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Home My WebLink About190-005From:Alaska NS - ASR - Well Site Managers To:Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: MPU E-04 BOPE Test 5/18/2022 Date:Saturday, May 28, 2022 6:23:39 PM Mr. Regg, It was the connection on between the targeted T on the choke side of the mud cross and the choke line hose. Regards, ASR DSM’s ASR-1 Rig: 907-685-1266 Hilcorp Alaska, LLC From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Friday, May 27, 2022 9:46 AM To: Alaska NS - ASR - Well Site Managers <AlaskaNS-ASRWellSiteManagers@hilcorp.com> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: RE: [EXTERNAL] RE: MPU E-04 BOPE Test 5/18/2022 Location of the grayloc connection? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Alaska NS - ASR - Well Site Managers <AlaskaNS-ASRWellSiteManagers@hilcorp.com> Sent: Friday, May 27, 2022 4:19 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: RE: [EXTERNAL] RE: MPU E-04 BOPE Test 5/18/2022 Mr Regg The failure on the VBR’s was the leaking gray-lock connection, test #2 on the chart, we miss marked the F/P as it was a different component that failed on that test and not the VBR’s themselves. 038( 37' 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. Attached is a corrected test report with the corresponding Information Apologies for the mistake. Regards, ASR DSM’s ASR-1 Rig: 907-685-1266 Hilcorp Alaska, LLC From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Wednesday, May 25, 2022 12:57 PM To: Alaska NS - ASR - Well Site Managers <AlaskaNS-ASRWellSiteManagers@hilcorp.com> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: [EXTERNAL] RE: MPU E-04 BOPE Test 5/18/2022 Appears you have at least 1 failure – FP for VBR. What about the Greylock connection (test 2) reference in remarks? PTD # is missing training zero. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Alaska NS - ASR - Well Site Managers <AlaskaNS-ASRWellSiteManagers@hilcorp.com> Sent: Thursday, May 19, 2022 5:17 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: MPU E-04 BOPE Test 5/18/2022 Hello, Please see attached BOPE test form. Thank you, ASR DSM O: (907) 685-1266 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:ASR 1 DATE: 5/18/22 Rig Rep.: Rig Phone: 685-1266 Operator: Op. Phone:685-1266 Rep.: E-Mail Well Name: PTD #11900050 Sundry #321-544 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:2500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2 1/16"P Inside Reel valves 0NA HCR Valves 1 2 1/16"P Kill Line Valves 2 2 1/16"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 1 choke line FP Time/Pressure Test Result System Pressure (psi)3100 P CHOKE MANIFOLD:Pressure After Closure (psi)1850 P Quantity Test Result 200 psi Attained (sec)16 P No. Valves 16 P Full Pressure Attained (sec)58 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4x2300 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:1 Test Time:7.0 Hours Repair or replacement of equipment will be made within 0 days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 05/17/2022 06:30 Waived By Test Start Date/Time:5/18/2022 16:30 (date) (time)Witness Test Finish Date/Time:5/18/2022 23:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Matt Herrera Hilcorp Annular closure time = 28 sec. Tested with 2 7/8" and 3 1/2" test jts. Tighten grey-lock connection on test #2 (connection on between the targeted T on the choke side of the mud cross and the choke line hose) C. Pace, J. Haberthur Hilcorp Alaska M. Strom / S. Menapace MPU E-04 Test Pressure (psi): skaNS-ASR-Well Site Managers@hilcorp.c Form 10-424 (Revised 02/2022) 2022-0518_BOP_Hilcorp_ASR1_MPU_E-04 9 9 9 99 9 9 9999 9 9 9 9 9 -5HJJ FP Annular closure time = 28 sec. Hilcorp ASR BOPE Test Chart – 5/18/2022 Page 1 of 2 BOPE Test Charts – Hilcorp ASR 1 5/18/2022 MPU E-04 (PTD 1900050) Hilcorp ASR BOPE Test Chart – 5/18/2022 Page 2 of 2 &KRNHOLQH*UH\ORF FRQQHFWLRQ -5HJJ -5HJJ Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 05/17/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU E-04 (PTD 190-005) MFC 03/21/2022 Please include current contact information if different from above. PTD:190-005 T36622 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.18 10:12:58 -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:Ted Kramer Subject:20220105 1447 APPROVAL Sundry 321-544 REVISION 1- MPU E-04 ESP CO PTD 190-005 Date:Wednesday, January 5, 2022 2:50:42 PM Attachments:MPU E-04 ESP CO Procedure W pkr and screens 1-5-2022.docx MP E-04 PROPOSED TEK 12-14-2021.pdf MP E-04 AOGCC 10-403 APPROVAL 10-15-2021.pdf Ted, Hilcorp is approved for to make changes to approved sundry 321-544 as per Revision 1 attached. No additional information is required for this change. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 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 Records From: Ted Kramer <tkramer@hilcorp.com> Sent: Wednesday, January 5, 2022 11:33 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Tom Fouts <tfouts@hilcorp.com> Subject: MPU E-04 ESP CO , Sundry # 321-544, PTD 190-005 Mel, Hilcorp would like to make a change to the attached Sundry for MPU E-4. The attached procedure contains the revisions (in red, steps numbers 17 and 18) which consist of making a scraper run, then running and setting a packer with screens below it. The ESP will then be ran as planned. An updated proposed Schematic is also attached. The reason for this change is that the well makes some solids and it is felt that the screens will help keep the solids from reaching the facility and will also improve the run time of the esp. Please let me know if this e-mail will be enough to make this change or if I need to re-submit the sundry. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp-Alaska LLC Office – 907-777-8420 Cell – 985-867-0665 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 hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. _____________________________________________________________________________________ Revised By: DH 12/14/2021 PROPOSED Milne Point Unit Well: MPE-04 Last Completed: 12/3/2019 PTD: 190-005 TD =9,900’(MD) / TD = 7,616’(TVD) Orig. KB Elev.: 58.00’/ GL Elev.: 34.0’ RKB-THF: 23.75’ (Doyon 16) 7” 3 & 4 7 8 9 9 9-5/8” 1 9-5/8” Hall Multi Stage Cementer @ 1,955’ KUP C Sands PBTD =9,789’ (MD) / PBTD = 7,533’(TVD) KUP B Sands 10 2 18 11 13-3/8” 14 MIN ID= 2.313 @ 8,930’ 12 13 Arctic Pack MIN ID= 2.313 @ 8,992’ Est. TOC @ 7,500’ 5 & 6 15 16 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / N/A N/A Surface 114'0.1571 9-5/8"Surface 36 / J-55 / BTC 8.921 Surface 5,741’0.0773 7"Production 26 / L-80 / BTC 6.276 Surface 9,880’0.0383 TUBING DETAIL 2-7/8"Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 8,761’ 0.00579 JEWELRY DETAIL No Depth Item 1 162’STA #2: GLM Camco 2 7/8 X 1'' S/P,W/DOSV BK Latch 2 8,512’STA #1: GLM Camco 2 7/8 X 1'' S/P GLM, W/ Dummy - BK Latch 3 8,680’ Discharge Head: GPDIS 4 8680.5’ Ported Discharge Head: 5 8,681’ Pump: 538PMSXD / 93 Flex 47 6 8,697’ Pump: 538PMSXD / 66 FLEX 47 7 8719’ Gas separator : 538GSHVV 8 8722’ ESP Assembly 9 8,759’ Zenith Sensor & Centralizer - Bottom @ 8,761 10 8,811’ 7” DLH Hydraulic Set Retrievable Packer 11 8,815’ 4-1/2” 250 micron Screens with bottom plug, bottom @ 8,895’ 12 8,905’ 2-7/8” Chemical Cut Tubing 13 8,930’ Baker SBR Seal w/ Otis 2.313” X Profile 14 8,945’ Otis 7” “HCM” PERMA-PACKER w/ Millout Extension (2.635” ID) 15 8,992’ Otis 2.313” X Profile 16 9,010’ Schlumberger Gun Release 17 9,657’ Fish: Top of Schlumberger Gun Assembly PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 9,048’9,090’6,990’7,021’42 5/12/1990 Open Kup. B Sands 9,116’9,150’7,041’7,066’34 5/12/1990 Open CEMENT DETAIL 13-3/8" Cmt w/ 500 sks of PF “C” in 30” Hole 9-5/8"Cmt w/ 406 bbl PF “E”, 70 bbl Class “G” in 12-1/4” Hole 7”Cmt w/ 125 bbl Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 45.7 deg. f/ 6,400’ Hole Angle through perforations = 41 deg. Max DLS = 6.36°/100’ @ 1,550’ TREE & WELLHEAD Tree 2-9/16”- 5M Cameron WKM Wellhead 11” x 11”” 5M Cameron WKM TDF, w/ 11” x 2-7/8” TDF- CS-1 Hanger 2-7/8” EU 8rd lift threads, 2.5” CIW H BPV GENERAL WELL INFO API: 50-029-21997-00-00 Drilled and Cased by Nabors 27E – 1/26/1990 Completed with Gaslift by EWS #4 – 5/14/1990 Convert to ESP by Nabors 4ES – 1/10/1995 ESP Repair by Nabors 4ES – 5/12/1997 & 10/17/1997 ESP Repair by Nabors 5S – 10/17/1997 ESP Repair by Nabors 4ES – 1/18/2000, 12/11/2001, 9/12/2005 & 2/22/2008 ESP Repair by Doyon 16 – 7/14/2012 ESP Repair by Doyon 16 – 5/17/2014 ESP Swap ASR#1 – 5/3/2017 & 12/3/2019 ESP Change-Out Well: MPU E-04 Date: 10-15-2021 Well Name: MPU E-04 API Number: 50-029-21997-00 Current Status: Shut-in ESP Producer Pad: E-Pad Estimated Start Date: October 28, 2021 Rig: ASR Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 218-104 First Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) AFE Number: Job Type: ESP Swap Current Bottom Hole Pressure: 1,257 psi @ 7,066’ TVD From FL shot on 10/11/21( 3.4 PPG) Maximum Expected BHP: 1,257 psi @ 7066’ TVD Offset injector is SI MPSP: 2,500 psi While pumping Max Inclination 45° @ 2,400’ MD Max Dogleg: 7.2°/100ft @ 1,500’ MD BPV Profile: 2-1/2” CIW Type H Brief Well Summary: MPU E-04 was drilled in 1990 using Nabors 27E and completed in the Kuparuk sands with a gaslift completion. The well was converted to ESP in 1995 using Nabors 4ES. The well has had 11 ESP changeouts since 1995. This well has had tendency for scaling. A MTT (Magnetic Thickness Tool) was run in July 2012 during a RWO, and no shallow subsidence issues were seen. During the 2019 ESP change out, the casing was pressure tested to 2,500 psi. The ESP average run time for the last 4 ESP installs is 2.2 years. The ESP was running until a field wide power shutdown caused the ESP to shut down. The unit failed on the restart and showed to be grounded down hole. Notes Regarding Wellbore Condition • Casing last tested to 2,000 psi for 30 min down to 8,740’ on 12/3/2019. • Permanent Packer is still in the well @ 8,945’ from the gas lift completion. • Scraper ran to 8,833’ on 12/1/2019. Objective: • Pull and replace ESP. Pre-Rig Procedure: 1. MIRU Slickline unit. a. Pull orifice valve from STA #2 @ 174’ and set DV. b. Pull DV from STA #1 @ 8,525’ MD. Leave pocket open. c. RD Slickline Unit. 2. Clear and level pad area in front of well. Spot rig mats and containment. 3. RD well house and flowlines. Clear and level area around well. 4. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH. a. Due to the low reservoir pressure, a tubing freeze protect should not be needed. b. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. ESP Change-Out Well: MPU E-04 Date: 10-15-2021 5. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 6. NU BOPE house. Spot mud boat. Brief RWO Procedure: 7. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. 8. 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/ 8.3 ppg source-water prior to pulling BPV. 9. Set TWC. ND WH, NU BOP. 10. 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 2-7/8” and 3-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 11. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 12. Bleed any pressure off casing to returns tank. Pull TWC. Kill well w/ 8.3 ppg source-water as needed. 13. Rig up spoolers for ESP #2 RD cable and 3/8” capillary string. a. Baker Hughes representative should be onsite for ESP pull. 14. MU landing joint or spear and PU on the tubing hanger. a. 2019 ASR #1 ESP completion pick up weights were PUW = 69k lbs and the SOW = 36k lbs. b. If needed, circulate (long or reverse) pill with lubricant, source-water, and/or baraclean pill prior to laying down the tubing hanger. 15. 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. a. Evaluate pulled tubing hanger for possible thread damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. ESP Change-Out Well: MPU E-04 Date: 10-15-2021 16. POOH racking back 2-7/8” tubing. Lay down ESP and motor. a. Note any sand, scale, or corrosion on the tubulars and ESP on the morning report. i. Look for over-torqued connections from previous tubing runs. ii. If any joints appear suspect of damage to threads or tubing, send to G&I for disposal and replace with new. b. The old completion has the following amount of clamps/guards/cap-string: i. 150 Cross Collar Cannon Clamps ii. 0 Flat Guards iii. 5 Protectolizers iv. ±8,675’ of 3/8” capillary tubing 17. PU RIH With casing scraper on WS to 8,890’. CBU. POOH W/ Casing Scraper. 18. PU RIH W/ Screens and Hydraulic set packer to 8,810’. Set packer and release off. POOH Laying down WS. 19. PU new ESP and RIH on 2-7/8” 6.5# L-80 tubing. Set base of ESP assembly at ±8,750’ MD. a. Upper 2-7/8”x 1” Side-pocket GLM @ ±200’ MD with orifice valve installed. b. 2-7/8” tubing. c. Lower 2-7/8”x 1” Side-pocket GLM with Dummy GLV. d. 2 full joints of 2-7/8” tubing. e. 2-7/8” XN (2.205” No-Go) Nipple. f. 1 joint of 2-7/8” tubing. g. ESP. 20. Land tubing hanger. RILDS. Lay down landing joint. Note Pick-up and slack-off weights on tally. 21. Set BPV. Post-Rig Procedure: 22. RD mud boat. RD BOPE house. Move to next well location. 23. RU crane. ND BOPE. 24. NU existing 2-9/16” 5,000# tree. Test tubing hanger void to 500 psi low/5,000 psi high. 25. Pull BPV. 26. RD crane. Move returns tank and rig mats to next well location. 27. Replace gauge(s) if removed. 28. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic 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? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,900'N/A Casing Collapse Conductor N/A Surface 2,020psi Production 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.W ell Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 7,616'9,789'7,533'2,500 N/A 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: AOGCC USE ONLY Ted Kramer tkramer@hilcorp.com 907-777-8420 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: Otis HCM PERMA-PKR and N/A 8,945'(MD) & 6,913'(TVD) and N/A See Schematic See Schematic 10/28/2021 2-7/8" PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL028231 190-005 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21997-00-00 Hilcorp Alaska LLC MILNE PT UNIT E-04 MILNE POINT / KUPARUK RIVER OIL C.O. 432D 115' 6.5# / L-80 / EUE TVD Burst 8,761' N/A 3,520psi 7,240psi 4,579' 7,633' 5,741' 9,880' Length Size 115' MD 9,880' Perforation Depth MD (ft): 114'13-3/8" 9-5/8" 7" 5,741' P t t s 1 6 5 6 Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. Operations By Meredith Guhl at 9:48 am, Oct 15, 2021 321-544 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2021.10.15 09:30:30 -08'00' David Haakinson (3533) X ADL0025518 DLB DSR-10/15/21 DLB 10/15/2021 BOPE test to 2500 psi. 2,500 10-404 MGR15OCT21dts 10/15/2021 10/15/2021 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.10.15 14:56:52 -08'00' RBDMS HEW 10/19/2021 ESP Change-Out Well: MPU E-04 Date: 10-15-2021 Well Name: MPU E-04 API Number: 50-029-21997-00 Current Status: Shut-in ESP Producer Pad: E-Pad Estimated Start Date: October 28, 2021 Rig: ASR Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 218-104 First Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) AFE Number: Job Type: ESP Swap Current Bottom Hole Pressure: 1,257 psi @ 7,066’ TVD From FL shot on 10/11/21( 3.4 PPG) Maximum Expected BHP: 1,257 psi @ 7066’ TVD Offset injector is SI MPSP: 2,500 psi While pumping Max Inclination 45° @ 2,400’ MD Max Dogleg: 7.2°/100ft @ 1,500’ MD BPV Profile: 2-1/2” CIW Type H Brief Well Summary: MPU E-04 was drilled in 1990 using Nabors 27E and completed in the Kuparuk sands with a gaslift completion. The well was converted to ESP in 1995 using Nabors 4ES. The well has had 11 ESP changeouts since 1995. This well has had tendency for scaling. A MTT (Magnetic Thickness Tool) was run in July 2012 during a RWO, and no shallow subsidence issues were seen. During the 2019 ESP change out, the casing was pressure tested to 2,500 psi. The ESP average run time for the last 4 ESP installs is 2.2 years. The ESP was running until a field wide power shutdown caused the ESP to shut down. The unit failed on the restart and showed to be grounded down hole. Notes Regarding Wellbore Condition x Casing last tested to 2,000 psi for 30 min down to 8,740’ on 12/3/2019. x Permanent Packer is still in the well @ 8,945’ from the gas lift completion. x Scraper ran to 8,833’ on 12/1/2019. Objective: x Pull and replace ESP. Pre-Rig Procedure: 1. MIRU Slickline unit. a. Pull orifice valve from STA #2 @ 174’ and set DV. b. Pull DV from STA #1 @ 8,525’ MD. Leave pocket open. c. RD Slickline Unit. 2. Clear and level pad area in front of well. Spot rig mats and containment. 3. RD well house and flowlines. Clear and level area around well. 4. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH. a. Due to the low reservoir pressure, a tubing freeze protect should not be needed. b. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. -00 DLB ESP Change-Out Well: MPU E-04 Date: 10-15-2021 5. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 6. NU BOPE house. Spot mud boat. Brief RWO Procedure: 7. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. 8. 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/ 8.3 ppg source-water prior to pulling BPV. 9. Set TWC. ND WH, NU BOP. 10. 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 2-7/8” and 3-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 11. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 12. Bleed any pressure off casing to returns tank. Pull TWC. Kill well w/ 8.3 ppg source-water as needed. 13. Rig up spoolers for ESP #2 RD cable and 3/8” capillary string. a. Baker Hughes representative should be onsite for ESP pull. 14. MU landing joint or spear and PU on the tubing hanger. a. 2019 ASR #1 ESP completion pick up weights were PUW = 69k lbs and the SOW = 36k lbs. b. If needed, circulate (long or reverse) pill with lubricant, source-water, and/or baraclean pill prior to laying down the tubing hanger. 15. 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. a. Evaluate pulled tubing hanger for possible thread damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. ESP Change-Out Well: MPU E-04 Date: 10-15-2021 16. POOH racking back 2-7/8” tubing. Lay down ESP and motor. a. Note any sand, scale, or corrosion on the tubulars and ESP on the morning report. i. Look for over-torqued connections from previous tubing runs. ii. If any joints appear suspect of damage to threads or tubing, send to G&I for disposal and replace with new. b. The old completion has the following amount of clamps/guards/cap-string: i. 150 Cross Collar Cannon Clamps ii. 0 Flat Guards iii. 5 Protectolizers iv. ±8,675’ of 3/8” capillary tubing 17. PU new ESP and RIH on 2-7/8” 6.5# L-80 tubing. Set base of ESP assembly at ±8,750’ MD. a. Upper 2-7/8”x 1” Side-pocket GLM @ ±200’ MD with orifice valve installed. b. 2-7/8” tubing. c. Lower 2-7/8”x 1” Side-pocket GLM with Dummy GLV. d. 2 full joints of 2-7/8” tubing. e. 2-7/8” XN (2.205” No-Go) Nipple. f. 1 joint of 2-7/8” tubing. g. ESP. 18. Land tubing hanger. RILDS. Lay down landing joint. Note Pick-up and slack-off weights on tally. 19. Set BPV. Post-Rig Procedure: 20. RD mud boat. RD BOPE house. Move to next well location. 21. RU crane. ND BOPE. 22. NU existing 2-9/16” 5,000# tree. Test tubing hanger void to 500 psi low/5,000 psi high. 23. Pull BPV. 24. RD crane. Move returns tank and rig mats to next well location. 25. Replace gauge(s) if removed. 26. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic _____________________________________________________________________________________ Revised By: TDF 1/7/2020 SCHEMATIC Milne Point Unit Well: MPE-04 Last Completed: 12/3/2019 PTD: 190-005 TD =9,900’(MD) / TD = 7,616’(TVD) Orig. KB Elev.: 58.00’/ GL Elev.: 34.0’ RKB-THF: 23.75’ (Doyon 16) 7” 3 6 & 7 8 9 & 10 9 9-5/8” 1 9-5/8” Hall Multi Stage Cementer @ MIN ID= 2.205 @ 8,629’ KUP C Sands PBTD =9,789’ (MD) / PBTD = 7,533’(TVD) KUP B Sands 11 2 18 12 13-3/8” 15 MIN ID= 2.313 @ 8,930’ 13 14 Arctic Pack MIN ID= 2.313 @ 8,992’ Est. TOC @ 7,500’ 4 & 5 16 17 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / N/A N/A Surface 114' 0.1571 9-5/8" Surface 36 / J-55 / BTC 8.765 Surface 5,741’ 0.0773 7" Production 26 / L-80 / BTC 6.151 Surface 9,880’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.347 Surface 8,761’ 0.00579 JEWELRY DETAIL No Depth Item 1162’STA #2: GLM Camco 2 7/8 X 1'' S/P,W/DOSV BK Latch 28,512’STA #1: GLM Camco 2 7/8 X 1'' S/P GLM, W/ Dummy - BK Latch 3 8629’ 2-7/8” XN-Nipple: (2.205 No-go ID) 4 8,680’ Discharge Head: GPDIS 5 8680.5’ Ported Discharge Head: 6 8681’ Pump: 538PMSXD / 93 Flex 47 7 8,697’ Pump: 538PMSXD / 66 FLEX 47 8 8719’ Gas separator : 538GSHVV 9 8722’ Upper Seal Section: GSB3DBUTH6SB/ABPFSA 10 8,729’ Lower Seal Section: GSB3DBLTH6SB/ABPFSA 11 8,736’ Motor: 562XP – 300Hp/ 2,090V / 88A 12 8,759’ Zenith Sensor & Centralizer - Bottom @’ 8,761 13 8,905’ 2-7/8” Chemical Cut Tubing 14 8,930’ Baker SBR Seal w/ Otis 2.313” X Profile 15 8,945’ Otis 7” “HCM” PERMA-PACKER w/ Millout Extension (2.635” ID) 16 8,992’ Otis 2.313” X Profile 17 9,010’ Schlumberger Gun Release 18 9,657’ Fish: Top of Schlumberger Gun Assembly PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 9,048’ 9,090’ 6,990’ 7,021’ 42 5/12/1990 Open Kup. B Sands 9,116’ 9,150’ 7,041’ 7,066’ 34 5/12/1990 Open CEMENT DETAIL 13-3/8" Cmt w/ 500 sks of PF “C” in 30” Hole 9-5/8" Cmt w/ 406 bbl PF “E”, 70 bbl Class “G” in 12-1/4” Hole 7” Cmt w/ 125 bbl Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 45.7 deg. f/ 6,400’ Hole Angle through perforations = 41 deg. Max DLS = 6.36°/100’ @ 1,550’ TREE & WELLHEAD Tree 2-9/16”- 5M Cameron WKM Wellhead 11” x 11”” 5M Cameron WKM TDF, w/ 11” x 2-7/8” TDF- CS-1 Hanger 2-7/8” EU 8rd lift threads, 2.5” CIW H BPV GENERAL WELL INFO API: 50-029-21997-00-00 Drilled and Cased by Nabors 27E – 1/26/1990 Completed with Gaslift by EWS #4 – 5/14/1990 Convert to ESP by Nabors 4ES – 1/10/1995 ESP Repair by Nabors 4ES – 5/12/1997 & 10/17/1997 ESP Repair by Nabors 5S – 10/17/1997 ESP Repair by Nabors 4ES – 1/18/2000, 12/11/2001, 9/12/2005 & 2/22/2008 ESP Repair by Doyon 16 – 7/14/2012 ESP Repair by Doyon 16 – 5/17/2014 ESP Swap ASR#1 – 5/3/2017 & 12/3/2019 _____________________________________________________________________________________ Revised By: TDF 10/12/2021 PROPOSED Milne Point Unit Well: MPE-04 Last Completed: 12/3/2019 PTD: 190-005 TD =9,900’(MD) / TD = 7,616’(TVD) Orig. KB Elev.: 58.00’/ GL Elev.: 34.0’ RKB-THF: 23.75’ (Doyon 16) 7” 3 6 & 7 8 9 & 10 9 9-5/8” 1 9-5/8” Hall Multi Stage Cementer @ MIN ID= 2.205 @ 8,629’ KUP C Sands PBTD =9,789’ (MD) / PBTD = 7,533’(TVD) KUP B Sands 11 2 18 12 13-3/8” 15 MIN ID= 2.313 @ 8,930’ 13 14 Arctic Pack MIN ID= 2.313 @ 8,992’ Est. TOC @ 7,500’ 4 & 5 16 17 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / N/A N/A Surface 114' 0.1571 9-5/8" Surface 36 / J-55 / BTC 8.765 Surface 5,741’ 0.0773 7" Production 26 / L-80 / BTC 6.151 Surface 9,880’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.347 Surface ±8,761’ 0.00579 JEWELRY DETAIL No Depth Item 1 ±162’STA #2: GLM Camco 2 7/8 X 1' 2 ±8,512’STA #1: GLM Camco 2 7/8 X 1'' 3 ±8629’ 2-7/8” XN-Nipple: (2.205 No-go ID) 4 ±8,680’ Discharge Head: 5 ±8680.5’ Ported Discharge Head: 6 ±8681’ Pump: 7 ±8,697’ Pump: 8 ±8719’ Gas separator : 9 ±8722’ Upper Seal Section: 10 ±8,729’ Lower Seal Section: 11 ±8,736’ Motor: 12 ±8,759’ Zenith Sensor & Centralizer - Bottom @’ ±8,761 13 8,905’ 2-7/8” Chemical Cut Tubing 14 8,930’ Baker SBR Seal w/ Otis 2.313” X Profile 15 8,945’ Otis 7” “HCM” PERMA-PACKER w/ Millout Extension (2.635” ID) 16 8,992’ Otis 2.313” X Profile 17 9,010’ Schlumberger Gun Release 18 9,657’ Fish: Top of Schlumberger Gun Assembly PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 9,048’ 9,090’ 6,990’ 7,021’ 42 5/12/1990 Open Kup. B Sands 9,116’ 9,150’ 7,041’ 7,066’ 34 5/12/1990 Open CEMENT DETAIL 13-3/8" Cmt w/ 500 sks of PF “C” in 30” Hole 9-5/8" Cmt w/ 406 bbl PF “E”, 70 bbl Class “G” in 12-1/4” Hole 7” Cmt w/ 125 bbl Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 45.7 deg. f/ 6,400’ Hole Angle through perforations = 41 deg. Max DLS = 6.36°/100’ @ 1,550’ TREE & WELLHEAD Tree 2-9/16”- 5M Cameron WKM Wellhead 11” x 11”” 5M Cameron WKM TDF, w/ 11” x 2-7/8” TDF- CS-1 Hanger 2-7/8” EU 8rd lift threads, 2.5” CIW H BPV GENERAL WELL INFO API: 50-029-21997-00-00 Drilled and Cased by Nabors 27E – 1/26/1990 Completed with Gaslift by EWS #4 – 5/14/1990 Convert to ESP by Nabors 4ES – 1/10/1995 ESP Repair by Nabors 4ES – 5/12/1997 & 10/17/1997 ESP Repair by Nabors 5S – 10/17/1997 ESP Repair by Nabors 4ES – 1/18/2000, 12/11/2001, 9/12/2005 & 2/22/2008 ESP Repair by Doyon 16 – 7/14/2012 ESP Repair by Doyon 16 – 5/17/2014 ESP Swap ASR#1 – 5/3/2017 & 12/3/2019 Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 9/15/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU E-04 (190-005) Multi Finger Caliper Log ANALYSIS FIELD DATA Please include current contact information if different from above. Received by the AOGCC 09/16/2020 PTD: 1900050 E-Set:33891 Abby Bell 09/16/2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS C JAN 2 1 2020 1. Operations Abandon LJ Plug Perforations LJ Fracture StimulateLi Pull Tubing L4J Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ ;rforate New Pool ❑ Repair We[(--] Re-enter Susp Well ❑ Other: ESP Changeout ❑✓ 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: µ (T` 7" C9 `1 Name: Development Exploratory p ❑ p ry ❑ Stratigraphic ❑ Service ❑ 190-005 V 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-21997-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL028231 MILNE PT UNIT E-04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 9,900 feet Plugs measured N/A feet true vertical 7,616 feet Junk measured N/A feet Effective Depth measured 9,789 feet Packer measured 8,945 feet true vertical 7,533 feet true vertical 6,913 feet Casing Length Size MD TVD Burst Collapse Conductor 114' 13-3/8" 115' 115' N/A N/A Surface 5,741' 9-5/8" 5,741' 4,579' 3,520psi 2,020psi Production 9,880' 7" 9,880' 7,633' 7,240psi 5,410psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# / L-80 / EUE 8,761' 6,774' Packers and SSSV (type, measured and true vertical depth) Otis HCM PERMA-PKR 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: 98 18 1736 220 221 Subsequent to operation: 1107 48 2541 220 227 14. Attachments (required per20 AAO 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations El Exploratory[--] Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 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: 319-519 for fG� Authorized Name: Chad Hel eson 9 �v Contact Name: Taylor Wellman Authorized Title: Operations Manager Contact Email: twellman(Whilcorp.com Authorized Signature: Date: 1/7/2020 Contact Phone: 777-8449 27•Z� RBDMS L6J .IAN 2 3 2020 Form 10-404 Revised 412017 Submit Original Only Orig. KB Elev.: 58.0(1/ GL Bev.: 34.0' 13-3/8" Arclic Pack 35/8".> , . EstTOC @7,500' MNID=2.205 @ 8,625 SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MPE-04 Last Completed: 12/3/2019 PTD: 190-005 Tree 2 -9/16" -SM Cameron WKM Wellhead 11 x11""SM Cameron WKM TDF,w/11"x2-7/8"TDF- Top CS-1Honger 2-7/8" EU End lift threads, 2.5" CIW H BPV 5 CEMENT DETAIL 1 13-3/8" Cmt w/ 500 sks of PF "C" in 30" Hole r ' 9-5/8" Cmt w/ 406 bbl PF "E", 70 bbl Class "G" in 12-1/4" Hale IIjT�I 7" Cmt w/ 125 bbl Class "G" in 8-1/2" Hale CASING DETAIL 2 7 =:•�' X74(, 35/8" Han Multi Stage Cementer@ 4&5 Y 6&7 t ✓ 8 i �9&10 I { 17 + 12 e MN ID=2.313 13 @8,931 14 15 MNID=2.313 ' I @8'99r 6 17 . KUP C Saris KUPBSarls 78 7" hi4f" TD = 9, 901(MD) / TD = 7,616'(M) PB1D=9,785 (M)) / PBTD=7,533'MM) Size Type Wt/Grade/Conn Drift ID Top Btm BPF 13-3/8" Conductor 48/H-40/N/A N/A Surface 114' 0.1571 9-5/8" Surface 36/J-55/BTC 8.765 Surface 5,741' 0.0773 7" Production 26/L-80/BTC 6.151 Surface 9,880' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE Srd 2.347 Surface 8,761' 0.00579 WELL INCLINATION DETAIL KOP @ 600' Max Hole Angle =45.7 deg. f/6,400' Hole Angle through perforations =41 deg. Max DLS = 6.36'/100'@ 1,550' JEWELRY DETAIL No Depth Item 1 162' STA GLM Camco 27/8X1"S/P ,W/DOSV BK Latch 2 8,512' STA#1: GLM Camco 27/8X1"S/P GLM, W/Dummy - BK Latch 3 8629' 2-7/8"XN-Nipple: (2.205 Ki -go im 4 8,680' Discharge Head: GPDIS 5 8680.5' Ported Discharge Head: 6 8681' Pump: 538PMSXD/93 Flex 47 7 8,697' Pump: 538PMSXD/66 FLEX 47 8 8719' Gas separator: 538GSHVV 9 8722' Upper Seal Sec[ion: GSB3DBUTH6SB/ABPFSA 10 8,729' Lower Seal Section: GS83 D BLTH6SB/AB P FSA 11 8,736' Motor562XP-300Hp/2,090V/88A 12 8,759' Zenith Sensor & Centralizer - Bottom @'8,761 13 8,905' 2-7/8" Chemical Cut Tubing 14 8,930' Baker SBR Seal w/ Otis 2.313" X Profile 15 8,945' Otis 7" "HCM" PERMA-PACKER W/ Mil lout Extension (2.635" ID) 16 1 8,992' 1 Otis 2.313"X Profile 17 9,010' Schlumberger Gun Release 18 9,657' Fish: Top of Schlumberger Gun Assembly PERFORATION DFTAII Sands Top (MD) 1 Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup.0 Sands 1 9,048' 1 9,090' 6,990' 7,021' 42 5/12/1990 Open KUp.B Sands 1 9,116' 1 9,150' 7,041' 1 7,066' 1 34 5/12/1990 1 Open GENERAL WELL INFO API: 50-029-21997-00-00 Drilled and Cased by Nabors 27E-1/26/1990 Completed with Gaslift by EWS #4 -5/14/1990 Convert to ESP by Nabors 4E5 -1/10/1995 ESP Repair by Nabors 4E5-5/12/1997 & 10/17/1997 ESP Repair by Nabors SS -10/17/1997 ESP Repair by Nabors 4ES -1/18/2000, 12/11/2001, 9/12/2005 & 2/22/2008 ESPRepair by Do on 16 -7/14/2012 ESP Repair by Doyon 16 - 5/17/2014 ESP Swap ASR#1 -5/3/2017 & 12/3/2019 Revised By: TDF 1/7/2020 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-04 ASR#1 50-029-21997-00-00 190-005 11/28/2019 12/4/2019 11/27/2019- Wednesday No operations to report. 11/28/2019: Thursday All buildings on location and set, Well but installed, BOP's installed, pits set. Stand up Derrick, Torque BOPE equipment, Connect all electrical and hydraulic lines, lay down containment, move in cat walk, jack up pits, and fix hydraulic leak on jacks for pits. Insulate all lines. Connect fire and gas alarms and test. Load 35 bbls of Fresh water into pits. Load 215 bbls of 80 degree Source water into the pits. 11/29/2019 - Friday Morning Crew change, daily plan forward and safety meeting. Complete insulating lines and prep to shell test. Obtain successful shell test to 2,500psi and Test BOP's. Test BOP'S with 2-7/8" and 3-1/2" test mandrels. Test 2-7/8" x 5-1/2"" VBR's 250 /2,500 psi. Test Blinds, annular, and all choke kill manifold valves, IBOP, TIW for 250 /2,500 psi good tests. Drawdown psi = 1,650 psi from 3,000psi, make up 200psi in 16 seconds and full recovery in 65 seconds. Test witnessed by Austin McCleod of AOGCC. P/U and hang ESP cable and cap string sheaves, R/U elephant trunk and pull rope through elephant trunk, P/U and M/U landing joint, verify well dead, BOLDS, pump 20 bbls down backside, blow down lines, pull hanger up @ 73K. Pulled free smooth. Pull hanger, de -terminate cap string and power cable, break out and lay down hanger, start POOH laying down. POH with 2-7/8" EUE 8rd ESP completion while spooling both the ESP cable and the 3/8" capillary tubing. Pumping double displacement every 15 joints OOH. NOTE: On 90% of the connection breaks we are seeing torque readings in excess of 2,800 ft -lbs on the tongs. Normally, there won't be any noticeable torque reading on the tongs when making these breaks. POH with 2-7/8" EUE 8rd ESP completion. Flow meter reading increases and LEL alarms started to go off. Check forflow. No flow. Gas alarms go off in pits. Still no flow. Secure well as a precaution and to monitor. Cut ESP cable and Capillary Tubing. Secure both to the tubing. Stab Safety Valve and close. Lower tubing so that Cables are below the Annular Preventer. Close Annular Preventer. Monitor well. No pressure. 2100' from surface with tubing and cable. Not pumping when alarms went off. No detectable flow from well. Monitored well 1 hour. NO flow NO pressure increase. Total pumped into well 650 bbls. (including kill and scale squeeze). 11/30/2019 - Saturday Continue monitoring well with annular closed for no pressure build after 1 hours, opened backside with zero psi. Vac truck on location with 290 bbls 120 degree produced water 8.3ppg. Pump all 290 bbls down well @ 4bpm @ 400 psi. S/d pumping and well on vac. Monitor well and return to POOH. Resume POOH with 72 joints left to pull plus ESP. Pump double displacement every 15 joints - well static. ESP on surface -pump 20 bbls down backside and blow down lines - break-out and lay down ESP. Lay down elephant trunk, swap lifting gear to 3-1/2". Swap tong and slip dies. Make up X -over (2-7/8" IF B x 3- 1/2" IF P - 1.0' long), Scraper with muleshoe( 5.75' long), P/U 1st joint 3.5" 10.4# work -string and start in hole. Pumping double displacement every 15 joints - well static. RIH w/ 3.5" 10.4# work string pumping double displacement every 15 joints and blowing dawn lines accordingly. Crew change. PJSM. Continue RIH w/ 3.5" 10.4# work string pumping double displacement every 15 joints and blowing down lines accordingly. With the Scraper at 8,833', POH and L/D 2 joints. Scraper now at 8,748'. RBIH w/ 2 joints of 3-1/2" work string to 8,833'. POH and L/D 2 joints once more. Top of Scraper now at 8,748'. Stab Safety Valve and close. Line up to IA and pump 30 bbls of 80 degree Source Water at 3 BPM and 20 psi. POH w/ 7" Casing Scraper while L/D 3-1/2" work string. Pumping double displacement every 15 joints. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number I Start Date End Date MP E-04 ASR#1 50-029-21997-00-00 1 190-005 1 11/28/2019 12/4/2019 12/1/2019 -Sunday Morning safety Meeting Crew Swaps and Check Fluids. Continue to POOH W/ scraper and 3.5" 10.4# work -string. pumping double displacement every 15 joints and blowing down lines accordingly. Adjustment of service loop alignment in derrick required while pulling. Necessary to re -tie hydraulic lines in derrick several times during pulling. 68 joints left to pull @ 11:30 hours. Resume to POOH. OOH @ 15:30 hours. Breakout and lay down casing scraper. P/U and M/U 7" test packer. RIH. RIH w/ 3.5" 10.4# work string and 7" test packer. BHA consisting of 2-7/8" IF B x 3-1/2" IF P x -over (1.0' long) and test packer assembly consisting of 7.68' long 3.5" IF pup joint (2.48' ID), test packer 5.96" OD in run position (2.99" ID and 8.36' long). Hoses came out of bundle in Derrick. Unable to move up or down with out hoses interfering. Shut down to re -bundle the hoses. Had to completely strip insulation/binding around service hoses, untangle them, and then re-insulate/bind. Continue to RIH w/ 3.5" 10.4# work string and 7" Test Packer. Stop with Test Packer at 2,012'. Rotate to the right one full rotation to set. Slacked off. Clear indication that Packer is set. Fill IA to surface with 55 bbls of Source Water. Pressure up to 345 psi. Hold for 5 minutes. Lost 4% in 5 minutes. Packer is in good working condition. Bleed IA pressure to 0 psi. Rotate to the left one full rotation. RIH and see Packer is free. Let Packer relax for 5 minutes. Continue to RIH w/ 3.5" 10.4# work string and 7" test Packer to 8,740'. Stop with Test Packer at 8,740'. Rotate to the right one full rotation to set. Slacked off. Clear indication that Packer is set. Fill IA to surface with 55 bbls of Source Water. Pressure up to 1,800 psi. Hold for 30 12/2/2019 - Monday Continue to complete pressure test on casing. Test packer elements @ 8,740' and test casing to 2,000psi for 30 minutes for good test. Bleed off pressure, equalize packer, let packer relax 15 mins and prep to POOH. SIMOPS check all fluids while waiting on packerto relax. Repairing centrifugal pump #1 offline. Start POOH w/ packer. POOH w/ 3.5" 10.4# work -string w/ test packer pumping double displacement every 15 joints. 112 joints pulled @ 12:30 hours. Continue POOH w/ work - string and test packer. Packer on surface. Break-out and lay down packer. Pulled 105 joints since 12:30 hours. Prep to pick up ESP. Move in new 2-7/8" 6.5# 8rnd EUE tubing. Move in Centrilift ESP and start to P/U. P/U and M/U ESP: Centralizer, Sensor, Motor, Lower Tandem Seal, Upper Tandem Seal, Intake, Pump, Pump, and Discharge Head. Tally 2-7/8" Tubing. Hydraulic control on tongs is leaking. Shut down and repair by replacing valve. RIH w/ ESP on 2-7/8" 6.5# L-80 EUE 8rd Tubing. Install Clamp on first ten Joints and every other Joint thereafter. Filling hole with double displacement volume every 15 Joints. Testing ESP cable every 1,000'. 12/3/2019 -Tuesday Crew swaps and check fluids. Continue RIH with 2-7/8" 8rnd EUE 6.5# tubing and ESP. Continue RIH w/ 2-7/8" tubing and ESP clamping every other joint with re -used clamps. RIH pumping double displacement every 15 joints. Joint 270 in hole of 280 to make ESP cable splice @ 1700hrs. Centrilift make cable splice at Joint # 277. Continue RIH w/ 2-7/8" tubing and ESP clamping every other joint with re -used clamps. P/U and M/U Tubing Hanger and Landing Joint. Centrilift make bottom connection and Penetrator to Hanger. Land Tubing Hanger. Visually verify Hanger is set properly by looking through IA valve. RILDS. L/D Landing Joint. Set BPV. Spot Crane. R/D Mud Boat. R/D Rig Floor. N/D BOPE. N/U 2-9/16" 5000# Tree. Test Tubing Hanger void to 500psi low and 5,000psi high. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-04 ASR#1 50-029-21997-00-00 190-005 11/28/2019 12/4/2019 12/4/2019- Wednesday - - - Crew swaps and check fluids. Continue RIH with 2-7/8" 8rnd EUE 6.5# tubing and ESP. Rig hydraulics and blocks surging while trying to RIH on high speed. Crews trying to work through but incapable of managing high speed. RIH in forced low to prevent surging and contacting prostar. Throw outjoint 117 due to thread gouge, replace joint 117 with new joint. Continue RIH w/ 2-7/8" tubing and ESP clamping every otherjoint with re -used clamps. String weight greater than 22K and surging on blocks quit. Surge occurs between 6K and 21K. RIH pumping double displacement every 15 joints. Joint 270 in hole of 280 to make ESP cable splice @ 1700hrs. Centrilift make cable splice at Joint # 277. Continue RIH w/ 2-7/8" tubing and ESP clamping every other joint with re -used clamps. P/U and M/U Tubing Hanger and Landing Joint. Centrilift make bottom connection and Penetrator to Hanger. Land Tubing Hanger. Visually verify Hanger is set properly by looking through IA valve. RILDS. L/D Landing Joint. Set BPV. End of ASR operations on E-04. Centrilift made final checks on ESP 12/5/2019 - Thursday No operations to report. 12/6/2019 - Friday No operations to report. 12/7/2019 -Saturday No operations to report. 12/8/2019 -Sunday No operations to report. 12/9/2019 -Monday No operations to report. 12/10/2019 -Tuesday No operations to report. 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, Kuparuk River Pool, MPU E-04 Permit to Drill Number: 190-005 Sundry Number: 319-519 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 �. cog cc.a laska. 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, Jere m Price Chair DATED this `day of November, 2019. IBDMS & Nov 10 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 9n AAc 9,,?Rn RECEIVED NOV 12 2019 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well p ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑r 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: Hilcorp Alaska LLC Exploratory ❑ Development 0. Stratigraphic Service El 190-005 - 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-21997-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D Will planned perforations require a spacing exception? Yes ❑ No ❑ MILNE PT UNIT E-04 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL028231 MILNE POINT/ KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,900' 7,616' 9,789' 7,533' 1,554 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 114' 13-3/8" 115' 115' N/A N/A Surface 5,741' 9-5/8" 5,741' 4,579' 3,520psi 2,020psi Production 9,880 7^ 9,880' 7,633' 7,240psi 5,410psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 2-7/8" 6.5# / L-801 EUE 8,778' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Otis HCM PERMA-PKR and N/A 8,945'(MD) & 6,913'(TVD) and N/A 12. Attachments: Proposal Summary E Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations11/25/2019 OIL ❑ . WINJ E]WDSPL E] Suspended 1:1: 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: Taylor Wellman—7wA,/ Authorized Title: Operations Manager Contact Email: twellirlan hilcor .Com Contact Phone: 777-8449 Authorized Signature: Date: 111 I Z. COMMISSION USE ONLY Conditions of approval: Notify Commission so that representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical Integrity Test EJ Location Clearance ❑ Other: ,-V 2 370 0 < /J C)io / CS T- / A 7'gs �- �,. ��:s�� 1860es` ZBDMS —[F�kNOV 1 02019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: y Q APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 14> � 4 1 A u5 b Form and Farm 10-403 Revised 4/2017 Approved appliC ti i r om the ate of approval. Attachments it Duplicate N Hilmrp Alaska, LG ESP Change -Out Well: MPU E-04 Date: 11-08-2019 Well Name: MPU E-04 API Number: 50-029-21997-00 Current Status: Shut-in ESP Producer Pad: E -Pad Estimated Start Date: November 25th, 2019 Rig: ASR Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 218-104 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) AFE Number: Job Type: ESP Swap Current Bottom Hole Pressure: 1,772 psi @ 6,775' TVD Maximum Expected BHP: 2,230 psi @ 6,775' TVD MPSP: 1,554 psi Max Inclination 45" @ 2,400' MD Max Dogleg: 7.2'/100ft @ 1,500' MD BPV Profile: 2-1/2" CIW Type H Downhole Gauge: 3 -week PBU (8/29/19) 15.1 PPG 45 -day PBU Extrapolation 16.4 PPG Gas Column Gradient (0.1 psi/ft) Brief Well Summary: MPU E-04 was drilled in 1990 using Nabors 27E and completed in the Kuparuk sands with a gaslift completion. The well was converted to ESP in 1995 using Nabors 4ES. The well has had multiple ESP changeouts since 1995, (1997, 1997, 2000, 2001, 2005, 2008, 2012, 2014 and the most recent was an ESP changeout in 2017). This well has had tendency for scaling. A MTT (Magnetic Thickness Tool) was run in July 2012 during the RWO, and no shallow subsidence issues were seen. During the 2017 RWO, the gas separator was found to have eroded to the point of parting leaving the lower section of the ESP in the well. Fishing operations were able to recover the lower ESP section. The ESP ran for 2.5 years before the transformer developed a bushing seal leak. The ESP was shut in to repair and shortly after startup, the downhole gauge was lost and quickly followed by the ESP becoming grounded. flu 1� Notes Regarding Wellbore Condition • Casing last tested to 3,000 psi for 30 min down to 8,850' on 7/14/2012. • During the 2017 RWO, the gas separator parted during pulling of the completion. See wellfiles for pictures of parting and description of fishing tools used for recovery. • Last Fill Depth: 8,905' MD tagged tubing stub on 5/12/1997. Objective: • Pump Scale Inhibition Treatment (pre -rig) �s� '7 `e4 • Pull 2-7/8" Tubing String, Flex 17.5 ESP, and 300 HP motor. 0 iOJ • Install new Baker Hughes 300 HP motor, Baker Hughes ESPs, new ESP cable, and re -run pulled 2-7/8" tubing. Pre -Rig Procedure: 1. MIRU Slickline unit. a. Pull orifice valve from STA #2 @ 174' and set DV. b. Pull DV from STA #1 @ 8,525' MD. Leave pocket open. c. RD Slickline Unit. 2. RU LRS and PT lines to 3000 psi. 3. Pump 1 IA volume (265 bills) with 8.3 ppg source -water down IA. B Dilcom Almkn, LG 4. Bullhead the following scale inhibition treatment down the tubing to the formation: a. 2.0 drums of WAW5206 + 32.4bbls of mix water= 32bbls total. b. 7.0 drums of SCW4004 + bbls of mix water= 64bbls total. t1c. 155bbis of 8.3ppg source water down the tubing. \LI " d. Ensure MSDS's are reviewed and available on location prior to RU. 5. Clear and level pad area in front of well. Spot rig mats and containment. 6. RD well house and flowlines. Clear and level area around well. 7. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH. a. Due to the low reservoir pressure, a tubing freeze protect should not be needed. ESP Change -Out Well: MPU E-04 Date: 11-08-2019 b. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 8. RD Little Red Services. 9. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 10. NU BOPE house. Spot mud boat. Brief RWO Procedure: 11. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. 12. 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/ 8.3 ppg source -water prior to pulling BPV. 13. Set PBV Plug (converting BPV to TWC). 14. 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. 'toqr b. Perform Test per ASR #1 BOP Test Procedure dated 11/03/2015. / 5" yS 0 c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" and 3-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails 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. n Hilt m Alaska, LG ESP Change -Out Well: MPU E-04 Date: 11-08-2019 16. Bleed any pressure off casing to returns tank. Pull BPV plug and BPV. Kill well w/ 8.3 ppg source -water as needed. 17. Rig up spoolers for ESP #2 RD cable and 3/8" capillary string. a. Baker Hughes representative should be onsite for ESP pull. 18. MU landingjoint or spear and PU on the tubing hanger. a. The 2017 ASR #1 ESP completion the PUW = 67k lbs and the SOF = 32k lbs. b. If needed, circulate (long or reverse) pill with lubricant, source -water, and/or baraclean pill prior to laying down the tubing hanger. 19. 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. a. Evaluate pulled tubing hanger for possible thread damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. 20. POOH and lay down the 2-7/8" tubing. Lay down ESP and motor. a. Note any sand, scale, or corrosion on the tubulars and ESP on the morning report. i. Look for over -torqued connections from previous tubing runs. ii. If any joints appear suspect of damage to threads or tubing, send to G&I for disposal and replace with new. b. The old completion has the following amount of clamps/guards/cap-string: i. 146 Cross Collar Cannon Clamps ii. 2 Flat Guards iii. 5 Protectolizers iv. ±8,778' of 3/8" capillary tubing < 21. PU 7" scraper and RIH to ±8,800' md. Circulate x1.5 BU or until clean. POOH. 4(� \ 22. MU 7" test packer and RIH with workstring to ±8,750' md. Set and pressure test casing to 1.800nsi for 1 ck i5, 30 min (charted). a. Contingency: If casing pressure test does not pass. i. Pull up 500' and and retest. Contact Ops Engineer for discussion on depth to move uphole or if pressure test readings need review. 23. PU new ESP and RIH on 2-7/8" 6.5# L-80 tubing. Set base of ESP assembly at±8,750' MD. a. Upper 2-7/8"x 1" Side -pocket GLM @ ±200' MD with orifice valve installed. b. 2-7/8" tubing. �Y c. Lower 2-7/8"x 1" Side -pocket GLM with Dummy GLV. d. 2 full joints of 2-7/8" tubing. e. 2-7/8" XN (2.205" No -Go) Nipple. f. 1 joint of 2-7/8" tubing. g. Downhole gauge for discharge temperature and pressure. i. Connected with a jumper from the lower sensor. Does not require a separate tech -wire. h. Baker Hughes 159 stage 538FIex47 ESP L Tandem Gas Separator j. 300 HP Baker Hughes 562XP Motor ESP Change -Out Well: MPU E-04 Ililcurp Alaekx, LU Date: 11-08-2019 k. Motorgauge I. Base of ESP centralizer @ ±8,750' MD 24. Land tubing hanger. RILDS. Lay down landing joint. Note Pick-up and slack -off weights on tally. 25. Set BPV. Post -Rig Procedure: 26. RD mud boat. RD BOPE house. Move to next well location. 27. RU crane. ND ROPE. 28. NU existing 2-9/16" 5,000# tree. Test tubing hanger void to 500 psi low/5,000 psi high. 29. Pull BPV. 30. RD crane. Move returns tank and rig mats to next well location. 31. Replace gauge(s) if removed. 32. Turn well over to production. RU well house and flowlines. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic 4. Blank RWO MOC Form Orig. KB Elev.: 58.00'/ GL Elev.: 34.0' 9 5/8" Est. TOC 07,500' , 3'8' SS CaWmg -; MIN ID= 2.250 @ 8,668' 0 MN ID= @ 8,930' MIN ID= 2.313 @ 8,992' SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MPE-04 Last Completed: 5/3/2017 PTD: 190-005 Tree 2-9/16"-5M Cameron WKM Wellhead 11" z 11"" 5M Cameron WKM TDF, w/ 11" x 2-7/8" TDF - Top CS -1 Hanger 2-7/8" EU 8rd lift threads, 2.5" CIW H BPV F OPEN HOLE / CEMENT DETAIL 1 13-3/8" Cmt w/ 500 sks of PF "C" in 30" Hole 9-5/8" Cmt w/ 406 bbl PF "E", 70 bbl Class "G" in 12-1/4" Hale 7" Cmt w/ 125 bbl Class "G" in 8-1/2" Hole CASING DETAIL .�I 9-5/8" Hall Multi St Cementer @ 1,955' Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 13-3/8" Conductor 48/H-40/N/A N/A Surface 114' 0.1571 9-5/8" Surface 36/1-55/BTC 8.765 Surface 5,741' 0.0773 7" Production 26/L-80/BTC 6.151 Surface 9,880' 0.0383 TUBING DETAIL 2 • WELL INCLINATION DETAIL n KOP @ 600' e Max Hole Angle = 45.7 deg. f/ 6,400' Hole Angle through perforations = 41 deg. Max DLS = 6.36°/100' @ 1,550' N JEWELRY DETAIL 3 i '4 ,5&6 7 8&9 10 11 13 14 15 16 n 1,1 L' C'r . KUP C Sands 18 TO = 9,91V (MD) /TD= 7,616'(TVD) PBTD= 9,789' (MD) / PBTD = 7,533'M) No Depth Item 1 174' STA #2: Camco 2-7/8" x 1" Sidepocket KBMM GLM w/ SOV Dummy 2 8,525' STA #1: Camco 2-7/8" x 1" Sidepocket KBMM GLM w/ Dummy 3 8,668' XN-Nipple: (2.205 No-go In 4 8,710.73' Discharge Head: GPDIS 5 8,711' Pump: Type-52FLEX47, Model-SSDM 6 8,724' Pump: Type-66FLEX47, Model -SXD H6 7 8,740' Intake: GPBARCINT FER H6 8 8,741' Upper Seal Section: GSB3DBUT SB/SB PFSA 9 1 8,748' Lower Seal Section: G583DBUTSB/SB PFSA 10 8,755' Motor CL5: XP -200F, 300HP, 2,090 volt&88amps 11 8,775' Sensor: Welli-ift Type 12 8,776' Centralizer/ Bottom @ 8,778' 13 8,905' 2-7/8" Chemical Cut Tubing 14 8,930' Baker SBR Seal w/ Otis 2.313" X Profile 15 8,945' Otis 7" "HCM" PERMA-PACKER w/ Millout Extension (2.635" ID) 16 8,992' Otis 2.313" X Profile- rofle17 17 9,010' Schlumberger Gun Release 18 9,657' Fish: Top of Schlumberger Gun Assembly PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status ).CSands 1 9,048' 9,090' 6,990' 1 7,021' 1 42 1 5/12/1990 Open 1. BSands 9,116' 9,150' 7,041' 1 7,066' 1 34 1 5/12/1990 Open GENERAL WELL INFO API: 50-029-21997-00-00 Drilled and Cased by Nabors 27E-1/26/1990 Completed with Gaslift by EWS #4-5/14/1990 Convert to ESP by Nabors 4ES -1/10/1995 ESP Repair by Nabors 4ES-5/12/1997 & 10/17/1997 ESP Repair by Nabors SS -10/17/1997 ESP Repair by Nabors 4ES -1/18/2000, 12/11/2001, 9/12/2005 & 2/22/2008 ESP Repair by Doyon 16 -7/14/2012 ESP Repair by Doyon 16 - 5/17/2014 ESP Swap ASR#1- 5/3/2017 Revised By; TDF 5/15/2017 Iiilrnrp Alaska. LLC Orig. KB Elev.: 58,W1 GL Elev.: 34.0' RKB-THF: 23.75' 142n 161 WW_Tr 133/8" IIII C 1 Arctic Pack II I I 9-5/8" .I . Est. TOC Qa 7.500' A MIN ID= 2.250 @8,668' MIN ID= @ 8,930' MINID=2.313 @8,992 rs l 9-5/8" Hall Multi Stage Cementer @ 1,955' Milne Point Unit Well: MPE-04 PROPOSED Last Completed: 5/3/2017 PTD: 190-005 TREE & WELLHEAD OPEN HOLE/ CEMENT DETAIL 13-3/8" Tree 2-9/16"-5M Cameron WKM Cmt w/ 406 bbl PF "E", 70 bbl Class "G" in 12-1/4" Hole 7" Wellhead 11"x11"" SM Cameron WKM TDF, w/11"x2-7/8"TDF- 13-3/8" Conductor 48/H-40/N/A CS-1 Hanger 2-7/8" EU 8rd lift threads, 2.5" CIW H BPV Surface OPEN HOLE/ CEMENT DETAIL 13-3/8" Cmt w/ 500 sks of PF "C" in 30" Hole 9-5/8" Cmt w/ 406 bbl PF "E", 70 bbl Class "G" in 12-1/4" Hole 7" Cmt w/ 125 bbl Class "G" in 8-1/2" Hole CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 13-3/8" Conductor 48/H-40/N/A N/A Surface 114' 0.1571 9-5/8" Surface 36/1-55/BTC 8.765 Surface 5,741' 0.0773 7" Production 26/L-80/BTC 6.151 Surface 9,880' 0.0383 TUBING DETAIL 2 WELL INCLINATION DETAIL KOP @ 600' Max Hole Angle = 45.7 deg. f/ 6,400' Hole Angle through perforations = 41 deg. Max DLS = 6.36°/100' @ 1,550' JEWELRY DETAIL 3 4 ,5&e 7 S&9 10 11 12 13 14 15 16 17 1 KUP C Sands 18 TD = 9,900'(M1D) /TD = 7,616'(TVD) PBTD= 9,789' (MD) / PBTD = 7,533'(TVD) No1+8,690'MDischargeHead: Top (MD) Item 1TA Btm (TVD) #2: GLM 2 Status STA GLM 3N 9,090' -Nipple: (2.205 No-go ID) 4Discharge 42 Head:5ump:6ump: Open KUP.BSands 1 9,116' 9,150' 7,041' 7,066' 7 ±8,710' Intake: 8 ±8,720' Upper Seal Section: 9 ±8,730' Lower Seal Section: 10 ±8,735' Motor: 11 ±8,740' Sensor: 12 ±8,748' Centralizer /Bottom@±8,750' 13 8,905' 2-7/8" Chemical Cut Tubing 14 8,930' Baker SBR Seal w/ Otis 2.313"X Profile 158,945' Otis 7" "HCM" PERMA-PACKER w/ Millout Extension (2.635" ID) 16 8,992' 1 Otis 2.313" X Profile 17 9,010' Schlumberger Gun Release 18 9,657' Fish: Top of Schlumberger Gun Assembly PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 1 9,048' 9,090' 6,990' 7,021' 42 5/12/1990 Open KUP.BSands 1 9,116' 9,150' 7,041' 7,066' 1 34 5/12/1990 Open GENERAL WELL INFO API: 50-029-21997-00-00 Drilled and Cased by Nabors 27E-1/26/1990 Completed with Gaslift by EWS #4-5/14/1990 Convert to ESP by Nabors 4ES-1/10/1995 ESP Repair by Nabors 4ES-5/12/1997 & 10/17/1997 ESP Repair by Nabors 55 -10/17/1997 ESP Repair by Nabors 4ES-1/18/2000, 12/11/20017 9/12/2005 & 2/22/2008 ESP Repair by Doyon 16 - 7/14/2012 ESP Repair by Doyon 16 - 5/17/2014 ESP Swap ASR#1- 5/3/2017 Revised By: TDF 11/11/2019 Milne Point ASR Rig 1 BOPE 11" BOPE Updated 8/19/2015 311 or Pipe Rams ind -UF{ U a in 0 N N N d m E 0 Y R 0 v m s w N L O � � m m m U = C U � o Ew E rn o .S U C aN E N 3 a ` E N c L � o N � an > � m o a� CL 6 m 2 CW R .- o m Ol NC d R � L C U R N U 0 d o �a o a R O C Qw 3 �U N 0 C U1 E am U o O C CM O G L N r4)d - U � Q_) C UCc c f7o Q a Qa a H N p Ya_ =Qc CL Q m a w Y m:t R ._ =CLc L am Q Im R s U 3 a d U a Y R d a R CL CL w cu 0 o. CL M IC -o d R CL N M Schwartz, Guy L (CED) From: Taylor Wellman <twellman@hilcorp.com> Sent: Monday, November 18, 2019 9:24 AM To: Schwartz, Guy L (CED) Cc: Wyatt Rivard Subject: RE: [EXTERNAL] MPU E-04 ESP swap (PTD 190-005) Guy Sorry for the delayed response. I was out for part of last week with some medical reason. For E-04, I don't believe this well is showing any signs of subsidence for the following reasons: - 7", 26# casing nominal ID = 6.276" - 2017 RWO: During fishing of the parted gas separator of the ESP, there was a 6.125" OD stop sub that was run to 8,862' and without any indication of an overpull. Also runs with a 6.125" overshot/box tap didn't indicate any overpulls near surface. We were also watching our weight indicator quite closely as we were watching to see if we dropped the fish. - Planned tools during this RWO: 7" casing scraper (body OD = 5.25" w/ dogs extending to casing walls) & 7" test packer (running OD = 5.9"). If we run into any overpulls or indications of tight spots, I would say we would go to pull a caliper or run a full drift. As a base case, I'm not finding indications in the history for this well of issues. Thanks and let me know what you think. -Taylor Taylor Wellman Hilcorp Alaska, LLC — Ops Engineer: Alaska North Slope Team Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Schwartz, Guy L (CED) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, November 14, 2019 2:09 PM To: Taylor Wellman <twellman@hilcorp.com> Cc: Wyatt Rivard <wrivard@hilcorp.com> Subject: [EXTERNAL] MPU E-04 ESP swap (PTD 190-005) Taylor, As E pad has a history of subsidence have you guys considered running a casing caliper (0-1000 ft or so) after ESP is pulled? (regardless if you see any drag pulling ESP out). The RWO ESP swap sundry already has you doing a casing test... Was also curious if you saw anything indicating subsidence the last time the ESP was pulled? (IE near -surface drag) Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 low. 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 Guy Schwartz at (907-793-1226) or (Guv schwartz@claska gov). The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA • AL.OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations LI Fracture Stimulate U Pull Tubing L Operations shutdown L,( Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Well Repair 2.Operator p CIRe-enterSusp Well❑ Other:ESP Changeout ❑✓ Name: Hilcorp Alaska LLC 4.Well Class Before Work: 5.Permit to Drill Number: Development Q Exploratory ❑ 190-005 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic ill Service ❑ 6.API Number: AK 99503 50-029-21997-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL028231 MILNE PT UNIT E-04 PIECE' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): VED N/A MILNE POINT/KUPARUK RIVER QY j 9 11.Present Well Condition Summary: 017 Total Depth measured 9,900 feet Plugs measured N/A fe8t""' CC true vertical 7,616 feet Junk measured N/A feet Effective Depth measured 9,789 feet Packer measured 8,945 feet true vertical 7,533 feet true vertical 6,913 feet Casing Length Size MD TVD Burst Collapse Conductor 114' 13-3/8" 115' 115' N/A N/A Surface 5,741' 9-5/8" 5,741' 4,579' 3,520psi 2,020psi Production 9,880' 7" 9,880' 7,633' 7,240psi 5,410p si Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8,778' 6,787' Packers and SSSV(type,measured and true vertical depth) Otis HCM PERMA-PKR 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/AitiED /avE t.. I 17 tr m : 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 0 700 0 Subsequent to operation: 124 31 1435 140 194 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory El Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas 2 WDSPL E] Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG El 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: 316-065 • Authorized Name: Bo York Contact Name: Taylor Wellman✓ Authorized Title: Operations Manager Contact Email: twellman hiIcorp.com Authorized Signature:' ' Date 5/19/2017 Contact Phone: 777-8449 y.., RBDMS LV t.?.'.'' 1 9 2017 Form 10-404 Revised 4/20171/217 Submit Original Only i Milne Point Unit 14 Well: MPE-04 SCHEMATIC Last Completed: 5/3/2017 Iiilcorp Alaska,LLC PTD: 190-005 TREE&WELLHEAD Orig.KB Elev.:58.00'/GL Elev.:34.0' Tree 2-9/16"-5M Cameron WKM RKB-THF:23.75'(Doyon 16 Wellhead 11"x 11""5M Cameron WKM TDF,w/11"x 2-7/8"TDF- k k CS-1 Hanger 2-7/8"EU 8rd lift threads,2.5"CIW H BPV 13-3/8" i 1 OPEN HOLE/CEMENT DETAIL 13-3/8" Cmt w/500 sks of PF"C"in 30"Hole 9-5/8" Cmt w/406 bbl PF"E",70 bbl Class"G"in 12-1/4"Hole Arctic Pack 7" Cmt w/125 bbl Class"G"in 8-1/2"Hole ) CASING DETAIL H Size Type Wt/Grade/Conn Drift ID Top Btm BPF e w 13-3/8" Conductor 48 H-40 N A 0.1571 t� �; `,�, � / / / N/A Surface 114' 9_5/g,E ".1 e t' a 9-5/8" Surface 36/1-55/BTC 8.765 Surface 5,741' 0.0773 7" Production 26/L-80/BTC 6.151 Surface 9,880' 0.0383 s 9-5/8"Hall Multi Stage TUBING DETAIL Est.TOC @ 7,500' ) I Cementer @ 1,955' gg 12 7/8 I Tubing I 6.5/L-80/EUE 8rd I 2.347 I Surface 8,778' 10.00579 3/8" Cap String Stainless Steel N/A Surface 8,778' N/A 2 3/8 sSCapstring �, - WELL INCLINATION DETAIL KOP @ 600' Max Hole Angle=45.7 deg. f/6,400' 4Y. Hole Angle through perforations=41 deg. I S" Max DLS=6.36°/100'@ 1,550' sa MIN ID 2.250 JEWELRY DETAIL @8,668' - 3 No Depth Item Ft +4 1 174' STA#2:Camco 2-7/8"x 1"Sidepocket KBMM GLM w/SOV Dummy $, 2 8,525' STA#1:Camco 2-7/8"x 1"Sidepocket KBMM GLM w/Dummy @� 5&6 3 8,668' XN-Nipple: (2.205 No-go ID) ,t 4 8,710.73' Discharge Head:GPDIS 5 8,711' Pump:Type-52FLEX47,Model-SSD M 1..1:i78,9 '7 6 8,724' Pump:Type-66FLEX47,Model-SXD H6 8&9 7 8,740' Intake:GPBARCINT FER H6 k 8 8,741' Upper Seal Section:GSB3DBUT SB/SB PFSA 9 8,748' Lower Seal Section:GSB3DBUT SB/SB PFSA 10 10 8,755' Motor CL5: XP-200F,300HP,2,090 volt&88 amps 11 8,775' Sensor:WeIlLift Type E 11 12 8,776' Centralizer/Bottom @ 8,778' 13 8,905' 2-7/8"Chemical Cut Tubing 12 14 8,930' Baker SBR Seal w/Otis 2.313"X Profile !4 15 8,945' Otis 7""HCM"PERMA-PACKER w/Millout Extension(2.635"ID) MINID=2.313 il N; 1� 13 16 8,992' Otis 2.313"X Profile @8,930 7 14 17 9,010' Schlumberger Gun Release a ► ' s 18 9,657' Fish:Top of Schlumberger Gun Assembly I i it 1 15 ! PERFORATION DETAIL MIN ID 2.313 ,I Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status @8,992' Kup CSands 9,048' 9,090' 6,990' 7,021' 42 5/12/1990 Open' 16r 'r Kup.BSands 9,116' 9,150' 7,041' 7,066' 34 5/12/1990 Open 17 GENERAL WELL INFO KUP C Sands API:50-029-21997-00-00 Drilled and Cased by Nabors 27E-1/26/1990 1}KUP B Sands Completed with Gaslift by EWS#4-5/14/1990 t Convert to ESP by Nabors 4ES-1/10/1995 ESP Repair by Nabors 4ES-5/12/1997&10/17/1997 ESP Repair by Nabors 5S-10/17/1997 18 ESP Repair by Nabors 4ES-1/18/2000,12/11/2001, 9/12/2005&2/22/2008 ESP Repair by Doyon 16-7/14/2012 TD=9,900(MD)/TD=7,616'(ND) ESP Repair by Doyon 16-5/17/2014 PBTD=9,789'(MD)/PBTD=7,533'(TVD) ESP Swap ASR#1-5/3/2017 Revised By:TDF 5/15/2017 • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-04 ASR1 50-029-21997-00-00 190-005 4/25/17 5/3/17 Daily Operations: 4/19/2017-Wednesday No activity to report. 4/20/2017 -Thursday No activity to report. 4/21/2017- Friday No activity to report. 4/22/2017-Saturday No activity to report. 4/23/2017 -Sunday No activity to report. 4/24/2017- Monday No activity to report. 4/25/2017 -Tuesday Accept rig @ 12:00pm 4/25/17. Rig crews continue to prep well E-04 for upcoming workover, and continue to clean around well E-14A in prep to hand well back over to pad operator. Roads and pads on location to perform crane work associated w/rig move. 24hr notice of BOPE test given @ 16:00hrs 4/24/17. Reply received from AOGCC rep Mathew Herrera @ 15:30hrs 4/25/17 waiving witness to testing. Roads and Pads spot working wellhouse onto E-04. 100psi pressure noted on the IA and TBG, indicating BPV is leaking. Lubricate BPV out. BPV stuck in open position w/debris. Bleed IA to flowback tank. Pressure quickly dropped off to 0 psi. R/U and bleed TBG pressure. Pressure also quickly reduced to 0 psi. Greg Ruge and John Morrow on location to set BPV. N/D tree and N/U BOPE. SIMOPS: LRS FP Well E-14A. Remove production tree and replace w/BOPE adapter flange, mud cross, and dual ram bodies. Stuff absorbent into tree and wrap with oily waste bag to ensure no leaks. Crane operator begins having issues w/crane controls. Contact VMS shop for further support w/crane malfunction. Crane boom locked out in extended position without any load. VMS on location to trouble shoot. Rig crews continue to R/U on well E-04 and clean up around well E-14A. R/U HCR and manual valves on mud cross. Continue to prep for operations on well E-04. Wrap all circulation lines w/Certek glycol lines to prevent freezing, and cover lines w/tarp covers. PEAK vac trucks on location w/480bbls of 100deg seawater. Unload into pits and upright tank in prep for well circulation. Load 3-1/2" RTS-8 work string into pipe tubs which were previously being cleaned at G&I. Scrape and clean any residual debris left in pipe staging area. • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig / API Number Well Permit Number Start Date End Date MP E-04 ASR1 50-029-21977-00-00 190-005 4/25/17 5/3/17 Daily Operations: r 4 4/26/2017-Wednesday ASRC Mechanic Amos and Curt Trouble Shot and Fixing Crane, (Manual Shift Lever For Hydraulic Pump was Disengaged). Finished Nipple up Bope Stack Install Annular and Manual Valves/ Finished Torquing up Bolts, Install Rig Floor, Rig up Hydraulic Lines F/Accumulator Trailer to Bope Stack, Charge up Lines,. Raise Derrick Jack Knife top section into Place and Pin, Rig up all Service Lines, Rig up Certek Heater and Lines. Well Head Rep Greg Ruge and John Morrow Pulled BPV and Installed TWC Valve. Finished Rigging up Pipe Racks and Miscellaneous Rig Equipment,. Greased all Valves, Function Test Bope Stack, Rigged up Test Equipment, Shell Test Bope 250/2,500psi Good Test, Electrician Rigged up Fire and Gas Alarms in Cellar/ Rig Floor and Pit Module Tested Good. (Notification witness waived for this test received by Matthew Herrera AOGCC 4-26-17 at 13. 52 Hrs.)Testing Bope Rams and Valves 250psi/2,500psi 5 min each Test Joints 2-7/8" -3-1/2 Test Annular 250psi/2,500psi 5 min each Record Accumulator Pre-Charge Pressures and Chart Test. SIMOPS: Load and tally first two rows of work string in prep for clean out run. Wellhead hands Greg Ruge and John Morrow on location to pull TWC. Pull TWC. Fluid level out of visual range. R/U and circulate 50bbI pill of baraklean followed by 270bbIs of seawater, down the IA taking returns up the TBG through the choke and out to the flow back tank. 320bbIs pumped, 140bbIs returned to surface. Fluid Loss= 180. Drain fluid lines and prepare floor for pulling ESP completion on 2-7/8" 6.5# EUE TBG. R/U elephant trunk hose off of ESP sheave, as well as slobber hose. Wellhead hand John Morrow on location to BOLDS. P/U 2-7/8" EUE landing joint, M/U to TBG hanger as per wellhead rep, BOLDS, and pull hanger to floor.TBG hanger released w/ 65klbs over pull. B/O ESP penetrator and L/D TBG hanger.Tie off ESP cable to spooler rope in prep to pull ESP. Pull ESP on 2- 7/8" 6.5# EUE TBG f/8,806'to 8,496'. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-04 ASR1 50-029-21977-00-00 190-005 4/25/17 5/3/17 Daily Operations: 4/27/2017-Thursday Hanging u Rig While Tripping out of the hole Service Loop Hydraulic Lines that Travels up/Down Derrick Keep 8,400'.g g p, Crew Continuing Wrapping and Tighing up Hydraulic Lines in Derrick Trying to make it work, While Jerry Chit wood and Shannon are on A-Pad Having the Insulator Crew making a Wrapping Blanket For Hydraulic Hoses for Service Loop. (0935 hrs. Loader Incident, Loader Backed into Truck Breaking Tail Light Denting Quarter Panel and Bumper) (Safety Sarra Ghiassi was Notified of Incident and a Incident Report was Filled out and Pictures Taking of Damage Truck) Continued TOOH W/old ESP Assembly on 2-7/8" 6.5# EUE TBG f/8400'to 5,290'. Back ups on the Power Tongs are Broke Tool pusher Went over to A-Pad to get Spare Parts For Tongs in Connex Trailer, No Spare Parts were Located for Power Tongs, Back Body was Remove From Tongs and Taken over to GBR Welding Shop to be Repaired) (VMS Shop Mechanic Amos Loaded up Computer to Rig change some Setting and Parameters to Rig). Continued TOOH W/old ESP Assembly on 2-7/8" 6.5# EUE TBG f/5,290'. to pump discharge head @ 78'md. Disconnect ESP cable and spool back to spooling unit utilizing rope from rig floor. Begin laying down ESP sections. When pulling the gas separator through the rotary table it was found that the ESP had parted at the lower dischaLge ports due to sand abrasion.All ESP cable was removed from the hole intact, but the tech wire that runs from the MGU to the discharge head was left in the hole on top of the fish. Contact Baker fishing and discuss fishing options. Rig crew clean and clear rig floor, swap over pipe handling equipment from 2-7/8" to 3-1/2". Contact Well Ops Engineer, Well Pad Foreman, and Well Ops Coordinator to discuss plan forward. Decision made to P/U rope spear on drill pipe and attempt to retrieve 1/4" stainless steel Tec line in order to clear up any obstruction from the potential fishing neck. Rig crews continue to load and tally DP, service the rig„--• , prep floor for picking up 3-1/2" work string. Contact Baker fishing to get rope spear and stop sub. Use Peak pickup truck to C1' hotshot spear out to location from Deadhorse. Rig crews continue to load and tally DP, service the rig, prep floor for picking up 3-1/2" work string. Waiting on rope spear from Baker fishing. Rig crews continue to prep rig floor for picking up 3-1/2" work string. Rope spear delivered to location. P/U rope spear and strap for tally. M/U BHA consisting of 8.29' rope spear, 6.125" OD stop sub and X-over f/3.5" IF to 3.5" RTS-8. RIH w/ Baker Rope Spear Fishing BHA f/surface to 1,900'. on 3.5" RTS-8 work string. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-04 ASR1 50-029-21977-00-00 190-005 4/25/17 5/3/17 Daily Operations: 4/28/2017 - Friday Service Rig Grease and Check Fluids. RIH w/ Baker Rope Spear Fishing BHA Continued Loading and Tally Total 300 Joints on Racks Continued TIH f/ 1,900' to 8,618' on 3.5" RTS-8 work string. with 290 Joints in the hole P/U/W=69K S/O/W=41K. R/U Circulating Hose and attempt to kelly up to work string. When attempting to rotate swivel, rotation was counter clockwise and RPM's were not recording. Contact Prostar, discover hydraulic lines were crossed on the rig carriage, reverse hoses and reset parameters on rig carriage, rotating clockwise but still not recording RPM. Continued Getting rotating parameters at 8,618'.Torque Limit set at 3,000'-lbs. ROT TQ= 1.8-2K'-lbs. Continued TIH to 8852'md.Tag up on top of fish located @ 8,852' and ASR RKB of 19' w/2-3klbs. Expected TOF based on fish falling to bottom and sitting on cut TBG =8,862'md. P/U until weight indicator breaks over, watch for any potential over pull on the way up. Set back down on fish w/2-3klbs, depth of tag consistent. Repeat process 2 more times to ensure we are on fish. P/U to work string neutral weight, and then pull an additional 2'to ensure we are clear from top of gas separator. Set string in slips and kelly up w/the power swivel. Once made up, release from slips and begin slowly rotating at lowest rotating setting (10-20RPM). 1.8-2.0K'-lbs TQ seen when rotation began, then briefly the TQ rose to 2.4K-lbs before quickly falling back to 1.8-2.0k. Work pipe —10' while rotating. Turn off the rotary, work any trapped TQ out of the string, and begin POOH w/Baker Fishing Rope Spear BHA on 3-1/2" RTS- 8 work string. Pull the first 2 joints slowly and consistently in order to watch for any potential over pull. No over pull seen. Continue to POOH f/8,852'md to surface. POOH w/fish. Recovered 12' of stainless steel 1/4"Tec line which was broken into two pieces (8' and 4' 10"). L/D BHA#1 Baker rope spear 4/29/2017-Saturday Rig Service Check Fluids and Grease. (PJSM) Make up BHA No'2' Box Tap w/OD 6-1/8 ID of 5'with a 5'extension Drive Bushing, Bumper sub, Oil Jar, 4-4-3/4, Drill collars BHA P/U/W=7K D/N/W=6K.TIH w/BHA No 2' on 3-1/2 RTS-8 Work String to 8836'. Kelly up on work string, close annular, and gain pumps on fishing parameters. P/U/W= 75klbs, D/N/W=4lklbs, circ pressure @ 1.8BPM = 140psi, pumping down TBG taking returns to pits. RIH w/circulation to TOF @ 8852'. and verify w/tag. Flush TOF and clear ID of box tap. P/U to ensure no pipe engagement prior to re-tagging fish to verify tag depth. (8852'. P/U 10' above fish, come down on the pumps, open annular, blow down circ lines. Gain fishing parameters w/ annular open. P/U/W= 72klbs, D/N/W=43klbs.Turn on rotary to 20-30RPM, ROT WT= 56klbs, Free TQ= 1.9k'-lbs. RIH to TOF w/rotation, set down 3-5klbs on fish and watch TQ. Slow increase in TQ f/1.9-2.6k'-lbs prior to TQ reducing back to 1.9k'-lbs and then slowly climbing again (Indicator fish rotating down hole).Turn off rotary and slowly P/U watching weight. 2-3klbs of drag noted on weight indicator. Turn on rotary, set back down on fish w/2-3Klbs and watch Torque climbed to 3.0k'-lbs before dropping off. Turn off rotary and slowly P/U off bottom. Increase of 2-3klbs seen on hook load w/ occasional drag seen increasing hook load 3-5klbs. (Good indication w/fish). POOH f/8852'. w/ Baker fishing box tap BHA #2 on 3-1/2" RTS-8 work string to surface. L/D BHA. Recovered 24' of Tec Line f/Box TQ__ • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-04 ASR1 50-029-21977-00-00 190-005 4/25/17 5/3/17 Daily Operations: 4/30/2017—Sunday Rig Service Change Oil and Filters on Rig Generator, Pit Generator and Tool Pusher Trailer Generator, Change Oil in Drop Box. (PJSM) Baker fish Rep Rick Vincent and Rig Crew, Make up BHA No'3' Box Tap w/OD 6-1/8 ID of 5' with a 5' extension Drive Bushing, Bumper sub, Oil Jar, (4)4-3/4, Drill collars BHA P/U/W=7K D/N/W=6K. TIH w/BHA No 2' on 3-1/2" RTS-8 Work String to 4,750'. Continue to RIH w/Baker fishing box tap BHA f/4750'md to 8852'md. Gain fishing parameters, P/U/W= 75klbs, D/N/W=44klbs, ROT TQ= 1.9K'-lbs, ROT DWN WT=42klbs. Set TQ trip max to 3k'-lbs. Set down and tag fish @ 8,852'. P/U lightly rotate and set down WT on fish in 1K increments. P/U and repeat until over pull is seen. 5-10klbs over pull seen, but unable to pull more than 6'. before losing fish. Attempt to rotate through obstruction, no success. Having issue w/power swivel TQ settings. Trips not working. Erratic TQ control when trying to TQ up on fish. Contact Prostar for assistance.Trouble shoot and find failing proxy switch. Change out and try swivel. Controls performing smoother. Continue to try and recover fish f/8 852'. Fish moved down hole, tag depth now at 8,854'md from working fish. TQ up on fish and attempt to work TQ down work string several times w/ no success. Call Engineer and discuss plan forward . Start POOH while discussing plan forward. Pull 15 jnts. Stop pulling pipe. Circulate down TBG to ensure no fish has been engaged. Pump pressures equal to pre-fishing pump pressures. Close pipe rams and perform injectivity test to ensure no damage to 2-7/8"TBG stump. Circulate @ 0.5BPM = 70psi, 1.0BPM = 75psi, 1.5BPM = 110psi. For 5bbls total injection. Good indication no flow obstruction down hole. RIH back to 8,852'. w/Baker fishing box tap BHA and prepare for pumping scale inhibition treatment. 5/1/2017- Monday Rig Service Check Fluids and Grease. Wait on the Arrival of Peak VacTruck Bring out 65 bbl. 80 degrees 8.5 ppg Sea Water to Location to mix w/7-Drums Scale Inhibitor(SCW4004). Mix and Bull Head D/Tubing 2-Drums Pre - Flush Added w/33 bbl. of 8.5 ppg Sea Water Total 35BBL. Pumped, (7.5% mutual solvent WAW5206) Peak Vac Truck Mix and Pumped 7-Drums Scale inhibitor Mixed w/65 bbl. of 8.5 ppg Sea Water Total 73 BBL. Pumped, 12.5%Scale inhibitor(SCW4004) Displaced with 145bb1. 8.5 ppg Sea Water, Pump Rate of 2.0 Bpm @ 335psi Bleed Pressure off, Check for flow, Open pipe Rams, B/N all Lines. Trip out of the hole off Bottom L/D 3-1/2" RTS-8 Work String on Pipe Racks f/8,852'. to BHA @ 151'.. R/U to L/D BHA. L/D 4,4-3/4" drill collars, P/U to L/D oil jars, bumper sub, drive bushing, and box tap assembly in one component. Fish found engagedin box tap. Set BHA in Baker Centrilift ESP stump, unscrew parted gas separator from upper seal assembly ' and L/D remainingfishingBHA w/ handling equipment / i k„. and / gas separator still engaged in box tap. M/U Centrilift a ui ment and L D e' remaining ESP fish. 20' of Tec wire remaining in hole. Remove Flex 17.5 Centrilift ESP assembly and load Flex 47 assembly. Roads and Pads on location to pull spooling unit out and load new ESP cable in spooling unit. Run ESP cable and capillary line to rig floor from spooling unit. P/U and M/U Baker Centrilift ESP assembly. Service upper and lower seal assembly. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-04 ASR1 50-029-21977-00-00 190-005 4/25/17 5/3/17 Daily Operations: F- 5/2/2017-Tuesday Rig Service Check Fluids and Grease. Service lower and Upper Seal Assembly,.TIH 2-7/8"Tubing and New ESP Pump Assembly, Check Cable at 2,000'.,. Well Kill on E-22 with LRS Bleed Gas off well Tubing and IA to Flow Back Tank, Pumped 300 bbl. down the Tubing with a Drum -Bara clean, with no Returns to the Flow tank, Pump Rate 4.5 Bpm at 900psi, Pumped down the IA Total bbl. Pumped 300bbl. at 5 Bpm with apsi=0 Well is Dead, Pumped 60/40 15 bbl. Down IA 5bbl. Down Tubing.TIH 2-7/8"Tubing and New ESP Pump Assembly, Check Cable at 4,000'. R/U Circulation Nipple and Hose Fill Tubing Pump 2 bbl. Flush ESP Pump.TIH 2-7/8"Tubing and New ESP Pump Assembly, Check Cable at 6,400'. Capillary tube pressuring up higher than desired when testing. Inspect surface spooling equipment for any potential blockage. Centrilift hand swap pump for back up and attempt to pressure up again. Still not bleeding off. Call Ops engineer and discuss plan forward. Baker Centrilift hand bleed off reel pressure and perform cap tube splice on rig floor to isolate down hole cap tubing from cap spool. Pressure up and test. Pressure bleeding off at higher than usual (3800psi). Splice capillary tube back together on rig floor and continue to RIH w/ ESP completion on 2-7/8" 6.5# EUE TBG to "7,900'md. Baker Centrilift perform reel to reel cable splice. SIMOPS: Roads and Pads on location w/crane and winch truck to set secondary well house on E- 22, remove tree from E-22, and set back up BOP stack on wellhead. Wellhead hands Greg Ruge and John Morrow on location to bleed the void on the production tree,function LDS, and inspect TBG hanger threads. Continue to RIH w/ESP completion on 2-7/8" 6.5# EUE TBG f/—7,900'md to 8,738'md. P/U and M/U TBG hanger. Wellhead hands Greg Ruge and John Morrow on location to line up TBG hanger and prep hanger f/ landing. Baker Centrilift perform penetrator splice on ESP cable. SIMOPS: Continue to prep well E-22 for up coming rig move. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-04 ASR1 50-029-21977-00-00 190-005 4/25/17 5/3/17 Daily Operations: 5/3/2017 -Wednesday Baker Centrilift perform penetrator splice on ESP cable. SIMOPS: Continue to prep well E-22 for up coming rig move. Land Hanger Well Head Rep Verify Hanger is Landed RILDS, B/O L/JT and lay down (272 Joints Ran) New ESP Pump Depth at 8,761 w/ASR RKB of 19' P/U/W= 67K D/N/W=32K Well Head Rep Greg Ruge and John Morrow, Installed BPV in Tubing Hanger, ASRC Vac Truck Removed 160 bbl. Sea Water From Pits Hauled to B-50 Injection ( Release Rig at 0800 hrs. 5-3-17) Bleed Down Accumulator System, Disconnect Accumulator Lines to Bop Stack, Blow Down and Disconnect all Service Lines, Rig Down Certex Heater System Trailer, Hilcorp Electricians Disconnected Fire and Gas Alarms in Cellar. Rig Floor and Pit Module ( NES Trucks Arrived on Location at 10 00 AM) Remove Pins From Top Section Break and Lay Over Derrick onto Carrier, Load Parts Connex and Drive Rig Carriage off Mud Boat, Load and Haul Rig Equipment to MPE-22, Move Pit Module,Tool Pusher to E-22 ASRC Crane on Location Remove Rig Floor, N/D Bop Stack Load on Flat Bed Truck, Remove Well House, N/U Production Tree,Well Head Rep Greg Ruge Test Hanger Void 5,000 psi Test,Tee Bar Test Hanger Void 5,000 psi Centrilift Conduct Final Check ( Good Test) Well Head Rep Tee Bar Removed BPV Valve. 5/4/2017 -Thursday No activity to report. 5/5/2017- Friday No activity to report. 5/6/2017-Saturday No activity to report. 5/7/2017 -Sunday No activity to report. 5/8/2017- Monday No activity to report. 5/9/2017-Tuesday No activity to report. • • • OF 001.' T, 001.'Iyy�4. THE STATE Alaska Oil and Gas ti -s ofLASI�:A Conservation Commission A 333 West Seventh Avenue 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALASW*. Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC ��v ,P R 0 32017 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU E-04 Permit to Drill Number: 190-005 Sundry Number: 317-065 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, P7R2Z-eftz Cat y P oerster Chair DATED this Ay of February, 2017. RBDMS L\, FEB 1 6 2017 0 • RECEIVED STATE OF ALASKA FEB 0 6 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRYSUNDRY APPA8Gdois J '7 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 ' CT FCO❑ Suspend ❑ Perforate p Other Stimulate ❑ Pull Tubing 0 • Change Approved Program 0 Plug for Redrill El Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Changeout0 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q. 190-005 • 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-21997-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.432D ' 1‘ Will planned perforations require a spacing exception? Yes ❑ No ❑ / MILNE PT UNIT X E-04 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL028231 ' MILNE POINT/KUPARUK RIVER OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,900' ` 7,616' •, 9,789', • 7,533' 2,332 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 114' 13-3/8" 115' 115' N/A N/A Surface 5,741' 9-5/8" 5,741' 4,579' 3,520psi 2,020psi Production 9,880' 7" 9,880' 7,633' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic • See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8,808 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Otis HCM PERMA-PKR and N/A k 8,945'(MD)&6,913'(TVD)and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic 0 Development Q ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 2/17/2017 Commencing Operations: OIL 0 • WINJ ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG Cl Commission Representative: N/A WTRSP ❑ 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 5,r7 Email sporholarhilcorp.com Printed Name Bo York Title Operations Manager Signature Phone 777-8345 Date 2/6/2017 _ , COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry I Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ 2 +t S 1 11 Other: r� "'�— )_ 2_ Soo flS 0C)r` �i,,5_(-_ Post Initial Injection MIT Req'd? Yes 0 No ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /O "41 04/ RBDMS 0/ FEB 1 6 2017 APPROVED BY Approved by: t1 COMMISSIONER THE COMMISSION Date:2—/s . Submit Form and Form 10-403 Revised 11/2015 ii/vGpirNioAsEid for 12 mo the from the date of proval. Attachments in Duplicate 0 ;% 7 • Well Prognosis Well: MPU E-04 Hilcorp Alaska,Lb Date:2/03/2017 Well Name: MPU E-04 API Number: 50-029-21997-00 Current Status: Oil Well [Failed ESP] Pad: E-Pad Estimated Start Date: February 17th, 2017 Rig: Doyon 14 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190-005 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: TypC ESnpair Current Bottom Hole Pressure: 2,500 psi @ 7,000' TVD (SBHPS 2/02/2017/6.87 ppg EMW) Maximum Expected BHP: 2,500 psi @ 7,000' TVD (No new perfs being added) J MPSP: 1,800 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU E-04 was drilled in 1990 using Nabors 27E and completed in the Kuparuk sands with a gaslift completion.The well was converted to ESP in 1995 using Nabors 4ES.The well has had multiple ESP changeouts since 1995, (1997, 1997, 2000, 2001, 2005, 2008, 2012 and the most recent was an ESP changeout in 2014 using Doyon #16 to run a new ESP). This well has had tendency for scaling. A MTT(Magnetic Thickness Tool) was run in July 2012 during the RWO, and no shallow subsidence issues were seen. CcaET'o55; '^'", Notes Regarding Wellbore Condition t;(� • Casing last tested to 3,000 psi for 30 min down to 8,850'on 7/14/2012. ✓'' • Max angle 45.7° @ 6,400'. • Deviation at perfs is 41.0°. • Min ID is 2.25"thru XN profile above ESP. Min ID is 2.313" above and below packer. • Last Fill Depth: 8,905' MD tagged tubing stub on 5/12/1997. • CO 390A: Hilcorp Alaska respectfully requests that a packer not be required on this ESP completion as the reservoir pressure is less than 8.55 ppg EMW. Objective: f, L 7-17 The purpose of this work is to pull the failed ESP, spot a scale inhibitor squeeze and run a new ESP. Brief RWO Procedure: 1. MIRU Doyon 14, ancillary equipment and lines to 500 bbl returns tank. 2. 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. 3. ND Tree. NU BOPE. 4. Test BOPE to 250 psi Low/2,5Q 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. Perform Test per Doyon 14 BOP Test Procedure. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. 11 i r Well Prognosis Well: MPU E-04 iukura Alaska,Lia Date:2/03/2017 d. Test VBR ram on 2-7/8" and 3-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 5. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. 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 re, the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking /re) 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. 6. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg seawater as needed. 7. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2014 ESP swap was 115K lbs(block weight of 40k) b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 8. 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. /9. POOH and lay down the 2-7/8" tubing. Number all joints. Tubing will be re-used based on tubing caliper results and visual inspection of the connections. Lay down failed ESP. a. Replace bad joints of tubing as necessary and note on tally any new tubing run. b. Note any sand or scale inside or on the outside of the ESP on the morning report. c. Look for over-torqued connections from previous tubing runs. 10. RIH with 7" 26#scraper assembly to^'8,905' MD (top of tubing stub)on 3-1/2"workstring. PU to "8,900' MD. Circulate the well clean with 8.5 ppg seawater. 11. Mix and pump 35.0 bbl of pre-flush (7.5%mutual solvent WAW5206), 73.0 bbl of squeeze pill G �f (12.5%scale inhibitor SCW4004), 155 bbl of displacement 8.5 ), p ppg seawater. [Scale Inhibitor St z . Treatment]. 12. POOH and LD 3-1/2" workstring and scraper assembly. 13. PU new ESP and RIH on 2-7/8"tubing. Set base of ESP at±8,750' MD. a. Upper GLM @ ± 135' MD w/SO b. Lower GLM @ ±8,500' MD w/ DGLV c. 2-7/8" XN (2.25" No-Go) @ ±8,650' MD d. Base of ESP centralizer @ ±8,750' MD • • Well Prognosis Well: MPU E-04 Ililcorp Alaska,LLI Date:2/03/2017 e. Install 3/8" external capillary string connected to centralizer. 14. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 15. Set BPV. ND BOPE. NU existing 2-9/16" 5,000#tree/adapter flange and test to 500/5,000 psi. 16. RDMO Doyon 14. 17. Replace gauge(s) if removed. 18. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Blank RWO MOC Form H . Milne Point Unit • Well: MPE-04 SCHEMATIC Last Completed: 5/17/2014 Mean)Alaska,LLC, PTD: 190-005 TREE&WELLHEAD Orig.KB Elev.:58.00'/GL Elev.:34.0' Tree 2-9/16"-5M Cameron WKM RKB-THF:23.75'(Doyon 16 Wellhead 11"x 11""5M Cameron WKM TDF,w/11"x 2-7/8"TDF- 0 CS-1 Hanger 2-7/8"EU 8rd lift threads,2.5"CIW H BPV > > OPEN HOLE/CEMENT DETAIL 13-3/8' . 13-3/8" Cmt w/500 sks of PF"C"in 30"Hole 9-5/8" Cmt w/406 bbl PF"E",70 bbl Class"G"in 12-1/4"Hole Arctic Pack 0' 7" Cmt w/125 bbl Class"G"in 8-1/2"Hole CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF :, 13-3/8" Conductor 48/H-40/N/A N/A Surface 114' 0.1571 la }5/g-� 0. ` 9-5/8" Surface 36/J-55/BTC 8.765 Surface 5,741' 0.0773 7" Production 26/L-80/BTC 6.151 Surface 9,880' 0.0383 9-5/8"Hall Multi Stage TUBING DETAIL Est.TOG @ 7,500' Cementer @ 1,955' 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surface 8,808' 0.00579 2 WELL INCLINATION DETAIL i' KOP @ 600' Max Hole Angle=45.7 deg. f/6,400' MIN ID 2.250 v" Hole Angle through perforations=41 deg. @ 8,693' 9 ii Max DLS=6.36°/100'@ 1,550' 000 3 w JEWELRY DETAIL 4 ro 4 No Depth Item " 1 139' STA#2:Camco 2-7/8"x 1"Sidepocket KBMM GLM w/DGLV 1-17-17 5 2 8,550' STA#1:Camco 2-7/8"x 1"Sidepocket KBMM GLM w/Open Pocket 1-17-17 6 3 8,693' XN-Nipple: w/2.313" landing Profile(2.250 No-go ID) ° 4 8,740' Welllift Discharge Gauge(Pump spline clean tag 2-02-17) III kol7 5 8,744' Discharge Head:GPDIS i At P 6 8,745' Pump:SXD Armor X 119-P23 r 8&9 7 8,762' Gas Separator:GSTHVER M FER ' 8 8,768' Upper Seal Section:GSB3DBUT SB/SB PFSA CL6 31 aik 4i 9 8,775' Lower Seal Section:GSB3DBLT SB/SB PFSA CL6 4,410 10 8,782' Motor-MSP1-250:294HP,2,315 volt&77 amps 11 8,804' WeIllift MGU sensor 11 12 8,806' Centralizer/Bottom @ 8,808' • 12 13 8,905' 2-7/8"Chemical Cut Tubing 14 8,930' Baker SBR Seal w/Otis 2.313"X Profile w, 15 8,945' Otis 7""HCM"PERMA-PACKER w/Millout Extension(2.635"ID) MIN ID=2.313 1p a, 13 16 8,992' Otis 2.313"X Profile @ 8,930 14 17 9,010' Schlumberger Gun Release r r r x 18 9,657' Fish:Top of Schlumberger Gun Assembly 15 4 MIN ID=2.313 .', IPERFORATION DETAIL @8'992' ae " 16 k Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status IL'r 17 Kup.C Sands 9,048' 9,090' 6,990' 7,021' 42 5/12/1990 Open 4x y Kup.B Sands 9,116' 9,150' 7,041' 7,066' 34 5/12/1990 Open 3l KUP C Sands . J GENERAL WELL INFO LO E. V}KUP B Sands API:50-029-21997-00-00 Drilled and Cased by Nabors 27E-1/26/1990 1 i4 Completed with Gaslift by EWS#4-5/14/1990 r Convert to ESP by Nabors 4ES-1/10/1995 lT; ° 18 ESP Repair by Nabors 4E5-5/12/1997 lc ESP Repair by Nabors 55-10/17/1997 7''' `t+7 . 44. ESP Repair by Nabors 4ES-1/18/2000 TD=9,900'(MD)/TD=7,616'(TVD) ESP Repair by Nabors 4ES-12/11/2001 PBTD=9,789'(MD)/PBTD=7,533'(TVD) ESP Repair by Nabors 4ES-9/12/2005 ESP Repair by Nabors 4ES-2/22/2008 ESP Repair by Doyon 16-7/14/2012 ESP Repair by Doyon 16-5/17/2014 Revised By:STP 2/03/2017 • 40 Milnll:e PointMPE-04 Unit We PROPOSED Last Completed: Proposed Hilcora Alaska,LLC PTD: 190-005 TREE&WELLHEAD Orig.KB Elev.:58.00'/GL Elev.:34.0' Tree 2-9/16"-5M Cameron WKM RKB-THF:23.75'(Doyon 16 Wellhead 11"x 11""5M Cameron WKM TDF,w/11"x 2-7/8"TDF- ,., 1 Hanger 2-7/8"EU 8rd lift threads,2.5"CIW H BPV S0 Let OPEN HOLE/CEMENT DETAIL 13-3/8 , " 13-3/8" Cmt w/500 sks of PF"C"in 30"Hole • 9-5/8" Cmt w/406 bbl PF"E",70 bbl Class"G"in 12-1/4"Hole Arctic Pack A' 7" Cmt w/125 bbl Class"G"in 8-1/2"Hole CASING DETAIL r; Size Type Wt/Grade/Conn Drift ID Top Btm BPF .:,40,�. g` 13-3/8" Conductor 48/H-40/N/A N/A Surface 114' 0.1571 9-5/8" ,7 9-5/8" Surface 36/J-55/BTC 8.765 Surface 5,741' 0.0773 7" Production 26/L-80/BTC 6.151 Surface 9,880' 0.0383 9-5/8"Hall Multi Stage Est.TOC @7,500' Cementer@1,955' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surface 8,750' 0.00579 0 2 38"SSCapstnng WELL INCLINATION DETAIL KOP@600' Max Hole Angle=45.7 deg. f/6,400' MIN ID=2.250 Hole Angle through perforations=41 deg. @8,650' A c Max DLS=6.36°/100'@ 1,550' a awl 3 JEWELRY DETAIL 14 LI 4 No Depth Item 5 1 ±135' STA#2:Camco 2-7/8"x 1"Sidepocket KBMM GLM w/SOV Dummy 2 ±8,500' STA#1:Camco 2-7/8"x 1"Sidepocket KBMM GLM w/Dummy 6 3 ±8,650' XN-Nipple: w/2.313" landing Profile(2.250 No-go ID) 4 ±8,690' Welllift Discharge Gauge IIID 5 ±8,694' Discharge Head:GPDIS 6 ±8,695' Pump:SXD 119-P18 8&9 7 ±8,710' Gas Separator:GSTHVER M FER 8 ±8,715' Upper Seal Section:GSB3DBUT SB/SB PFSA CL6 9 ±8,725' Lower Seal Section:GSB3DBLT SB/SB PFSA CL6 114 110 10 ±8,730' Motor-MSP1-250:294HP,2,315 volt&77 amps 11 ±8,745' Welllift MGU sensor r11 i 12 ±8,748' Centralizer/Bottom @ 8,750' 12813 13 ±8,750' 3/8"External Capillary String w/Check Valve ir 14 8,905' 2-7/8"Chemical Cut Tubing 15 8,930' Baker SBR Seal w/Otis 2.313"X Profile MIN ID=2.3131 ' 14 16 8,945' Otis 7""HCM"PERMA-PACKER w/Millout Extension(2.635"ID) @ 8,930' �'. 15 17 8,992' Otis 2.313"X Profile 18 9,010' Schlumberger Gun Release x '.; 16 19 9,657' Fish:Top of Schlumberger Gun Assembly If MIN ID=2.313 ( PERFORATION DETAIL @8,992 " 17 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status +1 18 Kup.C Sands 9,048' 9,090' 6,990' 7,021' 42 5/12/1990 Open Kup.B Sands 9,116' 9,150' 7,041' 7,066' 34 5/12/1990 Open i.}KLA'C Sands -,, GENERAL WELL INFO }KUP B Sands API:50-029-21997-00-00 �r Drilled and Cased by Nabors 27E-1/26/1990 h Completed with Gaslift by EWS#4-5/14/1990 ', Convert to ESP by Nabors 4ES-1/10/1995 19 ESP Repair by Nabors 4ES-5/12/1997 ESP Repair by Nabors 5S-10/17/1997 7"' ``Z;;? ESP Repair by Nabors 4ES-1/18/2000 TD=9,900'(MD)/TD=7,616'(TVD) ESP Repair by Nabors 4ES-12/11/2001 PBTD=9,789'(MD)/PBTD=7,533'(1VD) ESP Repair by Nabors 4ES-9/12/2005 ESP Repair by Nabors 4ES-2/22/2008 ESP Repair by Doyon 16-7/14/2012 ESP Repair by Doyon 16-5/17/2014 Revised By:STP 1/31/2017 • • 1/04/16 • DOYON 14 BOP'S DRILLING 19-5/8 5000 PSI RIG FLOOR n n n n n / )a-. HYDRIL 13-5/8" ANNULAR \ t / "GE" 5000 PSI +� p 7• O STUD z FLANGE v •HYD'RI'C51 m \ / Ii gaiinIGuunniii HYDRIL MPL DOUBLE GATE ' 1 � o • :i O 13-5/8" 5000 PSI _ tel„—,:. 0 44111i. •: r- STUD z STUD BX-180 C *-.� m�i to M 10" OPERATORS ). � ii O M PIPE RAMS ' � ■i ' O 6 cv I: ,Imr..11 --- ay- ii d' .i 10" OPERATORS ! ! 'd' BLIND RAMS \� a lL .. /� a 3-1/8" 6000 PSI MANUAL VALVE ` ! � -- E El _ ... � _ 9-1/8" 5000 PSI HCR VALVE -\\ ___ _ - -- --- i ! ! in urunnnn - - C\t -- _ --- �iGuunuiuuuiuuu� --� -- cv— MUD CROSS / - - 13-5/B" 5000 PSI FLANGE x FLANGE BX-160 nn.n.ruIurunuum WITH ISA. 3-1/8" do 4-1/18"OUTLSTS -- — ' '—' • ii HYDRIC MPL SINGLE GATE � � .� :i 13-5/8" 5000 PSI iü /� _ FLANGE z FLANGE BX-180 (X !l* i X10 c‘t SO" OPERATORS (�- G, co i c7 PIPE RAMS .� • �i MEi iii •--i... _ i i.uuin ail unniiuii TUBING SPOOL -I I- um■un ui urun■uu1 �I, ��- r GROUND LEVEL t ) H . • EXISTING TREE/WELLHEAD MPU E-04 Wellhead/Tree Milne Point Unit llilcorp Alaska,LLC Tree Cap ill Ina 1a. Tree Valve 2-9/16" 5M `" I#tONO Isa Tree Cross 2-9/16" 5M ________ 18 , e Tree Valve 2-9/16" 5M - SSV 2-9/16" 5M C� 7 I I 000 Tree Valve 2-9/16" 5M r o� 0E() ....,�.,.a ESP Cable "' '.' Tubing Adapter , _ Tubing Head InclIII 11" 5MTop x11" 5MBtm �� mill1 $11111 :ill" 411) i ' II Mir Casing Head -alit ._ 11" 5M Top x 11" 5M Btm >, !IIi rui1 i 0 _ CD4- > c pct _ 0• 0) C �° _ o2 o2E 0 ) OQ, y .0_0 a) aaa E rn o +, "CI 0 � d R -0 E Y > w 3 Q I Q.v C a) Q m = O N 15 N d 0• .2 CU • 3 i C N dEs o & I o 0 N C a) c0 Cr)_C C 0 (0 N t L U O � L 0 0 TO 4 _0 o O d• a) n o > cv w o mc a) Q C k a. as L co 2 o_ 3 s m -aaa 0 i5 0 .0 112 0 TS a`i Q zu o a) O a 0 D. • -c ca L m a � ca ccm II T0 0 L o ° N N cap ° aaQ V .- Q tO ° cco o 0 Ct ct 0 3 Q cc d H ea a a) u) ._ — U L `� cc c• a) a) 0 Cl) a y1 0 Li 0 CO RI a Lt c. E oU a) ^" 0 C.) ft > = UI t3 m a y Q a` Pages NOT Scanned in this Well History File XHVZE 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. I q ~'"' OC/~ 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/'rype OVERSIZED Logs of various kinds Complete [] Other COMMENTS: Scanned by: (~ev~edy~Bren Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd , STATE OF ALASKA • AOKA OIL AND GAS CONSERVATION COOISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS AUG 0 3 2012 1. Operations Performed: AOGCC ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver 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. ® Development ❑ Exploratory - 190 - 005 ' 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: - P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 21997 - 00 - 00 ' 7. Property Designation (Lease Number): , 8. Well Name and Number: ADL 028231 MPE - . . 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 9900 feet Plugs (measured) None feet true vertical 7649 feet Junk (measured) 9657' feet Effective depth: measured 9789 feet Packer: (measured) 8945' feet true vertical 7562 feet Packer: (true vertical) 6913' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13 -3/8" 80' 80' 1670 670 Surface 5741' 9 -5/8" 5741' 4579' 3520 2020 Intermediate Production 9880' 7" 9880' 7633' 7240 5410 Liner 2 I 201 Perforation Depth: Measured Depth: 9050' - 9152' True Vertical Depth: 6992' - 7069' Tubing (size, grade, measured and true vertical depth): 2 6.5# L 8801' 6805' 2 - 7/8" L - 80 8905' - 9010' 6883' - 6962' Packers and SSSV (type, measured and true vertical depth): 7" Otis 'HCM' Perma Packer with millout 8945' 6913' extension 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 49 4 941 220 180 Subsequent to operation: 34 3 395 200 213 14. Attachments ❑Copies of Logs and Surveys run 15. Well Class after work: ., ❑ Exploratory Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 16. Well Status after work: ••• ® Oil ' ❑ Gas ❑ WDSPL ❑ 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 Jesse Rosenbaum, 564 -5155 N/A Printed N Jo La ca Title Drilling Technologist Signature Phone 56 - 4091 Date %/ ! i� Prepared By Name /Number: � g Joe Lastufka, 564 -4091 \ Form 10-404 Revised 11/2011 BDMS AUG 06 2Q12 49p' - )-) /� y 7 /Zo/ e Su bmit Original Only ' �' �' // OJ cam- �l%L • $ �� ,7 ; , 'es erica ALfi a 0 aration Summary Common Well Name: MPE -04 AFE No Event Type: WORKOVER (WO) Start Date: 7/5/2012 End Date: X4- 00VJW -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time. 1/7/1990 12:00:00AM Rig Release: 7/14/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'19.307 "7 Long: 0149°26'08.526'W Active Datum: ORIG KELLY BUSHING @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/6/2012 19:00 20:30 1.50 RIGD P ■- PRE OUTSIDE EQUIPMENT. - MOVE CUTTINGS NGS BOX, , CREW TRAILER AND EQUIPMENT. 20:30 - 22:30 2.00 RIGD P PRE PJSM FOR PULLING OFF WELL. REVIEW DDI SOP. - NOTIFY DSO TO WITNESS PULLING OFF WELL. - JACK UP RIG, REMOVE SHIMS. WITH WSL, DSO AND TOOLPUSHER PRESENT. - PULL RIG OFF WELL. - MANIPULATE MATS UNDER RIG TO TURN. - MOVE RIG TO CENTER OF PAD. SET. RIG DOWN. 22:30 - 00:00 1.50 RIGD P PRE PJSM. INSTALL CRADLE TO REMOVE BOP STACK._ REMOVE STACK. - PREP AND L/D DERRICK . 7/7/2012 00:00 - 04:30 4.50 MOB P PRE PJSM. SECURE DERRICK. - INSTALL FRONT AND REAR BOOSTERS. LOAD OUT TRAILERS. „ T PREP FOR RIG MOVE. - STAGE SIGN IN TRAILER AT MPL -PAD. - CLOSE WELL TRANSFER PERMIT WITH DSO FOR MPF -37. - NOTIFY MPU SECURITY OF MOVE. 04:30 - 12:00 7.50 MOB"__ P PRE PJSM FOR RIG MOVE, REVIEW DDI SOP. - MOVE RIG TO PAD ENTRANCE. - LEAP FROG ON RIG MATS FROM F -L PAD. - SITE CONTROL BLOCKING ENTRANCE TO F -PAD ACCESS RD. 12:00 22:30 10.50 MOB PRE CREW CHANGE. MAKE RIG CHECKS. - CONTINUE TO MOVE FROM F TO L PAD - LEAP FROG ON RIG MATS TO L -PAD - SITE CONTROL BLOCKING ENTRANCE TO F -PAD ACCESS RD. 22:30 - 00:00 1.50 MOB P PRE PARK RIG ON MPL -PAD. - WAIT ON RIG MATS. - WELL SUPPORT LOAD AND STAGE RIG MATS ON MPL -PAD ACCESS ROAD. - PERFORM DDI WORK ORDERS. 7/8/2012 00:00 - 07:30 7.50 MOB P PRE RIG PARKED ON MPL -PAD. - WAIT ON RIG MATS. - WELL SUPPORT LOAD AND STAGE RIG MATS ON MPL -PAD ACCESS ROAD. - PERFORM DDI WORK ORDERS. 07:30 - 11:00 3.50 MOB P -_ PRE RIG MOVING ON L & F PAD ACCESS ROAD. - ROAD IS PARTIALLY MATTED 11:00 14:00 3.00 MOB P ■- PRE FROM L & F PAD TURN OFF TO THE MPU THE MPU Y. - WAITING FOR GRAVEL REMOVAL 14:00 17 :00 3.00 MOB P ■- PRE CONT WAITING FOR ACCESS INTO E -PAD - ON E -PAD , PREPING RIG FOR SPOTTING OVER WELL. 17:00 - 18:00 1.00 MOB P PRE MOVE RIG IN FRONT OF E -04 Printed 7/30/2012 10:24:21AM Common Well Name: MPE -04 AFE No Event Type: WORKOVER (WO) Start Date: 7/5/2012 End Date: X4- 00VJW -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/7/1990 12:00:00AM Rig Release: 7/14/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'19.307 "7 Long: 0149 °26'08.526 "W Active Datum: ORIG KELLY BUSHING @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 20:00 2.00 MOB P PRE RIG UP OPERATIONS. - MOVE EQUIPMENT FROM MPF -PAD TO MPE - PAD. - PJSM, RAISE DERRICK AND PIN. - R/D BRIDAL LINE. 20:00 - 23:00 3.00 MOB P PRE PJSM, REMOVE FRONT BOOSTERS. SET BOP ON PEDESTAL IN CELLAR. - REMOVE FRONT BOOSTER AND CAGE. 23:00 - 00:00 1.00 MOB P PRE R/U RIG FLOOR. HANG BRIDAL LINES. - CONTINUE WORK ON MUD PUMP. - LAY HERCULITE AROUND WELL - SPOT MATS AROUND WELL. 7/9/2012 00:00 - 00:30 0.50 MOB P PRE FINISH SETTING RIG MATS AROUND MPE -04. - SET KILL MANIFOLD AND NEW TREE IN CELLAR AREA. 00:30 - 01:30 1.00 MOB P PRE PJSM FOR BACKING RIG OVER WELL. - WITH WSL, TOOLPUSHER AND CREW. - NOTIFY DSO. - VERIFY TREE IS SHUT IN. - ALIGN RIG AND SPOT OVER WELL. - SHIM AND SET DOWN RIG. DSO WITNESSED BACKING OVER WELL. _- I /A= 775 PSI. O /A= 45 PSI. 01:30 - 02:30 1.00 RIGU P PRE SET RIG EQUIPMENT, MOVE CUTTINGS BOX TO E -PAD. - SET IN PLACE. - HARDLINE CREW ON LOCATION. - RIG ACCEPTED ON MPE -04 AT 02:30 HRS 02:30 - 06:00 3.50 RIGU P PRE SPOT TIGER TANK ON DS OF RIG 150' FROM CELLAR. - M/U KILL MANIFLD IN CELLAR. - FILL PITS WITH 120 DEG 8.8 PPG BRINE KWF. - R/U AND TEST HIGH LEVEL ALARM ON TIGER TANK. - DSM R/U HARDLINE TO TIGER TANK. - PRESSURE TEST HARDLINE TO 250/3500 PSI. - R/U SSV ACCUATOR ON RIG FLOOR. - CHANGE OUT MUD PUMP # 1 PRV 06:00 - 12:00 6.00 KILLW P DECOMP RU WELL SUPPORT LUBRICATOR AND PRESSURE TEST - 250 PSI LOW AND 3500 PSI HIGH, BOTH 5 MIN CHARTED. BOTH TESTS PASSED - PULL BPV - TBG- 800, IA 820 12:00 - 12:30 0.50 KILLW P DECOMP PJSM W /NEW CREW FOR WELL KILL OPERATIONS. - BP RWO SUPT, WSL, TOOLPUSHER, MUDMAN, TRUCK DRIVERS, SCS AND CREW IN ATTENDANCE. - REVIEW DDI WELL KILL SOP AND WELL PLAN. Printed 7/30/2012 10:24:21AM Common Well Name: MPE -04 AFE No Event Type: WORKOVER (WO) Start Date: 7/5/2012 End Date: X4- 00VJW -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/7/1990 12:00:00AM Rig Release: 7/14/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'19.307 "7 Long: 0149 °26'08.526 "W Active Datum: ORIG KELLY BUSHING @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:30 - 15:30 3.00 KILLW P DECOMP WSL AND TOOLPUSHER VERIFY VALVE ALIGMENT, - BLEED GAS FROM IA TO FLOW BACK TANK FROM 800 PSI TO 0 — 310 PSI. - SITP = 820 PSI SICP = 310 PSI - BRING PUMP UP TO 1000 PSI AND OPEN VALVE# H-4. - PUMP 60 BBLS KWF (8.8 PPG NA/CL) DOWN THE TBG TAKING RETURNS UP THE ANNULUS OUT TO THE TIGER TANK. - ICP = 3 BPM / 800 PSI, W/ 150 PSI MAX DOWN STREAM PRESSURE. - FLUID RETURNS TO SURFACE AFTER 2 BBLS PUMPED. FCP =3 BPM / 400 PSI. - WSL AND TOOLPUSHER VERIFY VALVE ALIGNMENT, - BULL HEAD 25 BBLS KWF DOWN THE TBG AT 3.5 BPM / 880 PSI . - CHECK THE TIGER TANK LEVEL- 60 BBLS, SHUT DOWN TO ALLOW VAC TRUCK TO SUCK OUT THE 60 BBLS. 15:30 - 17:30 2.00 KILLW P DECOMP - WSL AND TOOLPUSHER VERIFY VALVE . ALIGMENT, {:IRCI 11 ATF fOWN THE TRC, lIP THE.IA... THROI IAHT THE MANI JAI CHOKE TO THE, Fl OW RACK TANK. - PUMPED 2 -5 BPM WITH 1500 TO 1800 PSI - CIRCULATE ADDITIONAL 38 BBLS, UNTIL CLEAN SEAWATER RETURNS. - PUMPED TOTAL OF 428 BBLS FOR THE CIRCULATION 17:30 - 19:00 1.50 KILLW - P DECOMP SHUT -IN WELL FOR 30 MINUTES. - BOTH TBG AND IA ON A SLIGHT VACUUM. ,r - WELL IS DEAD. - TOTAL OF 513 BBLS 8.8 PPG KWF PUMPED. - TOTAL LOSS TO FORMATION = 28 BBLS. - 260 BBLS CRUDE / BRINE RECOVERED AND SENT TO GC2 - 205 BBLS LEFT IN THE TIGER TANK. - CLOSE MASTER VALVE. 19:00 - 21:30 2.50 WHSUR P DECOMP PJSM WITH DSM. R/U LUBRICATOR. - PRESSURE TEST LUBRICATOR TO 250/3500 PSI 5 MIN EACH CHARTED. - INSTALL TWC. - ATTEMPT TO PERFORM 10 MINUTE ROLLING PRESSURE TEST UNDER TWC. - PUMP 4.5 BPM 350 PSI. COULD NOT ACHIEVE 500 PSI. - TEST ABOVE TWC 250/3500 PSI 5 MIN EACH. CHARTED. 21:30 - 22:00 0.50 WHSUR P DECOMP R/D LUBRICATOR AND TEST EQUIPMENT. - EMPTY FLUID OUT OF TREE. - INSTALL LIFT CAP. - BLOW DOWN LINES. - R/D KILL MANIFOLD. - R/U TO PUMP DOWN VA WITH CHARGE PUMP AND BYPASS. - USE CONTINUOUS HOLE FILL DOWN VA WITH 8.8 PPG BRINE KWF. - STATIC LOSS RATE 18 BPH. Printed 7/30/2012 10:24:21AM ry� a :a� Common Well Name: MPE -04 AFE No Event Type: WORKOVER (WO) Start Date: 7/5/2012 End Date: X4- 00VJW -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/7/1990 12:00:00AM Rig Release: 7/14/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'19.307 "7 Long: 0149 °26'08.526 "W Active Datum: ORIG KELLY BUSHING @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 23:30 1.50 WHSUR P DECOMP PJSM FOR N/D AND N/U. - CAMERON REP BLEED HANGER VOID. - FUNCTION LDS. - MARK FOR WKM TREE AIGNMENT PINS. - N/D TREE AND ADAPTOR FLANGE. - CAMERON INSPECT 2 7/8" 8RD HANGER THREADS, SCREW IN X/O. 23:30 - 00:00 0.50 BOPSUR P DECOMP N/U BOPE. - USE CONTINUOUS HOLE FILL DOWN VA WITH 8.8 PPG BRINE KWF. - STATIC LOSS RATE 18 BPH. - LOSSES TO WELL IN LAST 12 HRS= 185 BBLS. 7/10/2012 00:00 - 02:30 2.50 BOPSUR P DECOMP PJSM WITH ONCOMING CREW. - CONTINUE TO N/U BOPE. - USE CONTINUOUS HOLE FILL DOWN VA WITH 8.8 PPG BRINE KWF. - STATIC LOSS RATE 18 BPH. 02:30 - 03:30 1.00 BOPSUR P DECOMP PJSM. REVIEW DDI SOP. - R/U TO TEST BOPE. 03:30 - 08:30 5.00 BOPSUR P DECOMP TFST ROPF AS PFR AOGCC AND BP _ REQUIREMENTS. TEST WITNESS WAIVED BY AOGCC JEFF JONES. - TEST RAMS AND VALVES @ 250 / 3500 PSI 5 MIN EACH. - USE CONTINUOUS HOLE FILL DOWN VA WITH 8.8 PPG BRINE KWF. - STATIC LOSS RATE 18 BPH. 08:30 - 12:00 3.50 BOPSUR P DECOMP RD TESTING EQUIPMENT - CLEAN & CLEAR RIG FLOOR - PU / MU OPSO LOPSO & C/O LOWER CROSS OVER TO THE PORTED 4 -1/2" IBT BY 2 -7/8" EUE - PU WELLS SUPPORT LUBRICATOR. - MU OPSO LOPSO INTO TOP OF HANGER, MAKE UP LUBRICATOR. - PRESSURE TEST THE OPSO AND LUBRICATOR, 250 PSI LOW AND 3500 PSI HIGH, 5 MIN CHARTED. BOTH TEST GOOD - MAINTAIN CONTINUOUS HOLE FILL @ 20 BPH 12:00 - 13:00 1.00 BOPSUR P DECOMP MPU WELLS SUPPORT TO LUBRICATE OUT THE 2" H PLUG TWC - RD LUBRICATOR AND OPSO. 13:00 - 14:30 1.50 BOPSUR P DECOMP PU LANDING JOINT TO RIG FLOOR - RU BAILS & ELEVATORS, POWER TONGS AND HANG ESP SHEAVE - MU LANDING JOINT TO HANGER WITH TIW MADE UP ON TOP , CAMERON REP TO BOLDS - SHUT DOWN HOLE FILL Printed 7/30/2012 10:24:21AM 4,4 W 3 ffi Common Well Name: MPE -04 AFE No Event Type: WORKOVER (WO) Start Date: 7/5/2012 End Date: X4- 00VJW -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/7/1990 12:00:00AM Rig Release: 7/14/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'19.307 "7 Long: 0149 °26'08.526'W Active Datum: ORIG KELLY BUSHING @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 - 15:30 1.00 BOPSUR P DECOMP PULL HANGER TO THE FLOOR - BROKE OVER AT 106K - LAY DOWN HANGER AND FIRST FULL JOINT - CUT ESP CABLE ABOVE CLAMP - RIH WITH LANDING JOINT & TIW TO SPACE ACROSS THE BOP. MU HEAD PIN AND FILL THE HOLE WITH 14 BBLS 15:30 - 19:00 3.50 BOPSUR P DECOMP CLOSE THE ANNULAR PREVENTOR AND CIRCULATE BOTTOMS UP THROUGH GAS BUSTER - CIRCULATE AT 2 -3 BPH WITH 320 -560 PSI. FCP = 2 BPM @ 320 PSI - MONITOR WELL 10 MIN = WELL ON VAC - OPEN ANNULAR, MONITOR WELL = WELL ON VAC - TOTAL LOSS DURING CBU = 166 BBLS - STATIC LOSS AFTER CIRCULATION = 60 BPH - MAINTAIN CONSTANT HOLE FEED AT 20 BPH WITH 8.8 PPG KWF 19:00 - 19:30 0.50 PULL P DECOMP RIH FROM 8831' TO 8905' - P/U SINGLES AND TAG TOP OF STUMP AT 8905' Mn - NOTIFY AND RECEIVE AUTHORIZATION TO PROCEED FROM TOWN ENGINEER - WILL NOT MAKE CLEAN OUT RUN - POOH, UD SINGLES, F/ 8905' T/ 8808' 19:30 - 22:00 2.50 PULL P DECOMP PJSM, REVIEW DDI SOP ON PULLING ESP COMPLETION, DISCUSSED DROPPED OBJECTS - POOH WITH 2 7/8 6.5# L -80 8RD ESP COMPLETION STRING - FEED ESP CABLE THROUGH SHEAVE AND ATTACH TO SPOOLING UNIT - POOH F/ 8808' T/ 8700' 22:00 - 22:30 0.50 PULL P DECOMP PJSM CHANGE OUT SPOOL REEL IN SPOOLING UNIT 22:30 - 00:00 1.50 PULL P DECOMP CONTINUE POOH F/ 8700' T/ 5929' - STAND 2 7/8" TUBING IN DERRICK - TOTAL FLUID LOSS = 579 BBLS 7/11/2012 00:00 - 00:30 0.50 PULL P DECOMP PERFORM SPCC CHECKS - SERVICE RIG AND POWER TONGS - DOUBLE CHECK RIG UP ON ESP SHEAVE AND RELATED EQUIPMENT 00:30 - 06:00 5.50 PULL P DECOMP PJSM - POOH WITH 2 7/8 6.5# L -80 8RD ESP r:r1MPl FTION STRING - CHANGE OUT JOINT #'S 94, 97, 99, 107, & 108 AS PER PROGRAM - POOH F/ 5929' T/ LAST STAND BEFORE ESP MOTOR AND PUMP ASSY - MONITOR WELL AND RECORD STATIC LOSS RATE 10 MINUTES Printed 7/30/2012 10:24:21AM Common Well Name: MPE -04 AFE No Event Type: WORKOVER (WO) Start Date: 7/5/2012 End Date: X4- 00VJW -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/7/1990 12:00:00AM Rig Release: 7/14/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'19.307 "7 Long: 0149°2608.526'W Active Datum: ORIG KELLY BUSHING @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 09:30 3.50 PULL P DECOMP LAY DOWN ESP ASSEMBLY - LD PUMP , MOTOR & SEAL ASSEMBLY - OBTAIN STATIC LOSS RATE OF 60 BPH. CLAMPS RECOVERED: - PROTECTOLIZERS = 5 - FLATGUARD = 3 - LASALLE = 144 09:30 - 12:00 2.50 PULL P DECOMP 'CLEAN AND CLEAR THE RIG FLOOR INSTALL WEAR RING ID= 6.4375 INCH - CHANGE OUT TWO BAD JOINTS WITH BAD THREADS # 32 -33 12:00 - 18:00 6.00 PULL P DECOMP PU / MU 7" HES CHAMP PACKER - TIH ON —6800' OF 2 -7/8" TUBING FROM THE DERRICK - CONTINUOUS HOLE FILL OF 20 BPH 18:00 - 21:00 3.00 PULL P DECOMP M/U CROSSOVERS FROM TUBING TO 4" DP - P/U DP 1X1 FROM PIPE SHED RIH F/ 6838' T/ 8850' 21:00 - 21:30 0.50 PULL P DECOMP PJSM ON SETTING PACKER AND TESTING CASING - CIRCULATE AROUND PACKER SET AREA, _GOT RETURNS AT 16 BBLS PUMPED - 5 BPM = 1100 PSI - PUWT = 107K, SOWT = 87K - POSITION AND SET CHAMP PACKER AT 8850' CFNTFR OF Fl FMFNTS - CLOSE PIPE RAMS 21:30 - 22:30 1.00 PULL P DECOMP PERFORM MIT -IA ON 7" 26# CASING TEST CV - TEST CASING TO 3000 PSI, 30 MIN, CHARTED = GOOD TEST - NOTIFIED "WTL" OF GOOD STRAIGHT LINE TEST - RECEIVED AUTHORIZATION TO PROCEED - BLEED PRESSURE OFF, OPEN RAMS - MONITOR WELL F/ 10 MIN 22:30 - 23:00 0.50 PULL P DECOMP RIG DOWN TEST EQUIPMENT - BLOW DOWN ALL LINES 23:00 - 00:00 1.00 PULL P DECOMP PJSM ON LAYING DOWN DRILL PIPE - POOH AND L/D DP 1X1 - F/ 8850 T/ 8447 - MAINTAIN CONSTANT HOLE FEED AT 20 BPH WITH 8.8 PPG KWF - TOTAL 24 HR FLUID LOSS = 490 BBLS 7/12/2012 00:00 - 00:30 0.50 PULL P DECOMP SERVICE RIG - PERFORM SPCC CHECKS 00:30 - 02:00 1.50 PULL P DECOMP PJSM ON LAYING DOWN DRILL PIPE - CONTINUE POOH AND L/D DP 1X1 - F/ 8447 T/ 6838 02:00 - 06:00 4.00 PULL P DECOMP L/D CROSSOVERS FROM DP TO TUBING - POOH AND STAND BACK 2 7/8" 6.5# TUBING - F/ 6838 T/ SURFACE - L/D CHAMP PACKER - CLEAR RIG FLOOR - FILLED THE HOLE AND RE- ESTABLISHED STATIC LOSS RATE 06:00 - 07:30 1.50 BOPSUR P DECOMP INSTALL TEST PLUG - RU DUTCH RISER SYSTEM - SPOT SWS TRUCKS IN PLACE Printed 7/30/2012 10:24:21AM Common Well Name: MPE -04 AFE No Event Type: WORKOVER (WO) Start Date: 7/5/2012 End Date: X4- 00VJW -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/7/1990 12:00:00AM Rig Release: 7/14/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'19.307 "7 Long: 0149 °26'08.526 "W Active Datum: ORIG KELLY BUSHING @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 09:30 2.00 BOPSUR P DECOMP PJSM WITH SWS AND RIG CREW - MADE TOOL INSPECTION & DISCUSSED RU AND POSSIBLE DROPPED OBJECT HAZARDS. - PU & MU SWS LUBRICATOR AND PACK OFF TOOL. 09:30 - 10:30 1.00 BOPSUR P DECOMP PRESSURE TEST DUTCH RISER SYSTEM AND - SWS LUBRICATOR - PT TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN PULL DUTCH RISER AND LUBRICATOR. - PULL & LAY DOWN TEST PLUG - INSTALL WEAR RING WITH 6.4375 ID . - RE- INSTALL DUTCH AND LUBRICATOR & RE -TEST AT THE QUICK TEST SUB. 10:30 - 12:00 1.50 EVAL P DECOMP MU SWS TOOLS - M/U PDS LOGGING TOOLS 12:00 - 18:00 6.00 EVAL N DECOMP PDS LOGGING - RIH WITH MTT LOG TOOL. - LOG 2 PASSES FROM 1100' [V C. - L/D MTT LOG TOOL. M/U PDS CALIPER LOG. - PRESSURE TEST QUICK TEST SUB TO _ o 250/3500 PSI. 5 MIN, GOOD TEST - LOG 1 PASS FROM 1100' WITH PDS CALIPER LOG. - DOWNLOAD DATA. - DATA IS INCONCLUSIVE - USE CONTINUOUS HOLE FILL WITH 8.8 PPG BRINE KWF 20 BPH. 18:00 - 22:00 4.00 EVAL P DECOMP DECIDE TO RE -RUN LOG - RUN MTT LOG F/ SURFACE T/ 1100', 2 PASSES _ - GOOD DATA RECOVERED 22:00 - 00:00 2.00 EVAL P DECOMP RIG DOWN WIRELINE , - R/D LUBRICATOR AND SWS LOGGING TOOLS - CLEAR RIG FLOOR OF SWS EQUIPMENT - R/D SWS UNITS - MAINTAIN CONSTANT HOLE FEED AT 20 BPH WITH 8.8 PPG KWF - TOTAL 24 HR FLUID LOSS = 387 BBLS 7/13/2012 00:00 - 01:00 1.00 RUNCOM P RUNCMP MOBILIZE ESP COMPLETION EQUIPMENT TO RIG FLOOR - SPOT SPOOLING UNIT 01:00 - 02:00 1.00 RUNCOM P RUNCMP PJSM ON RIG UP OF SHEAVE - REVIEW HANGING SHEAVE, DROPPED OBJECT MITIGATION - HANG ESP SHEAVE IN DERRICK AND SECURE - FEED ESP CABLE THROUGH SHEAVE AND TIE OFF ON RIG FLOOR Printed 7/30/2012 10:24:21AM Common Well Name: MPE -04 AFE No Event Type: WORKOVER (WO) Start Date: 7/5/2012 End Date: X4- 00VJW -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/7/1990 12:00:00AM Rig Release: 7/14/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'19.307 "7 Long: 0149°26'08.526'W Active Datum: ORIG KELLY BUSHING @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 06:00 4.00 RUNCOM P RUNCMP PJSM TO M/U MOTOR AND PUMP AND RUN ESP COMPLETION - REVIEW WELL PLAN STEPS AND COMPLETION TALLY - DISCUSS PLAN FOR NON SHEARABLES ACROSS BOP. - M/U KMH 195 HP MOTOR AND MODEL SXD PUMP ASSY PER CENTRILIFT REP - ATTACH ESP CABLE AND TEST SAME - INSTALL 5 PROTECTOLIZER CLAMPS ON PUMP / MOTOR ASSY - INSTALL 3 ARMSTER GUARDS - INSTALL 2 HALF CLAMPS - PERFORM CONDUCTIVITY TEST = GOOD TEST 06:00 - 17:00 11.00 RUNCOM P RUNCMP RtH WITH 80 STANDS — 7525' OF 2 7/8" ESP COMPI FTION AS PER TALLY, - RIH 2.5 - 3 MINUTES PER STAND. - INSTALL CANNON CLAMP ON EVERY COLLAR FOR THE FIRST 9 JTS. - THEN INSTALL CANNON CLAMPS EVERY OTHER JT. - MONITOR UN SPOOLING ESP CABLE. - USE CAUTION SETTING SLIPS- NOT TO DAMAGE ESP CABLE. - CONTINUOUS HOLE FILL WITH 8.8 PPG KWF 20 BPH. - FLUSH TBG AND TEST CONDUCTIVITY ON ESP ELECTRIC CABLE EVERY 2000'. 17:00 - 19:30 2.50 RUNCOM P RUNCMP REEL TO REEL SPLICE - SPLICE MADE AT 80 OF 89 STANDS IN THE HOLE , @8112' - CONTINUOUS HOLE FILL STILL AT 20 BPH 19:30 - 21:30 2.00 RUNCOM P RUNCMP CONTINUE TO RIH F/ 8112' T/ 8775' - FCP, .5 BPM = 230 PSI - M/U HANGER AND LANDING JOINT - ORIENT W/ ALIGNMENT PIN ON WELLHEAD 21:30 - 00:00 2.50 RUNCOM P RUNCMP INSTALL PENETRATOR IN HANGER - TERMINATE ESP CABLE AND TEST FOR CONTINUITY = GOOD TEST - MAINTAIN CONSTANT HOLE FEED AT 20 BPH WITH 8.8 PPG KWF - TOTAL 24 HR FLUID LOSS = 489 BBL 7/14/2012 00:00 - 00:30 0.50 RUNCOM P RUNCMP CONTINUE TERMINATE ESP CABLE - TEST CONDUCTIVITY = GOOD TEST TOTAL CLAMPS USED: - INSTALL 5 PROTECTOLIZER CLAMPS ON PUMP / MOTOR ASSY - INSTALL 3 ARMSTER GUARDS - INSTALL 2 HALF CLAMPS - INSTALL 152 FULL CANNON CLAMPS 00:30 - 01:30 1.00 RUNCOM P RUNCMP LAND HANGER AT 8800.97' - PUWT = 105K, SOWT = 75K, (INCLUDES 40K BLOCK WT) - CAMERON REP VERIFIED CORRECT LINE UP AND RILDS - INSTALLED TWC - R/U TO TEST TWC Printed 7/30/2012 10:24:21AM 9 A 6 Common Well Name: MPE -04 AFE No Event Type: WORKOVER (WO) Start Date: 7/5/2012 End Date: X4 OOVJW -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/7/1990 12:00:00AM Rig Release: 7/14/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °2719.307 "7 Long: 0149 °26'08.526 "W Active Datum: ORIG KELLY BUSHING @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 02:30 1.00 RUNCOM P RUNCMP PERFORM ROLLING TEST ON TWC FRC)M BELOW - 3.5 BPM, ICP = 275 PSI / FCP = 390 PSI, 10 MIN, CHARTED - PUMPED TOTAL OF 79 BBLS AWAY - TEST TWC FROM ABOVE 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED = GOOD TEST 02:30 - 03:30 1.00 RUNCOM P RUNCMP PJSM ON RIG DOWN OF ESP EQUIP - R/D AND SPOOL UP ESP CABLE - R/D SHEAVE FROM DERRICK - CLEAR RIG FLOOR OF ALL ESP EQUIP 03:30 - 05:00 1.50 BOPSUR P RUNCMP PJSM, N/D BOP STACK - BLOW DOWN ALL LINES AND VAC FLUID OUT OF BOP - N/D BOP 05:00 06:00 1.00 WHSUR P RUNCMP N/U CAMERON WKM 11" X 2 9/16" TUBING HEAD ADAPTER & FLANGE - CENTERLIFT PERFORMING FINAL CONDUCTIVITY TESTS AT THE HANGER PENETRATOR - PHASE TO PHASE ALL 3= 4.6 PHASE TO GROUND= 518 MEG. 06:00 - 09:30 3.50 WHSUR P RUNCMP CAMERON TESTING HANGER VOID TO 5000 PSI FOR 5 CHARTED MIN. CALLED THE AOGCC FOR 24 NOTICE OF INITIAL BOPE TEST FOR MPE -19 - CHUCK SCHEVE CALLED BACK AND WAIVED WITNESS TO THE TEST 09:30 - 11:00 1.50 WHSUB P RUNCMP - N/U WKM 2 9/16" 5M TREE 11:00 - 13:00 2.00 WHSUR P RUNCMP FILL TREE WITH DIESEL AND PRESSURE TEST. - PRESSURE TEST TO 250 LOW AND 5000 HIGH FOR 5 CHARTED MIN. - UNABLE TO GET A STABILIZED PRESSURE - TREE SHOWING NO VISABLE LEAKS 13:00 - 14:00 1.00 WHSUR P RUNCMP PU & MU LUBRICATOR AND PT 250 LOW & 3500 PSI HIGH - CHANGE OUT TWC 14:00 - 15:00 1.00 WHSUR P RUNCMP PRESSUE TEST TREE TO 250 PSI LOW AND 5000 HIGH PSI FOR 5 CHARTED MINUTES - STABILIZED PRESSURE, 5000 PSI FOR 5 CHARTED MIN - NO VISABLE LEAKS 15:00 16:30 1.50 WHSUR P RUNCMP PJSM. M/U LUBRICATOR. - TEST LUBRICATOR WITH DIESEL TO 250/3500 PSI FOR 5 MIN CHARTED. - PULL TWC. TBG ON VAC. - SET BACK PRESSURE VALVE - MAINTAIN CONSTANT HOLE FEED AT 20 BPH WITH 8.8 PPG KWF Printed 7/30/2012 10:24:21AM a s s 9 Common Well Name: MPE -04 AFE No Event T ype: WORKOVER (WO) Start Date: 7/5/2012 End Date: X4- 00VJW -E: (95 0,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1 /7/1990 12:00:00AM Rig Release: 7/14/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °27'19.3"7 0149 °26'08.526 "W Active KELLY BUSHING @42.50ft (above Mean Sea Date From - To Hrs Task Code NPT Level) NPT Datum: ORIG Depth Phase Description of 07 Operations Long: (hr) (ft) 16:30 - 18:00 1.50 WHSUR P RUNCMP PERFORM ROLLING TEST UNDER B 500 PSI. PUMP 4 PSI, ENDING 5 BPM PV 550 TO PSI FOR 10 MIN. CHARTED. SECURE TREE AND CELLAR. TOTAL 24 HR BPM FLU L - RIG RELEASED 440 FRO ID M OSS MP = 320 BBL E -04 AT 18:00 HRS. 1 Printed 7/30/2012 10:24:20AM r • Tree: 2 9/16" - 5M FMC M P E -04G KB. ELEV = 58' (N27E) ORIG BF. ELEV = 34' (N27E) Wellhead: 11" x 7" 5M FMC, Gen 5A w/ 2 7/8" WKM Tbg. Hgr. w/ 2 7/8" EU 8rd T &B Thds, and 2.5" CIW H BPV profile SLB 2 -7/8" x 1" KBMM GLM 139' KOP @ 600' MAX HOLE Angle 0,A1 45° AT 6400' MD 9 5/8 ", 36 # /ft, 5740' , , J -55 Butt i ell #1 ESP POWER CABLE SLB 2 -7/8" x 1" KBMM GLM 8546' 1,. , 2 -7/8" XN nipple 8689' (ID 2.250 ") 2 7/8" 6.5 ppf, L -80, 8rd EUE tbg. (drift ID = 2.347 ", cap. = 0.00579 bpf) WeIILift Discharge Gauge 8736' 7" 26 ppf, L -80, BTC prod. casing el TVD = 6756' (drift ID = 6.151 ", cap. = 0.0383 bpf) Pump, PMSXD 119 -P23 8741' Gas Separator GRSFTXAR H6 8759' Tandem Seal Section 8764' Model GSB3DBFERHLSSCVS/BSBPFSA Mae> MI y► Motor, KME -1 195 HP, 2145 volt, 8778' G 52 amp, Model (rerated) 3 °` ' S p WeIILift Gauge w/6 fin Centralizer 8797' TVD = 6802' `7 Chemical cut 2 7/8" tubing stub 8905' PERFORATION SUMMARY Baker'SBR' Seal w/ OTIS 2.313" 'X' Profile 8930' SIZE SPF INTERVAL OPEN /SQZ'D — OTIS 7" "HCM" PERMA- PACKER 8945' W/ MILLOUT EXT. (2.635" ID) 4.5" 5 9050 -9092' OPEN 2 7/8" Otis 'X' Nipple (2.313" ID) 8992' 4.5" 5 9118 -9152' OPEN Schlumberger gun release 9010' 11 9657' est Top of Schlumberger gun assembly 0 0 7557' tvd °o ORIG PBTD (fill) I 9789' - 7" 26#, L -80, BTRS I 9880' DATE REV. BY COMMENTS MILNE POINT UNIT 1/10/95 DBR RWO GL TO ESP CONVERSION 5/12/97 M. Linder RWO Nabor4-ES WELL E -04 10/17/97 MDO ESP RWO Nabors 5 -S API NO: 50- 029 -21997 1/18/00 GMH ESP RWO Nabors 4ES 12/13/01 BMH ESP RWO Nabors 4ES 2/22/08 REH ESP RWO Nabors 3S BP EXPLORATION (AK) 7/14/12 Hulme ESP RWO Doyon 16 STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Piug Pertorations ~ Stimulate~ Other 0 ACID Performed: A-ter Casing ~ Pull Tubing~ Perforate New Pool ~ Waiver~ Time Extension~ TREATMENT Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Di'i{~ Number: Name: Development ^~ Exploratory ^ "~ 190-0050 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 ``~ 50-029-21997-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number: `~ ADLO-028231 ~~ `~'~S` '~ MPE-04 ~j ELw 10. Field/Pool(s): ~`~ M~LNE POINT FIELD / KUPARUK RIVER OIL POOL S~[~ ~~~~Q~ 11. Present Well Condition Summary: Afssk~ Qil & G~s Cons. CQmmissi Total Depth measured 9900 feet Plugs (measured) None feet A~GhO!'8g9 true vertical 7648.53 feet Junk (measured) 9657' feet Effective Depth measured 9789 feet Packer (measured) 8945' true vertical 7562 feet (true vertical) 6913' Casing Length Size MD ND Burst Collapse Structural Conductor 80 13-3/8" 46# H-40 SURFACE - 80 SURFACE - 80 1670 670 Surface 5741 9-5/8" 36# J-55 SURFACE - 5741 SURFACE - 4579 3520 2020 Intermediate Production 9880 7" 26# L-80 SURFACE - 9880 SURFACE - 7663 7240 5410 Liner Liner Pertoration depth: Measured depth: 9050 - 9092 9118 - 9152 _ _ _ True Vertical depth: 6992.13 - 7023.68 7043.19 - 7068.81 _ _ _ Tubing: (size, grade, measured and true vertical depth) 2-7/8" 6.5# L-80 SURFACE - 8837 SURFACE - 6832 2-7/8" 6.5# L-80 8905 - 9010 6883 - 6962 Packers and SSSV (type, measured and true vertical depth) 7" OTIS HCM PERMA-PACKER _,.._ ..---••• --~~-~8945' 6913' - rt~~ ,- W/MILLOUT EXT~~ ~ 12. Stimulation or cement squeeze summary: Intervals treated (measured): p~~ ,~ ~'~._ ~i' G ~~{J~ ' !~ S `` p ~ 1~~~ ~ '~ - ~ "~ ,~ ,, , 9 Treatment descriptions including volumes used and final pressure: 13. Representative DailyAverage Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 63 34 602 182 Subsequent to operation: 65 34 611 181 14. Attachments 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 9/30/2009 n Form 10-404 Re`vised 7/2009 ~~''~'+'°~ ~~ ~~' ~~ ( ~ ~ ~~+~ ,~~~ Submit Original Only ~. ~ G ~ ~ ~ MPE-04 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 9/23/2009~T/I/0=250/260/60 ESP Acid Treatment Pumped 10 bbls Diesel , 8 ; bbls 10% DAD Acid, 3 bbls 60/40 methanol and 41 bbls dead crude down ltubing for scale removal. Well to soak for 30 mins. and Pad Op to flow back to tank after soak. FWHP=100/200/60 Master,lA, SSV and OA open. Swab ; and wing closed. FLUIDS PUMPED BBLS 10 DIESEL 8 10% DAD ACID 3 60/40 METHANOL 41 DEAD CRUDE 62 TOTAL STATE OF ALASKA "~ ~~ '~ ALA OIL AND GAS CONSERVATION COM~ION ~~~~~~~~ REPORT OF SUNDRY WELL OPERATIONS MAR 2 4 2008 1. Operations Performed: a 8S is ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Entl~d 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 190-005 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21997-00-00 7. KB Elevation (ft): 58 0 _ 9. Well Name and Number: MPE-04 - 8. Property Designation: 10. Field /Pool(s): ADL 028231- Milne Point Uni t / Kuparuk River Sands 11. Present well condition summary Total depth: measured 9900 ~ feet true vertical 7649 feet Plugs (measured) None Effective depth: measured 9789 feet Junk (measured) 9657' true vertical 7562 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 80' 80' 1670 670 Surface 5741' 9-5/8" 5741' 4579' 3520 2020 Intermediate Production 9880' 7" 9880' 7633' 7240 5410 Liner ~{~R APR ~ ~ 200 8 Perforation Depth MD (ft): 9050' - 9152' Perforation Depth TVD (ft): 6992' - 7069' 2-7/8", 6.5# L-80 8837' Tubing Size (size, grade, and measured depth): 2 7/8„ ~_~~ Packers and SSSV (type and measured depth): 7" Otis'HCM' Perma-Packer with millout extension 8945' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 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 0 320 0 Subsequent to operation: 53 7 1367 260 183 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 N/A if C.O. Exempt: Contact Nick, Frazier, 564-5633 N/A Printed Name Sondra Stewman Title Drilling Technologist Si nature Phone 564-4750 Date Prepared By Name/Number: ~ ,~~'(~ Sondra Stewman, 564-4750 ~.;~, =u. , Form 10-404 Revised 04/2006 v ~ ~ Submit Original Only _ , ~a ~ ~~~ ~l! <' 200E ~ ( ~ TREE: 2 9/16" - 5M WKM WELLHEAD: 11" SM WKM ACTUATOR: 2 7/8" EUE Srd threads top and bottom of hgr WKM Tubing Hanger w/. 3" 'H' Profle M P E SOT ORIG. KB. ELEV = 58' (N27E) ORIG. BF. ELEV = 34' (N27E) Camco 2-7/8" x 1° 170' sidepocket KBMM GLM NOTE: The casing hanger stud s 5/a", 36#/ft, 5740' bolts need to be changed out ~-s5 Butt .during the next RWO!!! 2 7/8" 6.5# EUE 8RD, L-80 Tbg. DRIFT ID: 2.441" CAPACITY: 0.00579 BBL/FT #1 ESP POWER CABLE CamcO 2-7/8" x 1" $~rj$$' sidepocket KBMM GLM 2-7/8" XN niPPle 8,731 ` (ID 2.25") KOP @ 600' MAX HOLE Angle 45DEG AT 6400' MD PERFORATION SUMMARY SIZ SPF INTERVAL OPEWSQZ'D 4.5" 4.5" 5 5 9050-9092' 9118-9152' OPEN OPEN DATE REV. BY _ COMMENTS 1/10/95 5!12(97 DBR M. Linder RWO GL TO ESP CONJERSION RWO Nabor 4{S 10/17/97 MDO ESP RWO Nabors 5-S 1/18/00 GMH ESP RWO Nabors 4ES 12/13/01 BMH ESP RWO Nabors 4ES 2/22/08 REH ESP RWO Nabores 3S Pump, PMSXD 142P21 8 779, Intake GSTHVEVXH6 8,795' Tandem Seal Section $ $00' Model GS63DBFERHLSSCVSB/SBPFSA , Motor, 190 HP, 2415 volt, 8,814` 48 amp, Model KMHG Phoenix Gauge w/6 fin Centralizer 8,831' ~ Chemical cut 2 7/8" tubing stub 8905' Baker'SBR' Seal w/ OTIS ' -2.313"'X' Profile 8930 . OTIS 7" "HCM" PERMA-PACKER gg45' W/ MILLOUT EXT. (2.635" ID) " " ' ' ~ ' Otis Nipple (2.313 ID) 2 7/8 X 8992 ~ Schlumberger gun release 9010' 657' est Top of Schlumberger gun assembly 0 0 7557' tvd ~ ° 9789' ORIG. PBTD (fill) 7" 26#, L-80, BTRS 9880' MILNE POINT UNIT WELL E-04 API NO: 50-029-21997 BP EXPLORATION (AK) • BP EXPLORATION Page 1 of 4 Operations Summary Report Legal Well Name: MPE-04 Common Well Name: MPE-04 Spud Date: 1/7/1990 Event Name: WORKOVER Start: 2/16/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/22/2008 Rig Name: NABOBS 3S Rig Number: i ~ Date From - To Hours Task '~ Code NPT Phase Description of Operations 2!17!2008 06:00 - 11:00 5.00 RIGD P PRE Rig down off of well slot MPE-31. Scope and lower the Derrick. Disconnect the Modules and load on the trucks. 11:00 - 15:30 4.50 MOB P PRE Move off of well slot MPE-31 with the WSL, Toolpusher and Pad Operator present. Attempt a dry run on backing upon MPE-04 (next well slot over) but unable to do so due to insufficient gravel around the cellar. Have Milne Roads and Pads asssist with gravel to complete dry run. Back the well on MPE-04 and back the Pits Module in place. We should be able to rig up on the well. Pull off of MPE-04 and allow for Roads and Pads to prep the site prior to rigging up. 15:30 - 19:00 3.50 RIGU P PRE Pad prep complete. Notify the pad operator and back up on well slot MPE-04. Begin building around the well cellar with 3 x 12's due to large cellar opening. Spot the BOPE Cradle behind the well. Lay out Herculite and Rig Mats. Back the Carrier over well slot MPE-04 with the Pad Operator present. 19:00 - 19:30 0.50 RIGU P PRE Jack and level carrier. R/U handi-berm around carrier. 19:30 - 20:30 1.00 RIGU P PRE Line up pipe shed and back into position on the carrier. Hook up truck to pit module and back into position. 20:30 - 21:30 1.00 RIGU P PRE Pull and connect elecrtical lines from carrier to pit and pipeshed modules. Continue with Handi-Berm. Set stairs and handrails. 21:30 - 23:00 1.50 RIGU P PRE Inspect derrick and lines. Raise derrick up off carrier. Scope derrick and install dogs. The Rig was accepted at 23:00 hrs on 2(17(2008. 23:00 - 00:00 1.00 RIGU P PRE Hook up steam and water lines. Put steam and water around rig. 2/18/2008 00:00 - 03:30 3.50 KILL P DECOMP R/U to tree for well kill. Install secondary valve on IA. Run hardline to tiger tank. Test surface lines to 3,500 psi. Good test. Test hardline to tiger tank to 500 psi. Good test. Blow lines down. 03:30 - 05:00 1.50 KILL P DECOMP R/U lubricator and test to 500 psi. Good test. Pull CIW 2-1/2" e H BPV. 250 psi on tubing and IA. R/D lubricator. 05:00 - 08:00 3.00 KILL P DECOMP Bleed down pressure, pump 50 bbls of 130 degree seawater down tubing, lined up to take returns out the IA through the choke manifold to the tiger tank. Just gas returns no fluid returns. 3 bpm at 60 psi. Shut in the choke and bullhead 50 bbls of seawater into the formation. Shut the pump down and monitor the well ,Tubing = 0 psi , IA = 0 psi. Ogen the choke and resume pumping down the Tubing and attempting to get returns up the IA at a rate of 2 bpm / 40 psi. Pump 75 bbls with no returns to surface. Shut the pump down an swa RTp down the 1 an u head kill the well. 08:00 - 09:30 1.50 KILL P DECOMP Bullhead down the IA with seawater at a rate of 4 bpm / 150 psi. Pumped a total of 390 bbls of seawater (IA volume = 260 bbls). 09:30 - 10:00 0.50 KILL P DECOMP Swap to bullhead down the Tubing with seawater. Pump at a rate of 4 bpm / 350 psi for 50 bbls (Tubing volume = 50 psi). 10:00 - 10:30 0.50 KILL P DECOMP Shut down and monitor the well for 30 minutes. The Tubing and the IA are on a strong vacuum 10:30 - 11:00 0.50 WHSUR P DECOMP PU T-bar and seta 2-1/2" Type "H" TWC with Cameron rep. It screwed in with 5-1/2 turns to the left. 11:00 - 14:00 3.00 WHSUR P DECOMP RU Test Equipment. Pressure test the TWC from below by injecting down the IA at a rate of 1 bpm / 2 psi or 30 charted Printed: 3/12/2008 11:43:17 AM • BP EXPLORATION Operations Summary Report Page2of4, Legal Well Name: MPE-04 Common Well Name: MPE-04 Spud Date: 1/7/1990 Event Name: WORKOVER Start: 2/16/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/22/2008 Rig Name: NABOBS 3S Rig Number: Date .From - To ~ Hours I Task Code i NPT i Phase 12/18/2008 11:00 - 14:00 I 3.00 WHSUR P 14:00 - 16:00 2.00 W HSU R I P 16:00 - 20:00 I 4.001 BOPSUR P 20:00 - 21:00 I 1.001 BOPSUR P 21:00 - 00:00 I 3.001 BOPSUR P 2/19/2008 00:00 - 01:00 1.00 BOPSUFI P 01:00 - 02:00 I 1.001 WHSUR I P 02:00 - 03:00 1.00 PULL P 03:00 - 04:00 1.00 PULL P 04:00 - 04:30 0.50 PULL P 04:30 - 10:30 6.00 PULL P Description of Operations DECOMP rains - OK. Pressure test the TWC from abrn~P to 3 Snn,_,_,n~++~r 30 - low down and RD Test Equipment. DECOMP ND Tree and Adapter Flange with Cameron rep. Check the Hanger threads -they are 2-7/8" EUE 8rd and in good shape. 8-1/2 turns to screw on. Replaced the packing on most of the gland nuts with Cameron rep. Filling the IA with 20 bbls of seawater per hour. Shoot fluid level at 15.3n nrc,•,ir1, wRll Supoort Techs, initial fluid level at 1,550' but droppina_ Thy DECOMP PU the BOPE off the Cradle and NU the 13-5/8" 5M BOPE. .Continue fillinq_the IA with 30 bbls of seawater per hour per evel at 3 000'. N/U Kill and Choke lines. Function Rams. DECOMP R/U test assembly. Fill BOPE stack and choke manifold with water. DECOMP Test BOPE choke valves, floor valves to 250 psi low and 3,500 psi high. Each test was held for 5 minutes. No failures. Perform Koomey test. AOGCC witness of test was waived Chuck Scheve. DECOMP Continue testing BOPE, choke valves, floor valves to 250 psi low and 3,500 psi high. Each test was held for 5 minutes. No failures. Perform Koomey test. AOGCC witness of test was waived Chuck Scheve. DECOMP M/U Opso Lopso and screw into hanger, P/U lubricator and test to 500 psi. Good test. Pull CIW 2-1/2" Type H TWC. Well is on vac. UD lubricator and Opso Lopso. Shot~fuicTPevels at 02:00 h0U1'S.,Both tubing anri IA IPVPIs arP at 3.000'. DECOMP Hang ESP sheave, drain hose and containment trunk. Run rope through sheave and containment trunk. DECOMP M/U Landing joint with TIW valve. Screw into hanger, made up 10 turns. Cameron wellhead tech backed out lock down screws. Pull hanger to rig floor. Hanger came off seat at 85,000#, up weight 80,000#. DECOMP UD hanger and Landing joint. Remove ESP cable from DECOMP POOH with ESP completion standing back 2-7/8" Tubing in the Derrick and spooling the ESP Cable in the Spooling Unit. Double displacing plus with seawater while POOH. As GLM with open port cleared fluid level at -3,000' started getting gas/air out tubing. Stab TIW valve. 10:30 - 14:30 4.00 PULL N DPRB DECOMP With TI va ve stab ed no indication of flow on IA. Dicussed options with Anchorage Team. Cut ESP cable and closgd in well bore. Watch for half hour. 5 psi on tubing, 0 psi on IA. After futher discussion wit Anchorage Team bleed off pressure on tubing through gas buster, Bled down quickly. Well on vac. Left open for half hour. No indication of gas flow or returns. Close well in for 1 hour, zero pressure build up. Well on vac. O en well up and monitor. AOGCC (Chuck Scheve) was notifi~_ closing the well in at 11:30 AM on 2/19/2008. 14:30 - 17:30 3.00 PULL P DECOMP POOH with comp a ion. un cut ESP cable over sheave through containment trunk to spooler. POOH to ESP. Continuous seawater fill down IA 1/2 bpm for 30 bph. 17:30 - 18:00 0.50 PULL P DECOMP R/D tubing handling tools. Run end of ESP cable over sheave Printed: 3/12/2008 11:43:17 AM • BP EXPLORATION Operations Summary Report Page 3 of 4 ~ Legal Well Name: MPE-04 Common Well Name: MPE-04 Spud Date: 1/7/1990 Event Name: WORKOVER Start: 2/16/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/22/2008 Rig Name: NABOBS 3S Rig Number: Date I From - To 1 Hours ` Task I. Code II NPT Phase Description of Operations 2/19/2008 17:30 - 18:00 0.50 PULL P DECOMP to spooler. 18:00 - 21:30 3.50 PULL P DECOMP Break out and UD ESP. Clear and clean rig floor. 21:30 - 23:00 1.50 BOPSU N DPRB DECOMP Install test plug for WKM 11" 5M welhead. Pressure test equipment shut in on well as per AOGCC regwr-' ements. nnu ar, oor va v , an i va ves were tested to 250 psi low and 3,500 psi. Each test was held for 5 minutes on chart. No failures. Shot fluid level. Shot showed Fluid level to be -3,500'. 23:00 - 00:00 1.00 WHSUR N DECOMP M/U WKM wear bushing running tool. Would not make up to wear bushing due to rust build up and burrs in J-slot. Dress out rust and burrs. 2/20/2008 00:00 - 00:30 0.50 WHSUR N CLEAN Continue to dress burrs and rust off Wear bushing and running tool. 00:30 - 01:00 0.50 WHSUR P CLEAN Install wear bushing 6-3/8" ID. L/D running tool. 01:00 - 01:30 0.50 CLEAN P CLEAN P/U Baker 7" Casing Scraper for 26# pipe. 01:30 - 06:00 4.50 CLEAN P CLEAN RIH with 7" Casing Scraper on 2-7/8" tubing from derrick. 06:00 - 07:00 1.00 CLEAN P CLEAN RIH 79 stands to 5007'. PU single of 2 7/8" tubing and reciprocate across 5000' setting depth for RBP. Hole fill ~ 30 Bbls / Hr. 07:00 - 08:30 1.50 CLEAN P CLEAN POH w/ Csg Scraper standing back 2 7/8" tubing in Derrick. Increase hole fill to -45 Bbls / Hr. 08:30 - 09:30 1.00 CLEAN P CLEAN 37 stands OOH, scraper ~ +/- 2600', Hot air visible from tubing. Stop and observe. Switch hole fill from IA to Tbg. Load Tbg with 30 Bbls of SW, Tbg on Vacuum. Flowcheck well. 09:30 - 11:00 1.50 CLEAN P CLEAN Continue POH w/ 7" Csg Scraper while filling the backside C~ rate of 45 Bbls / Hr with SW. 11:00 - 12:00 1.00 WHSUR P CLEAN BOLD 7" Csg Scraper. Pull 6-3/8" wear bushing. Clean and clear rig floor. 12:00 - 13:00 1.00 WHSUR P WHDTRE PUMU HES 7" Mod 3 RBP on 2 7/8" EUE running retrieving head. Tool OD - 5.76"., 8.92' OAL / 4.96" COE. RIH 3 stands. RBP dragging. POH and inspect RBP, grease drag blocks. 13:00 - 15:30 2.50 WHSUR P WHDTRE RIH w/ 7" RBP, after 1st 5 stands, continuous hole fill of _ 45 Bbl / Hr as RIH on 2 7/8" tubing from Derrick. 15:30 - 17:30 2.00 WHSUR P WHDTRE RIH to 5000', PUW of 40K, SOW of 30K. Set HES 7" RBP 5000'. POH 2 Stands and 1 single. Fill hole w/ 112 s o (equates to FL of 3200'). Close annular preventer and pressure to 1500 and Tes 7 sg. Chart for 30 minutes. Good Test. 17:30 - 19:30 2.00 WHSUR P WHDTRE Bleed pressure from wellbore, open bag, break out single of 2 7/8" Tbg. PUMU HES 7" Rtts Storm PKR. RIH on single. PUMU 1 single of Tbg (w is a een aid down). RIH to set RTTS 1 Stand in. Up weight 37,000#, Down weight 30,000#. POOH and stand running tool back. Close blinds and test to 3,500 psi. Chart for 30 minutes. Good test. 19:30 - 21:00 1.50 WHSUR P WHDTRE N/D BOPE, unhook hydraulic lines, choke line and kill line, N/D tubing spool. Move BOP stack to back side of cellar. 21:00 - 00:00 3.00 WHSUR P WHDTRE Remove nuts and bolts from top of casing spool. Bolts were tight and difficult to remove. 2/21/2008 00:00 - 01:00 1.00 WHSUR P WHDTRE Continue to remove nuts and bolts from top of casing spool. Bolts were tight and difficult to remove. Clean and prep casing spool, Change out Top seals on casing packoff. 01:00 - 03:30 2.50 WHSUR P WHDTRE N/U tubing spool and BOPE. Torque bolts to 2,000 ft/Ibs. Test Printed: 3/12/2008 11:43:17 AM • BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: MPE-04 Common Well Name: MPE-04 Spud Date: 1/7/1990 Event Name: WORKOVER Start: 2/16/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/22/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours ' Task Code i NPT Phase Description of Operations 2/21/2008 01:00 - 03:30 2.50 WHSUR P WHDTRE connection between casing head and tubing spool to 5,000 psi. Hook up hydraulic lines, kill and choke lines. Install flow riser. 03:30 - 04:30 1.00 WHSUR P WHDTRE Function test BOP's, Test choke line and kill line connections - to 250 psi low and 3,500 psi hig .Hold each test for 5 minutes on chart. Good test. 04:30 - 05:30 1.00 WHSUR P WHDTRE Latch into HES 7" Storm packer, and release. Pull to ri floor and D Storm packer. 05:30 - 06:00 0.50 WHSUR P WHDTRE Latch onto HES 7" RPB. Release RBP. as RBP wac rPieased well started taking fluid Start fillina backside with 45 ham,,, continuous fill. 06:00 - 07:00 1.00 WHSUR P WHDTRE Flow check well while filling ~ 45 bph. Rig down elephant trunk and prep for running completion. 07:00 - 09:30 2.50 WHSUR P WHDTRE POH w/ 7" RBP from 5000', standing back in Derrick, with continuous hole fill C~ -45 bph of SW. UD RBP 09:30 - 10:30 1.00 BUNCO RUNCMP Clean and clear rig floor. Prep for running ESP. PJSM 10:30 - 14:30 4.00 BUNCO RUNCMP PUMU ESP BHA 14:30 - 21:00 6.50 BUNCO RUNCMP RIH on 2 7/8",6.5#,EUE 8 rd tubing from Derrick. Install ' LaSalle Cable protectors on first nine joints en every second joint. check conductivity of cable every 2000'. MU torque of 2300 ft-Ibs. Using Best-O-Life 2000 pipe dope. RIH to joint # 242. Continous hole fill of 45 bph 21:00 - 00:00 3.00 BUNCO RUNCMP Remove empty ESP cable spool from spooling unit and replacq with partial spool. Prep ESP cable ends and begin making splice. Continous hole fill of 45 bph 2/22/2008 00:00 - 02:30 2.50 BUNCO RUNCMP Continue making splice in ESP cables and test conductivity. Tested good. Continous hole fill of 45 bph. 02:30 - 03:30 1.00 BUNCO RUNCMP RIH on 2 7/8",6.5#,EUE 8 rd tubing from Derrick. Install LaSalle Cable protectors on every second joint. check conductivity of cable every 2000'. MU torque of 2300 ft-Ibs. Using Best-O-Life 2000 pipe dope. RIH to joint #274. Ran 3 flat guards, 5 protectolizers, and 144 LaSalle clamps. Continous hole fill of 45 bph. 80,000# Up weight, 48,000# Down Weight. 03:30 - 04:30 1.00 BUNCO RUNCMP M/U landing joint and tubing hanger. Install ESP penetrator in hanger. 04:30 - 07:00 2.50 BUNCO RUNCMP Make hanger splice in ESP cable. 07:00 - 08:00 1.00 BUNCO RUNCMP PUW of 83K, SOW of 50K. Land tubing and hanger, RILDS. lay down 2 7/8" EUE 8 rd landing joint. Dry rod TWC. 08:00 - 10:30 2.50 WHSUR P RUNCMP Pump SW ~ 3 1/2 BPM, 150 psi down IA to test TWC from below. Pump for 30 minutes and chart. Test TWC to 1000 psi from above and chart for 30 minutes. Good test. 10:30 - 14:00 3.50 WHSUR P RUNCMP ND BOPE 14:00 - 16:30 2.50 WHSUR P RUNCMP NU tree. Centrilift final checks: 3.6 ohms phase to phase / 1.3 gig ohms phase to ground / 177 psi ~ intake, 144 deg F C~ motor. Pressure test hanger void to 5000 psi for 20 minutes. Test tree w/diesel to 5000 psi for 30 mins. (charted). 16:30 - 18:00 1.50 WHSUR P RUNCMP PUMU lubricator with pulling tool for TWC. Test to 500 psi. Pull TWC. T / IA / OA pressures of: 0 / 0 / 0 psi. Run BPV. Normal up tree and secure cellar. - 0.00 WHSUR P RUNCMP Release rig ~ 18:00 Hours for move to MPC-24 Printed: 3/12/2008 11:43:17 AM • • STATE OF ALASKA "r'~JQ7 OIL AND GAS CONSERVATION COMMISSION BOPS Test Report Submit to: Contractor: Nabors Rig No.: 3S DATE: 2/19/2008 Rig Rep.: J. GrecolJ.Fritts Rig Phone: 659~48T Rig Fax: 659- 4486 Operator: BP Op. Phone: 659- 4485 Op. Fax: 659-4628 Rep.: W. Hoffman! B. Burson Field/Unit 8~ Well No.: MPU E-04 PTD # 1900050 Operation: Drlg: Test: Initial: X Test Pressure: Rams: 25fl1351~ MISC. INSPECTIONS: Test Result Test Result Location Gen.: P Wei Sift 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 '! 135/8 5000 P Pipe Rams 1 2 718 P Lower Pipe Rams Blind Rams 1 Blind P Choke Ln. Valves 1 3 1/8" 513b0 P HCR Valves 2 3118" 51X~ P KiN Line Valves 1 21116" SDflfl P Check Valve 0 NA Workover: X Weekly: Ar~ar: 25fl135tm TEST DATA '-= Bi-Wee(dy Vafires: 250/3500 FLOOR SAFETY VALVES: Quantity Test Result tipper ICe~yr 1 NT Lower Keay 1 NT BaN Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Ghokes 1 P Hydrau8c Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressr~-e After Ck~e i 500 P MUD SYSTEM: V~uat Test Alarm Test 200 psi Att-airred 36sec P Trip Tank P P Fufl Prese Atta~ed 2 min 47 sec P Pit Level Indicators P P Box! Switch Goners: All stations P Flow Indicator P P Niter. Bootees {avg): 4@1975 Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: Test Time: 4A Hours Repair ar replacement of ecrrrer~t w~ be made w Inspector 659-3607, folow wtila wry confrmation to S~ at: Remarks: 24 HOUR NOTICE GIVEN YES X NO Date t)2J17108 Time 14:31) start 21(10 hrs Finish Componerrts tested ALL days. Notify the North Slope By Chuck Scheve Witness B. Burson/J.Fritts .BOP Test (for rigs) BFL 11/14/Q7 ~~i~ FEB ~ ~} 2~D$ Nabors 3S BOP Test MP E-04 2-19-08.x1s STATE OF ALASKA) Reef!fV!O ALASKA i AND GAS CONSERVATION CO,..,VlISSION OCT I ð 2005 . REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commissioh ESP Rw~ohorf)ge 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 28231 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): o Suspend 0 Operation Shutdown 0 Perforate 181 Other 181 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well 181 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 58.0 9900 7649 9789 7562 80' 5707' 9846' 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 190-005 6. API Number: 50-029-21997-00-00 99519-6612 9. Well Name and Number: MPE-04 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands feet feet Plugs (measured) None feet Junk (measured) 9657' feet Size MD TVD Burst Collapse 13-3/8" 80' 80' 1670 670 9-5/8" 5741' 4579' 3520 2020 7" 9880' 7633' 7240 5410 :~A'NNE[) NOV !)B 2005 9050' - 9152' 6992' - 7069' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2-7/8",6.5# L-80 2-7/8" L-80 7" Otis 'HCM Perm a-Packer with millout extension 8829' 8905' - 9010' 8945' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Treatment description including volumes used and final pressure: 13. RBDMS 8Ft 0 CT .-R J 2005 Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram 15. Well Class after proposed work: o Exploratory 181 Development D Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ D WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if c.o. Exempt: Contact David Reem, 564-5743 Title Technical Assistant Phone (.t::Jol} -q iSQ ORIGINAL r£)( -C5l~ Prepared By Name/Number: Date-....I I) Sondra Stewman, 564-4750 Submit Original Only _lG. KB. ELEV = 58' (N27E) ORIG. BF. ELEV = 34' (N27E) ) MP E-04 TREE: 29/16" - 5M WKM WELLHEAD: 11" 5M WKM ACTUATOR: 27/8" EUE 8rd threads top and bottom of hgr WKM Tubing Hanger wI. 3" 'H' Profile 1731' I Cameo 2-7/8" x 1" sidepoeket KBMM GLM I 5740' L-Ji 9 5/8", 36#/ft, J-55 Butt , 2 7/8" 6.5# EUE 8RD, L-80 Tbg. DRIFT ID: 2.441" CAPACITY: 0.00579 BBUFT I 8,590' I Cameo 2-7/8" x 1" sidepoeket KBMM GLM, #1 ESP POWER CABLE 18,734' I 2-7/8" XN nipple (ID 2.205") KOP @ 600' MAX HOLE Angle 45DEG AT 6400' MD Pump, 151GC1700 wI coated stages Model - GPMTAR 1:1 8,777' I I 8,795' I Intake GPXINTARH6FER Intake 8795' MD = 6800' TVD 18,796' I 18,809' I \8,823' I Tandem Seal Section Model GSB3 DB UT/L T AB/HSN PFSA Motor, 152 HP, 2325 volt, 40 amp, Model KMH PumpMate w/6 fin Centralizer PumpMate 8823' MD = 6821' TVD 8905' 8930' 8945' 8992' 9010' ~ Chemical cut 27/8" tubing stub _ ------ Baker 'SBR' Seal wI OTIS ..c: 2.313" 'X' Profile ::s< .:E!: - OTIS 7" "HCM" PERMA-PACKER ----=:J ~ WI MILLOUT EXT. (2.635" ID) ¡e:::=.,~ 2718" Qtl' 'X' Nipple (2.313·'01 ~ So"'"mbe'!)", goo ""ea.. dJ...If. ~ Jj ~- PERFORATION SUMMARY INTERVAL OPEN/SQZ'D SIZE SPF OPEN 5 4.5" 9050-9092' ~ OPEN 5 4.5" 9118-9152' -9657' est Top of Schlumberger gun assembly 7557' tvd 9789' ORIG. PBm (fill) 7" 26#, L-80, BTRS 9880' DATE REV. BY COMMENTS MILNE POINT UNIT 1/10/95 DBR ~ GL TO ESP CONVERSION 5/12/97 M. Linder RWO Naber 4-ES WELL E-04 10/17/97 MDO ESP RWO Nabors 5-S API NO: 50-029-21997 1/18/00 GMH ESP RWO Nabors 4ES 12/13/01 BMH ESP RWO Nabors 4ES BP EXPLORATION (AK) 9/12/05 Lee Hulme ESP RWO Nabors 4ES Operations Summary RE!Port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-04 MPE-04 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Dàte FrOm-To HoÜrs Task Code NPT Phase 9/10/2005 PRE PRE PRE 09:00 - 10:30 1.50 RIGD P 10:30 - 12:30 2.00 MOB P 12:30 - 14:00 1.50 RIGU P 14:00 - 16:00 2.00 RIGU P 16:00 - 18:00 2.00 WHSUR P 18:00 - 20:00 2.00 KILL P PRE DECOMP DECOMP 20:00 - 20:30 0.50 WHSUR P 20:30 - 21:00 0.50 WHSUR P 21 :00 - 23:00 2.00 BOPSUP P 23:00 - 00:00 1.00 BOPSUR P 9/11 /2005 00:00 - 02:30 2.50 BOPSUP P 02:30 - 04:00 1.50 BOPSUR P 04:00 - 04:30 0.50 WHSUR P 04:30 - 05:30 1.00 PULL P 05:30 - 06:00 0.50 PULL P 06:00 - 12:00 6.00 PULL P 12:00 - 13:30 1.50 PULL P 13:30 - 14:00 0.50 PULL P 14:00 - 16:00 2.00 RUNCOMP 16:00 - 21 :00 5.00 RUNCOMP 21 :00 - 00:00 3.00 RUNCOMP 9/12/2005 00:00 - 00:30 0.50 RUNCOMP 00:30 - 01 :00 0.50 RUNCOrvP 01 :00 - 02:30 1.50 RUNCOrvP 02:30 - 03:00 0.50 RUNCOrvP 03:00 - 04:00 1.00 BOPSUR P 04:00 - 06:00 2.00 WHSUR P DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP Start: 9/11/2005 Rig Release: 12/11/2001 Rig Number: 4ES Spud Date: 1/7/1990 End: DésÞription bfc>perätiohê Rig down from MPA-03. Scope and lower Derrick. RDMO from MPA-03 and move to MPE-04. Spot Sub Base, Pits, Pipe Shed, and Camp. Raise and scope Derrick. Take on Sea Water in Pits. Spot Tiger Tank. Lay Lines. Test Lines at 250/3500 psi. Accept Rig at 14:00 hrs. Piek-up Lubricator. Pull BPV. Lay down same. TP = 500 psi. CP = 580 psi. Bleed gas. Bullhead kill Well with 120 deg Sea Water at 5.0 bpm/150 psi. Total barrels pumped = 330. Monitor Well on vae. Set and test TWC. Bleed Void. Nipple down Produetion Tree. Nipple up BOPE. Rig-up test equipment. Begin BOPE Test. Finished testing BOPE per BP/AOGCC requirements at 250/3500 psi. Good Test. State's right to witness test waived by J. Spaulding. Rig down test equipment. Piek-up Lubricator and pull TWC. Lay down same. Piek-up Landing Joint. BOLDS. Pull Tubing Hanger to Rig Floor with no problems. Lay down Tubing Hanger and Landing Joint. Finish rig-up to pull ESP Completion. Pull 27/8" ESP Completion. Total Joints = 274. Lay down ESP Assembly. Motor problems. Change out Reels in Spooling Unit. Clear and Clean Floor. Pick-up and service new ESP Assembly. Start to run 2 7/8" ESP Completiom. Stop at -8,760' to make Reel to Reel Spliee. Finish running in hole with 2 7/8" ESP Completion. Make-up Tubing Hanger. Install Penetrator. Splice in Field Connector Cable. Attaeh Cable and test. Land Tubing Hanger. RILDS. Set TWC and test. Nipple down BOP Stack. Nipple-up Production and test to 5,000 psi. Make final ESP Cable check. Release Rig at 06:00 hrs. Printed: 9/19/2005 8:02:46 AM STATE OF ALASKA ALASKA ,.,.~. AND GAS CONSERVATION COMM~,.,,51ON REPORT OF SUNDRY WELL OPERATIONS i" Ope'rations performed: [] Operation S~utdown [] ~timt~late [] Plugging l"l'Perforate ' I~ Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator"' 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 58' 3. Address [] Exploratory 7. Unit or Property Name [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1344' SNL, 1995' WEL, Sec. 25, T13N, R10E, UM MPE-04 At top of productive interval 9. Permit Number / Approval No. 190-005 2135 SNL, 3291' EWL, Sec. 30, T13N, R10E, UM 10. APl Number At effective depth 50- 029-21997-00 2053' SNL, 3756' EWL, Sec. 30, T13N, R10E, UM 11. Field and Pool At total depth Kuparuk River Field 2040' SNL, 3824' EWL, Sec. 30, T13N, R10E, UM ,,,,,,, 12. Present well condition summary Total depth: measured 9900 feet Plugs (measured) true vertical 7649 feet Effective depth: measured 9789 feet Junk (measured) Estimated top of Schlumber gun assembly at 9657' true vertical 7562 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 13 3/8" 500 sx Permafrost 'C' 80' 80' Surface 5707' 9 5/8" 406 Bbls PF 'E', 70 Bbls Class 'G' 5741' 4579' Intermediate Production 9846' 7" 125 Bbls Class 'G' 9880' 7633' Liner Perforation depth: measured 9050' - 9092', 9118'- 9152' ' '~ ~ '/~ true vertical 6992' - 7024', 7043' - 7069' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 8854'; 2-7/8" from 8905' to 9010 '-"'~,~ ~;:'~,.;~ ~ ~ .... '~,~;,.;~o~; Packers and SSSV (type and measured depth) 7" Otis 'HCM' Perma-packer with millout e~ension at 8945' 13. Stimulation or cement squeeze summa~ Inte~als treated (measured) Treatment description including volumes used and final pressure 14. ' Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. A~achments 16. Status of well classifications as: ~ Copies of Logs and Su~eys run ~ Daily Repo~ of Well Operations ~ Oil D Gas ~ Suspended Se~ice 17. I hereby ce~i~ that the foregoing is true and correct to the best of my knowledge S,.ne eohn,..,*..,stant .ate -- Z;- ................ Prepared By Name/Number: Sondra Stewman, 564-47~ Form 10-404 Rev. 06/15/88 Submit In Duplicate , , Legal Well Name: MPE-04 Common Well Name: MPE-04 Spud Date: 1/7/1990 Event Name: WORKOVER Start: '12/10/2001 End: 12/11/2001 Contractor Name: NABORS Rig Release: 12/11/2001 Rig Name: NABORS 4ES Rig Number: , , 12/8/2001 15:00 - 16:30 1.50 MOB P PRE SCOPE DOWN AND LOWER DERRICK. PREP TO MOVE. 16:30 - 18:00 1.50 MOB P PRE MOVE RIG AND EQIPMENT FROM MPI-12 TO MPE-04. CREW CHANGE. 18:00 - 20:30 2.50 MOB P PRE COMPLETE MOVING RIG AND EQUIPMENT TO MPE-04. 20:30 - 21:30 1.00 RIGU P PRE SPOT RIG AND EQUIPMENT. 21:30 - 23:00 1.50: RIGU P PRE RAISE AND SCOPE DERRICK. ACCEPT RIG AT 23:00 HRS 12/08/2001. TAKE ON 120 DEC SEA WATER. 23:00 - 00:00 1.00! RIGU P DECOMP PRE JOB OPERATIONS AND SAFETY MEETING. BEGIN TO HOOK UP LINES. 12/9/2001 00:00 - 00:30 0.50 RIGU P DECOMP FINISH RIGGING UP LINES. 00:30 - 01:00 0.50 WHSUR P DECOMP PICK UP LUBRICATOR AND PULL BPV. LD. 01:00 - 02:00 1.00 KILL P DECOMP PRESSURE TEST LINES TO 3,500 PSI. OPEN UP WELL. TBG = 790 PSI. ANNU = 900 PSI. 02:00 - 06:00 4.00 KILL P DECOMP BLEED GAS. CIRCULATE AND DISPLACE WELL WITH HOT SEA WATER. MONITOR. TBG = 100 PSI. ANNU = 90 PSI. CREW CHANGE. 06:00 - 09:00 3.00 KILL P DECOMP CONTINUE TO CIRCULATE AND CLEAN UP WELL. 09:00 - 11:00 2.00 KILL P DECOMP DISPLACE WELL OVER TO 9.0 BRINE. MONITOR. SLIGHT VAC. 11:00 - 11:30 0.50 WHSUR ~ DECOMP SET TWC. 11:30 - 12:30 1.00 WHSUR ~ DECOMP REMOVE PRODUCTION TREE. 12:30 - 14:30 2.00 BOPSUF.P DECOMP INSTALL ADAPTOR AND BOP. 14:30 - 17:00 2.50 BOPSUF P DECOMP PERFORM DOPE TEST PER AOGCC AND BP REQUIREMENTS. 250~3,500 PSI. STATE'S RIGHT TO WlTTNESS TEST WAIVED BY C. SHEVE. 17:00 - 18:00 1.00 WHSUR ~ DECOMP PICK UP LUBRICATOR AND PULL TWC. CREW CHANGE. 18:00 - 00:00 6.00 PULL N RREP DECOMP PROBLEMS WITH SCR SYSTEM. TROUBLESHOOT AND REPAIR. 12/10/2001 00:00 - 00:30 0.50 PULL P DECOMP PULL HANGER TO FLOOR. LD. 00:30 - 01:30 1.00 PULL P DECOMP START TOH WITH 2 7/8" TBG AND ESP ASSY. 01:30 - 02:00 0.50 PULL P DECOMP STOP TO CHANGE CABLE SPOOLS. 02:00 - 06:00 4.00 PULL P DECOMP CONTINUE TOH WITH ESP ASSY. CREW CHANGE. 06:00 - 07:30 1.50 PULL P DECOMP CONTINUE TOH WITH ESP ASSY. 07:30 - 10:00 2.50 PULL P DECOMP INSPECTAND LD ESP ASSY. CLEAR FLOOR. 10:00 - 13:30 3.50 RUNCOI~ COMP PICK UP AND SERVICE NEW ESP ASSY. INSPECT AND TEST. 13:30 - 18:00 4.50 RUNCOI~ COMP START TIH WITH ESPASSYAND 2 7/8" TBG. CREW CHANGE. 18:00 - 19:30 1.50 RUNCOI~ COMP FINISH TIH WITH ESP ASSY AND 2 7/8" TBG. TEST AND FLUSH EVERY 18 STDS. 19:30 - 20:00 0.50 RUNCOI~' COMP MAKE UP HANGER. INSTALL PEN. 20:00 - 21:30 1.50 RUNCOI~' COMP MAKE UP AND ATTACH FIELD CONNECTOR. TEST. 21:30 - 22:30 1.00 RUNCOI~I~ COMP LAND TBG HANGER. RILDS. INSTALL TWC. TEST. 22:30 - 23:00 0.50 RUNCOI~P COMP CLEAR AND CLEAN FLOOR. 23:00 - 00:00 1.00 BOPSUR P COMP NIPPLE DOWN DOPE. 12/11/2001 00:00 - 02:30 2.50 WHSUR P COMP NIPPLE UP TREE. & TEST SAME TO 5000 PSI. & MAKE FINAL TEST ON ESP CABLE. OK. 02:30 - 03:00 0.50 WHSUR P COMP PULL TWC & SET BPV. 03:00 - 05:00 2.00 RUNCOF/P COMP FREEZE PROTECT WELL WITH HB&R WITH 15-BBL. DIESEL IN TBG. & 65-BBL. DEAD CRUDE IN ANNULUS 05:00 - 06:00 1.00 RIGD P COMP SECURE TREE AREA & RELEASE RIG @ 0600 HRS. 12/11/2001 Printed: 12/14/2001 5:09:16PM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27 2000 PL C:LORIKMP~M.DOC T E R IA L HIS MA E E E W UNDER R K E R '-' STATE OF ALASKA ALASKA ,,.,iL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Pull Tubing [--I Alter Casing [~ Repair Well 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1344' SNL, 1995' WEL, Sec. 25, T13N, R10E, UM At top of productive interval 2135 SNL, 3291' EWL, Sec. 30, T13N, R10E, UM At effective depth 2053' SNL, 3756' EWL, Sec. 30, T13N, R10E, UM At total depth 2040' SNL, 3824' EWL, Sec. 30, T13N, R10E, UM [] Perforate [~Other Change Out ESP 5. Type [~ well: Development [--[ Exploratory [--I Stratigraphic i--I Service 6. Datum Elevation (DF or KB) KBE = 58' 7. Unit or Property Name Milne Point Unit 8. Well Number MPE-04 9. Permit Number / Approval No. 190-005 10. APl Number 50- 029-21997-00 11. Field and Pool Kuparuk River Field 12. Present well condition summary Total depth: measured 9900 feet true vertical 7649 feet Effective depth: measured 9789 feet true vertical 7562 feet Casing Length Size Structural Conductor 80' 13 3/8" Surface 5707' 9 5/8" Intermediate Production 9846' 7" Liner Plugs (measured) Junk (measured) Estimated top of Schlumber gun assembly at 9657' Cemented MD TVD 500 sx Permafrost 'C' 80' 80' 406 Bbls PF 'E', 70 Bbls Class 'G' 5741' 4579' 125 Bbls Class 'G' 9880' 7633' Perforation depth: measured true vertical 9050'-9092', 9118'-9152' 6992'-7024', 7043'-7069' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 8843'; 2-7/8" from 8905' - 9010' ORIGINAL Packers and SSSV (type and measured depth) 7" Otis 'HCM' Perma-packer with millout extension at 8945' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure FEB 2000 A!as~ 011 & Gas Cons. C0mmisst0n Anchorage 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [--j Copies of Logs and Surveys run [~ Daily Report of Well Operations 16. Status of well classifications as: [] Oil [--I Gas i~ Suspended Service 17. I hereby certify that the fo, regoing is true and correct to the best of my knowledge Signed Terrie Hubble j~~ ~ Title Technical Assistant Ill Prepared By Name/Number: Date ~)~'0~' '~ Terrie Hubble, 564-4628 Submit In Duplicate Form 10-404 Rev. 06/15/88 Facility Date/Time 15 Jan 00 16 Jan 00 17 Jan 00 18 Jan 00 Progress Report M Pt E Pad Well MPE-04 Rig Nabors 4ES Page 1 Date 24 January 00 21:00-06:00 21:00-06:00 06:00 06:00-09:00 06:00-09:00 09:00 09:00-09:30 09:00-09:30 09:30 09:30-12:30 09:30-12:00 12:00 12:00-12:30 12:30 12:30-15:30 12:30-15:30 15:30 15:30-17:30 15:30-16:00 16:00 16:00-17:30 17:30 17:30-20:00 17:30-20:00 20:00 20:00-22:30 20:00-22:30 22:30 22:30-23:30 22:30-23:30 23:30 23:30-06:00 23:30-06:00 06:00 06:00-10:30 06:00-10:30 10:30 10:30-00:00 10:30-00:00 00:00 00:00-02:00 00:00-02:00 02:00 Duration 9 hr 9 hr 3 hr 3 hr 1/2 hr 1/2 hr 3 hr 2-1/2hr 1/2 hr 3 hr 3 hr 2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr 1 hr 1 hr 6-1/2 hr 6-1/2 hr 4-1/2 hr 4-1/2 hr 13-1/2 hr 13-1/2 hr 2 hr 2 hr Activity Move rig Rig moved 100.00 % Move in rig up & spot rig & safe out equipment. At well location - Slot Fluid system Fill pits with Seawater take on seawater & rig tiger tank. to tree Completed operations Wellhead work Removed Hanger plug Equipment work completed Derrick management Rigged up HCR valve rig hard line & hcr valve to annulus of tbg. spool. Equipment work completed Tested High pressure lines test lines to tree to 3000 psi. Pressure test completed successfully - 3000.000 psi Well control Circulated closed in well at 8824.0 ft Hole displaced with Seawater - 125.00 % displaced Wellhead work Installed Hanger plug set twc & test to 2500 psi. Equipment work completed Removed Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi Wellhead work Removed Hanger plug Equipment work completed Pull Single completion, 2-7/8in O.D. Pulled Tubing in stands to 5500.0 ft pull & lay dn hanger & pooh with esp completion Stopped: To hold safety meeting Pull Single completion, 2-7/8in O.D. (cont...) Pulled Tubing in stands to 0.0 ft pooh with completion & lay dn esp assy. found pump washed out with sand problems. Completed operations Run Single completion, 2-7/8in O.D. Ran Tubing in stands to 8843.0 ft mu & rih with esp completion Making mid-line splice etc. Completed run with ESP to 8843.0 ft Wellhead work Installed Tubing hanger install tbg. hanger & make esp splice to same. Equipment work completed, seal energised Facility M Pt E Pad Progress Report Well MPE-04 Page Rig Nabors 4ES Date 2 24 January 00 Date/Time 02:00-03:30 02:00-03:30 03:30 03:30-06:00 03:30-04:30 04:30 04:30-06:00 06:00 06:00-06:00 06:00-08:00 08:00 Duration 1-1/2 hr 1-1/2 hr 2-1/2 hr 1 hr 1-1/2 hr 24 hr 2 hr Activity Nipple down BOP stack Removed BOP stack Equipment work completed Wellhead work Installed Xmas tree Equipment work completed Tested Xmas tree Pressure test completed successfully - 5000.000 psi Wellhead work (cont...) Installed Hanger plug Equipment work completed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other ESP Exchange 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1344' SNL, 1995' WEL, Sec. 25, T13N, R10E, UM At top of productive interval 2133' SNL, 3303' EWL, Sec. 30, T13N, R10E, UM At effective depth 1998' SNL, 3763' EWL, Sec. 30, T13N, R10E, UM At total depth 1996' SNL, 3773' EWL, Sec. 30, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE: 56' 7. Unit or Property Name Milne Point Unit 8. Well Number MPE-04 9. Permit Number / Approval No. 90-5 10. APl Number 50- 029-21997 11. Field and Pool Kuparuk River Field 12. Present well condition summary Total depth: measured 9880' feet true vertical 7631' feet Effective depth: measured 9789' feet true vertical 7533' feet Casing Length Structural Conductor Surface Intermediate Production Liner Size Plugs (measured) Junk (measured) 9657' Cemented 80' 13 3/8" To surface 5707' 9 5/8" 55 bbl Class 'C' 40 bbl Perm 'E' 9846' 7" 125 bbl C/ass 'C' MD TVD 114' 114' 5741' 4566' 9880' 7604' Perforation depth: measured 9050'-9092', 9118'-9152' true vertical 6992'-6992',6992'-7069' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 8871' Packers and SSV (type and measured depth) Otis 7" HCM Perma Packer w/millout ext. @ 8945' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or In!ection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge .............. Signed Chip Alvord..~,~,,,,, .~ ~ ......... Title Engineering Supervisor Da!,e, ...... ,"5,,(,/.~,,,I Prepared By Name/Number: Mary Youngers 564-5242 Form 10-404 Rev. 06/15/88 Facility M Pt E Pad Progress Report Well MPE-04 Page 1 Rig Nabors 5S Date 23 December 97 Date/Time 10 Oct 97 11 Oct 97 12 Oct 97 13 Oct 97 12:00-18:00 12:00-18:00 18:00 18:00-06:00 18:00-18:30 18:30 18:30-06:00 06:00 06:00-11:30 06:00-10:00 10:00 10:00-11:30 11:30 11:30-06:00 11:30-13:00 13:00 13:00-15:00 15:00 15:00-18:00 18:00 18:00-21:00 21:00 21:00-22:30 22:30 22:30-00:00 00:00 00:00-03:00 03:00 03:00-06:00 06:00 06:00-07:00 06:00-07:00 07:00 07:00-21:00 07:00-08:00 08:00 08:00-08:30 08:30 08:30-10:30 10:30 10:30-12:00 12:00 12:00-18:00 18:00 18:00-21:00 21:00 21:00-06:00 21:00-00:00 00:00 00:00-01:00 01:00 01:00-06:00 06:00 Duration 6hr 6hr 12hr 1/2 hr 11-1/2 hr 5-1/2 hr 4hr 1-1/2 hr 18-1/2 hr 1-1/2 hr 2 hr 3hr 3hr 1-1/2 hr 1-1/2 hr 3hr 3hr lhr lhr 14hr lhr 1/2 hr 2hr 1-1/2 hr 6hr 3hr 9hr 3hr lhr 5hr Activity Fluid system Fill pits with Seawater Completed operations Perform integrity test Held safety meeting Completed operations Installed Surface tree Equipment work completed Test well control equipment Installed High pressure lines Equipment work completed Tested All tree annulus valves Function test completed satisfactorily Well control Reverse circulated at 8800.0 ft String displaced with Seawater - 100.00 % displaced Circulated at 8800.0 ft Stopped: To circulate Circulated closed in well at 8800.0 ft Stopped: Spot sample Circulated at 8800.0 ft Hole displaced with Seawater - 100.00 % displaced Circulated at 8800.0 ft Hole displaced with Lo/Hi vis combination - 100.00 % displaced lcm pill Flow check Observed well static Circulated at 8800.0 ft Pressure changed from 800.0 psi to 2500.0 psi in 1.00 hr - Hole impn Circulated at 8800.0 ft 20.000 bbl LCM pill spotted downhole, LCM content 10.0 lb/bbl Well control (cont...) Bleed down well Completed operations Nipple up Choke manifold Rigged up High pressure lines Equipment work completed Installed Internal BOPs Equipment work completed Removed Surface tree Equipment work completed Rigged down HCR valve Eqmpment work completed Installed BOP stack Equipment work completed Installed BOP stack Eqmpment work completed Test well control equipment Functioned Kill manifold Equipment work completed Held safety meeting Completed operations Tested BOP stack Pressure test completed successfully - 5000.000 psi ved Facility M Pt E Pad Progress Report Well MPE-04 Page 2 Rig Nabors 5S Date 23 December 97 Date/Time 14 Oct 97 15 Oct 97 06:00-09:30 06:00-09:30 09:30 09:30-10:30 09:30-10:30 10:30 10:30-12:30 10:30-12:30 12:30 12:30-13:30 12:30-13:30 13:30 13:30-19:00 13:30-19:00 19:00 19:00-06:00 19:00-20:00 20:00 20:00-00:00 00:00 00:00-02:00 02:00 02:00-04:00 04:00 04:00-06:00 06:00-00:00 06:00-06:30 06:30 06:30-20:00 20:00 20:00-00:00 00:00 00:00-04:00 00:00-04:00 04:00 04:00-06:00 04:00-06:00 06:00 06:00-06:00 06:00-06:30 06:30 06:30-09:00 09:00 09:00-10:30 10:30 10:30-11:30 11:30 11:30-15:00 15:00 Duration 3-1/2 hr 3-1/2 hr lhr lhr 2 hr 2hr lhr lhr 5-1/2 hr 5-1/2 hr llhr lhr 4hr 2hr 2hr 2hr 18hr 1/2 hr 13-1/2 hr 4hr 4hr 4hr 2hr 2hr 24 hr 1/2 hr 2-1/2 hr 1-1/2 hr lhr 3-1/2 hr Activity Test well control equipment (cont...) Tested All functions Pressure test completed successfully - 5000.000 psi Well control Monitor wellbore pressures Observed well static Pull Other completion type completion, 2-7/8in O.D. Removed Tubing hanger Observed 20.00 klb overpull Fluid system Circulated at 8880.0 ft Began precautionary measures attempt to circ no go 2500g Slickline wireline work Conducted slickline operations on Slickline equipment - Tool run Completed run with Tubing punch from 8810.0 ft to 8809.0 ft Pull Single completion, 2-7/8in O.D. Removed Tubing hanger Equipment work completed Circulated at 8880.0 ft Hole displaced with Seawater - 100.00 % displaced Pulled Tubing in stands to 8880.0 ft Hanger assembly laid out Installed Tubing handling equipment Equipment work completed Retrieved ESP Pull Single completion, 2-7/8in O.D. (cont...) Held safety meeting Completed operations Retrieved ESP Retrieved 0.0 ft from ESP recoverd 143 lasalle clamps,4 protectilizers Laid down 67.0 ft of Tubing Completed operations Pull Single completion, 2-7/8in O.D. Rigged down sub-surface equipment - ESP Equipment work completed Run Single completion, 2-7/8in O.D. Ran Tubing in stands to 0.0 ft Stopped · To hold safety meeting Run Single completion, 2-7/8in O.D. Held safety meeting Completed operations Ran Tubing in stands to 300.0 ft Stopped · To change handling equipment RIH w/ESP Serviced Electric cable Equipment work completed C/O ESP sheeve, repair armor on cable, Centralift had wrong sheeve to start Ran Tubing in stands to 1165.0 ft Stopped' To splice cable Serviced Electric cable Equipment work completed Facility M Pt E Pad Progress Report Well MPE-04 Page Rig Nabors 5S Date 3 23 December 97 Date/Time 16 Oct 97 15:00-03:30 03:30 03:30-06:00 06:00 06:00-09:00 06:00-06:30 06:30 06:30-08:00 08:00 08:00-08:30 08:30 08:30-09:00 09:00 09:00-11:00 09:00-11:00 11:00 11:00-12:00 11:00-12:00 12:00 12:00-01:00 12:00-14:15 14:15 14:15-15:00 15:00 15:00-20:00 20:00 20:00-00:00 17 Oct97 00:00 00:00-01:00 01:00 01:00-06:00 01:00-03:00 03:00 Duration 12-1/2 hr 2-1/2 hr 2hr 2hr lhr lhr 13hr 2-1/4 hr 3/4 hr 5hr 4hr lhr 5hr 2hr Activity Ran Tubing in stands to 8870.0 ft Completed run with ESP to 8870.0 ft Serviced Electric cable Stopped: To hold safety meeting Splice ESP cable Run Single completion, 2-7/8in O.D. (cont...) Held safety meeting Completed operations Ran Tubing on landing string to 8870.0 ft Hanger landed Retrieved Tubing landing string Completed operations Tested Tubing hanger Pressure test completed successfully - 5000.000 psi Tested hanger to 5000 psi/10 minutes Nipple down All functions Rigged down BOP stack Equipment work completed Set TWC, blow down all surface lines,N/D Planned maintenance Held safety meeting Completed operations PJSM on well head work, cleaned rig Wellhead work Installed Xmas tree Equipment work completed Tested Xmas tree Pressure test completed successfully - 5000.000 psi Tested flange and tree to 5000 psi/10 minutes Serviced Swab valve Equipment work completed Pull TWC,R/U to U-tube, swab valve on tree will not function, wait for wells group to check valve, valve ok Circulated at 8870.0 ft String displaced with Diesel - 100.00 % displaced Pump 80 bbl diesel down tbg @ .6 bpm/2000 psi, cleaning pits Monitor pressures Resumed operations U-tube diesel freeze protect, cont cleaning pits Wellhead work Installed Xmas tree Equipment work completed Set BPV, C/O tree cap, finish cleaning pits, Rig released at 03:00 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX/ARCO Well Name: MPE-04 Rig Name: N-4ES AFE# 339045 Accept Date: 05/09/97 Spud Date: . Release Date: 05/12/97 MAY 09, 1997 RIG ACCEPTED @ 1100 HRS. RIG UP LUB PULL BPV RIG UP HD LINES TO TREE & TT, TAKE ON SOURCE WATER F/WELL KILL. TEST SURF LINES TO 3000#, TBG PRESS = 160# ANNULI = 160#. BLEED BOTH DOWN TO "O". CIRC SOURCE WATER THRU GLM @ 8737' LOST 120 BBLS, MIX LCM PILL (2.5# XANVIS, 15# BARAFIBER, 2# FL7., 10# BARACARB, 15# OM SEAL) SPOT PILL @ PERFS, CONT WELL KILL NO FLUID LOSS INSTALL TWC ND COMP TREE NU BOP RIG UP TEST BOP 250# 5000# AOGCC WAIVE WITNESS TEST. PULL TWC, INSTALL LANDING JT BK OUT LDS, LD HANGER LANDING JT POOH W/2 7/8" COMPL. MAY 10, 1997 LUB RIG, TOH W/2 7/8" TUBING W/ESP ASSY. RIH UP HOWCO W/GAUGE RING JUNK BASKET MADE FOUR RUNS RECOVERED 19 ESP BANDS LAST RUN TAG TOP TBG STUB @ 8905' SLIP CUT 42' DRL LINE. MU SERVICE ESP ASSY. RIH W/2 7/8" TUBING ESP ASSY. CHANGE OUT CABLE SPOOL/MU CABLE SPLICE CONT RIH W/2 7/8 TUBING ESP ASSY/MU HANGER & SPLICE. MAY 11, 1997 MU ESP CABLE TO PIGTAIL TEST LINE CK OK. LAND TUBING RILDS LD LANDING JT INSTALL TWC. NU BOP, NU TREE TEST TREE ADAPTER FLNGE TO 5000# TEST SURFACE LINES TO 3000#. PULL TWC, INSTALL BPV A'I'TEMPT TO BULL HEAD FREEZE PROTECT NO GO, PRESS UP TO 2800# PULL BPV, ATTEMPT TO CIRC FREEZE PROTECT COMMUN THRU DBLE ORFACE VALVE ** ESP BAD CK INSTALL TWC ND COMP TREE NU BOP. TEST BOP MU LANDING JT BOLDS PULL HANGER TEST ESP BELOW SPLICE CK BAD RU TO PULL ESP ASSY. POOH W/ESP LD ESP MOTOR MU SERVICE NEW ESP MOTOR RIH W/2ND ESP. MAY 12, 1997 LUB RIG, RIH W/2 7/8" ESP COMP. MU ESP SPLICE @ 8000' IN CONT RIH, MU HANGER & LANDING JT. SPLICE PIGTAIL @ HANGER & LANDING JT. SPLICE PIGTAIL @ HANGER TEST OK. LD HANGER RILDS, INSTALL TWC. ND BOPS, NU TREE. TEST ADAPTER & COMP TREE TO 5000# TEST SURFACE LINES TO 3500#, MAKE FINAL CK ON ESP OK. DISPL WELL W/DIESEL FREEZE PROTECT DOWN TUBING @ .5 BPM/110 BBLS CLEAN PITS SECURE WELL. RIG RELEASED @ 2100 HRS. Page 1 of 1 MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission David Joh~ DATE: October 13, 1997 Chairman THRU: Blair Wondzeil, ~ FILE NO: P. I. Supervisor ; ~/~ aw9kjiee.doc FROM: Chuck Scheve, ¢ .5 SUBJECT: Petroleum Inspector BOPE Test Nabors 5S MPU E-4 PTD # 90-05 Sunday August 31~ 1997: I traveled to BPX's MPU E-4 Well and witnessed the initial BOPE test on Nabors Rig 5S As the attached AOGCC BOPE test report shows the test lasted 7 hour__....._,s with 3 failures. The 3 failures were all minor flange leaks that were easily tightened and retested. This was the initial test on this rig since Nabors bought it several years ago. The crews are very inexperienced and will require time to learn to work together. To Nabors credit they have an extra supervisor from another rig assigned to this project to develop written procedures and assist in training the crews. The rig was clean and all related equipment appeared to be in good working order. The location though crowded was well organized. Summary: I witnessed the initial BOPE test on Nabors Rig 5S working over Well MPU E-4 Nabors SS, 10113/97, Test time 7 hours, 3 failures Attachment: aw9kjiee.xls X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg:_____ Workover: X DATE: 10/13/97 Drlg Contractor: Nabors Rig No. 5S PTD # 90-0005 Rig Ph.# 659-4456 Operator: BPX Rep.: Jessie New Well Name: MPU E-4 Rig Rep.: David Rhodes Casing Size: Set @ Location: Sec. T. R. Meridian Test: Initial X Weekly Other , . ~ Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location ,, , , Standing Order Posted Yes Well Sign Drl. Rig OK Hazard Sec. OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. N/A Pressure 250/5, 000 250/5, 000 P/F N/A N/A . P ~ P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F P 1 250/2500 I 250/5, 000 N/A N/A I 250/5, 000 1 250/5, 000 , , ,, , 2 250/5, 000 ,25o/5,o0o , N/A , ,,N/A N/A P CHOKE MANIFOLD: No. Valves No. Flanges 28 Manual Chokes Hydraulic Chokes 1 Test Pressure P/F 250/5, 000 P 250/5, 000 P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure 3000 I, Pressure After Closure 2200 I MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 25 Trip Tank , O,,K OK System Pressure Attained 1 minutes 30 ..,, Pit Level Indicators OK OK Blind Switch Covers: Master: OK Remote: Flow Indicator OK O,K,,, Nitgn. Btl's: 4 (~ 3175 PSI Meth Gas Detector OK OK Psig. , . - H2S Gas Detector OK OK sec. sec. OK Number of Failures: 3 ,Test Time: 7.0 Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 IIIII I II IIII IIII , I IIII IIIII I II 21 i ii ii ii iii REMARKS: 3 Minor flang, e,, ,leaks II I III I I II. I I I I Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector FI-021L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: . AW9KJIEE.XLS Chuck Scheve STATE OF ALASKA AIJ'~or~, OIL AND GAS CONSERVATION COMMI,~[~I REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown .. Stimulate .. Plugging__ Pull tubing ~(_ Alter casing __ Repair well Othe7//?~ / 6. Daturr{~evation (DF 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service or KB) 7. Unit or.RreDerty name feet 4. Location of well at surface 1343' SNL, 1995' WEL, SEC. 25, T13N, RIOE At top of productive interval 2133' SNL, 1988' WEL, SEC. 30, T13N, RIOE At effective depth 2037' SNL, 1464' WEL, SEC. 30, T13N, R11E At total depth 2036' SNL, 1464' WEL, SEC. 30, T13N, RIOE 8. Well number MPE-04 9. Permit number/approval number 90-5/Cons. Order #347 10. APl number 50- O29-21997 11. Field/Pool Prudhoe Bay Field/Off Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 9891 feet Plugs (measured) 7640 feet feet Junk (measured) feet Size Cemented 2-7/8", L-80 Tubing to 8871' MD Measured depth True vertical depth RECEIVED A!sska 0ii & Gas Cons. Commission Anchor; Packers and SSSV (type and measured depth) Otis 7" HCM Packer @ 8945' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run . Daily Report of .Well Operations x Oil x Gas__ Suspended 17. I hereby certify/tfhat the foregoing is true and correct to the best of .Si~lned ~ ' "~ ~ Form 10-404~Rev036/15~88 my knowledge. Title Drilling En~ineer Supervisor Service Date SUBMIT IN DUPI~CAfE 3P/ALI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MPU E-04 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 01/07/95 08:00 SPUD: RELEASE: 01/10/95 02:00 OPERATION: DRLG RIG: WO/C RIG: NABORS 4ES 01/07/95 (1) TD: 9880 PB: 9657 SPOT RIG OVER MPU E-04 MW: 0.0 WAIT ON PRE-RIG WORK PREP. MOVE RIG FROM MPU E-06 TO MPU E-04 AND SPOT OVER WELL. 01/08/95 (2) TD: 9880 PB: 9657 01/09/95 (3) TD: 9880 PB: 9657 01/10/95 ( 4) TD: 9891 PB: 9657 RIG LUBRICATOR TO PULL TWC MW: 0.0 RAISE AND SCOPE DERRICK, BERM RIG AND TANKS. MU HARD LINE TO THRASH TANK AND TE=REE. RU LUB PULL BPV. RD LUB. REPAIR LINER WASH PUMP. TEST LINES. BLEED GAS OFF ANNULUS TO THRASH TANK. CIRC DN TBG. TAKING RETURNS TO THRASH TANK. W/ CRUDE AND GAS, KILL WELL. ND TREE INSTALL NEEDLE VALVE ON CONTOL LINE AND OPEN SSSV. NIPPLE UP BOPS AND RIG UP TO TEST. CHG PACING ON RILDS AND TEST BOPS. RIG UP OFFSET LUBRICATOR TO PULL TWC. POH W/ 2 7/8" TBG MW: 0.0 PULL TWC AND R/D LUBRICATOR. RIG LANDING JT AND BOLDS. PULL HGR FREE AND CONT TO PULL ON SBR 10 130K COULD NOT GET SBR TO GIVE ANY FREE TRAVEL. RIG ATLAS. RIH W/ CUTTER GET ON DEPTH WITH CCL CUT TBG @ 8905'. POH W/ WIRELINE. HANGING IN SSSV VALVE. ATTEMPT TO OPEN SSSV AND PULL TOOL THROUGH BY CIRC DOWN THROUGH TBG. DID GET TOOL INTO VALVE BUT DUE TO LARGER OD AT BOTTOM OF TOOL UNABLE TO GET THROUGH. RIG SHEAVE IN DERRICK AND HANG LUBRICATOR ON AIR HOIST AND PULL TBG HGR TO RIG FLOOR AND REPAIR SSSV CONTROL LINE THAT HAD EVIDENTLY BEEN DAMAGED BY STABBING LUBRICATOR TO PULL TWC. PRESSURE SSSV AND OPEN. PULL ATLAS TOOL OUT OF HOLE AND VERIFY ALL TOOL RECOVERED AND CHEMICAL SHOT. RIG DOWN ATLAS. LOOSING 60 BBLS OF LUID PER HOUR AFTER CUTTING TBG EVIDENTLY PLUG IN TAIL PIPE BLOWN WHEN CUTTER FIRED. LAY DOWN HANGER AND PUMP 50 BBL XANVIS PILL AND SPOT ON BOTTOM. POH W/ 2 7/8" TBG, DRIFT AND STRAP SAME. HANG TBG AND RILDS TEST HGR MW: 0.0 LUB RIG. POH W/ TBG LAY DOWN ALL COMP EQUIP AND NORM INSPECTION. CUT JT 8905' HAD A REAL NEAT CUT. RIG UP TO RUN ESP. MU AND SERVICE ESP. RIH W/ ESP AND TOTAL OF 277 JT 2 7/8" 6.5# L80 8RD EUE TBG. MAKE UP HANGER AND SPLICE ESP CABLE TO PENETRATOR AND CHECK. LAND TBG AND RILDS AND TESTING HGR. ~ELL : MPU E-04 OPERATION: RIG : NABORS 4ES PAGE: 2 01/11/95 ( 5) TD: 9880 PB: 9657 RELEASE RIG MW: 0.0 LUB RIG. RILDS AND TEST HANGER SEALS. ST BPV. ND BOP STACK. NU TREE. TEST ADAPTER FLG AND TREE AND CHECK ESP PENETRATOR. FILL ANNULUS AND PUMP 13 BBLS INTO FORMATION TO ASSURE THAT PLUG DISK WAS RUPTURED. LET ANNULUS GO ON VACUUM. HOLE IS TAKING A VERY TRIVIAL AMOUNT OF FLUID. RIG LUBRICATOR AND PULL TWC. PUMP 65 BBL DIESEL DOWN ANNULUS TAKING RETURNS FROM TBG AND PUMP 15 BBLS DOWN TBG. SET BPV. SECURE TREE. RIG DOWN AND SECURE CELLAR. CLEAN PITS. RELEASE RIG @ 1400 HRS ON 01/10/95. SIGNATURE: (drilling superintendent) DATE: Oil & G~s Cons. Commission Anc~.or~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP MPE-04 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Date: RE: 16 January 1995 Transmittal of Data ECC #: 6343.00 Sent by: MAIL Data: CCL Prints/Films: CCL/CH.CUT FNL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnst_~_t~'''~, DATE: Chairm~__..~ January 8, 1995 THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor ,('~¢_le¢' FROM' Lou Grimaldi,/~ SUBJECT: Petroleum Inspector QW9JAHCD.DOC Rig BOPE inspection Nabors 4-ES BPX well # E-4 Miine Point Unit PTD # 90-5 Sunday, January 8, 1995: I traveled to BPX E pad in the Milne Point Unit to make a Rig BOPE inspection on Nabors rig 4-ES. The rig was Preparing to pull tubing and was rigging up E-line when I arrived. I found all BOPE equipment to be in place and in apparent good condition. Larry Meyers (Company Rep.) and Gene Sweat (Nabors Toolpusher) do a good job of maintaining this rig. Access to the rig was fair considering the small size of the pad. The location surrounding the rig was clean and orderly. SUMMARY: I made a Rig/BOPE inspection on Nabors 4-ES with all equipment aPpearing to be in compliance. Attachments: QW9JAHCD.XLS cc: Scott Sigurdsen / Steve Horton (Prudhoe Bay drilling) qO 5 (e.) ~ ,~' ~nao,eea,~on z~er~ (~.) e,~o~n~ ~(~) FI-032 (Rev, 3/93) QW9J^IICD.×LS FROM~ Lineberger, Van TO: Hastings, A1 Soptei, Bob Stock, Wade L. ,ECEiVED 2 8 1991 AJaska Oil & 6as Cons. Com~i~Jo~, Anchorage " CC: Andrew, Jim Shannon ~ Marc erpas, wayne U;"'ANNc/~EP~NA Stevens, Hal D. ANNC/MPEPNA Wilson, Don L. ANNC/MPEPNA SrJGJEOT: M~U E 4 WELL I~E~/iSF~D ~I~L FOR AOCCC PRIORITY: ATTACHMENTS: SERT GROUP: DATE: 05-24-91 TIME: 09:31 ST~VE MCMAHON WITH THE AOGCC CONTACTED HAL STEVENS AND QUESTIONED THE BHL INFORMATION SUBMITTED WITH THE MPU ~-4 WELL 407. APPARENTLY, THE PROPOSED BHL INFORMATION WAS TRANSCRIBED AND SUBMITTED AS ACTUA/~7'M~AS~TfED"~AT~- ·LEASE CONTACT MCMAHON W.I']'H '['H~ K~;],i,~;W]~ ~0~T~D DA~A~ 4. LOCATION OF WELL AT SURFACE 1343~ FNL, 199S* FEL~ SEC. 25, T13N, R10E, U.M., NSB 2133' FNL, 1987' FEL, SEC. 30, T13N, AT TOTAL D~PTH 2038' FNL, 1~48' FET,, SEC. 30, THANKS, VAN ORIG AL Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99,503 (907) 564-760O May 16, 1991 Mr. David Johnston Commissioner, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: RE: Sundry Approval Applications Attached please find Sundry Approval Applications for Wells L-2 and E-4 at the Milne Point Unit. If you have any questions or require additional information please contact me at 564- 7617. Yours very truly, Bob Soptei Coordinator- Environmental Affairs RJS(jcd) Attachments cc Well Files RE'[EIV£D MAY ~ 0 t991 Alaska Oil & Gas Cons. Oommiss'toa Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATIO# FOR $11#DRY APPROVALS 1. Type of Request: Abandon__ Suspend __ Alter casing __ Repair well Change approved program Operation shutdown Re-enter suspended well Plugging __ Time extentJon __ Stimulate ~ Pull tubing m Vadance __ Perforate ~ Other X Install ESP Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 Location of well at surface 1343' FNL, 1995' FEL, Sec. 25, T13N, RIOE, U.M. At top of productive interval 2133' FNL, 1988' FEL, Sec. 30, T13N, R11E, U.M. At effective depth 2037' FNL, 1464' FEL, Sec. 30, T13N, R11E, U.M. At total depth 2036' FNL, 1464' FEL, Sec. 30, T13N, R11E, U.M. ,5. Type of Well: Development X Exploratory __ Stratigraphic ~ 6. Datum elevation (DF or KB) 56' KDB 7. Unit or Property name Milne Point Unit 8. Well number E-4 9. Permit number 90-5 lO. APl number 50-029-21997 11. Field/Pool Kuparuk River Field feet 12, Present well condition summary Total depth: measured 9891' feet true vertical 7640' feet Plugs (measured) Effective depth: measured 9880' feet true vertical 7631' feet Junk (measured) 9769' Casing Structural Conductor Surface Intermediate Production Uner Perforation Depth: Length Size 80' 13-3/8" 5707' 9-5/8" 9846' 7" measured 9048-9090'; 9116-9150' Cemented Measured depth True vertical depth To Surface 114' 114' 55 bbl Class C 5741' 4566' 406 bbl Permf E 125 bbl Class C 9880' 7604' true vertical 6990-7022'; 7041-7067' Tubing (size, grade, and measured depth) 2-7/8", L-80, 8945' Packers and SSSV (type and measured depth) Otis FMX SCSSV @ 558'; I ECEIVED MAY 2 0 t99 Alaska Oil & Gas Cons. Commission Anchorage Otis HCM Pkr. 8945' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation July 15, 1991 16. If proposal was verbally approved Oil X Name of approver / Date approved Service 17. I hereby certi~j that t/~e foregoing is true and correct to the best of my knowledge. ! /I Signed L_.~ //~,O~%j J.H. Andrew Title Production Engineer 15. Status of well classification as: Gas ~ Suspended May 14, 1991 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Su'---bsequent Mechanical Integrity Test form required 10- ~:~ Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SM!TH Commissioner Date ]Approval No.?/... /~, ~3r O~ ~' C~ Form 10-403 Rev 06/15/88 ~_______~/~~___~/~~.~[~ ! 2..--' //---' ~.~--- SUBMIT IN TRIPLICATE Milne Point Unit E-4 Well ESP Conversion Procedure Summary lo Bleed casing pressure to zero. RU wireline. GIH and pull gas lift valves from mandrels at 8677' 7903' 6606' and 4295' Install dummies in the upper three mandrels. · Kill well by pumping 10.0 ppg NaBr/NaCl brine down casing and taking returns up tubing. Spot salt-based LCM pills, if necessary, to control fluid losses. · GIH and install dummy valve in the mandrel at 8677'. POOH and RD wireline. 4. MIRU rig. 5. ND tree. NU and test BOP's. · MU landing joint to tubing hanger. PU tubing 20' to slide off of PBR. Monitor well. 7. POOH and LD 2-7/8" production tubing. 8. MU ESP assembly and TIH on 2-7/8" production tubing. · MU a dual packer with BIW penetrator on short string side. Install a 2-7/8" tubing retrievable SCSSV in the production string above the packer and a 2-7/8" gas lift mandrel one joint below the packer. Space out to place SCSSV at least 500' below ground level. 10. Land production tubing hanger and freeze protect annulus. 11. RU wireline and set a plug in an Otis X nipple located below the production packer. Pressure up against the plug to set the packer. POOH with plug and RD wireline. 12. Pressure test casing and packer mechanical integrity by pressuring up to 1850 psig in presence of AOGCC. Hold pressure for 30 minutes. Bleed to zero. 13. Freeze protect tubing. ND BOP's, NU and test tree. 14. RDMO rig. RU and test flowline. Return well to production. MAY ..?_ 0 t99 OiJ & Gas Cons. Commission Anchorage Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 April 29, 1991 Mike Minder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Milne Point Unit E-4 Form 407 Dear Mr. Minder: Enclosed you will find a Form 10-407 for our Milne Point Unit E-4 well. As you can see this well was completed last year in May. The completion was reported on a Form 10-404 that is enclosed. This error was discovered while reviewing records and verbally reported to your office. If you have any questions, please contact Van Heare or me at 659-6322. Hal Stevens Senior Production Specialist cc well file 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE 2. Name of Operator ~ "/!]~i~[P,~ 7. Permit Number CONOCO INC. POUCH 340045, Prudhoe Bay, ~ 99734 50-029-21997 ¢~--' . 4. Location of well at surface ~ ~-~'~P~ ~: r;75:' ,9. Unit or Lease Name ~ ~i~,~ Milne Point Unit 1343' FNL, 1995' FEL Sec. 25 T13N, R10E, U.M. NSB~~ At Top Producing Interval ~ ~ ~ 10. Well Number 2130' FNL, 1988' FEL, Sec. 30, T13N, RIlE ~ 20~' FNL, ~' FEL, Sec. 30, T13N, RilE Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. 55' KB MSL~ ADL 28231 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1-7-90 1-24-91 5-14-90 NA feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (M~D) 19. Directional Survey ~ 20. Depth whereSSSV set 21. Thickness of Permafrost L 9900'~ 7616'T~ 9789'~ 7533'TVD YES~ NO~~ 558 feetMD ~ 1800' , , 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING $IZ~ WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 48 H-40 0' (GL) 80' 30" 500 sx PermaFrost C NONE 9-5/8" 36 J-55 O' 5741' 12-1/4" ~06 BBL PermaFrost E NONE 70 BBL Premium G 7" 26 L-80 O' 9880' 8-1/2" 125 BBL Premium G NONE 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD ~ ~ ....... interval, size and number) ~ DEPTH SET (MD) PACKER SET (MD) ~ -1 9048~ - 9090~ ~ ;'~' ~'~ ~''~ 8945 .... 6990' - 7021' TVD ~.~.'~' ~ (~7~ ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~l;~a{~ (.)*, 'DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED MK -2 9116' - 9150' ~ ¢ .... 27. PRODUCTION TEST Date First Production } Method of Operation (Flowing, gas lift, etc.) 5-15-91 DateofTest HoursTes~ed PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE [GAS-OILRATIO 5-16-91 24 TEST PERIOD ~ 2092 510 0 64/64] 244 Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (corr) P~ss. 235 NA 24-HOUR RATE ~ 2092 510 0 22.0 , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE ..... STATE OF ALASKA 0 R 16 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top of MK-1 9048' 6990' NONE Top of MK-2 9116' 7041' 31. LIST OF ATTACHMENTS Plat, Gyro Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Sr. Prod. Foreman Date 4-29-91 ____ 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 STA~ P~ANE COQRO[NATE~ ARE Z0,NE ~. ALL GEOEIE[~C POSIT~oNS ARE. N.A.D, ;97.7. ._EC,,0N CORNER POSI,~ONS. N',, \ .., .o '·,.. Iv,, · ~.~ x,,,j ~ MILNE FT. VICINITY ,MAP MILES i i LOCATION i ~',,i SECTION 2¢--',_,. T. ",~: N.. R, 10 r-,,, iJ.M., ALASKA ! '~LL i FROM NORTH LiNE , E---6i 1,4.46' ~ E-7 I 1493' i E-a ! '~194.' i 1914' 1877' 2107' E PAD STA% PLANE 000fiDI~,IATES ZONE ,1 5,016,371.44 6,016,32~.6~ ~'AST (x) 569.Z~0.07 569,267.62 569,0~4.~5 LEGEND EXIS .'FN C, WELL ~EC)DE~C POSITIONS NAD !92.7 WELL NORTH LA I'ITUOE. '¢~.$T LONGI'T'ODE. E-7 E:-8 70' 27' 18.506" 70" 27' 1,'.~2" 70' 27' 20.782" I~9' 26' 06.159" :49' 26' !49' 26' 11.818" III, PROP OSED WELL E-6, E-7 & LOCATIONS E-8 SURVEYED FOR: ..,ATE: 5-1-9! DRAWN: STOI. t. CHECKED: VAIL JOB NO.: go-o5~ ~ SCALE; 1' = 300' · 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 E-4 COMPLETION: DATE OPERATION 05/08/90- 05/09/90 05/10/90- 05/11/90 05/12/90- 05/14/90 05/15/90- 05/20/90 05/21/90 05/23/90 05/26/90 EOR RESPECTFULLY, J.D. POLYA DRILLING FOREMAN MIRU. N/D TREE, N/U AND PRESSURE TEST BOP'S. BIT AND SCRAPER RUN AND CASING WASH. RIH W/ PERFORATING GUNS AND GAS LIFT MANDRELS. TEST SCSSV. SPACE OUT AND LAND HANGER. SET PACKER. N/D BOP's AND N/U AND TEST TREE TO 5000 PSIG -- OK. RIG DOWN WORKOVER RIG. DROP BAR AND DETONATE PERFORATING GUNS. FLOW TEST AND CLEAN UP WELL. FLOW TEST WELL. SHUT WELL IN. HOOK UP TEST SEPARATOR TO WELL AND TIE IN TO PRODUCTION LINE. OPEN WELL TO FLOW TEST. SHUT WELL IN, R/U WIRELINE UNIT, RIH, AND DROP TUBING CONVEYED GUNS INTO RATHOLE. OPEN WELL BACK UP TO FLOWTEST. Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 May 10, 1990 Mr. Lonnie Smith Alaska Oil &. Gas Conservation Commission 301 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Enclosed is a copy of the Gyro Survey run on the E-4 Well (Milne Point) on 4/30/90. Sincerely, Drilling Foreman cl Encl. RECEIVE ~f~'~.si'~a Oil & Gas Cons. Commissior~ '. gnch0rag~a May 1, 1990 Mr. Joe Polya Mr. Dave Mountjoy Conoco, Inc. Pouch 340045 Prudhoe Bay, AK 99734 Re: Our Boss Gyroscopic Survey Job No. AK-BO-00054 Well: E-4 Milne Pt., Alaska Survey Date: 04/30/90 Operator: D. Harger Dear Gentlemen: 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. Enclosures Sincerely, Ken Broussard Area Manager 8537 Corbin Drive (99507) · P.O. Box 231649 ° Anchorage, Alaska 99523 (907) 522-3256 ° Fax (907) 522-3432 A Baroid Company CONOCO, INC. E-4 MILNE POINT ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA 5/ 1/90 DATE OF SURVEY: 4-30-90 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-00054 KELLY BUSHING ELEV. = 58.00 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. 0 .00 -58.00 0 0 N .00 E .00 .00 .00 .00 100 100.00 42.00 0 45 N 9.70 E .76 .65N .liE .03 200 199.99 141.99 0 45 N 3.60 E .08 1.96N .26E .01 300 299.98 241.98 0 30 N 39.60 E .45 2.96N .59E .21 400 399.97 341.97 1 4 N 51.40 E .58 3.88N 1.60E 1.09 500 499.94 441.94 1 31 N 61.20 E .51 5.11N 3.50E 2.82 600 599.85 541.85 3 5 N 77.20 E 1.68 6.35N 7.31E 6.43 700 699.56 641.56 5 22 N 83.60 E 2.32 7.47N 14.60E 13.52 800 798.88 740.88 7 47 N 83.80 E 2.42 8.72N 25.98E 24.65 900 897.61 839.61 10 26 N 86.30 E 2.68 10.04N 41.77E 40.13 1000 995.22 937.22 14 31 N 88.70 E 4.11 1100 1091.49 1033.49 16 47 N 89.70 E 2.30 1150 1139.06 1081.06 19 1 S 87.80 E 4.72 1200 1185.87 1127.87 22 7 S 85.70 E 6.35 1300 1277.69 1219.69 24 28 S 84.10 E 2.44 10.91N 63.35E 61.43 11.27N 90.33E 88.14 ll.00N 105.70E 103.42 9.98N 123.24E 120.95 6.44N 162.62E 160.46 1400 1367.40 1309.40 27 56 S 85.00 E 3.48 1500 1455.33 1397.33 28 55 S 85.10 E .99 1550 1498.40 1440.40 32 6 S 85.30 E 6.36 1600 1540.19 1482.19 34 27 S 85.30 E 4.68 1700 1622.11 1564.11 35 31 S 84.90 E 1.09 2.26N 206.59E 204.59 1.85S 254.02E 252.16 3.97S 279.32E 277.53 6.22S 306.66E 304.93 11.12S 363.78E 362.21 1800 1702.23 1644.23 37 58 S 85.20 E 2.46 1900 1780.41 1722.41 39 10 S 84.50 E 1.28 2000 1856.42 1798.42 41 51 S 83.30 E 2.80 2100 1930.02 1872.02 43 20 S 82.20 E 1.67 2200 2002.44 1944.44 43 50 S 81.30 E .79 16.27S 423.37E 421.97 21.87S 485.46E 484.26 28.79S 550.05E 549.20 37.34S 617.19E 616.89 47.24S 685.43E 685.83 2300 2073.91 2015.91 44 55 S 80.30 E 1.29 2400 2144.52 2086.52 45 15 S 79.40 E .72 2500 2214.95 2156.95 45 12 S 81.80 E 1.70 2600 2285.74 2227.74 44 40 S 82.00 E .55 2700 2358.27 2300.27 42 18 S 81.90 E 2.36 58.43S 754.47E 755.73 70.91S 824.17E 826.46 82.50S 894.19E 897.39 92.45S 964.12E 968.01 102.09S 1032.25E 1036.82 2800 2432.49 2374.49 41 51 S 82.20 E .49 2900 2506.79 2448.79 42 9 S 82.10 E .31 3000 2580.83 2522.83 42 18 S 81.80 E .25 3100 2654.43 2596.43 42 54 S 81.10 E .76 3200 2727.62 2669.62 43 0 S 80.80 E .23 111.36S 1098.62E 1103.84 120.50S 1164.92E 1170.76 129.91S 1231.48E 1237.97 139.98S 1298.42E 1305.65 150.70S 1365.71E 1373.76 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 CONOCO, INC. E-4 MILNE POINT ALASKA COMPUTATION DATE: 5/ 1/90 DATE OF SURVEY: 4-30-90 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-00054 KELLY'BUSHING ELEV. = 58.00 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. 3300 2800.88 2742.88 42 46 S 80.80 E .23 3400 2874.36 2816.36 42 39 S 80.30 E .36 3500 2947.75 2889.75 42 55 S 79.40 E .67 3600 3021.35 2963.35 42 17 S 78.50 E .88 3700 3095.01 3037.01 42 49 S 77.30 E .97 161.58S 1432.90E 1441.79 172.72S 1499.81E 1509.58 184.69S 1566.67E 1577.42 197.66S 1633.11E 1644.97 211.84S 1699.24E 1712.38 3800 3167.62 3109.62 44 2 S 76.60 E 1.30 3900 3239.57 3181.57 43 55 S 75.40 E .84 4000 3311.39 3253.39 44 15 S 74.80 E .53 4100 3383.37 3325.37 43 39 S 74.20 E .73 4200 3456.36 3398.36 42 34 S 76.20 E 1.75 227.37S 1766.21E 1780.78 244.17S 1833.59E 1849.76 262.06S 1900.83E 1918.75 280.61S 1967.72E 1987.46 298.07S 2033.79E 2055.22 4300 3530.51 3472.51 41 43 S 77.40 E 1.17 4400 3605.18 3547.18 41 39 S 80.10 E 1.80 4500 3679.70 3621.70 42 0 S 79.40 E .58 4600 3753.76 3695.76 42 25 S 78.30 E .86 4700 3826.98 3768.98 43 25 S 78.40 E .99 313.40S 2099.11E 2121.96 326.37S 2164.32E 2188.30 338.24S 2229.95E 2254.91 351.24S 2295.87E 2321.95 364.99S 2362.57E 2389.86 4800 3899.40 3841.40 43 46 S 79.20 E .65 4900 3971.70 3913.70 43 37 S 78.00 E .84 5000 4043.84 3985.84 44 2 S 77.60 E .50 5100 4115.58 4057.58 44 16 S 77.30 E .32 5200 4187.53 4129.53 43 42 S 75.70 E 1.25 378.38S 2430.21E 2458.66 392.03S 2497.92E 2527.57 406.67S 2565.61E 2596.57 421.81S 2633.61E 2665.95 438.01S 2701.14E 2735.00 5300 4259.71 4201.71 43 53 S 74.70 E .72 5400 4332.04 4274.04 43 27 S 74.30 E .52 5500 4404.56 4346.56 43 35 S 74.10 E .20 5600 4476.81 4418.81 43 53 S 74.50 E .41 5700 4548.99 4490.99 43 42 S 73.80 E .52 455.69S 2768.05E 2803.62 474.15S 2834.59E 2871.98 492.89S 2900.84E 2940.09 511.60S 2967.40E 3008.50 530.50S 3033.98E 3076.95 5800 4621.01 4563.01 44 9 S 74.20 E .54 5900 4692.30 4634.30 44 53 S 74.40 E .74 6000 4763.48 4705.48 44 20 S 75.20 E .78 6100 4834.81 4776.81 44 37 S 75.80 E .50 6200 4905.84 4847.84 44 50 S 76.40 E .48 549.63S 3100.67E 3145.54 568.60S 3168.17E 3214.92 587.02S 3235.95E 3284.50 604.56S 3303.80E 3354.04 621.47S 3372.13E 3423.97 6300 4976.57 4918.57 45 7 S 76.50 E .29 6400 5046.79 4988.79 45 39 S 77.00 E .63 6500 5117.51 5059.51 44 19 S 77.80 E 1.44 6600 5189.79 5131.79 43 5 S 78.70 E 1.38 6700 5262.56 5204.56 43 30 S 78.60 E .42 638.04S 3440.86E 3494.26 654.35S 3510.15E 3565.07 669.78S 3579.14E 3635.47 683.85S 3646.79E 3704.36 697.35S 3714.04E 3772.79 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 CONOCO, INC. E-4 MILNE POINT ALASKA COMPUTATION DATE: 5/ 1/90 DATE OF SURVEY: 4-30-90 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-00054 KELLY BUSHING ELEV. = 58.00 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. 6800 5335.00 5277.00 43 38 S 78.70 E .15 6900 5407.42 5349.42 43 34 S 78.30 E .28 7000 5479.60 5421.60 44 0 S 78.70 E .52 7100 5551.44 5493.44 44 9 S 78.80 E .16 7200 5623.20 5565.20 44 7 S 78.50 E .21 710.92S 3781.62E 3841.55 724.67S 3849.20E 3910.34 738.46S 3917.01E 3979.36 752.04S 3985.24E 4048.76 765.74S 4053.52E 4118.24 7300 5694.77 5636.77 44 28 S 79.00 E .49 7400 5766.06 5708.06 44 35 S 78.80 E .19 7500 5837.09 5779.09 44 53 S 79.00 E .33 7600 5908.49 5850.49 43 59 S 80.80 E 1.55 7700 5980.93 5922.93 43 10 S 83.30 E 1.91 779.37S 4122.02E 4187.92 792.87S 4190.84E 4257.90 806.42S 4259.91E 4328.14 818.70S 4328.83E 4398.06 828.25S 4397.08E 4466.98 7800 6054.04 5996.04 42 52 S 85.40 E 1.46 7900 6127.45 6069.45 42 39 S 87.80 E 1.64 8000 6201.39 6143.39 41 58 S 88.60 E .87 8100 6275.80 6217.80 41 51 S 89.80 E .81 8200 6350.26 6292.26 41 53 N 89.40 E .53 834.97S 4464.96E 4535.16 838.99S 4532.73E 4602.88 841.11S 4600.02E 4669.89 842.05S 4666.82E 4736.25 841.81S 4733.57E 4802.42 8300 6424.96 6366.96 41 27 N 88.10 E .97 8400 6500.42 6442.42 40 33 N 86.50 E 1.38 8500 6576.48 6518.48 40 24 N 85.50 E .67 8600 6652.23 6594.23 41 5 N 84.50 E .95 8700 6727.65 6669.65 40 58 N 83.60 E .60 840.37S 4800.03E 4868.15 837.28S 4865.56E 4932.75 832.76S 4930.33E 4996.40 827.06S 4995.36E 5060.16 820.26S 5060.66E 5124.05 8800 6802.91 6744.91 41 24 N 82.80 E .67 8900 6878.17 6820.17 40 57 N 82.40 E .51 9000 6953.61 6895.61 41 5 N 81.40 E .67 9100 7028.79 6970.79 41 24 N 80.20 E .85 9200 7104.25 7046.25 40 36 N 80.10 E .79 812.46S 5126.05E 5187.91 803.98S 5191.34E 5251.57 794.73S 5256.33E 5314.84 784.18S 5321.41E 5378.03 772.96S 5386.06E 5440.71 9300 7180.37 7122.37 40 15 N 80.20 E .37 9400 7257.04 7199.04 39 37 N 80.00 E .63 9500 7334.52 7276.52 38 47 N 79.80 E .85 9600 7412.65 7354.65 38 27 N 79.50 E .38 761.87S 5449.95E 5502.65 750.83S 5513.20E 5563.96 739.75S 5575.43E 5624.26 728.53S 5636.84E 5683.72 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5683.72 FEET AT SOUTH 82 DEG. 38 MIN. EAST AT MD = 9600 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 97.36 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 CONOCO, INC. E-4 MILNE POINT ALASKA COMPUTATION DATE: 5/ 1/90 DATE OF SURVEY: 4-30-90 JOB NUMBER: AK-BO-00054 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASDVERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -58.00 1000 995.22 937.22 2000 1856.42 1798.42 3000 2580.83 2522.83 4000 3311.39 3253.39 .00 .00 .00 10.91 N 63.35 E 4.78 4.78 28.79 S 550.05 E 143.58 138.80 129.91 S 1231.48 E 419.17 275.59 262.06 S 1900.83 E 688.61 269.44 5000 4043.84 3985.84 6000 4763.48 4705.48 7000 5479.60 5421.60 8000 6201.39 6143.39 9000 6953.61 6895.61 406.67 S 2565.61 E 956.16 267.54 587.02 S 3235.95 E 1236.52 280.37 738.46 S 3917.01 E 1520.40 283.87 841.11 S 4600.02 E 1798.61 278.21 794.73 S 5256.33 E 2046.39 247.79 9600 7412.65 7354.65 728.53 S 5636.84 E 2187.35 140.96 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 CONOCO, INC. E-4 MILNE POINT ALASKA COMPUTATION DATE: 5/ 1/9o DATE OF SURVEY: 4-30-90 JOB NUMBER: AK-BO-00054 KELLY BUSHING ELEV. = 58.00 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 -58.00 .00 .00 .00 58 58.00 .00 .12 N .02 E .00 158 158.00 100.00 1.41 N .23 E .01 258 258.00 200.00 2.66 N .36 E .02 358 358.00 300.00 3.40 N 1.00 E .02 .00 .01 .01 .00 458 458.00 400.00 4.57 N 2.53 E .04 558 558.00 500.00 5.85 N 5.13 E .09 658 658.00 600.00 7.03 N 10.75 E .26 758 758.00 700.00 8.12 N 20.45 E .74 859 858.00 800.00 9.55 N 34.87 E 1.79 .02 .05 .17 .48 1.05 961 958.00 900.00 10.65 N 54.26 E 3.68 1065 1058.00 1000.00 11.22 N 80.22 E 7.01 1170 1158.00 1100.00 10.66 N 112.52 E 12.13 1278 1258.00 1200.00 7.36 N 153.71 E 20.36 1389 1358.00 1300.00 2.70 N 201.69 E 31.40 1 3 5 8 11 .89 .33 .12 .23 .03 1503 1458.00 1400.00 1.97 S 255.53 E 45.07 1621 1558.00 1500.00 7.22 S 318.84 E 63.60 1744 1658.00 1600.00 13.40 S 389.41 E 86.16 1871 1758.00 1700.00 20.12 S 467.29 E 113.10 2002 1858.00 1800.00 28.96 S 551.45 E 144.12 13 18 22 26 31 .67 .53 .55 .94 .02 2138 1958.00 1900.00 40.93 S 643.36 E 180.47 2277 2058.00 2000.00 55.75 S 738.82 E 219.53 2419 2158.00 2100.00 73.41 S 837.54 E 261.15 2560 2258.00 2200.00 88.64 S 936.96 E 302.99 2699 2358.00 2300.00 102.05 S 1032.00 E 341.63 36 39 41 41 38 .36 .05 .62 .84 .64 2834 2458.00 2400.00 114.46 S 1121.27 E 376.25 2969 2558.00 2500.00 126.95 S 1210.91 E 411.13 3104 2658.00 2600.00 140.49 S 1301.69 E 446.87 3241 2758.00 2700.00 155.23 S 1393.68 E 483.54 3377 2858.00 2800.00 170.18 S 1484.96 E. 519.76 34 34 35 36 36 .62 .87 .74 .67 .22 3514 2958.00 2900.00 186.44 S 1576.05 E 556.00 3649 3058.00 3000.00 204.38 S 1665.82 E 591.59 3786 3158.00 3100.00 225.21 S 1757.16 E 628.62 3925 3258.00 3200.00 248.64 S 1850.77 E 667.59 4064 3358.00 3300.00 274.02 S 1944.43 E 706.93 36 35 37 38 39 .24 .58 .04 .97 .34 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 CONOCO, INC. E-4 MILNE POINT ALASKA COMPUTATION DATE: 5/ 1/90 DATE OF SURVEY: 4- 30- 90 JOB NUMBER: AK-BO-00054 KELLY BUSHING ELEV. = 58.00 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 VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 4202 3458.00 3400.00 4336 3558.00 3500.00 4470 3658.00 3600.00 4605 3758.00 3700.00 4742 3858.00 3800.00 298.43 S 2035.25 E 744.22 37.29 318.75 S 2123.03 E 778.83 34.61 334.65 S 2210.75 E 812.81 33.97 352.02 S 2299.67 E 847.75 34.94 370.88 S 2391.34 E 884.72 36.97 4881 3958.00 3900.00 5019 4058.00 4000.00 5159 4158.00 4100.00 5297 4258.00 4200.00 5435 4358.00 4300.00 389.32 S 2485.15 E 923.07 38.35 409.61 S 2578.98 E 961.69 38.62 431.05 S 2673.79 E 1001.15 39.46 455.26 S 2766.46 E 1039.63 38.47 480.80 S 2858.26 E 1077.75 38.13 5573 4458.00 4400.00 5712 4558.00 4500.00 5851 4658.00 4600.00 5992 4758.00 4700.00 6132 4858.00 4800.00 506.77 S 2949.97 E 1115.91 38.15 532.91 S 3042.25 E 1154.47 38.56 559.42 S 3135.34 E 1193.64 39.17 585.65 S 3230.78 E 1234.34 40.70 610.18 S 3325.99 E 1274.58 40.24 6273 4958.00 4900.00 6416 5058.00 5000.00 6556 5158.00 5100.00 6693 5258.00 5200.00 6831 5358.00 5300.00 633.68 S 3422.72 E 1315.68 41.10 656.93 S 3521.32 E 1358.03 42.35 678.00 S 3617.57 E 1398.43 40.40 696.50 S 3709.80 E 1435.72 37.29 715.22 S 3803.12 E 1473.78 38.06 6969 5458.00 5400.00 7109 5558.00 5500.00 7248 5658.00 5600.00 7388 5758.00 5700.00 7529 5858.00 5800.00 734.37 S 3896.55 E 1511.96 38.19 753.27 S 3991.49 E 1551.14 39.18 772.45 S 4086.64 E 1590.50 39.36 791.32 S 4183.04 E 1630.68 40.18 810.39 S 4280.35 E 1671.51 40.83 7668 5958.00 5900.00 7805 6058.00 6000.00 7941 6158.00 6100.00 8076 6258.00 6200.00 8210 6358.00 6300.00 825.74 S 4375.72 E 1710.57 39.05 835.26 S 4468.63 E 1747.41 36.84 840.07 S 4560.85 E 1783.53 36.13 841.99 S 4650.87 E 1818.10 34.57 841.74 S 4740.51 E 1852.40 34.30 8344 6458.00 6400.00 8475 6558.00 6500.00 8607 6658.00 6600.00 8740 6758.00 6700.00 8873 6858.00 6800.00 839.36 S 4829.15 E 1886.06 33.66 833.99 S 4914.64 E 1917.73 31.67 826.58 S 5000.37 E 1949.66 31.93 817.32 S 5086.86 E 1982.20 32.54 806.29 S 5173.99 E 2015.29 33.09 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 7 CONOCO, INC. E-4 MILNE POINT ALASKA COMPUTATION DATE: 5/ 1/90 DATE OF SURVEY: 4-30-90 JOB NUMBER: AK-BO-00054 KELLY BUSHING ELEV. = 58.00 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 9005 6958.00 6900.00 9138 7058.00 7000.00 9270 7158.00 7100.00 9401 7258.00 7200.00 9530 7358.00 7300.00 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 794.15 S 5260.12 E 2047.83 32.54 779.80 S 5346.79 E 2080.94 33.11 765.09 S 5431.29 E 2112.69 31.75 750.69 S 5513.98 E 2143.24 30.55 736.40 S 5594.00 E 2172.12 28.88 9600 7412.65 7354.65 728.53 S 5636.84 E 2187.35 15.23 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS SPERRY E-LI MILNE POINT ALASKR 4-80-90 -SUN OR ILL I N6 SERV I CE5 HOB I ZONTRL PBOJECT I ON START TVD = FINISH TVD = SCALE IS 1SO0 O. O0 7L~12.65 FEET/IN MORIT'ONTRL DI§PLRCEHENT IS 5685.72 OEPFIBTUBE 0 ~500 3000 4500 6000 7500 I I I I I I ERST 9000 -1500 -~000. -4500 -6000 -7500- -9000 9600 5503 B:BO00054 SPERRY- E-Y MILNE POINT ALI4SKA 4-30-90 SUN DR ILL I NO SERV ICES VEF~T I CRL PF~OJECT I ON START TVD = 0.00 FINISH TVD = ?~112.65 SCALE IS 1500 FEET/IN 1500- I-- ~000' ~ ~500' rr' §000. 741~.8 7500- 5505 ts6o 2060 VER T I CFtL SEC T I ON BISECTION = 97.36 us6o 6060 B: B000054 PERMIT # ~ a - ,3~ WELL NAME _ . AOGCC GEOLOGICAL'MATERIALS INVENTORY LIST ( check off or list,data as it is re.~eived ! , 407 ! -~'/~,/~P/ drilling histo~("l~ su~ey I ~ well tests ! ~rK' dcs~ipti,on cored ,i, nt~als, core,,an~l~is - d~ ditch inte~als digital data ........ LOG l",t1~E ' RUN INTEI:WALS SCAIF NO. lOl 11] , , 1~] 14] 16] 17] ~81 · 1. Operations performed: STATE OF ALASKA 0 ALASKA OIL AN D GAS CONSERVATION COM MISSION REPORT OF SUNDRY WELL OPERATIONS Operation shutdown ~ Stimulate __ Plugging __ Perforate X RI 6 Pull tubing __ Alter casing __ Repair well B Other __ iN 2. Name of Operator / 5. Type of Well: CONOCO INC Development X · I Exploratory __ 3, Address Stratigraphic_ P.O. BOX 340045, PRUDHOE BAY, AK 9973 Service__ 4. Location of well at surface 1343' FNL, 1995'FEL,SECZ5,T13N,R10E,UM At top of productive interval At effective depth At total depth 2049'FNL, 1268'FEL, SEC30,T13N,R11E,UM 6. Datum elevation (DF or KB) 55'KB NSL 7. Unit or Property name M I LNE PO INT UN IT 8. Well number E-4 9. Permit number/approval number 90-5/90-152 10. APl number 5o- 029-21997 11. Field/Pool KUPARUK feet 12. Present well condition sUmmary Total depth: measured true vertical 9900' feet 7616' feet Effective depth: measured 9789 ' feet true vertical 7533 ' feet Casing Length Size Structural Conductor 80' 13-3/8" Surface 5706' 9-5/8" Intermediate Production 9896' 7" Liner Perforation depth: measured Plugs (measured) N/A Junk (measured) N/A Cemented Measured depth True vertical depth TO SURFACE 114' RKB 114' RKB 406 BBLS PERHE 5741'RKB 4566'RKB 55 BBLS CLASS C 125 BBLS PERH C 9880'RKB 7604'RKB HK1 9067'-9109' HKZ 9135'-9169' true vertical Tubing (size, grade, and measured depth) 2-7/8" L-80 6.5# EUE Packers and SSSV (type and measured depth) RCSSV .- OT ! S 13. Stimulation or cement squeeze summary PACKER: OTIS 7" 'HCH' PERH. PACKER 2- 7/R" ' FMX ' TRRV t~.E6 ' RKR · Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2092 510 0 PKR 8945' RKB ;':-;ka 0ii .& Gas Cons. Tubing Pressure 262 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil .X_ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed L' I)_ C(~6/15)88 Form 10-404 Rev Title SENIOR PRODUCTTON FOREMAN Date SUBMIT IN DUPLICATE IS, ION OF' ~...HLUMB£11~G£R TE:CHNOLOGY HOUSTON. TE:XAS; 772S I o~) I ?~ 41LEAIE REPLY TO MAY 1.. MAY ! 4 1990 ~CHLWBERGERWELL MIWlOES Nas~ Oil & Gas Cons. Commission Anchorage CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Affention: Marc Shannon Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore_2_JlL_prints of the Depth Determination Log, Run 1, 5/12/90 Company CONOC0, Inc, Well Milne Point Unit E-4 Field Milne Point Additiormlprintsorebeingsentto: I BL prints CONOCO, Inc, .600 North Dairy Ashfor~ Houston, TX 77079 Attn: Georze Lamb - OF 2018 PER -- County ~nrth Slope State, Alaska ,on: _A_]lL_prints, 1 RF Sepia C~N~CO, Thc_ 1000 South Pine Ponca City, OK 74603 Attn: Log Library 1BL prints, 1RF Sepia OXY U.S.A., Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrol *(915/685-5600) _l_~rints, 1RF Sepia Chevron U.S.A. 6001BollJnger Canyon Road San Ramon~ CA 96583-O~43 AttB: Prlscllla MacLeroy *(615/842-1OOO) l~~rints, 1 RF Sepia~ /~as~a Oil & Gas Conservation~ /Commission ( 3001 Porcupine Drive ~ Anchorage, AK 99501 ~-Attn: John Boyle The film is returned to Conoco: Log Library. We appreciate the privilege of serving you. prints prints prints ReceJ ved by: Date: Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter DISTRICT MANAGER 327-t: 8CHLUMBERGEFI WELL SERVICES A DIVISION OF KHLUMB£IIK~IrR T[CHNOLOGY COI~POIqATIC)N HOUSTON. TE~XAS 77a:51 -~' 175 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Affention: Marc Shannon Pouch 360069 Prudhoe Bay, AK 99736-0069 Attn: Bernie/Shelley Gentlemen: C ~'r~ Enclosed ore_g_AL_prints of the ~.c.~, Run !, 4/J0 / 90 Company CONOCO, [nc, . Well MJlne PoJ. nt Unit E-4 Field Milne point Additionalprintsorebeingsent ~: I BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 At,n: George Lamb - OF 2018 PER County Nnrth S!ope State Alaska _iJIL_prints, 1 gF Sepia ..1000 Sough pine Ponca City, OK 74603 Attn: Log Library I BL prin~, 1RF Sepia OXY U.S.A., Inc. 0 Desta Drive Midland, TX 79710 Attn: John Carrol *(915/685-5600) _l_~rints, 1RF Sepia Chevron U.S.A. .6001BollJnger Canyon Road San Ramon, CA 94583-0943 Attn; Priscilla HacLeroy *(415/842-1000) 1BL ~rint~, l;,RF:Sepia Alaska:'Oll & Gas Conservat'~6~.'~,,~, ....... ~'Commission 3001 Porcupine Drive Anchorage, AK 99501 "'~,Attn: John Boyle The film is returned to Conoco~ Log Library. We appreciate the privilege of serving you. prints prints prints Received by: Date: MAY - 8 1990 Alaska Oil & Gas Cons. G0mmisskm Very truly yours, Anchorage SCHLUMBERGER WELL SERVICES David M, Saalwaechter DISTRICT IdANAGER SWS-- 13~"/4r STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY' APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program m Operation shutdown __ Re-enter suspended we~ Plugging __ Time exteqs~on __ Stimulate __ Pull tubing __ Variance __ Pedorate __ Other ..~ 2. N_a_m. ,e_ ~ _O p,,e.r ~io r I~UNUI.;U INI~. 3. Address P.0. Box 340045, Prudhoe Ba,y..~...A.K... 99734 4. Location of well at surface 1343' FNL, 1995' FEL, Sec 25, T13N, R10E, UM At top of productive interval At effective depth Gyro Survey Not Presently Available At total depth 5. Type of Well: Development Exploratory Stratigraphic Service 6. Daturr~ev~o~[ or KB) 7. Unit or Property name M I LNE PO INT UN IT 8. Well number E-4 9. Permit number 90-5 10. APl number 50-- 029-2]997 11. Field/Pool Kuparuk 12. Present well condition summary feet Total depth: Effective depth: Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: measured true vertical measured true vertical Length 80' 5706' 9900' feet Plugs (measured) N/A 7616' feet MAY - 8 1990 9789' feet Junk (measured) N/A Alaska 0Ii & Gas Col'Is. COmllllsl 7533' feet N/A A~chorage Size Cemented Measured depth True vertical depth 13-3/8"54#/ft To Surface 9-5/8"36#/ft 406 BBL Perm E 55 BBL Class C 9896' 7"26#/ft 125 BBL Perm C 9880' 7604'RKB measured 114' RKB 114' RKB 5741 'RKB 4566'RKB trueverticaINote: Survey depths based on MWD directional data not available from Gyro. Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth~/A 13. Attachments Description summary of proposal(__ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation · ~ay 3, 199.0 ..... 16. If proposal was verbally approved Oil .¢Y~....,,,~,. Gas ~ Name of approver Date approved Service 17. I hereb, y~certif~hat the foregoing is true and correct to the best of m,, knowledge. Signed ~(" '~ /"2~, [.,(~ ~/Jl~ Title PPoductioll Foreman ............ ' FOR COMMISSION 'USE ONLY 15. Status of well classification as: Suspended~ Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance Mechanical Integrity Test ~ Subsequent form required 1"~'- Approval No. ~O --- -1~-,~:)' · Approved by order of the Commission ,,,, , , ..... ,, Form 10-403 Rev 06115/88 ORIGINAL SIGNED BY LONNIE C. SMITH Approved C.opy [011 SUBMIT IN T~RIpLICATE' ~ COt'IPLET ION PROCEDURE MPU Well E-4 Milne Point Unit Surface location: ],343' FNL, ],955' FEL, Sec. 25, TI3N, R]OE, UM All depths are measured from KB datum. Casing: Surface - 9 5/8", 36#/ft, J-55, btrs., set at 5,765'. Production- 7", 26#/ft, L-80, btrs., set at 9,943'. Capacity: 3.82 bbl/lO0' Burst Pressure: 7,240 psig _Tubing: 2-7/8", 6.5#/ft, EUE, L-80, @ g,O00 Capacity: 0.579 bbl/lO0' Capacity of tubing/casing annulus: 3.02 bbl/]O0' Burst Pressure: 10,160 psig (no safety factor) _Objective: Complete well E-4 in the MK-1 and MK-2, flow test and conduct a PBT. A stimulation procedure will follow if necessary. Recommended Procedure: 1) Hold a safety meeting at Milne Point with all contractors involved with the completion prior the job. 2) RIH with 2 7/8" tubing, 6" bit and 7" 26# casing scraper. Clean casing to 20' below bottom of Kuparuk interval {9,180'). Hole will contain 10.4 ppg NaBr brine which was used as displacement fluid on the primary cement job. Circulate and condition brine to 10 microns. POOH Pressure test casing to 1,000 psig. 4) Rig up electric line company to run gyro survey and GR/CCL from T.D. (9,943') to surface: Correlate GR/CCL with the open hole logs dated 1/25/90. Rig down electric line company. 5) Hold a safety meeting with perforating company on location prior to rigging up the guns. Make up perforating/completion assembly from bottom up as Follows: (See Figure 1) NK-1 from 9,048'-9,090' and the NK-2 from 9,116'-9,150' open hole logs). Note: Measure O. D., I. D. and length of all tools to be run in the hole. Insure that all tools are free from obstructions. Measure and record distance from top shot on gun assembly to the marker joint. Perforate the Distribution: DLB, JOC, PMS(2), MPU Senior Foreman MAY - 8 1990 Alaska 0Il & Gas Cons. Commission Anchorage Completion Procedu,. MPU Well E-4 April 18, 1990 Page 2 ITEM DESCR!PT!ON I.D. O.D. LENGTH DEPTH Bottom Shot of Guns 4 ]/2", 5 SPF, W/37 gm DP CHG. 60 deg. PHS., DP 5lB HJll RDX Top Shot of Guns Schlumberger Redundent Firing Head & Safety Spacer 2 7/8", 8rd, EUE, Tubing 2.44" Schlumberger Debris Circ. Sub 2.38" Schlumberger Hydro-Mech Gun 5 3.67" 30.00' 6 3.67" 1.5' 7 Release 2.31" 3.67" 3.0' 8 2 7/8", 8rd, EUE, Pup Joint 2.44" 3.67" 10.00' 9 Otis "X" Nipple (P/N 711x9) 2.313" 3.67" 1.20' 10 2 7/8", 8rd, EUE, Tubing 2.44" 3.67" 30.00' 11 Otis "HCM" Hyd. Perm. Pkr. 2.313" 5.88" 21.40' 12 2 7/8", 8rd, EUE, Tubing 2.44" 3.67" 90.00' 13 2 7/8", 8rd, EUE, Marker 2.44" 3.67" 5.0' 14 2 7/8", 8rd, EUE, Tubing 2.44" 3.67" 8,855' 15 Otis Series 10, FMX, SCSSV 2.313" 4.76" 7.0' 16 2 7/8",8rd, EUE, Tubing 2.440" 3.67" 550' 17 1/4" Stainless Steel cntl. In 600' 9,150' 9,048' 8,950' 550' 6) Strap in the hole with perforation/completion assembly on 2-7/8" tubing. Install 1-1/2" gas lift mandrels and dummies at 8,925', 8,660', 8,400', 8,150', 7,900', 7,200', 6,600', 6,000', 4,300' and 2,200' MD. Install Otis SCSSV AT 550' and run 1/4" control line to surface. 7) Rig up electric line company and run GR/CCL. Correlate with the existing GR/CCL and open hole logs. Use the 5' locator sub to position guns at top shot depth. If guns are off depth, mark off feet of tubing on surface required to place top perforation shot on correct depth. Position guns on depth and rerun GR/CCL to confirm gun position. Repeat if necessary. 8) Rig up slickline and RIH with tubing plug. Set in the "X" nipple located below the packer (8,980'). Set packer by pressuring the tubing to 1,000 psig and increasing the pressure in 500 psig increments to a maximum of 5,000 psig. Bleed off tubing pressure and pressure annulus to 1,000 psig to test packer. RIH with slickline and retrieve the tubing plug. POOH. 9) Pick up on tubing and shear out of the PBR. Circulate 52 bbls of diesel down the tubing to create approximately 1000 psig underbalance for perforating. Sting back into the PBR assembly. ]0) Nipple down BOPs and nipple up the tree. Pressure test the tree to 5,000 psig. Connect surface lines and pressure test to 3,000 psig. 11) Rig up 20' lubricator and shot detection equipment. Detdi PF l l l::l dropping roller bar. I~, I.. ~.; i.. m ¥1.. i./ MAY - B 1990 Naska Oil & Gas Cons. Commission ;Anchorage Completion Proced..~ HPU Well E-4 April 18, 1990 Page 3 12) Flow test the well and perform a pressure buildup as follows: a) Bring the vlell on slowly with choke set at 32/64. Allow well to cleanup by gradually opening choke to 64/64 over a two hour period. Obtain a stabilized 48 hour flow test and report stabilized fluid rates, cuts and GOR to the Anchorage office. b) Rig up wireline, lubricator and pressure recorder with surface readout. RIH with pressure gages making 15 minute gradient stops at 1,000' intervals. Set gage at 8,980' and obtain a 2 hour flowing pressure survey. If it is necessary to shut-in the well to run gauge, make the shut-in period as short as possible. Once the gauge is on bottom the previous rate should be re-established and maintained for three times the shut-in time used to run the gauge plus the two hour flow test period. Rates for the two hour flow test should be same as the stabilized 48 hour test rate. c) Shut-in the well at the surface and make sure there are no leaks. Obtain a pressure buildup test and report pressure data to the Anchorage office. Engineering will terminate test when sufficient data has been collected. POOH with gauge making ]5' gradient stops at ],000' intervals. NOTE: The objectives of the flow test and pressure buildup test are to determine reservoir pressure, kh and skin. 13) Drop 1.6875" ball to seat in the tubing release. Pressure tubing to ],200 psig to release guns and associated tools (approximately 132') into the rathole. When guns release a pressure drop will occur. 14) Rig down completion rig and move off location. Rig up slickline. Retrieve dummies and run gas lift valves. Return well to production with gas lift and report stabilized well tests to engineering on a weekly basis. Prepared By: R. S. Rossberq Senior Production Engineer Approved BY'supervising ro .~n/g. ld Superintendent I~F. PARFD FC~: Conoo~ AT--ON OF: Mr. St~we Roc.~erg FIELD NAME: M/lne Point WE-lL NAME: E-4 LOCkT~C~: Milne Point, Alaska C~$ING: 7" 26 ~ ~L~: 2-7/8" 6.5 ppf 8RD 432/1020/01/90 April 16, 1989 ~: Ray ~v~ - ~~, ~ (907) 344~144 1. Tubin~ - (Inoco ~t[:91i~d 2.44" m !/4" Stainless Steel O0ntxol Line .049" Wall Tn/ckness x 600' ~ 316 Material (P/N 22 SXX 31060) Otis "FMX" Series 10 Tubtn~ B~trievable H2S Se_~vtoe 2-7/8" ~.5 ppf Box x Bin (P/N 77a FMX 23111-E) 5. w/Schlumbexger Tie-In Sub --9 7.'/ -- 10 11 8.'./' O, 3.668" .25' 2.313" 4.76" 7.0' 550' 2.44" 2.25" Tubi~ - ~ Supplied 2.44" Otis "HO, l" ~la~z-aulic Permanent 2.313" Packer 7" 26-32 lb 10' Effect/ve Seal Strd~. / 2.3~. "x" selective [an:ttng Nipple (?/N 2U mm 7o14) Millout Extension 3.73" (P/N 232 D 5845) 3. 668" 3.688" 5.0' 3.668" 5.88" 21.4' 5.88" 8.0' 3.668" 30.0' Tubir~ - Omoco Sup~li~ 2.44" --12 13 9e ~/' 10. 11. Otis "X" Selective Landir~ Nipple (P/N 711 X 9) Pup Joint~ Supplt~ Sd~~er Hydro M~d~n~a~ Sch] um~rger Debris- circulation Sub 2.313" 3.668" 1.2' 2.44" 3.668" 10.0' 2.31" 3.668" 3.0' 2.38" 3.668" 1.5 ' (A~0X.) 8950' 14 13. · 14. 2.44" 3.668" 30.0' Firing Head, Sa fety Spacer, Schematic RECEIVED I-}CAb ,_.SHOULD ~,¢... MAY - 8 1990 Alaska 011 & Gas Cons. Commission ;mchomge 0.0 SP (MV ) 100'00i CP 32.2 30000 .20000 .......... SFLU~OHMM) ,29900 .... /~ FILE 2 ,/l~- I~ 5"t100' 25-JAM-1990 Ot$~ 29 200 Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 March 9, 1990 Mr. Mike Minder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Letter of Application Dear Mr. Minder, As per your request, I am submitting the Form 10-40~'s to be added to the end of Well Form 10-40~'s, Operation Summaries and logs that Jim Fox submitted at the conclusion of the E-4 and L-3 Wells. We are requesting to shut down well operations on these wells until we can move the drilling rig far enough ahead of the workover rig to conduct completion operations. The cement plug was bumped, casing pressure tested, the tree was flanged up and tested and the well was shut in. Sincerely, J.D. Polya Drilling Foreman JDP/djw STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 6 1. Type of Request: Abandon __ Suspend __ Operation shutdownx._. Re-enter suspended well __ Alter casing m Repair well __ Plugging ~ Time extension ~ Stimulate m Change approved program ~ Pull tubing __ Variance ~ Pedorate ~ Other __ 2. Name of Operator CONOCO INC. 3. Address P~O= Box 340045, 4. LoCation of well at surface 1343' FNL, 1995' At top of productive interval P~mm~hn~ Rmv AK 99734 5. Type of Well: Development -X- Exploratory __ Stratigraphic __ Service ~ FEL, Sec 25, T13N, RIOE, UM At effective depth Gyro Survey Not At total depth Present 1 y Avai 1 able 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80 ' Surface 5706 ' Intermediate Production 9896 ' Liner 9900' 7616' 9789' 7533' feet Plugs (measured) N/A feet feet Junk (measured) N/A feet N/A Size Cemented Measured depth 13-3/8"54#/ft To Surface 114'RKB 9-5/8"36#/ft 406 BBL Perm E 5741'RKB 55 BBL Class C 7"26#/ft 125 BBL Perm C 9880' 6. Datum elevation (DF or KB) 55 KB MSL feet 7. Unit or Property name M!LNE PO!NT UN!T 8. Well number F-4 9. Permit number 90-5 10. APl number 50-- O29-21~97 11. Field/Pool Kuparuk RECEIVED MAP, 16 :,~,.~ ,.-,~(~; 0ii & Gas Cons, C0mmissi01 Tr~leY~epth 1 i 4' RKB 4566' RKB 7604' RKB Perforation depth: measured N/A truevertica~lote: Survey depths Gyro. Tubing (size, grade, and measured depth) N/A based on MWD directional data not available from Packers and SSSV (type and measured depth~l/A 13. Attachments Description summary of proposaJ(__ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation ~,,-,,ot 10 ~990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended X-- Service 17. I hereb ,.y~e~fy that-t~foregoing is true and correct to the best of my knowledge. Signed'' Title ~n'i ,~ .o. co ,ssroN on Foreman Date ;.~//Z,/~,,'/_.,2 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- . Approved by order of the Commission ORIGINAl. SIGNED BY LONNIE C. SMITH . I_Appr°va' N°' ( ~'~-'~"~-~'~ov e d CoPY AP~eturned Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE STAYE OF' ALA&KA ALASKA 01L AND GAS CONSERVAT I ON ¢OMMt ~ilON Permt% f __ Pit geuge Flow a~nftor Annular preventer , Ptp~ r~m~ .... ,jY~.o,,,., · ,, ', ch,o, v.~v, i m __ L__.. mi K~LY AND FLO0~ UlCer Kelly Lo, mr Kelly Ball ~ype int~de B~ Choke mmnlfold Number velvet AdJua~mb~a oh~kem Hydrlultomlly ope '~30 Blind lwltoh oovtA,. C.'"- VALV[5~ Tilt premlure ....~-.O0.O.___ T.., ,.,,,~.. 4:0 0...o.: ....... ,~ed ohoke e - Operetoe o - &upervtaer C,O0~ (rev I .mpeo~r m i' ~' SCHLUMBERGER WELL SERVICES A DIVISION OF ~HLUHBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS ?7251-2175 CONOCO, Inc 3201 "C" Street, Suite 200 Anchorage, Alaska 99503 Attention: Rick Wheeler PLEASE RElY TO 8CHLUMBERGER WELL ~RVICES Pouch 340069 Prudhoe Bay, AK 99734-0069 ATTN: Bernie/Shelley Gentlemen: DIL(PHASOR), NGT (2" & 5"), CNL (BAW) Enclosed ore 1 Blprints of the CNL (PORO); Cyher!o_nk. _~.1.!n 1, 1/25/90' Company CONOCO, Inc Well Milne Point Unit E-4 Field Milne Point Additionol prints ore being sent to: 1 BL prints CONOCO Anchorage 3201 "C" Street: Ru~te 200 Anchorage: Alaska 99503 ATTN: Marc Rhmnnon County North RIop. State Alaska 1BL prints, and 1RF Sepia .. Alaska Oil & Gas Conservation CommtgSion 3001 Porcupine Dr chorage, Alaska 99501 ~A~TN: John Boyle 1BL prints CONOCO~ Inc Houston: TX 77079 ATTN: G.nrge I.amh - O~-20!8 PER 1BL prints; 1RF Sepia and all Film CONOCO, Inc Log Library 1000 South Pine Ponca City: OK 7~603 _l_BL_prints and 1RF Sepia OXY URA: Thc P 0 Rnw 50250 Midlmnd; TX 79710 ATTN: Ne~l Buttram prints _l_JlL_prints and 1RF Sepia CHEVRON_ P 0 Box 5043 San Ramon, CA 94583-09943 ATTN: Pricilla MacLeroy prints PLEASE SIGN AND RETURN ONE COPY OF THIS TRANSMITTAL. THANK YOU The film is sent to CONOCO Log Library RECEIVED B~'/~._ We appreciate the privilege of serving you. RECEIVED DATE: ,~-~- ' Alaska Oil& Gas Oon . Anchorage Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter DISTRICT MANAGER January 4, 1990 Telecopy No. (907) 276-7542 D F Rainwater Sr Production Foreman Conoco Inc Pouch 340045 prUdhoe Bay, ~ 99734 Re~ Milne Pt Unit E-4 COnoc° Inc Permit ~ 90-5 Surf Loc Btmhole Loc Dear Mr Rainwater: 1343'FNL, 1995'FEL, Sec 25, T13N, R10E, UM 2049'FNL, 1268'FEL, Sec 30, T13N, RllE, UM 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 pe~itting 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 so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~ truly ~yours, / ,;: .,.:,,.," ., / Chai~an Alaska Oil and Gas Conservation Commission BY oRDER OF T~ COMMISSION jO .: Enclosure c: Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl CONOCO MPU OPS CTR 907-659-6190 002 5'FEIF,~ GORPOBATION 1'.0, Bo~ 1830 Pueblo, Color,do 81002 TEL N0. ~O0-gg~-gg00 DATE: 0~nuary 2, 1990 PAG£ J_ o¢ _.L. TO: Dave MountJoy Conoco A1 aska FAX NO: 901-659-6390 FROM: J, E. Otontsto Hanagee-Tubular Products B~low ave listed some impact values for APl K-SS product as requested, AIl were conduct.d at room temperature, Hoat~ I .mmmci~ Value (Ava_) Ft/Lbs 3-7337 35.8 4-0607 ~1,0 4-0608 35.0 3-7335 34.5 3-7328 35,5 4-0581 30,3 3-7313 ~7,0 3-7314 27.5 4-0580 36.8 'These impacts are above most manufacturers K-SS product as CF&I designs their steel for tou~hne&~. As previously ~tated, the Arctic service meet API J-~$ in every sense but is designed t~or better impmct prop.tries at low temperatuPmm. If further information is required, let me know, ~.~, , .., J. E, Otontslo Man~ger-Tubul ar ProducLs OEO/sp Conoco Inc. Suite 200 3201 C Street Anchorage. AK 99503 (907) 564-7600 December 21, 1989 Mr. Robert P. Crandall Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Drilling Permits for E-4, L-2, & L-3 Dear Mr. Crandall: This letter is to provide information omitted from our recently submitted drilling permit applications. The intent of these wells is to extend the existing development of the Kuparuk Pool within the Milne Point Unit. These wells are to be completed in the Kaparuk formation as producing wells. I have attached checks to cover the application fees for these wells. We appreciate your assistance with these permits applications and apologize for any inconvenience associated with these omissions. Should further information be required for these applications, please call me in Anchorage at 564-7616. Very truly yours, ..-'""~~el and I ~/Pr~/ducti on Superintendent J~C (j.r) ~/1ttachments ALASK/LOIL AND~(~i~;~C~'~N~~,~iON CD.~MMISSION PERMIT TO DRILL 20 AAC 25.005 '' ................. la. Type of work Drill '~ Redrill [] lb.':fyp(~"~f well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry ~ De,.e. pen .... Servi, ce,.~ Developement Gas [] Single Zonev~/ Multiple Zone ' 2.' Name'~f Operator 5. Datum Elevation (DF or KB) 10. Field and Pool CONOCO INC. KB 35' feet Kuparuk River Field 3. Addre~'s .... 6. PropertY'Designation Pouch 340045, Prudhoe Bay, AK 99734 ADL 2823] 4. Location of well ai' surface ......... 7. Unit or property Name 11. Type Bond Isee 20 AAC 25.0251 1343'FNL, 1995'FEL, Sec.25,T13N,RlOE, U.H. Hilne Point Unit Blanket · m ......... At }op of productive interval 8. Well nurpber Number ]980 FNL, ]850' FEL,Sec.30,T]3N, RI ] E,U.H. E-4 8086-]5-54 At total depth 9. Approximate spud date Am/~ou~¢--~'~ / 2049' FNL, ]268' FEL,Sec.30,TI3N, R] 1E,U.H. ~-~ 200,000 12. Distance to' nearest 13. Distance'l'to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line ~ ,At TD 59]' feet ...]5'/32-25@76!. feet 2,555 ...... 7600'TVD/9908'MI)eet 16. To be 'completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (eX2)) Kickoff depth 500 feet Maximum hole angle 440 Maximum surface 3200 psig At total depth ('FVD) 3800 psig 18. 'Casi'ng program setting Depth. '' size Specifications Top Bottom Quantity of cement Hole Casing weight Grade Coupling 'L~ngth 'MD TVD MD TVD (include s't~'g'e data) 30" 13-378' 48 H=40 Weld ' "80" 357 .... 35' i15 115' "+ 480 sks permafrost --1~~= 9-5~--3~-~-;J~55 BIRS b130' 35' 35' §16§ 4598' 645 sks Permafrost F ......... 268 sks Class ~ ' j 2nd stage 5i3 sks Fet'mafrost L a /~ sks Class G u ./~ , ~u L-SO om,o ~uo oa 35' uu~o /oaS' .~u sks Class u 19. l:o be completed for Rodrill, Re-entry, and Deepen Operations. + 273 sks Fum-m;'r:,t C Present well condition summary + 60 Bbls Dead Crude Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured · feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor su,, c Intermediate Production Liner ~' Perforation depth: measured ~i..,..i~$~. ~i~ & ~-~ CO~S, ~.~ true vertical Pit Sketch x -~0. Attainments Filin_,q fee ~X Property"~la~X BOP Sketch'~X Diverter Sketch ©X" Drilling program c~X Drilling fluid program ~_A Time vs depth plot ~J~ Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements .... 21. i her~'by certify that ,,q:~%foreg°ing is true and correct to the best of my knowledge Signed'x~"~/~.~.~.~/'/~'~,,, Title Senior Production Foreman Da..,!e CommissiOn Use Only ' -'~Permit Number ! APl number _ "i App'r0val date ! See cover letter ?o - ,¢ , I 50- 0~--~- ~_.//¢'~/~ ,.. J o,1,/o4/9o , i !,,or oth..er requirements ~di{i~ approval Samples required ~ Yes ~ No I~Ud ICg r(~quired L-] Yes ~-'~N° Hydrogen sulfide measures [] Yes ~ No Direcfi'onal.survey required /~Yes C Required working ~ure for3BOPE '~; ~ 3M; ~.~M; ~ 10M; [~ 15M Other: ~' ) ,,.-~J /' .,//'// ,J ~ . /. / / ~' "),/ / ~'~" .... - by order of ......Approved by L ~..._//,' .~__._~~~~,/,' . Commissioner .... the commission Date ~ _ Form 10-401 Rev. 12-1-85 Submit il triplicate \ \ N bi M~'bUN LAGOON M~LNE lq'. UNIT [~OLIND/LR¥ SCALE ,N M,,rs CONOC0 MILNE POINT UNIT EXISTING DEVELOPMENT T IZ~ NOTES: !. STATE PLANE CO.ORDINATES ARE ZONE 4. 2. ALL GEODETIC POSITIONS ARE BASED ON N.A.D. 19Z7. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. 4. LOCATED WITHIN SECT. 25 , T 13,N, R I0 E, U.M., AK. i . _ , i _l i1 ill 11 E-i E-~ LOCATION IN SECTION FROM N. LINFI FROM E. UNE NORTHINGS STATE PLANE C0"OROS. I 3,~9' 1983' 6,016 ,457. 87 1262' 20 54' 6,016 ,554.30 569, 088.27 I :Z $ O ' :Z1'78' // ? ?.~ i EASTINGS . 569, 159.84 , ,.n,I , l GEODETIC POSITION LATITUDE LONGITUDE 149° Z6'08.178" W. 70° 27' 19.162" N. 70° Z7' ZO.IIT"N. 149° Z6' I0.Z55" W. LSka 0il & Cas Cm Anchora DATE II- I - 84 CHECKED R.M FIELD BOOK 4-84 L.O. Z6 - 85 JJ E-9 j ~E- K) CERTIFICATE OF SURVEYOR : ! HEREBY CERTIFY THAT ! AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY ~ADE BY ~E OR UNDER ~Y SUPERVISION..~J~D THAT ~LL D~ENS~ONS ANO OTHER DE. TAIL~ ARE CORRECT. - ENGINEERS AND LAND SURVEYOR:S 'E' PAD AS- BUILT WELL LOCATION Surveye~ for CONOCO SCALE : I SHEET : I" · 400' J I OF 2 COMMENTS ~ T 13 N R 9 E T 13 N R 10 E T 13 N R 11 E MILNE PAIN' UNIT .: : ,.- , ,, , ,,, ,,.L: : '~: k: :" ~ " -" ~ .... ~"'~'" (~ D®notea Ir.ct Total Unit 35,744 Acrel ADL-3~OT~Z 12S5 AC ~ ~L 8/84 ' ~'*D~743~68 A~ X __ ~-255~ 2533AC ADL-47434 2~60 AC ADL-47433 ~60 AC CONOCO E~ A~ ~ CONOCO ET AL 1 ~ ~ C.~ CHEVRON 18 17 ' . 16 15 I 13 18 + + __ · ADL-25516 )~ ADL-47439 ADL-3158~ · OL-3~SIee 1280 AC ADL-47437 2560 AC ADL-47438 2544~C 1280 AC .1280 AC .~-25514 2560 AC ADL-25515 2~ AC 12e~ A~ ,, ,, ,,, , 30 29 28 2T 26 - 25 30 29 ~ EXHIBIT A + - ~ ~ MILNE POINT UNIT AREA ~~ ~ ~ 31 3~ 33 34 8lied Off -- ~-~~ ~ ~ i 35 3e 31 32 O > ~ ,~ ~ A~-25617 ~ ~ Mille ~ ~ ADL-28231 2555 AC 2235 AC 20 ADL-25~ 2560 AC ADL'25518 2560 AC ~~ ~ ~ b., ~. lit JI till I I ~ I I ltl I Meridian,Alaska I 2 ~ i Scale r MUD CLEANER F~OM SAL&MANCERS MUO TROUGH w& T F..R ~ HGLE FiLL ?AI~KI 1 ~avO kex H0~$ i L'~:G~ER r4Ub"~;LL u~X CaAaGE CH,'~qGE laL.~--~ 2 PL;~,'~' i PutaP 2 AGIIAT~ I~uT T£nFLY VALVE: GATE VALVE ~UD GU~ Psv :. SUCT~N V~VE SuC~Ca CR 0~SCH~GE [ ~ V~) Ptoxcr ~G 2 7 ~ FLOW SHEET [ FROW MUD KILL MANIFOLD FROM REMOTE HIGH REWOTE PRESSURE GAGE SENSCR PRESSURE PUMP --'- NOTE: HYDRAULIC CONTROLLED L ~RaULIC CON~L S~STE~ FOR B~ ~C~ B CNO~ REMOTE OPERATED L~;ED REVOTELT WITH 3~0 PSI ~CCUUULATOR a 160 G~. RESE~IR a ~UX. E~ERGY SOURCE. (5) STA. ~NTROL WANIF~ PLUS ~RIAB~ CHOKE ~NT~L TO BE ~CATED ON RIG FLOOR. DRILLING z KiLL ~ CHO~ ~4N)FOLDS ~ ~EET A~ RPS) ~. SW S~S. SP~L ~. KILL ~ANIF~D SIZE-RATING 2'- 5~0 HYDRAULIC CONTROLLED R~OTE OPIATED REMOTE PRESSURE GAGE SENSOR · CHOKE ADJUSTABLE ADJUSTABLE MANIFOLD CHOKE CHOKE __ VARIABLE CHOKE REMOTE CONTROL TO SHALE SHAKER I · RECEIVED TO ATMOSPHERIC MUD/GAS SEPARATOR DE ~ ~ 01739 ~-jast~ Oil & G~s Cons. Anchorage CHOKE 8 KILL MANIFOLDS FOR ct~/8'~ 8 7" OD CASING BOP STACK BOP MANIFOLD LAYOUT- CONOCO, INC. : CONOCO, INC. MILN£ POINT UNIT DIVERTER STACK FOR 13 3/8' .CONDUCTOR ~ ~r triLL UP LIN[ / ~ lrLOW LIN! _ RECEIVED 1. The hydraulic contpol sys%e~ will be in accordance with API specifications and P~ requirements. ~. The HCR valve will open e~hen the ppeventep closes. A single 10" pelief line will pun off of= the drilling spool HCR valve and will have a targeted do~nstpeam tee fop downwind dive.sion. Valves on both sides of the tee will be full opening and linked %o~ethep to enabIa on~ to al~ays be open and the other to be closed. MILNF. POINT UNIT BOP STACK FOR 9-5/8" SURFACE CASING LINE ~ I[.~ ' FLOW LINE I ! : '- ' 13%1 = APl 50004 RAId lOP IS "J/e" APl 5000 · IS~" APl 5000 · R CEIVEO ANNULAR PREV[NT[R ,. SPOOL ~ L ~ ,,~,e _ ' ' ...... Il'/I, APl $000 (1) (2) RAM BOP APl $0OO*1 · 'il' APl 5000 II ' APl 5000 (:~) (/~) J OUTLtTS .U,/ ~, SPOOL Threaded (5) R.O.P. stack size rating meets AP1 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 p~pe rams. Choke and kill manifolds shown separately to meet APl RP 53 class 5M requirements. SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT E-4 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 +480 sacks Permafrost type "C". B. Ce The 9-5/8" surface casing will be cemented in 2 stages with the first stage using _+645 sacks of Permafrost "E" cement followed by _+268 sacks of Class "G" cement. A DU tool will be placed at _+ 1946' MD. The second stage will contain _+513 sacks of Permafrost "E" cement followed by _+73 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. . The 7" production casing will be cemented in two stages. The first stage will consist of -+410 sacks of Class "G" cement pumped around the casing shoe. The secondary cement job will consist of _+273 sacks of permafrost type "C" cement followed by -+60 barrels of Arctic Pack pumped down the 7" x 9-5/8" annulus. II. Drilling Fluid Program A® 0-500' 9.0 ppg freshwater spud mud. 500'-5730' 9.0 ppg-9.8 ppg freshwater spud mud. RECEIVED C. 5730'-7240' 9.0 ppg-9.5 ppg dispersed. D. 7240'-TD 10.4 ppg dispersed. III. Drilling Program ,Mcholage Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River Field. The mud system will be low solids, non- dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at TD will be 10.4 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. Maxtmum downhole pressure ts based on tnittal reservoir pressure. Maxlmum surface pressure ts based on an unexpanded gas bubble, temperature taken tnto account. The closest wellbore is E-! with ~5Lof closure at a depth of 761' Dead crude w111 be placed in the 7^ 9-5/8" annulus after disposing of excess drtlltng fluids. The well will be perforated and completed after releasing the drilling rig. A. Drill a 30' conductor hole to +80' and set 13-3/8" conductor, B. Drtll a 12-1/4" surface hole to _+4563' TVD (5730' MD) and set 9-5/8" casing. Ce Drill an 8-]/2" production hole to 9908' MD and set 7" casing. TVD MD FORMATION BIT MUD 14T YP PV YIS FL O' O' Gravel* 1-1-4 9,0 32 20 90 15 500' 500' Sand/Clay 1-1-4 9.0 25 20 65 15 3850' 4732' "K" Sands 1-1-4 9.2 25 15 65 14 4115' 5094' "M" Sands 1-1-4 9,4 25 15 65 13 4310' 5361' "N" Sands 1-1-4 9.4 25 15 65 12 4445' 5545' "0" Sands 1-1-4 9.4 25 15 65 12 4563' 5730' Surface Casing 6800' 8764' Kup Top 1-1-6 10.2 8 12 35 5 6980' 9010' MK 1-1'6 10.2 8 12 35 5 7020' 9065' L.K. 1-1-6 10.2 8 12 35 5 7045' 9099' L K (1) 1-1-6 10.2 8 12 35 5 7210' 9323' L K (2) 1-1-6 10.2 8 12 35 5 7240' 9434' B I K 1-1-6 10.4 6 12 35 5 76005 9908' TD 1-1-6 10,4 6 12 35 5 * The proposed depth ts an estimate only. If the actual depth exceeds the permit depth by over 300' TVD a Sundry Nottce wtll be submitted. The well E-1 ( 32-25 ) is plugged and abandoned. RECEIVED A. B. C. D. E. F. G. H. T. ,.1. TOTALS TIME ESTIMATE Rig Up Drill Surface Hole Run Surface Casing and Cement Drill Out and Test Dr i 11 Producti on Hole Log Open Hole Condition, POOH, L.O. Run Producti on Casing Cement Production Casing Move Rig Hours Days Cum. Days 10 0.42 100 4.16 4.58 36 1.50 6.O8 8 O.33 6.41 120 5.00 11.42 36 1.50 12.91 20 0.83 13.74 10 0.42 14.16 10 0.42 14.58 10 0.42 15 360 15 15 WP/PERMSUPP 3 -1 -2 -3 -4 -5 -6 -7 -8 -9 10 11 MILNE POINT UNIT WELL Rate vs. Depth ~.~ C~,~ q 0.00 2.00 4.00 6.00 8.00 10.00 12.00 14.00 16.00 18.00 RI~ DAYS ,,. CONOCO, ! no. Ped E, Well NOt ~---, Propoeed MI Ine Point Unt~. North Slope, Alaska ........ 0 _ _ RrB ELEVATION, 2000 KOP TVD=500 TMD=$O0 DEP-O 3 BUILD PER ! O0 FT · 3g EOB TVD=181 .............. 3000 m AVERAGE ANGLE ~:~ DEG 22 MI N 6000 9 5/8' CSO PT ....... TVD-4563 THD-5?30 DEP-3120 , I /':JlChd;ag0 7000 TAROET / TOP KUP TVD=6g80 TMD=g055 DEP=5404 TD / 7" LINER TVD=7600 TMD=gg08 DEP=5989 8O0O 0 1000 J I I 2000 3000 4000 VERTIOAL SECTION I $000 i 6000 2000 , z 1000 _ c:) i -r 0 - 1000 _ SURF'^CE LOCATION · SEC. ~$. TI3N. RI~ HORIZONTAL ..... O,JE, CT I ON SCALE I IN. = 1000 FEET OONOCO. ln~. , ' ~ i i Pad E. Well No,!4 P~poeed t ..... !WEST'EAST ~ 1 000 0 SURFACE 000 2000 ~ 3000 ~ a,.O00 , , , I ...... I. I .. . $000 TAR(NET TVD-6g~80 TPID"905~ DEP-5404 SOUTH 637 EAST 5366 TAROET LOCATIOg~ 1980' FNL. 1 ll~' FEi. SEC- .30. T13N. R11E 6O00 ,I TD LOOAT l ON ~ : 204.e' FNL, 1268' FEL : ~E:C. :30, T13N. R11E 150 . 100 . 50 50 _ 100 _ 150 _ 150 · II II I Il , , f 150 - iu L 100 ~ 32-25 Is P & A'd. 100 , , 200 25u i I 250 200 I2/JOx89 ~07:~1 .. CONOCO MPU, OPS CTP~'~07-659-6390 OOl · ,1 P. I OATE; December ~9, 1989 TO: Dave Mount Joy Conoco A1 aska FAX NO: g0}'-659-6390 FROM: 3. E. OJonJ$to I~anager-Tubul ar Products Please flnci below the tmpact values for the five heats conducted on 3/4 s~ze specimens tt -LO°P. Heat 3-3899 Heal 3-~00 Heat 4-7330 Heat 4-733! Heat 8-9110 Indtv.,t~ual Tests~FD/Lbs) 3 Tes~ avq~ .10, lZ, l? 13.0 20, 14, 9 14.3 33, 42, 32 3S'.7 22, 21, 28 ~3.7 15, 21, 24 20.0 Mtnlmum allowable eye,ag. ?or 3/4 size specimen - 12 ?t/lb~ Htntmum tndtvidua~ %es% for 3/4 stze specimen - 9 ~t/~bs If ~ou requlre further tn?o~atton, don't he~ttate to call, ~anage?-Tubu3 aw PPoducts ~ED/sp cc: J. O, Hotttnqe~ 07:~0 CONOCO MPU OPS CTR 90?-659-6390 001 Conoco Inc. Requ~t For Facsimile Trammi~ion To No, of Cove~ + .. Fax Reply Number: (907) 659-6390 ETN ~81-6390 Please noclfy (907) 659-63~0 if comple=e Cra~em£ss~o~ is not received. 12/28x89 16:J9 CONOCO MPU OPS CTR 90?-659-6390 002 [ ~ ~'~- t~~~~ ' -- ! ~~'~ I~'~~ LI · / ~ ~ ~ ' ~ ..... PUEBLO, COl.0, ~t ~92 t ~ · / ~CONOCO, INC, ~TTN: LUCY FCL.[.~R~ ~OX 4413 HOUSTON, ~X 772~ 0 i' "~('~-- LU~_Y__.FEL_L, Et~ .......... *;','*-~_i · ':';' "::'" P,~IRT ,. ,',' ,,.::- ' ,, ...:,.u. PROC t~RCTIC CL.O~F'D AND 'b'.-:; ;'. PROT£CTOR$ · ' SATISFACTORY TI;} FURNISH GRADE .... K-55: COUPLING,I' ON ENTIRE IN~P ELEC~ROHAGNETIC $A-2 SPECIAL END AREA tG~[ THREAD GAUGING . ORDERED ONLY. SEE SPECIAL INSTRUCTIONS ;:i..'..: · ~AGENT,EEATTLE, WA.RULE °FOR FURTHERANCE TO AL. AEK~ ANCHORAGE,AK TO {IHt. DAD A DELIVER 46376 CI~&I STEEL COItPORATION P.O. Box 316 mm~. i'uoblo, ColQr~do 81~2 Nu~er 33899 33900 47330 ~'-- ~ ~i C~ ~ lC ~ F S S1 Cu N~ Cr Mo ~]'~ ~ t 0.24 0.~3 .009 .006 .19 .19 ,07 0.05 ,013 .015 .000 ,000% .004 ,0014 0,23 0.99 ,014 .004 ,22 .24 .07 0.09 .012 .OL6'-.O00 .0005 .004 .0014 0.26 0.97 .013 ,003 .23 ,24 .07 0.08 ,0il .015 .000 .0004 .00~ .0016 0.15 0,94 .011 ,004 .~0 .13 .07 0,08 .010 .0i8 .000 .0004 .004 .0015 Hea~ Lot Number Number 33899 33900 4,7330 ~7331 .__ I Samp 1 · I Number 1 Dimens ions Yield U1 ~ma~e -~lon~at 1 on- t PSI PSI In,lin. Pct. BHNI z 34.0 0 2 32.0 0 2 34.0 0 2 38.0 0 ¢92 x .'.iAi- x .373 55,700 s2,4oo 1.490 X .386 55,800 81,600 1.493 X .365 , 56,000 80.600 ALL MELTING AND M,%NUFACTURINO P~0CESSE$ OF THE MATF~RIAL SUBJECT Tt.~ THIS TEST C~RTIFICAT~ OCCURRWD IN THE uNITED STATES OF AMERICA. This is to certify that the materl&l mubJec= ko ~hin cer~ifi¢~ of inspection and Notice of Limited Warranty was m.znufactured in accordance with and conforms %o the specifications designated hereon. NO WARRANTY 15 w. XPRE$$ED OR IMPLIED other than those set forth above. In particular. CF&I Steel Corporation ~peciftcally disclaims any implied warranty of merchantabilit}' o~' fitne~for · Oualit , -~"-'*/' 12/28×89 :[6:40 CONOCO MPU OPS CTR 90?-659-6:390 003 /~ ~~~~:-~~,~~~ .... .~__-__. ~.~ '"j~~~ ............... / .~:. - ...... ~~ ' ~-I m I~l~l ~~~'~~ ........ j:,:~ PU[~L0, C0L0, el ee2 T _ _ ~ ~ ~t~ . {,:{[:.~ _. . _ . ~ . _ ~ONDCO, 1NC, ~AG FOR=CONOCO ZHC. SEAHLE$$ STEEL PZPE J-~ FOR RRCI~ $~R¥~C£ R-$ BUTTRESS HEAT QTY U0M THRD LENGTH 3;-$877 I~ JNT 2e,7 4-73;3;1 t 9' JNT 29 , ? ~g. TO SHZP FEET 576,,7 23t9. t ,,' --..':':-:'. P 0 E~OX 3:t6 :.'.~,,.: ...:.~,:... PU£~.o, cot. o. 8~ 002 · :... CONOCO, INC. · % CF&I STEEL COI~FORATION n__ _1. _ i I ii Ill .......... · mn _mn___ i i ----- II II II Illllllll I ..... 01 TP~X ~XEHPT T~G FOR:COHOCD INC. P. 0. CONOCO ~AHL~ gTE~L CA~ZHG (O,C.T.G.) H b K GRADE J-5~ FOR ARCTZC ~ERVZCE R-3 9UT;RES; T/C ' 62t t HE~T QTY UO~ THRD LENGTH 3-~899 16 JNT 2e,7 =-~oe z6 JNT 2e.7 4-753e 26 JNT 2e,.7 4-75~t ~2 JNT 2e,7 ~AL, TO SHIP TOTAL, TOTRL NET WT, CONOCO MPU OPS CTP ~07-659-6390 ~-~ ~:~',~:J ~UU.'~ I 00'7 679.~t 1t12.9 2444g 3:?229 40G64 47909 F:>A F__ CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8) (9 thru 13) (i0 an~ ~3) (4) Casg (14 thru 22) (5) BOPE ~ (23 thru 28) Company_~_~_~ 1. Is the permit fee attached .......................................... · 2. 4. 5. 6. 7. 8. e 10. 11. 12. 13. 14. 15. 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 ......................... Lease & Well No. YES NO , ~S .~- - '- t / -- 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/f~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~DO~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER (6) Add: thru 31) 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 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 ............................................. For 29. 30. 31. 32. o rev: 01/30/89 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE /-.o,'/ o 1/3 z cZ ,,, Additional Remarks: ~ .5~C, ~ ,, ?~,~ ~ / / . !