date Annotation _ 9/16/1999 NOTE:WAIVERED WELL:IA x OA COMMUNICATION ija" 421/2005 NOTE:WELL SIDETRACKED FOR SECOND TIME - 1/22/2006 NOTE 3H-14BL4"'ONLY ACCESSIBLE LEG" 122/2006 NOTE:3H-14BL1(OPEN HOLE PILOT HOLE-PLUGGED OFF) LINER 3112;7.780.38,450.0 SLOTS;8,243.69,499.0 Liner L4;8.040.69,532.0 i KUP PROD 3H-14B ConocoPhillips Alaska,Inc. f rirrrilvihT 31-1-140,1/182015 7:49:19 AM Vertical schematic(actual) Notes:General&Safety End Date Annotation HANGER 375 1/22/2006 NOTE:MULTI-LATERAL WELL 3H-14B/3H-14BL1/3H-14BL2/3H-14BL3/3H-14BL4 �' — 228/2006 NOTE:CHEMICAL CUT 3H-14BL4 LINER TOP DOWN TO 8040'CLEAR 3H-14B LINER 1/4/2011 NOTE:View Schematic w/Alaska Schematic9.0 3/1/2011 NOTE"TUBING COMPONENT DEPTHS QUESTIONABLE"TALLY/DETAIL SHEETS VARY CONDUCTOR;36.0-115.0-4 • SAFETY VLV;2.328.6 (_ " GAS LIFT;2,966.7 SURFACE;35.23455 6— GAS LIFT,4,824.4 . I B GAS LIFT;6,021.6 g,- B • SEAL ASSY;6,781.0 GAS LIFT;7,004.4 GAS LIFT;7,705 6 NIPPLE;7,7478 SEAL ASSY;7,789.1 CATCHER;7,813.6 +i`! PLUG;7,818.0 (PERF;7,884.0.7,886.0 I IPERF;7,886 0-7.888.0 II SCAB LINER;6.038.9-7,925.0 WNpatock;8,025.01 Window L4;8,016.08,026.0 _ APERF;8,147.08.157.0 APERF;8.172.08,182.0, FRAC;8,172.0 APERF;8,182.0-8,187.0 APERF;8,212.0-8,222.0 _ _ PRODUCTION;33.0-8,220.2- — — RETAINER;8,223.0 lilt LINER 31/2;7,780.38,450.0, SLOTS;8,243.0.9,499.0 Lina(L4;8,040.0-9,532.0 �, · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ¿¿OS - ð~ 1 Well History File Identifier Organizing (done) D Two-sided ""1111111 III" III D Rescan Needed 1111111111111111111 RESCAN ~ Color Items: ¢GreYSCale Items: D Poor Quality Originals: DI~TAL DATA \.Ø'Diskettes, No. , D Other, NolType: OVERSIZED (Scannable) o Maps: D Other Items Scannable by a Large Scanner D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: Date to/ ~C¡/[)7 o Other:: BY: ~ 151 rtlP 111111111/1111 "III Project Proofing BY: ~ Date to I rlfJ / (j 7 .d- ft;() 151 YVlP BY: Date: Scanning Preparation Production Scanning 111111111/1111 "III Stage 1 Page Count from Scanned File: 'be> (Count does include cover sheet) /YES Stage 1 Page Count Matches Number in Scanning prefaration: ~ Date: Co/:J-1/07 If NO in stage 1, page(s) discrepancies were found: NO IS/Wl P NO BY: YES BY: Maria Date: 151 1111/111111I111111/ Scanning is complete at this point unless rescanning is required. ReScanned 111111111/1111 "III BY: Maria Date: 151 Comments about this file: Quality Checked "'"1111111"11111 10/6/2005 Well History File Cover Page.doc ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 'M~9~.D~-~. ~ ~E~E~lJE~ APR ~ ~ ~ 2414 ~I1a~~GasCons.~~ A ~,d~/o~ ~ ..r ~3 3~ Dear Mr. Dan Seaniount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRin. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space.. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 2 and 21, 2010. The corrosion inhibitor/sealant was pumped March 27, 28 and 29, 2010. The attached spreadsheet presents the well name, trop of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, MJ L veland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/31/10 3A. 3B_ 3C_ 3G_ 3H_ 31.31.3M_ 3A & 3R PAI']'_c Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-02 ' 50029214310000 1852050 Surface Na 26" n/a 4.25 3/292010 3A-04 50029214330000 1852070 SF n/a 26" n/a 4.25 3292010 3A-07 50029214440000 1852230 SF n/a 25" n/a 4.25 329/2010 3A-16 50029214920000 1852840 SF n/a 23" n/a 3.4 3292010 3B-10 50029213660000 1851140 6'6" n/a 6'6" Na 25.5 3282010 3C-11 50029213570000 1851020 SF Na 25" n/a 4.25 3/272010 3G-08 50103201280000 1900650 SF 0.65 27" 32/10 5.52 3/282010 3G-09 50103201290000 1900670 SF 0.60 22" 3/2/10 4.67 3/282010 3G-22 50103201470000 1901420 SF Na 22" n/a 4.25 3/282010 3H-01 50103200840000 1871100 SF n/a 21" n/a 4.25 3/28/2010 3H-03 50103200850000 1871110 17" 0.40 8" 3/21/10 1.7 3/28/2010 3H-14B 50103200920200 2050210 SF Na 23" n/a 3.4 3292010 31-02 50029215150000 1853080 SF n/a 22" n/a 2.97 3292010 31-10 50029219340000 1890370 39' 3.50 24" 321/10 3.4 3/29/7010 3J-04 50029214000000 1851650 SF n/a 23" n/a 3.4 3282010 3J-14 50029214960000 1852880 SF n/a 25" n/a 4.67 3282010 3J-15 50029214970000 1852890 SF Na 22" n/a 3.4 328/2010 3M-05 50029217060000 1870250 SF n/a 21" n/a 3.4 3/292010 3M-07 50029217080000 1870270 SF n/a 22" n/a 4.25 329/2010 30-09 50029218250000 1880610 SF n/a 23" n/a 4.25 3/27/2010 30-16A 50029217960100 1880430 SF Na 22" n/a 3.52 3272010 3R-10A 50029222530100 1920310 SF n/a 21" n/a 4.25 3272010 3R-11 D 50029222480000 1920160 SF n/a 17" n/a 3.25 3/272010 3R-15 50029222580000 1920340 SF n/a 24" n/a 3.82 327/2010 3R-19 50029222690000 1920460 1" n/a 21" n/a 5.1 3/27/2010 3R-25 50029226220000 1951810 SF n/a 21" n/a 5.52 327/2010 • • _,~ MICROFILMED 03/01 /2008 DO NOT .PLACE -. ~~~ ~K. I^'~gZ."~~r. p - ~. ~rz~ ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFichelCvrPgs_InsertslMicrofilm Marker.doc J 3 JI.ta.t~ DATA SUBMITTAL COMPLIANCE REPORT 5/31/2007 Permit to Drill 2050210 Well Name/No. KUPARUK RIV UNIT 3H-14B Operator CONOCOPHILLlPS ALASKA INC )~ ~l'- API No. 50-103-20092-02-00 MD 8450 TVD 6409 Completion Date 5/13/2005 Completion Status 1-01L Current Status 1-01L UIC N ~._-----~~ -.------- REQUIRED INFORMATION Directional~ Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GRlRes, SCMT Well Log Information: (data taken from Logs Portion of Master Well Data Maint Name Interval Start Stop Interval e Log Log Run OH/ Scale Media No Start Stop CH Received Comments -----,--,------- -----1 6203 8450 Open 5/4/2005 IIFR I 6240 8450 Open 2/22/2006 ROP DGR EWR plus I Graphics I 5 Col 6846 8253 5/23/2005 CEMENT BOND I LOG.lSCMT-CB/PSP i 6176 8390 Open 6/10/2005 MWD-GRlEWR4/PWD I 6176 8390 Open 6/10/2005 MWD-GRlEWR4/PWD 6176 8450 Open 1/29/2007 LIS Veri, GR, ROP, FET w/Graphics -----.-J ~--~- Sample Set Sent Received Number Comments Log/ Electr Data Digital Dataset ~ Med/Frmt Number Name D Asc Directional Survey ~ C Lis 13686 Induction/Resistivity W Cement Evaluation ~D Lis 13162 Induction/Resistivity 13162 LIS Verification D C Las 14429 Induction/Resistivity L Well Cores/Samples Information: it ADDITIONAL INFORMATION Well Cored? -fG) Daily History Received? ~N f"ð'N Chips Received? -"I'-Ht""" Formation Tops Analysis Received? ...;!)X Comments: Permit to Drill 2050210 MD 8450 TVD 6409 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 5/31/2007 Well Name/No. KUPARUK RIV UNIT 3H-14B Operator CONOCOPHILLlPS ALASKA INC Completion Date 5/13/2005 Completion Status 1-01L Current Status 1-01L Date: API No. 50-103-20092-02-00 UIC N e e . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cornrn. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14, 2006 RE: MWD Formation Evaluation Logs: IB-15A, lC-21_Ll_L2_L3, ID-28_Ll, IF-01A, 3F-19A,3H-14B. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 IB-lSA: 90J.../-;)s-G:, ft 1'-!¿../:!:D Digital Log Images: 1 CD Rom 50-029-23465-01 ~ ICd. dD-S--034¡9öS--/DO¡ 90S -101 190 - lC-2l_Ll_L2_L3: jt../L/?/-f 1443{) 14LI3Io I'ILIQ?- Digital Log Images: 1 CD Rom 50-029-23253-00, 60, 61, 62 ID-28 Ll: Digital Log Images: 50-029-23237-00, 60 ;)ó<l-g3"? /"/43d f)O£( -.Q31r" /l.../¿/33 1 CD Rom IF-OlA: dO~ -Og::7 ~ ¡'-ILl!]?) Digital Log Images: 50-029-20889-01 1 CD Rom 3F-19A: f)D'-I-ÓICo p-/L/'-I3/ Digital Log Images: 50-029-22680-0 I 1 CD Rom 3H-14B: 066 -Oéil 1t 14LIêP/ Digital Log Images: 50-103-20092-02 1 CD Rom . . WELL LOG TRANSMITTAL doE)"O~\ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16,2006 ~ 'òUJßtp RE: MWD Formation Evaluation Logs 3H-14B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 3H-14B: LAS Data & Digital Log hnages: 50-103-203092-02 1 CD Rom ~Dm4ì 8'1 ()0/ [Ífl . . Mike Mooney Wells Group Team Leader Drilling & Wells ConocJPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 October 26, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3H-14B (APD 205-021) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforation activity on the Kuparuk well 3H-14B. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, 4, Jj ðÞ~~) M. Moonèy Wells Group Team Leader CPAI Drilling and Wells MM/skad . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS forT ,,~. 0 'J '1íJC-: . """ !ø ð [IJ1 J 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 ¡ ;~¡Ej $ k [I 'j'þ~" lliil f' Ú ._'~f-:1,~ Lrj<~: " ,""0""', {'" Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time ExtêftØðlJía6.å Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 205-021 / 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20092-02 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 39' 3H-14B 8. Property Designation: 10. Field/Pool(s): ADL 25531, ALK 2657 Kuparuk River Field I Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8450' feet true vertical 6409' feet Plugs (measured) retainer @ 8223' Effective Depth measured 8223' feet Junk (measured) true vertical 6224' feet Casing Length Size MD rvD Burst Collapse Structural CONDUCTOR 80' 16" 115' 115' SURFACE 3414' 9-5/8" 3455' 3001' PRODUCTION 5998' 7" 6039' 4847' LINER 1886' 5-1/2" 7925' 6007' LINER 660' 3-1/2" 8440' 6400' Perforation depth: Measured depth: 7884'-7888',8147'-8157',8172'-8187', 8212'-8222', 8250'-8254' true vertical depth: 5981'-5984',6165'-6172',6184'-6196', 6215'-6223', 6245'-6248' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7780' MD. Packers & SSSV (type & measured depth) Baker CPH liner top pkr, Baker 'HR' SZP liner @ 6039', 7780' SSSV= Cameo TRMA-10E @ 2329' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable RBDMS BFt 0 C1 '2 ~ 2005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 261 1039 55 -- 153 Subsequent to operation 255 1370 72 -- 153 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 GlNJ 0 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: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Leader ~ Signature 1M /l¡ð7lMh~\ Phone Date . /d z 7/J.s Prenared b~' "'horon AI/sun-Drake 263-4612 { , ( --/ (1 Rl G f\11 Form 10-404 Revised 04/2004 '..- ., Submit Original Only !,' """~~" : \ L . 3H-148 Well Events Summary . Date Summary 10107/05 PERFORATED 8147'-8157' & 8212'-8222' WITH 2.5" HSD GUNS, 6 SPF POWERJET. e ConocJ'Phillips -- Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 September 9, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 3H-148 (205-021/305-010) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent rig operations of the Kuparuk well 3H-148. If you have any questions regarding this matter, please contact me at 265-6830 or Jake Flora at 265-6040. Sincerely, ~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT Iskad tt STATEOFA~S~ tt ALAS~ OIL AND GAS CONSERVATION COMMISSION ; .. WELL COMPLETION OR RECOMPLETION REPORT. AND LOG· 1a. Well Status: Oil [2] Gas U Plugged U Abandoned U Suspended U WAG 0 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development [2] Exploratory ·lSj GINJ 0 WINJ 0 WDSPl 0 No. of Completions _ Other - Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp.. Susp., ~~ 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: " .;;-., 205-0211 305-010 3. Address: 6. Date Spudded: ¡;~.¡,Þ$ 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 April 5, 2005 - 'tf.1 50-103-20092-02 4a. location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1157' FNL, 281' FWL, Sec.12, T12N, R8E, UM April 15, 2005 .> 3H-14B At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s): Horizon: 1430' FSL, 1230' FEL, Sec. 1, T12N, R8E, UM 41' RKB, Pad 39' Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): Kuparuk Oil Pool 1530' FSL, 984' FEL, Sec. 1, T12N, R8E, UM 8223' MD 1 6224' rvD 4b. location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): , 16. Property Designation: Surface: x- 498655 - y- 6000500 ' Zone· 4 I 8450' MD 1 6409' rvD ADL 25531 TPI: x- 502422 y- 6003087 Zone-4 11. Depth where SSSV set: 17. land Use Permit: Total Depth: x- 502669 ... y- 6003187 .- Zone- 4 2329' ALK 2657 18. Directional Survey: Yes [2] NoU 19. Water Depth. if Offshore: 20. Thickness of N/A feet MSL Permafrost: 2451' MD 21. logs Run: -r/ÍdUdò'J ; kZ2.7 'mÞ I c..¡CJZ32 /-¡-I,Z> GRlRes, SCMT ,-6b C;. ,,/. c> 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD PUllED CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE 16" 62.5# H-40 Surf. 115' Surf. 115' 24" 200 sx AS I 9-5/8" 36# J-55 Surf. 3455' Surf. 3001' 12.25" 1350 sx AS 111,400 sx Class G 7" 26# J-55 Surf. 6039' Surf. 4847' 8.5" 800 sx Class G, 175 sx AS I 5.5" 15.5# L-80 6039' 7925' 4847' 6007' 6.75" 201 sx Class G 3.5" 9.3# L-80 7780' 8440' 5916' 6400' 4.75" 17 bbls 15.8 Class G HES EZ retainer @ 8223' 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 3.5" 7771' 6039' 1 7780' 7884'-7888' MD 5981 '-5984' rvD 4 spf I 8172' - 8187' MD 6184'· 6196' rvD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8250' - 8254' MD 6245'- 6248' rvD 6 spf DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 8172' - 8187' 132,000# 16/20 Carbolite 26. PRODUCTION TEST Date First Production Method of Operation (Flowing. gas lift, etc.) September 3, 2005 Gas Lift Oil Date of Test Hours Tested Production for Oll-BBl GAS-MCF WATER-BBl CHOKE SIZE GAS-OIL RATIO 9/3/2005 14.5 Test Period --> 434 218 62 176 Bean 563 Flow Tubing Casing Pressure Calculated Oll-BBl GAS-MCF WATER-BBl Oil GRAVITY -API (corr) press. 160 psi not available 24-Hour Rate -> 722 407 46 21.6° , 27. CORE DATA Brief description of lithology. porosity, fractures. apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". p----- CúM~,;J'~ i UAn..., RBDMS BFl SEP 1 6 2005 ...i.:..t3 ' C::f NONE \It:C,qi::D l~~__.~ Form 10-407 Revised 12/2003 o R \ G \ N A L CONTINUED ON REVERSE 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD rvD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 3H-14B Top C4 8018' 6070' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Na Signature Title: Greater KUDaruk Area Drillina Team Leader Phone '-65" 6-33ð Date 4/or 10S" Prepared by Sharon Allsup-Drake 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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13:00 - 14:30 14:30 - 15:30 15:30 - 19:00 19:00 - 21 :30 3/30/2005 21 :30 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 04:30 04:30 - 06:00 06:00 - 10:00 10:00 - 12:00 12:00 - 14:00 14:00 - 18:00 18:00 - 00:00 3/31/2005 00:00 - 02:00 02:00 - 02:30 02:30 - 04:00 04:00 - 06:00 06:00 - 09:30 09:30 - 10:00 10:00 - 15:30 15:30 - 20:30 4/1/2005 20:30 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 03:30 03:30 - 06:00 06:00 - 15:00 15:00 - 15:30 15:30 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 20:30 Rig accepted on 3H-14B @ 10:00 hrs 03/29/2005. Pull VR plug (IA) Rig up displacement tank, choke skid & hard line from tree to choke & tank. Note; OA has 50 psi on it. Rig up lubricator & pull BPV Test lines to 4000 psi. Blow down lines to tank. Rig up & test surface lines from pumps to tree. Test same to 1500 psi. Test good. DECOMP Displace diesel & seawater w/ seawater. Pump MI pipe clean wI seawater. Pump total of 450bbls. Monitor well static. RID lines to tree and companion flange. Install BPV. Nipple down tree. Nipple up riser & BOPE. NU 8' riser and l' spacer spools. Set BOPs and hook up kill line. Work on Bell nipple and adjusting same. Work on choke line leaks. NU BOPs and riser. Cut flowline extension. RU turnbuckles and make up fill line. DECOMP Change top set of pipe rams to 3-1/2". RU choke line extensions. Take BOP measurements. DECOMP Install upper flowline lid and seal. PU and set mouse hole. DECOMP PU 3-1/2" joint of tubing and screw into hanger. Fill stack and choke manifold. Test choke manifold, upper pipe rams, HCR, choke line. Leaks found below the rig floor in the choke line extension. Repair leaks and continue testing to 250 I 5000 psi. Attempt to body test BOPE and Choke manifold. Fix leaks on choke line and flange on stack/riser. Pull and inspect tubing test joint, and apply teflon tape to threads. RIH and screw test joint in. Test okay. DECOMP Test Top Pipe Rams and Choke Manifold (body test) to 250 psi & 5000psi. Hold test for 5 min. OK. Test Hydril to 250 psi & 3500 psi OK. Pull HP plug RlU GBR tongs & Tbg equipment, control line spooler Hold PJSM. MIU landing joint, back out LDS, Pull tubing hanger to floor. UD Tubing hanger. POOH laying down 3-1/2" IBT tubing. Continue POOH, LD SSSV. Recover 30 steel bands for control line. LD control line spooling unit. Continue POOH and LD 3-1/2" IBr tubung (193 joints out). NORM tested all joints. DECOMP Repair rig draworks. Brake coolant lines crossed. One 1-1/4" coolant line ruptured. Continue POOH with 3-1/2" tbg. Pulled 239 jts total + cutoff. RD tubing handling equip. Change out top and btm Rams, change saver sub die and guide on TD. Change Top & bottom rams, Saver sub & Bell guide on Top Drive. RlU to test BOPE, fill stack & choke manifold wI water. Test Blind Ram, lower pipe Rams, choke and kill valves, floor valves to 250 I 4,000 psi. Test Annular to 250 13,500 psi Test Koomey unit drawdown and high and low flowline. Test choke manifold valves 250 I 4,000 psi. HCR valve failed. Prep to replace. 0.50 WELLSR OTHR DECOMP Set Wear Bushing 1.50 WELLS~ PLGM DECOMP RU wireline equipment for running bridge plug. PJSM. 1.00 WELLS~ PLGM DECOMP RIH with 6.04" guage ring and junk basket to 6,450' md. 1.00 WELLS9 PLGM I DECOMP POOH with Guage ring and junk basket, LD same. Recovered 3 pieces j of teflon rings, 2_3" long. 1.50 WELLSl PLGM DECOMP I PU CIBP and wireline running assembly. 3H-14 3H-14 ROT - SIDETRACK doyonc@ppco.com Doyon 15 1.00 WELCT 1.00 WELCT 0.50 WELCT 4.50 WELCT 1.50 WELCT 4.00 WELCT 2.00 WELLS PULD 1.00 RIGMNT RGRP 0.50 WELCT BOPE 3.50 WELCTL NUND 2.50 WELCT BOPE 9.00 WELCT BOPE Start: 3/29/2005 Rig Release: 4/19/2005 Rig Number: Spud Date: 3/29/2005 End: 4/19/2005 Group: Œ.ECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Printed: 4/26/2005 4:12:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-14 3H-14 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 3/29/2005 Rig Release: 4/19/2005 Rig Number: Spud Date: 3/29/2005 End: 4/19/2005 Group: RIH and set CIBP at 6,260' WLM. POOH and RD wireline equipment. RU and test Top Drive lower and upper safety valves to 250 I 4,000 psi. 4/2/2005 Test manuallBOP on Top Drive to 250 psi & 4000 psi. Test HCR (choke line) to 250 psi. NOTE: testing witnessed by Jeff Jones of the AOGCC. 01 :30 - 03:30 2.00 RIGMNT RGRP DECOMP Rig generator dropped off line & died (Gen. 1) Start D-399. Start blowinfg down rig. Wait on mechanic & electrician to arrive at location. 03:30 - 06:00 2.50 RIGMNT RGRP DECOMP Bring 3516 back on line. Thaw out rig equipment, Top drive, steam heaters & lines, Choke & kill lines. 06:00 - 10:30 4.50 R1GMl RGRP DECOMP Continue to thaw out TD, choke and kill lines. 10:30 - 11 :30 1.00 WE LeT BOPE DECOMP Pull wear ring. 11 :30 - 12:00 0.50 WELCT BOPE DECOMP RU to test BOPE. Set test joint and plug. 12:00 -13:00 1.00 WELCT BOPE DECOMP Test HeR valve to 250 I 4,000 psi. 13:00 - 14:30 1.50 RIGMNTIRGRP DECOMP Work on Top Drive processing unit. NOTE: Started converting our milling fluid into drilling mud, and mixing additional new mud for Doyon 141. 14:30 - 15:30 1.00 WELCT DECOMP Test Upper IBOP to 250 I 4,000 psi. 15:30 - 16:30 1.00 WELCT DECOMP Install wear ring, LD test joint, MU Kelly hose. 16:30 - 18:00 1.50 WINDO DECOMP PU BHA subs. RU tongs, bit breaker and slips. Hold PJSM with Baker Fishing rep. 18:00 - 00:00 ULD DECOMP PU window milling BHA and 4" DP, drifting every joint and filling every 75jts. 4/3/2005 00:00 - 06:00 6.00 DRILL PULD DECOMP PIU 4" DP, Drift DP, Fill pipe every 75 jts. Tag CIBP @ 6259' DP measurement. (6260' WLM) 06:00 - 07:30 1.50 DRILL SFTY DECOMP Hold stripping drill and Well Kill drill with both crews. 07:30 - 08:30 1.00 DRILL OTHR DECOMP Blowdown Top Drive, choke and mud pumps 08:30 - 11 :00 2.50 DRILL OTHR DECOMP Cut and slip drilling line. PJSM. Set TD at appropriate height, cut and slip 265' of drill line. Adjust brakes, unhang blocks. 11 :00 - 12:00 1.00 DRILL OTHR DECOMP MU floor valve and cut hose for chart recorder. 12:00 - 13:30 1.50 DRILL OTHR DECOMP Test casing, circulate air out of surface lines and choke manifold. Test casing to 3,000 psi for 15 minutes. 13:30 - 14:30 1.00 DRILL OTHR DECOMP Pump dry job. Blow down. Calibrate Sperry-Sun & Blocks 14:30 - 18:00 3.50 DRILL TRIP DECOMP POOH SLM - no correction. 18:00 - 19:30 1.50 DRILL TRIP DECOMP POOH, stand back milling BHA 19:30 - 23:30 4.00 WINDO ULD DECOMP PJSM, PU whipstock and anchor. Orient and upload MWD. 23:30 - 00:00 0.50 WINDO RIP DECOMP Continue RIH with whipstock BHA. 4/4/2005 00:00 - 06:00 6.00 WINDO RIP DECOMP RIH wI Whipstock @ 2min std. 06:00 - 07:30 1.50 WINDO ETW DECOMP Orient & set whipstock 6245', Top fo window @6227'. Whipstock oriented 18 degrees to right of high side. 07:30 - 09:00 1.50 WINDO IRe DECOMP Displace well wI 9.8 ppg mud. 09:00 - 10:00 1.00 RIGMNT RGRP DECOMP Work on Top Drive electrical system (DTI card) Bypass card. 10:00 - 10:30 0.50 WINDO IRe DECOMP Circ, change screens, install ditch magnets. 10:30 - 16:00 5.50 WINDO TWP DECOMP Mill window f/ 6227' to 6256'. TOW 6227' BOW 6240' 16:00 - 17:30 1.50 WINDO IRe DECOMP Pump sweep around, work thru window w/ mills. 155k up wt. 140k Dn wt. 17:30 - 18:00 0.50 DRILL LOT DECOMP I RlU & perform LOT. 15.6 ppg EMW. 1500 psi, mud wt 9.8 ppg, 5001' tvd. Bled back .75 bbls 18:00 - 18:30 0.50 DRILL RIRD DECOMP RID lines. blow down lines, clear floor. 18:30 - 19:00 0.50 WINDO IRC DECOMP Monitor well for flow (static) Pump slug 19:00 - 19:30 0.50 RIGMNT RSRV DECOMP Service Rig & Top Drive 19:30 - 00:00 4.50 WINDO RIP DECOMP POOH wI whipstock assy. Printed: 4/26/2005 4:12:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-14 3H-14 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 3/29/2005 Rig Release: 4/19/2005 Rig Number: Spud Date: 3/29/2005 End: 4/19/2005 Group: 19:30 - 00:00 4.50 WINDO RIP DECOMP 00:00 - 02:30 2.50 DRILL PULD INTRM1 Handle BHA, Stand Hwt in Derrick, LD DC 02:30 - 03:00 0.50 DRILL PULD INTRM1 Download MWD 103:00 - 03:30 0.50 DRILL PULD INTRM1 PU Stack Washer & Wash out Stack ... LD Same 03:30 - 07:30 4.00 DRILL PULD INTRM1 PU 4" DP & TIH 07:30 - 08:00 0.50 DRILL CIRC INTRM1 Circ through DP to remove scale ... monitor well 08:00 - 09:00 1.00 DRILL PULD IINTRM1 POOH & stand DP back in Derrick 09:00 - 09:30 0.50 DRILL SFTY INTRM1 Clear Rig Floor... Held Pre-Job Safety Meeting on PU BHA. PU BHA 09:30 - 11 :00 1.50 DRILL PULD INTRM1 PU Directional BHA 11 :00 - 12:00 1.00 DRILL PULD INTRM1 Orient & Upload Directional Assy 12:00 - 13:00 1.00 DRILL DEQT INTRM1 PU BHA ... Shallow test Motor & MWD 13:00 - 17:00 4.00 DRILL TRIP INTRM1 TIH with Directional Assy 17:00 - 17:30 0.50 RIGMNT RSRV INTRM1 Service Rig 17:30 - 19:00 1.50 RIGMNT RGRP INTRM1 Change out DTI card on Top Drive 19:00 - 19:30 0.50 DRILL OTHR INTRM1 Calibrate Totco Block Height 19:30 - 20:00 0.50 DRILL SURV INTRM1 Get parameters, Orient toolface & TIH thru casing window 20:00 - 00:00 4.00 DRILL DRLG INTRM1 Directional Drilling from 6256' to 6462' MD (12k WOB, 90 rpm, PU = / 165k, SO = 125k, Rot = 140k, Torque = 6500 ft-Ibs, 300 gpm) 4/6/2005 00:00 - 06:00 6.00 DRILL DRLG INTRM1 Slide Drilling from 6462 - 7020' MD 06:00 - 12:00 6.00 DRILL DRLG INTRM1 Drilling from 7020' to 7331' MD 12:00 - 18:00 6.00 DRILL DRLG INTRM1 Drilling from 7331 to 7861' MD (PU = 190k, SO = 140k, Rot = 150k, Torque = 7k on bottom & 6k Off bottom) 18:00 - 20:00 2.00 DRILL DRLG INTRM1 Drilling from 7861' to 7935' MD 20:00 - 21 :00 1.00 DRILL CIRC INTRM1 Circ & Cond, Weight up from 10.1 to 12.0 ppg 21 :00 - 23:00 2.00 DRILL CIRC INTRM1 Losing circulation (appx 35 BBUhr) Max ECD = 14.5 ppg MWE ... Circulate and lower mud weight to 10.8 ppg. 23:00 - 00:00 1.00 DRILL CIRC INTRM1 Pump 10.8ppg mud around (mud wt 11.0 ppg comming out) 4/7/2005 00:00 - 01 :00 1.00 DRILL CIRC INTRM1 Circ & lower MW from 11.5 - 10.8ppg 01 :00 - 02:00 1.00 DRILL CIRC INTRM1 Cont Circ... MW 10.8ppg in & 11.0ppg out 02:00 - 06:00 4.00 DRILL TRIP INTRM1 10.8 ppg in & out... POOH, Pull tight @ 6600' MD (80k overpull on elevators), Wash & Ream thru with no overpull. 06:00 - 09:15 3.251 DRILL TRIP INTRM1 Continue POOH, Rack back Hwt and LD jars 09:15 - 12:00 2.75 DRILL PULD INTRM1 LD BHA ... Download MWD 12:00 - 13:00 1.00 DRILL PULD INTRM1 Clean floor - hold PJSM. PU Hole opener Assy 13:00 - 17:00 4.00 DRILL TRIP INTRM1 TIH with Hole Opener to 6275' MD 17:00 - 17:30 0.50 DRILL DEQT INTRM1 Establish parameters: PU = 160k, Rot = 140k, SO = 125k, 6k Torque, 150 rpm, 275gpm, 1620psi SPP ... I Shear pins on Near Bit Reamer arms - verify open with increase in torque. Pull up to 6243' MD 17:30 - 18:00 0.50 DRILL REAM INTRM1 Open hole to 7" from 6243' MD to 6395' MD. 18:00 - 00:00 6.00 DRILL REAM INTRM1 Continue hole opening from 6395' to 7143' MD. PU = 180k, Rot = 150k, SO = 140k, 7k Torque, 100rpm, 270gpm, 1500psi SPP 4/8/2005 00:00 - 06:00 6.00 DRILL ¡REAM INTRM1 Cont Opening Hole from 7143' to 7891' MD 06:00 - 07:30 1.50 DRILL REAM INTRM1 Cont Opening Hole from 7891' to 7932' MD (TD) 07:30 - 08:45 1.25 DRILL CIRC INTRM1 Pumped Sweep I Circ & Cond Mud ... Pumped 2 bottoms up@ 285gpm, 1800psi, Rot = 160k, PU = 190k, SO = 130k, TQ = 8k, 150rpm 08:45 - 12:00 3.25 DRILL TRIP INTRM1 POOH to 5460' MD, String pulled wet, Pumped 25 BBL slug, cont POOH to 3778' MD ... PU = 180k, SO = 125k 12:00 - 13:00 1.00 DRILL TRIP INTRM1 POOH from 3778' MD to HWDP 13:00 - 14:45 1.75 DRILL PULD INTRM1 LD HWDP, Flex Collars, & Hole Opener Assy Printed: 4/26/2005 4:12:44 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-14 3H-14 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 3/29/2005 Rig Release: 4/19/2005 Rig Number: Spud Date: 3/29/2005 End: 4/19/2005 Group: 4/8/2005 14:45 - 18:00 3.25 CASE PULR INTRM1 Clean Floor, Held PJSM, RU & Run 5-1/2",15.5#, L-80 Hydril511 Liner 18:00 - 19:00 1.00 CASE PULR INTRM1 19:00 - 19:45 0.75 CASE PULR INTRM1 19:45 - 20:00 0.25 RIGMNT RGRP INTRM1 20:00 - 22:15 2.25 CASE RUNL INTRM1 122:15 - 22:45 0.50 CASE RUNL INTRM1 122:45 - 00:00 1.25 CASE RUNL INTRM1 4/9/2005 00:00 - 01 :15 01: 15 - 01 :45 01 :45 - 03:00 03:00 - 04:00 04:00 - 06:00 06:00 - 10:45 10:45-11:15 11:15-12:00 12:00 - 13:45 13:45 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 -16:00 16:00 - 18:00 4/10/2005 18:00 -19:30 19:30 - 22:30 00:00 - 02:30 SPR @ 7900' wI MW @ 10.8ppg #1 30 SPM = 1020psi, 40 SPM = 1220psi #230 SPM = 1010psi, 40 SPM = 1250psi Cont RIH w/5-1/2", 15.5#, L-80 Hydril511 Liner (44 jts) PU Liner Hanger & RIH ... 35k PU on Liner Bad Pin in Elevators ... Change out Elevators TIH w/4# DP, Rabbit every stand ... pipe flowing over so MU Top Drive to every stand. TIH @ 1.5 to 2 minlstand, Having to steam some stands due to cold weather (ice not allowing Rabbit thru pipe). Break down stand looking for Rabbit ... Remove Rabbit stuck due to ice. TIH w/4" DP ... Rabbit every stand wI steel Rabbit due to icy pipe, MU to Top Drive every stand due to pipe flowing over while TIH. Curr @ 3637' MDI 3132' rvD PU = 110k, SO = 100k 1.25 DRILL TRIP INTRM1 Cont. TIH wI 4" DP ... Rabbit every stand wI steel Rabbit due to icy pipe, MU to Top Drive every stand due to pipe flowing over while TIH. 0.50 RIGMNT RGRP INTRM1 Work on Top Drive ... Pipe Handler not Rotating 1.25 CASE RUNL INTRM1 TIH wI 4" DP ... Rabbit every stand wI steel Rabbit due to icy pipe, MU to Top Drive every stand due to pipe flowing over while TIH... Curr@ 5312' MD PU = 145k, SO = 115k Suddenly Liner Assy Taking Wt (- 60k) ... Shoe @ 5312' MD /4329' rvD Hanger @ 3450' MD I 2999' rvD Decision to POOH and Inspect Liner Hanger 1.00 CASE OTHR INTRM1 Attempt to POOH ... Hole Swabbing PU = 145k, SO = 115k 2.00 CASE OTHR INTRM1 Pump OOH Due to Liner OD in Csg causing Hole to Swab ... to 4197' MD 4.75 CASE 0.50 CASE 0.75 CASE 1.75 CASE 0.25 CASE 0.50 CASE 0.50 WELCT 1.00 WELCT 2.00 WELCT OTHR OTHR OTHR OTHR OTHR RIRD BOPE BOPE BOPE INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 Pump @ 2 BPM w/ 500psi SPP Cont Pumping OOH Due to Swabbing ...4197' MD to 2000' MD LD Hanger Assy RU to LD 5.5", 15.5#, L-80 Hydril 511 Liner ... Held PJSM LD Liner Heat & Break Baker-Locked Joints & LD same RD Liner Equipment ... Clear Rig Floor - Prepare to Test BOPs RU Test Joint & Pull Wear Ring Drain Stack, Install Test Plug, RU Test Equipment and Open Ann. Blew Air Thru Choke Maniforl - Fill Stack & Choke Man. w/ water ... I BOP test waived by State Rep. Tested Hydril and Body to 250psi Low I 3500psi High Work on Test Pump Manifold (Leaking) ... Change Valve and Pipe 'T' Test BOPE ... 250psi Low I 4000psi High Continue Testing BOPE ... 250psi Low I 4000psi High Printed: 4/26/2005 4: 12:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-14 3H-14 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 3/29/2005 Rig Release: 4/19/2005 Rig Number: Spud Date: 3/29/2005 End: 4/19/2005 Group: 06:00 - 07:45 INTRM1 07:45 - 12:00 INTRM1 12:00 - 13:30 INTRM1 13:30 - 14:00 0.50 WE LeT INTRM1 14:00 - 14:30 0.50 WELCT INTRM1 14:30 - 15:00 0.50 DRILL INTRM1 15:00 - 17:00 2.00 DRILL PULD INTRM1 17:00 - 17:30 0.50 RIGMNT RSRV INTRM1 17:30 - 18:00 0.50 DRILL TRIP INTRM1 18:00 - 23:00 5.00 DRILL TRIP INTRM1 23:00 - 23:45 0.75 DRILL REAM INTRM1 23:45 - 00:00 0.25 DRILL REAM INTRM1 4/1112005 00:00 - 03:00 3.00 DRILL REAM INTRM1 03:00 - 06:00 3.00 DRILL REAM INTRM1 Work on Hoses on Test Pump Continue to Test BOPE and Floor Valves, Top Drive Upper and Lower Valves ... 250psi Low /4000psi High Continue Testing BOPE ... 250psi Low I 4000psi High Attempt to Pull Test Plug - Junk on Top of Plug ... Attempt to Wash over Plug While Attempting to Pull RU to Blow Air over Top of Plug and Flush Same ... After Several Attempts Cleared Debris and Pulled Test Plug RU Stack Washer and Attempt to Wash Debris from Inside of BOP Install Wear Ring Held PJSM on PU BHA... RU Same PU Clean-Out Assy (wI Hole Opener & Junk Basket) Service Rig I Top Drive TIH w/ Clean-Out Assy TIH ... Insert Magnet on Top of Stand 12 (1128' Above Hole Opener) ... Continue TIH to 7466' MD ... Tag, Set 20k Down Wash & Ream from 7466' to 7623' MD .., 260gpm, 1940psi SPP, 120 rpm, 7k Torque Circulate - Loosing Mud Over Shaker Due to Bottom Up ... Slow Pump Down, Stage Up Pump, Shaker Cleaned Up Continue Washing & Reaming from 7623' to 7658' MD @ 260gpm, 1900psi SPP, 120rpm, 7k TQ ... Hole Packing Off - Work Pipe Thru Pack-Off Spots @ 7716', 7810', 7838', & 7884' Hole Packed off @ 7884' MD wI 180gpm, 300gpm, 2100psi SPP .., Hole Starts Taking Mud - Lost 98 BBLs, Slow Pump to 180gpm and Regain Returns, Bring Pump up to 222gpm and Wash & Ream to Bottom 06:00 - 07:15 PU = 195k, Rot = 145k, SO = 120k 1.25 DRILL REAM INTRM1 Con!. Washing & Reaming to Bottom ... 07:15 - 08:45 08:45 . 09:00 09:00 - 10:00 1.50 DRILL CIRC INTRM1 0.25 DRILL OBSV INTRM1 1.00 RIGMNT RGRP INTRM1 10:00 - 12:00 12:00 - 14:00 2.00 I DRILL 2.00 DRILL TRIP INTRM1 CIRC INTRM1 I 14:00 - 16:45 16:45 - 17:45 17:45 - 18:00 18:00 - 20:30 20:30 - 00:00 ITRIP PULD SFTY RURD RUNL 2.75 DRILL 1.00 DRILL 0.25 CASE 2.50 CASE 3.50 CASE INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 PU = 190k, Rot = 145k, SO = 120k Pump Sweep & Circ & Cond Mud @ 220gpm, 1400psi SPP Monitor Well DTI Card in Top Drive Control Panel Failed, Had to Wait on Rig Electrician who was preparing for Crew Change Away from Location. SPR #1 610psi @ 30spm I 810psi @ 40spm SPR #2 625psi @ 30spm / 840psi @ 40spm ... @ 7935' MD w/10.8ppg Mud POOH to 6221' MD ... Dropped Dart for Circulation Sub Circ Sub Sheared @ 2350psi, Establish Circ @ 300gpm, 1250psi SPP, 125rpm, 5k TQ, Pumped 'Super Sweep' and followed w/2 Bottoms Up PU = 160k, Rot = 150k, SO = 130k Monitor Well, Pump Slug, Drop Drift and Continue POOH LD Hwt, Jars, Flex Collars, & Hole Opener I Junk Basket BHA Clear Floor and PJSM to RU to Run Liner RU to Run 5-1/2" Liner PJSM wI Co Man, Toolpusher, Rig Crew, and Casing Hand Printed: 4/26/2005 4:12:44 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-14 3H-14 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 3/29/2005 Rig Release: 4/19/2005 Rig Number: Spud Date: 3/29/2005 End: 4/19/2005 Group: 4/11/2005 20:30 - 00:00 3.50 CASE RUNL INTRM1 PU & RIH wI 45 joints of 5-1/2",15.5# L-80 Hydril511 Liner, Float & Shoe, Centralizer Sub per Running Order 4/12/2005 00:00 - 02:30 2.50 CASE PULR INTRM1 Change Out Elevators to 4" DP, PU Liner HangerlPacker, PU Single & MU to Top Drive, Circ Liner Volume @ 3BPM (400psi), Break out Single & Blow Down Top Drive, PU = 97k, SO = 88k 02:30 - 06:00 3.50 CASE RUNL INTRM1 TIH @ 1.5 - 2 minlstand wI 4" DP from Derrick, Filling Pipe Every 10 Stands (6191' MD) 06:00 - 06:45 0.75 CASE RUNL INTRM1 Cont TIH w/5-1/2" Liner to 6191' MD 06:45 - 07:45 1.00 CASE CIRC INTRM1 Circ DP & Liner Volume @ 3BPM (650psi) 07:45 - 09:30 1.75 CASE RUNL INTRM1 LD Two Singles for Space Out ... Cont TIH wI Liner 09:30 - 10:15 0.75 CASE RURD INTRM1 MU Rot Cmt Head & Cmt Hose 10:15 - 10:30 0.25 CASE RUNL INTRM1 RIH & Tag Bottom, Pipe Became Sticky, Set Shoe @ 7925' MD 10:30 - 12:00 1.50 CASE CIRC INTRM1 Establish Circ @ 3BPM (890psi) ... Cont to Circ & Condition Mud 12:00 - 13:30 1.50 CASE CIRC INTRM1 Held PJSM wI Co Rep, TP, Cementers, Baker Hand, and Rig Crew. Cont to Circ & Condition Mud while Cementers Batched Up. 13:30 - 14:15 0.75 CEMEN PUMP INTRM1 Turned Over to Cementers, Fill Lines and Pressure Test Lines to 3500psi, Pumped 20BBL of CW 100. Mix & Pump 20 BBL of Mud Push II Spacer @ 13ppg, Mix and Pump 40BBL of Tail @ 15.8ppg. 14:15 -15:00 0.75 CEMEN DISP INTRM1 Drip Plug, Pump 20 BBL of Water & Turned over to Rig Pump 3BPM (350psi) Bumped @ 863 strokes & Pressure up to 3500psi 15:00 - 16:00 1.00 CASE RUNL INTRM1 Set Liner Hanger According to Baker, Insured Dies were Set, Pull Running Tool Above Liner Top and Circ & Condition mUd. Circ 5.5BPM (770psi) PU = 145k, SO = 120k 16:00 - 16:15 0.25 CASE DEQT INTRM1 Tested Liner & Liner Lap to 500psi for 5 min 16:15 - 16:45 0.50 CEMEN PULD INTRM1 RD Cmt Head & Blow Down Cmt Lines 16:45 - 18:00 1.25 DRILL TRIP INTRM1 I Monitor Well, Pumped Slug & POOH 18:00 - 20:30 2.50 DRILL TRIP INTRM1 Cont POOH, Standing Back DP & LD Liner Running Tool 20:30 - 23:30 3.00 WELCT EQRP INTRM1 Drain BOPs, C/O Upper & Lower Rams to 2-7/8" x 5" VBRs 23:30 - 00:00 0.50 WE LeT BOPE INTRM1 Fill BOP wI Water & Test Upper & Lower Rams to 250spi Low, 4000psi High, Chart Same 4/13/2005 00:00 - 01 :00 1.00 WELCT BOPE INTRM1 Pull test plug, Set wear ring in wellhead. 01 :00 - 03:00 2.00 DRILL PULD INTRM1 M/U 4-3/4" BHA 03:00 - 04:00 1.00 DRILL DEQT INTRM1 Upload MWD Tool 04:00 - 08:30 4.50 DRILL PULD INTRM1 RIH with 4-3/4" BHA, picking up 2-7/8" drillpipe. 08:30 - 09:00 0.50 DRILL RIRD INTRM1 Change out elevators and handling tools. 09:00 - 10:30 1.50 DRILL TRIP INTRM1 RIH with 4" drillpipe to TOL at 6,010' 10:30 - 12:00 1.50 DRILL CIRC INTRM1 Circ. and condition mud. 12:00 - 15:30 3.50 CASE DEQT INTRM1 Attempt to test csg. Air in mud. Circ. and condition with defoamer. Pressure test casing to 3,400 psi, Bled to 3180 psi in 30 min, OK. 15:30 -16:00 0.50 DRILL RIRD INTRM1 RID head pin, blow down circulating lines. 16:00 - 17:30 1.50 RIGMNT RSRV INTRM1 Slip and cut 114' drilling line 17:30 - 18:00 0.50 RIGMNT RSRV INTRM1 Service rig 18:00 - 20:15 2.25 DRILL TRIP INTRM1 RIH to 7,786' 20:15 - 21 :45 1.50 CEMEN DSHO INTRM1 MIU TD, wash down to top of landing collar at 7,832', Drill float CIRC I'NTRM1 equipment and cement to 7,923' 121 :45 - 00:00 2.25 DRILL Circ. and condition mud. MW out 10.6 ppg, MW in 10.8ppg 4/14/2005 00:00 - 01 :45 1.75 DRILL DRLG PROD Drill 4-3/4" OH to 7,955' 01 :45 - 02:45 1.00 DRILL CIRC PROD Circulate and condition mud for FIT. 02:45 - 03:15 0.50 RIGMNT RGRP PROD Trouble shoot top drive. 03:15 - 04:15 1.00 DRILL FIT PROD RlU test equipment, perform FIT, MWE = 15.3 ppg, RID test Equipment I I Printed: 4/26/2005 4:12:44 PM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-14 3H-14 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 3/29/2005 Rig Release: 4/19/2005 Rig Number: Spud Date: 3/29/2005 End: 4/19/2005 Group: 4/14/2005 04:15 - 10:30 6.25 RIGMNT RGRP PROD Trouble shoot top drive. 10:30 - 15:00 4.50 DRILL DRLG PROD Drill 4-3/4" OH to 8,001' 15:00 - 23:00 8.00 RIGMNT RGRP PROD Trouble shoot top drive with Varco Rep. 23:00 - 00:00 1.00 DRILL DRLG PROD Drill 4-3/4" OH to 8,010' 4/15/2005 00:00 - 13:45 13.75 DRILL DRLG PROD Drill 4-3/4" OH from 8,010' to 8,450' TD. Slight flow on connections, raise mud to 12.0 ppg. 13:45 - 14:30 0.75 DRILL CIRC PROD Pump up survey at 8,450', slight flow with pumps off. 14:30 - 17:00 2.50 DRILL CIRC PROD Circulate and condition mud, raise mud weight to 12.2 ppg. 17:00 - 21 :30 4.50 DRILL CIRC PROD Monitor well, slight flow with pumps off, Raise mud weight to 12.6 ppg. Monitor well, static. 21 :30 - 22:30 1.00 DRILL WIPR PROD Short trip to casing shoe and back to bottom, hole in good condition. 22:30 - 00:00 1.50 DRILL CIRC PROD Circulate and condtion mud, gas cut mud at BU. Returns 12.4 ppg to 12.5 ppg. Circulate untíl12.6 ppg inlout. 4/16/2005 00:00 - 00:30 0.50 DRILL CIRC PROD Ciculate and condition Mud. 00:30 - 02:30 2.00 DRILL TRIP PROD Monitor well, static, POH to 5-1/2" liner top at 6,039' 02:30 - 03:00 0.50 DRILL TRIP PROD Drop ball to open circ sub. Pressure up to 3,600 psi, No shear. 03:00 - 05:30 2.50 DRILL TRIP PROD POH to SWHWDP. 05:30 - 13:00 7.50 DRILL PULD PROD Lay down SWHWDP, Stand 2-7/8" drill pipe, Lay down 4-3/4" BHA. 13:00 - 14:00 1.00 CASE RURD CMPL TN RlU Casing running equipment. 14:00 - 14:30 0.50 CASE SFTY CMPL TN Held PJSM on running casing. 14:30 - 17:15 2.75 CASE PULR CMPL TN MIU 3-1/2" Liner, RIH 17:15 - 19:15 2.00 CASE RUNL CMPL TN RIH with liner on 2-7/8" drill pipe 19:15 - 20:00 0.75 CASE RURD CMPL TN C/O drill pipe handling equipment to 4". Fill pipe, break circulation. 20:00 - 22:45 2.75 CASE CIRC CMPL TN Circulate and condition mud. Gas cut mud at BU. Circulate until MW 12.6 ppg inlout. 10 min flow check, well static. 22:45 - 00:00 1.25 CASE RUNL CMPL TN RIH with liner on 4" drillpipe. 4/17/2005 00:00 - 02:30 2.50 CASE RUNL I CMPL TN RIH with 3-1/2" liner on 4" drill pipe to 6,039'. Top of 5-1/2" liner. 02:30 - 04:15 1.75 CASE CIRC CMPL TN Circulate and condition mud at TOL. Gas cut mud at BU. Circulate until 12.7 MW inlout, 10 min flow check, well static. 04:15 - 09:00 4.75 CASE RUNL CMPL TN RIH with 3-1/2" liner to 8,429', MIU Baker Cement Manifold. Break circulation. Up Wt. 155K, Dn Wt. 125K 09:00 - 12:00 3.00 CASE CIRC CMPL TN Tag btm. with 3-1/2" liner at 8,450', Circulate and condition mud at 3 I BPM, 1,220 psi. Reciprocate liner. Up WI. 165K Dn Wt. 120K 12:00 - 13:00 1.00 CEME1CIRC CMPL TN Circulate and conditon mud for cement job. Held 15 min PJSM on cementing 3-1/2" liner. Schlumberger cementers batch mix liner cement. 13:00 - 15:00 2.00 CEMEN PUMP CMPL TN . Shut down mud pump, switch lines over to Schlumberger. Pump 2 bbls water, PT surface lines to 4,000 psi. OK. Pump 15 bbls 13.5 ppg Mud push. Pump 17 bbls 15.8 ppg cement. Drop DPWP. Pump 20 bbls water. Switch lines to rig pump. Displace with 12.7 ppg mud and pump at 3 bpm 1,090 psi, 1,300 psi observed as cement was displaced into 13-1/2" x 4-3/4"annulus. Plug did not bump at calculated strokes. Pump 3 additional bbls, did not bump. Discuss options with Drilling Management. Pump additional 6 bbls mud. Bump plug. Floats held. Presure up to 2,600 psi to set hanger, Slack off 35K to set hanger. Pressure up to 3,600 psi to release running tool. Circulate to ensure running tool released, OK. Slack off 40K to set ZXP packer. CIP at 1.00 CMPL TNI CIRC 15:00 hrs. 15:00 - 16:00 CMPL TN Circulate btms up 4 bpm at 1,380 psi. Dump 10 bbls cement I contaminated mud to cuttings tank. Continue to circulate until clean returns observed at surface. 16:00 - 16:15 0.25 CMPL TN DEQT CMPL TN Pressure test 3-1/2" x 5-1/2" liner top to 1,500 psi. OK. 16:15 - 18:30 2.25 CMPL TN CIRC CMPL TN Displace well bore to 8.5 ppg seawater. Circulate until clean returns Printed: 4/26/2005 4:12:44 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-14 3H-14 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 3/29/2005 Rig Release: 4/19/2005 Rig Number: Spud Date: 3/29/2005 End: 4/19/2005 Group: 4/17/2005 16:15 - 18:30 2.25 CMPL TN CIRC CMPL TN observed at surface. 18:30 - 19:00 0.50 CMPL TN RURD CMPL TN RID Baker Cement Manifold, Blow down surface lines. 19:00 - 00:00 5.00 CMPL TN TRIP CMPL TN Flow check well, static, POH, lay down 4" drill pipe. 4/18/2005 00:00 - 01 :45 1.75 CMPL TN TRIP CMPL TN POH,Lay down 4" drill pipe 01 :45 - 03:45 2.00 CMPL TN TRIP CMPL TN POH, lay down 2-7/8" drill pipe and Baker running tool. 03:45 - 05:00 1.25 CMPL TN RURD CMPL TN Clear rig floor, pull wear ring, RlU completion running equipment 05:00 - 05:30 0.50 CMPL TN SFTY CMPL TN Held PJSM on running 3-1/2" Completion. 05:30 - 12:00 6.50 CMPL TN RUNT CMPL TN RIH with 3-1/2" Completion String. 12:00 - 13:00 1.00 CMPL TN RURD CMPL TN M/U TRSSSV, Hook up control line. PT elL. 13:00 - 16:00 3.00 CMPL TN RUNT CMPL TN RIH with 3-1/2" Completion string with C/L 16:00 - 18:00 2.00 CMPL TN SOHO CMPL TN Space out tubing to land in tie-back sleeve. MIU space out pup, tbg hgr, and landing jt. Hook up elL to Tbg Hgr. 18:00 - 19:30 1.50 CMPL TN SOHO CMPL TN Attempt to land tbg hgr in wellhead. Unable to fully land tbg string. Pull tbg hgr to surface. CIO lower seal on CIW tbg hgr to correct size. Land tbg hgr in wellhead. RILDS. OK. 19:30 - 21 :30 2.00 CMPl TTUND CMPL TN Back out and lay down landing jt. Set tree testing plug in tbg hgr. 21 :30 - 22:30 1.00 CMPL TN NUND CMPL TN Pull and lay down mouse hole, Blow down top drive and choke manifold. 22:30 - 00:00 1.50 CMPL TN NUND CMPL TN N/D BOPE 4/19/2005 00:00 - 02:00 2.00 CMPL TN NUND CMPL TN NID BOPE 02:00 - 03:00 1.00 CMPL TN NUND CMPL TN NIU 7-1/16" x 3-1/8" CIW adapter flange. Test to 5,000 psi, OK 03:00 - 04:30 1.50 CMPL TN NUND CMPL TN NIU 3-1/8" CIW Tree. 04:30 - 06:00 1.50 CMPL TN SEQT CMPL TN RlU Test lines, Pump open hydraulic actuator valve.PT tree to 5,000 psi, ok 06:00 - 08:00 2.00 CMPL TN OTHR CMPL TN RlU circulating lines to Hot oil unit. PT lines to 3,500 psi. OK 08:00 - 09:30 1.50 CMPL TN OTHR CMPL TN Pull Tree testing plug from tbg. hgr. Pump open TRSSSV. 09:30 - 11 :30 2.00 CMPL TN OTHR CMPL TN Attempt to pressure test tbg. pump down tbg observed returns thru annulus 2 bpm, 200 psi. RlU on annulus. Pump down annulus observed returns up tbg at 2 bpm 200 psi. No test on tbg. 11 :30 - 12:30 1.00 CMPL TN FRZP CMPL TN Hot oil unit pump 70 bbls freeze protect diesel down tbg. 12:30 - 13:30 1.00 CMPL TN FRZP CMPL TN U-tube diesel. 13:30 - 15:00 1.50 CMPL TN NUND CMPL TN RID Hot Oil Unit, RID test equipment from tree. 15:00 - 16:00 1.00 CMPL TN NUND CMPL TN Set BPV, Close TRSSSV and surface actuator. 16:00 - 17:00 1.00 CMPL TN NUND CMPL TN Finish cleaning pits, Secure well head and tree. Prep for rig move. I Released rig from operations on well 3H-14B at 17:00 hrs on 4-19-05. I Printed: 4/26/2005 4:12:44 PM e 3H-14B Well Events Summary e Date Summary 04/22/05 SET CAT SV IN 0 NIPPLE @7717'RKB,PULL DV'S @ 7675',6974',5991' 4794'&2936' RKB.SET GLV'S @2936',4794'&6974' RKB. [GLV] 04/24/05 SET GLV @ 5991'RKB & 1/4" OV@7675'RKB,MIT TBG TO 2500 PSI,PULL CAT SV @7717' RKB. [GL V, MIT] 04/30105 RAN SCMT CEMENT BOND LOG FROM 8253' TO 6846': NO CEMENT SEEN BEHIND 31/2" LINER -- TAGGED BOTTOM AT 8267' 05/09/05 PULLED GLVs FROM STATIONS 3,4,5. SET DV IN STATION 5. IN PROGRESS. [GLV] 05/10105 PULL STA# 1,2 LV,S & SET DUMMY GLV'S IN ALL STATIONS, ,SET CAT VALVE PT TUBING 2500# HOLDING SOLID, PULL CAT, RUN 2.5"X 10' DMY GUN TO 8268' RKB [GLV, Tag] 05/13/05 PREPARE WELL FOR CEMENT SQUEEZE. PERF THE LOWER INTERVAL 8250'- 8254' USING 2506 POWERFLOW HMX LOADED 6 SPF, 60 DEG PHASING. API PENE=4.8". EH=0.66". ALL 25 SHOTS FIRED. PUNCH TUBING WITH 9 HOLES (4 SPF, 0 DEG PHASING) FROM 7886'-7888'. EH=0.38". ALL SHOTS FIRED. INSTALLED HALLIBURTON 3-1/2" EZ-DRILL-SVB CEMENT RETAINER @ 8223.3' (7' ABOVE PROPOSED SET DEPTH) DUE TO BECOMING STUCK WHILE RIH SAT DOWN EARLY. OVERPULLED 300# TENSION, TOOL DID NOT MOVE. DECISION TO SET @ THIS DEPTH. TAGGED TO CONFIRM SET. PUMPED 5.5 BBL DIESEL DOWN TUBING AT 2700 PSI & 0.46 BPM TO VERIFY TUBING PUNCH. WELL LEFT SHUT IN. 05/15/05 ATTEMPTED CEMENT SQUEEZE. UNABLE TO ESTABLISH CIRC. THROUGH SQUEEZE PERFS/ANNULUS- NO FLOW TO SURFACE ONCE STUNG IN RETAINER PUMPING 1.0 BPM, 3200 PSI CTP--- WELL BLEEDS TO 0 PSI. SUSPECT EITHER FLOW PATH IS PARTIALLY BLOCKED WI CEMENT OR POOR PENETRATION I SIZE OF TBG PUNCH PERFS. WELL LEFT FREEZE PROTECTED W/DIESEL. 05/18/05 SHOT 9 TUBING PUNCHER HOLES FROM 7884' TO 7886' -- USED SMALL CHARGES -- TUBING PRESSURED UP TO 3300 PSI AFTER PUMPING 6 BBLS DIESEL, FINAL TBG PRESS= 2400 PSI -- FINAL IA PRESS WAS 2550 PSI UP FROM 260 PSI AT START OF JOB -- BLEED IA PRESS AND TBG PRESS TRACKED. 05/20105 TEST TUBING WI 0&0 FROM 7008'(WLM) TOP 4 STATIONS PASSED. [Leak Detect-Patch] 05/21/05 TEST TUBING WI 0&0 BELOW STA# 5. IA TRACKED. PULL STA# 5, SET NEW DV. SET 2.75" CAT. PT TO 2500# TEST FAILED. TEST TUBING WI 31/2" 0&0 @ 7670 (WLM) TEST SOLID 15 MIN. 05/22/05 MITIA failed, pumped down lA, tbg pressured up immediately. SL ponytail LDL pumping down T @ 1.5 BPM taking returns up IA unable to find leak point: RUN 18" PONY-TAIL MAKE 2 PASSES FROM 7862' WLM-6974' WLM-SAW NO LEAK, RUN 3.5" 0&0 HOLEFINDER TO 7642' WLM TEST TUBING TO 1300#, GOOD TEST. RUN 0&0 HOLEFINDER TO 7642' WLM TEST TUBING TO 1300#, GOOD TEST. RUN 0&0 HOLEFINDER TO 0 NIPPLE # 7718' RKB, TEST TUBING TO 1300#, GOOD TEST, RUN 3.5" CAT STANDING VALVE TO 0 NIPPLE 2600 PSI TEST GOOD. LEAK IS BELOW 0 NIPPLE. 05/26/05 LOGGED SPINNER, GR, CCL IN TBG FROM 7000' TO 8000' WLM. LOGGED COLLARS @ 100 FPM FROM 8000' WLM TO SURFACE. [Leak Detect-Patch] e 3H-14B Well Events Summary e 05/29/05 EQUIPMENT & MATERIAL COSTS FOR CEMENT PREP. ADHOC CEMENT UNIT FOR 5 HOURS & 1 HR FOR THE BATCH MIXER. ALSO INCLUDED IS THE COST OF MATERIALS THAT WERE PREMIXED & SENT TO DISPOSAL. **THE CEMENT JOB DIDN'T OCCUR AS PLANED DUE TO THE DISCOVERY OF A TUBING X IA COMMUNICATION PROBLEM. 06/07/05 SBHP OF 2451 PSI @ 8154' RKB, GRADIENT SBHP = 2385 PSI @ 8030' RKB. PULL DV @ STA#5. SET 2500# DCR. 06/08/05 SET WRP AT 7861'. DID NOT TAG TD 06/09/05 MIT T & IA TO 2500# HOLDING ONLY LOST 60# AFTER 30 MIN, BLEED BACK TO T/IIO = 75/25/140, HELD 30 MIN (GOOD), SET 31/2" JUNK CATCHER, 7' OAL TO TOP OF WRP @ 7861' RKB, SET FRAC SLEEVE 80" OAL, 2.30" ID @2018' RKB [MIT, SSSV Work] 06/20/05 PULLED BACK PRESSURE VLV. PULLED FRAC SLEEVE @2329' RKB. PULLED SOY AT 7706' RKB. CIRCULATE 221 BBLS DIESEL DOWN TBG AND OUT IA. SET DV 7706' RKB. MITrA TO 2500 PSI. PASSED. PULLED JUNK CATCHER FROM TOP OF WRP. PULLED WRP AT 7860' RKB. ATTEMPTED TO PUMP THROUGH PERFS. TBG PRESSURED UP TO 2000# & HELD. COULD NOT PUMP THROUGH. [MIT, GLV] 07/30/05 ATTEMPTED TO BREAK DOWN UPPER SQUEEZE PERFS. 2500 PSI, W/O INJECTION. 07/31/05 PRE-PERF DRIFTED TBG WITH 17' X 2.5" DUMMY GUN TO 7930' WLM. [Tag] 08/02/05 TAGGED WHAT APPEARS TO BE TOP OF EZ DRILL @ 8202' SLM (8223' ELM). ATTEMPT TO DRIFT WI 15' OF 2.5 DUMMY GUN AND SAT DOWN @ 7930' SLM ( UNABLE TO PASS THROUGH). DRIFT W/ 12' OF 2.5 SPENT DUMMY GUN AND ABLE TO WORK DRIFT THROUGH AREA @ 7930' SLM PERIODICALLY AND TAG @ 8202' SLM. 08/03/05 DRIFTED TBG. W/ 9.5' OF 2.5 BAILER DOWN TO 8202' SM ( BOBBLED THROUGH AREA @ 7930' SLM, BUT NEVER SAT DOWN. DRIFTED TBG. W/ 2.73 SWEDGE DOWN TO 8202' SLM W/ NO PROBLEMS. DRIFTED TBG. W/ 2.73 CENT., 5' STEM, AND 2.71 GAUGE RING (7'4" OAL) SAT DOWN @ 7775' SLM, UNABLE TO DRIFT THROUGH AREA CLEANLY, BUT ABLE TO GET THROUGH BY SURGING TOOLS AND DRIFTING DOWN TO 8202' SLM W/ NO PROBLEMS. 08/09/05 PERFORATION INTERVAL 8172' - 8187'.GUN DETAIL: 2.5" HSD 6 SPF , 60 DEGREE PHAG. API PEN: 25.2", API HOLE ENTR: 0.32" GUN 1 INTERVAL 8182- 8187' / 5' GUN - ALL SHOTS FIRD. GUN 2 INTERVAL 8172- 8182' /10' GUN - ALL SHOTS FD. WHILE PULLING OUT OF HOLE WITH GUN 2 (2.5" 10') OVERPULL OF 200 LBS AT 7930', WELLHEAD PRESSURE INCREASE 400 PSI AFTER GUN 1 FIRED, MAINTAINED 1500 PSI. 08/14/05 SET FRAC SLEEVE (2.30" ID) @ 2329' RKB. JOB COMPLETE. [SSSV Work] 08/17/05 MITIA (PRE-FRAC) -passed. [ANN COM ISSUES, WH Maintenance] 08/28/05 PUMPED A SAND FRAC. PLACED 100% OF DESIGN, 132,000# 16/20 CL, 10 PPA ON PERFS. FLUSHED TO COMPLETION. SAW TSO AT -19 MINUTES INTO TREATMENT. ADJUSTED PAD VOLUME TO 140 BBLS FOLLOWING DATAFRAC ANALYSIS. RECOVERED 50% OF TREESAVER RUBBERS. [Frac-Refra e 3H-14B Well Events Summary e 08/29/05 JETTED FRAC SAND TO 9200" TAGGED RETAINER, 2:1 RETURNS AT 600 PSI WHP. [FCO] 08/30/05 PULLED FRAC SLEEVE @ 2329' (RKB). EXPERIENCED DIFFUCUL TV RIH DUE TO HEAVY FLUID WITH TRACE FRAC SAND. LRS PUMPED TO ASSIST. WILL RETURN AFTER WELL HAS HAD A CHANCE TO CLEAN UP TO TANKS. [GLV] 09/06/05 TAGGED FRAC SAND IN THE TBG @ 6576' SLM. DRIFT TBG W. 2.72" G. RING TO 6576' SLM. IN PROGRESS. [Tag, GL V] e Halliburton Sperry-Sun Western North Slope Con 0 coPhillips 3H-14B Job No. AK-ZZ-3573297, Surveyed: 15 April, 2005 Survey Report 29 April, 2005 Your Ref: API 501032009202 Surface Coordinates: 6000500.41 N, 498655.43 E (70· 24' 45.3641" N, 150" 00' 39.4184" It'\? Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 79.600 above Mean Sea Level e Survey Ref: svy2143 Halliburton Sperry-Sun Survey Report for 3H-148 Your Ref: API 501032009202 Job No. AK-ZZ-3573297, Surveyed: 15 April, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ("/100ft) 6203.60 44.600 43.040 4886.01 4965.61 1961.22 N 2479.35 E 6002461.18 N 501135.13 E 3149.59 Tie On Point MWD Magnetic 6227.00 44.700 42.940 4902.66 4982.26 -. 1973.25 N 2490.56 E 6002473.21 N 501146.35 E 0.522 3165.57 Window Point 6299.36 48.330 48.550 4952.47 5032.07 2009.80 N 2528.18 E 6002509.75 N 501183.97 E 7.534 3217.10 6394.93 50.750 55.660 5014.53 5094.13 2054.34 N 2585.54 E 6002554.28 N 501241.34 E 6.198 3289.51 6488.00 53.830 67.960 5071.58 5151.18 2088.86 N 2650.29 E 6002588.79 N 501306.10 E 10.956 3362.56 e 6580.77 53.440 68.590 5126.59 5206.19 2116.51 N 2719.69 E 6002616.43 N 501375.50 E 0.690 3435.72 6674.06 53.120 68.170 5182.37 5261.97 2144.06 N 2789.20 E 6002643.97 N 501445.02 E 0.498 3508.91 6767.92 52.750 68.080 5238.94 5318.54 2171.96 N 2858.71 E 6002671.86 N 501514.53 E 0.402 3582.29 6861.90 51.980 68.040 5296.33 5375.93 2199.77 N 2927.74 E 6002699.65 N 501583.57 E 0.820 3655.23 6954.58 53.920 65.850 5352.17 5431.77 2228.75 N 2995.78 E 6002728.62 N 501651.62 E 2.817 3727.98 7048.39 55.500 64.110 5406.37 5485.97 2261.14 N 3065.16 E 6002761.00 N 501721.00 E 2.265 3803.73 7141.53 55.300 64.540 5459.25 5538.85 2294.36 N 3134.26 E 6002794.20 N 501790.10 E 0.436 3879.69 7235.82 54.700 63.780 5513.34 5592.94 2328.02 N 3203.77 E 6002827.86 N 501859.62 E 0.917 3956.25 7327.94 54.240 63.270 5566.87 5646.47 2361.44 N 3270.88 E 6002861.26 N 501926.73 E 0.673 4030.67 7421.94 53.420 63.740 5622.35 5701.95 2395.30 N 3338.79 E 6002895.11 N 501994.65 E 0.961 4106.00 7516.05 52.310 62.860 5679.16 5758.76 2429.00 N 3405.81 E 6002928.80 N 502061.68 E 1.395 4180.51 7609.41 54.050 64.480 5735.11 5814.71 2462.14 N 3472.80 E 6002961.92 N 502128.67 E 2.324 4254.67 7703.33 53.470 63.360 5790.64 5870.24 2495.44 N 3540.83 E 6002995.21 N 502196.71 E 1.143 4329.79 7796.39 52.770 67.670 5846.50 5926.10 2526.29 N 3608.54 E 6003026.05 N 502264.43 E 3.780 4403.30 7873.51 49.840 68.080 5894.71 5974.31 2548.96 N 3664.30 E 6003048.71 N 502320.18 E 3.822 4462.32 7962.79 50.060 70.030 5952.16 6031.76 2573.38 N 3728.12 E 6003073.12 N 502384.01 E 1.690 4529.04 8026.73 42.820 69.460 5996.19 6075.79 2589.40 N 3771.56 E 6003089.13 N 502427.46 E 11.341 4574.12 e 8119.47 42.460 66.130 6064.42 6144.02 2613.13 N 3829.71 E 6003112.85 N 502485.61 E 2.463 4635.73 8213.19 37.660 69.010 6136.14 6215.74 2636.20 N 3885.40 E 6003135.91 N 502541.31 E 5.489 4694.92 8306.31 35.640 67.750 6210.85 6290.45 2656.67 N 3937.08 E 6003156.37 N 502592.99 E 2.315 4749.32 8400.08 34.170 67.460 6287.75 6367.35 2677.11 N 3986.69 E 6003176.80 N 502642.60 E 1.578 4801.99 8410.54 34.060 67.840 6296.41 6376.01 2679.34 N 3992.12 E 6003179.03 N 502648.03 E 2.293 4807.75 - 8450.00 34.060 67.840 6329.10 6408.70 2687.67 N 4012.58 E ~ 6003187.36 N 502668.50 E _ 0.000 4829.42 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 56.580· (True). 29 April, 2005 - 13:53 Page 2 of 3 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 3H-14B Your Ref: API 501032009202 Job No. AK-ZZ-3573297, Surveyed: 15 April, 2005 ConocoPhillips Western North Slope Based upon Minimum Curvature type calculations, at a Measured Depth of 8450.0Oft., The Bottom Hole Displacement is 4829.53ft., in the Direction of 56.185° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment e 6203.60 6227.00 8450.00 4965.61 4982.26 6408.70 1961.22 N 1973.25 N 2687.67 N 2479.35 E 2490.56 E 4012.58 E Tie On Point Window Point Projected Survey Survey toolproaram for 3H-14B From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 6203.60 0.00 4965.61 6203.60 8450.00 4965.61 Good Gyro - GCT-MS (3H-14) 6408.70 MWD Magnetic (3H-14B) e 29 April, 2005 - 13:53 Page 3 of 3 Drill Quest 3.03.06.008 3H-14B TxIA communication report . e Subject: 3H-14B TxIA communication report From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Tue, 31 May 2005 22:23:22 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> cc: "Gober, Howard" <Howard.Gober@conocophillips.com> ~f)'S -0 (7-\ Tom, 3H-14B (PTD 2050210) was a recently sidetracked producer. The rig moved off on 4/21/05. The well has not been on production yet, so not sure if you have received any sundry reports yet. The rig was unable to pass an MITIA and assumed that a DV was leaking. Diagnostics with slickline have been on going to fix the problem since the rig left. An LDL ran on 5/26/05 identified the tbg leak at the seal bore assembly which can not be patched. The rig will return to workover the well to fix the leak before it is put on production. Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 1 of 1 6/3/2005 1 :44 PM . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 3H-14B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,203.60 I MD 6,227.00 I MD 8,450.00 I MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage,AK 99518 Date 'i rr~ Ì0N r- Signed 'jLJ û1LJ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 30-Apr-05 )..0)-- ÔAt . ?4Js- 02 \ . Jake, AOGCC hereby approves proposed changes to we1l3H-14B (prO 205-021) drilling operations, as described below. All other permit stipulations apply. Winton Aubert AOGCC 7973-1231 Flora, Jacob M wrote: Winton, I was just told that Tom is out for the day, would you please review the following and advise? We're currently drilling ahead and should be above the Kuparuk by sometime later this evening. Thanks- Jake. Tom, We would like to change the approved drilling program with respect to the longstringltopset option. A LOT of 15.6# EMW was achieved at the window. This is less than the 17.0# LOT in the approved drilling program needed to potentially longstring into the Kuparuk. Predicted reservoir pressures fall between 10.4-14.8 ppg with 11.8 ppg expected. Current drilling data from PWD sensor confirms our hydraulic modeling showing ECDs of +2ppg at bit. We would like approval to change the drilling program according to the following plan-forward allowing us to reconsider the longstring option. 1. Increase MW to 12.0 ppg by 7935'MD/6012' TVD (+1- 100' above Kuparuk). 2. C & C. Short trip into window. 3. Perform open hole static LOT. 4. If LOT of 15.0# is achieved POOH, PU Nukes, TIH, cautiously drill ahead into Kuparuk and proceed to longstring. 5. If LOT less than 15.0# POOH, prepare to topset. Anticipated static LOT: MW Psurface EMW(éQTD EMW(éQwindow 12.0 936 15.0 15.6 Thanks for your time, Jake Flora Drilling Engineer Conoco Phillips Alaska Inc. Office: 907 265-6040 Re; 3H-14B Side Tmck Approved Pennit #20' Subject: Re: 3H-14B Side Track Approved Permit #205-021 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 31 Mar 2005 15:02:36 -0900 To: "Flora, Jacob M" <Jacob.M.F10ra@conocophillips.com> , . Jake, I pulled the file and I did write 5000 based on the calculated MASP. Reducing the test pressure to 4000 psi is acceptable. With the increased formation pressures, does this cause concern for production operations.?? Torn Maunder, PE AOGCC Flora, Jacob M wrote: Tom, We would like to lower our BOP test to 4000psi based on internal policy limiting the test pressure to 80% of casing burst pressure. 7" J-55 CasinQ Burst pressure 4980psi 80% Burst Pressure 3984psi Max Surface Pressure The maximum pressure of 4700 psi at 6200' TVD converts to a gradient of 0.76 psi/ft or 14.6 EMW. The MPSP while drilling 3H-14B is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk A sand target at 6166' TVD: MPSP =(6166 ft)*(0.76 - 0.11 psi/ft) = 4007 psi Thanks for your time- sorry we didn't catch this sooner. Jake Flora Drilling Engineer Conoco Phillips Alaska Inc. Office: 907265-6040 1 of 1 3/31/20053:16 PM ~lI . rmo ~.. lA\ n ~ ~IW Æ\ LW U LnJ L6 IrJ @ U~ ¡rJ . AI.ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk 3H-14B ConocoPhillips Alaska, Inc. Pennit No: 205-021 Surface Location: 1158' FNL, 281' FWL, SEe. 12, TI2N, R8E, UM Bottomhole Location: 1537' FSL, 966' FEL, SEC. 1, T12N, R8E, UM Dear Mr. Thomas: Enclosed is the approved application for pennit to drill the above referenced development well. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. 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 (907 659-3 ager). DATED this2day of February, 2005 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . oC PERMIT TO DRILL It d( \ "6 /ll1...(I· 20 AAC 25.005 : /- -.. .. 1 a. Type of Work: Drill~ Redrill l.fI 1b. Current Well Class: Exploratory U Development Oill:;] MtlltipléiGne'O Re-entry D Stratigraphic Test D Service D Development Gas D Single Zone 0 2. Operator Name: 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 3H-14B 3. Address: 6. Proposed Depth: 12. Field/Pool(s): / P.O. Box 100360 Anchorage, AK 99510-0360 / MD: 8477' rvD: 6428' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1158' FNL, 281' FWL, Sec.12, T12N, R8E, UM ADL 25531 Kuparuk Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1447' FSL, 1210' FEL, Sec. 1, T12N, R8E, UM ALK 2657 2/25/2005 Total Depth: 9. Acres in Property: 14. Distance to > 3 ""-t 'I~ 1537' FSL, 966' FEL, Sec. 1, T12N, R8E, UM / 2560 Nearest Property: ~ .A .c . a,.' 17' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- I / 498655 y- 6000499 Zone- 4 (Height above GL): 44' RKB Well within Pool: 3H-20, 2592' 16. Deviated wells: 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) A " Kickoff depth: 6270' ft. Maximum Hole Angle: 54° Downhole: 4686 psig Surface: 4007 psig 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8.5" 7" 26# J-55 BTCM 6250' 4997' l "'" ~ () "-.) "') 7" 5.5" 15.5# L-80 Hydril 511 1864' 6100' 4854' 7964' 6031' 190 sx Class G 4.75" 3.5" 9.3# L-80 Hydril 511 663' 7814' 5934' 8477' 6428' 70 sx Class G 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re·Entry Operations) Total Depth MD (It): Total Depth TVD (It): Plugs (measured) Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) 7709' 5986' 7697' Casing Length Size Cement Volume MD TVD Structural Conductor 80' 16" 200 sx AS I 115' 115' Surface 3455' 9-5/8" 1350 sx AS III, 400 sx Class G 3455' 3001' Intermediate Production 7685' 7" 800 sx Class G, 175 sx AS I 7685' 5970' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): open hole 7690.5'-7709' 5974'-5986' 20. Attachments: Filing Fee 0 BOP SketchD Drilling Program 0 Time v. Depth Plo!O- Shallow Hazard Analysis Q Property Plat D Diverter Sketch D Seabed Report D Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature , 1 ,~ - Phone ~~'''f 'SO Date .~..( era$'" ..... , . ChM~~ .ð.llclln_n'OIl<-o Commission Use Only Permit to Drill API Number: ~~ Permit APpr~ 0 .- See cover letter Number: .u6-ôZ-1 50- /03 - :;..C>ð9 z. - ð Date: ~;;1-3 ð~ for other requirements Conditions of approval: Samples required DYes Hf'Jo Mud log required DYes K No )£;'0900 "lffd. meas",~ gVe' D No 0;,.,"_, '"NO, œq"'œd ~Yes D No Other:~O ;.Y; ~~~,,>\. ::r~\\\t.~\.:4-~\ f'A..~~ 'olè W\~~~<;~. (-r J¡V"Æ" .-...,'" \ .ç." 00"\.,,-.- "".. \ \ ~ '\ ~){"'-i<;'. #'~/Df APPROVED BY I Appruv=r-q¡ . J . THE COMMISSION Date: '-/V T , Form 10-401 Revised 6/2004 OR\G\Nt~L ç Submit in Duplicate · APPlie for Permit to Drill, Well 3H-14B Revision No.O Saved: 10-Feb-05 Permit It - Kuparuk Well 3H..14B Application for Permit to Drill Document Mo):<imizl; W!¡!II VQII,II; Table of Contents 1. Well Name ...... ....... ............ ..................... ................ ..... .................... ...... ..... ........ ....... 2 Requirements of 20 AAC 25.005 (f).... .................................."........... ...................................................... 2 2. Location Sum mary .... ........................... .......................................... ................... ....... 2 Requirements of 20 AAC 25.005(c)(2) ........... ................................ ....... ...... ............. ........... ................... 2 Requirements of 20 AAC 25. 050(b)........ ............... ................................... .......................... .................... 3 3. Blowout Prevention Equipment Information .........................................................3 Requirements of 20 AAC 25.005(c)(3) ... ................. ........... ...... .................... .................... ...... ................ 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program.............................................................................4 Requirements of 20 AAC 25.005(c)(6) .. .................................................. ............................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ...................................... ...... ....................................................... 4 8. Drilling Fluid Program .............................................................................................4 Requirements of 20 AAC 25. 005( c)(B) ................................................................................................... 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................5 1 O. Seism ic Analysis.. .................. .................. .............. ........................................... ....... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................5 11. Seabed Condition Analysis ................................n................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ............................... ................................................................. 5 12. Evidence of Bonding ..........................................".................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ............................... ................................................................. 5 13. Proposed Drilling Program ................................".................................................... 5 3H-148 PERMIT IT. DOC Page 1 of 6 Printed: 10-Feb-05 ORIGIN AiL · APPlie for Permit to Drill, We1l3H-14B Revision No.O Saved: 10-Feb-05 Requirements of 20 AAC 25.005 (c)(13) .................................................................................................5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................6 15. Attachments : ............ .... ............ .......... .................... ........ ...... ................ ........ .... ....... 6 Attachment 1 Drilling Program.................. .................................... ................................... ...................... 6 Attachment 2 Directional Plan ............................................................................................................... 6 Attachment 3 Well Schematic - TOPSET ............................. ................................................................. 6 Attachment 4 Well Schematic - LONGSTRING.................... .................................................................6 Attachment 5 Doyon 15 BOP Schematic.............................. ................................................................. 6 Attachment 6 Doyon 15 Mud System Schematic .................................................................................. 6 Attachment 7 Cementing Details............................................................................................................ 6 Attachment 8 Drilling Hazards Summary...................;.............................................. ......... ......... ....... ..... 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040(b). For a well with multiple well branche~ each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 3H-14B. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to DJiII must be accompanied by each of the fOJïowing items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation and at total depth referenced to governmental section lines. (B) the coordinates of the proposed location of the we/I at the surface. referenced to the state plane coordinate system for this state as maintained by the National Geodetic SUlVey in the National Oceanic and AtmospheJic Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth,' Location at Surface 11158' FNL 281' FWL See 12, T12N, R8E, UM NGS Coordinates RKB Elevation I 83' AMSL Northings: 6,000,499 Eastings: 498,655 ,- Pad Elevation I 39' AMSL Location at Top of Productive Interval Ku aruk C-4 Sand NGS Coordinates Northings: 6,003,104 1447' FSL, 1210' FEL, See 1, T12:N, R8E, UM Eastings: 502,442 Measured De th RKB: Totall/ertical De th RKB: Total Vertical De th 55: 8052' 6092' 6016' Location at Total De 1537' FSL 966' FEL NGS Coordinates Northings: 6,003,194 Eastings: 50~686 See 1 T12~N R8E, UM Measured De th, RKB: Totall/ertical De th RKB: Total Vertical De th 55: 8477' 6428' 6352' and (D) other information required by 20 MC 25.050(b); ORIGIN AIL 3H-14B PERMIT IT,DOC Page 2 of 6 Printed: 10-Feb-05 . APPI. for Permit to Drill, Well 3H-14B Revision No.O Saved: 10-Feb-05 Requirements of 20 AAC 25.050(b) I{a well is to be intentionally deviatec? the application {or a Penmt to Dni~ (Form 10-401) must (1) ;ìlclude a plat drawn to a sUItable scaler show¡ilg the path of the propo::..-ed wellbor~ ;ìlcluding all adjacent wellbores within 200 feet of any portion of the proposed wel!¡' Please see Attachment 2: Directional Plan and (2) for all wells within 200 feet of the proposed well bore (A) list the names of the operators of those wellSr to the extent that those names are known or discoverable in public recordSr and show that each named operator has been furnished a copy of t/le application by certifìed mai¿' or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of tIle following itemSr except for an Item already on fìle with the commission and identífíed in the application: (3) a diagram and description at the blowout prevention equipment (BOP'!:) as required by 20 MC 25.03~ 20 AAC 25.036; or 20 MC 25.03~ as applícable/ Please reference the attached BOP schematic for Doyon 15. Please make the attached schematic the AOGCC file copy if none exists. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application tor a Permit to Drill must be accompanied by each of the following itemSr except for an item already on file with the commission and identified in the application: (4) intormation on drilling hazardSr including . (A) the maximum downhole pressure that may be encounteree¿ criteria used to determine it, and maximum potentia! surface pressure based on a methane gradient/ BHP data on offset injectors indicates that the current reservoir pressure for 3H-14B is between 3300 and 4700 psi. The expected pressure is 3780 psi at 6200' 1VD. "" The expected pressure of 3780 psi at 6200' 1VD converts to a gradient of 0.61 psijft or 11.8 EMW. ,// The maximum pressure of 4700 psi at 6200'1VD converts to a gradient of 0.76 psi/ft or 14.6 EMW. ./ The maximum potential surface pressure (MPSP) while drilling 3H-14B is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk A sand target at 6166' 1VD: MPSP =(6166 ft)*(0.76 - 0.11 psi/ft) = 4007 psi .I (B) data on potential gas zoneSr' The well bore is not expected to penetrate any gas zones between KOP and TD. / and (C) data conceming potential causes of hole problems such as abnormall)/ geo-pressured strata, lost circulation zoneSr and zones that have a propensity tor differential sticking; 1. Large pressure uncertainty in the reservoir will require careful contingency planning for mud v weight changes and potential kicks. 2. Differential sticking is not expected to be a problem. The A and C sands are expected to have J minimal pressure difference. 3H-14B PERMIT IT. DOC Page 3 of 6 Printed: 10-Feb-05 ORIGINAL · APPle for Permit to Drill, We1l3H-14B Revision No.O Saved: 10-Feb-05 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drí/I must be accompanied by each of the fo/lowing item"" except for an item already on file vrlitll the commission and identified in the application: (5) a description of the procedure for conducting formation integrity test"" as required under 20 AAC 25.030(tJ· A procedure is on file with the commission for performing LOT's. For 3H-14B the procedure will be followed after milling the window, with one exception. The formation at the window depth will be pressured until leak-off occurs or to 17 ppg EMW, which ever comes first (see step 6 in the procedure). If a 17 ppg FIT is achieved at the window, a 16.1 ppg FIT at the topset depth will be performed. If 16.1 ppg is not achieved, the well will be topset. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Pem7it to Drill must be acr.:vmpanied by eacll of the fo/lowing item:,~ except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25: 03~ and a description of any s10tted liner;. pre- perforated liner;. or screen to be installeft· TOPSET OPTION CasinQ and Cementing Program I Hole Top Btm CsglTbg Size Weight Length MDITVD MDITVD 00 (in) (in) (Ib/ft) Grade Connection (ti) (ft) (ft) Cement Proqram 7" 8-1/2 26 J-55 BTC-Mod 8192' 44'/44' 8220'/6352' Oriqinal TOC = 5300' MD Window 8-1/2 26 J-55 BTC-Mod NA 6250'/4997' NA NA In the 7" Casinq 5-1/2" 7" 15.5# L-80 Hydril 1864' 6100'/4854' 7964'/6031' 190 sx 15.8 Class "G" Liner 511 3-1/2" 4-3/4" 9.3# L-80 Hydril 663' 7814'/5934' 8477'/6428' 70 sx 15.8 Class "G" Liner 511 3-1/2 9.3# L-80 8RD-Mod 7700' 44'/44' 7814'/5934' Stung into a Baker Tubinq PBR/HGR & ZXP LNR PKR 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of tIle following item"" except for an item already on file with the commission and identified in the application: (7j a diagram and desCliption of the diverter system as required by 20 MC Zi. 03~ unless tliis requirement is waived by the commission under 20 MC 25.035(11)(2)/ This rotary sidetrack will exit pre-existing casing at ± 6250'. BOPE will be installed prior to exiting the casing, and therefore, no diverter is required. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following items, except for an Item already on file with the commission and identified in the application: (8) a drilling fluid progra¡n including a diagram and description or the drilling fluid system, as required by 20 MC Zi. 033/ Drilling will be done using an LSND mud system having the following properties: ORIGINAL 3H-14B PERM/T /T.DOC Page 4 of 6 Printed: 10-Feb-05 . APPle for Permit to Drill, We1l3H-14B . Revision No.O Saved: 11-Feb-05 S·d t k H I d rt· I e rac oemu prope les initial Base Kalubik Kuparuk-TD Density (ppg) 9.8-10.2 10.8 11.8-14.8 Funnel Viscosity 45-55 42-58 42-58 (seconds) Yield Point 11-15 20-25 20-25 (cP) Plastic Viscostiy (lb/100 6-12 8-18 15-25 sf) 10 second Gel Strength 2-5 4-7 4-8 (lb/1 00 sf) 10 minute Gel Strength 4-10 7-12 8-16 (lb/1 00 sf) pH 9-9.5 9-9.5 9-9.5 API Filtrate(cc) <6 <4 <4 Solids (%) 6-11 1 0-15 15-19 //' Please see attached Doyon 15 redesigned mud system schematic. Please place this new mud system schematic on file at AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (9ì for an exploratory or stratigraphic test wel¿ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 2S.033(f); Nj A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items; except for an item already on file with the commission and Identified in the application: (iO) for an exploratory or stratigraphic test we/~ a seismic refraction or reflection analysis as required by 20 MC 2S061(a}; NjA - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following Item.~ except for an Item already on file with the commission and Identified in the application: (11) tor a well drilled from an offshore platform, mobile bottom-founded structure, jackcup rig or floating drilling vesse¿ an analysis of seabed conditions as required by 20 MC 2S061(b); Nj A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Pelmlt to Drill must be accompanied by each of the fO/lowing Items; except for an Item already on file with the commission and Identified ìr¡ the application: (12) evidence showing that the requirements of 20 AAC 25:025- {Bondlng}have been met· Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the fol/owlng Items; except for an item already on tHe with the commission and Identified In the application: See drilling program and well schematics, attachments 1, 3, and 4. 3H-14B PERMIT IT. DOC Page 5 of 6 Printed: 11-Feb-05 ORIGINAL · APPle for Permit to Drill, We1l3H-14B Revision No.O Saved: 10-Feb-05 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a PermIt to Dnll mustc be accompanied by each of the following Item~ except for a/7 Item already 0/7 file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intend,; to request authorization under 20 MC 2.5.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of at KRU's, 1R-18 Class II disposal well. All cuttings will be processed through the Doyon 15 rock washer and then disposed of either at KRU's, 1R-18 Class II disposal well, or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection at the G & I facility on DS-04. 15. Attachments : Attachment 1 Drilling Program Attachment 2 Directional Plan Attachment 3 Well Schematic - TOPSET Attachment 4 Well Schematic - LONGSTRING Attachment 5 Doyon 15 BOP Schematic Attachment 6 Doyon 15 Mud System Schematic Attachment 7 Cementing Details Attachment 8 Drilling Hazards Summary 3H-148 PERMIT IT. DOC Page 6 of 6 Printed: 10-Feb-05 ORIGINAL . . Well 3H-14B Revision No.O Saved: 10-Feb-05 3H-14B Drillina Proaram Pre-Rig Well Work: 1. PT wellhead packoffs (Tubing, IC and oq. Cycle Tubing LDS's 2. MIT IA to 3000 psi 3. File Plug Back Sundry notice. 4. Perform injectivity test into OH section. 5. Pull lower DV at 7629' (if not possible, using E-line tubing puncher & shoot tubing holes at 7645'). 6. Notify AOGCC inspector 24 hours before commencing plug back work. 7. RU CTU and lay in cement from PBTD (7700' approx.) to 250' above top packer to 7425'. Attempt to squeeze in cement if possible. 8. Open IA and pump 6.5 bbls cement down CT string taking returns up the IA to surface. This puts 250' of cement in the IA above the packer. 9. RU Slickline and tag top of cement. PT to 2000 psi with AOGCC witness present. 10. Rig up E-line and cut tubing at approx. 7300'. 11. Set VR and BPV. Remove well house and flowlines. ~~ r-O~ U ;0':/ Rig Work: 1. Notify the AOGCC field inspector 24 hours before spud and BOP test. MI/RU Doyon 15. Install a TWC. ND the upper tree assembly. NU and test the 13-5/8" BOPE to 250# / 3500# Retrieve the TWC. 2. Pull and L/D 3-1/2" tubing hanger. Circulate the well clean with seawater. L/D completion. 3. R/U E-Line. Run a CCL/Gage Ring/Junk Basket to + 6400' (125' below CIBP set point). Run a CCL log from + 6400' up to + 6100'. POOH. 4. MU Baker 7" CIBP. RIH on wireline and set at 6273'. POOH. - ----- ~ r- 5. RIH with Baker's "WindowMaster" whipstock system, bottom trip anchor, MWD, and UBHO on drill pipe ~ 6. :::::: ::~i:~iP:::: a~i:p:::h:::::::k:::ng ::~ :::~ In the 7", 26#, J-55 casing. ~ /!..(S 7. Perform FIT/LOT: Minimum acceptable LOT for topset = 11.5 ppg. Maximum necessary for longstring = (V 17.0 ppg. POOH. d " 8. If FIT is 17.0 ppg, go to LONGSTRING section step 9. If LOT is between 11.5 ppg and 17.0 ppg, go to TOPSET section, step 12. If LOT is less than 11.5 ppg, cement squeeze the window, drill out and retest. 9. LONGSTRING: Directionally drill 6 1/8" hole to topset depth (+/- 7964' MD) according to directional ,/ plan. Run directional, GR, resistivity, and neutron density tools. (Neutron density only possible in longstring option) Perform open hole FIT to 16.1 ppg EMW @ topset point. If leak off occurs below 16.1, go to TOPSET section, step 13. If FIT is achieved, continue to directionally drill 6 1/8" hole to total depth (+/- 8477' MD). Circulate and condition hole. POOH. 10. Run e-line Dipole Sonic. / 11. Run and cement 3.5" 9.3# liner assembly. Go to COMPLETION section step 17. 12. TOPSET: Directionally drill 6 1/8" hole to topset depth (+/- 7964' MD) according to directional plan. Run directional, GR, and resistivity. Circulate and condition hole. POOH. ",/ 3H-148 DRILLING PROGRAM.doc Page 1 of 2 Printed: 10-Feb-OS ORIGINAL . . Well 3H-148 Revision No.O Saved: 10-Feb-05 13. Run hole opener assembly and open hole to 7". 14. Run and cement 5 1/2", 15.5#, L80, HYDRIL 511, R3 liner assembly. v' 15. Directionally drill 4 3/4" hole to total depth (+/- 8477' MD) according to directional plan. Run directional, GR, and resistivity tools. 16. Run and cement 3.5" 9.3# liner assembly. 17. COMPLETION: Run 3.5" 9.3#, L-80, 8 RND MOD tubing. Test tubing, PBR and liner to 3500 psi with the IA open. Bleed the tubing down to 2000 psi. Test the lA, PBR and TOL to 3500 psi. Bleed off all pressures. 18. Displace well with inhibited sea water. 19. Install a TWe. ND BOPE. NU and test the tree to 5000 psi with the IA open. Pull the TWe. Pressure up the IA to + 2500 psi and shear the "RP" valve. Displace the well with diesel freeze protect fluid through the "RP" valve. Install a BPV. RID and M/O Doyon Rig 15. Post-Rig Well Work: 1. Install DV's for perf and frac. 2. Perforate the Kuparuk as directed. 3. Fracture stimulate as directed. 4. Perform CTU clean out. 5. Install gas lift design. 6. Put on production. 3H-148 DRILLING PROGRAM.doc Page 2 of 2 Printed: 10-Feb-05 ORIGINAL 3-1/8- ( 2-1/16- ADAPT. flANGE 2-1/16- MANUAL - 2-1/16- HCR C.:J ;0 ~~:Ð ~~ """"~ ~= ~~ ~~ r J'I" +-~ J' I-J/8" J/8" J/S" 2' ,/.. J/"~ ,,' '"'I" I 11'2" J- MUD CROSS J~ 1 /8- HCR 3-1/8- MANUAL "'" 134M RISER SPOOL 2'0· - __ 2-1/16" MANUAL J/B" 7 1/16" BQE STACK ARRANGEMENT (SM) 7-1/16- ( 4-1/16" XO SPOOL 7-1/16" TEST SPOOL ADAPT. FlANGE TUBING SPOOL CASING SPOOL "" ':If: '11'. "'. '" """"""" . . ~è~~~~~~~Of ~yon "'""'" """""'OY LEA 'tv. DWG. NO. .... c=} """J~i #-'\;' ) ø--~: G-) ~~" I i I r::::::I--I' ·ì , , ! I i ¡'...... ...l, 1 J 5/8". 5000 PSI, HYDRIL ANNULAR BOP STUDOED TOP/FLANGED BOTTOM :~ ,::Ç" s. I' '0" ; '/I~t-·~·:~~~~·__·_·_·~· t :3 1/8" 5000 PSI HCR VALVE J 3/8.r----~-1LL5-0.Q2. PSI~ VALVE 1'103/4" _ l flANGE BOTTOM/FlANGE TOP BX 160 - 135/8", 5000 PSI,1Q" MPL OPERATORS HYORll PIPE RAM flANGE BOTTOM/STUDDED TOP BX 160 _ 13 5/8", 5000 PSI, 14"MPl OPEARTORS, HYDRIl BUND/SHEAR RAM ~T~~~~D 5~8r~~(~tt~G~ALW' ex 160 2" KILL UNE J 1/8" 5000 PSI GATE VALVE FLANGE BOTTOM/STUDDED TOP ex 160 _135/8",5000 PSI, 10· MPL OPERATORS, HYORIl PIPE RAM STUDDED BOTTOM/fLANGE TOP ex 160 ADAPTER SPOOL fLANGE/FlANGE BOP STACK WELLHEAD ~::~~¡~i~-1::~~~ " ~ltf" i I BOP STAC~ ELEVATION 12" 150 PSI HYDR OPERATED KNIFE GATE VALVE 4'J" ~'I"!--. " 3 15/tll" t--- .__1_. 12" flG'a VENT LINE 21 1/4" 2000 PSI, MSP HVORIL BOP /DNERTER STUDDED TOP/fLANGED BOTTOM ftANGE/HANGE RX 73 /:~U~H~~~~N~~~\I~) 21 1/4" 2000 PSI FLANGE SURFACE DIVERTER CONFIGURATION ACCUMULATOR: TRIPLEX PUMP: AIR PUMP: KOOMEY, 180 GAL. 6 STATION 575 VAC. 25 HP NATIONAL F SERIES. NL SHAFFER ,- ACCUMULATOR MANIFOLD 16 BOTTLES, 10 GALLONS EACH NITROGEN BACKUP BOTTLES 4 BOTTLES, 3000 PSI 11-2B-9 .." , RtV. ... NO. "' DRAWN TO AUTOCAD APPR. "' D£SCAIPTfQN VALVE LEGEND 1 BYPASS 2 KILL 3 CHOKE 4 BOTTOM RAMS 5 BLIND RAMS 6 TOP PIPE RAMS 7 ANNULAR O· 0' O· ./. ../../. .. .. ,. IMANI~OLO PR!:.SSUREJIACCUMULA1OR PRE.SSUREIIANNULAR PRE.SSURE. I ~ ~ I~N:~:f ::~~:,1 M C£;:J REMOTE PANEL IN DOGHOUSE AND UTILITY MODULE ~ I~ ~~~~ ~~~F~~J:J~~u~~~~tV~. Of ~.,yon RIG 15 BOP SYSTEM AND CONTROL LEA ,,,. 2 SHT. . . ?'\i\? ~\\--\-- '0\>\--'¿ 3'/-.6. 0 1 ~ ~ ~~ PIT 112 - - - DEGASER PUMP PIT 111 TRIP TANI< s~'¿~ ~ ~\F? ?\S~\? ~ ,\~þ.~ (þ<¡':~<¡'<'S t>\<¡'" ~\),,~ c,~ .:;'f..b b \~C- S ,?\\'<J\'? c,'0~?-\\) y\'? "j'/-.G '!A'? ,*,C- '<J\\'f.. '?~\)\) '0? 'o-¡..'ò ---:a _1_'_..__..__ ·\·r"....·_· 1- PIT liS H I PIL.L PIT --.1--41 L ======== "õ<;i;:.~"=~~)\) ~,,:,'.'_.~.;.."''''''' :~ 0 :1m: CHARGE PUMP DEMCO VALVE (. - <:=<:=1 SUCTION VALVE RISER DOYON 15 SUCTION PIPING DIM STDRAGE DIM STDRAGE ?0V.? ~\'v'v 00> S ':,1-/\ ;AS~S'?- Ù,!\? ,,?-þ; ? \ ,?-0?? ?0V.? ",0~? (;:0 0 (),,(O\Y' G\J 0' v.t>-'"' ~0GS :\,?-\'i b\) "0 G'0~ ,,?-\ \) j.b c,S'"' ~ ( I OJ DOYON 15 DISCHARGE PIPING ,~? '0'2. ?\)\" 0 v.\'/' \)\J 0' \:;/-0 \ C, CCWC::""'"'::!::O-' AUGER DOYON SHAKER *3 4 PANEL 15 MUD TROUGH SHAKER #2 4 PANEL SHAKER #1 4 PANEL / EQUIPMENT SCALPER SHAKER #2 Pi SCALPER SHAKER .. 1 IU' \ "~""" .- -.-,--' ·~,..,...,(,·.i( ~K ',' AUGER \==-~"= , °w 0l::) Iii;:) þ¡ Co: (.)1- <1:% >1.1.I (1)(.) L PI IT , o ORIG ~ L . . DOYON O"-o~- '-I¿' '-1.\- ··oa :r-5Ì '7~' '-7¿ PIT #5 PILL PIT #1 PILL PIT ~2 PIT #4 PIT #3 PIT #2 _ LI\IIL _ LI\IIL _ LI\IIL _ LI\IIL _ LI\IIL _ LI\IIL 144M .... 12"-'¿- -.. 12"·'t 11M .... 12"-'¡- -.. 12""¡- ~.. -.. La .. UI.. .7'S" 1M .... 1.6 .. ... -'i' ''I'S'' 12""¡- -- -- -- -- -- -- I'-~~' '-s~ '-lIt 26'·i í' - ~·-s¡..... 6'-O~- DBH -IIi- 7'-0t STORAGE PIT #1 _ LI\IIL _ LI\IIL - .... /61:11 .. .... ..... -- -- .ut 12"'3ii- , TRIP TANK 7'-O¡' :-..LI\IIL .',oii- DBH .'IS .... STORAGE -- _ LI\IIL - .... .... -- - ---i!'-lIi'- 15 PIT VOLUMES 7ii' Rig: Doyon 15 Location: Kuparuk Client: CPAI Revision Date: 2/09/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Top ofTail at < 5,900' MD < Liner Top at 6,100' MD Previous Csg. 7", 26.0# casing at 6,250' MD < 51/2", 15.5# casing in 6 1/8" OH TD at 7,964' MD (6,031' rvD) Preliminary Job Design based on limited input data. For estimate purposes only. Sch b8PgØP Volume Calculations and Cement Systems Volumes are based on 160% excess. Displacement is calculated with a 4.0"- 14.0# drill string. Tail Slurry Minimum thickening time: 120 min. (pump time plus 90 min.) 15.8 ppg Class G + 2.0 gps D600G + 0.03% B155 + 0.35% 065 + 0.2 gps 047 -1.17 ft3/sk Liner Cap: 3 0.1276 ft 1ft x 200' x 1.00 (no excess) = Liner Lap.: 3 0.0498 ft 1ft x (6250' - 6100') x 1.00 (no excess) = Annular Volume: 3 0.0396 ft 1ft x (7964' - 6250') x 2.60 (160% excess) = Shoe Volume: 3 0.1336 ft 1ft x 80' x 1.00 (no excess) = Totals: 25.5 ft3 + 7.5 ft3 + 176.5 ft3 + 12 ft3 = 221.5 ft3/1.17 ft3/sk = Round up to 190 sks 25.5 ft3 7.5 ft3 176.5 ft3 12 ft3 221.5 ft3 189.3sks BHST = 140°F, Estimated BHCT = 109°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume (bbl) Cumulative Stage Time Time (min) (min) CW100 5.0 5.0 1.0 1.0 Pause 0.0 0.0 10.0 11.0 CW100 5.0 15.0 3.0 14.0 MUDPUSH /I 5.0 20.0 4.0 18.0 Liner - C 5.0 39.4 7.9 25.9 Pause 0.0 0.0 5.0 33.9 Mud 5.0 40.0 8.0 41.9 Mud 3.0 55.0 18.3 60.2 Mud 2.0 13.0 6.5 66.7 MUD REMOVAL Recommended Mud Properties: 12.0 ppg. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.0 ppg MudPUSH* /I, Centralizers: Recommend 1 % per joint from 6100' MD to TO for proper cement placement. Mark of Schlumberger OR'G Rig: Doyon 15 Location: Kuparuk Client: CPAI Revision Date: 2/10/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Top of Tail at < 7,614' MD < Liner Top at 7,814' MD Previous Csg. 51/2", 15.5# casing at 7,964' MD < 31/2",9.3# casing in 4 3/4" OH TD at 8,477' MD (6,428' rvD) Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 50% excess. Displacement is calculated with a 2.9"-10.4# drill string. Tail Slurry Minimum thickening time: 110 min. (pump time plus 90 min.) 15.8 ppg Class G + 2.0 gps D600G + 0.03% B155 + 0.35% 065 + 0.2 gps 047 -1.17 ft3/sk ~ Liner Cap: 3 0.0886 ft 1ft x 200' x 1.00 (no excess) = Liner Lap.: 3 0.0668 ft 1ft x (7964' - 7814') x 1.00 (no excess) = Annular Volume: 3 0.0562 ft 1ft x (8477' - 7964') x 1.50 (50% excess) = Shoe Volume: 3 0.0488 ft 1ft x 80' x 1.00 (no excess) = Totals: 17.7 ft3 + 10 ft3 + 43.2 ft3 + 4.4 ft3 = 75.3 ft31 1.17 ft3/sk = Round up to 70 sks 17.7 ft3 10 ft3 43.2 ft3 4.4 ft3 75.3 ft3 64.4 sks BHST = 151°F, Estimated BHCT = 11roF. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume (bbl) Cumulative Stage Time Time (min) (min) CW100 3.0 10.0 3.3 3.3 MUDPUSH II 3.0 10.0 3.3 6.6 Line 3.0 13.4 4.5 11.1 Pause 0.0 0.0 5.0 16.1 Mud 3.0 40.5 13.5 29.6 MUD REMOVAL Recommended Mud Properties: 13.0 ppg, As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.5 ppg MudPUSH* II Centralizers: Recommend 1 Y2 per joint from 7791' MD to TD for proper cement placement. Mark of Schlumberger R! '{ . · . 3H-14B Drilling Hazards Summary, 6-1/8" Hole (Opened to 7" - If Topset) / 3.5" Casin9 Interval (5.5" - If TODset) Event Risk Level Mitigation Strategy Shale stability in HRZ and K-l Low Control with hiqher MW and proper drillinq practices. High ECD and swabbing with close High Condition mud prior to trips. Monitor ECD's with PWD tolerance annuli and higher MW's tool while drilling across pay interval. Pump and rotate required out on trips as a last resort. Use Auto Fill float equipment on casinq if available. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud vi weight as needed. Ensure adequate kick tolerance prior to drillinq pav interval. Have spike fluid available.\/'"' Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 4-3/4" Hole / 3-1/2" Liner Interval lIfTopset) Event Risk Level Mitigation StrateGY High ECD and swabbing with close High Condition mud prior to trips. Monitor ECD's with PWD tolerance annuli and higher MW's tool while drilling across pay interval. Pump and rotate required out on trips as a last resort. Use Auto Fill float equipment on casinq if available. Abnormal Reservoir Pressure Moderate v Follow mud weight schedule and do not fall behind. Stripping tfrTIfs, shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance prior to drillinq pav interval. Have spike fluid available. ~ Differential Sticking Low Wiper trips as needed. Do not leave pipe static for extended period of time. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, Use LC decision tree. 3H-14B Drilling Hazards Summary 1028 BASE DOCUMENT. doc prepared by Scott Lowry 11/18/04 OR'G'~tAL Page 1 of 1 . Co~illips ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 3H Pad Plan: 3H-14 Plan 3H-14 8 Plan: Plan: 3H-148 (wp05) Standard Planning Report 03 February, 2005 ORIGINAL . 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 (650 ft/in) -650 2275 o l() ~ 3250 3575 2600 2925 -325 325 625 950 650 975 300 Dir Whipstock Set: Begin Dir @ 15.9 DLS: 6250,000ft Target FEL, End Dir, Start Sail @ 54.000: 6546.260ft MD, Minimum Curvature ISCWSA Elliptical Conic Rules Based Trav. Cylinder North ¡Iii Calculation Method: Error System: Scan Method: Error Surface: Warning Method: ~/ ConocoPhillips Engineering Kuparuk Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based 475 950 1900 2375 0 !.O 2850 ~ .s::; ã. (J) 0 3325 ëi3 ü :¡:;; (¡j > 3800 (J) :::¡ ¡.:: 4275 4750 sun . . ~illips SPERRY_SUN HES Planning Report EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 3H Pad Plan: 3H-14 Plan 3H-14 B Plan: 3H-14B (wp05) Well Plan: 3H-14 Elev: 76 @ 76.0oof! (WBP) Elev: 76 @ 76.000f! (WBP) True Minimum Curvature Kuparuk River Unit, North Slope Alaska, United States Map System: Geo Datum: Map Zone: US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Kuparuk 3H Pad 0.000f! Northing: Easting: Slot Radius: 6,000,110.730ft 498,655.440ft 0" Latitude: Longitude: Grid Convergence: 70' 24' 41.531" N 150' 00' 39.416" W -0.01 ' Site Position: From: Position Uncertainty: Map Well Position Uncertainty 0.000f! 0.000f! 0.000f! Northing: Easting: Wellhead Elevation: 6,000,499.140 f! 498,655.510 II f! Latitude: Longitude: Ground Level: 70' 24' 45.352" N 150' 00' 39.416" W 0.00011 Well Position +N/-S +E/-W Plan 3H-14 B 6,250.000 44.820 42.834 4,997.546 1,986.793 2,503.279 0.00 0.00 0.00 0.00 6,270.000 47.111 45.903 5,011.449 1,997.063 2,513.336 15.90 11.45 15.34 45.00 6,546.259 54.000 65.500 5,187.880 2,114.651 2,688.930 6.00 2.49 7.09 72.02 7,746.259 54.000 65.500 5,893.223 2,517.244 3,572.339 0.00 0.00 0.00 0.00 8,041.990 45.045 69.714 6,085.000 2,603.004 3,779.998 3.22 -3.03 1.42 160.30 3H-14 B Top of Kupar 8,061.990 45.045 69.714 6,099.131 2,607.911 3,793.274 0.00 0.00 0.00 0.00 8,107.797 39.548 69.714 6,133.000 2,618.594 3.822.178 12.00 -12.00 0.00 180.00 8,129.034 37.000 69.714 6,149.671 2,623.155 3,834.516 12.00 -12.00 0.00 180.00 8,272.189 37.000 69.714 6,264.000 2,653.025 3,915.325 0.00 0.00 0.00 0.00 8,273.515 36.953 69.636 6,265.059 2,653.302 3,916.073 5.00 -3.54 -5.87 -135.08 8,477.414 36.953 69.636 6,428.000 2,695.955 4,030.988 0.00 0.00 0.00 0.00 3H-14 B TD 2/3/2005 7:15:37AM Page 2 of 6 COMPASS 2003.11 Build 50 ORIGINAL . . CooocJ'Pt,illips SPERRY_SUN HES Planning Report 100.000 0.230 183.510 100.000 -0.240 -0.022 -0.151 0.00 0.00 0.00 200.000 0.220 167.900 199.999 -0.628 0.006 -0.341 0.06 -0.01 -15.61 300.000 0.200 156.480 299.998 -0.976 0.116 -0.441 0.05 -0.02 -11.42 400.000 0.340 140.800 399.997 -1.366 0.373 -0.441 0.16 0.14 -15.68 500.000 0.390 130.760 499.995 -1.818 0.818 -0.319 0.08 0.05 -10.04 600.000 0.470 113.810 599.992 -2.206 1.451 -0.004 0.15 0.08 -16.95 700.000 0.550 105.180 699.988 -2.497 2.290 0.535 0.11 0.08 -8.63 800.000 0.630 104.110 799.983 -2.757 3.286 1.224 0.08 0.08 -1.07 900.000 0.600 108.070 899.977 -3.053 4.317 1.921 0.05 -0.03 3.96 1,000.000 0.740 95.450 999.971 -3.277 5.458 2.750 0.20 0.14 -12.62 1,100.000 0.810 96.290 1,099.961 -3.416 6.803 3.796 0.07 0.07 0.84 1,200.000 2.040 81.570 1,199.929 -3.232 9.266 5.953 1.27 1.23 -14.72 1,300.000 6.220 69.010 1,299.649 -1.030 16.088 12.860 4.25 4.18 -12.56 1,400.000 10.020 65.880 1,398.628 4.468 29.091 26.741 3.82 3.80 -3.13 1,500.000 13.800 65.460 1,496.458 12.980 47.887 47.117 3.78 3.78 -0.42 1,600.000 17.700 63.000 1 ,592.686 24.839 72.291 74.017 3.96 3.90 -2.46 1,700.000 20.610 59.470 1,687.142 40.686 101.003 106.709 3.13 2.91 -3.53 1,800.000 25.540 60.610 1,779.114 60.218 134.966 145.815 4.95 4.93 1.14 1,900.000 30.330 61.330 1,867.436 82.924 175.926 192.508 4.80 4.79 0.72 2,000.000 34.200 59.630 1,951.981 109.257 222.346 245.756 3.97 3.87 -1.70 2,100.000 36.900 58.900 2,033.334 138.979 272.309 303.828 2.73 2.70 -0.73 2,200.000 40.580 55.420 2,111.330 172.962 324.818 366.372 4.27 3.68 -3.48 2,300.000 42.870 51.740 2,185.971 212.498 378.323 432.805 3.35 2.29 -3.68 2,400.000 43.530 51.070 2,258.868 255.202 431.823 500.980 0.80 0.66 -0.67 2,500.000 44.060 49.110 2,331.053 299.605 484.900 569.737 1.46 0.53 -1.96 2,600.000 44.880 49.590 2,402.414 345.239 538.050 639.234 0.89 0.82 0.48 2,700.000 44.960 49.640 2,4 73.224 390.990 591.835 709.325 0.09 0.08 0.05 2,800.000 45.390 49.620 2,543.718 436.930 645.872 779.730 0.43 0.43 -0.02 2,900.000 45.870 49.990 2,613.647 483.065 700.475 850.715 0.55 0.48 0.37 3,000.000 45.910 50.540 2,683.251 528.962 755.690 922.080 0.40 0.04 0.55 3,100.000 46.150 50.670 2,752.679 574.639 811.308 993.660 0.26 0.24 0.13 3,200.000 46.060 51.650 2,822.014 619.832 867.434 1,065.398 0.71 -0.09 0.98 3,300.000 45.780 53.120 2,891.582 663.677 924.334 1,137.038 1.09 -0.28 1.47 3,400.000 44.950 54.760 2,961.842 705.567 981.850 1,208.117 1.43 -0.83 1.64 3,500.000 44.170 56.300 3,033.096 745.282 1,039.688 1.278.266 1.33 -0.78 1.54 3,600.000 44.360 56.330 3,104.707 783.994 1,097.767 1,348.063 0.19 0.19 0.03 3,700.000 44.440 56.400 3,176.155 822.749 1,156.020 1,418.029 0.09 0.08 0.07 3,800.000 44.560 56.570 3,247.480 861.450 1,214.457 1,488.120 0.17 0.12 0.17 3,900.000 44.680 56.800 3,318.658 900.029 1,273.154 1,558.359 0.20 0.12 0.23 4,000.000 44.500 54.080 3,389.879 939.843 1,330.959 1,628.535 1.92 -0.18 -2.72 4,100.000 44.500 51.070 3,461.212 982.430 1,386.608 1,698.439 2.11 0.00 -3.01 4,200.000 44.630 50.950 3,532.458 1,026.581 1,441.149 1,768.280 0.15 0.13 -0.12 4,300.000 44.810 50.840 3,603.513 1,070.963 1 ,495.751 1,838.299 0.20 0.18 -0.11 4,400.000 44.700 50.780 3,674.526 1,115.454 1,550.321 1,908.350 0.12 -0.11 -0.06 4,500.000 44.780 50.710 3,745.556 1,159.994 1,604.825 1,978.375 0.09 0.08 -0.07 4,600.000 44.830 50.660 3,816.507 1,204.643 1,659.345 2,048.472 0.06 0.05 -0.05 4,700.000 44.850 50.660 3,887.415 1,249.343 1,713.880 2,118.609 0.02 0.02 0.00 4,800.000 44.710 50.570 3,958.397 1,294.038 1,768.322 2,188.667 0.15 -0.14 -0.09 4,900.000 44.250 50.300 4,029.746 1,338.667 1,822.336 2,258.331 0.50 -0.46 -0.27 5,000.000 43.900 50.070 4,101.589 1,383.207 1,875.766 2,327.458 0.38 -0.35 -0.23 5,100.000 43.650 50.010 4,173.795 1,427.640 1,928.793 2,396.191 0.25 -0.25 -0.06 5,200.000 43.310 49.940 4,246.357 1,471.893 1,981.486 2,464.545 0.34 -0.34 -0.07 5,300.000 43.040 49.830 4,319.283 1,515.980 2,033.812 2,532.502 0.28 -0.27 -0.11 5,400.000 43.990 47.670 4,3(j1.806 1,561.381 2,085.565 2,600.704 1.7.6 0.95 -2.16 2/3/2005 7:15:37AM Page 3 of 6 COMPASS 2003.11 Build 50 ORIGINAL . Conoc;p.,illips SPERRY_SUN HES Planning Report . 5,500.000 45.110 45.100 4,463.075 1,609.776 5,600.000 44.640 45.060 4,533.939 1,659.597 5,700.000 44.550 44.960 4,605.148 1,709.234 5,800.000 44.540 44.690 4,676.418 1,758.987 5,900.000 44.370 44.180 4,747.798 1,808.995 6,000.000 44.410 43.870 4,819.258 1,859.294 6,100.000 44.410 43.380 4,890.693 1,909.950 6,200.000 44.600 43.040 4,962.012 1,961.040 6,250.000 44.820 42.834 4,997.546 1,986.793 Whipstock Set: Begin Dir@15.9 DLS: 6250.000ftMD,4997.546ft TVD 6,270.000 47.111 45.903 5,011.449 1,997.063 Continue Dir @ 6.00 DLS: 6270.01 Oft MD, 50n.455ft TVD 6,300.000 47.689 48.216 5,031.756 6,400.000 49.939 55.611 5,097.654 6,500.000 52.627 62.490 5,160.240 6,546.259 54.000 65.500 5,187.880 .End Dir, start Sail@ 54.000: 6546.26Oft MD, 5187.88Oft TVD 6,600.000 54.000 65.500 5,219.469 6,700.000 54.000 65.500 5,278.247 6,800.000 54.000 65.500 5,337.026 6,900.000 54.000 65.500 5,395.804 7,000.000 54.000 65.500 5,454.583 7,100.000 54.000 65.500 5,513.361 7,200.000 54.000 65.500 5,572.140 7,300.000 54.000 65.500 5,630.918 7,400.000 54.000 65.500 5,689.697 7,500.000 54.000 65.500 5,748.475 7,600.000 54.000 65.500 5,807.254 7,700.000 54.000 65.500 5,866.032 7,746.259 54.000 65.500 5,893.223 Begin Pir@3.24 DLS: 7746.30Oft MD,5893.247ft TVP 7,756.053 53.705 65.642 5,899.000 TOp Kalubik 7,800.000 7,900.000 7,923.560 K-1 EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit 52.374 49.346 48.635 66.265 67.690 68.035 5,925.424 5,988.540 6,004.000 2,012.103 2,058.395 2,098.398 2,114.651 2,132.681 2,166.230 2,199.780 2,233.329 2,266.878 2,300.428 2,333.977 2,367.526 2,401.076 2,434.625 2,468.175 2,501.724 2,517.244 2,520.514 2,534.824 2,565.158 2,571.857 2,136.335 2,186.295 2,235.948 2,285.398 2,334.429 2,383.044 2,431.325 2,479.318 2.503.279 2,513.336 2,529.501 2,588.708 2,655.593 2,688.930 2,728.492 2,802.110 2,875.727 2,949.344 3,022.962 3,096.579 3,170.197 3,243.814 3,317.432 3,391.049 3,464.666 3,538.284 3,572.339 3,579.539 3,611.605 3,682.975 3,699.442 2,669.735 2,738.876 2,807.659 2,876.336 2,944.804 3,013.085 3,081.284 3,149.482 3,183.665 3,197.716 3,219.493 3,294.407 3,372.264 3,409.041 3,451.992 3,531.914 3,611.837 3,691.759 3,771.681 3,851.604 3,931.526 4,011.448 4,091.371 4,171.293 4,251.216 4,331.138 4,368.109 4,375.921 4,410.566 4,486.841 4,504.275 2.12 0.47 0.11 0.19 0.40 0.22 0.34 0.30 0.53 15.90 5.99 6.00 6.00 6.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.24 3.23 3.22 3.21 1.12 -0.47 -0.09 -0.01 -0.17 0.04 0.00 0.19 0.44 11.45 1.93 2.25 2.69 2.97 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -3.02 -3.03 -3.03 -3.02 -2.57 -0.04 -0.10 -0.27 -0.51 -0.31 -0.49 -0.34 -0.41 15.34 7.71 7.39 6.88 6.51 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.45 1.42 1.42 1.46 8,000.000 46.318 69.115 6,055.664 2,592.441 3,751.876 4,559.375 3.21 -3.03 1.41 8,041.990 45.045 69.714 6,085.000 2,603.004 3,779.998 4,588.665 3.20 -3.03 1.43 Target (Top Kuparuk) :8041.99Oft MD,6085.000ftTVD, (3836ft FNL,1217ft FEL, Sec1-T12N'R8E- TopD -3H-14 BTop of Kuparuk 8,051.897 45.045 69.714 6,092.000 2,605.434 3,786.575 4,595.493 0.00 0.00 0.00 Top C4 8,061.990 45.045 69.714 6,099.131 2,607.911 3,793.274 4,602.448 0.00 0.00 0.00 8,073.001 43.724 69.714 6,107.000 2,610.581 3,800.498 4,609.948 12.00 -12.00 0.00 TopB 8,100.000 40.488 69.714 6,127.029 8,107.797 39.548 69.714 6,133.000 3H"14 B A3 Penetration 8,108.000 39.548 69.714 6,133.157 Begin Dir @ 12.00 DLS:8108.00Oft MD,6133.157ft TVD 8,129.034 37.000 69.714 6,149.671 8,139.463 37.000 69.71±--......J3,.1.§8.00Q.. 2,616.856 2,618.594 2,618.639 3,817.475 4,627.575 3,822.178 4,632.457 3,822.299 4,632.583 2,623.155 3,834.516 4,645.266 2,625.:33.1-..-__ 3,840.4Q.L 4,651.378 11.99 -11.99 12.05 -12.05 0.00 0.00 12.12 -12.12 0.00 0.00 ~ COMPASS 2003.11 Build 50 . 0.00 0.00 0.00 2/3/2005 7:15:37AM 0.00 0.00 Page 4 of 6 ORIGINAL . . ConocJ'Phillips SPERRY_SUN HES Planning Report TopA6 8,144.472 37.000 69.714 6,162.000 2,626.376 3,843.230 4,654.314 0.00 0.00 0.00 Top AS 8,149.480 37.000 69.714 6,166.000 2,627.421 3,846.057 4,657.249 0.00 0.00 0.00 Top A3 8,178.279 37.000 69.714 6,189.000 2,633.430 3,862.314 4,674.127 0.00 0.00 0.00 Top A'}, 8,200.000 37.000 69.714 6,206.347 2,637.962 3,874.575 4,686.857 0.00 0.00 0.00 8,218.348 37.000 69.714 6,221.000 2,641.790 3,884.932 4,697.610 0.00 0.00 0.00 Top A1 8,272.189 37.000 69.714 6,264.000 2,653.025 3,915.325 4,729.164 0.00 0.00 0.00 3H.14 BBase ofKupaurk. 3H·14B Base of Kupaurk Har(lLine 8,273.515 36.953 69.636 6,265.059 2,653.302 3,916.073 4,729.941 5.00 -3.54 -5.87 8,285.955 36.953 69.636 6,275.000 2,655.904 3,923.084 4,737.226 0.00 0.00 0.00 Base A1 8,300.000 36.953 69.636 6,286.224 2,658.842 3,930.999 4,745.451 0.00 0.00 0.00 8,400.000 36.953 69.636 6,366.137 2,679.761 3,987.358 4,804.012 0.00 0.00 0.00 8,477.414 36.953 69.636 6,428.000 2,695.955 4,030.988 4,849.346 0.00 0.00 0.00 TD (BHL)-8468.1UO ft MD, 6427.830 ft TVD; 3743ft FNL& 966ft FEL, Sec1·T12N·R8E . 3H-14B TD 3H-14 B Base of Kupal 0.00 359.99 6,264.000 2,652.830 3,913.404 - plan misses by 1.931ft at 8272.1891t MD (6264.000 ND, 2653.025 N, 3915.325 E) - Polygon SE pt 563.056 -456.046 NW pt -2.000 315.032 3H-14 B A3 Penetratio 0.00 359.99 6,133.000 2,633.000 3,843.000 - plan misses by 25.319ft at 8107.797ft MD (6133.000 TVD, 2618.595 N, 3822.178 E) - Point 6,003,151.000 502,569.000 700 25' 11 .432" N 1490 58' 44.659" W 6,002,695.00 503,132.00 6,003,466.00 502,567.00 6,003,131.185 502,498.600 70025' 11.237" N 149058' 46.723" W 3H-14 B TO - plan hits target - Point 0.00 0.00 6,428.000 2,695.955 4,030.988 6,003,194.100 502,686.580 700 25' 11.855" N 1490 58' 41.210" W 3H-14 B Base of Kupal 0.00 -0.01 6,264.000 2,652.830 3,913.404 6,003,151.000 - plan misses by 1.931ftat 8272.1891t MD (6264.000 ND, 2653.025 N, 3915.325 E) - Point 502,569.000 70025' 11.432" N 1490 58' 44.659" W 3H-14 B Top of Kupal1. - plan hits target - Point 0.00 359.99 6,085.000 2,603.000 3,780.000 6,003,101.199 502,435.600 70025' 10.942" N 149058' 48.571" W 2/3/2005 7:15:37AM Page 50f6 COMPASS200~11BuHd50 ORIGINAL . . Co~illips SPERRY_SUN HES Planning Report 7,756.053 5,899.000 Top Kalubik 0.00 7,923.560 6,004.000 K-1 0.00 8,041.990 6,085.000 Top D 0.00 8,051.897 6,092.000 Top C4 0.00 8,073.001 6,107.000 TopB 0.00 8,139.463 6,158.000 Top A6 0.00 8,144.472 6,162.000 Top A5 0.00 8,149.480 6,166.000 Top A3 0.00 8,178.279 6,189.000 Top A2 0.00 8,218.348 6,221.000 TopA1 0.00 8,285.955 6,275.000 Base A 1 0.00 6,250.000 6,270.010 6,546.259 7,746.300 8,041.990 8,108.000 8,477.400 4,997.546 5,011.455 5,187.880 5,893.247 6,085.000 6,133.157 6,427.989 1,986.793 1,997.068 2,114.651 2,517.257 2,603.004 2,618.639 2,695.952 2,503.279 2,513.341 2,688. 930 3,572.369 3,779.998 3,822.299 4,030.980 Whipstock Set: Begin Dir @ 15.9 DLS: 6250.00Oft MD,4997.546ft TVD Continue Dir @ 6.00 DLS: 6270.01 Oft MD, 5011.455ft TVD End Dir, Start Sail @ 54.000: 6546.260ft MD, 5187.88Oft TVD Begin Dir @ 3.24 DLS: 7746.300ft MD,5893.247ft TVD Target (Top Kuparuk): 8041.99Oft MD, 6085.00Oft TVD, (3836ft FNL, 1217ft FE Begin Dir @ 12.00 DLS: 8108.00Oft MD,6133.157ft TVD TD (BHL)-8468.810 ft MD, 6427.830 ft TVD; 3743ft FNL & 966ft FEL, Sec1-T12 2/3/2005 7:15:37AM Page 6 of 6 COMPASS 2003.11 Build 50 ORIGINAL · . Conoco illips ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 3H Pad Plan: 3H-14 Plan 3H-14 B Plan: 3H-148 (wp05) Travelling Cylinder Report 06 January, 2005 ORIGINAL Conocri'Phillips . SPERRY_SUN HES Anticollision Summary Report Company: ConocoPhillips Alaska Inc. (Kuparuk) LOCal Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Reference Site: Kuparuk 3H Pad MD Reference: Site Error: 0.0000 North Reference: Reference Well: Plan: 3H-14 Survey Calculation Method: Well Error: 0.0000 Output errors are at Reference Wellbore Plan 3H-14 B Database: Reference Design: Plan: 3H-14B (wp05) Offset TVD Reference: . Well Plan: 3H-14 Elev: 76 @ 76.000ft (WBP) Elev: 76 @ 76.000ft (WBP) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Reference Plan: 3H-14B (wp05) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.0000 Error Model: Depth Range: 8,050.000 to 8,477.414ft Scan Method: Results Limited by: Maximum center-center distance of 10,000.000' Error Surface: Warning Levels Evaluated at: 0.00 Sigma ISCWSA Trav. Cylinder North Elliptical Conic Date 2/3/2005 i ! Survey Tool Program From To (ft) (ft) Survey (Well bore) Tool Name 100.000 6,250.000 6,250.000 3H-14 (3H-14) 8,477.414 Plan: 3H-14B (wp05) (Plan 3H-14 B) GCT-MS MWD Description Schlumberger GCT multishot MWD - Standard Summary Site Name Offset Well - WeUbore - Design Kuparuk 3H Pad 3H-10 - 3H-10 Sidetrack 1 - 3H-10 Sidetrack 1 3H-20 - 3H-20 - 3H-20 3H-21 - 3H-21 - 3H-21 Reference Measured Depth (ft) Offset Measured Depth (ft) Distance BetWeen BetWeen Centres Ellipses (ft) (ft) SeJ»lration Factor Warning 8,050.000 76.000 7,626.953 7,480.547 8,067.336 8,675.000 2,591.643 2,353.979 8,051.204 9,425.000 4,248.032 4,007.011 52.094 CC, ES, SF 10.905 CC, ES, SF 17.625 CC, ES, SF CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2/10/2005 3:52:13PM Page 2 of 3 COMPASS 2003.11 Build 50 OR' G\NiAL COMPANY DETAILS: CpnOGoPhilllps Alaska Inc. (Kuparuk) weLl.. DETAU...s: Plan:;!H·14B Ground u.v~l: 0.000 Slot +NI-S +EJ.W Northing Eastíng Latittuáe longitude 400$56.510 10"24'MS.352N 150·0'39A16W 3H·14 MOÒ 6000499.140 Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based Engineering Kuparuk o 3H-21/3H-21 330 30 300 60 90 270 120 210 150 180 ANTI-COLLISION Interpolation Method: Depth Range From: MD Interval: 25Stations 8050 To 8477.414 Maximum Range:10000Plan: Plan: 3H-14B (wp05) o 180 Travelling Cylinder Azimuth (TFO+AZI) ¡oJ vs Centre to Centre Separation 110 ft/inJ SECTlON DETAlLS Travelling Cylinder Azimuth (TFO+AZI) [°1 vs Centre to Centre Separation 12500 ft/inJ '" I 2 3 , , , 7 , , !6 " D1£g TF!1.~'i1 vSœ TugS 0.00 11.00 3183.665 1~96 45.00 3197.716 6.00 12.02 MØ9.041 0.00 ROO 4J68.109 3.22 160.30 <i.~665 3H"14 B Tap GfKuparuk $.00 0.00 4úOO.448 12.00 180.00 4632.451 U.OO 100.00 4645,266 0.00 0,00 4729.164 5.00 ·1.35.00 4129.941 It.OO 0.00 4849.346 3H·¡4BTD 90 . . (; ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 3H Pad Plan: 3H-14 Plan 3H-14 B Plan: 3H-14B (wp05) Sperry-Sun GEO Report 03 February, 2005 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan: 3H-14 Elev: 76 @ 76.000ft (WSP) N True / API - US Survey Feet HALLIBURTON OR I GINAL . . ConocoPhillips Alaska Inc. (Kuparuk) HALLIBURTON Kuparuk River Unit Plan Report for Plan: 3H-14 - Plan 3H-14 B - Plan: 3H-14B (wp05) Measured Sub-System Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth Depth Depth +N/-S +E/-W Northing Easting Rate Section (ft) n e) (ft) (ft) (ft) (ft) (ft) (ft) e 110Oft) (ft) 100.000 0.230 183.510 24.000 100.000 -0.240 -0.022 6,000,498.900 498,655.488 / 0.00 -0.151 200.000 0.220 167.900 123.999 199.999 -0.628 0.006 6,000,498.512 498,655.516 0.06 -0.341 300.000 0.200 156.480 223.998 299.998 -0.976 0.116 6,000,498.164 498,655.625 0.05 -0.441 400.000 0.340 140.800 323.997 399.997 -1.366 0.373 6,000,497.774 498,655.882 0.16 -0.441 500.000 0.390 130.760 423.995 499.995 -1.818 0.818 6,000,497.322 498,656.328 0.08 -0.319 600.000 0.470 113.810 523.992 599.992 -2.206 1.451 6,000,496.934 498,656.961 0.15 -0.004 700.000 0.550 105.180 623.988 699.988 -2.497 2.290 6,000,496.643 498,657.799 0.11 0.535 800.000 0.630 104.110 723.983 799.983 -2.757 3.286 6,000,496.383 498,658.795 0.08 1.224 900.000 0.600 108.070 823.977 899.977 -3.053 4.317 6,000,496.086 498,659.826 0.05 1.921 1,000.000 0.740 95.450 923.971 999.971 -3.277 5.458 6,000,495.862 498,660.966 0.20 2.750 1 ,100.000 0.810 96.290 1,023.961 1,099.961 -3.416 6.803 6,000,495.723 498,662.312 0.07 3.796 1,200.000 2.040 81 .570 1,123.929 1,199.929 -3.232 9.266 6,000,495.906 498,664.775 1.27 5.953 1,300.000 6.220 69.010 1 ,223.649 1,299.649 -1.030 16.088 6,000,498.107 498,671.596 4.25 12.860 1,400.000 10.020 65.880 1 ,322.628 1,398.628 4.468 29.091 6,000,503.602 498,684.598 3.82 26.741 1,500.000 13.800 65.460 1,420.458 1 ,496.458 12.980 47.887 6,000,512.110 498,703.394 3.78 47.117 1,600.000 17.700 63.000 1,516.686 1,592.686 24.839 72.291 6,000,523.964 498,727.798 3.96 74.017 1,700.000 20.610 59.470 1,611.142 1,687.142 40.686 101.003 6,000,539.803 498,756.510 3.13 106.709 1,800.000 25.540 60.610 1,703.114 1,779.114 60.218 134.966 6,000,559.327 498,790.474 4.95 145.815 1,900.000 30.330 61.330 1,791 .436 1,867.436 82.924 175.926 6,000,582.024 498,831.434 4.80 1 92.508 2,000.000 34.200 59.630 1,875.981 1,951.981 109.257 222.346 6,000,608.346 498,877.853 3.97 245.756 2,100.000 36.900 58.900 1,957.334 2,033.334 138.979 272.309 6,000,638.056 498,927.817 2.73 303.828 2,200.000 40.580 55.420 2,035.330 2,111.330 172.962 324.818 6,000,672.026 498,980.327 4.27 366.372 2,300.000 42.870 51.740 2,109.971 2,185.971 212.498 378.323 6,000,711.549 499,033.833 3.35 432.805 2,400.000 43.530 51.070 2,182.868 2,258.868 255.202 431.823 6,000,754.239 499,087.336 0.80 500.980 2,500.000 44.060 49.110 2,255.053 2,331.053 299.605 484.900 6,000,798.628 499,140.415 1.46 569.737 2,600.000 44.880 49.590 2,326.414 2,402.414 345.239 538.050 6,000,844.247 499,193.568 0.89 639.234 2,700.000 44.960 49.640 2,397.224 2,473.224 390.990 591 .835 6,000,889.984 499,247.356 0.09 709.325 2,800.000 45.390 49.620 2,467.718 2,543.718 436.930 645.872 6,000,935.910 499,301.396 0.43 779.730 2,900.000 45.870 49.990 2,537.647 2,613.647 483.065 700.475 6,000,982.030 499,356.002 0.55 850.715 3,000.000 45.910 50.540 2,607.251 2,683.251 528.962 755.690 6,001,027.913 499,411.219 0.40 922.080 3,100.000 46.150 50.670 2,676.679 2,752.679 574.639 811.308 6,001,073.576 499,466.840 0.26 993.660 3,200.000 46.060 51.650 2,746.014 2,822.014 61 9.832 867.434 6,001 ,118.754 499,522.969 0.71 1,065.398 3,300.000 45.780 53.120 2,815.582 2,891.582 663.677 924.334 6,001,162.584 499,579.871 1.09 1,137.038 3,400.000 44.950 54.760 2,885.842 2,961.842 705.567 981.850 6,001 ,204.460 499,637.389 1.43 1,208.117 3,500.000 44.170 56.300 2,957.096 3,033.096 745.282 1,039.688 6,001,244.160 499,695.229 1.33 1,278.266 3,600.000 44.360 56.330 3,028.707 3,104.707 783.994 1,097.767 6,001 ,282.858 499,753.308 0.19 1 ,348.063 3,700.000 44.440 56.400 3,100.155 3,176.155 822.749 1,156.020 6,001 ,321 .598 499,811.562 0.09 1 ,418.029 3,800.000 44.560 56.570 3,171.480 3,247.480 861.450 1 ,214.457 6,001,360.285 499,870.001 0.17 1 ,488.120 3,900.000 44.680 56.800 3,242.658 3,318.658 900.029 1 ,273.1 54 6,001,398.850 499,928.699 0.20 1 ,558.359 4,000.000 44.500 54.080 3,313.879 3,389.879 939.843 1,330.959 6,001,438.650 499,986.505 1.92 1 ,628.535 4,100.000 44.500 51.070 3,385.212 3,461.212 982.430 1,386.608 6,001 ,481 .222 500,042.156 2.11 1 ,698.439 4,200.000 44.630 50.950 3,456.458 3,532.458 1,026.581 1,441.149 6,001,525.359 500,096.700 0.15 1 ,768.280 4,300.000 44.810 50.840 3,527.513 3,603.513 1,070.963 1 ,495.751 6,001,569.727 500,151.304 0.20 1,838.299 4,400.000 44.700 50.780 3,598.526 3,674.526 1,115.454 1,550.321 6,001,614.203 500,205.876 0.12 1,908.350 4,500.000 44.780 50.710 3,669.556 3,745.556 1,159.994 1,604.825 6,001,658.729 500,260.383 0.09 1,978.375 4,600.000 44.830 50.660 3,740.507 3,816.507 1 ,204.643 1,659.345 6,001,703.364 500,314.906 0.06 2,048.472 4,700.000 44.850 50.660 3,811.415 3,887.415 1,249.343 1,713.880 6,001,748.049 500,369.443 0.02 2,118.609 4,800.000 44.710 50.570 3,882.397 3,958.397 1,294.038 1,768.322 6,001,792.731 500,423.888 0.15 2,188.667 4,900.000 44.250 50.300 3,953.746 4,029.746 1,338.667 1,822.336 6,001,837.345 500,477.904 . 0.50 2,258.331 5,000.000 43.900 50.070 4,025.589 4,101.589 1,383.207 1,875.766 6,001,881.871 500,531.337 0.38 2,327.458 5,100.000 43.650 50.010 4,097.795 4,173.795 1,427.640 1,928.793 6,001,926.290 500,584.367 0.25 2,396.191 5,200.000 43.310 49.940 4,1 70.357 4,246.357 1,471.893 1,981.486 6,001,970.529 500,637.062 0.34 2,464.545 5,300.000 43.040 49.830 4,243.283 4,319.283 1,515.980 2,033.812 6,002,014.602 500,689.391 0.28 2,532.502 5,400.000 43.990 47.670 4,315.806 4,391.806 1,561.381 2,085.565 6,002,059.990 500,741.147 1.76 2,600.704 5,500.000 45.110 45.100 4,387.075 4,463.075 1 ,609.776 2,136.335 6,002,108.371 500,791 .921 2.12 2,669.735 5,600.000 44.640 45.060 4,457.939 4,533.939 1,659.597 2,186.295 6,002,158.178 500,841.885 0.47 2,738.876 5,700.000 44.550 44.960 4,529.148 4,605.148 1,709.234 2,235.948 6,002,207.801 500,891.542 0.11 2,807.659 5,800.000 44.540 44.690 4,600.418 4,676.418 1,758.987 2,285.398 6,002,257.540 500,940.996 0.19 2,876.336 5,900.000 44.370 44.180 4,671.798 4,747.798 1,808.995 2,334.429 6,002,307.534 500,990.031 0.40 2,944.804 03 February, 2005 - 7:16 Page 2 of 5 COMPASS f1 INAl_ (\ . HALLIBURTON . ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Plan Report for Plan: 3H-14 - Plan 3H-14 B - Plan: 3H-14B (wp05) Measured Depth (ft) Sub-System Depth (ft) Vertical Depth (ft) Inclination CO) Azimuth CO) v~ Local Coordinates +N/-S +E!-W (ft) (ft) 2,383.044 2,431.325 2,479.318 2,503.279 Map Coordinates Northing Easting (ft) (ft) 6,002,357.819 6,002,408.461 6,002,459.538 6,002,485.284 501,038.651 501,086.935 501,134.933 501 ,1 58.896 Dogleg Rate CO/l00ft) Vertical Section (ft) 0.22 0.34 0.30 0.53 3,013.085 3,081 .284 3,149.482 3,183.665 2,513.336 6,002,495.551 501,168.954 2,012.103 2,058.395 2,098.398 2,114.651 6,002,510.586 6,002,556.863 6,002,596.850 6,002,613.095 501,185.120 501 ,244.330 501,311.215 501,344.551 15.90 3,197.716 2,728.492 2,802.110 2,875.727 2,949.344 3,022.962 3,096.579 3,170.197 3,243.814 3,317.432 3,391 .049 3,464.666 3,538.284 3,572.339 3,579.539 3,611 .605 3,682.975 3,699.442 6,002,631.116 6,002,664.649 6,002,698.182 6,002,731.715 6,002,765.247 6,002,798.780 6,002,832.313 6,002,865.846 6,002,899.378 6,002,932.911 6,002,966.444 6,002,999.977 6,003,015.489 6,003,018.758 6,003,033.060 6,003,063.378 6,003,070.074 8,000.000 46.318 69.115 5,979.664 6,055.664 2,592.441 3,751.876 6,003,090.646 8,041.990 45.045 69.714 6,009.000 6,085.000 2,603.004 3,779.998 6,003,101.203 Target (Top Kuparuk) : 8041.9900 MD, 6085.0000 TVD, (3836ft FNL, 1217ft 8,051.897 45.045 69.714 6,016.000 6,092.000 2,605.434 3,786.575 6,003,103.632 TopC4 8,061.990 45.045 69.714 6,023.131 6,099.131 2,607.911 3,793.274 6,003,106.107 8,073.001 43.724 69.714 6,031.000 6,107.000 2,610.581 3,800.498 6,003,108.776 TopB 8,100.000 40.488 69.714 6,051.029 6,127.029 2,616.856 3,817.475 6,003,115.047 8,107.797 39.548 69.714 6,057.000 6,133.000 2,618.594 3,822.178 6,003,116.784 3H·14 B A3 Penètration 8,108.000 39.548 69.714 6,057.157 6,133.157 2,618.639 3,822.299 6,003,116.829 Begin Dir @ 12.00 DLS: 8108.000ft MD,6133.151ft TVD 8,129.034 37.000 69.714 6,073.671 6,149.671 2,623.155 3,834.516 6,003,121.342 8,139.463 37.000 69.714 6,082.000 6,158.000 2,625.331 3,840.403 6,003,123.517 Top A6 501 ,384.113 501,457.729 501,531.345 501,604.961 501,678.578 501,752.194 501 ,825.810 501 ,899.426 501,973.042 502,046.658 502,120.274 502,1 93.890 502,227.944 502,235.145 502,267.210 502,338.578 502,355.045 502,407.477 502,435.599 5.99 6.00 6.00 6.00 3,219.493 3,294.407 3,372.264 3,409.041 6,000.000 44.410 43.870 4,743.258 4,819.258 1,859.294 6,100.000 44.410 43.380 4,814.693 4,890.693 1,909.950 6,200.000 44.600 43.040 4,886.012 4,962.012 1,961.040 6,250.000 44.820 42.834 4,921.546 4,997.546 1,986.793 Wl"lipstockSèt: ·~in Dlr@15.9Dt.S:6250.000ft MD,4997.546ftTVD 6,270.000 47.111 45.903 4,935.449 5,011.449 1,997.063 ContitlljeDir @6.00 DL$:6270.01OftMD, 5011.4~ftTVD 6,300.000 47.689 48.216 4,955.756 5,031.756 6,400.000 49.939 55.611 5,021.654 5,097.654 6,500.000 52.627 62.490 5,084.240 5,160.240 6,546.259 54.000 65.500 5,111.880 5,187.880 ErídD¡r,~tart Sail@54.0QO:65:46.26OftMD,i5187.880ftTVD 6,600.000 54.000 65.500 5,143.469 5,219.469 6,700.000 54.000 65.500 5,202.247 5,278.247 6,800.000 54.000 65.500 5,261.026 5,337.026 6,900.000 54.000 65.500 5,319.804 5,395.804 7,000.000 54.000 65.500 5,378.583 5,454.583 7,100.000 54.000 65.500 5,437.361 5,513.361 7,200.000 54.000 65.500 5,496.140 5,572.140 7,300.000 54.000 65.500 5,554.918 5,630.918 7,400.000 54.000 65.500 5,613.697 5,689.697 7,500.000 54.000 65.500 5,672.475 5,748.475 7,600.000 54.000 65.500 5,731.254 5,807.254 7,700.000 54.000 65.500 5,790.032 5,866.032 7,746.259 54.000 65.500 5,817.223 5,893.223 2,517.244 Begin DW@3.24 DLS: 77l.tì.3ØOft MD,5893.241ftTVD 7,756.053 53.705 65.642 5,823.000 5,899.000 2,520.514 T9ØKåjtibik 7,800.000 7,900.000 7,923.560 K·4 2,529.501 2,588.708 2,655.593 2,688.930 2,132.681 2,166.230 2,199.780 2,233.329 2,266.878 2,300.428 2,333.977 2,367.526 2,401.076 2,434.625 2,468.1 75 2,501.724 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3,451.992 3,531.914 3,611.837 3,691.759 3,771.681 3,851 .604 3,931.526 4,011.448 4,091 .371 4,171 .293 4,251.216 4,331.138 4,368.109 52.374 49.346 48.635 5,849.424 5,912.540 5,928.000 5,925.424 2,534.824 5,988.540 2,565.158 6,004.000 2,571.857 3.21 4,559.375 3.20 4,588.665 3.24 4,375.921 502,442.175 3.23 3.22 3.21 4,410.566 4,486.841 4,504.275 66.265 67.690 68.035 0.00 4,595.493 502,448.874 502,456.098 0.00 4,602.448 12.00 4,609.948 502,473.075 502,477.777 11.99 4,627.575 12.05 4,632.457 502,477.898 0.00 4,632.583 502,490.11 4 502,496.001 12.12 4,645.266 0.00 4,651.378 37.000 69.714 0.00 4,654.314 37.000 69.714 6,086.000 6,162.000 2,626.376 3,843.230 6,003,124.561 8,144.472 Top AS 8,149.480 Top A3 8,178.279 Top A2. 8,200.000 8,218.348 Top Al 502,498.828 6,090.000 6,166.000 2,627.421 3,846.057 6,003,125.606 502,501.656 0.00 4,657.249 6,113.000 6,189.000 2,633.430 3,862.314 6,003,131.611 37.000 69.714 0.00 4,686.857 0.00 4,697.610 69.714 69.714 6,130.347 6,206.347 2,637.962 3,874.575 6,003,136.141 6,145.000 6,221.000 2,641.790 3,884.932 6,003,139.967 37.000 37.000 502,517.912 502,530.172 502,540.529 0.00 4,674.127 03 February, 2005 - 7:16 COMPASS Page 3 of 5 OR\GINAL . . ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit HALLIBURTON Plan Report for Plan: 3H-14 - Plan 3H-14 B - Plan: 3H-14B (wp05) Measured SUb-System Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth Depth Depth +N!-S +E!-W Northing Easting Rate Section (ft) e) e) (ft) (ft) (ft) (ft) (ft) (ft) e/10Oft) (ft) 89 37.000 69.714 8,273.515 6,189.059 6,265.059 2,653.302 502,571.669 4,729.941 8,300.000 36.953 69.636 6,210.224 6,286.224 2,658.842 3,930.999 0.00 4,745.451 8,400.000 36.953 69.636 6,290.137 6,366.137 2,679.761 3,987.358 0.00 4,804.012 ./ 36.953 69.636 Based upon Minimum Curvature type calculations, at a Measured Depth of 8,477.41 ft the Bottom Hole Displacement is 4,849.44ft in the Direction of 56.23° (Grid). Plan Annotations Measured Depth (ft) 6,250.000 6,270.010 6,546.259 7,746.300 8,041.990 8,108.000 8,477.400 Vertical Depth (ft) 4,997.546 5,011.455 5,187.880 5,893.247 6,085.000 6,133.157 6,427.989 Local Coordinates +N!-S +E!-W (ft) (ft) Comment 1,986.793 1,997.068 2,114.651 2,517.257 2,603.004 2,618.639 2,695.952 2,503.279 2,513.341 2,688.930 3,572.369 3,779.998 3,822.299 4,030.980 Whipstock Set: Begin Dir @ 15.9 DLS: 6250.000ft MD,4997.546ft TVD Continue Di r @ 6.00 DLS: 6270.01 Oft MD, 5011.455ft TVD End Dir, Start Sail @ 54.000: 6546.260ft MD, 5187.880ft TVD Begin Dir @ 3.24 DLS: 7746.300ft MD,5893.247ft TVD Target (Top Kuparuk) : 8041.990ft MD, 6085.000ft TVD, (3836ft FNL, Begin Dir @ 12.00 DLS: 8108.000ft MD,6133.157ft TVD TD (BHL)-8468.810 ft MD, 6427.830 ft TVD; 3743ft FNL & 966ft FEL, Sec1- Vertical Section Information Angle Type Target Origin Origin Start Azimuth Type +N!_S +E!-W TVD e) (ft) (ft) (ft) 56.576 0.000 0.000 76.000 User No Target (Freehand) 03 February, 2005 - 7:16 Page 4 of 5 COMPASS RJGINAL . . HALLIBURTON ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit North Reference Sheet for Kuparuk 3H Pad - Plan: 3H-14 - Plan 3H-14 B Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 using datum NAD 1927 (NADCON CONUS), ellipsoid Clarke 1866 .; Projection method is Transverse Mercator (Gauss-Kruger) Central Meridian is -150.00°, Longitude Origin:O.OO°, Latitude Origin:O.OO° False Easting: 500,000.00011, False Northing: 0.00011, Scale Reduction: 0.99990000 Grid Coordinates ot Well: 6,000,499.140, 498,655.510 Geographical Coordinates otWell: 70° 24' 45.35" N, 150000' 39.42" W Grid Convergence at Surface is: -0.010 Magnetic Convergence at surface is: -24.340 (13 December 2004, , BGGM2004) T M Magnetic Model: Date: D ec ¡¡nation: I nc IinationJDip: F ¡eld Strength: 88GM 2004 13-Dec-04 24.33" 80.77" 57569 Grid N or1h is 0 D1 " West ofTrue North (G rid Convergence) MagneticNorth is24.33" East ofTrue North (Magnetic Dedination) Magnetic North is 24 .34" East otG rid North (Magnetic Convergence) To convert a True Direction to a Grid Direction, Add 0.01" To convert a Magnetic Direction to a True Direction, Add 24.33" To convert a Magnetic Direction to a G rid Direction, Add 24.34" 03 February, 2005 - 7:16 Page 5 of 5 COMPASS OR\GI~JAL 3H-14B SIDETRAC.roduce;oPsET3H.14Bschematic CONTINGENCY TOPSET COMPLETION 9-5/8" L80 casing @ 3455' MD I 3001 rvD (Original LOT 12.5 ppg) 5.5" X 7" Liner Top 6100' MD I 4854' rvD Sidetrack KOP @ +1- 6250' MD, +/- 4997 rvD Baker "K-1" CIBP @ +/- 6273' MD 3-%" tbg cut and pulled from +1- 50' above the packer PKR 7674' MD Original Wellbore 7.0" csg 26.0# J-55 7685' MD ·conoc6PhmipS - 3-1/2" 5M FMC Gen IV tubing hanger with 3-1/2" L-80 EUE 8rd pin down Regular Drift 2.867" 3-1/2",9.3#, L-80 EUE 8rd tubing to surface Regular Drift 2.867" Camco TRM-4E SCSSV 5.176" OD x 2.812"10 SIN HVS-378 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to GLM 3-1/2" 9.3# L-80 EUE 8rd Mod tubing as necessary Planned Gas Lift Mandrels 311;," x 1" Cameo 'KBG-2-9' (KBUG above 5.5" Liner) mandrels 3 %" x 6' L-80 handling pups installed above & below. EUE 8RD Mod 1 2 3 4 5 Place gas-lift mandrels at the following planned depths- adjust accordingly at TD TVD MD GL Valve 2650 2951 1.00 3975 4823 1.00 4850 6043 1.00 5450 6992 1.00 5866 7700 1.00 3-1/2" 9.3# L-80 EUE 8rd Mod tubing as necessary 5-'1:." x 7" " LINER ASSEMBLY 5-1/2" X 7" CPH Liner Hanger Packer 5-1/2" X 7" HMC Hydraulic Liner Hanger 5-%" Hydril511 Liner as needed 5-%" Landing Collar One Joint 5-%" Hydril 511 Casing 5-%" Float Collar Two Joints 5-%" Hydril 511 Casing 5-%" Float Shoe 3-'1:." tbg will tie into the 4"x5-'l:." ZXP liner Hanger packer 3 %" Cameo 'D' nipple 2.75" No-Go profile, handling pups installed top and bottom One Joint 3-%" Tubing Bullet Seal Stem with 4-1/8" OD seals Contingent Topset Point 5.5" Liner 7964' MD, 6031' TVD 3.5" Liner 8477' MD 6428' TVD ..¡ OR I C;IN·. AL .. . ~ \,... i . Ii 3-1/2" LINER ASSEMBLY **4" X 5-1/2" ZXP Liner Hanger Packer wI HR Profile and 4-1/8" ID TieBack Sleeve wI 15' stroke 3-1/2" X 5-1/2" HMC Liner Hanger 3-%" Hydril 511 Liner as needed 3-%" Landing Collar One Joint 3-%" Tubing 3-%" Float Collar Two Joints 3-%" 3-%" Float Shoe Production Hole Logging: Longstring - Triple Combo Topset - Gamma Ray/ Resitivity Open Hole Logging: Dipole Sonic if no topset Orawn b PJR 117/05 MDK 1/26/05 3H-14B PROPOSED Š;9D'EllAëKrp;~dA~H~;'~H-14B SidetracklWell Planlsc.csCDiagrams ~Ph.I.I.. - COMPLETION onoco I IpS 9-5/S" L80 casing @ 3455' MD 13001 rvD (Original LOT 12.5 ppg) 3.5" X 7" Liner Top 6100' MD / 4854' TVD Sidetrack KOP +/- 6250' MD +/-4997 TVD Baker "K-1" CIBP @ +/- 6273' MD 3_%" tbg cut and pulled from +/- 50' above the packer PKR 7674' MD Original Wellbore 7.0" csg 26.0# J-55 7685' MD 3-1/2" 5M FMC Gen IV tubing hanger with 3-1/2" L-80 EUE Srd pin down Regular Drift 2.867" 3-1/2",9.3#, L-80 EUE Srd tubing to surface Regular Drift 2.867" Camco TRM-4E SCSSV 5.176" OD x 2.812"'D SIN HVS-37S 3-1/2" 9.3# L-SO EUE 8rd Mod tubing to GLM Planned Gas Lift Mandrels 3}s" x 1" Cameo KBUG mandrels 3 W' x 6' L-80 handling pups installed above & below. EUE 8RD Mod Place gas-lift mandrels at the following planned depths- adjust accordingly at TD 1 2 3 TVD TSO TSO TSO GL Valve TSO TSO TSO MD TSO TSO TSO 3-1/2" 9.3# L-80 EUE 8rd Mod tubing as necessary 3-1/2" Camco 'D' nipple with 2.75" ID profile 3-1/2" Seal Assy, 4.00" OD seals, 17' effective stroke 3-%" tbg will tie into the 80-40 CSR below liner hanger 3-1/2" X 7" LINER ASSEMBLY 5" X 7" ZXP Liner Top Packer' 5" RS Nipple 5" X 7" Flexlock Liner Hanger- 80-40 Casing Sealbore Receptacle, 4.00" ID Sealbore 3-%" Hydril511 Liner as needed 3-%" Landing Collar One Joint 3-%" Tubing 3-%" Float Collar Two Joints 3-%" 3_"%" Float Shoe Production Hole Logging: Longstring - Triple Combo 01 Topset - Gamma Rayl Resitivity Open Hole L099in9: Dipole Sonic if no topset v· 3.5" Liner 8477' MD v' 6428' TVD 01 Drawn by MD K 1/26/05 Drawn by PJR 1/7/05 ORIGINAL conoc~lIips . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com February 10, 2005 Alaska Oil and Gas Conservation Commission 333 West y'h Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, Rotary Sidetrack, Injector 3H-14B Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill/Sidetrack an onshore Injector well, KRU 3H-14B, a development well. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). The expected spud date is February 25, 2005. If you have any questions or require any further information, please contact Pat Reilly at 265-6048. Sincerely, ~t~ Randy Thomas GKA Drilling Team Leader MEMO .:0 ~ . .00 -- o CHASE . a.. a.. .- - 2 .aa.. 7 .1ì0 7g DATE cL $ )tJO. 00 ~/OÞ ~ S,.çutlIyFea!yres DOLLARS I ~=;".." VLA.-" Þ¿ . ¡¡£ ~~-~ _.~-------.--~------- . 2 7 bill .0 gO . . PAVTOTHE ORDER OF. SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 700 G ST. ANCHORAGE AK 99501 1090 . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER PTD# ----L'Development Service WELL NAME klett 3)/-/m 2-Ds-- ó ~ / Exploration Stratigraphic CHECK WßA T ADD-ONS "CLUE"· APPLIÈS (OPTIONS) MULTI The permit is for a new weJlbore ·segment of LATERAL existing weD . Permit No, API No. . (If API number productioD. sbould continue to be reponed as last two. (2) digits a function' of tbe original API number. stated are between 60-69) above. Pfi,OT BOLE In accordance witb· 20 AAC 25.005(1), a1l (PH) records, data and logs acquired 'or the pilot bole must be clearly differentiated In both name (name on permit pJus PH) .. and API Dumber (SO - 70/80) from records, data and Jogs acquired for well (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION " compJiaDce with 20 AAC 25..055~ Approval to perforate and produce is contingent upon issuance of I! conservation order approving a spacing ex cep1ion. (Company Name) assumes tbe liability of any protest totbe spacing . exception tbat may occur. : DRY DITCH AU dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater 1ban 30' .. sample intervals from below tbe permafrost or from where samples are lint caught and ] 0' sample inter:vals tbrough target zones. .. Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNIT 3H-14B Program DEV Well bore seg PTD#: 2050210 Company CONOCOPHILLlPS ALASKA INC Initial Class/Type DEV I PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal 1 P~rmitfee attached. . . . . . . . . . . .Y~s. ...... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 .Leas~.number .appropriate. . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 .U.nique well.n.al)1~.aod o~mb.er . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . _ . . . _ . . . . . . . . . 4 WelUQcat~d in a defil1ed.ppol. . . . . .Y~s .... Kup.aruk River Oil ~Qol, gov.ern~d by COl1servatipo Ord.er No. 432C . . . . . . . 5 WeJUQcat~d proper distaoce. from driJling ul1itb.oul1dal)'. . . . . Yes. ..... WelJborewil[ be.mQre thao 500' frQm exteroal bou.ndary.. . . . . . . . . . . . . . . . . . . 6 WelUQcat~d prpper .distance from otber wells. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . No interweJI restriçtions. . . . . .. ....... . . . . . . . 7 .S.ufficiel1t acreage.ayailable indrilliog unjL . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 Jf.d~viated, js weJlbQre plaUl1cJuded . . . . . . . . .Y~s . . . . . . . . . . . . . . .. ......... . . . . . . . . . 9 .Operator Ol1ly affected party. . . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 .Operator bas.apprppriate.bond inJorce . . . . . . . _ . . . . . . . . . . . . . . . . . _ . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . 11 P~rmit ~o be iss~ed witbQut co.nserva.tiOI1 order. . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Appr Date 12 P~rmitc.an be iss~ed witbQut admil1istratÍlleapprpvaJ . . . . . . .. . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . SFD 2/17/2005 13 Can permit be approved before 15-day wait Yes 14 WelUQcated withil1 area an.d.strataauthorized by.lnjectipo Ord~r # (putlO# in.cpml)1.ents) (For .NA. ....... . . . . . . . . . . . . . 15 .AJI wells. withi.n .1 l4.mile.area.of reyiew id~otified (Fpr servjc.e .well Ol1ly). . . . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 Pre-produced injector; .duratio.n of pre-productipl1 less than. 3 mon.tbs (For service well onJy) . . NA . 17 ACMP Fïn.djng .of Consistency has bee.n issued.fortbis pr.oiect . . . . . . . . . . . . . . . . . . .NA Administration Engineering Appr Date TEM 2/18/2005 )ft?bvt Geology Appr SFD Date 2/17/2005 Geologic Commissioner: ö7G - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 Conductor strin.g.prQvided . . . . . . . . . . . . . . . . . . . . NA . . . . Con.ductorseto.n3H-1.4(187~1.23t . . 19 Surface .casil1g protecJs all. known USDWs . . . . . . . .. .... .NA . . . . All aquifers ex~mpted 40 CfFO 47.102 (b)(3). 20 .CMT. v.ol adequateto circ.ulateoncOl1ductor. & surfcsg .NA . Surface casing cementedin.3H-14.. . . . . . . . . . 21CMT v.ol adequate. to tie-in .!Qngstring to surf csg. No. . Surface ca.si.ng cemented in.3H-14.AII.hydrocarboo zon.es covered. 22CMT.will coyer.all kl10wnprQductiYe borizons . . . . . . . . . Yes. .................. ....... 23 Casing de.signs adec¡uaJe fpr C,.T, B& permafr.ost. . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . 24 Adequatetan.kage.or re.serve pit. . . . . . . . . . . . . . .Y~s . . . . . Rig js.equippe.d.with steelpits. No. rese.rve.pjtplanoe.d. All waste to.apprpveda!'1ouJ~s.Of disposal welJs. . 25 Jf.a.re-drilt hasa. 10A03 fo.r abandon.me.nt be~o approved. .................... .Y~s . .. . . 305~0.10 approved to.pJug3H-16A. 1/19JQ5,.. . . . . . . 26 .Mequate.wellbofeseparatjo.n.P[oj)Qsed...... _........... _.... _......... .Y~s...... .prp~imity.analysispe.rf.orme.d, Nearestw~lIbpre.isabando.nedsection.o.fprjgin.alwell, Npproximjtyiss~es... 27 Jf.djv~rter required, dQes it meet reguJatiol1s. . . . . . . . . . . . . . . . . . . . . . . .NA . . . . BOp stack will alreadybeil1 place, ..... .... . . . . . . . . . . . . 28 .Drilliogflujdprogramschematic&eq.uipJist.adequate......................... Yes. .. .Expectedfprmation.pressur~.1j.].EMW,'pØ$S.ibility.Qf.14.6EMW..MWsplal1ned.11.8o 14.8 ppg. . ...... 29 .BOPEs,.d.othey meetreguJatioo . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ....... . . . . . . 30 .BOPEpfess ratiog appropriate;.test to.(put psig i.n.commel1ts) . . . . . . . . . . . . .Y~s . . . . MASP calcuJate.dat 4007 psi.using 14.8 EMW~ .5000 psi BOP test appropriate. . . . . . . . . . . 31 Choke. manifold cQmpJies w/API. RP-53 (May 64). . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32 WQrk will occur withouLoperationsbutdow.n. . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33 Jspresenceo.fH2Sgas.probable....... ........ .......... Yes. .. . -2S is produced PO 3Hpad. Mud.sbouJd.preclu.deH2Sporig..Rig isec¡uippedwHbsensorsal1dalarms. 34 Mecba.nicalcpodition pfwells withil1 AOB. veri.fied (Fors.ervice w~1j on.!y) . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. .......... - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 35 P~(lTJit c.an be iss~ed w/o. hydrogen. s.ulfide meaS!Jres . 36 .D.atapreseoted on. pote.ntial pverpres.surezOl1es. . . . . . . 37 .S~i.smic.analysjs Qf sbaJlow gaszpoes. . . . . . . . . . . . . . . . . . . . . . . 38S~abed .col1djtjpo survey (if ofH¡hpre) . . . . . . . 39 . Conta.ct n.amelphon.efor.weekly progress reports [exploratpl)' .only] .. .. . . . . . .No . . . . . . . . . . . . .Y~s. .NO,3.H-pad.weJlsbavel)1.easured120~400.ppm.H2S,....... ........ . . . . . OVERfJRESS.uREEXPECTED: highJy. u.ncertain, but e~p~cted to be .11.6 - 14.6 ppg EMVV~ wilj . . .bedriJIed.with1.1..8.-J4.8ppgmud......... ........ ...... - - - - - - - - - - - - - - - NA .NA .. .NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: ~ I r J~ Engineering Commissioner: Date blic Date ;,,;ooe, ~/ o.r- D D . e . 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 . :2..0 S- - 0 2..A $Revision: 3 $ LisLib $Revision: 4 $ Fri Apr 29 11:01:51 2005 #!)lV;?- Reel Header Service name.... ........ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/04/29 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name........... ... ..UNKNOWN Continuation Number.... ..01 Previous Reel Name...... .UNKNOWN Comments. ............... .STS LIS Writing Library. Scientific Technical Services Tape Header Service name....... .... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/04/29 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.............. ..UNKNOWN Continuation Number... ...01 Previous Tape Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 3H-14B 501032009202 ConocoPhillips Alaska, Inc. Sperry Drilling Services 29-APR-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003573297 J. PANTER F. HERBERT MWD RUN 2 MW0003573297 T. GALVIN F. HERBERT MWD RUN 3 MW0003573297 T. GALVIN G. WHITLOCK # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 8E 1157 281 .00 79.60 38.70 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 6.125 4.750 CASING SIZE (IN) 7.000 5.500 DRILLERS DEPTH (FT) 6227.0 7930.0 # . . REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE 3H-14A WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 6227'MD/4982'TVD. 4. MWD RUN 1 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND PRESSURE WHILE DRILLING (PWD). THE PURPOSE OF THIS RUN WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. 5. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL, DGR, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUN 2 ALSO INCLUDED PWD. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER PHONE CALL BETWEEN DOMINIQUE VAN NOSTRAND, CONOCOPHILLIPS ALASKA, INC., AND BUSTER BRYANT (SDS) ON 4/29/2005. MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 3 REPRESENT WELL 3H-14B WITH API#: 50-103-20092-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8450'MD/6409'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 (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .05/04/29 Maximum Physical Record. .65535 File Type... ............ .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP 1 and clipped curves; all bit runs merged. .5000 START DEPTH 6176.0 6227.0 STOP DEPTH 8390.0 8450.0 FET RPD RPM RPS RPX $ . 6230.0 6230.0 6230.0 6230.0 6230.0 8403.0 8403.0 8403.0 8403.0 8403.0 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 6176.0 6205.0 7887.5 MERGE BASE 6256.5 7935.0 8450.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.. ...0 Logging Direction.............. ...Down Optical log depth units.... ..... ..Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record. . . . . . . . . . . . .Undefined Absent value. .................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6176 8450 7313 4549 6176 8450 ROP MWD FT/H 0.1 259.27 111.181 4447 6227 8450 GR MWD API 40.35 581.07 128.952 4429 6176 8390 RPX MWD OHMM 0.33 840.12 5.02272 4347 6230 8403 RPS MWD OHMM 0.46 2000 28.0243 4347 6230 8403 RPM MWD OHMM 0.38 2000 14.6292 4347 6230 8403 RPD MWD OHMM 1.42 2000 36.8672 4347 6230 8403 FET MWD HOUR 0.2 185.76 5.86453 4347 6230 8403 First Reading For Entire File......... .6176 Last Reading For Entire File.... ...... .8450 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.... ...05/04/29 . 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..... ..05/04/29 Maximum Physical Record..65535 File Type........ . . . . . . . . LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 6176.0 6227.0 STOP DEPTH 6204.5 6256.5 # 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): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # 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 04-APR-05 Insite 66.37 Memory 6256.0 6227.0 6256.0 .0 .0 TOOL NUMBER 178513 6.126 6240.0 LSND 10.00 53.0 9.3 13000 5.8 .360 .330 .400 .580 68.0 75.0 68.0 68.0 . . MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units....... ....Feet Data Reference Point.......... ....Undefined Frame Spacing.......... ......... ..60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR MWD010 MWD010 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Service Order Units FT FT/H API Size 4 4 4 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6176 6256.5 6216.25 162 6176 6256.5 ROP MWD010 FT/H 0.1 17.67 7.60067 60 6227 6256.5 GR MWD010 API 71.9 86.18 82.3567 58 6176 6204.5 First Reading For Entire File......... .6176 Last Reading For Entire File.......... .6256.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation. .... ..05/04/29 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...... .05/04/29 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: 3 header data for each bit run in separate files. 2 . DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPX RPS ROP $ .5000 START DEPTH 6205.0 6230.0 6230.0 6230.0 6230.0 6230.0 6257.0 STOP DEPTH 7894.0 7887.0 7887.0 7887.0 7887.0 7887.0 7935.0 # 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: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY 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.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units..... ......Feet Data Reference Point... .......... .Undefined Frame Spacing.................... .60 .1IN . 06-APR-05 Insite 66.37 Memory 7935.0 6256.0 7935.0 48.3 55.5 TOOL NUMBER 178513 159439 6.125 6240.0 LSND 10.00 55.0 9.3 10000 5.8 .560 .300 .460 .710 60.0 118.0 60.0 60.0 . . Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6205 7935 7070 3461 6205 7935 ROP MWD020 FT/H 1. 32 259.27 128.538 3357 6257 7935 GR MWD020 API 59.92 581. 07 140.274 3379 6205 7894 RPX MWD020 OHMM 0.76 704.44 3.96547 3315 6230 7887 RPS MWD020 OHMM 1. 04 749.56 4.07369 3315 6230 7887 RPM MWD020 OHMM 1. 03 532.7 4.37566 3315 6230 7887 RPD MWD020 OHMM 1. 42 1866.02 6.4009 3315 6230 7887 FET MWD020 HOUR 0.2 37.24 1.16628 3315 6230 7887 First Reading For Entire File....... ...6205 Last Reading For Entire File.......... .7935 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number......... ..1.0.0 Date of Generation..... ..05/04/29 Maximum Physical Record..65535 File Type....... ........ .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name. ... ....... ..STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..05/04/29 Maximum Physical Record..65535 File Type....... ........ .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS 4 header data for each bit run in separate files. 3 .5000 START DEPTH 7887.5 7887.5 7887.5 STOP DEPTH 8403.0 8403.0 8403.0 . RPX FET GR ROP $ 7887.5 7887.5 7894.5 7935.5 8403.0 8403.0 8390.0 8450.0 # 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: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RES IS. 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..................O Data Specification Block Type.....O Logging Direction........... ......Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing................... ..60 .1IN Max frames per record....... ......Undefined Absent value........... .......... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 15-APR-05 Insite 4.3 Memory 8450.0 7935.0 8450.0 34.1 50.1 TOOL NUMBER 72829 10684864 4.750 7930.0 LSND 12.00 55.0 10.1 5000 4.0 .950 .540 .700 1. 400 70.0 129.4 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 >.. . . ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7887.5 8450 8168.75 1126 7887.5 8450 ROP MWD030 FT/H 1.41 154.28 60.6437 1030 7935.5 8450 GR MWD030 API 40.35 140.04 93.1081 992 7894.5 8390 RPX MWD030 OHMM 0.33 840.12 8.41883 1032 7887.5 8403 RPS MWD030 OHMM 0.46 2000 104.959 1032 7887.5 8403 RPM MWD030 OHMM 0.38 2000 47.5657 1032 7887.5 8403 RPD MWD030 OHMM 1.56 2000 134.732 1032 7887.5 8403 FET MWD030 HOUR 0.53 185.76 20.9563 1032 7887.5 8403 First Reading For Entire File......... .7887.5 Last Reading For Entire File.......... .8450 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number........ ...1.0.0 Date of Generation.. .....05/04/29 Maximum Physical Record..65535 File Type...... . . . . . . . . . .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name.. .......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/04/29 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.......... ... ...UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/04/29 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name........... .....UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File