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Home My WebLink About213-136Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/04/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231004 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# IRU 41-01 50283200880000 192109 9/17/2023 HALLIBURTON Coilflag KBU 32-06 50133206580000 216137 9/8/2023 HALLIBURTON PPROF LRU C-02 50283201900000 223057 9/13/2023 HALLIBURTON RBT MPU E-37 50029236160000 218158 9/24/2023 READ Caliper Survey MPU F-53A 50029225780100 213136 9/27/2023 READ Caliper Survey MPU F-79 50029228130000 197180 9/26/2023 READ Caliper Survey MPU L-57 50029236090000 218072 9/26/2023 READ Caliper Survey MPU S-06 50029231630000 203109 9/29/2023 READ Caliper Survey MPU B-32 50029235700000 216151 9/12/2023 HALLIBURTON Perf TBU K-09 50733201100000 1068038 10/1/2023 READ Caliper Survey Please include current contact information if different from above. T38028 T38029 T38030 T38031 T38032 T38033 T38034 T38035 T38036 T38037 10/4/2023 MPU F-53A 50029225780100 213136 9/27/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.04 13:03:04 -08'00' 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: ESP Swap 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,988'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi A Liner 11,170psi AL1 Liner 11,170psi AL2 Liner 10,540psi AL2 Liner AL2 Liner 11,170psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager 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 10,570psi 225' 3-1/2" 11,951' 7,024' 10,160psi 243' 3-1/4" 12,194' 7,143' MILNE PT UNIT F-53A MILNE POINT KUPARUK RIVER OIL N/A 7,282' 11,988' 7,282' 1,830 N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 10,570psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/27/2023 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 / ADL0355018 213-136 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22578-01-00 Hilcorp Alaska LLC C.O. 432E Proposed Pools: MD TVD 6.5# / L-80 / EUE 8rd 10,293' 10,570psi Burst 7,240psi N/A 5,750psi 110' 4,409' 7,055' 110' 6,750' 7,280'14,425' 11,988' 7,239' 2-7/8" Length Size 20" 9-5/8" 78' 7"11,955' 6,715' 12.6# / L-80 / Work String 11,607' 7" x 4.5" TNT & KB LTP and N/A See Schematic 1,848' 2-7/8" See Schematic 14,333'1,949' 2-7/8" 11,674 MD / 6,774 TVD & 11,726 MD/ 6,839 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 810' 2-7/8" 14,369' 7,254' 4-1/2" Perforation Depth MD (ft): 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 1:02 pm, Sep 28, 2023 323-533 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.09.28 10:57:13 - 08'00' Taylor Wellman (2143) DSR-9/28/23MGR03OCT23 SFD 10-404 *BOPE test to 2500 psi. 14428' SFD 10/5/2023*&:JLC 10/6/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.06 10:25:56 -08'00'10/6/23 RBDMS JSB 101023 Well: MPF-53A PTD: 213-136 API: 50-029-22578-01-00 Well Name:MPF-53A API Number:50-029-22578-01-00 Current Status:Shut-in Producer Rig:ASR #1 Estimated Start Date:10/27/2023 Estimated Duration:7 days Regulatory Contact:Tom Fouts Permit to Drill Number:213-136 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 2419 psi @ 5,893’ TVD 5/29/2023 |7.9 PPGE Max Potential Surface Pressure: 1,830 psi Gas Column Gradient (0.1 psi/ft) Max Angle:67° @ 4,602’ MD Brief Well Summary: MPU F-53A was drilled in August 1995, fracture stimulated in September, and completed in February 1996 as a Kuparuk River producer. ESP installation history: Feb 1996 (initial), Aug 2000, Dec 2000, and June 2005. The well was prepared for CTD ST in Nov 2013. CTD sidetracked the well in Jan 2014 as a tri-lateral well as MP F- 53A. The ESP installation for MP F-53A was installed Feb 2014, Dec 2016. The ESP has failed. Objectives: Pull failed ESP completion, run new ESP completion. Notes Regarding Wellbore Condition: - 7” casing test to 11/05/2013. ESP CT required. Pre-Rig Procedure (Non Sundried Work) Slickline 1. RU slickline, pressure test PCE to 250psi low / 2,500psi high. 2. Drift and tag with sample bailer. 3. Attempt to pull dummy valve from GLM at 10,032’ MD and leave open. 4. Pull GLV and set dummy valve in upper GLM at 127’ MD. 5. RDMO. Coiled Tubing (Contingency) 1. Pressure test PCE to 250 psi low / 2,500 psi high. 2. PU 1.75” jet nozzle. 3. Jet down to discharge head at 10,218’ MD. 4. Following best practices in PE manual, pump gel sweeps to clean up tubing. 5. Chase gel out of hole. 6. PU tubing punch. 7. RIH and tag discharge head. 8. Pump down ball to fire tubing punch. 9. Confirm circulation by pumping down backside of coil. 10. Freeze protect tubing as POOH. 11. RDMO. Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. Well: MPF-53A PTD: 213-136 API: 50-029-22578-01-00 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure (Begin Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 3. Test BOPE to 250 psi low/ 2,500 psi high. Test 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. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” and 3-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out Centrilift for ESP pull. 6. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an FMC 11” x 2-7/8” EUE threads top and bottom. b. 2016 ASR #1 tubing PU weight was recorded as 68 kip. Slack off weight recorded as 29 kip. c. 2-7/8” L-80 EUE yield is 144 kip. 7. Confirm hanger free, lay down tubing hanger. 8. POOH and lay down the 2-7/8” tubing. a. Do not keep tubing. b. Keep ported discharge head and centralizer for future use. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Recorded Clamp Totals: i. Canon Clamps: 171 ii. Protectolizers: 6 e. Lay Down ESP. 9. Pressure test pulled 3/8” capillary tubing to 3500 psi. If PT passes, plan to save for future work. Well: MPF-53A PTD: 213-136 API: 50-029-22578-01-00 10. PU 3-1/2” workstring, 7” casing scraper, and muleshoe. RIH to 10,300’ MD. 11. Circulate well clean. 12. Scrape casing interval from 10,300’ to 10,400’ MD. 13. POOH while filling hole with 2x displacement. 14. PU and RIH with 7” test packer to 10,350’ MD. 15. Test 7” casing to 1,500 psi for 30 minutes. 16. POOH with test packer. 17. RIH with new 2-7/8” 6.5# L-80 ESP completion to +/- 10,293’ and obtain string weights. a. Check electrical continuity every 1000’. b. Note PU and SO weights on tally. c. Install ESP clamps per Baker, and cross coupling clamps every other joint d. Run single 3/8” cap string the length of the completion, clamping with cable. Nom. Size Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 4.5 2 Intake Sensor 30 5.62 34 Motor - 250HP 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 8 Gas Separator 52 5.38 57 Pumps – Flex-47 45 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 XN-nipple 2.313" / 2.505" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 9,905 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, 1/4" OV 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 18. Land tubing hanger. Use extra caution to not damage cable. Well: MPF-53A PTD: 213-136 API: 50-029-22578-01-00 19. Lay down landing joint. 20. Set BPV. 21. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOPE Schematic DATE REV. BY COMMENTS Orig. KB Elev.= 49.2' (N 27E) Orig. GL elev. = 13.6' RT To Tbg. Spool = 32.62' (N 27E) Tree: Cameron 2 9/16" 5M, Wellhead: 11" x11" 5M FMC Gen 5 w/ 11" x 2 7/8" tbg. hng. andw/ 2 7/8" 8 rd EUE threads top and bottom and 2.5" CIW 'H' bpv profile MILNE POINT UNIT WELL F-53 API NO: 50-029-22578 9 5/8", 40#/ft, L-80 Btrc. BP EXPLORATION (AK) 7" Float collar (PBTD) KOP @ 500' Max. hole angle = 66 deg. from 3700 to TD. Hole angle across perfs = 33 deg. 7" Float shoe 20" 91.1 ppf, H-40 MPU F-53 113' 12,309' 12,398' 6750' 09/11/95 JBF D &C by Nabors 27E 7" Short Joint 11819‘ 11838’ Note: Tree saver rubber (6" x 1" x 1" ) left in the hole 9/25/95 Top of 25 bands & 4 Flat Guards 12265' 7" 26 ppf, L-80, NSCC Casing (drift ID = 6.151", cap. = 0.0383 bpf) (cap w/ 2 7/8“ tubing inside = .02758 bpf) Camco 2 7/8" x 1" sidepocket KBMM GLM Phoenix Multi Sensor Sensor TVD = 6928‘ Centrilift Pumps SXD - 85 P37 Centrilift Tandem Seal Section GSB3DB UT/LT SB/SB PFSA Centrilift Motor Model MSP1-250 HP 336 / 2650 Volts / 77 Amps 02/19/96 DLH Initial Completion by Nabors 4 ES 27/8"6.5ppf,L-80,8rdEUEtbg. ( drift ID = 2.347", cap. = 0.00592 bpf ) 8/8/00 GMH RWO Nabors 4ES XN Centrilift Tandem Rotary Gas Separator, Model - GRSFTXAR H6 6 Fin Centralizer HES “XN” nipple (2.250”ID) Camco 2 7/8" x 1" sidepocket KBMM GLM 138’ 11257’ 11394’ 11437’ 11472’ 11477’ 11490’ 11515’ 11517’ 12/20/00 M. Linder RWO Nabors 4ES 6/14/05 L. Hulme ESP Upsize & Add Perf Nabors 4ES X 4.5" Tubing Stub - 11,607'7" X 4.5" TNT PKR - 11,674' 4.5" X Nipple, ID = 3.813" - 11,705' KB Liner Top Packer - 11,726' 4.5" RCH LCH ASSY - 11,661' 02/19/2014 B. Bixby Nordic 2 sidetrack multi lateral / Doyon 16 Install ESP Multi Lateral: 1) With deployment sleeve, aluminum liner billet and slotted liners. Total completion length - 2643' Total measured depth is 14,371.5' 2) With deployment sleeve, aluminum liner billet and slotted liners. Total completion length - 1949' Total measured depth is 14,335.5' 3) With aluminum liner billet and slotted liners. Total completion length - 930' Total measured depth is 14,427.5' Cement Plug 4.5 “ X 7 “ Monobore Whipstock 127' 10,032' 10,175' 10,218' 10,246' 10,250' 10,263' 10,289' 10,290' BTM @ 10,293' HILCORP ALASKA LLC w/ DSOV w/ Dummy (2.313" ID) Centrilift Pumps 52FLEX47 & 66FLEX47 Centrilift Intake - GSHVVX H6 FER GSB3DBUT SB/SB PFSA Centrilift Motor CL5: MSP3-325 240 HP/ 2,455V / 59A Sensor: Phoenix XT150 ESP Swap by ASR#1 - 12/14/2016 _____________________________________________________________________________________ Revised By: TDF 9/27/2023 PROPOSED Milne Point Unit Well: MPU MP F-53A Last Completed: 12/15/2016 PTD: 213-136 15 F-53A 2-3/8” Alum. Billit w/ GS FN F-53A1 F-53A2 TD=11,988’ (MD) / TD = 7,055’(TVD) 20” Top of Whipstock @ 11,982’ Orig. KB Elev.: 49.2’/ GL Elev.: 13.6 (N27E) RT to Tbg. Spool = 32.62’ 7” 3 5& 6 7 8 & 9 10 11 1 11 12 13 9-5/8” 1 2 14 PBTD =11,988’(MD) / PBTD =7,055’(TVD) 4 7” Short Joint 11,819’ to 11,838’ 15 16 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 48 / H-40 / Weld 19.124 Surface 110’ 9-5/8" Surface 36 / J-55 / Btc. 8.835 Surface 6,750’’ 7" Production 26 / L-80 / Btc 6.276 Surface 11,988’ 2-7/8” A Liner 6.5 / L-80 / HYD 511 2.441 12,577’ 14,425’ 2-7/8” AL1 Liner 6.5 / L-80 / HYD 511 2.441 12,384’ 14,333’ 3-1/2” AL2 Liner 9.2 / L-80 / STL 2.992 11,726’ 11,951’ 3-1/4” AL2 Liner 6.6 / L-80 / TCII 2.800 11,951’ 12,194’ 2-7/8” AL2 Liner 6.5 / L-80 / HYD 511 2.441 12,194’ 13,004’ TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / WS 3.958 11,607’ 11,800 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±10,293’ JEWELRY DETAIL No Depth Item 1 ±127’ GLM #2 Camco 2-7/8” x 1” Side Pocket, w/ DSOV 2 ±10,032’ GLM #1 Camco 2-7/8” x 1” Side Pocket, w/ Dummy 3 ±10,175’ 2-7/8” XN-Nipple (2.205 No-go ID) 4 ±10,217’ Discharge Head: 5 ±10,218’ Pump: Model SXD 6 ±10,231’ Pump: Model SXD 7 ±10,246’ Gas Separator: 8 ±10,250’ Upper Tandem Seal 9 ±10,257’ Lower Tandem Seal 10 ±10,263’ Motor: CL5 (MSP3-235) 11 ±10,289’ Phoenix XT150 & Centralizer – Bottom = ±10,293’ 12 11,661’ RCH Latch Assy. 13 11,647’ 7” x 4.5” TNT Packer 14 11,705’ 4.5” ‘X’ Nipple (3.813” ID) 15 11,726’ KB Liner Top Packer 16 11,726’ 2-3/8” Deployment Sleeve OPEN HOLE / CEMENT DETAIL 20" 250 sx Arcticset I (approx.) in 30” Hole 9-5/8" 1,292 sx PF ‘E’, 250 sx Class ‘G’, 124 sx PF ‘E’ in 12-1/4” Hole 7” 234 sx Class “G” in 8-1/2” Hole TREE & WELLHEAD Tree Cameron 2-9/16” 5M Wellhead 11” x 11” 5M FMC Gen 5 w/ 11” x 2-78” tbg. Hng. and w/ 2-7/8” 8rd EUE threads top and bottom and 2.5” CIW ‘H’ bpv profile. GENERAL WELL INFO API: 50-029-22578-01-00 Drilled and Cased by Nabors 27E- 8/15/1995 Completed by Nabors 4ES – 2/16/1996 RWO by Nabors 4ES – 8/7/2000 ESP RWO by Nabors 4ES – 6/14/2005 CTD Sidetrack by Nordic 2 – 1/17/2014 ESP Swap by ASR #1 – 12/14/2016 WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 6 deg. f/ 3,700’ to TD’ (Original Wellbore) Hole Angle through perforations = 33 deg. WINDOW DETAIL Top of Window @ 11,988’ / Bottom of Window @ 11,993’ SLOTTED LINER DETAIL MD / TVD A Liner 12,587’ to 13,505’ & 13,510’ to 14,423’ / 7,161’ to 7,180’ & 7,180’ to 7,279’ AL1 Liner 12,395' to 12,778’ & 12,797’ to 14,331’ / 7,151’ to 7,180’ & 7,182’ to 7,238’ AL2 Liner 12,320’ to 13,002’ & 13,006 to 14,367’ / 7,148’ to 7,189’ & 7,189’ to 7,253' 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 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMI ION REPORT OF SUNDRY WELL OPERATIONS DEC 2 8 2016 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ ChanA p am ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ Other: ESP Change-out ❑ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory 0 213-136 3.Address: Stratigraphic III Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22578-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025509/ADL0355018 MILNE PT UNIT KR F-53A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured 14,428 feet Plugs measured N/A feet true vertical 7,282 feet Junk measured N/A feet Effective Depth measured 14,428 feet Packer measured 11,647 feet true vertical 7,282 feet true vertical 6,774 feet Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 110' 110' N/A N/A Surface 6,715' 9-5/8" 6,750' 4,409' 5,750psi 3,090psi Production 11,955' 7" 11,988' 7,055' 7,240psi 5,410psi Liner 2,702' 3.5"/3.25"/2-7/8" 14,428' 7,282' N/A N/A Perforation depth Measured depth 12,577'-14,428' O ng True Vertical depth 7,160'-7,282' SC NK° MAR i Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5/L-80/EUE 8rd 10,293' 5,927' Packers and SSSV(type,measured and true vertical depth) 7"x 4.5"TNT Packer N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 280 0 Subsequent to operation: 251 125 2,248 380 224 14.Attachments(required per'20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas LI WDSPL LI Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-614 Contact Paul Chan Email pchanhilcorp.com Printed Name Bo York Title Operations Manager Signature Phone 777-8345 Date 12/27/2016 /z-a_q-/4. 0 /elf Form 10-404 Revised 5/2015 ORIGINAL Submit Original Only RBDMS \/DEC 2 9 2016 Tree: Cameron 2 9/16" 5M, ® • Wellhead: 11"x11"5M FMC Gen 5 MPU F-53 w/ 11"x 2 7/8"tbg. hng. andw/2 1 Orig. KB Elev.= 49.2' (N 27E) 7/8"8 rd EUE threads top and Orig.GL elev.= 13.6' RT To Tbg.Spool=32.62'(N 27E) bottom and 2.5" CIW'H' bpv profile 20"91.1 ppf, H-40 113' Camco 2 7/8"x 1" 127' KOP @ 500' sidepocket w/DSOV Max. hole angle = 66 deg.from 3700 to TD. Hole angle across perfs= 33 deg. 9 5/8", 40#/ft, L-80 Btrc. 6750' , Camco 2 7/8"x 1" sidepocket w/Dummy 10,032' 2 7/8"6.5pp f, L-80, 8 rd EUE tbg. HES"XN" nipple(2.313" ID) 10,175' 9 (drift ID = 2.347", cap. = 0.00592 bpf) 11, Centrilift Pumps 52FLEX47& 10,218' 7"26 ppf, L-80, NSCC Casing %• 66FLEX47 (drift ID =6.151", cap. = 0.0383 bpf) (cap w/2 7/8" tubing inside= .02758 bpf) 0 Centrilift Intake-GSHVVX H6 FER 10,246' %-' 0. Centrilift Tandem Seal Section 10,250' GSB3DBUT SB/SB PFSA ICentrilift Motor CL5:MSP3-325 10,263' 240 HP/2,455V/59A Sensor:Phoenix XT150 10,289' ill 1 6 Fin Centralizer 10,290' BTM @ 7"X 4.5"TNT PKR-11,674' `L I 4.5"Tubing Stub-11,607' 10,293' 4.5"X Nipple, ID=3.813"-11,705'\ 4.5"RCH LCH ASSY-11,661' KB Liner Top Packer-11,726' — /7" Short Joint 11819' 11838' I 4.5"X 7"Monobore Whipstock Multi Lateral "'-.....,„ 1)With deployment sleeve,aluminum liner billet �, and slotted liners.Total completion length-2643' Cement Plug Total measured depth is 14,371.5' :^ '4 2)With deployment sleeve,aluminum liner billet Note:Tree saver rubber(6"x 1"x 1") td , z +-- and slotted liners.Total completion length-1949' left in the hole 9/25/95 � Total measured depth is 14,335.5' � .tib Y 3)With aluminum liner billet and slotted liners. Top of 25 bands&4 Flat Guards Total completion length-930' 12265' Total measured depth is 14,427.5' �"/WI" 7" Float collar(PBTD) 12,309' 7" Float shoe 12,398' DATE REV.BY COMMENTS MILNE POINT UNIT 09/11/95 JBF D&C by Nabo27E 02/19/96 DLH Initial Completionrs by Nabors 4 ES WELL F-53 8/8/00 GMH RWO Nabors 4ES API NO: 50-029-22578 12/20/00 M.Linder RWO Nabors 4ES 6/14/05 L.Hulme ESP Upsize&Add Perf Nabors 4ES H I LCORP ALASKA LLC 02/19/2014 B.Bixby Nordic 2 sidetrack multi lateral/Doyon 16 Install ESP (ESP Swap byASR#1 -12/14/2016 i • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-53A ASR#1 50-029-22578-00-00 213-136 12/11/2016 12/16/2016 Daily Operations: 12/7/2016-Wednesday No activity to report. 12/8/2016-Thursday No activity to report. 12/9/2016- Friday No activity to report. 12/10/2016-Saturday No activity to report. 12/11/2016-Sunday Nipple down BOP to 4 bolts, disconnect choke & kill lines, disconnect all service lines, disconnect gas alarms. Move Catwalk, pipe racks, Un pin & lay derrick over, move rig off of mud boat, move Company rep trailer&change house, Well site trailer and set on MPF-29. Rig up crane and remove Rig floor and walk over to MPF-29, Pull tree on F-53A, remove BOP from F-29. NU BOP on F-53A and torque, set well house and rig floor with crane, set mud boat, spot mud pit trailer,take on 250bbls of 100deg seawater in pits. (SIMOPS: NU Tree on F-29). Back carrier onto mud boat, spot c-can storage trailers into place, rig up heaters on hydraulic system in prep for raising the mast. Spot Certek heating trailers into place and begin settng heating lines. Raise mast into place, tie off support lines to outriggers. Continue to rig up glycol heating lines from Certek heating unit. L/D Herculite containment for catwalk and pipe racks. Spot catwalk into place.;Aluminum shim found wedged in the radiator. Radiator damaged and leaking fluid into mudboat containment. Carrier shut down. Contact VMS to trouble shoot. Radiator replacement needed. Crews continue to prep rig by placing skirting around catwalk and carrier, prepping well cellar with herculite containment. 12/12/2016- Monday Build Cover over Rig engine for VMS shop mechanic, assist VMS mechanic removal of Radiator, Maintain rig, clean Rig service rig, grease all fittings under Rig carrier. Wait on fan blade to arrive on flight, Continue to clean and maintain Rig equipment. Expediter on location @ 19:00 w/ radiator fan,VMS on location @ 19:30 w/ used radiator.VMS and ASR hands install radiator fan and used radiator. Fill radiator w/glycol, cycle engine allowing glycol to circulate, top off radiator fluid level. Carrier engine showing error codes.VMS reset engine computer. Rig crew break down cover that was constructed for mechanics to perform radiator repair. Warm up hydraulic system in prep to finish rigging up over F-53A. Level carrier on mud boat w/ hydraulics, finish pinning carriage track into place in the derrick, place power tongs into working position from transport position. Open BOP annular and ram cavities. P/U t-bar, pull BPV, and replace w/TWC. Wellhead hand Dean Norris on location. Set riser spool into place and secure. R/U secondary rig stairs and secure in place. R/U hydraulic lines from rig floor power tongs back to hydraulic system on carrier. Circulate warm water through BOP stack to reduce any potential thermal changes when testing BOPE and eliminate any trapped air from within the BOP ram cavities.VMS mechanic on location to investigate fluctuating rpm's on carrier engine. Loose sensor on engine crank case.Tighten sensor and codes were cleared. S S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-53A ASR#1 50-029-22578-00-00 213-136 12/11/2016 12/16/2016 Daily Operations: 12/13/2016-Tuesday Rig up for BOP Test.Test BOP per Well Program,tested with 2-718" Test joint& 3-1/2°Test joint, Tested to 250/2,500psi, � Tested Annular on 2-7/8"Test joint, Performed Koomey Test, gas alarms were all tested and good. (Witness was waived by "(e5 AOGCCJeffJones @ 12:30 PM on 12-10-16) Pull TWC, make up Landing joint to tubing hanger, Back out LDS, Monitor Annulus, Pull tubing hanger @ 72K, Lay down landing joint and hanger. TOOH with 2-7/8" EUE L-80 6.5#Tubing T/9,400' (NPT) Spooling unit generator down Continue to TOOH with 2-7/8" EUE L-80 6.5#Tubing F/9,400' to ESP completion @ —82'md. Spooling unit generator's alternator having issues. VMS on location to assess, utilize battery charger and air heater to keep generator running. (30mins NPT) L/D ESP completion f/"82'md to surface. Recovered 179 cross collar clamps, 6 protectrolizers, and 3 flat guard clamps. SIMOPS: secondary Baker Centrilift hand on location to wrap used ESP spools for transport. Roads and Pads on location to pull ESP spooler out and swap both ESP cable reels. Load new ESP onto catwalk in prep for completion run. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-53A ASR#1 50-029-22578-00-00 213-136 12/11/2016 12/16/2016 Daily Operations: 12/14/2016-Wednesday Service rig, Check fluid in all equipment. Make up & service new ESP assembly TIH with ESP completion on 2-7/8" EUE 6.5# L-80 tubing to ESP cable splice depth of 8,300'md.Test ESP cable each 2,000', circulate every 5,000'md. Check ESP connectivity (Good), perform ESP cable splice, verify ESP cable and splice connectivity. R/U & circulate through ESP. 12/15/2016-Thursday Service Rig, Check fluid in all equipment. Continue to TIH with ESP completion assembly on 2-7/8" EUE 6.5# L-80 tubing F/8,300'T/10,273' Make up landing joint &tubing hanger, Install field connector to ESP cable, install and connect to penetrators. Land tubing hanger, run in lock down screws. back out& lay down landing joint. Install BPV (Release Rig from MPF-53A @ 12:30 Hrs.) PU wt. =68k SO wt. =29K, Ran a total of 323 joints. ND BOPE to 4 bolts. Disconnect Choke & Kill Lines. Disconnect Gas Alarms. Move Catwalk& Pipe Racks. RU Crane & hook to carrier(Power Swivel assembly). Spot Lynden trailer. Pull pins from Carrier. Lift same and spot on Lynden Trailer for transport. Move trailer to edge of pad. Lay down Derrick. Move rig off of Mud Boat. Disconnect Certek heaters. Move equipment to A-Pad for maintenance. 12/16/2016- Friday Continue to move rig to A-Pad for Maintenance. ND BOPE. Install tree per Wellhead Rep. Secure well. NOTE:TWC was left in tree as the BPV threads were questionable and Wellhead Rep. was unsure of tree orientation for hookup (Well Support may need to turn it). Wellhead Rep. test tree.The well was not freeze protected as the fluid level was below the permafrost. Wells Supervisor&Well Support were aware. 12/17/2016-Saturday No activity to report. 12/18/2016-Sunday No activity to report. 12/19/2016- Monday No activity to report. ................ 12/20/2016-Tuesday No activity to report. • OF 7.4 • • 4)////y * THE STATE Alaska Oil and Gas to of Conservation Commission LASKA 333 West Seventh Avenue T t GOVERNOR BILL WALKER Anchorage, Alaska 99501 3572 "' Main: 907.279.1433 OF ALAS*P' Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR F-53A Permit to Drill Number: 213-136 Sundry Number: 316-614 Dear Mr. York: 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, I Daniel T. Seamount,Jr. Commissioner DATED this / day of December, 2016. s MA i 7 RBDMS L DEC - 9 2016 0 sAt-040,0 vAk0 RECEIVED STATE OF ALASKA E 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION ` APPLICATION FOR SUNDRY APPROVALS AOGCC, 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well Q Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program Q Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development 04 213-136 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-22578-01-00• 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D• Will planned perforations require a spacing exception? Yes ❑ No 0 f MILNE PT UNIT KR F-53A • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025509/ADL0355018 ' MILNE POINT/KUPARUK RIVER OIL ' 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): • 14,428' ' 7,282' • 14,428' • 7,282' 1,260 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 110' 110' N/A N/A Surface 6,715' 9-5/8" 6,750' 4,409' 5,750psi 3,090psi Production 11,955' 7" 11,988' 7,055' 7,240psi 5,410psi Liner 2,702' 3.5"/3.25"/2-7/8" 14,428' 7,282' N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2-7/8/" 6.5#/L-80/EUE 8rd 11,519 12,577-14,428 ' 7,160-7,282 4-1/2" 12.6#/L-80/N/A 11607-11800 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"x 4.5"TNT Packer and N/A 4 11,674'MD/6774'TVD and N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑Q Exploratory ❑ Stratigraphic❑ Development 0 t Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 12/11/2016 Commencing Operations: OIL ❑✓ • WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Paul Chan Email pchanccahilcorp.com Printed Name Bo York Title Operations Manager Signature yr • one 777-8345 Date 12/9/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .-- USZ — (-IZ`-( Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: le- Z. h) /,S€. iS :,•c' `-r b . Post Initial Injection MIT Req'd? Yes ❑ No ❑ _ 9 �stt Spacing Exception Required? Yes ❑ No IA Subsequent Form Required: `d 11C-t RBDMS L t- DEC - 2016 4 /, APPROVED BY li / Approved byi COMMISSIONER THE COMMISSION Date: /2, / 6 -t7 k /41/A. Y i Z'1-4, Submit Form and Form 10-403 Revised 11/2015 0 RitailltiAtlid for 12' nth re date of approval Attachments in Duplicate • • Well Prognosis Well: MPU F-53A Hiker')Alaska,LI) Date:12/08/2016 Well Name: MPU F-53A API Number: 50-029-22578-01 Current Status: Oil Well [Failed ESP] Pad: F-Pad Estimated Start Date: December 11th, 2016 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 213-136 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Job Type: ,,r . e*.epair Current Bottom Hole Pressure: 1,960 psi @ 7,000' TVD (SBHPS 12/08/2016/5.39 ppg EMW) Maximum Expected BHP: 1,960 psi @ 7,000' TVD (No new perfs being added) MPSP: 1,260 psi v (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-53A was drilled in August 1995,fracture stimulated in September, and completed in February 1996 as a Kuparuk River producer. ESP installation history: February 1996 (initial),August 2000, December 2000, and June 2005. The well was prepared for CTD ST in November 2013. CTD sidetracked the well in January 2014 as a tri-lateral well as MP F-53A. The ESP installation for MP F-53A was installed February 2014. The ESP has failed. Notes Regarding Wellbore Condition • The 7" production casing was tested to 3000 psi down to 11,760' MD on November 5, 2013. • CO 390A: Hilcorp Alaska respectfully requests that a packer not be required on this ESP completion as the reservoir pressure is less than 8.55 ppg EMW. Ad'AA. goo r- Objective: i°�' Co .37 0'4 Replace failed ESP. fZ�-�-C� Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volu ie with 8.5 ppg sea water down tubing,taking returns up casing to 500 bbl returns tank. �'' h.� �� • 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. •111 • Well Prognosis Well: MPU F-53A Ililcarp Alaska,LL Date: 12/08/2016 Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg sea water prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/USD_ASLHigh, 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. YJ0 a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" and 3-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (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. oft') 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. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg sea water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2010 ESP swap was 100K lbs. (block weight not noted) b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 16. Recover the 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. 17. POOH and lay down the 2-7/8"tubing. Number all joints. Tubing will be re-used as noted. Lay down failed ESP. a. Replace bad joints of tubing as necessary and note on tally any new tubing run. b. Note any sand or scale inside or on the outside of the ESP on the morning report. c. Look for over-torqued connections from previous tubing runs. 18. PU new ESP and RIH on 2-7/8"tubing. Set base of ESP at± 10,302' MD. • • Well Prognosis Well: MPU F-53A kcora Alaska,LL Date: 12J08J2016 a. Upper GLM @ ± 138' MD w/SO b. Lower GLM @ ± 10,042' MD w/DGLV c. 2-7/8" XN (2.205" No-Go) @ ±10,179' MD d. Base of ESP centralizer @ ± 10,302' MD 19. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 20. Set BPV. Post-Rig Procedure: 21. RD mud boat. RD BOPE house. Move to next well location. 22. RU crane. ND BOPE. 23. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 24. RD crane. Move 500 bbl returns tank and rig mats to next well location. 25. Replace gauge(s) if removed. 26. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Blank RWO MOC Form Tree: Cameron 2 9/16" 5M, •MPU F-53 • • Wellhead: 11"x11"5M FMC Gen 5 w/ 11"x 2 7/8"tbg. hng. andw/2 <I Orig. KB Elev.= 49.2' (N 27E) / Orig. GL elev. = 13.6' 7/8"8 rd EUE threads top and / JJJJJ RT To Tbg.Spool=32.62'(N 27E) bottom and 2.5"CIW'H' bpv profile / 2° 20" 91.1 ppf, H-40 113' / ! // / �', Camco 2 7/8"x 1" 138' KOP @ 500' / ' ' f sidepocket KBMM GLM Max. hole angle = 66 deg.from 3700 to TD. Hole angle across perfs = 33 deg. 9 5/8",40#/ft, L-80 Btrc. 6750' I / // / / / / Camco 2 7/8"x 1" , sidepocket KBMM GLM 11257' / / i 2 7/8"6.5 ppf, L-80, 8 rd EUE tbg. /NN' HES"XN" nipple (2.250"ID) 11394' (drift ID = 2.347", cap. = 0.00592 bpf) I Centrilift Pumps SXD-85 P37 7"26 ppf, L-80, NSCC Casing - 11437' (drift ID = 6.151",cap. = 0.0383 bpf) hitk Centrilift Tandem Rotary (cap w/2 7/8" tubing inside= .02758 bpf) Gas Separator, 11472' atModel-GRSFTXAR H6 Centrilift Tandem Seal Section 11477' GSB3DB UT/LT SB/SB PFSA Centrilift Motor Model MSP1-250 11490' HP 336/2650 Volts/77 Amps ;..., , Phoenix Multi Sensor 11515' Sensor TVD=6928` ft I1)H' 6 Fin Centralizer 11517' 7"X 4.5"TNT PKR-11,674' 4.5"Tubing Stub-11,607' l' g 4.5"RCH LCH ASSY-11,661' 4.5"XNipple, ID=3.813"-11,705'x` KB Liner Top Packer-11,726' /7" Short Joint 11819` 11838' ' ` A 4.5"X 7"Monobore Whipstock ""'>---, Multi Lateral' ''. Iti. 1)With deployment sleeve,aluminum liner billet and slotted liners.Total completion length-2643' Cement Plug "7, "'', L *,',. Total measured depth is 14,371.5' f,-...::; ,r�'' atm. :,, p v< vix X y` vrx,1, 2)With deployment sleeve,aluminum liner billet Note:Tree saver rubber(6"x 1"x 1" ) , � 75 '.',' a,:.'""�s' and slotted liners.Total completion length-1949' �, r. Total measured depth is 14,335.5' left in the hole 9/25/95 --",?,,;:ie .yA. *k ,e.�,,,i ., {'' 3)With aluminum liner billet and slotted liners. Top of 25 bands&4 Flat Guards -l~td.Y? + i• Total completion length-930' 12265' `°**•"-- Total measured depth is 14,427.5' '� 7" Float collar(PBTD) 12,309' 7" Float shoe 12,398' DATE REV BY COMMENTS MILNE POINT UNIT 09/11/95 JBF D&C by Nabors 27E 02/19/96 DLH Initial Completion by Nabors 4 ES WELL F-53 8/8/00 GMH RWO Nabors 4ES API NO: 50-029-22578 12/20/00 M.Linder RWO Nabors 4ES 6/14/05 L.Hulme ESP Upsize&Add Perf Nabors 4ES H I LCORP ALASKA LLC 02/19/2014 B.Bixby Nordic 2 sidetrack multi lateral/Doyon 16 Install ESP Tree: Cameron 2 9/16" 5M, •MPU F-53 PROPOSED III • Wellhead: 11"x11"5M FMC Gen 5 w/ 11"x 2 7/8"tbg. hng. andw/2 ! 1 Orig. KB Elev.= 49.2' (N 27E) Orig. GL elev. = 13.6' 718"8 rd EUE threads top and RT To Tbg.Spool = 32.62' (N 27E) bottom and 2.5"CIW'H' bpv profile 20" 91.1 ppf, H-40 113' "i i Camco 2 7/8"x 1" +/- 138' KOP @ 500' , 3 sidepocket KBMM GLM Max. hole angle = 66 deg. from 3700 to TD. Hole angle across perfs = 33 deg. 9 5/8",40#/ft, L-80 Btrc. 6750' , Camco 2 7/8"x 1" sidepocket KBMM GLM +/- 10,042 2 7/8"6.5 ppf, L-80, 8 rd EUE tbg. HES "XN" nipple (2.250"ID) +/- 10,179' (drift ID = 2.347", cap. = 0.00592 bpf) 11 0 iCentrilift Pumps SXD-85 P37 .11 p +1- 10,221' 7"26 ppf, L-80, NSCC Casing (drift ID =6.151",cap. = 0.0383 bpf) %h' Centrilift Tandem Rotary (cap w/2 7/8" tubing inside= .02758 bpf) 0. Gas Separator, +/- 10,256' d Model-GRSFTXAR H6 Centrilift Tandem Seal Section +/- 10,261' �., I GSB3DB UT/LT SB/SB PFSA Centrilift Motor Model MSP1-250 +1- 10,274' HP 336/2650 Volts/77 Amps alPhoenix Multi Sensor +1- 10,298' Sensor TVD=6928' 411 IS ,,. 6 Fin Centralizer +1- 10,300' BTM @ 7"X 4.5"TNT PKR-11,674' \ 'e__________4.5"Tubing Stub-11,607' +/- 10,302' 4.5"XNipple, ID=3.813"-11,705'` 4.5"RCH LCH ASSY-11,661' • KB Liner Top Packer-11,726' /7" Short Joint 11819' 11838' o X 4.5"X 7"Monobore Whipstock "r...... Multi Lateral � ..I , 1)With deployment sleeve,aluminum liner billet and slotted liners.Total completion length-2643' Cement Plug - 't 6kt j Total measured depth is 14,371.5' .#1 r 1t i,W7 2)With deployment sleeve,aluminum liner billet Note:Tree saver rubber(6"x 1"x 1") ► x 4 and slotted liners.Total completion length-1949' ^_� Total measured depth is 14,335.5' left in the hole 9/25/95 ''''''.1:'` 3)With aluminum liner billet and slotted liners. Top of 25 bands&4 Flat Guards ~` Total completion length-930' 12265' Total measured depth is 14,427.5' ..1Whi 7" Float collar(PBTD) 12,309' 7" Float shoe 12,398' DATE REV.BY COMMENTS MILNE POINT UNIT 09/11/95 JBF D&Ca by Nabors 27E 02/19/96 DLH Initial Completion by Nabors 4 ES WELL F-53 8/8/00 GMH RWO Nabors 4ES API NO: 50-029-22578 12/20/00 M.Linder RWO Nabors 4ES 6/14/05 L.Hulme ESP Upsize&Add Perf Nabors 4ES HILCORP ALASKA LLC 02/19/2014 B.Bixby Nordic 2 sidetrack multi lateral/Doyon 16 Install ESP • • IIEXISTING TREE/WELLHEAD Wellhead/Tree Hilcorp Alaska,l.I C Milne Point Unit Tree Cap .I ; 1.1 -1:21410.1 I1 41' 0 Tree Valve 2-9/16"5M ��°�® Tree Cross 2-9/16"5M I[o0lro)0o]I Tree Valve 2-9/16"5M �- o SSV 2-9/16" 5M P iswilim p 0 Heat Trace Tree Valve 2-9/16"5M 4+/o ado ESP Cable ►P . Tubing Adapter ': i g I ,, Tubing Head ,tj— O 11"5M Top x 11"5M Bt - -.1,1 ' ' 11-0.11Crif,714111111"1 1111 IlaleZ,Z) 1VittIVOI Ill t 111 itt Casing Head iiIgo ��` I o 11"5M Top x 11" 5M Btm i�I� Elm " •ito � j�...7 �: i„�' ~ • 0 . fit Milne Point ASR Rig 1 BOPE Ililenrp 464411,l.u: 11" BOPE \ Stripping Head 1 1 3.98' Shaffer ° 11"- 5000 Li! iii Ili Wilt If CEJ IJ LIT I := 4.54' CI / -U H VBR or Pipe Rams 11u-5000 H Blind :Irl l I P yon lit Iii It III ','41 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves 2.00' - • . `� 1 Ilk II-,' . r(( lr $A Mrfrilinfiniarj Manual Manual Manual HCR Updated 8/19/2015 • • •a _ a) $3 m .>_ (e a) 0 ° ai vac E0 aaa E E E rn O .c mN a) 0 Y > r EQ o c = a) 20.E .3 0- 0.M/,_ L,E Q W a) CL > Y L ++ o m Q _ 2 aai = Q L a3 C CL CT a CO> o & o a V7 c C U CO a) L _C 0 --• Q) m To o' Q O M -a , L u_ °• 2 c 0. m s. m as U a 0` v L W i Ea) 0. L _ 3 U CD al c� Oy Q. c 0. 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