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Home My WebLink About189-028Nolan 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: 08/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250807 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 6/26/2025 AK E-LINE PPROF T40741 BCU 25 50133206440000 214132 7/16/2025 AK E-LINE Plug/Cement T40742 BRU 211-35 50283201890000 223050 6/11/2025 AK E-LINE Perf T40743 BRU 211-35 50283201890000 223050 6/20/2025 AK E-LINE PPROF T40743 BRU 213-26 50283201920000 223069 7/7/2025 AK E-LINE Perf T40744 BRU 213-26T 50283202040000 225038 7/2/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 7/4/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 6/28/2025 AK E-LINE Perf T40745 BRU 241-23 50283201910000 223061 7/18/2025 AK E-LINE Perf T40746 GP 11-13RD 50733200260100 191133 6/2/2025 AK E-LINE PPFROF T40747 KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF T40748 MPU E-28 50029232590000 202055 5/8/2025 AK E-LINE Caliper T40749 MPU F-21 50029226940000 196135 7/10/2025 AK E-LINE Caliper T40750 MPU G-02 50029219260000 189028 7/6/2025 AK E-LINE Puncher T40751 MPU I-01 50029220650000 190090 7/7/2025 AK E-LINE TubingPunch T40752 NS-19 50029231220000 202207 6/27/2025 AK E-LINE Perf T40753 PBU J-07C 50029202410300 225026 5/29/2025 BAKER MRPM T40754 PBU N-07B 50029201370200 223122 6/7/2025 BAKER MRPM T40755 PCU-05 50283202030000 225037 7/10/2024 AK E-LINE Perf T40756 TBU D-07RD2 50733201170200 192155 7/19/2025 AK E-LINE Perf T40757 TBU M-09 50733204760000 196127 7/18/2025 AK E-LINE Perf T40758 Please include current contact information if different from above. T40751MPU G-02 50029219260000 189028 7/6/2025 AK E-LINE Puncher Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.08 11:16:55 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Hayden.Moser@hilcorp.com Cc:DOA AOGCC Prudhoe Bay; Ryan Lewis; Erik Nelson - (C); Tom Fouts; Taylor Wellman Subject:20250716 0901 APPROVAL BOPE 3 ram stack MP G-02 AOGCC 10-403 (Sundry # 325-374) (PTD # 189-028) Date:Wednesday, July 16, 2025 9:08:59 AM Attachments:MP G-02 AOGCC 10-403 APPROVAL 7-14-2025.pdf ASR 11 inch Triple Stack 2.375 Pipe Ram .pdf Hayden, Hilcorp is approved to utilize the 3 ram BOPE stack with an additional set of rams for 2-3/8” pipe on Sundry 325-374. As noted in the approved sundry, the BOPE diagram was mistakenly identified as a 2 ram stack with only 2-7/8” x 5” VBRs and Blind ram. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. AOGCC Inspectors From: Hayden Moser <hayden.moser@hilcorp.com> Sent: Tuesday, July 15, 2025 4:54 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com>; Erik Nelson <Erik.Nelson@hilcorp.com>; Ryan Lewis <Ryan.Lewis@hilcorp.com> Subject: MP G-02 AOGCC 10-403 (Sundry # 325-374) (PTD # 189-028) Hello Mr. Rixse, We made an error on this Sundry and attached the wrong BOP schematic. We would like to run a triple stack with a 2 3/8” pipe ram. The verbiage in the sundry is correct and references the triple stack. Just wanted to clear this with you. Thanks, Hayden Moser Operations Engineer | Milne Point Unit | C, J, M Pads Hilcorp Alaska, LLC | 3800 Centerpoint Drive | Anchorage, AK 99503 O: (907) 564-4389 | C: (479) 899-8940 | Hayden.Moser@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Updated 10/9/2024 11” BOPE INTEGRATED 11'’-5000 INTEGRATED 4.30'INTEGRATED 11" - 5000 2-7/8" x 5" VBR Blind 11'’- 5000 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManual Stripping Head ManualManual 2-3/8" Pipe Ram Milne Point ASR 11” BOP w/ Jacks 05/17/2017 Milne Point ASR 11” BOP (Triple) 10/9/2024 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 Change-out 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): 5,714'N/A Casing Collapse Conductor N/A Surface 4,760psi Production 7,020psi 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 2,856' 5,694' todd.sidoti@hilcorp.com 777-8443 Perforation Depth MD (ft): See Schematic See Schematic 2-7/8" 2-3/8" 4.7 / L-80 / Supermax SC-1L & Model D Perm/ and N/A 4,669' MD/ 3,770' TVD & 5,110' MD/ 4,143' TVD and N/A Todd Sidoti 4,701' MD N/A 6,870psi 8,160psi 2,485' 4,683' 2,856' 5,694' 110' Proposed Pools: 110' 110' 6.5 / L-80 / 8rd EUE TVD Burst 5,110' 4,527' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 189-028 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21926-00-00 Hilcorp Alaska LLC C.O. 477.005 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 7/16/2025 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 MILNE PT UNIT G-02 Length 5,614' 4,609' 804 N/A MILNE POINT SCHRADER BLUFF OIL N/A Suspension Expiration Date: Size 13-3/8" 9-5/8" 7" 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 11:08 am, Jun 20, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.06.19 10:43:16 - 08'00' Taylor Wellman (2143) 325-374 DSR-6/23/25 10-404 MGR30JUN2025 * BOPE pressure test to 2000 psi. 24 hour notice for opportunity to witness. * 30 minute charted pressure test of IC w/ test packer to 1500 psi. No state witness necessary. A.Dewhurst 14JUL25JLC 7/14/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.07.14 12:09:11 -08'00' 07/14/25 RBDMS JSB 071425 ESP Change-Out Well: MPU G-02 Well Name: MPU G-02 API Number: 50-029-21926-00 Current Status: Shut-in ESP Producer Pad: J-Pad Estimated Start Date: July 16th 2025 Rig: ASR Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 189-028 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: Current Bottom Hole Pressure: 1140 psi @ 3364’ TVD ESP Pressure Gauge 11/15/24 – 6.6 PPG MPSP: 804 psi Gas Column Gradient (0.1 psi/ft) 47° Max Inclination: ~4,400’ MD Brief Well Summary: MPU G-02 is completed as a Schrader N-Sand well with a gravel pack across the formation. MPG-02 has a history of sand and scale production. The ESP has failed due to scale/sand seizing the pumps. Notes Regarding Wellbore Condition x Passing 1500 psi MIT on 7” performed 10/31/2017. Objective: x Pull 2-3/8” x 2-7/8” ESP completion x Perforate Schrader NE Sands x Install new 2-7/8” chrome ESP completion Non- Sundried work Slickline: 1. Pull 2-3/8” patch assembly from 3117’. a. AD-2 stop b. D&D packoff c. Top 21’ spacer pipe d. Bottom 20’ spacer pipe with D&D packoff e. AA stop 2. Pull bottom GLV and leave pocket open. 3. Pull top GLV and dummy off mandrel. Sundried Procedure (Approval Required to Proceed) Fullbore: 4. RU FB and PT lines to 3,000 psi. 5. Pump diesel spear followed by 250 bbls KWF (source water) down the tubing taking returns up the IA. a. Bullheading might be necessary due to higher circulation point in tubing at ~3125’. 6. Confirm well is dead. 7. RD FB. 8. Clear and level pad area in front of well. Spot rig mats and containment. ESP Change-Out Well: MPU G-02 9. RD well house and flowlines. Clear and level area around well. 10. RU crane. Set BPV. ND Tree. Inspect the tubing hanger lift thread and note any damage. 11. NU BOPE. RD Crane. 12. Spot mud boat. RWO Procedure: 13. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to returns tank. 14. If needed, bleed off any residual pressure off the IA. Check for pressure and if 0 psi, pull BPV. If needed, kill well with KWF prior to pulling BPV. 15. Set TWC. 16. Test BOPE to 250 psi Low/ 2,000 psi High, annular to 250 psi Low/ 2,000 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 2-3/8” ram on 2-3/8” test joint. e. Test VBR ram on 2-7/8” and 3-1/2” test joints. f. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 17. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/ KWF as needed. 18. Rig up spoolers for ESP cable. 19. MU landing joint or spear, BOLDS and PU on the tubing hanger. a. PUW was 28klbs and SO was 20klbs during installation. 20. Lay down tubing hanger. 21. POOH and lay down the 2-3/8” x 2-7/8” tubing while spooling ESP cable. Lay down ESP and motor. a. Wash and toss tubing. b. Note any sand or scale inside or on the outside of the ESP in WSR. c. The completion has the following clamps installed: i. 66 Cross Collar Clamps ii. 2 Pump/Seal Clamps iii. 3 Protectrolizers iv. 1 Motor Clamp 22. PU 7” casing bit and scraper on 3-1/2” workstring. 23. RIH to to 4660’ and tag SC-1L packer. 24. Make 2 scraper passes from 4660’-4500’. 25. Tag SC-1L packer and POOH. a. It may be necessary to pick up a motor and mill if too much scale is present for an effective bit and scraper run. 26. MIRU E-line. PT lubricator to 250 psi low / 2000 psi high. 27. MU and RIH with 2” HSD perforating guns. a. Perforate from ±5112’ - ±5155’. ESP Change-Out Well: MPU G-02 b. Top of perforated interval may be lowered once the bottom gravel pack packer is logged. We will not perforate across the packer. 28. RDMO E-line. 29. PU 7” test packer BHA on 3-1/2” workstring. 30. RIH to 4600’ and perform MIT-T to 1500 psi for 30 minutes charted. POOH. 31. PU new ESP and RIH on new 2-7/8” 6.4# 13Cr JFEBEAR tubing. Set base of ESP assembly at ± 4,524’ MD. a. Check ESP cable conductivity every 2,000’ Proposed Running Order a. Base of ESP centralizer @ ±4,524’ MD b. Motor Gauge c. Motor d. Tandel Seals e. Gas Separator f. 400 series Pump g. Downhole gauge for discharge temperature and pressure. h. 1 joint of 2-7/8” i. Lower 2-7/8” GLM with Dummy GLV j. ± XXX joints 2-7/8” k. GLM, 2-7/8”, DPSOV installed with pups (setting depth +/- 200’ MD). l. +/- XXX joints, 2-7/8” 32. PU and MU the 2-7/8” 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. 33. 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. 34. Set TWC. 35. RDMO ASR. Post-Rig Procedure: 36. RD mud boat. RD BOPE house. Move to next well location. 37. RU crane. ND BOPE. 38. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 39. Pull TWC. 40. RD crane. Move returns tank and rig mats to next well location. 41. Replace gauge(s) if removed. 42. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic ESP Change-Out Well: MPU G-02 2. Proposed Schematic 3. BOP Schematic _____________________________________________________________________________________ Revised By: JH 10/3/23 SCHEMATIC Milne Point Unit Well: MPU G-02 Last Completed: 1/24/2020 PTD: 189-028 TD =5,714’ (MD) / TD= 4,701’(TVD) 13-3/8” KB Elev.: 59.3’AMSL/GL Elev.: 28.6’ AMSL Doyon 16: 22.74’ RKB to THF 7” 3 4 & 5 6 9 8 & 9 12 13 15 9-5/8” 1 2-3/8” patch 3117’-3163’ min i.d. Estimated TOC @ ± 3,500’ 16 PBTD =5,614’ (MD) / PBTD = 4,609’(TVD) Schrader “N” Sands 7 10 11 14 17 18 &19 2 1 JEWELRY DETAIL No Depth Item 1 28’ 2-7/8” EUE x 2-3/8” Supermax Crossover 2 228’ GLM STA #2: DPSOV 0.25" orifice BK Latch 3 4,362’ GLM STA #1: Dummy VLV BK Latch 4 4,481.9’ Discharge Head: Bolt On 5 4,482’ Ported Discharge Head: Zenith PRESS PORT 400P 6 4,483’ Pump: Baker FLEXER H6 SXD 7 4,499’ Gas Separator: GRS FER N AR 8 4,502’ Upper Tandem Seal: GSB3DB H6 SB/AB PFSA 9 4,509’ Lower Tandem Seal: GSB3DB H6 SB/AB PFSA 10 4,516’ Motor: 562XP 100Hp/ 1820V / 34A 11 4,524’ Sensor: Zenith Gauge w/ Centralizer –Bottom @ 4,527’ 12 4,669’ Baker SC-1L Packer 70B2-40 –4.0” ID 13 4,678’ Sliding Sleeve –4.0” ID 14 4,704’ 2-7/8” Shear out Safety Joint w/ 44K Shear –2.43” ID 15 5,001’ Bakerweld 2-7/8” 0.012” Ga.Screen 96’ w/ 2.44” ID 16 5,097’ O-Ring Seal Sub 17 5,098’ Bakerweld 2-7/8” 0.012” Ga. Tell Tale Screen –11’ w. 2.44” ID 18 5,109’ Baker S-22 Snap Latch Seal Assembly 19 5,110’ Baker Model D Permanent Packer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NA 5,022’ 5,046’ 4,064’ 4,086’ 24 See Below Open NB 5,056’ 5,076’ 4,095’ 4,113’ 20 See Below Open NB/NC 5,085’ 5,094’ 4,121’ 4,129’ 9 See Below Open Perforation Charge Detail: 4-5/8” Vann Gun Assembly – 24SPF Executed on 3/30/1990 & 4/7/1990 OPEN HOLE / CEMENT DETAIL 13-3/8" 60 bbls of Arcticset to surface in 30” Hole 9-5/8" 171 bbls of 12.3ppg PF “E”/ 123 bbls of 15.8 ppg Prem. “G” in a 12-1/4” Hole 7” 65 bbls of 15.6 ppg Prem. “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 48 deg. Max Hole Angle through perforations = 27 deg. TREE & WELLHEAD Tree 5M FMC 2-9/16” Wellhead 11” 5M FMC w/ 2-7/8” WKM Tbg. Hngr., w/ 2-7/8” 8 rd top, 2-7/8” lower, 2-1/2” CIW H BPV profile GENERAL WELL INFO API: 50-029-21926-00-00 Drilled and Cased by Parker 141 - 8/29/1989 Perforate, Gravel Pack & Test by Pool #102 –5/10/1990 Completed with ESP by EWS Rig #4 –11/20/1990 ESP Change-out by Nabors 4ES –2/15/1999 ESP Change-out by Nabors 3S –12/8/2008 ESP Change-out by Doyon 14 –3/24/2013 ESP Change-out by ASR#1 –11/2/2017 & 1/24/2020 WELL STIMULATION Gravel Pack: 5,022’ to 5,094’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / Btrs 12.715 Surface 110’ 0.157 9-5/8" Surface 47 / L-80 / Btrs 8.681 Surface 2,856’ 0.0732 7" Production 29 / L-80 / Btrs 6.184 Surface 5,694’ 0.0372 TUBING DETAIL 2-3/8” Tubing 4.7 / L-80 / Supermax 1.995 Surface 4,527’ 0.0039 2-7/8” Tubing 6.5 / L-80 / 8rd EUE 2.441 4,669’ 5,110’ 0.00579 _____________________________________________________________________________________ Revised By: TDF 6/19/2025 PROPOSED Milne Point Unit Well: MPU G-02 Last Completed: 1/24/2020 PTD: 189-028 TD =5,714’ (MD) / TD = 4,701’(TVD) 13-3/8” KB Elev.: 59.3’AMSL/GL Elev.: 28.6’ AMSL Doyon 16: 22.74’ RKB to THF 7” 2 3 & 4 5 9 7 & 8 11 12 14 9-5/8” Estimated TOC @ ± 3,500’ 15 PBTD =5,614’ (MD) / PBTD =4,609’(TVD) Schrader “N” Sands 6 9 10 13 16 17 & 18 1 Schrader “NE” Sands 1 JEWELRY DETAIL No Depth Item 1 XXX’ GLM STA #2: 2 ±X,XXX’ GLM STA #1: 3 ±X,XXX’ Discharge Head: 4 ±X,XXX’ Ported Discharge Head: 5 ±X,XXX’ Pump: 6 ±X,XXX’ Gas Separator: 7 ±X,XXX’ Upper Tandem Seal: 8 ±X,XXX’ Lower Tandem Seal: 9 ±X,XXX’ Motor: 10 ±X,XXX’ Sensor: Gauge w/ Centralizer –Bottom @ ±X,XXX’ 11 4,669’ Baker SC-1L Packer 70B2-40 –4.0” ID 12 4,678’ Sliding Sleeve –4.0” ID 13 4,704’ 2-7/8” Shear out Safety Joint w/ 44K Shear –2.43” ID 14 5,001’ Bakerweld 2-7/8” 0.012” Ga.Screen 96’ w/ 2.44” ID 15 5,097’ O-Ring Seal Sub 16 5,098’ Bakerweld 2-7/8” 0.012” Ga. Tell Tale Screen –11’ w. 2.44” ID 17 5,109’ Baker S-22 Snap Latch Seal Assembly 18 5,110’ Baker Model D Permanent Packer PERFORATION DETAIL Schrader Bluff Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NA 5,022’ 5,046’ 4,064’ 4,086’ 24 See Below Open NB 5,056’ 5,076’ 4,095’ 4,113’ 20 See Below Open NB/NC 5,085’ 5,094’ 4,121’ 4,129’ 9 See Below Open NE ±5,112’ ±5,155’ ±4,145’ ±4,185’ ±43 Future Future Perforation Charge Detail: 4-5/8” Vann Gun Assembly – 24SPF Executed on 3/30/1990 & 4/7/1990 OPEN HOLE / CEMENT DETAIL 13-3/8" 60 bbls of Arcticset to surface in 30” Hole 9-5/8" 171 bbls of 12.3ppg PF “E”/ 123 bbls of 15.8 ppg Prem. “G” in a 12-1/4” Hole 7” 65 bbls of 15.6 ppg Prem. “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 48 deg. Max Hole Angle through perforations = 27 deg. TREE & WELLHEAD Tree 5M FMC 2-9/16” Wellhead 11” 5M FMC w/ 2-7/8” WKM Tbg. Hngr., w/ 2-7/8” 8 rd top, 2-7/8” lower, 2-1/2” CIW H BPV profile GENERAL WELL INFO API: 50-029-21926-00-00 Drilled and Cased by Parker 141 - 8/29/1989 Perforate, Gravel Pack & Test by Pool #102 –5/10/1990 Completed with ESP by EWS Rig #4 –11/20/1990 ESP Change-out by Nabors 4ES –2/15/1999 ESP Change-out by Nabors 3S –12/8/2008 ESP Change-out by Doyon 14 –3/24/2013 ESP Change-out by ASR#1 –11/2/2017 & 1/24/2020 WELL STIMULATION Gravel Pack: 5,022’ to 5,094’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / Btrs 12.715 Surface 110’ 0.157 9-5/8" Surface 47 / L-80 / Btrs 8.681 Surface 2,856’ 0.0732 7" Production 29 / L-80 / Btrs 6.184 Surface 5,694’ 0.0372 TUBING DETAIL 2-7/8” Tubing 6.4 / 13CR / JBear 2.441 Surface ±X,XXX’ 0.0058 2-7/8” Tubing 6.5 / L-80 / 8rd EUE 2.441 4,669’ 5,110’ 0.0058 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 Nolan 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: 09/29/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230929 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU B-28 50029235660000 216027 9/22/2023 READ Caliper Survey MPU G-02 50029219260000 189028 9/18/2023 READ Caliper Survey MPU K-13 50029226550000 196040 9/18/2023 READ Caliper Survey MPU L-29 50029225430000 195009 9/17/2023 READ Caliper Survey Please include current contact information if different from above. T38019 T38020 T38021 T38022 9/29/2023 MPU G-02 50029219260000 189028 9/18/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.09.29 12:48:41 -08'00' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ` 14 2020 1. Operations Abandon Plug Perforations LJ Fracture StimulateLJ Pull Tubing L4J Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Ch 6 rogram ❑ Plug for Redrill ElBrforate New Pool El Repair Wel] Re-enter Susp Well ❑ Other: E C ange-out ❑✓ 2. Operator Name: Hilcorp Alaska LLC 4. Well Class Before Work: Development Q Stratigraphic❑ Exploratory ❑ Service ❑✓ 5. Permit to Drill Number: 189-028 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-21926-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025906 MILNE PT UNIT G-02 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / SCHRADER BLUFF OIL 11. Present Well Condition Summary: Total Depth measured 5,714 feet Plugs measured N/A feet true vertical 4,701 feet Junk measured N/A feet Effective Depth measured 5,614 feet Packer measured 4,669 & 5,110 feet true vertical 4,609 feet true vertical 3,770 & 4,143 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 13-3/8" 110' 110' N/A N/A Surface 2,856' 9-5/8" 2,656' 2,485' 6,870psi 4,760psi Production 5,694' 7" 5,964' 4,683' 8,160psi 7,020psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 2-3/8" 4.7 / L-80 / Supermax 4,527' 3,666' Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5 / L-80 / 8rd EUE 5,110' 4,143' SCA L Packers and SSSV (type, measured and true vertical depth) Model D Perm 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: 1 0 0 0 420 8 Subsequent to operation: 1 81 37 84 280 209 14. Attachments (required per 20 AAC 25.070, 25.071, &25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory❑ Development❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil j Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-567 Authorized Name: Chad Helgeson Contact Name: j David Haakinson Authorized Title: Operations Manager Contact Emai: dhaaklnson a)hllcorD.col Authorized Signature: Date: 2/24/2020 Contact Phone: 777-8343 7/-zf�Sc1ld IL- Form 10-404 Revised 4/2017 RBDMSI+�' FEB 2 5 2020 Submit Original Only n Nilrprp Alaska, LLC KB Bev.: 59.3' XvS/GL Bev.: 2&6 AMSL To= 5,714' (N1D)/TD=4,701'(W) PBTD=5,614'(ND)/PBM=4,609'( VD) SCHEMATIC Milne Point Unit Well: MPU G-02 Last Completed: 1/24/2020 PTD: 189-028 TREE & WELLHEAD Tree 5M FMC 2-9/16" Wellhead 11" 5M FMC w/ 2-7/8" WKM Tbg. Hngr., w/ 2-7/8" 8 rd top, Top 2-7/8" lower, 2-1/2" CIW H BPV profile OPEN HOLE / CEMENT DETAIL CASING DETAIL SizeType Depth Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 1 48/H-40/Btrs 12.715 Surface 110' 0.157 9-5/S" Surface1 47 / L-80 / Btrs 8.681 Surface 2,856' 0.0732 7" Production 1 29/L-80/Btrs 6.184 Surface 5,694' 0.0372 TUBING DETAIL 2-3/8" Tubing 4.7/L-80/Supermax 1.995 Surface 4,527' 0.0039 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 1 4,669' 5,110' 0.00579 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle =48 deg. Max Hole Angle through perforations= 27 deg. JEWELRY DETAIL No Depth Item 1 28' 2-7/8" EUE x 2-3/8" Supermax Crossover 2 228' GLM STA #2: DPSOV 0.25" orifice BK Latch 3 4,362' GLM STA#1: Dummy VLV BK Latch 4 4,481.9' Discharge Head: Bolt On 5 4,482' Ported Discharge Head: Zenith PRESS PORT400P 6 4,483' Pump: Baker FLEXER H6 SXD 7 4,499' Gas Separator: GRS FER N AR 8 1 4,502' 1 Upper Tandem Seal: GSB3D6 H65B/AB PFSA 9 4,509' Lower Tandem Seal: GSB3DB H6 SB/AB PFSA 10 4,516' Motor: 562XP 100H /1820V/34A 11 4,524' Sensor: Zenith Gauge w/ Centralizer -Bottom @ 4,527' 12 4,669' Baker SC -1L Packer 7082410-4,0"ID 13 4,678' Sliding Sleeve -4.0" ID 14 4,704' 2-7/8" Shearout Safety Jointw/44K Shear -2.43" ID 15 5,001' Bakenveld 2-7/8" 0.012" Ga.Screen 96' w/ 2.44" ID 16 5,097' O -Ring Seal Sub 17 5,098' Bakerweld 2-7/8"0.012" Ga.Tell Tale Screen -11'w. 2.44" ID_ 18 5,109' Baker S-225nap Latch Seal Assembly 19 5,110, Baker Model D Permanent Packer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NA 5,022' 5,046' 4,064' 4,086' 24 See Below Open NB 5,056' 5,076' 4,095' 4,113' 20 See Below Open NB/NC 5,085' 5,094' 4,121' 4,129' 9 1 See Below Open Perforation Charge Detail: 4-5/8" Vann Gun Assembly - 245PF Executed on 3/30/1990 & 4/7/1990 WELL STIMULATION Gravel Pack: 5,022' to 5,094' GENERAL WELL INFO API: 50-029-21926-00-00 Drilled and Cased by Parker 141 - 8/29/1989 Perforate, Gravel Pack & Test by Pool #102-5/10/1990 Completed with ESP by EWS Rig #4 -11/20/1990 ESP Change -out bNabors 4ES - 2/15/1999 ESP Change -out by Nabors 3S -12/8/2008 ESP Change -out by Doyon 14 - 3/24/2013 ESP Change -out by ASR#1 - 11/2/2017 & 1/24/2020 Revised By: TDF 2/21/2020 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-02 ASR#1 50-029-21926-00-00 189-028 1/22/2020 1/28/2020 1/22/2020- Wednesday No operations to report. 1/23/2020 - Thursday No operations to report. 1/24/2020 - Friday No operations to report. 1/25/2020 -Saturday Start filling stack to begin shell test. Circulate all test lines and re -shoot temps, shell test 250 low and2,500psi high good for 5 minutes. Test with 2-7/8 mandrel with annular closed on mandrel. Notify Guy Cook with AOGCC. AOGCC Rep and Electricians on site. Test Alarms. Begin BOP test, test with 2-7/8" test joint to 250psi low /2,500psi high. LD 2-7/8" joint, PU 2-3/8" testjoint. Test to 250psi low /2,500psi high. Test Annular against 2-3/8" test joint to 250psi low /2,500psi high. Test complete at 0100 hrs on Jan 26. RD from BOP test. Prepare to open up to well. Pull 2-7/8" test sub from hanger above BPV. Slight pressure on IA, rig up and bleed into Bleed Trailer, immediate drop. Pull BPV, no pressure from well - static. RU to spool control line, heat trace, and ESP cable. Pull tubing hanger, no issues - PUW 42k. Stage TIW, fill well. 1/26/2020 -Sunday Crew swaps and fluid checks - well static, pump 40 bbls down backside and no sign of fluid level. Rig up lines for spooling ESP cable, Heart trace, and cap string. Start POOH with 2-7/8 6.5 # EUE tubing, unclamping Heat trace, cap string and power cable. pumping double displacement 8.3ppg source water, Cap string spooler moving slow due to cold - retarp and adjust heaters, found pin hole in jt #6 and #7 on way out of hole. Pin holes were under heat trace cable. 26joints out of hole @ 1030hrs. Continue to POOH w/ 2-7/8" 6.5# EUE tbg. Pumping double displacement w/ 8.3 ppg source water. Crew continue to adjust heaters as needed. Cap spooler and hydraulic elevators running exceptionally slow due to cold. Baker Centrilift personnel slipped while walking away from rig floor and stepping over heater hose. Twisted ankle. Sent to medic. Notified Wells Foreman and Safety Dept. 42 joints out of hole @ 12:30 hrs. Crews eating lunch and Continue to POOH w/ 2- 7/8" 6.5# L-80 tubing. Pumping double displacement of 8.3 ppg source water. 68 jts out of hole @ 15:30 hrs. Conduct walkaround for safety check on walk paths. Use loader to scratch common walk areas. Continue to POOH w/ 2-7/8" 6.5# 11- 80 tubing. Pumping double displacement of 8.3 ppg source water. 90 jts out of hole at 1800 hrs. Fill well with double displacement of fluids. Lower flow volume, trace where possible freeze restriction is. Move around heaters to keep equipment operational and to keep lines from freezing. Thaw lines, confirm good flow, function test spoolers. POH with 2- 7/8" 6.5# L-80 tubing, spooling ESP and Heat trace cables and capillary line. Pump double displacement of 8.3 ppg fluid every 15 joints. 118 joints out of hole as of midnight. 135 2-7/8" 6.5# L-80 joints out of well. Conduct Kick While Tripping Drill, install TIW, pick up and simulate cutting cables and spacing out. Crew eat lunch. Fill hole with double displaced volume, no returns. Continue to pull completion string. Lay down Gas -Lift Mandrel and remaining joints. Pull and LD ESP assembly. Clear and clean rig floor and prep for picking up new assembly. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-02 ASR#1 50-029-21926-00-00 189-028 1/22/2020 1/28/2020 1/27/2020 - Monday Crew swaps and continue to swap out spools on spooler. Well static, continue to pump 10 bbls every hour of 8.3ppg source water while spool swap operations ongoing. Re -spot spooling unit and prep to P/U ESP. Begin P/U and assemble ESP. Upon lifting the pump section with winch and following on old catwalk - lifting clamp connected to winch line entangled on v -door and pump swung off of slide and hit the well house. Concerns with cold and internal parts of pump called for swapping to new pump section. Centrilift swapping to new pump section. Centrilift en -route to shop, replace gas separator on pump section and return to ASR. SIMOPS ASR crew and Centrilift continue to service motor section of ESP and pull and prep power Cable for installation. New pump on location and picked up to floor uneventfully. Complete assembly of ESP install final pump clamps and prep to RIH w/ ESP assembly. Pump 10 bbls into well of 8.3ppg source water. Well static. Swap all lifting gear, very slow to all parts extremely frozen. Load and tally 2-3/8" Supermax tubing. Connect discharge head to pump and sensing line to ported discharge head. Crew swap out - discussion focused on handling equipment on pipe skate and monitoring fluids lines during the cold weather. Complete make-up of ESP assembly, RIH on 2-3/8" 4.7# L- 80 Supermax thread. Install clamps per Baker rep, test ESP cable every 1,000'. MU, RIH with 2-3/8" 4.7# L-80 tubing and testing ESP cable every 1,000'. Joint 50 in the well as of midnight. Filling well with double displacement volume every hour. MU, RIH with 2-3/8" 4.7# L-80 tubing and testing ESP cable every 1,000'. Filling well with double displacement volume every hour. Joint 79 in the well as of 0215 hrs. Main 300KV generator has shut down. Troubleshoot generator, call out VMS personnel to location. Walk through well control contingency with crew. 1/28/2020 -Tuesday Monitor well - Well static - Continue troubleshooting 300kw generator, order out and install 300kw from VMS it ran 15 minutes and shut down. VMS troubleshooting their 300kw and determined diesel in oil - continue troubleshooting 300kw on ASR. Crew split and retrieving heaters from around the field to keep pits, and centrilift spooler thawed. Crews managing heaters on equipment. VMS continue to work on ASR 300kw, found blown fuse on ESD and loose belts, tightend belts and disconnected coolant sensor as it was found malfunctioning. ASR 300kw running, spare 400kw coming from town, Crews walk down all equipment, pump 15 bbls to well of 8.3ppg source water. Prep to RIH with ESP Joint 79 on hook @ 1500 hrs. Start RIH w/ ESP assembly on 2-3/8" 4.7# Supermax tubing. RIH w/ 4joints and test cable. Test good on cable. Continue to RIH w/ 2-3/8" 4.7#, Supermax tubing and ESP assembly. Pumping double displacement of 8.3ppg source water every 15 joints. 100 jts in hole @ 1700 hrs. Continue RIH w/ 2-3/8" 4.7# Supermax tbg. and ESP assembly. Pumping double displacement every 15 joints of 8.3ppg source water. Continue RIH w/ 2-3/8" 4.7# Supermax tbg. and ESP assembly. Pumping double displacement every 15 joints of 8.3ppg source water. Continue RIH w/ 2-3/8" 4.7# Supermax tbg. and ESP assembly. Pump double displacement every 15 joints of 8.3ppg source water. Install Upper GLM with DPSOV orifice and BK Latch, continue with tubing for total of 142 joints 2-3/8" 4.7# L-80 Supermax thread tubing run, 66 Canon Clamps in well. Bring hanger to rig floor, MU and space out for ESP termination. Terminate, test ESP cable. Land hanger, PUW 28k, SOW 18k. Run-in Lock Down Screws. Remove landing joint, install BPV. Well secure at 0100 hrs with BPV set. Begin rig down operations as weather permits. Secure hoses, prep rig for lay down, power -wash pits, call out Vac truck to suck out pits, prep cellar for ND of BOP. THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU G-02 Permit to Drill Number: 189-028 Sundry Number: 319-567 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.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, Jessie L. Chmielowski Commissioner DATED this Ig day of December, 2019. RBDMS��a'/DEC 19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS on A AC oc non RECE:mmr DEC 16 2019 07-S A ^C�(9i� 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tutting Qo Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Cahange-out Q 2. Operator Name: 4. Current Well Class 15. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 189-028 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-21926-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No MILNE PT UNIT G-02 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025906 MILNE POINT/SCHRADER BLUFF 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): 5,714' 4,701' 5,614' 4,609' 903 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor110' 13-3/8" 110' 110' N/A N/A Surface 2,856' 9-5/8" 2,856' 2,485' 6,870psi 4,760psi Production 5,694' 7" 5,694' 4,683' 8,160psi 7,020psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 2-7/8" 6.5 / L-80/ 8rd EUE 4,602 See Schematic See Schematic 2-7/8" 6.5 / L-80 / 8rd El E 5,110 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): SC -1 L & Model D Perm/ and N/A 4,669' MD/ 3,770' TVD & 5,110' MD/ 4,143' TVD and N/A 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: 1/8/2020 - OIL ❑� 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: Chad Helgeson Contact Name: David Haakinson Authorized Title: Operations Manager Contact Email: dhaakinSon hl Or .Coln .J Contact Phone: 777-8343 Authorized Signature: Date: 12/16/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test I/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Z 5-00 111'j c, /I e)P /�� L RBDMS I�''`'�DEC 19 2019 Post Initial Injection MIT Req'd? Yes F] No EJ,] U Spacing Exception Required? Yes ❑ No O Subsequent Form Required: APPROVED BY Approved by: 1 . COMMISSIONER THE COMMISSION Date: t y r G1 (' ORIGINAL / ',2-191'f Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. /Submit Form and Attachments in Duplicate U lrilmm Alaska, LU ESP Change -Out Well: MPU G-02 Date: 12-16-19 Well Name: MPU G-02 API Number: 50-029-21926-00 Current Status: Shut-in ESP Producer Rig: ASR #1 Estimated Start Date: January 8`^, 2020 Estimated Duration 3 Days Reg. Approval Req'd? Yes Date Reg, Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 189-028 First Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) Second Call Engineer: Ian Toomey (907) 777-8434 (0) (907) 903-3987 (M) AFE Number: Job Type: ESP Swap Current Bottom Hole Pressure: 1,255 psi @ 3,717' TVD Maximum Expected BHP: 1,275 psi @ 3,717' TVD MPSP: 903 psi Max Inclination 48° @ 2,700' MD Max Dogleg: 4.1"/100ft @ 3,600' MD BPV Profile: 2-1/2" CIW Type H Downhole Gauge: 1 -month PBU (12/5/19) 16.49 PPG 2 -Month PBU Extrapolation 1 6.6 PPG Gas Column Gradient (0.1 psi/ft)' Brief Well Summary: MPU producer G-02 was drilled and completed as a gravel -packed N -Sand producer in 1989. The well has had a history of RWOs related to tubing leaks and motor failures. The tubing leaks appear to be related to the installation of downhole heat trace and thus the heat trace will be removed. Regarding historical motor failure, producer G-02 has evidence of past calcium carbonate scaling leading to high motor temperatures. As part of the well kill, a scale squeeze will be pumped on the well. The average ESP run -life has been approximately seven years, not accounting for the last two workovers due to tubing leaks. The last two ESP pulls have indicated sand in the pump, indicating a failure of the screens. After the RWO, the suction pressure target will be raised from 500 psig to 600 psig to limit sand production. Notes Regarding Wellbore Condition • The 7" production casing passed an MIT to 1,500 psig from 4,651' MD on 10/31/17 • The well has tubing leaks at 1,065' MD and 1,101' MD • Offset Injector Support o G-01: Shut-in Injector Obiective• • Pull 2-7/8" Tubing String, ESP, and 100 HP motor. • Install new Baker Hughes motor, Flex7 ESP, and new 2-3/8" tubing. Pre -Rig Procedure: -3 — 1 1. Ensure tubing patch and gas -lift valve slickline work is complete prior to the well -kill. 2. RU LRS and PT lines to 3000 psi. 3. Bullhead 70 bbls of 8.3 ppg source -water down tubing, taking fluid out the IA to a returns tank. 4. Bullhead 40 bbls of 8.3 ppg source water down tubing to the formation. 5. Bullhead 300 bbls of 8.3 ppg source -water down IA to the formation. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. ESP Change -Out Well: MPU G-02 Ilil..m Alaska, LLi Date: 12-16-19 7. RD Little Red Services. 8. Clear and level pad area in front of well. Spot rig mats and containment. 9. RD well house and flowlines. Clear and level area around well. 10. RU crane. Set BPV. ND Tree.�nspect the tubing hanger lift thread and note any damage) 11. NU BOPS. RD Crane. 12. Spot mud boat. Brief RWO Procedure: 13. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to returns tank. 14. If needed, bleed off any residual pressure off the IA. Check for pressure and if 0 psi, pull BPV. If needed, kill well w/ 8.3 ppg produced or source -water prior to pulling BPV. 15. Set TWC. 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" dated 11/03/2015. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-3/8" and 2-7/8" testjoints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. A email explaining the wellhead situation prior to performing the rolling test. send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure m Regg (AOGCC) via AOGCC may elect to 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. 18. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/ 8.3 ppg produced or source -water as needed. 19. Rig up spoolers to pull heat trace, 3/8" capillary string, and ESP #2 RD cable. a. Baker Hughes representative should be onsite for ESP pull. 20. MU 2-7/8" landing joint or spear, BOLDS and PU on the tubing hanger. 1 {�, a. The PU weight= 40K and SO= 281(for the November 2017 ASR #1 RWO. 1✓ b. Circulate (long or reverse) pill with heated source water, and baraclean pill prior to laying down the tubing hanger. 21. Recover the tubing hanger. n IIil..P Ah.kx, LL ESP Change -Out Well: MPU G-02 Date: 12-16-19 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. 22. POOH and lay down the 2-7/8" tubing spooling ESP cable. Lay down ESP and motor. a. Tubing will not be reused. Send all tubing to G&I for washing and disposal, as necessary. b. Dispose of Heat Trace and 3/8" Capillary String c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. The completion has the following amount of clamps/guards/cap-string: i. 508 Heat Trace Cannon Clamps (every 5') ii. 119 Dual Channel Cross Collar Cannon Clamps iii. 24 Cross Collar Cannon Clamps iv. 5 Pump Clamps v. 3 Protectolizers vi. 2 Flat Guards 23. PU new ESP and RIH on 2-3/8" 4.7# L-80 tubing. Set base of ESP assembly at 4,520' MD. (� \� a. Check ESP cable conductivity every 1,000'. b. Optimum tubing make-up torque: 1,200 ft -lbs i. Minimum: 950 ft -lbs. Maximum: 1,400 ft -lbs. a. Base of ESP centralizer @ ±4,520' MD b. Motorgauge c. 100 HP Baker Hughes 562XP Motor d. Baker Hughes 126 stage Flex7 ESP e. Downhole gauge for discharge temperature and pressure. i. Connected with a jumper from the lower sensor. Does not require a separate tech -wire. f. 3 joints of 2-3/8", 4.7# L-80 Supermax tubing g. Lower 2-3/8"x 1" Side -pocket GLM @ ±4350' MD with DV h. 2-3/8", 4.7#, L-80, Supermax tubing i. Upper 2-3/8"x 1" Side -pocket GLM @ ± 200' MD with 0.25" OV j. 2-3/8", 4.7#, L-80, Supermax tubing 24. PU and MU the tubing hanger with landing joint. 25. Land the tubing hanger and RILDS. Lay down landing joint. Note Pick-up and slack -off weights on tally. 26. Set TWC 27. RDMO ASR. Post -Rig Procedure: 28. RD mud boat. RD BOPE house. Move to next well location. 29. RU crane. NO BOPE. 30. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. H Ilik.n, Al.&.. LL, 31. Pull TWC. 32. RD crane. Move returns tank and rig mats to next well location. 33. Replace gauge(s) if removed. 34. Turn well over to production. RU well house and flowlines. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic ESP Change -Out Well: MPU G-02 Date: 12-16-19 n Hileorp Alaska, LLC NB GeV.: ]9.3' AN'WU UEV.: 28.0 AMSL I 11,101' SLM 5/20/2019 1� B-5/8" 111 1I �r Ce•rNlifthaattace C� 7 k13,417 I' Es[ImatedTOC 2 MN ID= 2205" @4.505' 3 4 5 6 7&6 9 3B'SS Capstnng ' LU 10 11 '12 13 SSadvMsatler"N'f 14 15 "16 17&18 r. 1 TD=5,714' (MD)/TD=4,701'(TVD) PBTD =5,614' (MD) / PBTD=4,609'(TVD) SCHEMATIC Milne Point Unit Well: MPU G-02 Last Completed: 11/2/2017 PTD: 189-028 TREE & WELLHEAD Tree SM FMC 2 -9/16 - Wellhead 11- SM FMC w/2-7/8" WKM Tbg. Hngr., w/2-7/8"8 rd top, 2-7/B" lower, 2-1/2" CIW H BPV profile OPEN HOLE /CEMENT DETAIL 13-3/8" 60 bbls of Arcticset to surface In 3D" Hole 9-5/8" 1 171 bbls of 12.3ppg PF "E"/ 123 bbls of 15.8 ppg Prem. "G" in a 12-1/4" Hole 7" 1 65 bbls of 15.6 ppg Prem. "G" in 8-1/2" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/etrs 12.715 Surface 110' 0.157 9-5/8" Surtace 47/L-80/Btrs 8.681 Surface 2,856' 0.0732 7" Production 29/L-80/e[rs 6.184 1 Surface 5,694' 0.0372 TUBING DETAIL 6.5/L-80/Brd EUE 2.441 Surface 6.5/L-80/8rd EUE 1 2.441 1 4,669' WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle =48 deg. Max Hole Angle through perforations = 27 deg. JEWELRY DETAII Nod Top (MD) Item 1GLM Btm (TVD) STA #2: CAMCO 2-7/8" x 1" Side pocket W/ Dmy 1/6/19 2 Status GLM STA q3: CAMCO 2-7/8" x 1" Side pocket w/ Dmy 1/6/193 5,022' 5,046' XN Nipple W/ 2.205" No- Go ID4 4,086' 1 24 Discharge Head: FPD155 Open NB Pump: FLEXER/H6SXD6 5,076' 4,095' Gas Separator: GRS FER N AR7 20 See Below Upper Tandem Seal: GSB31)BUTSB/SB PFSA 8 4,583' Lower Tandem Seal: GSB3DBUTSB/SB PFSA 9 4,590' Motor: CLS/XP-100HP, 1,820V, 34A 10 4,598' Sensor: Welll-lft Type E w/ Centralizer- Bottom @ 4,602' 11 4,669' Baker SC -1L Packer 7002-40-4,0"ID 12 4,678' Sliding Sleeve -4.0" ID 13 4,704' 2-7/8" Shear out Safety Joint w/ 44K Shear- 2.43" ID 14 5,001' Bakerweld 2-7/8" 0.012" Ga.Screen 96' w/ 2.44" ID 15 5,097' O -Ring Seal Sub 16 5,098' Bakerweld 2-7/8" 0.012" Ga. Tell Tale Screen -11' w. 2.44" ID 17 5,109'Baker 5-22 Snap Latch Seal Assembly 18 5,110' Baker Model D Permanent Packer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NA 5,022' 5,046' 4,064' 4,086' 1 24 See Below Open NB 5,056' 5,076' 4,095' 4,113' 1 20 See Below Open NB/NC 5,085' 5,094' 4,121' 4,129' 9 See Below Open Perforation Charge Detail: 4-5/8" Vann Gun Assembly -245PF Executed on 3/30/1990 & 4/7/1990 WELLSTIMULATION Gravel Pack: 5,022'to 5,094' GENERAL WELL INFO API: 50-029-21926-00-00 Drilled and Cased by Parker 141 -8/29/1989 Perforate, Gravel Pack & Test by Pool #102-5/10/1990 Completed with ESP by EWS Rig 44 -11/20/1990 ESP Change -out by Nabors 4ES -2/15/1999 ESP Change -out by Nabors 3S -12/8/2008 ESP Change -out by Doyon 14 - 3/24/2013 ESP Change -out by ASR#1-11/2/2017 Revised By: TDF 8/21/2019 K corn Al..", LLC KB Elev.:59.3' AMSL/61- Bev.:2&6'AMSL TD = 5,714' (MD) / TD=4,701'(IVD) PBTD= 5,614' (MO)/ PBT[)= 4,609'(IVD) Milne Point Unit Well: MPU G-02 PROPOSED Last Completed: 11/2/2017 PTD: 189-028 TREE & WELLHEAD Tree SM FMC 2-9/16" Wellhead 11 5M FMC w/2-7/8" WKM Tbg. Hngr., w/2-7/8"8 rd top, 2-7/8" lower, 2-1/2" CIW H BPV profile OPEN HOLE / CEMENT DETAIL 13-3/8" 60 6615 of Arcticset to surface in 30" Hale _ 9-5/8" 171 bbls of 12.3ppg PF "E"/ 123 6615 of 15.8 ppg Prem "G" in a 12-1/4" Hole 7" 1 65 bbls of 15.6 ppg Prem. "G" in 8-1/2" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top 1 Btm BPF 13-3/8" Conductor 48/H-40/Btrs 12.715 Lsurface 1 110' 1 0.157 9-5/8" Surface 47/L-80/Btrs 8.681 Surface 2,856' 0.0732 7" Production 29/L-80/Btrs 6.184 Surface 5,694' 0.0372 TUBING DETAIL 2-3/8" Tubing 4.7/L-80/Superman 2.441 Surface 14,520' 0.0039 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle = 48 deg. Max Hole Angle through perforations = 27 deg. g JEWELRY DETAIL No Depth Btm (MD) 1 ±20 2-3/8" Crossover 2 ±200 A N2: 3 ±4,3S0' A NI: jGal�n�ramr 4 ±4,455' e Head: 5 ±4,460' aker Hughes 126 stage FIex7 ESP 6 ±4,475' 4,113' 7 ±4,480' andem Seal: 8 ±4,490' LowerTandem Seal: 9 ±4,500' Motor: Baker Hughes 1001-1p 562XP 30 ±4,518' Sensor: Motor Gauge w/ Centralizer - Bottom @ ±4,520' 11 4,669' Baker SC -1L Packer 7082-40-4,0"ID 12 4,678' Sliding Sleeve -4.0" ID 13 4,704' 2-7/8" Shear out Safety Joint w/ 44K Shear -2.43"JD 14 5,001' Bakerweld 2-7/8" 0.012" Ga.Screen 96' w/ 2.44" ID 15 5,097' 0 -Ring Seal Sub 16 5,098' Bakerweld 2-7/8" 0.012" Ga. Tell Tale Screen - 11' w. 2.44" ID 17 5,139' 1 Baker 5-22 Snap Latch Seal Assembly 18 5,110' I Baker Model D Permanent Packer PERFORATION nFTAII Sands Top (MD) Btm (MD) Top (ND) Elm (ND) FT Date Status NA 5,022' 5,046' 4,064' 4,086' 24 See Below Open NB 5,056' 5,076' 4,095' 4,113' 20 See Below Open NB/NC 5,085' 5,094' 4,121' 4,129' 9 See Below Open Perforation Charge Detail: 4-5/8" Vann Gun Assembly- 24SPF Executed on 3/30/1990 & 4/7/1990 WELL STIMULATION Gravel Pack: 5,022' to 5,094' GENERAL WELL INFO API: 50-029-21926-00-00 Drilled and Cased by Parker 141-8/29/1989 Perforate, Gravel Pack & Test by Pool #102 -5/10/19 9 0 Completed with ESP by E WS Rig p4 -11/20/1990 ESP Change -out by Nabors 4ES - 2/15/1999 ESP Change -out by Nabors 3S -12/8/2008 ESP Change -out by Doyon 14 - 3/24/2013 ESP Change -out by ASR#1-11/2/2017 Revised By: TDF 12/13/2019 Milne Point ASR Rig 1 BOPE 2019 11" BOPE Updated 5/14/2018 VBR Pipe Rams lind ,es STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS M ` m rt ufi a„.p?2 SEP 13 �Hi9 1. Operations Abandon LJ Plug Perforations LJ Fracture StimulateLj Pull Tubing Li Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair WeII❑ Re-enter Susp Well ❑ Other: Install Patch Q 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Stratigraphic❑ Exploratory ❑ Service ❑ 189-028 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-21926-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025906 MILNE PT UNIT G-02 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / SCHRADER BLUFF OIL 11. Present Well Condition Summary: Total Depth measured 5,714 feet Plugs measured N/A feet true vertical 4,701 feet Junk measured N/A feet Effective Depth measured 5,614 feet Packer measured 4,669 & 5,110 feet true vertical 4,609 feet true vertical 3,770 & 4,143 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 13-3/8” 110' 110' N/A N/A Surface 2,856' 9-5/8" 2,856' 2,485' 6,870psi 4,760psi Production 5,694' 7" 5,964' 4,683' 8,160psi 7,020psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 2-7/8" 6.5 / L-80 / 8rd EUE 4,602' 3,720' Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5 / L-80 / 8rd EUE 5,110' 4,143' SC -1L Packers and SSSV (type, measured and true vertical depth) Model D Perm N/A See Above N/A 12. Stimulation or cement squeeze summary: NIA 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 1,140 0 Subsequent to operation: 35 37 58 240 195 14. Attachments (required per 20 AAC 25.070, 25.071, &25.283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory[] Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas LJ WDSPLLJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 319-251 Authorized Name: Chad Helgeson Contact Name: David Haakinson ( LL 1n Authorized Title: Operations Manager Contact Email: dhaakinSon.hllcorp.cf (7a i/>%Opp'eerraa/t Authorized Signature: Date: 9/13/2019 Contact Phone: 777-8343 Form 10-404 Revised 4/2017 3BDMS1'5-JSEP 16 2019 Submit Original Only .R H#corn Alaska, LLC KB Elev.: 59.3' AMSIJGL Sint.: 28.6' AMSL E 3 to 7.110. '@Fbks@1,OG5' 5 W BGt,n aI j , &1,. SIM 95/8" J: I h r Ce,dllB heal trace Esdmated TOC b3,41T @ 3,5 A 00 2 MIN ILk 2.205" @4,506 1, 3 4 5 6 7&8 9 39" SS Capab g Sdrad N� M. 14 ? 1s 116 J• 17& 18 TD=5,714' (MD)/TD=4,701'(1VD) PBTD =5,614' (MD) / PBTD=4,609'(TVD) Milne Point Unit Well: MPU G-02 SCHEMATIC Last Completed: 11/2/2017 PTD: 189-028 TREE & WELLHEAD Tree SM FMC 2 -9/16 - Wellhead SS" SM FMC w/ 2-7/8" WKM Tbg. Hngr., 2-7/8" lower, 2-1/2" CIW H BPV profile OPEN HOLE / CEMENT DETAIL 13-3/8" 60 bbls of Arcticset to surface in 30" Hole 9-5/8" 171 bbls of 12.3ppg PF "E"/ 123 bbls of 15.8 ppg Prem. "G" in a 12-1/4" Hole 7" 65 bbls of 15.6 ppg Prem. "G" in 8-1/2" Hole CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/Btrs 12.715 Surface 110' 0.157 9-5/8" Surface 47/L-80/Btrs 8.681 Surface 2,856' 0.0732 7" Production 29/L-80/Bins 6.184 Surface 5,694' 0.0372 TUBING DETAIL 2-7/8" 1 Tubing 6.5/L-80/Srd EUE 2.441 1 Surface 4,602" 0.00579 2-7/8" Tubing 6.5 / L-80 /Srd EUE 2.441 4,669' 5,110' 0.00579 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle = 48 deg. Max Hole Angle through perforations = 27 deg. JEWELRY DETAIL No Depth Item 1 134 GLM STA #2: CAMCO 2-7/8" x 1" Side pocket w/ Dmy 1/6/19 2 4,456' GLM STA #1: CAMCO 2-7/8" x 1" Side pocket w/ Dor1/6/19 3 4,506' XN Nipple W/ 2.205" No- Go ID 4 4,548.63' Discharge Head: FPDIS 5 4,549.15' Pump: FLEXER/H6 SXD 6 4,573' Gas Separator: GRS FER N AR 7 4,576' Upper Tandem Seal: GSB3DBUT SB/SB PFSA 8 4,583' Lower Tandem Seal: GSB3DBUT SB/SB PFSA 9 4,594 Motor: CLS / XP - 100HP, 1,820V, 34A 10 4,598' Sensor: Well Lift Type E w/Centralizer - Bottom @4,602' 11 4,669' Baker SC -SL Packer 7082-40-4.0" ID 12 4,678' Sliding Sleeve - 4.0" ID 13 4,704' 2-7/8" Shear out Safety Joint w/44K Shear -2,43"ID 14 5,001' Bakerweid 2-7/8" 0.012" Ga.Screen 96' w/ 2.44" ID 15 5,09T O -Ring Seal Sub 16 5,098' Bakerweld 2-7/8" 0.012" Ga. Tell Tale Screen -11' w. 2.44" ID 175,109' Baker 5-22 Snap Latch Seal Assembly 18 5,110' Baker Model D Permanent Packer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NA 5,022' 5,046' 4,064' 4,086' 24 See Below Open NB 5,056' 5,076' 4,095' 4,113' 20 See Below Open NB/NC 5,085' 5,094' 4,121' 4,129' 9 See Below Open Perforation Charge Detail: 4-5/8" Vann Gun Assembly -24SPF Executed on 3/30/1990 & 4/7/1990 W ELL STIM U LATION Gravel Pack: 5,022'to 5,094' GENERAL WELL INFO API: 50-029-21926-00-00 Drilled and Cased by Parker 141- 8/29/1989 Perforate, Gravel Pack & Test by Pool #102 -5/10/1990 Completed with ESP by EWS Rig #4 -11/20/1990 ESP Change -out by Nabors 4ES - 2/15/1999 ESP Change -out by Nabors 3S -12/8/2008 ESP Change -out by Doyon 14 - 3/24/2013 ESP Chan e,out by ASR#1 - 11/2/2017 Revised By: TDF 8/21/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-02 Slickline 50-029-21926-00-00 189-028 5/21/2019 7/18/2019 Daily Operations. 5/15/2019- Wednesday No activity to report. 5/16/2019 - Thursday No activity to report. 5/17/2019 - Friday No activity to report. 5/18/2019 -Saturday No activity to report. 5/19/2019 -Sunday No activity to report. 5/20/2019 - Monday **WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 200L/2500H**. SET CAT SV IN XN-NIP AT 4487' SLM/4506' MD RUN 1-1/4" BM (rope leak detect) WITH LRS PUMPING DIESEL 1bpm AND 1.5bpm FROM 1200' SLM UP (find 2 holes at 1101' SLM and 1065' SLM). PULL CAT SV FROM XN-NIP AT 4487' SLM/4506' MD. SET 2-7/8" SLIP STOP TBG STOP (EXTERNAL F/N) @ 1110' SLM. SET 2-7/8" PACKOFF (25") @ 1106' SLM. **JOB COMPLETE, NOTIFY PAD -OP & LEAVE WELL 5/1 UPON DEPARTURE**. 5/21/2019 -Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-02 Slickline 50-029-21926-00-00 189-028 5/21/2019 1 7/18/2019 Daily Operations. 7/17/2019- Wednesday No operations to report. 7/18/2019 -Thursday WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 200L/2500H. FOUND 2 HOLES @ 1101' SLM AND 1065' SLM ON 5/21/19. SEE LOG FOR SPECS ON EACH SECTION OF PATCH, 3 TOTAL. SET 22' 2-7/8" BTM STRADDLE PATCH @ 1088' SUM, SLIP STOP AND LOWER PACKOFF SET ON 5/21/19 @ 1106' SLM. SET 22'2-7/8" MIDDLE STRADDLE PATCH @ 1067'. SET 17' UPPER STRADDLE PATCH @ 1048', 2-7/8" PACKOFF THREADED ON TOP. ATTEMPT TO TEST TBG ABOVE UPPER PACK OFF W/ 2- 7/8" D&D HOLE FINDER, PUMP 13bbls OF DIESEL, APPEAR TO HAVE COLUMN OF FLUID TO SURFACE, BUT COULD NOT BUILD PRESSURE. SET 2-7/8" D&D SLIP STOP (EXTERNAL F/N) @ 1047' SUM. MIN ID in well is now 1.10" (ID of 1.66" pipe within straddle packer) from 1,106' to 1,048'. AS OF 1/6/19 STA#f2 @ 134' MD STILL HAS 1" DGLV INSTALLED. 7/19/2019 - Friday No operations to report. 7/20/2019 -Saturday No operations to report. 7/21/2019 -Sunday No operations to report. 7/22/2019 - Monday No operations to report. 7/23/2019 -Tuesday No operations to report. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS a 1. Operations Abandon LJ Plug Perforations Ll Fracture StimulateLi Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Brforate New Pool ❑ Repair Wel[] Re-enter Susp Well ❑ Other: Install Patch ❑✓ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska LLC Development Q Stratigraphic❑ Exploratory ❑ Service ❑ 189-028 3. Address: 3800 Centerpoint Or, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-21926-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025906 MILNE PT UNIT G-02 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT/ SCHRADER BLUFF OIL 11. Present Well Condition Summary: Total Depth measured 5,714 feet Plugs measured N/A feet true vertical 4,701 feet Junk measured N/A feet Effective Depth measured 5,614 feet Packer measured 4,669 & 5,110 feet true vertical 4,609 feet true vertical 3,770 & 4,143 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 13-3/8" 110' 110' N/A N/A Surface 2,856' 9-5/8" 2,856' 2,485' 6,870psi 4,760psi Production 5,694' 7" 5,964' 4,683' 8,160psi 7,020psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 2-7/8" 6.5 / L-80 / 8rd EUE 4,602' 3,720' Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5 / L-80 / 8rd EUE 5,110' 4,143' SCA L Packers and SSSV (type, measured and true vertical depth) Model D Perm 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: 1 0 0 0 1,140 0 Subsequent to operation: 10 0 0 260 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.293) 15. Well Class after work: Daily Report of Well Operations 2 Exploratory[] Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ✓ Gas LJ WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-251 Authorized Name: Chad Helgeson Contact Name: David Haakinson- Authorized Title: Manager Contact Email: dhaaklnSon(G h ICorO.coi �Operations Authorized Signature: (/�Y Date: 8/21/2019 Contact Phone: 777-8343 ijoi �/liBDMS AUG 2 3 20t9Form 10-404 Revised 4/2017 �(`6[ � Submit Original C H Hileom Alaska, LLC KB Bev.: 59.3' GL Bev.: 28.6JVvtSL 6: 22 g4' T F ` 1,110' 9-5/8" Cer#lift hem trace WAV � MIN I[�22: P45f a8 S5 f-rpsmN 1 2 3 Hiles@1p65' &1,101' SIM 5/1D/NB9 EsumatedTOC 4 5 6 7&8 9 .' 12 3 Schrader -IN", 14 Sam 15 ." .i6 17&18 7" Ir TD=5,714'(MD)/To 4,701'(TVD) PBTD=5,614' (MD)/PBTD=4,609'(7VD) SCHEMATIC Milne Point Unit Well: MPU G-02 Last Completed: 11/2/2017 PTD: 189-028 TREE & WELLHEAD Tree 5M FMC 2-9/16" Wellhead 11" SM FMC w/ 2-7/8" W KM Tbg. Hngr., w/ 2-7/8" 8 rd top, Top 2-7/8" (ower, 2-1/2" CIW H BPV profile CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/Btrs 12.715 Surface 110' 0.157 9-5/8" Surface 47 / L-80 / airs 8.681 surface 2,856' 0.0732 7" Production 29/L-80/Bins 6.184 Surface 5,694' 0.0372 TUBING DETAIL J 2-7/8" Tubing 6.5/L-80/Srd EUE 2.441 Surface 4,602" 0.00579 2-7/8" Tubing 6.5/L-80/8rd EUE li 2.441 4,669' 5,110' 1 0.00579 WELL INCLINATION DETAIL KOP � 500' Maz Hole Angle = 48 deg. Max Hole Angle through perforations - 27 deg. JEWELRY DETAIL No Depth Item 1 134 GLM STA #2: CAMCO 2-7/8" x 1" Side pocket w/ Dmy 1/6/19 2 4,456' GLM STA #1: CAMCO 2-7/8" x 1" Side pocket w/ Dmy 1/6/19 3 4,506' XN Nipple W/ 2.205" No- Go ID 4 4,548.63' Discharge Head: FPDIS 5 4,549.15' Pump: FLEXER / H6 SXD 6 4,573' Gas Separator: GRS FER N AR 7 4,576' Upper Tandem Seal:G583DBUTSB/SB PFSA 8 4,583' Lower Tandem Seal:G583DBUTSB/SBPFSA 9 4,590' Motor: CL5 / XP-1DOHP, 1,820V, 34A 10 4,598' Sensor: Weltift Type E w/ Centralizer - Bottom @ 4,602' 11 4,669' Baker SC -1L Packer 7082-40-40ID 12 4,678' Sliding Sleeve - 4.0" ID 13 4,704' 2-7/8" Shear out Safety Joint w/44K Shear - 2.43" ID 14 5,001' Bakerweld 2-7/8" 0.012" Ga.Screen 96' w/ 2.44" ID 15 5,097' O -Ring Seal Sub 16 5,098' Bakerweld 2-7/8"0.012" Ga. Tell Tale Screen -11'w. 2.44" ID 17 5,109' Baker S-22 Snap Latch Seal Assembly 18 5,110' Baker Model D Permanent Packer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NA 5,022' 1 5,046' 4,064' 4,086' 24 See Below Open NB 5,056' 5,076' 4,095' 4,113' 20 See Below Open NB/NC 5,085' 5,094' 4,121' 4,129' 9 See Below Open Perforation Charge Detail: 4-5/8" Vann Gun Assembly -245PF Executed on 3/30/1990 & 4/7/1990 WELL STIMULATION Gravel Pack: 5,022'to 5,094' GENERALWELL INFO API: 50-029-21926-00-00 Drilled and Cased by Parker 141- 8/29/1989 Perforate, Gravel Pack & Test by Pool #102 -5/10/1990 Completed with ESP by EWS Rig #4 -11/20/1990 ESP Change -out by Nabors 4ES - 2/15/1999 ESP Change -out by Nabors 35 -12/8/2008 ESP Change -out by Doyon 14 - 3/24/2013 ESP Change -out by ASR#1 - 11/2/2017 Revised By: TDF 8/21/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-02 Slickline 50-029-21926-00-00 189-028 5/21/2019 7/18/2019 Daily Operations. 5/15/2019 - Wednesday No activity to report. 5/16/2019 - Thursday No activity to report. 5/17/2019 - Friday No activity to report. 5/18/2019 -Saturday No activity to report. 5/19/2019 -Sunday No activity to report. 5/20/2019 - Monday **WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 200L/2500H**. SET CAT SV IN XN-NIP AT 4487' SLM/4506' MD RUN 1-1/4" BM (rope leak detect) WITH LRS PUMPING DIESEL 1bpm AND 1.5bpm FROM 1200'SUM UP (find 2 holes at 1101' SLM and 1065' SLM). PULL CAT SV FROM XN-NIP AT 4487' SLM/4506' MD. SET 2-7/8" SLIP STOP TBG STOP (EXTERNAL F/N) @ 1110' SLM. SET 2-7/8" PACKOFF (25") @ 1106' SUM. **JOB COMPLETE, NOTIFY PAD -OP & LEAVE WELL S/I UPON DEPARTURE**. 5/21/2019 -Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPG -02 Slickline 50-029-21926-00-00 189-028 5/21/2019 7/18/2019 Daily Operations. 7/17/2019- Wednesday No operations to report. 7/18/2019 - Thursday WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 20DL/2500H. FOUND 2 HOLES @ 1101' SLM AND 1065' SUM ON 5/21/19. SEE LOG FOR SPECS ON EACH SECTION OF PATCH, 3 TOTAL. SET 22' 2-7/8" BTM STRADDLE PATCH @ 1088' SLM, SLIP STOP AND LOWER PACKOFF SET ON 5/21/19 @ 1106' SLM. SET 22' 2-7/8" MIDDLE STRADDLE PATCH @ 1067'. SET 17' UPPER STRADDLE PATCH @ 1048', 2-7/8" PACKOFF THREADED ON TOP. ATTEMPT TO TEST TBG ABOVE UPPER PACK OFF W/ 2-7/8" D&D HOLE FINDER. PUMP 13bbls OF DIESEL, APPEAR TO HAVE COLUMN OF FLUID TO SURFACE, BUT NEVER BUILD PRESSURE, SEE LOG. SET 2-7/8" D&D SLIP STOP (EXTERNAL F/N) @ 1047' SLM. MIN ID in well is now 1.10" (ID of 1.66" pipe within straddle packer) from 1,106' to 1,048'. 7/19/2019 - Friday No operations to report. 7/20/2019 -Saturday No operations to report. 7/21/2019 -Sunday No operations to report. 7/22/2019 - Monday No operations to report. 7/23/2019 -Tuesday No operations to report. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU G-02 Permit to Drill Number: 189-028 Sundry Number: 319-251 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. aogcc.olaska.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, Daniel T. Seamount, Jr. Commissioner DATED this / day of May, 2019. 313DMS''� MAY 2 0 2019 STATE OF ALASKA MAY 15 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A®GCC 20 AAC 25.280 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: Install Patch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ . Straligraphic ❑ Service ❑ 189-028 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-21926-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 L-A Will planned perforations require a spacing exception? Yes ❑ No Q MILNE PT UNIT G-02 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025906 MILNE POINT/ SCHRADER BLUFF 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): 5,714' 4,701' • 5,614' 4,609' 986 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 110' 13-3/8" 110' 110' N/A N/A Surface 2,856' 9-5/8" 2,856' 2,485' 6,870pSi 4,760psi Production 5,694' 7" 5,694' 4,683' 8,160psi 7,020psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 2-7/8'. 6.5 / L-80 / 8rd EUE 4,602 See Schematic See Schematic 2-7/8" 6.51 L-80 / 8rd EUE 5,110 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): SC -1 L & Model D Perm/ and WA 4,669' MD/ 3,770' TVD & 5,110' MD/ 4,143' TVD and N/A 12. Attachments: Proposal Summary Lj Wellbore schematic L:�J 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑A Service ❑ 14. Estimated Date for 15. Well Status after proposed work: CommencingOperations: 5/29/2019 P OIL 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. e� Authorized Name: Chad Helgeson Contact Name: David Haakinson ` Authorized Title: Operations Manager Contact Email: dhaakinson hit or .COm Contact Phone: 777-8343 Authorized Signature: Date: 511,57-Afz COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3N -261 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3BDMSL�MAY 2 0 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑� Spacing Exception Required? Yes F-1NoL� Subsequent Form Required: I (3— y O ty / APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: v r �51r�rtvo\ 17 -,?ORIGINAL Submit Form and Form -403 Revised 412017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate n filen, M.A.. LG Tubing Patch Well: MPU G-02 Date: 05-09-19 Well Name: MPU G-02 API Number: 50-029-21926-00 Current Status: Shut In- ESP Producer Pad: G -Pad Estimated Start Date: May 29th, 2019 Rig: SL Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 189-028 First Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) Second Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) AFE Number: P.O. Job Type: Tubing Patch Current Bottom Hole Pressure: 1392 psi @ 4,064' TVD ESP Gauge (5/9/19) 16.59 PPG Maximum Expected BHP: 1392 psi @ 4,064' TVD Stable SBHP 16.59 PPG MPSP: 986 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 48° @ 2,800' MD Max Dogleg: 4.6°/100ft @ 4,700' MD Brief Well Summary: MPU G-02 was drilled and completed as a vertical N sand producer in August 1989. The well has had numerous ESP changeout RWO's completed in its past with the last RWO completed in November 2017 and completed with 2-7/8" tubing. The well has been a stable 70-100 BOPD producer, but in December 2018, the well stopped surfacing fluids. All indications lead to believe that the ESP and motor are in good condition for restart. It is anticipated that the well can be restored to production with a tubing patch installation. Notes Regarding Wellbore Condition • Well was SI on 12/18/19 due to increasing FBHP and increase in downhole motor load. • Tubing leak identified at 1,060' SLM on 1/6/19 with rope and D&D hole -finder • Dummy Valves replaced in GLM #1 and GLM #2 on 1/5/19 Objective: • Set D&D tubing patch (Sundry Approval Required) • Backup Contingency: o Memory Caliper o Memory Spinner Log o E -line Paragon packer patch Procedure Slickline 1. MIRU SL. PT lubricator to 200 psig low, 2500 psig high. 2. Set CAT -SV in XN Nipple @ 4,506' MD 3. Set Junk Catcher on top of CAT -SV. a. Prevent tubing solids/scale from landing on top of CAT -SV 4. RU LRS for pump support 5. RIH w/ rope leak detect to leak interval and locate leak depth. Flag wire and POOH. 6. Brush and Flush tubing at patch setting interval (+/- 20' up/down from leak point). H Hil.m Alaeku, LG 7. Pull junk catcher from depth @ 4,506' MD. 8. Pull CAT -SV from XN Nipple @ 4,506' MD 9. RIH with tubing slip -stop and set +/-10' below leak depth (flagged wire). 10. Set D&D pack -off on slip -stop. 11. RIH with stinger, +/- 20' spacer pipe, and upper D&D pack -off. 12. Land in lower D&D pack -off seal assembly and set upper D&D pack -off. 13. RIH with D&D test tool and land in upper packer. Tubing Patch Well: MPU G-02 Date: 05-09-19 14. PT tubing to 1500 psig to confirm upper packer and up -hole tubing integrity. 15. After passing test, RIH w/ 2.875" tubing stop and set on top of upper D&D pack -off. 16. RDMO Slick -line and LRS. Leave well SL Contingency Tubing Patch Set (If D&D patch is unsuccessful) Slickline 1. MIRU SL. PT lubricator to 200 psig low, 2500 psig high. 2. Pull D&D tubing patch. 3. RIH with 24 -arm memory caliper to ESP discharge head @ 4,548' MD 4. POOH @ 50 fpm to surface for caliper survey. 5. Confirm good caliper data. 6. Set CAT SV in 2.205" XN Nipple @ 4,506' MD 7. RU LRS 8. RIH with memory full -bore spinner, pressure, temperature, and GR/CCL. a. Come online with pump rate at 0.5 to 0.7 BPM (previous leak rate). b. Please utilize source -water for the leak detect. c. GR/CCL will be utilized for future depth correlation if E -line is used. d. Perform down -pass at 60 fpm to 4,480' MD 9. Perform 60 fpm up -pass from 4,480' MD to surface. 10. Pull CAT -SV from XN Nipple @ 4,506' MD. E -line 1. MIRU EL. PT lubricator to 200 psig low, 2500 psig high. 2. RIH with GR/CCL and 2.875" paragon packer and set packer mid -element @ +/- 1,075' MD a. Correlate to SL Memory Spinner/GR/CCL. b. Note that final depth will be determined post spinner log completion. Slickline 3. MIRU SL. PT lubricator to 200 psig low, 2500 psig high. 4. RIH with latch seal assembly, +/- 20' of 1.9" spacer pipe, and top 2.875" paragon packer. H Ililcorn Ahn.ka. LU 5. Land in lower paragon packer and set top packer mid -element @ +/- 1,050' MD 6. RIH with 2.875" paragon packer test tool and land in upper packer. 7. PT tubing to 1500 psig to confirm upper packer and up -hole tubing integrity. 8. RDMO Slick -line Attachments: 1) Current Schematic 2) Proposed Schematic Tubing Patch Well: MPU G-02 Date: 05-09-19 K HJlewu Alaska, LLC KB Elev.: 59.3' ANWGL Elev.: 28,6 AMSL Doyo 16: 22 74' RKB to THF A ` 13-3/8' 1 i. Hole @ SII, 06C) 201199 9-5/9' Denlilift heat trace to3,41T � 2 MN 12 2205" @4,506' - 3 30' SS Capstring Sdyadw "N' Sands Estinatd TOC 0-3.500' I� 4 5 6 7&8 9 SCHEMATIC Milne Point Unit Well: MPU G-02 Last Completed: 11/2/2017 PTD: 189-028 TREE & WELLHEAD Tree SM FMC 2-9/16" Wellhead I3" SM FMC w/ 2-7/8" WKM Tbg. Hngr., w/ 2-7/8" 8 rd top, Top 2-7/8" lower, 2-1/2" CIW H BPV profile OPEN HOLE / CEMENT DETAIL CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor48/H-40/Btrs 3 12.715 Surface 110' 0.157 9-5/8" Surface 47/L-80/Strs 8.681 Surface 2,856' 0.0732 7" Production 29/L-80/Strs 6.184 Surface 5,694' 0.0372 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface 4,602" 0.00579 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 4,669' 1 5,110' 0.00579 WELL INCLINATION DETAIL - KOP 050L Max Hole Angle = 48 deg. Max Hole Angle through perforations = 27 deg. JEWELRY DETAIL No Depth Item 1 134 GLM STA #2: CAMCO 2-7/8" x 1" Side pocket w/ Dmy 1/6/19 2 4,456' GLM STA #1: CAMCD 2-7/8" x 1" Side pocket w/ Dmy 1/6/19 3 4,506' XN Nipple W/ 2.205" No- Go ID 4 4,548.63' Discharge Head: FPDIS 5 4,549.15' Pump: FLEXER/HIS SXD 6 4,573' Gas Separator: GRS FER N AR 7 4,576' Upper Tandem Seal: GSB3DBUT SB/SB PFSA 8 4,583' Lower Tandem Seal: GSB313BUT SB/SB PFSA 9 4,590' Motor: CLS/XP- 100HP, 1,820V, 34A 10 4,598' Sensor: WellLiftType Ew/Centralizer-Bottom@4,602' 11 4,669' Baker SC -1L Packer 7013240-4,0"ID 12 4,678' Sliding Sleeve - 4.0" ID 13 4,704' 2-7/8" Shear out Safety Joint w/44K Shear -2,43'ID 14 5,001' Bakerweld 2-7/8" 0.012" Ga.Screen 96' w/ 2.44" ID 35 5,097' O -Ring Seal Sub 16 5,098' Bakerweld 2-7/8" 0.012" Ga. Tell Tale Screen -11' w. 2.44" ID 17 5,109' Baker S-22 Snap Latch Seal Assembly 18 5,110' Baker Model D Permanent Packer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NA 5,022' 5,046' 4,064' 4,086' 24 See Below Open NB 5,056' 5,076' 4,095' 4,113' 20 See Below Open NB/NC 5,085' 5,094' 4,121' 4,129' 9 See Below Open Perforation Charge Detail: 4-5/8" Vann Gun Assembly-24SPF Executed on 3/30/1990 & 4/7/1990 I1 WELL STIMULATION 12 Gravel Pack: 5,022'to 5,094' 13 14 GENERAL WELL INFO 16 17&18 7"ij .. :: IP TD= 5,714' (MD) /TD = 4,701'(TVD) PBTD= 5,614' (MD) / PBTD= 4,609'(1VD) API: 50-029-21926-00-00 Drilled and Cased by Parker 141- 8/29/1989 Perforate, Gravel Pack & Test by Pool #102 -5/10/1990 Completed with ESP by EWS Rig #4 -11/20/1990 ESP Change -out by Nabors 4ES - 2/15/1999 ESP Change -out by Nabors 3S -12/8/2008 ESP Change -out by Doyon 14 - 3/24/2013 ESP Change -out by ASR#1-11/2/2017 Revised By: TDF 5/8/2019 K Hilcorp Alaaka, LLC KB Elev.: 59.3' AMSL/GL Elev.: 28,6 AMSL Dn 16: 22174' RIB to THF 1 t 1 I 133/8" Z 1 Poposed Tubirg 31,050 to ±1.0701 35/8" Cedilla het #ace to3,41T 11 B6rretedTOC f@±3,504 2 MIN 122.205" ' @4,506' f' 3 t 4 5 6 7&8 9 38'SS Capstrkg 10 :$ 012 .13 Sands "N'� iY ; 14 Sands R<r x' K15 a 16 17&18 � t 7" TO=5,714' (MD)/TD=4,701'(TVD) PBTD = 5,614' (MD) / P91 D= 4,60YM) Milne Point Unit Well: MPU G-02 PROPOSED Last Completed: 11/2/2017 PTD: 189-028 TREE & WELLHEAD Tree I 5M FMC 2-9/16" Wellhead 11" 5M FMC w/ 2-7/8" WKM Tbg. Hngr., w/ 2-7/8" 8 top, Top I 2-7/8" lower, 2-1/2" CIW H BPV profile OPEN HOLE / CEMENT DETAIL CASING DETAIL Size Type Wt/Grade/Conn ID Top I Btm BPF 13-3/8" Conductor 48/H-40/Btrs 12.715 Surface 110' 0.157 9-5/8" Surface 47/L-80/Btrs 8.681 Surface 2,856' 0.0732 7" Production 29/L-80/Btrs 6.184 Surface 5,694' 0.0372 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 1 Surface 4,602" 0.00579 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 1 4,669' 5,110' 1 0.00579 WELL INCLINATION DETAIL KOP 0_5 00' Max Hole Angle = 48 deg. Max Hole Angle through perforations = 27 deg. JEWELRY DETAIL No Depth Item 1 134 GLM STA #2: CAMCO 2-7/8" x 1" Side pocket w/ Dmy 1/6/19 2 1,050' 1.25" ID Tubing Patch +/- 20' Length 3 4,456' GLM STA #1: CAMCO 2-7/8" x 1" Side pocket w/ Dmy 1/6/19 4 4,506' XN Nipple W/ 2.205" No- Go ID 5 4,548.63' Discharge Head: FPDIS 6 4,549.15' Pump: FLEXER / H6 SXD 7 4,573' Gas Separator: GRS FER N AR 8 4,576' Upper Tandem Seal: GSB3DBUT SB/SB PFSA 9 4,583' Lower Tandem Seal: GSB3DBUTSB/SB PFSA 10 4,590' Motor: CL5 / XP - 300HP, 1,820V, 34A 11 4,598' Sensor: WeliL'rR Type E w/Centralizer - Bottom @4,602' 12 4,669' Baker SC -1L Packer 70B2-40-4,0"ID 13 4,678' Sliding Sleeve - 4.0" ID 14 4,704' 2-7/8" Shear out Safety Joint w/ 44K Shear - 2.43" ID 15 5,001' Bakerweld 2-7/8" 0.012" Ga.Screen 96'w/ 2.44" ID 16 5,097' O -Ring Seal Sub 17 5,098' Bakerweld 2-7/8" 0.012" Ga. Tell Tale Screen -11' w. 2.44" ID 18 5,109' Baker S-225nap Latch Seal Assembly 19 5,110' Baker Model D Permanent Packer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NA 5,022' 5,046' 4,064' 4,086' 24 See Below Open NB 5,056' 5,076' 4,095' 4,113' 20 See Below Open NB/NC 1 5,085' 5,094' 4,121' 4,129' 9 See Below Open Perforation Charge Detail: 4-5/8" Vann Gun Assembly- 24SPF Executed on 3/30/1990 & 4/7/1990 WELL STIMULATION Gravel Pack: 5,022' to 5,094' GENERAL WELL INFO API: 50-029-21926-00-00 Drilled and Cased by Parker 141 - 8/29/1989 Perforate, Gravel Pack & Test by Pool #102-5/10/1990 Completed with ESP by EWS Rig #4 -11/20/1990 ESP Change -out by Nabors 4ES - 2/15/1999 ESP Change -out by Nabors 3S -12/8/2008 ESP Change -out by Doyon 14 - 3/24/2013 ESP Change -out by ASR#1-11/2/2017 Revised By: TDF 5/9/2019 STATE OF ALASKA • RECEIVED ALOKA OIL AND GAS CONSERVATION COMMISSION NOV 2 0 2017 REPORT OF SUNDRY WELL OPERATIONS AOGGC 1.Operations Abandon U Plug Perforations L] Fracture Stimulate LI Pull TubingLI LI Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate Q Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well Q Re-enter Susp Well❑ Other: ESP Change-out s 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC lorato❑ment Develo D Exploratory p ry❑ 189-028 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic Service ❑ 6.API Number: AK 99503 50-029-21926-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 MILNE PT UNIT G-02 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 5,714 feet Plugs measured N/A feet true vertical 4,701 feet Junk measured N/A feet Effective Depth measured 5,614 feet Packer measured 4,669&5,110 feet true vertical 4,609 feet true vertical 3,770&4,143 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 13-3/8" 110' 110' N/A N/A Surface 2,856' 9-5/8" 2,856' 2,485' 6,870psi 4,760psi Production 5,694' 7" 5,964' 4,683' 8,160psi 7,020psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 2-7/8" 6.5/L-80/8rd EUE 4,602' 3,720' Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5/L-80/8rd EUE 5,110' 4,143' SC-1L Packers and SSSV(type,measured and true vertical depth) Model D Perm 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 SCANNED ,,JAN 0 ?n?e 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 160 0 Subsequent to operation: 30 41 316 100 203 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑� Exploratory❑ Developments Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil s Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-430 Authorized Name: Bo York Contact Name: Stan Porhola5TP Authorized Title: Operations Manager Contact Email: Sporhola@hilcorp.com Authorized Signature: / Dat 11/20/2017 Contact Phone: 777-8412 i ii—ri 7 . ' ��y�> REDS i'o' 2 a 26'17 Form 10-404 Revised 4/2017 Submit Original Only • • Milne Point Unit Ei Well: MPU G-02 SCHEMATIC Last Completed: 11/2/2017 Hilcorp Alaska,LLC PTD: 189-028 KB Elev.:59.3'AMSL/GL Elev.:28.6'AMSL TREE&WELLHEAD Do on 16: 22.74'RKBtoTHF Tree 5M FMC 2-9/16" Wellhead 11"5M FMC w/2-7/8"WKM Tbg.Hngr.,w/2-7/8"8 rd top, 2-7/8"lower,2-1/2"CIW H BPV profile 13-3/8 OPEN HOLE/CEMENT DETAIL 3' I r 1 13-3/8" 60 bbls of Arcticset to surface in 30"Hole 9-5/8" 171 bbls of 12.3ppg PF"E"/123 bbls of 15.8 ppg Prem."G"in a 12-1/4"Hole Ek0. 7" 65 bbls of 15.6 ppg Prem."G"in 8-1/2"Hole o itl V at: CASING DETAIL tt Size Type Wt/Grade/Conn ID Top Btm BPF ✓� 13-3/8" Conductor 48/H-40/Btrs 12.715 Surface 110' 0.157 9-5/8" Surface 47/L-80/Btrs 8.681 Surface 2,856' 0.0732 f� t7" Production 29/L-80/Btrs 6.184 Surface 5,694' 0.0372 rorii TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface 4,602" 0.00579 ` ",•` 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 4,669' 5,110' 0.00579 +)y WELL INCLINATION DETAIL a KOP@500' Max Hole Angle=48 deg. Max Hole Angle through perforations=27 deg. I. k Ei;lit ` i+ , JEWELRY DETAIL 9-5/8"` 1 i [ .1.,;,t. .0 No Depth Item Centilift heat trace 1 134 GLM STA#2:CAMCO 2-7/8"x 1"Side pocket w/DOSV to3,41T Estimated TOC 2 4,456' GLM STA#1:CAMCO 2-7/8"x 1"Side pocket w/Dummy A---- @±3,500' 3 4,506' XN Nipple W/2.205"No-Go ID ., i `d 4 4,548.63' Discharge Head:FPDIS 5 4,549.15' Pump:FLEXER/H6 SXD 6 4,573' Gas Separator:GRS FER N AR 7 4,576' Upper Tandem Seal:GSB3DBUT SB/SB PFSA 2 8764 4,583' Lower Tandem Seal:GSB3DBUT SB/SB PFSA !4s 9 4,590' Motor:CL5/XP-100HP,1,820V,34A MIN I�1.790 10 4,598' Sensor:WeIlLift Type E w/Centralizer-Bottom @ 4,602' @4,510' v E : 3 11 4,669' Baker SC-1L Packer 7082-40-4.0"ID f ., 12 4,678' Sliding Sleeve-4,0"ID 13 4,7042-7/8"Shear out Safety Joint w/44K Shear-2.43"ID Ct 4 14 5,001'' Bakerweld 2-7/8"0.012"Ga.Screen 96'w/2.44"ID ti 1 i•5 11643 5 5,097' 0-Ring Seal Sub 16 5,098' Bakerweld 2-7/8"0.012"Ga.Tell Tale Screen-11'w.2.44"ID III 6 17 5,109' Baker 5-22 Snap Latch Seal Assembly x 18 5,110' Baker Model D Permanent Packer 7&8 PERFORATION DETAIL t Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status NA 5,022' 5,046' 4,064' 4,086' 24 See Below Open a' SSCapstnng 4 NB 5,056' 5,076' 4,095' 4,113' 20 See Below Open - 10 ? NB/NC 5,085' 5,094' 4,121' 4,129' 9 See Below Open f Perforation Charge Detail:4-5/8"Vann Gun Assembly-245PF Executed on 3/30/1990&4/7/1990 t 1).7_,,41.1 WELL STIMULATION ` #13 Schrader"N { Gravel Pack:5,022'to 5,094' Sands .14 s t 1i.15 GENERAL WELL INFO ;•; 16 API:50-029-21926-00-00 * .. '{ 17&18 Drilled and Cased by Parker 141-8/29/1989 * Perforate,Gravel Pack&Test by Pool#102-5/10/1990 Completed with ESP by EWS Rig#4 -11/20/1990 ESP Change-out by Nabors 4ES-2/15/1999 TD=5,714'(MD)/TD=4,701'(TVD) ESP Change-out by Nabors 3S-12/8/2008 PBTD=5,614'(MD)/PBTD=4,609'(TVD) ESP Change-out by Doyon 14-3/24/2013 ESP Change-out by ASR#1-11/2/2017 Revised By:TDF 11/7/2017 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-02 ASR#1 50-029-21926-00-00 189-028 10/29/2017 11/2/2017 Daily Operations: gib` 10/25/2017-Wednesday No activity to report. 10/26/2017-Thursday No activity to report. 10/27/2017- Friday No activity to report. 10/28/2017-Saturday No activity to report. 10/29/2017-Sunday R/U Certek unit and begin warming lines. Wrap fluid lines w/glycol lines and enclose w/tarps. Load 45bbls of fresh water in pit 1 for testing BOPE. R/U flow line on Hydrill Annular and riser spool w/bird bath. Function test new BOPE several times to ensure functionality. Grease and function choke and kill manifold. Well support on location to grease mud cross. Wellhead rep pull BPV set TWC. Fill BOPE w/fresh water.Test BOPE as per Sundry w/2-3/8" and 3-1/2" test joints to 250psi low and 2,500psi high f/5 charted mins each.Test annular w/2-3/8"test joint to 250psi low and 2,500psi high f/5 charted mins.AOGCC rep Chuck Sheave on location to witness testing. SIMOPS: continue to R/U winterization around rig, spot pipe racks into place,take on 1% KCL from upright tank into pits. R/U to pull ESP completion. Pull TWC. Hang dual cable sheave from mast, R/U hose to catch fluid drip from cable sheave as well as hose to contain ESP cable and heat trace back to spooler. Blow down choke and kill lines from BOPE testing. Mix half a drum of Baraklean w/62bbls of brine and bullhead down the IA to clean the string prior to POOH w/ ESP completion. M/U landing joint and x-over in prep to POOH w TBG HGR. Pull hanger t/floor(hanger came free @ 30k, assembly moving @ 34k) 1/d landing jt& hanger, cont. r/u cable to sheaves, clamp& handling tools. Conduct well control meeting with floor crew to discuss procedure for shutting in the well with ESP cable and heat trace. Pre-form bare pipe shut in drill with crew, POOH w/2 3/8" completion,found holes on jt 25, cont. POOH 1/d 100 jts total at report time. 10/30/2017-Monday Continue to POOH w/ ESP completion on 2-3/8"4.7ppf TBG f/jnt 100 to x-over pup above ESP (4,600'md). Mild scale noted on the exterior of the last 5 joints and x-over pup above the ESP. (146 joints recovered, 2 GLM's, 1 XN nipple, no missing equipment),fill hole to verify fluid level prior to pulling completion into BOPE. 18bbls to catch returns to surface. L/D ESP completion. Mild scale seen throughout the completion. Continue to fill hole w/5bph while laying down BHA. R/D ESP pulling equipment, load and tally 120 joints of 3.5" NC-31 work string, M/U Baker Fishing 7" scraper w/mule shoe BHA, RIH w/ Baker Fishing 7" scraper BHA on 3.5" NC-31 work string f/ 11'md to 4,650'md (JNT 115) P/U/W=42klbs, 5/0/W= 31.5klbs. P/U joint 116 and work scraper across entire joint. P/U jnt 117 and set down 11' into joint w/4-5klbs. P/U 10' and go back down to tag again. Same tag depth 11' into jnt 117. P/U 1'to neutral weight for final tag depth of 4,660'md. L/D jnt 117 and R/U to reverse circulate. Reverse circulate 164bbls (3 x B/U) of 8.4ppg 1% KCL w/20% loss rate @ 4BPM w/ 700psi. R/D circulating lines& blow down, POOH 1/d 7" scraper assy. C/O handling Eq. p/u c/o assy-2" mill,xtreme mud motor, circ. valve, disconnect,jar, dual BPV, xo's, 13 jts 1.66 tubing,xo, pump out sub, xo=433.11', shallow test motor @ .5 BPM,400 psi, @ 1 BPM 825psi RIH, p/u 3 1/2" wk string. t/4,515', up wt 32k, do wt 24k Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-02 ASR#1 50-029-21926-00-00 189-028 10/29/2017 11/2/2017 Daily Operations _ 10/31/2017-Tuesday Continue to RIH to jnt 105 (4,635'md). R/U to circulate through power swivel. M/U power swivel to TBG stump and gain milling parameters, P/U=39klbs, S/O = 30klbs, circ pressure = 920psi w/1BPM. Wash down f/4,635'md to 5,088'md (10' into joint 117), circulating @ 1BPM= 920psi. Wash down very cautiously to ensure we don't stack out with slim pipe in the hole. Pressures vary between 910-940psi throughout each joint. Pump 65bbls while washing down, w/4bbls losses total. L/D jnt 117, R/U head pin for circulating, drop Baker Fishing pump out sub dart into work string, M/U head pin and pump dart onto seat. Pressure up to 2,500psi to shear pump out sub open. Pump 40bbls @ 4BPM =400psi, swap line up and reverse circulate @ 4BPM = 660psi f/ 100bbls (2.5x B/U). Returns coming back clean. Shut down pumps and prep to POOH. POOH w/ Baker Cleanout BHA f/4635'md on tapered 1.660" x 3.5" workstring utilizing double displacement. Hole maintaining 1-2bbl losses every 15 jnts. Conduct table top well control drill w/operator on shutting in w/1.660" pipe in the hole. Clean and clear rig floor. Prep for picking up Baker PKR.Top off hole w/7bbls 1% KCL Service rig, p/u Baker 7" Retrievamatic test packer,TIH t/4,651', up wt 42k, dn wt 30k, Kelly up, set packer w/12k dn on it, R/U test casing t/1,500psi for 30 min good Unseat packer, break circulation w/rig pump t/verify, good, R/u LRS p/t lines t/250/2,500 psi good, pump scale Inhibitor treatment as per pump schedule, ( 35 bbls pre-flush, 7.5%WAW5206, 42 BBLS 12.5%scw4004) chase w/140 bbls @ 3 bpm, 1100 psi (97bbls to formation 43 bbls. work string volume) R/D blow down lines, POOH t/ BHA • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-02 ASR#1 50-029-21926-00-00 189-028 10/29/2017 11/2/2017 Daily Operations. 11/1/2017-Wednesday Perform rig service. Continue to L/D Baker Completions CSG PKR as per Baker rep. P/U Baker Centrilift ESP completion as per Centrilift rep and service. Rig crews prep to RIH w/ ESP, spot spoolers into place, load and tally 2-7/8" EUE TBG. Continue to load and tally 2-7/8" EUE TBG. M/U cap tube to ESP centralizer, pull new MLE pothead over sheave, connect to ESP motor and proceed in hole. ;RIH w/ ESP completion and cap tube on 2-7/8" 6.5ppf EUE TBG f/surface to 1,185'md. Check ESP connectivity @ 500'md and every 1,000'md thereafter. Fill hole every 15 joints to verify fluid level. Lost Spooler generator,get spare off A-pad, wire to accommodate spooler trailer.Test run good. Cont. RIH w/ ESP completion and cap tube on 2-7/8" 6.5ppf EUE TBG f/1,185't/2,593' md. Check ESP connectivity every 1,000' and Fill hole every 15 joints to verify fluid level. Started running heat trace @ 1,215' on jt 36. 11/2/2017 -Thursday Continue to RIH w/ESP completion, heat trace cable, capillary string, on 2-7/8" EUE TBG f/jnt 80 to jnt 143 as per tally. P/U TBG hanger and M/U. Baker Centrilift R/U to perform splice on ESP cable and heat trace cable as well as penetrate hanger w/capillary tube. P/U =40klbs, S/O = 28klbs, 72bbls losses on tower. Splice on ESP cable t/penetrator lead install heat trace penetrator, install capillary tube to hanger penetration, P/U =40klbs, S/O= 28klbs, Land hanger, run in LD pins, pull landing jt, lay down same, install BPV, ( release rig from G-02) Clear&secure rig floor, prep & I/d mast, start moving eq to C pad &stage to get on C-45. 11/3/2017 - Friday No activity to report. 11/4/2017=Saturday No activity to report. 11/5/2017 -Sunday No activity to report. 11/6/2017- Monday No activity to report. .11 OF 7.4 • • • y/y��A THE STATE Alaska Oil and Gas ti : , �, of TT ®® sKA. Conservation Commission _ 333 West Seventh Avenue GOVERNOR BILL WALKER AAnchorage, Alaska 99501-3572 �' Main: 907.279.1433 OF „mm:,,- Q, ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager sFp 2 5 2.017, Hilcorp Alaska, LLC tIE 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Unit, Schrader Bluff Oil Pool, Milne Point Unit G-02 Permit to Drill Number: 189-028 Sundry Number: 317-430 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, Hollis S. French Chair DATED this day of September, 2017. RDD '1S t `' b .i° 1 9 2017 0 • RECEIVED STATE OF ALASKA SEP 1 1 Z017 ALASKA OIL AND GAS CONSERVATION COMMISSION /QTS' 988 7 APPLICATION FOR SUNDRY APPROVALS AOG 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0- 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 Change-out 2, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ 189-028 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-21926-00-00 1 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 ' Will planned perforations require a spacing exception? Yes ❑ No ❑., / MILNE PT UNIT G-02 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 ' MILNE POINT/SCHRADER BLUFF 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): 5,714' , 4,701'* 5,614'. 4,609' (7-7-1,56..) N/A N/A Casing Length Size MD iBurst Collapse Conductor 110' 13-3/8" 110' 110' N/A N/A Surface 2,856' 9-5/8" 2,856' 2,485' 6,870psi 4,760psi Production 5,694' 7" 5,964' 4,683' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2-3/8" 4.7/J-55/8rd EUE 4,605 See Schematic . See Schematic 2-7/8" 6.5/L-80/8rd EUE „4, 8 Si 1 o s'cf Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SC-1 L&Model D Perm/and N/A • 4,669'MD/3,770'TVD&5,110'MD/4,143'ND and N/A 12.Attachments: Proposal Summary ❑� Wellbore schematic ❑I 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: 9/22/2017 Commencing Operations: OIL ❑., • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ 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. Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhoIa( hiIcorp.com Contact Phone: 777-8412 i Authorized Signature: / / Date: 11 Sid— COMMISSION USE ONLY Conditions of approval: Noti• Commission so that a representative may witness Sundry Number: 3l—t-L{So Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: * 2.560 d; &mil`" ---T;::-*,. 1-- Post Initial Injection MIT Req'd? Yes ❑ No ❑ �� RBDMS 4 � �� 1 n J 2017�7 Spacing Exception Required? Yes ❑ No V Subsequent Form Required: 10 / APPROVED BY Li \ 5 I\� Approved by: �l COMMISSIONER THE COMMISSION Date: NI 1113'201?" (W/ .7 /... et-ice--f7 0P%,klI r1NAL Submit Form and Form 10-403 Revised 4/2017p valid for 12 months from the date of approval. Attachments in Duplicate • • • Well Prognosis Well: MPU G-02 Hikorp Alaska,LLI Date:9/06/2017 Well Name: MPU G-02 API Number: 50-029-21926-00 Current Status: SI Oil Well [ESP] Pad: G-Pad Estimated Start Date: September 22nd, 2017 Rig: "NTA— ,r4.3f2_ 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 189-028 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Job Type: Tbg/ESP Replace Current Bottom Hole Pressure: 1,175 psi @ 4,000' TVD (BHP 8/03/2017/5.65 ppg EMW) Maximum Expected BHP: 1,175 psi @ 4,000' TVD (No new perfs being added)/ MPSP: 775 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU G-02 was drilled in 1989 using Parker 141 and completed using Pool 102 rig as a Gravel-Packed completion in the Schrader Bluff N sands with an ESP pump. This testing ESP was pulled and the well temporarily isolated in 1990 to install permanent surface facilities. The temporary plug was pulled using the EWS 4 rig and an ESP pump was installed. ESP changeouts took place in 1999 (Nabors 4ES) where the well was switched from 2-7/8" to 2-3/8" tubing, 2008 (Nabors 3S), and the most recent was an ESP changeout in 2013 using Doyon #16 to replace the failed ESP. In January 2016, the well failed to surface fluids and initial slickline diagnostics identified a hole in the tubing at +/- 3,995'. A memory caliper ran on 1/30/16 found 2 holes. Those holes were patched with 2 retrievable stop/packoff tubing patches that will be pulled prior to the rig workover. A recent pump-in test indicated that another hole has developed at an unknown depth. Notes Regarding Wellbore Condition • S-shaped well (max angle 48.1° @ 2,700';thru perfs 22°-28°). • " Casing last tested to 1,500 psi for 30 min down to 6,014'on 3/22/2013. • 2 Holes noted in January 30, 2016 tubing caliper. Patched on 3/26&3-27. • Patches to be pulled before rig mobilization. c„.9.• 4 b i t..tt' 4 +-ei‹.' • Pump-in-test on 9/05/17 indicates another hole at an unknown location. e •is'r7 Objective: The purpose of this work is to pull the failed ESP, spot a scale inhibitor squeeze and run a new ESP. / Pre-Rig Procedure: K-4,1 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 volume with 8.5 ppg seawater down tubing,taking returns up casing to 500 bbl returns tank. 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. NU11_��E.E.. RD Crane. • • • Well Prognosis Well: MPU G-02 Hikorp Alaska,LU Date:9/06/2017 9. NU BOPE house. Spot mud boat. 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 seawater prior to pulling BPV. Set TWC. 12.Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/2,500 psi High (hold each t ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. gr 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 o " and 3-1/2" test joints. ��. t� 's 2 3 e. Submit to AOGCC c mpeted 10-424 form within 5 days of BOPE test. 13. ontingenc f the tubing hanger won't pressure test due to either a penetrator leak or the BPV e 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. 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 seawater as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2013 ESP swap was 74K lbs(block weight of 40k) 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 2-3/8" tubing. Tubing will be junked. Lay down failed ESP. a. Existing patches will be pulled before rig mobilization. b. Junk all joints of 2-3/8" tubing. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Look for over-torqued connections from previous tubing runs. 18. MU 2.0" mill, 1-11/16" motor,jars and RIH 15 jts of 1.660" 3.02# BTS-8 small tubing. • • • Well Prognosis Well: MPU G-02 Ilileorp Ala.ka,LL Date:9/06/2017 19. RIH with 7" 26#scraper assembly to "'4,669' MD (top of SC-1L) on 3-1/2" workstring and 1.660" clean out to 5,097' MD inside screens. Circulate the well clean with 8.5 ppg seawater. 20. Mix and pump 24.0 bbl of pre-flush (7.5% mutual solvent WAW5206), 37.0 bbl of squeeze pill (12.5%scale inhibitor SCW4004), and 140 bbl of displacement 8.5 ppg seawater. [Scale Inhibitor Treatment]. 21. POOH and LD 1.660", motor and mill, 3-1/2" workstring and 7" scraper assembly. 22. PU 7" RTTS test packer and RIH on workstring to+/-4,600' MD. �� cti`s les 23. Set test packer and pressure test 7" casing to 1,500 psi for 30 min (charted). 24,1 24. Unseat test packer and POOH while laying down the workstring. 25. PU new ESP and RIH on 2-3/8" tubing. Set base of ESP at±4,600' MD. a. XO from 2-7/8" to 2-3/8" below tubing hanger. b. Upper GLM @ ± 135' MD w/SO c. Lower GLM @ ±4,450' MD w/ DGLV d. 2-3/8" XN (1.791" No-Go) @ ±4,510' MD e. Base of ESP centralizer @ ±4,600' MD f. Install 3/8" external capillary string connected to centralizer. 26. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 27. Set BPV. Rig down ASR. Post-Rig Procedure: 28. RD mud boat. RD BOPE house. Move to next well location. 29. RU crane. ND BOPE. 30. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 31. RD crane. Move 500 bbl returns tank and rig mats to next well location. 32. Replace gauge(s) if removed. 33. 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 Changes Form II . • Milne Point Unit Well: MPU G-02 SCHEMATIC Last Completed: 3/24/2013 Ailearp Alaska,LLC PTD: 189-028 TREE&WELLHEAD KB Elev.:59.3 MSL Tree 5M FMC 2-9/16" t 11"5M FMC w/2-7/8"WKM Tbg.Hngr.,w/2-7/8"8 rd top, °? 1 20 ^J. ' * Wellhead 2-7/8"lower,2-1/2"OW H BPV profile OPEN HOLE/CEMENT DETAIL l. I ; 13-3/8" 60 bbls of Arcticset to surface in 30"Hole 2 9-5/8" 171 bbls of 12.3ppg PF"E"/123 bbls of 15.8 ppg Prem."G"in a 12-1/4"Hole 7" 65 bbls of 15.6 ppg Prem."G"in 8-1/2"Hole :::,:t:: CASING DETAIL `'J Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/Btrs 12.715 Surface 110' 0.157 r 9-5/8" Surface 47/L-80/Btrs 8.681 Surface 2,856' 0.0732 Upper Patch 7" Production 29/L-80/Btrs 6.184 Surface 5,694' 0.0372 1,941'-1,966'`s f& 3/27/16 s !Hole in Tubing TUBING DETAIL @1.954' 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface 27 0.00579 t, 2-3/8" Tubing 4.7/1-55/8rd EUE 1.995 27' 4,605' 0.00387 to o '' 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 4,669' 5,110' 0.00579 ' I WELL INCLINATION DETAIL KOP @ 500' :' Max Hole Angle=48 deg. 4 ,,e #�7, Max Hole Angle through perforations=27 deg. ,,; r4t4 ,-Z; JEWELRY DETAIL r 9-5/8" ;),,,,, of No Depth Item Centilrft heat trace 1 27' XO Pup 2-7/8"x 2-3/8" to 3,50(Y iI Estimated TOC @±3,500' 2 195' GLM STA#2:2-3/8"x 1"KBMM w/SOGLV set 7/17/17 Lower Patch .'� 3 4,425' GLM STA#1:2-3/8"x 1"KBMM w/Dummy set 3/24/13 3,971'-3,996' l.. 3/26/16 Hole in Tubing 4 4,563' 2-3/8"XN-Nipple(1.79 No-go ID) @3,987' 5 4,605' XO Pup 2-3/8"B x 2-7/8"P k , 6 4,606' Well Lift Gauge 2-7/8"8rd EUE ll al 3 k 7 4,610' Discharge Head:FPHVDIS(2-7/8"EUE) 8 4,611' Pump:141-P6 117 PMSXD 1:7 MIN ID=1.790' s' k';i 9 4,627' Gas Separator:GRSFTX AR H6(400 Internals) @4,563' , y 10 4,632' Upper Tandem Seal:GSB3DB UT/LTAB/AB PFSA 4 11 4,639' Lower Tandem Seal:GSB3DB UT/LTAB/AB PFSA 15 12 4,645' Motor:MSP1-84 Hp/2,210V/23 A 6&7 13 4,654' Sensor:WellLift MGU with Centralizer-Bottom @ 4,658' 14 4,669' Baker SC-1L Packer 7082-40-4.0"ID $"$ 15 4,678' Sliding Sleeve-4.0"ID ti 16 4,704' 2-7/8"Shear out Safety Joint w/44K Shear-2.43"ID dg t Litt it 17 5,001' Bakerweld 2-7/8"0.012"Ga.Screen 96'w/2.44"ID 't: '�l.10&11 18 5,097' 0-Ring Seal Sub a' 19 5,098' Bakerweld 2-7/8"0.012"Ga.Tell Tale Screen-11'w.2.44"ID t ,t, 20 5,109' Baker S-22 Snap Latch Seal Assembly 't12 21 5,110' Baker Model D Permanent Packer f PERFORATION DETAIL ' " 13 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status NA 5,022' 5,046' 4,064' 4,086' 24 See Below Open + _.4 '°y14 NB 5,056' 5,076' 4,095' 4,113' 20 See Below Open 15 t ` ` 16 NB/NC 5,085' 5,094' 4,121' 4,129' 9 See Below Open " M 17 Perforation Charge Detail:4-5/8"Vann Gun Assembly-24SPF Executed on 3/30/1990&4/7/1990 Sands i Wr t , ; ?x,,16 GENERAL WELL INFO 1. n .; 19 API:50-029-21926-00-00 v -�, ► M1 20&21 Drilled and Cased by Parker 141-8/29/1989 0. s Perforate,Gravel Pack&Test by Pool#102-5/10/1990 4 I. 7" Completed with ESP by EWS Rig#4 -11/20/1990 TD=5,714'(MD)/TD=4,701'(1VD) ESP Change-out by Nabors 4ES-2/15/1999 PBTD=5,614'(MD)/PBTD=4,609'(TVD) ESP Change-out by Nabors 3S-12/8/2008 ESP Change-out by Doyon 14-3/24/2013 WELL STIMULATION Gravel Pack:5,022'to 5,094' Created By:STP 8/03/2017 • H . • Milne Point Unit Well: MPU G-02 PROPOSED Last Completed: Proposed ffilcorp Alaska,LLC PTD: 189-028 KB Elev.:59.3'AMSL/GL Elev.:28.6'AMSL TREE&WELLHEAD Dovon 16: 22.74'RKBtoTHF Tree 5M FMC 2-9/16" r 11"5M FMC w/2-7/8"WKM Tbg.Hngr.,w/2-7/8"8 rd top, ,4 Wellhead ,+ 2-7/8"lower,2-1/2"CIW H BPV profile 20 Is (H' OPEN HOLE/CEMENT DETAIL kk 13-3/8" 60 bbls of Arcticset to surface in 30"Hole ki 2 9-5/8" 171 bbls of 12.3ppg PF"E"/123 bbls of 15.8 ppg Prem."G"in a 12-1/4"Hole 7" 65 bbls of 15.6 ppg Prem."G"in 8-1/2"Hole i''''' CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/Btrs 12.715 Surface 110' 0.157 9-5/8" Surface 47/L-80/Btrs 8.681 Surface 2,856' 0.0732 7" Production 29/L-80/Btrs 6.184 Surface 5,694' 0.0372 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface 27' 0.00579 2-3/8" Tubing 4.7/J-55/8rd EUE 1.995 27' 4,605' 0.00387 414 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 4,669' 5,110' 0.00579 WELL INCLINATION DETAIL ' KOP@500' 3Max Hole Angle=48 deg. i s± Max Hole Angle through perforations=27 deg. t"t JEWELRY DETAIL 9-5/8' . .I: No Depth Item Centilift heat trace I Estimated TOC 1 27' XO Pup 2-7/8"x 2-3/8" to3,5ar @_+3,500 2 135' GLM STA#2:2-3/8"x 1"KBMM w/SOGLV 3 4,450' GLM STA#1:2-3/8"x 1"KBMM w/Dummy 4 4,510' 2-3/8"XN-Nipple(1.79 No-go ID) 5 4,550' XO Pup 2-3/8"B x 2-7/8"P 7 4,610' Discharge Head IWS8 4,553' Pump 3 9 4,569' Gas Separator MIN ID=1.790 10 4,575' Upper Tandem Seal @4,510' 11 4,581' Lower Tandem Seal Litt12 4,587' ESP Motor 613 4,596' Sensor:WeIILift MGU with Centralizer-Bottom @ 4,600' IMI614 4,669' Baker SC-1L Packer 7062-40-4.0"ID - 15 4,678' Sliding Sleeve-4.0"ID 7 16 4,704' 2-7/8"Shear out Safety Joint w/44K Shear-2.43"ID 17 5,001' Bakerweld 2-7/8"0.012"Ga.Screen 96'w/2.44"ID 8 18 5,097' 0-Ring Seal Sub 9&10 19' 5,098' Bakerweld 2-7/8"0.012"Ga.Tell Tale Screen-11'w.2.44"ID 20 5,109' Baker S-22 Snap Latch Seal Assembly 21 5,110' Baker Model D Permanent Packer 11 PERFORATION DETAIL 4 12'-` Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status NA 5,022' 5,046' 4,064' 4,086' 24 See Below Open ® ` 13 14 NB 5,056' 5,076' 4,095' 4,113' 20 See Below Open "`'%S':sm`'`%` is NB/NC 5,085' 5,094' 4,121' 4,129' 9 See Below Open Schrader N fa' r 16 Perforation Charge Detail:4-5/8"Vann Gun Assembly-24SPF Executed on 3/30/1990&4/7/1990 Sands i,,•`. 17 GENERAL WELL INFO 18 API:50-029-21926-00-00 . ► 19&20 Drilled and Cased by Parker 141-8/29/1989 4 Perforate,Gravel Pack&Test by Pool#102-5/10/1990 7"4 I► Completed with ESP by EWS Rig#4 -11/20/1990 TD=5,714'(MD)/TD=4,701'(TVD) ESP Change-out by Nabors 4ES-2/15/1999 PBTD=5,614'(MD)/PBTD=4,609'(TVD) ESP Change-out by Nabors 3S-12/8/2008 ESP Change-out by Doyon 14-3/24/2013 WELL STIMULATION Gravel Pack:5,022'to 5,094' Created By:STP 9/06/2017 • • • II Milne Point ASR Rig 1 BOPE Htk ip Ala.l.a,III. 11" BOPE Stripping Head p 3.98' Shaffer ° 11"- 5000 - lil Eli Ill thin ill lid CI i -UNW __�� ,«r VBR or Pipe Rams 4.54 ... .taw; c co emu ,� •I 11"-5000 � Blind r,r Ili iii iii ilii 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves N _/ Li j g 2.00 1 . o � � � � o) � a :( !I i : ! ' [1_, c i iii iiRilileiliR J Lt. c i _ ��: Manual Manual Manual HCR Updated 8/19/2015 • • MPG-02 8-3-2017 Swab Valve Cameron 2 9/16" tree w/2 7/8" FL 2 9/16" 5K, manual gate Tbg Hgr. Prepped for 1 iv, i , Tbg valve, EE PSL2,PR2 ea. 1/2" NPT x 3/8" x1/4" col^`' PN 141523-31-02-01 Control line and 2 %2" "H" 052 , BPV prep. Comes with q0 Wing valve Cameron alignment screw and non- 0 p Q OFL-2 9/16" 5K, manual gate rotating flanges valve, EE PSL2,PR2 Ilia III PN 141523-31-02-01 sift) 4...,,,,—,,,cAnN p SSV Cameron FL-2 9/16" 5K, O� �7 reverse actuating gate valve, iii - EE.PSL2,PR2 w/Cameron "�� 's" actuator PN 174370-08 77 Assy PN 207043-03-03-01 Master Cameron I.,_ &a It FL-2 9/16" 5K, manual gate VIM sMMW Tbg Hgrwit , valve, EE PSL2,PR2 WKM TDF 11" 5K x 2 9/16" p PN 141523-31-02-01 5K, w/lea '/z" NPT control 1 t:-,..:... line prep, lea BIW ESP Tbg Hd adapter WKM 11" penetrator and lea HT AMC, , 5K x 2 9/16" 5K, rotating penetrator. 1/2" Control line flanges, w/lea control line prep through hanger preps and lea BIW ESP Prepped for 2 1/2" "H" BPV penetrator and lea HT PN 2133643-03-01 penetrator preps. Bottom SN 1111 I' in prepped for 2 7/8" seal neck. PN iilal -II - !.P nlil• rol ii I to 1:1 - -ti. o �� °Jo 1� ION-i,. ,:, . . - O . . m . .1 1111 ilt ilii- ' III Y iatta„:1:®,® ' 009 E 16 ) ° V,, , IT _ a ' 0 . c2 ) a) 2 0 cl) 13 o � c kco / 0 > as = 02 ■ .g o o = = « tea EE S CD E V \ § k fE Ik= $ / « m (O $ � 0 � § k 22 0- E ase � � § 2 < m a 2 3 \ o 0 k/ c o 0 � 0 . o — 0 k§ 0 9\ / 0 2 c ■ U. 2 $ CD / .';.- s / U \ / 0 . $ % 9 S w ■ E § 2 = = 0 a 2 / 'K i 2 2 ) a- a o c 0_ _ _ $ 2 -0 = I a) 2 §N CL / c 2 co 2 0-4 0 Q / � ° O co it = Cd 00 E O et o E c Cl / . 0 .0 @ © ■ 2 co o . 2 a .. = 5 ¢ E w N < a_ STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations U Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ ?rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Install Tubing Patches ❑., 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory ❑ 189-028 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-21926-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVEC ADL0025906 MILNE PT UNIT SB G-02 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): APR 2 7 2016 N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: 1OGCC Total Depth measured 5,714 feet Plugs measured N/A feet true vertical 4,701 feet Junk measured N/A feet Effective Depth measured 5,614 feet Packer measured 4,669&5,110 feet true vertical 4,609 feet true vertical 3,770&4,143 feet Casing Length Size MD TVD ' "" - — durst Collapse Conductor 110' 13-3/8" 110' 110' N/A N/A Surface 2,856' 9-5/8" 2,856' 2,485' 6,870psi 4,760psi Production 5,694' 7" 5,694' 4,683' 8,160psi 7,020psi Perforation depth Measured depth See Attached Schematic Cf RNNED MAY0 2016 True Vertical depth See Attached Schematic �7�•I� 2-3/8" 4.7/J-55/8rd EUE 4,605' 3,722' Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5/L-80/8rd EUE 4,658' 3,762' SC-1L Packers and SSSV(type,measured and true vertical depth) Model D Perm 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 0 530 0 Subsequent to operation: 105 94 330 250 219 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 316-115 c��1,I/Y(f Contact Stan Porhola Email sporhola(C�hilcorp.col'TT Printed Name Bo York Title Operations Manager Signature /7;.'7/ - -------'N- Phone 777-8345 Date 4/27/2016 )4.._ S'.-3—t‘ RBDMS l,t, P'''P L 9 2016 Form 10-404 Revised 5/2015 Submit Original Only Ill Milne Point Unit H . Well: MPU G-02 . 'H SCHEMATIC Last Completed: 3/19/2013 Ililcorp Alaska,LLC PTD: 189-028 TREE&WELLHEAD KB Elev.:59.3 MSL Tree 5M FMC 2-9/16" 1 Wellhead 11"5M FMC w/2-7/8"WKM Tbg.Hngr.,w/2-7/8"8 rd top, 2a F * 2-7/8"lower,2-1/2"ow H BPV profile ij , OPEN HOLE/CEMENT DETAIL 13-3/8" 60 bbls of Arcticset to surface in 30"Hole 2 9-5/8" 171 bbls of 12.3ppg PF"E"/123 bbls of 15.8 ppg Prem."G"in a 12-1/4"Hole IA 1 :' 7" 65 bbls of 15.6 ppg Prem."G"in 8-1/2"Hole N CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 3 13-3/8" Conductor 48/H-40/Btrs 12.715 Surface 110' 0.157 i _ 9-5/8" Surface 47/L-80/Btrs 8.681 Surface 2,856' 0.0732 Upper Patch L ) 7" Production 29/L-80/Btrs 6.184 Surface 5,694' 0.0372 1,941-1,966, t 3/27/16 Hole in Tubing TUBING DETAIL @1,954' 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface 27' 0.00579 °` * 2-3/8" Tubing 4.7/1-55/8rd EUE 1.995 27' 4,605' 0.00387 P 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 4,669' 5,110' 0.00579 ,' WELL INCLINATION DETAIL KOP @ 500' 14 0 Max Hole Angle=48 deg. Max Hole Angle through perforations=27 deg. I 44,7St ,, JEWELRY DETAIL 9-,- fi°+,$ 3 ,wot`.k No Depth Item 1 27' XO Pup 2-7/8"x 2-3/8" 2 195' GLM STA#2:2-3/8"x 1"KBMM w/Screen 3 4,425' GLM STA#1:2-3/8"x 1"KBMM w/Dummy Estimated TOC 4 4,563' 2-3/8"XN-Nipple(1.79 No-go ID) Lower Patch i @±3,500' 5 4,605' XO Pup 2-3/8"B x 2-7/8"P 3,971'-3,996' t 1 6 4,606' Well Lift Gauge 2-7/8"8rd EUE 3/26/16 ', Hole inTubing 7 4,610' Discharge Head:FPHVDIS(2-7/8"EUE) ., a, @ 3,987' 8 4,611' Pump:141-P6 117 PMSXD 1:7 LO N MIN L790" 9 4,627' Gas Separator:GRSFTX AR H6(400 Internals) at @4,563' • 4 10 4,632' Upper Tandem Seal:GSB3DB UT/LT AB/AB PFSA 11 4,639' Lower Tandem Seal:GSB3DB UT/LT AB/AB PFSA 5 ' 12 4,645' Motor:MSP1-84 Hp/2,210V/23 A • 6&7 13 4,654' Sensor:WellLift MGU with Centralizer-Bottom @ 4,658' a 14 4,669' Baker SC-1LPacker 70B2-40-4,0"ID 8 15 4,678' Sliding Sleeve-4,0"ID r1 16 4,704' 2-7/8"Shear out Safety Joint w/44K Shear-2.43"ID II.I1 9 17 5,001' Bakerweld 2-7/8"0.012"Ga.Screen 96'w/2.44"ID a10&11 18 5,097 0-Ring Seal Sub 19 5,098' Bakerweld 2-7/8"0.012"Ga.Tell Tale Screen-11'w.2.44"ID 20 5,109' Baker S-22 Snap Latch Seal Assembly 12 21 5,110' Baker Model D Permanent Packer PERFORATION DETAIL ra t 13 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Schrader"N" 5,022' 5,046' 4,064' 4,086' 24 See Below Open :4,1,4 rx< 14 5,056' 5,076' 4,095' 4,113' 20 See Below Open x 15 Sands - • 16 5,085' 5,094' 4,121' 4,129' 9 See Below Open Schrader"N'I a 17 Perforation Charge Detail:4-5/8"Vann Gun Assembly-24SPF Executed on 3/30/1990&4/7/1990 sands 1 GENERAL WELL INFO :18 API:50-029-21926-00-00 .,19 �_®I+20&21 Drilled and Cased by Parker 141-8/29/1989 z 4 Perforate,Gravel Pack&Test by Pool#102-5/10/1990 7„6 ,t, Completed with ESP by EWS Rig#4 -11/20/1990 ESP Change-out by Nabors 4ES-2/15/1999 TD=5,714'(MD)/TD=4,701'(TVD) ESP Change-out by Nabors 3S-12/8/2008 PBTD=5,614'(MD)/PBTD=4,609'(1VD) ESP Change-out by Doyon 14-3/24/2013 WELL STIMULATION _ Gravel Pack:5,022'to 5,094' Created By:STP 3/30/2016 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-02 Slickline 50-29-21926-00-00 189-028 3/26/16 3/27/16 (Daily Operations: 3/23/2015 -Wednesday No activity to report. 3/24/2015 -Thursday No activity to report. 3/25/2015 - Friday No activity to report. 3/26/2015 -Saturday MIRU Slickline and PCE. PT lubricator to 3,500 psi Hi 250 psi Low. RIH w/tubing stop and set at 3,996' MD. RIH w/ packoff and set at 3,994' MD. RIH w/spacer pipe and set at 3,974' MD. RIH w/packoff and set at 3,972' MD. RIH w/tubing stop and set at 3,971' MD. Lower patch set. RD Slickline and PCE. SDFN. 3/27/2015-Sunday MIRU Slickline and PCE. PT lubricator to 3,500 psi Hi 250 psi Low. RIH w/tubing stop and set at 1,966' MD. RIH w/ packoff and set at 1,964' MD. RIH w/spacer pipe and set at 1,944' MD. RIH w/packoff and set at 1,942' MD. RIH w/tubing stop and set at 1,941' MD. Upper patch set. RD Slickline and PCE. Turn well over to production. 3/28/2015- Monday No activity to report. 3/29/2015 -Tuesday No activity to report. •aF T� • • O 1"02-4S \��yyy�8� THE STATE Alaska Oil and Gas F �4 Of/\ T r0SKA Conservation Commission O ->E-gl2 r� 333 West Seventh Avenue l'.111 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Off, -_ P Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York ,-t--I-) ) r,jik Operations Manager e� ` F.:D W J•,J Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB G-02 Permit to Drill Number: 189-028 Sundry Number: 316-115 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°91q- 41' Cathy P. oerster , Chair CU" DATED this d--ay of February, 2016. RBDMS FEB 1 1 2016 0 0 RECEIVED STATE OF ALASKA FEB 0 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION111 t n� APPLICATION FOR SUNDRY APPROVALS AOU C 20 AAC 25.280 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: Install Tubing Patches Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ • 189-028 3.Address: Stratigraphic ❑ Service ii 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-21926-00-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No 0 - MILNE PT UNIT SB G-02 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0025906 " MILNE POINT/SCHRADER BLUFF 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): 5,714' 4,701' 5,614' 4,609' 875 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 110' 13-3/8" 110' 110' N/A N/A Surface 2,856' 9-5/8" 2,856' 2,485' 6,870psi 4,760psi Production 5,694' 7" 5,964' 4,683' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2-3/8" 4.7/J-55/8rd EUE 4,605 See Asttached Schematic See Asttached Schematic 2-7/8" 6.5/L-80/8rd EUE 4,658 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SC-1L&Model D Perm/and N/A 4,669'MD/3,770'TVD&5,110'MD/4,143'TVD and N/A 12.Attachments: Proposal Summary M Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development [i " Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 2/23/2016 Commencing Operations: OIL Q . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ 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. ContactStan Porhola ` ' Email sporhola(a7hilcorp.com Printed Name b"�/ y Bo York Title Operations Manager Signature 'o' //I �— Phone 777-8345 Date 219/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3i(.(— \ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No [-Z' Spacing Exception Required? Yes ❑ No © Subsequent Form Required: VO— 40 4. APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 2 -1O - /6 Submit Form and Form 10-403 Revised 11/2015 topr rs alid for 12 months from the date of approval. Attachments in Duplicate U F\ RBDMS LL Fa 1 1 MP L-,``T/ , • • Well Prognosis Well: MPU G-02 Ilileorp Alaska,LLQ Date:2/08/2016 Well Name: MPU G-02 API Number: 50-029-21926-00 Current Status: SI Oil Well [ESP] Pad: G-Pad Estimated Start Date: February 23rd, 2016 Rig: N/A Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 189-028 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) AFE Number: 1650315 Current Bottom Hole Pressure: 1,275 psi @ 4,000' TVD (BHP 1/28/2016/6.12 ppg EMW) Maximum Expected BHP: 1,275 psi @ 4,000' TVD (No new perfs being added) MPSP: 875 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU G-02 was drilled in 1989 using Parker 141 and completed using Pool 102 rig as a Gravel-Packed completion in the Schrader Bluff N sands with an ESP pump. This testing ESP was pulled and the well temporarily isolated in 1990 to install permanent surface facilities. The temporary plug was pulled using the EWS 4 rig and an ESP pump was installed. ESP changeouts took place in 1999 (Nabors 4ES) where the well was switched from 2-7/8" to 2-3/8" tubing, 2008 (Nabors 3S), and the most recent was an ESP changeout in 2013 • using Doyon #16 to replace the failed ESP. In January 2016, the well failed to surface fluids and initial slickline • diagnostics identified a hole in the tubing at+/-3,995'.A memory caliper ran on 1/30/16 found 2 holes. Notes Regarding Wellbore Condition • S-shaped well (max angle 48.1° @ 2,700';thru perfs 22°-28°). • Casing last tested to 1,500 psi for 30 min down to 6,014'on 3/22/2013. • Tubing to be prepped before installing patch (drifted; brushes/scratchers above and below hole). • 2 Holes noted in January 30, 2016 tubing caliper. Objective: The purpose of this work is to patch the tubing with 2 each slickline set/retrievable patches. Brief Procedure: Slickline Procedure: 1. MIRU Slickline and PCE (Press Control Equip) PT lubricator to 1,500 psi Hi 250 Low. 2. RIH w/tubing patches to cover holes at+/-1,954'SLM and+/-3,987'SLM with the following items: a. AD-2 stop/Packoff/1.0" ID Spacer Pipe/Packoff/AA stop (Bottom to Top). 3. RD Slickline and PCE. 4. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic • • Milne Point Unit II Well: MPU G-02 SCHEMATIC Last Completed: 3/19/2013 IHilcoru Alaska,LLC PTD: 189-028 KB EIev.:59.3 MSL TREE&WELLHEAD Tree 5M FMC 2-9/16" llti *t 1 ` L Wellhead 11"5M FMC w/2-7/8"WKM Tbg.Hngr.,w/2-7/8"8 rd top, 2a' " 2-7/8"lower,2-1/2"CIW H BPV profile ,.; OPEN HOLE/CEMENT DETAIL a 2 13-3/8" 60 bbls of Arcticset to surface in 30"Hole 9-5/8" 171 bbls of 12.3ppg PF"E"/123 bbls of 15.8 ppg Prem."G"in a 12-1/4"Hole l'' '' 7" 65 bbls of 15.6 !+ ppg Prem."G"in 8-1/2"Hole CASING DETAIL I, Size Type Wt/Grade/Conn ID Top Btm BPF to 13-3/8" Conductor 48/H-40/Btrs 12.715 Surface 110' 0.157 9rt 9-5/8" Surface 47/L-80/Btrs 8.681 Surface 2,856' 0.0732 7" Production 29/L-80/Btrs 6.184 Surface 5,694' 0.0372 h i a Hole in Tubing TUBING DETAIL ' @ 1,954' 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface 27' 0.00579 ' +' 2-7/8"2-3/8" Tubing 4.7/J-55/8rd EUE 1.995 27' 4,605' 0.00387 it J Tubing 6.5/L-80/8rd EUE 2.441 4,605' 4,658' 0.00579 i4 ht. 41 a I WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle=48 deg. SMax Hole Angle through perforations=27 deg. °'`. ..°A) . et*tt'9-5/8" Wel 44 JEWELRY DETAIL "' 3No Depth Item 1 27' XO Pup 2-7/8"x 2-3/8" 2 195' GLM STA#2:2-3/8"x 1"KBMM w/Screen 3 4,425' GLM STA#1:2-3/8"x 1"KBMM w/Dummy Estimated TOC 4 4,563' 2-3/8"XN-Nipple(1.79 No-go ID) @±3,500' 5 4,605' XO Pup 2-3/8"B x 2-7/8"P l' '" Hole 6 4,606' Well Lift Gauge 2-7/8"8rd EUE @398y 7 4,610' Discharge Head:FPHVDIS(2-7/8"EUE) a 8 4,611' Pump:141-P6 117 PMSXD 1:7 MINID=1. 9 4,627' Gas Separator:GRSFTX AR H6(400 Internals) @4,563' '' t 10 4,632' Upper Tandem Seal:GSB3DB UT/LT AB/AB PFSA 9 4 ,`°°°i ° *‘'‘,ty 11 4,639' Lower Tandem Seal:GSB3DB UT/LT AB/AB PFSA 5 )� 12 4,645' Motor:MSP1-84 Hp/2,210V/23 A 6&7 13 4,654' Sensor:WeIlLift MGU with Centralizer-Bottom @ 4,658' 14 4,669' Baker SC-1L Packer 7082-40-4.0"ID 6l 15 4,678' Sliding Sleeve-4.0"ID t Ii /tsl 9 16 4,704' 2-7/8"Shear out Safety Joint w/44K Shear-2.43"ID 17 5,001' Bakerweld 2-7/8"0.012"Ga.Screen 96'w/2.44"ID V. 10&11 18 5,097 0-Ring Seal Sub mw 4 19 5,098' Bakerweld 2-7/8"0.012"Ga.Tell Tale Screen-11'w.2.44"ID 20 5,109' Baker S-22 Snap Latch Seal Assembly t 1 ;,.,$12 21 5,110' Baker Model D Permanent Packer tit it PERFORATION DETAIL ‘i 13 13 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status r `14 Schrader"N,. 5'022 5,046' 4,064' 4,086' 24 See Below Open e 15 Sands 5,056' 5,076' 4,095' 4,113' 20 See Below Open s 16 5,085' 5,094' 4,121' 4,129' 9 See Below Open Schrader"N'I 417 Perforation Charge Detail:4-5/8"Vann Gun Assembly-24SPF Executed on 3/30/1990&4/7/1990 Sands L 618 GENERAL WELL INFO ,+19 API:50-029-21926-00-00 " -� '� 20&21 Drilled and Cased by Parker 141-8/29/1989 Perforate,Gravel Pack&Test by Pool#102-5/10/1990 7"J Completed with ESP by EWS Rig#4 -11/20/1990 TD=5,714'(MD)/TD=4,701'(ND) ESP Change-out by Nabors 4ES-2/15/1999 PBTD=5,614'(MD)/PBTD=4,609(ND) ESP Change-out by Nabors 35-12/8/2008 ESP Change-out by Doyon 14-3/24/2013 WELL STIMULATION IGravel Pack:5,022'to 5,094' Created By:STP 2/08/2016 • Milne Point Unit elMPU G-02 . II PROPOSED SCHEMATIC L sstlCompleted 3/19/2013 Ililcarp Alaska,LLC PTD: 189-028 KB Elev.:59.3 MSL TREE&WELLHEAD Tree 5M FMC 2-9/16" ie c., 1 Wellhead 11"5M FMC w/2-7/8"WKM Tbg.Hngr.,w/2-7/8"8 rd top, 20' 2-7/8"lower,2-1/2"CIW H BPV profile OPEN HOLE/ i CEMENT DETAIL k A 2 13-3/8" 60 bbls of Arcticset to surface in 30"Hole 4` 9-5/8" 171 bbls of 12.3ppg PF"E"/123 bbls of 15.8 ppg Prem."G"in a 12-1/4"Hole V 1 7" 65 bbls of 15.6 ppg Prem."G"in 8-1/2"Hole Py 9 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/Btrs 12.715 Surface 110' 0.157 t" 9-5/8" Surface 47/L-80/Btrs 8.681 Surface 2,856' 0.0732 Proposed o 7" Production 29/L-80/Btrs 6.184 Surface 5,694' 0.0372 Patch @ ±1,850'to Hole in Tubing TUBING DETAIL 1,050 r @1,954' 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface 27' 0.00579 r "' 2-3/8" Tubing 4.7/J-55/8rd EUE 1.995 27' 4,605' 0.00387 P. 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 4,605' 4,658' 0.00579 WELL INCLINATION DETAIL KOP@500' hr a Max Hole Angle=48 deg. ` Max Hole Angle through perforations=27 deg. , JEWELRY DETAIL Ido V,..„...MNo Depth Item 1 27' XO Pup 2-7/8"x 2-3/8" 2 195' GLM STA#2:2-3/8"x 1"KBMM w/Screen 3 4,425' GLM STA#1:2-3/8"x 1"KBMM w/Dummy ' edTIx 4 4,563' 2-3/8"XN-Nipple(1.79 No-go ID) �/@±3,500 5 4,605' XO Pup 2-3/8"B x 2-7/8"P ProposedPatch@ 6 4,606' WellUftGau / ±3,900'to±4,100' Hole in Tubing ge 2-7 8"8rd EUE @3,987 7 4,610' Discharge Head:FPHVDIS(2-7/8"EUE) 8 4,611' Pump:141-P6 117 PMSXD 1:7 MIN ID 1. „" 9 4,627' Gas Separator:GRSFTX AR H6(400 Internals) @4,563' r i ' . 10 4,632' Upper Tandem Seal:GSB3DB UT/LTAB/AB PFSA 11 4,639' Lower Tandem Seal:GSB3DB UT/LT AB/AB PFSA I'.1 12 4,645' Motor:MSP1-84 Hp/2,210V/23 A iY 6&7 13 4,654' Sensor:WellLift MGU with Centralizer-Bottom @ 4,658' 6 14 4,669' Baker SC-1L Packer 70B2-40-4.0"ID 15 4,678' Sliding Sleeve-4.0"ID 9 16 4,704' 2-7/8"Shear out Safety Joint w/44K Shear-2.43"ID Ili 17 5,001' Bakerweld 2-7/8"0.012"Ga.Screen 96'w/2.44"ID if *`10&11 18 5,097' 0-Ring Seal Sub 19 5,098' Bakerweld 2-7/8"0.012"Ga.Tell Tale Screen-11'w.2.44"ID 20 5,109' Baker S-22 Snap Latch Seal Assembly 12 21 5,110' Baker Model D Permanent Packer PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status w ._. 14 Schrader"N„ 5,022' 5,046' 4,064' 4,086' 24 See Below Open a 15 Sands 5,056' 5,076' 4,095' 4,113' 20 See Below Open '� 16 5,085' 5,094' 4,121' 4,129' 9 See Below Open Schrader Sands "V{ :, 17 Perforation Charge Detail:4-5/8"Vann Gun Assembly-24SPF Executed on 3/30/1990&4/7/1990 16 GENERAL WELL INFO 19 API:50-029-21926-00-00 f=E r *1 20&21 Drilled and Cased by Parker 141-8/29/1989 Perforate,Gravel Pack&Test by Pool#102-5/10/1990 7 € Completed with ESP by EWS Rig#4 -11/20/1990 TD=5,714'(MD)/TD=4,701'(TVD) ESP Change-out by Nabors 4ES-2/15/1999 PBTD=5,614'(MD)/PBTD=4,60Y(TVD) ESP Change out by Nabors 3S-12/8/2008 ESP Change-out by Doyon 14-3/24/2013 WELL STIMULATION Gravel Pack:5,022'to 5,094' Created By:STP 2/08/2016 • • \.460)- 023 THE STATE Alaska Oil and Gas °f .LAs Conservation Commission z_�_ 333 West Seventh Avenue ieepGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York scov,a0 FEB 1 6 ?1-M Manager Operations p g Cf Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB G-02 Permit to Drill Number: 189-028 Sundry Number: 316-065 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, Cathy P. oerster Chair DATED this 3 day of February, 2016. RBDMS t-t, FEB 0 4 2016 • • RECEIVED STATE OF ALASKA FEB 0 1;g ALASKA OIL AND GAS CONSERVATION COMMISSION oil Z43/ 46, APPLICATION FOR SUNDRY APPROVALSGC 20 AAC 25.2804 l 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: Install Tubing Patch❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC • Exploratory ❑ Development Q- 189-028 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-21926-00-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05• Will planned perforations require a spacing exception? Yes ❑ No 2 MILNE PT UNIT SB G-02 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0025906 . MILNE POINT/SCHRADER BLUFF 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): • 5,714' . 4,701' . 5,614' - 4,609' 875 N/A N/A Casing Length Size MD ND Burst Collapse Conductor 110' 13-3/8" 110' 110' N/A N/A Surface 2,856' 9-5/8" 2,856' 2,485' 6,870psi 4,760psi Production 5,694' 7" 5,964' 4,683' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2-3/8" 4.7/J-55/8rd EUE 4,605 See Asttached Schematic• See Asttached Schematic 2-7/8" 6.5/L-80/8rd EUE 4,658 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): , SC-1L&Model D Perm/and N/A -4,669'MD/3,770'TVD&5,110'MD/4,143'TVD and N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 2/12/2016 E. ❑ ❑ Suspended ❑ Commencing Operations: OIL � . WINJ WDSPL 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ 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 Stan Porhola Email sporhola(cthilcorp.com Printed Name Bo York Title Operations Manager Signatur: Phone 777-8345 Date 1/29/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No LJ Subsequent Form Required: /b i...../ a ` APPROVEDIBY Approved by: 2167/2 COMMISSIONER THE COMMISSION Date: Z_3—( °RI/013NA Submit Form ane Form 10-403 Revised 1/2015 alid for 12 months from the date of approval. Attachments in Duplicate RBDMS L L, FEB 0 4 2016 • • Well Prognosis Well: MPU G-02 IIilearp Alaska,LL Date: 1/29/2016 Well Name: MPU G-02 API Number: 50-029-21926-00 Current Status: SI Oil Well [ESP] Pad: G-Pad Estimated Start Date: February 12th, 2016 Rig: N/A Reg.Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 189-028 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: 1650315 Current Bottom Hole Pressure: 1,275 psi @ 4,000' TVD (BHP 1/28/2016/6.12 ppg EMW) Maximum Expected BHP: 1,275 psi @ 4,000' TVD (No new perfs being added) MPSP: 875 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU G-02 was drilled in 1989 using Parker 141 and completed using Pool 102 rig as a Gravel-Packed completion in the Schrader Bluff N sands with an ESP pump. This testing ESP was pulled and the well temporarily isolated in 1990 to install permanent surface facilities. The temporary plug was pulled using the EWS 4 rig and an ESP pump was installed. ESP changeouts took place in 1999 (Nabors 4ES) where the well was switched from 2-7/8" to 2-3/8" tubing, 2008 (Nabors 3S), and the most recent was an ESP changeout in 2013 using Doyon #16 to replace the failed ESP. In January 2016, the well failed to surface fluids and slickline diagnostics identified a hole in the tubing at+/-3,995'. Notes Regarding Wellbore Condition • S-shaped well (max angle 48.1° @ 2,700'; thru perfs 22°-28°). • Casing last tested to 1,500 psi for 30 min down to 6,014' on 3/22/2013. • Hole in tubing at+/-3,955'SLM. • Corrosion/pitting noted in January 2013 tubing caliper.Tubing replaced w/ Doyon#16. • Tubing to be prepped before installing patch (drifted; brushes/scratchers above and below hole). Objective: The purpose of this work is to patch the tubing with a slickline set/retrievable patch. Brief Procedure: Slickline Procedure: 1. MIRU Slickline and PCE (Press Control Equip) PT lubricator to 1,500 psi Hi 250 Low:,, 2. RIH w/tubing patch to cover hole at+/-3,995' SLM with the following items: a. AD-2 stop/Packoff/1.0" ID Spacer Pipe/Packoff/AA stop (Bottom to Top). 3. RD Slickline and PCE. 4. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic • • Milne Point Unit - 11. Well: MPU G-02 SCHEMATIC Last Completed: 3/19/2013 Hilcorp Alaska,LLC PTD: 189-028 TREE&WELLHEAD KB Elev.:59.3 MSL Tree 5M FMC 2-9/16" °) 7 1 Wellhead 11"5M FMC w/2-7/8"WKM Tbg.Hngr.,w/2-7/8"8 rd top, 20 t 2-7/8"lower,2-1/2"CIW H BPV profile A, 4 i € OPEN HOLE/CEMENT DETAIL .1 `v 13-3/8" 60 bbls of Arcticset to surface in 30"Hole 4 2 9-5/8" 171 bbls of 12.3ppg PF"E"/123 bbls of 15.8 ppg Prem."G"in a 12-1/4"Hole 44 7" 65 bbls of 15.6 ppg Prem."G"in 8-1/2"Hole Y e CASING DETAIL 42 Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/Btrs 12.715 Surface 110' 0.157 ? I g 9-5/8" Surface 47/L-80/Btrs 8.681 Surface 2,856' 0.0732 i y 7" Production 29/L-80/Btrs 6.184 Surface 5,694' 0.0372 g TUBING DETAIL s2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface 27' 0.00579 1,1 2-3/8" Tubing 4.7/1-55/8rd EUE 1.995 27 4,605' 0.00387 WI id ( 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 4,605' 4,658' 0.00579 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle=48 deg. Max Hole Angle through perforations=27 deg. JEWELRY DETAIL 9-518 ./ 3 .` No Depth Item 1 27' X0 Pup 2-7/8"x 2-3/8" I 2 195' GLM STA#2:2-3/8"x 1"KBMM w/Screen 3 4,425' GLM STA#1:2-3/8"x 1"KBMM w/Dummy Estimated TOC 4 4,563' 2-3/8"XN-Nipple(1.79 No-go ID) @±3,500' 5 4,605' X0 Pup 2-3/8"B x 2-7/8"P . -� 6 4,606' Well Lift Gauge 2-7/8"8rd EUE Hole in Tubing 07 4,610' Discharge Head:FPHVDIS(2-7/8"EUE) @3,995' 8 4,611' Pump:141-P6117 PMSXD 1:7 MIN ID 1.79`1 i 9 4,627' Gas Separator:GRSFTX AR H6(400 Internals) @4,563' ... 10 4,632' Upper Tandem Seal:GSB3DB UT/LTAB/AB PFSA ( 4 ' 11 4,639' Lower Tandem Seal:GSB3DB UT/LTAB/AB PFSA 5 V': 12 4,645' Motor:MSP1 84 Hp/2,210V/23 A r 6&7 13 4,654' Sensor:WeIILift MGU with Centralizer-Bottom @ 4,658' if, 14 4,669' Baker SC-1L Packer 7082-40-4.0"ID 6 15 4,678' Sliding Sleeve-4.0"ID 16 4,704' 2-7/8"Shear out Safety Joint w/44K Shear-2.43"ID 11 9 17 5,001' Bakerweld 2-7/8"0.012"Ga.Screen 96'w/2.44"ID X10&11 18 5,097' 0-Ring Seal Sub 19 5,098' Bakerweld 2-7/8"0.012"Ga.Tell Tale Screen-11'w.2.44"ID 20 5,109' Baker S-22 Snap Latch Seal Assembly `y 12 21 5,110' Baker Model D Permanent Packer PERFORATION DETAIL kV 13 I Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 5,022' 5,046' 4,064' 4,086' 24 See Below Open .N _ 14 Schrader"N" 5,056' 5,076' 4,095' 4,113' 20 See Below Open S! iTit Sands X16 5,085' 5,094' 4,121' 4,129' 9 See Below Open SandsS� N{ :::17 Perforation Charge Detail:4-5/8"Vann Gun Assembly-24SPF Executed on 3/30/1990&4/7/1990 l e4 ,�; rp18 GENERAL WELL INFO ' API:50-029-21926-00-00 19 '* :a �►_.},20&21 Drilled and Cased by Parker 141-8/29/1989 ' Perforate,Gravel Pack&Test by Pool#102-5/10/1990 7 �+ Completed with ESP by EWS Rig#4 -11/20/1990 7 ESP Change-out by Nabors 4ES-2/15/1999 TD=5,714'(MD)/TD=4,701'(1VD) ESP Change-out by Nabors 3S-12/8/2008 PBTD=5,614'(MD)/PBTD=4,609'(1VD) ESP Change-out by Doyon 14-3/24/2013 WELL STIMULATION Gravel Pack:5,022'to 5,094' Created By:TDF 1/29/2016 410 • Milne Point Unit ., ti Well: MPU G-02 PROPOSED Last Completed: 3/19/2013 Hi!carp Alaska,LLC PTD: 189-028 TREE&WELLHEAD KB Elev.:59.3 MSL Lo Tree 5M FMC 2-9/16" °z 1Wellhead 11"5M FMC w/2-7/8"WKM Tbg.Hngr.,w/2-7/8"8rd top, 20g, 1 ..:j 2-7/8"lower,2-1/2"CIW H BPV profile OPEN HOLE/CEMENT DETAIL '`45 i ,/ 2 13-3/8" 60 bbls of Arcticset to surface in 30"Hole 4 9-5/8" 171 bbls of 12.3ppg PF"E"/123 bbls of 15.8 ppg Prem."G"in a 12-1/4"Hole 7" 65 bbls of 15.6 ppg Prem."G"in 8-1/2"Hole 0 ., ; �. CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF !r I ° 13-3/8" Conductor 48/1-1-40/Btrs 12.715 Surface 110' 0.157 1. ' i; 9-5/8" Surface 47/L-80/Btrs 8.681 Surface 2,856' 0.0732 1. 7" Production 29/L-80/Btrs 6.184 Surface 5,694' 0.0372 v TUBING DETAIL f i iz _: +< 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface 27' 0.00579 v. ? k7 2-3/8" Tubing 4.7/1-55/8rd EUE 1.995 27' 4,605' 0.00387 VRt 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 4,605' 4,658' 0.00579 WELL INCLINATION DETAIL KOP @ 500' %.4 I Max Hole Angle=48 deg. 4S'''.. 41 s � x� Max Hole Angle through perforations=27 deg. Mt 1 ¢ F I�¢ � . JEWELRY DETAIL x . ,e ' t �5/g� ,A, 3 r No Depth Item 1 27' XO Pup 2-7/8"x 2-3/8" 2 195' GLM STA#2:2-3/8"x 1"KBMM w/Screen Estimated TOC 3 4,425' GLM STA#1:2-3/8"x 1"KBMM w/Dummy @±3,500 4 4,563' 2-3/8"XN-Nipple(1.79 No-go ID) 5 4,605' XO Pup 2-3/8"B x 2-7/8"P Proposed Patch @ l 6 4,606' Well Lift Gauge 2-7/8"8rd EUE ±3,900 to±4,100', 'HoleinTubing 7 4,610' Discharge Head:FPHVDIS(2-7/8"EUE) ' @ 3,995' 8 4,611' Pump:141-P6 117 PMSXD 1:7 '` 9 4,627' Gas Separator:GRSFTX AR H6(400 Internals) MIN ID=1.79E , p @4,563' �A 4 aN 10 4,632' Upper Tandem Seal:GSB3DB UT/LT AB/AB PFSA 11 4,639' Lower Tandem Seal:GSB3DB UT/LT AB/AB PFSA 5 '.s 12 4,645' Motor:MSP1-84 Hp/2,210V/23 A 6&7 13 4,654' Sensor:WellLift MGU with Centralizer-Bottom @ 4,658' 14 4,669' Baker SC-1L Packer 7082-40-4.0"ID 8 15 4,678' Sliding Sleeve-4.0"ID * 16 4,704' 2-7/8"Shear out Safety Joint w/44K Shear-2.43"ID 1` III 9 17 5,001' Bakerweld 2-7/8"0.012"Ga.Screen 96'w/2.44"ID v, filL X10&11 18 5,097' 0 Ring Seal Sub i 7 C.i 19 5,098' Bakerweld 2-7/8"0.012"Ga.Tell Tale Screen-11'w.2.44"ID 20 5,109' Baker S-22 Snap Latch Seal Assembly 12 21 5,110' Baker Model D Permanent Packer PERFORATION DETAIL 13 i.. Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status st 5,022' 5,046' 4,064' 4,086' 24 See Below Open ria, ;`_� 314 Schrader"N" 5,056' 5,076' 4,095' 4,113' 20 See Below Open 15 Sands 5,085' 5,094' 4,121' 4,129' 9 See Below Open X16 Schrader ds 17 Perforation Charge Detail:4-5/8"Vann Gun Assembly-24SPF Executed on 3/30/1990&4/7/1990 , 18 GENERAL WELL INFO T4:'," API:50-029-21926-00-00 r19 .?-...2:-.4.11.1.1..?-...2:-.4.11.1.1. k"20&21 Drilled and Cased by Parker 141-8/29/1989 t mj Perforate,Gravel Pack&Test by Pool#102-5/10/1990 T k Completed with ESP by EWS Rig#4 -11/20/1990 ESP Change-out by Nabors 4ES-2/15/1999 TD=5,714'(MD)/TD=4,701'(TVD) ESP Change-out by Nabors 35-12/8/2008 PBTD=5,614'(MD)/PBTD=4,609'(TVD) ESP Change-out by Doyon 14-3/24/2013 WELL STIMULATION Gravel Pack:5,022'to 5,094' Created By:TDF 1/29/2016 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. / .'~9"' 0~,~ File Number of Well History File PAGES TO DELETE 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 Complete COMMENTS: Scanned by: ~Bren TO RE-SCAN Notes: Vincent Nathan Lowell Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: /si NOTScanned.wpd STATE OF ALASKA AISKA OIL AND GAS CONSERVATION CcISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS ,APR 16 ' 2013 1. Operations Performed: Ati,JG\./V ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver IN Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic .r 189 - 028 3. Address: Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 -" 50 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025906 ' ✓ MPG - 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): r Milne Point Unit / Schrader Bluff 11. Present well condition summary: Total depth: measured 5714' feet Plugs:(measured) None feet true vertical 4701' feet Junk: (measured) None feet Effective depth: measured 5613' feet Packer: (measured) 4669' , 5110' feet true vertical 4608' feet Packer: (true vertical) 3770' , 4143' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 13 -3/8" 110' 110' 1740 750 Surface 2856' 9 -5/8" 2856' 2485' 6870 4760 Intermediate Production 5694' 7" 5694' 4683' 8160 7020 Liner Perforation Depth: Measured Depth: 5022' - 5094' feet True Vertical Depth: 4064' - 4129' feet Tubing (size, grade, measured and true vertical depth): 2 -3/8 ", 4.7# J -55 4658' 3761' Packers and SSSV (type, measured and true vertical depth): 7B Gr r av SC -1 L el Pack Packer Screen Baker Mode Assembly frl "D" om Pa 466cker 9' - 5110' 4669' , 5110' 3770' , 4143' Bake 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED APR 2 4 2.013 Treatment description 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: 30 11 42 220 193 Subsequent to operation: 55 19 77 260 197 14. Attachments: ❑ Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory ❑ Stratigraphic' 'Z Development ❑ Service ® Daily Report of Well Operations 16. Well Status after work: ' ■1 Oil ❑ Gas ❑ WDSPL _ Well Schematic Diagram ❑ 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: Contact: David Bjork, 564 -5683 N/A Email: David.Bjork @bp.com Printed N e: Joe L st a Title: Drilling Technologist Signature. ��— Phone: 564 -4091 Date: 4I1 1 Form 10 -404 R ' ed 10/20 DMS APR 18 203 ,' , " ILF 'Wig 1 J 3 �/j� _ / Submit Original Only < � • NothAmerica - ALASKA " - - 4* Rid, Operation Summary: Report Common Well Name: MPG -02 AFE No (W ) S Event Type: WORKOVER O Start Date: 3/18/2013 I End Date: 3/25/2013 X4- 00X68 - E:DRILL (1,200,000.00 " Project: Milne Point Site: M Pt G Pad Rig Name/No.: DOYON 16 Spud Date/Time: 8/22/1989 12:00:00AM Rig Release: 3/25/2013 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °26'57.264 "4 Long: 0149 °31'58.520 "W Active datum: ORIG KELLY BUSHING @48.50usft (above Mean Sea Level) Date From - To Hrs I Task Code 1 NPT NPT Depth Phase Description of Operations (hr) _ (usft) 3/18/2013 ! 12:00 - 14:00 2.00 I MOB P PRE CLEAN UP CELLAR AREA IN MPG -18. ! PREP TO MOVE RIG. -- - --- -- --- - - - -- 1 14:00 - 15:30 1.50 MOB P PRE I MOVE RIG OFF WELL 18 AND DOWN THE PAD I !TO WELL 02. SET RIG DOWN, SHIM TO LEVEL AND START 15:30 17:00 1.50 -iI RIGGING UP. MOB P PRE RIG UP. BERM AROUND CELLAR. SPOT CHANGE TRAILER AND FUEL TANK. 17:00 - 19:30 2.50 MOB P PRE PJSM, RU TO PT KILL MANIFOLD AND I HARDLINE TO FBT. - PRESSURE TEST KILL MANIFOLD AND HARD LINE. - 250 / 3500 PSI FOR 5 CHARTED MIN. PASSED. - TEST ALARM ON FLOW BACK TANK. - ACCEPT RIG AT 17:00 HRS 19:30 22:00 2.50 ! MOB P PRE FILL PITS FILL PITS WITH 110 DEG F 1% KCL 22:00 - 23:30 1.50 MOB P PRE ! PREP FOR MORNING KILL I CLEAN & CLEAR RIG, COMPLETE WORK _ ORDERS AND GENERAL MAINTENANCE 23:30 - 00:00 0.50 MOB I P PRE HELD H2S EVAC DRILL. I AAR - WSL, TOOLPUSHER, SCS, RIG CREW, THIRD PARTY PERSONNEL ACCOUNTED FOR. - SIREN COULD BE HEARD BY ALL PERSONNEL INVOLVED ON BOTH SIDES OF RIG. ACTION FOR THIS CREW WAS TO ASSIGN ROUSTABOUT TO BLOCK 2ND ENTRANCE TO PAD WITH CREW VAN AND COMMUNICATE - – — VIA VAN RADIO 3/19/2013 00:00 - 00:30 0.50 MOB P PRE PRE -TOUR MEETING< SPCC CHECKS 00:30 01:00 0.50 MOB P PRE HELD H2S EVAC DRILL. S AAR - ALL PERSONNEL ON LOCATION ARRIVED AT PRIMARY SAFE AREA IN TIMELY MANNER I- DISCUSSION AT SAFE AREA REGARDING 'NEXT STEPS' FOR TOOL PUSHER AND WSL - ACTION FOR THIS CREW WAS TO ASSIGN ROUSTABOUT TO BLOCK 2ND ENTRANCE TO PAD WITH CREW VAN AND COMMUNICATE VIA VAN RADIO 01:00 - 02:00 1.00 WHSUR li P WHDTRE ' PJSM, PU DSM LUBRICATOR. - PICK UP DSM LUBRICATOR I- RU TEST HOSES. - TEST LUBRICATOR TO 250 / 3500 PSI FOR_5 CHARTED MIN. EACH. _ 02:00 - 06:00 4.00 WHSUR N WAIT WHDTRE PREPARE FOR DAYLIGHT KILL. 06:00 - 07:50 1.83 WHSUR 'I P DECOMP PULL BPV. VERIFY VALVE LINEUP. PJSM WITH CREWS FOR KILLING WELL. SCS MAKES NOTIFICATIONS TO PAD OPERATOR AND MPU SECURITY FOR GAS VENTING. Printed 4/8/2013 10:19:38AM • • Nor2 A =fit - - ;,., „. "' v: Operation Surimna : e{p # rt Common Well Name: MPG -02 AFE No Event Type: WORKOVER (WO) I Start Date: 3/18/2013 End Date: 3/25/2013 X4- 00X68 - E:DRILL (1,200,000.00 ) I -1 Project Milne Point 1 Site: M Pt G Pad Rig Name/No.: DOYON 16 Spud Date/Time: 8/22/1989 12:00:00AM Rig Release: 3/25/2013 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °26'57.264"4 Long: 1 0149°31'58.520"W Active datum: ORIG KELLY BUSHING @48.50usft (above Mean Sea Level) Date From - To Hrs ' Task Code NPT 1 NPT Depth , Phase 1 Description of Operations (hr) (usft) 07:50 - 10:25 2.58 KILLW P DECOMP 1 START BLEEDING GAS FROM IA. ' BLEED IA FROM 500 PSI TO ZERO IN 13 MIN. ,SMALL AMOUNT OF FLUID AT THE END. PUMP 10 BBLS DOWN TUBING AT 3 BPM TO I 1ENSURE ITS CLEAR. I 1 OPEN UP TO IAAND PUMP 450 BBLS DOWN IA 'AND TUBING AT 7 BPM. ICP = 100 PSI, FCP = • 1 PSI. AFTER 450 BBLS SHUT DOWN, ALLOW TUBING AND IA TO BLEED OFF. AFTER 30 MIN IA IS ZERO, 40 MIN TUBING IS ZERO. 10:25 - 11:05 0.67 KILLW P DECOMP I OPEN IA AND TUBING, MONITOR PRESSURES. TUBING IS ON VAC, IA IS DEAD. 1 ------ -- - -- - -- — - - - - -- 11:05 - 12:30 1.42 WHSUR P DECOMP FILL IA WITH 5 BBLS. PREP TO SET TWC. 12:30 - 14:00 1.50 WHSUR P DECOMP SET TWC. PERFORM ROLLING TEST DOWN IA TO_P_T__ TWC FROM BELOW. � PUMP 1 BPM INTO ANNULUS TO GET TO 500 1 PSI, PUMP FOR 10 MIN. !PRESSURE UP TWC FROM ABOVE, TEST TO 250 / 3500 PSI, GOOD. 14:00 - 15:00 I 1.00 WHSUR P DECOMP I BLOW DOWN LINES THAT WERE USED EARLIER IN CELLAR FOR WELL KILL. HOOK UP SECONDARY FILL LINE TO IA. 15:00 - 18:00 3.00 WHSUR P DECOMP PJSM WITH CAMERON AND DOYON CREWS FOR RIGGING DOWN TREE. BREAK TUBING SPOOL BOLTS LOOSE. LIFT UP TREE, STORE IT IN A CORNER OF THE CELLAR. CAMERON CREW FUNCTION LDS. CHECK HANGER THREADS, 2 7/8” EUE 8RD, 9.5 TURNS RH 18:00 - 20:00 2.00 BOPSUR P DECOMP .i PJSM FOR NIPPLE UP BOP N/U 3 PREVENTOR BOP STACK '- ANNULAR PREVENTOR, BLIND SHEAR RAMS, MUD CROSS, 2 3/8 LOWER SOLID BODY PIPE RAMS - JEFF JONES OF AOGCC WAIVED STATES RIGHT TO WITNESS BOP TEST AT 19:45 HOURS 20:00 - 21:00 1.00 BOPSUR P DECOMP 1 R/U BOP TEST EQUIPMENT 1- M/U FLOOR VALVES AND TEST JOINT - FILL STACK AND CHECK FOR LEAKS 21:00 - 22:00 1.00 BOPSUR P DECOMP PERFORM INITIAL BODY TEST - FOUND NEWAPI RING LEAKING, TIGHTENED FLANGE = GOOD - FOUND KILL SIDE OTECO RING LEAKING, REPLACE = GOOD Printed 4/8/2013 10:19:38AM North America - ALASKA BP , • . Operation Summary Report . Common Well Name: MPG -02 AFE No Event Type: WORKOVER (WO) Start Date: 3/18/2013 End Date: 3/25/2013 X4- 00X68 -E: DRILL (1,200,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/22/1989 12:00:00AM Rig Release: 3/25/2013 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °26'57.264 "4 Long: 0149 °31'58.520 "W Active datum: ORIG KELLY BUSHING @48.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) L (usft) 22:00 - 00:00 2.00 BOPSUR P DECOMP PJSM, TEST THREE PREVENTER BOPE AND RELATED EQUIPMENT TEST BOPE ACCORDING TO AOGCC RE U�, LATIOIANYOfPROCFDURES, - TEST ANNULAR WITH 2 3/8" TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES EACH, CHARTED - TEST 2 3/8" SOLID BODY PIPE RAMS, 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST BLIND RAMS, FLOOR VALVES, AND CHOKE MANIFOLD TO 250 PSI, 3500 PSI, 5 MIN, CHARTED TEST WITH FRESH WATER 1 - AFTER A GOOD TEST ON THE 2 3/8" PIPE RAMS, FOUND GLAND NUT & LDS AT TUBING HANGER LEAKING C - ATTEMPTED TO TIGHTEN GLAND NUT TO Q STOP LEAK = UNSUCCESSFUL - CALL OUT CAMERON REP FROM PRUDHOE TO REPAIR GLAND NUT AND LOCK DOWN !PACKING CONTINUE TO TEST CHOKE MANIFOLD VALVES OA = 0 PSI - LOSS RATE = 14 BPH - FLUID LOSS = 137 BBLS 8.4 KCL (DOES NOT INCLUDE 503 BBLS BULLHEADED DURING WELL KILL) - - - -- - - - -- 3/20/2013 00:00 - 07:00 7.00 BOPSUR P DECOMP PJSM, TEST THREE PREVENTER BOPE AND RELATED EQUIPMENT TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES - TEST ANNULAR WITH 2 3/8" TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES EACH, CHARTED - TEST 2 3/8" SOLID BODY PIPE RAMS, 250 PSI, 3500 PSI, 5 MIN, CHARTED TEST BLIND RAMS, FLOOR VALVES, AND CHOKE MANIFOLD TO 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST WITH FRESH WATER - CAMERON REP. C/O LOCK DOWN PACKING = TESTED GOOD ALL COMPONENTS PASS EXCEPT ANNULAR PREVENTER. I I i I_ JEFF JONES OF AOGCC WAIVED STATES RIGHT TO W ITNESS BOP TEST AT 19:45 HOURS ON 3/19/2013 TEST IS WITNESSED BY TOURPUSHER, WSL. 07:00 - 09:30 2.50 BOPSUR N RREP DECOMP PJSM FOR CHANGING OUT ANNULAR ELEMENT. MOVE CIRCULAR PLATE WITH DRILLPIPE CONNECTION INTO CELLAR. LIFT UP PLATE AND BOLT TO TOP CAP OF ANNULAR. REMOVE INDEXING PIN FROM TOP CAP OF 'ANNULAR. Printed 4/8/2013 10:19:38AM . • • Notth �eFic a - ALASKA" - BP • 4 Ao ' Operation Summary Report , " " : " Common Well Name: MPG -02 AFE No Event Type: WORKOVER (WO) Start Date: 3/18/2013 End Date: 3/25/2013 X4- 00X68 -E: DRILL (1,200,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/22/1989 12:00:00AM Rig Release: 3/25/2013 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °26'57.264 "4 Long: 0149 °31'58.520 "W Active datum: ORIG KELLY BUSHING @48.50usft (above Mean Sea Level) Date I From - To I Hrs I Task I Code I NPT I NPT Depth Phase I Description of Operations (hr) (usft) 09:30 - 12:00 2.50 BOPSUR , N RREP I DECOMP • MAKE UP SHORT JOINT OF DRILL PIPE TO • 1 !CIRCULAR BREAKOUT PLATE. USE BREAKOUT TONGS ON RIG FLOOR TO I I UNSCREW ANNULAR CAP. I I UNPIN JOINT OF DP AND LAY DOWN. ' LIFT ANNULAR CAP AWAY TO THE SIDE OF THE STACK AND LOWER IT DOWN. REMOVE OLD ANNULAR ELEMENT. 1 12:00 - 14:00 2.00 BOPSUR 1 N RREP i DECOMP INSPECT SEALS INSIDE ANNULAR BODY. I LIFT UP NEWANNULAR ELEMENT AND PUT IN I PLACE. ' I LIFT ANNULAR CAP UP, START THREADS THEN USE RIG TONGS TO MAKE IT UP. LINE UP ALIGNMENT PIN ON CAP. REMOVE JOINT OF HWDP, LAY DOWN. 14:00 - 16:00 2.00 BOPSUR I N RREP ' I DECOMP I' UNBOLT CIRCULAR PLATE FROM ANNULAR CAP, LAY IT DOWN. INSTALL BELL NIPPLE. HOOK UP HYDRAULIC HOSES. I VAC OUT STACK DOWN TO TWC, LOOK FOR ANY RUBBER PIECES, NONE FOUND. 16:00 - 18:00 2.00 BOPSUR P DECOMP FUNCTION TEST ANNULAR, GOOD. RIG UP 2 -3/8" TEST JOINT. 18:00 - 18:30 0.50 I BOPSUR P I r DECOMP TEST ANNULAR WITH 2 3/8" TEST JOINT i ! I - 250 PSI / 3500 PSI, 5 MIN, CHARTED = GOOD ' TEST 18:30 - 19:00 0.50 BOPSUR ; P DECOMP I R/D TEST EQUIPMENT I I - BLOW DOWN CHOKE AND ALL LINES BEING I TESTED - R/D AND UD TEST JOINT_ 1 - 21:00 2.00 1 WHSUR P DECOMP PJSM WITH DSM CREW - M/U DSM OFF -SET LUBRICATOR TO HANGER I - TEST TO 250 PSI / 3500 PSI, 5 MIN, CHARTED - WSL VERIFY NO PRESSURE ON IA, IA IS ON I 'A VAC I- PULL TWC • _ --- L/D DSM LUBRICATOR 21:00 - 22:30 1.50 WHSUR P DECOMP PJSM WITH CREW, CAMERON AND I CENTRILIFT I - M/U LANDING JOINT AND FOSV TO HANGER '; 1 I- WSL VERIFY NO PRESSURE ON IA, IA IS ON I • A VAC I - CAMERON BOLDS, 2 OF THE LDS WERE TIGHT, WORKED ON THEM UNTIL FREE, I- MAINTAINED CONSTANT HOLE FILL THRU IA WHILE WORKING ON LDS AT 14 BPH WITH 8.4 PPG '22:30 23:30 1.00 PULL P DECOMP PULL HANGER TO RIG FLOOR 1- HANGER PULLED FREE AT 75K (INCLUDES 1 40K BLOCK WT) • 1 I - PUW W T = 65K, SO1 = 65K - DISCONNECT ESP CABLE AND HEAT TRACE FROM HANGER PENETRATORS ' - PULL UP TO FIRST FULL JOINT BELOW • 1 HANGER, CUT ESP CABLE AND HEAT TRACE • - LOWER HANGER BACK DOWN TO FLOOR ! UD LANDING JOINT ' M/U FOSV TO HANGER _ Printed 4/8/2013 10:19:38AM • • With America r ALASKA = BP ' . Fags 6 of 1 a' Operation "Summary Report Common Well Name: MPG -02 AFE No Event Type: WORKOVER (WO) Start Date: 3/18/2013 End Date: 3/25/2013 X4- 00X68 - E:DRILL (1,200,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/22/1989 12:00:00AM Rig Release: 3/25/2013 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °26'57.264 "4 Long: 0149 °31'58.520 "W Active datum: ORIG KELLY BUSHING @48.50usft (above Mean Sea Level) _ Date From - To Hrs Task 1 Code I NPT NPT Depth Phase I Description of Operations (hr) (usft) 23:30 - 00:00 0.50 PULL I P DECOMP I FILL IAAND TUBING = 13 BBLS TO FILL CLOSE ANNULAR, LINE UP TO CIRCULATE THRU GAS BUSTER - PUMP ONE TUBING VOLUME, 3 BPM = 740 PSI - 20 BBLS CRUDE RETURNED BEFORE BEGINNING TO CLEAN UP PUMP A TOTAL OF 50 BBLS I- PUMPS OFF, WSL ENSURE NO PRESSURE I ON IA ;- OPEN ANNULAR, MONITOR WELL FOR 10 MINUTES ESTABLISH LOSS RATE = 12 BPH ' I i - OA= 0 PSI - LOSS RATE = 12 BPH - 24 HOUR FLUID LOSS = 239 BBLS 8.4 KCL 3/21/2013 00:00 - 01:30 1.50 PULL P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - CONTINUE MONITOR WELL, LOSS RATE = 1 12 BPH PUMP DEEP CLEAN SURFACE TO SURFACE I TO CLEAN PIPE, 4 BPM = 1440 PSI I- HANG ESP SHEAVE AND TRUNK 1- R/U CENTRILIFT EQUIPMENT 1 01:30 - 02:00 0.50 PULL P DECOMP PJSM FOR PULLING ESP COMPLETION - MONITOR WELL 10 MINUTES, LOSS RATE = 8 BPH - BLOW DOWN CHOKE AND KILL LINES, DRAIN GAS BUSTER 4. 02:00 - 06:00 4.00 PULL P DECOMP L/D HANGER - POOH WITH 2 3/8" 4.7# EUE 8RD ESP IX\ COMPLETION WITH HEAT TRACE - FROM 4649', TO 3411' (AT 6:00) - PUWT= 65K, SOWT = 65K 06:00 - 13:30 7.50 PULL P DECOMP CONTINUE POOH WITH 2 -3/8" 4.7# EUE 8RD ESP COMPLETION WITH HEAT TRACE. L/D ABOUT 15 JTS /HR. AROUND 08:50 CONDUCT A KICK WHILE TRIPPING DRILL. GOOD RESPONSE BY CREWS. SIMULATE CUTTING THE WIRE, THEN LOWER THE SLICK JOINT DOWN, MAKE UP TIW, CLOSE ANNULAR. ESTIMATE TIME TO SHUT IN WELLABOUT 2 I MIN. CONDUCT AAR AFTERWARDS. CONTINUE L/D PIPE. 13:30 - 15:00 1.50 PULL P DECOMP AT 120 JTS LAID DOWN, CONDUCT KICK WHILE TRIPPING DRILL. ESTIMATED TIME TO SHUT IN WELL ABOUT 2 MIN. CONDUCT AAR AFTERWARDS. CONTINUE L/D 2 -3/8" PIPE. 15:00 - 18:00 3.00 PULL P T DECOMP I BRING ESP PUMP TO RIG FLOOR. CUT OFF CABLE. BREAK DOWN PUMP FOR SHIPPING. SPOOL UP REMAINING ESP CABLE TO THE SPOOLING UNIT. I- ALL CLAMPS RECOVERED Printed 4/8/2013 10:19:38AM • • W'E:1, mei'� ALAS - N P... ,.' Pafge6cf10 Operation S "mmary Report . - Common Well Name: MPG -02 AFE No Event Type: WORKOVER (WO) Start Date: 3/18/2013 End Date: 3/25/2013 X4- 00X68 - E:DRILL (1,200,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name/No.: DOYON 16 Spud Date/Time: 8/22/1989 12:00:00AM Rig Release: 3/25/2013 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °26'57.264 "4 Long: 0149 °31'58.520 "W Active datum: ORIG KELLY BUSHING @i48.50usft (above Mean Sea Level) Date From - To Hrs Task 1 Code ' NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 19:30 1.50 PULL P DECOMP R/D CENTRILIFT EQUIPMENT - CLEAR AND CLEAN RIG FLOOR ' - M/U RUNNING TOOL _ - SET WEAR RING, ID = 6 1/4" 19:30 - 00:00 4.50 CASING P DECOMP PJSM TO M/U CHAMP PACKER - M/U 7" CHAMP PACKER - RIH ON 2 3/8" TUBING 1X1 FROM PIPE SHED - FROM SURFACE TO 2795' - OA =0PSI - LOSS RATE = 8 BPH - 24 HOUR FLUID LOSS = 189 BBLS 8.4 KCL 3/22/2013 00:00 - 03:00 3.00 CASING P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - RIH WITH 7" CHAMP PACKER ON 2 3/8" TUBING'1X1 FROM PIPE SHED - FROM 2795' TO 4550' - PUWT = 54K, SOWT = 57K - LOSS RATE DURING TRIP = 7 BPH 03:00 - 03:30 ' 0.50 CASING P DECOMP R/U TEST EQUIPMENT - CIRCULATE / WASH PACKER, 4 BPM = 1010 I PSI - SET 7" CHAMP PACKER AT 4550' WITH 15K DOWN WT 03:30 - 04:30 1.00 i CASING P 1 DECOMP J IT -IA 7 CASING - PRESSURE TEST 7" CASING TO 1500 PSI, 30 MIN, CHARTED = GOOD TEST - MONITOR OA PRESSURE DURING TEST = 0 PSI - MAINTAIN CONSTANT FILL DOWN TUBING DURING TEST - NOTIFY WTL OF GOOD CASING TEST, RECEIVE AUTHORIZATION TO PROCEED 04:30 - 05:00 0.50 CASING P DECOMP I RELEASE CHAMP PACKER - PICK UP TO PUWT TO OPEN PACKER BYPASS, VERIFY ON LOSS RELEASE PACKER - MONITOR WELL 10 MIN = WELL IS ON LOSSES - RIG DOWN TEST EQUIPMENT - BLOW DOWN TOP DRIVE AND TEST LINES 05:00 - 06:00 1.00 CASING P DECOMP POOH WITH 7" CHAMP PACKER UD 2 3/8" TUBING 1X1 I - FROM 4550' TO 4240' (AT 6:00) 1 ' 06:00 - 10:30 4.50 CASING P DECOMP CONTINUE L/D 2 -3/8 TUBING. 120 JTS UD AS OF 0920. 10:30 - 11:00 0.50 CASING P DECOMP BRING PACKER TO FLOOR AND LAY IT DOWN. PULL WEAR BUSHING OUT. 11:00 - 11:30 0.50 RUNCOM P RUNCMP I MAKE DUMMY RUN WITH HANGER TO i ENGAGE INDEXING PIN ON TUBING HANGER. — - 11:30 - 12:30 1.00 RUNCOM P RUNCMP PREP RIG FLOOR TO RUN COMPLETION. 12:30 - 16:00 3.50 RUNCOM P RUNCMP PJSM FOR PICK UP AND ASSEMBLY OF ESP. REVIEW PROCEDURE. ASSEMBLE ESP ON RIG FLOOR AS PER — _ " CENTRILIFT REP. Printed 4/8/2013 10:19:38AM " • • " " : Nof#h �rrter� "- ia►LAS�SA w: BP : <;, ; . "..:, - .: . °Operation 'Summary. Report Common Well Name: MPG -02 AFE No Event Type: WORKOVER (WO) Start Date: 3/18/2013 End Date: 3/25/2013 IX400X68- E:DRILL (1,200,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name/No.: DOYON 16 I Spud Date/Time: 8/22/1989 12:00:00AM Rig Release: 3/25/2013 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °26'57.264 "4 Long: 0149 °31'58.520 "W Active datum: ORIG KELLY BUSHING @48.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 1 (usft) 16:00 - 18:30 2.50 RUNCOM P RUNCMP RUN ESP CABLE AND HEAT TRACE UP THROUGH SHEAVE ABOVE WINDWALL. TERMINATE CABLE TO ESP MOTOR AND PUMP ASSY 18:30 - 00:00 5.50 RUNCOM P RUNCMP 1 RIH WITH 2 3/8" 4.7# J -55 EUE 8RD TUBING ESP COMPLETION - P/U FROM PIPE SHED 1X1 FROM ESP I ASSEMBLY TO 1500' MD. I- TUBING TORQUE = 1300 FT /LBS - INSTALL CANNON CLAMPS ON EVERY COLLAR ON THE FIRST 9 JOINTS, THEN EVERY OTHER JOINT THEREAFTER TO 1050' - STRING HEAT TRACE OVER SHEAVE AND I ATTACH AT JOINT #35, INSTALL CANNON CLAMP PER CENTRILIFT REP / TALLY 1- CHECK ESP CABLE CONDUCTIVITY EVERY 2000', CHECK HEAT TRACE EVERY 1000' - PUMP 5 BBLS TO FLUSH THRU PUMP AT .50 BPM = PSI EVERY 2000', NOT TO EXCEED 3000 PSI -OA =0 PSI LOSS RATE = 6 BPH - 24 HOUR FLUID LOSS = 156 BBLS 8.4 KCL 3/23/2013 00:00 - 01:00 1.00 RUNCOM P RUNCMP PJSM, PERFORM SPCC AND EQUIPMENT ICHECKS - SERVICE RIG, INSPECT TOP DRIVE AND I DRAW WORKS - CENTRILIFT HAND CHECK CONDUCTIVITY 01:00 - 06:00 5.00 RUNCOM P RUNCMP RIH WITH 2 3/8" 4.7# J-55 EUE 8RD TUBING ESP COMPLETION WITH HEAT TRACE - CONTINUE RIH 1X1 FROM 1500' TO 2433' MD (AT 6:00) - TUBING TORQUE = 1300 FT /LBS - CHECK ESP CABLE CONDUCTIVITY EVERY 12000', CHECK HEAT TRACE EVERY 1000' - PUMP 5 BBLS TO FLUSH THRU PUMP AT .50 BPM = 1490 PSI AT 2000' (JT 65) 06:00 - 13:30 7.50 ; RUNCOM P RUNCMP ; CONTINUE RIH WITH 2 3/8" 4.7# J -55 EUE 8RD TUBING ESP COMPLETION WITH HEAT TRACE. AVERAGE ABOUT 8 JTS /HR. 0630 BRING IN ANOTHER BOX OF CLAMPS. 0900 CHECK HEAT TRACE AND ESP CABLE AFTER 90 JTS RAN. CONTINUE RIH WITH 2 3/8" 4.7# J -55 EUE 8RD TUBING ESP COMPLETION WITH HEAT TRACE. 13:30 - 15:00 1.50 RUNCOM P 1 RUNCMP AFTER 119 JTS PUMP 0.5 BPM / 1730 PSI THROUGH TUBING FOR 5 BBLS. CHECK CABLE CONTINUITY. BRING IN ANOTHER BOX OF CLAMPS. CONTINUE RIH WITH 2 3/8" 4.7# J -55 EUE 8RD TUBING ESP COMPLETION WITH HEAT TRACE. Printed 4/8/2013 10:19:38AM S • .„ .......„,. „„ „ .„. a pe ary R+�'port ration Summ , Common Well Name: MPG -02 AFE No Event Type: WORKOVER (WO) Start Date: 3/18/2013 End Date: 3/25/2013 X4- 00X68 - E:DRILL (1,200,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/22/1989 12:00:00AM Rig Release: 3/25/2013 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °26'57.264 "4 Long: 0149 °31'58.520 "W Active datum: ORIG KELLY BUSHING @48.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 19:30 4.50 RUNCOM P RUNCMP JOINT #122 IS DAMAGED BY THE SLIPS. LAY IT BACK DOWN IN THE SHED, PICKUP A SIMILAR LENGTH SPARE JOINT. • 1- RIH WITH ESP COMPLETION, HEAT TRACE FROM 3305', TO 4534' PUMP 5 BBLS TO FLUSH THRU PUMP AT .50 BPM = 1730 PSI AT 3700' 19:30 - 20:00 0.50 RUNCOM P RUNCMP • CHANGE OUT ELEVATORS TO 2 7/8" I- INSTALL TWC IN HANGER, WELL IS ON CONSISTENT 6 BPH LOSSES - M/U 2 7/8" EUE 8RD LANDING JOINT TO HANGER - M/U HANGER TO STRING, CAMERON REP'S VERIFY POSITION OF LOCK PIN LOCATOR ON HANGER 20:00 - 23:00 3.00 RUNCOM P RUNCMP INSTALL HANGER PENETRATORS - CENTRILIFT REP TERMINATE ESP AND HEAT TRACE CABLES AT PENETRATORS - TEST CONDUCTIVITY OF BOTH LINES i- CLAMPS USED: i - 5' DUEL CHANNEL = 544 - 2' SINGLE CHANNEL HEAT TRACE = - STD DUEL CHANNEL = 109 - STD ESP SINGLE CABLE = 17 - PROTECTOLIZERS = 3 - FLAT GUARDS = 2 - HALF CLAMPS = 2 -STEEL BANDS =3 RUNCOM P 23:00 - 23:30 0.50 RUNCMP ' LAND HANGER WSL AND CAMERON REP VERIFY "J -IN" ON LOCATOR PIN 23:30 - 00:00 0.50 RUNCOM P RUNCMP CAMERON HANDS RUN IN LOCK DOWN SCREWS �I I - OA =0PSI - LOSS RATE = 6 BPH ,- 24 HOUR FLUID LOSS = 95 BBLS 8.4 KCL 3/24/2013 00:00 - 00:30 0.50 RUNCOM P RUNCMP PJSM, PERFORM SPCC AND EQUIPMENT !CHECKS I- L/D LANDING JOINT - R/U TO TEST TWC - CAMERON HANDS EXPERIENCING DIFFICULTIES WITH ONE LDS - GLAND NUT IS WORKING PROPERLY 1 - RETRIEVE NEW LDS FROM CAMERON SHOP 00:30 - 02:00 1.50 WHSUR P RUNCMP PJSM, TEST TWC - TEST TWC FROM BELOW, .5 BPM = 500 PSI, i10 MIN - LOST 14 BBLS DURING ROLLING TEST, MONITOR PRESSURE TO 0 PSI - TEST TWC FROM ABOVE, 250 / 3500 PSI, 5 IN, CHARTED 02:00 - 03:00 1.00 WHSUR P RUNCMP PJSM, R/D ESP SHEAVE FROM DERRICK CLEAR RIG FLOOR OF CENTRILIFT — — ' EQUIPMENT 03:00 - 04:00 1.00 WHSUR P RUNCMP SUCK OUT BOP STACK - BLOW DOWN ALL LINES 1 - MAINTAIN CONTINUOUS HOLE FILL DOWN IA • WITH 8.4 KCL BRINE Printed 4/8/2013 10:19:38AM • • ' , North America - ALASKA - BP of 4 Operation Summary Report Common Well Name: MPG -02 I AFE No Event Type: WORKOVER (WO) Start Date: 3/18/2013 End Date: 3/25/2013 1X4- 00X68 - E:DRILL (1,200,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/22/1989 12:00:00AM Rig Release: 3/25/2013 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °26'57.264 "4 Long: 0149 °31'58.520 "W Active datum: ORIG KELLY BUSHING @48.50usft (above Mean Sea Level) Date From - To I Hrs I Task Code 1 NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 05:00 l 1.00 BOPSUR P RUNCMP PJSM, N/D BOP STACK - CENTRILIFT REP PERFORM FINAL CHECKS ON PENETRATORS - ESP CABLE CONDUCTIVITY = GOOD 05:00 - 06:00 1.00 WHSUR N DFAL RUNCMP HEAT TRACE CABLE SHOWS THAT IT IS IGROUNDED '- DISCUSS OPTIONS WITH MPU WELL OPS CORD AND ODE I- DISCUSS WITH RWO SUPT. DECISION IS MADE TO RIG UP BOP STACK AND PULL TWC, THEN BRING HANGER TO RIG FLOOR. 06:00 - 06:45 0.75 WHSUR N 1 SFAL RUNCMP RETAP ONE OF THE LDS GLAND NUT THREADS AND RUN IN GLAND NUT. r 1 06:45 - 08:15 I I 1.50 BOPSUR N DFAL RUNCMP PJSM TO REVIEW PROCEDURE FOR RIGGING I UP BOPS. USE BRIDGE CRANE TO MOVE BOPS ONTO TUBING SPOOL, TIGHTEN UP FLANGE BOLTS. 08:15 09:30 1.25 BOPSUR N DFAL RUNCMP FUNCTION TEST BOPS. PJSM THEN MAKE UP OFF - CENTER LUBRICATOR TO PULL TWC. , 'PRESSURE TEST LUBRICATOR AND STACK BREAK TO 250 / 3500 PSI, GOOD. 09:30 - 10:30 1.00 RUNCOM N DFAL RUNCMP PULL TWC, WELL ON VAC. MAKE UP 2 -7/8" LANDING JOINT TO TUBING IHANGER. BACK OUT LDS. ' PULL 67K TO UNSEAT HANGER, PULL TO RIG I FLOOR. 10:30 - 13:00 2.50 RUNCOM N DFAL RUNCMP CENTERLIFT REPS CUT OFF CABLE SPLICE AND RE -DO. 13:00 - 14:00 1.00 RUNCOM N i DFAL RUNCMP SPLICE IS FINISHED, CABLE TEST IS GOOD. TURN OFF HOLE FILL, LET FLUID DROP PAST THE HANGER. LAND HANGER, SLACKOFF WT IS 68K. j I LAY DOWN LANDING JOINT. 14:00 - 15:30 1.50 WHSUR I N DFAL RUNCMP SET TWC. ROLLING TEST FROM BELOW, 0.6 BPM DOWN IA IS 530 PSI. VISUALLY CONFIRM NO LEAKS PAST TWC. PRESSURE TEST TWC FROM ABOVE, 250 / 3500 PSI, GOOD. BOTH TESTS CHARTED. 15:30 - 17:00 1.50 BOPSUR N DFAL RUNCMP I PJSM, REVIEW PROCEDURE FOR RIGGING DOWN BOP STACK. MAINTAIN CONTINUOUS HOLE FILL, 8 -10 I ' BBLS /HR. - CAMERON REP SERVICE / CHASE THREADS ON LOCK DOWN SCREW = GOOD 1 17:00 - 18:00 1.00 BOPSUR N DFAL RUNCMP N/D BOP STACK - CENTRILIFT REP CHECK CONDUCTIVITY ON BOTH ESP AND HEAT TRACE = GOOD TESTS 18:00 - 19:00 1.00 WHSUR P WHDTRE I N/U CAMERON TREE I- WKM 11' X 2 9/16" 5M ADAPTER FLANGE AND TREE 19:00 - 22:00 3.00 WHSUR P WHDTRE TEST ADAPTOR FLANGE VOID PER I 'CAMERON HAND - 250 PSI - 5 MIN, 5000 PSI - 30 MIN, = GOOD 'TEST - TEST TREE, 250 PSI, 5000 PSI, 5 MIN, CHART Printed 4/8/2013 10:19:38AM • • • North Arrierica - ALASKA - BP i0 t 10, Operation Summary Report . Common Well Name: MPG -02 ! AFE No Event Type: WORKOVER (WO) Start Date: 3/18/2013 End Date: 3/25/2013 I X4- 00X68 - E:DRILL (1,200,000.00 ) Project: Milne Point Site: M Pt G Pad , Rig Name /No.: DOYON 16 Spud Date/Time: 8/22/1989 12:00:00AM I Rig Release: 3/25/2013 Rig Contractor: DOYON DRILLING INC. UWI: / Let: 070 °26'57.264 "4 Long: 0149 °31'58.520 "W Active datum: ORIG KELLY BUSHING @48.50usft (above Mean Sea Level) Date From - To Hrs Task 1 Code NPT 1 NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 23:30 1.50 1 WHSUR P WHDTRE PJSM, R/U DSM LUBRICATOR TEST 250 PSI, 3500 PSI, 5 MIN, CHART i - PULL TWC, M/U BPV ON RUNNING TOOL ' I- RE -TEST LUBRICATOR - INSTALL BPV - R/D DSM LUBRICATOR AND EQUIP 23:30 - 00:00 —,- 0.50 WHSUR P WHDTRE PERFORM ROLLING TEST FROM BELOW BPV - .5 BPM = 500 PSI, 10 MIN CHARTED = GOOD -OA =0 PSI - LOSS RATE = 8 BPH T — - 24 HOUR FLUID LOSS = 198 BBLS 8.4 KCL 3/25/2013 00:00 - 01:30 1.50 WHSUR I P WHDTRE ' PJSM, PERFORM SPCC AND EQUIPMENT CHECKS BLOW DOWN ALL LINES IN CELLAR I - R/D TEST EQUIPMENT AND PREP CELLAR FOR RIG MOVE 01:30 - 04:30 3.00 WHSUR P WHDTRE ' PJSM, R/U LITTLE RED SERV. - PUMP HOT OIL FREEZE PROTECT DIESEL TO 2585' - 10 BBLS DOWN TUBING, .3 BPM = 1200 PSI, FINAL = 125 PSI - 80 BBLS DOWN IA, 1.5 BPM = 1200 PSI, FINAL = 400 PSI - R/D LRS 04:30 - 05:00 0.50 WHSUR P WHDTRE PJSM, MOVE RIG OFF OF MPG -02 '- PERFORM MOVING SYSTEM EQUIPMENT AND SPCC CHECKS - FUNCTION TEST EMERGENCY SHUT DOWN - JACK RIG UP AND REMOVE SHIMS ' :- RELEASE RIG AT 05:00 HOURS Printed 4/8/2013 10:19:38AM • Tree: 2 9/16" - 5M FMC O' KB Elev. = 59.3" Wellhead: 11" 5M FMC MPU G -02 Orig. GL Elev. = 28.6" w/ 2 7/8" WKM Tubing Hanger , w/ RT To Tbg. Spool = 28.6" 2 -7/8" 8 rd. top, 2 -3/8" Lower, 2.5" CIW H BPV profile 13 3/8' 48 ppf, H -40 110' 1 Camco 2 3/8" x 1" KBMM 195' GLM KOP @ 500' j Max. hole angle = 48 deg. Hole angle thru' perfs = 27 deg 9 5/8 ", 47 # /ft, L -80 BTC 2,856' Centrilift heat trace 3,500' Camco 2 3/8" x 1" KBMM 4425' 2 3/8" 4.70" ppf, J -55, 8rd EUE tbg. GLM ( drift ID = 1.995 ", cap. = 0.00387 bpf ) 7" 29 ppf, L -80, BTC production csg. HES 2.313" XN- Nipple 4563' ( drift ID = 6.184 ", cap. = 0.0371 bpf) Mil (1.791" No -Go ID) WeIILift Discharge Sensor 4606' Gauge: 3723' TVD Centrilift ESP, 141 -P6 117, 4610' PMSXD 1:1 ik Gas Separator GRSFTxAR H6 4627' Intake: 3738' TVD . Tandem Seal Section 4632' •< GSB3DB UT /LT AB /AB PFSA Motor MSP1 -250 4645' at 84 hp./2210v./23 amps mmir mot WeIILift MGU Sensor W/ 4654' 6 Fin Centralizer Intake Sensor. 3758' TVD Perforation Summary >< Baker SC -1 L Pkr. (4.0" id) 4,669' Ref log: Sperry Sun 8/27/89 Baker blank pipe (ID = 2.441 ") 4,706' — (295') Size SPF Interval (TVD) i Bakerweld 2 -7/8" 0.012" Ga. 5,001' 24 5,022' - 5,046' 4,065' - 4,086' — — screen. (96' W/ 2.44" id ) 24 5,056' - 5,076' 4,095'- 4,113' 24 5,085' - 5,094' 4,121'- 4,130' — / — Gravel pack (N- sands) 20/40 0-Ring seal sub (1.90 "id) 5,097' — Bakerweld 2- 7/8"0.012" Ga. 5,098' Tell -Tale screen (11' 2.44 "id) ?� Baker Model "D" Pkr. 5,110' 7" float collar PBTD 5,613' WLMD Tag fill @ 5548' ( ) 7" float shoe 5,694' DATE REV. BY COMMENTS MILNE POINT UNIT 11/20/89 Onginal Completion Parker 141 5/08/90 Gravel Pack & completion Pool 102 WELL G -02 2/16/99 MDO ESP & Tbg. chg. RWO Nabors 4 -ES API NO: 50 - 029 - 21926 12/8/08 L. Hulme ESP Replacement - Nabors 3S 03/24/13 L. Hulme ESP Replacement - Doyon 16 BP EXPLORATION (AK) '~ ~ 6C ~ STATE OF ALASKA i~ S 1~9 ~ E 1/ E I `!(C c~ ~ ALA OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPE~TIONS DEC 3 1 2008 ~~ ~~ 1. Operations Performed: G 1 as ons. ommi ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Ent~k~~i1d Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP - ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ~ ^ Exploratory 189-028 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21926-00-00 - 7. KB Elevation (ft): 58, 9. Well Name and Number: MPG-02 8. Property Designation: 10. Field /Pool(s): ADL 025906 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 5714 feet true vertical 4701 ~ feet Plugs (measured) None Effective depth: measured 5613 feet Junk (measured) None true vertical 4608 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 13-3/8" 110' 110' 1740 750 Surface 2856' 9-5/8" 2856' 2485' 6870 4760 Intermediate Production 5694' 7" 5694' 4129' 8160 7020 Liner Perforation Depth MD (ft): 5022' - 5094' Perforation Depth TVD (ft): 4064' - 4129' 2-3/8" 4.7# J-55 4653' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" Gravel Pack Screen Assembly from 4669' - 5110' 4669' Baker SC-1 L Packer and a Baker Model 'D' Packer 5110' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 1000 0 Subsequent to operation: 105 26 60 240 220 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil - ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or wA if C.O. Exempt: Contact Hank Baca, 564-5444 N/A Printed Name Sondra Stewman Title Drilling Technologist Si ure Prepared By Name/Number. Phone 564-4750 Date ~ ~ -~ondra Stewman 564-4750 Form 10-404 Revised 04/2006 Submit Original Only !~-`l~, sior~ Tree: 2 9/16" - 5M FMC ~ Wellhead: 11" 5M FMC w/ 2 7/8" WKM Tubing Hanger , w/ 2-7/8" 8 rd. top, 2-3/8" Lower, 2.5" CIW H BPV profile 13 3/8' 48 ppf, H-40 110' MPU G-02 ~I<B Elev. = 59.3" Orig. GL Elev. = 28.6" RT To Tbg. Spool = 28.6" KOP @ 500' Max. hole angle = 48 deg. Hole angle thru' perfs = 27 deg 9 5/8", 47#/ft, L-80 BTC 2,856' 2 3/8" 4.70" ppf, J-55, 8rd EUE tbg. ( drift ID =1.995 ", cap. = 0.00387 bpf ) 7" 29 ppf, L-80, BTC production csg. (drift ID = 6.184", cap. = 0.0371 bpf ) Perforation Summary Ref log: Sperry Sun 8/27/89 Size SPF Interval (TVD) 24 5,022'-5,046' 4,065'-4,086' 24 5,056'-5,076' 4,095'-4,113' 24 5,085'-5,094' 4,121'-4,130' WLMD Tag fill @ 5548' Camco 2 3/8" x 1" KBMM 195' GLM Centrilift heat trace 3,500' Camco 2 3/8" x 1" KBMM 4424' I GLM 2-3/8" HES XN-Nipple (1.79" id) 4564' WeIILift Discharge Sensor 4605' Centrilift ESP, 141-P6 117, PMSXD 1:1 4607' Gas Separator GRSFTX AR H6 4623' Intake: 3735' tvd Tandem Seal Section 4628' GS63DBFERHLSSCVH6PFSA Centrilift KMH-A 562 series, 4642' Rerated: 40 hp, 1209 v. / 20 amps WeIILift MGU Sensor W/ 4649' 6 Fin Centralizer Intake Sensor: 3755` tvd Baker SC-1 L Pkr. (4.0" id) 4 669' Baker blank pipe (ID = 2.441") 4,706' (295') Bakerweld 2-7/8" 0.012" Ga. 5 001' screen. (96' W/ 2.44" id ) Gravel pack (N-sands) 20/40 O-Ring seal sub (1.90"id) 5 097' ' Bakerweld 2-7/8"0.012" Ga. 5 098' Tell-Tale screen (11' 2.44"id) Baker Model "D" Pkr. 5 110' 7" float collar (PBTD) 5 613' 7" float shoe 5 694' DATE REV. BY COMMENTS 11/20/89 Original Completion Parker 141 5/08/90 Gravel Pack & completion Pool 102 2/16/99 MDO ESP &Tbg. chg. RWO Nabors 4-ES 12/8/08 L. Hulme ESP Replacement -Nabors 3S MILNE POINT UNIT WELL G-02 API NO: 50-029-21926 BP EXPLORATION (AK) • • Well History Well Date Summary MPG-02 9/24/2008 T/V0=150/200/0 (Freeze R-otect) Pumped 11 bbls Dead G7ude dow n tubing. At 7 bbls away pressured up to 2500 psi. FWHP= 500/200/0 Master, IA, and OA open. Wing, Swab, and SSV closed. MPG-02 9/25/2008 Flush/Freeze R-otect Laterals (Pre-RWO) -Rush/freeze protect production w/2 bbls 60/40 methanol, 3 bbls diesel & 2 bbls 60/40. Freeze protect test lateral w/1 bbl 60/40 (no flow path on test header w ith out seperator on pad & no other w ell than this one w ith a test to production jumper) Close & flag lateral valves & bleed to 0 psi. IA/OA & master open. Swab, ssv & w ing closed. Tag w ell & notify operator. Note: Only 1 bbl 60/40 in test lateral MPG-02 10/24/2008 ***WELL S/I ON ARRNAL*** SBHP*`* TAG TOP OF ESP 4599' MD. 15 MIN GRADIEN T P 00' MD 17:25-17:40. 1 HR BHPS STOP @ 4556' MD (XN-NIPPLE) 17:49-18:49. MPG-02 11/28/2008 ***WELL S/I ONARRNAL*** (pre rwo) PULL DGLV FROM 4510' MD *********POCKET LEFT OPEN********* PULL DPSOV & SET DGLV @ 188' MD RUN SBHP 30 MIN STOP @ 4099' SLM AND 3 HOUR STOP @ 4596' SLM ***WELL S/I ON DEPARTURE*** »»»»BFV SET«««« MPG-02 11/28/2008 MPU Well ST, Set BPV w ith Slick- Line .Before they moved off.Waiting on l7ectrion for disconnect for demobe. MFG-02 11/30/2008 T/VO=SSV/1000/0, Temp=S1. PPPOT-T (PASS), PPPOT-IC {PASS), pre RWO. PPPOT-T: Stung into test port (200 psi), bled to 0 psi. Functioned LDS, all moved freely. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (0+ psi), bled to 0 psi. Functioned LDS, all rraved freely. Ressured void to 3500-psi for 30 min test, lost 100 psi in 15 rrin, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 2 gland nuts are bottomed out on w ell head (no more adjustment), packing w ill need to be replaced/ added (not leaking at this time). MPG-02 12/1/2008 MPU Well ST demobe w ell house flow-lines and foundation blinds installed and TQ to spec. Note : BFV is set . MPG-02 12/6/2008 PULLED AND RESET DGLV. SET DPSOV FOR RIG 3S. MANDRELS FLAGGm AND TAGGED. MPG-02 12/8/2008 (Freeze Protect Well) T/V0= 0/0/0 Ramp 10 bbls dead crude dow n TBG follow ed by 80 bbls dead crude dow n IA to freeze protect w ell. (Aw gers continued on 12-09-08 ) MPG-02 12/9/2008 (Freeze Protect well) T/V0= 0/0/0 FLmp 10 bbls dead crude dow n TBG follow ed by 80 bbls dead crude down IA to freeze protect well. FWHP= 0/0/0 Swab-shut /ssv-shut /master-shut /wing-shut / IA and OA open to gauges. Operator notified of departure. MPG-02 12/17/2008 MPU Well ST pulled BFV w ith Crane, walked w ell dow n piping and pressure tested, Production and Test flow lines to 1150 PSI w ith diesel for 10 min. PT Passed. MPG-02 12/18/2008 T/V0=120/0/0. (Warm up w ellbore/ R-e-POP) Rarrp 125 bbls crude down IA to w arm up w ellbore before POP. FWHP=300/0/0. Print Date: 12/29/2008 Page 1 of 1 • BP EXPLORATION Operations Summary Report Page 1 of 3 ~ Legal Well Name: MPG-02 Common Well Name: MPG-02 Spud Date: 8/22/1989 Event Name: WORKOVER Start: 12/4/2008 End: 12/8/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/8/2008 Rig Name: NABOBS 3S Rig Number: i Date ~ From - To Hours .Task ', Code I NPT- Phase Description of Operations 12/3/2008 06:00 - 12:00 6.00 MOB P PRE Rlg released for MPL-34 C~ 06:00. Scope down and lower derrick. Disconnect pit and pipe shed modules. Prepare for rig move. 24 hour notice to AOGCC for BOPE testing on MPG-02 C~ 11:00 am. 12:00 - 14:00 2.00 MOB P PRE Travel from MPU-L pad to MPU-G pad. 14:00 - 20:00 6.00 MOB P PRE MIRU on well MPG-02. Spot camp and support equipment. Spot carrier, pipe shed, and pit modules. Hook up all components. 20:00 - 00:00 4.00 MOB P PRE Raise and scope up Derrick. RU lines, handrails and steam. Spot LRS unit. 12/4/2008 00:00 - 03:30 3.50 RIGU P PRE i3ig arrepted at 00:00 hours 12/4/2008. RU second annulus valve on IA, hard lines to kill manifold and Tiger tank. Take on seawater to Pits. Test surface lines to 3,000 psi and hard lines to Tiger tank to 500 psi. 03:30 - 04:00 0.50 RIGU P PRE MU and test lubricator to 500 psi, Well support tech pulled PV. 04:00 - 04:30 0.50 RIGU P PRE PJSM with truck drivers and LRS on Well kill operation. 04:30 - 06:00 1.50 KILL P DECOMP WHP tbg = 1,000 psi, IA = 1,000 psi, OA = 0 psi. Bleed IA down to 190 psi and pump 20 bbls 140 Deg Seawater down tbg at~3 bpm taking returns through the choke with '0' returns at the Tiger tank. Bull head 60 bbls down tbg at 3 bpm. 06:00 - 08:00 2.00 KILL P DECOMP Flowcheck well, tubing and IA on vacuum. Open choke and pump 60 Bbls with no returns. Close choke and bullhead 250 Bbls down IA. Caught fluid after pumping 150 Bbls. Bullhead c~ 4 BPM, 800 psi on IA, 700 psi on Tbg. Shut down, Tubing and IA on vaccum. Bullhead 40 Bbls down Tbg. Flowcheck well. Tubing and IA on vacuum. 08:00 - 09:00 1.00 PULL P DECOMP Dry rod TWC with Cameron wellhead tech. Test from above to_ 3500 psi and chart or menu es. ow w n rig own lines. L to a w o 25 Bbls/Hr. 09:00 - 11:00 2.00 WHSUR P DECOMP ND 2-9/16" tree. Check top tubing hanger threads - 2-7/8" EUE 8rd, 7-1/2 turns. Add additional packing to 5 LDS on Tbg spool and 3 LDS on Csg spool 11:00 - 21:00 10.00 BOPSU P DECOMP NU DSA and 13-5/8" BOPE w/ 2-3/8" fixed rams and Blind/Shears. Adding 20 Bls/Hr Seawater in IA every hour. 21:00 - 22:00 1.00 BOPSU P DECOMP Function test BOPE, M/U 2-3/8" test joint. 22:00 - 00:00 2.00 BOPSU N DECOMP Retighten bottom flange on top rams, replace door seal on O.D.S. Blind /Shear rams. 12/5/2008 00:00 - 01:30 1.50 BOPSU N DECOMP Replace D.S. door seal on Blind /Shear rams. 01:30 - 08:30 7.00 BOPSU P DECOMP Test BOPE with 2-3/8" test joint against TWC per BP / AOGCC, 250 psi 3,5 psi. inspector John Crisp waived state's right to witness MPG-02 initial BOP test at 01:30 hrs,12/5/2008. Test witnessed by BP/WSL and Nabors Tourpusher. 08:30 - 10:30 2.00 WHSUR P DECOMP Maintain continuous hole fill @ 20 Bls/Hr in IA. Attempt to break loose stud nuts on 3 ea bolts on casing spool, to adjust to proper MU depths. Unable to make adjustment. 10:30 - 11:30 1.00 WHSUR P DECOMP PUMU Opso-Lopso and screw into hanger with 9-1/2 turns. PUMU lubricator with polish rod extension and pulling tool. Pull TWC with 0 psi on T / IA / OA. Lay down u ricator, ro , an Opso-Lopso. 11:30 - 13:00 1.50 PULL P DECOMP PUMU 2-7/8" landing joint with TIW valve installed. Break out LDS on tubing spool. PU and unseat hanger with 38K PUW. Printed: 12/18/2008 1:25:21 PM • BP EXPLORATION Page 2 of 3 Operations Summary Report Legal Well Name: MPG-02 Common W ell Name: MPG-02 Spud Date: 8/22/1989 Event Nam e: WORKO VER Start : 12/4/2008 End: 12/8/2008 Contractor Name: NABOB S ALAS KA DRI LLING I Rig Release: 12/8/2008 Rig Name: NABOB S 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/5/2008 11:30 - 13:00 1.50 PULL P DECOMP Pull han er above rig floor. Start hole fill regulated C~? 20 Bbls/Hr. BOLD landing Point an va ve. hanger and XO- 2-78" x 2-3/8". Remove penetrators. 13:00 - 22:30 9.50 PULL P DECOMP PU and run heat trace and ESP cable over dual shieve in derrick and out to spooling unit. POH laying down jewelry, and standing back 2-3/8" tubing in Derrick. 46 stands out. 22:30 - 23:00 0.50 PULL P DECOMP Crew change and pe orm pre-tour c ~ecks. 23:00 - 23:30 0.50 PULL P DECOMP Rig service. 23:30 - 00:00 0.50 PULL P DECOMP Continue POH with Heat trace and ESP, standing 2-3/8" tbg in Derrick. 51 stands out. 12/6/2008 00:00 - 02:00 2.00 PULL P DECOMP Continue POH with Heat trace and ESP, standing 2-3/8" tbg in Derrick. from stand # 51 to ESP assembly. Recovered 1876 bands, 559 = Eft, 42 = 38', 1 = 46.5", 1 = 57' Flatguards, 2 = Protectolizers. Maintain continuous hole fill C~3 20 Bls/Hr. 02:00 - 06:00 4.00 PULL P DECOMP Service and lay down pump an mo or assem ly with Centrilift rep. Serious pitting on ESP assembly and several cap bolts heads rotted away. ump oc a -up. 06:00 - 07:00 1.00 PULL P DECOMP Clean and clear rig floor. emove elephant trunk from shieve. 07:00 - 10:00 3.00 WHSUR P RUNCMP Cameron wellhead techs remove and adjust 4 ea stud bolts on casing spool as per BP specs. Maintaining hole fill @ - 20 Bls/Hr. 10:00 - 15:00 5.00 BUNCO RUNCMP PUMU ESP BHA.as per Centrilift. 15:00 - 16:30 1.50 BUNCO RUNCMP Run ESP and Heat trace cable over shieve in derrick. MU to ESP BHA and test. 16:30 - 18:00 1.50 BUNCO RUNCMP RIH with ESP on 2-3/8" 4.7#, J-55, EUE 8 Rd tubing from derrick. Start ea race in mi e o s an as IH. 7 stan sin at 18:00 hours. 18:00 - 18:30 0.50 BUNCO RUNCMP Crew change, perform pre-tour checks. 18:30 - 00:00 5.50 BUNCO RUNCMP Run ESP completion assembly on 2-3/8" tbg from Derrick, from stand # 7 to 25 with Centrilift rep. Start Heat Trace in middle of stand #18 as RIH. Maintaining hole fill ~ - 20 Bls/Hr. 12/7/2008 00:00 - 18:30 18.50 BUNCO RUNCMP Run ESP completion assembly on 2-3/8" tbg from Derrick, from stand # 25 to # 40 with Centrilift rep. Maintaining hole fill ~ 20 Bls/Hr. Check cable conductivity and flush pump w/10 bbls seawater 1/3 bpm at 950 psi every 2,000 ft. 40 stands run at 05:30 hrs. Ran 146 joint 2-3/8" tbg, 2 - GLM and ESP assembly to 4652' md, 3 = protectolizers,45 = 3 ft, 1 = 4 ft and 1 = 5 ft, 551 = 6 ft Flatguards, 2 = Armsterguards, 1,865 steel bands. Fluid loss at -12 bbl / hrs. 18:30 - 19:30 1.00 BUNCO RUNCMP PU landing joint, MU and orient tbg hanger with Cameron Well head rep. PUW = 35K, SOW = 30K. 19:30 - 23:30 4.00 BUNCO RUNCMP Install penetrators and Centrilift rep's make ESP and HT splices. 23:30 - 00:00 0.50 RNTBH P TUBHGR Land tbg hanger, with Cameron well head rep. 12/8/2008 00:00 - 01:30 1.50 RNTBH P TUBHGR Continue to land tbg hanger and RILDS with Cameron re . 01:00 - 01:30 0.50 BUNCO RUNCMP D rod TWC with Cameron well head rep, test to 3,500 si from above for 10 charted minutes. 01:30 - 02:00 0.50 BOPSU P OTHCMP Drain BOP stack and ow own mes. 02:00 - 06:00 4.00 BOPSU P OTHCMP ND BOPE and change bottom Rams to 2-7/8" X 5" VBR, remove HCR kill valve. 06:00 - 07:00 1.00 BOPSU P OTHCMP Lay down BOPE. ND DSA. 07:00 - 10:00 3.00 BOPSU P OTHCMP NU 2-9/16" 5K tree with new tubing head adaptor. Test hanger void to 5000 psi for 30 minutes. Test tree to 5000 psi and chart Printed: 12/18/2008 1:25:21 PM BP EXPLORATION Page 3 of 3 Operations Summary Report Legal Well Name: MPG-02 Common Well Name: MPG-02 Spud Date: 8/22/1989 Event Name: WORKOVER Start: 12/4/2008 End: 12/8/2008 Contractor Name: NABORS ALASKA DRI LLING I Rig Release: 12/8/2008 Rig Name: NABORS 3S Rig Number: Date From - To I, Hours Task Code. NPT Phase Description of Operations 12/8/2008 07:00 - 10:00 3.00 BOPSU P OTHCMP for 10 minutes. Centrilift final checks: BHP-1203 psi / Temp-81 deg F /phase to phase-3.6 ohms /phase to ground-100 gig ohms. 10:00 - 11:00 1.00 BOPSU P OTHCMP PUMU lubricator. Pull TWC with 0 psi on T/IA/OA. Dry rod BPV. Rig down ou a va v . 11:00 - 12:00 1.00 BOPSU P OTHCMP Norma up tree and cellar. Prep for Rlg move. Rig released at 12:00 noon. Printed: 12/18/2008 1:25:21 PM STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION Bt?PE Test Report Submit to: Contractor: Nabors Rig No.: 3S DATE: 12/5/2008 Rig Rep.: R.Bjofius/D.Ric~ards Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: Bp Op. Phone: 659485 Op. Fax: 659-4628 Rep.: J.MenkelD.Rhodes FieldlUnit & Well No.: MP G-0Z PTD # 4890280 Operation: Drlg: w Test: Infial: x Test Pressure: Rams: 250/3500 Workover. x Weekly: Anrw~ar: 250<3500 TEST DATA. MISC. INSPECTIONS: Test Result Test Result Location Gen.: P WeA Sign P Housekeeping: P Dri. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 3/8" P Lower Pipe Rams 0 NA Blind Rams 1 Blind P Choke Ln. Valves 1 31/8" 5000 F HCR Valves 2 3118" 5000 P Kill Line Valves 1 2 1116" 5000 F Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Explor.: Bi-Weekly Valves: 250/3500 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 FP Inside BOP 1 P CHOKE MANIFOLD: Quantity Test R No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 1800 P 200 psi Attained 35sec P Fug Pressure Attained 150 sec P BCmd Switch Covers: RII stations P Nitgn_ Bottles (avg): 2000 Test Results Number of Failures: 4 Test Time: &S Houcs Comc~onents tested ALL Repair or replacement of equipment w~l be made vvitt~n days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Remarks: and tested good flange on choke manifold leaked, tightened and tested good. TIW ball valve leaked, 24 HOUR NOTICE GIVEN YES X NO Date 12/03/08 Time Test start 1:30 Finish BOP Test (for rigs) .,,.,, BFL 11/14/07 v.~~~ ~~~~ w~ ~ ~~~~ 11:00 hrs By John Wi~ress D.Richards/D.Rhodes Nabors 3s BOP Test MP G-02 12-05-2008.x1s MEMORANDUM Commissioner THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 1, 2000 Blair Wondzeli P.I Supervisor John Crisp Petroleum InspectOr NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests BPX F & G Pads F-83i, G-01i,03i,05i,07i Milne Point Unit Milne Point Field P.T.D.] 2001030 Notes: P:T.D.] 1890290 Notes: Well[ G-03i P.T.D.I 1890280 Notes: P.T.D.I 1890460 Notes: P.T.D.I 1890450 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. s IT'v'D' !942 ==°° 1==°° I= 00 I I.te~,all '~ Type test] P I T~stpsil 1606 '] CasingI 1900I 2680 I 2660I 2'650 ] P/F ] 15`. Type lnj. I s'] T.V.D. I 3690 ITubingl 1200l 13601 1340l 1340 ]IntervalI 4 Type test ] ,, , P ITestp,si] 923 I Casi.gl 0 I ~Z=~I ~Z=~I ~Z=S '1' ¢/""1'-P- I Typelnj. I S I T.v.D. I 3791 I Tubingl 1720 I 1720 ] 1720 1472o I,,terva,I 4 Type test[ P ITestpsil '948 I Casingl 950 I 2190l 218°l 21751 P/F [ P.. Type lnj.] S ] T.V.D. I 3929 ITubingl 900'I 900 [ 900 ] 900 I lntervall 4 Typetest] P ]Testpsi] 982'lC~;ingi 0 I 177~5 I 1750 I 173°I P/F ] P- Type lnj,I- S ] T.V.D. 13963 I Tubing 12000 ]2000 I 2000 12000 I,.terVa,I 4 ] Type test] P ]Testpsi] 991 ]CasingI 620 ] 2500 I 2480 I 2480 ]' P/F I P -~ / Type INJ. Fluid Codes F FRESHWATER INJ. G = GAS INJ. S = SALT WATER IN J, N = NOT INJECTING Type Test M= Annulus MonitOring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details I witnessed 5 successful MIT's ~ BP's MPU. Interval I= Initial Test 4= Four Year Cycle V= Required by Vadance W= Test during Workover O= Other (describe in notes) .I.T.'s performed: 5_ Attachments: Number of Failures: 0 Total Time during tests: 2 hrs. AC: MIT report form 5/12J00 L.G. MIT MPU F & G Pads 10-01-0()jc.xls 10/3/00 ON OR BEFORE c:t,o~r~°c STATE OF ALASKA .... ALASKA b,-AND GAS CONSERVATION COM,v;ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [~ Operation Shutdown [~ Pull Tubing 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3585' SNL, 3354' WEL, SEC. 27, T13N, R10E, UM At top of productive interval 4629' SNL, 889' WEL, SEC. 27, T13N, R10E, UM At effective depth 4691' SNL, 736' WEL, SEC. 27, T13N, R10E, UM At total depth 4709' SNL, 695' WEL, SEC. 27, T13N, R10E, UM [] Stimulate [] Plugging [~ Perforate [~] Alter Casing [~ Repair Well ~] Other Change Out ESP Type of well: [~ Development [] Exploratory [~ Stratigraphic [~ Service 6. Datum Elevation (DF or KB) KBE = 59.3' 7. Unit or Property Name Milne Point Unit 8. Well Number MPG-02 9. Permit Number / Approval No. 89-28 10. APl Number 50-029-21926 11. Field and Pool Milne Point Unit / Kuparuk River Sands & Schrader Bluff 12. Present well condition summary Total depth: measured 5714 feet true vertical 4701 feet Effective depth: measured 5613 feet true vertical 4608 feet Casing Length Structural Conductor 110' Surface 2856' Intermediate Production 5694' Liner Plugs (measured) Junk (measured) Size Cemented 13-3/8" Arcticset to surface 9-5/8" 172 Bbls PF 'E' 7" 123 Bbls Class 'G', 24 Bbls Arcticset I MD TVD 110' 110' 2856' 2485' 5694' 4683' Perforation depth: measured true vertical 5022'-5046', 5056'-5076', 5085'-5094' 4065'-4086', 4095'-4113', 4121'-4130' Tubing (size, grade, and measured depth) 2~3/8", 4.7#, J-55, 8rd EUE tubing to 4646' Packers and SSSV (type and measured depth) 7" Gravel Pack Assembly from 4669' - 5110' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORI®INAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments { 16. Status of well classifications as: E~ Copies of Logs and Surveys run I ~Oil [~ Gas [~ Suspended [] Daily Report of Well Operations 17. I hereby certify that the foc'egoing is true and correct to the best of my knowledge Signed Terrie Hubble ¢~,¢,A~~, ~ Title Technical Assistant III Prepared By Name/Number: Service Date .0 ~"~-¢¢ Terrie , Submit In Duplic~ Form 10-404 Rev. 06/15/88 Progress Report Facility M Pt G Pad Well MPG-02 Rig ~ J~r'$ q~;S Page 1 Date 08 March 99 Date/Time 12 Feb 99 13 Feb 99 14 Feb 99 15 Feb 99 18:00-02:00 02:00-06:00 06:00-10:00 10:00-11:30 11:30-14:00 14:00-17:00 17:00-19:00 19:00-20:00 20:00-21:00 21:00-00:00 00:00-00:30 00:30-03:00 03:00-05:00 05:00-06:00 06:00-09:00 09:00-13:00 13:00-16:00 16:00-06:00 06:00-10:00 10:00-15:00 15:00-17:00 17:00-19:30 19:30-22:00 Duration 8hr 4hr 4hr 1-1/2 hr 2-1/2 hr 3hr 2hr lhr lhr 3hr 1/2 hr 2-1/2 hr 2hr lhr 3hr 4hr 3hr 14hr 4hr 5hr 2hr 2-1/2 hr 2-1/2 hr Activity Rig moved 100.00 % Circulated closed in well at 4600.0 ft Circulated closed in well at 4526.0 ft Removed Xmas tree Installed BOP stack Tested BOP stack Removed Tubing hanger Rigged up Completion string handling equipment Repaired Completion string handling equipment Laid down 2500.0 ft of Tubing Repaired Completion string handling equipment Laid down 4562.0 ft of Tubing Worked on BOP - Variable ram Rigged up Completion string handling equipment Installed ESP Ran Tubing to 1200.0 ft (2-3/8in OD) Rigged up Completion string handling equipment Ran Tubing to 3760.0 ft (2-3/8in OD) Ran Tubing to 4646.0 ft (2-3/8in OD) Installed Tubing hanger Removed BOP stack Installed Xmas tree Freeze protect well - 8.000 bbl of Diesel STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status ot Well OIL~ GAS ~ SUSPENDED Im ABANDONED [] 2. Name of Operator CONOCO INC. Classification of Service ~iJ;,? ;,TIC',/$ r 3. Acldress 8. APl Number P.O BOX 340045 PRUDHOE B~Y, AK 99734 5¢~29-21926 4. Location of well at surface 3585' FNL, 3354t FEL, SECTION 27, T13N, R10E, OM At Too Producing Interval -4629t FNL, 889t FEL, SECTION 27, T13N, R10E, UM At Total Depth 4709t FNL, 695' FEL, SECTION 27, T13N, R10E, OM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KB 59.3' = 59.3 MBL ADL25906 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. 08/22/89 08/27/89 I. 11/20/90 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 5714'/4701' i613,/4608 "IW'D YES~ NO [--~ 22. Type Electric or Other Logs Run EWR/ DeR/ CNO/ 4 ~rm Caliper/Gyro Unit or Lease Name MILNE POINT UNIT 10. Well Number G-2 11. Field and Pool KUPARUK RIVER FIELD SCHP~tDER BLUFF POOL I lS, Water Depth; if offshore !16. No. of Completions N/A feet MSL I NONE 20. Depth where SSSV set 21. ThicKness of Permafrost N/A feet MD '{'1800 I 23. CASING SIZE 13-3/8" , 9-5/8t~ WT. PER FT. 48 47 2'9 CASING, LINER AND CEMENTING RECORD / HOLE SIZE I CEMENTING RECORD AMOUNT PULLED 30" ~RC. SET TO SURF.' NONE 12 1/4'!172 BBL PERMF 'Et NONE 8 1/2t11~23 BBL CLASS 'G'. NONE 4 BBL ARC SET 'I NONE 2 BB~.S DEAD CRU3E J SETTING DEPTH MD GRADE ITOP I BOTTOM H-40 SFRFACE }110,RKB L-80 SD~tFACE 2865 ' RKB L-80 siRFAc~. 1694'RKB 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 4626t N SANDS N~ 5022 NB 5056 NC 5085 24SPF ( 406 S~Z~'D) -5046 ( 4086'Z~D) (409S~Z~q:)) -507 6 ( 43.13~Z~D ) (412 I~D) -S094 (413 0'Xq~) 2 7/8" 4669t 5110' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 5022 -5046 GRAVEL PACK 27. PRODUCTION TEST . Date First Production I Method of Operation (Flowing, gas lift, ITC.) DSTt S 04/01/90-05/01/9~ Electrical Submersible Pump 05/01/90 24 TEST PERIOD I~ 400 88 0 28/64 220 Flow Tubing Casing Pressure ICALCULATED I~b OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 102 125 124.HOUR RATE 'vI 400 88 0 19.0 28. CORE DATA Brief description of iithology, porosity, fractures, apparent clil3s and presence of oil, ps or ware r. Submit core chips. N/A ~;,. '~--,~- ~ , Submit in duplicate Form 10-407 29. 30. NAME Top Upper Ugn Top Lower Ugn Top West Sak GEOLOGIC MAt.r,,ERS MEAS. DEPTH RKB 4411~ 4746~ 5199~ TRUE VERT. DEPTH RKB 3586~ 3860~ 4224~ FORMATION TESTS Include interval tested, pressure data, alt fluids recovered and gr~avity, GOR, and time of each phase. 31.J. IST OF ATTACHMENTS _ ~yro Survey and Daily Activity Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 9~1,--,- (~, ~,~'j~/~--~ Title ~r,~ L,%. "~'~r"~'d Date I ~." 3' 0 - ? 0 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 Conoco, Inc. Daily Well Activity Repo,! Alaska Well: ~V~.["~U ~---~-2... I Oat~: }[:-~0 "C:~O I AFE/Facility: V~(f__., {."~0'::::~ I Cum. Days for Activity: Activity: ~.tJhJ L.~-S~:::' ~,v,,~ Zone(s)Open: tk/ ¥'~-[ ~,~ ~ [ ~[. Weather: Wind: ~,i @ ,.,q' Kts.; GustsTo: ~ Kts.; Temp;.,.2...o OFI__~C) 0FWC; Visibility: ~ 0 Mi. From To Daily Operations ~o ~oo Ps~ Hold Fo~ ~ ~(~ lT~b~, / We, Bore Fluid, Prope~ies: Type ~iN ~ Weight: ~ ~~ Total Fluid Pr~uced: Last 24 Hrs. ~ BBLS, Cum. BBLS, Type , Weight PPG, Vi~. S~. Total Fluid Lost: Last 24 Hrs. ~ BBLS, Cum. BBLS, Type , Weight PPG, Visc. Sec. BPV: In~ ~0 8SSV~~d Downhole Plug: Yes Depth Type Se~icePersonnel:13 ~~/ [ ~tC~ ~' ~~f ~~/ ~ Rig~~ ~t~y / J Supe~isor: ~~ 0 Daily Cost Estimate: $ ~ ~ ) J Cum. Well/ActiviWCost:$ ~q!~3 J Auth. Amt:$ ~x Conoco, Inc. Daily Well Activity Repu, { Alaska Activity: ~'=l~eu~, "/" ]'~I'~P ct, ~.u.,I, ~.5. P zone(s)Open: t,,tl'~I l',l.t%; Weather: Wind: ~ ~" @ ~,~ Kts.; Gusts To: /0 Kts.; Temp: --,,.~0 °F/ ,.5-'~) °FWC; Visibility: 3 ~ Mi. From To Daily Operations ~ ~ ~/u ~ ~u~ ~P, , - I Well Bore Fluid, Prope~ies: Type /~/g/~ Weight: ~/~ Produced: Last 24 Hrs. ~ BBLS, Cum. BBLS, Type , Weight PPG, Vi~. S~. Total Fluid Lost: Last 24 Hrs. ~ BBLS, Cum. BBLS', Type , Weight PPG, Vi~. S~. BPV: In¢ C~¢ SSSV~ Downhole Plug: Yes Depth Type SewicePersonnel:~ ~3, ~ ~~ ~ ~~~~, ~ ~A~, ~ ~~, "~: ~= ~, ~ ~ ~ I su,~sor: ~ ~ ~3 ~~ Daily Cost Estimate: $ ~ ~ ~ 5 ~ I Cum. Well/Activi~ Cost: $ ~ ~-~ ] Auth. Amt: $ 3 ~ ~/ : J · Conoco, inc. Daily Well Activity Report Alaska Well: F~' ~' ~ ~" ~-' J Date: Activin: Weather: Wind: ~ ~ /0 Kts.; GustsTo: /D Kts.; Temp:--~ OF/--~O oFWC; Visibili~: ~ ~ Mi. From To D~iy Operations / ._ . we, Bor~ F~u~, P~o~.~es: T~e Total Fluid Pr~uc~: ~st 24 Hrs. ~ BBLS, Cum. BBLS, Type , Weight PPG, Vi~. S~. Total Fluid Lo~: ~st 24 Hrs. ~ BBLS, Cum. BBLS, Type , Weight PPG, Vi~. S~. BPV: In~ ~ 0 .... F~ .......... D~h~l~ Plu~: Y~ D~p~h T~ 8~mP~nn~l:l~ ~ / ~ ~~ ~ ~ ~oN~O Rig: ~~ Daily Cost Estimate: $ 1~, Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 October 6, 1989 John Boyle Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle' Please find enclosed the gyroscopic surveys on the Milne Point G-l, G-2, G- 3 and G-4 wells. No LIS tape or floppy disk format directional data is available for these wells. Sincerely, Senior Reservoir Engineer cc' well files (4) 0 I::t I I--I-- ! I~] G S ~::: I::! %/I C ~::: S Mr. Steve Rossberg Conoco, Inc. 3201 "C" Street, Suite 200 Anchorage, Alaska 99503 September 1, 1989 ORIGINAL Re: Our Boss Gyroscopic Survey Job No. AK-BO-90087 Well: G-2 Milne Pt., Alaska Survey Date: 08/29/89 Operator: D. Harger Mr. Rossberg: Please find enclosed two copies of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard District Manager Directional Services 8537 Corbin Drive (99507) · RO. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company i CONOCO INC. G-2 MILNE POINT ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 9/ 1/89 DATE OF SURVEY: 08/29/89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90087 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER i TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DGMN 0 .00 100 100.00 200 200.00 300 299.99 400 399.99 -59.27 40.73 140.73 240.72 340.72 0 0 0 31 0 15 0 13 0 49 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST N .00 E .00 .00 .00 N 60.30 E .53 .23N .40E N 37.00 E .31 .64N .94E N 46.30 E .05 .96N 1.22E S 45.80 E .84 .60N 1.88E VERT. SECT. .00 .28 .62 .75 1.50 500 499.93 600 599.67 700 698.85 800 797.29 900 895.07 1000 991.98 1100 1087.33 1200 1180.96 1300 1272.83 1400 1362.04 1500 1449.25 1600 1536.20 1700 1623.61 1800 1709.73 1900 1793.16 440.66 2 35 540.40 5 30 639.58 9 4 738.02 11 6 835.80 12 58 932.71 1028.06 1121.69 1213.56 1302.77 1389.98 1476.93 1564.34 1650.46 1733.89 15 35 19 24 21 39 24 49 28 51 29 44 29 27 28 39 32 23 34 30 S 52.60 E 1.78 1.27S 4.19E S 50.90 E 2.91 5.67S 9.70E S 55.80 E 3.62 13.12S 19.94E S 59.00 E 2.11 22.52S 34.72E S 64.50 E 2.19 32.31S 53.12E S 69.80 E 2.92 41.79S 75.87E S 70.70 E 3.83 51.93S 104.17E S 70.90 E 2.25 63.46S 137.30E S 70.10 E 3.19 76.64S 174.49E S 70.00 E 4.02 92.05S 216.92E S 69.50 E .92 108.99S 262.82E S 70.00 E .37 126.08S 309.16E S 69.30 E .87 142.97S 354.70E S 68.80 E 3.74 161.14S 402.12E S 68.20 E 2.14 181.34S 453.39E 4.35 11.14 23.48 40.75 61.50 86.15 116.17 151.17 190.56 235.64 284.52 333.86 382.38 433.13 488.22 i 2000 1874.82 2100 1954.69 2200 2032.19 2300 2106.44 2400 2177.18 2500 2245.38 2600 2312.64 2700 2379.68 2800 2446.56 2900 2514.23 3000 2584.63 3100 2657.15 3200 2730.38 3300 2804.54 3400 2879.82 1815.55 36 0 1895.42 37 57 1972.92 40 24 2047.17 43 42 2117.91 46 12 2186.11 47 47 2253.37 47 40 2320.41 48 8 2387.29 47 54 2454.96 46 54 2525.36 2597.88 2671.11 2745.27 2820.55 43 35 43 27 42 22 41 53 40 25 S 68.50 E 1.51 202.63S 507.03E S 69.80 E 2.11 224.02S 563.24E S 69.20 E 2.47 246.15S 622.39E S 70.00 E 3.34 269.48S 685.17E S 69.50 E 2.53 293.93S 751.44E S 69.70 E 1.59 319.42S 819.98E S 69.20 E .39 345.40S 889.27E S 69.20 E .47 371.75S 958.63E S 69.00 E .27 398.27S 1028.09E S 69.00 E 1.01 424.65S 1096.81E S 68.90 E 3.31 450.15S 1163.07E S 67.50 E .97 475.72S 1227.01E S 66.30 E 1.35 502.43S 1289.63E S 65.10 E .94 530.03S 1350.78E S 63.90 E 1.67 558.35S 1410.17E 545.91 606.02 669.12 736.03 806.59 879.65 953.58 1027.73 1102.03 1175.60 1246.57 1315.41 1383.50 1450.56 1516.29 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 CONOCO INC. G-2 MILNE POINT ALASKA COMPUTATION DATE: 9/ 1/89 DATE OF SURVEY: 08/29/89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90087 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3500 2955.50 2896.23 41 12 S 64.30 E .83 3600 3028.32 2969.05 45 17 S 64.70 E 4.10 3700 3097.75 3038.48 46 44 S 65.50 E 1.55 3800 3166.33 3107.06 46 40 S 65.80 E .23 3900 3234.92 3175.65 46 43 S 65.80 E .05 586.89S 1468.97E 1581.56 616.38S 1530.81E 1650.00 646.67S 1596.07E 1721.91 676.68S 1662.38E 1794.67 706.51S 1728.76E 1867.42 4000 3303.95 3244.68 45 57 S 65.60 E .77 4100 3373.10 3313.83 46 32 S 65.90 E .63 4200 3441.71 3382.44 46 47 S 65.80 E .26 4300 3510.04 3450.77 47 0 S 66.00 E .25 4400 3578.16 3518.89 47 7 S 65.70 E .25 736.28S 1794.69E 1939.75 765.95S 1860.56E 2011.97 795.71S 1926.94E 2084.70 825.53S 1993.59E 2157.70 855.48S 2060.39E 2230.89 4500 3646.78 3587.51 46 12 S 65.50 E .94 4600 3717.81 3658.54 43 15 S 65.40 E 2.94 4700 3793.32 3734.05 38 38 S 65.10 E 4.62 4800 3873.38 3814.11 34 57 S 65.30 E 3.68 4900 3957.06 3897.79 31 23 S 65.00 E 3.56 885.52S 2126.63E 2303.60 914.76S 2190.64E 2373.94 942.18S 2250.15E 2439.43 967.31S 2304.51E 2499.29 990.30S 2354.17E 2553.97 5000 4043.95 3984.68 27 55 S 65.20 E 3.48 5100 4133.64 4074.37 24 32 S 65.10 E 3.38 5200 4225.27 4166.00 22 38 S 66.90 E 2.02 5300 4317.71 4258.44 22 10 S 66.70 E .49 5400 4410.26 4350.99 22 21 S 67.00 E .22 1011.14S 2399.04E 2603.42 1029.70S 2439.14E 2647.59 1046.00S 2475.69E 2687.60 1061.02S 2510.73E 2725.72 1075.91S 2545.57E 2763.61 5500 4502.75 4443.48 22 18 S 67.90 E .35 5550 4549.03 4489.76 22 13 S 67.90 E .18 1090.49S 2580.67E 2801.61 1097.62S 2598.22E 2820.55 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2820.55 FEET AT SOUTH 67 DEG. 5 MIN. EAST AT MD = 5550 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 112.90 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 CONOCO INC. G-2 MILNE POINT ALASKA COMPUTATION DATE: 9/ 1/89 DATE OF SURVEY: 08/29/89 JOB NUMBER: AK-BO-90087 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASDVERTICALVERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -59.27 1000 991.98 932.71 2000 1874.82 1815.55 3000 2584.63 2525.36 4000 3303.95 3244.68 .00 .00 .00 41.79 S 75.87 E 8.02 8.02 202.63 S 507.03 E 125.18 117.16 450.15 S 1163.07 E 415.37 290.18 736.28 S 1794.69 E 696.05 280.68 5000 4043.95 3984.68 5550 4549.03 4489.76 1011.14 S 2399.04 E 956.05 260.01 1097.62 S 2598.22 E 1000.97 44.92 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE CONOCO INC. G-2 MILNE POINT ALASKA COMPUTATION- DATE: 9/ 1/89 DATE OF SURVEY: 08/29/89 JOB NUMBER: AK-BO-90087 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH 0 .00 59 59.27 159 159.27 259 259.27 359 359.27 SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE -59.27 .00 .00 .00 .00 .04 N .08 E .00 100.00 .49 N .83 E .00 200.00 .85 N 1.10 E .01 300.00 1.00 N 1.46 E .01 VERTICAL CORRECTION .00 .00 .00 .00 459 459.27 559 559.27 659 659.27 761 759.27 863 859.27 400.00 .16 S 2.74 E .03 500.00 3.49 S 7.00 E .18 600.00 9.80 S 15.18 E .72 700.00 18.67 S 28.32 E 1.99 800.00 28.76 S 45.67 E 3.99 .02 .15 .55 1.26 2.00 966 959.27 1070 1059.27 1176 1159.27 1285 1259.27 1396 1359.27 900.00 38.62 S 67.63 E 6.85 1000.00 48.75 S 95.17 E 11.09 1100.00 60.64 S 129.16 E 17.39 1200.00 74.55 S 168.67 E 25.83 1300.00 91.54 S 215.51 E 37.58 2.86 4.24 6.30 8.43 11.75 1511 1459.27 1626 1559.27 1740 1659.27 1858 1759.27 1980 1859.27 1400.00 110.99 S 268.18 E 52.27 14.69 1500.00 130.54 S 321.41 E 67.23 14.96 1600.00 150.12 S 373.51 E 81.68 14.45 1700.00 172.71 S 431.78 E 99.62 17.94 1800.00 198.49 S 496.52 E 121.51 21.89 2105 1959.27 2235 2059.27 2374 2159.27 2520 2259.27 2669 2359.27 1900.00 225.26 S 566.59 E 146.54 2000.00 254.45 S 644.44 E 176.63 2100.00 287.39 S 733.93 E 214.84 2200.00 324.74 S 834.34 E 261.41 2300.00 363.66 S 937.34 E 310.15 25.03 30.09 38.22 46.56 48.74 2818 2459.27 2964 2559.27 3102 2659.27 3239 2759.27 3373 2859.27 2400.00 403.31 S 1041.23 E 359.70 2500.00 441.28 S 1140.05 E 405.35 2600.00 476.49 S 1228.86 E 443.66 2700.00 513.02 S 1313.77 E 479.84 2800.00 550.65 S 1394.45 E 513.73 49.55 45.65 38.31 36.19 33.89 3505 2959.27 3644 3059.27 3789 3159.27 3935 3259.27 4079 3359.27 2900.00 588.34 S 1471.98 E 545.77 3000.00 629.76 S 1559.16 E 584.78 3100.00 673.61 S 1655.55 E 630.44 3200.00 717.11 S 1752.34 E 676.25 3300.00 759.99 S 1847.23 E 720.62 32.04 39.01 45.66 45.81 44.37 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE CONOCO INC. G-2 MILNE POINT ALASKA COMPUTATION DATE: 9/ 1/89 DATE OF SURVEY: 08/29/89 JOB NUMBER: AK-BO-90087 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4225 3459.27 3400.00 803.38 S 1943.99 E 766.38 45.76 4372 3559.27 3500.00 847.11 S 2041.85 E 812.97 46.59 4517 3659.27 3600.00 890.87 S 2138.36 E 858.68 45.71 4655 3759.27 3700.00 930.32 S 2224.49 E 896.47 37.79 4782 3859.27 3800.00 963.13 S 2295.43 E 923.43 26.96 4902 3959.27 3900.00 990.86 S 2355.37 E 943.31 19.87 5017 4059.27 4000.00 1014.49 S 2406.31 E 958.02 14.71 5128 4159.27 4100.00 1034.63 S 2449.76 E 968.91 10.89 5236 4259.27 4200.00 1051.57 S 2488.74 E 977.58 8.67 5344 4359.27 4300.00 1067.72 S 2526.30 E 985.61 8.03 5452 4459.27 4400.00 1083.75 S 2564.14 E 993.73 8.12 5550 4549.03 4489.76 1097.61 S 2598.22 E 1000.97 7.25 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS 'SPERRY--SUN HORIZONTAL ¢-2 mILNE POINT ALASKA 08/29/89 DRLG. SVCS. PROJECTTON START TVD = 0 FINISH TVD = 4549.03 SCALE TS 500 FEET/IN 5OO 1000 1500 2000 2500 3000 DEPARTURE 0 500 1000 1500 2000 2500 3000 I I I I I I I SPERRY--SUN DRLG. --SVCS. 6-2 MILNE POINT ALASKA 08/29/89 VERTICAL PROJECTTON START TVD = 0 FINISH TVD = 4549.03 SCALE IS 1000 FEET/IN LLI 1000 200O 8000 40OO 5000 SO00 7000 2820.55 lO~)O eobo aobo 4oho VERTICAL SECTION DIRECTION = 0.20 GYRO SURVEY G--2 ;"1I - PO t f'"l,T ;:"i.O.. -.J. LrlpE,, Ri_RSK~ MERSURED DEPTH <FT) If'iCL 0 I00 '=' 0 F{ L. 300 400 0.00 O. 53 O. 26 O. 23 O. 82 ~ZIMUTH n. 8 60.°.~ 3 7. 0 46.3 1. 34.,_.':' PR6E ORIGINAl. i 8/29.'"89 RK-BD-90 TRUE '"-~ v=.,.. LRTI'TUBE DEPHRTURE DDG LEG DEPTH SEVERITY (FT) (FT') <FT) O. O0 O. O0 ri IOO. oo 0.23 M °i'tO 00 O. 64 t'-I 300. O0 0.96 M 400. O0 0.60 r'-I 500 2.59 127.4 499.9'9 I 2, 6n0 5 50 129.1 599. ,.-::: ._.~,,. 700 9.07 124.2 699.02 13.10 :--: 00 ! 1. 1 i 121 . n_ 7 q_. 7. =~-.J '--' 22.4 E: 900 _~ 2.98 I ." 5.5 895. 3'- 5 3'Z. a6 1000 1100 1200 1300 1400 1500 T. O0 '~'00 1800 1900 15.5'9 19.41 21.6,6 24.83 ~. :~5 00 {] . 2100 '="=' 0 I'l l__~ . 2300 2400 110.2 ! 09.3 109. I 109.9 110.0 110 = 110.0 !I0.7 111 '--' · L. _1 11. ,_':: 111.5 I 10.'~ 110.8 !10.0 110.5 i10 o 110.8 110. c, 111. L1 111.0 111.I 112.5 !14.9 116. i 115.? 115.3 ~I4.= 114 o 114.2 29.74 29.46 28.66 34.50 2500 26 0 n 2700 28 00 2900 36. O0 37.96 40.40 43.70 46.21 ':'...., 0 A_ {] °100 :S' 2 00 3300 :34 00 qc~::, ':'~ 41 -'= 3 -- -. ~.. i -_, - I l' ._1 I 087. ~'--;' . 1181.4i 63.39 1273.34 76 .57 ..~'-' 1362. E_--2 91.98 :S 14¢9 86 1 08.88 1536. S5 125.95 1624.3~ 142.81 171~.48 160.98 ~7~3 97 181 17 187~.67 202.:39 3 1955.61 223.76 S o 033 t '-~ 245. f;~ .S 2107 50 269. o--, .-- ::/17E',. 2:3 293. ,? 1 :S 2246.46 °19.21 2313.72 345.19 2380.74 371 58 2447.61 398.14 '-- . 2515.27 424 58 0.00 E 0.40 E 0.5 0.94 E 0.3 1.22 E 0,1 1.88 E 0.9 47.79 47.67 48.14 47.91 46.90 3500 · _-, 600 3700 ..~00 43.59 43.45 42 '-"-' . .2, ,-, 41.89 40.42 4I. 21 45.30 46. ~4 46.67 46.7'2 4.19 E 1.8 9.68 E 2.9 19 90 E o 6 34.67 E ~. 1 .... :..04 E ,- 104.05 E 3.8 137 18 E o o 174.36 E 216.79 E 4.0 262.68 E 0.9 3 08.99 E O. 3 354.51 E 0.8 401.95 E 3.7 453.81 E 8.1 · J06.84 E 1.5 563.08 E 2.0 622.25 E 2.4 -. 685. ;]2 E ~ ~ 751. '--'='~,_ E ~.."'- 5 819.91E 1.6 889.24 E 0.1 958.62 E 0.5 1028.09 E 0.2 1096.83 E l.O 2585. ,?1 450. 11 3 1163..~ 1 -~ ~.° 3 2658.28 475.64 S 1227. F'~Jo E 0 1. 2731.55 502. :32 :S 1289.6,3 E 1.1 2805.-'--%, ~ 529.89 S 1350.76 E 0.5 2:881 09 =:~' 1,.' ..:. . · ,..',-',=,. 141 0 15 E 1.5 · 2956.8 :L 586.68 S 1468.94 E O. 8 3029.65 616. !7 ::E.: 1530.82 E 4.1 :309q...06 646.49 ~ ° _1596.12 E 1.5 3167.E. 2 6?6.50 3 1662.47 E 0.1 3236.19 "?06.35 S 1728.88 E 0. I I ' ':' ~: E R ~ ;f ~ S U H G Y R D 3 U R V E":' ~-~DHDCD Mi. ~ PDIRT ~" ' ~LRSg'.R hiD. .'-.~.I]F E, MERSURED DEPTH ,:'. FT) i HCL 4000 4t00 4200 4300 4400 45.96 46.55 46.80 47. 00 47.13 4500 4600 4700 4800 4900 46.20 4:3.2.:6 38.64 :__.',4.96 :31.40 5000 5100 5200 5300 54 00 · 24.54 ;--'2.6,5 22.17 2;-'. 36 '~500 22.3! '='.22 RZIMUTH 114.4 114.1 1 t4 m 1.. !14.0 !14.3 114.5 i14.6 114.9 !14.7 115.0 114. :3 114.9 113.! I13.3 113. O 112.1 11o.~ TRUE VERT. DEPTH (FF) 3305.2'2 .%'~. :3374.3, 3442.98 3511.29 3579. :38 3647.98 3719. 06 3794.63 :S874 -"._ :3958.5 0 4045.45 4135.21 4226.9 0- 4319.39 441 i ~" 4504.52 455 0.81 LRTITUBE (FT) 736.12 :S 765.78 S 795.57 :S 825.41S 855.40 S 885.47 914.69 942.07 967.14 990.09 1010.8'.4. :.-.: 1 029.45 3. t 045.75 3 1060.74 S 1075.6 O 3 1 090.15 .Z 1097.27 3 PRGE '2 8/29/89 RK-BD-9008]~' DEPRRTURE (FT) 1794.84 E 1860.,2 E 1927.13 E 1993.81E 2060.63 E 2126.89 E 2190.94 E 2250.47 E '~°04 85 ~ 2354.52 E 2399.40 E 2439.49 E 2476.02 E 2511.04 E 2545.87 E 258 O. 95 E 2598.49 E ])D~ LEG S EVER I T",' 0.8 0.6 0.3 0.2 0.1 2.9 4.6 "~ 3.4 2.0 O. 5 0.2 0.1 0.2 .i PCF ~. S L~ED ,EPTH NL SPERRY-~JUN iNTERNATIONAL SURVEY DATA .... 27-AUG- 1989 16: 52' 41 ANGLE DIRECTION VERTICAL LATITUDE DEPARTURE VERTICAL DOG DEC DEG DEPTH FEET FEET SECTION LEG o,00 59!.00 683.00 774.00 865.00 956.00 1138.00 !229.00 10.20 S 54.20 E 772. 12 24. 77 S 23. 15 E 30, 65 2, 77 11. 80 S 61,9~ E 861.45 33, 87 S 37.90 E 47.71 2.38 13. 70 S 66, 00 E 950. 21 42, 63 S 55.95 E 67, 72 ' 2, 31 20.30 S 70.20 E 1124, 16 62, 12 S 105.40 E 12~. 87 3.69 21. 70 S 71. 8Q E 1209. 12 72.72 S 136,24 E 153, 45 1,66 1320.00 1441.00 1536. ee 166.3.0o ~758. ,se 24. 80 S 71. 20 E 1292.72 84. 13 S 170.30 E 189. 31 3, 42 ,-9.00 S 71.20 E 1400. 60 lO1. 77 S 222. 11 E 243.98 3, 47 Se. 20 s 72. le E !483.20 116, 53 S 266, 65 E 290. 82 1, 35 !9. !0 S 71. 10 E 1593.57 136. 35 S 326. 26 E 353, 55 0, 95 29.70 S 69, 80 E '1676,34 151. 96 S 370, 20 E 400. 15 0,92 :914.00 2006.00 210!. 00 2193.00 2288.00 34. 10 S 68, 60 E 1808. 75 181.28 S 447. 23 E 482. 56 2. 85 35. 80 S 67.40 E 1884. 15 20 1.03 S 496.09 E 535. 25 1.99 37. 80 S 69. 80 E 1960. 22 221. 76 S 549.07 E 592. 15 2, 59 39. 80 S 69. 10 E 2031,92 242.00 S 603. e4 E 649. 78 2, 23 43. 10 S 69, 80 E 2103. 11 264, 06 S 661, 92 E 712, 65 3, 51 __J83,00 2476.00 2666.00 2808. e0 2945. ee 45, 80 S 70, 40 E 2170. 93 286.70 S 724.47 E 779. 14 2, 88 47.70 S 69. 80 E 2234.64 309. 76 S 788. 16 E 846. 84 2. i0 4.8.30 S 69. 80 E 2361.78 358.52 S 920.67 E 988.00 0.32 47. 80 S 70.40 E 2456. 70 394.46 S 10 19. 97 E 1093. 56 0.47 45.60 S 71.60 E 2550.66 426, 94 S 1114.23 E 1193. 15 l, 73 3162 3545 .3735 3921 4320 .00 .00 .00 42. 90 S 68, 80 E 2706. !0 478. 13 S 1256. 69 E 1344. 45 1, 54 42. 70 S 68. 10 E 2987. 12 573. Y1 S 1498. 72 E 1604, 67 0. 13 46. 30 S 68. 10 E 3122. 61 623, 38 S 1622. 26 E 1737. 82 1. 89 46, 50 S 70.20 E 3250. 89 671. 31 S 1748. 13 E 1872. 49 0. 82 46, 80 S 68, 20 E 3524. 80 774.34 S 2019. 33 E 2162.57 0.37 4444.00 4507.00 4632,00 4756.00 4883.00 46. 80 $ 69, 80 E 3609.68 806, 73 S 2103. 71 E 2252.95 0.94 46, le S 69, 70 E 3653.09 822.54 S 2146. 55 E 2298.60 1, 12 42.30 S 68.20 E 3742.69 853.79 S 2227. 87 E 2385.72 3. 15 37.00 S 68,60 E 3838. 13 882. 92 S 2301. 41 E 2464. 82 4, 28 32.60 S 68, 10 E 3942. 39 909,64 S 2368. 77 E 2537.28 3, 47 5009.00 5198.00 5322.0o 5511.00 5599.00 28. !0 s 67. 40 E 4051, 10 933. 72 S 2427. 69 E 2600, 92 3, 58 22.40 S 68, 40 E 4221.97 964, 11 S 2502. 32 E 2681. 50 3.02 22. 20 S 68, 80 E 4336.69 981. 28 S 2546, 13 E 2728. 56 0, 20 22. 20 S 69. 80 E 4511.68 !006,52 S 2612. 93 E 2799. 96 0, 20 22.00 S 68, 80 E 4593. 22 1018. 22 S 2643. 90 E 2833.06 0.48 THE nnG FG _ ..... ;,_L_,_ SEVERITY IS IN DEGREES PER lee FEET THE VERTICAL SECTION WAS COMPUTED ALONG S 68. 38 E BASED L!PON MINIMUM CPRVATURE TYPE CALCULATIONS. THE BOTTOM HOLE DISPLACEMENT iS 2833. 19 FEET IN THE DIRECTION OF S 68. 94 E COORDINATE VALUES ARE GIVEN RELATIVE TO THE WELLHEAD CONOCO INC. G-2 MILNE POINT ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVIC~:S ANCHORAGE ALASKA 9/ 1/89 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 0 .00 -59 100 100.00 40 200 200.00 140 300 299.99 240 400 399.99 340 500 499.93 440 600 599.67 540 700 698.85 639 800 797.29 738 900 895.07 835 .27 .73 .73 .72 .72 0 0 0 31 0 15 0 13 0 49 · 66 2 35 .40 5 30 .58 9 4 .02 11 6 .80 12 58 1000 991.98 932.71 1100 1087.33 1028.06 1200 1180.96 1121.69 1300 1272.83 1213.56 1400 1362.04 1302.77 PAGE 1500 1449.25 1389.98 1600 1536.20 1476.93 1700 1623.61 1564.34 1800 1709.73 1650.46 1900 1793.16 1733.89 15 35 19 24 21 39 24 49 28 51 29 44 29 27 28 39 32 23 34 30 DATE OF SURVEY: 08/29/89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90087 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. N .00 E .00 .00 .00 N 60.30 E .53 .23N .40E N 37.00 E .31 .64N .94E N 46.30 E .05 .96N 1.22E S 45.80 E .84 .60N 1.88E .O0 .28 .62 .75 1.50 2000 · 1874.82 1815.55 36 0 2100 1954.69 1895.42 37 57 2200 2032.19 1972.92 40 24 2300 2106.44 2047.17 43 42 2400 2177.18 2117.91 46 12 S 52.60 E 1.78 1.27S 4.19E S 50.90 E 2.91 5.67S 9.70E S 55.80 E 3.62 13.12S 19.94E S 59.00 E 2.11 22.52S 34.72E S 64.50 E 2.19 32.31S 53.12E 4.35 11.14 23.48 40.75 61.50 2500 2245.38 2186 2600 2312.64 2253 2700 2379.68 2320 2800 2446.56 2387 2900 2514.23 2454 $ 69.80 E 2.92 41.79S 75.87E S 70.70 E 3.83 51.93S 104.17E S 70.90 E 2.25 63.46S 137.30E S 70.10 E 3.19 76.64S 174.49E S 70.00 E 4.02 92.05S 216.92E 86.15 116.17 151.17 190.56 235.64 3000 2584.63 2525 3100 2657.15 2597 3200 2730.38 2671 3300 2804.54 2745 3400 2879.82 2820 S 69.50 E .92 108.99S 262.82E S 70.00 E .37 126.08S 309.16E S 69.30 E .87 142.97S 354.70E $ 68.80 E 3.74 161.14S 402.12E S 68.20 E 2.14 181.34S 453.39E 284.52 333.86 382.38 433.13 488.22 S 68.50 E 1.51 202.63S 507.03E S 69.80 E 2.11 224.02S 563.24E S 69.20 E 2.47 246.15S 622.39E S 70.00 E 3.34 269.48S 685.17E S 69.50 E 2.53 293.93S 751.44E 545.91 606.02 669.12 736.03 806.59 .11 47 47 .37 47 40 .41 48 8 .29 47 54 .96 46 54 S 69.70 E 1.59 319.42S 819.98E S 69.20 E .39 345.40S 889.27E S 69.20 E .47 371.75S 958.63E S 69.00 E .27 398.27S 1028.09E S 69.00 E 1.01 424.65S 1096.81E 879.65 953.58 1027.73 1102.03 1175.60 .36 .88 .11 .27 .55 43 35 43 27 42 22 41 53 40 25 S 68.90 E 3.31 450.15S 1163.07E S 67.50 E .97 475.72S 1227.01E S 66.30 E 1.35 502.43S 1289.63E S 65.10 E .94 530.03S 1350.78E S 63.90 E 1.67 558.35S 1410.17E R EJVED 1246.57 1315.41 1383.50 1450.56 1516.29 NOV £ 9 lg )O Oil .& Gas Cons, Commissio~ Anchorage spERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE CONOCO INC. G-2 MILNE POINT ALASKA COMPUTATION DATE: 9/ 1/89 DATE OF SURVEY: 08/29/89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90087 KELLY BUSHING ELEV. = 59.27 OPERATOR: D. HARGER FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES VERT. DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3500 2955.50 2896.23 41 12 3600 3028.32 2969.05 45 17 3700 3097.75 3038.48 46 44 3800 3166.33 3107.06 46 40 3900 3234.92 3175.65 46 43 S 64.30 E .83 586.89S 1468.97E 1581.56 S 64.70 E 4.10 616.38S 1530.81E 1650.00 S 65.50 E 1.55 646.67S 1596.07E 1721.91 S 65.80 E .23 676.68S 1662.38E 1794.67 S 65.80 E .05 706.51S 1728.76E 1867.42 4000 3303.95 3244.68 45 57 4100 3373.10 3313.83 46 32 4200 3441.71 3382.44 46 47 4300 3510.04 3450.77 47 0 4400 3578.16 3518.89 47 7 S 65.60 E .77 736.28S 1794.69E 1939.75 S 65.90 E .63 765.95S 1860.56E 2011.97 S 65.80 E .26 795.71S 1926.94E 2084.70 S 66.00 E .25 825.53S 1993.59E 2157.70 S 65.70.E .25 855.48S 2060.39E 2230.89 4500 3646.78 3587.5L-- 46 12 4600 3717.81 3658F5'4 43 15 4700 3793.32 3735.05 38 38 4800 3873.38 3814.11 34 57 4900 3957.06 3897.79 31 23 S 65.50 E .94 885.52S 2126.63E 2303.60 S 65.40 E 2.94 914.76S 2190.64E 2373.94 S 65.10 E 4.62 942.18S 2250.15E 2439.43 S 65.30 E 3.68 967.31S 2304.51E 2499.29 S 65.00 E 3.56 990.30S 2354.17E 2553.97 5000 4043.95 3984.68 27 55 5100 4133.64 4074.37 24 32 5200 4225.27 4166.00 22 38 5300 4317.71 4258.44 22 10 5400 4410.26 4350.99 22 21 S 65.20 E 3.48 1011.14S 2399.04E 2603.42 S 65.10 E 3.38 1029.70S 2439.14E 2647.59 S 66.90 E 2.02 1046.00S 2475.69E 2687.60 S 66.70 E .49 1061.02S 2510.73E 2725.72 S 67.00 E .22 1075.91S 2545.57E 2763.61 5500 4502.75 4443.48 22 18 S 67.90 E .35 5550 4549.03 4489.76 22 13 S 67.90 E .18 1090.49S 2580.67E 2801.61 1097.62S 2598.22E 2820.55 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2820.55 FEET AT SOUTH 67 DEG. 5 MIN. EAST AT MD = 5550 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 112.90 DEG. RE(EiVED NOV Alaska OJJ & Gas Oons. Anchorage CONOCO INC. G-2 MILNE POINT ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 DATE OF SURVEY: 08/29/89 9/ 1/89 JOB NUMBER: AK-BO-90087 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 .00 -59.27 1000 991.98 932.71 2000 1874.82 1815.55 3000 2584.63 2525.36 4000 3303.95 3244.68 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 .00 41.79 S 75.87 E 8.02 8.02 202.63 S 507.03 E 125.18 117.16 450.15 S 1163.07 E 415.37 290.18 736.28 S 1794.69 E 696.05 280.68 5000 4043.95 3984.68 5550 4549.03 4489.76 1011.14 S 2399.04 E 956.05 260.01 1097.62 S 2598.22 E 1000.97 44.92 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. NOV 2 9 iS~9¢9 Alaska Oil & Gas 6ons. 6ommissio~l Anchorage CONOCO INC. G-2 MILNE POINT ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE DATE OF SURVEY: 08/29/89 9/ 1/89 JOB NUMBER: AK-BO-90087 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 .00 -59.27 .00 .00 .00 59 59.27 .00 .04 N .08 E .00 159 159.27 100.00 .49 N .83 E .00 259 259.27 200.00 .85 N 1.10 E .01 359 359.27 300.00 1.00 N 1.46 E .01 459 459.27 400.00 .16 S 2.74 E .03 559 559.27 500.00 3.49 S 7.00 E .18 659 659.27 600.00 9.80 S 15.18 E .72 761 759.27 700.00 18.67 S 28.32 E 1.99 863 859.27 800.00 28.76 S 45~67 E 3.99 966 959.27 900.00 38.62 S 67.63 E 6.85 1070 1059.27 1000.00 48.75 S 95.17 E 11.09 1176 1159.27 1100.00 60.64 S 129.16 E 17.39 1285 1259.27 1200.00 74.55 S 168.67 E 25.83 1396 1359.27 1300.00 91.54 S 215.51 E 37.58 .00 .00 .00 .00 .02 .15 .55 1.26 2.00 2.86 4.24 6.30 8.43 11.75 1511 1459.27 1400.00 110.99 S 268.18 E 52.27 1626 1559.27 1500.00 130.54 S 321.41 E 67.23 1740 1659.27 1600.00 150.12 S 373.51 E 81.68 1858 1759.27 1700.00 172.71 S 431.78 E 99.62 1980 1859.27 1800.00 198.49 S 496.52 E 121.51 2105 1959.27 1900.00 225.26 S 566.59 E 146.54 2235 2059.27 2000.00 254.45 S 644.44 E 176.63 2374 2159.27 2100.00 287.39 S 733.93 E 214.84 2520 2259.27 2200.00 324.74 S 834.34 E 261.41 2669 2359.27 2300.00 363.66 S 937.34 E 310.15 2818 2459.27 2400.00 403.31 S 1041.23 E 359.70 2964 2559.27 2500.00 441.28 S 1140.05 E 405.35 3102 2659.27 2600.00 476.49 S 1228.86 E 443.66 3239 2759.27 2700.00 513.02 S 1313.77 E 479.84 3373 2859.27 2800.00 550.65 S 1394.45 E 513.73 14.69 14.96 14.45 17.94 21.89 25.03 30.09 38.22 46.56 48.74 49.55 45.65 38.31 36.19 33.89 3505 2959.27 2900.00 588.34 S 1471.98 E 545.77 3644 3059.27 3000.00 629.76 S 1559.16 E 584.78 3789 3159.27 3100.00 673.61 S 1655.55 E 630.44 3935 3259.27 3200.00 717.11 S 1752.34 E 676.25 4079 3359.27 3300.00 759.99 S 1847.23 E 720.62 RECEIVE 32.04 39.01 45.66 45.81 44.37 NOV 1990 Alaska Oil & Gas Cons. CommissiO Anchorage ~PERRY-SUN DRILLING SERvIC~ ANCHORAGE ALASKA PAGE CONOCO INC. G-2 MILNE POINT ALASKA COMPUTATION DATE: 9/ 1/89 DATE OF SURVEY: 08/29/89 JOB NUMBER: AK-BO-90087 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 4225 3459.27 3400.00 803.38 S 1943.99 E 766.38 4372 3559.27 3500.00 847.11 S 2041.85 E 812.97 4517 3659.27 3600.00 890.87 S 2138.36 E 858.68 4655 3759.27 3700.00 930.32 S 2224.49 E 896.47 4782 3859.27 3800.00 963.13 S 2295.43 E 923.43 45.76 46.59 45.71 37.79 26.96 4902 3959.27 3900.00 990.86 S 2355.37 E 943.31 5017 4059.27 4000.00 1014.49 S 2406.31 E 958.02 5128 4159.27 4100.00 1034.63 S 2449.76 E 968.91 5236 4259.27 4200.00 1051.57 S 2488.74 E 977.58 5344 4359.27 4300.00 1067.72 S 2526.30 E 985.61 19.87 14.71 10.89 8.67 8.03 5452 4459.27 4400.00 1083.75 S 2564.14 E 993.73 5550 4549.03 4489.76 1097.61 S 2598.22 E 1000.97 8.12 7.25 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POI~ITS NOV 2 9 Oil & 6as Cons. Cornmissio~ Anchorage AOGCC GEOLOGICAL MATE~.iALS iNYENTORY LiST COMDLE~ON DATE / ! 1 ~ / '~'~"80, CONTACT ~x~'~;/,~'~ a check off or list data as it is receivcd,*list received date for 407. if not rcouired list as NR * / drillin~ history survey 'well tests core descri cored intervals core anaivsis dry ditch intervals dioital data , n~---rt~n~: ' ' ' r~UN LV~I i IrL NO. !''~} ~"~to~'/~ ~i~~ c~g 9! 10] 118! i ! ~I,~I, LL [inchl! 00'1 ! ~ i Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 November 19, 1990 Mr. Lonnie C. Smith Commissioner Alaska 0il & Gas Conservation Commission Subject: Milne Point Unit, Well No. G-2 Dear Mr. Smith: Please find enclosed an application for Sundry Approvals in triplicate for the above referenced well. Sincer~ely, , C. Van L~neberger Sr. Production Engineer NOV 9 1990 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Alter casing __ Change approved program __ 3. A~ 'C' ST,· 4. Location of well at surface Suspend __ Repair well __ Pull tubing __ Variance __ 5. Type of Well: Development Exploratory ~,~Stratigraphic SUITE 2 0 0 # AI~TCHO GE · ,-~,.~, Service 9950~1 3585" FNL, 3354I FEL, ~topofproductiveinterval 4629" FNL, 889" FEL, ~effectivedepth 4709" FNL, 6951 FEL, ~totaldepth Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Perforate __ Other _]~ 6. Datum elevation (DF or KB) KB-59.3" MSL feet 7. Unit (~[P~.i~F ~NT UNIT 8. Well number 9'. Permit number SECTION 27· T13N· R10E· UM SECTION 27, T13N, R10E, UM SECTION 2?, T13N· R10E, UM 89-28 10. APl number 50--029-21926 11. Field/Pool UPPER CRET-W SAK RECEIVEr) 12. Present well condition summary Total depth: measured 5714 I feet:" Plugs (measured) true vertical 4 ? 011 feet ' . . . Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 5022" Length 80I 2843I 5666! measured -5046" 5063,5066 true vertical Tubing (size, grade, and measured depth) feet Junk (measured) feet Size Cemented N/A NOV 1990 N/A Alasl(a 0ii & Gas Cons. Com 'tssiot Ancho ge Measured depth ~rue'vertical depth 13-3/8" 9-5/8" 48#/FT 60 47 #/FT 172 123 29# 24 52 BBLS ARC SET 110I RKB 110I RKB BBLS PERF E 2665I RKB 24907 RKB BBLS CLASS G 123 BBLS CLASS G 5694I RKB 4682I ~ BBLS ARC SET I, FOLLOWED BY BBLS DEAD CRUDE -5069",5072"50761,5085-5094I 4063I - 4127" 2-7/8", 6.4#/FT. L-80, EUE, 4548I RKB Packers and SSSV(type and measured depth) BAKER RETRIEVABLE BRIDGE PLUG SET @45481 BAKER MOD 'D' p~RMANENT ~;%CKER ~E,~ ~4~ql ~_ 13. Attachments Description summary of proposal __ Detailed operations prograrnx._ BOP sketch __ 14. Estimated datefor commencing operation 11/16/90 16. If proposal was verbally approved LONNIE SMITH Name of approver 11/14/90 Date approved 15. Status of well classification as: Oil ~ Gas__ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,~ ~ ///~,/¢~ Title SR. PRODUCTION ENGINEERDate FOR COMMISSION USE ONLY 11/19/9o Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required lO- Approved Copy Returne~l Approved by order of the Commission '-- ' - ' '-' ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner J Approval N o.~,,~ _,¢~¢,Z.~, Form 10-403 Rev 06/15/88 KB BL MPU G-2 WELL Milne Point Unit PROPOSED ESP RUNNING PROCEDURE AFE No. 10-61-1309 11/16/90 - CVL Objective: Clean up fluids; Retrieve bridge plug; run ESP and postpone start-up until surface equipment hook-up is completed. Surface Location: 3585' FNL & 3354' FEL of Sec. 27, T13N, RIOE Depths: All depths are measured from original RKB (59.3') and MWD open hole logs dated 8/27/89. Casinq: Surface: 9-5/8", 47 #/ft, L-80, btrs. set @ 2856' Production: 7", 29 #/ft, L-80, btrs. set @ 5694'. Capacity : 0.0371 bbl/ft Drift ID = 6.184" Burst Pressure : 8160 psi Tubinq/workstr: 2-7/8", 6.5 #/ft, L-80, EUE 8rd Capacity : 0.00579 bbl/ft tubing; 0.0291 bbl/ft annulus ID : 2.441"; Drift ID : 2.347" Burst Pressure : 10,570 psi Torque (ft-lb): Min : 1730; Optimum : 2300; Max : 2880 Misc:. Retrievable bridge plug (RBP) @ 4548' (Baker Model "G") PBTD : 5613'(driller)/5064'(TDT-GP log 4-13-90) TD : 5714' Pore pressure = 8.7 ppg equivalent (1835 psi) Fluid in well = 9.2 ppg NaCl(possibly topped off w/ diesel) Proposed completion fluid -- 9.2 ppg NaCl (10 deg F TCT) Max Angle : 48 deg; Angle through pay : 26 deg Perforations: NA; 5022'-46' NB; 5056' -76' NC; 5085' -94' RECEIVED NOV ~ Alaska Oi~ .& Gas Oons, /mchorag~ Proposed RU, Cleanup, and Bridge Pluq Retrievinq Procedure- NOTE: Hold frequent on site safety meetings prior to all potentially haZardous tasks. · Skid rig to the G-2 well and RU on well. Install pump-through BPV in tubing hanger profile. ND tree and tubing hanger. NU BOP's. Install pipe rams for 2-7/8" tubing. Test rams to 250/4000 psi and test Hydril to 350/3500 psi. Record tests on AOGCC and Conoco daily reports. Pull BPV. NOTE: Insure that well is dead. Freeze protection may have induced an underbalance on formation if bridge plug is leaking. It may be necessary to kill well by circulating 9.2 ppg brine throughout wel 1 bore. · Back out hold-down pins on hanger and PU tubing to remove tubing hanger. GIH to 4543' (5' above RBP @ 4548'). Reverse circulate the following cleansing pill at maximum pump rates. a· c· Lead pad - 25 bbls of 3.5 #'s HEC/bbl of brine Chemical pad - 50 bbl s of brine + I drum of surfactant/dispersant(Safe-Kleen, Dirt Magnet, etc..) Tail pad - 25 bbls of 3.5 #'s HEC/bbl of brine Post flush - circulate with filtered brine (10 microns) at maximum rates until less than 50 NTU NOTE: 1. Safety and environmental precautions must be taken when handling brine and chemicals. Review MSDS sheets prior to handling. 2. Chemicals must be mixed and maintained above 70 deg F. 3~ · Monitor brine clarity every 50 bbls during post flush with a Turbidity Meter. Submit results to engineering. GIH and latch RBP @ 4548'. running/pul 1 ing tool. POOH and rack back tubing. L/D RBP and RECEIVED NOV 2. 9 1990 Alaska Oil & Gas Cons. Commission Anchorage Proposed ESP and Tubing Runnin_q Procedure' 1. MU ESP assembly on 2-7/8" tubing as follows- ae g. h. i. Centrilift PHD (BHP device) unit Centrilift 65 hp 562 Series motor w/ centralizer (7", 29 #/ft casing) Centrilift 513 GSB seal section Centril ift FRSX Gas Separator Centrilift FC-650 400 Series pump w/ !62 stages X-over to 2-7/8" EUE 8rd 2 jts 2-7/8" EUE 8rd 2-7/8" AVA ported nipple (w/o sleeve or check valve) 2-7/8" EUE 8rd to surface e RIH w/ ESP assembly no faster than 30' per minute. Attach two cable bands per joint. Attach additional bands above and below each cable splice. e Locate bottom of ESP assembly at + 4630'. Maintain 30'-50' above gravel pack packer @ 4669'. NOTE: Do not space out with pup joints at surface. Spot the assembly with a full joint connection at the wellhead for ease in NU tree. e Pump sufficient diesel down annulus allowing it to U-tube back through the kelly hose into tubing to allow 1800'-2000' of freeze protection. 5~ ND BOP's. NU tree. RD and move to next well. Await surface facilities connection for production. Prepared by' Reviewed bY-\r-~ Marc Shannon i~. Supervising Prod. Engr. Approved by' ~: D. E. Howell Production Supt. NOV 2 9 ~la-~a.OjJ.& Gas Cons. Commission Anchorago cc' DEH, PMS, MPU Sr. Fm. (2), CVL, Original to File' G-2 Well File ~,-ERATOR /50~D~OI SIZE WEIGHTi GRAOE i THREAD COMPANY REP, I WELL# ¢' ''~ LINER FIELD /~'/A/! '/~'"~' / i; STRING , m SHORT STATE O. O~ ~ coM~r,o. FLU,O I. C~S,.~ DATE I--I New Completion [] Workover WT. ON ~. DEm'H LE~'H OO ID =ESC,IP'nO~ ~ ~Ocl~.n.~ II. I~ 3,,$o :.,,,id "-7-.~1/ "'~',a/~ .~e~,~,~J -- ~;no~.~q · , ~'7'7,& .,~S ~.~. ~'t. ,-~.~]'~ ~.4q " ~ "'~' .... ~ ~1. 75.32 ~.R~ ~.'50 ~.~ . . . . ~, .. _.. . . . . . DISTRI~ ~RFORMING ABOVE SERVIC~ CIRCLED ' BA R COBOL - '- WELL PROFILE" I' !i .., · ~'~;'::-; ':.' - ' /'¢ -.-.- ~-' - -.~.-.~-.)-:: 7.:- -.::- :;-7-~-.--:* ~ - 57_ _~%~ -::~ ~_. : ::5_<::-_-'::3 ~-. . .,:,Jr'cT:i- I . ' .... $oz~' [~t "' i~. I .~..' '<'/.- / I -&';' 3. 5 '" .. ._ · · YELL Initial 'LUIDS Final ~ rm 6001 . ._.- £~. ,'RILIFT EQUIPMEN . G ~ OTATION A Baker Hughes company 200 W. Stuart Roosa Dr. · Claremore, Oklahoma 74017 · (918) G41.9600 DATE 8- 02- 90 CONOCO QUOTATION NO. ~R~SENTEO-By ,, D2213-06-22-3181 $. Hester · CAPACITY TOTAL HEAD FREQUENCY Post Office ~ox 340p~5 pr. pdhoe Bay, AK 997-34 AT'TN:" 'Van Ltnebe~ger ~'iL NAMe: c- 2 FIELD NAME: Milne Point -~-OC ;T~O N: ' Prudhoe- B~y, ~ I ' GR. PERFS SE~RNG DEPTH 9850 H-,~% B.H.T. PRIMARY VOLTAGE 1250 REQ. SURFACE VOLTAGE G.D.R. CASING O.D. WEIGHT TUBING SIZE REQUIRED KVA THREAD NET LIFT SURFACE PSt 400 [=RICTION LOSS T.O.H. VARIABLE FREQUENCY -~ 60 HERTZ -~ $O HERTZ MOTOR H.P, 65 VOLTAGE. ],250 AMPERAGE 30 NO. PCS. ], RATING SERIES 562 MODEL [~v[~ LENGTH 9 · 1 PUMP STAGES TYPE FL650 HSG. NO, 8 NO. PCS. 162 SERIES 400 MODEL FPU LENGTH [3,2 PUMP INTAKE SERIES MODEL FRSX LENGT~ ~'~parato PUMP DSCHRG. SERIES MODEL LENGTH CONN. GAS SEPARATOR SERIES MODEL LENGTH SEAL SECTION SERIES MODEL GS]~ LENGTH POWER CABLE AW~' ' ' TYPE LENGTH ARMOR FLAT CABLE - ' SERIES TYPE LEN~'r~ " FLAT GUARDS CAi~LE SADDLES CABLE BANDS CABLE BANDS SWAGED NIPPLE CHECK VALVE DRAIN VALVE EQUIPMENT COATING: ,MOTOR CONTROLLER ACCESSORIES iNCLUDE; VARIABLE FREQUENCY CONTROLLER: TRANSFORMER6 ~IZE PRIMARY TAPS TYPE LENGTH MODEL SIZE VOLTAGE OVERLOAD -. UNDERCURRENT$.D. [] RECORDING AMMETER ~."= AUTO RESTART 2 LIGHTING ARRESTER ~' OTHER KVA TYPE SECONDARY TAPS VARIABLE FREQUENCY TRANSFORMER 130 KVA M~ltf,' TaP We~ ,I Isola'tion JUNCTION BOX (VENTED-SAfETY) ~ [~V TU~ING HEAO Do~nho 1 PED ~Surface Induc=or Package~ Adaptor 400 x 513 CONOCO Mods for ICS Drive ECEiVED NOV 2. 9 1990 0il & Gas Cons. Com~SS[oD ~ch0mge CABLE GUIDE CABLE REEL NO. REEL SUPPORT SHIPPING CASE QTY. ~HIPPING CASE QTY, SHIPPING CASE QTY. SIZE SiZE SiZE SHIPPING CASE QTY. SIZE NOTE: SERVICING EQUIPMENT MAY BE RETURNED FOR 100% CREDIT WITHIN 6 MO.. SUBJECT TO A REPAIR CHARGE EQUAL TO 25% OF THE LIST PRICE. Discoun~ (D f.._r.~ LE I--I I--,I £0 6-2 ft I O0 200 300 400 ~i00 600 700 gO0 gO0 lO(X) 1100 1200 I Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 MR. LONNIE SMITH STATE OF ALASKA OIL AND GAS COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 RE: LETTER OF APPLICATION DEAR MR. SMITH, I AM REQUESTING SHUTDOWN OF WELL OPERATIONS FOR THE G-2 WELL UNTIL THE CONTRACTED WORKOVER RIG CAN FINISH WITH COMPLETION OPERATIONS AND STIMULATION WORK ON THE KUPARUK WELLS. ALSO, WE WILL REQUIRE TIME TO CONSTRUCT THE PRODUCTION FACILITIES FOR THE G-PAD PRODUCTION. THE WELL WAS FREEZE PROTECTED, A RETRIEVABLE BRIDGE PLUG WAS SET IN THE WELL AT 4669', AND THE WELLHEAD TREE WAS FLANGED UP AND PRESSURE TESTED TO 5000 PSIG. CONOCO WILL SUBMIT THE APPLICATION FOR SUNDRY APPROVAL TO RE- ENTER THE SUSPENDED G-PAD WELLS UPON COMPLETION OF THE ABOVE OPERATIONS. RESPECTFULLY, J.D. POLYA DRILLING FOREMAN STATE OF ALASKA .~-~ ALASKA OIL AND GAS CONSERVATION COMMISSION ,~.. ',' APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Alter casing ~ Change approved program __ Pull tubing __ Variance 2. Name of Operator / CONOCO INC. 3, Address 9973. Suspend __ Operation shutdownx__ Re-enter suspended well __ Repair well __ Plugging __ Time extension p Stimulate __ Perforate Other __ 5. Type of Well: Development --X-- Exploratory __ Stratigraphic __ Service __ T13N, RIOE, UR T13N, RIOE, UM ~ T13N, RIOE, UR p_n_ Rn¥ ~4nn4_~_ PRU_nHOE_nAy. AK 4. L~oo~tibnT:)f-~-ell~t-s-uT'f&Je' 3585' FNL, 3354' FEL, Section 27, At top of productive interval 4629' FNL, 889' FEL, Section 27, At effective depth 470g' FNL, 695' FEL, Section 27, At total depth 6. Datum elevation (DF or KB) KB-5g.3 MSL feet 12. Present well condition summary Total depth: measured true vertical 5714 ' feet Plugs (measured) N/A feet 4701' Effective depth: measured 5613 ' feet Junk (measured) N/A true vertical feet 7. Unit or Property name M ! L~E PO !.".T ~J~ ! T 8. Well number g. Permit number 89 -28 10. APl number 50-- 11. Field/Pool Upper Cret-W Sak Casing Length Size Cemented Measured depth Structural True vertical depth Conductor 80' 13-3/8"48#/Ft 60 BBLS ARC SET 110'RKB Surface 2834' 9-5/8"47#/Ft 172 BBLS PERMF E 2865'RKB Intermediate 123 BBLS CLASS G 110'RKB 2490'RKB Production 5666' 7" 29# 123 BBLS CLASS G 5694'RKB Liner 24~BBLS ARC SET I,FOLLOWED BY Perforation depth:measured 52 BBLS DEAD CRUDE 5022'-5046'5056'-5063' 5066'-5069' 5072'5076' 5085'-5094' true verticaj~,063, -4127' Tubing (size, grade, and measured depth) 2-7/8", 6.4#/FT, EUE +4548' RKB 4682' RKB Anchora~a Packers and SSSV (type and measured depth~AKER RETRIEVABLE BRIDGE PLUG SET()4548'.BAKER MODEL"D" PERMANENT PACKER SET e466g'RKB. 13. Attachments Description summary of propose__ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 17. I hereby certify that the foregoing is true and correct to the best of m, 15. Status of well classification as: oik_ Service Gas ~ Suspended knowledge. Signed Title .~FNTnR pRnnmmnTff)N FOREMAN Date 5 I'~,--'/ ~' ~ ~ FORCOMM1SS1ON-USEONLY--' Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearancb ~ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Approved Copy Returned Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C[br6~dibner J Approval No.~' O- "<//~ ~ Date ~2/~/C~_~) SUBMIT IN TRIPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown X.~ Stimulate__ Plugging __ Pull tubing __ Alter casing __ Repair well __ Perforate ][ Other .~X 2. Name of Operator CONOCO INC. 3. Address P.O. BOX 340045, PRUDHOE BAY, AK 99734 5. Type of Well: Development ~X Exploratory __ Stratigraphic __ Service __ 4, Location of well at surface ' 3585' FNL, 3354' FEL, Section 27, T13N, RIOE, UR At top of productive interval 4629' FNL, 889' FEL, Section 27, T13N, RIOE, UH ; At effective depth 4709' FNL, 695' FEL, Section 27, T13N, RIOE, UM At total depth 5714 ' feet Plugs (measured) N/A 4701' feet 12. Present well condition summary Total depth: measured true vertical 6. Datum elevation (DF or KB) KB-59.3' MSL 7. Unit or Property name Milne Point Unit 8. Well number G-2 feet 9. Permit number/approval number 89-28 10. APl number 5o- 029-21926 Effec!ive depth: measured true vertical 5613' feet Junk (measured) N/A feet Casing Length Structural N/A Conductor 80 ' Surface 2834' Intermediate N/A Production 5666' Liner N/A Perforation depth: measured 11. Field/Pool Upper Cret-W Sak Size Cemented Measured depth True vertical depth 13-3/8"48#/Ft 60 bbls Arc Set 110'RKB 110'RKB 9-5/8"47#/Ft 17Z bbls Permf E 2865' RKB 2490'RKB 123 bbls Class G 7" 2g#/Ft 123 bbls Class G 5694' RKB 4682' RKB 24 bbls Arc Set I.FOLLOWED BY 52 bbls DEAD CRUDE 5022'-5046'5056'-5063' 5066'-5069' 5072'-5076' 5085'-5094' true vertical 4063' -4127 Tubing (size, grade, and measured depth) 2-7/8",6.5#,N-80 SETe4548' RKB Packers and SSSV (type and measured depth) BAKER RETRIEVABLE BRIDGE PLUG SET e4548'RKB BAKER MODEL"D" PERMANENT PACKER SET ~4669' RKB SAND (FTP=IO00 PSI. ) 13. Stimulation or cement squeeze summary GRAVEL PACK N SANDS Intervalstreated(measured) GRAVEL PACK SCREENS f/5001'-5098' RKB Treatment description including volumes used and final pressure PUMPED 2650 1 bs. Prior to well operation Subsequent to operation N/A Representative Daily Ave'rage Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 350 84 0 125 PSIG Tubing Pressure 102 PSIG 14. 16. Status of well classification as: OilK_ Gas __ Suspended Service 15. Attachments Copies of Logs and Surveys run B Daily Report of Well OperationsX__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Senior Production Foreman Date SUBMIT IN DUPLICATE ned Form 10-404 ev 06/15/88 Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 MR. LONNIE SMITH STATE OF ALASKA OIL AND GAS COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 DEAR MR. SMITH, FOLLOWING IS THE DAILY REPORT OF WELL OPERATIONS FOR THE G-2 COMPLETION: i)¢ITE OPERATION 03/27/90 03/30/90 03/31/90- 04/02/90 04/07/90 04/08/90- 04/11/90 04/12/90- 04/22/90 04/23/90 04/24/90- 05/01/90 05/02/90 05/07/90- 05/09/90 05/10/90 MIRU WORKOVER RIG, N/D TREE, N/U BOP's AND PRESSURE TEST -- OK. PERFORATE N SANDS. DST. PERFORATE N SANDS. GRAVEL PACK N SAND INTERVAL & RIH W/ ELECTRIC SUBMERSIBLE PUMP. WELL TEST AND PRESSURE BUILD UP SURVEY. N/D BOP's, N/U AND TEST TREE TO 5000 PSIG -- OK. MOVE RIG OFF WELL. FINISH WELL TEST. COMPLETE WELL TEST, FREEZE PROTECT AND SHUT IN WELL. MIRU WORKOVER RIG, N/D TREE, N/U BOP's AND PRESSURE TEST -- OK. POOH W/ ELECTRIC SUBMERSIBLE PUMP. RIH AND SET RETRIEVABLE BRIDGE PLUG AT 4548', FREEZE PROTECT WELL, N/D BOP's, N/U AND TEST TREE TO 5000 PSIG -- OK. INSTALL BPV AND MOVE RIG OFF LOCATION. EOR RESPECTFULLY, J.D. POLYA DRILLING FOREMAN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~IISSION BOPE Inspection Report DATE Operator ~_~ ~t O ~ o ~-~ c~ Location: Sec .~..? T ~)~ A/ R /0~- M ~/v~ / Drlg contrctr Location (general) ~ Well sign General housekeeping Reserve pit /o~-~ MUD SYSTEMS: Visual Audio Flow monitor ~,C , I~ BOPE STACK: Test Pressure Annular preventer _ 2~--() '- -~(~C'~ ~/ Pipe rams ~~ - ~00 ~'/ Blind rams J~O -- ~000 ~J/ Choke line valves - ~&~O '-~~ ~J/ HCR valve ~0 '~ ~~ ~/ KJ-ll l~ne valves ~ Check va 1va ~~ TEST RESULTS: Representati ve ,,/~ ~)' oy Permit # ~-- 5~!~ /0~-- Rep ACCUMULATOR SYSTEM: Full charge pressure Press after closure Pump i ncr clos press 200 ps ig Full charge press attained . Controls: Master Remote ft psig psig mi n /~ sec min ~sec psig. KELLY AND FLOOR SAFETY VALVES: Upper Kelly Test pressure Lower Kelly Test pressure Ball type ~ Test pressure Inside BOP ~/~ Test pressure Choke manifold J Test pressure. J.~ Number valves Number flanges Adjustable chokes Hydraulically operated choke RECEIVE ,? Failures ~JO~j~A' Test time _~ hrs -_ Repair or replacement of failed equipment to be made within /~ days ~% 1 and I nspector/C~i ssi on offi ce noti fi ed. ~8~a .Oil l& Gas Distribution: orig - AOCCC c - Operator c - Supervisor C.004 (rev 03/17/89) Inspector: R ECF..IV F.D CONOCO MPU OPS CTR 90?-659-6390 002 Re{remit or rePlec~ma~nt; of fa~led equ~pm~n+. ~ be made (rev 0311 ?I~0) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown X Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator | CONOCO INc. 3. Address P.O. BOX 340045, PRUDHOE BAY, AK 9973 4. Location of well at surface 3585' FNL, 3354' FEL, Section 27, T13N, At top of productive interval 4629' FNL, 889' FEL, Section 27, T13N, At effective depth 4709' FNL, 695' FEL, Section 27, T13N, At total depth 5. Type of Well: Development .~X Exploratory __ Stratigraphic __ Service __ RiOE, UM RIOE, UR RIOE, UR 6. Datum.e/eva_tLon.(DF. or. KB) Kl¢-bg. 3 NSL 7. Unit or Property name MILNE POINT UNIT 8. Well number 6-2 9. Permit number 89-28 10. APl number 5o- 029-21926 11. Field/Pool Upper Cret-W Sak feet 12. Present well condition summary Total depth: meas'ured true vertical 5714 ' feet Plugs (measured) N/A 4701' feet Effective depth: measured 5613 ' feet Junk (measured) N/A true vertical feet Casing Length Size Cemented Measured depth Structural Conductor 80' 13-3/8"48#/Ft 60 BBLS ARC SET 110'RKB Surface 2834' 9-5/8"47#/Ft 172 BBLS PERMF E 2865'RKB Intermediate 123 BBLS CLASS G Production 5666' 7" 29#/Ft 123 BBLS CLASS G 5694'RKB Liner 24 BBLS ARC SET I,FOLLOWED BY Perforation depth: measured 52 BBLS DEAD CRUDE 5022'-5046'5056'-5063', 5066'-5069' ,5072'5076', 5085'-5094' true vertical 4063' -4127' True vertical depth 110'RKB 2490' RKB 4682' RKB RECEIVEi' ? Tubing (size, grade, and measured depth) 2-7/8", 6.4#/FT, RUE _+4520' Packers and SSSV (type and measured depth) RETR! EVABLE BRIDGE PLUG ~ +4550' MAY 1 ] ]99n AJaska 0il & Gas Cons, Commission ;Anchorag~ 13. Attachments Description summary of proposalX_.._ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation APRIL 8, 1990 16. If proposal was verbally approved LONNIE SMITH Name of approver 5/7Z90 Date approved 17. I hereby certify that the foregoing is true and correct to the best of m' Signed 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service / knowledge. Title SENIOR DRILLING FOREMAN FOR COMMISSION USE ONLY Date 05/07/90 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test__ Subsequent form required lO- mn, NfO BY. ORIGIN.a! .~ ..~,, Approv~o LONN~ u. ~- Returned Approved by order of the Commission , ~--~ Form 10-403 Rev 06/15/88 Commissioner I Approval No.¢ ¢ ... ~~ Date SUBMIT IN TRIPLICATE OPERATIONS SHUTDOWN PROCEDURE FOR G-2 I, POOH WITH ESP. RIH WITH RETRIEVABLE BRIDGE PLUG SET @ + 4550' . PU 1 JT ABOVE THE BRIDGE PLUG. DISPLACE TOP 1000' OF BRINE WITH DIESEL. LAND TUBING IN HANGER. 4. . ND BOP, NU TREE. TEST TREE TO 5000 PSI. LEAVE WELL SHUT-IN UNTIL PRODUCING FACILITIES ARE INSTALLED. CONOCO, Inc. 3201 "C" Street, Suite 200 AnchoraRe. AK 99503 A~ention:. Marc,Sh~nnop SCHLUMBERGER WELL SER¥1CE$ A ~VI$1(~NOF~,T. HLUMBERGER~CHNO~OGY COqq~ATION HOUSTON. TEXAS 77251-217~ ~ ~Y TO APR ! ~ lggO "C-"LUM.E.~E. WELL Pouch 340069 Prudhoe BaT, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore 2~rints of the Company CONOCO, [nc. TDT-PGravel Pack LoR. Run 1, 4/11/90 Well Milne Point Unit G-2 Field. Milne Point Aclditionol prints ore being sent to: i BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER 1BL prints , 1RF Sepia OXY U.S.A., Inc. 6 Midland, TX 79710 Attn:. John Carrol * (915/685-5600) . County North Slope · . · Stote.._ Alaska 1 BL prints, 1 RF'Sepia CONOCO, In¢, .. 1000 s0~uth Pine -"" Ponca City, OK 746,03 Attn: Log' Li. brary :. ', rints 1 Field. Tape n lj -_ S: A 1 BL prints, 1 RF Sepia Chevron U.S.A. 6001Bollinger Canyon Road San Ramon, CA 94583-0943 Attn: Priscilla MacLeroy * (415/842-1ooo) 1 BL~i~s-,~:l RF Sepia "'-- \ /~asfa Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ~'~n: 'John Boyle The film is returned to Conoco, Log Library. prints prints 1950 by: Date: We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter OISTRICT MANAGER $W~--1327~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ '--Re-unter~us'laeT'rded'~ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate _X. Other 2. Name of Operator CONOCO INC. 3. Address 3201 C St #200, 4. Location of well at surface 3585' FNL, 3354' At top of productive interval 4629' FNL, 889' At effective depth 4709' FNL, 695' At total depth Anchorage 99503 FEL, Section 27, FEL, Section 27, FEL, Section 27, 5. Type of Well: Development _X_X Exploratory __ Stratigraphic __ Service __ T13N, R10E, UM T13N, R10E, UM T13N, R10E, UM 6. Datumelevation(DFor~L KB-59.3' ZUnitorPropedyname MILNE POINT UNIT 8. Well number G-2 9. Permit number 89-29 10. APl number 50-- 029-21926 11. Field/Pool Upper Cret-W Sak 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80 ' Sudace 2834 ' Intermediate Production 5666 ' Liner Perforation depth: Tubing (size, grade, and measured depth) 5714 ' feet Plugs (measured) N/A 4701 ' feet 5613 ' feet Junk(measured) N/A 4608 ' feet Size Cemented Measured depth 13-3/8"48#/Ft 60 bbls Arc Set 9-5/8"47#/Ft ~ ~cLass~ermf 7" 29#/Ft measured 5022'-5046' 5056'-5076' 5085t-5094' truevertical 4065,-4086, 40957-4113' 4121'-4130' 2-7/8'7, Blank 5063 ' -5066 ' 5069,-5072' True vertical depth 110 ' RKB 110 ' RKB 2865' RKB 2490'RKB 5694'RKB 4682'RKB 6 4#/Ft, L-80, EUE, ....... '"'.~"~ .'~,~ .c~ 6as O0~S~ Packers and SSSV (type and measured depth) Retri evabl e @ +4850 ' 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch ~__ 14. Estimated date for commencing operation ~arch 7. 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil _~ Gas__ Suspended x Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~"'/~ Title Production Foreman - ' - /,~" FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~c,~ Approved by order of the Commission ORIGINAL SIGNED BY_LONNIE C. SMITH Commissioner IApprOvalNO' ¢O-// /~2 feet Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE G-2 COMPLETION AND TEST SUMMARY ~ ~ MiRU~ NU BOP, test BOP RIH w/ 2 7/8" tbg. w/Vann g~zn assembly to depth. Perforate "N" Sands @ 8 shots/ft. 200 PSI underbalanced w/diesel at the following intervals: MD 5022 - 5046 5056 - 5076 5085 - 5094 TVD 4065 - 4086 4095 - 4113 4121 - 4130 ~ ~ ~ . Run 24 hour flow test° POOH w/guns. RiH w/ESP and retrievable packer. Set pump @ 4900' MD. ND BOP, RD, move to G-3. Test w/ESP for 7 - I0 days° POOH w/ESP. MILNE POINT UNIT BOP STACK FOR 9-5/8" SURFACE CASING FILL-tIP Lille ANNULAR PREVENTER (z) "----'"-"'-- 13%1 ' APl 50004 ~ RAM BOP SPOOL ~ - APl 5OO0 SiDE OUTLET8 , ~ RAM BOP i~S/t- APl ~0OOi s 'H" AP~ ~OOO tP~ ~OOO ' ~ II' APl ~000~ ~000' ~~,~ ~,~ APt ~1 ~1,1 , CSG SIDE OUTL(T$ U ~ J SPOOL ~ ~ U Threaded Connect/on . .. · . -lEo ~ · .- -' Ano. · ~': ' ' · '' '"'' '!! ' ,. - ,.'-'., B.O.P. stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. BOPE to be operated on each trip & pressure tested weekly. Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. Choke and kill manifolds shown separately to meet APl RP 53 class 5M requirements. 1. Operations performed' Operation shutdown ~ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ STATE OF ALASKA ALAbKA OIL AND GAS CONSERVATION COMMISsiON REPOFIT OF SUNDRY WELL OPEFIATIO S 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. JSigned ~ Title Senior Form '10-404 [:lev 6/ 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ~__ 16. Status of well classification as: Oil .J~ Gas __ Suspended __ Service Prior to well operation :N/A Subsequent to operation I~/A Perforate __ Other 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 4. Location of well at suflace 3585' FNL, 3354' FEL, Section 27, T13N, R10E, UM At top of productive interval 4629' FNL, 889' FEL, Section 27, T13N, R10E, UM At effective depth 4709' FNL, 695' FEL, Section 27, T13N, R10E, UM At total depth 12. Present well condition summary Total depth' measured true vertical 5714 ' feet Plugs (measured) ~/A 47 01 ' feet 6. Datum elevation (DF or KB) KB-59.3' MSL feet 7. Unit or Property name Milne Point Unit 8. Well number G-2 9. Permit number/approval number 89-29 10. APl number 50-- 029-21926 11. Field/Pool Upper Cretac. - W S~ Effective depth: measured 5613 · feet Junk (measured) N/A true vertical 4608 · feet Casing Length Size Cemented Measured depth True vertical depth Structural N/A Conductor 80' 13-3/8",48#/Ft 60 bb]s Arc Set 110'RKB 110'RKB Sudace 2834' 9-5/8",47#/Ft 172 bbls Perm¢ E 2865' RKB 2490'RKB Intermediate N/A 123 bbls Class G Production 5666' 7" 29#/Ft 24 bbl Arc Set I 5694' RKB 4682' RKB Liner ~/A ~24 ~bls Arc Set I s Dead Oil Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) ~/A RECEIVED 14. N/A Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Production Foreman Date 12/05/89 SUBMIT IN DUPLICATE Lk 2. Name of Operator ! 5. Type of Well: CONOCO INC. I Development__X Exploratory __ 3. Address Stratigraphic __ 3201 C ST #200, ANCHORAGE, AK 9 503 Service. CHRONOLOGICAL WELL HISTORY Kuparuk River (SOS) North Slope Borough, Alaska W.I. 1.0000000% Milne Point G No. 2 Confidential Kuparuk River SOS AFE 10-61-1203 API No. Ak. Permit No. , Elevation: K.B. Location: 3420' FEL, 4060' FNL, Sec 27, T13N, R10E, U.M. Auqust 22, 1989 Accept rig at 0600 hours. NU diverter stack and diverter lines, function test. PU bit and light HWDP. Drilling ice f/35'-114'. POOH 2/d HWDP, PU Navidrill, MWD, FTB. Drilling f/114'931, now drilling. DEPTH ANGLE TVD DIRECTION 410 0.8 410 Sll.6E 501 2.3 500 S29.6E 591 4.5 590 S41.2E 683 7.8 682 S49.3E 774 10.2 772 S54.2E 865 11.8 861 S62.0E Daily Mud Cost: Daily Cost: $ 3,024 Cumulative Mud Cost: $ 3,024 $ 118,217 Cumulative Cost: $ 118,217 August 23, 1989 Drilling 931' to 1022'. Short trip 931' to 277'. Drilling 1022' to 1917'. Ream 1850' to 1917'. Drilling 1917' to 1949'. Short trip 10 stds. Ream out 1837' to 1949'. Drilling 1949' to 2795'. Now drilling. DEPTH ANGLE 1320 24.8 1758 29.7 2101 37.8 2383 45.8 2476 47.7 2666 48.3 Daily Mud Cost: $ Daily Cost: $ 5,596 Cumulative Mud Cost: $ 8,620 38,371 Cumulative Cost: $ 156,588 August 24, 1989 Drilling 2795 to 2875'. Circ, pump pill. Short trip to 247'. Circ and cond hole. POOH and LD BHA. Clean off floor. Rig up casing crew. Run 72 joints 9-5/8" L-80, 47# BTRC casing FS at 2856'. FC at 2775'. Circ, pump 40 bbls sepiolite spacer, test lines to 300#. Cemented with 172 bbls permafrost 'E' with 5#/sk Auqust 24, 1989 (Continued) silsonite and 123 bbls 'G' with 3% NaC1, 0.2% CFR3, 1% gel, drop plug, displace with 195 bbls mud, bump plug to 2500 psi. Bleed off pressure, RD cement equipment, 20 joint. ND divertor stack, makeup 7" casing head, NH BOP stack, choke line, K00ME4 lines. Daily Mud Cost: Daily Cost: $ 3,719 Cumulative Mud Cost: $ 12,339 $ 177,353 Cumulative Cost: $ 333,941 August 25, 1989 NU BOP. RU to test BOP, test to 500# & 5000 #, chokelines, choke, manifold, inside BOP & safety valves. LD test equip & set wear ting. Witnessed by Bobby Foster, AOGCC. RU BHA, RIH. Test csg to 1500 psi. Drld cmt, plug, float collar, float shoe & 10' new hole 2874'-2884'. Ran 11.5 MEW test. Drld 2884'-3277'. Circ, POOH, change BHA, RIH. Drld 3277'-3499'. POOH to 3238, check MWD, RIH. Drlg 3499' to 3562'. Daily Mud Cost: $ Daily Cost: $ 1,117 Cumulative Mud Cost: $ 13,456 40,569 Cumulative Cost: $ 374,510 August 26, 1989 Drilled 3562' to 4439'. POOH to change BHA. Changed BHA. R/H resurvey 3277', 3660', 3850', 4036' 2D 4 joints DP. Ream 4267' to 4373' for MWD log. L/D damaged joint and change out clips. Ream 4373' to 4437' for MWD log. Drilled L/4437' to 4835'. DEPTH ANGLE DIRECTION 3545 42.7 S68.1E 3735 46.3 S68.2E 3921 46.5 S70.2E 4320 46.8 S68.2E Daily Mud Cost: $ Daily Cost: $ 4,599 Cumulative Mud Cost: $ 18,055 46,178 Cumulative Cost: $ 420,688 August 27, 1989 Drilled 4835' to 5124'. Short trip 10 stds. Drilled 5124' to 5714'. Circ, pump slug. POOH to shoe. Cut 80' drilled line, reset and test arown-o-matic. R/H 0' fill. Circ and cond mud. POOH L/D mud, now reading RLL. DEPTH ANGLE DIRECTION 4632 42.3 4883 32.6 5009 28.1 5198 22.4 Daily Mud Cost: $ Daily Cost: $ 3,897 Cumulative Mud Cost: $ 21,952 54,170 Cumulative Cost: $ 474,858 August 28, 1989 POOH RU run caliper log 5714'-2856' RD loggers LD motor & RLL TIH. Circ & cond mud. POOH, LD. Pull wear bushing, test rams to 2500#. RU & run 146 jts of 7" csg shoe @ 5694'. Circ & pump 40 bbls Sepiolite preflush. Pump 65 bbls Class G w/0.2% Halad 344, oil to diesel, 0.2% CFR-3, drop plug. Displace cmt w/198 bbls 9.6 brine & 10 bbls diesel. Bumped plug to 2000 psi. Daily Mud Cost: Daily Cost: $ 3,207 Cumulative Mud Cost: $ 25,159 $ 214,505 Cumulative Cost: $ 689,363 August 29, 1989 ND landing jnt, cmt head & csg. Crew NU blind flange on wellhead. RIG RELEASED @ 05:00. Run junk basket f/5603' WLM (w/6" gauge ring) to surface, RU run GR/CCL & Gyro f/5500' to 2800'. RD. Daily Mud Cost: $ Daily Cost: $ Cumulative Mud Cost: $ 21,596 Cumulative Cost: $ 710,959 D !~ I I--I,.I N [3 TO: Mr. John Boyle Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 DATE: TRANS.#: September 15, 1989 89-0816AK REFERENCE: CONOCO Milne Point G-2 The following technical data is being submitted herewith. Please acknowledge receipt by signing and returning a copy of this letter to this office, attention Mr. Erik A. Opstad. ENCLOSED INFORMATION SUMMARY Well G-2 Digital: 1 Each Blueline; Total 3 1 Each Sepia; Total 3 1 Each Blueline; Total 1 1 Each Sepia; Total 1 1 LIS Tape 1 LIS Tape Verification Listing Received By: A.O.G.C.C. / Date 8537 Corbin Drive (99507) · RO. Box 231649 . Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company State of Alaska Alaska Oil and Gas Conservation Comnission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 XEROX 295 (Automatic) (907) 276-7542 FACSIMIIM PHONE NO. Mike Minder AK Oil & Gas Conservation Commission Anchorage, Alaska 99501 CONFIRMATION PHONE NO. (907) 279-1433 Ext. 44 Number of pages, including transmittal sheet: 'IF T~,F. COPY DOES NOT ~L~NSbffT PROPERLY, t~.FASE CATL IMMED~Y. 6.M~N. O1 06/08/88 MEMORANDUM State Alaska A.T.~&SKA OIL A~ND GAS CONSERVATION CO!~,!ISSION TO: Lonnie C. Smith D~E: Commissioner FILE NO: September 6, 1989 D.BDF.090 THRU: FROM: TELEPHONE NO: Michael T [--ilnder .... · SUBJECT: Sr Pe_ro~eum Engineer Petroleum inspector BOP Test Conoco ~ MZPU ~ G-2 Permit No. 89-28 IK~-t-n~---t~ Field _Frzaa',_:)! August: =_ 25 The test began at 2:00 am and was concluded at 4:30 am. As~t~attached BOP test report shows there were no failures. As noted on the test report the line from the choke manifold to the gas buster and the line from the gas buster to the shale shaker are not in compliance with APi 6A-13. i requested that this be corrected as soon as possible, when i met with Daivd Mountroy, Conoco rep and Bob Neuman, Parker Drilling rep and both agreed to this request. In summary, I witnessed the BOP test on Conoco's G-2. Attachment 02-001A (Rev. 8~85) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report ft Location (general) General housekeeping . Reserve pit ~/ Well sign ~.,.,,i' Rig u~/ MUD SYSTEMS: Trip tank Pit gauge Flow monitor Gas detectors Visual Audio BOPE STACK: Annular preventer Pipe rams Blind rams Choke line valves HCR valve Kill line valves Check valve Test Pressure ACCUMULATOR SYSTEM: Full charge pressure Press after closure psi g psig Pump incr clos press 200 psig -- min ~'~] sec 1 Full charge press attained ~7/ min ~ sec N2 ~ ~ _~/(~6D psig Controls: Master Remote ~4~_~_~_ Blind switch cover~~~ / KELLY AND FLOOR SAFETY VALVES: , / Test pressure Upper Kelly · Lower Kelly / Test pressure · Ball type / Test pressure Inside BOP / Test pressure Choke manifold L~¢~.J' Test pressure ~'-~/~m~ Number valves Number flanges Adjustable chokes Hydraulically operated choke TEST RESULTS: Failures Repair or replacement of failed equipment to be made within and Inspector/Commission office notified. days orig - AOGCC c - Operator c - Supervisor C.004 (rev 03/17/89) May 5, 1989 Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay~ AK 99734 (907) 659-6300 SR ENG ENG "LF,; ,_-',,EOL_~! ~i~-^"r TECH! _! STAT'TE~Fi!_~-I Mr. D. Johnston Alaska Oil an Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE' Milne Point Unit; Wells G-l, G-2, G-3, and G-4 Dear Mr. Johnston' With reference to Bob Soptei's conversation with Mr. Bob Crandell on May 5, 1989 and the AOGCC mud logging and sampling requirements returned with the approved subject permits dated March 21 and April 21, please be advised that Conoco agrees to mud log Well G-1 and take mud samples on Wells G-1/2/3/4. No mud logs are planned on Wells G-2/3/4. Conoco regrets any confusion that may have occurred when we informed you we were planning to mud log all the subject wells. If you should have any questions please call Bob Soptei or Hal Stevens at (907) 659-6327. Yours very truly, D. F. Rainwater/E. L. Robinson Senior Production Foreman RJS - cc Field Superintendent, Anchorage Safety & Compliance Coordinator Senior Production Specialist RECEIVED Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 April 12, 1989 Mr. C. V. Chatterton Chairman of the Commission Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' RE- PERMITS; MILNE POINT UNIT; WELLS G-l, G-2,1G-3 AND G-4 Enclosed you will find ApplicatiOns for Sundry Approvals for Milne Point Unit Wells G-1 and G-2 (original drilling permits approved by your office on March 6, 1989) and Permit to Drill Applications for Wells G-3 and G-4. A check for $200 is included for the Drilling Applications. If you should have any questions, please contact Bob Soptei or Hal Stevens at 659-6327. · TX R. Painter Oivision Manager RJS/jah File 500.21.04 STATE OF ALASKA ALAS.;,,,-, OIL AND GAS CONSERVATION COMIv,,oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request' Abandon Suspend ' ' Operation Shutdown ] Re-enter suspended well '- Alter casing E] Time extension Change approved program X Plugging ~ Stimulate ~_]. Pull tubing . Amend order f' Perforate ,~' Other 2. Name of Operator Cortoco Tnt. 3. Address 3201 C Street, Suite 200, Anchorage, AK 99503 4. Location of well at surface Revised Locations 3585' FNL, 3354' FEL Sec. 27, T 13N, R 10E, UM At top of productive interval 4579' FNL, 845' FEL Sec. 27, T 13N, R 10E, UM At effective depth N/A At total depth 4649' FNL, 669' FEL Sec. 27, T 13N, R 10E, UM 5. Datum elevation (DF or KB) KB 28 6. Unit or Property name Milne Point Unit 7. Well number 6;-2 8. Permit number 89-28 9. APl number 50--029-21926 10. Pool feet Upper Cretaceous-West Sac 11. Present well condition summary Total depth: measured (Revisions) true vertical Effective depth: measured true vertical 5762'* feet 4685'* feet N/A feet feet Plugs (measured) Junk (measured) Casing (Revisions) Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented 13-3/8" 2895' 9-5/8" 5734' 7" No Changes Measured depth 108' 2923' True Vertical depth 108' 2500' 5762' 4685' true vertical Tubing (size, grade and measured depth) Well will not be tested or completed at this time. Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal ~ Detailed operations program R; BOP sketch 13. Estimated date for commencing operation August 1989 14. If proposal was verbally approved Name of approver ~ Date approved 15.1 hereby~/for~egyg~~ue and correct to the best of my knowledge Signed ' ///~¢ k,~~(~-~ Title Division Manager Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. ~ Plug integrity [] BOP Test ~ Location clearanceI ApProved Returnedopy ORIGINAL SIGNED ~ Approved by LONNIE C. SMITH Commissioner Form 10-403 Rev 12-1-85 by order of the commission Date Submit in triplicate ?~ SUPPLEMENTAL DATA SHEET APPLICATION FOR SUNDRY APPROVALS CONOCO MILNE POINT UNIT G-2 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503 I · Casing and Cementing Program ae The 13-3/8" conductor will be set at 80' below the surface, then cemented to the surface with ±485 sacks of Permafrost Type "C". Be The 9-5/8" surface casing will be cemented with ±486 sacks of Permafrost "E" cement followed by ±592 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. C. The 7" production casing will be cemented in two stages. The first stage will consist of ± 64 sacks of Permafrost "E" cement pumped around the casing shoe followed by ±379 sacks of Class "G" cement. The secondary cement job will consist of +409 sacks of Permafrost "C" cement followed by ± 60 barrels of Arctic Pack pumped down the 7" x 9- 5/8"annulus. II. Drilling Fluid Program ae Be Ce 0-3685' 9.0 ppg freshwater spud mud. 3685'-3905' 9.2 ppg low solids non-dispersed. 3905' - TD 9.4 low solids non-dispersed. III. Drilling Program Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River field (Upper Cretaceous-West Sac). The mud system will be low solids, non-dispersed with a mud weight in surface hole of 9.0 ppg. Mud weight at TD will be 9 4 ppg. A 20", 2000 psi diverter will be installed on the . -3/8" conductor for drilling surface hole , 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure test will be performed as per State Regulations. BOP's, choke manifold, upper and lower kelly will be tested to 500 psig and 5,000 psig, the Hydril to 350 psig and 3500 psig. Casing will be pressure tested to 1,500 psig. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is G-1 with a closure of 60 feet at the surface. The well will not be completed or tested at this time. ao Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. Be Drill a 12-1/4" surface hole to _+2500' TVD (2923' MD) and set 9-5/8" casing. Co Drill a 8-1/2" production hole to 5762' MD and set 7" casing. TVD MD FORMATION BIT MUD WT YP PV VIS FL 0' 0' Gravel 1-1-4 9.0 32 20 90 15 2500' 2923' Sand/Clay 1-1-4 9.0 25 20 65 15 3685' 4602' "K" Sand 1-1-4 9.2 25 15 35 10 3905' 4870' "M" Sand 1-1-4 9.4 25 15 35 10 4165' 5163' "N" Sand 1-1-4 9.4 25 12 35 5 4335' 5344' "0" Sand 1-1-4 9.4 25 12 35 5 4685' 5762' TD 1-1-4 9.4 25 12 35 5 *The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300 feet TVD, a Sundry Notice will be submitted. CONOCO, Inc. ~ Pad G, Well Not 2 Revised Propoeel Hilne Point Unit, North Slope, Aleeke 0 .. RKB ELEVATION ~ 1 000 _ 2000 _ 3;000 _ 4000 _ 5000 KOP TVD'600 THD-600 DEP-O , ~ , , BUILD 3 DEO ,: PER 1 O0 FT ~ g I$ 21 2t' ,.39 MAX I MUM AN GLE 48 DEO 20 =MI N EOB TVD-202? THD-22! 1 DEP-640 g 5/8' CSG PT TVD-2$O0 THDm2923 DEP'11?2 DROP 3 DEO PER 1 04:) FT TARGET ANGLE 20 .DEO . 42 24 I I 1 000 2000 VERTICAL SECTION BEGIN ANOLE DROP TYD=3392 THD-4264 DEP-2174 K SNDS TVD-3685 THD-4662 DEP-2441 Hi SNDS TVD-3905,THD-4923 DEP-258! TARGET / N SNDS TVD-4165 THD-5208 DEP-26gg 0 SNDS TVD-4335 THD-5389 DEP-2761 TD / 7" CSG PT TVD-4685 THD-5762 DEP-2888 PERHITTED DEPTH TVD-4985 THD-6081 DEP=2gg? 3;000 HORIZONTAL PROJECTION SCALE 1 IN. = 1000 FEET SURFACE LOCAT [ ON ' 3585' FNL. ,3354' FEL SEC- 27. T13N. RIlE 1000 ,, m ~ 1000 ,C 2000 PERHITTED DEPTH LOCAT[O#~ ,1.6~9' F#L. E,68' FEL SEC. 27. T13N. RIOE 3000 _ CONOCO. Ino. Psd O, Well Nos 2 Revimed Propossl HI I ne Po int Un I t, North SI ope. Al smke 'i WEST'EAST ~ooo o · iooo 2000 S 68 DEC; 23 HI N E 2699' (TO TARGET) ~000 i 4000 I TARGET / N SNDS TVD-4165 TIID-5208 DEP-2699 SOUTH g g4 EAST 2509 TARGET LOCATION s 45'/'9' FNL. g45' FEL SEC. 27. TI3N. RIOE TD LC)CAT 1014 ' '1'649' FNL. 669' FEL SEC. 27. T13N. RIOE 3350 _ 3400 _ 3450 _ 3500 _ 3550 _ 3600 _ 3650 _ 3700 _ 3750 _ 3500 345C 3400 3350 3250 3200 I I I I ~ 1 200 1000 900 ~oo 600 I I I ,300 / ""1 200 ! · ~'i 100 /°~ 000 "go-o.w ~oo 600 800 ,ooo J ! 1100 I *'I-200 I I I 200 I I 34C 345 I I j _ 350 I J _ 355' I I _ 360( I I -., ~.oo "! ~/F 365C I _ 370( _ 375C i 3500 3450 3400 3350 3300 3250 3200 NO TE S: 1. ,STATE PLANE COORDINATES ARE ZONE 4 2. ALL GEODETIC POSITIONS ARE BASED ON N.A.D. 1927 3. OFFSET8 TO ,SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSTION$ 30' 120' 30' G-2 O PAD _ 60'~j.... 80' j_ 180' _1 IO' ./.'.,.:::.:.:.':..:'_ TYPICAL SECTION NO SCALE F. Robert llllllJ. LOCATION IN i I i r m MIt. NE POINT UNIT MILNE PT. VICINITY MAP 0 I ~ MILE~ ii i - i r~ SEC. 27, T13N, RICE, UMIAT MERIDIAN WELL FROM NORTH LINE FROM EAST LINE G-1 G-2 4,060' 4,000' 3,420' 3,420' STATE PLANE COORDINATES-ZONE 4 WELL NORTH FAST G-1 G-2 6, O13,655.310 6, O13,716.293 GEODETIC POSITIONS NAD 1927 557,190.417 657,189.846 WELL NORTH LATITUDE WEST LONGITUDE G-1 G-2 70' 26'52.5959' 70* 26'53.1859 149° 32'00.4390 149' 82'00.4423 --~j '~--~-=-'~- ~ .~ . ' - ~--~- 2 ' i ~ _ i ii , -, I I ,~ i ERTI~ICATE Ot: ,SURVEYOR: '~Y~M PROPERLY REGISTERED AND ~'~ LICENSED TO PRACT~E LAND ~RVEYING IN THE STATE OF ALA~A A~ T~T T~3 PLAT R~RE~ENT3 A LOCATION ~?~_..~ '**:~ ~R~Y MADE BY ~ OR U~ BY 6UPERVISlON, A~ THAT ~ :~L~=:p~E~N$ A~.~T~ ~ET~s, ARE CORRECT. , ~.~~...~*~?~ ¢ ~,~ ~ ' LOCATIONS R ~:~' ~-~~"~~ FIELD BOOK SCALE ~':200' JOB NO. 89009 i ;.,),-,a .uJl .& Gas Cons, Conlrrds~.L. March 21, 1989 Telecopy: (907)276-7542 T. R. Painter Division Manager Conoco Inc. 3201 C Street, Suite 200 Anchorage, Alaska 99503 Mitne Point Unit No. G-2 ConOco InC. Permit No. 89-28 Sur. Loc. 3420'FEL, 4000'FNL, Sec. 27, T13N, R10E, UM. Btmhoie Loc. 660'FEL, 4621'FNL, Sec. 27, T13N, R10E, U~-~. Dear Mr. Painter Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled° Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation ~o that the Comm-ission may witness testing before dritlimg below the ~hoe of the conductor pipe. Very t~_uly you=s, /'~ i -,i -/ :: ,'-: / i-' Chaiman of Alaska Oii and Gas Conservation Co~ission BY ORDER OF THE CO~,IISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 March 2, 1989 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE' Milne Point Unit; Permits to Drill; Wells G-1 and G-2 Dear Mr. Chatterton' Attached please find Permit to Drill Applications for the Milne Point Unit, Wells G-1 and G-2, Property ADL-25906. A check for $200 is i ncl uded. If you have questions please call Jim Fox or Steve Brady at (907) 659- 6322. ~ You~ ~ , ~:i ~' .Pa-~.nter Division Manager JDC/cl Attachment STATE OF ALASKA , ALASK'~'~IL AND GAS CONSERVATION ' ..... 'MMISSION PERMIT TO DRILL 20 AAC 25.OO5 Type of work Drill [] Redrill []i lb, Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenE31 Service [] Developement Gas [] 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, ste 200, Anchorage, AK 9950 Location of well at surface 3420' FEL, 4,000' FNL SEC 27, T13N,R10E,UM At top of productive interval 845' FEL, ~4579' FNL SEC 27, T!3N, R10E,UM At total depth ...;_~ __._ 660' FEL, 4621' FNL SEC 27, Ti3N, R10E,UM 12. Distance to nearest property line @ target 845 feet 13. Distance to nearest well 60 feet 16. To be completed for deviated wells Kickoff depth 600 feet Maximum hole angle 48 0 5. Datum Elevation (DF or KB) KB 28 feet Single Zone ~ Multiple Zone [] 10. Field and Pool 6. Property Designation ADL 25906 7. Unit or property Name Milne Point Unit 8. Well nurpber G-2 9. Approximate spud date August 1989 14. Number of acres in propert 256O Kuparuk River Field 11. ~pe Bond(s. 20 ~C25.025) Blanket Number 8086-].5-54 Amount $200,000 15. Proposed depth (MD and TVD) 5718MD*/.4685TVD* feet 17. Anticipated pressure (see 20 AAC 25.035 (eX2)) Maximum surface 2200 psig At total depth ti'VD) 2300 psig 18. Casing programl size Specifications Hole Casing Weight1 Grade i Coupling 30" 13-3/8" 48¢/ lu-4o I Weld 12¼" 9-5/8" 3~'# tE=551B?RS I I 8½ 7 26#'I I - " L-80 3T~S Length 80' 2880' 5690' Setting Depth Top Bottom MD I TVD I MD ! TVD 28',I I lO8' ! 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Quantity of cement (include stage data) --+485 SKS Permafrost C _~486 SKS Permafrost E +592 SKS Class G !+64 SKS Permafrost E i~379 SKS Class G +409 SKS Permafrost C +60 Bbls. Arctic Pak Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth True Vertical depth RECEIVED i'JlF~i-, tU :,, :? -- ' 'daska .Oil & Gas Cons, Commjssll Anchorage 20. Attachments Filing fee I~ Property plat [] BOP Sketch [3 Diverter Sketch [] Drilling program [] Drilling fluid program~~dep~h plot BI Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements ..~ 21. I here~at/~e fore, goi~~ct to the best of my knowledge Signed-~'d~ / ~' k'.//~"- .7/ ',..~ ~/-'~:~--~.J'"'~ ~-' Title Division Manager Date 3-2-89 / ' Commission Use Only Permit Number I APlnumber IApprovaldate !See cover letter ~'~. ~ ~ 50-- O.2_ ~ - ~ / '~ .9_. ~/~ 0 q, / ? 1 / g 9 for other requirements Conditions of approval Samples required '~o Yes/~No Mud Icg re~luir~a E] Yes ~No Hydrogen sulfide measures [] Yes /~ No Directional survey required '1~ Yes Eli No [] 10M; ~] 15M Required working pressure,f, or BOP__E E]2M; i~ 3M; . [] 5M; Other: /~.,~/ //~/ / ,- by order of Approved by ~.~'_ _./,', ~~Z,,¢~ :-. Commissioner the commission Form 10-401 Rev. 12-1-85 Date Subrffft in ,~plic~.te SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT G-2 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503 I · Casing and Cementing Program a. The 13-3/8" conductor will be set at 80' below the surface, then cemented to the surface with ±485 sacks of Permafrost Type "C". Be The 9-5/8" surface casing will be cemented with ±486 sacks of Permafrost "E" cement followed by ±592 sacks of Class "G" cement. A top job will be done if cement is~ not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The first stage will consist of ± 64 sacks of Permafrost "E" cement pumped around the casing shoe followed by ±379 sacks of Class "G" cement. The secondary cement job will consist of ±409 sacks of Permafrost "C" cement followed by ± 60 barrels of Arctic Pack pumped down the 7" x 9- 5/8"annulus. II. Drilling Fluid Program a. Be 0-3685' 9.0 ppg freshwater spud mud. 3685'-3905' 9.2 ppg low solids non-dispersed. RECEIVED C· 3905' - TD 9.4 low solids non-dispersed. III. Drilling Program ,daska 0/1 .& Gas Cons., O~,ommis$1oi~- ' ' : ~lrmhorage Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River field (Upper Cretaceous). The mud system will be low solids, non-dispersed with a mud weight in surface hole of 9.0 ppg. Mud weight at TD will be 9.4 ppg. A 20", 2000 psi diverter will be installed on the 13-3/8" conductor for drilling surface hole. A 13-3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing· Pressure test will be performed as per State Regulations. BOP's, choke manifold, upper and lower kelly will be tested to 500 psig and 5,000 ps±g, the Hydril to 350 psig and 3500 psig. Casing will be pressure tested to 1,500 psig. Maximum downhole pressure is based on initial reservoir pressure· Maximum surface pressure is based on an unexpanded gas bub~!>~.~ taken into account. The closest wellbore is G-1 with a closure of 60 feet at the surface. The well will not be completed or tested at this time. A, Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. Bo Drill a 12-1/4" surface hole to +2500' TVD (2908' MD) and set 9-5/8" casing. C, Drill a 8-1/2" production hole to 5718' MD and set 7" casing. TVD 0! 2500' 3685' 3905' 4165' 4335' 4685' MD FORMATION BIT MUD WT YP PV VIS FL 0' Gravel 1-1-4 9.0 32 20 90 15 2908' Sand/Clay 1-1-4 9.0 25 20 65 15 4602' "K" Sand 1-1-4 9.2 25 15 35 10 4870' "M" Sand 1-1-4 9.4 25 15 35 10 5163' "N" Sand 1-1-4 9.4 25 12 35 5 5344' "O" Sand 1-1-4 9.4 25 12 35 5 5718' TD 1-1-4 9.4 25 12 35 5 *The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300 feet TVD, a Sundry Notice will be submitted. CONOCO. Ine, Ps(! G, Wel I No, HI Ine Poln{ Unl{, 2 r'roposed Nor{h SI ope, 0 _ RKB ELEV^TION' 1 000 _ 2000. 3000 _ .. 4ooo_ 5000, KOP TVD=600 TMD=600 DEP=O I$ BUILD ,3 DEe PER ! O0 Fl' 27' : ,33 EOB TYD=2002 TMD=2174 DEP=613 9 5/8" CSG PT TYD=2500 TMD=2908 DEP=115! MAXI HUM ANGLE 47 DEQ 14 MI N DROP 3 DEe 27' PER 100 FT- TARGET ANGLE 2O DEG I I 1000 2000 BEGIN ANGLE DROP TVD=3416 THD=4257 DEP=2142 K SNDS TVD=3685 THD=4618 DEP=2382 H SNDS TVD=3905 TMD=4879 DER=2522 TARGET / N SNDS TVD=4165 TFID=5164 DER=2639 0 SNDS TVD=4335 THD=5345 DER=2701 TD / 7" CSG PT TVD=4685 TMD=5718 DEP=2829 PERHI TTED DEPTH TVD=4985 TMD=6037 DEP=2938 3000 YERTICAL SECTION HORIZONTAL SCALE ~ IN. PROJECTION -- 1000 FEET CONOCO, ][nc. P~d G. Well No' Hl lne Poln~ Unl~, 2 Proposed North Slope, AleeEa SURFACE LOCATION, 4.000' FNL. 3420' FEL SEC, 27. T13N, RIOE z PERHITTED DEPTH LOCATION' 4644' FNL, 554' FEL SEC. 27, T13N, RIOE 1000 1000 2OOO 1000 SURFACE TD LOCATION, 4.621' FNL. 660' FEL SEC. 27, TI~N, RIOE WEST-EAST 0 1000 2000 i I I :$000 TARGET / N SNDS TVD=4165 THD=$164 DEP=2639 SOUTH 579 EAST 2575 TARGET LOCATION, 4579' FNL. 845' FEL SEC. 27. T13N. RIOE S 77 DEG 20 MI N E 2639' (TO TARGET) 3600 :3550 :3500 .3450 3400 :3350 -:3300 :3250 :3200 E I I I I I I I I :3900 _ :3950 _ 4000 _ 4050 _ 4100 _ 4150 _ 4200 _ / 3600 I 3550 I 3500 I 3450 ., ~600 ~' 800 ~ 900 1000 ~' 1100 ~.1200 ~ 1300 1400 '~ 15oo I I 3400 3350 . I i _ I I I _ I ! ! - I I _ I I I ;3300 :3250 3200 _ .3900 :3950 4000 4050 4100 4150 4200 DEVELOPMENT WELL WELL NAME: WELL G-2 06-Feb-89 CONDUCTOR SETTING DEPTH: SURFACE CASING SETTING DEPTH: INTERMEDIATE CASING SETTING DEPTH: PRODUCTION CASING SETTING DEPTH: 80 2,908 0 5,718 DEPTH 0 0 (2,908) (2,908) (2,908) (2,908) (2,908) (2,908) (3,008) (5,718) (5,718) (5,718) (5,718) (5,718) (5,718) (5,718) (5,718) (5,718) OPERATION: A RIG MOVE: B RIG-UP; SET CONDUCTOR: C DRL/SURVEY SURFACE HOLE: D SURFACE HOLE LOGGING: E CONDITIONING TRIP: F RU/RUN SURFACE CASING: G RU/CEMENT SURFACE CASING: H CHNG BOPs; PU BHA; RIH: I DRL OUT; TEST; TOOH; RIH: J DRILL PRODUCTION HOLE: K CORING OPERATIONS: L LOGGING OPERATIONS: M CONDITIONING TRIP: N RU/RUN PRODUCTION CASING: 0 RU/CEMENT PRODUCTION CASING: P ND BOPs; NU TREE: Q ADDITIONAL RIG-TIME: R RIG-DOWN; MOVE RIG: CUM HOUR DAYS DAYS 0 0.00 0.00 12 0.50 0.50 51 2.14 2.64 0 0.00 2.64 3 0.12 2.76 10 0.40 3.16 6 0.25 3.41 9 0.37 3.78 9 0.39 4.17 62 2.60 6.77 0 0.00 6.77 18 0.75 7.52 10 0.40 7.93 15 0.63 8.56 6 0.24 8.79 12 0.50 9.29 0 0.00 9.29 0 0.00 9.29 TRACT 14 DEVEI[~OP~/fE~qT WELL G., .2 1000 iA O~ B DEPTH -1000 -2000 -5000 EFFGH -4O0O -5OOO -6000 0 2 4 6 8 10 DRLLNG RG DAYS T 15, NR 9E AJ:X.-2~5 OG 2~ '~x.~ '! '" ';e / IU3L-2~StE; 25~4 ,~C 31 2~3~ AC -- i i :22 AD L-2.~5 16 ..... AOL-¢;'437 2561:) AC "~,~1 CJ"JEYRON &OL-2.~5 lB 2 .~-0 AC , , . .... 31 ADL-28231 _ 32 2 $S5 AC I MILNE POINT UNIT ToLoI &r,a in U~IL ~5.744 Acr~m ~ Unit 8Ou~mry ~L ~ ~ COHOCO ET AL. AOL-47429 I 2~0 AC ..... 15 22 AIDL-31584 ~ EXHlgLT A MILNE POINT UNIT AREA ~ VEN1 PI1 G PAD MILNE PT. VICINITY MAP O $ · MILE8 LOCATION IN SEC. 27, '1'13N, R1OE, UMIAT MERIDIAN WELL FROM NORTH LINE FROM EAST LINE G-! 4,060' 4,000' 3,420' 3,420' STATE PLANE COORDINATE$-2ONE 4 WELL NORTH G-1 6,013,655.300 557,190.418 GEODETIC POSITIONS NAD 1927 WELL NORTH LATITUDE W~ST LONGITUDE G-1 ?0' 26'52.5958' 149° 32'00.439" Note: Certified Map to Follow. F. Robert~ I m~u~ ~ ~1 ~ PROP SE WELL ~~~g, , ;,~~,, G-1 LOCATION F~D B OK ~~.~ ~ [ I SCALE I,%20~ ~B NO. 87033 ~~~ LCvEL CONOCO, INC. MILNE POINT UNIT BOP STACK FOR 9-5/8" SURFACE CASING FILL-UP LINE ( FLOW LINE &NNULAR PREVENTER Threaded Connection ~';.' '.'. '. · · - & .' ·, · · ' · ' · ISle ' APl SO004 RAM BOP R&M BO P [ . _ RAM BOP ~eAPl $000~ - 3' A~ ~000 Sl~[ OUTLfTS ~ ~ ~ 4 · ~ · , APl 5000 it APt 5000~ APl 5000 SIDE OUTLETS APl 5000 ~I 155/I' APl $OOOi · '11' APl 5000 (l) B.O.P. stack size rating meets AP1 RP 53 & spec 6A for class 5M with clamo & hub connectors all hydraulically operated. (2) BOPE to be operated on each trip & pressure tested weekly. (3) Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation· (4) Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams· (5) Choke and kill manifolds shown separately to meet AP! RP 53 class 5M requirements. CONOCO, INC, MILNE POINT UNIT DIVERTER STACK FOR 13 3/8' -CONDUCTOR ,. FILL UP LINE FLOW LINE ~O" BELL NIPPLE ~Oe Jd) l I:000 pli AI~NUL&R PREVENTER 0" RELIEF VALVE DIVERTER OUICK CONNECT ASSEMBLY SAVER *SUB ASSEMBLY START INO H£&O 1. The hydpaulic contpol system will be in accordance with APl speci~=ications and AOGCC ~equire~ents. ~. The HCR valve will open ~hen the preventer closes. A single 10" pelief line will Fun off of the dpillin§ spool HCR valve a~d will have a targeted downstream tee for downwind divepsion. Yalves on both sides of the tee will be full opening and linked together to enable one to always be open and the other to be closed. ~At_t_ VAL.V~ L BLA N K P~PE HOUS~ PiT $cxjK) PSi MANU,,~L CHOKE 5O00 5~ ~o, ooo HYD C 140KE CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 2. 3. 4. 5. 6. 7. (3) Admin ,, Xh/~f'~ 9. ~-('9 ~hru 13)' I 10. (10 and' 13) 12. 13. (4) Casg w~.~<v.,,., ,Y-?-B~ (14 thru 22) (5) BOPE (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company the permit fee attached .......................................... Lease & Well No. /~~t~_ /~. ~//t~/? YES NO REMARKS Is well to be located in a defined pool ............................. Is well located proper distance from property line .................. _~ Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ . Is well to be deviated and is wellbore plat included ................ ~ Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground, source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate /~w Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. ' (29 thru~ 3~1) ~ (6) Add: ~, ~,.~f, Geology.: En~in~eering: DWJ~ Lcs -~?~'BEW rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented__ Additional requirements ............................................. Additional Remarks: INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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. **** LIS READ **** (NOTE: MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SPERRY DATE: 89/09/12 ORIGIN OF DATA: MWD REEL NAME: CONOCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 89/09/12 ORIGIN OF DATA: G-2 TAPE NAME: MILNE PT CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE ********** RECEIVED AI~I~ Oil & Gas Cons. Anchom~]e ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: G-2 FE/LOG SERVICE NAME: RLL VERSION #: REV 2.3D DATE: 89/09/12 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 GRC AAPI 0 0 0 0 1 4 0 1 68 ROP FT/H 0 0 0 0 1 4 0 1 68 FXE HRS 0 0 0 0 1 4 0 1 68 NFO CTS 0 0 0 0 1 4 0 1 68 NFl CTS 0 0 0 0 1 4 0 1 68 NN0 CTS 0 0 0 0 1 4 0 1 68 NN1 CTS 0 0 0 0 1 4 0 1 68 EWR OPIMI~ 0 0 0 0 1 4 0 1 68 RHOB G/C3 0 0 0 0 1 4 0 1 68 NPS P.U. 0 0 0 0 1 4 0 1 68 TVD FT 0 0 0 0 1 4 0 1 68 NDIS FT 0 0 0 0 1 4 0 1 68 EDIS FT 0 0 0 0 1 4 0 1 68 DEVI DEG 0 0 0 0 1 4 0 1 68 CAL IN 0 0 0 0 1 4 0 1 68 DRHO G/C3 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 GRC AAPI 0 0 0 0 1 4 0 1 68 ROP FT/H 0 0 0 0 1 4 0 1 68 FXE HRS 0 0 0 0 1 4 0 1 68 NFO CTS 0 0 0 0 1 4 0 1 68 NFl CTS 0 0 0 0 1 4 0 1 68 NN0 CTS 0 0 0 0 1 4 0 1 68 NN1 CTS 0 0 0 0 1 4 0 1 68 EWR OHMM 0 0 0 0 1 4 0 1 68 RHOB G/C3 0 0 0 0 1 4 0 1 68 NPS P.U. 0 0 0 0 1 4 0 1 68 TVD FT 0 0 0 0 1 4 0 1 68 NDIS FT 0 0 0 0 1 4 0 1 68 EDIS FT 0 0 0 0 1 4 0 1 68 DEVI DEG 0 0 0 0 1 4 0 1 68 CAL IN 0 0 0 0 1 4 0 1 68 DRHO G/C3 0 0 0 0 1 4 0 1 68 ** 451 DATA RECORDS ** FROM 2650.00 TO ** FILE TRAILER** FILE NAME: G-2 FE/LOG SERVICE NAME: RLL VERSION #: REV 2.3D DATE: 89/09/12 MAX. RECORD LENGTH: 1024 FILE TYPE: EO NEXT FILE NAME: ** TAPE TRAILER** SERVICE NAME: RLL DATE: 89/09/12 ORIGIN OF DATA: G-2 TAPE NAME: MILNE PT CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT 5800.00 FT ** REEL TRAILER ** SERVICE NAME: SPERRY DATE: 89/09/12 ORIGIN OF DATA: MWD REEL NAME: CONOCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT