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196-096
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Upsize ESP 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: MILNE POINT 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6,205'N/A Casing Collapse Conductor N/A Surface 2,020psi Production 5,410psi 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 WTRSP 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 Todd Sidoti 3-1/2" MILNE PT UNIT J-02 Length 1,113 5,441' TERTIARY UNDEF WTRSP & SCHRADER BLUFF OIL N/A Suspension Expiration Date: Size 13-3/8" 9-5/8" 7" 12/22/2024 Subsequent Form Required: 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: PRESENT WELL CONDITION SUMMARY Hilcorp Alaska LLC C.O. 477.05 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 5,441' 3,866' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 190-096 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22071-00-00 Proposed Pools: 105' 105' 9.2# / L-80 / Vam Top TVD Burst 4,204 4,450' MD N/A 3,520psi 7,240psi 2,382' 4,430' 2,920' 6,179' 105' Wells Manager ( Todd Sidoti for Taylor Wellman) 2,920' 6,179' todd.sidoti@hilcorp.com 777-8443 Perforation Depth MD (ft): 7" CSMP-NR gravel pack, 7" Fluorol Wicker sump, 7" WTF Hydrow, 7" HES “VST” Versa-Trieve & 7” 26-32# HES Perma and N/A 4,279 MD / 3,024 TVD, 4,634 MD / 3,282 TVD, 5,371 MD / 3,881 TVD, 5,725 MD 4,084 TVD & 5,920 MD / 4,234 TVD and N/A See Schematic See Schematic No 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 8:04 am, Dec 10, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.12.09 14:07:52 - 09'00' Taylor Wellman (2143) 324-691 10-404 * * applies to the Schrader Bluff Oil Pool. SFD Witnessed BOP Test and Annular Test to 2500 psi. JJL 12/11/24 X DSR-12/16/24SFD 12/10/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.12.17 09:54:48 -09'00'12/17/24 RBDMS JSB 121824 ESP Change-Out Well: MPU J-02 12-9-2024 Well Name: MPU J-02 API Number: 500292207100 Current Status: Online ESP WSW Pad: J-Pad Estimated Start Date: 12/22/2024 Rig: ASR Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190096 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (O) (907) 947-9553 (M) AFE Number: 242-01187 Current Bottom Hole Pressure: 1,438 psi @ 3250 TVD SBHP 2016 – 8.5 PPG Maximum Expected BHP: 1,438 psi @ 3250 TVD SBHP 2016 – 8.5 PPG MPSP: 1,113 psi Gas Column Gradient (0.1 psi/ft) Brief Well Summary: MPU J-02 is a current online WSW averaging 2000 BWPD. With new J pad development in 2024, J-02 current ESP will not maintain a VRR of 1 to support all the new drills at J pad. The new ESP will be sized to meet 12,000 bwpd to support the future development in 2024. This purpose Change of Approved Program submittal is to address the pause in work on MPJ-02 and resumption of work once Doyon 14 has moved off of J-Pad. Notes Regarding Wellbore Condition x The 7” production casing passed an MIT to 2000 psi on 11/26/2024. x There is a 4-1/2” kill string installed at a depth of 1570’. Objective: x Pull ESP x Pull kill string. x Casing test to 2000 psi x Install new ESP Non- Sundried work SL: Caliper Tubing Sundry Procedure (Approval Required to Proceed) Pre-Rig Procedure 1. RU FB and PT lines to 3,000 psi. 2. Review the well Kill procedure with the engineer, plan to pump estimated 8.7 ppg kill wt fluid down the IA taking returns to the TBG . Shut the well in obtain updated shut-in well pressures with known fluids. 3. Confirm well is dead. 4. RD FB. 5. Clear and level pad area in front of well. Spot rig mats and containment. 6. RD well house and flowlines. Clear and level area around well. 7. RU crane. Set BPV. ND Tree. Inspect the tubing hanger lift thread and note any damage. 12,000 bwpd ESP Change-Out Well: MPU J-02 12-9-2024 8. NU BOPE. RD Crane. 9. Spot mud boat. RWO Procedure: 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to returns tank. 11. If needed, bleed off any residual pressure off the IA. Check for pressure and if 0 psi, pull BPV. If needed, kill well w/ 8.7 ppg KWF prior to pulling BPV. 12. Set TWC. 13. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per “ASR 1 BOP Test Procedure” c. Confirm test pressures per the Sundry Conditions of approval. d. Test rams on 3-1/2” and 4-1/2’’ test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 14. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 15. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/ 8.7 ppg KWF as needed. 16. Rig up spoolers for ESP cable. 17. MU landing joint or spear, BOLDS and PU on the tubing hanger. a. 26 Klbs up and 19k down when landed 2017. 18. Lay down tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. a. Evaluate pulled tubing hanger for possible damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. 19. POOH and lay down the 3-1/2” tubing while spooling ESP cable. Lay down ESP and motor. a. Inspect the connections ESP Change-Out Well: MPU J-02 12-9-2024 b. Tubing should be washed and inspected and place in inventory. Discard any joints that are visually bad and joints noted in the caliper reviewed by the OE. c. Note any sand or scale inside or on the outside of the ESP in WSR. d. The completion has the following amount of clamps: i. 106 Cross Collar Clamps ii. 4 Protectolizer clamps iii. 1 Flat guard Pulled Equipment Disposition Tubing hanger Visually inspect on site then re-stock Tubing & Pup joints Wash and toss. Place in inventory ESP Cable Inspect GLMS N/A ESP Equipment Visually inspect on site then provide to vendor for tear down, PU new Summit ESP Clamps Clamps will be replaced from Summit XN Nipple Place in inventory 20. MU 7’’ test packer and RIH to 4000’ MD and perform a casing test to 2000 psi. Above work has been done and is considered complete as of 02 December Below work is to be completed when ASR returns to MPU J-02. 21. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to returns tank. 22. If needed, bleed off any residual pressure off the IA. Check for pressure and if 0 psi, pull BPV. If needed, kill well w/ 8.7 ppg KWF prior to pulling BPV. 23. Set TWC. 24. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. f. Notify AOGCC 24 hours in advance of BOP test. g. Perform Test per “ASR 1 BOP Test Procedure” h. Confirm test pressures per the Sundry Conditions of approval. i. Test rams on 3-1/2” and 4-1/2’’ test joint. 25. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 26. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/ 8.7 ppg KWF as needed. 27. Pull 4-1/2” kill string. 28. MU and RIH with 7” bit and scraper assembly and clean out to top of packer at ~4279’. POOH. 29. PU new ESP and RIH on 3-1/2” 9.3 lbs/ft L-80 tubing. Set base of ESP assembly at ± 4200’ MD. a. Check ESP cable conductivity every 2,000’. ESP Change-Out Well: MPU J-02 12-9-2024 Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Lb/ft Material Notes 3-1/2’’ Centralizer ~4200 MD 9.8 L-80 3-1/2’’ Sensor, Zenith 9.8 L-80 Baker 3-1/2’’ Motor 9.8 L-80 Summit 3-1/2’’ Lower Tandem Seal 9.8 L-80 Summit 3-1/2’’ Upper Tandem Seal 9.8 L-80 Summit 3-1/2’’ Pump 9.8 L-80 Summit 3-1/2’’ Pump 9.8 L-80 Summit 3-1/2’’ 1 joint 9.8 L-80 3-1/2’’ 10' Pup Joint 9.8 L-80 3-1/2’’ XN nip 9.8 L-80 3-1/2’’ 10' Pup Joint 9.8 L-80 3-1/2’’ Joints 9.8 L-80 3-1/2’’ Space out PUPS 9.8 L-80 3-1/2’’ 1 joint 9.8 L-80 3-1/2’’ PUP 9.8 L-80 3-1/2’’ Tubing Hanger 9.8 L-80 PU and MU the 3-1/2” tubing hanger with landing joint. Make the final splice of the ESP cable to the penetrator. Plug off any additional control line ports if present. 30. Land the tubing hanger and RILDS (Caution do not damage the Cable when landing). Lay down landing joint. Note Pick-up and slack-off weights on tally. 31. Set TWC. 32. RDMO ASR. Post-Rig Procedure: 33. RD mud boat. RD BOPE house. Move to next well location. 34. RU crane. ND BOPE. 35. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 36. Pull TWC. 37. RD crane. Move returns tank and rig mats to next well location. 38. Replace gauge(s) if removed. 39. Turn well over to production. RU well house and flowlines. ESP Change-Out Well: MPU J-02 12-9-2024 Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic _____________________________________________________________________________________ Revised By: TDF 12/3/2024 SCHEMATIC Milne Point Unit Well: MPU J-02 Last Completed: 11/30/2024 PTD: 190-096 TD =6,205’(MD) / TD =4,450’(TVD) Orig. DF Elev.: 70.2’/ Orig. GL Elev.: 35.6’ RKB –Tbg Hanger: 32.0’ (Nabors 27E) 7” 9 6 13 14 15 PBTD =6,098’ (MD) / PBTD = 4,368’(TVD) 8 16 17 9-5/8” 13-3/8” TOC – 3,740’ MD CBL 10/31/16 7 Cement Plug – 5,714’ Inf Plug – 5,740’ 12 11 18 19 NA NB NC NE OA OB Milled magna range bridge plug 5,648’ CTM 10/13/16 Cement Plug 5,441’-5,648’ Lower Prince Ck (Water Source) 10 3 4 5 6 1 2 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 54.5 / K-55 / N/A 12.459” Surface 105' 9-5/8" Surface 36 / K-55 / BTC 8.765” Surface 2,920’ 7” Production 26 / L-80 / BTC 6.151” Surface 6,179’ TUBING DETAIL 4-1/2” Kill String 12.6 / L-80 / Vam Top 3.958” Surface 1,571’ JEWELRY DETAIL No Depth Item 1 16’ Hanger 2 1,530’ Mule Shoe – Btm @ 1,571' 3 4,279’ 7” Gravel Pack Packer (3.250” ID) 4 4,303’ 3-1/2” Blank Pipe, 6 jts (180’ total length) 5 4,483’ 3-1/2” 12-gauge (300 Micron) ProWeld Screens,5 jts (151’ total length) 6 4,634’ 7” Sump Packer – Tubing Tail @ 4,640’ (2.912” ID) 7 5,371’ 7” HES “VST” Versa-Trieve Gravel Pack Packer 8 5,397’ 3-1/2” Howard Smith Blank Screen (165’ length) 2.992” ID 9 5,532’ 3-1/2” 0.12 Ga. Howard Wire Wrapped Screen (ID=2.992”) 10 5,648’ 3.5” Magna Range Bridge Plug (Milled Up), capped w/ 207’ cement 11 5,724’ 3.25” HES Straight Slot Locator Seal Assembly (6 molded seals)2.75” ID 12 5,725’ 7” HES “VST” Versa-Trieve Gravel Pack Packer 13 5,740’ Baker Inflatable Bridge Plug (capped w/ 26’ of cement) Tag cmt 4/30/2004 14 5,748’ 3-1/2” Howard Smith Blank Screen (26’ length) 2.992” ID 15 5,774’ 3-1/2” 0.12 Ga. Howard Wire Wrapped Screen (ID=2.992”) 16 5,919’ 3.25” HES Straight Slot Locator Seal Assembly (3 molded seals) 2.97” ID 17 5,920’ 7” 26-32# HES “AWD” Perma-Series Packer (Set on E-line) 18 5,927’ 3-1/2” Collet Guide –Btm @ 5,928’ 19 5,976’Fish – 2 prong grab w/ 1.75” fishing neck w/ inf pkr parts; Lost 7/93 PERFORATION DETAIL Schrader Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Lower Prince Ck 4,499’ 4,608’ 3,207’ 3,266’ 109’ 11/01/16 Open NA 5,568’ 5,600’ 3,964’ 3,998’ 32’ 5/09/91 Isolated NB 5,608’ 5,625’ 3,995’ 4,008’ 17’ 5/09/91 Isolated NC 5,645’ 5,655’ 4,023’ 4,031’ 10’ 5/09/91 Isolated NE 5,675’ 5,705’ 4,046’ 4,069’ 30’ 5/09/91 Isolated OA 5,781’ 5,823’ 4,127’ 4,159’ 42’ 5/02/91 Isolated OB 5,865’ 5,900’ 4,192’ 4,218’ 35’ 5/02/91 Isolated Lower Prince Creek – 5-1/8” 5132 HMX Razor, 16 spf (32 gr) TCP Schrader Bluff - SWS: 4-1/2”, 12spf (24gr), N-sands (Wireline); 4-1/2”, 12 spf (24gr), O-sands (TCP) WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 61 deg. @ 4,400’ Hole angle thru perfs= 39-40 deg. TREE & WELLHEAD Tree CIW 3-1/8” 5M ‘WKM’ Wellhead 11”x 11” 5M WKM tubing hanger 3-1/2” NS-CT threads top and 3-1/2” Vam Top bottom and 3.0” CIW-H BPV profile GENERAL WELL INFO API: 50-029-22071-00-00 Drilled and Cased by Nabors 27E - 12/23/1990 Run ESP Completion by EWS #4 – 5/13/1991 Convert to injector by EWS #4 – 2/16/1992 Convert to WSW by ASR #1 – 11/03/2016 Run Gravel Pack & ESP by I-rig – 1/21/2017 Install Kill String by ASR 11/30/2024 OPEN HOLE / CEMENT DETAIL 13-5/8” Cmt w/500 sx PF ‘C’ in a 30” Hole 9-5/8” 1,100 sx PF ‘E’, 220 sx Class ‘G’, in a 12-1/4” Hole 7” 306 xs Class ‘G’ in a 8-1/2” Hole GRAVEL PACK DETAIL LPC-sands: 4,507 lbs of 20-40 Carbolite proppant behind screen N-sands: 12,600lbs of 20-40 Mesh Gravel proppant behind screen O-sands: 10,300lbs of 20-40 Mesh Gravel proppant behind screen _____________________________________________________________________________________ Revised By: TDF 12/9/2024 PROPOSED Milne Point Unit Well: MPU J-02 Last Completed: 1/21/17 PTD: 190-096 TD =6,205’(MD) / TD =4,450’(TVD) Orig. DF Elev.: 70.2’/ Orig. GL Elev.: 35.6’ RKB –Tbg Hanger: 32.0’ (Nabors 27E) 7” 15 6 19 20 21 PBTD =6,098’ (MD) / PBTD = 4,368’(TVD) 14 22 23 9-5/8” 13-3/8” TOC – 3,740’ MD CBL 10/31/16 13 Cement Plug – 5,714’ Inf Plug – 5,740’ 18 17 24 25 NA NB NC NE OA OB Milled magna range bridge plug 5,648’ CTM 10/13/16 Cement Plug 5,441’-5,648’ Lower Prince Ck (Water Source) Min ID = 2.750” 16 9 10 11 12 8 4 5 6 7 1 2 9 3 6666666666666666666666666666666666666666666666666666666666666666666666666 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 54.5 / K-55 / N/A 12.459” Surface 105' 9-5/8" Surface 36 / K-55 / BTC 8.765” Surface 2,920’ 7” Production 26 / L-80 / BTC 6.151” Surface 6,179’ TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / Vam Top 3.958” Surface ±4,200’ JEWELRY DETAIL No Depth Item 1 ±XX’ 4-1/2” Tubing Hanger 2 ±X,XXX’ 4-1/2” XN Profile, 3.813” Packing, Min ID = 3.725” 3 ±X,XXX’ Discharge Head: 4 ±X,XXX’ Tandem Pumps: 5 ±X,XXX’ Pump Intake: 6 ±X,XXX’ Tandem Seal Section: 7 ±X,XXX’ Motor: 8 ±X,XXX’ Sensor w 6 fin Centralizer – Bottom @ ±4,200’ 9 4,279’ 7” Gravel Pack Packer (3.250” ID) 10 4,303’ 3-1/2” Blank Pipe, 6 jts (180’ total length) 11 4,483’ 3-1/2” 12-gauge (300 Micron) ProWeld Screens,5 jts (151’ total length) 12 4,634’ 7” Sump Packer – Tubing Tail @ 4,640’ (2.912” ID) 13 5,371’ 7” HES “VST” Versa-Trieve Gravel Pack Packer 14 5,397’ 3-1/2” Howard Smith Blank Screen (165’ length) 2.992” ID 15 5,532’ 3-1/2” 0.12 Ga. Howard Wire Wrapped Screen (ID=2.992”) 16 5,648’ 3.5” Magna Range Bridge Plug (Milled Up), capped w/ 207’ cement 17 5,724’ 3.25” HES Straight Slot Locator Seal Assembly (6 molded seals)2.75” ID 18 5,725’ 7” HES “VST” Versa-Trieve Gravel Pack Packer 19 5,740’ Baker Inflatable Bridge Plug (capped w/ 26’ of cement) Tag cmt 4/30/2004 20 5,748’ 3-1/2” Howard Smith Blank Screen (26’ length) 2.992” ID 21 5,774’ 3-1/2” 0.12 Ga. Howard Wire Wrapped Screen (ID=2.992”) 22 5,919’ 3.25” HES Straight Slot Locator Seal Assembly (3 molded seals) 2.97” ID 23 5,920’ 7” 26-32# HES “AWD” Perma-Series Packer (Set on E-line) 24 5,927’ 3-1/2” Collet Guide –Btm @ 5,928’ 25 5,976’Fish – 2 prong grab w/ 1.75” fishing neck w/ inf pkr parts; Lost 7/93 PERFORATION DETAIL Schrader Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Lower Prince Ck 4,499’ 4,608’ 3,207’ 3,266’ 109’ 11/01/16 Open NA 5,568’ 5,600’ 3,964’ 3,998’ 32’ 5/09/91 Isolated NB 5,608’ 5,625’ 3,995’ 4,008’ 17’ 5/09/91 Isolated NC 5,645’ 5,655’ 4,023’ 4,031’ 10’ 5/09/91 Isolated NE 5,675’ 5,705’ 4,046’ 4,069’ 30’ 5/09/91 Isolated OA 5,781’ 5,823’ 4,127’ 4,159’ 42’ 5/02/91 Isolated OB 5,865’ 5,900’ 4,192’ 4,218’ 35’ 5/02/91 Isolated Lower Prince Creek – 5-1/8” 5132 HMX Razor, 16 spf (32 gr) TCP Schrader Bluff - SWS: 4-1/2”, 12spf (24gr), N-sands (Wireline); 4-1/2”, 12 spf (24gr), O-sands (TCP) WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 61 deg. @ 4,400’ Hole angle thru perfs= 39-40 deg. TREE & WELLHEAD Tree CIW 3-1/8” 5M ‘WKM’ Wellhead 11”x 11” 5M WKM tubing hanger 3-1/2” NS-CT threads top and 3-1/2” Vam Top bottom and 3.0” CIW-H BPV profile GENERAL WELL INFO API: 50-029-22071-00-00 Drilled and Cased by Nabors 27E - 12/23/1990 Run ESP Completion by EWS #4 – 5/13/1991 Convert to injector by EWS #4 – 2/16/1992 Convert to WSW by ASR #1 – 11/03/2016 Run Gravel Pack & ESP by I-rig – 1/21/2017 OPEN HOLE / CEMENT DETAIL 13-5/8” Cmt w/500 sx PF ‘C’ in a 30” Hole 9-5/8” 1,100 sx PF ‘E’, 220 sx Class ‘G’, in a 12-1/4” Hole 7” 306 xs Class ‘G’ in a 8-1/2” Hole GRAVEL PACK DETAIL LPC-sands: 4,507 lbs of 20-40 Carbolite proppant behind screen N-sands: 12,600lbs of 20-40 Mesh Gravel proppant behind screen O-sands: 10,300lbs of 20-40 Mesh Gravel proppant behind screen Milne Point ASR Rig 1 BOPE 2023 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR 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: Tubing Patch 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 6898'feet 6557'feet true vertical 6273' feet None feet Effective Depth measured 6557'feet 4032', 4903', 4919', 5061', 6514' feet true vertical 6071'feet 4018', 4820', 4835', 4967', 6044' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 4983' MD 4895' TVD Packers and SSSV (type, measured and true vertical depth) 4032' MD 4903' MD 4919' MD 5061' MD 6514' MD N/A 4018' TVD 4820' TVD 4835' TVD 4967' TVD 6044' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 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: HRD-E ZXPN LTP Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: Baker C-2 ZXP LTP Packer: NSAK MonoPak LTP SSSV: None Shelby Sumrall shelby.sumrall@conocophillips.com 265-6678Well Integrity Specialist 6535-6554', 6570-6575', 6580-6620' 6057-6068', 6078-6081', 6084-6109' 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 116' ~ ~~ Well Remains Shut-In ~~ ~ measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-096 50-029-20853-01-00 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: ADL0025652 Kuparuk River Field/ Kupaurk River Oil Pool KRU 1F-03A Plugs Junk measured Length Production Liner 5199' 1841' Casing 5124' 3-1/2" 5231' 6895' 6271' 2207' 116'Conductor Surface Intermediate 16" 10-3/4" 81' 2242' 2242' 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 10:33 am, Aug 13, 2024 Digitally signed by Shelby Sumrall DN: OU=Alaska, O=Conocophillips, CN=Shelby Sumrall, E=Shelby.Sumrall@conocophillips.com Reason: I am the author of this document Location: Anchorage Alaska Date: 2024.08.13 09:55:51-08'00' Foxit PDF Editor Version: 13.0.0 Shelby Sumrall DTTMSTART JOBTYP SUMMARYOPS 7/20/2024 ACQUIRE DATA PULLED EXTENDED PACKING DV @ 4910' RKB, PULLED 3 1/2 AVA CATCHER @ 5037' RKB, PULLED 2.81 CSA-2 EQ PRONG & PLUG BODY @ 5039' RKB, BRUSH & FLUSH TBG FROM 5000' TO 4800' RKB TBG OPEN 2.75", CLEAN DRIFT TO 5050' RKB W/ 2.72" x 23' DUMMY PATCH, SET 2.72" P2P @ 4921' RKB (CE) (OAL 4.01' / SN:CPP353301), SET 3 1/2 TTS TEST TOOL IN 2.72" P2P @ 4921' RKB CMIT TBG x IA 2500 PSI (PASS). IN PROGRESS. 7/21/2024 ACQUIRE DATA PULLED 3 1/2 TTS TEST TOOL @ 4921' RKB, SET 2.72" UPPER P2P SPACER ANCHOR LATCH @ 4905' RKB (CE) TOP @ 4902.55' RKB, SET 3 1/2 TTS TEST TOOL @ 4902' RKB, MIT-T 2500 PSI (PASS), CMIT-TxIA 2500 PSI (PASS), PULLED GLV @ 4430' RKB, SET 1" BTM LATCH OV @ SAME (5/16" PORT), PULLED GLV'S @ 3587' & 2494' RKB REPLACED IN KIND, GOOD TBG TEST & IA DRAW DOWN AFTER VLV WORK, PULLED 3 1/2 TTS TEST TOOL @ 4905' RKB. JOB COMPLETE. 1F-03 Patch Summary of operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,572.0 1F-03A 11/27/2021 praffer Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Patch, C/O GLVs 1F-03A 7/21/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: VIDEO LOG SHOWS COLLAPSED LINER @ 6586' 1/30/2004 triplwj NOTE: WELL SIDETRACKED OUT BOTTOM OF PRODUCTION CSG 7/5/1996 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 35.0 116.0 116.0 62.58 H-40 WELDED SURFACE 10 3/4 9.95 34.5 2,241.8 2,241.7 45.50 K-55 BUTT PRODUCTION 7 6.28 32.5 5,231.0 5,124.5 26.00 K-55 BTC Scab Liner 5 1/2 4.83 4,031.6 5,082.8 4,987.0 15.50 L-80 Hydril 563 LINER 3 1/2 2.99 5,053.8 6,895.0 6,271.3 9.20 L-80 ABM-BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.6 Set Depth 4,983.3 Set Depth 4,895.2 String Max No 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Mod 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) 25.6 25.6 0.26 HANGER 6.000 Tubing Hanger, TC-1A-EN, 6" x3-½" EUE 8rd Box x Box, 3" ISA BPVG FMC TC-1A- EN 2.992 2,494.4 2,494.2 0.71 GAS LIFT 5.968 3-1/2" x 1-1/2", SN: 086AG09 Camco MMG 2.915 3,597.8 3,597.2 7.21 GAS LIFT 5.968 3-1/2" x 1-1/2", SN: 165AG09 Camco MMG 2.915 4,430.1 4,389.3 23.66 GAS LIFT 4.730 3-1/2" x 1", SN: 16905-16 Camco KBG-2-9 2.818 4,909.6 4,827.3 23.10 GAS LIFT 4.740 3-1/2" x 1", SN: 18439-01 Camco KBG-2-9 2.818 4,964.6 4,878.0 22.92 LOCATOR 4.500 Locator Sub, GBH-22 (bottom of locator spaced out 6.9'') Baker GBH-22 2.990 4,965.1 4,878.4 22.92 SEAL ASSY 3.980 Seal Assembly, 80-40 Baker 80-40 2.990 Top (ftKB) 4,031.6 Set Depth 5,082.8 Set Depth 4,987.0 String Max No 5 1/2 Tubing Description Tubing Production Wt (lb/ft) 15.50 Grade L-80 Top Connection Hydril 563 ID (in) 4.83 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,031.6 4,018.0 19.10 LTP 6.050 HRD-E ZXPN Liner Top Packer (11.00' tie back sleeve with 5.5" ID), 5-1/2" Hydril 563 Box down Baker HRD-E ZXPN 4.900 4,048.0 4,033.5 19.30 HANGER 6.030 HMC Liner Hanger (9 cone), 5-1/2" Hydril 563 Pin x BTC Pin Baker HMC (9 cone) 4.870 4,063.1 4,047.8 19.48 Liner 5.500 Casing, 5-1/2", 15.5#, L-80, Hydril 563 Box x Pin 4.825 4,971.6 4,884.4 22.89 XO Reducing 6.050 Crossover, 5-1/2" Hydril 563 Box x 5" BTCM Box 4.380 4,973.1 4,885.8 22.89 SBE 5.000 SBE, 80-40, 5" BTC Pin x Pin (locating shoulder at 4971.96') Baker 80-40 4.000 4,991.4 4,902.7 22.83 XO Reducing 5.500 Crossover, 5" BTCM Box x 3-1/2" EUE 8rd Pin 2.960 5,039.0 4,946.6 22.59 NIPPLE 4.500 Nipple, Camco, 2.813" DS Camco 2.813" DS 2.813 5,056.7 4,962.9 22.50 LOCATOR 4.500 Locator Sub, GBH-22 (bottom of locator spaced out 3.38') Baker GBH-22 2.980 5,057.8 4,964.0 22.49 SEAL ASSY 3.980 Seal Assembly, 80-40 Baker 80-40 2.980 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) 4,902.6 4,820.9 23.12 PACKER - PATCH - UPR 2.725" PIIP UPR PKR MID- ELEMENT AT 4905' RKB WITH SPACER PIPE AND ANCHOR LATCH ASSEMBLY, OAL 16' TTS PIIP CPP3 5363 / CPAL 35205 7/21/2024 1.625 4,906.2 4,824.2 23.11 SPACER PIPE 2-1/16" P-110 SPACER PIPE WITH ANCHOR LATCH 7/21/2022 1.600 4,918.6 4,835.6 23.07 PACKER - PATCH - LWR 2.725" PIIP LWR PKR MID- ELEMENT AT 4921' RKB, OAL 4.01' TTS PIIP CPP3 5301 7/20/2024 1.625 6,514.0 6,043.8 51.87 PACKER Northern Solutions AK Mono- Pak Liner Top Packer w/1.781" RX nipple @ 6,522' RKB NSP0 19 4/26/2022 1.781 6,530.0 6,053.7 51.93 WHIPSTOCK 4/8/2022 0.000 6,557.5 6,070.6 52.22 PLUG 2.72" RBP (4.98' OAL) MID ELEMENT @ 6560' RKB CPP3 5241 / CPEQ 35022 1/6/2021 0.000 6,586.0 6,088.0 52.53 OBSTRUCTI ON Collapsed Liner 1/30/2004 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,494.4 2,494.2 0.71 1 GAS LIFT GLV RK 1 1/2 1,269.0 7/21/2024 CAMCO MMG 0.188 1F-03A, 8/12/2024 1:17:02 PM Vertical schematic (actual) LINER; 5,053.8-6,895.0 FLOAT SHOE; 6,893.4-6,895.0 FLOAT COLLAR; 6,830.8- 6,831.7 LANDING COLLAR; 6,799.6- 6,800.4 IPERF; 6,580.0-6,620.0 OBSTRUCTION; 6,586.0 RPERF; 6,570.0-6,575.0 PLUG; 6,557.5 APERF; 6,535.0-6,554.0 WHIPSTOCK; 6,530.0 AL1 slotted liner; 6,521.2- 7,653.0 XO Threads (Casing); 6,526.9- 6,529.9 PACKER; 6,514.0 PRODUCTION; 32.5-5,231.0 FLOAT SHOE; 5,229.2-5,231.0 FLOAT COLLAR; 5,155.1- 5,156.7 Scab Liner; 4,031.6-5,082.8 SBE; 5,074.3-5,087.1 HANGER; 5,067.5-5,074.3 SEAL ASSY; 5,057.8 SEAL ASSY; 5,057.8-5,082.8 PACKER; 5,061.2-5,067.5 TIEBACK; 5,053.8-5,061.2 LOCATOR; 5,056.7 LOCATOR; 5,056.7-5,057.8 Tubing - Pup; 5,050.4-5,056.7 Tubing - Pup; 5,040.2-5,050.4 NIPPLE; 5,039.0-5,040.2 NIPPLE; 5,039.0 Tubing - Pup; 5,029.0-5,039.0 Tubing; 4,997.4-5,029.0 Tubing - Pup; 4,993.2-4,997.4 XO Reducing ; 4,991.4-4,993.2 XO Reducing ; 4,991.4 SBE; 4,973.0 SBE; 4,973.0-4,991.4 SEAL ASSY; 4,965.1 XO Reducing; 4,971.6 XO Reducing; 4,971.6-4,973.0 LOCATOR; 4,964.6 PACKER - PATCH - LWR; 4,918.6 GAS LIFT; 4,909.5 SPACER PIPE; 4,906.2 PACKER - PATCH - UPR; 4,902.5 Liner; 4,063.1 Liner; 4,063.1-4,971.5 GAS LIFT; 4,430.1 Liner - Pup; 4,058.8 Liner - Pup; 4,058.8-4,063.1 XO Threads; 4,057.0 XO Threads; 4,057.0-4,058.8 HANGER; 4,048.0 HANGER; 4,048.0-4,057.0 LTP; 4,031.6 LTP; 4,031.6-4,048.0 XO Threads; 3,806.4 GAS LIFT; 3,597.8 GAS LIFT; 2,494.4 SURFACE; 34.5-2,241.8 FLOAT SHOE; 2,240.0-2,241.8 FLOAT COLLAR; 2,160.6- 2,162.1 CONDUCTOR; 35.0-116.0 HANGER; 34.5-38.2 HANGER; 32.5-36.0 HANGER; 25.6 KUP PROD KB-Grd (ft) 36.59 RR Date 12/28/198 2 Other Elev 1F-03A ... TD Act Btm (ftKB) 6,895.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292085301 Wellbore Status PROD Max Angle & MD Incl (°) 53.90 MD (ftKB) 6,806.79 WELLNAME WELLBORE1F-03A Annotation Last WO: End Date 3/26/2016 H2S (ppm) 40 Date 9/4/2017 Comment SSSV: NONE Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,597.8 3,597.2 7.21 2 GAS LIFT GLV RK 1 1/2 1,269.0 7/21/2024 CAMCO MMG 0.188 4,430.1 4,389.3 23.66 3 GAS LIFT OV INT 1 0.0 7/21/2024 CAMCO KPG-29 0.313 4,909.6 4,827.3 23.10 4 GAS LIFT OPEN INT 1 0.0 7/20/2024 OPEN POCK ET CAMCO KBG-29 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) 4,031.6 4,018.0 19.10 LTP 6.050 HRD-E ZXPN Liner Top Packer (11.00' tie back sleeve with 5.5" ID), 5-1/2" Hydril 563 Box down Baker HRD-E ZXPN 4.900 4,057.0 4,042.0 19.40 XO Threads 6.100 Crossover, 5-1/2" BTC Box x 5- 1/2" Hydril 563 Pin 4.870 4,971.6 4,884.4 22.89 XO Reducing 6.050 Crossover, 5-1/2" Hydril 563 Box x 5" BTCM Box 4.380 4,991.4 4,902.7 22.83 XO Reducing 5.500 Crossover, 5" BTCM Box x 3-1/2" EUE 8rd Pin 2.960 5,039.0 4,946.6 22.59 NIPPLE 4.500 Nipple, Camco, 2.813" DS Camco 2.813" DS 2.813 5,056.7 4,962.9 22.50 LOCATOR 4.500 Locator Sub, GBH-22 (bottom of locator spaced out 3.38') Baker GBH-22 2.980 5,053.8 4,960.2 22.52 TIEBACK 5.750 BAKER TIEBACK SLEEVE 5.250 5,061.2 4,967.1 22.48 PACKER 6.150 BAKER C-2 ZXP LINER PACKER 4.437 6,799.6 6,215.1 53.90 LANDING COLLAR 3.500 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,535.0 6,554.0 6,056.7 6,068.4 A-5, 1F-03A 10/19/2021 6.0 APERF 19', 2" PowerJet Omega 2006, HMX, 60 Deg Phasing 6,570.0 6,575.0 6,078.2 6,081.3 A-4, 1F-03A 10/19/2021 6.0 RPERF 5', 2" PowerJet Omega 2006, HMX, 60 Deg Phasing 6,580.0 6,620.0 6,084.3 6,108.6 A-4, 1F-03A 7/12/1996 4.0 IPERF 2.5" Hollow Carrier; 180° Phase; 93° CCW Oriented 1F-03A, 8/12/2024 1:17:03 PM Vertical schematic (actual) LINER; 5,053.8-6,895.0 FLOAT SHOE; 6,893.4-6,895.0 FLOAT COLLAR; 6,830.8- 6,831.7 LANDING COLLAR; 6,799.6- 6,800.4 IPERF; 6,580.0-6,620.0 OBSTRUCTION; 6,586.0 RPERF; 6,570.0-6,575.0 PLUG; 6,557.5 APERF; 6,535.0-6,554.0 WHIPSTOCK; 6,530.0 AL1 slotted liner; 6,521.2- 7,653.0 XO Threads (Casing); 6,526.9- 6,529.9 PACKER; 6,514.0 PRODUCTION; 32.5-5,231.0 FLOAT SHOE; 5,229.2-5,231.0 FLOAT COLLAR; 5,155.1- 5,156.7 Scab Liner; 4,031.6-5,082.8 SBE; 5,074.3-5,087.1 HANGER; 5,067.5-5,074.3 SEAL ASSY; 5,057.8 SEAL ASSY; 5,057.8-5,082.8 PACKER; 5,061.2-5,067.5 TIEBACK; 5,053.8-5,061.2 LOCATOR; 5,056.7 LOCATOR; 5,056.7-5,057.8 Tubing - Pup; 5,050.4-5,056.7 Tubing - Pup; 5,040.2-5,050.4 NIPPLE; 5,039.0-5,040.2 NIPPLE; 5,039.0 Tubing - Pup; 5,029.0-5,039.0 Tubing; 4,997.4-5,029.0 Tubing - Pup; 4,993.2-4,997.4 XO Reducing ; 4,991.4-4,993.2 XO Reducing ; 4,991.4 SBE; 4,973.0 SBE; 4,973.0-4,991.4 SEAL ASSY; 4,965.1 XO Reducing; 4,971.6 XO Reducing; 4,971.6-4,973.0 LOCATOR; 4,964.6 PACKER - PATCH - LWR; 4,918.6 GAS LIFT; 4,909.5 SPACER PIPE; 4,906.2 PACKER - PATCH - UPR; 4,902.5 Liner; 4,063.1 Liner; 4,063.1-4,971.5 GAS LIFT; 4,430.1 Liner - Pup; 4,058.8 Liner - Pup; 4,058.8-4,063.1 XO Threads; 4,057.0 XO Threads; 4,057.0-4,058.8 HANGER; 4,048.0 HANGER; 4,048.0-4,057.0 LTP; 4,031.6 LTP; 4,031.6-4,048.0 XO Threads; 3,806.4 GAS LIFT; 3,597.8 GAS LIFT; 2,494.4 SURFACE; 34.5-2,241.8 FLOAT SHOE; 2,240.0-2,241.8 FLOAT COLLAR; 2,160.6- 2,162.1 CONDUCTOR; 35.0-116.0 HANGER; 34.5-38.2 HANGER; 32.5-36.0 HANGER; 25.6 KUP PROD 1F-03A ... WELLNAME WELLBORE1F-03A Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread AL1 slotted liner 2 3/8 1.99 6,521.2 7,653.0 4.60 L-80 STL 1F-03AL1, 8/12/2024 1:17:03 PM Vertical schematic (actual) AL1 slotted liner; 6,521.2- 7,653.0 Shoe; 7,652.6-7,653.0 XO Threads (Casing); 6,940.9- 6,944.0 LINER; 5,053.8-6,895.0 XO Threads (Casing); 6,526.9- 6,529.9 PACKER; 6,514.0 PRODUCTION; 32.5-5,231.0 FLOAT SHOE; 5,229.2-5,231.0 FLOAT COLLAR; 5,155.1- 5,156.7 Scab Liner; 4,031.6-5,082.8 SBE; 5,074.3-5,087.1 HANGER; 5,067.5-5,074.3 SEAL ASSY; 5,057.8 SEAL ASSY; 5,057.8-5,082.8 PACKER; 5,061.2-5,067.5 TIEBACK; 5,053.8-5,061.2 LOCATOR; 5,056.7 LOCATOR; 5,056.7-5,057.8 Tubing - Pup; 5,050.4-5,056.7 Tubing - Pup; 5,040.2-5,050.4 NIPPLE; 5,039.0 NIPPLE; 5,039.0-5,040.2 Tubing - Pup; 5,029.0-5,039.0 Tubing; 4,997.4-5,029.0 Tubing - Pup; 4,993.2-4,997.4 XO Reducing ; 4,991.4 XO Reducing ; 4,991.4-4,993.2 SBE; 4,973.0 SBE; 4,973.0-4,991.4 SEAL ASSY; 4,965.1 XO Reducing; 4,971.6 XO Reducing; 4,971.6-4,973.0 LOCATOR; 4,964.6 PACKER - PATCH - LWR; 4,918.6 GAS LIFT; 4,909.5 SPACER PIPE; 4,906.2 PACKER - PATCH - UPR; 4,902.5 Liner; 4,063.1 Liner; 4,063.1-4,971.5 GAS LIFT; 4,430.1 Liner - Pup; 4,058.8 Liner - Pup; 4,058.8-4,063.1 XO Threads; 4,057.0 XO Threads; 4,057.0-4,058.8 HANGER; 4,048.0 HANGER; 4,048.0-4,057.0 LTP; 4,031.6-4,048.0 LTP; 4,031.6 XO Threads; 3,806.4 GAS LIFT; 3,597.8 GAS LIFT; 2,494.4 SURFACE; 34.5-2,241.8 FLOAT SHOE; 2,240.0-2,241.8 FLOAT COLLAR; 2,160.6- 2,162.1 CONDUCTOR; 35.0-116.0 HANGER; 34.5-38.2 HANGER; 32.5-36.0 HANGER; 25.6 KUP PROD KB-Grd (ft) 36.59 RR Date 12/28/198 2 Other Elev 1F-03AL1 ... TD Act Btm (ftKB) 7,653.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292085360 Wellbore Status PROD Max Angle & MD Incl (°) 24.40 MD (ftKB) 4,600.00 WELLNAME WELLBORE1F-03A Annotation End DateH2S (ppm) 40 Date 9/4/2017 Comment Originated: Delivered to:13-Aug-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1A-26 50-029-22115-00 909422974 Kuparuk River Leak Detect Log Field- Final 18-Jul-24 0 1 2 1A-26 50-029-22115-00 909422974 Kuparuk River Multi Finger Caliper Field & Processed 18-Jul-24 0 1 3 1D-12 50-029-22948-00 909422973 Kuparuk River Leak Detect Log Field- Final 15-Jul-24 0 1 4 1D-12 50-029-22948-00 909422973 Kuparuk River Multi Finger Caliper Field & Processed 15-Jul-24 0 1 5 1D-101 50-029-22988-00 909422480 Kuparuk River Patch Setting Record Field- Final 9-Jul-24 0 1 6 1F-03A 50-029-20853-01 909423152 Kuparuk River Packer Setting Record Field- Final 20-Jul-24 0 1 7 1G-01 50-029-20805-00 909469740 Kuparuk River Multi Finger Caliper Field & Processed 31-Jul-24 0 1 8 1G-01 50-029-20805-00 909469740 Kuparuk River Packer Setting Record Field- Final 30-Jul-24 0 1 9 1G-07A 50-029-20872-01 909383029 Kuparuk River Leak Detect Log Field- Final 2-Jul-24 0 1 10 1G-07A 50-029-20872-01 909383029 Kuparuk River Multi Finger Caliper Field & Processed 11-Jul-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39431 T39431 T39432 T39432 T39433 T39434 T39435 T39435 T39436 T39436 190-166 199-084 200-183 196-096 182-130 218-051 8-14-2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.14 08:29:49 -08'00' 6 1F-03A 50-029-20853-01 909423152 Kuparuk River Packer Setting Record Field- Final 20-Jul-24 0 1 196-096 Originated: Delivered to:9-Jul-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1A-11 50-029-20685-00 909447215 Kuparuk River Radial Bond Record Field & Processed 3-Jul-24 0 1 2 1B-04 50-029-20595-00 909359143 Kuparuk River Plug Setting Record Field- Final 5-Jun-24 0 1 3 1C-24 50-029-23063-00 n/a Kuparuk River Plug Setting Record Field- Final 6-May-24 0 1 4 1C-157 50-029-23754-00 909345851 Kuparuk River Water Flow Record Field & Processed 25-May-24 0 1 5 1D-135 50-029-22816-00 n/a Kuparuk River Plug Setting Record Field- Final 25-May-24 0 1 6 1D-145 50-029-23526-00 909335380 Kuparuk River Jewelry Record Field- Final 14-May-24 0 1 7 1E-08A 50-029-20496-01 909539034 Kuparuk River Plug Setting Record Field- Final 1-Jun-24 0 1 8 1F-03A 50-029-20853-01 909382731 Kuparuk River Leak Detect Log Field- Final 18-Jun-24 0 1 9 1F-03A 50-029-20853-01 909424095 Kuparuk River Multi Finger Caliper Field & Processed 2-Jul-24 0 1 10 1G-04 50-029-20835-00 909359162 Kuparuk River Patch Setting Record Field- Final 11-Jun-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39146 T39147 T39148 T39149 T39150 T38151 T39152 T39153 T39153 T39154 181-173 181-065 201-248 223-038 197-184 214-138 210-181 196-096 182-161 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.10 13:03:51 -08'00' 1F-03A 50-029-20853-01 909382731 Kuparuk River Leak Detect Log Field- Final 18-Jun-24 0 1 9 1F-03A 50-029-20853-01 909424095 Kuparuk River Multi Finger Caliper Field & Processed 2-Jul-24 0 1 T39153 T39153 196-096 Originated: Delivered to:20-Jun-22Halliburton 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 1D-135 50-029-22816-00 n/a Kuparuk River Packer Setting Record Field- Final 9-Jun-22 0 12 1F-03A 50-029-20853-60 907799903 Kuparuk River Multi Finger Caliper Field & Processed 9-Apr-22 0 13 1H-103 50-029-23593-00 n/a Kuparuk River Leak Detect Log Field- Final 3-Jun-22 0 14 1H-103 50-029-23593-00 n/a Kuparuk River Leak Detect Log Field- Final 4-Jun-22 0 15 1H-103 50-029-23593-00 n/a Kuparuk River Multi Finger Caliper Field & Processed 3-Jun-22 0 16 1H-104 50-029-23610-00 n/a Kuparuk River Leak Detect Log Field- Final 6-Jun-22 0 17 1H-104 50-029-23610-00 n/a Kuparuk River Multi Finger Caliper Field & Processed 7-Jun-22 0 18 2M-33 50-029-22816-00 n/a Kuparuk River Packer Setting Record Field- Final 15-May-22 0 19 3R-107 50-029-23660-00 n/a Kuparuk River Packer Setting Record Field- Final 20-May-22 0 110PLEASE 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: ! 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The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϵϲϬϵϲϬ Ͳ^Ğƚ͗ϯϲϮϱϬJRBy Abby Bell at 1:43 pm, Dec 21, 2021 3M-1750029217290000 KRU WLWFLFINAL FIELD24-Apr-213M-1950029217370000 KRU WLLDLFINAL FIELD25-Apr-213H-0150103200840000 KRU WLCHCFINAL FIELD26-Aug-213H-1250103200880000 KRU WLCCLFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCHCFINAL FIELD29-Aug-213H-1250103200880000 KRU WLCUTTERFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCUTTERFINAL FIELD24-Sep-211L-1250029220330000 KRU WLSBHPSFINAL FIELD6-Nov-213G-2450103201450000 KRU WLTBG CORRFINAL FIELD29-Oct-211A-2550029221160000 KRU WL WHIPSTOCKFINAL FIELD12-Oct-211A-2350029221310000 KRU WLRBPFINAL FIELD12-Jun-211R-2050029222070000 KRU WLPPROFFINAL FIELD2-Jun-212M-1150103201590000 KRU WLPPROFFINAL FIELD27-Aug-212M-0750103201780000 KRU WLBACKOFFFINAL FIELD5-Aug-211Y-1950029223910000 KRU WLPPROFFINAL FIELD31-May-212T-3050103202190000 KRU WLLDLFINAL FIELD2-May-211Q-20A50029225890100 KRU WLSET RECFINAL FIELD2-Aug-212M-3350103202400000 KRU WLLDLFINAL FIELD18-Oct-211F-03A50029208530100 KRU WLPERFFINAL FIELD19-Oct-211Q-08A50029212250100 KRU WLIPROFFINAL FIELD30-Apr-211E-3350029227970000 KRU WLPPROFFINAL FIELD26-Mar-211D-13550029228160000 KRU WLLDLFINAL FIELD16-Jul-213F-13A50029214990100 KRU WLGLSFINAL FIELD17-Jul-212N-318 50103203430000 KRU WLSCMTFINAL FIELD12-Nov-211C-12750029230240000 KRU WLIPROFFINAL FIELD17-Nov-213S-24A50103204560100 KRU WLCUTTERFINAL FIELD25-Oct-213S-0350103204580000 KRU WLIBPFINAL FIELD26-Oct-211B-2050029231640000 KRU WLPPROFFINAL FIELD22-Apr-211E-11950029231980000 KRU WLLDLFINAL FIELD26-Jun-212W-1750029233700000 KRU WLPPROFFINAL FIELD28-Aug-211H-11850029235780000 KRU WLIPROFFINAL FIELD4-Nov-211H-11450029235840000 KRU WLIPROFFINAL FIELD23-Jun-211H-11350029235880000 KRU WLWFLFINAL FIELD22-May-21 ! 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H " #E #E +*( ( (= H H " J ,02+.1)3#)26/ "* & )363#)33758)3+2#)3+358)3/2#))125 )23+#)2)/58)2+/#)2/58)2/7#)2/5 2#727 24121 " 62( By Samantha Carlisle at 1:22 pm, Nov 10, 2021 Stefan Weingarth Digitally signed by Stefan Weingarth Date: 2021.11.10 13:07:28 -09'00' VTL 01/24/2022 DSR-11/10/21 RBDMS HEW 11/12/2021 SFD 11/15/2021 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 6,553.0 11/2/2021 1F-03A fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason; Tag 1F-03A fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 35.0 Set Depth (ftKB) 116.0 Set Depth (TVD) … 116.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 34.5 Set Depth (ftKB) 2,241.8 Set Depth (TVD) … 2,241.7 Wt/Len (l… 45.50 Grade K-55 Top Thread BUTT Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 32.5 Set Depth (ftKB) 5,231.0 Set Depth (TVD) … 5,124.2 Wt/Len (l… 26.00 Grade K-55 Top Thread BTC Casing Description LINER OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 5,053.8 Set Depth (ftKB) 6,895.0 Set Depth (TVD) … 6,271.0 Wt/Len (l… 9.20 Grade L-80 Top Thread ABM-BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 5,053.8 4,959.9 22.49 TIEBACK BAKER TIEBACK SLEEVE 5.250 5,061.2 4,966.8 22.45 PACKER BAKER C-2 ZXP LINER PACKER 4.437 5,067.5 4,972.6 22.42 HANGER BAKER HMC HYDRAULIC LINER HANGER 4.375 5,074.3 4,978.9 22.38 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 Tubing Strings Tubing Description Tubing – Production String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 25.6 Set Depth (ft… 4,983.3 Set Depth (TVD) (… 4,894.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 25.6 25.6 0.27 HANGER 2.992 6.000 FMC TC-1A- EN FMC Tubing Hanger, TC- 1A-EN, 6" x 3-1/2" EUE 8rd Box x Box, 3" ISA BPVG 4,964.6 4,877.6 22.90 LOCATOR 2.990 4.500 Baker GBH-22 Locator Sub, GBH-22 (bottom of locator spaced out 6.9'') 4,965.1 4,878.1 22.90 SEAL ASSY 2.990 3.980 Baker 80-40 Seal Assembly, 80-40 Tubing Description Tubing – Production String Ma… 5 1/2 ID (in) 4.83 Top (ftKB) 4,031.6 Set Depth (ft… 5,082.8 Set Depth (TVD) (… 4,986.7 Wt (lb/ft) 15.50 Grade L-80 Top Connection Hydril 563 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 4,031.6 4,017.8 19.15 PACKER 4.900 6.050 Baker HRD-E ZXPN HRD-E ZXPN Liner Top Packer (11.00' tie back sleeve with 5.5" ID), 5-1/2" Hydril 563 Box down 4,048.0 4,033.3 19.34 HANGER 4.870 6.030 Baker HMC (9 cone) HMC Liner Hanger (9 cone), 5-1/2" Hydril 563 Pin x BTC Pin 4,063.1 4,047.6 19.53 Liner 4.825 5.500 Casing, 5-1/2", 15.5#, L- 80, Hydril 563 Box x Pin 4,971.6 4,884.1 22.88 XO Reducing 4.380 6.050 Crossover, 5-1/2" Hydril 563 Box x 5" BTCM Box 4,973.1 4,885.4 22.88 SBE 4.000 5.000 Baker 80-40 SBE, 80-40, 5" BTC Pin x Pin (locating shoulder at 4971.96') 4,991.4 4,902.3 22.82 XO Reducing 2.960 5.500 Crossover, 5" BTCM Box x 3-1/2" EUE 8rd Pin 5,039.0 4,946.3 22.57 NIPPLE 2.813 4.500 Camco 2.813" DS Nipple, Camco, 2.813" DS 5,056.7 4,962.6 22.48 LOCATOR 2.980 4.500 Baker GBH-22 Locator Sub, GBH-22 (bottom of locator spaced out 3.38') 5,057.8 4,963.7 22.47 SEAL ASSY 2.980 3.980 Baker 80-40 Seal Assembly, 80-40 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,586.0 6,087.7 52.53 OBSTRUCTION Collapsed Liner 1/30/2004 0.000 Mandrels Station No/SPM Top (ftKB) Top Incl (°) Item Des OD Nominal (in) Nominal ID (in) Make Model Top (TVD) (ftKB) 1 2,494.4 0.72 GAS LIFT 5.968 2.915 Camco MMG 2,494.2 2 3,597.8 7.46 GAS LIFT 5.968 2.915 Camco MMG 3,597.2 3 4,430.1 23.70 GAS LIFT 4.730 2.818 Camco KBG-2-9 4,388.9 4 4,909.6 23.09 GAS LIFT 4.740 2.818 Camco KBG-2-9 4,827.0 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,494.4 2,494.2 0.72 1 1/2 GAS LIFT GLV RK 0.188 1,297.0 3/31/2016 2 3,597.8 3,597.2 7.46 1 1/2 GAS LIFT GLV RK 0.188 1,277.0 3/31/2016 3 4,430.1 4,388.9 23.70 1 GAS LIFT GLV INT 0.188 1,257.0 3/31/2016 4 4,909.6 4,827.0 23.09 1 GAS LIFT OV INT 0.250 0.0 6/7/2019 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,535.0 6,554.0 6,056.5 6,068.1 A-5, 1F-03A 10/19/2021 6.0 APERF 19', 2" PowerJet Omega 2006, HMX, 6 SPF, 60 Deg Phasing 1F-03A, 11/10/2021 10:59:05 AM Vertical schematic (actual) LINER; 5,053.8-6,895.0 IPERF; 6,580.0-6,620.0 OBSTRUCTION; 6,586.0 RPERF; 6,570.0-6,575.0 APERF; 6,535.0-6,554.0 PRODUCTION; 32.5-5,231.0 GAS LIFT; 4,909.5 GAS LIFT; 4,430.1 GAS LIFT; 3,597.8 GAS LIFT; 2,494.4 SURFACE; 34.5-2,241.8 CONDUCTOR; 35.0-116.0 HANGER; 25.6 KUP PROD KB-Grd (ft) 36.59 Rig Release Date 12/28/1982 1F-03A ... TD Act Btm (ftKB) 6,895.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292085301 Wellbore Status PROD Max Angle & MD Incl (°) 53.90 MD (ftKB) 6,806.79 WELLNAME WELLBORE1F-03A Annotation Last WO: End Date 3/26/2016 H2S (ppm) 40 Date 9/4/2017 Comment SSSV: NONE ! " #$ $ " % & ' ( % )*+ ,# -"./0 1# 12'" + ,# 3 34 + 56% % % '" ++ % 6 ,# - #$ 2' #$ $+5 + 7++ 55 % %6 ,# % % ' " - 241!#1 86 69 ' 6 ' : " % & ' " ++ % !"# $% %% &' ( !"# ) * + + + % * " , % % )" -./0.123045 6771.80/9-.123045 " , + + Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,570.0 6,575.0 6,077.9 6,081.0 A-4, 1F-03A 10/19/2021 6.0 RPERF 5', 2" PowerJet Omega 2006, HMX, 6 SPF, 60 Deg Phasing 6,580.0 6,620.0 6,084.0 6,108.3 A-4, 1F-03A 7/12/1996 4.0 IPERF 2.5" Hollow Carrier; 180° Phase; 93° CCW Oriented Notes: General & Safety End Date Annotation 1/30/2004 NOTE: VIDEO LOG SHOWS COLLAPSED LINER @ 6586' 7/5/1996 NOTE: WELL SIDETRACKED OUT BOTTOM OF PRODUCTION CSG 1F-03A, 11/10/2021 10:59:06 AM Vertical schematic (actual) LINER; 5,053.8-6,895.0 IPERF; 6,580.0-6,620.0 OBSTRUCTION; 6,586.0 RPERF; 6,570.0-6,575.0 APERF; 6,535.0-6,554.0 PRODUCTION; 32.5-5,231.0 GAS LIFT; 4,909.5 GAS LIFT; 4,430.1 GAS LIFT; 3,597.8 GAS LIFT; 2,494.4 SURFACE; 34.5-2,241.8 CONDUCTOR; 35.0-116.0 HANGER; 25.6 KUP PROD 1F-03A ... WELLNAME WELLBORE1F-03A 6,570.0 6,575.0 6,077.9 6,081.0 A-4, 1F-03A 10/19/2021 6.0 RPERF 5', 2" PowerJet Omega 2006, HMX, 6 SPF, 60 Deg Phasing I1. Operations Performed: (Name: Eli STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS E3 Fracture Stimulate ❑ Pull Tubing F]Operations shutdown Abandon 171 Plug Perforations LJ Alter casing ❑ Change Approved Program El Suspend 171 Perforate ❑ Other Stimulate El Plug for Reddll ❑ 'erforate New Pool ❑ Repair Well CO Re-enter Susp Well ❑ Permit to Drill Numberer: Carbo : Proppant DumpO 4. Well Class Before Work: 196-096 EEEH7 Development El Exploratory ❑Stratigraphic❑ Service ❑ 6. API Number: ge, 50-029-20853-01-00 B. Well Name and Number: KRU 1F -03A data per NIA Field / Kuparuk River Oil Pool Perforation depth: Measured depth: 6580-6620 feet True Vertical depth: 6084-6108 feet collapse L-80 4,983' MD 4,895' TVD (size, grade, measured and true vertical depth) 3. s and SSSV (type, measured and true vertical depth) PACKER - HRD-E ZXPN LINER TOP PCKR 4,032' MD 4,018' TVD Talion or cement squeeze summary: treated (measured): N/A descriptions including volumes used and final pressure: Prior to well operation: SHUT - Subsequent to operation: SHUT - 14. Attachments (required per 20 AAC 25.070, 25.071, Daily Report of Well Operations O Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ .-. , �_-_�....e..ir., tear rhe foredoinp is true and cc Dh+- Z✓� to kr(_ 3/57-7 a Form 10-404 Revised 4/2017 A S "7/�w 2.7 Water -Bbl Casing Pressure uon,a MCI _ I tdass a¢e, — Service ❑ Straligraphic [IExploratory ❑ Development WDSPL ❑ Oil [D Gas El Status aflerwork: SUSP❑ SPLUG❑ t El WIND El WAG [jGINJ ❑ or NIA if C.O. Exempt: of my knowledge. Sundry Number 320-010 Contact Name: John Peirce Contact Email: John.W.Peirce@cop-com Z /3 /Z o 2© Contact Phone: (907) 265-6471 Submit Original Only RBDMS �"' FEti 0 4 2010 Plugs measured None feet al Depth measured 6,898 feet Junk measured None feet true vertical 6 feel feet Packer measured 4,032 feet active Depth measured 6,585 true vesical 4,018 feet true vertical 1 feet MD TVD Burst slog Length Size 116' MD 116' TVD CONDUCTOR81 feet 16 10 314 " 2,242' MD 2242'TVD E SURFACE 2,207 feet 5,231' MD TVD PRODUCTION 5,199 feet 7 " 6,895' MD 6271' TVD LINER 1,641 feet 3 1/2 Perforation depth: Measured depth: 6580-6620 feet True Vertical depth: 6084-6108 feet collapse L-80 4,983' MD 4,895' TVD (size, grade, measured and true vertical depth) 3. s and SSSV (type, measured and true vertical depth) PACKER - HRD-E ZXPN LINER TOP PCKR 4,032' MD 4,018' TVD Talion or cement squeeze summary: treated (measured): N/A descriptions including volumes used and final pressure: Prior to well operation: SHUT - Subsequent to operation: SHUT - 14. Attachments (required per 20 AAC 25.070, 25.071, Daily Report of Well Operations O Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ .-. , �_-_�....e..ir., tear rhe foredoinp is true and cc Dh+- Z✓� to kr(_ 3/57-7 a Form 10-404 Revised 4/2017 A S "7/�w 2.7 Water -Bbl Casing Pressure uon,a MCI _ I tdass a¢e, — Service ❑ Straligraphic [IExploratory ❑ Development WDSPL ❑ Oil [D Gas El Status aflerwork: SUSP❑ SPLUG❑ t El WIND El WAG [jGINJ ❑ or NIA if C.O. Exempt: of my knowledge. Sundry Number 320-010 Contact Name: John Peirce Contact Email: John.W.Peirce@cop-com Z /3 /Z o 2© Contact Phone: (907) 265-6471 Submit Original Only RBDMS �"' FEti 0 4 2010 WELLNAME 1F -03A WELLBORE 1F -03A KUP PROD Ie Mn.AnnBMD TD ConocoPhillips Alzska, Inc. CONDUCTOR: IMm Wa.: MNGER: %011uWc„ Lma-PUR WSLfff: NM. sm.. NIVME: In Lnwmn. F I Lem LOLPTOR:5,6'b.T Top (IVDA Blm (IVD) T mN ImL m oil a - n an n 61 83 ,1F-0 I I IPhe ,9314; C I11RF:8.9BJ.GB,W-- _ LINER:5.�6E.WE0��- 1 F -03A CARBO FUSION GRAVEL PACK DTTM JOB SUMMARYOPS START TYP 1/21/20 abc TAG 2.83" DS -NIPPLE @ 5039' RKB (TCIF) WI 2.83" GAUGE RING; TAG IMPINGED LINER W/ EMPTY DUMP BAILER @ 6583' RKB; DUMP BAIL 2 GALLONS OF CARBO FUSION @ SAME. IN PROGRESS. 1/22/20 abc TAG TOP OF DUMP BAIL 10 GAB ONS OF FUSIONARBO US ON TO 6 BLIND 4'RKB. N PROGRESS. 1/23120 abc LIND TAG TOP OF CARBO 'RKBIN DUMP BAIL 8 GALLONS OFOCARBO FUSION TO 6534Lg 1/24/20 abc PROGESS. DUMP BAIL 6 GALLONS OFG TOP OF CARBO CARBO 3BLIND OX CARB0FUS ON TO 6517'KBB OB COMPLETE. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1F -03A Permit to Drill Number: 196-096 Sundry Number: 320-010 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4V DATED this 15 day of January, 2020. 3MMSLK�JAN 162020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED 212�/ r S 2� 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ d Progr Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approva c 9y'or y m❑ VC pp Plug for Redrill ❑ Perforate New Pool ElRe-enterSusp Well EIAlter Casing ❑ Other: Ca a Fusion Proppent Dum[7 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocOPhllll s Alaska Inc. Exploratory ❑ Development o • Stratigraphic ❑ Service ❑ 196-096 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20853-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1 F -03A ' Will planned perforations require a spacing exception? Yes ❑ No O 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25652 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,898' 6,273" 6585 1796 3730psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 81' 16" 116' 116' Surface 2,207' 103/4 2,242' 2,242' Production 5,199' 7" 5,231' 5,124' Liner 1,841' 31/2 6,895' 6,271' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6580-6620 6084-6108 3.500" L-80 4,983' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - HRD-E ZXPN LINER TOP PACKER MD= 4032 TVD= 4018 12. Attachments: Proposal Summary Wellbore schematic t7 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development t7 • Service ❑ 14. Estimated Date for 1/27/2020 15. Well Status after proposed work: Commencing Operations: OIL El WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce John Peirce Contact Name: Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com /� r� Y /� Contact Phone: (907)265-6471 Authorized Signature: !•ar 1 22.0 hz. Vv" .c-• Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .1t Z v^_©1�o Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: IMMS JAN 16 2020 Post Initial Injection MIT Req'd? Yes ❑ No (>� Spacing Ex eption Required? Yes ❑ No Subsequent Form Required: — �� 9- APPROVED Approved by: '� /�hlvJ COMMISSIONER THE COMMISSISI ON Date: r r �U'r, " e, ORIGINAL 114 Submit Form and Farm 10-403 Revised 4/2017 Approved a plication is valid for 12 months from the date of approval �o��® �hment: in Duplicate KUP PROD WELLNAME 1F -03A WELLBORE 7F -03A Corweoi'hillips "' nnr'b° Max Angle & MD rD Flar Nama We114Dre APIV WeIIWre Sutus Id(-) MI'ma) Act mrs pal Alaska. ft. IKI /PARI IK RI\/FR/INT MADAMS 301 1PROO �G9n F0.9F TO FAec9 1FL3j 1RlNM1139',9gM Last Tag Vu4W ¢Ianvhi 1pcGeQ AnnoWion peplM1 (IIKR) Eno pate Wellbore Lasl Mctl By ........................................................................................... Last Tag: ROK (Est 38' of Fill, Leaving 2' of Open Peds) 6582.0 12/242019 1F -03A zembaej raucER; Se. Last Rev Reason Annotmon End pate Weapons twat MW By Rev Reason: Updated Tag Depth 12124/2019 1F -03A zembaej Casing Strings Lasin a Description ED (in) 10(in) Tap(XKEI SO Depth SWED SO Depth (NO)... WXLen0 = Top Thread CONDUCTOR 16 1506 35.0 116.0 116.0 6258 H-00 WELDED Lasing Desctlptlon DD(in) Ip(In) Top SPIE) Set Depth gross SO Depth /NIS WIILen(I Jethro Top TM1wE SURFACE 10314 9.95 34.5 2,241.8 2,2413 45.50 K-55 BUTT CONDUCTOR;dair led codes D...riellon 00(in) mpp 7oSpmi) Set Depth bass) Set Depth UPRD.. IMI-en(Ipshe TOP TM1me PRODUCTION 7 628 32.5 6231.0 5,124.2 26.00 K-55 BTC Casing pescriptn^ Us' in'Mtin) Top (flK01 SN oepto real Rt Depth INed WXLen 11... Gra]e Top iM1rea4 LINER 3112 299 5,0538 6,895.0 6,271.0 920 LA0 ABM -BTC Liner Details - - SURFACE: U.",2<19� terminal ID Top grain "D-VDIIXKB) Topmem(-) here Des COM (am 6053.8 4,959.9 2249 TIEBACK BAKER TIEBACK SLEEVE 5,250 5,081.2 4,866.8 22.45 PACKER BAKER C-2 ZXP LINER PACKER 4437 GASUl attl 5,0675 4,972.6 22.42 IHANGER BAKER HMC HYDRAULIC LINER HANGER 4.375 5,074.3 4,9]6.9 22.38 JbRt BAKER 8040 SEAL BORE EXTENSION 4.000 Tubing Strings GAS LIFT 3Swe Tubing Deseliplion Shing Ma...inghp iop (XKB) Set Deplur-j4et Depth Fl I...WI(011dm GraOe Top ConneClino TUBING RW0201fi 3112 2.99 25.6 4,983.3 4,894.9 930 LA0 EUE Brtl M9tl Completion Details x.1mere:a,ad mpIND) Toped No ImI Top (MES LSK0) f) lam Des Com ID (in) 256 256 OD HANGER FM Tubing Hanger, TC -1A- N, x -12"EUE 6r0 Boxx U. 3" 2.992 PACKER: 4.r018 IBA BPVG HANGER) 4.04 4,964.6 4,8776 22.911 LOCATOR Locator Sub, GBH -22 (bottom of locator spaced out 6.9") 2.980 . 1hlw4d;4,WT0 4,965.1 4,818.1 22.90 SEALASSY Seal Assembly, 8040 2.990 L'nO-vupJ,C69.a Tubing Dsc�etlon Seng Ma... LINER RW0201fi 512 @4971 goes to 3112" 10 (in) 483 Top (flKB) 4,031.6 Se[DeptM1 (R. 5,082.8 Set 4pq (ND)(._wUiphI 4,9667 15.50 ... L-00 Top Lonnecton Hydri GAS LIFT; 4,4ap.1 Completion Details hi.c4,W31 Top".) Top ea Nominal Top(XKR) gir l N nem Des cum ID(e) 4,031.6 4,017.8 1915 PACKER HRD-E ZXPN Liner Top Parker (11.00' de back sleeve with 5.5" 4.900 ID). 5-112" Hydril 563 Box down GAS uvT:+sva.5 4,0480 4,033.3 1934 HANGER HMC Liner Hanger IS cone), 5-112" Hydril 563 Pin BTC Pin 4.870 4,083.1 4,0426 1953 Liner Casing ,5-112',15 5#T L-80, Hytlri1563 Boxx Pin 4.825 Reducing 4,9]1.6 4,884.1 22,8870 Crossover.5-112' Hydril 563 Box x 5"BTCMBO% 4.380 LOCATOR', 4,1 7973.1 4,885.4 22.88 SBE SBE, 8040, 5- BTC Pin x Pin( locating shoulder at4971. 96') 4.00 4,991.4 7902.3 22.82 %O RetlucinA Crossover, 5"BTCM eoxx312'EUE Brd Pin 2.960 xo Raeumy; awls SEALASSY;4:96 5,039.0 4,9463 22.57 NIPPLE Nipple, CamL0, 2.813'DS 2.813 SaS KIPso 5,0563 4,9626 22.48 LOCATOR Locator SUb,GBH-22(bohpm of locator spacetl out 338') 2.980 NO Re]Ldng:!snl < 5,057.6 4,963) 22.4) SEALASSY Seal Assembly, 80-40 2980 Perforations & Slots Shot NIPPLE: 5.Wg0 Top (XKn) afm (XNB) 1p(TVD) (flKID ardn UPe m -m) Lmis.Zmm Oa@ Dens (shotsm ) Type Com 6,580.0 6,620.0 6,084.0 9,108.3 A-0,iF-03A 7/1211996 4.0 /PERF 2.5' Hollow Carrier, 180 deg Phase; 93 deg. CCW Oriented Mandrel Inserts UDEATOR', SLOM7 an St Of N Topmag Valve Lash PoXSLx4�(�.RTop(we) (XKB) Make so, Type Type 9)un an.sFALgssv; sone 1 2,494.4 2.4942 Camro GAS LIFT GLV RK 0.1881/20162 J1.1'DOW 359]8 359)2 Gamco GAS LIFT GLVRK20163 4,430.1 4388.9 Camco GAS LIFT GLV INT 0.188120164 4909.6 4,8".0 Camco GAS LIFT OV INT 02502019 Notes: General & Safety PRODUCTION: sates Sal a� Red Date I finnomlo^ 41252018Note:Ta9Aedocementlikemud in 353.5"liner 91912010 NOTE: View Schemadcwl Alaska SohemetlC9.0 fi152009 NOTE: TAGGED COLLAPSED LINER Lb 6571 SUM � a t P� wERea,sm.oe,emo- y/ (7J LINEn.trD arespe5.o� 1F -03A Fusion Gravel Pack of Collapsed Liner Proposal 1F -03A Kuparuk 'A4 Sd only' producer was Rig Sidetracked in 1996 from 1F-03 which got SI in 1995 due to a fish in hole and severe casing damage caused by rock production. Several fishing attempts had been unsuccessful. A video log of 1/30/04 showed 1 F -03A had collapsed liner at 6586' RKB. Following failed 2013 TIFL, a 2014 LDL identified tubing leaks at 4914', 4755' and 4499'. During diagnostics a possible casing leak was also observed. A casing LDL then found a leak in 7" casing at 4910' RKB, which resulted in a 2016 RWO to correct 1F -03A tubing and casing leaks. The RWO set a 5.5" scab liner and new 3.5" gas lift completion, but the collapsed 3.5" liner at 6571' was not addressed. l 1F -03A is a consistent rock producer due to collapsed 3.5" Liner at 6570' RKB. Large amounts of fill and rocks produced through collapsed liner creates difficulty in maintaining production from 1 F -03A. Frequent CT cleanouts have been needed. The liner collapse was last tagged on 1/3/18 with a CTjunk mill hard tag at 6570' RKB. The milling BHA showed 'metal -to -metal' wear from milling collapsed liner. It is now proposed that a Fusion Gravel Pack placement be installed inside the collapsed liner to cover the collapsed liner section of the wellbore to halt rock production and the need for continual CT FCO's. Proppant plus an activator react via special coating on proppant to bond proppant grains together at point-to-point contacts between grains. This forms a fused proppant pack of a high compressive strength. The proppant pack will greatly resist degradation when 1 F -03A returns to production. The proppant pack is designed to retain very high permeability while halting solids production from 3.5" liner. Proposed Procedure Slickline: 1) MIRU SL. Host PJSM, inspect location, document hazards. Ensure all materials required for Fusion Proppant mixing are on location. 2) RIH to Nipple at 5039' RKB to locate, then RIH to confirm prior SL tag of 12/24/19 at 6582' RKB. 3) RIH with 2.5" bailer filled with proper 16/20 Fusion Proppant mixed with Activator to locate bailerjust above tag (step 2), and then dump bail Fusion Proppant into the liner. Tag Fusion Gravel Pack proppant to confirm top depth for confirmation that the Fusion Proppant pack is accumulating upward in the liner and not being lost to rathole and/or collapsed liner below. POOH to reload bailer. 4) Repeat making additional Fusion Proppant bailing runs until Fusion Gravel Pack top has risen enough to tag top at a minimum of 6546' RKB. The preferred final top target is 6520' RKB. 5) Freeze protect tubing with Diesel. 6) RD SL. Leave 1 F -03A SI 2 to 3 days for the Fusion Proppant Pack to fully cure before returning to production. STATE OF ALASKA AL. A OIL AND GAS CONSERVATION COM SIGN REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 1....... Plug Perforations r....... Fracture Stimulate r...... Pull Tubing 17 Operations Shutdown Performed: Suspend 7 Perforate 7 Other Stimulate 1— Alter Casing F, Change Approved Program P Plug for Redrill r Perforate New Pool 7 Repair Well Fi Re-enter Susp Well I— Other: Scab Liner 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 'F Exploratory P 196-096 3.Address: 6.API Number: P. O. Box 100360,Anchorage, Alaska 99510 Stratigraphic F Service 50-029-20853-01 7. Property Designation(Lease Number): 8.Well Name and Number: ADL 25652 KRU 1 F-03A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 6898 feet Plugs(measured) 5107 true vertical 6273 feet Junk(measured) None Effective Depth measured 6585 feet Packer(measured) 0 true vertical 1796 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 116 116 SURFACE 2207 10 3/4 2242 2242 PRODUCTION 5199 7 5231 5124 LINER 1841 31/2 6895 6271 Scab Liner 1051 5 1/2 5083 4987 RECEIVED Perforation depth: Measured depth: 6580-6620 APR 2 2 2016 True Vertical Depth: 6084-6108 SCANNED JUN 2 4 20161 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 4983 MD,4895 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER C-2 ZXP Liner Top Packer @ 5061 MD-4967 TVD NIPPLE-CAMCO DS NIPPLE @ 494 MD and 494 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NONE 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 100 1200 550 1000 150 Subsequent to operation SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 57 Exploratory 7 Development in,i Service I Stratigraphic Copies of Logs and Surveys Run r.._.. 16.Well Status after work: Oil r.7 Gas 1— WDSPL P Printed and Electronic Fracture Stimulation Data P GSTOR I...._ WINJ r... WAG P GINJ r- SUSP 1— SPLUG 1- 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: 316-008 Contact Diana Guzman a 265-6318 Email Diana.Guzman(c�conocophillips.com Printed Name Diana Guzman Title Sr. Wells Engineer Signature Phone:265-6318 Date April Z 2, Z0/6 ' 1vrL 5/9 /l , Form 10-404 Revised 5/2015 �� � RBDMS kA, APR 2 5 2016 Submit Original Only I • • 4.41:i.,.'„--,i.,,, ,: Operations Summary (with Timelog Depths) ' .: y�he `°'-` I F-03 Qmocafttillips Rig: NABORS 7ES Job: RECOMPLETION Time Log,, Start Depth Start Time '> End Time Dur(hr) Phase Op Code Activity Code,.. Time P-T-X Operation (ttKB) End Depth(ftKE) 3/20/2016 3/20/2016 1.00 MIRU MOVE RURD P RD berming around the pits,sub,and 0.0 0.0 22:00 23:00 cuttings box. Load up the shop, satellite office,parts house,mud man shack,electrician shack,and cutting box. 3/20/2016 3/21/2016 1.00 MIRU MOVE MOB P Pull the pits away from the sub and 0.0 0.0 23:00 00:00 install the jeep. Move the pits,satellite office,and shop from 3H pad to 1F pad. 3/21/2016 3/21/2016 2.50 MIRU MOVE RURD P Bridle up the blocks and complete 0.0 0.0 00:00 02:30 derrick down checklist. 3/21/2016 3/21/2016 1.00 MIRU MOVE MOB P Move the sub off well 3H-22. 0.0 0.0 02:30 03:30 3/21/2016 3/21/2016 1.00 MIRU MOVE RURD P Clean up the cellar,roll up the 0.0 0.0 03:30 04:30 herculite,load rig mats,and clean up around well 3H-22. 3/21/2016 3/21/2016 0.75 MIRU MOVE MOB P Move the sub to the entrance of the 0.0 0.0 04:30 05:15 pad to lower the derrick. 3/21/2016 3/21/2016 0.75 MIRU MOVE RURD P PJSM. Lower the derrick. 0.0 0.0 05:15 06:00 3/21/2016 3/21/2016 10.50 MIRU MOVE MOB P Move the sub 15.3 miles from 3H pad 0.0 0.0 06:00 16:30 to 1F pad. Move the sub to the back side of the pad in front of 1 F-03A and position the sub to raise the derrick. 3/21/2016 3/21/2016 1.00 MIRU MOVE RURD P PJSM. Raise and pin the derrick. 0.0 0.0 16:30 17:30 3/21/2016 3/21/2016 1.00 MIRU MOVE RURD P Hang the tree in the cellar,lay down 0.0 0.0 17:30 18:30 herculite for the cellar,and stage wellhead equipment behind the well. 3/21/2016 3/21/2016 2.00 MIRU MOVE MOB P Spot the sub over well 1F-03A and lay 0.0 0.0 18:30 20:30 down herculite for the LEPD tank. 3/21/2016 3/21/2016 1.50 MIRU MOVE MOB P Spot the pits to the sub,set rig mats 0.0 0.0 20:30 22:00 and lay down herculite for the pits/cuttings box 3/21/2016 3/22/2016 2.00 MIRU MOVE RURD P RU berming around the sub,pits,and 0.0 0.0 22:00 00:00 cuttings box. 3/22/2016 3/22/2016 1.00 MIRU MOVE RURD P Continue RU berming around the sub, 0.0 0.0 00:00 01:00 pits,and cuttings box. Hook up the interconnect. 3/22/2016 3/22/2016 2.00 MIRU MOVE RURD P Load the pits with 600 bbls of 10.6 0.0 0.0 01:00 03:00 NaCI/NaBr brine. Raise the cattle chute,tighten the Kelly hose,and bridal down the blocks. Rig accepted at 03:00 hours. 3/22/2016 3/22/2016 2.00 MIRU WELCTL MPSP P PU and RU lubricator. PT to 1500 psi 0.0 0.0 03:00 05:00 (good test). Pull 3"ISA BPV(tubing pressure=500 psi,IA pressure=350 psi,and OA pressure=40 psi). RD and lay down the lubricator. 3/22/2016 3/22/2016 2.50 MIRU WELCTL RURD P RU secondary IA valve. RU to 0.0 0.0 05:00 07:30 circulate through the rig choke utilizing the cellar manifold to the kill tank. Blow steam and air out to the kill tank to ensure lines a clear. RU circulating lines to the IA and tubing. Line up the rig choke and cellar manifold to the kill tank. PT all surface lines to 250/3000 psi(good test) Page 1/8 Report Printed: 4/5/2016 • Operations Summary (with Timelog Depths) 1F-03 ConocoP°hiiiips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time. End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation'. (ftKB) End Depth(ftKB) 3/22/2016 3/22/2016 1.00 MIRU WELCTL KLWL P Bleed the tubing to 0 psi and line up to 0.0 0.0 07:30 08:30 pump down the tubing taking returns out the IA to the kill tank. Stage the pumps up to 5 BPM and pump 195 bbls of 10.6 ppg NaCI/NaBr brine(ICP =630 psi and FCP=500 psi). Shut down the pumps. 3/22/2016 3/22/2016 0.50 MIRU WELCTL RURD P Blow down all circulating lines and RU 0.0 0.0 08:30 09:00 to monitor the well. 3/22/2016 3/22/2016 0.50 MIRU WELCTL OWFF P Monitor the well on gauges;tubing 0.0 0.0 09:00 09:30 and IA=0 psi. Open the well to atmosphere and observe the well for flow for 30 minutes. The well is static. 3/22/2016 3/22/2016 0.25 MIRU WELCTL RURD P RD circulating equipment. 0.0 0.0 09:30 09:45 3/22/2016 3/22/2016 0.25 MIRU WHDBOP MPSP P Install 3"'ISA BPV with dry rod. 0.0 0.0 09:45 10:00 3/22/2016 3/22/2016 1.50 MIRU WHDBOP NUND P RU wire slings to the TD and RU 0.0 0.0 10:00 11:30 slings to the tree. ND the tree and tubing head adapter. Pull the tree free with the TD. RU the bridge crane to the tree. Lay down the tree and tubing head adapter. 3/22/2016 3/22/2016 1.00 MIRU WHDBOP NUND P Clean and inspect the tubing hanger 0.0 0.0 11:30 12:30 lift threads(threads are good). Check all the LDS and install the blanking plug(9-3/4 right hand turns). 3/22/2016 3/22/2016 2.50 MIRU WHDBOP NUND P NU the BOP stack. Install the turn 0.0 0.0 12:30 15:00 buckles and riser. Air up the air boots on the riser. 3/22/2016 3/22/2016 1.50 MIRU WHDBOP RURD P RU BOPE testing equipment. 0.0 0.0 15:00 16:30 Flush/fill BOP stack and choke manifold with fresh water. Shell test the BOP stack to 250/3000 psi(good test) 3/22/2016 3/22/2016 1.50 MIRU WHDBOP BOPE P Conduct initial BOPE test to 250/3000 0.0 0.0 16:30 18:00 psi: test 2-7/8"x 5"VBR's(upper pipe rams)with 3-1/2"test joint;test 5-1/2" solid body rams(lower pipe rams)with 5-1/2"test joint;test annular to 250/3000 with 3-1/2"and 5-1/2"test joints;conducted Koomey drawdown test(all tested passed). The test was witnessed by AOGCC inspector Johnnie Hill. Tests: 1) Blind Rams,2"Demco Kill,Upper IBOP,Outer Test Spool,Chokes 1,2, 3,&16(Passed) 2) Blind Rams, HCR Kill, Inner Test Spool,Lower IBOP,Chokes 4,5,&6 (Passed) 3/22/2016 3/22/2016 1.25 MIRU WHDBOP BOPE T Test: 0.0 0.0 18:00 19:15 3) Blind Rams, Manual Kill,Inner Test Spool,HT-38 Dart Valve,Chokes 7,8, &9. Choke 7 failed high test, greased,and retest passed. (Passed) Page 2/8 Report Printed: 4/5/2016 • • Operations Summary (with Timelog Depths) .,at telt,, 1F-03 ConocoPhillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Tiara '., Our(hr} Phase Op Code. Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/22/2016 3/22/2016 4.25 MIRU WHDBOP BOPE P Tests: 0.0 0.0 19:15 23:30 4) Super Choke and Manual Adjustable Choke(Passed) 5) Blind Rams, Manual Kill,Inner Test Spool,Chokes 8, 10,&11 (Passed) 6) Blind Rams,Manual Kill,Chokes 8, 12, 13,&15(Passed) 7) Annular with 3-1/2"test joint, Manual Kill,3-1/2"EUE 8rd TIW, Choke 14(Passed) 8) Upper Pipe Rams with 3-1/2"test joint,Choke HCR,Manual Kill,3-1/2" EUE 8rd TIW(Passed) 9) Annular with 5-1/2"test joint, Manual Choke(Passed) 10)Lower Pipe Rams with 5-1/2"test joint,HT-38 TIW(Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure=2900 psi Accumulator Pressure After Closer= 1600 psi Pressure Gain of 200 psi= 17 seconds Full System=96 Seconds Average N2(5 Bottles)=2000 psi 3/22/2016 3/23/2016 0.50 MIRU WHDBOP RURD P Blow down BOPE testing equipment 0.0 0.0 23:30 00:00 and RD BOPE testing equipment. 3/23/2016 3/23/2016 0.50 COMPZN RPCOMP RURD P RU Weatherford power tubing tong 0.0 0.0 00:00 00:30 and 3-1/2"tubing elevators. 3/23/2016 3/23/2016 0.25 COMPZN RPCOMP MPSP P Pull the blanking plug. Check for 0.0 0.0 00:30 00:45 pressure under BPV(no pressure) and pull 3"ISA BPV with dry rod. 3/23/2016 3/23/2016 0.25 COMPZN RPCOMP RURD P MU landing joint,MU TIW to landing 0.0 0.0 00:45 01:00 joint,MU landing joint to tubing hanger,and MU the TD. 3/23/2016 3/23/2016 0.50 COMPZN RPCOMP PULL P PJSM. BOLDS,unseat the tubing 0.0 5,034.0 01:00 01:30 hanger,and the tubing pulled free at 110K. Pull tubing hanger to the rig floor(PU=70K and SO=70K). Lay down landing joint,TIW,and tubing hanger. 3/23/2016 3/23/2016 4.25 COMPZN RPCOMP PULL P POOH laying down 3-1/2"tubing from 5,034.0 0.0 01:30 05:45 5034'RKB to surface. Recovered 155 joints,4 GLM assemblies,DS nipple, and a cut joint= 12.63'. 3/23/2016 3/23/2016 0.25 COMPZN RPCOMP SFTY P Well control drill. Shut in time=27 0.0 0.0 05:45 06:00 seconds and CRT=66 seconds. AAR with crew. 3/23/2016 3/23/2016 1.00 COMPZN RPCOMP RURD P RD Weatherford power tubing tongs 0.0 0.0 06:00 07:00 and change elevators to 3-1/2"DP. Clean and clear the floor. 3/23/2016 3/23/2016 0.50 COMPZN RPCOMP RURD P MU wear ring running tool to a joint of 0.0 0.0 07:00 07:30 DP,install wear ring,lay down wear ring running tool,and lay down joint of DP. 3/23/2016 3/23/2016 1.00 COMPZN RPCOMP SVRG P Derrick inspection. TD DOMS and 0.0 0.0 07:30 08:30 service TD. Page 3/8 Report Printed: 4/5/2016 • • • x ..,? Operations Summary (with Timelog Depths) v f. 1F-03 ConocoPhillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (WE) End Depth(ftKE)' 3/23/2016 3/23/2016 2.00 COMPZN RPCOMP BHAH P PJSM. PU and MU BHA#1 -overshot 0.0 317.0 08:30 10:30 assembly. 3/23/2016 3/23/2016 3.50 COMPZN RPCOMP PULD P RIH with BHA#1 on 3-1/2"DP from 317.0 5,018.0 10:30 14:00 the pipe shed to 5018'RKB. 3/23/2016 3/23/2016 1.00 COMPZN RPCOMP FISH P Obtain parameters. PU= 115K,SO= 5,018.0 5,025.0 14:00 15:00 100K,rotating weight=105K,free torque=2400 ft-lbs,and 6 BPM=900 psi. Tag top of cut joint at 5029'RKB. Attempt to get over tubing stub. Rotate at 20 RPM with 6 BPM=900- 1600 psi to work onto the tubing stub. Shut down the pumps and swallow 5' of the tubing stub with 10K down. PU to 150K,bleed the jars,continue to PU to 176K,seals free,and pull seals out of SBE at 196K. 3/23/2016 3/23/2016 1.75 COMPZN RPCOMP CIRC P Circulate 163 bbls at 4 BPM=1480 5,025.0 5,025.0 15:00 16:45 psi. Slow the pumps down at MU to 2 BPM=450 psi. Got a fair amount of sand back across the shakers. 3/23/2016 3/23/2016 0.25 COMPZN RPCOMP OWFF P Observe the well for flow,no flow,and 5,025.0 5,025.0 16:45 17:00 the hole is slightly taking fluid. 3/23/2016 3/23/2016 3.00 COMPZN RPCOMP TRIP P Install the stripping rubbers,stand 5,025.0 317.0 17:00 20:00 back 1 stand,and blow down the TD. TOOH from 4955'RKB to 500'RKB. Monitor the well for 5 minutes and the well is slightly taking fluid. Finish TOOH to BHA. 3/23/2016 3/23/2016 2.00 COMPZN RPCOMP BHAH P Lay down(9)4-3/4"DCS and BHA#1 317.0 0.0 20:00 22:00 -overshot assembly. 3/23/2016 3/23/2016 1.00 COMPZN RPCOMP PULL P Break out fish and lay down cut joint, 51.0 0.0 22:00 23:00 D nipple,and seal assembly(total fish length=51.39'). The entire fish was packed off with sand. 3/23/2016 3/24/2016 1.00 COMPZN WELLPR WAIT T Wait for cleanout tools to arrive from 0.0 300.0 23:00 00:00 Deadhorse. SimOps: PU 3-1/2"IF mule shoe and RIH with(9)4-3/4"DC's. 3/24/2016 3/24/2016 0.50 COMPZN WELLPR WAIT T Wait for cleanout tools to arrive from 300.0 0.0 00:00 00:30 Deadhorse. SimOps: TOOH standing back DCs and lay down 3-1/2"IF mule shoe. 3/24/2016 3/24/2016 0.50 COMPZN WELLPR RURD T Offload cleanout tools and bring to the 0.0 0.0 00:30 01:00 rig floor. 3/24/2016 3/24/2016 1.50 COMPZN WELLPR BHAH T PU and MU BHA#2-cleanout 0.0 348.0 01:00 02:30 assembly. 3/24/2016 3/24/2016 2.00 COMPZN WELLPR TRIP T TIH with BHA#2 to 5018'RKB(PU= 348.0 5,018.0 02:30 04:30 110K and SO= 105K). 3/24/2016 3/24/2016 2.00 COMPZN WELLPR WASH T Mud pump#1 SPR: 2 BPM=140 psi 5,018.0 5,084.0 04:30 06:30 and 3 BPM=260 psi. Wash down from 5018'RKB at 2 BPM=140 psi, free torque=1300 ft-lbs,and tag at 5076'RKB. Continue to cleanout sand down to 5084'RKB with 10K down and circulate the well clean. 3/24/2016 3/24/2016 0.25 COMPZN WELLPR TRIP T Observer the well for flow for 10 5,084.0 5,084.0 06:30 06:45 minutes and the well is slightly taking fluid. Page 4/8 Report Printed: 4/5/2016 x qi • • Operations Summary (with Timelog Depths) ' .,*„ 1F-03'4 .F. ConocoPhitlips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code. Time P-T-X Operation (ftKB) End Depth(MB) 3/24/2016 3/24/2016 0.25 COMPZN WELLPR RURD T Lay down a joint of DP,stand back 1 5,084.0 4,987.0 06:45 07:00 stand of DP,and blow down the TD. 3/24/2016 3/24/2016 0.50 COMPZN WELLPR SVRG P Service and inspect the TD. 4,987.0 4,987.0 07:00 07:30 3/24/2016 3/24/2016 2.00 COMPZN WELLPR TRIP T TOOH with BHA#2 from 4987'to 348' 4,987.0 348.0 07:30 09:30 RKB. 3/24/2016 3/24/2016 2.50 COMPZN WELLPR BHAH T Lay down(9)4-3/4"DC's and BHA#2 348.0 0.0 09:30 12:00 -cleanout assembly. Clean and clear the floor. 3/24/2016 3/24/2016 0.50 COMPZN WELLPR WWWH T MU stack jetting tool to a joint of DP, 0.0 0.0 12:00 12:30 jet the stack to flush any sand out of the BOP stack,lay down stack jetting tool,and lay down joint of DP. 3/24/2016 3/24/2016 0.50 COMPZN RPCOMP RURD P RU Weatherford power tong and 0.0 0.0 12:30 13:00 handling equipment for running 5-1/2" scab liner. 3/24/2016 3/24/2016 2.75 COMPZN RPCOMP PUTB P PU and MU seal assembly,nipple 0.0 1,059.0 13:00 15:45 assembly, 1 joint of 3-1/2"tubing, SBE,23 joints of 5-1/2"15.5#casing, and HMC liner hanger/ZXPN liner top packer assembly to 1059'RKB(PU= 50K and SO=50K). 3/24/2016 3/24/2016 0.50 COMPZN RPCOMP SFTY P Safety stand up with CPAI town 1,059.0 1,059.0 15:45 16:15 management. 3/24/2016 3/24/2016 1.50 COMPZN RPCOMP RUNL P TIH with 5-1/2"scab liner on 3-1/2"DP 1,059.0 2,478.0 16:15 17:45 to 2478'RKB(PU=64K and SO= 64K). 3/24/2016 3/24/2016 0.25 COMPZN RPCOMP SFTY P Well control drill;kick while tripping. 2,478.0 2,478.0 17:45 18:00 Shut in time=33 seconds and CRT= 53 seconds. AAR with crew. 3/24/2016 3/24/2016 2.50 COMPZN RPCOMP RUNL P Continue to TIH with 5-1/2"scab liner 2,478.0 4,088.0 18:00 20:30 on 3-1/2"DP from 2478'to 4088'RKB (PU=90K and SO=90K). 3/24/2016 3/24/2016 0.25 COMPZN RPCOMP SFTY P Safety stand up with CPAI town 4,088.0 4,088.0 20:30 20:45 management. 3/24/2016 3/24/2016 2.00 COMPZN RPCOMP RUNL P Continue to TIH with 5-1/2"scab liner 4,088.0 5,064.0 20:45 22:45 on 3-1/2"DP from 4088'to 5064'RKB (PU=100K and SO=100K). 3/24/2016 3/24/2016 0.50 COMPZN RPCOMP RURD P RU circulating equipment. 5,064.0 5,064.0 22:45 23:15 3/24/2016 3/24/2016 0.25 COMPZN RPCOMP SFTY P PJSM for pumping corrosion inhibitor 5,064.0 5,064.0 23:15 23:30 with truck driver,Baker,and rig crew. 3/24/2016 3/25/2016 0.50 COMPZN RPCOMP HOSO P Roll the charge pump,SO,and seen a 5,064.0 5,083.0 23:30 00:00 pressure increase as seals entered the SBE at 5074'RKB. Bleed off the pressure and locate out at 5083'RKB with 10K down. 3/25/2016 3/25/2016 1.00 COMPZN RPCOMP HOSO P Tagging a couple feet higher than 5,083.0 5,083.0 00:00 01:00 expected. There still might be some fill. Review the number to confirm the seal location. Again roll the charge pump,SO,and seen a pressure increase as seals entered the SBE at 5074'RKB. Bleed off the pressure and locate out at 5083'RKB with 10K down. Page 5/8 Report Printed: 4/5/2016 • k 't 1444 Operations Summary (with Timelog Depths) fi41:01.14 1F-03 ConocoPhitHps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKS) End Depth(ftK6)' 3/25/2016 3/25/2016 0.50 COMPZN RPCOMP CRIH P Pull the seals out of the SBE. 5,083.0 5,060.0 01:00 01:30 Circulate 38 bbls of 10.6 ppg corrosion inhibited NaCI/NaBr brine at 3 BPM= 500 psi and chase with 36 bbls of 10.6 ppg NaCI/NaBr brine at 3 BPM=480 psi. 3/25/2016 3/25/2016 0.75 COMPZN RPCOMP PACK P Drop the ball&rod,SO to setting 5,060.0 4,032.0 01:30 02:15 depth,and PU to string weight. Pressure up to 1700 psi and set down 50K to set the HMC liner hanger. Continue to pressure up to 2900 psi to release the HRD-E liner running tool. Bleed the pressure off and PU to confirm running tool is released(PU= 90K),PU 8'to expose the rotating dog sub,and set down 45K to set the ZXPN liner top packer(good shear indication at surface). PU 15K to test liner top packer. 3/25/2016 3/25/2016 0.25 COMPZN RPCOMP PRTS P PT the ZXPN liner top packer and 7" 4,032.0 4,032.0 02:15 02:30 casing to 2500 psi for 10 minutes (good test). 3/25/2016 3/25/2016 0.75 COMPZN RPCOMP RURD P RD and blow down circulating 4,032.0 3,976.0 02:30 03:15 equipment. Install stripping rubbers and air slips. Lay down 1 joint of DP. 3/25/2016 3/25/2016 0.50 COMPZN RPCOMP SVRG P Service and inspect the TD. 3,976.0 3,976.0 03:15 03:45 3/25/2016 3/25/2016 2.25 COMPZN RPCOMP PULD P POOH with HRD-E liner running tool 3,976.0 1,645.0 03:45 06:00 laying down 3-1/2"DP from 3976'to 1645'RKB. 3/25/2016 3/25/2016 0.50 COMPZN RPCOMP TRIP P TIH with remaining stands in the 1,645.0 2,401.0 06:00 06:30 derrick to 2401'RKB. 3/25/2016 3/25/2016 2.50 COMPZN RPCOMP PULD P POOH laying down DP from 2401' 2,401.0 0.0 06:30 09:00 RKB to surface and lay down HRD-E liner running tool. 3/25/2016 3/25/2016 1.50 COMPZN RPCOMP RURD P MU wear ring pulling tool to a joint of 0.0 0.0 09:00 10:30 DP,pull the wear ring,lay down the wear ring pulling tool,and lay down joint of DP. Clean and clear the rig floor. Organize the pipe shed for running completion. RU Weatherford power tubing tongs and 3-12"tubing elevators. 3/25/2016 3/25/2016 6.00 COMPZN RPCOMP PUTB P PJSM. PU and MU seal assembly, 1 0.0 4,944.0 10:30 16:30 joint of 3-1/2"tubing,and GLM with SOV. RIH with 3-1/2"tubing installing GLM's per tally to 4944'RKB. 3/25/2016 3/25/2016 0.50 COMPZN RPCOMP RURD P RU circulating equipment to joint 4,944.0 4,944.0 16:30 17:00 #254. 3/25/2016 3/25/2016 0.75 COMPZN RPCOMP HOSO P SO,observed pressure increase as 4,944.0 4,956.0 17:00 17:45 seals engaged at 4972',and locate out at 4990'RKB. Lay down joint#'s 254, 253,and 252. MU joint 253 for space out(no pups needed). 3/25/2016 3/25/2016 0.25 COMPZN RPCOMP THGR P MU the tubing hanger and landing 4,956.0 4,971.0 17:45 18:00 joint with TIW. SO into position for pumping corrosion inhibitor. 3/25/2016 3/25/2016 0.25 COMPZN RPCOMP SFTY P PJSM with rig crew and truck drives 4,971.0 4,971.0 18:00 18:15 for pumping corrosion inhibitor. Page 6/8 Report Printed: 4/5/2016 • • qs i .4.:o ,." ° > _ Operations Summary (with Timelog Depths) 4- E men 1F-03 c ftthps A€•ak::a Rig: NABORS 7ES Job: RECOMPLETION Time Log start Depth Start Time.. End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (fEB) End Depth(ftKB)'.. 3/25/2016 3/25/2016 1.75 COMPZN RPCOMP CRIH P Pump 20 bbls 10.6 ppg hi vis spacer 4,971.0 4,971.0 18:15 20:00 followed at 2 BPM by 30 bbls 8.6 ppg hi vis spacer followed at 2 BPM by 200 bbls 8.6 ppg corrosion inhibited seawateer(ICP at 2 BPM=800 psi and FCP at 4 BPM=430 psi). Shut down the pumps 3/25/2016 3/25/2016 0.50 COMPZN RPCOMP THGR P Land the tubing hanger and RILDS. 4,971.0 4,983.0 20:00 20:30 3/25/2016 3/25/2016 1.50 COMPZN RPCOMP PRTS P PT the tubing to 3000 psi for 15 0.0 0.0 20:30 22:00 minutes(good test),bleed the tubing to 1500 psi,and PT the IA to 2500 psi for 30 minutes(good test). Bleed the IA to 0 psi,bleed the tubing to 0 psi, and ramp up the pressure on the IA to shear the SOV(sheared at 2500 psi). Pump 1 bbl down the IA at 1 BPM= 400 psi and pump 1 bbl down the tubing at 1 BPM=300 psi;does not appear that the SOV sheared properly. 3/25/2016 3/25/2016 0.50 COMPZN RPCOMP RURD P Blow down and RD circulating 0.0 0.0 22:00 22:30 equipment. RD TIW and lay down the landing joint. 3/25/2016 3/25/2016 0.25 COMPZN WHDBOP MPSP P Install 3"ISA BPV with dry rod. 0.0 0.0 22:30 22:45 3/25/2016 3/26/2016 1.25 COMPZN WHDBOP OTHR P Blow down all surface lines,choke 0.0 0.0 22:45 00:00 line,kill line,choke manifold,and hole fill. RD Weatherford power tubing tongs and elevators. Off load Weatherford equipment. 3/26/2016 3/26/2016 2.00 COMPZN WHDBOP OTHR P Remove the 5-1/2"solid body rams 0.0 0.0 00:00 02:00 from the lower ram cavities and install 2-7/8"x 5 VBR's into the lower ram cavities. 3/26/2016 3/26/2016 2.00 COMPZN WHDBOP OTHR P Cleanout under the rotary table and 0.0 0.0 02:00 04:00 steam tables with a super sucker. 3/26/2016 3/26/2016 2.00 COMPZN WHDBOP NUND P Pull the riser,remove lower Koomey 0.0 0.0 04:00 06:00 line off the annular,remove turn buckles,and attach the lift ring. ND the BOP stack and ND the DSA. Set the BOP stack on the stump and secure. 3/26/2016 3/26/2016 0.50 COMPZN WHDBOP NUND P NU tubing head adapter. 0.0 0.0 06:00 06:30 3/26/2016 3/26/2016 0.50 COMPZN WHDBOP PRTS P PT the tubing hanger void to 250/5000 0.0 0.0 06:30 07:00 psi(good test). 3/26/2016 3/26/2016 1.50 COMPZN WHDBOP NUND P NU the Cameron 3-1/8"tree. Change 0.0 0.0 07:00 08:30 the orientation of the swab valve 180° and torque the bolts. 3/26/2016 3/26/2016 0.50 COMPZN WHDBOP MPSP P Pull the 3"ISA BPV and install the tree 0.0 0.0 08:30 09:00 test plug with dry rod. 3/26/2016 3/26/2016 1.75 COMPZN WHDBOP PRTS P Fill the tree with diesel and RU testing 0.0 0.0 09:00 10:45 equipment. PT the tree to 250/5000 psi for 5 minutes each(good test). 3/26/2016 3/26/2016 0.25 COMPZN WHDBOP MPSP P Pull the tree test plug with dry rod. 0 0 0.0 10:45 11:00 3/26/2016 3/26/2016 1.00 COMPZN WHDBOP FRZP P RU circulating lines to freeze protect 0.0 0.0 11:00 12:00 the well and RU Little Red Services (LRS). Page 7/8 Report Printed: 4/5/2016 • rz‘t4J Operations Summary (with Timelog Depths) 1F-03 qtr conocommps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dor(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKD) 3/26/2016 3/26/2016 4.00 COMPZN WHDBOP FRZP T PJSM. PT LRS lines and circulating 0.0 0.0 12:00 16:00 lines to 3500 psi(good test). Start pumping diesel with LRS down the IA taking returns out the tubing to the cutting box at 1.75 BPM= 1600 psi, pressure continuing to increase,slow the pump rate to 0.3 BPM,but pressure continues to increase,and shutting down the pumps at 3000 psi. Pumped a total of 53 bbls into the IA. The SOV did not shear properly and closed while pumping diesel. Discussed options with town. 3/26/2016 3/26/2016 0.50 COMPZN WHDBOP FRZP P RD LRS and blow down circulating 0.0 0.0 16:00 16:30 lines. 3/26/2016 3/26/2016 0.25 COMPZN WHDBOP MPSP P Install 3"ISA BPV with dry rod. 0.0 0.0 16:30 16:45 Final well pressures: Tubing=0 psi, IA=95 psi,and OA= 175 psi. 3/26/2016 3/26/2016 2.25 DEMOB MOVE RURD P RD all cellar lines and RD annulus 0.0 0.0 16:45 19:00 valve. Install gauges on the tree, secure the well,and secure the cellar. Release the rig at 19:00 hours on 3-26 -16. Page 8/8 Report Printed: 4/5/2016 KUP ilif D1 F-03A ConocoPhillips $' Well Attribu Max Angle D TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) C0800bP.Niko, 500292085301 KUPARUK RIVER UNIT PROD 53.90 6,806.79 6,895.0 a,., L ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1F-03A,4/21/20166.25.49 AM SSSV:NONE 35 9/15/2010 Last WO: 3/26/2016 36.59 12/28/1982 Vertical schematic(actual) Annotation Depth(060) End Date Annotation Last Mod By End Date Last Tag:SLM 6,565.0 4/3/2016 Rev Reason:WORKOVER;GLV CIO;TAG lehallf 4/11/2016 HANGER,256 It Casing Strings • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len 0...Grade Top Thread _ CONDUCTOR 16 15.062 35.0 116.0 116.0 62.58 H-40 WELDED Casing Description 'OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ±I SURFACE 103/4 9.950 34.5 2,241.8 2,241.7 45.50 K-55 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I.. Grade 'Top Thread 1 II, PRODUCTION 7 6.276 32.5 5,231.0 5,124.2 26.00 K-55 BTC ' ' t`t`t'Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER 31/2 2.992 5,053.8 6,895.0 6,271.0 9.20 L-80 ABM-BTC titi CONDUCTOR;35.0.11t0- Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 5,053.8 4,959.9 22.49 TIEBACK BAKER TIEBACK SLEEVE 5.250 5,061.2 4,966.8 22.45 PACKER BAKER C-2 ZXP LINER PACKER 4.437 SURFACE;34.5-2,241.8 5,067.5 4,972.6 22.42 HANGER BAKER HMC HYDRAULIC LINER HANGER 4.375 II 5,074.3 4,978.9 22.38 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 GAS LIFT;2,494.4 1 Tubing Strings n Tubing Description String Ma...ID(in) Top(0140) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING RWO 2016 3 1/2 2.992 25.6 4.983.3 4,894.9 9.30 L-80 EUE Ord Mod ( Completion Details Nominal ID GAS LIFT;3,597.8 - Top(ftKB) Top(ND)(ftKB) Top Incl r) Item Des Com (in) 25.6 25.6 0.27 HANGER FMC Tubing Hanger,TC-1A-EN,6"x 3-1/2"EUE 8rd Box 2.992 x Box,3"ISA BPVG 4,964.6 4,877.6 22.90 LOCATOR Locator Sub,GBH-22(bottom of locator spaced out 6.9") 2.990 XO Threads;3,806.4 i 4,965.1 4,878.1 22.90 SEAL ASSY Seal Assembly,80-40 2.990 PACKER;4,031.6 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection LINER RWO 2016 51/2 4.825 4,031.6 5,082.8 4,986.7 15.50 L-80 Hydri(563 HANGER;4,048.0 ;II @4971 goes to 3 1/2" SOThreads;4,057.0 Nominal ID Completion Details Liner-Pup,4,058.8 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 4,031.6 4,017.8 19.15 PACKER HRD-E ZXPN Liner Top Packer(11.00'tie back sleeve 4.900 with 5.5"ID),5-1/2"Hydril 563 Box down GAS LIFT,4,430.1 ! 4,048.0 4,033.3 19.34 HANGER HMC Liner Hanger(9 cone),5-1/2"Hydril 563 Pin x BTC 4.870 Pin Liner;4,063.1 i gi 4,063.1 4,047.6 19.53 Liner Casing,5-1/2",15.58,L-80,Hydril 563 Box x Pin 4.825 4,971.6 4,884.1 22.88 XO Reducing Crossover,5-1/2"Hydril 563 Box x 5"BTCM Box 4.380 4,973.1 4,885.4 22.88 SBE SBE,80-40,5"BTC Pin x Pin(locating shoulder at 4.000 GAS LIFT;4,909.5 1': 4971.96) la 4,991.4 4,902.3' 22.82 XO Reducing Crossover,5"BTCM Box x 3-1/2"EUE 8rd Pin 2.960 l IF 5,039.0 4,946.3 22.57 NIPPLE Nipple,Camco,2.813"DS 2.813 5,056.7 4,962.6 22.48 LOCATOR Locator Sub,GBH-22(bottom of locator spaced out 3.38') 2.980 LOCATOR;4,984.5 MIR Ili 5,057.8 4,963.7 22.47 SEAL ASSY Seal Assembly,80-40 2.980 XO Reducing;4,971.6 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SEAL ASSY;4,985.1 'i Top(TVD) Top Incl SBE;4,973.0 Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 5,107.0 5,009.1 22.21 PLUG 2.72"SOS PIIP/RBP(ser#cpp35061)W/EQZ 3/18/2016 00 Reducing;4,991.4 .*' VALVE,FILL EXT&BULL NOSE @ 5110'RKB. ii Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/ NIPPLE,5.039.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 6,580.0 6,620.0 6,084.0 6,108.3 A-4,1F-03A 7/12/1996 4.0 (PERF 2.5"Hollow Carrier;180 deg Phase;93 deg. CCW Oriented Mandrel Inserts LOCATOR',5056.7 ;. I St ar a> ati ;' on Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn SEAL ASSY;5,057.81 2,494.4 2,494.2 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,297.0 3/31/2016 . 2 3,597.8 3,597.2 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,277.0 3/31/2016 It 3 4,430.1 4,388.9 Camco KBG-2- 1 GAS LIFT GLV INT 0.188 1,257.0 3/31/2016 id 9 IR 4 4,909.6 4,827.0 Camco KBG-2- 1 GAS LIFT OV INT 0.250 0.0 3/31/2016 SOV 9 did PLUG;5,107.0 N'. not shear prope Fly Notes:General&Safety End Date Annotation PRODUCTION,32s-5.231.5--.- 7/5/1996 NOTE:WELL SIDETRACKED OUT BOTTOM OF PRODUCTION CSG 1/30/2004 NOTE:VIDEO LOG SHOWS COLLAPSED LINER @ 6586' 6/5/2009 NOTE:TAGGED COLLAPSED LINER @ 6571 SLM 9/9/2010 NOTE:View Schematic w/Alaska Schematic9.0 IPERF;8,580.06,620.0 LINER;5,053.86,895.0 of ry • THE STATE o f Alaska Oil and Gas sLA .KA Conservation Commission � 333 West Seventh Avenue " `r? GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wh' ALAS�p' Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Diana Guzman Sr. Wells Engineer ' ConocoPhillips Alaska, LLC P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1F-03A Permit to Drill Number: 196-096 Sundry Number: 316-008 Dear Ms. Guzman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a/4iaq-4.4474... Cathy P.7 erster q Chair DATED this O day of January, 2016. Ci RBDMS`�JAN 1 1 2016 NIVEL ' • STATE OF ALASKA • JAN 0 6 2j016 ALASKA OIL AND GAS CONSERVATION COMMISSION QTS () 1" APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 7 Plug Perforations r Fracture Stimulate E Repair Well ✓• Operations Shutdown I Suspend %YY.. Perforate I Other Stimulate I- Pull Tubing . , Change Approved Program J Plug for Redrill Perforate New Pool L_.. Re-enter Susp Well I....- Alter Casing F Other: deiSii+q�7Rith 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number:✓✓ ConocoPhillips Alaska, Inc. • Exploratory fl Development 147. 196-096 3.Address: 6.API Number: Stratigraphic I— Service P.0.Box 100360,Anchorage,Alaska 99510 50-029-20$'553-01 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes ',7 No p-/ KRU 1F-03A 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL 25652 • Kuparuk River Field/Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth;Vpi MPSP(psi): Plugs(MD): Junk(MD): 6,898' 6,273' 65 $S 6 O S rKK I -7 q (, none Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 16" 116' 116' Surface 2,207' 10 3/4 2,242' 2,242' Intermediate Production 5,199' 7" 5,231' 5,128' Liner 1,841' 3 1/2 6,895' 6,275' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6580-6620=MD 6084-6108=TVD 3 1/2 L-80 5,061' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): BAKER C-2 ZXP PACKER • 5061=MD 4967=TVD SSSV: NIPPLE ' 494=MD 494=TVD 12.Attachments: Proposal Summary E Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 1— Stratigraphic 1- Development • Service F- 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1/19/2016 OIL y ' WINJ I— WDSPL E Suspended 1--- 16.Verbal Approval: Date: GAS F WAG I... GSTOR ..._ SPLUG I.... Commission Representative: GINJ I Op Shutdown Abandoned F- 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Diana Guzman Email Diana.Guzmanc Cop.com Printed Name Diana Guzman@265-6318 Title Sr.Wells Engineer ` �,a � �/� 1/q 16 Signature / Phone Date b/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\u_ - th c¢ `ts' Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 90P t2.-5,44 to Z SUv p s (MV 5 0 i'5 i ' p 5-/, /9-4,14-1c/-1 arpre Y'l.7 err f--r5- tv 2psI, . Post Initial Injection MIT Req'd? Yes ElNo ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /a - 4c ii_ APPROVED BY Approved by. P A CPMMISSIONER THE COMMISSION Date:_(- j (G, Form 10-403 Rev.ed 11/201 prov��a�xl�cAn�is valid for 12 tionnths from the date of,o7. FRB• U`,Jq ' i �� 6 J R 1... JAN 1 1 2016 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 4,2016 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover the Kuparuk Well 1F- 03A(PTD# 196-096). Well 1F-03A is a Kuparuk A sand only producer sidetracked in 1996 from the existing 1F-03 wellbore. The mother bore was shut-in in 1995 due to a fish in the hole and severe casing damage due to rock production from the C-sand. Several fishing attempts by slickline and coil tubing were unsuccessful. A video log performed in 2004 found the liner on 1F-03A collapsed at 6586'. Following a failed Tubing Integrity Fluid Level (TIFL) on 2013, a leak detect log (LDL) was ran in 2014. Tubing leaks were identified at 4914', 4755' and 4499'. During the diagnostics a possible casing leak was observed. A casing LDL was performed later that year and a casing leak at 4910' was identified. Prior to being shut-in in 2013 due to the tubing and casing leaks, well IF-03A production rate was 106 BOPD. The purpose of this workover is to repair the tubing and casing leaks on 1F-03A. This will be accomplished by pulling the existing 3 '/2"tubing and install a 5 '/2"scab liner with 3 '/2"tubing. This sundry is intended to document the proposed work on the producer well,as well as request approval to workover 1F-03A. If you have any questions or require any further information,please contact me at 907-265-6318. Sincerely, v1.2lA.w / Diana Guz n Wells Eng' eer CPAI Drilling and Wells • 1F-03A Rig Workover • Pull 3 Y2" Tubing, Install 5 1/2" Scab Liner w/ 3 1/4" Tubing (PTD #: 196-096) Current Status: This well is currently shut in and awaiting pre-RWO well work. Scope of Work: • Pull 3 'h"tubing. • Install 5 'h"scab liner and 3 'h"tubing. General Well info: Well Type: Producer MPSP: 1796 psi using 0.1 psi/ft gradient(Most recent SBHP=2633 psi on 11/01/12) Reservoir Pressure/TVD: 2381 psi/5847' TVD(7.8 ppg)on 11/01/12 Wellhead type/pressure rating: FMC Gen IV/5M psi BOP configuration: Annular/Pipe Rams/Blind Rams/Flow Cross/Pipe Rams TIFL/MIT results: CMIT—TxIA failed January 22,2014 MIT—OA passed December 2,2015 Earliest Estimated Start Date: January 19,2016 Drillsite Petroleum Engineer: Amanda Patterson Workover Engineer: Diana Guzman Work:265-6318 E-mail:Diana.Guzman@conocophillips.com Pre-Rig Work 1. Pull plug at 5110', obtain a new SBHP.Reset plug at 5110'. Dummy off all GLM's leaving bottom GLM open for circulation.Cut 3 'h"tubing at 5034' 2. PT tubing and casing packoffs,FT LDS's. 3. Set BPV. Proposed Procedure: 1. MIRU 2. Pull BPV. Circulate workover fluid. Obtain SITP& SICP, if still seeing pressure at surface,calculate new KWF,weight up,and repeat circulation as necessary. Verify well is dead. 3. Set BPV&blanking plug or two-way check,PT from below if possible.ND tree,NU BOPE&test to 2500 psig. 4. Pull blanking plug&BPV. Screw in landing joint,BOLDS's,and pull tbg hgr to the rig floor. 5. POOH laying down 3 'h"tubing. 6. RIH with new 5 'h" scab liner to assembly. Engage SBE. Space out. Pull out of SBE. Reverse circulate corrosion inhibited brine and diesel.Engage SBE and pressure up to set the liner hanger. 7. Slack off the liner top to set the liner top packer.PT the IA to 2500 psig to test liner for 10 minutes.POOH laying down inner string assembly and DP. 8. RIH with new 3 'h"tubing and gas lift completion. 9. Engage seal assembly into SBE. Space out w/pups,MU hanger. Spot a balanced pill of corrosion inhibited brine.Land the hanger.RILDS. 10. Install space out pups below the hanger,MU hanger. Land the hanger,RILDS. 11. PT the tubing_anIA.Ramp up the IA pressure quickly to shear the SOV. 12. Pull the landing joint,install two-way check.PT two-way check through IA. 13. ND BOPE,NU tree. Pull BPV,install tree test plug. Test tree. Pull tree test plug. • • 1F-03A Rig Workover Pull 3 '/2" Tubing, Install 5 '/2" Scab Liner w/ 3 1/2" Tubing (PTD #: 196-096) 14. Freeze protect well. 15. Set BPV. 16. RDMO. Post-Rig Work 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: Run GLD replace w/DV,retrieve plug. Set up for production. 4. Handover to Ops to put back on injection. • ConocoPhillips 1 F-03A Proposed Completion 5 1/2" Scab Liner with 3 1/2" Gas Lift 16"62.58#, H-40 to 116' MD ► Completion 31/2", 9.3#, L-80 8rd EUE Tbg ll 10 3/4"45.5#, K-55 to 2242' MD 1103 t/2"x 1 Y2" MMG Production Mandrel 3 1/2"x 1 '/2" MMG Production Mandrel J 5 Y2"x 7"ZXP& Flex Lock Liner Hanger �� 3'/2", 9.3#, L-80 IBTM-SCC Tbg 1I 5'/2" 15.5#, L-80, BTCM SCC l j ! 4-q IC1 iii I3 1/"x 1" KBG 2-9 Production Mandrel 3 '/2"x 1" KBG 2-9 Production Mandrel ii I 3 1/2"x 1" KBG 2-9 Production Mandrel 1 011 1 1 I• i i Nipple Profile Baker 80-32 LTSF • It• Baker ZXP Liner Packer& HMC Hydraulic Liner Hanger 7" 26.0#, K-55 to 5231 MD --► Perforations&Slots top)1VDi etm IWVD) Top ifloe) E.luue) (flue) IttKe) lou. Dat. 6•i.a 0 6.620 0 6.003 0 6 i 1^3 A-4 10-036 7)131996 3 1/2" 9.2#, L-80 to 6895'MD --0.- I Date: January 4,2016 I Drawn By: Diana Guzman KUP PROD 0 1F-03A ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska'Inc. Wellbore APIIUWI Field Name Wellbore Status eel(') MD(ftKB) Act Btm(ftKB) Cnnn,0rHArpf 500292085301 KUPARUK RIVER UNIT PROD 53.90 6,806.79 6,895.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1F-03A,2/15/2014 1:2720 PM SSSV:NIPPLE 35 9/15/2010 Last WO: 6/28/1996 36.59 12/28/1982 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ...................................................... Last Tag:SLM 6,183.0 11/1/2012 Rev Reason:PULL PATCH hipshkf 205/2014 HANGER;25.6 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread ,*, - - • •.. • • MN‘6,16666,CONDUCTOR 16 15.062 35.0 116.0 116.0 62.58 H-40 WELDED Cas ng Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len Len(I...Grade Top Thr 1 SURFACE 10 3/4 9.950 34.5 2,241.8 2,241.8 45.50 K-55 BUTT Casing Description 0D(in) ID(in) -Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 32.5 5,231.0 5,128.2 26.00 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD). Wt/Len(I...Grade Top Thread LINER 31/2 2.992 5,053.8 6,895.0 6,275.0 9.20 L-80 ABM-BTC Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inel(.1 Item Des Com (in) 5,053.8 4,963.9 22.49 TIEBACK BAKER TIEBACK SLEEVE 5.250 �`A`�t s 5,061.2 4,970.8 22.45 PACKER BAKER C-2 ZXP LINER PACKER s 4.437 CONDUCTOR;35.0.116.0 5,067.5 4,976.6 22.42 HANGER BAKER HMC HYDRAULIC LINER HANGER 4.375 5,074.3 4,982.9 22.38 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 NIPPLE;494.2 Tubing Strings Tubing Description String Ma...ID Ord Top(ftKB( Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 25.6 5,061.2 4,970.8 9.30 L-80 ABM-EUE Completion Details Nominal ID . Top(ftKB) Top(ND)(ftKB) Top tool(") Item Des Com (in) SURFACE;34.5-2,247.8- 25.6 25.6 0.30 HANGER FMC GEN IV HANGER 3.500 494.2 494.2 0.63 NIPPLE CAMCO DS NIPPLE 2.812 5,050.9 4,961.2 22.51 NIPPLE CAMCO D NIPPLE NO GO 2.750 5,057.9 4,967.7 22.47 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 4.000 GAS LIFT;2,294.7- ( 4 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) __ Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 5,108.0 5,014.1 22.20 PLUG SET WRP AT 5110'RKB MID ELEMENT 1/27/2014 p Perforations&Slots Shot GAS LIFT;3,702.9 ® Dens i Top(ND) Btm(ND) Ishotslt Top(566) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com -- 6,580.0 6,620.0 6,088.0 6,112.3 A-4,1F-03A 7/12/1996 4.0 IPERF 2.5"Hollow Carrier;180 deg Phase;93 deg. CCW Oriented Mandrel Inserts GAS LIFT,4,449.4 ':. St ati N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (MB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn I 2,294.7 2,294.7 CAMCO MMM ' 11/2 GAS LIFT GLV RK 0.188 1,249.0 11/5/2013 W/PK G GAS LIFT,5,004.9 2 3,702.9 3,702.9 CAMCO MMM 1 1/2 GAS LIFT GLV RK 0.188 1,257.0'11/5/2013 W/PK G - - 3 4,449.4 4,410.6 WFT MMM 11/2 GAS LIFT OV RK 0.188 0.0 11/5/2013 W/PK G NIPPLE;5.050.9 4 5,004.9 4,918.8 CAMCO MMM 11/2 GAS LIFT DMY RK 0.000 0.0 11/5/2005 Notes:General&Safety End Date Annotation 7/5/1996 NOTE:WELL SIDETRACKED OUT BOTTOM OF PRODUCTION CSG SEAL ASSY;5.0579 1/30/2004 NOTE:VIDEO LOG SHOWS COLLAPSED LINER @ 6586' 6/5/2009 NOTE:TAGGED COLLAPSED LINER @ 6571 SLM 9/9/2010 NOTE:View Schematic w/Alaska Schematic9.0 PLUG,5.108.0 PRODUCTION,325-5,231.0. IPERF;6580.0-6,6200 / LINER;5,0535-6,895.0 • • Bettis, Patricia K (DOA) From: Guzman, Diana <Diana.Guzman@conocophillips.com> Sent: Thursday, January 07, 2016 10:37 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 1F-03A (PTD No. 196-096): Sundry Application Patricia, The effective depth for 1F-03A is 6585' MD and 6088'TVD. Thank you so much for your help. Sincerely, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, January 07, 2016 9:16 AM To: Guzman, Diana Subject: [EXTERNAL]KRU 1F-03A (PTD No. 196-096): Sundry Application Good morning Diana, What is the current effective depth, both MD and TVD,for the KRU 1F-03A well. This information was missing from Form 10-403. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, January 07, 2016 9:16 AM To: 'Diana.Guzman@conocophillips.com' Subject: KRU 1F-03A (PTD No. 196-096): Sundry Application Good morning Diana, What is the current effective depth, both MD and TVD,for the KRU 1F-03A well. This information was missing from Form 10-403. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis( alaska.gov. 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. [ ~ ~ .. 0c/~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS' Scanned by: Beverly ~...,~.ann~Vincent TO RE-SCAN Nathan Lowell Date: 3-1~ Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl ConocoPhillips ~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 18, 2008 ~ jj~,,,~~ )YIH~ r :" ~UIJ~ ~~i'~~Pa.s! Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ ~ J n ~. ~ M h~ '+~3' '~ ~ 2®~g ~u . °e~ ~c1 ~s /~ ~ar~~. Co ~, ~., ~~CnOj~~~ rze~v}~jB~ Ij~ gLIF-p3A Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLI). 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 February 13th, 2009. The corrosion inhibitor/sealant was pumped March 4th, 11th & 16th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Pens ~u.,~~~ 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 3/16/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 F-01 A 205-029 7" N/A 7" N/A 1.7 3/16/2009 1F-02 182-211 SF N/A SF N/A 2.90 3/4/2009 1F-03A 196-096 SF N/A SF N/A 2.20 3/4/2009 1 F-04 182-172 20" N/A 20" N/A 5.20 3/4/2009 1 F-05 182-132 SF N/A SF N/A 1.60 3/4/2009 1 F-06 182-145 SF N/A SF N/A 2.10 3/4/2009 1 F-07 182-156 SF N/A SF N/A 2.40 3/4/2009 1F-08 182-162 SF N/A SF N/A 2.20 3/4/2009 1 F-10 183-105 20" NA 20" NA 1.70 3/11 /2009 1 F-12 183-136 54' 7.50 5'6" 2/13/2009 18.70 3/11/2009 1F-13 183-144 SF NA 6" NA 1.30 3/11/2009 1F-16A 201-209 SF NA 22" NA 1.70 3/11/2009 RECEIVED ALASKA OILAND GAS CONSERVATION COMMISSION DEC 2 6 Z005 REPORT OF SUNDRY WELL OPERA TION~aska Oil & Gas CoP~ COmfni$$ìor, Abandon D Repair Well 0 Plug Perforations D Stimulate D Other An~rage Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 196-0961 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20853-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 111' 1 F-03A Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 767 279 Not available Not available 15. Well Class after proposed work: Exploratory D Development 0 Service 0 16. Well Status after proposed work: oil0 GasD WAG 0 GINJD WINJ D 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: NA 1. Operations Performed: 8. Property Designation: Kuapruk River Unit 11. Present Well Condition Summary: Total Depth measured 6898' 6273' true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR SUR. CASING PROD. CASING LINER Length Size 16" 10-3/4" 116' 2130' 5120' 1841' 7" 3-1/2" Perforation depth: Measured depth: 6580-6620' . . true vertical depth: 6084-61080" Tubing (size, grade. and measured depth) 3-1/2" , J-55, 5054' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIPPLE SSSV= 494' 12. Stimulation or cement squeeze summary: NA Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Oil-Bbl 149 Not available Daily Report of Well Operations _X Contact Printed Name MJ Loveland/Marie McConnell MJ L~cconneIl659~ ~. STATE OF ALASKA 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool feet feet feet feet Plugs (measured) Junk (measured) MD TVD Burst Collapse 116' 2241' 5231' 6895' 116' 2241' 5124' 6~It. 5t;ANNED DEC 2 8 2005 Casinç¡ Pressure 706 Tubinç¡ Pressure 157 Not available Not available WDSPL 0 Title Phone: 659-7224 Problem Well Supervisor Date ReDMS 8Fl DEC 2 7 2nO~ / ~ -;;>-/-ð,s-- ORIGINAL Submit Original Only ) ) KRU C' ·Ph+Jf . AI' k' I . ,orU?c'Q :. J..fþS" ..$$.: .~~t nc~ ; 1 F-03A . NIPPLE (494-495, OD:4.540) TUBING (0-5054, OD:3.500, ID:2.992) Gas Lift andrellDummy Valve 1 (2295-2296, OD:6.018) Gas Lift andrellDum m y Valve 2 (3703-3704, OD:6.018) Gas Lift andrellDum m y Valve 3 (4449-4450, OD:6.018) Gas Lift andreI/Dummy Valve 4 (5005-5006, OD:6.018) NIP (5051-5052, OD:4.540) SEAL (5058-5059, OD:5.000) PROD. CASING (0-5231, OD:7.000, Wt:26.00) Perf (6580-6620) LINER (5054-6895, OD:3.500. Wt:9.20) ..:.:-:.:. 'Ii~:; -:- ..:.:.:.:. ~ .::: :::;:::::: ' tI:~:~¡¡¡j¡¡¡j:~j¡:¡::::¡¡:::::;::: . :.:.:.......... '................ I , .;:::~::::;:;:. :",:::::;::~:: ., I J:¡ :'::::1111 ~ ::;: :::;;::::: : jI1:ì~~ l:t I ~..~ i . .......... ~ till ; ··········1 IJ,~·é,::l·11 .....:...... I I r"""'~' I I~ ¡ ....""....,.. , t~~~~&1MK~tj t.·.:.·;·.:::.,·:~::.:.~~:;~. ~;.., - ~ ~ - API: 500292085301 SSSV Type: Nipple Well Type: PROD Orig 6/29/1996 Completion: Last W /0: 6/28/1996 Annular Fluid: Ref Log Date: TO: 6898 ftKB Max Hole Angle: 54 deg @ 6898 Reference Log: Last Tag: 6585 Last Tag Date: 10/9/2005 Casing String - ALL STRI NGS Description Size SUR. CASING 10.750 PROD. CASING 7.000 CONDUCTOR 16.000 LINER 3.500 TUbing String - TUBING Size I Top Bottom I:PØrfÓ~:6~n~:summarY":' .. . . 50~.4 Interval TVD 6580 - 6620 6084 - 6108 Top o o o 5054 Bottom 2241 5231 116 6895 TVD 4960 Wt 9.20 .. .... '" .' ... .... .. Zone A-4 Status Ft SPF 40 4 Date Type Comment 7/12/1996 IPERF 2.5" Hollow Carrier; 180 deg Phase; 93 deg. CCW Oriented FGás. Lift::MandrelsNaIVeš: St MD TVD Man Man Type Mfr Cameo Cameo Cameo Cameo .. ... ... V Mfr V Type V OD Latch DMY DMY DMY DMY 1.5 1.5 1.5 1.5 MMM MMM MMM MMM 1 2295 2295 2 3703 3701 3 4449 4406 4 5005 4915 1. WI. PKG 2. WI. PKG 3. Wl PKG 4. WI. PKG I ·Othêr:~~phJgs,::e(ìLiít).:, :etc~): ~··J·EWELRY::·· .. I Depth TVD Type 494 494 NIPPLE Cameo 'OS' ! 5051 4957 NIP Cameo '0' Nipple NO GO 5058 4964 SEAL Baker GBH-22 LOCATOR SEAL ASSEMBLY I 5061 4967 PACKER Baker Liner C-2 ZXP I d2~~i'äJ4~~e$ .:.:~:E~~.:...:: Baker 80-40 SEAL BOR~EXTENSION Date Note 1/30/2004 VIDEO LOG SHOWS COLLAPSED LINER @ 6586' 4/4/2004 TAGGED COLLAPSED LINER @ 6563' WLM Description 1 F ..03A Angle @ TS: 51 deg @ 6328 Angle @ TO: 54 deg @ 6898 Rev Reason: PULL PLUG, GLV C/O Last Update: 11/8/2005 TVD 2241 5124 116 6271 Wt 45.50 26.00 62.58 9.20 Grade K-55 K-55 H-40 J-55 Thread Grade J-55 Thread ABM-EUE .. ... ... ... . Port TRO Date Run 11/4/2005 11/5/2005 11/4/2005 11/5/2005 Vlv Cmnt (1 ) (2) (3) (4) RK RK RK RK 0.188 1285 0.188 1275 0.188 1255 0.188 0 . . ID 2.812 2.750 3.000 4.438 4.000 . .' . . fcAbi I"'ð fJot1t:-h S7e.f t"" t' Lf7'i3 ~ '1/1'3 ~Ifß f ConocoPhilIips Alaska, Inc. REPORT OF SUNDRY OPERATIONS 10-404 IF-03 (PTD 1960960) A tubing patch was set in Kuparuk we111F-03 on 12/17/05. The operations summary is as follows: 11/08/05 : RAN LDL: PUMPED DIESEL DOWN TBG AT 1.0 BPM WITH WELL SHUT IN WHILE LOGGING -- FOUND LEAK AT 4755', 5' BELOW A TBG JOINT 12/08/05 : DRIFTED TBG TO 5040' RKB WITH 2.74" x 22.5' DUMMY PATCH. 12/17/05: Set 2-piece 21.34 ft Eclipse patch over the leak at 4755 ft. Bottom packer was set at 4763 ft and the upper patch latched onto it, set at 4743ft. Final Eclipse patch interval 4743 to 4763 ft. Min ID = 1.63". Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 2C-05 2Z-09 2D-09 3F-03 3F-01 3F-15 1 F-03A 1 G-l1 1 J-164 3G-25X 1 Q-20A 11072930 11057062 11141218 11141219 11057064 11057065 11141222 11141221 N/A 11141229 11144038 SIGNED:¿~_~C~~.' '.- ~ . ~" r1 j c, (~~ E t\! r: D /'" t\ ¿ 1 2YJ5 i\J~i \c0 };. Gas Cons, C:J;rJ:¡~5s;cr i\nt~hor8g5 11/18/05 NO. 3604 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman f 333 West 7th Ave, Suite 100 b· - ÔQ \e7 Anchorage, AK 99501 \ C( -, Field: Kuparuk BL Color CD ~ ') a '2.Û\J~ r NO\! t.." fJ Log DescriP~~\.d¡· - - Date INJECTION PROFILE INJECTION PROFiLE LEAK DETECTION LOG INJECTION PROFILE PRODUCTION PROFILE INJECTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE USIT SBHP SURVEY SBHP SURVEY 11102/05 11/03/05 11/04/05 11/05/05 11/05/05 11/07/05 11/08/05 11/07/05 11/12/05 11/16/05 11/17/05 1 1 1 1 1 1 1 1 ì53-0'99 U¡ 1[y5-- \30 L'1C 15-'4- iò3 j 'ô3 -,;).;21 U'I ( iS5- d.}5 155 -/}.Cf5. U¡ C:.. #qLz~ 090 ì <1 C¡ -Ot:c:1.. ,205- 144- i Cff..p - i 30 /q5 -f5~ ¡q r, - cA Ø 1 1 1 --- DATE: n)PI ¡06 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ON OR BEFORE c:LO~vlylL~'DOC PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 07/07/98 RUN RECVD 96-096 NGP-MD 96-096 NGP-TVD 96-096 7601 ~111-6890 ~5013-6269 ~PERRY GR/RES 10-407 ~COMPLETION DATE ?~ /q~/ DAILY WELL OPS R ~//~/~ / TO ?//~/~ / Are dry ditch samples required? yes ~And received? Was the well cored? yes ~.Analysis & description received? Are well tests required? ~Tes ~~Received? Well is in compliance ~.~.~ In£[ial COMMENTS FINAL 01/15/97 FINAL 01/15/97 1 01/29/97 ~}~/~ I~l~ Iq~l /~ I~ I ~ I yes yes--fro WELL LOG TRANSMITTAL To: State of Alaska January 29, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. 6'~ ~ Anchorage, Alaska 99501 MWD Formation Evaluation Logs - 1F-03A AK-MW-60081 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.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted LIS tape with verification listing. API#: 50-029-20853-01 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company sperry-sun CI Ft I I--I--I ~ G S El I::! ~./I r' E S WELL LOG TRANSMITTAL To: State of Alaska January 15, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS 1F-03A, AK-MW-60081 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention off Ytrn Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 os m0 i: c) co. oct 2"x 5"MD Gamma Ray Logs: 50-029-20853-01 2"x 5" TVD Gamma Ray Logs: 50-029-20853-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, In¢, Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 22, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ORIGINAL Subject: 1F-03A (Permit No. 96-96) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1F-03A. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad RECEIVED OCT 2 $ 1998 Alaska Oil & Gas C;ons, Oommission Anohorage ....... ' STATE OF ALASKA ' : ~LASKA OIL AND GAS CONSERVATION C,.,.TIMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS r~ SUSPENDED ~] ABANDONED [] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 96-96 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 _._ 50-029-20853-01 · 4 Location of well at sudace ~" ?:{--~'~i'?:-;':':::i,:~t, .... , ........ ~ :~, .~,~,7.~..~'¢~.~. 9 Unit or Lease Name 1397' FNL, 347' FEL, Sec. 19, T11 N, R10E, UM [ ,,/; ....... Y'~;~L.[,~ ~ Kuparuk River Unit At lop Producing Interval 1356' FNL, 1622' FEL, Sec. 19, T11N, R10E, UM i t/i:):::;;:i~i; At Total Depth i .... f_'../_~L.~ : _~ . .......... ..',, .~_ ~ ..... ~ .... 11 Field and Pool 1296' FNL, 2069' FEL, Sec. 19, T11N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. Nordic Rig #2 RKB 32', PAD 79.4'I ADL 25652 ALK 2578 12 Date Spudded I 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore J16 No. of Completions 23-Jun-96 (sidetrack) 25-Jun-96 12-Jul-96 (perf'd) NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 6898' MD & 6273' TVD 6799 MD&6215 'I-VD YES xL~ NO L_JI NA feetMDI =1380'ss APPROX 22 Type Electric or Other Logs Run 23 ~_ CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT : ~ '~ (~RADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF. 116' 24" 150 sx AS II 10.75" 45.5# K-55 SURF. 2241' 13.5" 1000 sx Fondu Lead, 250 sx Permafrost O 7" 26# K-55 SURF. 5231' 8.5" 685 sx Class G, 250 sx Permafrost C (original wellbore) 3.5" 9.2# L-80 5061' 6895' 6.125" 340 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 5061' 5061' 6580'-6620' MD 4 spf 6084' - 6108' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6580'-6620' total proppant pumped was 213,469# (15072# of #20/40, 183154# of #12/18, and 15243# of #10/14) w/10 ppa of #10/14 @ perfs, left 991 # prop in wellbore 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 7/23/96I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO lO/~ ~/96 12 TEST PERIOD 12 103 951 176 176 9282 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 183 398 24-HOUR RATE I~ 205 1901 352 =24° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL [ ECEIVED OCT 2. 1996 Alaska 011 & (]as COrlS ~$it~Jlg:~te Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE _~. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6331' 5930' Bottom Kuparuk C 6376' 5958' Top Kuparuk A 6519' 6047' Bottom Kuparuk A 6710' 6162' FREEZE PROTECT ANNULUS WITH DIESEL 31. LIST OF A-I-I-ACHMENTS Directional Survey, Daily Drilling History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 9/5/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:iF-03A RIG'NORDIC WELL ID: 998446 AFC: 998446 TYPE- STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:06/15/96 START COMP: BLOCK: FINAL: WI: 0% SECURITY:0 AFC EST/UL:$ 885M/ 1125M API NUMBER: 50-029-20853-01 06/16/96 ( 1) TD: 0' ( 0) SUPV: DLW DAILY: 06/17/96 (2) TD: 0'( 0) SUPV:DLW DAILY: 06/18/96 (3) TD' 0' ( 0) SUPV: DLW DAILY: 06/19/96 ( 4) TD: 0'( 0) SUPV:DLW DAILY: 06/20/96 (5) TD' 0'( 0) SUPV:DLW DAILY: 06/21/96 ( 6) TD' 0' ( 0) SUPV: DLW MW: 11.0 PV/YP: 19/23 APIWL: 4.4 N/U 11" BOPS Turn key well to well rig move from 1F-20 to 1F-03A. Accept rig @ 0700 hrs. Pump seawater down tubing and take returns to production flow line to kill well. Well dead. Install BPV. N/D tree. N/U 11" BOPs. $56,173 CUM: $56,173 ETD: $0 EFC: $941,173 MW: 11.0 PV/YP: 19/23 APIWL: 4.4 CIRC & WAIT ON SCHLUMBERGER Continue N/U 13-5/8" BOPs. Test BOPs and manifold to 250/3500 psi, Hydril to 2500 psi. Pull on 3.5" tubing to 125K 80% strength. Work tubing unable to shear out of PBR. Circulate 11 ppg mud down tubing through GLM @ 5853' getting gas cut mud and losing 15 to 20 bbls per/hr. Wait on Schlumberger to cut tubing. $37,863 CUM: $94,036 ETD: $0 EFC: $979,036 MW: 11.0 PV/YP: 19/23 APIWL: 4.5 RIH W/7" RETAINER ON DP R/U to cut tubing @ 5883' Work tubing unable to break tubing where cut. RIH with super cutter %2 and make cut 1.5" joints above GLM @ 5862' Work tubing pulled up to ll0K tubing parted @ cut up weight 55K, pull tubing to rig floor. Pull and L/D 184 joints & cut off of 3.5" tubing. RIH with cement retainer on 3.5" DP. $49,434 CUM: $143,470 ETD: $0 EFC: $1,028,470 MW: 9.7 PV/YP: 16/43 APIWL: 3.6 POOH TO CHANGE TBG SPOOL Set 7" 'K-i' cement retainer @ 5441' Test casing to 3000 psi for 15 min. OK. Sting into retainer and pump cement slurry. CIP 1618 hfs 6/18/96. Condition mud to milling fluid 9.6 ppg. Build and spot 18 ppg pill to cover from 5000' to 5440' Prepare to cut 7" section @ 5231' to 5281' $53,942 CUM: $197,412 ETD: $0 EFC: $1,082,412 MW: 9.8 PV/YP: 20/51 APIWL: 3.8 RIH W/7" SECTION MILL N/D 13-5/8" stack. N/D 11" 3M x 11" 3M tubing spool, change 7" x 10-3/4" packoff, install 11" 3M x 7-1/16" 5M tubing spool. Test packoff to 3000 psi for 15 min. OK. N/U 7-1/16" BOPs. Test BOPs & manifold to 250/3500 psi, Hydril to 250/3000 psi. RIH with 7" millmaster section mill. $47,852 CUM: $245,264 ETD: $0 EFC: $1,130,264 MW: 10.1 PV/YP: 23/54 APIWL: 3.8 RIH W/OPEN ENDED 3.5" DP Spot section mill knives @ 5231' Start pumps slowly and make cut out. Mill 50' section to 5281' Good iron recovery Date: 9/5/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 DAILY: 06/22/96 ( 7) TD: 5150' ( 0) SUPV:DLW DAILY: 06/23/96 (8) TD: 5525' (375) SUPV: DLW DALLY: 06/24/96 (9) TD: 6100' (575) SUPV:DLW DAILY: 06/25/96 (10) TD' 6890' (790) SUPV:DLW DAILY: 06/26/96 (11) TD' 6890' ( 0) SUPV:DEB DALLY: 06/27/96 (12) TD: 6898' ( 8) SUPV:DEB DAILY' 06/28/96 ( 13} TD: 6898' ( 0) SUPV:DEB DAILY: throughout job. M/U 3.5" mule shoe joint RIH to 5380' $56,001 CUM: $301,265 ETD: $0 EFC: $1,186,265 MW: 10.4 PV/YP: 23/61 APIWL: 3.8 C/O CEMENT @ 5150' Pump cement. CIP @ 0753 hrs. 6/21/96. Run hesitation squeeze. M/U drilling BHA %1 M/U and break in new HWDP while running in hole. RIH on 3.5" DP. Tag cement stringers @ 4962' Circulate and condition cement contamination from 4975' to 5075' Firm cement. Clean out firm cement to 5150'. $64,329 CUM: $365,594 ETD: $0 EFC: $1,250,594 MW: 9.9 PV/YP: 13/19 APIWL: 5.7 DRILLING 6-1/8" HOLE @ 5525' Clean out firm cement from 5150' to 5236' Kick point 5' below 7" section. Rotate and drill 6-1/8" new hole to 5300' Perform FIT. Continue to directional drill 6-1/8" hole from 5300' $51,552 CUM: 6417,146 ETD' $0 EFC: $1,302,146 MW: 10.0 PV/YP: 15/26 APIWL: 6.6 DRILLING 6-1/8" HOLE @ 6100' Continue directional drilling 6-1/8" hole by sliding from 5530' to 5865' for angle build and direction. Rotate and drill ahead from 5865' to 6100' $58,521 CUM: $475,667 ETD: $0 EFC: $1,360,667 MW: 11.2 PV/YP: 22/38 APIWL: 4.1 SHORT TRIP @ 6890' TD 6-1/8 H Continue directional drilling 6-1/8" from 6100' to 6302'. FIT @ 6302' MD. 12.6 ppg EMW. Continue drilling 6-1/8" hole from 6302' to 6890' TD 6-1/8" hole. , $55,495 CUM' $531,162 ETD' $0 EFC' $1,416,162 MW: 11.7 PV/YP: 19/26 APIWL: 4.6 RUNNING 3.5" LINER Got gas & oil cut mud at about half way to bottoms up. Close bag & circulate out gas cut thru poor boy degasser. Monitor well, stable. Wash to bottom @ 6890' no fill , · Circulate 2 bottoms up to condition mud and hole. No gas cut, hole stable. Run 3.5" liner. $46,218 CUM: $577,380 ETD: $0 EFC: $1,462,380 MW: 11.7 PV/YP: 19/26 APIWL: 4.6 LDDP RIH with liner on 3.5" DP to 5177' Pump cement. Bumped plug. CIP @ 1700 hrs. 6/26/96. $88,429 CUM: $665,809 ETD: $0 EFC: $1,550,809 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 DISPLACE TO SEA WATER Test BOPE to 300/3500 psi, Annular to 300/3000 psi. Pull test plug. Load 3.5" tubing & jewelry into pipe shed. Run 3.5" completion assembly. Test 7" casing & 3.5" liner to 3500 psi for 30 minutes, no loss, OK. Reverse circulate sea water into well. $38,267 CUM: $704,076 ETD: $0 EFC: $1,589,076 Date: 9/5/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 3 06/29/96 (14) TD: 6799' ( 0} SUPV:DEB DAILY: MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Freeze protect well. Test tubing to 3500 psi for 15 minutes, lost 125 psi, OK. Hook up kill line to annulus. Bleed off tubing. Test annulus to 3500 psi for 15 minutes, lost 100 psi, OK. ND BOPE. NU tree. Test tree to 250/5000 psi. Test packoff to 5000 psi. Secure well. Prepare rig for move. Release rig @ 1730 hfs, 6/28/96. $108,193 CUM: $812,269 ETD: $0 EFC: $1,697,269 End of WellSummary for We11:998446 KUPARUK RIVER UNIT WELL SERVICE REPORT KI(1F-03A(W4-6)) Wl:'I I. JOB NUMBER 1F-03A 0702961920.2 DATE 07/12/96 DAY 3 JOB SCOPE PERFORATE, PERF SUPPORT DAILY WORK UNIT NUMBER PERF 'A' SAND OPERATION COMPLETE I SUCCESSFUL Il KEY PERSON SUPERVISOR YES YES SWS-JOHNSON PAIGE Initial Tbg Pr~s$ I Final TUg Press IInitia~ Inner AI'[n F~al ~er ~0 i~SI 975 PSI 0 PSI 0 PSI Ir~itial Outer Ai'l.n 1250 DAILY SUMMARY Final Outer Ann 250 PSI PERF 'A' SAND INTERVAL 6580'-6620' (REF NGP DATED 6/26/96) US]BIG 2-1/2" HOLLOW CARRIER W/BH CHARGES, 4 SPF, 180 DEG PH, [ ORIENTED 93 DEG CCW F/HIGH SIDE. WHP ]NCR 975# FOLLOWING PERF JOB. I TIME LOG ENTRY 08:00 MIRU SWS. HELD SAFETY MTG. 09:00 RIH W/TOOL STRING - WGT BAR, CCI_,, GR 10:30 COMPLETED RUNNING GR LOG W/CCL FOR TIE-]N 11: 00 AT SURF W/TOOL STRING 11:15 PT LUB TO 3000~; TEST OK. RIH W/GUN#1 - CCL, MPD, 20' 2-1/2" HOLLOW CARRIER W/BH CHARGES, 4 SPF, 180 DEG PH, ORIENTED 93 DEG CCW F/HIGH SIDE TO SHOOT 6600' - 6620' (REF NGP DATED 6/26/96) 11:45 IN POSITION TO SHOOT PERFINTERVAL; ]NCR WHP TO 1500#. FIRED GUN#1. POH. 12: 00 GUN STICKING; PULLED 900~ OVER LiNE WGT TO GET OFF. CONTINUE POH. 12:30 AT SURF W/GUN#i; ALL SHOTS FIRED. 12:50 PT LUB TO 3000g; TEST OK. RIH W/GUN#2 - CCL, MPD, 20' 2-1/2" HOLLOW CARRIER W/BH CHARGES, 4 SPF, 180 DEG PH, ORIENTED 93 DEG CCW F/HIGH SIDE TO SHOOT 6580' - 6600' (REF NGP DATED 6/26/96) 13:30 FIRED GUN#2; POH. 13: 50 GUN STICKING; PULLED 1400~ OVER LINE WGT TO GET OFF. CONTINUE POH. 14:30 AT SURF W/GUN#2; ALL SHOTS FIRED. 15:30 RDMO. SPE~_R,Y-SUN DRILLING SERVICES ANCHORAGE AJ.J~S ~ PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT/1F-03A 500292085301 NORTH SLOPE SLOPE COMPUTATION DATE: 7/31/96 DATE OF SURVEY: 062596 MWD SURVEY JOB NUMBER: AK-MW-60081 KELLY BUSHING ELEV. = 111.00 FT. OPERATOR: ARCO ALASKA, INC. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 5251.00 5143.00 5032.00 21 7 S 85.02 W .00 48.00S 570.00W 545.98 5274.25 5164.58 5053.58 22 28 S 86.18 W 6.09 48.66S 578.61W 554.24 5304.41 5192.36 5081.36 23 23 S 86.89 W 3.15 49.37S 590.34W 565.54 5337.61 5222.71 5111.71 24 23 S 87.59 W 3.13 50.01S 603.77W 578.51 5366.22 5248.68 5137.68 25 16 S 88.40 W 3.30 50.43S 615.78W 590.14 5396.66 5276.00 5165.0.0 26 59 S 88.70 W 5.67 50.77S 629.18W 603.14 5426.83 5302.68 5191.68 28 40 S 88.70 W 5.57 51.09S 643.26W 616.82 5461.65 5332.95 5221.95 30 36 N 86.80 W 8.46 50.79S 660.46W 633.68 5491.06 5357.96 5246.96 32 49 N 87.00 W 7.56 49.95S 675.89W 648.92 5521.66 5383.37 5272.37 34 55 N 87.00 W 6.90 49.06S 692.92W 665.74 5552.80 5408.61 5297.61 36 42 N 84.50 W 7.40 47.70S 711.09W 683.77 5584.46 5433.88 5322.88 37 22 N 83.40 W 2.98 45.69S 730.05W 702.72 5616.14 5458.96 5347.96 37 56 N 83.40 W 1.77 43.46S 749.28W 721.97 5648.35 5484.23 5373.23 38 44 N 81.20 W 4.91 40.78S 769.08W 741.88 5678.80 5507.67 5396.67 40 31 N 81.10 W 5.88 37.80S 788.27W 761.26 5710.86 5531.78 5420.78 41 56 N 79.80 W 5.15 34.29S 809.10W 782.36 5740.97 5553.84 5442.84 43 49 N 78.70 W 6.72 30.46S 829.23W 802.83 5773.55 5576.87 5465.87 46 11 N 78.40 W 7.30 25.89S 851.80W 825.86 5804.88 5598.07 5487.07 48 38 N 77.40 W 8.17 21.05S 874.35W 848.92 5868.72 5638.91 5527.91 51 49 N 80.80 W 6.45 11.81S 922.52W 897.95 5964.03 5698.11 5587.11 51 24 N 77.00 W 3.16 2.56N 995.81W 972.61 6054.33 5754.88 5643.88 50 44 N 82.50 W 4.79 15.07N 1064.88W 1042.75 6149.24 5815.10 5704.10 50 30 N 83.80 W 1.09 23.82N 1137.71W 1115.75 6246.36 5876.73 5765.73 50 43 N 83.40 W .39 32.19N 1212.30W 1190.37 6337.11 5933.81 5822.81 51 19 N 80.20 W 2.82 42.25N 1282.10W 1260.69 6430.86 5992.16 5881.16 51 42 N 84.20 W 3.36 52.20N 1354.78W 1333.80 6526.59 6051.37 5940.37 51 53 N 83.60 W .53 60.20N 1429.58W 1408.55 6620.15 6108.46 5997.46 52 54 N 85.00 W 1.60 67.55N 1503.33W 1482.13 6712.15 6163.34 6052.34 53 53 N 79.90 W 4.58 77.27N 1576.50W 1555.67 6806.80 6219.11 6108.11 53 54 N 80.60 W .60 90.22N 1651.86W 1632.05 6898.00 6272.85 6161.85 53 54 N 80.60 W .02 102.26N 1724.56W 1705.63 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1727.59 FEET AT NORTH 86 DEG. 36 MIN. WEST AT MD = 6898 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 282.54 DEG. TIE-IN SURVEY AT 5,251.00' MD PROJECTED SURVEY AT 6,898.00' MD RECEIVED OC'r · : ...... , 1996 Alaska Oil & Gas Cons, Anch~rag.~ Tape 'Subfi!e 2 is type: 1 TAPE HEADER KUPARUK RIVER UNIT LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1F-0BA 500292085301 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 20-JAN-97 MWD RUN 1 AK-MW- 60081 T. FLYNN D. WESTER 19 liN 10E 1397 347 111.00 104.50 74.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 116.0 10.750 2241.0 7.000 5231.0 6.125 6890.0 MWD - GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. THIS WELL, 1F-03A, WAS KICKED OFF FROM 1F-03 THROUGH A WINDOW CUT IN THE 7" CASING FROM 5231 - 5281'. THIS WELL IS REPRESENTED BY 1 RUN, WHICH IS DIRECTIONAL WITH NATURAL GAMMA PROBE, A SCINTILLATION TYPE GAMMA RAY (NGP/SGRD) . WELL 1F-03A WAS DRILLED TO TD AT 6890'. NO DEPTH SHIFTS WERE APPLIED PER LYNN GETTINGER, ARCO ALASKA, INC. TONY KNOWLES, GOVERNOR ~LASKA OIL AND GAS ~ONsERYATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 16, 1996 Michael Zanghi Drill Site Develop. Supv. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1F-03A ARCO Alaska, Inc. Permit No. 96-96 Sur. Loc. 1397'FNL, 347'FEL, Sec. 19, T1 IN, R10E, UM Btmnhole Loc. 1223'FNL, 2046'FEL, Sec. 19, T1 iN, R10E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to redrill the above referenced well. Approval for annular injection is contingent on the operator's submittal of an Application for Sundry Approvals (10-403)with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and any diagnostic logs that were nm. The documentation submitted should assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to wimess a test of BOPE installed prior to drilling new hole. Notice max' be given bx' ld inspector on the North Slope pager at 659-3607. David W. 3o~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE D/4, 99501. Date: 1 July 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: DESCRIPTION WELL ?{_0%~Y-01 i PLS F=NAL BL+RF X-11/ I PLS FIN~ ~L+R~ H-17 (34-15-11-13) '--"' 1 PFC/PERF FINAL BL+RF B-05A~'"' 1 CCL FIN~ BL+RF ECC No. Run # 1 801.05 Run ~ 1 3886.02 Run # 1 4735.04 Run ~ 1 5665.12 Run $ 1 6713.01 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by: . _ _ Date: JUL 1 2 1995 0i~ & G~s C. on~. Commission A~qcho~a~te HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHOP_AGE AK, 99501. Dear Sir/Madam, Reference: BP PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Date: RE: DLL/MLL FINAL BL+RF Run # 1 ZDL/CN FINAL BL+RF Run # 1 ~ CN FINAL BL+RF Run # 1 1 DAC FINAL BL+RF Run # 1 BH PRO FINAL BL+RF Run # 1 ~1 SSVD FINAL BL+RF Run # 1 27 June 1996 Transmittal of Data ECC #: 6713.00 Sent by: HAND CARRY Data: OH-LDWG Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 J~chorage, ~ 99518 Or~07) 563-7803 Date: R GEIVEL) JUL n. & nc,,. nnn_~ nnmmis~Jon Anchorage STATE OF ALASKA ALA~'KA OIL AND GAS CONSERVATION COIVIMIS~ON PERMIT TO DRILL 20 AAO 25.005 la. TypeofWork Drill Redrill X lb TypeofWell Exploratory E] StratigraphicTest E] Development Oil X Re-Entry r'! Deepen r=l Service I--I Development Gas I--I Single Zone X auitipleZone [-~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 111', Pad 79.4' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25652, ALK 2578 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.O25) 1397' FNL, 347' FEL, Sec. 19, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1317' FNL, 1625' FEL, Sec. 19, T11N, R10E, UM 1F-03A #U-630610 At total depth 9. Approximate spud date Amount 1223' FNL, 2046' FEL, Sec. 19, T11N, R10E, UM 6/5/96 $200~000 12. Distance to nearest 13. Distance Io nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) property line 1 F-04 6881' MD 3655' @ Target feet 120' @ surface feel 2560 6271' TVD leer 16. To be completed for deviated wells 17. Anticipaled pressure (see 2O AAC 25.035(e)(2)) Kickoff depth 5251' feet Maximum hole angle 50.3° Maximurnsurface 2750 pslg At total depth (TVD) 3400 pslg 18. Casing program Settin~l Depth size Specifications Top Bottom Quantib/ of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sla~le data) 6-1/8' 3-1/2' 9.3# L-80 BTC 1800' 5081' 4986' 6881' 6271' 330sxs Class G ,FFm:iVFD 19. To be completed for Reddll, Re-entry, and Deepen Operations. ~/~¥ v Present well condition summary Total depth: measured 6712 feet Plugs (measured) true vertical 6543 feet ~ask~ 011 & Gas Cons, Commission Anchorage Effective depth: measured 6 61 5 feet Junk (measured) true vertica 6449 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' 1 6' 150 Sx AS II 1 16' 1 16' Surface 2205' 10-3/4' 1000 sx CSlII, 250 sx Permafrost C 2241' 2241 ' Intermediate Production 6650' 7 ' 650 sx Class G, 250 sx Permafrost C 6691' 6524' Liner Perforation depth: measured 6076'-6110', 6195'-6203', 6216-6249' MD true vertical 5925'-5962', 6041'-6048', 6061'-6093' TVD 20. Altachments Filing fee X Property plat [-~ BOP Sketch X Diverter Sketch [--~ Drilling program X Drilling fluid program X Time vs depth plot D Refraction analysis E] Seabed report D 20 AAC 25.050 requirements X Signed Title Drill Site Develop. Supv. Date ?'"- Commission Use Onl)/ Permit Number I APl number - . I Approval date.~-/ /.~ ~ See cover letter for ?~'- ~'~' I 5 0- (~ .7._ q -' 2. O ~ ~..~ .' O J I 5/! ~/V~ I other requirements Conditions of approval Samples required O Yes '~ No Mud logrequirbd [] Yes J~ No Hydrogen sulfide measures r~ Yes D No Directional survey required [] Yes D No Required working pressure for BOPE E] 2M r~ 3M D 5M [~] 10M D 15M Other: Original Signed By David W. Johnston by order ofrr'~"'//~, ,/~ Approved by Commissioner the commission Date . Fnrm 113-401 RRv 7-24-R.Cl ,~ ~lic.,3fR REDRILL PLAN SUMMARY Well 1F-03A Type of well (producer/injector): Surface Location: Target Location: Bottom Hole Location: MD: TVD: Rig: Estimated Start Date: Operation Days to Complete: Producer 1397' FNL, 347' FEL, SEC 19, T11N, R10E, UM 1317' FNL, 1625' FEL, SEC 19, T11N, R10E, UM 1223' FNL, 2046' FEL, SEC 19, T11N, R10E, UM 6881' 6271' Nordic Rig 2 6-5-96 15 Drill FIuid~ Pr~pgram: Milling Section in 7" casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.5 >25 15-35 85-95 20-30 30-40 8.5-9.5 Kick off to weight up 9.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.3 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Swaco Geolograph Adjustable Linear Shaker Brandt SMC-10 Mud Cleaner Triflow 600 vacuum Degasser, Poor Boy Degasser Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators and Jetting Guns REC£1V D MAY 0 9 1996 011 & Ga~ Cons. commission Anchorage Notes: Ddlling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page 1 Casing/Tubing Hole size 6-1/8" Program: Csg/'l'bg 3-1/2", 9.3#, L-80, BTC Tubing 3-1/2", 9.3#, L-80, EUE Length TQ_D {MD/'rVD) Btm (MD/I'VD 1800' 5081 '/4986' 6881 '/6271' 5052' 29'/29' 5081 '/4986' Cement Calculations: Casina to be cemented: -- 3-1/2" in 6-1/8" open hole Volume = 330 sxs of class G Blend @ 1.19 cu ft/sx Based on: Shoe volume, open hole volume + 50%, & 150' liner lap. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 2,750 psi and is calculated using a gas column to surface. The expected leak-off at the section cut in the 7" casing is estimated at 14.5 ppg EMW. With an expected formation pressure in the Kuparuk of 3400 psi and a gas gradient of 0.11 psi/fi, this shows that formation breakdown would not occur before a surface pressure of 2,750 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE schematic. Drilling Hazards: Lost Circulation: Ove _rpressured Intervals: Other HCzards; The suspect lost circulation zones throughout the Kuparuk field are the K- 10 and the K-5 intervals. The sidetrack 1F-03A, will kick off out of the 7" casing +/-1,235' TVD below the K-10 and +/-102' below the K-5 interval. The casing around the kick-off window will be squeezed with cement pdor to ddlling out, which should isolate the K-10 and K-5 from the sidetrack operations. Nevertheless, even If not isolated the K-10 and K- 5 intervals should be able to handle the expected mud weights to be used for this sidetrack. Off-set ddlling data shows that several wells in the area of 1F-03 were ddlled to TD with 11.5 ppg mud without any loses. The kick-off point in 1F-03A is below any zones which would be of pressure concern prior to weighting up for the Kuparuk interval. None Directional- KOP: Max hole angle: Close approach: 5251' MD / 5143' TVD 50.3° (in sidetrack portion) No Hazards RECEIVED MAY 09 199(; Alaska 0tt & Gas Cons. Commission Anchorage Page 2 Logging Program: Open Hole Logs: GR/Resistivity Cased Hole Logs: GR/CCL Notes: All ddll solidsgenerated from the 1F-03A sidetrack will be hauled to CC-2A in Prudhoe Bay for gdnd and inject. If the Kuparuk River bddge outage will not allow trucking of these solids to Prudhoe, they will be stored and later processed or disposed of in a permitted solids disposal area. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or to Parker 245 to be disposed by annular pumping into the permitted annulus Parker is connected to at that time. The permitted well will be within the Kuparuk River Unit. R£C£ V£D ~Ay 09 1996 Na~k~ 011 & Ga~ Cons. Gommis~ion Anchorage Page 3 KRU 1 F-03A GENERAL SIDETRACK PROCEDURE PRE-RIG WORK: 1. RU slickline unit. RIH and dummy off all GLMs, leave deepest GLM open. Leave circulation valves in all C Sand mandrels. 2. Set BPV in tubing. Install VR plug in annulus valve if necessary. WORKOVER RIG WORK: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits w/kill weight mud. Circulate well to kill weight mud. Ensure well is dead. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH laying down all tubing and jewelry. . PU DP and RIH with cement retainer. Set retainer at 5435' MD. Pump cement squeeze below retainer into A and C Sand perfs filling 7" casing to bottom A Sand perf / top of fill. Unsting from retainer and circulate well to milling fluid. Spot an 18 ppg balanced mud pill from PBTD to the base of proposed section. POOH standing back DP. 6. RIH w/section mill. Cut a 50' section in the 7" casing from 5235' - 5285'. POOH w/mill. . RIH w/open ended DP. Wash down through section and circulate any metal shavings from well. Mix and pump balanced cement kick-off plug f/100' below base of section to 200' above top of section. POOH. . . 10. 11. 12. RIH w/6-1/8" bit, mud motor, MWD, and steerable ddlling assembly. Dress off cement to top of section. Kick-off well and directionally ddll to total depth as per directional plan. Short tdp to window in casing. POOH. Run 3-1/2" liner to TD w/150' of ovedap to top of milled section. Cement liner. Set liner hanger and liner top packer. POOH w/DP. Pressure test casing and liner lap to 3500 psi for state test. RECEIVED MAY 09 1996 Alaska 011 & Gas Cone. Commissior~ Anchorage RIH w/completion assembly and sting into polished bore receptacle at top of liner. Space out. Displace well to sea water at max rate. Test tubing and annulus. 13. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. 14. Clean out well to PBTD w/coiled tubing. Perforate through tubing. Lower Limit: 12 days Expected Case: 14 days Upper Limit: 20 days No problems milling section, ddlling new hole, or running completion. Difficulties encountered milling section, or ddlling new hole. WSl 5/6/96 Page 4 ARCO ALASKA, Inc. Structure : Pad 1F Well : SA Point IKOP I. End of Build iTarget iEnd of Hold iEn~ 9f Hold WELL MD 52.5'1 575~1 651e/ 6681 68~1 TD LOCATION: 1225' FNL, 204.6' FEI,. SEC. 19, TllN, R10E 5100_ 5250_ (D 5400_ r~ '-~ 5550_ 23.87 Field : Kuparuk River PROFILE DATA -- Inc Bit TUg North East Deg/lOOJ 21.13 265.0Z 51 H~, -48 -570 0.00J I 50.14 282.54- 55 ,;lt.-13 -858 6.00I 50.14- 282.54. 591H 80 -1278 0.00 50.14- 282.54. 61q~ 140 -154.9 0.OO 50.14- 282,54 62-7J 174 -1699 Unit Location : North Slope, Alaska N 77.46 DEG W (TO 1800 1700 16OO I i I I I < W e s f · o.oo 1500 14OO 1300 1200 1100 1OO0 900 800 700 600 500 400 400 0.3 5700_ _ :3 5850_ I-- - I - V 615o_ -- 6300_ 645O_ I I I I 450 600 Scole 1 : 75.00 .~,~, TARGET LOCATION: 1517' FNL 1625' ~ KOP -- ~de~ck ~ (~pth Shiff~) SEC. 19, T11N, RIOE AVERAGE ANGLE Ba...z 50.14 DEG K-! Mank~ 40,95 ¢6.78 EOC T~J~{~c'r - T/ Unit C Unit B 300 200 ? _ 100 I aa 100 Top Unit A Top Unit A4. Base Kup Sands 29.45 55.16 I I I I I I I I I I I I I- I I ''1 750 900 1050 1200 1350 1500 1650 1800 Vertical Section on 282.54 azimuth with reference 0.00 N, 0,00 E from slot #SA Cre~ted by : ~ For: B ISAACSON Dote INotted : l-May--g6 Ptot Reference i~ C~i~t~ are in f~t ~f~e ~ot 'Trna VeH~ol ~Pt~ 7-1/16" 5000 PSI BOP STACK ACCUMULATOR CAPACITY TEST I ANNULAR PREVENTER 7 6 PIPE RAM ~ ] BUND RAM 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP ~TACK TEST MUD CROSS 4 3 PIPE RAM ~ I J 1 1. FILL BOP STACK AND MANIFOLD WITH WATER 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 5 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE LINE VALVES. CLOSETOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND OUTSIDE MANUAL VALVE ON KILL LINE. 6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3500 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BO3-FOM RAMS TO 250 PSI AND 3500 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BLIND RAMS AND TESTTO 3500 PSI FOR 5 MINUTES. BLEED TO ZERO PSI. 11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILIJNG POSITION. 12. TEST STANDPIPE VALVES TO 3500 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP. 14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1.11" - 3000 PSI CASING HEAD 2. 11" - 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16" - 5000PSI SINGLE GATE W/PIPE RAMS 4.7-1/16" - 5000 PSI DRLG SPOOL W/CHOKE & KILL LINES 5.7-1/16" - 5000 PSi SINGLE GATE W/ BUND RAMS 6.7-1/16" - 5000 PSI SINGLE GATE W/PIPE RAMS 7.7-1/16" - 5000 PSI ANNULAR PREVENTER NORDIC RIG g2 LEVEL 1 12'-¢" i EMSCO F-800 i (~ TRIPLEX MUD i PUMP SPIRAL STAIRS CONTROL ]CONSOLE 53'-0' 25'-0' RE:MOVABLE BOP ENCLOSURE 48-57 REC£1VED MAY 09 1996 Alaska Oil & (;as Cons. Commissioo Anchorage ]~ORDIC RIG g2 LEVEL 2 H~T RECEIVED MAY 09 1996 Alaska Oil & Gas Cons. Commission Anchorage NORDIC RIG LEVEL IDRILLINo I I UNE I ISPOOL .... ~ I USTER AIR HEATER MUD TANK 750 BFILS SPIRAL STAIRS MANIFOLD OFRCE WATER TANK /~L¥COL TANK HYDRAUUC 84'--0' RECEIVED Naska Oit & G~s ConS. commission Anchorage 15'-6" , RACK , -- 7'-11' -- ':?/ '~. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATiC~ COMMISSION APPLICATION FOR SUNDRY APPROVALS Alter casing _ Change approved program _ Abandon ~ Suspend_ Operation Shutdown _ Re-enter suspended well _ Repair well Plugging X Time extension Stimulate Pull tubing_ Variance_ PeHorate _ Other X 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. ltl(;:, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1397' FNL, 347' FEL, Sec. 19, T11N, R10E, UM At top of productive interval 1469' FNL, 1173' FEL, Sec 19, TllN, R10E, UM At effective depth 1475' FNL, 1304' FEL, Sec. 19, T11N, R10E, UM At .total depth 1476' FNL, 1325' FELr Sec. 19, T11N, R10E, UM 12. Present well condition summary Total Depth: measured 671 2' (approx) true vertical 65 4 3' feet Plugs (measured) feet Effective depth: measured (approx) true vertical 6615' 6449' feet Junk (measured) feet None 13. Casing Length Size Structural 8 0' 1 6 ' Conductor Surface 2205' 1 0-3/4' Intermediate Production 6650' 7 ' Liner Perforation depth: measured 6076'-6110', 6195'-6203', true vertical 5925'-5962', 6041'-6048', Cemented 150 Sx AS II 1000 sx CSIII & 250 sx Permafrst C 685 sx Class G 250 sx Permafrst C 6216'-6249' 6061 '-6093' Tubing (size, grade, and measured depth) 3-1/2', J-55, @ 6159' MD Packers and SSSV (type and measured depth) Otis 'WD' @ 6144'~ Otis 'RH' @ 5930'~ Otis 'FMX' SSSV @ 1931' Attachments Description summary of proposal X RKB 115'. Pad Elev. 79.4' 7. Unit or Property name Kuparuk River Unit Conditions of approval: lotify Commi,~=rn'-'~esen~ Plug integrity .,~_~Test .~ L~ion cie Mechanical Integ~~.~~~~ on~ Approved by the order of the Commission ~ ~ 8. Well number 1 F-03 9. Permit number 02-179 Plugback for Reclrill feet 10. APl number 50-0;~9-20853 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool. Measured depth True vertical depth 116' 116' 2241' 2241' 6691' 6524' RECEIVED MAY 0 8 1996 Alaska 0il & Gas Cons. Commission Ant, hnrnnq Detailed operation program m' ....... BOP sketch_ 14" Estimated date for commencing operation June 1. 199{} 16. If proposal was verbally approved Name of approver~ Date approved Service 17. I hereby certify t_.hat ~e foregoing is true and correct to the best of my knowledge. Signed Title Drill Site Development Supervisor ' ' (,-,) / ~ FOR COMMISSION USE ONLY 10-403 Rev 06/15/88 15. Status of well classification as: Oil X Gas __ Suspended Form 9o? CommJssioner Date IApproval~Ho. Date ~'"'"~ ,//? r S UBM IT/l~l T F~I F;LTCAT E ? .... STATE OF ALASKA ALAS.., OIL AND GAS CONSERVATION COMMIS;. APPLICATION FOR SUNDRY APPROVALS I. Type of Request: Abandon X Suspend_ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well Plugging ~ Time extension Stimulate Change approved program _ Pull tubing _ Variance _ Perforate _ Other X 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, In¢, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Weii: Development X Exploratory _ Stratigraphic _ Service 1397' FNL, 347' FEL, Sec. 19, Tl lN, R10E, UM At top of productive interval 1469' FNL, 1173' FEL, Sec 19, TllN, R10E, UM At effective depth 1475' FNL, 1304' FEL, Sec. 19, T11N, R10E, UM At total depth 1476' FNL, 1325' FEL, Sec. 19, TllN, RIOE, UM DUPLICATE 12. Present well condition summary Total Depth: measured (approx) true verticai 6712' 6543' RKB 115', Pad Elev. 79,4' 7. Unit or Property name Kuparuk River Unit 8. Well number 1F-03 9. Permit number {~2-179 10. APl number 50-0:~9-R0853 Plugback for Reddll feet Plugs (measured) feet 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Effective depth: measured (approx) true vertical 6615' 6449' feet Junk (measured) feet None Casing Length Size Structural 8 0' 1 6 ' Conductor Surface 2205' 1 0-3/4" Intermediate Production 6650' 7 ' Liner Perforation depth: measured 6076'-6110', 6195'-6203', true vertical 5925'-5962', 6041 '-6048', Cemented 150 Sx AS II 1000 sx CSIII & 250 sx Permafrst C 685 sx Class G 250 sx Permafrst C 6216'-6249' 6061'-6093' Measured depth True vedicaidepth 116' 116' Tubing (size, grade, and measured depth) 3-1/2', J-55, @ 6159' MD Packers and SSSV (type and measured depth) Otis 'WD' @ 6144', Otis 'RH' @ 5930', Otis 'FMX' SSSV @ 1931' 2241' 2241' 6691' 6524' RECE1VF_D MAY 0 8 1996 Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments Descnption summary of proposal ~ Detailed operation program m BOP sketch _ 14. Estimated date for commencing operation June 1. 1@~ Oil X 16. if proposal was verbally approved Name of approver 17. I hereby ce~tify/,/~a, ~'le foregoing is Sic~ned . 15. Status of well classification as: Gas __ Suspended Date approved true and correct to the best of my knowledge. Service Title Drill Site Development Supervisor FOR COMMISSION USE ONLY Date Conditions of approval: ~1%tih/ Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test m Subsequent form require Approved by the order of the Commission 10- Commissioner IIAppr°val N~ ~ _/C 3 Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE · WELL PERMIT CHECKLIST COMPANY FIELD&POOL f-/?~O_)~o INITCLASS ~z_./ WELL NAME,/~'~(..,,('. / ~ GEOL AREA PROGRAM: exp [] dev/~ redrll/~ sen/I-'1 wellbore seg [] ann. disposal para req UNIT# , //?¢~rb ON/OFFSHORE ADMINISTRATION 1 1 Permit fee attached ....................... Lease number appropriate ................... Unique well name and number ................ Well located in a defined pool ................. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ......... Sufficient acreage available in drilling unit .......... If deviated, is wellbore plat included ............. Operator only affected party .................. Operator has appropriate bond in force ............ Permit can be issued without conservation order ...... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ........ ENGINEERING REMARKS 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................... Y N Surface casing protects all known USDWs .......... Y N~ i -~''~ CMT vol adequate to circulate on conductor & surf csg .... Y N CMT vol adequate to fie-in long string to surf csg ...... ..~N CMT will cover all known productive hodzons ......... ~N Casing designs adequate for C, T, B & permafrost ...... Adequate tankage or reserve pit ................ ~ N If a re-drill, has a 10-403 for abndnmnt been approved... Adequate wellbore separation proposed ............ ~ N If diverter required, is it adequate ................ 'Y--N- Ddlling fluid program schemafic & equip list adequate .... .(~ N BOPEs adequate ........................ ~_~N BOPE press rating adequate; test to ~'~ ~ psig. Choke manifold complies w/APl RP-53 (May 84) ....... Work will occur without operation shutdown .......... ('~ N Is presence of H2S gas probable ............... Y~N GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures ..... Y I~ /// 31. Data presented on potential overpressure zones ....... Y/N //(/¢ ,/'7~ 32. Seismic analysis of shallow gas zones ............. Z .N "- 33. Seabed condition survey (if off-shore) ........... ./4 Y N 34. Contact name/phone for weekl~ progress, report;s, ,..../.. Y N Lexpmrarory onlyj / GEOL(~Y: ENGINEERING: COMMISSION: JDH _ TAB ~' ;"rT.' / Comments/Instructions: o 0 '1-4 HOW/lib - A:~ORMS~'~klist rev 4J96 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. 000000'S£0~ 000000'0689 66 S66 06 P IO 0I£ 06 P ~ S~X~ ~IOI (0 #~6X~) CIHODEH W~G . P HHd~ I 89 (IMI4 60H pox sIO clXz clK& q~Su~q ~zTs s~Iu~ ssIdm~s ~poo IOOi ~m~M :ssA~nD E tfXStffIlf : .wdO~IS HJ,HOM : H~LAIH XflHlfdflM : lf£0 -MI : 'DNI 'lfHStf-i~ ODH~f : Z~IS NflOD NM ND S'6889 ES~ ~gH~N 0'IIIS dOi M~MMN OM Nile £I~ H£dHG G~iZIHSNII iN~qtfAI~O~ 0'£E89 H£dHG dOZS :SZMIHS MOM MAhlflD O'StO~ H~ ~b'~$ ~fiOD ~00~ 000S' :£M~N~DMI -psBxsm sunx ~7q II~ !SSAXnO p~ddlIo pu~ ps~lqs H~f~H ~I~ -- -.__/ **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4448 datums Tape Subfile: 2 126 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NIIMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SIIMMARY VENDOR TOOL CODE START DEPTH GR 5075.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE .(MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 6823.0 26-JUN- 96 MSC 1.34 NGP 5.74 MEMORY 6890.0 5111.0 6890.0 0 21.1 53.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 110 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 6.125 5231.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 11.20 60.0 10.0 700 4.1 .000 .000 .000 .000 .0 145.9 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 1. CN WN FN COUN STAT : ARCO ALASKA, INC. : 1F-03A : KUPARUK RIVER : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units GR MWD 68 1 AAPI 4 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 44 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 995 99 1 Tape File Start Depth = 6890.000000 Tape File End Depth = 5075.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4448 datums Tape Subfile: 3 107 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS 9?/ 1/20 01 **** REEL TRAILER **** 97/ 1/20 01 Tape Subfile: 4 2 records... MinimUm record length: 132 bytes Maximum record length: 132 bytes End of execution: Mort 20 JAN 97 4:13p Elapsed execution time = 1.86 seconds. SYSTEM RETURN CODE = 0
