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Home My WebLink About196168Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/10/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230423 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END MPI 2-04 50029215850000 186082 6/11/2023 READ MAPP MP B-15A 50029213740100 223022 6/22/2023 READ Caliper Survey MP F-10 50029226790000 196094 7/5/2023 READ Caliper Report MP K-30 50029227110000 196168 6/22/2023 READ Caliper Survey Please include current contact information if different from above. T37818 T37819 T37820 T37821MP K-30 50029227110000 196168 6/22/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.10 14:44:17 -08'00' CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Rixse, Melvin G (OGC) To:Todd Sidoti - (C) Cc:Regg, James B (OGC); DOA AOGCC Prudhoe Bay Subject:20230629 1555 APPROVAL to Perforate MPK-30 (PTD: 196-168 SUNDRY: 323-285) Date:Thursday, June 29, 2023 3:59:34 PM Attachments:MPU K-30 RWO ESP Swap 6-29-23 REV1.pdf Todd, Hilcorp is approved to perforate with PCE under Sundry 323-285 as per the revised program attached. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). A From: Todd Sidoti <Todd.Sidoti@hilcorp.com> Sent: Thursday, June 29, 2023 3:15 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Tom Fouts <tfouts@hilcorp.com> Subject: RE: [EXTERNAL] RE: MPK-30 (PTD: 196-168 SUNDRY: 323-285) Hi Mel, Please see attached. Thanks, Todd From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, June 29, 2023 2:54 PM To: Todd Sidoti <Todd.Sidoti@hilcorp.com> Subject: [EXTERNAL] RE: MPK-30 (PTD: 196-168 SUNDRY: 323-285) AOGCC requires a revised procedure. Can be approved via email. 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. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Todd Sidoti <Todd.Sidoti@hilcorp.com> Sent: Thursday, June 29, 2023 1:12 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MPK-30 (PTD: 196-168 SUNDRY: 323-285) Hi Mel, Hilcorp requests to add the following Kuparuk B Silt perforations to well MPK-30 during its next workover operation. SAND MD TVD KUP B SLT 10,765-10,820’ 7,120-7,148’ KUP B SLT 10,845-10,885’ 7,161-7,181’ Please let me know if you would like any additional information. Thanks, Todd Todd Sidoti | Operations Engineer | Hilcorp Alaska | 907-632-4113 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. RWO – ESP Swap Well: MPU K-30 Date: 29 June 2023 REVISION 1 Well Name: MPU K-30 API Number: 50-029-22711-00-00 Current Status: Producer [ESP Failing] Pad: K-Pad Estimated Start Date: May 10th, 2022 Rig: ASR 1 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-168 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) Second Call Engineer: Scott Pessetto (907) 564-4373 (O) (801) 222-2203 (M) Current Bottom Hole Pressure: 2,944 psi @ 7,000’ TVD (SBHP measured 3/19/2016) 8.09 PPG Max. Predicted Surf Pressure: 2,244 psi (Using 0.1 psi/ft gas gradient) Max Inclination: 60° @ 4428’ MD Brief Well Summary: MPU K-30 was drilled in 1996 using Nabors 22E and completed in the Kuparuk B and C sands. The well has had multiple ESP changeouts and sand control screens ran and pulled since 1996, the most recent was an ESP changeout in 2016. The ESP is starting to fail and the objective is to replace it. Notes Regarding Wellbore Condition • Casing tested to 3,500psi for 30 min down to 10,538’ on 1/05/2014. • The intake pressure gauge on the ESP is still functional and can be used to verify BHP prior to RWO. Objective: Replace failed ESP with new assembly and return well to production. Pre-Rig Procedure (No sundry required): Slickline Pumping & Well Support 1. MIRU SL and PT PCE to 250 psi low / 1500 psi high. 2. Run memory caliper from top of ESP to surface. 3. Pull dummy valve from deep station. 4. Pull orifice and dummy off top station. 5. RDMO SL. 6. Clear and level pad area in front of well. Spot rig mats and containment. 7. RD well house and flowlines. Clear and level area around well. 8. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 9. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. 10. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH or diesel. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 11. RD Little Red Services and reverse out skid. RWO – ESP Swap Well: MPU K-30 Date: 29 June 2023 12. RU crane. Set BPV. ND tree and NU BOPE. RD Crane. 13. NU BOPE house. Spot mud boat. Brief RWO Procedure: 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well with ppg produced water prior to setting CTS. 3. 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. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” and 3-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. 5. Call out Summit for ESP pull. 6. RU Spooler to pull ESP cable. 7. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2016 ESP WO was 84K lbs and SO weight was 34k lbs. 8. Recover the tubing hanger. 9. POOH and lay down the 2-7/8” tubing. Number all joints b. Keep all tubulars for future rig workovers c. Tubing caliper will be run, and bad joints will be identified prior to the RWO. d. Keep XN nipple and GLMs for future use. e. Keep ported discharge head and centralizer for future use. f. Note any sand or scale inside or on the outside of the ESP on the morning report. g. Look for over-torqued connections from previous tubing runs. h. Recover the following amount of clamps/guards from the completion: i. 325 cross collar (Cannon) clamps ii. 3 splice clamps iii. 17 body clamps on ESP iv. 1 half clamp on ESP 10. Lay Down ESP. 11. RIH with 7” test packer assembly on 3-1/2” WS to 9,500’. POOH. a. Estimated TOC behind the 7” production casing is 9,339’. 12. Test casing to 3,000 psi for 30 minutes charted. POOH with test packer. 13. MIRU eline and pressure test lubricator to 250 psi low / 2500 psi high. 14. MU and RIH with perforating gun runs. a. Perforate from 10,765’-10,820’ (55’). RWO – ESP Swap Well: MPU K-30 Date: 29 June 2023 b. Perforate from 10,845’-10,885’ (40’). c. Correlate to GR/CCL log dated 11/25/1996. 15. RDMO eline. 16. PU new ESP and RIH on 2-7/8” tubing, making electrical checks every 2,000 feet. a. Set base of ESP assembly at ± 10,400’ MD. b. 1 joint of 2-7/8” Tubing c. 2-7/8” GLM w/ DV installed d. 2-7/8” Tubing e. 2-7/8” GLM w/ OV installed at ± 125’ MD. f. 2-7/8” Tubing 17. Land tubing hanger and space out. RILDS. Lay down landing joint. Note PU and SO weights on tally. 18. Set BPV. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE 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 Swap 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,145'N/A Casing Collapse Conductor N/A Surface 4,760psi Intermediate 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL 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: Operations Manager 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 9-5/8" 7" 6,652' 11,122' Perforation Depth MD (ft): MD N/A 6,870psi 7,240psi 4,908' 7,295' 6,652' 11,122' Length Size Proposed Pools: 112' 112' TVD Burst PRESENT WELL CONDITION SUMMARY 7,306' 11,041' 7,257' 2,244 N/A 112' 20" MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0375132 196-168 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22711-00-00 Hilcorp Alaska LLC KUPARUK RIVER OIL N/A C.O. 432E MILNE PT UNIT K-30 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 6.5#/ L-80/ EUE 8rd 10,397' 5/31/2023 N/A and N/A N/A and N/A See Schematic See Schematic 2-7/8" 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 todd.sidoti@hilcorp.com 777-8443 Todd Sidoti Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:04 pm, May 12, 2023 323-285 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.05.12 15:00:23 - 08'00' Taylor Wellman (2143) 10-404 2,244 ADL0375133, MGR26MAY23 BOPE test to 2500 psi. Annular to 2500 psi. SDR-5/12/23 SFD SFD 5/19/2023GCW 05/26/23 JLC 5/26/2023 5/26/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.26 14:08:57 -08'00' RBDM JSB 053023 RWO – ESP Swap Well: MPU K-30 Date: 18 Apr 2023 Well Name: MPU K-30 API Number: 50-029-22711-00-00 Current Status: Producer [ESP Failing] Pad: K-Pad Estimated Start Date: May 10th, 2022 Rig: ASR 1 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-168 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) Second Call Engineer: Scott Pessetto (907) 564-4373 (O) (801) 222-2203 (M) Current Bottom Hole Pressure: 2,944 psi @ 7,000’ TVD (SBHP measured 3/19/2016) 8.09 PPG Max. Predicted Surf Pressure: 2,244 psi (Using 0.1 psi/ft gas gradient) Max Inclination: 60° @ 4428’ MD Brief Well Summary: MPU K-30 was drilled in 1996 using Nabors 22E and completed in the Kuparuk B and C sands. The well has had multiple ESP changeouts and sand control screens ran and pulled since 1996, the most recent was an ESP changeout in 2016. The ESP is starting to fail and the objective is to replace it. Notes Regarding Wellbore Condition x Casing tested to 3,500psi for 30 min down to 10,538’ on 1/05/2014. x The intake pressure gauge on the ESP is still functional and can be used to verify BHP prior to RWO. Objective: Replace failed ESP with new assembly and return well to production. Pre-Rig Procedure (No sundry required): Slickline Pumping & Well Support 1. MIRU SL and PT PCE to 250 psi low / 1500 psi high. 2. Run memory caliper from top of ESP to surface. 3. Pull dummy valve from deep station. 4. Pull orifice and dummy off top station. 5. RDMO SL. 6. Clear and level pad area in front of well. Spot rig mats and containment. 7. RD well house and flowlines. Clear and level area around well. 8. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 9. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. 10. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH or diesel. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 11. RD Little Red Services and reverse out skid. RWO – ESP Swap Well: MPU K-30 Date: 18 Apr 2023 12. RU crane. Set BPV. ND tree and NU BOPE. RD Crane. 13. NU BOPE house. Spot mud boat. Brief RWO Procedure: 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well with ppg produced water prior to setting CTS. 3. 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. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” and 3-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. 5. Call out Summit for ESP pull. 6. RU Spooler to pull ESP cable. 7. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2016 ESP WO was 84K lbs and SO weight was 34k lbs. 8. Recover the tubing hanger. 9. POOH and lay down the 2-7/8” tubing. Number all joints b. Keep all tubulars for future rig workovers c. Tubing caliper will be run, and bad joints will be identified prior to the RWO. d. Keep XN nipple and GLMs for future use. e. Keep ported discharge head and centralizer for future use. f. Note any sand or scale inside or on the outside of the ESP on the morning report. g. Look for over-torqued connections from previous tubing runs. h. Recover the following amount of clamps/guards from the completion: i. 325 cross collar (Cannon) clamps ii. 3 splice clamps iii. 17 body clamps on ESP iv. 1 half clamp on ESP 10. Lay Down ESP. 11. RIH with 7” test packer assembly on 3-1/2” WS to 9,5000’. a. Estimated TOC behind the 7” production casing is 9,339’. 12. Test casing to 3,000 psi for 30 minutes charted. POOH with test packer. 13. PU new ESP and RIH on 2-7/8” tubing, making electrical checks every 2,000 feet. a. Set base of ESP assembly at ± 10,400’ MD. b. 1 joint of 2-7/8” Tubing Lubricate BPV if risk of pressure below. - mgr RWO – ESP Swap Well: MPU K-30 Date: 18 Apr 2023 c. 2-7/8” GLM w/ DV installed d. 2-7/8” Tubing e. 2-7/8” GLM w/ OV installed at ± 125’ MD. f. 2-7/8” Tubing 14. Land tubing hanger and space out. RILDS. Lay down landing joint. Note PU and SO weights on tally. 15. Set BPV. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 5/20/2016 SCHEMATIC Milne Point Unit Well: MPU K-30 Last Completed: 5/3/2016 PTD: 196-168 TD =11,145’ (MD) / TD = 7,306’(TVD) 20” DF Elev.: 57.5’/ GL Elev.: 28’ (Nabors 22E) DF to 7” Casing Hanger = 28.5 7” 15 14 9-5/8” Howco ES Cementer 9-5/8” Min ID @ 10,238’ MD KUP C Sands PBTD =11,041’(MD) / PBTD = 7,257’(TVD) KUP B Sands 6, 7 & 8 9 & 10 13 1 2 3 45 11 & 12 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40E / N/A N/A Surface 112' 0.355 9-5/8" Surface 47 / L-80 / NSCC. 8.679 Surface 4,544’ 0.0732 9-5/8" Surface 47 / L-80 / Btrc. 8.679 4,544’ 4,796’ 0.0732 9-5/8" Surface 47 / P-110 / Btrc. 8.679 4,796’ 6,652’ 0.0732 7" Production 26 / L-80 / Btrc 6.276 Surface 11,122’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surf 10,397’ 0.00579 JEWELRY DETAIL No Top (MD) Item 1 126’ 2-7/8” x 1” MANA Side Pocket w/ Dual Screen Orifice 2 10,160’ 2-7/8” x 1” MANA Side Pocket w/ Dummy BK-2 Top Latch 3 10,238’ 2-7/8” XN Nipple –ID= 2.250 No-Go 4 10,281’ 2-7/8” EUE 8rd, Discharge Bolt 5 10,281.7’ 2-7/8” EUE 8rd, SLB Ported Pressure Discharge 6 10,282’ Pump - 125 Stage SF 1750, 11/16 Inconel Shaft 15 HSG 7 10,304’ Pump - 125 Stage SF 1750, 11/16 Inconel Shaft 15 HSG 8 10,326’ Pump - 125 Stage SF 1750, 11/16 Inconel Shaft 15 HSG 9 10,348’ Gas Separator 400X, Vortex AR, LT, Inconel Shaft 10 10,351’ Gas Separator 400X, Vortex AR, LT, Inconel Shaft 11 10,353’ BPDSL, Premium Seal, AR Bearing 12 10,361’ BPDSL, Premium Seal, AR Bearing 13 10,370’ Motor – 456 Series FMS 180Hp/ 2,597V/ 48A 14 10,393’ Gauge OD 4.5” 15 10,395’ 2-3/8” EUE Pin Up 6 Fin Centralizer –Btm @ 10,397’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 10,588’ 10,658’ 7,024’ 7,063’ 70 11/26/2015 Open Kup. B Sands 10,704’ 10,748’ 7,088’ 7,111’ 44 11/25/1996 Open Ref Log: 11/25/1996 GR/ CCL – 4.5”/ 5 SPF OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I in 24” Hole 9-5/8" 1,500 sx Trinity Lite Wate, 750 sx PF “E”, in 12-1/4” Hole 7” 245 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = 57 to 62 deg. f/ 3,650’ to 11,041 Max Hole Angle through perforations = 58 deg. TREE & WELLHEAD Tree 5M CIM 4-1/16” Wellhead 11” x 11” 5M FMC Gen 5A, w/ 4-1/16” FMC Tbg. Hngr., L.H.Acme thread 4”CIW H BPV profile GENERAL WELL INFO API: 50-029-22711-00-00 Orig. Completion by Nabors 4-ES - 11/27/1996 RWO Screens added / Pig Tail Pull & Land – 6/15/1998 RWO w/ Nabors 4-ES – 4/5/2002 & 5/5/2004 ESP RWO w/ Nabors 4-ES – 10/6/2007 ESP RWO & Replace Screens w/ Nabors 3S – 8/3/2008 ESP RWO & Replace Screens w/ Nabors 4-ES – 8/15/2010 ESP RWO w/ Doyon 16 – 8/5/2011 & 1/13/2014 TTC/ ESP Change-out w/ Nordic #3 – 12/16/2015 ESP Swap w/ ASR#1 – 5/3/2016 _____________________________________________________________________________________ Revised By: TDF 4/18/2023 PROPOSED Milne Point Unit Well: MPU K-30 Last Completed: 5/3/2016 PTD: 196-168 TD =11,145’ (MD) / TD = 7,306’(TVD) 20” DF Elev.: 57.5’/ GL Elev.: 28’ (Nabors 22E) DF to 7” Casing Hanger = 28.5 7” 14 13 9-5/8” Howco ES Cementer 9-5/8” KUP C Sands PBTD =11,041’(MD) / PBTD = 7,257’(TVD) KUP B Sands 5, 6 & 7 8&9 12 1 2 3 & 4 10 & 11 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40E / N/A N/A Surface 112' 0.355 9-5/8" Surface 47 / L-80 / NSCC. 8.679 Surface 4,544’ 0.0732 9-5/8" Surface 47 / L-80 / Btrc. 8.679 4,544’ 4,796’ 0.0732 9-5/8" Surface 47 / P-110 / Btrc. 8.679 4,796’ 6,652’ 0.0732 7" Production 26 / L-80 / Btrc 6.276 Surface 11,122’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surf ±10,397’ 0.00579 JEWELRY DETAIL No Top (MD) Item 1 ±126’ 2-7/8” x 1” GLM w/ Side Pocket 2 ±10,160’ 2-7/8” x 1” GLM w/ Side Pocket 3 ±10,281’ Discharge: Bolt-on 4 ±10,281.7’ Ported Pressure Discharge: 5 ±10,282’ Pump #3: 6 ±10,304’ Pump #2: 7 ±10,326’ Pump #1: 8 ±10,348’ Gas Separator: 9 ±10,351’ Gas Separator: 10 ±10,353’ Upper Tandem Seal: 11 ±10,361’ Lower Tandem Seal: 12 ±10,370’ Motor; 13 ±10,393’ Sensor: 14 ±10,395’ 2-3/8” EUE Pin Up 6 Fin Centralizer – Btm @ ±10,397’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 10,588’ 10,658’ 7,024’ 7,063’ 70 11/26/2015 Open Kup. B Sands 10,704’ 10,748’ 7,088’ 7,111’ 44 11/25/1996 Open Ref Log: 11/25/1996 GR/ CCL – 4.5”/ 5 SPF OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I in 24” Hole 9-5/8" 1,500 sx Trinity Lite Wate, 750 sx PF “E”, in 12-1/4” Hole 7” 245 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = 57 to 62 deg. f/ 3,650’ to 11,041 Max Hole Angle through perforations = 58 deg. TREE & WELLHEAD Tree 5M CIM 3-1/18” Wellhead 11” x 11” 5M FMC Gen 6, w/ 4-1/16” FMC Tbg. Hngr., L.H.Acme thread 4”CIW H BPV profile GENERAL WELL INFO API: 50-029-22711-00-00 Orig. Completion by Nabors 4-ES - 11/27/1996 RWO Screens added / Pig Tail Pull & Land – 6/15/1998 RWO w/ Nabors 4-ES – 4/5/2002 & 5/5/2004 ESP RWO w/ Nabors 4-ES – 10/6/2007 ESP RWO & Replace Screens w/ Nabors 3S – 8/3/2008 ESP RWO & Replace Screens w/ Nabors 4-ES – 8/15/2010 ESP RWO w/ Doyon 16 – 8/5/2011 & 1/13/2014 TTC/ ESP Change-out w/ Nordic #3 – 12/16/2015 ESP Swap w/ ASR#1 – 5/3/2016 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 Blind Ram 2-7/8" x 5" VBRs I STATE OF ALASKA ALIIIL OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations Shutdown❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well Q Re-enter Susp Well❑ ESP Change-out Q 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development Q Exploratory❑ 196-168 /C6 1 4.-,) 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22711-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0375132 MILNE PT UNIT KR K-30 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 11,145 feet Plugs measured N/A RE C E I V E D true vertical 7,306 feet Junk measured N/A feet JUN 0 8 2016 Effective Depth measured 11,041 feet Packer measured N/A feet true vertical 7,257 feet true vertical N/A fe OGCC Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' Surface 6,652' 9-5/8" 6,652' 4,908' 6,870psi 4,760psi Intermediate 11,122' 7" 11,122' 7,295' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 10,397' 6,915' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A SCANNED JAN 0 92017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 270 0 Subsequent to operation: 82 7 1,420 220 198 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data p GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-211 lk:Th Contact Ted Kramer Email tkramer(c�hilcorp.com Printed Name Bo York Title Operations Manager Signature Phone 777-8345 Date 6/7/2016 — YG .2/-/6 *- 6.A .‘ Form 10-404 Revised 5/2015 RBDMS LU .1 I 0 9 2016 Submit Original Only Milne Point Unit in • SCHEMATIC • Well: MPU K-30 Last Completed: 5/3/2016 I�acorp Alaska,LLC PTD: 196-168 TREE&WELLHEAD DF Elev.:57.5'/GL Elev.:28'(Nabors 22E) Tree 5M CIM 4-1/16" DF to 7"Casing Hanger=28.5 11"x 11"5M FMC Gen 5A,w/4-1/16"FMC Tbg. Wellhead Hngr.,L.H.Acme thread 4"CIW H BPV profile 20" OPEN HOLE/CEMENT DETAIL g 1 ..t 20" 250 sx of Arcticset I in 24"Hole 1 9-5/8" 1,500 sx Trinity Lite Wate,750 sx PF"E",in 12-1/4"Hole r, 7" 245 sx Class"G"in 8-1/2"Hole r c CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 20" Conductor 91.1/H-40E/N/A N/A Surface 112' 0.355 9-5/8 ` 9-5/8" Surface 47/L-80/NSCC. 8.679 Surface 4,544' 0.0732 Homo ES Cementer 9-5/8" Surface 47/L-80/Btrc. 8.679 4,544' 4,796' 0.0732 ES C 9-5/8" Surface 47/P-110/Btrc. 8.679 4,796' 6,652' 0.0732 7" Production 26/L-80/Btrc 6.276 Surface 11,122' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 10,397' 0.00579 WELL INCLINATION DETAIL KOP @ 400' Max Hole Angle=57 to 62 deg. f/3,650'to 11,041 Max Hole Angle through perforations=58 deg. JEWELRY DETAIL No Top(MD) Item 1 126' 2-7/8"x 1"MANA Side Pocket w/Dual Screen Orifice 2 10,160' 2-7/8"x 1"MANA Side Pocket w/Dummy BK-2 Top Latch 3 10,238' 2-7/8"XN Nipple-ID=2.250 No-Go 4 10,281' 2-7/8"EUE 8rd,Discharge Bolt 5 10,281.7' 2-7/8"EUE 8rd,SLB Ported Pressure Discharge 6 10,282' Pump-125 Stage SF 1750,11/16 Inconel Shaft 15 HSG 7 10,304' Pump-125 Stage SF 1750,11/16 Inconel Shaft 15 HSG 8 10,326' Pump-125 Stage SF 1750,11/16 Inconel Shaft 15 HSG 9 10,348' Gas Separator 400X,Vortex AR,LT,Inconel Shaft 10 10,351' Gas Separator 400X,Vortex AR,LT,Inconel Shaft 2 11 10,353' BPDSL,Premium Seal,AR Bearing Min Io @r12 10,361' BPDSL,Premium Seal,AR Bearing 121.3 Mo- 3 , 13 10,370' Motor-456 Series FMS 18OHp/2,597V/48A 5 4 14 10,393' Gauge OD 4.5" 15 10,395' 2-3/8"EUE Pin Up 6 Fin Centralizer-Btm @ 10,397' 011 6,7&8 ME PERFORATION DETAIL WI 9&10 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 11&12 Kup.C Sands 10,588' 10,658' 7,024' 7,063' 70 11/26/2015 Open Kup.B Sands 10,704' 10,748' 7,088' 7,111' 44 11/25/1996 Open Ref Log:11/25/1996 G R/CCL-4.5"/5 SPF 13 GENERAL WELL INFO it , 14 API:50-029-22711-00-00 Orig.Completion by Nabors 4-ES -11/27/1996 15 RWO Screens added/Pig Tail Pull&Land-6/15/1998 RWO w/Nabors 4-ES-4/5/2002&5/5/2004 KUP C sands ESP RWO w/Nabors 4-ES-10/6/2007 - }KUP B Sands ESP RWO&Replace Screens w/Nabors 35-8/3/2008 ESP RWO&Replace Screens w/Nabors 4-ES-8/15/2010 ESP RWO w/Doyon 16-8/5/2011&1/13/2014 TTC/ESP Change-out w/Nordic#3-12/16/2015 y"arc ESPSwapw/ASR#1-5/3/2016 TD=11,145'(MD)/TD=7,306'(1VD) PBTD=11,041'(MD)/PBTD=7,257'(TVD) Revised By:TDF 5/20/2016 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPU K-30 ASR1 50-029-22711-00-00 196-168 4/27/16 5/3/16 Daily Operations: r ;,o 4/27/2016-Wednesday MIRU ASR#1 4/28/2016-Thursday Continue Rigging up. Function Test Bope Equipment, Spot ESP Spooler, R/U Generator. (JSA)Testing Bop, Test all valves & Rams to 250 psi low/3,000 psi high,Test Annular @ 250 psi low/2,500 psi high. (Charles, Scheve with AOGCC Waived Bop Test 4-28-16 @1812 Hrs).Well Head Rep Pulled TWC Valve From Hanger. 4/29/2016- Friday Service Rig, Check fluids in all Equipment. Continue to Rig up Rig floor with Casing Jacks to POOH with completion tubing, Wait on XO for floor safety valve. Inspection of Jacking System was completed by AOGCC, Lou Grimaldi before pulling the Tubing Hanger. Back out Lock Down screws, POOH, Lay down Hanger,Tie ESP cable off&control line, begin jacking for TOOH. Service Rig, Check fluids in all Equipment. (JSA)Tooh Jacking 4.5 Tubing ESP& Control Line Lay Down Same;(JSA) TOOH with 4.5" Pulling on Elevators to 3,000 ft. 4/30/2016-Saturday Continue to TOOH laying down 4.5" Hydril 521. Change out spool on ESP Spooling unit. Rig Service, Check fluid in all equipment. Continue to TOOH utilizing Jacking system. Continue to TOH on the Elevators laying down 4.5"Tubing to 7,500 FT. Service Rig, Check fluids in all Equipment. (JSA)TOOH laying down 4.5" Hydril 521 Tubing From 7,500'to 10,309'.Total Joints ( 259)(497 Cannon Clamps) ( 3 Protectrilizers)( 2 Flat Guards) Did Not Observe any Visual ESP Cable Damage while Pooh. (JSA) Break& Lay Down ESP Pump Assembly. (JSA) Roads& Pads Changed out ESP Reels in Spooler, Removed Casing Jacks from Rig Floor, Install Spacer Spools on Annular. Load New ESP Pump Assembly on Catwalk. 5/1/2016-Sunday Continue loading ESP equipment, Load 2-7/8"Tubing. Make up&Service Summit ESP Assembly, continue to load &tally completion tubing.TIH with ESP ASSY. on 2-7/8"Tubing. Service Rig, Check fluids in all Equipment. (JSA)TIH with 2-7/8 Completion Tubing & ESP Assembly to 3,600'. Checking Cable every 2,000'. (JSA) Summit Rep Making Reel to Reel ESP Cable Splice @ 3,600. (JSA)TIH with 2-7/8" Completion Tubing& ESP Assembly to 7,425'. Checking Cable Every 2,000'. 5/2/2016-Monday Rig service, Check fluids in all equipment. Continue to TIH to 7,425' with ESP &2-7/8"Tubing. Pull spooler out with Roads & Pads truck,Truck had Engine problems, swap trucks, change spool out. Make Reel to Reel splice on ESP cable. Continue to TIH with ESP &2-7/8"Tubing;Service Rig, Check fluids in all Equipment. (JSA)TIH with ESP & 2-7/8"Tubing, Checking ESP Cable every 2,000 ft. (JSA) Make up Landing Joint into Hanger, Well Head Rep Aligned Hanger and ESP Penetrator to Flow Line. (JSA)Summit Rep Splice Cable to Penetrator and Install into Hanger. Removed ESP Shieve from Derrick, Moved Extra 2-7/8" Tubing and Pipe Racks to the Back Yard. (JSA) Land Tubing Hanger, Well Head Rep RILDS Break out and Lay down Landing Joint, P/U=84K S/0=34K Ran (321 JTS) ( 2-GLMS) ( 325 Cross Collar Clamps) (17 Body Clamps) (1 Half Clamp) ( 3 Splice Clamps). (JSA) Well Head Rep Tee Bar BPV Valve into Hanger. (JSA), Roads and Pads Hauled off 185bbls,Sea Water from Pits to B-50, N/D and Remove Spacer Spools from Annular, Removed Hydraulic Hoses from Bope Stack, Roads and Pads Hauled Spooling Unit to Back Side of Pad, Moved Change House and CO,Man Shack and Well site Trailer House and Catwalk. (JSA) Electricians Disconnected Alarm System in Pits, Rig Floor and Cellar, Rig down Handling Equipment from Rig Floor. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPU K-30 ASR1 50-029-22711-00-00 196-168 4/27/16 5/3/16 Daily Operations: 5/3/2016-Tuesday Rig Service Grease and Check Fluid Levels. (JSA) Lay Derrick over, Move Rig off of Mud Boat, Remove Mud Boat. OSA) Remove Rig floor from well enclosure, Remove well Enclosure from well. OSA) Nipple down BOPs, Nipple up production tree, Test Hanger void to 500/5,000 psi. pull BPV, install TWC Test Tree to 5,000 psi. Turned well over to Production. yor 7r4 • • e,N Iy/, 4 THE STATE Alaska Oil and Gas of e K ®® Conservation Commission tsr£ 333 West Seventh Avenue Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 SFA SSP Fax: 907.276.7542 www.aogcc.alaska.gov Bo York 7�R Operations Manager ?` Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR K-30 Permit to Drill Number: 196-168 Sundry Number: 316-211 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this y of April, 2016. RBDMS V✓ APR 0 5 2016 • • RECEIVED STATE OF ALASKA MAR 2 16 ALASKA OIL AND GAS CONSERVATION COMMISSION 424 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑✓ ' Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q , Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out ❑Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ . 196-168 -' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-22711-00-00. 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432C Will planned perforations require a spacing exception? Yes ❑ No 0 MILNE PT UNIT KR K-30 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0375132 ' 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): 11,145' - 7,306' - 11,041' ' 7,257' - 2,142 N/A 10,170' Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 6,652' 9-5/8" 6,652' 4,908' 6,870psi 4,760psi Intermediate 11,122' 7" 11,122' 7,295' 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 4-1/2" 12.6#/L-80/Hydril 521 10,392 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development ❑✓ t Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 4/12/2016 ❑ ❑ Commencing Operations: OIL WINJ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Ted Kramer 41— Email tkramer( hilcorp.com Printed Name Bo York Title Operations Manager 7-)* 1, -- - Signature Phone 777-8345 Date 3/30/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. n / 1.LQ - `k_ Plug Integrity ❑ BOP Test l�iJ Mechanical Integrity Test ❑ Location Clearance ❑ Other: i✓' 31700 1651 &15P 7;754- --:- ,e-- ;'-S4- ,e-- ci.5 !� Jet c,k— �.s�tr�icvi !`c,� wart-� h�« �' l O . Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /0` 7 0 RBDMS 0- APR 0 5 2016 APPROVED BY Approved by:aii j' (/ COMMISSIONER THE COMMISSION Date:43,t.lzi-4f,ii4Ls - PIO 344))/c ,/,///44 4 _/ alleGpliNAILid* SubmiForm ane Form 10-403 Revised 11/2015 Afor 12 months from the date of approval. Attachments in Duplicate • Well Prognosis Well: MPU K-30 Hilcorp Alaska,LL) Date: 3/30/2016 Well Name: MPU K-30 API Number: 50-029-22711-00 Current Status: SI Oil Well [TTC-ESP] Pad: K Pa Estimated Start Date: April 12th, 2016 Rig: (SR##1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-168 First Call Engineer: Ted Kramer (907) 777-8320 (0) (985) 867-0665 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: 1552056 Current Bottom Hole Pressure: 2,842 psi @ 7,000'TVD (SBHP measured 7/30/2015 from ESP gauge) Maximum Expected BHP: 2,842 psi @ 7,000'TVD (No new perfs being added/ EMW= 7.81 ppg)) Max. Predicted Surf Pressure: 2,142 psi (Using 0.1 psi/ft gas gradient) Brief Well Summary: MPU K-30 was drilled in 1996 using Nabors 22E and completed in the Kuparuk B and C sands. The well has had multiple ESP changeouts and sand control screens ran and pulled since 1996, the most recent was an ESP changeout in 2015 to re-run a TTC-ESP. During the replacement, the ESP cable was damaged running the equipment in the well and the unit was pulled out, the cable repaired, and the unit re-ran. The ESP failed after a 14 day runtime and a TDR test of the cable indicated a ground fault at (+/-) 3,800ft. Notes Regarding Wellbore Condition • Casing tested to 250/3,500psi for 30 min down to 10,538' on 1/05/2014. • Found no fill during the RWO while cleaning out to 10,777' with Doyon#16 in 2014. • Found no fill in the well during the December 2015 RWO. Objective: The purpose of this work is to retrieve the failed TTC-ESP, and run a new conventional ESP on new 2-7/8" tubing. Brief Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RU Slick Line and pull the tubing stop, pack off, and ESP Pumps. RDMO Slick Line. 3. RD well house and flowlines. Clear and level area around well. 4. RU Little Red Services and 500bbl returns tank with choke manifold. 5. Pressure test lines to 3,000psi. 6. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing, taking returns up casing to 500bbl returns tank. 7. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 8. RD Little Red Services. 9. Set BPV. RU crane. ND Tree. NU 11" BOPE. RD Crane. ! 0 11 Well Prognosis Well: MPU K-30 Ilikoip Aif kf,LI: Date:3/30/2016 10. NU BOPE house. Spot mud boat. WO Rig Procedure: 11. MIRU Hilcorp ASR#1 WO Rig,_ancillary equipment and lines to 500 bbl returns tank. L.: '�� 12. PU Casing Jacks via the beaver slide and Tugger winches to rig floor. CP, 13. Set casing jacks on top of the BOP Annular with Tuggers. Connect Hydraulics and function test J same. 14. Check for pressure and if Opsi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5ppg seawater prior to pulling BPV. Set TWC. 15. Test BOPE to 250psi Low/3,000psi High,annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8" and 4-1/2" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 16. 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. I(+k' 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 '�,tf' 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. 17. Bleed any pressure off casing to 500bbl returns tank. Pull TWC. Kill well w/8.5 ppg seawater as needed. 18. If able to circulate well, mix and pump caustic soda pill (-5 lb/bbl) ahead of Baraklean pill (^'4 gal/bbl) to clean oil of tubulars. Displace with 8.5 ppg seawater. 19. Casing Jack RU Procedure: a. RU Casing jack Hydraulics to the ASR#1 control Panel. Set pressure relief high point as eus.1 1,698 psi. ( . l4Z, L /4.N.) (.p(-I'- b. Cycle jacks up and down to ensure proper function ( dry run without being connected to D)S hanger). 20. MU 4-1/2" landing joint and BOLDS. I 111 Well Prognosis Well: MPU K-30 llileorp Aii,-ka,LL Date: 3/30/2016 21. Set Casing Jack pressure to 1,327 psi (150,000 lbs). Slowly pressure up on jacks. Hold for 5 min. a. If hanger does not unseat, increase pressure in 50 psi increments holding for 5 min between pressure increases. Note:do not exceed 1,698 psi (192,000 lbs) 22. Once hanger becomes free check for flow to insure well is dead. LD Tubing hanger. y"'> 7 a. Contingency: (If a rolling test was conducted.) tfj7' i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 23. RU spoolers and continue to jack tubing out of the well until string weight is comfortably less than ✓� 150,000 lbs. -.If J3o0 px P guy U2.1"„ 24. Set tubing in slips and remove casing jacks. down 4-1 2" Hydril 521 tubingand the TTC-ESP With ASR# 1 Rig. � 25. Continue POOH. Laying / y g t7 P o a. Install thread protectors on pin end of tubing prior to laying down. Tubing should be sent to L ` fps inspection to make ready to re-use. b. Note and take samples of any scale deposits observed on tubing or on the pump. 26. MU RIH with new ESP on 2-7/8" tubing. 27. Land tubing hanger. RILDS. Lay down landing-joint.Test tubing hanger to 250psi low/5,000psi High. a. Note PU (Pick Up) and SO (Slack Off) weights on tally. 28. Set BPV. 29. RD Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500bbl returns tank. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. 2. RU crane. ND BOPE. Pull BPV. Set TWC. 3. NU 4" 5,000#tree and adapter flange and test to 500 psi low/5,000 psi high. 4. Test tubing hanger void to 500psi low/5,000psi high. 5. Pull TWC. RD crane. 6. Move 500bbl returns tank and rig mats. 7. Replace IA x OA pressure gauge if removed (7" x 9-5/8"). 8. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic 5. Existing Tree/Wellhead 6. FWD Circ to Kill Tank Flow Diagram 7. REV Circ to Kill Tank Flow Diagram 8. Bleed to Pits Flow Diagram 9. Blank RWO Changes Form • Milne Point Unit H . SCHEMATIC Well: MPU K-30 Last Completed: 12/16/2015 PTD: 196-168 Itilaorp Alaska,LLC TREE&WELLHEAD DF Elev.:57.57G1 Elev.:28'(Nabors 22E) Tree 5M CIM 4-1/16" DF to 7"Casing Hanger=28.5 11"x 11"5M FMC Gen 5A,w/44/16"FMC Tbg. Wellhead I i l`, I Hngr.,LH.Acme thread 4"CIW H BPV profile 20', , OPEN HOLE/CEMENT DETAIL ., 20" 250 sx of Arcticset 1 in 24"Hole T 9-5/8" 1,500 sx Trinity lite Wate,750 sx PF"E",in 12-1/4"Hole 1: 7" 245 sx Class"G"in 8-1/2"Hole r CASING DETAIL s' t Size Type Wt/Grade/Conn Drift ID Top Btm • BPF 20" Conductor 91.1/H-40E/N/A N/A Surface 112' 0.355 95/8 '' 9-5/8" Surface 47/L-80/NSCC. 8.679 Surface 4,544' 0.0732 ESC,Fianceementer 9-5/8" Surface 47/L-80/Btrc. 8.679 4,544' 4,796' 0.0732 ES C 9-5/8" Surface 47/P-110/Btrc. 8.679 4,796' 6,652' 0.0732 7" Production 26/L-80/Btrc 6.276 Surface 11,122' 0.0383 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/Hydril 521 3.958 Surf 10,392' 0.0152 WELL INCLINATION DETAIL ��(yt b KOP @ 400' Max Hole Angle=57 to 62 deg. f/3,650'to 11,041 Max Hole Angle through perforations=58 deg. TTC DETAIL No Top(MD) Item 1 10,297' D&D Tubing Stop:AA w/4"GS FN 1 2 10,299' D&D Pack-off:DDIC Hi-Flow w/Peek Rings 2 3 10,302' D&D Kobe Knockout::Steel Pin recommended to mitigate erosion due to solids. 3 4 10,307' D&D Stinger:2-7/8"EUE BOX x Moly Packing 5 10,308' Hanger Receptacle:4"'G'Fishing Neck,4-1/2"X 2-3/8"EUE 8RD Pin 12.6/12.754 6 10,309' Discharge Head:380 PUMP 4&5 7 10,309.43' Pump:116-P18 P2P 6 7 8 10,329' Pump:116_P18 P2P 9 10,351' Intake:380 GSVTHV XM(High Volume) • 8 - 10 10,355' Pump Eye:TTCESP I 'i ESP DETAIL 9 1(A&B A 10,344' Crossover:4-1/2"521 Hydril Box X,4-1/2"NSTC Pin,12.6 ff 10 B 10,346' TTC Drilled Tubing Crossover:'ITC 4-1/2"NSTC BOX >atC C 10,357' Upper Tandem Seal:GSB3 DR HL H6 PFS ''2 D 10,364' Lower Tandem Seal:GSB3 DB HI H6 PFS ____ ' E 10,370' Motor:CL-5,MSP1-250-210Hp/2,380V/53A D F 10,387' Sensor:Pheonix X7150 Type 0 G 10,390' Centralizer:Six Fin-BIM iB 10.312' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.C Sands 10,588' 10,658' 7,024' 7,063' 70 11/26/2015 Open F Kup.BSands 10,704' 10,748' 7,088' 7,111' 44 11/25/1996 Open u: G , Ref Log:11/25/1996 GR/CCL-4.5"/5 SPF GENERAL WELL INFO API:50-029-22711-00-00 =}KUPC Sands Orig.Completion by Nabors 4-ES -11/27/1996 ;'f RWO Screens added/Pig Tail Pull&Land-6/15/1998 tpt4 71- KtIPBSarxi RWO w/Nabors 4-ES-4/5/2002&5/5/2004 ¢4 •• ESP RWO w/Nabors 4-ES-10/6/2007 ESP RWO&Replace Screens w/Nabors 3S-8/3/2008 " ESP RWO&Replace Screens w/Nabors 4-ES-8/15/2010 7"4:,r V. ESP RWO w/Doyon 16-8/5/2011&1/13/2014 TD=11,145'(MD)/TD=7,306'(TVD) TTC/ESP Change-out w/Nordic 83-12/16/2015 PBTD=11,041'(MD)/PBTD=7,257'(TVD) Revised By:TDF 1/14/2016 H . • Milne Point Unit PROPOSED Well: MPU K-30 Last Completed: 12/16/2015 Hileori Alaska,LIC PTD: 196-168 TREE&WELLHEAD DF Elev.:57.5'/GL Elev.:28'(Nabors 22E) Tree 5M CIM 4-1/16" DF to 7"Casing Hanger=28.511"x 11"SM FMC Gen 5A,w/4-1/16"FMC Tbg. I:' L:, } i,. Wellhead 20 Hngr.,L.H.Acme thread 4"CIW H BPV profile r' :"' L OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole " '. 9-5/8" 1,500 sx Trinity Lite Wate,750 sx PF"E",in 12-1/4"Hole 7" 245 sx Class"G"in 8-1/2"Hole ' CASING DETAIL .� Size Type Wt/Grade/Conn Drift ID Top Btm BPF 20" Conductor 91.1/H-40E/N/A N/A Surface 112' 0.355 9.5/8"'r® _' \ 9-5/8" Surface 47/L-80/NSCC. 8.679 Surface 4,544' 0.0732 ESC Homoementer9-5/8" Surface 47/L-80/Btrc. 8.679 4,544' 4,796' 0.0732 ES C 9-5/8" Surface 47/P-110/Btrc. 8.679 4,796' 6,652' 0.0732 7" Production 26/L-80/Btrc 6.276 Surface 11,122' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.4/L-80/Hyriril 521 2.347 S,irr ±10,392' 0.00579 WELL INCLINATION DETAIL KOP @ 400' Max Hole Angle=57 to 62 deg. f/3,650'to 11,041 Max Hole Angle through perforations=58 deg. r JEWELRY DETAIL ,/ No Top(MD) Item 1 =10,344' Pump 2 ±10,354' Gas Seperator 3 ±10,357' Upper Tandem Seal 4 ±10,364' Lower Tandem Seal I5 ±10,370' Motor L 6 ±10,387' Sensor wi Centralizer:Six Fin-BTM @-±70,3 i2' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status Kup.C Sands 10,588' 10,658' 7,024' 7,063' 70 11/26/2015 Open ,I Kup.B Sands 10,704' 10,748' 7,088' 7,111' 44 11/25/1996 Open t' Ref Log:11/25/1996 GR/CCL—4.5"/5 SPF L GENERAL WELL INFO API:50-029-22711-00-00 Orig.Completion by Nabors 4-ES -11/27/1996 RWO Screens added/Pig Tail Pull&Land—6/15/1998 flit 2 RWO w/Nabors 4-ES—4/5/2002&5/5/2004 )3&4 ESP RWO w/Nabors 4-ES—10/6/2007 ESP RWO&Replace Screens w/Nabors 3S-8/3/2008 ESP RWO&Replace Screens w/Nabors 4-ES—8/15/2010 it ESP RWO w/Doyon 16-8/5/2011&1/13/2014 ITC/ESP Change-out w/Nordic#3—12/16/2015 5 'IC I 6 r, .;. ii n4}KUP C Sands j}KuPes 7". .r `.C,.:►' TD=11,145'(MD)/TD=7,306'(TVD) PBTD=11,041'(MD)/PBTD=7,257'(TVD) Revised By:TDF 1/14/2016 • • 11 Milne Point 2016 ASR Rig 1 nth AA,i.�, Knight Oil Tools BOP lstokSlips 200 Ton Slips ; ', Jacking System Ir 4 Shaffe � s 11" - 5000 11111i1 1B1 111111111 III III, A.111,111 li �-y rr - ■ _ T m 401 Yilib . in irt - is . .. ...._,„,... i .-, Blind zuniz_ ,.- , ._. ‘ '.-. . , "" , ,...,___,,,„ .,. . Kill Li„ , ne 2" Choke Line ;� 1fiE 1!1 !!1 1!'1 .111 "° ,,,,, ; - .,, , „ ,,, . . ,..ii. } , . , .... .. ..„. .: „ , , „,.., ,.. , . _ _ _ ; . . Ifl 1!! r 111 aft Manual Manual Manual HCR Updated 2/08/16 • • II Choke Manifold ASR#1 11/01/2015 no,,ai1 '11,,I,A.Lf C Digital Reverse line back to Kill Manifold Pressure Readout `` C2 ��`J, C3 Digital Pressure Transmitter i- I 1 0 I., r°j - ,- a ,a From Choke Line Manual Choke i( i�J� o ..,o_...____ B amu . ��o , c.� ___� .a ( o VII Remote `; A Choke C4 C5 C6 C711100.1por II II ,k l I } `GS J, , C) Ci 7� C) 7 ry I 1111 It, II III III 9111k. I X1. 31 - n� _ ill /II �.'�, C9 . All Valves 2" I Piper Series PB Ball Valves 6,170 psi Working 10,000 psi Tested Auk .4,1rt C8�� C11 - CI0IIIIII 10, E. Jam► t 111 C13 f C15 if P Iii t*1 C12 5, E A.-- Ir= �� !� C14 ®� CI6rt 0 oma I P,, II 11 To Panic Line 1502 Union Outside Alik End Capped To Gas Buster C I 1 EXISTING TRAD MPU IC-30 Wellhead/Tree Milne Point Unit 'Mem p LLC Tree Caplirk Tree Valve 4-1/16" 5M 4;\_...0,�. p� 14:111111?il III Tree Cross 4-1/16" 5M I\Dro)01 Tree Valve 4-1/16" 5M O SSV 4-1/16" 5M 4:601.. 7 Tree Valve 4-1/16" 5M Ivo for ;(i_pOj/ ESP Cable Control Line •r Tubing Adapter rig I Tubing Head iii Ill 11"5M Top x11" 5M Bt ,1 fit` [1] 1:111K6c;147,11 114 lii ti El= I sit psi ,i 40 Casing Head I�II�I ■rim , •t, ]I 11"5M Top x 11"5M Btm ! ala t r� • • 1 0 g. (3 -a• p- -,-, 0 › c, em 3 -..s, -,. -,f,',, t--.• *4141XCI-7140 0 0 '0 OD 9T3 & 6 E =2. '',. '3'. .`" (D 0 5_ ..., .7, pa. 0 ..., Y 4 2 u 'V c0 7, ",,,i -c,,, •''''. V tal 1:0400:1---iXICI ca A -a a 2 o u 0 m o u f , 0v4 it t 0 co 1 co _. to 0 0 ca Ul o 83 o 4 m (.4 U :It! 2 gf Y 0 -C 1.1 w0 "- I iw 1 u t ra 2 - 2. v . . . 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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 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 Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From: Tom Fouts [mailto:tfouts@hilcorp.com] Sent: Wednesday, March 30, 2016 10:32 AM To: Schwartz, Guy L (DOA); Ted Kramer Cc: Quick, Michael J (DOA); Taylor Wellman Subject: RE: K-30 WO with Casing Jack(PTD 196-168) Guy, Hilcorp Alaska LLC is requesting the cancelation of Sundry No. 316-033 for K-30. Thanks, Tom Fouts ( Senior Ops/Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907)777-8398 Mobile: (907) 351-5749 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, March 30, 2016 9:56 AM To: Ted Kramer Cc: Quick, Michael J (DOA);Tom Fouts; Taylor Wellman Subject: RE: K-30 WO with CAsing Jack(PTD 196-168) 1 RBDMS I-L-- APR 0 1 2016 Ted, I think it would be better to cancel the original sundry and submit a new sundry with the casing jack procedure. There is a lot of supporting documentation I want to include and it would just be cleaner. Technically we are there . Just want to clean up the paperwork. 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 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 Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From: Ted Kramer [mailto:tkramer@hilcorp.com] Sent: Wednesday, March 23, 2016 8:00 AM To: Schwartz, Guy L (DOA) Cc: Quick, Michael J (DOA); Tom Fouts; Taylor Wellman Subject: RE: K-30 WO with CAsing Jack(PTD 196-168) Guy, I have an update to Question number 1 below. There is some confusion in the industry on the connection limitation for the 4-1/2" 12.6#L-80 Hydril 521 connection strength. The literature on the Tennaris Website shows the pipe body rated to 288K and the 521 connection (published) good to 66.5%tensile or efficiency(192K). I consulted with Kevin Walker at Weatherford and learned that typically the industry believes that Hydril connections are rated the same as the pipe body. I then researched the BP files on this well and found that in their design criteria for this well they used 80%of pipe body tensile (80%of 288K)or 231K as their design criteria. I have a call into Tennaris but unless I can prove that we can go to 231K, I am backing down the max pull for K-30 to 192,000 pounds in agreement with the Tennaris published data of 66.5%of body yield strength. We were on the well on December 7th, 2015 and at that time we pulled 160K to unseat the tubing hanger.So I do not believe it will be an issue but I want to be sure. Sincerely, Ted Kramer Sr. Operations Engineer Hilcarp Alaska, LLC. 0 907-777-8420 C 985-867-0665 2 • • • From: Ted Kramer Sent: Tuesday, March 22, 2016 6:58 AM To: 'Schwartz, Guy L(DOA)' Cc: Quick, Michael J (DOA); Tom Fouts; Taylor Wellman Subject: RE: K-30 WO with CAsing Jack(PTD 196-168) Guy, Please see responses below in blue: Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From: Schwartz, Guy L(DOA) [mailto:guv.schwartz@alaska.gov] Sent: Thursday, March 17, 2016 2:44 PM To: Ted Kramer Cc: Quick, Michael J (DOA) Subject: K-30 WO with CAsing Jack(PTD 196-168) Ted, A couple more things I have questions on: 1) What will be your max pressure ( pull tension)when using jack in case you can't move pipe initially at 161,000Ibs(ie 1424 psi ram pressure)? Maximum pressure will be 2,050 psi. This equates to a pressure of 231,732 lbs. (80%of the capacity of the 4-1/2" L-80 521 Hydril tubing string) 2) Do you have a pic of the BOP with stabilizer rams and chains rigged up so we can see how this looks? I do not have a picture yet. System is still being assembled for this job. I will get a picture once we get it assembled on the well. 3) What model is this casing jack? Model#Atlas V1200 Ton Hydraulic Casing Jack 4) Will need a procedure for casing jack inserting into the sundry at step 15 . Be detailed . Look at KDU -1 as example. Chad sent a detailed procedure for the 385 jack that was rigged up. Attached 3 • • 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 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 Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). 4 • Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Tuesday, March 22, 2016 6:58 AM To: Schwartz, Guy L(DOA) Cc: Quick, Michael J (DOA);Tom Fouts;Taylor Wellman Subject: RE: K-30 WO with CAsing Jack (PTD 196-168) Attachments: MPU K-30 WO Procedure W Casing Jacks 2016-2-2 V3.docx Follow Up Flag: Follow up Flag Status: Flagged Guy, Please see responses below in blue: Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, March 17, 2016 2:44 PM To: Ted Kramer Cc: Quick, Michael J (DOA) Subject: K-30 WO with CAsing Jack(PTD 196-168) Ted, A couple more things I have questions on: 1) What will be your max pressure ( pull tension) when using jack in case you can't move pipe initially at 161,000lbs(ie 1424 psi ram pressure)? Maximum pressure will be 0psi. This equates to a pressure of 32 lbs. (80%of the capacity of the 4-1/2" L-80 521 Hydril tubing string) /2 U ( CI Z,Gz,)Ili, h ef-q'1` - C 2) Do you have a pic of the BOP with stabilizer rams and chains rigged up so we can see how this looks? I do not have a picture yet. System is still being assembled for this job. I will get a picture once we get it assembled on the well. 3) What model is this casing jack? 1 II S Model#Atlas YJ 200 Ton Hydraulic Casing Jack 4) Will need a procedure for casing jack ...... inserting into the sundry at step 15 . Be detailed . Look at KDU -1 as example. Chad sent a detailed procedure for the 385 jack that was rigged up. Attached 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 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 Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). 2 Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Friday, March 11, 2016 10:55 AM To: Schwartz, Guy L(DOA) Cc: Taylor Wellman; Bo York;Tom Fouts; Mike Dunn Subject: MPU K-30 Follow Up to Use of Casing Jacks Discussion Sundry# 316-033 PTD# 196-168 Attachments: Atlas Weight to Pressure Conversion Chart.xlsx; MPU K-30 WO Procedure W Casing Jacks 2016-3-8 V3.docx Guy, This e-mail is a follow up response to the meeting we had detailing the use of Casing Jacks on the above well workover The meeting was attended by AOGCC Engineers Jim Regg, Mike Quick and yourself and Hilcorp Engineers Taylor Wellman and myself on February 22nd, 2016. The questions Hilcorp was asked to explore were: 1.) What is the Axial load that the 9-5/8" Surface Casing would be able to support with the given the Well configuration plus the weight of the Completion equipment, BOP Stack and the casing jacks? 2.) How would that load be affected by a well head that was tilted off center(side loading) and How does Hilcorp plan to manage these side loads. 3.) What circuit on the ASR#1 Rig will the Casing jacks plug into? 4.) What will the pressure data sheet to force conversion look like for this set of Casing Jacks? 1.) What is the Axial load that the 9-5/8" Surface Casing would be able to support with the given the Well configuration plus the weight of the Completion equipment, BOP Stack and the casing jacks? Summary: Hilcorp utilized an independent third party engineering firm to perform the structural analysis on this well. The Axial Load Capacity for the 9-5/8" Casing String was calculated to be to be 625,000 pounds. The axial load of the system was calculated to be 334,500 pounds in case#1 and 189,500 pounds in case#2. Both well within the 9-5/8" Axial Load Capacity. Discussion: The Axial Load Capacity is based on the steel of the 9-5/8" 47#L-80 Casing. The cement job was taken into consideration but was not used in the calculations, only the 9-5/8" casing. Cement Job on the 9-5/8" Casing is as follows: Stage# 1—294 bbls. of 13.2 ppg Trinity Lite Wate cement. Stage#2 -60 bbls. of 13.2 ppg Trinity Lite Wate cement squeezed into the stage collar at 2,800 ft. Top job—290 bbls of permafrost cement pumped from 1,250'to surface. 1 The Axial Load of the system in case# was calculated to be 334,500 pounds. Thi includes the casing jacks+BOP Stack + the tubing string ESP completion (zero allowance for buoyancy)+50%of the 7" casing string. The weight of the casing jacks is 7,500 pounds. The weight of the BOP stack is 21,000 pounds. The weight of the Tubing and ESP Completion was calculated to be 161,000 pounds in air(no buoyancy)which is conservative. The weight contribution of the 7" casing was taken to be 50%of the weight of the casing string. Hilcorp feels that this is also conservative. The 7" casing was cemented with 245sx of class"G"cement. This was enough cement to cover the zones of interest. While the remaining casing was not cemented in place,the drilling mud left in the 7"X 9-5/8"annulus was sure to have solidified and acts to grout the casing string in place to some degree. The other piece of information we do not have is how much tension the 7"was put in when the slips were set. This would be a better indication of how much downward force the 7 "exerts on the well head. Since these factors are unknown,50%of the 7" casing weight was used for case 1. 2.) How would that load be affected by a well head that was tilted—leaning off center( side loading) and How does Hilcorp plan to manage these side loads. Summary: To answer this question Hilcorp Arrived at a Maximum Allowable tilt of the bop Stack, such that,the resulting combined axial and side load equals the allowable stress of the 9-5/8" L-80 casing(with a safety factor applied 60%of 80,000). The results of this exercise is that as long as the top of the BOP Stack is not off plumb by more than 5 inches (1.4 degrees),the 9-5/8" casing can support the combined load(axial and side)without mitigation measures. Discussion: Hilcorp looked at the three cases below in order to arrive at the maximum amount of well head deviation to be allowed. Jack and BOP 7"Casing Load Tubing String Total Axial on 9- Allowable Angle Deflection at Top of Stack Weightg Weight (lbs) Case (lbs) Weight(lbs) note 1 note 2 5/8" Casing(lbs) Off Vertical (Tilt) (inches) Stack 1 28,500 161,000 145,000 334,500 0.9 degrees 3" 2 28,500 161,000 na 189,500 1.4 degrees 5" 3 28,500 140,000 na 168,500 1.7 degrees 6" Notes: 1. Tubing string weight in LC 1 and LC 2 does not assume buoyancy. Tubing string weight in LC 3 assumes buoyancy. 2. 7" casing is connected to 9-5/8" casing and also cemented at bottom of hole. LC 1 assumes 50%of weight supported by the 9-5/8" casing. 3. Deflection at top of BOP stack is how far from a plumb line through center of casing at surface, based on an overall height of 17.6 feet to top of stack. Load case#1 was deemed not applicable due to the fact that the 7" casing is hung at the bottom of the stack and therefore does not exert a side loading component acting on the bending moment of the BOP/Casing Jack stack. Also the 7'casing is most likely self-supporting. Load Case#2 was selected as being the most applicable to the K-30 pulling plan.This case assumes no buoyancy factor which we know is not true so that only adds to the safety factor. 2 • • The axial Load of 189,500 lbs. divided by the cross sectional area of the 9-5/8" casing is 13,964 psi of the 80,000 psi associated with the L-80 casing. Even with a 60%safety factor applied (80,000 X .6=48,000),the 13,964 psi accounts for 29%of the casing strength. The remaining 34,036 psi is available to support a side load component. From there,the angle and the distance from plumb the 17.6' moment arm would have to be bent in order to produce enough bending force to equal the remaining allowable force available in the 9-5/8" casing(with the 60%Safety Factor). This distance calculated out to 5.9" (rounded to 5") or 1.4 degrees. This assumes that no mitigation measures are taken and the stack is allowed to move to its own will. This is not the case (See Mitigation below). Load case#3 is really load case#2 with buoyancy applied. Mitigation: The ASR#1 Rig does have measures to adjust and hold the BOP Stack in the vertical position. ASR#1 is equipped with a hydraulic system (attached to the front of the rig)that attaches to the BOP stack and has the capability of correcting the BOP to the desired vertical position. Once the BOP is plumb,the cylinders can be locked in place.This will insure that the BOP Stack is in the vertical position. Since the casing Jacks attach to the BOP stack with an adapter plate, proper alignment is assured. Here are some Sketches of the plumbing system. Note: The ring that fits around the BOP stack will actually be a chain with binders. We opted for the chain set up so it would be easier to adjust for different stack heights and sizes of BOP stacks(11"vs. 13-3/8" BOP stacks). 3 i • t.a_MI / 4 \ / . 6 . .�.• t \ • I_ / he L / , ,c,, /(0,, ,,. 7 „ ..,....... „, „. ( 0 0 i n 1111 \ el _ �� . ' :,.......„..----; - I I i` Ir' L r i _ 4 0 I/ 1„ '''--1,...„,---1 Iiii ', „.., 's-..."' I I,a.."'"li10 '-'., . 1 II ,'A ' ? **--,,, ;:ti r 1 . gpr _ . 1111 .rd,,,„.,.--'**".."-- "''.\ ,_*-,-,:i- 7 7_, IL /./. -..., _ 011111111.r- - --, -- -— id____':,* - - . 41,.. fir _ 41Silloo, / \soh, I,/ 4r / ,ibill,,,4, i f / ( . „..--- je / 3.) What circuit on the ASR#1 Rig will the Casing jacks plug into? The casing Jacks will tie into the Tong Circuit. This will be the same circuit as the oil cooler Fan, and the rig up valve bank. 4.) What will the pressure data sheet to force conversion look like for this set of Casing Jacks? Attached to this e-mail is a Weight to pressure chart for converting pressure to lbs of force. To match the weight of the K-30 Completion,a pressure of 1,424 psi converts to the 161,000 lb weight of the completion. Also attached is the modified Sundry for your approval. Changes from the original approved Sundry are in red. Please let me know if this explanation is satisfactory and that the modifications are approved,or if further clarification is required. 5 I } E _6�)AL 'ik-'t : ftiC:,..,,54,14%,= :fnl ' Ntr t PC 14Ia. 6. A `,!4--",.,111,1:14eJ4, • U�. 'Ii€�tre7,,. , pe$ ') or AALAAe s 7 Q 044/94,; $.::- /t) 4-/t .6, %14.1 A •-i c.1, O LA1 $ .(kfc- i . .52. .-. %.(1.7...6"1 2.9.. < o,it! 6 �. Q, c Z :auks: _z. 3�,s75'` 1 (]ii 7aK 430k-11 le izeFbf1 '(f T4P1: : 6. 41.9.4L4fil . C3 - r wtAre.44-- efixig. itie (DFM B '-s Weftawr 5c. rv:7 0 re" icr A J -11% 1.67 •Kl.. ,-,10. 61i5`1 - 11.47' `(f"71 ` �i r .- : 3 .2'1 Fr '�l Keg itfaizefof cr _ 0,GS-6"F"j •r AL 0.65'6 a!o' 6 •r i , .*_/ -,,� 4:, ,-� - cr2- fir ' C1acx2tb (1.1'srL) ' Ltf.‘1) 2- . A : 15.5'7,ti� 43 w -7&,13i1--5; 413.67k a") 47 V71 K • • k . P10001 (4C. 3 o '&L.L- �'g�/s.v cAII M6 Gtt . iv `b i4 W 8 �o. ACOFF ,Q wag,iv,' �� 3110 J t 6 5) NGINEER,S Ett7�t �-�Fti a wICI dale 006 i • Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Thursday, March 17, 2016 10:15 AM To: Schwartz, Guy L(DOA); Quick, Michael J (DOA) Cc: Taylor Wellman; Bo York;Tom Fouts; Mike Dunn Subject: RE: MPU K-30 Follow Up to Use of Casing Jacks Discussion Sundry# 316-033 PTD# 196-168 Attachments: 201603161103.pdf Follow Up Flag: Follow up Flag Status: Flagged Guy, Please refer to the answers below in Red. From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, March 16, 2016 9:31 AM To: Ted Kramer; Quick, Michael 3 (DOA) Cc: Taylor Wellman; Bo York; Tom Fouts; Mike Dunn Subject: RE: MPU K-30 Follow Up to Use of Casing Jacks Discussion Sundry # 316-033 PTD # 196-168 Ted, We have a couple of follow up questions: 1) How was the axial load capacity calculated for the 9 5/8"casing? (you stated 625,000 lbs) I have attached the Axial Load Capacity calculation above for your review. In discussing the calculation with Coffman Engineering,the crux of the caic is the amount of unsupported casing sticking up out of the ground as it relates to its resistance to buckling. Since this unsupported distance is short(18.5") and the casing is cemented in place with the top job(see below),the resistance to buckling is higher. The actual calculation comes out to 639,740 pounds. I rounded down to 625,000 pounds. 2) Has wellhead vendor been contacted to verify if compressional load and operation is safe as proposed? Hilcorp has contacted the Wellhead Vendor(FMC)and received a verbal response that FMC does not see a problem with this operation as proposed. Hilcorp is currently awaiting a written response. Hilcorp has also discussed this operation with Cameron and received a similar response. This was more to get a second opinion as Cameron is not the wellhead vendor at Milne Point. 3) Not sure about using chain instead of clamp for stabilizing BOP stack. Chain would have some slack no matter how you tighten and would allow BOP movement since you are only attached at two points. Using clamps that are integral to the BOP would eliminate movement. The use of chains and binders on BOP stacks for stabilization is not an uncommon practice. The chain, in this case,can be wrapped around the BOP stack and bites well onto the metal of the BOP. It then can be properly tightened with the binders. The cylinders do attach at two points but each cylinder is capable of pushing or pulling which yields control in the full circle of motion. The advantage of using the chain is that it easily adapts to the different diameters of the BOP stack relative to height changes. Hilcorp believes that this will yield better tightness and control than a ring clamp wrapped around the BOP stack that may not line up exactly where it needs to with varying wellhead heights. 1 • • 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 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 Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From: Ted Kramer [mailto:tkramer@hilcorp.com] Sent: Friday, March 11, 2016 10:55 AM To: Schwartz, Guy L(DOA) Cc: Taylor Wellman; Bo York; Tom Fouts; Mike Dunn Subject: MPU K-30 Follow Up to Use of Casing Jacks Discussion Sundry # 316-033 PTD # 196-168 Guy, This e-mail is a follow up response to the meeting we had detailing the use of Casing Jacks on the above well workover The meeting was attended by AOGCC Engineers Jim Regg, Mike Quick and yourself and Hilcorp Engineers Taylor Wellman and myself on February 22"d, 2016. The questions Hilcorp was asked to explore were: 1.) What is the Axial load that the 9-5/8" Surface Casing would be able to support with the given the Well configuration plus the weight of the Completion equipment, BOP Stack and the casing jacks? 2.) How would that load be affected by a well head that was tilted off center( side loading) and How does Hilcorp plan to manage these side loads. 3.) What circuit on the ASR#1 Rig will the Casing jacks plug into? 4.) What will the pressure data sheet to force conversion look like for this set of Casing Jacks? 1.) What is the Axial load that the 9-5/8"Surface Casing would be able to support with the given the Well configuration plus the weight of the Completion equipment, BOP Stack and the casing jacks? Summary: Hilcorp utilized an independent third party engineering firm to perform the structural analysis on this well. The Axial Load Capacity for the 9-5/8" Casing String was calculated to be to be 625,000 pounds. The axial load of the system was calculated to be 334,500 pounds in case#1 and 189,500 pounds in case#2. Both well within the 9-5/8" Axial Load Capacity. Discussion: The Axial Load Capacity is based on the steel of the 9-5/8"47#L-80 Casing. The cement job was taken into consideration but was not used in the calculations, only the 9-5/8" casing. Cement Job on the 9-5/8" Casing is as follows: Stage#1—294 bbls. of 13.2 ppg Trinity Lite Wate cement. 2 • Stage#2 -60 bbls. of 13.2 ppg Trinity Lite Wate cement squeezed into the stage at 2,800 ft. Top job—290 bbls of permafrost cement pumped from 1,250'to surface. The Axial Load of the system in case# 1 was calculated to be 334,500 pounds. This includes the casing jacks+BOP Stack + the tubing string ESP completion (zero allowance for buoyancy)+50%of the 7" casing string. The weight of the casing jacks is 7,500 pounds. The weight of the BOP stack is 21,000 pounds. The weight of the Tubing and ESP Completion was calculated to be 161,000 pounds in air(no buoyancy) which is conservative. The weight contribution of the 7" casing was taken to be 50%of the weight of the casing string. Hilcorp feels that this is also conservative. The 7" casing was cemented with 245sx of class "G" cement. This was enough cement to cover the zones of interest. While the remaining casing was not cemented in place,the drilling mud left in the 7" X 9-5/8" annulus was sure to have solidified and acts to grout the casing string in place to some degree. The other piece of information we do not have is how much tension the 7" was put in when the slips were set. This would be a better indication of how much downward force the 7 "exerts on the well head. Since these factors are unknown, 50%of the 7" casing weight was used for case 1. 2.) How would that load be affected by a well head that was tilted—leaning off center( side loading) and How does Hilcorp plan to manage these side loads. Summary: To answer this question Hilcorp Arrived at a Maximum Allowable tilt of the bop Stack, such that,the resulting combined axial and side load equals the allowable stress of the 9-5/8" L-80 casing(with a safety factor applied 60%of 80,000). The results of this exercise is that as long as the top of the BOP Stack is not off plumb by more than 5 inches (1.4 degrees),the 9-5/8" casing can support the combined load (axial and side) without mitigation measures. Discussion: Hilcorp looked at the three cases below in order to arrive at the maximum amount of well head deviation to be allowed. Jack and BOP 7" Casing Load Tubing String Total Axial on 9- Allowable Angle Deflection at Top of Stack Weight Weight(lbs) Case (lbs) Weight (lbs) note 1 note 2 5/8" Casing(lbs) Off Vertical (Tilt) BOP Stack(inches) 1 28,500 161,000 145,000 334,500 0.9 degrees 3" 2 28,500 161,000 na 189,500 1.4 degrees 5" 3 28,500 140,000 na 168,500 1.7 degrees 6" Notes: 1. Tubing string weight in LC 1 and LC 2 does not assume buoyancy. Tubing string weight in LC 3 assumes buoyancy. 2. 7"casing is connected to 9-5/8" casing and also cemented at bottom of hole. LC 1 assumes 50%of weight supported by the 9-5/8" casing. 3. Deflection at top of BOP stack is how far from a plumb line through center of casing at surface, based on an overall height of 17.6 feet to top of stack. 3 Load case# 1 was deemed not applicable due to the fact that the 7" casing is hung at the bottom of the stack and therefore does not exert a side loading component acting on the bending moment of the BOP/Casing Jack stack. Also the 7' casing is most likely self-supporting. Load Case#2 was selected as being the most applicable to the K-30 pulling plan.This case assumes no buoyancy factor which we know is not true so that only adds to the safety factor. The axial Load of 189,500 lbs. divided by the cross sectional area of the 9-5/8" casing is 13,964 psi of the 80,000 psi associated with the L-80 casing. Even with a 60%safety factor applied (80,000 X.6=48,000),the 13,964 psi accounts for 29%of the casing strength. The remaining 34,036 psi is available to support a side load component. From there,the angle and the distance from plumb the 17.6' moment arm would have to be bent in order to produce enough bending force to equal the remaining allowable force available in the 9-5/8" casing(with the 60%Safety Factor). This distance calculated out to 5.9" (rounded to 5")or 1.4 degrees. This assumes that no mitigation measures are taken and the stack is allowed to move to its own will. This is not the case (See Mitigation below). Load case#3 is really load case#2 with buoyancy applied. Mitigation: The ASR#1 Rig does have measures to adjust and hold the BOP Stack in the vertical position. ASR#1 is equipped with a hydraulic system (attached to the front of the rig)that attaches to the BOP stack and has the capability of correcting the BOP to the desired vertical position. Once the BOP is plumb,the cylinders can be locked in place.This will insure that the BOP Stack is in the vertical position. Since the casing Jacks attach to the BOP stack with an adapter plate, proper alignment is assured. Here are some Sketches of the plumbing system. Note:The ring that fits around the BOP stack will actually be a chain with binders. We opted for the chain set up so it would be easier to adjust for different stack heights and sizes of BOP stacks(11"vs. 13-3/8" BOP stacks). 4 • • 1 i ,--------tr-21-------„ / 0 0 to Ns\\\ , a .0 n ___ // I .i (---___ 0 ( 0 7 .„- \ 0_ _ 1E i 0 . J ..,.. 0, 144) 1 0 1. \ , , - 1 / 0 - / ,./ 7--zz--- .....,.....„------ .:_.? .. , ....___ . .,..,, Y rri i tl / \ raj-----1 T-7 7 5 c j 1lv y ll Vis.- Il. � , 1, __.... r.. I � t - I1( IIJ 1 f iiii(-. 1" rilr" i 1 0 r, -�. _,.___ D .e,„..,--''''''' / (11-S,. e. I)/ 41411k144111k A e IV 0 ,./; / r\ / I &--...,. ,.... .,..„ / a)is a/ ,,,,/, . 6)-)1L-Y ., . --,- / f; \ 0„. ,.--------,,,,, r:. ! 3.) What circuit on the ASR#1 Rig will the Casing jacks plug into? The casing Jacks will tie into the Tong Circuit. This will be the same circuit as the oil cooler Fan, and the rig up valve bank. 4.) What will the pressure data sheet to force conversion look like for this set of Casing Jacks? Attached to this e-mail is a Weight to pressure chart for converting pressure to lbs of force. To match the weight of the K-30 Completion, a pressure of 1,424 psi converts to the 161,000 lb weight of the completion. Also attached is the modified Sundry for your approval. Changes from the original approved Sundry are in red. Please let me know if this explanation is satisfactory and that the modifications are approved, or if further clarification is required. 6 Sincerely, • • Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 7 • • Atlas Casing Jack Pressure to Force Conversion Chart Single Cylinder 4 Cylinder System PSI LBS LBS W 500 14,130 56,520 500,000 ! 1000 28,260 113,040 1500 42,390 169,560 450,000 - 2000 56,520 226,080 2500 70,650 282,600 400,000 ----- 3000 84,780 339,120 350,000 --__ 3500 98,910 395,640 4000 113,040 452,160 N 300,000 a 250,000 --------_� O _ X 161000 200,000 ---________—_ _ 161,100 Lbs. 1500 169560 150,000 =--- i 100,000 ---- X=(161,000)*(1,500) /(169,560) = 1424 Psi. 50,000 ---- -- - 0 500 1000 y yL k 0'6 12.6 `1/6'f Z 8$ aoa /6s c • • ►eight to Pressure Chart • LBS Linear(LBS) 1,424 psi 1500 2000 2500 3000 3500 4000 4500 Pressure(Psi) eai 111 49e i p o Q a a_ LU 0 LCD 0 _c +- N 0 N co V � CSA _a a)U- co U 4- O CU • • - " a D o E6 at g 443 g ti 3 - 2 U °; r .1:4 3. 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MI) , ir f \IIP 111111111k lir AC.:,„.:.,:;:',.. ,,A,::',-;':: :l\\ "P'' 3 , .1 '', '''.40040114**P'Or ri . • x n } 2 m Fo- N j j V Y = rig xi u A o.v, r.- cti n Y. `C i:.2 .ss - wee. us CO & y - Y t IA+) v)� - 6 VP L IP Y •,.. 2 2.U C6 u- 4--a tib a) O 0 .4:7s, 1 i U U C v co 0 0 2 v) -I—+ L)aJ •_ hAa LL C C CO tab ` CO N a) N -0 E -0 > 0) V 'S tiO 0 v ° co co 4p 5 im O ' 61 p U C •_ v) I i-+ CN Q U C o }' oa) a) C co '' IU L 0 O 00 cc p ' p cu p 0L _ -a' N Mi. a) N +-1 4-, M C a) Q- •bC—.A a--+ +a) = U O L- C 1- a) u J (0 I O +-, 0 N 'M E C }' a) = L C • 0 U a--' Q N (0 f6 C - a) •— O -0 co O E O c- —14 'a0 > 's a) < ' N I— _ 0 I cr 0 R- N C CIO - •—• • •CO N U • ca a) U 0 r 4 vOF Tici //7,, �,,s THE STATE Alaska�// Alaska Oil and. Gas rte ofALAsKA Conservation Commission 333 West Seventh Avenue if GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS' Fax: 907.276.7542 } www.aogcc.alaska.gov iCtk 03 Bo York Operations Manager ct Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR K-30 Permit to Drill Number: 196-168 Sundry Number: 316-033 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair 5F DATED this U day of January, 2016. RBDMS L-`' JAN L 5 2016 • • RECEIVED ` STATE OF ALASKA JAN 14 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q . Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing El Other: ESP Change-out Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC - Exploratory ❑ Development ❑✓ 196-168 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-22711-00-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432C Will planned perforations require a spacing exception? Yes ❑ No ❑., / MILNE PT UNIT KR K-30 - 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0375132 - 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): . 11,145' 7,306' • 11,041' ' 7,257' 2,142 N/A 10,170' Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 6,652' 9-5/8" 6,652' 4,908' 6,870psi 4,760psi Intermediate 11,122' 7" 11,122' 7,295' 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 4-1/2" 12.6#/L-80/Hydril 521 10,392 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development Q, Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 1/27/2016 WDSPL ❑ Suspended❑ - ❑ ❑ Commencing Operations: OIL WINJ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact • Ted Kramer Email tkramer(a�hilcorp.com Printed Name Bo York Title Operations Manager lie Me'lc Signature �idZ-140-L„ Phone 777-8345 Date 1/14/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\�- a33 Plug Integrity ❑ BOP Test d Mechanical Integrity Test ❑ Location Clearance ❑ Other: # 3 aop/0, pfd c .. Seo 1.--- Post _Post Initial Injection MIT Req'd? Yes ❑ No ❑ r.� �. Spacing Exception Required? Yes ❑ No Subsequent Form Required: /t0" I 0 1 lAPPROVED BY / / Approved by: , ' ✓9 COMMISSIONER THE COMMISSION Date: /— z(- /6. yz (-z',- ,t. >aQ, ii' I� ,LK W/� Submit Form and v d Form 10-403 Revised 11/2015 op Iciii `� id for 12 months fr m the date of approval. Attachments in Duplicate RBDMS LL JAN 2 5 2016 • Well Prognosis Well: MPU K-30 Hilcorp Alaska,LL, Date: 1/14/2016 Well Name: MPU K-30 API Number: 50-029-22711-00 Current Status: SI Oil Well [TTC-ESP] Pad: K-Pad Estimated Start Date: January 27, 2016 Rig: ASR# 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-168 • First Call Engineer: Ted Kramer (907) 777-8320 (0) (985)867-0665 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 2,842 psi @ 7,000'TVD (SBHP measured 7/30/2015 from ESP gauge) Maximum Expected BHP: 2,842 psi @ 7,000'TVD (No new perfs being added/ EMW=7.81 ppg)) Max. Predicted Surf Pressure: 2,142 psi � (Using 0.1 psi/ft gas gradient) L �5 / 1 1`4-"j Vo �c�t 1=�"� nnom_ o fc-r, Brief Well Summary: 10 Hf 0 Go 3rfC3, MPU K-30 was drilled in 1996 using Nabors 22E and completed in the Kupa uk B and C sands. The well has had multiple ESP changeouts and sand control screens ran and pulled since 1996, the most recent was an ESP changeout in 2015 to re-run a TTC-ESP. During the replacement, the ESP cable was damaged running the equipment in the well and the unit was pulled out, the cable repaired, and the unit re-ran. The ESP failed after a 14 day runtime and a TDR test of the cable indicated a ground fault at (+/-) 3,300ft. Notes Regarding Wellbore Condition • Casing tested to 250/3,500psi for 30 min down to 10,538'on 1/05/2014. • Found no fill during the RWO while cleaning out to 10,777'with Doyon#16 in 2014. • Found no fill in the well during the December 2015 RWO. Objective: The purpose of this work is to retrieve the failed TTC-ESP, and run a new ESP on new 2-7/8" tubing. / Brief Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well.Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services and 500bbl returns tank with choke manifold. 4. Pressure test lines to 3,000psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing,taking returns up , casing to 500bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services. 8. Set BPV. RU crane. ND Tree. NU 11" BOPE. RD Crane. 9. NU BOPE house. Spot mud boat- . • , H Well Prognosis • Well: MPU K-30 IIilcorp Alaska,LLQ Date: 1/14/2016 WO Rig Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if Opsi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5ppg seawater prior to pulling BPV. Set TWC. 12. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8" and 3-1/2" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure ,•:-'1-)� c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor K ✓ the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) ( f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500bbl returns tank. Pull TWC. Kill well w/8.5 ppg seawater as needed. 15. If able to circulate well, mix and pump caustic soda pill (-5 lb/bbl) ahead of Baraklean pill ("'4 gal/bbl) to clean oil of tubulars. Displace with 8.5 ppg seawater. 16. MU 4-1/2" landing joint and BOLDS. 17. Pull over string weight on tubing hanger to confirm free . LD tubing hanger. a. Contingency: (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. -- s 4l.5 4 i) 1-e>11 <-1,- 18. a18. POOH. Lay down 4-1/2" Hydril 521 tubing and the TTC-ESP. a. Install thread protectors on pin end of tubing prior to laying down. Tubing should be sent to inspection to make ready to re-use. b. Note and take samples of any scale deposits observed on tubing or on the pump. 19. MU RIH with new ESP on 2-7/8"tubing. • Well Prognosis Well: MPU K-30 IIilcorn Alaska,LL, Date: 1/14/2016 20. Land tubing hanger. RILDS. Lay down landing-joint.Test tubing hanger to 250psi low/5,000psi High. a. Note PU (Pick Up) and SO (Slack Off) weights on tally. 21. Set BPV. 22. RD Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500bbl returns tank. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. 2. RU crane. ND BOPE. Pull BPV. Set TWC. 3. NU 4" 5,000#tree and adapter flange and test to 500 psi low/5,000 psi high. 4. Test tubing hanger void to 500psi low/5,000psi high. 5. Pull TWC. RD crane. 6. Move 500bbl returns tank and rig mats. 7. Replace IA x OA pressure gauge if removed (7" x 9-5/8"). 8. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic 5. Existing Tree/Wellhead 6. FWD Circ to Kill Tank Flow Diagram 7. REV Circ to Kill Tank Flow Diagram 8. Bleed to Pits Flow Diagram 9. Blank RWO Changes Form Milne Point Unit . 11 • SCHEMATIC • Well: MPU K-30 Last Completed: 12/16/2015 [Ideon,Alaska.LLC PTD: 196-168 TREE&WELLHEAD DF Elev.:57.5'/GL Elev.:28'(Nabors 22E) Tree 5M CIM 4-1/16" DF to 7"Casing Hanger=28.5 11"x 11"5M FMC Gen 5A,w/4-1/16"FMC Tbg. .j ,",, ,, 1 Wellhead Hngr.,L.H.Acme thread 4"CIW H BPV profile zo 6 ' OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole t: 9-5/8" 1,500 sx Trinity Lite Wate,750 sx PF"E",in 12-1/4"Hole 4 7" 245 sx Class"G"in 8-1/2"Hole i f CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF I:K20" Conductor 91.1/H-40E/N/A N/A Surface 112' 0.355 9-5/8"1& 9-5/8" Surface 47/L-80/NSCC. 8.679 Surface 4,544' 0.0732 9-5/T Homo i ES Cementer 9-5/8" Surface 47/L-80/Btrc. 8.679 4,544' 4,796' 0.0732 ; 9-5/8" Surface 47/P-110/Btrc. 8.679 4,796' 6,652' 0.0732 7" Production 26/L-80/Btrc 6.276 Surface 11,122' 0.0383 TUBING DETAIL 1 4-1/2" Tubing 12.6/L-80/Hydril 521 3.958 Surf 10,392' 0.0152 WELL INCLINATION DETAIL KOP @ 400' Max Hole Angle=57 to 62 deg. f/3,650'to 11,041 Max Hole Angle through perforations=58 deg. 1 TTC DETAIL } No Top(MD) Item 1 10,297' D&D Tubing Stop:AA w/4"GS FN 2 10,299' D&D Pack-off:DDIC Hi-Flow w/Peek Rings 2 3 10,302' D&D Kobe Knockout::Steel Pin recommended to mitigate erosion due to solids. 3 4 10,307' D&D Stinger:2-7/8"EUE BOX x Moly Packing 5 10,308' Hanger Receptacle:4"'G'Fishing Neck,4-1/2"X 2-3/8"EUE 8RD Pin 12.6/12.75# 6 10,309' Discharge Head:380 PUMP 4&5 7 10,309.43' Pump:116-P18P2P 6 8 10,329' Pump:116-P18 P2P 7 9 10,351' Intake:380 GSVTHV XM(High Volume) • 8 10 10,355' Pump Eye:TTCESP . ESP DETAIL e A 10,344' Crossover:4-1/2"521 Hydril Box X,4-1/2"NSTC Pin,12.6# '..A&B 10 k= B 10,346' TTC Drilled Tubing Crossover:TTC 4-1/2"NSTC BOX C C 10,357' Upper Tandem Seal:GSB3 DB HL H6 PFS °s D 10,364' Lower Tandem Seal:GSB3 DB HL H6 PFS W' E 10,370' Motor:CL-5,MSP1-250-21OHp/2,380V/53A € D F 10,387' Sensor Pheonix XT150 Type O r 4t, G 10,390' Centralizer:Six Fin-BTM @ 10.392' it, PERFORATION DETAIL E Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status it Kup.C Sands 10,588' 10,658' 7,024' 7,063' 70 11/26/2015 Open F Kup.B Sands 10,704' 10,748' 7,088' 7,111' . 44 11/25/1996 Open G Ref Log:11/25/1996 GR/CCL-4.5"/5 SPF GENERAL WELL INFO API:50-029-22711-00-00 a}KUP C Sands Orig.Completion by Nabors 4-ES -11/27/1996 KUP B Sands RWO Screens added/Pig Tail Pull&Land-6/15/1998 `;' ^} RWO w/Nabors 4-ES-4/5/2002&5/5/2004 ',' ESP RWO w/Nabors 4-ES-10/6/2007 ESP RWO&Replace Screens w/Nabors 3S-8/3/2008 ESP RWO&Replace Screens w/Nabors 4-ES-8/15/2010 ESP RWO w/Doyon 16-8/5/2011&1/13/2014 TD=11,145'(MD)/TD=7,306'(1VD) TTC/ESP Change-out w/Nordic#3-12/16/2015 PBTD=11,041'(MD)/PBTD=7,257(TVD) Revised By:TDF 1/14/2016 • PROPOSED • Milne Point Unit Well: MPU K-30 Last Completed: 12/16/2015 Hamm Alaska,LLC PTD: 196-168 TREE&WELLHEAD DF Elev.:57.5'/GL Elev.:28'(Nabors 22E) Tree 5M CIM 4-1/16" DF to 7"Casing Hanger=28.5 11"x 11"5M FMC Gen 5A,w/4-1/16"FMC Tbg. Wellhead 1r% Hngr.,L.H.Acme thread 4"CIW H BPV profile ti 20' r OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole 9-5/8" 1,500 sx Trinity Lite Wate,750 sx PF"E",in 12-1/4"Hole 7" 245 sx Class"G"in 8-1/2"Hole CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 20" Conductor 91.1/H-40E/N/A N/A Surface 112' 0.355 95/8"'I# 9-5/8" Surface 47/L-80/NSCC. 8.679 Surface 4,544' 0.0732 9-5/8 Fbvwo 9-5/8" Surface 47/L-80/Btrc. 8.679 4,544' 4,796' 0.0732 ri ES Cementer 9-5/8" Surface 47/P-110/Btrc. 8.679 4,796' 6,652' 0.0732 7" Production 26/L-80/Btrc 6.276 Surface 11,122' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.4/L-80/Hydril 521 2.347 Surf ±10,392' 0.00579 WELL INCLINATION DETAIL KOP @ 400' Max Hole Angle=57 to 62 deg. f/3,650'to 11,041 Max Hole Angle through perforations=58 deg. • JEWELRY DETAIL No Top(MD) Item •U �e 1 ±10,344' Pump I tb r 2 ±10,354' Gas Seperator 3 ±10,357' Upper Tandem Seal 4 ±10,364' Lower Tandem Seal 5 ±10,370' Motor 6 ±10,387' Sensor w/Centralizer:Six Fin-BTM @±10,392' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.C Sands 10,588' 10,658' 7,024' 7,063' 70 11/26/2015 Open .d el Kup.B Sands 10,704' 10,748' 7,088' 7,111' 44 11/25/1996 Open Ref Log:11/25/1996 GR/CCL-4.5"/5 SPF GENERAL WELL INFO API:50-029-22711-00-00 1 Orig.Completion by Nabors 4-ES -11/27/1996 RWO Screens added/Pig Tail Pull&Land—6/15/1998 11.11 2 RWO w/Nabors 4-ES—4/5/2002&5/5/2004 -}3&4 ESP RWO w/Nabors 4-ES—10/6/2007 i ESP RWO&Replace Screens w/Nabors 35—8/3/2008 ' _tib S^ ESP RWO&Replace Screens w/Nabors 4-ES—8/15/2010 • '..5 ESP RWO w/Doyon 16—8/5/2011&1/13/2014 TTC/ESP Change-out w/Nordic#3—12/16/2015 O gi 6 =1-1-}KUP C Sands =}KUP B Sands t TD=11,145'(MD)/TD=7,306'(1VD) PBTD=11,041'(MD)/PBTD=7,257'(1VD) Revised By:TDF 1/14/2016 . • Milne Point 2015 ASR Rig 1 Knight Oil Tools BOP li kurp MaAl.*,IJ ' — .14mimillim Stripping Head lik V' Shaffer ° I. 11" - 5000 lii Iii Initial 1111111111110111.10 a6 1=16111111111111 i 1 1 RI ET 1 za *'' CIW-u 2 7/8" —5" VBR 'Clile ille 2 11110114 11" 000 Ea.gs“ ®= Blind u. — ®, 2" Kill Line 2" Choke Line 111 11 111 111 '11 Id c e7-' ..;;A‘ 117. 7,.7 ' 1 1r, , G® a ® ��.° 1J . til.. i, :gi A - b [C,- Hi 11 111/1111 , Manual ManualJl Manual HCR Updated 11/03/15 • • , il Choke Manifold ASR#1 11/01/2015 ihl.orp ALasko.1.IA. Digital Reverse line back to Kill Manifold Pressure Readout II Ii tC2 0 C3 bl ii Digital Pressure Transmitter I "" - - From Choke Line Manual Choke ( oMO B III Remote C4 C5 It, , C6 C7 Choke 11' 1 C t011ill �O K:01 O r. ll 111 111 �.,� a"` _ 11E an. 131 C9 10 alt All Valves 2" Piper Series PB Ball Valves 6,170 psi Working 10,000 psi Tested C8 - C11 �0\ C10�0, Mg I C13 C15 , I w -1 .: ' ., III .. xy ilk C12 000 K401C14 �0 _ •111110 .4 ,l, VIE To Panic Line 1502 Union Outside 11 End Capped To Gas Buster 14 • NV • MPU K-30 EXISTING TREEELLHEAD Wellhead/Tree Milne Point Unit Iiilrurp Alaska.LIA: Tree Cap at, 111 1!1 OW III ti',.0 0 Tree Valve 4-1/16" 5M c)`,5-0' All IMO 111 F Oe,' O 1 Tree Cross 4-1/16" 5M O1/0)o1 Tree Valve 4-1/16" 5M ,� "fit) ti SSV 4-1/16" 5M 1 .191 41 Tree Valve 4-1/16" 5M 'I 0 '4) III�In ESP Cable 1I' "' ..-.,. .....`- Control Line Tubing Adapter all I4I. 1: Tubing Head ii Es 11 5M Top x 11 5M Btm a ... iltriPAII4til :" in is0 — or Casing Head � : I il - I�II . ■ n C 11 ' 5MTop x11' 5M Btm q � g tat �i . 0 0 - E C AL...v. = .,. 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Dkk / ,k1 a o \ 0 s \ / 2 k \ � / CD 2 E § a. k -o 0 L .0 / o S ca § _ »> as c 0 _ Cl) W / C w � > = $ @ ■ CD o > � § CL 2 � C al / 0 i. k Q. / > I 0. . \ k § 0 co - cn Q m xo » & o x / 2 m 0 ai 0 C MI / co >, co co 0 .. # E. _ . . a = q Z o E / > % = g e 0 o $ CO < 2 STATE OF ALASKA • ALTA OIL AND GAS CONSERVATION COMOSION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑✓ Operations Shutdown❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well El Re-enter Susp Well❑ TTC-ESP Change-out ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development Q Exploratory ❑ 196-168 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22711-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0375132 MILNE PT UNIT KR K-30 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 11,145 feet Plugs measured N/A RECEIVED true vertical 7,306 feet Junk measured N/A feet .LAN 1 4 2016 Effective Depth measured 11,041 feet Packer measured N/A feet true vertical 7,257 feet true vertical N/A feet AOG CC Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' Surface 6,652' 9-5/8" 6,652' 4,908' 6,870psi 4,760psi Intermediate 11,122' 7" 11,122' 7,295' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematic feet stAa ''.) `,",'f Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/Hydril 521 10,392' 6,912' — Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 80 0 Subsequent to operation: 0 0 0 220 0 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q 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.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: 315-717 Contact Ted Kramer Email tkramer(c�hilcorp.com Printed Name Bo York �°` Title Operations Manager Signature <� 'r%`� . r ea /�'j� /,� Phone 777-8345 Date 1/14/2016 Z v-/—160. i40 2-4///,‘ Form 10-404 Revised 5/2015 RBDMS Li- JAN 1 9 2016 Submit Original Only Milne Point Unit 0 SCHEMATIC . Well: MPU K-30 Last Completed: 12/16/2015 Ililcorp Alaska,LLC PTD: 196-168 TREE&WELLHEAD DF Elev.:57.5'/GL Elev.:28'(Nabors 22E) Tree 5M CIM 4-1/16" DF to 7"Casing Hanger=28.5 11"x 11"5M FMC Gen 5A,w/4-1/16"FMC Tbg. Wellhead Hngr.,L.H.Acme thread 4"CIW H BPV profile 20 • �` OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole 9-5/8" 1,500 sx Trinity Lite Wate,750 sx PF"E",in 12-1/4"Hole '_; 7" 245 sx Class"G"in 8-1/2"Hole CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 20" Conductor 91.1/H-40E/N/A N/A Surface 112' 0.355 9-5/8" • 9-5/8" Surface 47/L-80/NSCC. 8.679 Surface 4,544' 0.0732 a5/g Herrn ES Cementer 9-5/8" Surface 47/L-80/Btrc. 8.679 4,544' 4,796' 0.0732 9-5/8" Surface 47/P-110/Btrc. 8.679 4,796' 6,652' 0.0732 7" Production 26/L-80/Btrc 6.276 Surface 11,122' 0.0383 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/Hydril 521 3.958 Surf 10,392' 0.0152 WELL INCLINATION DETAIL KOP@400' I Max Hole Angle=57 to 62 deg. f/3,650'to 11,041 Max Hole Angle through perforations=58 deg. TTC DETAIL I No Top(MD) Item 1 10,297' D&D Tubing Stop:AA w/4"GS FN 1 2 10,299' D&D Pack-off:DDIC Hi-Flow w/Peek Rings 2 3 10,302' D&D Kobe Knockout::Steel Pin recommended to mitigate erosion due to solids. s 4 10,307' D&D Stinger:2-7/8"EUE BOX x Moly Packing iail 5 10,308' Hanger Receptacle:4"'G'Fishing Neck,4-1/2"X 2-3/8"EUE 8RD Pin 12.6/12.75# 6 10,309' Discharge Head:380 PUMP 4&5 6 7 10,309.43' Pump:116-P18P2P 7 8 10,329' Pump:116-P18 P2P 9 10,351' Intake:380 GSVTHV XM(High Volume) 8 10 10,355' Pump Eye:TTCESP . ESP DETAIL 9 A&B A 10,344' Crossover:4-1/2"521 Hydril Box X,4-1/2"NSTC Pin,12.6# 10 B 10,346' TTC Drilled Tubing Crossover:TTC 4-1/2"NSTC BOX r iC C 10,357' Upper Tandem Seal:GSB3 DB HL H6 PFS _ _ { D 10,364' Lower Tandem Seal:GSB3 DB HL H6 PFS E 10,370' Motor:CL-5,MSP1-250-210Hp/2,380V/53A D F 10,387' Sensor:Pheonix XT150 Type O G 10,390' Centralizer Six Fin-BTM @ 10.392' PERFORATION DETAIL s E Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status sw Kup.C Sands 10,588' 10,658' 7,024' 7,063' 70 11/26/2015 Open F Kup.B Sands 10,704' 10,748' 7,088' 7,111' 44 11/25/1996 Open G , Ref Log:11/25/1996 GR/CCL-4.5"/5 SPF GENERAL WELL INFO API:50-029-22711-00-00 g} KUP C Sands Orig.Completion by Nabors 4-ES -11/27/1996 --}KUP B Sands RWO Screens added/Pig Tail Pull&Land-6/15/1998 RWO w/Nabors 4-ES-4/5/2002&5/5/2004 ESP RWO w/Nabors 4-ES-10/6/2007 ESP RWO&Replace Screens w/Nabors 3S-8/3/2008 ESP RWO&Replace Screens w/Nabors 4-ES-8/15/2010 re' ne ESP RWO w/Doyon 16-8/5/2011&1/13/2014 TD=11,145'(MD)/TD=7,306(TVD) TTC/ESP Change-out w/Nordic#3-12/16/2015 PBTD=11,041'(MD)/PBTD=7,257(TVD) Revised By:TDF 1/14/2016 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP K-30 Nordic#3 50-029-22711-00-00 196-168 12/4/15 12/16/16 Daily Operations: 12/2/2015-Wednesday No activity to report. 12/3/2015 -Thursday No activity to report. 12/4/2015 - Friday Spot rig over K-30. Set in cutting tank, level rig, off load 450 bbls of sea water, winterize cellar. Accept Rig @ 01:00 hrs. Rig up and pull BPV. 12/5/2015-Saturday Pull BPV. Record pressures with 50 psi on tbg, 50 psi on IA and 200 psi on OA. Rig up hard line to kill tank. PT hard line to 250psi low/3,000 psi high. Blow down hard line. Blow air through TD. Bleed down IA and Tubing to kill tank. 0 psi in 15 minutes. Kill well circulating down the tubing, up the IA,taking returns through full open choke to Kill tank @ 3 bpm, 1,050 psi. Caught pressure in tubing @ 106 bbls away. Obtained returns up IA @ 70 bbls away. Had FP returns @ start of circulation. Circulated 358 bbls with 156 bbls back to kill tank. Circulate additional 157 bbls tubing volume. Circulate additional 157 bbls tubing volume 3.5bpm 1280 psi. Set TWC. N/D tree and inspect threads, (Lift threads damaged). N/U 11' BOP stack. Change lower set of pipe rams from 2-7/8" solid to 4-1/2" solid. Installed hoses, fill stack and all test lines. Shell Test BOP's, One grey lock didn't hold, replace, retest (good).Test BOP's 250psi low/3,000 psi high on valves, rams and Annular. BOP test was performed with 4-1/2" &3-1/2" test joint. BOP test was waived to witness by State Rep. Chuck Scheve. Rig down/blow down test equipment, pull TWC, rig up to spear tubing hanger. Engage tubing hanger with spear/grapple and back out lockdown. Pull hanger to floor P/U 160k (Top Drive Weight 38k string weight 122k). Terminating ESP lines from tubing hanger. 12/6/2015-Sunday Pull hanger to floor P/U 160K(Top Drive Weight 38k string weight 122k)Terminating ESP lines from tubing hanger. Lay down tubing hanger. Rig up to pull completion. Hang ESP sheave. Lay down 3 jts, pass cable through sheave to spooler. Continut to POOH with ESP, laying down 4-1/2", 12.6#, L-80, Hyd 521 tubing. Rack, drift and tally tubing in pipe shed. POOH to 7,537'. Cut cable and change out cable spools with crane. Remove Auto Driller Equipment from draw works for Rep. Continue POOH with ESP completion laying down 4-1/2" tubing from 7,537'. Rack, drift, strap and Tally 4-1/2" tubing in pipe shed for re-run. 12/7/2015 - Monday Continue POOH with ESP completion laying down 4-1/2"tubing from 1,050'. Rack, Drift, strap and tally 4-1/2" tubing in pipe shed for rerun. Lay down joint with pack off stuck in it. Kicked out a total of 26 bad joints with holes in pin end and excessive wear on ID. Remove TTC ESP assembly. Lay down motor assembly. Clean and clear rig floor of ESP equipment. Change out handling equipment to 3-1/2". Continue to Load, strap and tally 3 1/2" drill pipe. Install wear ring and continue loading pipe shed. Change out floor equipment, organize BHA, and strap 6 4-3/4" DC. PJSM, pick up BHA 1 clean out assembly. RIH with 3-1/2" drill pipe from pipe shed to 4,183'. Load and tally 243 jnts. of 3-1/2" drill pipe (Steam is being used to take protectors off) continue RIH with 3-1/2" drill pipe from pipe shed from 4,183'. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP K-30 Nordic#3 50-029-22711-00-00 196-168 12/4/15 12/16/16 Daily Operations: 12/8/2015-Tuesday Continue to P/U 3-1/2" drill pipe from pipe shed F/4,183' T/ 10,800'. No tag. 52' past btm perf. POOH F/ 10,800'TI 10,488'. 100' Above the top perf. Break Circ with circ hose down the Dp. Circ @ 5 bpm 1,275 psi. Got returns @ 52 bbl away. Circ oil cap off of well. Dumped 30 bbl to cuttings box. Lost 40 bbl while circulating and establishing a loss rate while circulating. Shut down and monitor annulus on the trip tank @ 80 static loss. rate. Circ through the top drive staging up pumps to 8.5 bpm. Circ through the top drive staging up pumps to 8.5 bpm. Losses @ 200+ bph.Total losses 120 bbls during circ. Shut down. Blow down TD. R/U circ hose & pump 40 bbl 10.6 ppg 200 vis saturated salt pill. ( 60 ppb saturated salt). Chase with 80 bbl seawater. Spot pill. POOH F/ 10,500'T/9,000' +/. Monitoring well on trip tank. Monitor well static letting pill soak. Losses @ 40bph. RIH from 9,000'to 10,030' pick up weight 150k slack off 105k. Circ. 25bb1. hi-vis sweep @ 2 bpm until the sweep left the drill string, once sweep was above the BHA pump rate was increased to 5pbm and ROT 30rpms 1,120psi. Sweep came back 2,000 strk. over calc. and increase of 95%cuttings. (cutting structure very fine sand/oil mix).TIH from 10,030' to 10,800' and circ the saturated salt pill out, easing pump rate up to 5bpm 1,250psi rot 30 rpm tq 5k. Salt pill brought back 30%of cuttings, sand. (while circ. the sweep and the salt pill out the dynamic lost rate stayed at 80bph). Pull from 10,800'to 10,030, monitor well static loss rate 120bph. Rig up and slip and cut off 86' of drilling line. Rig down slip and cut equipment and brought ESP pump into pipe shed. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP K-30 Nordic#3 50-029-22711-00-00 196-168 12/4/15 12/16/15 Daily Operations: 4'4 12/9/2015-Wednesday Finish loading new ESP in the pipe shed. Box& Crate old ESP &send out. L/D 3-1/2" drill pipe F/ 10,030'T/ BHA giving the hole a double pipe displacement. L/D BHA: 6 steel DC, Mill,Jars and Boot baskets (Boot basket had 2 gal. of fine sand and scale). Pull wear ring. PJSM with crane, pick cap spool and MLE spool with crane and set on rig floor. R/U sheave, tack weld ESP spool to floor with welder, change out floor equipment. Make up ESP motor(Centralizer-Sensor-Motor-CL5-Lower Tandem Seal-Upper Tandem Seal-TTC Drilled Tubing Crossover).Attempted to set pumps and set the pack-off, but 4.5" cross over pup (1.9') was to sort and would have exposed the pump and the pack-off, and by adding a full joint instead of a pup it would have made the assembly to long and wouldn't be able to pull enough of the motor assembly to the floor to plug in the ESP line.A 6'to 10' pup would have been the correct size for this application 1 full jnt tubing. Wire line group will come out to set pumps and pack off. Continue installing and ESP cable. Attempted to test Cap Line but set pump failed. Rep shop is having one sent out. New pump test, retest line (Good). Install ESP cable to pump. 12/10/2015-Thursday Change out check valve on Cap string. Set check @ 2,500'. Test cap string and check. Pumped through @ 4,500'. M/U cable to MLE. Meg cable @ 1,000 volts. Good. Run in hole T/297'. PJSM, R/U slick line. Run &set two pumps, pack off& test tool. Attempt to test pack off. Pump through 10 bbl 60 psi. Pull test tool & pack off came with. Redress and check tools. Looks Good. Re-run and set pack off&test tool. R/U circ equipment.Try to test. No good. Pumping through. Pull test tool. Pull pack off. Replace D&D packoff with new one. Run D&D pack off. Set test tool. R/U circ equipment.Test pack off to 1,000psi. Good. Rig down slick line equipment. PJSM: Run in the hole with 4-1/2" ESP completion and cap line.Test cable every 2,000'for continuity and the Cap Line to 2,500 psi. At 6,061'joint#151 ESP cable had a tear in the armor coming off the reel. Reps repaired and tested (Good). Continue run in the hole with 4-1/2" ESP completion and cap line from 6,061'to 7,597'. 12/11/2015- Friday Continue to P/U 4.5" tubing T/7,569'. Prep for spool swap. McLcable.Showinggrounded out.Test cap tube. Good. Change out Meg tool.Still showing phase to ground. Pooh inspecting cable for damage. Found smashed cable on joint#163 (6,516'). 10' below the collar. Decide to pooh to armor repair @ 6,064'. Cut cable at armor repair. Showing phase to ground on the down hole side and the reel side. Continue POOH F/6,469'T/3,400'.Splice cap string due to kink. Continue to POOH with 4.5" Hydrill 521 looking for damage in the ESP cable. F/3,400'T/1,422'.Cable damage @ 1,422'.The cable was cut and tested below the damaged spot(Good Test). Continue to POOH with 4.5" Hydrill 521 looking for damage in the ESP cable. 1,422'to Pump (no damage to report) 2 jnt of 4-1/2" Hydril, XO,TT drilled tubing xo and D&D packer racked back in the derrick (The 2 pumps were left inside the stand in the derrick). L/D Upper and Lower tandem Motor seal. Load dutch riser into pipe shed. Load out with crane damage ESP spool cable. Install wear ring. Install dutch riser on top of BOP's. PJSM on rig up slick line. Pick up lubricator and make up Wireline Services caliper logging tools to slick line. Function test caliper (failed) change out. Re-program and re-test(good). Pressure test lubricator to 500psi against the blinds, Good. Run in the hole with caliper. BHA: rope socket6.5/quick connect 11" /roller stem 3.0/roller stem 3.0/quick connect 11"/knuckle joint 9"/ long stroke spange 7.125/quick connect 11/centralizer 12"/quick connect 117 shock absorber 2.0/Slick line knuckle joint 1.08/ UWBA 2.38-Centh/Arm Centralizer 2.52/ Finger Caliper Ext. finger 4.54/Arm Centralizer 2.52 Bull Plug with Terminator.22. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP K-30 Nordic#3 50-029-22711-00-00 196-168 12/4/15 12/16/15 Daily Operations: ' h 4r. 12/12/2015-Saturday RIH with Wireline Services 40 arm caliper on slick line T/ 10,400'. Log up to surface @ 50 FPH+/-. R/D slick line, L/D lubricator, N/D dutch riser. Clear floor of tools. Load pipe with 3-1/2" DP. Pull wear bushing. PJSM, Strap &tally BHA. P/U clean out BHA, Mule shoe, XO,XO, Boot baskets, Boot basket, 7" casing scraper,String Magnet. 3-1/2" DP. P/U 3-1/2" DP F/ Surface T/5,000'+/-. Pump down tubing @ 5 bpm. Fill hole. Got returns @ 40bbl away. Circ 2 btm up @ 5,080'. Stage up pumps F/2 bpm @ 65 psi, 3 bpm 195psi, Loosing 70 bph. Close annular& reverse circ @ 2biani 65,1asi,3._bpm 90psi 5 bpm. 281psi. Loosing 70 bph about a 1gal. of sand/oil mixture came back 155bbl pumped 85bbl loss during Circ. P/U 3-1/2" DP F/ 5,080'to 6,000' +/- From 6,000' to 10,400'there was nothing in the hole that held up the work string P/U 155k S/0 112k. Pump down tubing @ 2 bpm. Fill hole. Got returns @ 32bb1. away. Circ 2 btm up @ 10,400'. Close annular& reverse circ. easing rate 5 bpm @ 450psi losing 135bph (total 15 gal of sand and scale came back).411bb1 pumped lost 237bb1 during circ. Blow down top drive/fill trip tank(Static Loss rate 25bph). POOH L/D 3-1/2" drill pipe F/10,400'T/5,144' ( No over pull seen ). State Rep was notified 10:16 12/12/2015. 12/13/2015-Sunday Install TIW valve in string. Install test plug in string. Land test plug in stack. R/U to test bops.Try to perform body test. Unable to find small leak. Pull test plug &change 0 rings. Land string on test plug. Perform body test chasing small leaks. Found leaking test pump isolation valve. Found leaking needle valve on choke purge valve. Get first test against blinds.Test in L1 bops as per AOGCC to 250psi low/3,000psi high. Had a pass fail on Kill isolation valve. Cycle valve and retest on high. Pass fail on valve#6 on the choke manifold. Grease and retest. Pass.Test lower rams to 4.5",Test VBRs to 3-1/2" &4-1/2",Test annular to 3-1/2" &4-1/2"- 250psi low/3,000psi high.Test witnessed by Brian Bixby with the AOGCC.Test Gas alarms. Good. Perform accumulator draw down test. Initial 3,000psi. After closure 1,950psi. 200psi Increase 18 sec,total recovery, 90 sec. N2-4 BTL @ 2,000psi. PJSM, picking up and installing new MLE spool on pedestal with crane. Pull test plug and L/D. PJSM; POOH F/5,140' T/3,234' L/D 3-1/2" drill pipe filling the hole with double displacement. Fill hole from trip tank lubricated sea water.Took 23bbls to seawater to surface.Static loss rate 90bph. Continue POOH 3,234'T/2,280' drill pipe became wet. Stop trouble shoot the problem (drill pipe or bha was partially pack-off).Attempted to clear pipe with pumps, no success, 800psi. @ .5bpm ( We could get some flow through but no 100% ). Continue POOH with wet F/2,280'T/BHA. L/D BHA: Mule shoe, XO,XO, Boot baskets, Boot basket, 7" casing scraper, String Magnet. One boot basket was empty the second had 1/2 gal of scale,sand.The plug was found in the cross over below the scrapper. It was 75% plugged off with a fine sand and grease mixture. Remove pipe handling equipment& rig up to 4-1/2" competion. Make up 3/8" Cap line and test 2,500psi (failed ). Change out Cap check valve, retest 2,500psi (good). Filled hole 23bb1. Static loss rate 90bph. Make motor and install cap line and test (failed). Change out install and retest (good). Service Motor, pick up and assemble seals, connect MLE line to pump and test, load clamps on to the rig floor. . . Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP K-30 Nordic#3 50-029-22711-00-00 196-168 12/4/15 12/16/15 IL k: Daily Operations, `°, 12/14/2015-Monday, Continue to Service Motor, pick up and assemble seals, connect MLE line to pump and test, load clamps on to the rig floor. PJSM: Run in the hole with 4-1/2" ESP completion and cap line.Test cable every 2,000' for continuity and the Cap Line to 2,500psi.Test continuity in cable and the Cap Line to 2,500psi. 2,070' (Good). Continue Run in the hole with 4-1/2" ESP completion and cap line F/2,070'T/4,010'.Test continuity in cable and the Cap Line to 2,200psi. 4,010' (Good). Off load clamps onto rig floor. Continue Run in the hole with 4-1/2" ESP completion and cap line F/4,010' -T/6,015'.Test continuity in cable and the Cap Line to 2,200psi. 6,015' (Good). Fill trip tank. Continue Run in the hole with 4-1/2" ESP completion and cap line F/6,015'T/7,443' Park @ 7,443' and make cable splice to 2nd ESP Spool.Test cable and capillary line.Test cable splice(good). 27bb1 to fill hole circ. over top of the hole with trip tank 60bph +/-. Continue Run in the hole with 4-1/2" ESP completion and cap. line F/7,443'T/8,100'. 12/15/2015-Tuesday Continue Run in the hole with 4-1/2" ESP completion and cap line F/8,100'T/ 10,360'.Test cable @ 9,100', Good. M/U Hanger and landing joint with XO.Terminate cap string and ESP cable. M/U Penatrator and dress out hanger. Load out old clamps from Pipe shed. Prep ESP Spool to be removed. Perform final check on cap sting and penatrator, Good. While preparing to land hanger it was noticed the pup under the hanger had crush damage. Remove penetrator from hanger. Remove cap string. Inspect other XO & hangers. Decide to send hanger in to get new pup bucked on. Send hanger in for new pup. Remove ESP &Cap string spools off of rig floor with crane. Change out lights in the derrick. Clear rig floor and pipe shed for rig move. Load 2-7/8" for back up joints for E-15. M/U new hanger& Pup.Take measurements & make new cut on ESP cable. M/U penetrator& Install new penetrator. Cut cap string and install in hanger. Install penetrator in hanger. Install final clamps. Land hanger, set @ 10,391.97', UP/DN 160/115 (35k block wt included). RILDS. Set TWC per wellhead rep. Final clamp count(518 cannon clamps, 3 protectolizers, 2 flat guard clamps, 1 splice clamp, 2 band clamps below hanger). N/D BOPE.Attempt to N/U tree, control line ports are 1/4" off and do not line up, well head rep attempting to locate correct adaptor flange for hanger. Continue to prep for rig move. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP K-30 Nordic#3 50-029-22711-00-00 196-168 12/4/15 12/16/15 Daily Operat1ons: 12/16/2015-Wednesday Plug off cap string due to adapter not cut to hanger for cap string. N/U tree and adapter flange.Test void to 250psi low/ 5,000psi high-Good. Perform final checks on ESP- Good. Pull TWC. R/U LRS. Bullhead 38 bbl down the annulus & 26 bbl down the tubing as per Field Forman. R/D Nordic 3. Release rig @ 1430. Move rig off well. Clean up pad and cellar area. Remove rig mats. Move rig to E-15. Move camp to E Pad. 12/17/2015 -Thursday No activity to report. 12/18/2015- Friday No activity to report. 12/19/2015-Saturday No activity to report. 12/20/2015 -Sunday No activity to report. 12/21/2015 - Monday No activity to report. 12/22/2015-Tuesday No activity to report. V OF 7`44, • • \��\I ,, THE STATE Alaska Oil and Gas "I, of Canservati®n Commission LASICA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS1 Fax: 907.276.7542 www.aogcc.alaska.gov W>itklitiED FEB 0 2 2016 Bo York Area Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR K-30 Sundry Number: 315-717 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, Daniel T. Seamount, Jr. Commissoiner DATED this day of December, 2015 Encl. �t0� 03 Rep�i11S • • RECEIVED STATE OF ALASKA NOV 2 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q r Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 2_ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: _TTC-ESP Changeout_❑✓ 2.Operator Name: 4.Current Well Class: '',i4b 5. Permit to Drill Number Hilcorp Alaska LLC - Exploratory ❑ Development a 196-168 ' 3.Address: 6.API Number. Stratigraphic ❑ Service ❑ 3800 Centerpoint Dr,Suite 1400 50-029-22711-00-00 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 432C Will planned perforations require a spacing exception? Yes ❑ No ❑✓ ✓ MILNE PT UNIT KR K-30 ' 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0375132 • 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): 11,145' ' 7,306' 11,041' 7,257' 2,142 ' N/A 10,170' Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 6,652' 9-5/8" 6,652' 4,908' 6,870psi 4,760psi Intermediate 11,122' 7" 11,122' 7,295' 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 4-1/2" 12.6#/L-80/Hydril 521 10,380 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A, 12.Attachments: Proposal Summary ❑ Wellbore schematic RI 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 ' Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3-Dec-15 OIL ❑ , WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned 17. I hereby certify that the foregoing is true and the procedure approved q'� herein will not be deviated from without prior written approval. Contact Paul Chan ` Email pchan@hilcorp.com Printed Name Bo York Title Area Operations Manager Signature -;--ttYu'�4one 777-8345 Date /[l2_�r L.S. COMMISSION USE ONLY f Conditions of..4pproval: Notify Commission so that a representative may witness Sundry Number: 16- 7 (7 Plug Integrity ❑ BOP Test i Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4- 3606 mss;.. 1j:---e �TI"1'"--jU� .--(--Z -1--- . ��l`- g f lir e-i,—. FC 0 h.,,, rt''- r pe " gg +G Post Initial Injection MIT Req'd? Yes�] No ❑ R 'At Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /D--�a ik OMs3 APPROVED BY [� Approved by:&--- /V'h COMMISSIONER THE COMMISSION Date: J Z l 4 ((S 7,Z 1413 filk3117-- i � Submit Fore Form 10-403 Revised 11/2015 Ap"� ie�ag11Iiia AIL:or 12 months from the date of approval. Attachments in Duplicate i • • Well Prognosis Well: MPU K-30 Hileorp Alaska,LL Date: 11/20/2015 Well Name: MPU K-30 API Number: 50-029-22711-00 Current Status: SI Oil Well [TTC-ESP] Pad: K-Pad Estimated Start Date: December 3, 2015 Rig: Nordic 3 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-168 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 2,842 psi @ 7,000'TVD (SBHP measured 7/30/2015 from ESP gauge) Maximum Expected BHP: 2 842si @ 7,000'TVD p (No new perfs being added/EMW= 7.81 ppg)) Max. Predicted Surf Pressure: 2,142 psi (Using 0.1 psi/ft gas gradient) • Brief Well Summary: r`` ouzr teted4.4,./ 7e MPU K-30 was drilled in 1996 using Nabors 22E and completed in the Kuparuk B and C sands. The well has had multiple ESP changeouts and sand control screens ran and pulled since 1996, the most recent was an ESP changeout in 2014 using Doyon #16 to run a TTC-ESP. In August 2015, the ASR #1 WO Rig was able to recover the tubing stop but unable to recover the packoff, leaving it up hole approximately 100' above its original set point. Slickline was able to move the packoff 9' up hole in September 2015. CTU attempted to retrieve the pack off without success in October. Notes Regarding Wellbore Condition ✓• Casing tested to 250/3,500 psi for 30 min down to 10,538'on 1/05/2014. V. Found no fill during the RWO while cleaning out to 10,777' with Doyon#16 in 2014. �• Packoff stuck in the 4-1/2" tubing @ "'10,185' CTM. Objective: The purpose of this work is to retrieve the failed TTC-ESP, perform a fill cleanout, and run a new TTC-ESP. Brief Procedure: WO Rig Procedure: 1. MIRU Nordic#3 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 2. Pull BPV(if set). Pump down well with 8.5 ppg sea water down tubing and casing. 3. Set TWC. ND Tree. NU 11" BOPE and test. 4. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and tesffor 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per Nordic 3 BOP Test Procedure. b. Notify AOGCC 24 hrs in advance of BOP test. c. Submit completed 10-424 BOPE test results within 5 days of completed test. d. Confirm test pressures per the Sundry Conditions of approval. e. Test VBR rams on 3-1/2" and 4-1/2" test joint. • • • Well Prognosis Well: MPU K-30 Hilcorp Alaska,LL Date: 11/20/2015 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. 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 kif 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. Pull TWC. Bleed any pressure off tubing and casing to 500 bbl returns tank. Kill well w/8.5 ppg seawater as needed. 7. MU 4-1/2" landing joint and BOLDS. a. Contingency: (If landing joint won't make up to tubing hanger) (bad threads). Sfei.) c.14. b. MU spear and pull 10k tensa n over string weight on tubing hanger to confirm free. = /.5a/e— ,2.c.-=+0,(F' K (o s'c:t: 8. Pull over string weight (apdox. U) on tubing hanger to confirm free. LD tubing hanger. a. Contingency: (If a rolling test was conducted.) i. 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. Lay down 4-1/2" Hydril 521 tubing and the TTC-ESP. a. Drift tubing while POOH. b. Install thread protectors on pin end of tubing prior to laying down. Tubing will be visually inspected and re-used. c. Replace bad joints of tubing as necessary. d. Look for over-torqued connections from previous Doyon #16 tubing run. :ci 10. Contingecy: Perform FCO if TTC-ESP shows signs of scale. MU cleanout BHA on 3-1/2" workstring wl bi and RIH. Cleanout well bore to maximum depth with filtered seawater/brine. Pump hi-vis sweeps as needed. Circulate wellbore clean at maximum rate. 11. Contin ncy: If unable to cleanout well with brine, clean out well with N2 as follows: .-- a. RU i ping Head and test to 1000 psi. yt. b. Mobilize , _ equipment (N2 pumper&transport) r , 4ki c. Rig up N2 equip -nt with " .rd line and hose to rig floor. d. Make up TIW and e. , . ve to workstring. e. Clear pe�nel from iron an. •• floor and pressure test lines to 3,000 psi. f. P nip N2 and 8.5ppg SW taking all re . ns through the choke to tank with open hatch. If necessary, pump N2 slugs followed by sea, .ter to clean the wellbore. g. Close valve on the workstring and rig down N2 ire • from rig floor. • Well Prognosis Well: MPU K-30 Hilcorp Alaska,LL Date: 11/20/2015 h. Rig down N2 equipment and demobilize. i. Circulate out all N2 from the well with seawater. j. Confirm well is dead before POOH. 12. Contingency: If any tight spots are noted, a caliper log may be run. Discuss with OE on the need for caliper run. a. If caliper run needed, RU SL with stuffing box, lubricator, pump in sub, and wireline valve. PT to 500 psi. RIH with caliper log to maximum depth. b. POOH. Download data. RD SL. R. 13. MU new TTC-ESP as follows: 7( a. Centralizer I1( b. Phoenix Gauge c. Motor—CL5 d. Lower Tandem Seal e. Upper Tandem Seal od., f. TTC Drilled Tubing Crossover c, 1. f g. Crossover,4-1/2" Hydril 521 box x NSTC pin ‘)0 t' h. 1 joint 4-1/2" Hydril 521 L-80 tubing 1kl); i. Dummy tubing hanger j. Landing joint 14. Land tubing hanger and RILDS. LD landing joint. 15. PU and screw in dummy landing joint. Ensure top of landing joint is at a convenient working height. 16. MU pump assembly#1 and land in TTC assembly: a. Model 450 Pump Eye b. Model 380 Pump Intake c. Model 380 Pump 17. MU pump assembly#2 and land on pump assembly#1: a. Model 380 Pump b. Model 380 Discharge Head c. Hanger receptacle 18. MU pack off assembly#1 and land on pump assembly#2 a. D&D Stinger b. 4' Spacer Pup c. D&D Kobe Knockout d. D&D Packoff 19. Run test tool and test packoff assembly. LD test tool. 20. Run tubing stop assembly. LD dummy landing joint. 21. PU 4-1/2" landing joint and screw into tubing hanger. BOLDS. 22. LD dummy tubing hanger. 23. MU ESP power cable to MLE. Run 3/8" external capillary string w/clamps down to base of ESP. 24. RIH on existing 4-1/2" Hydril 521 L-80 tubing with clamps for power cable and capillary string. 25. Set base of TTC-ESP at+/-10,380'. • • Well Prognosis Well: MPU K-30 Hilcorp Alaska,LL Date: 11/20/2015 26. Land tubing hanger. RILDS. Lay down landing joint. Test tubing hanger to 250/5,000 psi a. Note PU (Pick Up) and SO (Slack Off)weights on tally. 27. Set TWC. ND BOPE. 28. NU existing 4" 5,000#tree and test to 250 psi low/5,000 psi high. Pull TWC. 29. RD Nordic#3 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 30. Replace IA x OA pressure gauge if removed (7" x 9-5/8"). 31. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic 5. N2 Flow Schematic 6. Existing Tree/Wellhead 7. Blank RWO Changes Form . 11111 4, Milne Point Unit Well: MPU K-30 SCHEMATIC Last Completed: 1/13/2014 Hilcorp Alaska,LLC PTD: 196-168 CASING DETAIL DF Elev.:57.5'/GL Elev.:28 (Nabors 22E) Size Type Wt/Grade/Conn Drift ID Top Btm DF to 7"Casing Hanger=28.5 20" Conductor 91.1/H-40E/N/A N/A Surface 112' 4 I } i} ka4 9- 5/8" Surface 47/L-80/NSCC. 8.679 Surface 4,544' t.20' ¢* c+ 9-5/8" Surface 47/L-80/Btrc. 8.679 4,544' 4,796' a;' 9-5/8" Surface 47/P-110/Btrc. 8.679 4,796' 6,652' ? 7" Production 26/L-80/Btrc 6.276 Surface 11,122' TUBING DETAIL r4-1/2" Tubing 12.6/L-80/Hydril 521 3.958 Surf 10,378' tit JEWELRY DETAIL .1 :pINNo Depth Item 9-5/8" 9y6'Fkrnco 1 10,170' D&D Packoff Assembly w/Kobe Knockout(STUCK!) ES Cementer 2 10,290' Centrilift TTC-ESP Top 3 10,338' TTC Drilled Tubing Crossover 4.5"NSTC Pin x 4.5"521 Hydril Box 4 10,348' Upper Tandem Seal GSB3 DB UT/HL H6 PFS 5 10,362' Motor,168HP,3460 Volt,30 amp 6 10,378' Pumpmate w/6 Fin Centralizer-Bottom @ 10,380' PERFORATION DETAIL / Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status J Kup.C Sands 10,588' 10,658' 7,024' 7,063' 70 11/26/2015 Open i.f(/L I Kup.B Sands 10,704' 10,748' 7,088' 7,111' 44 11/25/1996 Open 449_, WELL INCLINATION DETAIL KOP @ 400' Max Hole Angle=57 to 62 deg. f/3,650'to 11,041 Max Hole Angle through perforations=58 deg. OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole 9-5/8" 1,500 sx Trinity Lite Wate,750 sx PF"E",in 12-1/4"Hole 7" 245 sx Class"G"in 8-1/2"Hole :•• t TREE&WELLHEAD I# 1Tree 11"CIM4-1/16" .11 Packoff stuck in tubing 11"x 11"SM FMC Gen 5A,w/4-1/16"FMC Tbg. * * @ 10,170'SLM as of 9/06/15 Wellhead Hngr.,L.H.Acme thread 4"CIW H BPV profile 2 :p v ,1 s GENERAL WELL INFO 4" API:50-029-22711-00-00 ' Orig.. `r O g Completion by Nabors 4-ES -11/27/1996 r. r4 RWO Screens added PigTail Pull&Land-6/15/1998 ,a / 9 II RWO w/Nabors 4-ES-4/5/2002&5/5/2004 a, ESP RWO w/Nabors 4-ES-10/6/2007 Iii ';a 5 ESP RWO&Replace Screens w/Nabors 35-8/3/2008 k+ ESP RWO&Replace Screens w/Nabors 4-ES-8/15/2010 ESP RWO w/Doyon 16-8/5/2011&1/13/2014 a .,k 6 i s rt tl w. I.,' a' ,,.; }KUPCSands it LET KUPBSands P TD=11,145'(MD)/TD=7,306'(1VD) PBTD=11,041'(MD)/PBTD=7,257(TVD) Revised By:STP 9/06/2015 410 Milne Point Unit 14 P POSED SCHEMATIC well: MPU K-30 Last Completed: 1/13/2014 Hilcorp Alaska,LLC PTD: 196-168 CASING DETAIL DF Elev.:57.5'/GL Elev.:28 (Nabors 22E) Size Type Wt/Grade/Conn Drift ID Top Btm DF to 7"Casing Hanger=28.5 pp 20" Conductor 91.1/H-40E/N/A N/A Surface 112' 4 9-5 /8" Surface 47/L-80/NSCC. 8.679 Surface 4,544' t' 9-5/8" Surface 47/L-80/Btrc. 8.679 4,544' 4,796' 9-5/8" Surface 47/P-110/Btrc. 8.679 4,796' 6,652' 4 �+ 7" Production 26/L-80/Btrc 6.276 Surface 11,122' µ TUBING DETAIL t, f. '' 4-1/2" Tubing 12.6/L-80/Hydril 521 3.958 Surf ±10,378' 4 r' JEWELRY DETAIL 719-5/\ No Depth Item �5/gr g"F 1 ±10,170' D&D Packoff Assembly w/Kobe Knockout 5 , ES Cementer 2 ±10,290' Centrilift TTC-ESP Top 3 ±10,338' TTC Drilled Tubing Crossover 4.5"NSTC Pin x 4.5"521 Hydril Box 4 ±10,348' Upper Tandem Seal GSB3 DB UT/HL H6 PFS 5 ±10,362' Motor,168HP,3460 Volt,30 amp 6 ±10,378' Pumpmate w/6 Fin Centralizer—Bottom @±10,380' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status Kup.C Sands 10,588' 10,658' 7,024' 7,063' 70 11/26/2015 Open Kup.B Sands 10,704' 10,748' 7,088' 7,111' 44 11/25/1996 Open WELL INCLINATION DETAIL KOP @ 400' Max Hole Angle=57 to 62 deg. f/3,650'to 11,041 Max Hole Angle through perforations=58 deg. OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole 9-5/8" 1,500 sx Trinity Lite Wate,750 sx PF"E",in 12-1/4"Hole 7" 245 sx Class"G"in 8-1/2"Hole TREE&WELLHEAD x Tree 5M CIM 4-1/16" 11"x 11"5M FMC Gen 5A,w/4-1/16"FMC Tbg. Wellhead Hngr.,L.H.Acme thread 4"CIW H BPV profile 12 j"s GENERAL WELL INFO "" API:50-029-22711-00-00 Orig.Completion by Nabors 4-ES -11/27/1996 1 '4 RWO Screens added/Pig Tail Pull&Land—6/15/1998 '! RWO w/Nabors 4-ES—4/5/2002&5/5/2004 ESP RWO w/Nabors 4-ES—10/6/2007 e. a�5 ESP RWO&Replace Screens w/Nabors 3S-8/3/2008 ESP RWO&Replace Screens w/Nabors 4-ES—8/15/2010 Y w ESP RWO /Doyon 16—8/5/2011&1/13/2014 g 1.4A i, j.KUP C Sands C' }KUP B Sarxls �a u Y 7"iStrnat4 TD=11,145'(MO)/TD=7,306'(1VD) PBTD=11,041'(MD)/PBTD=7,257'(1VD) Revised By:TDF 11/20/2015 i • , HMilne Point Nordic#3 Class III BOPE 11/12/2015 Ililrorp 11u.1u.1.1.1: r 1 O O ,[Mil fitl (fel (a1 frit ittkrt i Hydril 11" 5M , ill) rill f -I l r11 ct J _, , , Shaffer , — L ®• , 2 7/8"-5-%2" VBR • — M(' L 11" SM lill:2 Blinds o 3 1/8 5M Kill Valves 1 3 1/8 5M Choke Valves Manual and HCR Br _1111111"1 Manual and HCR IOu4 _ r r w n n xw « " Ax Ar V 4 r r v44 . w w A . Aw . 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Houston Specialty Products Page 1 of 2 • • eiHouston Specialty Products COMPANY 1 PRODUCTS Serving the oil field industry since 1985 . , Swab Cups Our Tubing Stripper Heads Stripper Rubbers Pipe Wipers HS2400 Stripper Head Oil Saver Rubbers Ram Rubbers/Ram Blocks �__—__-_ I A Wil— Rod Wipers �-'SPC.�� f9 NE N �'� Rod Guides j i Drill Pipe Protector 6r rI 1 Control Master ;,fn DA Stuffing Box Packing Tubing Stripper Heads The HS-2400 Stripper/Tubing Head is designed for use on Products&Part Numbers cavitation wells,as well as, Reseller Form conventional drilling and reverse circulation.The self Company Information energizing packing rubber ®. forms a seal on the O.D.of the 1:=1 tubing or casing string while 'v---i going in and out of the well or while rotating.The packing ,i 4 r 4 rubber is held in place by a 3 I I hinged clamp that makes r."IF(MT change out simple and fast. Each stripper/tubing head has a 2-3/8"side outlet for flow control. Hall Stripper Head With No Hall Stripper Head With Outlet Outlet ,40041/11111110 a 1 http://www.houstonspecialtyproducts.com/products/tubing_stripper_heads.html 11/24/2015 Page 1 of 1 • • 111 http://www.houstonspecialtyproducts.com/images/stripper_rubbers/biwsmall jpg 11/25/2015 STATE OF ALASKA • AleKA OIL AND GAS CONSERVATION COM SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon UPlu Perforations ❑ Fracture Stimulate UP II Tubing U Operations Shutdown L j Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Rednll ❑ erforate New Pool ❑ Repair Well ❑Q Re-enter Susp Well❑ CT Pull Pump❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development:El Exploratory ❑ 196-168 • 3.Address: Stratigraphic El Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22711-00-00 w 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0375132 1 MILNE PT UNIT KR K-30 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL e 11.Present Well Condition Summary: Total Depth measured 11,145 • feet Plugs measured N/A feet C tbri,. true vertical 7,306 , feet Junk measured 10,170 feet 0 r 1 0 2015 Effective Depth measured 11,041 feet Packer measured N/A feet true vertical 7,257 feet true vertical N/A feetfr4r`""h Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' Surface 6,652' 9-5/8" 6,652' 4,908' 6,870psi 4,760psi Intermediate 11,122' 7" 11,122' 7,295' 7,240psi 5,410psi Production Liner C Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/Hydril 521 10,380' 6,906' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 140 0 Subsequent to operation: 0 0 0 80 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: t Daily Report of Well Operations [] Exploratory❑ Development[] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run El 16.Well Status after work: Oil [] Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ ' SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-557 Contact Stan Porhola Email sporhola at hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature Phone 777-8412 Date 10/19/2015 Form 10-404 Revised 5/2015 DZ. /6 2Z�(JJ RBDMSVCT 2 1 2015 Submit Original Only • • MilnWell:e PointMPUK-30 Unit ti SCHEMATIC Last Completed: 1/13/2014 Hilcorp Alaska,LLC PTD: 196-168 CASING DETAIL DF Elev.:57.5'/GL Elev.:28 (Nabors 22E) Size Type Wt/Grade/Conn Drift ID Top Btm DF to 7"Casing Hanger=28.5 j ,X FF 20" Conductor 91.1/H-40E/N/A N/A Surface 112' K+ t ['k 9-5/8" Surface 47/L-80/NSCC. 8.679 Surface 4,544' f R 9-5/8" Surface 47/L-80/Btrc. 8.679 4,544' 4,796' 9-5/8" Surface ace 47 P-110 Btrc. 8.679 4 796' / / 6,652' 14 ,4 1.1 ." 7" Production 26/L-80/Btrc 6.276 Surface 11,122' TUBING DETAIL 1 Y'. F.: 4-1/2" Tubing 12.6/L-80/Hydril 521 3.958 Surf 10,378' "< JEWELRY DETAIL 9-5/g, No Depth Item gyg"Homo 1 10,170' D&D Packoff Assembly w/Kobe Knockout(STUCK!) ES Cementer 2 10,290' Centrilift TTC ESP Top 3 10,338' TTC Drilled Tubing Crossover 4.5"NSTC Pin x 4.5"521 Hydril Box 4 10,348' Upper Tandem Seal GSB3 DB UT/HL H6 PFS 5 10,362' Motor,168HP,3460 Volt,30 amp 6 10,378' Pumpmate w/6 Fin Centralizer—Bottom @ 10,380' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.C Sands 10,588' 10,658' 7,024' 7,063' 70 11/26/2015 Open i Kup.B Sands 10,704' 10,748' 7,088' 7,111' 44 11/25/1996 Open WELL INCLINATION DETAIL KOP @ 400' Max Hole Angle=57 to 62 deg. f/3,650'to 11,041 Max Hole Angle through perforations=58 deg. OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole 9-5/8" 1,500 sx Trinity Lite Wate,750 sx PF"E",in 12-1/4"Hole 7" 245 sx Class"G"in 8-1/2"Hole 1 TREE&WELLHEAD tt Tree SM CIM 4-1/16" V� Packoff stuck in tubing @ 10,170'SLM as of 9/06/15 Wellhead 11"x 11"SM FMC Gen 5A,w/4-1/16"FMC Tbg. Hngr.,L.H.Acme thread 4"CIW H BPV profile t,2 3 GENERAL WELL INFO !ti API:50-029-22711-00-00 A t+; Orig.Completion by Nabors 4-ES -11/27/1996 4 RWO Screens added/Pig Tail Pull&Land—6/15/1998 RWO w/Nabors 4-ES—4/5/2002&5/5/2004 ESP RWO w/Nabors 4-ES—10/6/2007 '• 5 ESP RWO&Replace Screens w/Nabors 3S—8/3/2008 ESP RWO&Replace Screens w/Nabors 4-ES—8/15/2010 6 ESP RWO w/Doyon 16-8/5/2011&1/13/2014 to. Ir 11 }KUP C Sands }KUP B Sands Yr TD=11,145'(MD)/TD=7,306(TVD) PBTD=11,041'(MO)/PBTD=7,257(TVD) Revised By:STP 9/06/2015 • • Hilcorp Alaska, LLC Hi!ca p Alaska.1.11-C Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP K-30 50-029-22711-00-00 196-168 10/4/2015 10/7/2015 Daily Operations: 9/30/15-Wednesday No operations to report. 10/1/15-Thursday No operations to report. 10/2/15-Friday No operations to report. 10/3/15-Saturday No operations to report. 10/4/15-Sunday Hold Safety meeting and discuss JSA and job procedure with crew. Rig up CTU. Make up CC 2.88" Od, Pull test 30k. Install DFCV, 2.88"Od, Bi-Di Mechancial slinger 2.88"OD, Weight bar 2.88"Od, Bi-Di Hydraulic Jars 2.88" OD,TJ hydraulic Disconnect with .75in ball seat 2.88"Od, Pressure test MHA to 250/3,500 psi.Good pressure test. Instal 4" Hydraulic GS pulling tool 3.625"OD.Stab lubricator on well. 305 bbls of sea water in upright tank. Perform walk around of location. Location secure. Crews off location. Stabbed on well ready to RIH in the morning. 10/5/15-Monday Perform safety meeting. Discuss Job procedures. Online down CT. Pressure building.Crews confirmed lined up down CT. Must be ice chunk at end of BHA. Ready to RIH to attempt to thaw ice plug.Open swab. Fusible cap installed on SSV. 24.5 turns.Confirm masters open. RIH.3,500'WT chk 10.5K, 7500" 17K.9500" 21K. Plck up wt at 10,000' 24K. RIH to tag GS profile.Stacked -4K at 10,199'. Pick up to 47K 20 Over pull lick. Reset jars. Pick up 50K. 30K over.Jar at 10,138'. Pull to 60K. No luck. 12 jar lick over pull to 50K weight 30k over string weight. 10,134'. Pack off doesn't seem to be moving. Coil is stretching. RIH for down jar lick.Stack-20K. 19K slack off.Jar lick no luck.Continue jarring. RIH stack 15K. Down jar. No movement.Continue Jarring up.50 Jar licks achieved. Have to come out of hole and re-head.Stack 10k on fishing neck. Line up down back side. Online with pump at.5 bbls/min pressure increase to 4,000 psi something gave loose and pressure dropped rapidly to 350 psi. Increase pumping to 1 bbl/min. Pressure 350 psi. Release from GS profile 2,850 psi on CT pressure. POOH.At surface Freeze protecting. Ordered Tote of xylene for following day. Master swab closed. Break off above BOPS. RIH and break down tool string. Cut off coil connector. Cut 250'of coil. Install 1.75in OD tools.CC,check valves,disco,straight bar,wash nozzle.Stab back on well. Hammer up flange.Secure location.Crews off location. Night crane op and roustabout on duty. • S 10/6/15-Tuesday Hold safety meeting. Discuss job procedure. Install tee for vendor to hook up for xylene treatment. Line up valves to circuate freeze protect fluid to holding tank(60/40). Had trouble getting pump primed up. Fluid packing with sea water. Pressure test stack and iron to 250/3,500psi. Bleed down.Open well and RIH.Xylene tote on location. HSE bringing out PPE to handle xylene. RIH. PU WT at 10,050'. 23K Clean. Inject down back side and CT at same time 4 bbls/min @ 1,800psi. Down on pump. RIH through pack off and tag Top of pump @ 10,321'. Estimated top of pump via tubing tally is 10,303'. Previous day stacked weight on Pack off at 10,199'. Pack off moved off pump 110'from previous attempts.4.5" tubing is 65 ft/bbl with 6.3bbls of xylene we can cover 410'of tubing. Hold saftey meeting with vendors to discussed PPE requirements. Pressure test LRS to 3,500psi with diesel.Zero CT fluid totalizer.Online down CT with Xylene 7bbls pumped.Swap to diesel. Back flush tote with 1bbl diesel. Pump 5bbls diesel behind xylene pill. Online with sea water. RIH to 10,300'and wait for xylene to hit nozzle.34.5bbls is CT volume. 34.5bbls away.Xylene at nozzle pumping 1bbl/min start laying in xylene at 1:1 pulling 65 ft/min from 10,300'.At 9,100' headed back down to 9,300'.7bbls of xlyene away shut down pump. POOH to 9,900'.Online with pump to clear diesel out of string. POOH to surface.Shift change out. Break off well. RIH to break down nozzle BHA and make up Jars. Make up external slip connector. Pull test 30K.CC 2.88", DFCV 2.88",ACCEL 2.88",WT bar 2.88",WT bar 2.88", BiDi Jars 2.88",TJ DISCO 2.88',4in GS spear 3.625".Stabbing on well. Flanged up. PT 250/3,500psi.Swab and master open. RIH Parked at 9,500'. Crews online down CT to push xylene away.Shut down.Operator noticed fluid coming from Injector head. ALL STOP! Investigated spill.Called Enviro, pad operator,and field foreman.Coned off spill area and dispatched spill response to clean area. Pumping down CT x 4.5" annulus at 2 bbls/min for 5 minutes to flush xylene. Do not want xylene around fishing neck.Could possibly damage internals on Hydraulic release GS spear.564psi @ 2bbls/min. Down on pump. 10bbI flush.Wt check at 9,500' @ 21.5K. RIH to 10,000'.WT check @ 10,000' 22k. RIH to tag top of pack off.Stack weight on pack of at 10,211'.Set down 5k to 10,215'. PU to 10,191'jars fired.Over pull to 60k. 10,182'. Looked to be dragging up hole.Set down at 10,204'. PU for jar lick. No jar lick.Slack back down to-10k. Pick up to 50k. Up lick. 10,185'. No movement.Continue jar licks.Stack 30k down jar. Online 3bbls min down back side of ct. 1,075 psi. PU. Pressure dropped from 1,075psi to 830psi. Injected 15bbls down back side.Attempt 2 up jars and 2 down jars while injecting. No change.Continue jaring.5 down jars without up licks.Still no movement.48 Jar licks.80%fatigue aquired on pipe cycle life. 1.2 bbls min 1,400psi release from GS spear. Clean up wt of 25K.82 bbls of sea water pumped. POOH. Circulate 60/40 methanol to freeze protect reel. Freeze protect surface lines. Bullhead 15 bbls of 60/40 down wellbore tubing.4.5"to freeze protect wellbore.Tag up at surface. Master swab closed. Perform walk around of location.Wellsite secure. Injector will stay on well for the night. Night crane operator and roustabout will monitor crane while suspended.Crews off location. Dispatched well support to fill methanol transport. Dispatched roads and pads to pull down open top returns tank. Hilcorp Alaska, LLC Alats.ka. LIU Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP K-30 50-029-22711-00-00 196-168 10/4/2015 10/7/2015 Daily Operations: 10/7/15-Wednesday Hold safety meeting and discuss plan forward for rigging down CTU.Start rigging down CTU QRS unit. Location secure. Pad work for well support,and roads and pads. 10/8/15-Thursday No operations to report. 10/9/15-Friday No operations to report. 10/10/15-Saturday No operations to report. 10/11/15-Sunday No operations to report. 10/12/15-Monday No operations to report. 10/13/15-Tuesday No operations to report. Rteg- i STATE OF ALASKA . ALL OIL AND GAS CONSERVATION COM.SION G REPORT OF SUNDRY WELL OPERATIONSt 4 - 1 2015 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing , "' ''s.. Shutdown❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program Q Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑., Re-enter Susp Well ❑ Other: ESP Change-outO 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ 196-168 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22711-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0375132 MILNE PT UNIT KR K-30 1 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 11,145 ` feet Plugs measured N/A feet true vertical 7,306 ' feet Junk measured 10,170 feet Effective Depth measured 11,041 feet Packer measured N/A feet true vertical 7,257 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' Surface 6,652' 9-5/8" 6,652' 4,908' 6,870psi 4,760psi Intermediate 11,122' 7" 11,122' 7,295' 7,240psi 5,410psi Production Liner Perforation depth Measured depth See Attached Schematic feet SCANNK NOV 2 42015 True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/Hydril 521 10,380' 6,906' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 450 197 Subsequent to operation: 0 0 0 140 0 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations E Exploratory❑ Development ' Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run El 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG El 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: 315-458&315-483 Contact Stan Porhola Email sporhoIa C(!�'.hiIcorp.com Printed Name Stan Porhola Title Operations Engineer Signature (fit, Phone 777-8412 Date 9/30/2015 Form 10-404 Revised 5/2015 4 Or 74 10l3rs t�tBDMSc OCT 0 2 2015 Submit Original Only ii 0 0 Milne Point Unit Well: MPU K-30 SCHEMATIC Last Completed: 1/13/2014 Hilcorp Alaska,LLC PTD: 196-168 CASING DETAIL DF Elev.:57.5'/GL Elev.:28 (Nabors 22E) Size Type Wt/Grade/Conn Drift ID Top Btm DF to 7'Casing Hanger=28.5 20" Conductor 91.1/H-40E/N/A N/A Surface 112' ,< L9-5/8" Surface 47/L-80/NSCC. 8.679 Surface 4,544' 20' g! 9-5/8" Surface 47/L-80/Btrc. 8.679 4,544' 4,796' 9-5/8" Surface 47/P-110/Btrc. 8.679 4,796' 6,652' 14 + 7" Production 26/L-80/Btrc 6.276 Surface 11,122' t. TUBING DETAIL ' 4-1/2" Tubing 12.6/L-80/Hydril 521 3.958 Surf 10,378' bf 4 JEWELRY DETAIL 1 No Depth Item 9-5/8" • gyg^Hoaco 1 10,170' D&D Packoff Assembly w/Kobe Knockout(STUCK!) ES Cementer 2 10,290' Centrilift TTC-ESP Top I 3 10,338' TTC Drilled Tubing Crossover 4.5"NSTC Pin x 4.5"521 Hydril Box 4 10,348' Upper Tandem Seal GSB3 DB UT/HL H6 PFS 5 10,362' Motor,168HP,3460 Volt,30 amp 6 10,378' Pumpmate w/6 Fin Centralizer—Bottom @ 10,380' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status t Kup.C Sands 10,588' 10,658' 7,024' 7,063' 70 11/26/2015 Open Kup.B Sands 10,704' 10,748' 7,088' 7,111' 44 11/25/1996 Open WELL INCLINATION DETAIL KOP@400' Max Hole Angle=57 to 62 deg. f/3,650'to 11,041 Max Hole Angle through perforations=58 deg. OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole 9-5/8" 1,500 sx Trinity Lite Wate,750 sx PF"E",in 12-1/4"Hole ( # 7" 245 sx Class"G"in 8-1/2"Hole 1 TREE&WELLHEAD ITree 5M CIM 4-1/16" ky Packoff stuck in tubing 11"x 11"SM FMC Gen 5A,w/4-1/16"FMC Tbg. 11 @ 10,170'SLM as of 9/06/15 Wellhead Hngr.,L.H.Acme thread 4"CIW H BPV profile rGENERAL WELL INFO API:50-029-22711-00-00 Orig.Completion by Nabors 4-ES -11/27/1996 4 RWO Screens added/Pig Tail Pull&Land—6/15/1998 RWO w/Nabors 4-ES—4/5/2002&5/5/2004 ESP RWO w/Nabors 4-ES—10/6/2007 5 ESP RWO&Replace Screens w/Nabors 3S—8/3/2008 ESP RWO&Replace Screens w/Nabors 4-ES—8/15/2010 6 ESP RWO w/Doyon 16-8/5/2011&1/13/2014 x y4 1 KUP C Sands ;r* }KUP B Sands : 14 6ti 7"taw Pla4k TD=11,145'(MD)/TD=7,305(1VD) PBTD=11,041'(MD)/PBTD=7,257(TVD) Revised By:STP 9/06/2015 • • Hilcorp Alaska, LLC Hileorp Alaska,LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date _End Date MP K-30 50-029-22711-00-00 196-168 8/12/2015 8/25/2015 oaf ' ns`: w 8/12/15-Wednesday Move in spot most equipment.SITP 260 SICP 550. Blow down both sides.Annulus to zero but slugging fluid.Shut in same. Blow down tbg. Continue rigging up.Tubing continues to light trickle with periodic minor slugs of oil,more perculation than slugs. RU LRS PJSM Pump 6 bbls down tubing pressure up to 1000 psi. Bleed off same, repeat pressure to 1,500 in 1 bbl repeat. Monitor.SITP 10 psi. Bleed off,set all containment,offload 225 bbls 150°8.5 ppg SW set BPV wait on crane on J-01 for hook up. ND Tree Inspect threads all Ok. NU BOPE tree is leaning.Continue MIRU set catwalk, run pump lines. 8/13/15-Thursday Continue rig up center BOPs.Offload 2-3/8" PH-6 rental work string. BOPE test and chart 250psi low/3,000 psi high, ,n annular 250psi low/2,500psi high,test chokes and perform accumulator draw down test. MU BHA with 3.7 OD insert mill, P?' boot basket and xovers.Torque to spec and RIH.Well displacing up the tubing also gassing and percolating. Reconfigure 1 44 displacement line up to stripping head.Open annulus stripping head outlet, install stripping rubber. PJSM. POOH w/2 mts and milling assy.Vac out stack.Start RIH again w/milling assembly using closed TIW to force displacement out annulus. Well still gassing,gas bubble vented. Continue in hole w/o TIW in PU jts. 50 jts- 1,580'.Annulus 2 4.5"x 7" has increased from 90 psi after blow down to 180 psi. 8/14/15-Friday PJSM.Continue in hole fighting tubing displacement to 77 jts 2,400'. Rig up to circ depth hole volume 35 bbls. Bleed off 4- 1/2" x 7"annulus, 190 psi. Bled to zero/slugging fluid leave open. RIH with 2-3/8" PH6.TIW all joints. 189 buried depth 5,854'. PJSM,strap pipe calibrating floor monitors. RIH to JT 253 tag up on fish @ 7,827'. PU 36 SO 23 set down 10K fish is solid. LD tag joint install crossovers back to rotary connection to prevent galling with swivel make up.Change plumbing to accept 1502, plumb directly to kill tank.Circ. hot 140°8.5 SW 110 bbls @ 3 bpm @ 2,100psi and displace hole. 2bpm@ 600psi and 320psi @ lbpm references recorded.Saw torque applied 5250 at 50 rpm. max torque on work string is 3,400psi and at top sub 2,000psi. Blow down lines RD LRS. Prepare to POOH for PDM Ordered 2-7/8" PDM. POOH LD 2- 3/8" PH-6 work string to 3,482' 112 jts to pull. 8/15/15-Saturday POOH with workstring BO/LD BHA. PU MU 3.7" bladed insert mill, 2-7/8" PDM, 2-7/8"Circ sub drop ball has been checked),x-over 2-3/8" PH-6 box x 2-3/8" PAC Pin. MU and torque motor to 2,300 ft/lbs RIH with 2 joints rig up to centrifugal and function test PDM. RIH w 2-3/8" P-110 5.95#work string to jt 152,order contingency SW.Swivel up on Jt 153, line up circ lines. Est Circ rate 2 BPM @ 1,700 psi fluid pack hole work down saw 1,900psi differential increase briefly and intermittently minimal obstruction engagement.Continue inhole repeating for 2 more joints and differential decreasing. PU pipe and RIH dry. No eveidence of tags.Continue RIH standard procedures to 10,161'.50K overpull stuck. PDM good to 75K overpull.Swivel up, resume wash down operations pushing/washing ahead 2 BPM with 100psi differential on motor.50/50 0/W Bottoms up returns 90%oil flow increase pit gain of"5 bbls.Wash down to 10,286' work last tag off and on pump. PDM in and out.TD achieved. +6' reported completion tally of 10,280. LD tag Joint,drop 5/8" ball to circ sub pump 40 bbl 2 bpm to ball on seat shear circ sub, pressure drop 500 psi after shaking pipe.Circ 150 bbls to kill tank. RD off swivel.Vac oil out of rig pits, Utilize Lil red for hole fill during trip,fill pits with clean SW,POOH LD workstring 90 jts out. • • 8/16/15-Sunday PJSM.Continue POOH BO/LD PDM and Mill, PU MU 4" Hydraulic GS 1.95'L and 3-3/4"OD. PU 2-3/8" P-110 5.95#work string RIH.At jt 250 displacement coming up tubing begin running with TIW,Yellow dog transfer pump freezing up. Order Tioga, rig up tarps. Continue running thru jt 332. Rig up swivel w/2-7/8" IF extender sub and install x-over to 2-3/8" PH-6. Swivel up on jt 233 RIH to tag TOF.Tag fish PU circulate 1 BPM @ 570 BPM 2 BPM 2,200psi wash off fish. Kill pump.Tag up on fish at tool joint PU single jt 234 has moved down 16'.Tally depth now 10,303'. Fish appears to want to travel down.Set down on fish. Check Pump pressure @ 1 bpm now to 1,000psi. Kill pump PU/LD single tubing standing full, PU from—10,287'overpull 20k drop back down. Continue and LD JT 333,continue POOH with drag halfway out on jt 332, depth is"'10,242'. Pulled to 60 K pipe not moving.Alternate pipe and pump/fish is plugged off 1 bpm pressure to 1,300 psi no returns.Work pipe to 75K and S/0 and alternate pump combination, pressures and rig overpull/SO regain movemment down/and regain circ. 1.3 bpm @ 950psi. No pipe movement up @ 25k overpull.Circ bottoms up @ 1.3 BPM 1,000psi some fine sand in returns. PU 60k pipe moving SW 53K. BO swivel LD single continue POOH. 8/17/15-Monday POOH with workstring. Full recovery of tbg stop.Cannot release from GS.Tbg stop has some stuck/drag scarring ID is clear. PJSM wait on slickline remove stripping head. Install 11"x 7"spool adapter rig up slickline. Rig crew organize A pad and Inventory rental equipment. PJSM RU S/L running in hole 3-3/8"gauge ring past 7,800' no problem @ 9,800' @ report time. 8/18/15-Tuesday PJSM.Crew change continue S/L ops. RIH w/gauge run to 10,282'. Follow with LIB had difficult time last few feet. Hit 15 times POOH no impression. RIG the pump bailer and GS combo work down to fish S/L depth achieved is 10,300'. No success getting in profile. RIH with GR catch,order slim hole wash out stinger.Work with S/L 2 hours lost hole to 10,272', no progress POOH with S/L. RD S/L. PJSM MU stinger with 2.131" OD 10.38'xover 2-3/4"OD 2-3/8" PAC x 2-3/8" PH 6 and RIH w 2-3/8" P-110 PH-6 5.95#tbg. Install Stripping head rubber and RIH to 6,500'. • . • Hilcorp Alaska, LLC HiIv ey ,l.,ska. 1.1_t: Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP K-30 50-029-22711-00-00 196-168 8/12/2015 8/25/2015 Daily Operations: 8/19/15-Wednesday Continue RIH with 2.131"stinger to jt 332. PJSM RU LRS RU to circ. covenentional. RIH w/jt 332 taking weight 4'out on depth^'10,262' (10'higher then S/L last run).Swivel up and PT all lines to 3,500psi.SW is 48K vs 54k previous trip with same string. Est. circ. rates 1 bpm 370 psi, 2bpm 1,100 psi,3 bpm 2,200psi.Wash down from connection 332 to 10,266' @ 2bpm 1,100psi, no pressure increase noted. Make connection 333,wash from 10,266-10,284'. Light instant bobble last 2k wt and 100psi pressure loss then back to SW and 1,100psi duration 10 seconds.Continue wash down to 10,298'.Circ 80 bbls.Stop pump,check flow, make connection.Wash to 10,315'-87psi pressure increase and weight loss. Repeat 4 times not washing off.Top connection leaking. Kill pump BO/LD and change saver sub MU and resume circulation @ 1 BPM no pressure, 100psi less. Work down to psi increase. PU 2 feet. Increase annular BOP pressure to 1,100psi. Close annulus, attempt to bullhead thru Kobe.Tbg and csg pressure to 2,500psi bled 100psi in 2 minutes. Bleed off and resume circ after set back down to cleanout final depth of 10,316'. Resume circ at 2 bpm-2nd full circulation. Returns clean. RD LRS POOH with 2-3/8" PH-6 workstring. Pull 6 jts, remove stripping head rubber,continue POOH. Resume POOH.Crew running speed POOH is 1,280' per hour. BOLD stinger no scars no buckling. PU MU 4" GS and x-over to work string. PJSM RIH with 2-3/8" PH-6 work string to 6,600' running speed 1:35 sec per joint. 8/20/15-Thursday Resume RIH with 4" hydraulic GS to retrieve pack off RIH to jt 334 Swivel up. RU LRS and PT lines to 3,500psi. Fill hole,get circ in 3 bbls. Kill pump set down on fish did not see latch with this indicator. PU to SW kick in pump pressure up to 3,000psi. String plugged. Kill pump LD single. RU swivel, pull 1 single and pump down tbg,gain circulation.Continue circulation @ 2BPM 1,900psi for BU 100 bbls.Set back down at depth to ensure engagement with pump on at 1 BPM the tools traveled down hole 13',we saw this phenomena prior on the first milling run.Stop pump to stop wash down. Ensure fish engagement PU stuck.Work to 30k over,work JT 334 out and LD.Work jt 333 up 10ft and stuck, no movement at 65K over, install TIW. Line up on annulus pump to 700psi in less than 2 bbls.Trap pressure work pipe, pressure bled off, pipe free, no communication with tbg. Open TIW tbg flat,connection dry, POOH with dry 2-3/8" PH-6 tbg to 9,000'. POOH w 2-3/8"work string,grease all valves, POOH no fish on retrieving GS. GS externally appears OK cannot function test on surface in current environment to see if internal spring is bad. Load face yield is 71,800Ibs, our full string overpull was max 65K per weight indicator.Call State Rep.for AOGCC and Wellhead Specialist to set TWC. Prepare for test. Set TWC. Hook up LRS PT all lines.Set up, begin test @ 0245.Testing BOPs. 8/21/15-Friday Continue BOPE test. Low test all hold good under 200 psi. High tests all acceptable no bleed off below 3,000 psi. BOPE tested 250/3,000psi,annular tested 250/2,500psi, accumulator drew down and gas alarms complete.Test witnessed by Lou Grimaldi AOGCC and final approval to return to TT operations was authorized. Pull TWC 4.5 "tbg is on a strong vacuum. Fill 4.5"x 7" annulus 3.8 bbls SW. Establish injection at 2 BPM 300psi no communication with 4.5"Tubing. Fill 4.5"Tubing 2.5bbls(was on vacuum) attempt to circulate with 7", tbg is packed off, pressure to 2,500psi. Bleed off 130psi in 2 minutes. PU MU new 4" Hydraulic GS and RIH w 2-3/8" PH-6 workstring to 10,257'. MU JT 333 to swivel. RIH to 10,288'work 2 times thru previous stuck spot, no tag, no drag. MU jt 334 connection. Light tag @ 10,297. PU check tag, no tag, continue to 10,302, 1k dn. PU no drag, repeat. GS tag same weight 1 ft deeper. Repeat 2 times,set down 3 K. LD jt 334.String is wet pull 333 string draining slowly. Elect to not attempt to circ.Continue POOH.String draining slow @ 7,355' report time. Rangeland working on catwalk. t 4 • • 8/22/15-Saturday Resume POOH. No recovery. Rangeland remove counter balances on swivel and function test swivel.Check GS all good. MU to worksring and RIH to jt 248,7,700' taking heavy oil slugs up tubing. Rig up to circ down tbg. LRS RU same PT all line to 3,500psi. Pump 30 bbl SW 8.5 ppg down tbg @ 850psi, 1 BPM 30 bls in 29 bbls out. Resume RIH thru Jt 333 @ 10,287'. PU &SU on joint 334. RIH to 4'above last tag. Circ. @ 1BPM"'850psi 1.5 BPM @ 1,800psi AV is 166 ft/min. @ 0510 am with 47 bbls away drop to 1'above TOF, no pressure increase.Trace of oil noted at 62 bbls away.At report time: 82bbls pumped,70 bbls recovered. 8/23/15-Sunday PJSM, continue wash to 10,308' 1.5 BPM @ 1,850psi.Swap out peak trucks vac off kill tank. New Strap on kill tank,total losses 9 bbls.Continue to wash down to pipe depth 10,312'+7' Doyon KB error is 10,319.39'deeper than tally depth. Wash in and out of fish top several times observe weight loss and 200psi pressure increase no depth gain. PU and do injection test down 2-3/8"x 4.5"annulus. No 7"communication locked up at 2,500psi with minimal bleed off.Set down in fish, kick out pumps. PU GS is latched.Work pipe LD single pipe stuck at 10,295'.Work multiple pump rates and overpulls of all variations/combinations to max rig pull. Hole is still packed off, no communication w/7"annulus. Pipe moving. POOH w/3 jts, 20-40K drag then packoff stuck again @^'10,195. Continue working pipe. Hang pipe in 50K overpull tension.Call mechanics. Mechanics arrive resume rig operations while they troubleshoot and reset faults. Resume working pipe at alternating weights and pulls using wobbler for pipe orientation changes gain 4.5'and lose 1' working to 30K- 153K max available. Slight movement. Elevators jammed from overpull no slack off capabilities to release, manually release. LD single.Crown saver will not allow working higher. Relatch and resume working pipe. 8/24/15-Monday PJSM,continue work pipe, previous slight movement was hydraulic and stretch not real. PU single and swivel. RU LRS P/T lines,fill tubing 2 bbls,5 bbls to catch circ.Set down on fish increase rate to 1.5 BPM. PU GS is released. Rig Down. LRS RD swivel. Drain all lines.Strap tag single 17.21' in fish top,depth of 4"GS profile on packoff is 10,201.37'. POOH LD 2-3/8" workstring BO/LD GS spear(in great shape for future reference 100K pulled this style GS for 18 hours).AOGCC manifold inspection and boiler design team evaluation while preparing for next run. PJSM, RIH 81 jts "'2,500' 2-3/8" PH-6 to freeze protect well. RU LRS P/T all lines displace 2500'with diesel^'34 bbls.Swap over and pump 40 bbls diesel down original 7"annulus. POOH, LD 81 jt, kill string, install BPV. Begin RDMO. Rig is LD all lines diconnected and pipe ready to move. 8/25/15-Tuesday ND BOPE. NU tree. ti. OF TRi I4, THE STAT• AlaskaOil and Gas ti, T. AS Conservati®n Commissi®n KA itEr : 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS* Fax: 907.276.7542 v✓ww.aogcc.alaska.gov Stan Porhola scow JAN 1 1 2 U 1 ; Operations Engineer IHilcorp Alaska, LLC (9 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR K-30 Sundry Number: 315-557 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair RBD SEP 11 201 DATED this 11 day of September, 2015 Encl. • • RECEIVED • SEP 0 8 2015 STATE OF ALASKA A7�yS�w9� it'�S ALASKA OIL AND GAS CONSERVATION COMMISSION 4,./4�I CC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program 0 Plug for Redrill❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: CT Pull Pump ❑.r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: T7"C- r5P Hilcorp Alaska,LLC , Exploratory ❑ Development El • 196-168 - 3.Address: Stratigraphic ❑ Service 1116.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22711-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.432C , Will planned perforations require a spacing exception? Yes ❑ No 0 / MILNE PT UNIT KR K-30 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0375132 . MILNE POINT/KUPARUK RIVER OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,145 • 7,306 • 11,041 • 7,257 • N/A 10,170' Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' Surface 6,652' 9-5/8" 6,652' 4,908' 6,870psi 4,760psi Intermediate 11,122' 7" 11,122' 7,295' 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 4-1/2" 12.6#/L-80/Hydril 251 10,380' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch E Exploratory ❑ Stratigraphic❑ Development Et Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/22/2015 Commencing Operations: OIL Q 1 WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ 0 Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email sDorhola(c hilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature Pert/'- Phone 777-8412 Date 9/8/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No V Subsequent Form Required: it) -t-10(1 04) APPROVED BY Approved by: (._ COMMISSIONER THE COMMISSION Date:9—//-65--- RBDM EP11 % 14,,--- IGINALSubmitForm and Form 10-403 Revi ed 5/2015 Approved application is vQR for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MPU K-30 Hilcarp Alaska,LL Date:9/08/2015 Well Name: MPU K-30 API Number: 50-029-22711-00 Current Status: SI Oil Well [TTC-ESP] Pad: K-Pad Estimated Start Date: September 22"d, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-168 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: Current Bottom Hole Pressure: 2,135 psi @ 7,000' TVD (Last BHP measured 5/05/2015) Maximum Expected BHP: 2,135 psi @ 7,000' TVD (No new perfs being added) I Max.Allowable Surf Pressure: 0 psi (Based on SBHP taken 5/05/2015 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000'ND of oil cap) Brief Well Summary: MPU K-30 was drilled in 1996 using Nabors 22E and completed in the Kuparuk B and C sands. The well has had multiple ESP changeouts and sand control screens ran and pulled since 1996, the most recent was an ESP changeout in 2014 using Doyon #16 to run a TTC-ESP. In August 2015, the ASR #1 WO Rig was able to recover the tubing stop but unable to recover the packoff, leaving it up hole approximately 100' above its original set point. Slickline was able to move the packoff 9' up hole in September 2015. Notes Regarding Wellbore Condition • Casing last tested to 250/3,500 psi for 30 min down to 10,538'on 1/05/2014. • Found no fill during the rig WO while cleaning out to 10,777'with Doyon#16 in 2014. • Packoff stuck in the 4-1/2"tubing @ 10,170'SLM. Objective: The purpose of this work/sundry is to pull the stuck Packoff, pull the rest of the failed TTC-ESP and run a new TTC-ESP, packoff, and stop(Change to Sundry 315-483). ✓ Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. 2. RIH w/2.00" coil w/GS pulling tool and pull packoff+/- 10,170' MD. POOH. 3. RIH w/2.00" coil w/GS pulling tool and pull TTC-ESP pump+/- 10,290' MD. POOH. 4. RIH w/2.00" coil w/2.75"wash nozzle and cleanout to top of TTC receiver at+/- 10,338' MD using 8.5 ppg sea water. POOH. 5. RIH w/2.00" coil w/GS running tool and run TTC-ESP pump+/- 10,290' MD. POOH. 6. RIH w/2.00" coil w/GS running tool and run packoff+/- 10,223' MD. POOH. 7. RIH w/2.00" coil w/Test tool to+/- 10,200' MD.Test packoff to 250/1,000 psi for 15 min. POOH. 8. RIH w/2.00" coil w/GS running tool and run tubing stop+/- 10,221' MD. 9. PU to+/- 10,200' MD. Displace well over to 8.5 ppg sea water. a. Estimated volume(w/o coil in hole) is 84 bbl. • • Well Prognosis Well: MPU K-30 Hilcoru Alaska,LL Date:9/08/2015 10. POOH w/coil. LD GS running tool. 11. RD Coiled Tubing. 12. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic H . • Milne Point Unit Well: MPU K-30 SC H E M ATI C Last Completed: 1/13/2014 [lilt...,Alaska,LLC PTD: 196-168 CASING DETAIL DF Elev.:57.5'/GL Elev.:28'(Nabors 22E) Size Type Wt/Grade/Conn Drift ID Top Btm DF to 7"Casing Hanger=28.5 20" Conductor 91.1/H-40E/N/A N/A Surface 112' L9-5/8" Surface 47/L-80/NSCC. 8.679 Surface 4,544' 20' 9 5/8" Surface 47/L-80/Btrc. 8.679 4,544' 4,796' 9-5/8" Surface 47/P-110/Btrc. 8.679 4,796' 6,652' 7" Production 26/L-80/Btrc 6.276 Surface 11,122' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/Hydril 521 3.958 Surf 10,378' JEWELRY DETAIL No Depth Item 9-5/8" 9-5/8"Homo 1 10,170' D&D Packoff Assembly w/Kobe Knockout(STUCK!) ES Cementer 2 _ 10,290' Centrilift TTC-ESP Top 3 10,338' TTC Drilled Tubing Crossover 4.5"NSTC Pin x 4.5"521 Hydril Box 4 10,348' Upper Tandem Seal GSB3 DB UT/HL H6 PFS 5 10,362' Motor,168HP,3460 Volt,30 amp 6 10,378' Pumpmate w/6 Fin Centralizer—Bottom @ 10,380' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.C Sands 10,588' 10,658' 7,024' 7,063' 70 11/26/2015 Open Kup.B Sands 10,704' 10,748' 7,088' 7,111' 44 11/25/1996 Open WELL INCLINATION DETAIL KOP @ 400' Max Hole Angle=57 to 62 deg. f/3,650'to 11,041 Max Hole Angle through perforations=58 deg. OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole 9-5/8" 1,500 sx Trinity Lite Wate,750 sx PF"E",in 12-1/4"Hole 7" 245 sx Class"G"in 8-1/2"Hole 1 TREE&WELLHEAD UTree 5M CIM 4-1/16" -� Packoff stuck in tubing 11"x 11"5M FMC Gen 5A,w/4-1/16"FMC Tbg. @ 10,170'SLM as of 9/06/15 Wellhead Hngr.,L.H.Acme thread 4"CIW H BPV profile - 2 ••• 3GENERAL WELL INFO , ••• API:50-029-22711-00-00 Orig.Completion by Nabors 4-ES -11/27/1996 4 RWO Screens added/Pig Tail Pull&Land—6/15/1998 RWO w/Nabors 4-ES—4/5/2002&5/5/2004 • ESP RWO w/Nabors 4-ES—10/6/2007 5 ESP RWO&Replace Screens w/Nabors 3S—8/3/2008 ESP RWO&Replace Screens w/Nabors 4-ES 8/15/2010 6 ESP RWO w/Doyon 16—8/5/2011&1/13/2014 _}KUP C Sands KUP B Sands Ern7"a 1' TD=11,145'(MD)/TD=7,306'(TVD) PBTD=11,041'(MD)/PBTD=7,257'(TVD) Revised By:STP 9/06/2015 . 11 • • Milne Well: Point MPU K-30Unit PROPOSED Last Completed: Proposed PTD: 196-168 Harm.")Alaska,LLC CASING DETAIL DF Elev.:57.5'/GL Elev.:28'(Nabors 22E) DFto7 Casing Hanger Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 91.1/H-40E/N/A N/A Surface 112' .+ LI, 9-5/8" Surface 47/L-80/NSCC. 8.679 Surface 4,544' 20" p� 9-5/8" Surface 47/L-80/Btrc. 8.679 4,544' 4,796' is". 9-5/8" Surface 47/P-110/Btrc. 8.679 4,796' 6,652' "� * 7" Production 26/L-80/Btrc 6.276 Surface 11,122' Ai 4 TUBING DETAIL k.7., 4-1/2" Tubing 12.6/L-80/Hydril 521 3.958 Surf 10,378' JEWELRY DETAIL No Depth Item 9-5/8"tt 95/8"Fico 1 ±10,221 D&D Tubing Stop ES Cementer 2 ±10,223' D&D Packoff Assembly w/Kobe Knockout 3 ±10,290' Centrilift TTC-ESP Top 4 10,338' TTC Drilled Tubing Crossover 4.5"NSTC Pin x 4.5"521 Hydril Box 5 10,348' Upper Tandem Seal GSB3 DB UT/HL H6 PFS 6 10,362' Motor,168HP,3460 Volt,30 amp 7 10,378' Pumpmate w/6 Fin Centralizer-Bottom @ 10,380' 1 i i S i i PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.C Sands 10,588' 10,658' 7,024' 7,063' 70 11/26/2015 Open i Kup.B Sands 10,704' 10,748' 7,088' 7,111' 44 11/25/1996 Open WELL INCLINATION DETAIL _'; 2 s-" KOP @ 400' ,. '' Max Hole Angle=57 to 62 deg. f/3,650'to 11,041 i t, s+3 Max Hole Angle through perforations=58 deg. ,4 " OPEN HOLE/CEMENT DETAIL mow ,- 20" 250 sx of Arcticset I in 24"Hole ,':5 9-5/8" 1,500 sx Trinity Lite Wate,750 sx PF"E",in 12-1/4"Hole 7" 245 sx Class"G"in 8-1/2"Hole i;, 'I 6 TREE&WELLHEAD Tree SM CIM 4-1/16" 11"x 11"5M FMC Gen 5A,w/4-1/16"FMC Tbg. 7 Wellhead Hngr.,L.H.Acme thread 4"CIW H BPV profile v GENERAL WELL INFO API:50-029-22711-00-00 C= Orig.Completion by Nabors 4-ES -11/27/1996 ;% RWO Screens added/Pig Tail Pull&Land-6/15/1998 }KUP C Bawls RWO w/Nabors 4-ES-4/5/2002&5/5/2004 ESP RWO w/Nabors 4-ES-10/6/2007 }KUP B Sands ESP RWO&Replace Screens w/Nabors 3S-8/3/2008 1.1 ESP RWO&Replace Screens w/Nabors 4-ES-8/15/2010 ESP RWO w/Doyon 16-8/5/2011&1/13/2014 7"" .'s R.?1tix,.d;Y TD=11,145'(MD)/TD=7,306'(TVD) PBTD=11,041'(MD)/PBTD=7,257'(TVD) Revised By:STP 9/08/2015 . • • Milne Point Unit COIL BOPE MPU K-30 09/08/2015 Hilrorp 1,Ia.k..l.t.t. MPU K-30 ali 20 X 9% X 7 X 4 Coil Tubing BOP 3 Lubricator to injection head Lil 1.75"Tandem Stripper . ae- -4 1/16 10 -- •' I Blind/Shear __Blind/Shear ,I,'•• 1 MN Blind/Shear = =_ mimm 01.1.1 1111111.11 - - c O0 tom; �j C_ Slip =r Slip 1.11; l•i i Pipe Mlle Pipe .I,'• Mud Cross %•J �l �i 4 1/16 10M X 4 1/16 10M Outlet IMI w/2-2 1/16 10M full opening FMC valves . 9114 O. 8 •IN • i( I,o I IMAM: Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M Uj 2 1/16 10M 2 1/16 10M Crossover spool of 4 1/16 10M X 4 1/16 5M ,No, Valve,Swab,WKM-M, ''*•-‘--%. �\��OFA 4 1/16 5M FE v Ja\�e e.,,,\ I.n.1 1.1.1 iiii, .r 11.,4111 II NI Valve,Upper Master,Baker, O 4 1/16 5M FE,w/Hydraulic • Valve,Lower Master,WKM-M, 4 1/16 5M FE '4411' Tubing Adapter,4 1/16 5M II II • • PTD 196 -/66 Loepp, Victoria T (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Friday, August 21, 2015 12:57 PM To: Loepp, Victoria T (DOA); Schwartz, Guy L (DOA) Cc: Grimaldi, Louis R(DOA) Subject: RE:*URGENT* K-30 (PTD 196-168) notice to proceed Follow Up Flag: Follow up Flag Status: Flagged Thank you,Victoria. satitiWill update you on the diagnostics on the leak. 0Q� 016 Stan From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.go;] Sent: Friday, August 21, 2015 12:55 PM To: Stan Porhola; Schwartz, Guy L(DOA) Cc: Grimaldi, Louis R(DOA) Subject: RE: *URGENT* K-30 (PTD 196-168) notice to proceed Stan, Approval is granted to proceed through your approved sundry with the suspected tubing hanger leak. Further diagnostics are expected to confirm the source of the leak and to correct the problem. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoepP alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: Stan Porhola [mailto:sporhola@hilcorp.com] Sent: Friday, August 21, 2015 12:00 PM To: Schwartz, Guy L(DOA) Cc: Loepp, Victoria T(DOA); Wayne Biart- (C) Subject: *URGENT* K-30 (PTD 196-168) notice to proceed 1 • • Guy, We are currently doing our weekly BOPE test on well MPU K-30(PTD 196-168) under sundry 315-483. During the test we have seen a consistent leak of 6-10 psi per min at 3,000 psi and no leak at 250 psi and have ruled out all possibilities except for the tubing hanger. This is an ESP well and we suspect the leak is thru the cable penetrator in the hanger. We are currently still working inside the 4-1/2"tubing w/our 2-3/8"workstring(Steps#6-#10 on the procedure).The annulus (4-1/2"x 7") is not communicating with the 4-1/2"tubing and does not have connectivity to the reservoir(likely packed off with sand above the ESP). We do have communication from the tubing to the reservoir(well is taking fluid after our BOPE test).We would like to continue to proceed working to pull the thru-tubing components of the ESP and after the thru-tubing components of the ESP are pulled we can establish communication up the annulus(4-1/2" x 7"). Our ultimate objective is to establish communication on the annulus (4-1/2" x 7") before attempting to pull the 4-1/2"tubing and the ESP. Lou Grimaldi is currently onsite for the weekly BOPE test witness and would like your approval before we proceed despite the current tubing hanger leak. Regards, Stan Porhola ' Operations Engineer North Mope Asset Team Hilcorp Alaska,LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 2 Titi • APV\O 11 ,- . THE STATE Alaska Oil and Gas i.%,�,;,—s ��—'�, o Conservation Commission _: -_- fALASI�:A est = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 fo;'' Main 907.279.1433 4t'ALAS* Fax. 907.276.7542 Satiti6 __ •' www.aogcc.alaska.gov Stan Porhola Operations Engineer bq Hilcorp Alaska, LLC I " 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR K-30 Sundry Number: 315-483 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this )311d-ay of August, 2015 Encl. RECEIVED STATE OF ALASKA AUG 0 7 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A�Gi��1 . <S 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing E • Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program Li Plug for Redrill❑ Perforate New Pool ❑ Repair Well [d ' Re-enter Susp Well ❑ Other: ESP Change-out ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC - Exploratory ❑ Development ❑✓ . 196-168 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22711-00-00 i 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432C Will planned perforations require a spacing exception? Yes ❑ No El / MILNE PT UNIT KR K-30 • 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0375132 ' MILNE POINT/KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,145 7,306 - 11,041 ' 7,257 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' Surface 6,652' 9-5/8" 6,652' 4,908' 6,870psi 4,760psi Intermediate 11,122' 7" 11,122' 7,295' 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 4-1/2" 12.6#/L-80/Hydril 251 10,380' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A ' 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑., Exploratory ❑ Stratigraphic Li Development❑✓ . Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 8/14/2015 Commencing Operations: OIL ❑✓ U WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: y_t3 -/s' GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: q s . _-t-s_. GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true aid correct to the best of my knowledge. Contact Stan Porhola Email sporhola@hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature Phone 777-8412 Date 8/7/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 36 - 1-kc Plug Integrity ❑ BOP Test wr Mechanical� � Integrity Test ❑ Location Clearance El Other: I( 7 ae9/-� 7 ��S P — '�, Jt30v �sc c t (3t, Spacing Exception Required? Yes El No Subsequent Form Required: f d•-V 0`I APPROVED BY Approved by: ia COMMISSIONER THE COMMISSION Date: 8—/_5-/5"-- it_ Y•' -%> `f&3pS��I �IS RBDMS` AUG 1 4 2015 f .* V 46-- Submit Form and Form 10-403 Revised 5/2015 ApproVea p aFio17 u ♦alitl L 12 months from the date of approval. Attachments in Duplicate Well Prognosis Well: MPU K-30 llilcorp Alaska,LL Date:8/07/2015 Well Name: MPU K-30 API Number: 50-029-22711-00 Current Status: SI Oil Well [TTC-ESP] Pad: K-Pad Estimated Start Date: August 14th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-168 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: Current Bottom Hole Pressure: 2,135 psi @ 7,000' TVD (Last BHP measured 5/05/2015) Maximum Expected BHP: 2,135 psi @ 7,000' TVD (No new perfs being added) Max. Allowable Surf Pressure: 0 psi Att.., _ (Based on SBHP taken 5/05/2015 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000' TVD of oil cap) Brief Well Summary: 13; - o r›- MPU K-30 was drilled in 1996 using Nabors 22E and completed in the Kuparuk B and C sands. The well has had multiple ESP changeouts and sand control screens ran and pulled since 1996, the most recent was an ESP changeout in 2014 using Doyon#16 to run a TTC-ESP. Notes Regarding Wellbore Condition • Casing last tested to 250/3,500 psi for 30 min down to 10,538' on 1/05/2014. • Found no fill during the rig WO while cleaning out to 10,777' with Doyon #16 in 2014. • Obstruction found in the 4-1/2"tubing @ 7,800'. Unable to pass and no image with a camera. Objective: ?J The purpose of this work/sundry is to pull the existing failed ESP and run a new ESP. / { Brief Procedure: WO Rig Procedure: 1. MIRU Hilcorp ASR#1 WO Rig. 2. Circulate well with 8.4 ppg lease water down tubing and fill casing. 3. Set BPV. ND Tree. 4. NU 11" BOPE. Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/ 1,500 psi High (hold each valve and test for 5-min). Recordacc�umulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test VBR rams on 2-7/8" test joint and 4-1/2" test joint. c. Test pipe rams on 2-3/8" test joint. 5. Bleed any pressure off tubing and casing. Pull BPV. 6. MU 3-7/8"junk mill and junk baskets. 7. RIH w/2-3/8" workstring to junk/obstruction at+/- 7,800' MD. 8. Mill out junk/obstruction at+/-7,800'. Cleanout to tubing stop at+/- 10,280' MD. 9. Establish circulation thru TTC-ESP with 8.4 ppg lease water. 10. POOH. Lay down 2-3/8" workstring and 3-7/8"junk mill and junk baskets. • Well Prognosis Well: MPU K-30 Hilcorp Alaska,LL Date:8/07/2015 a. ***Contingency*** If unable to establish circulation down tubing thru pump after clearing out junk/obstruction. b. MIRU E-line. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. c. BOPE connection is 11" studded top for lubricator on top of annular. d. RIH and punch tubing above tubing stop at+/- 10,280' MD. 11. MU 4-1/2" landing joint and pull over string weight(120k) on tubing hanger to confirm free. 12. POOH. Lay 4-1/2" tubing on the pipe rack(utilize as workstring). 13. MU 6-1/8" bit and junk baskets and RIH to+/- 10,300'. 14. Cleanout fill to +/- 11,000'. 15. Circulate bottoms up x 2 with 8.4 ppg lease water. 16. POOH. Lay down bit and junk baskets. Lay down 4-1/2"tubing. 17. PU new 475 series ESP and RIH with new 2-7/8" 8RD EUE L-80 tubing. a. Test 3/8" control line to 2,500 psi. b. RU to use clamps to secure control line to tubing (ensure adequate clamps). 18. Set base of ESP at+/-10,400' (Pump intake around +/- 10,320'). Land tubing hanger. 19. Lay down landing joint. Set BPV. ND BOPE. NU new 2-7/8" 5,000#tree. Pull BPV. 20. Set TWC. Test tubing hanger to 250/5,000 psi.Test tree to 250/5,000 psi. Pull TWC. 21. RD Hilcorp ASR#1 WO Rig. 22. Replace IA x OA pressure gauge if removed (7" x 9-5/8"). 23. Turn well over to production. Attachments: 1. As-built Schematic(Updated) 2. Proposed Schematic (Updated) 3. BOPE Schematic(Using 2-3/8"workstring) 4. BOPE Schematic(Pulling 4-1/2"tubing, Running 2-7/8"tubing) Milne Point Unit Well: MPU K-30 SCHEMATIC Last Completed: 1/13/2014 Ilikorp Alaska,LL(. PTD: 196-168 CASING DETAIL DF Elev.:57.5'/GL Elev.:28'(Nabors 22E) DF to 7"Casing Hanger 28.5 Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 91.1/H-40E/N/A N/A Surface 112' 9-5/8" Surface 47/L-80/NSCC. 8.679 Surface 4,544' 20'' 9-5/8" Surface 47/L-80/Btrc. 8.679 4,544' 4,796' 9-5/8" Surface 47/P-110/Btrc. 8.679 4,796' 6,652' 7" Production 26/L-80/Btrc 6.276 Surface 11,122' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/Hydril 521 3.958 Surf 10,378' JEWELRY DETAIL • No Depth Item 9-5/8" • gyg"Homo 1 10,280' D&D Tubing Stop ESCernenter 2 10,282' D&D Packoff Assembly w/Kobe Knockout 3 10,290' Centrilift ITC-ESP Top 4 10,338' TTC Drilled Tubing Crossover 4.5"NSTC Pin x 4.5"521 Hydril Box 5 10,348' Upper Tandem Seal GSB3 DB UT/HL H6 PFS 6 10,362' Motor,168HP,3460 Volt,30 amp 7 10,378' Pumpmate w/6 Fin Centralizer— aAtom @ 10,380' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.C Sands 10,588' 10,658' 7,024' 7,063' 70 11/26/2015 Open Kup.B Sands 10,704' 10,748' 7,088' 7,111' 44 11/25/1996 Open WELL INCLINATION DETAIL KOP @ 400' Max Hole Angle=57 to 62 deg. f/3,650'to 11,041 Max Hole Angle through perforations=58 deg. OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole • 9-5/8" 1,500 sx Trinity Lite Wate,750 sx PF"E",in 12-1/4"Hole 7" 245 sx Class"G"in 8-1/2"Hole TREE&WELLHEAD Tree 5M CIM 4-1/16" 1 • r + 2 Unknown Junk/Obstruction 11"x 11"5M FMC Gen 5A,w/4-1/16"FMC Tbg. 7 400'SLM Wellhead Hngr.,L.H.Acme thread 4"CIW H BPV profile 3 S 4 GENERAL WELL INFO • ,, API:50-029-22711-00-00 Orig.Completion by Nabors 4-ES -11/27/1996 5 � RWO Screens added/Pig Tail Pull&Land—6/15/1998 _ 1 RWO w/Nabors 4-ES—4/5/2002&5/5/2004 ESP RWO w/Nabors 4-ES—10/6/2007 6 ESP RWO&Replace Screens w/Nabors 3S—8/3/2008 ESP RWO&Replace Screens w/Nabors 4-ES—8/15/2010 7 ESP RWO w/Doyon 16—8/5/2011&1/13/2014 01 r7 }KUP C Sands KUP B Sands ti• TD=11,145'(MD)/TD=7,306'(TVD) PBTD=11,041'(MD)/PBTD=7,257'(TVD) Revised By:STP 8/07/2015 Milne Point Unit Well: MPU K-30 II PROPOSED Last Completed: Proposed Hilcorp Alaska,LLQ: PTD: 196-168 CASING DETAIL DF Elev.:57.5'/GL Elev.:28'(Nabors 22E) DF to 7 Casing Hamer 28.5 Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 91.1/H-40E/N/A N/A Surface 112' 9-5/8" Surface 47/L-80/NSCC. 8.679 Surface 4,544' 20' 9 5/8" Surface 47/L-80/Btrc. 8.679 4,544' _ 4,796' 9-5/8" Surface 47/P-110/Btrc. 8.679 4,796' _ 6,652' iri i . 7" Production 26/L-80/Btrc 6.276 Surface 11,122' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/Hydril 521 s.13ii Surf ±10,380' JEWELRY DETAIL No Depth Item gyg'How 1 ±200' GLM ES Cementer 2 ±10,155' GLM 3 ±10,278' D&D Tubing Stop 4 ±10,280' D&D Packoff Assembly w/Kobe Knockout 5 ±10,288' Centrilift TTC-ESP Top 6 ±10,336' Tit Drilled Tubing Crossover 4.5"NSTC Pin x 4.5"521 Hydril Box 7 ±10,346' Gas Separator-GRSFTXAR H6 8 ±10,351' Tandem Seal Section-GSBDBUT SB/SB PFSA:GSBDBIT SB/SB PFSA 9 ±10,365' Motor-MSP1-250 126HP/2,445 V/31A 10 ±10,376' 3/8"Stainless Steel External Capstring 11 ±10,376' Sensor/Centralizer-Bottom@±10,380' • ID 1 2 PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.C Sands 10,588' 10,658' 7,024' 7,063' 70 11/26/2015 Open Kup.B Sands 10,704' 10,748' 7,088' 7,111' 44 11/25/1996 Open 3 WELL INCLINATION DETAIL lig1 4 _ KOP @ 400' l 5 Max Hole Angle=57 to 62 deg. f/3,650'to 11,041 Max Hole Angle through perforations=58 deg. 6 7 C> OPEN HOLE/CEMENT DETAIL / 20" 250 sx of Arcticset I in 24"Hole 8 9-5/8" 1,500 sx Trinity Lite Wate,750 sx PF"E",in 12-1/4"Hole - 7" 245 sx Class"G"in 8-1/2"Hole 4 9 TREE&WELLHEAD Tree 5M CIM 4-1/16" 1O 11"x il"5M FMC Gen 5A,w/4-1/16"FMC Tbg. 11 + Wellhead Hngr.,L.H.Acme thread 4"CIW H BPV profile GENERAL WELL INFO . API:50-029-22711-00-00 Orig.Completion by Nabors 4-ES -11/27/1996 RWO Screens added/Pig Tail Pull&Land-6/15/1998 _}KUPCSarxis RWO w/Nabors 4-ES-4/5/2002&5/5/2004 ESP RWO w/Nabors 4-ES-10/6/2007 _ }KUP B Sands ESP RWO&Replace Screens w/Nabors 3S-8/3/2008 ESP RWO&Replace Screens w/Nabors 4-ES-8/15/2010 • ESP RWO w/Doyon 16-8/5/2011&1/13/2014 7„: . .1' TD=11,145'(MD)/TD=7,305(1VD) PBTD=11,041'(MD)/PBTD=7,257(TVD) Revised By:STP 8/07/2015 Milne Point 2015 ASR Rig 1 HiM.rp 11a44.1.1.I. Knight Oil Tools BOP 11" BOPE — 2-3/8" Workstring Stripping Head 3.98' W' pr Hyd ri l GK 11"-5000 111 lil III iamb I 1 �1— 111 1 I 4.54' M —= 2 3/8 Pipe Rams •i�tii' � - 11"-5000 ?sr, Blind - 1111 ill Iii Iii III 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves —, III 1111#1 III Illi 2.00 �ffh N °'Iii 11111 Ii1 Iil�;; -11 ,• ; 41 r: Manual Manual Manual HCR Updated 8/07/15 Milne Point 2015 ASR Rig 1 .. n ` ��..P ba'ka i.ta: Knight Oil Tools BOP 11" BOPE - 4-1/2" Tubing & 2-7/8" Tubing Stripping Head 3.98' Mlir 1111 pr Hydril 4 GK 11"-5000 1111 111 111 111111111 I i III 111111 III 111 / 1111. 4.54' - I �� mil- - o U (A" - 2 7/8-5 variables 'ti 11"-5000ilk 16110 - Blind Illi III Iii 111 iii 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves s - III IIIll IN .,.) 1. 0 ;2.00' 1 siII,c° r i . . ' " liLlillihlil !Ili iii' ' €— Manual Manual Manual HCR Updated 8/07/15 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, August 13, 2015 9:42 AM To: 'Stan Porhola' Cc: Tom Fouts Subject: RE:Verbal approval request - K-30 (PTD 196-168) and Cancel sundry 315-458 Stan, Verbal approval granted for the new sundry as written. We will withdraw previous sundry 315),8fras requested. y5c Guy Schwartz Senior 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 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 Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From: Stan Porhola [mailto:sporhola@hilcorp.com] Sent: Thursday, August 13, 2015 9:35 AM To: Schwartz, Guy L(DOA) Cc: Tom Fouts Subject: Verbal approval request- K-30 (PTD 196-168) and Cancel sundry 315-458 Guy, Requesting verbal approval for the submitted change approved program sundry for MPU K-30(PTD 196-168) submitted on 8/07/15.The ASR#1 rig is currently rigging up and preparing to test the BOPE later today. This change was requested to run a 2-3/8" workstring inside the 4-1/2" production tubing to deal with an obstruction in the tubing at+/-7,800'.This obstruction is preventing circulation thru the failed ESP, however we are able to bleed fluid back but do not have direct communication with the annulus.The goal would be to remove the obstruction and establish circulation between the 4-1/2" production tubing and the 7" production casing to reduce the likelihood of trapped pressure between the obstruction and the ESP. Please cancel sundry 315-458 since the submitted change approved program sundry covers the original scope plus the new changes. Regards, Stan Porhola Operations Engineer North Slope Asset Team Hilcorp Alaska,LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 1 I q D Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, August 13, 2015 9:42 AM To: 'Stan Porhola' Cc: Tom Fouts Subject: RE:Verbal approval request - K-30 (PTD 196-168) and Cancel sundry 315-458 Stan, Verbal approval granted for the new sundry as written. We will withdraw previous sundry 315-5 as requested. Guy Schwartz 1162$ Senior Petroleum Engineer AOGCC 907-301-4533 cell SCANNED AUG 1 4 2015 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 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Stan Porhola [mailto:sporhola@@hilcorp.com] Sent: Thursday, August 13, 2015 9:35 AM To: Schwartz, Guy L (DOA) Cc: Tom Fouts Subject: Verbal approval request - K-30 (PTD 196-168) and Cancel sundry 315-458 Guy, Requesting verbal approval for the submitted change approved program sundry for MPU K-30(PTD 196-168) submitted on 8/07/15.The ASR#1 rig is currently rigging up and preparing to test the BOPE later today. This change was requested to run a 2-3/8"workstring inside the 4-1/2" production tubing to deal with an obstruction in the tubing at+/-7,800'.This obstruction is preventing circulation thru the failed ESP, however we are able to bleed fluid back but do not have direct communication with the annulus.The goal would be to remove the obstruction and establish circulation between the 4-1/2" production tubing and the 7" production casing to reduce the likelihood of trapped pressure between the obstruction and the ESP. Please cancel sundry 315-458 since the submitted change approved program sundry covers the original scope plus the new changes. Regards, Stan Porhola , Operations Engineer North Slope Asset Team Hilcorp Alaska,LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 RBDMSJc1 AUG 1 4 2015 • of T� ,e,��1 77,'� THE STATE Alaska Oil and Gas =27 ofALAsK.A. Conservation Commission rpt_ 333 West Seventh Avenue IgipwGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 oFALAS/4'P' Fax. 907 276 7542 Y� ` CANy'ED www aogcc.alaska goy Stan Porhola Operations Engineer //� fbg 'j ( r Hilcorp Alaska, LLC NI /V/y 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR K-30 Sundry Number: 315-458 Dear Mr. Porhola: 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, 0167 P9r.k..,,(lc Cathy P. Foerster Chair DATED this 34 day of July, 2015 Encl. 7,4a Ei��1' ED STATE OF ALASKA ; 2 8 pi?6. ALASKA OIL AND GAS CONSERVATION COMMISSION I77S 7/..3 8/!s APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing El • Operations shutdown ❑ Suspend ❑ Perforate El Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redril❑ Perforate New Pool ❑ Repair Well 0 • Re-enter Susp Well ❑ Other. ESP Change-out Q • 2 Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC• Exploratory ❑ Development 0 - 196-168 ' 3.Address: Stratigraphic ❑ Service CI6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22711-00-00 . 7.If perforating. 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.432C Will planned perforations require a spacing exception? Yes ❑ No D / MILNE PT UNIT KR K-30 k 9.Property Designation(Lease Number)• 10.Field/Pool(s): ADL0375132 ' MILNE POINT/KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft). Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,145 . 7,306 • 11,041 . 7,257 • N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' Surface 6,652' 9-5/8" 6,652' 4,908' 6,870psi 4,760psi Intermediate 11,122' 7" 11,122' 7,295' 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 4-1/2" 12.6#/L-80/Hydril 251 10,380' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A / 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic❑ Development❑✓ - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 8/15/2015 Commencing Operations: OIL Q • WINJ ❑ WDSPL El Suspended ❑ 16 Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG Cl Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Stan Porhola Email sporhola(a�hilcorp.com Printed Name Stan Porhola Title Operations Engineer . `�1 Signature v Pell \_ Phone 777-8412 Date 7/28/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3l6 q5car Plug Integrity 0 BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3600 `'5: golf • ! €37 C MAS1 ' = / ! JS'f' 1 Spacing Exception Required? Yes ❑ No [� Subsequent Form Required: /O--Li c� 1 APPROVED BY Approved by: 4 �-� COMMISSIONER THE COMMISSION Date: 7_30_(.5-- 67 �,/�i/�- —z —r j� #'-6 7.1 9//5 RBDMS % AUG - 2 2015 Form 10-403 Revised 5/2015 OrRiGpINA r ,- for A 7 q1 Submit Form and 12 months from the date of approval. Attachments in Duplicate . ii Well Prognosis Well: MPU K-30 Hilcorp Alaska,LL Date:7/28/2015 Well Name: MPU K-30 API Number: 50-029-22711-00 Current Status: SI Oil Well [TTC-ESP] Pad: K-Pad Estimated Start Date: August 15th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-168 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: Current Bottom Hole Pressure: 2,135 psi @ 7,000' TVD (Last BHP measured 5/05/2015) Maximum Expected BHP: 2,135 i @ 7,000' TVD (No new perfs being added) Max. Allowable Surf Pressure: 0 (Based on SBHP taken 5/05/2015 and water cut of 50% (0.385psi/ft)with an added safety factor 2/3s- — 7oo _ of 1,000' ND of oil cap) 5�,,`' Brief Well Summary: L :..,,s TA_ 1ii3s` le 4^-- co 72 5;s, MPU K-30 was drilled in 1996 using Nabors 22E and completed in the Kuparuk B and C sands.The well g w c has had multiple ESP changeouts and sand control screens ran and pulled since 1996, the most recent was an ESP changeout in 2014 using Doyon#16 to run a TT�P. 12/31/43Notes Regarding Wellbore Condition • Casing last tested to 50/3,500 psi or 30 min down to 10,538' on 1/05/2014. • Found no fill during the rig while cleaning out to 10,777'with Doyon#16 in 2014. • Obstruction found in the 4-1/2"tubing @ 7,800'. Unable to pass and no image with a camera. Objective: The purpose of this work/sundry is to pull the existing failed ESP and run a new ESP. L- Se--J.- ' EP Brief Procedure: WO Rig Procedure: 1. MIRU Hilcorp ASR#1 WO Rig. 2. Circulate well with 8.4 ppg lease water down tubing and fill casing. 3. Set BPV. ND Tree. 4. NU 11" BOPE. Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/1,500 psi High (hold each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test VBR rams on 2-7/8" test joint and 4-1/2"test joint. 5. Bleed any pressure off tubing and casing. Pull BPV. 6. MU landing joint and pull over string weight(120k)on tubing hanger to confirm free. 7. POOH. Lay 4-1/2"tubing on the pipe rack(utilize as workstring). 8. MU 6-1/8" bit and junk baskets and RIH to+/- 10,300'. 9. Cleanout fill to+/- 11,000'. 10. Circulate bottoms up x 2 with 8.4 ppg lease water. 11. POOH. Lay down bit and junk baskets. Lay down 4-1/2" tubing. . . ii Well Prognosis Well: MPU K-30 Hilcorp Alaska,LL) Date:7/28/2015 12. PU new 475 series ESP and RIH with new 2-7/8" 8RD EUE L-80 tubing. a. Test 3/8" control line to 2,500 psi. b. RU to use clamps to secure control line to tubing(ensure adequate clamps). 13. Set base of ESP at+/-10,400' (Pump intake around +/- 10,320'). Land tubing hanger. 14. Lay down landing joint. Set BPV. ND BOPE. NU new 2-7/8" 5,000#tree. Pull BPV. 15. Set TWC.Test tubing hanger to 250/5,000 psi.Test tree to 250/5,000 psi. Pull TWC. 16. RD Hilcorp ASR#1 WO Rig. 17. Replace IA x OA pressure gauge if removed (7"x 9-5/8"). 18. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic Milne Point Unit • Well: MPU K-30 SCHEMATIC Last Completed: 1/13/2014 Hilcorp Alaska,LLC PTD: 196-168 CASING DETAIL DF Elev.:57.5'/GL Elev.:28'(Nabors 22E) Size Type Wt/Grade/Conn Drift ID Top Btm DF to 7"Casing Hanger=28.5 20" Conductor 91.1/H-40E/N/A N/A Surface 112' l 4 k 9-5/8" Surface 47/L-80/NSCC. 8.679 Surface 4,544' 20 s # 9-5/8" Surface 47/L-80/Btrc. 8.679 4,544' 4,796' 1. 9-5/8" Surface 47/P-110/Btrc. 8.679 4,796' 6,652' r 7" Production 26/L-80/Btrc 6.276 Surface 11,122' u: • TUBING DETAIL >'' 4-1/2" Tubing 12.6/L-80/Hydril 521 3.958 Surf 10,378' i; I JEWELRY DETAIL No Depth Item a p 9-5/8"t i1 1 10,280' D&D TubingStop 358"Homo P ES Cementer 2 10,282' D&D Packoff Assembly w/Kobe Knockout 3 10,290' Centrilift TTC-ESP Top 4 10,338' TTC Drilled Tubing Crossover 4.5"NSTC Pin x 4.5"521 Hydril Box 5 10,348' Upper Tandem Seal GSB3 DB UT/HL H6 PFS 6 10,362' Motor,168HP,3460 Volt,30 amp 7 10,378' Pumpmate w/6 Fin Centralizer-Bottom @ 10,380' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.C Sands 10,588' 10,658' 7,024' 7,063' 70 11/26/2015 Open Kup.B Sands 10,704' 10,748' 7,088' 7,111' 44 11/25/1996 Open WELL INCLINATION DETAIL KOP@400' Max Hole Angle=57 to 62 deg. f/3,650'to 11,041 Max Hole Angle through perforations=58 deg. OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole 9-5/8" 1,500 sx Trinity Lite Wate,750 sx PF"E",in 12-1/4"Hole k"-• 7" 245 sx Class"G"in 8-1/2"Hole 1 V TREE&WELLHEAD 1 =✓' Tree 5M CIM 4-1/16" ii: 2 11"x 11"SM FMC Gen 5A,w/4-1/16"FMC Tbg. ■■■■ Wellhead „,a Hngr.,L.H.Acme thread 4"CIW H BPV profile , i 'a 3 e 44 GENERAL WELL INFO A. API:50-029-22711-00-00 P` Orig.Completion by Nabors 4-ES -11/27/1996 k \ *i ., ,f5 RWO Screens added/Pig Tail Pull&Land-6/15/1998 t,; s RWO w/Nabors 4-ES-4/5/2002&5/5/2004 ,..i b ESP RWO w/Nabors 4-ES-10/6/2007 : 6 ESP RWO&Replace Screens w/Nabors 3S-8/3/2008 i, ESP RWO&Replace Screens w/Nabors 4-ES-8/15/2010 I7 €" ESP RWO w/Doyon 16-8/5/2011&1/13/2014 t. it 0 ,t i; }KUP C Sands t. }KUP B Sands ,e t 7", kw `:7a TD=11,145'(MD)/TD=7,306'(TVD) PBTD=11,041'(MD)/PBTD=7,257'(11/D) Revised By:TDF 7/23/2015 • Milne Point Unit • II Well: MPU K-30 PROPOSED Last Completed: Proposed Mean)Alaska,LLC PTD: 196-168 CASING DETAIL DF Elev.:57.5'/GL Elev.:28'(Nabors 22E) Size Type Wt/Grade/Conn Drift ID Top Btm DF to 7"Casing Ha :er=28.5 20" Conductor 91.1/H-40E/N/A N/A Surface 112' 9-5/8" Surface 47/L-80/NSCC. 8.679 Surface 4,544' 20 9-5/8" Surface 47/L-80/Btrc. 8.679 4,544' 4,796' , s 1 9-5/8" Surface 47/P-110/Btrc. 8.679 4,796' 6,652' r ; 7" Production 26/L-80/Btrc 6.276 Surface 11,122' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/Hydril 521 3.958 Surf ±10,380' JEWELRY DETAIL avx 915/g . No Depth Item 9-5/8"Homo 1 ±200' GLM ES Cementer 2 ±10,155' GLM 3 ±10,305' 2-7/8"XN Nipple, 2.250 ID 4 ±10,316' Discharge Head-FPHVDIS 5 ±10,317' Dual Tandem Pump Section-71 Flex 10 SXD(2) 6 ±10,346' Gas Separator-GRSFTXAR H6 7 ±10,351' Tandem Seal Section-GSBDBUT SB/SB PFSA:GSBDBIT SB/SB PFSA 8 ±10,365' Motor-MSP1-250 126HP/2,445 V/31A 9 ±10,376' 3/8"Stainless Steel External Capstring 10 ±10,376' Sensor/Centralizer-Bottom@±10,380' PERFORATION DETAIL 2 Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status Kup.C Sands 10,588' 10,658' 7,024' 7,063' 70 11/26/2015 Open Kup.B Sands 10,704' 10,748' 7,088' 7,111' 44 11/25/1996 Open WELL INCLINATION DETAIL 3 KOP @ 400' Max Hole Angle=57 to 62 deg. f/3,650'to 11,041 Max Hole Angle through perforations=58 deg. t3°1 � OPEN HOLE/CEMENT DETAIL I 4 5,0 ':fie 20" 250 sx of Arcticset I in 24"Hole 1 111✓"' 9-5/8" 1,500 sx Trinity Lite Wate,750 sx PF"E",in 12-1/4"Hole 5 7" 245 sx Class"G'in 8-1/2"Hole 6 TREE&WELLHEAD j' Tree 5M CIM 4-1/16" L )7 Wellhead 11"x 11"5M FMC Gen 5A,w/4-1/16"FMC Tbg. Hngr.,L.H.Acme thread 4"CIW H BPV profile \,' 8 GENERAL WELL INFO API:50-029-22711-00-00 / 10 ,,Orig.Completion by Nabors 4-ES -11/27/1996 RWO Screens added/Pig Tail Pull&Land-6/15/1998 RWO w/Nabors 4-ES-4/5/2002&5/5/2004 ESP RWO w/Nabors 4-ES-10/6/2007 ESP RWO&Replace Screens w/Nabors 3S-8/3/2008 ESP RWO&Replace Screens w/Nabors 4-ES-8/15/2010 }KUP C Sands ESP RWO w/Doyon 16-8/5/2011&1/13/2014 !!}KUPBSa1dS TD=11,145'(MD)/TD=7,306'(IVD) PBTD=11,041'(MD)/PBTD=7,257'(TVD) Revised By:STP 7/27/2015 . B Milne Point 2015 ASR Rig 1 rrdk,>.�;�iA.r,.,r.cc Knight Oil Tools BOP 11" BOPE Stripping Head ( 1 3.98' ` HydriI :ii° GK 11"-5000 limmomm ii iTt I III ii 1!l 1.11 IJI III 411 4.54' " a H 2 7/8 -5 variables _ i rk r11" 5000 ii' H N__L '� I f H Blind 6 �' iii ill til iii iii 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves ��- 1!rI I'l!rIIl'i.J E� It al 2.00' I :!Il ;I i c,_ -j4.3) 1t1.1ILlIllil.11l` _d t 41 ,- Manual Manual Manual HCR Updated 7/23/15 Pages NOT Scanned in this Well History File XHVZE This page identifies those items thai were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection: /~'6-'/~? File Number of Well History File PAGES TO DELETE Complete RESCAN n Color items- Pages: GraYScale, halftones, pictures, graphs, charts - Pages: ~</;' ~7_~/~., ~'~ Poor Quality Original' - Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type .OVERSIZED Logs of various kinds Other COMMENTS: Scanned Nalhan Lowell TO RE-SCAN Notes: STATE OF ALASKA RECEIVED ALr,SKA OIL AND GAS CONSERVATION COivuMISSION REPORT OF SUNDRY WELL OPERATIONS FE3 0113 2014 1. Operations Performed: AOGCC ❑Abandon 0 Repair Well 0 Plug Perforations 0 Perforate 0 Re-Enter Suspended Well ❑Alter Casing ®Pull Tubing 0 Stimulate-Frac 0 Waiver ®Other 0 Change Approved Program 0 Operation Shutdown 0 Stimulate-Other 0 Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic 196-168 3. Address: ®Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 • 50.029-22711-00-00 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 375133&375132 .• • MPK-30 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Milne Point Unit/Kuparuk River Oil 11. Present well condition summary: Total depth: measured , 11145' feet Plugs:(measured) None feet true vertical 7306' feet Junk:(measured) None feet Effective depth: measured 11041' feet Packer: (measured) None feet true vertical 7257' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 32'- 112' 32'- 112' Surface 6621' 9-5/8" 31'-6652' 31'-4908' 6870 4760 Intermediate Production 11094' 7" 28'- 11122' 28'-7295' 7240 5410 Liner RBDMS MAY 17 2014 Perforation Depth: Measured Depth: 10588'- 10748' feet True Vertical Depth: 7025'-7111' feet Tubing(size,grade,measured and true vertical depth): 4-1/2", 12.6# L-80 10380' 6906' Packers and SSSV(type,measured and true vertical depth): None None None 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: SCANNED JUL1 6 2014 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 660 0 Subsequent to operation: 0 0 0 20 0 14.Attachments: 0 Copies of Logs and Surveys run 15.Well Class after work: s 0 Exploratory 0 Stratigraphic IS Development 0 Service ®Daily Report of Well Operations 16. Well Status after work: • 0 Oil 0 Gas 0 WDSPL 0 Well Schematic Diagram 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 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: Cody Rymut,564-5452 Email: Cody.Rymut@bp.com N/A Printed Name: Joe LastufkTitle: Drilling Technologist Signature: k1J ._ ! : 564-4091 Date:/_/5//4— Form 10-404 Revised 10/20121/L /Z g /l / Submit Original Only North America-ALASKA-BP Page 1 of 14 Operation Summary Report Common Well Name:MPK-30 AFE No Event Type WORKOVER(WO) , Start Date:12/31/2013 End Date: 1/11/2014 X4-00YKK-E:(2,460,000.00) Project:Milne Point ' Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/19/1996 12:00:OOAM Rig Release: I Rig Contractor:DOYON DRILLING INC. UWI:500292271100 Active datum:19:30 6/28/1998 20:05 @56.30usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/31/2013 12:00 - 14:00 2.00 MOB P PRE SECURE CELLAR AND PREP RIG TO RDMO MPK-05 ' -MOVE CUTTINGS TANK,CREW AND FUEL TRAILERS AWAY FROM RIG ' -FUNCTION TEST MOVING SYSTEM AND ESD 14:00 - 15:00 1.00 MOB P PRE PJSM,FOR RIG MOVE,NOTIFY PAD I OPERATOR OF MOVE -MOVE RIG OFF OF WELL MPK-05,POSITION ON OPPOSITE SIDE OF PAD 15:00 - 16:00 1.00 MOB P PRE STAGE WELLHEAD EQUIPMENT,KILL MANIFOLD AND NEW TREE IN CELLAR AREA 16:00 - 17:30 1.50 MOB P PRE SPOT RIG OVER WELL MPK 30 -SHIM RIG,CLOSE CELLAR DOORS 17:30 - 18:00 0.50 MOB P PRE SPOT AND R/U,FUEL AND CREW TRAILERS, ' CUTTINGS TANK AND HOT SHACK RIG ACCEPT AT 18:00 HRS,12/31/2013 ON MPK-30 18:00 - 19:00 1.00 WHSUR P DECOMP SECURE ALL STAIRS AND LANDINGS -BERM AROUND OUTSIDE OF RIG,POSITON PIPE SHED RAMPS,PREP RIG FLOOR -WELL SUPPORT R/U HARD LINE TO FLOWW BACK TANKS 19:00 - 21:00 2.00 WHSUR P DECOMP PJSM,R/U WELL KILL MANIFOLD CIRC LINES TO TNFLOKTANK -R/U REE ANDAFUDNCTIONW TESTBACTSSV'S -OA=0 PSI,IA=750 PSI 2100 - 23:00 2.00 WHSUR P DECOMP PJSM,STEAM AND CLEAR HARDLINE TO 1 I FLOW BACK TANKS -LOAD PITS WITH 8.5 PPG SEA WATER -LOAD PIPE SHED WITH 4"DRILL PIPE 23:00 - 00:00 1.00 WHSUR P DECOMP PRESSURE TEST ALL CIRC LINES IN CELLAR AND OUT TO FLOW BACK TANKS -250,3500 PSI,5 MIN,CHARTED -BLOW DOWN HARD LINE TO TANKS 1/1/2014 00:00 - 00:30 0.50 WHSUR P DECOMP PJSM,PERFORM SPCC AND EQUIPMENT CHECKS 00:30 - 02:30 2.00 WHSUR P DECOMP R/U WELL SUPPORT LUBRICATOR -TEST,250/3500 PSI,5 MIN,CHART -PULL BPV -IA=PSI.TUBING=PSI,OA=PSI -R/D LUGRICATOR 02.30 - 03:00 0.50 KILLW P DECOMP HOLD RIG EVACUATION DRILL AND AAR Printed 1/21/2014 9:15:31AM • North America-ALASKA-BP Page 2 of 14 Operation Summary Report Common Well Name:MPK-30 AFE No Event Type:WORKOVER(WO) Start Date:12/31/2013 End Date:1/11/2014 X4-00YKK-E:(2,460,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/19/1996 12:00:00AM Rig Release: Rig Contractor DOYON DRILLING INC. UWI:500292271100 Active datum:19:_30 6/28/1998 20:05©56.30usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 06:00 3.00 KILLW P DECOMP PJSM,WELL KILL WITH 8.5 PPG SEAWATER. -REVIEW DDI WELL KILL S.O.P. -DISCUSSED INDIVIDUAL ROLLS AND RESPONSIBILITIES. -WSL AND TOOL PUSHER PRESENT FOR OPERATION. SITP=700 PSI, SICP=925 PSI,OA=10 PSI. KWF=8.5 PPG HEATED 120 DEG.SEAWATER. -WSL/TOOL PUSHER VERIFY VALVE ALIGNMENT -BLEED GAS FROM THE IA.FROM 925 PSI TO 150 PSI IN 9 MINUTES.SITP=500 PSI. -OBSERVED CRUDE/GAS FLUID RETURNS PUMP 65 BBLS KWF DOWN THE TUBING UP THE IA THROUGH THE CHOKE OUT TO THE FLOW BACK TANK. -ICP AT 3 BPM=550 PSI. -FCP AT 3 BPM=600 PSI. FULL FLUID RETURNS TO SURFACE AFTER 10 BBLS PUMPED BULL HEAD ON THE FLY:25 BBLS KWF,3 •BPM=700 PSI PUMP 450 BBLS KWF DOWN THE TUBING UP THE IA THROUGH THE CHOKE OUT TO THE FLOW BACK TANK. ICP:3 BPM=650 PSI i 06:00 - 07:00 1 1.00 KILLW P DECOMP CONTINUE PUMPING KWF DOWN TUBING, TAKING RETURNS FROM IA. AFTER 1.5 X ANNULUS VOLUME,SHUT DOWN PUMP AND MONITOR WELL. AFTER 15 MIN WELL IS ON SLIGHT VAC ON BOTH TUBING AND IA,VERIFIED BY WSL, TOOLPUSHER AND DRILLER. 07:00 - 08:00 1.00 KILLW P DECOMP BREAK DOWN CIRC SKID AND RIG UP SECONDARY KILL LINE TO IA. VAC OUT FLUID FROM BOTH FLOWBACK TANKS. 08:00 - 09:00 1.00 WHSUR P DECOMP START FILLING WELL THROUGH IA LINE. WELL IS TAKING 20 BBLS/HR WITH NO RETURNS. PJSM THEN RIG UP WELLS SUPPORT LUBRICATOR,PRESSURE TEST TO 250/3500 PSI,GOOD. 09:00 - 10:30 1.50 WHSUR P DECOMP SET TWO WAY CHECK. RIG DOWN TOOLS AND LUBRICATOR. PERFORM ROLLING TEST FROM BELOW TO 500 SPI,GOOD. TEST TWO WAY CHECK FROM ABOVE TO 250 /3500 PSI,GOOD. 10:30 - 11:30 1.00 WHSUR P DECOMP PJSM THEN REMOVE TREE AND ADAPTER FLANGE. TEST HANGER THREADS,GOOD.(3"LH ACME). INSTALL SPACER SPOOL. INSTALL BOPS. 11:30 - 12:00 0.50 WHSUR P DECOMP PJSM.N/U 7"X 13 5/8"&13 5/8"X 13 5/8" SPACER SPOOLS. - LOSSES TO FORMATION LAST(12)HRS= 349 BBLS 8.5 SEAWATER. Printed 1/21/2014 9:15:31AM • North America-ALASKA-BP Page 3 of 14 Operation Summary Report Common Well Name:MPK-30 AFE No Event Type:WORKOVER(WO) Start Date:12/31/2013 End Date:1/11/2014 X4-OOYKK-E:(2,460,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/19/1996 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292271100 Active datum:19:30 6/28/1998 20:05 @56.30usft(above Mean Sea Level) Date From-To Hrs Task Code NPT j NPT Depth Phase Description of Operations (hr) I (usft) 12:00 - 16:30 4.50 BOPSUR P DECOMP PJSM.N/U 13 5/8"X 5M BOPE. -CONTINUE LOADING 4"DP IN SHED. -SERVICE MUD CROSS,TEST SIERRA SYSTEM.OK. • -R/U AND TEST ALL KOOMEY LINES -R/U ALL FLOOR VALVES,TEST JOINTS AND BOP TEST EQUIPMENT 18:30 - 21:30 5.00 BOPSUR P DECOMP PJSM,TEST FOUR PREVENTER BOPE AND RELATED EQUIPMENT -TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES -TEST ANNULAR WITH 2 7/8"AND 4 1/2"TEST JOINTS TO 250 PSI LOW,3500 PSI HIGH,5 MINUTES EACH,CHARTED -TEST 2 7/8"X 5"VARIABLE RAMS WITH 2 7/8" AND 4 1/2"TEST JOINTS,250 PSI,3500 PSI,5 MIN,CHARTED -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,3500 PSI,5 MIN,CHARTED -TEST WITH FRESH WATER -PERFORM ACCUMULATOR DRAW DOWN TEST. -NO FAILURES. I-BOB NOBLE OF AOGCC WAIVED STATES RIGHT OF WITNESS BOP TEST 21:30 - 22:00 0.50 BOPSUR P DECOMP BLOW DOWN CHOKE,DRAIN STACK AND R/D ALL TEST EQUIPMENT -M/U LANDING JOINT AND XO 22:00 - 22:30 0.50 WHSUR P DECOMP I R/U OFF-SET LUBRICATOR -R/U WELL SUPPORT LUBRICATOR 22:30 - 23:30 1.00 WHSUR P DECOMP M/U WS LUBRICATOR TO HANGER -TEST,250/3500 PSI,5 MIN,CHART -PULL TWC,WELL IS ON A LOSSES 23:30 - 00:00 0.50 WHSUR P DECOMP P/U LANDING JT AND INSTALL XO -M/U TO HANGER AND TOP DRIVE -OA=20 PSI -24 HOUR FLUID LOSS=593 BBLS -MAINTAIN CONSTANT HOLE FEED,20 BPH, 8.5 PPG SEA WATER KWF 1/2/2014 00:00 - 00:30 0.50 WHSUR P DECOMP PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -SERVICE RIG FLOOR AND PIPE SKATE 00:30 - 01:00 0.50 WHSUR P DECOMP PJSM,FMC REP BACK OUT LOCK DOWN • SCREWS -PULL HANGER TO RIG FLOOR -PUWT=115K,SOWT=75K -ALL UP AND DOWN WTS INCLUDE TOP DRIVE WT,(40K). j-CUT ESP CABLE,PLACE SLICK PIPE ACROSS STACK CLOSE ANNULAR,LINE UP ON GAS BUSTER Printed 1/21/2014 9:15:31 AM • North America-ALASKA-BP Page 4 of 14 Operation Summary Report Common Well Name:MPK-30 AFE No Event Type:WORKOVER(WO) Start Date:12/31/2013 End Date:1/11/2014 X400YKK E:(2,460,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/19/1996 12:00:00AM Rig Release: Rig Contractor.DOYON DRILLING INC. UWI:500292271100 Active datum:19:30 6/28/1998 20:05©56.30usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:00 - 03:00 2.00 PULL P DECOMP CBU THRU GAS BUSTER 1X -5 BPM=2090 PSI,31 BBLS TO FILL -111 BBLS LOSS ON CIRCULATION -MONITOR WELL,ESTABLISH LOSS RATE= 51 BPH -MAINTAIN CONSTANT HOLE FEED AT 20 BPH,8.5 PPG SEAWATER KWF R/U ESP SHEAVE AND TRUNK 03:00 - 03:30 0.50 PULL P DECOMP BLOW DOWN TOP DRIVE AND CHOKE MANIFOLD -PREP TO L/D 2 7/8"TUBING 03:30 - 06:00 2.50 PULL P DECOMP PJSM,POOH AND UD,2 7/8"6.5#EUE 8RD TUBING AND ESP COMPLETION -POOH FROM 10411'TO 10101',STRING ESP CABLE OVER SHEAVE TO SPOOLING UNIT POOH FROM 10101'TO 9550' -MAINTAIN CONSTANT HOLE FEED AT 20 BPH,8.5 PPG SEAWATER KWF,NO RETURNS 06:00 - 12:00 6.00 PULL P DECOMP CONTINUE TO POOH W/2 7/8"TUBING, MAINTAINING CONSTANT HOLE FILL @ 20- 25 BPH. -POOH F/9550'-5474'.KICK DRILL WHILE POOH. -LOSSES TO FORMATION LAST(12)HRS= 388 BBLS 8.5 PPG SEAWATER. 0/A PRESSURE=30 PSI. 12:00 - 12:30 0.50 PULL P DECOMP SERVICE RIG,UNLOAD PIPE SHED. 12:30 - 14:30 2.00 PULL P DECOMP PJSM.CONTINUE TO POOH W/6.5#2 7/8" EUE 8 RND TUBING,LAY DOWN SAME. SPOOLING ESP CABLE.CONTINUOUS HOLE FILL,20-25 BPH. F/5474'T/4170' 14:30 - 16:00 1.50 PULL P DECOMP PJSM.CHANGE OUT ESP REELS IN SPOOLING UNIT. 16:00 - 21:30 5.50 PULL P DECOMP PJSM.CONTINUE TO POOH W/2 7/8"TUBING AND ESP CABLE. -F/4170'T/ESP MOTOR 21:30 - 00:00 2.50 PULL P DECOMP PJSM,L/D PUMP AND MOTOR ASSY -INITIAL DIAGNOSIS=ESP CABLE FAILURE, BOTH PUMPS LOCKED UP,SEPARATOR HAD TWISTED SHAFT,MOTOR WAS OPERABLE ALL CLAMPS RECOVERED i I -OA=40 PSI -24 HOUR FLUID LOSS=637 BBLS -MAINTAIN CONSTANT HOLE FEED,20 BPH, 8.5 PPG SEA WATER KWF 1/3/2014 00:00 - 01:00 1.00 PULL P DECOMP PJSM,CLEAN/CLEAR RIG FLOOR -R/D ESP SHEAVE AND TRUCK -L/D CENTRILIFT EQUIPMENT 01:00 - 01:30 0.50 FISH P DECOMP MOBILIZE BHA TO RIG FLOOR -C/O HANDLING EQUIPMENT -R/D POWER TONGS Printed 1/21/2014 9:15:31 AM North America-ALASKA-BP Page 5 of 14 Operation Summary Report Common Well Name:MPK-30 AFE No Event Type:WORKOVER(WO) Start Date:12/31/2013 End Date: 1/11/2014 X4-00YKK E:(2,460,000.00) Project:Milne Point Site:M Pt K Pad JI, Rig Name/No.:DOYON 16 Spud Date/Time:10/19/1996 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292271100 Active datum:19:30 6/28/1998 20:05 @56.30usft(above Mean Sea Level) Date From-To H rs Task Code NPT NPT Depth Phase Description of Operations (hr) r (usft) 01:30 - 02:30 1.00 FISH i P DECOMP PJSM,M/U BHA#1 TO FISH PACKER AND SCREENS -M/U HES RETRIEVING TOOL,BAKER BUMPER SUB,PUMP OUT SUB,(6)4 3/4" COLLARS 02:30 - 05:00 2.50 FISH P DECOMP RIH WITH BHA AND 4"DRILL PIPE 1X1 -F/212'T/1764' 05:00 - 06:00 1.00 FISH P DECOMP SERVICE AND INSPECT RIG FLOOR EQUIPMENT AND PIPE SKATE -CHANGE OUT RE-COIL SPRING ON PIPE SKATE 06:00 - 12:00 6.00 FISH P DECOMP CONT.RIH WITH BHA AND 4"DRILL PIPE 1X1 -F/1764"T/2236' -MAINTAIN CONSTANT HOLE FEED AT 20 BPH,8.5 PPG SEAWATER KWF -LOSSES TO FORMATION LAST(12)HOURS= 261 BBLS 8.5 PPG SEAWATER. 12:00 - 15:30 3.50 FISH P DECOMP PJSM.CONTINUE TO RIH W/FISHING BHA, PICKING UP DP FROM PIPE SHED,1 X 1. -MAINTAINING CONTINUOUS HOLE FILL®20 -25 BPH. 15:30 - 17:00 1.50 FISH P DECOMP PJSM.SLIPAND CUT (81)OF DRILLING LINE. -COMPLETE WORK ORDER ON DRAW WORKS. 17:00 - 20:00 3.00 FISH P DECOMP CONT RIH WITH BHA AND 4"DRILL PIPE 1 X 1 FROM 8143'TO 10449' -PUWT=199KSOWT=110K 20:00 - 21:00 1.00 FISH P DECOMP POOH WITH 10 STANDS IN DERRICK TO 9501' 21:00 - 22:00 1.00 FISH P DECOMP CONT RIH WITH SINGLES 4"DRILLPIPE FROM SHED TO 10500' -PU WT=200K SO WT=114K 22:00 - 23:00 1.00 FISH P DECOMP PJSM FOR LATCHING UP AND PULLING PACKER -PUWT=200K,SOWT=114K,SPR'S-2 BPM =100 PSI,4 BPM=350 PSI -LATCH UP ON VERSATRIEVE PACKER WITH 5K DOWN,5K OVER UP 10K DOWN -OBSERVE INDICATION OF SHIFTING SLEEVE SHEAR 23:00 - 00:00 1.00 FISH P DECOMP WORK STRING WT BETWEEN 135K AND 350K WITHOUT MOVEMENT -CALL TOWN TO DISCUSS OPTIONS -24 HOUR FLUID LOSS=595 BBLS 1-MAINTAIN CONSTANT HOLE FEED,20 BPH, 18.5 PPG SEA WATER KWF 1/4/2014 00:00 - 01:00 1.00 FISH P DECOMP CALL TOWN ENGINEER TO DISCUSS OPTIONS -PACKER NOT RELEASED 01:00 - 02:00 1.00 FISH P DECOMP ATTEMPT TO RELEASE PULLING TOOL FROM PACKER PER HES REPS -UNABLE TO RELEASE,WORKED AT MAX PARAMETERS=PACKER RELEASED 02.00 - 02:30 0.50 FISH P DECOMP CLOSE ANNULAR AND BULLHEAD 25 BBLS 8.5 PPG KWF TO FORMATION -3 BPM=250 PSI 02:30 - 03:00 0.50 FISH P DECOMP ALLOW PACKER ELEMENT TO RELAX,30 MINUTES Printed 1/21/2014 9:15:31AM North America-ALASKA-BP Page 6 of 14 Operation Summary Report Common Well Name:MPK-30 AFE No Event Type:WORKOVER(WO) Start Date:12/31/2013 End Date:1/11/2014 X4-00YKK-E:(2,460,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/19/1996 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292271100 Active datum:19:30 6/28/1998 20:05 @56.30usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 04:30 1.50 FISH P DECOMP CBU 1X THRU GAS BUSTER 4 BPM=580 PSI,MINIMAL RETURNS 04:30 - 05:30 1.00 FISH P DECOMP OPEN ANNULAR AND MONITOR WELL=WELL IS ON LOSSES BLOW DOWN CHOKE AND DRAIN GAS BUSTER 05:30 06:30 1.00 FISH P DECOMP POOH FROM 10500'MD WITH PACKER. -POOH(5)STANDS VERY SLOWLY,HOLE FILL 2.4 BBLS. -OCCASIONAL OVERPULL TO 250K AS PACKER RUBBERS ENCOUNTER CASING CONNECTIONS. -MONITOR WELL,FLUID IN BACKSIDE SLOWLY FALLING WITH PIPE STATIC. 06:30 - 07:00 0.50 FISH P DECOMP PJSM.LINE UP TO CIRCULATE WELL. -CIRCULATE DOWN DP @ 4 BPM/490 PSI. -PUMPED 100 BBLS,15 BBLS RETURNED WHILE CIRCULATING. -MONITOR WELL, GAVE SOME FLUID BACK, (2-3 BBLS). -FLUID SLOWLY DROPPING IN DP AND ON BACK SIDE WITH PIPE STATIC. 07:00 - 09:30 2.50 FISH P DECOMP BLOW DOWN TOP DRIVE AND CONTINUE TO POOH W/HALLIBURTON PACKER&SCREEN ASSEMBLY. -POOH VERY SLOWLY AS FLUID NOT DROPPING WHEN PULLING PIPE. -OVERPULLING FROM PACKER RUBBERS BECOMING LESS AND LESS. -POOH A TOTAL OF(25)STANDS TO 9596'. MAKE UP TOP DRIVE. 09:30 - 10:00 0.50 FISH P DECOMP PJSM.CIRCULATE DOWN DRILL PIPE,4 BPM/ 475 PSI. -CIRCULATE 100 BBLS,(8)BBLS RETURNED DURING CIRCULATION. -MONITOR WELL,APPROXIMATELY(2)BBLS BACK AND FLUID BEGAN DROPPING ON BACK SIDE. -BLOW DOWN TOP DRIVE. 10:00 - 12:00 2.00 FISH P DECOMP CONTINUE TO POOH W/PACKER AND SCREEN ASSEMBLY. -POOH F/8175'-5994'.CONTINUOUS HOLE FILL DURING THIS TRIP. -LOSSES TO FORMATION LAST(12)HRS= 603 BBLS OF 8.5 PPG SEAWATER. 0/A=60 PSI. 12:00 - 12:30 0.50 FISH P DECOMP SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT. -PULL STRIPPING RUBBER,SHUT OFF HOLE FILL AND OBSERVE FLUID SLOWLY DROPPING ON BACK SIDE. 12:30 - 16:30 4.00 FISH P DECOMP PJSM.CONTINUE TO POOH F/5994'W/ PACKER AND SCREEN ASSEMBLY. -CONTINUOUS HOLE FILL,LOSS RATE 41 BPH. 16:30 - 17:00 0.50 FISH P DECOMP CHECK TORQUE ON DRILL COLLARS AND STAND BACK -MONITOR WELL VERIFYING STILL LOSING 20 BPH Printed 1/21/2014 9:15:31AM North America-ALASKA-BP Page 7 of 14 Operation Summary Report Common Well Name:MPK-30 AFE No Event Type:WORKOVER(WO) Start Date:12/31/2013 End Date:1/11/2014 'X4-00YKK E:(2,460,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/19/1986 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292271100 Active datum:19:30 6/28/1998 20:05 @56.30usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 20:00 3.00 FISH P DECOMP UD VERSATRIEVE PACKER,PACKER AND SLIPS ARE IN TACT -PUNCH AND UD 6-SCREENS 20:00 - 21:00 1.00 FISH P DECOMP CLEAR RIG FLOOR -SERVICE BREAK PACKER HANDLING PUP 21:00 - 22:00 1.00 FISH P DECOMP CLEAN RIG FLOOR AND ALL HANDLING EQUIPMENT 22:00 - 22:30 0.50 FISH P DECOMP MOBILIZE BAKER BHA#2 TO RIG FLOOR 22:30 - 00:00 1.50 FISH P DECOMP PJSM,M/U BAKER CLEAN OUT ASSY -M/U BHA#2=6"JUNK MILL,(2)SMOOTH OD STRING MILLS,(3)BOOT BASKETS,BUMPER SUB,OIL JARS,(6)COLLARS -OA=60 PSI -24 HOUR FLUID LOSS=910 BBLS MAINTAIN CONSTANT HOLE FEED,20 BPH, 18.5 PPG SEA WATER KWF 1/5/2014 00:00 - 01:00 1.00 FISH P DECOMP PJSM,CONTINUE M/U BHA#2 CLEAN OUT ASSY 01:00 - 06:00 5.00 FISH P DECOMP RIH WITH BHA#2 -F/238'(BHA)to 10,777'. NO INDICATION OF FILL. 06:00 - 06:30 0.50 FISH P DECOMP PJSM.POOH TO 10,570'. -MAKE UP TO TOP DRIVE. 06:30 - 07:30 1.00 FISH P DECOMP PJSM.CIRCULATE 130 BBLS @ 4 BPM/420 PSI. -LOSS RATE=84 BPH.CONSULT ENGINEER AND OPT TO FOREGO CIRCULATING. -MONITOR WELL,WELL STABLE AND TAKING FLUID. 07:30 - 12:00 4.50 FISH P DECOMP PJSM.BLOW DOWN TOP DRIVE. -POOH F/10,570'-2040'. LOSSES TO FORMATION LAST(12)HRS= 317 BBLS 8.5 PPG SEAWATER. -OUTER ANNULUS PRESSURE BLED TO 0 PSI. 12:00 - 12:30 0.50 FISH P DECOMP SERVICE RIG,AND RIG FLOOR EQUIPMENT. -HELD WEEKLY SAFETY MEETING PRIOR TO COMING ON TOUR. 12:30 - 13:30 1.00 FISH P DECOMP PJSM.CONTINUE TO POOH W/CLEANOUT ASSEMBLY. -MONITOR WELL,(10)MINUTES,WELL STABLE. -CONTINUOUS HOLE FILL 20-25 BPH. 13:30 - 15:30 2.00 FISH P DECOMP PJSM.LAY DOWN 4 3/4"DRILL COLLARS. -BREAK OUT AND LAY DOWN BHA. -NO DEBRIS IN JUNK SUBS. -CLEAR AND CLEAN RIG FLOOR. 15:30 - 21:30 6.00 CASING P DECOMP PJSM.PICKUP AND MAKE UP HES RETRIEVABLE BRIDGE PLUG. -RIH ON 4"DRILL PIPE TO 10538'MD -PUWT=195K,SOWT=110K -CONTINUOUS HOLE FILL 20-25 BPH. 21:30 - 22:00 0.50 CASING P DECOMP PJSM FOR R/U AND CASING TEST -SETRBPIN 7"CASING AT 10538'MDCOE -RELEASE FROM RBPAND POOH 1 STAND Printed 1/21/2014 9:15:31AM North America-ALASKA-BP Page 8 of 14 Operation Summary Report Common Well Name:MPK-30 AFE No Event Type:WORKOVER(WO) 1 Start Date:12/31/2013 End Date:1/11/2014 X4-00YKK-E:(2,460,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/19/1996 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292271100 Active datum:19:30 6/28/1998 20:05©56.30usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 00:00 2.00 CASING P T DECOMP RN TEST EQUIPMENT AND CIRC LINES -FILL HOLE AND FLUID PACK LINES -MIT-IA 7"26#L-80 CASING TO 10538'MD -250 PSI 5 MIN,3500 PSI 30 MIN,CHARTED, GOOD TEST -NOTIFY WTLAND RECEIVE AUTHORIZATION TO PROCEED -BLEED OFF,BLOW DOWN AND R/D ALL CIRC LINES,OPEN RAMS -OA=0 PSI -24 HOUR FLUID LOSS=563 BBLS 1/6/2014 00:00 - 00:30 0.50 CASING P DECOMP BLOW DOWN CHOKE AND ALL TEST LINES _ -R/D TEST EQUIPMENT 00:30 - 05:00 4.50 CASING P DECOMP POOH WITH DP AND STAND BACK IN DERRICK -FROM 10475'TO 1745' 05:00 - 06:30 1.50 CASING P DECOMP PJSM,M/U AND SET RTTS -M/U RTTS AND RIH TO 97',SET PACKER AND POOH W/DRILL PIPE. -R/U TEST EQUIPMENT,CLOSE BLIND RAMS. -PRESSURE TEST TOP OF RTTS©250/3500 PSI/5 MIN/CHARTED,GOOD TEST. -BLEED OFF ALL PRESSURE,OPEN BLIND 1I RAMS -- ---------- -RIG DOWN TEST EQUIPMENT. 06:30 - 08:30 2.00 BOPSUR P DECOMP PJSM.NIPPLE DOWN BOPE. -DRAIN STACK,REMOVE TURN BUCKLES, PULL RISER. -UNBOLT STACK AND RACK BACK -0/A IS DEAD AND OPEN TO THE SLOP TANK 08:30 - 12:00 3.50 WHSUR P ; DECOMP PJSM.REMOVE ADAPTER SPOOLS. -NIPPLE DOWN TUBING SPOOL,PULL PACK OFF. -INSTALL NEW PACK OFF,RUN IN LOCK DOWN SCREWS. -LOSSES TO WELL LAST 12 HOURS=0 BBLS, O/A=0 PSI. i 12:00 - 15:30 3.50 WHSUR P DECOMP PJSM.NIPPLE UP TUBING SPOOL. -TEST PACK OFF TO 250 PSI/5 MIN&3500 PSI,30 MINUTES,CHARTED,GOOD TEST. -HARD LINE CREW RIGGING DOWN HARD LINE TO FLOW BACK TANK TO BE ABLE TO ACCESS CELLAR. 115:30 - 17:30 2.00 WHSUR P DECOMP ,PJSM.NIPLLE UP TC ATTACHEMENT. I -CLEAR CELLAR OF OLD WELL HEAD EQUIPMENT. 117:30 - 21:00 3.50 BOPSUR P DECOMP N/U BOPE,KOOMEY LINES,TURNBUCKLES, RISER,ETC -M/U OUTER IA VALVE ON NEW WELL HEAD -R/U SECONDARY KILL LINE TO IA -INSTALL 7"ID WEAR RING 21:00 - 21:30 0.50 BOPSUR P DECOMP FILL BOP,R/U TEST EQUIPMENT -CLOSE BLINDS RAMS AND TEST ALL FLANGE BREAKS -250/3500 PSI,5 MIN,CHARTED 21:30 - 22:00 ; 0.50 BOPSUR P DECOMP R/D AND BLOW DOWN ALL TEST EQUIPMENT AND LINES Printed 1/21/2014 9:15:31AM North America-ALASKA-BP Page 9 of 14 Operation Summary Report Common Well Name:MPK-30 AFE No Event Type:WORKOVER(WO) Start Date:12/31/2013 End Date:1/11/2014 X4-00YKK-E:(2,460,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/19/1996 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292271100 Active datum:19:30 6/28/1998 2005 @56.30usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 22:30 0.50 CASING P DECOMP RIH WITH RETRIEVING TOOL AND ENGAGE RTTS -ENSURE NO PRESSURE IN PIPE -CLOSE ANNULAR AND UN-SEAT RTTS -OPEN ANNULAR,PULL RTTS TO RIG FLOOR AND L/D 22:30 - 00:00 1.50 CASING P DECOMP RIH WITH RBP RETRIEVING TOOL,F/1754'TO 4471' -OA=0 PSI -24 HOUR FLUID LOSS=0 BBLS 1/7/2014 00:00 - 03:00 3.00 CASING P DECOMP PJSM,SPCC AND EQUIPMENT CHECKS RIH F/4471'T/10480' 03:00 - 04:00 1.00 CASING P DECOMP PJSM,SLIP AND CUT DRILLING LINE 04:00 - 06:00 2.00 CASING P DECOMP RIH TO 10538'TO RBP -ENGAGE RBP AND RELEASE -CLOSE ANNULAR AND BULLHEAD 20 BBLS TO FORMATION -FLOW CHECK 10 MINUTES 06:00 - 12:00 6.00 CASING P DECOMP PJSM.POOH AND LDDP. CONTINUOS HOLE FILL @ 20-25 BPH OVER DISPLACEMENT. -LOSSES TO FORMATION LAST(12)HRS= 176 BBLS 8.5 PPG SEAWATER. • -0/A=0 PSI. 12:00 - 18:00 6.00 CASING P DECOMP CREW CHANGE,PJSM. -CONTINUE TO POOH&LDDP. -LAY DOWN HES RBP CONTINUOUS HOLE FILL @ 20-25 BPH. 18:00 - 20:30 2.50 CASING P DECOMP PJSM HANG SHEAVE,SPOT SPOOLING UNIT -SPOT SPOOLING UNIT -HANG ESP SHEAVE -PULL WEAR RING -CLEAN AND CLEAR RIG FLOOR 20:30 - 23:00 2.50 CASING P DECOMP PJSM WITH CENTRILIFT FOR PICKING UP MOTOR ASSEMBLY,DUMMY HANGER. -PICK UP MOTOR ASSEMBLY -CENTRILIFT SERVICE MOTOR ASSEMBLY -MAKE UP SEAL ASSEMBLY. -BOLT ON TTC DRILLED TUBING CROSSOVER TO SEAL ASSEMBLY. 23:00 - 00:00 1.00 CASING P DECOMP LAND DUMMY HANGER -MAKE UP&TORQUE HYDRIL PUP AND HYDRIL JOINT. -MAKE UP 11"FMC DUMMY TUBING HANGER W/TC-II LANDING THREADS -FMC SET TWO WAY CHECK IN HANGER -LAND HANGER PER FMC REP. -RUN IN LOCK DOWN SCREWS PER FMC REP. -LAY DOWN LANDING JOINT. CONTINUAL HOLE FILL =25 BPH WITH KWF. NO RETURNS. 24 HOUR FLUID LOSS=504 BBLS 8.5 PPG, CUMULATIVE FLUID LOSS=3802 BBLS. Printed 1/21/2014 9:15:31AM North America-ALASKA-BP Page 10 of 14 Operation Summary Report Common Well Name:MPK-30 AFE No Event Type:WORKOVER(WO) Start Date:12/31/2013 End Date:1/11/2014 X4-00YKK-E:(2,460,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/19/1996 12:00:00AM Rig Release: Rig Contractor.DOYON DRILLING INC. UWI:500292271100 Active datum:19:30 6/28/1998 20:05 @56.30usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 1/8/2014 00:00 - 01:30 1.50 WHSUR P DECOMP SPCC CHECKS AND PRE TOUR MEETING PRESSURE TEST TWC -LINE UP TO PRESSURE TEST -PERFROM ROLLING TEST FROM BELOW TWC TO 500 PSI FOR 5 MINUTES. -TEST TWC FROM ABOVE TO 250 PSI LOW, 3500 PSI HIGH FOR 5 MINUTES. 01:30 - 08:00 4.50 BOPSUR P DECOMP PJSM,PULL ESP CABLE OVER WINDWALL. -STRING KEVLAR ROPE TO SPOOLING UNIT. -PULL FLAT ESP CABLE TO RIG FLOOR USING SNAKE ATTACHMENT. CENTRILIFT PERFORM ESP SLICE AT RIG FLOOR DURING BOP TEST PJSM,TEST FOUR PREVENTER 13-5/8"BOP AND RELATED EQUIPMENT. -TEST BOP ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES. -TEST ANNULAR WITH 4"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST 2-7/8"X 5"VARIABLE RAMS WITH 4" AND 4-1/2"TEST JOINT TO 250 PSI,3500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,3500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST WITH FRESH WATER. JEFF JONES OF AOGCC WAIVE STATES RIGHT OF WITNESS TO BOP TEST. 06:00 - 06:30 0.50 BOPSUR P DECOMP PJSM.BREAK DOWN LINES,RIG DOWN TEST EQUIPMENT. DRAIN BOP STACK 06:30 - 09:00 2.50 WHSUR P DECOMP PJSM.STEAM DUTCH RISER&INSTALL. !-RIG UP DSM LUBRICATOR,PRESSURE TEST @ 250/3500 PSI,5 MIN EACH. -PULL TWO WAY CHECK VALVE. -RIG DOWN LUBRICATOR AND DUTCH RISER, BREAK DOWN LINES. 09:00 - 12:00 3.00 RUNCOM P RUNCMP PJSM.CONTINUE TO WORK ON MOTOR LEAD CONNECTION. -BRING ESP TOOLS TO RIG FLOOR. FLUID LOSSES TO FORMATION LAST(12) HRS=283 BBLS 8.5 PPG SEAWATER. -0/A PRESSURE=0 PSI. 12:00 - 12:30 0.50 RUNCOM P RUNCMP PJSM/DISCUSSION ON THRU TUBING COMPLETION. -PICK UP(2)JTS 2 7/8"PAC PIPE AND MAKE UP CROSSOVERS AND BUMPER SUB. Printed 1/21/2014 9:15 31AM North America-ALASKA-BP Page 11 of 14 Operation Summary Report Common Well Name:MPK-30 AFE No Event Type:WORKOVER(WO) Start Date:12/31/2013 End Date:1/11/2014 X4-00YKK-E:(2,460,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/19/1996 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292271100 Active datum:19:30 6/28/1998 20:05 @56.30usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 113 0 5.50 RUNCOM P RUNCMP PJSM.MAKE UP 3 1/2"G SPEAR.PICK UP PUMP ASSEMBLY#1. • -RIH,LAND AND PUMP OFF TO RELEASE AND CHANGE OUT G SPEAR TO 4". -RIH W/PUMP ASSEMBLY#2 AND PUMP OFF TO RELEASE,POOH. -PICK UP PACK OFF ASSEMBLY AND LOCATE AND PUMP OFF TO RELEASE. -PICK UP PACK OFF TEST TOOL AND LOCATE AND PUMP OFF TO RELEASE. -PUMPING 2 BPM @ 1100 PSI PRIOR TO PICKING UP TO RELEASE ON ALL RUNS. -FLUID PACK AND CLOSE THE BLIND RAMS. -PRESSURE TEST THE PACK OFF TO 250/ 1000 PSI/10 MINUTES/CHARTED.GOOD TEST. -PULL THE PACK OFF TEST TOOL W/G !SPEAR. -RIH ENGAGE TUBING STOP ON TOP OF PACKOFF. -PICK UP 1000 LBS AND SHEAR THE BRASS PIN. 18:00 19:30 1.50 RUNCOM P RUNCMP LAY DOWN RUNNING TOOLS -POOH AND UD RUNNING ASSEMBLY -LAY DOWN 2-7/8"DP. -CLEAN&CLEAR RIG FLOOR -RIG UP TORQUE TURN -MOBILIZE CABLE CLAMPS TO RIG FLOOR 19:30 - 21:00 1.50 RUNCOM P RUNCMP PJSM,PULL DUMMY HANGER -CONFIRM WELL IS ON A VACUUM -FMC REP BACK OUT LOCK DOWN SCREWS -MAKE UP LANDING JOINT AND SAFETY VALVE -PULL HANGER TO RIG FLOOR -LAY DOWN HANGER&LANDING JOINT 21:00 - 22:00 1.00 RUNCOM P I RUNCMP CENTRILIFT PERFORM TIE IN ON ESP CABLE TO MOTOR. -CHECK CONDUCTIVITY OF CABLE -PERFORM TESTS ON MOTOR. -INSTALL 3 PROTECTORS,2 PLAT GUARDS,1 5 FT CLAMP ON BHA. 22:00 - 00:00 2.00 RUNCOM P RUNCMP PJSM,RIH WITH 4.5 12.6#HYDRIL 521 TUBING. -TUBING TORQUE=4700 FT/LBS. •-USE JET LUBE SEAL GAURD -INSTALL CROSS COLLAR CLAMP AT EACH JOINT -RIH TO 715 MD. CONTINUAL HOLE FILL =20 BPH WITH KWF. NO RETURNS. 24 HOUR FLUID LOSS=605 BBLS 8.5 PPG, SEAWATER 0/A=0 PSI Printed 1/21/2014 9:15:31AM North America-ALASKA-BP Page 12 of 14 Operation Summary Report Common Well Name:MPK-30 AFE No Event Type:WORKOVER(WO) Start Date:12/31/2013 End Date:1/11/2014 X4-00YKK-E:(2,460,000.00) Project:Milne Point • Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/19/1996 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292271100 Active datum:19:30 6/28/1998 20:05 @56.30usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 1/9/2014 00:00 - 06:00 6.00 RUNCOM P RUNCMP SPCC CHECKS AND PRE-TOUR MEETING RIH WITH 4.5 12.6#HYDRIL 521 TUBING. •-RIH FROM 715'MD. -TUBING TORQUE=4700 FT/LBS. -USE JET LUBE SEAL GAURD -INSTALL CROSS COLLAR CLAMP AT EACH JOINT -CHECK ESP CABLE CONDUCTIVITY EVERY 2000'. -PUMP 5 BBLS TO FLUSH THRU PUMP AT 1 BPM 1 BPM&200 PSI.AT 2000'. -LOSSES TO FORMATION LAST(12)HRS= 242 BBLS 8.5 -OUTER ANNULUS=0 PSI. 06:00 - 14:30 8.50 RUNCOM P RUNCMP PJSM.CONTINUE TO RIH W/4 1/2"HYDRIL 521 ESP COMPLETION. -INSTALLING CROSS COLLAR CLAMPS EVERY COLLAR. -USING JET LUBE SEAL GUARD AND TORQUE TURNING EACH CONNECTION @ -4700 FT/LBS. CHECKING CONDUCTIVITY EVERY 1000'& BREAKING CIRCULATION EVERY 2000'. -1 BPM @ 250 PSI.UP WT=128K&DOWN WT=110K @ 7000'. -PUMPING 20-25 BPH DOWN BACK SIDE W/ SAFE LUBE ADDED. 14:30 - 22:00 7.50 RUNCOM P RUNCMP PJSM.INSTALL NEW REEL AND MAKE SPLICE ON ESP FLAT CABLE. PERFORM CONDUCTIVITY TEST. 22:00 - 00:00 2.00 RUNCOM P RUNCMP PJSM.CONTINUE TO RIH W/41/2"HYDRIL 521 ESP COMPLETION. -RIH FROM JOINT#181 (-7000 FT) -INSTALL CANNON MID-JOINT SPLICE CLAMP AT SPLICE ON JOINT#187 -CONTINUE INSTALLING CROSS COLLAR CLAMPS EVERY COLLAR. -RUN IN HOLE TO-8000'MD -1 BPM @ 140 PSI.UP WT=130K&DOWN WT=95K @ 8000'. CONTINUAL HOLE FILL =20 BPH WITH KWF. NO RETURNS. 24 HOUR FLUID LOSS=525 BBLS 8.5 PPG, SEAWATER O/A=0 PSI 1/10/2014 00:00 - 06:00 6.00 RUNCOM P RUNCMP SPCC CHECKS AND PRE TOUR MEETING RIH W/41/2"HYDRIL 521 ESP COMPLETION. RIH FROM-8000'MD -INSTALLING CROSS COLLAR CLAMPS EVERY COLLAR. -USING JET LUBE SEAL GUARD AND TORQUE TURNING EACH CONNECTION @ 4700 FT/LBS. -CHECKING CONDUCTIVITY EVERY 1000'& BREAKING CIRCULATION EVERY 2000'. -1 BPM @170 PSI.@10370'.MD Printed 1/21/2014 9:15:31AM • North America-ALASKA-BP Page 13 of 14 Operation Summary Report Common Well Name:MPK-30 AFE No Event Type:WORKOVER(WO) Start Date:12/31/2013 End Date:1/11/2014 X4-OOYKK-E:(2,460,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/19/1996 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292271100 Active datum:19:30 6/28/1998 20:05 @56.30usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 06:30 0.50 RUNCOM P RUNCMP CLEAR RIG FLOOR OF CLAMPS AND THREAD PROTECTORS. -STAGE CENTRiLIFT EQUIPMENT ON FLOOR FOR ESP TERMINATION. 06:30 - 10:30 4.00 RUNCOM P RUNCMP PJSM,M/U TBG HANGER,R/D CABLES AND SHEAVE. -M/U 11"FMC TBG HANGER TO LANDING JOINT WITH FOSV AND ORIENT PER FMC REP -FMC REP INSTALL ESP PENETRATOR INTO HANGER. -CENTRILIFT REP TERMINATE CABLES.TEST SAME. 10:30 - 12:00 1.50 RUNCOM P RUNCMP PJSM,LAND TBG HANGER w/TWO WAY CHECK VALVE INSTALLED. -LAND 11"TBG HANGER PER FMC REP. -FMC AND WSL VERIFIED TBG HANGER ON SEAT. -PUW=160K INCLUDING 40K TOP DRIVE/ BLK WT.SOW=107K. -FMC REP RILDS. CANNON CLAMPS=260 PROTECTOLIZERS =3 FLAT GUARDS=2 CROSS SPLICE CANNON CLAMPS=1 LOSSES TO WELL LAST 12 HOURS=240 BBLS 8.5 PPG S.W. 12:00 - 13:00 1.00 RUNCOM P RUNCMP PERFORM ROLLING TEST FROM BELOW ON TWC. PUMP 6 BPM @ 500 PSI FOR 5 CHARTED MIN. -TEST FROM ABOVE 250/3500 PSI 5 CHARTED MIN.PASSED. -BD ALL TEST LINES. 13:00 - 14:00 1.00 BOPSUR P RUNCMP PJSM,N/D 13-5/8"5 M BOPS -N/D 13 5/8"BOPE -REMOVE FLOW NIPPLE AND TURNBUCKLES. -LOTO KOOMY AND REMOVE HOSES. -SET BACK BOP STACK -MAINTAIN CONTINUOUS HOLE FILL AT 20 BPH 8.5 PPG BRINE 14:00 - 20:00 6.00 WHSUR P WHDTRE PJSM,N/U 4 1/16"CAMERON PRODUCTION TREE/ADAPTER. -FMC REP CLEAN AND INSPECT TBG HANGER VOID. -N/U ADAPTER PER FMC REP. -PRESSURE TEST ADAPTER VOID -250 PSI FOR 5 CHARTED MINUTES PASSED. -5000 PSI FOR 30 CHARTED MINUTES. PASSED. -CENTRILIFT PERFORM FINAL CHECKS; DOWNHOLE GAUGE READS 3017 PSI BHP AND 125 F TEMP 20:00 - 22:30 2.50 WHSUR P WHDTRE -PRESSURE TEST PRODUCTION TREE -250/5000 PSI,BOTH 5 MINUTES CHARTED. PASSED. -WITNESSED BY WSL. -DRILL SITE OPERATOR VERIFIED ORIENTATION OF TREE. Printed 1/21/2014 9:15:31AM • North America-ALASKA-BP Page 14 of 14 Operation Summary Report Common Well Name:MPK-30 AFE No Event Type:WORKOVER(WO) Start Date:12/31/2013 End Date:1/11/2014 X4-00YKK-E:(2,460,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/19/1996 12:00:OOAM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292271100 Active datum:19:30 6/28/1998 20:05©56.30usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 00:00 1.50 WHSUR P WHDTRE PJSM,R/U AND TEST DSM LUBRICATOR -TEST 250/3500 PSI, FOR 5 CHARTED MINUTES. -PULL TWC 24 HOUR FLUID LOSS=371 BBLS 8.5 PPG, SEAWATER '5303 TOTAL BBLS KWF LOST TO WELL O/A=0 PSI 1/11/2014 00:00 - 02:30 2.50 WHSUR P WHDTRE SPCC CHECKS AND PRE-TOUR MEETING PJSM WITH LRS AND RIG CREW. -RU LRS TO TREE TO FREEZE PROTECT WELL. -TEST LINES TO 250/3500 PSI. -LOAD 35 BBLS DIESEL IN TBG. -PUMP 2 BPM©1200 PSI -RIG DOWN LRS 02:30 - 04:00 1.50 WHSUR P WHDTRE PJSM,R/U AND TEST DSM LUBRICATOR -TEST 250/3500 PSI, FOR 5 CHARTED MINUTES. -INSTALL 4"TYPE'H'BPV. -LAY DOWN LUBRICATOR -RIG UP LRS -LINE UP LRS TO PUMP DOWN I/A -2 BPM/500 PSI,42 BBLS PUMPED. -RIG DOWN LRS • 04:00 - 06:00 2.00 WHSUR P WHDTRE -SECURE ALL TREE VALVES. -SECURE CELLAR -PREPARE TO RDMO -SITP=0 PSI -SICP=0 PSI -OA=0 PSI -RELEASED RIG FROM MPK-30 FOR MOVE TO MPS-39 AT 06:00 HRS. -TOTAL TIME,(RIG ACCEPT TO RIG RELEASE),=10.5 DAYS. Printed 1/21/2014 9:15:31AM Tree: 4 1/16" 5M FMC Orig Elev. = 57.5' (N 22E) Wellhead: 11" x 11" 5M FMC Gen 5a Orig.K-30 (Kup.) Orig. Elev. = 28.0' w/ 4 1/16 FMC Tubing Hanger , DF To 7" csg. hng. =28.5' (N 22E) L.H.Acme Thread 4" CIW H BPV profile 20" 91.1 ppf, H-40 115 KOP @ 400' Max. hole angle = 57 to 62 deg. f/3650 toll,041' (PBTD) 9 5/8" Howco 'ES' 2479' Hole angle thru' perfs=58 deg O Cementer 9 5/8", 47 ppf, 6653' btm 44 jts. P-110 Btrc. next 6 jts. L-80 Mod. Btrc. top 109 jts L-80 NSCC Two 21' x 7" short joints D&D Tbg Stop 10,'280 f/ 10,255'-10,297' wlm. 1 D&D PackoffAssy w/Kobe Knockout 10,282' 4.5 12.6 ppf, L-80, Hydrill 521tbg.. ( drift ID =3.958", cap. = 0.00152 bpf ) Centrilift TIC-ESP Top 10,290' 7" 26 ppf, L-80, Btrc. prod. casing ( drift ID = 6.151", cap. =0.0383 bpf ) ; • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 , 51 4-AWNED FE.13 2012 December 30, 2011 Mr. Tom Maunder — u Alaska Oil and Gas Conservation Commission �� av 0 333 West 7 Avenue Anchorage, Alaska 99501 1 1 Subject: Corrosion Inhibitor Treatments of MPK -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPK -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator r . -„ .., ., ... _ .,:� . ....:... . .... ... .. -u s;• �r . mow' n4 s :!r s .' c: n'cs.'�a' a+ t • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPK 10/29/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPK -02 1960810 50029226750000 0.2 NA 0.2 NA 5.1 9/5/2011 MPK -05 1960680 50029226700000 1.9 NA 1.9 NA 17.9 8/24/2011 MPK-06 1961910 50029227250000 1.5 NA 1.5 NA 8.5 8/27/2011 MPK -09 2050140 50029232470000 1.9 NA 1.9 NA 12.8 8/24/2011 MPK -13 1960400 50029226550000 1.7 NA 1.7 NA 14.5 8/24/2011 MPK -17 1960280 50029226470000 1 NA 1 NA 2.6 8/24/2011 MPK -18A 1970270 50029227330100 4.6 NA 4.6 NA 23.8 8/27/2011 MPK -21A 2031620 50029227180100 0.4 NA 0.4 NA 6.9 10/29/2011 MPK -22 2050220 50029232490000 2 NA 2 NA 5.1 8/27/2011 MPK -25 1960320 50029226500000 4.2 NA 4.2 NA 30.6 8/24/2011 --> MPK -30 1961680 50029227110000 1.5 NA 1.5 NA 17.0 8/25/2011 MPK-33 1962020 50029227290000 1.7 NA 1.7 NA 15.3 8/24/2011 MPK -34 1961690 50029227120000 2.5 NA 2.5 NA 25.5 8/25/2011 MPK -37 1960760 50029226740000 2 NA 2 NA 17.0 8/24/2011 MPK-38 1960300 50029226490000 3.2 NA 3.2 NA 15.3 8/25/2011 MPK -43A 1970410 50029227380100 1.7 NA 1.7 NA 13.6 9/16/2011 STATE OF ALASKA ALAS- AND GAS CONSERVATION COMMIS REPORI'OF SUNDRY WELL OPERANS 1. Operations Performed: ❑ Abandon ■4 Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver 0 Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Change Out ESP Completion 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. Development ❑ Exploratory * 196 - 168 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 .,50 - 029 - 22711 - 00 - 00 7. Property Designation: 8. Well Name and Number: • ADL 375132 & 375133 • MPK 9. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured 11145 feet Plugs (measured) 10772 feet true vertical 7306 feet Junk (measured) N/A feet Effective depth: measured 11041 feet Packer: (measured) 10520 feet true vertical 7257 feet Packer: (true vertical) 6986 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' Surface 6621' 9 -5/8" 6652' 4908' 6870 4760 Intermediate Production 11094' 7" 11122' 7295' 7240 5410 Liner : A. AN *IV �t. ' 1 ZGl6 Perforation Depth: Measured Depth: 10588' - 10748' True Vertical Depth: 7025' - 7111' Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.5# L -80 10407' MD 6921' TVD Packers and SSSV (type, measured and true vertical depth): 7" HES Versatrive Packer 10520' MD 6986' TVD 4-1/2" Weatherford Duragrip screen assemblies 10533' - 10773' MD 6993' - 7124' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): RECEIVED Treatment description including volumes used and final pressure: AUG 1 2011 Maki ON & Gas Cainc. Commission Anci►era g 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 Subsequent to operation: 133 185 1634 0 188 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory 0 Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations ■4 Well Schematic Diagram 15. Well Status after work: ❑ GINJ s 0 Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WtNJ 16. 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 Wilmer Hoffman, 564 -4592 N/A Printed Name Elizabeth Barker Title Drilling Technologist /'� Prepared By Name/Number. Signature r . r Phone 564 -5674 Date e /t3 / /// Elizabeth Barker, 564 -5674 Form 10-404 ?4BDMc1o 0 1 ZQ � ` ).,, I ( / Submit Original Only • • MPK -30 Well History (Pre Rig RWO) Date Summary 12 -Jul -2011 Conducted PJSM. Counted turns & bled off IA. R/U lubricator & PT to 300 psi low & 3500 psi high (charted). Set 2- 1/16" VR plug & removed front side IA. Installed tapped blind flange w/ needle valve. PT to 500 psi low & 3500 psi high (charted & recorded). Verified barrier on back side IA & removed flange. Installed second IA on back side of well w/ integral. PT to 300 psi low & 3500 psi high. Pre RWO. 14 -Jul -2011 TAGGED ADV @ 10317' SLM/ 10331' MD ( -14' CORRECTION) W/ 1.50" LIB, GOOD PIC RAN PDS CALIPER AS PER PROGRAM RAN SBHPS MADE 15 MIN STOP @ 9365' MD CURRENTLY ON 3 HR STOP @ 10,300' MD 15 -Jul -2011 FINISHED 3 HR STOP 10300' MD WITH SBHPS PULLED 1" BK -DGLV FROM ST #1 @ 10141' MD PULLED 1" BEK -DPSOV FROM ST #2 @ 138' MD SET 1" BK -DGLV IN ST #2 © 138' MD 27 -Jul -2011 PPPOT -T: Stung into test port (0 psi). Functioned LDS (ET), all moved freely (1"). Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT -IC: Stung into test port (0+ psi), bled to 0 psi. Functioned LDS (ET), all moved freely (3/4 ") Pumped through voi, good returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 31 -Jul -2011 Conducted PJSM. Verified barriers. R/U lubricator & PT to low & high (charted) (For all subsequent lubricator breaks as well). « «« Set 2 9/16 H style BPV » » » ». Tested tree cap to 500 psi. Page 1 of 1 Tree: 2 9/16" - 5M FMC M P U K -30 KU Orig. DF ES= 57.5' (N 22E) Wellhead: 11" x 7" 5M FMC Gen 5a _ ( P Orig. GL Elev. = 28.0' w/ 2 7/8" WKM Tubing Hanger , w/ 3" DF To 7" csg. hng. = 28.5' (N 22E) L.H. Acme Thread , 2.5" CIW H BPV profile 20" 91.1 ppf, H -40 115 Camco 2 - 7/8" x 1" 140' D sidepocket KBMM GLM KOP @ 400' Max. hole angle = 57 to 62 deg. f/ 3650 to11,041' (PBTD) 9 5/8" Howco 'ES' 2479' Hole angle thru' perfs = 58 deg 0 Cementer A 11 9 5/8 ", 47 ppf, 6653' btm 44 jts. P -110 Btrc. next 6 jts. L -80 Mod. Btrc. top 109 jts L -80 NSCC Two 21' x 7" short joints f/ 10,255'- 10,297' wim. Camco 2 -7/8" x 1" 10,144' sidepocket KBMM GLM 2 -7/8" XN nipple 10,291' (ID 2.205 ") 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. drift ID = 2.347 ", cap. 0.00592 b f - ( P• = P ) GPDIS Discharge Head 10,334' 7" 26 ppf, L -80, Btrc. prod. casing ( drift ID = 6.151", cap. = 0.0383 bpf) FP Tandem Pumps,119 P23 & 18 P75 10,335' .11r "f: g_ Model - SXD tungsten coated Gas Separator - GSTHV 10,358' ,.;A, Intake @ 6893' TVD Mid - perf TVD = 7075' Tandem Seal Section ,! Mid - pert MD = 10681' Model GSB3 DB UT SB /SB PFSA 10 PBTD TVD = 7316 Motor, 562 Series MSP1, PBTD MD = 11041' 336 HP, 2650 volt, 77 amp, 10,378' Now Stimulation Summary ® Q � PumpMate XTO gauge 10,405' none w/6 fin Centralizer (selectively perforated rather than frac Gauge TVD = 6920' packed) Perforation Summary 7" HES Versatrieve Pkr 10,520' Ref loci 11/25/96 GR/CCL — . ■. Size SPF Interval TVD — it Kup 'C' Sand — 4.5" Weatherford Duragrip 10,533 -772' .020 gauge Screen (6 Jts.) 4.5" 5 10,588` 10,658' 7024` - 7063' _ = — Kup 'B' Sand _ WM al 4.5" 5 10,704'- 10,748' 7088` -7111' 4.5" Bull plug 10,772' 7" float collar (PBTD) 11041' 7" float shoe 11122' DATE REV. BY COMMENTS 11/27/96 JBF Initial ESP completion by Nabors 4ES 06/15/98 M. Linder RWO Screens added/ Pig tail pull & land MILNE POINT UNIT 04/05/02 B. Hasebe RWO Nabors 4ES WELL K -30 05/05/04 J. Cubbon RWO Nabors 4ES 1 10/6/07 REH ESPRWO -4ES API NO: 50-029 -22711 8/3/08 L Hulme ESP RWO & replace screens - 3S 8/15/10 L Hulme ESP RWO & replace screens - 4ES 8/05/11 B. Bixby ESP RWO - Doyon 16 BP EXPLORATION (AK) / • • North America - ALASKA - BP Page 1 of 6 Operation Summary Report Common Well Name: MPK -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/23/2011 End Date: X4- 00TQY -E: (800,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/19/1996 12:00:00AM Rig Release: 8/5/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292271100 Active Datum: 19 : 30 6/28/1998 20:05 @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/1/2011 18:00 - 00:00 6.00 MOB P PRE BACK OFF OF K -33 AT 19:3Q - MOVE RIG AROUND BACKSIDE OF PAD, REPOSITION MATS TO MOVE ONTO OPPOSITE SIDE OF PAD. 8/2/2011 00:00 - 04:00 4.00 MOB P PRE MOVE RIG MATS TO CONTINUE RIG MOVE ONTO K -30. - DOUBLE MAT AROUND K -30. 04:00 - 08:00 4.00 RIGU P PRE MOVE OVER WELL AT 0400. -SPOT TANKS AND TRUCKS. -OAP = 100 PSI, BLEED TO SLOP TANK. 08:00 - 12:00 4.00 RIGU N DECOMP PRE SPUD MEETING. -IT WAS DISCOVERED THAT HARD LINE WAS NON COMPLIANT TO FLOW BLACK TANK. -CALL OUT HARD LINE CREW TO REPLACE HARD LINE THAT WAS OUT OF COMPLIANCE. -HOLD CLASS WITH CREW ON TOUR ON COLOR CODES OF HARD LINE AND EQUIPMENT. -HOLD FIRE EVAC DRILL WITH CREW AND TEST EMERGENCY SHUT DOWN. (ESD WORK WELL) -HOLD AAR ON DRILL: CAPTURE LESSONS LEARNED. -WAIT ON DSM HARD LINE CREW. -RIG ACCEPTED AT 0800 HRS. 12:00 - 14:30 2.50 RIGU P DECOMP HARD LINE CREW ARRIVES ON LOCATION. -SWAP OUT NON COMPLIANT HARD LINE WITH COMPLIANT HARDLINE. 14:30 - 15:00 0.50 RIGU P DECOMP PJSM. - PRESSURE TEST LINES TO FLOW BACK TANK TO 250 PSI LOW AND 3500 PSI HIGH. GOOD TEST 15:00 - 15:30 0.50 RIGU P DECOMP HOLD EVAC DRILL. -ALL PERSONAL ACCOUNTED FOR AND IN PROPER EVAC LOCATION. -SCS HAD A GOOD HANDLE ON ALL 3RD PARTY PERSONEL AND RIG CREW FOR ACCOUNTABILITY. 15:30 - 17:30 2.00 KILLW P DECOMP PJSM P/U DSM LUBRICATOR. -R/U TO PULL BPV. -TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH. - WELL SUPPORT PULLED BPV 450 PSI ON THE IA AND 300 PSI ON THE TBG Printed 8/30/2011 2:54:12PM •rth America. - ALASKA - BP Page 2 of 6 Operation Summary Report Common Well Name: MPK -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/23/2011 End Date: X4- 00TQY -E: (800,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/19/1996 12:00:00AM Rig Release: 8/5/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292271100 Active Datum: 19 : 30 6/28/1998 20:05 @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 19:30 2.00 KILLW P DECOMP PJSM WITH RIG CREW AND VAC TRUCK DRIVERS - BLEED GAS CAP OFF THE WELL. BLEED GAS TO THE FLOW BACK TANK , KEEPING THE PRESSURE DOWN STREAM OF THE CHOKE — 100 PSI - BLED THE TBG & IA TO 50 PSI EACH, BEFORE GETTING SMALL AMOUNT OF CRUDE BACK - PUMPED 100 BBLS DOWN THE TUBING, LINED UP TO TAKE RETURNS UP THE IA AND OUT TO THE TIGER TANK - NEVER SAW RETURNS AFTER PUMPING 100 BBLS, PUMPED @ 5 BPM WITH 1900 PSI. - SHUT DOWN AND LINE UP TO BULL HEAD A WELL BORE VOLUME AND A HALF 19:30 - 21:00 1.50 KILLW P DECOMP PJSM FOR BULL HEAD OPERATIONS - BULLHEADED —600 BBLS DOWN THE TBG AND IA AT 6 -1/2 TO 7 BPM WITH 500 TO 900 PSI. - SHUT DOWN TO MONITOR WELL. 300 PSI ON BOTH THE IA & TBG - LINED UP TO THE GAS BUSTER AND BLED PRESSURE DOWN TO 30 PSI ON BOTH SIDES 21:00 - 22:00 1.00 KILLW P DECOMP MONITOR WELL - WELL WENT ON A VAC ON BOTH THE TBG AND IA. 22:00 - 22:30 0.50 WHSUR P DECOMP PJSM FOR INSTALLING TWC. -R/U LINES TO MONITOR WELL. CONTINUOUS HOLE FILL OF 20 BPH. - INSTALL TWC. - TFSTED TWC TO 500 PSI ROI I INA I OSSINC; 50 BBLS. - TESTED TWC FROM ABOVE TO 250 PSI LOW AND 3500 PSI HIGH. BOTH GOOD TESTS. 22:30 - 00:00 1.50 WHSUR P DECOMP PJSM -N /D TREE. - CONTINUOUS HOLE FILL OF 20 BPH. 8/3/2011 00:00 - 02:00 2.00 WHSUR P DECOMP HELD PJSM. FMC PREPPED THE WELL HEAD FOR REMOVAL. NIPPLED DOWN TREE AND ADAPTER FLANGE. NINE THREADS ON THE HANGER. - CONTINUOUS HOLE FILL OF 20 BPH. 02:00 - 05:30 3.50 BOPSUR P DECOMP PJSM FOR N/U BOPE - INSTALL 7 -5/8" X 13 -3/8" SPOOL. - NIPPLE UP THE BOPS CONFIGURED WITH 2 -7/8" X 5" VBR'S, MUD CROSS, BLIND SHEAR, ANNULAR. - CONTINUOUS HOLE FILL OF 20 BPH. Printed 8/30/2011 2:54:12PM ,rth America - ALASKA - BP Page 3 of 6 Operation Summary Report Common Well Name: MPK -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/23/2011 End Date: X4- 00TQY -E: (800,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/19/1996 12:00:00AM Rig Release: 8/5/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292271100 Active Datum: 19 : 30 6/28/1998 20:05 @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:30 - 15:00 9.50 BOPSUR P DECOMP PJSM FOR TESTING BOPE. PRESSURE TESTING 3- PREVENTER 13 -5/8" BOPE - ANNULAR, BLIND SHEARS, MUD CROSS, AND 2 -7/8" X 5" VBR'S. - TEST TO 250 -PSI LOW AND 3500 -PSI HIGH FOR 5 -MIN EACH CHARTED - TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS. - RAMS TESTED TO 250 PSI LOW AND 3500 (,I ° PSI HIGH. ��••��`"' - TESTED USING A 2 -7/8" TEST JOINT. - TESTS WITNESSED BY BP WSL, DDI TP, DDI GS DRILLER AND JOHN CRISP WITH AOGCC. KOOMEY - SYSTEM PSI OF 2900, PSI AFTER CLOSE OF 1900, 200 PSI INCREASE AFTER 20 SEC., FULL PSI AFTER 77 SEC. 5 BOTTLES AT 1800 PSI. -ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT - AK -10 -45 -- FAIL / PASS AS FOLLOWS: F/P THE ANNULAR CLOSING PRESSURE REGULATOR ON THE REMOTE PANEL. REGULATOR WAS NOT TRACKING CORRECTLY WITH THE KOOMEY. F/P ON THE ANNULAR DUE TO THE ABOVE REGULATOR. F/P THE SUPER CHOKE AIR OVER HYDRAULIC PUMP WAS NOT OPERATING PROPERLY, THE PUMP WOULD NOT STOP CYCLING EVEN WHEN THE CHOKE WAS NOT BEING ACTUATED. F/P THE WRONG OTECO CLAMP WAS ALSO FOUND ON THE CHOKE LINE AND REPLACED. A CALL WAS MADE TO THE RWO SUPT AND DECISION WAS MADE TO SUSPEND OPERATIONS UNTIL THESE PROBLEMS WERE CORRECTED. THE ANNULAR PRESSURE WAS A FAIL / PASS DUE TO THE TIME IT TOOK TO GET A GOOD TEST, THIS WAS ATTRIBUTED THE TO THE PROBLEM WITH THE PRESSURE REGULATOR. THE PRESSURE REGULATOR WAS CHANGED OUT WHICH ALSO CORRECTED THE GAUGE ON THE REMOTE PANEL THAT WAS NOT TRACKING ACCURATELY. THE SUPER CHOKE HAD THE 4 -WAY VALVE AND PISTON 0-RING ON THE AIR PUMP CHANGED OUT. THE CHOKE LINE HAD A FAIL PASS DUE TO A LEAK AT THE CONNECTION, THE WRONG CLAMP WAS INSTALLED. THE CLAMP WAS C/O WITH THE CORRECT ONE AND THE LEAK STOPPED. Printed 8/30/2011 2:54:12PM IV America - ALASKA - BP • Page 4 of 6 Operation Summary Report Common Well Name: MPK -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/23/2011 End Date: X4- 00TQY -E: (800,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/19/1996 12:00:00AM Rig Release: 8/5/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292271100 Active Datum: 19 : 30 6/28/1998 20:05 @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:00 - 17:30 2.50 BOPSUR P DECOMP RIG DOWN TEST EQPT -RIG UP OPSO LOPSO - RU LUBRICATOR FOR PULLING TWC - RU SHEAVE FOR PULLING ESP CABLE RIG MECHANIC AND ELECTRICIAN WORKING ON THE TWO FAILURES FROM THE BOP TEST. BOTH PROBLEMS WERE ABLE TO BE CORRECTED. 17:30 - 19:30 2.00 BOPSUR P DECOMP PJSM FOR R/U LUBRICATOR. -R/U LUBRICATOR AND TEST TO 250 PSI LOW AND 3000 PSI HIGH FOR 5 MIN. GOOD TEST. -PULL TWC. THE WELL WAS NOTED TO BE ON A VAC. 19:30 - 21:30 2.00 PULL P DECOMP PJSM ON PULLING HANGER. -R/U XO ON LANDING JOINT TO M/U TO HANGER. -M/t1 I ANOING .I01NT TO HANGER -PULL HANGER FRFF AT 175K -P /U OF 108K. - ESTABLISH STATIC LOSS RATE OF 145 BPH. -BULL HEAD 70 BBLS OF SEAWATER AT 4.5 BPM AND 1950 PSI. - MONITOR WELL FOR 10 MIN. WELL ON A VAC WITH 30 BPH FILL RATE. 21:30 - 22:30 1.00 PULL P DECOMP L/D HANGER. -LAY DOWN LANDING JOINT. -TRIM ESP CABLE. -RUN ESP CABLE THROUGH SHEAVE. -RIG UP ESP CABLE TO SPOOLING UNIT. - CONTINUE TO FILL HOLE AT 30 BPH 22:30 - 00:00 1.50 PULL P DECOMP -PULL OUT OF HOLE, STANDING BACK IN DERRICK. 2 -7/8" 6.5# L -80 EUE 8 RD. FROM 10407' TO 9500' - CONTINUE TO FILL HOLE AT 30 BPH 8/4/2011 00:00 - 04:00 4.00 PULL P DECOMP -PULL OUT OF HOLE. STANDING BACK IN DERRICK. 2 -7/8" 6.5# L -80 EUE 8 RD. FROM 9500' - CONTINUE TO FILL HOLE AT 30 BPH 04:00 - 04:30 0.50 PULL P DECOMP A KICK WHILE TRIPPING DRILL WAS CONDUCTED WITH THE NEW MOTOR MAN ON THE BRAKE. -AN AAR WAS HELD AND THE DRILL WAS DISCUSSED WITH THE CREW. 04:30 - 06:00 1.50 PULL P DECOMP - CONTINUE TO PULL OUT OF HOLE. STANDING BACK IN DERRICK. 2 -7/8" 6.5# L -80 EUE 8 RD. - POH TO —2353' - CONTINUE TO FILL HOLE AT 30 BPH Printed 8/30/2011 2:54:12PM S th America - ALASKA - BP Page 5 of 6 Operation Summary Report Common Well Name: MPK -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/23/2011 End Date: X4- 00TQY -E: (800,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/19/1996 12:00:00AM Rig Release: 8/5/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292271100 Active Datum: 19 : 30 6/28/1998 20:05 @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 08:30 2.50 PULL P DECOMP - CONT TO TOH WITH ESP COMPLETION. - POH F/ 2,353' TO THE TOP OF THE PUMP ASSEMBLY - RACKING THE 2 -7/8" 6.5# EUE IN THE DERRICK, VISUALLY INSPECTING THE TBG AS IT IS PULLED. - MAINTAINING CONTINUOUS HOLE FILL AT 30 BPH - STOP AND MONITOR WELL BEFORE PULLING THE PUMP & MOTOR THROUGH THE BOP STACK. - FILLED THE HOLE COMPLETLY TO VERIFY WHAT THE ACTUAL LOSS RATE WAS. - LOSS RATE STILL HOLDING AT 120 -130 BPH. 08:30 - 10:00 1.50 PULL P DECOMP BREAK OUT AND LAY DOWN ESP COMPLETION. - DISCUSSION WITH CREW AND DRILLER ABOUT WHAT THE PLAN WAS FOR WELL CONTROL WITH THE NON SHEARABLES ACROSS THE STACK. - CENTRILIFT INSPECTING THE PUMP AND MOTOR ASSY BEFORE LAYING DOWN. 10:00 - 12:00 2.00 PULL P DECOMP CHANGE OUT ESP SPOOLS. - LAY DOWN ELEPHANT TRUNK. - MPU PE REDRESSED THE GLM'S. - START PICKING UP NEW ESP COMPLETION. 12:00 - 16:00 4.00 RUNCOM P RUNCMP PU & MU NEW ESP ASSEMBLY - CENTRILIFT CONNECTING NEW MOTOR LEAD EXTENSION. 16:00 - 21:00 5.00 RUNCOM P RUNCMP START RIH WITH 2 -7/8" 6.5# L -80 EUE 8 RD. FROM THE DERRICK. -RIH FROM 274' TO 5,568' BREAK CIRCULATION. PUMP 10 BBLS EVERY 2,000' 1.5 BBLS PER MIN. WHILE CHECKING CONDUCTIVITY OF ESP CABLE. - CONTINUE FILLING HOLE AT 30 BPH. 21:00 - 21:30 0.50 RUNCOM P RUNCMP CONDUCTED KICK WHILE TRIPPING WITH ESP CABLE DRILL. - FOLLOWED BYAAR. DISCUSSED LACK OF ESD IN SPOOLER UNIT. CENTRILIFT HAND TO INITIATE A PLAN TO INSTALL. 21:30 - 22:03 0.55 RUNCOM P RUNCMP CONTINUE TO RIH FROM 5.586' TO 6.480' - CONTINUE TO PUMP ACROSS HOLE. 22:03 - 00:00 1.95 RUNCOM P RUNCMP CENTRLIFT REEL TO REEL SPLICE. 8/5/2011 00:00 - 02:00 2.00 RUNCOM P RUNCMP CONTINUE ESP CABLE SPLICE. 02:00 - 08:30 6.50 RUNCOM P RUNCMP CONTINUE TO RIH WITH 2 -7/8" 6.5# L -80 EUE 8 RD. FROM THE DERRICK. -FILL HOLE AT 30 BPH. - BREAKING CIRCULATION AND CHECKING CONDUCTIVITY EVERY 2000' - PU & MU A REDRESSED 7" X 2 -7/8" WKM TUBING HANGER - CENTRILIFT TO MAKE PENETRATOR SPLICE. 08:30 - 09:00 0.50 RUNCOM P RUNCMP PJSM FOR LANDING THE HANGER. - PUW 110 K, SOW 76 K - LAND HANGER WITH FMC REP TO RILDS - FMC REP INSTALLED TWC Printed 8/30/2011 2:54:12PM d �rth America - ALASKA - BP Page 6 of 6 Operation Summary Report Common Well Name: MPK -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/23/2011 End Date: X4- 00TQY -E: (800,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/19/1996 12:00:00AM Rig Release: 8/5/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292271100 Active Datum: 19 : 30 6/28/1998 20:05 @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 10:30 1.50 RUNCOM P RUNCMP TESTING TWC - TEST TWC FROM ABOVE TO 250 PSI LOW AND 3500 PSI HIGH FOR 10 MIN CHARTED - PERFORM ROLLING TEST FROM BELOW, PUMPED AT 6 BPM WITH 560 PSI , TOTAL OF 50 BBLS PUMPED AWAY 10:30 - 11:00 0.50 RUNCOM P RUNCMP BREAK DOWN LINES - RIG UP FOR CONTINUOUS HOLE FILL 11:00 - 15:00 4.00 BOPSUR P RUNCMP PJSM FOR ND OF BOPE -ND BOP STACK - CENTRILIFT MAKING FINAL CHECKS. - NU TUBING HEAD ADAPTER AND TREE - MAINTAIN CONTINUOUS HOLE FILL AT 30 BPH 15:00 - 16:30 1.50 WHSUR P RUNCMP PRESSURE TEST ADAPTER AND TREE - PRESSURE TEST TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN. 16:30 - 19:00 2.50 WHSUR P RUNCMP PU & MU LUBRICATOR - PRESSURE TEST TO 250 PSI LOW AND 3000 PSI HIGH FOR 5 CHARTED MIN. GOOD TEST. - INSTALL BPV. PREPARATION FOR MOVING THE RIG ON A WELL TO WELL MOVE. 19:00 - 20:00 1.00 WHSUR P RUNCMP R/U LINES TO TEST BPV. - BULL HEAD AT 6 BPM TO MAINTAIN 500 PSI UNDER BPV. HOLD FOR 10 CHARTED MIN. - R/D EQUIPMENT. 20:00 - 00:00 4.00 WHSUR P RUNCMP SECURE WELL. - CLEAR AND CLEAN RIG FLOOR. - EMPTY AND CLEAN PITS. - RELEASE RIG AT MIDNIGHT. Printed 8/30/2011 2:54:12PM STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI N REPOR OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Change Out ESP and Replace Screens 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration Alaska Inc. ® Development ❑ Exploratory °f 196 - 168 P ( Alaska) p P rY 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 y 50 - 029 - 22711 - 00 - 00 7. Property Designation: 8. Well Name and Number: ADL 375132 s 4 MPK - 9. Field / Pool(s): J Milne Point Unit / Kuparuk River Saad6 01 1( 3 1 l e 10. Present well condition summary Total depth: measured 11145 feet Plugs (measured) 10772' true vertical 7306 feet Junk (measured) None Effective depth: measured 11041 feet Packer: measured 10520 feet true vertical 7257 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' Surface 6621' 9 -5/8" 6652' 4908' 6870 4760 Intermediate Production 11094' 7" 11122' 7295' 7240 5410 Liner Perforation Depth: Measured Depth: 10588'10748' AOMW NOV I True Vertical Depth: 7025' - 7111' Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.5# L -80 10411' MD 6923' TVD Packers and SSSV (type, measured and true vertical depth): 7" HES Verstrive with 4 -1/2" Weatherford 10526' MD 6989' TVD Duragrip screen assemblies at 10533'- 1077 ' 993' - 7124' TVD Fs r� 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: g� AII 12_ Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1360 0 Subsequent to operation: 323 108 2575 340 201 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: • Daily Report of Well Operations " ® Development ❑ Service ❑ Exploratory ❑ Stratigraphic • Well Schematic Diagram 15. Well Status ® Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ Suspended after work: ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG 16. 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: Contact David Bjork, 564 -5683 1 NIA Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number. Si ature �vr Phone 564 -4750 Date - ic) Sondra Stewman, 564 -4750 Form 104!)4 Revised 07/2009910DNIS Nov 5 / /s. /O /00 '� S it Original Only Tree: 2 9/16" - 5M FMC MPU K -30 ( Kup.) Orig. DF = 57.5' (N 22E) Wellhead: 11" x 7" 5M FMC Gen 5a Orig. GL = 28.0' W/ 2 7/8" WKM Tubing Hanger, w/ 3" DF To 7" csg. hng. = 28.5' (N 22E) L.H. Acme Thread, 2.5" CIW H BPV profile 20" 91.1 ppf, H -40 115' Camco 2 -7/8" x 1" 138' ` sidepocket KBMM GLM KOP @ 400' Max. hole angle = 57 to 62 deg. f/ 3650 to11,041' (PBTD) 9 5/8" Howco 'ES' 2479' Hole angle thru' perfs = 58 deg Cementer 9 5/8 ", 47 ppf, 6653' btm 44 jts. P -110 Btrc. next 6 jts. L -80 Mod. Btrc. top 109 jts L -80 NSCC Two 21' x 7" short joints f/ 10,255'- 10,297' wlm. Carrico 2 -7/8" x 1" 10,141' sidepocket KBMM GLM 2 -7/8" XN nipple 10,288` (ID 2.205 ") 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. ( drift ID = 2.347 ", cap. = 0.00592 bpf) Automatic Diverter Valve 10,331' 7 26 ppf, L -80, Btrc. prod. casing ( drift ID = 6.151 ", cap. = 0.0383 bpf) Tandem Pumps, 74- P31 &74 -P31 10,337' Model - SXD tungsten coated Gas Separator 10,366` Intake @ 6898' TVD Mid -perf TVD = 7075' _ Tandem Seal Section Mid -pert MD = 10681' Model GSB3 DB UT /LT AB /AB 10,371' PFSA/FSA CI-5 PBTD TVD = 7316 Motor, 266 HP, 2345 volt, PBTD MD = 11041' 69 amp, 562 Series KM 10,385' H Stimulation Summary 10,407` PumpMate XTO gauge none a w/6 fin Centralizer (selectively perforated rather than frac Gauge TVD = 6921' packed) 10,520' Perforation Summary 7" HES Versatrieve Pkr Ref log: 11/25/96 GR /CC Size SPF Interval TVD Kup 'C' Sand 4.5" Weatherford Duragrip 10,533 -772' .020 gauge Screen (6 Jts.) 4.5" 5 10,588'- 10,658' 7024' -7063' Kup 'B' Sand 4.5" 5 10,704'- 10,748' 7088' -7111' 4.5" Bull plug 10,772' 7" float collar (PBTD) 11041' 7" float shoe 11122' DATE REV. BY COMMENTS 11/27/96 JBF Initial ESP completion by Nabors 4ES 06/15/98 M. Linder RWO Screens added/ Pig tail pull & land MILNE POINT UNIT 04/05/02 B. Hasebe RWO Nabors 4ES WELL K -30 05/05/04 J. Cubbon RWO Nabors 4ES 10/6/07 REH ESP RWO- 4ES API NO: 50- 029 -22711 8/3/08 L Hulme ESP RWO & replace screens - 3S 8/15/10 L Hulme ESP RWO & replace screens -4ES BP EXPLORATION (AK) MPK -30, Well History Date Summary 06/21/10 ** *WELL S/I ON ARRIVAL * ** ( Rig Prep) PULL 1" BK -DGLV FROM ST #1 AT 10206' MD * * * * * * * ** *POCKET LEFT OPEN * * * * * * * * ** PULL 1" DPSOV FROM 138' MD. SET 1" BK -DGLV IN ST #2 @ 138' MD. WELL LEFT S/I ON DEPARTURE 07/11/10 MPU well ST demobed the well house and flow lines and foundation. 08/05/10 * ** WELL S/I ON ARRIVAL * ** (sbhps) RAN 1.80" CENT,S.S & DUAL SPARTEK GAUGES.MADE 15 MINUTE STOP @ 9892' MD & 3 HOUR STOP @ 10395' MD. ASSISTED SUPPORT TECHS INSTALL BPV. »» BPV SET «« * ** WELL S/I ON DEPARTURE * ** 08/06/10 T /I /O = 800/1250/200 PPPOT -T (pass) Tested to 5000 psi f /30 min lost 100 psi in 30 min LDS all functioned & torqued @ 350 ft #'s. PPPOT -IC (pass) Tested @ 3500 psi for 30 min w /no pressure loss. 08/11/10 LRS Unit 64 Load & Transport Diesel 08/17/10 T /1 /0= 0/20/40 Scale Inhibitor Treatment. Pump 475 bbls 10% EC6085A source water mix displaced by 120 bbls source water down Tbg. Freeze protect Tbg w/ 67 bbls crude. Freeze protect IA w/ 58 bbls crude. FWHP= 450/150/40. Swab, Wing, Ssv closed. Mst., IA, OA open. NOVP 09/09/10 ASRC Test Unit #5 travel to MPK, MIRU. Start 6 hour test ** *job in progress * ** ** *MPK -pad test header * ** 09/10/10 ASRC Test Unit #5 Complete 6 hour test ** *job complete * ** ** *MPK -pad test header * ** 10/01/10 ASRC Test unit #5, MIRU, divert well * *job in progress ** * *test header ** 10/02/10 ASRC Test unit #5, complete 6 hour test * *job complete ** * *test header ** Page 1 of 1 Narth 'America - ALASKA - BP _Page of 1 © eratiorr hum °rna - Fe or't M1 a ; Common Well Name: MPK -30 AFE No Event Type: MOBILIZATION (MOB) Start Date: 8/8/2010 End Date: 8/8/2010 X4- OORF7 -E (50,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 10/19/1996 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292271100 Active Datum: 19 : 30 6/28/1998 20:05 @56.30ft ( above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/8/2010 00:00 - 02:00 2.00 MOB P PRE MOVING RIG FROM MILNE PT TEXACO PAD TO MPK -30 02:00 - 06:00 4.00 MOB P PRE PJSM. -SPOT CAMP, SHOP, LAY MAT BOARDS AND SPOT SUB OVER MPK -30. -DS OPERATOR NOTIFIED OF SUB SPOTTING OVER WELL. =WSL WITNESSED SUB SPOTTING OVER WELL. 06:00 - 08:00 2.00 MOB P PRE R/U PITS, PIPE SHED AND RIG FLOOR. TOOLPUSHER, DERRICK HAND, WSL AND RIG ELECTION INSPECT NEW "MOC" ON 110 %TIGER TANK. -AAR: NEED TO BUILD A TEST CUP. SO THE HI-LEVEL ALARM CAN BE FLUID TESTED PROPERLY. RIG ACCEPTED' @ 08:00 HRS, 08108/2010. 08:00 - 08:30 0.50 MOB P PRE TAKE ON 8.45 PPG 120 DEG SEAWATER, VERIFIED WEIGHT AND TEMP -R /U KILL LINES TO TREE AND TIGER TANK. 08:30 - 11:00 2.50 MOB P PRE PJSM'WITH WELL SUPPORT CREW -P /U LUBRICATOR AND TEST 250 / 2,700 PSI FOR 5 CHARTED MIN. GOOD TEST. -2700 PSI TEST WAS DERIVED FROM MASP PLUS 20% -PULL BPV AND UD LUBRICATOR. WHP's: TBG = 1100, IA = 1050, OA = 160 PSI. AAR: 1.) FIRST TIME CHARTING LUBRICATOR TEST WENT WELL. 2.) NEW r' BLEED -OFF LINE TO TIGER TANK WAS ATTACHED TO LUBRICATOR AND WORKED WELL TO BLEED -OFF GAS. Printed 9/20/2010 5:11:44PM Noah America ALASKA - BP A Or C)prati ©n Summary Repl_ort _ All °.. Common Well Name: MPK -30 AFE No Event Type: WORKOVER (WO) Start Date: 8/8/2010 End Date: X4- OORF7 -E (700,000.00) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 10/19/1996 12:00:OOAM Rig Release: /S'' .�a 0/ p Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292271100 Active Datum: 19: 20:05 @56.30ft (abov Mean Sea Level) _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/8/2010 11:00 - 11:30 0.50 BOPSUR P DECOMP RIG SERVICE 11:30 - 12:30 1.00 BOPSUR P DECOMP PRESSURE TEST LINES TO TIGER TANK TO 500 PSI -2" DEMCO VALVE ON MUD MANIFOLD FAILED TO TEST AND WAS REBUILD AND SURFACE LINES AND VALVES WERE TESTED TO 3,500 PSI. 12:30 - 19:00 6.50 BOPSUR P DECOMP PJSM WITH TRUCK DRIVERS AND CREW. -W ELL KILL: BLEED -OFF GAS ON TBG F /11 T/ 160 PSI AND IA F/ 1050 T/ 220 PSI AND OA F/160 T/ O PSI. - PUMP -60 BBLS 120 DEG 8.45 # SEAWATER DOWN THE TBG AT '3 BPM / 660 PSI. -LOST —20 BBLS. ` -CLOSE THE CHOKE AND BULL HEAD 40 BBLS INTO THE FORMATION AT 2 BPM / 260 PSI. -TBG ON SLIGHT VACUUM, IA DROPPED FROM 350 PSI TO 320 PSI IN 10 MINUTES. BLEED -OFF —4 BBLS. - PUMPED 4 BBLS TO CATCH FLUID. PUMPED A TOTAL OF 505 BBLS HEATED SEAWATER DOWN THE TBG THROUGH THE CHOKE TO THE TIGER TANK AT 3 -1/2 BPM / 990 PSI WITH — 250 PSI ON THE CHOKE. —242 BBLS THICK CRUDE THEN DIESEL. - RETURNS SLOW TO CLEAN -UP. TOTAL LOSSES = —333 BBLS TO FORMATION. - MONITOR WELL FOR 20 MINUTES -TBG AND IA ON A SLIGHT VACUUM. ON SITE VISIT BY KEN MILLER RWO SUPERINTENDENT: - DISCUSSIONS AROUND LEVEL 0,& LEVEL 1 NOTIFICATION CHARTS -DRILL AFTER ACTION REVIEWS AND ACTION ITEMS 19:00 - 20:00 1.00 BOPSUR P DECOMP F MC SET & TEST 2 -1/2 CIW. "H" STYLE TWC - ATTEMPTED TO TEST FROM BELOW, PUMPED 3 BPM @ 30 PSI FOR 10 CHARTED MIN. - TESTED FROM ABOVE TO 3500 PSI FOR 10 CHARTED MIN. 20:00 21:30 1.50 WHSUR P DECOMP RD LINES BLOW DOWN TREE. -BLEED VOID -ND 2- 9/16" 5M TREE. 21:30 - 00:00 2.50 BOPSUR P DECOMP NU 13 -5/8" "GK HYDRILL BO PE - INSTAL LNEW NIPPLES & SWINGS ON BAG -MU KOOMY LINES, REPLACE SWIVEL ON HCR, - INSTALL NEW STUDS ON CHOKE BLOCK. 8/9/2010 00:00 - 01:30 1.50 BOPSUR P DECOMP NU 13 -5/8" "GK" HYDRILL BOPE - INSTAL NEW NIPPLES & SWINGS ON BAG -MU KOOMY LINES, REPLACE SWIVEL ON HCR, - INSTALL NEW STUDS ON CHOKE BLOCK. Printed 9/20/2010 5:06:07PM b :. Worth America. AE ASKA BP "' Page �f 9 ' �lQ �ranmary R6port - :. " AR ,,: Common Well Name: MPK -30 AFE No Event Type: WORKOVER (WO) Start Date: 8/8/2010 End Date: X4- OORF7 -E (700,000.00) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 10/19/1996 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292271100 Active Datum: 19 : 30 6/28/1998 20:05 @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 03:00 1.50 BOPSUR P DECOMP NU BOPE'S - REPLACE 1 QT BLADDER BOTTLE FROM ANNULAR. -BRING TONGS TO RIG FLOOR - FUNCTION TEST 03:00 - 04:00 1.00 BOPSUR P DECOMP WEELY SAFETY MEETING WITH CREW: - NABORS VIDEO FOR MAKE UP & BREAK OUT TONG SAFETY. - REVIEWED PREVIOUS WEEKS INCIDENTS ON 4ES. - REVIEWED WELL CONTROL, DROPPED OBJECTS & PERSONAL SAFETY. 04:00 - 06:00 2.00 BOPSUR P DECOMP RIGGING UP FOR BOP TESTING -MU 2 -7/8 ", 3 -1/2" TEST JOINTS -BRING SLIPS &'ELEVATORS TO RIG FLOOR RU TESTING EQUIPMENT 06:00 - 06:30 0.50 BOPSUR P DECOMP RIG SERVICE AND PERFORM PRE -TOUR CHECKS. 06:30 - 07:00 0.50 BOPSUR P DECOMP FINISH R/U TESTING EQUIPMENT. 07:00 - 14:30 7.50 BOPSUR P DECOMP STARTED BOP TESTS 13 -5/8" HYDRILL 5M BOP TEST AS FOLLOWS BaP TEST BOPE TO 250 PSI LOW AND 3,500 PSI HIGH. -TEST BLINDS, CHOKE MANIFOLD VALVES, CHOKE AND KILL LINE VALVES, -FLOOR VALVES, 2 -7/8" X 5" VBR'S, ANNULAR PREVENTER. -TEST VBR'S AND ANNULAR PREVENTER WITH 2 -7/8" TEST JOINT. -AOGCC WITNESSING OF TEST WAIVED BY BOB NOBLE @ 19:20 8/6/2010 -TEST WITNESSED BY BP WSL, NABOR'S TOOL PUSHER & NABORS DRILLER - PERFORM KOOMEY DRAW DOWN TEST -200 PSI BUILD UP TO 1800 PSI FROM 1600 PSI = 45 SECONDS. -FULL BUILD UP TO 3000 PSI = 193 SECONDS. -4 BOTTLES x 2050 PSI. 14:30 - 15:00 0.50 BOPSUR P DECOMP PJSM -R/D TEST EQUIPMENT -HANG ESP SHEAVE AND ESP CABLE TRUNK IN DERRICK -N /U DUTCH SYSTEM TO ANNULAR. 15:00 - 17:00 2.00 BOPSUR P DECOMP PJSM - WELLSUPPORT -P /U M/U LUBRICATOR -TEST DUTCH LUBRICATOR SYSTEM -250 PSI LOW / 2700 PSI HI,CHARTED BOTH F/ 5 -MIN. GOOD TESTS -PULL TWC TBG AND IA ON A VACUUM. -L /D LUBRICATOR AND DUTCH SYSTEM 17:00 - 18:00 1.00 WHSUR P DECOMP M/U LANDING JOINT WITH TIW VALVE AND XO -FMC WELL HEAD TECH TO BOLDS -IA ON A VACUME -PULL HANGER OFF = 83K -LD LANDING JOINT AND HANGER Printed 9/20/2010 5:06:07PM ' N.rrt l,Arne lbq - ALASKA - BP Page of 9 C?peration, SurnmaRe�or# Common Well Name: MP -30 AFE No Event Type: WORKOVER (WO) Start Date: 8/8/2010 End Date: X4- OORF7 -E (700,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 10/19/1996 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292271100 Active Datum: 19: 30 6/28/1998 20:05 @56.30ft (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 WHSUR P DECOMP CIRCULATE A TUBING VOL PLUS 20 BBLS -3.5 BPM @ 1010 PSI -GOT RETURNS AT 60 BBLS -LOSS RATE OF 120 BPH DURING CIRCULATION - RECIEVED THE OK FROM TOWN TO STOP THE CIRCULATION THERE. 20:00 21:30 1.50 PULL P DECOMP T OH W/ 2 -7/8 ", 6.5#,L-80 EUE TUBING -POH RACKING BACK IN THE DERRICK WITH ONE STAND ATTACH ESP CABLE TO SPOOLER - CONTINUOUS HOLE FILL @ —20 BPH. - MONITORING TRIP SHEET & KEEPING ACCURATE STRAP OF FLUIDS. (RIG EVAC DRILL:) - DRILLER CALLED THE DRILL ALL CREW MEMBERS MUSTERED TO THE CORRECT MUSTER AREAL, ALERTING THE THIRD PARTY TRUCK DRIVER ON LOCATION. AAR: IDENDTIFIED THE LACK OF THE DRILL BEING CALLED OUT OVER THE HARMONY RADIO SYSTEM 21:30 - 00:00 2.50 PULL P DECOMP CONT: -TOH W/ 2 -7/8 ", 6.5#,L-80 EUE TUBING -POH RACKING BACK IN THE DERRICK. - ATTACH ESP CABLE TO SPOOLER - CONTINUOUS HOLE FILL @ —20 BPH. - MONITORING TRIP SHEET & KEEPING ACCURATE STRAP OF FLUIDS. (CAMP FIRE DRILL CALLED:) -CREW MUSTERED TO THE RIG CAMP FOR ASSISTANCE MOC PHONE CALLS WERE MADE TO THE CORRECT PEOPLE, -MP SECURITY, RWO SUPERINTENDENT. AAR: -DRILL WENT EXACTLY AS PLANNED, EACH RIG PERSONELL CARRIED OUT HIS TASK CORRECTLY 8/10/2010 00:00 - 01:00 1.00 PULL P DECOMP CONT: -TOH W/ 2 -7/8 ", 6.5#,L-80 EUE TUBING -POH RACKING BACK IN THE DERRICK. - CONTINUOUS HOLE FILL @ —20 BPH. - MONITORING TRIP SHEET & KEEPING ACCURATE STRAP OF FLUIDS. 01:00 - 02:00 1.00 PULL P DECOMP -TOH W/ 2 -7/8 ", 6.5#,L-80 EUE TUBING, 28 STANDS — 3400 TO FIRST SPLICE -ESP CABLE REEL TO REEL CHANGE OUT. 02:00 - 06:00 4.00 PULL P DECOMP CONT: -TOH W/ 2 -7/8 ", 6.5#,L-80 EUE TUBING F/ 28 STANDS -POH RACKING BACK IN THE DERRICK - CONTINUOUS HOLE FILL @ —20 BPH. - MONITORING TRIP SHEET & KEEPING ACCURATE STRAP OF FLUIDS -93 STANDS OUT OF HOLE. 06:00 - 06:30 0.50 PULL P DECOMP RIG SERVICE AND PERFORM PRE -TOUR CHECKS. Printed 9/20/2010 5:06:07PM liirkh America = AL BF' _ ; pate 4 0 I C}peration Summary,, Report Common Well Name: MPK -30 AFE No Event Type: WORKOVER (WO) Start Date: 8/8/2010 End Date: X4- OORF7 -E (700,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 10/19/1996 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292271100 Active Datum: 19: 30 6/28/1998 20:05 @ 56.30ft (above M ean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 08:00 1.50 PULL P DECOMP CONT: -TOH W/ 2 -7/8 ", 6.5#,L-80 EUE TUBING F/ 93 STANDS -POH RACKING BACK IN THE DERRICK CONTINUOUS HOLE FILL @ —20 BPH. - MONITORING TRIP SHEET & KEEPING ACCURATE STRAP OF FLUIDS -327 JTS OUT OF HOLE. - MONITER WELL AT THE ESP. - RECOVERED: 173 = LASALLE CLANPS, 5 = PROTECTOLIZERS, 3 = FLAT GUARDS. 08:00 - 10:30 2.50 PULL P DECOMP PJSM -BO / LD ESP PUMP AND MOTOR ASSEMBLY. -SCALE ON ESP ASSEMBLY NO DAMAGE OR FAILURE NOTED. 10:30 12:00 1.50 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR OF ESP EQUIPMENT. -PLACE ESP PUMP AND MOTOR IN SHIPMENT BOXES IN PIPE SHED. 12:00 - 12:30 0.50 PULL P DECOMP PJSM- R/D ESP CABLE TRUNK. 12:30 - 16:00 3.50 PULL P DECOMP PJSM- P/U M/U 3 -1/2" KELLY AND SWIVEL XO AND UPPER KELLY VALVE RU TEST EQUIPMENT PRESSURE TEST T/ 250 LOW / 3,500 PSI, CHART BOTH F/ 5 -MIN. GOOD TEST -RD TEST EQUIPMENT, WU KELLY HOSE. -RACK BACK KELLY. 16:00 - 17:00 1.00 WHSUR P DECOMP INSTALL 6.125" WEAR RING -PU BHA TOOLS TO RIG FLOOR. 17:00 - 18:00 1.00 FISH P DECOMP CONDUCT A "MAN DOWN' DRILL. AAR: -CREW FAMILIARIZED WITH NEW AED - LITTER NOW LOCATED IN CHANGE ROOM. 18:00 - 18:30 0.50 FISH P DECOMP SERVICE RIG, CHECK CROWN O MATIC, OK. 18:30 - 20:30 2.00 FISH P DECOMP PJSM. PICK UP BHA: HALLIBURTON PACKER RET TOOL BUMPER SUB 9 4 3/4" DC PUMP OUT SUB. 20:30 - 23:00 2.50 FISH P DECOMP RIH W/ PACKER RET TOOL ON 3 V2" DP, PICKING UP DP FROM PIPESHED 1 X 1. 23:00 - 23:30 0.50 FISH P DECOMP BOP DRILL, UNANNOUNCED, W/ RIH WITH DP. DRILLER CONDUCTED DRILL WHILE MOTORMAN WAS ON BRAKE HANDLE SAFETY VALVE STABBED & TORQUED, WELL SHUT IN AND SECURED WITH ALL HANDS AT THEIR RESPECTIVE STATIONS, 1 MIN AND 52 SEC. AAR, NO ISSUES, GOOD RESPONSE. 23:30 - 00:00 0.50 FISH P DECOMP CONTINUE TO RIH W/ 3 1/2" DP AND PACKER RET ASSEMBLY, 80 JTS IN. 8/11/2010 00:00 - 06:00 6.00 FISH P DECOMP CONTINUE TO RIH W/ PACKER RET ASSEMBLY ON 3 V2" DP, SINGLING IN FROM PIPE SHED. - CONSTANT HOLE FILL @ 20 BPH, SEAWATER, W/ RIH T/ JT# 248. 06:00 - 06:30 0.50 FISH P DECOMP RIG SERVICE AND PERFORM PRE -TOUR CHECKS. Printed 9/20/2010 5:06:07PM North - America - ALASKA - BP = age f 9 Operation Summary Report - Common Well Name: MPK -30 AFE No Event Type: WORKOVER (WO) Start Date: 8/8/2010 End Date: X4- OORF7 -E (700,000.00) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 10/19/1996 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292271100 Active Datum: 19: 30 6/28/1998 20:05 @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 - 07:00 0.50 FISH P DECOMP M/U TIW VALVE AND PUMP 30 BBLS SEAWATER -DOWN THE TBG AT 3 -1/2 BPM / 700 PSI -TO FLUSH RUST AND PIPE DOPE OUT. 07:00 - 09:30 2.50 FISH P DECOMP CONTINUE TO RIH W/ PACKER RET ASSEMBLY ON 3 V2" DP, SINGLING IN FROM PIPE SHED. - CONSTANT HOLE FILL @ 20 BPH, SEAWATER, W/ RIH F/ JT# 248 T/ JT# 320. 09:30 10:30 1.00 FISH P DECOMP PJSM: CUT AND SLIP 89' DRILLING LINE. -HELD D -1 DRILL, CREW ON STATION 1 MIN 20 SEC -AAR: WHEN MOVING FLUID IN PITS, WAIT FOR DRILLER TO REPEAT MESSAGE ON RADIO. 10:30 - 11:00 0.50 FISH P DECOMP CONTINUE RIH W/ PACKER RET ASSEMBLY F/ JT #320 T/ JT #326 11:00 - 14:00 3.00 FISH P DECOMP PJSM: WITH CREW AND HES REP. DISCUSS TOOL JOINT ACROSS BLIND SHEAR RAM WITH DRILUTOOLPUSHER. -RIH F /JT# 326 T /JT# 328 -PU KELLY AND PUP(23.90'), PUW =160K, SOW =94K -TAG PACKER AT 10,529'W/ 5K DOWN. - PUW =170K TO CONFIRM LATCH. THEN SET DOWN 11 K. - PUMPED 8 BBLS TO FILL IA. SEAL ON PACKER RETRIEVING TOOL HOLDING. - CIRCULATE ACROSS THE TOP OF WELL TO MONITOR WELL, NO LOSSES. - OBSERVE TOOL SHEAR DOWN @80K AND UP @ 180K. -PULL 225K (65K OVER) TO FREE PACKER -LOST RETURNS, CLOSED ANNULAR. -BULL HEAD DOWN THE IA (10.5 BBLS) @ 1/2 BPM / 900 PSI, PRESSURE BUILDING. -STOP BULL HEAD, 10 MIN TO BLEED TO "0" PSI. -WORK PIPE UP / DOWN, LET PACKER ELEMENTS RELAX FOR 30 -MIN WITH WELL SHUT -IN. PACKER FREE W/ 180 PUW. 14:00 20:00 6.00 FISH P DECOMP CIRCULATE DOWN THE TBG THROUGH THE CHOKE / GAS BUSTER TO PITS. -2 BPM / 300 PSI, 3 BPM /700 PSI, RETURNS W/ 30 BBLS PUMPED. i -58 BBLS AWAY AND LOST RETURN AT 4 BPM / 1090 PSI - PUMPED 20 BBLS AT 2 BPM / 300 PSI W/ NO RETURNS. -PUMPS OFF, WORK PIPE, IA ON A VACUUM NOW. -WORK PIPE A FEW MORE TIMES. - RESUME CIRCULATING 2 BPM / 290 PSI, GOT RETURNS W/ 12.5 BBLS AWAY. -WITH A 50% LOSS RATE. (2 BPM) IN (1 BPM OUT) PRESSURE AND RATE HOLDING CONSTANT DURING CIRCULATION. - PUMPED A TOTAL OF 560 BBLS SEAWATER. Printed 9/20/2010 5:06:07PM North America ALASKA BP - Pace 8 of N , ' P' 8- ry Report Common Well Name: MPK -30 AFE No Event Type: WORKOVER (WO) Start Date: 8/8/2010 End Date: X4- OORF7 -E (700,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 10/19/1996 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292271100 Activ Datum: 19: 30 6/28/1998 20:05 @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 22:00 2.00 FISH P DECOMP MONITOR WELL, STABLE. OPEN ANNULAR PREVENTOR. - PULL (2) SINGLES & LAY DOWN SAME, UP WT - 175,000 #. - PULL (4) STANDS, OBSERVING SOME BIT OF SWABBING WHILE PULLING SLOWLY. -FLUID LEVEL DROPPING STEADILY AFTER EACH STAND PULLED & PUMP OFF. 22:00 - 23:30 1.50 FISH P DECOMP PJSM. DROP DART & PUMP DOWN 28 BBLS - OBSERVE PUMP OUT SUB SHEAR @ 2100 PSI - BRING PUMP RATE UP TO 4 BPM / 1050 PSI .WHILE CIRCULATING, - 1 BPM LOSS RATE C T , CBU, WELL STABLE. 23:30 00:00 0.50 FISH P DECOMP POOH W/ 3 1/2" DP, (SLOWLY), MONITORING FOR SWABBING. NO SWABBING. 8/12/2010 00:00 - 06:00 6.00 FISH P DECOMP CO NTINUE TO POOH W/ 3 1/2" DP & HALLIBURTON_PACK AND SCRE ASSEMBLY � WELL IS TAKING FLUID. PUMPING IN 20 - 25 BPH OVER PIPE DISPLACEMENT. 90 STANDS OUT. 06:00 - 08:00 2.00 FISH P DECOMP = CONTINUE POH F/ STAND #90 TO #109 08:00 - 09:30 1.50 FISH P DECOMP PJSM: UD 7" VTA PACKER / SCREEN ASSEMBLY. - LIGHT SCALE BUILD UP ON OD / ID OF SCREENS. 09:30 - 10:00 0.50 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR -COVER SCREENS WITH PLASTIC WRAP FOR TRANSPORT OFF LOCATION. 10:00 - 10:30 0.50 FISH P DECOMP RIG SERVICE AND PERFORM PRE -TOUR CHECKS. 10:30 - 11:00 0.50 BOPSUR P DECOMP PSJM: -MU RETRIEVING TOOL AND PULL WEAR RING. 11:00 - 14:30 3.50 BOPSUR P DECOMP PSJM - INSTALL TEST PLUG -PU 2 -7/8" TEST JOINT, RU TEST EQUIPMENT. Q�P -TEST ANNULAR PREVENTOR TO 250 / 3,500 PSI -FOR 5- CHARTED MINUTES. -LD TEST JOINT, RETRIEVE TEST PLUG. - INSTALL 6.125" WEAR RING. 14:30 15:30 1.00 CLEAN P DECOMP PJSM. PICK UP CLEAN OUT BHA INCLUDING: - BIT, SCRAPER, (2) JUNK SUBS, BIT SUB, BUMPER SUB AND (9) DC - OVERALL LENGTH = 298.24' 15:30 - 20:00 4.50 CLEAN P DECOMP PJSM. RIH W/ CLEAN OUT ASSEMBLY ON 3 1/2" - PUMPING IN WELL BORE, (SEAWATER), @ 20 BPH W/ RIH - RECIPROCATE SCRAPER 10,487'- 10,559'. - CONTINUE IN TO 10,777', NO FILL ENCOUNTERED. 20:00 - 20:30 0.50 CLEAN P DECOMP PJSM. POOH & UD (10) SINGLES 20:30 - 21:00 0.50 CLEAN P DECOMP PJSM. CIRCULATE (1) DP VOLUME @ 3 BPM/ 650 PSI. - 69 BBLS PUMPED, LOST 32 BBLS W/ PUMPING. Printed 9/20/2010 5:06:07PM Ubrfh America - RLl�51fA BP Pa3of mz C? era tion Summary Report Common Well Name: MPK -30 AFE No Event Type: WORKOVER (WO) Start Date: 8/8/2010 End Date: X4- OORF7 -E (700,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 10/19/1996 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292271100 Active Datum: 19 : 30 6 /28/1998 20: @56 Oft (above can Sea Level) Date From - To Hrs Task ode NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 00:00 3.00 CLEAN P DECOMP PJSM. POOH W/ 3 1/2" DP AND CLEAN OUT ASSEMBLY. - PUMP IN TO WELL BORE, (SEAWATER), @ 20 -25 BPH OVER PIPE DISPLACEMENT. 8/13/2010 00:00 - 03:00 3.00 CLEAN P DECOMP CONTINUE TO POOH W/ 3 1/2" DP AND CLEAN OUT ASSEMBLY. - PUMPING IN TO WELL @ 20 BPH, (SEAWATER), OVER PIPE DISPLACEMENT. 03:00 - 04:30 1.50 CLEAN P DECOMP PJSM. UD CLEAN OUT BHA, JUNK SUBS CLEAN. 04:30 06:00 1.50 CLEAN P DECOMP CLEAN FLOOR, BRING SCREENS AND PACKER INTO PIPESHED. - PREP TO RUN PACKER / SCREEN ASSEMBLY 06:00 - 09:00 3.00 RUNCOM P RUNCMP PJSM: PU PACKER / SCREEN ASSEMBLY. -RU SCREEN MAKE UP TABLE. -RUN: BULL NOSE, (6) 4 -1/2" SCREENS (0.02 "), PUP, OX, 7" HALLIBURTON V.T. PACKER - = 253.20' -RD SCREEN MU TABLE 09:00 - 12:00 3.00 RUNCOM P RUNCMP' 'PJSM: R 7" VTA PACKER / SCREEN ASSEMBLY -ON 3 -1/2" DP FROM DERRICK PER HALLIBURTON REP -1.5 MINUTES PER STAND TO STAND # 38 12:00 - 13:00 1.00 RUNCOM P RUNCMP PTSM: WEEKLY CREW CHANGE FROM TOWN - PERFORM PRE -TOUR CHECKS 13:00 19:00 6.00 RUNCOM P RUNCMP CONTINUE TO RIH WITH RUN 7" VTA PACKER / SCREEN ASSEMBLY ON 3 -1/2" DP FROM DERRICK F/ STAND # 38 T/ STAND #109. - PUMPING IN TO WELL @ 20 BPH, (SEAWATER), OVER PIPE DISPLACEMENT. - PICK UP (10) SINGLES, WU 5' PUP & 1 MORE SINGLE & HEADPIN. - TOP OF PACKER 10,520'.160K UP WT, 88K DOWN WT. - BOP DRILL W/ RIH, WELL SECURED IN 58 SECONDS - ALL HANDS AT STATIONS, VERY GOOD RESPONSE. Printed 9/20/2010 5:06:07PM ort h America - ALASKA BP Page 8 of 9 qw ©peratio>I� S,urnmary; Report s: Common Well Name: MPK -30 AFE No Event Type: WORKOVER (WO) Start Date: 8/8/2010 End Date: X4- OORF7 -E (700,000.00) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 10/19/1996 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292271100 Active Datum: 19: 30 6/28/1998 @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 21:30 2.50 RUNCOM P RUNCMP PJSM. PRESSURE TEST SURFACE LINES TO 3300 PSI, OK. - LINE UP AND PRESSURE DP TO 500 PSI - HOLD 500 PSI FOR 5 MINUTES, OK. - BRING PRESSURE UP TO 2900 FOR 5 MIN. - OBSERVED BOBBLE @ 780 PSI, START TO SET PACKER PICKED UP 1 OK OVER TO 170K AND SLACKED OFF TO 78K. PRESSURE DP UP TO 2900, HOLD FOR A FEW AND ON UP TO 3250 PSI. - HOLD THAT FOR 5 MIN, BLEED OFF ALL PRESSURE. FILL ANNULUS, CLOSE ANNULAR PREVENTOR - PRESSURE 7" ANNULUS TO 1000 PSI / 10 MIN / CHARTED, OK. - BLEED OFF, OPEN BAG & PRESSURE DP TO 3300 PSI - PICK UP TO 165K, SHEARED OFF, RELEASED FROM PACKER. 21:30 - 00:00 2.50 RUNCOM P RUNCMP PJSM. POOH W/ 3 1/2" DP & UD SAME. PUMPING SEAWATER IN TO WELL @ 20 BPH OVER DISPLACEMENT. 8/14/2010 00:00 - 06:00 6.00 RUNCOM P RUNCMP CONTINUE TO POOH & LDDP. PUMPING 20 BPH IN TO WELL OVER PIPE DISPLACEMENT. -L /D 220 JOINTS 06:00 - 07:00 1.00 RUNCOM P RUNCMP PTSM - RIG SERVICE AND PERFORM PRE -TOUR CHECKS. 07:00 - 10:30 3.50 RUNCOM P ' RUNCMP CONTINUE TO POH & LDDP F/ JOINT # 220 T/ 337. -LD PACKER RUNNING TOOL. 10:30 - 11:00 0.50 WHSUR P_ RUNCMP PULL WEAR RING WITH RETRIEVING TOOL. 11:00 - 12:30 1.50 RUNCOM P RUNCMP LD 3 -1/2" DP HANDLING EQUIPMENT 12:30 - 13:30 1.00 RUNCOM P RUNCMP CLEAN AND CLEAR RIG FLOOR -LOAD ESP ASSEMBLY IN TO PIPE SHED. 13:30 18:00 4.50 RUNCOM P RUNCMP PJSM WITH CENTRILIFT AND CREW. -CHECK ALL LIFTING DEVICES BE FOR THE JOB PU MU AND SERVICE ESP ASSEMBLY -PULL ESP CABLE OVER SHEAVE IN DERRICK. 18:00 - 18:30 0.50 RUNCOM P RUNCMP SERVICE RIG, PERFORM TOURLY CHECKS. 18:30 00:00 5.50 RUNCOM P RUNCMP RIH W/ ESP COMPLETION STRING AS PER PROGRAM. - MEG CABLE EVERY 2000'& PUMP DOWN TBG @ 1 BPM / 10 BBLS USE BEST 0 LIFE 2000 PIPE DOPE TORQUE ALL 2 7/8" EUE 8 RND CONNECTIONS @ 2300 FT /LBS. USING LA SALLE CLAMPS Printed 9/20/2010 5:06:07PM Nbrth America - ALASKA - BP . Page 9 of s, ©pera #ion Summary Report Common Well Name: MPK -30 AFE No Event Type: WORKOVER (WO) Start Date: 8/8/2010 End Date: X4- OORF7 -E (700,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 10/19/1996 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292271100 Active Datum: 19: 30 6/28/1998 20:05 @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/15/2010 00:00 - 02:00 2.00 RUNCOM P RUNCMP CONTINUE TO RIH W/ 2 7/8" EUE 8 RND TUBING & ESP COMPLETION ASSEMBLY. - CHECKING CONDUCTIVITY OF CABLE EVERY 2000' - PUMPING DOWN TBG, (10 BBLS) @ 1 BPM EVERY 2000' 75 STANDS IN, (7100'). PUMPING IN TO WELL @ 20 BPH, (SEAWATER). 02:00 - 06:00 4.00 RUNCOM P RUNCMP PJSM. PERFORM SPLICE IN ESP CABLE AND CHANGE OUT REELS. - CHECK CONDUCTIVITY OF CABLE 06:00 - 06:30 0.50 RUNCOM P RUNCMP RIG SERVICE AND PERFORM PRE -TOUR CHECKS. 06:30 - 09:30 3.00 RUNCOM P RUNCMP C ONTINUE TO RIH W /'2 7/8" EUE 8 RND TU BING & ESP COMPLETION ASSEMBLY. - CHECKING CONDUCTIVITY OF CABLE EVERY 2000` -FILL AND FLUSH PUMP (10 BBLS) @ 2 BPM / 280 PSI, EVERY 2000' -F/ STAND # 75 TO JOINT # 325. PUMPING IN TO WELL @ 20 BPH, (SEAWATER) -RAN 171 - LASALLE CLAMPS, 3 -FLAT GUARDS, 5 PROTECTOLIZERS. -24 HRS NOTICE OF BOPE TEST, LEFT MESSAGE 659 -3607 AT 07:45 8/15/2010. 09:30 - 10:30 1.00 RUNCOM P RUNCMP PU 8' PUP, TBG HANGER, LANDING JOINT - AND TIW VALVE. 10:30 12:30 2.00 RUNCOM P RUNCMP INSTALL ESP PENETRATOR CENTRILIFT REP, PERFORM PENETRATOR SPLICE 12:30 - 14:00 1.50 RUNCOM P RUNCMP LAND TBG HANGER -PUW = 70 K, SOW = 47 K -FMC REP RILDS AND DRY ROD TWC. - TESTED TWC FROM ABOVE TO 3,500 PSI FOR 10 CHARTED MINUTES. - PERFORM A ROLLING TEST FROM BELOW 3 BPM / 60 PSI. 14:00 15:00 1.00 RUNCOM P RUNCMP WEEKLY SAFETY MEETING. RIG TONG TRAINING. - TENETS OF OPERATIONAL EXCELLENCE - ADW INCIDENT REVIEWS 15:00 - 17:00 2.00 BOPSUR P RUNCMP PJSM- SUCK -OUT BOP STACK -ND BOPE 13 -5/8 BOP STACK. 17:00 - 18:30 1.50 WHSUR P RUNCMP PJSM. N/U TREE. 18:30 - 20:30 2.00 WHSUR P RUNCMP PJSM. TEST VOID @ 5000 PSI 130 MINUTES / CHARTED, GOOD TEST. 20:30 - 23:00 2.50 WHSUR P RUNCMP P/U LUBRICATOR, TEST TO 500 PSI / 5 MIN / CHARTED PULL TWC, SET BPV TEST BPV FROM BELOW, PUMPING 3 BPM FINAL PRESSURE ACHEIVED BELOW BPV - 130 PSI - 57 BBLS TOTAL PUMPED 23:00 - 00:00 1.00 WHSUR P RUNCMP SECURE WELL, CLEANUP AROUND WELLHEAD RIG RELEASED @ 00:00 HRS, 08/15/2010. Printed 9/20/2010 5:06:06PM STATE OF ALASKA ~ ~ !~ ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS AUG ~ 7 200 1. Operations Performed: AfiG~OC3 ~ e ^ Abandon ®Repair Well nded Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Susp ^ 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 196-188 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22711-00-00 - 7. KB Elevation (ft): KBE = 56.95' - 9• Well Name and Number: MPK-30 8. Property Designation: 10. Field /Pool(s): ADL 375132 ~ Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 11145 - feet true vertical 7306 - feet Plugs (measured) 10784' Effective depth: measured 11041 feet Junk (measured) N/A true vertical 7257 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' Surface 6621' 9-5/8" 6652' 4908' 6870 4760 Intermediate Production 11094' 7" 11122' 7295' 7240 5410 Liner ~y i ~~~~ ~ ~. ~ ~ ~ ~ U U EI Perforation Depth MD (ft): 10588' - 10748' Perforation Depth TVD (ft): 7025' - 7111' - 2-7/8", 6.5# L-80 10458' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" HES Versatrive with two 4-1/2" Poroplus screen 10526' assemblies at 10576' and 10745' 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 Subsequent to operation: 273 105 2235 200 285 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: _ ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil - ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Howard West, 564-5471 N/p Printed Name. Sondra Stewman Title Drilling Technologist Prepared By NameMumber (~`~F2 ~ 7 Si lure Phone 564-4750 Date . 17 Sondra Stewman 564-4750 ion Form 10-404 Revised 04/2006 Submit Original ly ('~` "`- , \ 4 1 Tree: 2 9/16" - 5M FMC ~ MPU K-30 (Kup.) Wellhead: 11" x 7" 5M FMC Gen 5a w/ 2 7/8" WKM Tubing Hanger , w/ 3" L.H. Acme Threads , 2.5" CIW H BP profile 20" 91.1 ppf, H-40 115' KOP ~ 400' Max. hole angle = 57 to 62 deg. f/ 3650 to11,041' (PBTD) Hole angle thru' perfs = 58 deg 9 5/8", 47 ppf, 6653' btm 44 jts. P-110 Btrc. next 6 jts. L-80 Mod. Btrc. top 109 jts L-80 NSCC Two 21' x 7" short joints f/ 10,255'-10,297' wlm. 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btrc. prod. casing ( drift I D = 6.151 ", cap. = 0.0383 bpf ) Mid-pert TVD = 7075' Mid-perf MD = 10681' PBTD TVD = 7316 PBTD MD = 11041' Stimulation Summary none (selectively perforated rather than frac packed) Perforation Summary Ref lou: 11/25/96 GR/CCL Size SPF Interval TVD Kup 'C' Sand 4.5" 5 10,588'-10,658' 7024'-7063' Kup 'B' Sand 4.5" 5 10,704'-10,748' 7088'-7111' Orig.d~lev. = 57.5' (N 22E) Orig. GL Elev. = 28.0' DF To 7" csg. hng. = 28.5' (N 22E) Camco 2-7/8" x 1" 138' sidepocket KBMM GLM 9 5/8" Howco'ES' 2479' Cementer Camco 2-7/8" x 1" 10,206' sidepocket KBMM GLM 2-7/8" XN nipple 10 353` (ID 2.205") , Pump, 100 - P31 10 396` Model - SXD tungsten coated , Gas Separator 10 416` Intake @ 6926' TVD , Tandem Seal Section ` Model OSB3 DB UT/LT AB/AB 10,421 PFSA/FSA CL5 Motor, 228 HP, 2305 volt, 10 435` 60 amp, 562 Series KMH , PumpMate w/6 fin Centralizer 10,454` 7" HES Versatrieve Pkr 10526' 4.5" Weatherford Duragrip 10576' .020 gauge Screen (Top) blank pipe 10660'- 10705' 4.5" Weatherford Duragrip 10745' .020 gauge Screen (Bottom) 4.5" Bull plug 10784' 7" float collar (PBTD) 11041' 7" float shoe 11122' 11/27/96 06/15/98 JBF M. Linder Initial ESP completion by Nabors 4ES RWO Screens added/ Pig tail pull & land )4/05/02 B. Haseb RWO Nabors 4ES 05/05/04 J. Cubbon RWO Nabors 4ES 10/6/07 REH ESP RWO- 4ES 8/3/08 L Hulme ESP RWO & replace screens - 3S MILNE POINT UNIT WELL K-30 API NO: 50-029-22711 BP EXPLORATION (AK) Page 1 'of 1 • • Well: MPK-30 Well History Well Date Summary MPK-30 5/5/2008 T/I/0=400/500/180 (Freeze Protect) Pumped 15 bbls Diesel down tubing. Pumped 2 bbls Diesel and 3 bbls 60/40 methanol down production and test flowlines. Closed lateral valves and bleed pressure down to 0 psi on flowlines. FWHP=0/500/180 MPK-30 5/10/2008 *** WELL SI ON ARRIVAL *** (Pre RWO) PULLED 1" BK-DGLV FROM 10211' MD, LEFT POCKET OPEN (Scale on latch) PULLED 1" BEK-DPSOV FROM 137' MD, SET 1" BK-DGLV. (Scale restricting latch and lower check completely scaled off) ***CONTINUE ON 5/11/08 *** MPK-30 6/1/2008 T/I/0=959/830/140,.( ESP Acid Treatment) Pumped 10 bbls Dead Crude , 3 bbls 60/40 methanol and 10 bbls 7.5% Acid followe y s methanol and 55 bbls Dead Crude down tubing. Let soak at pump for thirty minutes. Displaced into formation with 25 bbls Dead Crude and 90 bbls Produced Water. Continued on 06-02-08 WSR, MPK-30 6/2/2008 (ESP Acid Treatment) Continued from 06-01-08 WSR. Pumped remaining 90 bbls produced water for displacement down tubing. Pumped 15 bbls 60/40 methanol for freeze protect. Well left S/I FW H P=0/980/200 MPK-30 6/5/2008 Well Suaoort Techs ripped up and set a BPV after an acid wash on the tba was performed. The hanger may need to be replaced during the RWO due to the problems encountered with scale in the profile and the need to acidize the tubing to set the BPV. ****NOTE***** BPV set. MPK-30 7/23/2008 Support Techs pulled wellhouse,flowlines and foundation for Nabors Rig 3S. BPV in hole MPK-30 7/29/2008 ***SURFACE WORK 3S*** SET 1 "BEK-DPSOV IN SPM TO BE RUN ON TOP (MARKED AND FLAGGED) VERIFIED 1" BK-DGLV IN SPM TO BE RUN ON BOTTOM (MARKED "dummy") ***NOTIFIED COMPANY REP OF STATUS OF MANDRELS*** MPK-30 8/5/2008 Freeze Protect Post RWO Job postponed. MPK-30 8/6/2008 The Well Support Techs rigged up and set the foundation, flowlines and the wellhouse. They then pulled the back pressure valve and leak tested the flowlines to 1150 psi. NOTE: The BPV was left OUT and the leak test was GOOD!!!! MPK-30 8/6/2008 Freeze Protect post RWO T/I/0= 0/0/150 Pumped 15 bbls Dead Crude down tubing. Pumped 65 bbls Dead Crude down IA. FWHP= Wing, Swab,SSV closed. Master, IA, and OA open. Print Date: 8/27/2008 Page 1 of 1 BP EXPLORATION Page 1 of 8 Operations Summary Report Legal Well Name: MPK-30 Common Well Name: MPK-30 Spud Date: 10/19/1996 Event Name: WORKOVER Start: 7/24/2008 End: 8/5/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/5/2008 Rig Name: NABOBS 3S Rig Number: Date 'From - To Hours ~ Task Code NPT Phase Description of Operations 7/24/2008 12:00 - 21:30 9.50 RIGD P PRE Wait on pad prep at MPK-30 due to last minute schedule change. Rig down off of well slot MPG-14. Scope and lower the Derrick at 14:30 hours. Finish RD of modules. Back off of well slot MPG-14 with the Pad Operator present at 20:00 hrs. Prepare to connect modules to the trucks. 21:30 - 23:30 2.00 MOB P PRE Move the Rig and Modules from MPG-Pad to MPK-Pad. 23:30 - 00:00 0.50 RIGU P PRE Arrive on MPK-Pad and move to the backside of the Pad. 7/25/2008 00:00 - 06:00 6.00 RIGD P PRE Spot the Camp and Shop per Siting Assessment. Spot the BOPE behind well slot MPK-30. Lay mats and herculite. Back the Carrier over the well with the Pad Operator present. Spot the Pipe Shed and Pits. RU Handyberm. Raise and scope the Derrick. Accepted the Riq at 06:00 hrs on 7/25/2008. 06:00 - 08:30 2.50 KILL P DECOMP RU circulating lines to the Tree. Take on heated seawater to the Pits. Wait on hardline crew from GPB to arrive to RU return line to the Tiger Tank. 08:30 - 10:00 1.50 WHSUR P DECOMP RU Lubricator and ressure test to 500 si with diesel I Support Techs. Pull 2" Type "H" BPV. Note the WHPs: Tbg = 0 psi , IA = 900 psi , OA = 160 psi. LD Lubricator. 10:00 - 10:30 0.50 KILL P DECOMP Hold pre-spud and pre-kill safety meeting with the crew. Discuss the workover as a whole and discuss in detail the kill procedure. Wait on the hardline crew from GPB. 10:30 - 11:30 1.00 KILL P DECOMP Hardline crew arrives on location. RU hardline to the Tiger Tank. 11:30 - 12:00 0.50 KILL P DECOMP Pressure test the downstream line to the Tiger Tank to 500 psi - OK. Pressure test all surface lines and equipment to 3,500 psi - OK. 12:00 - 16:00 4.00 KILL P DECOMP O en the well to a closed Choke. SITP = 0 si SICP = 900 psi. Break circulation with hot seawater down the Tubing taking returns up the IA at a rate of 2 bpm / 30 psi on the Tubing with 180 psi on the IA. Increase rate to 3 bpm / 240 psi on the Tubing and 190 psi on the IA. Pumped a total of 75 bbls. Close returns and bullhead 30 bbls of seawater into the formation at a rate of 3 bpm / 300 psi. The IA came up to 290 psi. Open the Choke and resume circulating to the Tiger Tank with hot seawater. Initial returns are thick crude and a roximatel 67% returns. The returns rate fell down throughout the circulation as more seawater was circulated into the well. Circulate until seawater returns observed on surface. Pumped a total of 525 bbls of seawater to clean up the IA (IA volume = 310 bbls). Total returns to surface were 281 bbls - approximatel 47%. 16:00 - 16:30 0.50 KILL P DECOMP Shut down and monitor the well. SITP = 0 psi ,SICP = 0 psi. Open the IA and it is on a vacuum. 16:30 - 17:00 0.50 KILL P DECOMP Blow down and RD circulating lines from the Tree. Check the Tubing and it is on a vacuum. 17:00 - 20:00 3.00 WHSUR P DECOMP PU T-bar and set 2" Type "H" TWC with FMC rep. Test TWC rom a ove to psi or carte minutes. Good test (Made repeated attempts to get a solid 10 min test) 20:00 - 21:00 1.00 WHSUR P DECOMP ND production Tree. Tubing hanger void was bled to 0 psi, FMC rep noted that more than the normal volume of (contaminated) fluid was released. Some scale was found when the Tree was removed. Hanger threads = 3" LH Acme. Screw XO onto Hanger to check the threads - OK. Printed: 8/25/2008 2:08:54 PM • • BP EXPLORATION Page 2 of 8 Operations Summary Report Legal Well Name: MPK-30 Common Well Name: MPK-30 Spud Date: 10/19/1996 Event Name: WORKOVER Start: 7/24/2008 End: 8/5/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/5/2008 Rig Name: NABOBS 3S Rig Number: Date ~ From - To Hours !, Task Code NPT Phase Description of Operations 7/25l2008 21:00 - 00:00 3.00 BOPSU P DECOMP -- PU BOP from shipping cradle and NU BOPE and DSA, flow riser and accumulator hoses. 7/26/2008 00:00 - 03:00 3.00 BOPSU P DECOMP Continue to NU BOPE. 00:30 - 01:00 0.50 BOPSU P DECOMP Fill BOPE and function BOPE components. 01:00 - 05:00 4.00 BOPSU P DECOMP Test BOPE 250 psi / 3,500 si with 2-7/8" and 3-1/2" test joints per BP/AOGCC Regulations. Test witnessed by NAD toolpusher and BP WSL. The State's right to witness the test was waived by Bob Noble at 17:00 hrs on 7/25/2008. 05:00 - 06:00 1.00 BOPSU P DECOMP Blow down lines and drain BOP stack. 06:00 - 06:30 0.50 WHSUR P DECOMP Pre-tour checks and service the Rig. 06:30 - 07:30 1.00 WHSUR P DECOMP PUMU Opso Lopso and Lubricator with Well Support Techs. Pressure test to 500 psi with diesel - OK. Pull 2" Type "H" TWC. The Tubing is on a vac. Check the IA and it is also on a vac. 07:30 - 08:30 1.00 PULL P DECOMP PUMU 3-1/2" Landing Joint with 3" LH Acme XO on bottom and TIW valve with circulating hose on top. Screw into the Hanger with 8-1/2 turns. BOLDS with FMC rep. Pull the Hanger off seat and to the Ri Floor with a PUW = 72K. 08:30 - 09:00 0.50 PULL P DECOMP Flush the Tubing with hot seawater at a rate of 2.5 bpm / 300 psi. Pumped a total of 75 bbls of seawater. RU Elephant Trunk. 09:00 - 16:00 7.00 PULL N HMAN DECOMP While POOH with the Hanger and completion, observed the Tubing string rubbing on the off-driller's side bushing. Check the level of the Rig and it is not level. Discuss issue with rig leadership team and superintendents and decision made to re-level the Rig. Land the Hanger and RILDS with FMC rep. Close the Blind Rams. Continue feeding the IA with 15 bbls of seawater er hour. RD Elephant Trunk. Scope and lower the Derrick at 11:30 hrs. 16:00 - 16:30 0.50 PULL C DECOMP Have inspector on location to function test bridge cranes in the Cellar. Visually inspecting the Tugger Sheaves in the Derrick as well as inspect the Derrick as a whole. 16:30 - 17:30 1.00 PULL N DECOMP PUMU 3-1/2" Landing Joint with 3" LH Acme XO on bottom and TIW valve on top. Screw into the Hanger with 8-1/2 turns. BOLDS with FMC rep. Pull the Hanaar off seat and to the Ria Floor with aPUW = 72K. Break out and lay down Tubing Hanger and Landing Joint. 17:30 - 22:00 4.50 PULL P DECOMP POOH with existing ESP Completion laying down 2-7/8" Tubing in the Pipe Shed. Maintain 15 bbl/hour fill rate while POOH to joint 85 (2,700') at 22:00 hrs. 22:00 - 23:00 1.00 PULL P DECOMP Change out cable spools in spoiling unit at splice. 23:00 - 00:00 1.00 PULL P DECOMP Continue to POH / LD 2-7/8" tubing from joint 85 (-2,700') to joint 110 (-3,500'). 7/27/2008 00:00 - 09:00 9.00 PULL P DECOMP POH with existing ESP Completion laying down 2-7/8" Tubing in the Pipe Shed. Maintain 15 bbl/hour fill rate while POH to joint 260 (-8,200') at 05:30 hrs. L/D bent joint (#112). Recovered a total of 327 Joints of 2-7/8" Tubing, 2 GLMs and 1 XN Nipple. None of the Tubing had any evidence of scale and the XN Ni le ID was clean. 09:00 - 12:00 3.00 PULL P DECOMP Break out and lay down existing ESP Assembly with Centrilift rep. Recovered a total of 170 LaSalle Clamps, 5 Protectolizers and 2 Flat Guards. 12:00 - 13:00 1.00 PULL P DECOMP Clear and clean Rig Floor. Maintain 15 bbl per hour seawater Printed: 8/25/2008 2:08:54 PM • BP EXPLORATION Page 3 of 8 Operations Summary Report Legal Well Name: MPK-30 Common Well Name: MPK-30 Spud Date: 10/19/1996 Event Name: WORKOVER Start: 7/24/2008 End: 8/5/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/5/2008 Rig Name: NABOBS 3S Rig Number: Date From - To ~ Hours Task Code NPT Phase Qescription of .Operations 7/27/2008 12:00 - 13:00 1.00 PULL P DECOMP fill rate. 13:00 - 14:30 1.50 PULL P DECOMP Cut and slip 60' of Drilling Line. 14:30 - 16:30 2.00 PULL P DECOMP Load and strap remaining 3-1/2" IF Drill Pipe into the Pine Shed. RD Elephant Trunk. Weld and mount sensors on the Skate with Columbia reps. RU 3-1/2" Handling Equipment. 16:30 - 17:00 0.50 WHSUR P DECOMP Set 6-1/8" ID Wear Ring. PU 7" Halliburton Versatrieve Packer Retrieval Tool. 17:00 - 00:00 7.00 PULL P DECOMP TIH with 7" Halliburton Versatrieve Packer Retrieval Tool on 3-1/2" Drill Pipe from the Pipe Shed. Maintain 15 bbl per hour fill rate with seawater while TIH to 170 joints (5,330' MD). Clear DP at _2,200' MD, 2 bpm / 1000 psi. 7/28/2008 00:00 - 05:00 5.00 PULL P DECOMP Continue PU 3-1/2" DP from pipe shed and RIH with packer retrieval tool. Maintain 15 bbl per hour fill rate with seawater while TIH. From 170 joints (-5,330' MD) to 340 joints (-10,546' MD). 05:00 - 06:00 1.00 PULL P DECOMP Pump through Drill Pipe to establish pump parameters at 2 bpm / 920 psi. Milne Point Well Support Techs shoot fluid level in the IA. The fluid level is inconclusive, maybe at -800'. 06:00 - 08:00 2.00 PULL P DECOMP RIH to engage 7" Versatrieve Packer. MU TIW valve arid circulating hose to jet down on top of Packer in case of any fill or debris. Establish parameters: PUW = 125K ,SOW = 80K. RIH and stack wei ht at 20' in on Joint #240 = 10 545' 3SM Pick up and shear the brass pins at 142K. Continue picking up and shear the lug nut housing at 155K. Slack off and set 5K down on the Packer (SOW = 75K). Turn the Drill Pipe to the left three turns on surface to engage the Bowen Spear (need 1/6 of a turn downhole). Pick up to a PUW = 175K (need 30K over to release the Packer and allow the Packer to release and the elements to relax. 08:00 - 11:30 3.50 PULL P DECOMP Wait for 1 hour to allow the elements to relax. Call out Well Support Techs to shoot another fluid level down the IA - _2,000'. Work string weight up to 225K (100K overpull) with no evidence of the Packer bein released. Confer with Anchorage Engineering on plan forward. 11:30 - 12:30 1.00 PULL P DECOMP Line up to pump down the Drill Pipe with seawater. Pump 100 bbls at a rate of 2.25 bpm / 1,350 psi with final pressure~- 1,500 si. Never saw returns. 12:30 - 16:30 4.00 PULL P DECOMP Attem t to ull the Packer and Screen Assembly by pulling up to 225K - no Jo .Work the Pipe and try to release the pear from the Packer Bore by turning to the right. Having difficulty getting off of the Packer. Continue to work the ipe~'in an attempt to get free. 16:30 - 18:00 1.50 PULL P DECOMP on er wit nc orage Engineering on plan forward. Decision made to pull to max pull of 280K. PJSM with the crew on next step. Work the Pipe up in small increments of 5-10K. Pulled free at PUW = 260K and the weight fell off to 87K. Pick up with the ish an o serve = 133 about 8K over riot to latchin Packer . Lay down Joint #340 and make up TIW. 18:00 - 20:00 2.00 PULL P DECOMP Observe well, wait 1/2 hour to allow the elements to relax. Pump 65 bbl seawater down IA, got returns, pumps off IA, on a Vac, RU and pump 20 bbls seawater down DP at 2 bpm / 1220 psi with no returns and DP on a Vac. Circulate across the top of well bore at 1.5 bpm with returns and a loss rate o 42 bph. Pnntetl: 8/25/2008 2:08:54 PM • • BP EXPLORATION Page 4 of 8 Operations Summary Report Legal Well Name: MPK-30 Common Well Name: MPK-30 Spud Date: 10/19/1996 Event Name: WORKOVER Start: 7/24/2008 End: 8/5/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/5/2008 Rig Name: NABORS 3S Rig Number: Date ~ From - To i Hours Task. ~ Code ~ NPT Phase Description of Operations _ ~_ 7/28/2008 18:00 - 20:00 2.00 PULL __ P DECOMP At 18:20 hours, noticed a leak from a 1/2" valve on the IA, resulting in a -4 gal leak. All notices were made and the fluid was cleaned up and disposed of properly. Held stand down and discussed incident with crew. 20:00 - 00:00 4.00 PULL P DECOMP POH slow from -10 525' MD while circulatin across well bore and pulling the first 10 stands, observed swabbing and drag (10-25K) (max pull = 155K) every -40'. Maintain 15 bbl per hour fill rate with seawater while POH slow, 20 stands out at 22:00 hours. (6,520' MD) 65 stands out at 00:00 hours. 7/29/2008 00:00 - 07:30 7.50 PULL P DECOMP Continue to POH slow from 6,520' MD (65 stands) with 3-1/2" DP and possible VTL packer and screen assembly. Maintain 15 bbl per hour fill rate with seawater. Pipe started coming wet at stand 148 BOLDS and BO / LD VTL Packer, 1 joint of 4-1/2" tubin and 2.59 ft of screen. 07:30 - 09:00 1.50 FISH C DECOMP Have morning call with Anchorage Engineering and discuss plan forward. Call out Baker Fishing tools and rep to go in and spear the remaining Fish. 09:00 - 13:00 4.00 FISH C DECOMP Wait on Fishing Tools to arrive on location. Fishing tools arrive at 11:30 hrs. Work on the Upper Pipe Skate Extension with Columbia reps. Perform maintenance and housekeeping projects while waiting. 13:00 - 15:00 2.00 FISH C DECOMP PUMU BHA #1 as follows: ITCO S ear Extension, Extension, Stop Sub, Bumper Sub, Jar, (8) ea 4-3/4" Drill Collars, Intensifier and Pump Out Sub. OAL = 287.64. 15:00 - 21:30 6.50 FISH C DECOMP TIH with BHA #1 on 3-1/2" Drill Pipe from the Derrick to 10,579' 21:30 - 22:00 0.50 FISH C DECOMP R/U circulating head and hose. 22:00 - 23:30 1.50 FISH C DECOMP Establish parameters, up weight 144,000#, down weight 76,000#, 2-1/2 bpm at 250 psi. Wash down, Top of Fish at 10 593', sting in to screen to 10,603'. Start working and jarring pipe with 175,000# working up to 235,000#. Fish parted or came loose at 235 000#. 4,000# of drag coming off bottom. 23:30 - 00:00 0.50 FISH C DECOMP Monitor well and R/D circulating head. 7/30/2008 00:00 - 07:00 7.00 FISH C DECOMP POOH with BHA #1, Spear Assembly and fish. Standing back 3-1/2" DP in the derrick. Maintain 15 b h fill rate with seawater. 07:00 - 10:30 3.50 FISH C DECOMP On surface with BHA #1 and Fish. Break out and lay down Fish with Baker Fishing rep. Recovered 28.50' of the first arted 'oint of screens 31.86' of the second 'oint of screens, 35.95' of 4-1 /2" s ace out u s, and 24.38' of the third 'oint of screens arted . No evidence of sand or scale on an of the com onents. No wash out observed on any of the screens. 10:30 - 11:30 1.00 FISH C DECOMP Confer with Anchorage Engineering. Re-make up the same BHA Assembly to spear the remaining screens and attempt to fish out. 11:30 - 14:00 2.50 FISH C DECOMP TIH with BHA #2 on 3-1/2" Drill Pipe from the Derrick. Maintain 15 bbl per hour fill rate with seawater while TIH. TIH to fish out remaining screen assembly. 14:00 - 14:30 0.50 FISH C DECOMP Have safety stand down with Workover Operations Superintendent, ADW HSE Advisor and RLG Consultant over Annulus Valve incident (control of work). 14:30 - 19:30 5.00 FISH C DECOMP Resume TIH with BHA #2 to 10,611', maintaining fill rate at 15 bbls er hour with seawater. 19:30 - 20:30 1.00 FISH C DECOMP M/U circulating head and hose and establish parameters, up weight 142,000#, down weight 76,000#, 170 psi at 2 bpm. Printed: 8/25/2008 2:08:54 PM ~ • BP EXPLORATION Page 5 of 8 Operations Summary Report weight 170 psi at 2 bpm. Engage fish at 10,714,', pump pressure increased to 350 psi. Jar at 175,000# working up to 225,000#. Fish worked up hole approximately 4' before coming loose. Up weight increased to 148,000#. 22:30 - 23:00 0.50 FISH C DECOMP R/D circulating head and monitor well. 23:00 - 00:00 1.00 FISH C DECOMP POOH with BHA #2 and fish, maintaining 15 bph fill rate. 7/31/2008 00:00 - 07:00 7.00 FISH C DECOMP POOH with BHA #2 and fish, maintaining 15 bph fill rate. 07:00 - 09:30 2.50 FISH C DECOMP On surface with BHA #2 and the remaining Fish. Recovered the remainin arted screen, a full 'oint of screens acked off with sand and crude , 10' u , XN Ni le, 10' u and WLEG. Utilized the Tubing Punch to drain as much sand/crude as posse a rom the screens and also used the Punch below the ipp a to ensure no trappe gas or well ore ui s in t e tailpipe. Break out and lay down BHA and Fish with Baker rep. 09:30 - 10:30 1.00 FISH C DECOM tear and clean Rig Floor. Pick up BHA components for the next run to the Rig Floor. 10:30 - 15:00 4.50 FISH C DECOMP Finish working on Skate modifications with Columbia reps prior to TIH with next BHA. Continue filling the well with 15 bbls of seawater per hour. 15:00 - 15:30 0.50 FISH P DECOMP PJSM on picking up next BHA components. Columbia reps instruction with crew on new sensors and additions to the Skate. 15:30 - 16:30 1.00 FISH P DECOMP PUMU BHA #3 as follows: 6" Bit, 7" Casing Scraper, Bit Sub, Bumper Sub, Jar, (8) ea 4-3/4" Drill Collars, Pump Out Sub. OAL = 270.65'. 16:30 - 23:30 7.00 FISH P DECOMP TIH with BHA #3 on 3-1/2" Drill Pipe to 10,780', No fill. Maintain 15 bbls per hour fill rate with seawater while TIH. Work scraper through packer setting depth of 10,528' six times. 23:30 - 00:00 0.50 FISH P DECOMP M/U circulating head and pump DP volume of 80 bbls at 2.5 bpm with 220 psi. No returns. 8/1/2008 00:00 - 00:30 0.50 FISH P DECOMP Pump DP volume of 80 bbls at 2.5 bpm with 220 psi. No Legal Well Name: MPK-30 Common Well Name: MPK-30 Spud Date: 10/19/1996 Event Name: WORKOVER Start: 7/24/2008 End: 8/5/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/5/2008 Rig Name: NABOBS 3S Rig Number: Date From - To I Hours Task ~ Code NPT Phase Description of Operations 7/30/2008 19:30 - 20:30 1.00 FISH C DECOMP Wash from 10,611' to 10,714'. 20:30 - 22:30 2.00 FISH C DECOMP Establish parameters, 145,000# up weight, 78,000# down 00:30 - 07:00 6.50 FISH P DECOMP POOH with BHA #3 standing back 3-1/2" DP. Maintain 15 bph holefill with seawater. At 0630 hrs, notified AOGCC Inspector Jeff Jones with 24 hour notice of upcoming BOPE test. 07:00 - 08:00 1.00 FISH P DECOMP On surface with BHA #3. Break out and lay down BHA components with Baker rep. 08:00 - 08:30 0.50 FISH P DECOMP Clear and clean Rig Floor. 08:30 - 09:30 1.00 BUNCO RUNCMP RD 3-1/2" Handling Equipment. RU 4-1/2" Handling Equipment and Screens Table. Load the Pipe Shed with the Packer and Screens Assembly. Discuss space out of Screens with Anchorage Engineering due to 40' Joints sent out instead of 30' Joints. Make changes to the running order per discussion with Anchorage Engineering. 09:30 - 12:00 2.50 BUNCO RUNCMP Wait on 6' Pup Joint to be machined with the correct threads and brought out to location. Perform maintenance projects and general housekeeping on the Rig. 12:00 - 12:30 0.50 BUNCO RUNCMP Pup Joint arrives on location. Load, drift and strap in the Pipe Shed. Pup Joint = 5.48'. 12:30 - 13:00 0.50 BUNCO RUNCMP Pre-job safety meeting with Halliburton rep on BHA and running order. Have Columbia rep explain the new features to new Printed: 8/25/2008 2:08:54 PM • • BP EXPLORATION Page 6 of 8 Operations. Summary Report Legal Well Name: MPK-30 Common Well Name: MPK-30 Spud Date: 10/19/1996 Event Name: WORKOVER Start: 7/24/2008 End: 8/5/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/5/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/1/2008 12:30 - 13:00 0.50 BUNCO RUNCMP crew. 13:00 - 15:00 2.00 BUNCO RUNCMP PUMU 7" Versatrieve Packer Assembl with Weatherford 316E 15:00 - 17:00 I 2.001 RU 17:00 - 18:00 1.00 WHSUR~C 18:00 - 19:00 1.00 BOPSU C 19:00 - 23:30 4.50 BOPSU C 23:30 - 00:00 0.50 BOPSU C 8/2/2008 00:00 - 00:30 0.50 WHSUR C 00:30 - 02:30 2.00 BUNCO 02:30 - 04:30 2.00 04:30 - 06:00 1.50 06:00 - 16:00 I 10.00 16:00 - 18:00 I 2.00 18:00 - 00:00 I 6.00 18/3/2008 100:00 - 01:30 I 1.50 01:30 - 02:30 I 1.00 I R 02:30 - 04:30 I 2.001 RU Dura ri Screens. Notice that the Packer is not properly finned in the run osition and that the possibility of it hanging up or pre-setting while RIH exists. Have to send the Packer back to the Halliburton shop to inspect and re-dress. RUNCMP Break out and lay down the Screens and Packer Assembly with Halliburton rep. Call Jeff Jones with the AOGCC and explain change of plans and desire to test BOPE while waiting on the Packer - he OK'd the request. RUNCMP Pull Wear Ring. RUNCMP Install test plug and M/U test assemblies. RUNCMP Test BOPE to 250 psi low and 3,500 psi high. each test was held for 5 minutes on the chart. Tested pipe rams, blind rams, annular, manual kill line valve, HCR kill line valve, manual choke line valve, HCR choke line valve, choke manifold valves, floor valve and Dart valve. Pipe rams and annular were tested with both 2-7/8" and 3-1/2" test joints. Performed drawdown test on Koomey. AOGCC witness of ROPE test was waived by Jeff Jones. Test was witnessed by the BP WSL and Nabors Toolpusher. Good Test, No Failures. RUNCMP Pull test plug and install wear bushing. RUNCMP Pull test plug and install wear bushing. RUNCMP PUMU 7" Versatrieve Packer Assembly with Weatherford 316E Duragrip Screens. plotice that the second packer is not properly pinned in the run position and that the possibility of it hanging up or pre-setting while RIH exists. L/D packer and inspect. Second packer was inspected when loaded into the pipe shed and looked to be properly set up. Discuss options with the well engineer. Have to send the Packer back to the Halliburton shop to inspect and re-dress. RUNCMP R/U screen table and L/D screen assembly. Clear rig floor. RUNCMP Service and clean rig equipment while waiting on HES to transport and rebuild packer. RUNCMP Wait on the Packer to be broken down and inspected. Speak with Halliburton throughout the day and they have been working with their global advisor on the Packer troubleshooting. Inspect the running tool and Packer and can't find anything wrong with it. Work on 3rd Packer that was initially set aside for another job. RUNCMP The Packer arrived on location at 1600 hrs. PUMU 7" Versatrieve Packer Assembly ith Weatherford 316E Duragrip Screens. Check the Packer and everything looks good. RUNCMP TIH with 7" Versatrieve Packer op 3-1/2" Drill Pipe from the Derrick maintaining 15 bbls per hour fill rate with seawater. RUNCMP TIH with 7" Versatrieve Packer on 3-1/2" Drill Pipe from the Derrick maintaining 15 bbls per hour fill rate with seawater. RUNCMP M/U circulating head and space HES VTA packer out to 10,528'. Up weight 136,000#, down weight 76,000#. RUNCMP Drop 1-1/2" setting ball and pump down at 2 bpm with 170 psi. Pressure up to 500 psi, pressure not holding. Isolate floor valves. Floor valves holding, leakingoff downhole. Discuss options with HES Supervisor, pressure up to 1,000 psi. Went to Printed: 8/25/2008 2:08:54 PM ~~ ~J BP EXPLORATION Operations Summary Report Page 7 of 8 Legal Well Name: MPK-30 Common Well Name: MPK-30 Spud Date: 10/19/1996 Event Name: WORKOVER Start: 7/24/2008 End: 8/5/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/5/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task 'I Code NPT .Phase Description of Operations 8/3/2008 02:30 - 04:30 2.00 04:30 - 05:30 1.00 05:30 - 06:30 1.00 06:30 - 07:00 0.50 07:00 - 17:30 10.50 17:30 - 18:00 0.50 BUNCO 18:00 - 19:00 1.00 BUNCO 19:00 - 19:30 0.50 WHSUR P 19:30 - 20:30 1.00 BUNCO 20:30 - 00:00 3.50 BUNCO 8/4/2008 100:00 - 11:00 I 11.001 RUN RUNCMP shut in Demco valve on pump and handle threads stripped. Bleed off pressure. RUNCMP Change out Demco valve on mudoumo. RUNCMP Pressure up to 1,000 psi. Still leaking by setting ball. Discuss options with Well Engineer, decision made to set packer. Pressure up to 2,550 psi for 5 minutes. Bleed off pressure, P/U to 146,000#, 10,000# over string weight, S/O to 66,000#, and set 10,000# on packer. Pressure up to 3,150 psi and hold for 5 minutes. P/U to shear out, sheared at 145,000#. Slack off and set 10 000# on acker to ensure it is set - OK. RUNCMP Blow down lines and RD circulating hose, headpin and TIW. RUNCMP POOH la in down 3-1/2" Drill Pipe in the Pi a Shed. Maintain 15 bph fill rate with source water while POOH. 80 Joints laid down at 0930 hrs. 120 Joints out at 1100 hrs. 190 Joints out at 1330 hrs. 240 Joints out at 1500 hrs. 320 Joints out at 1700 hrs. RUNCMP UD HES VTA packer running tool. RUNCMP R/D 3-1/2" handling equipment and Clear rig floor. RUNCMP Pull wear bushing. RUNCMP Load ESP in shed and R/U 2-7/8" handling equipment. RUNCMP P/U and M/U ESP assembly. Perform checks and service on ESP. RUNCMP RIH with ESP completion picking up 2-7/8", 6.5#, L-80, EUE torque of 2,300 ft/Ibs. Maintain 15 bph fill while RIH. Stop every 2,000 ft to check the conductivity of the cable and fill the Tubing with source water. Flush the Pump with 10 additional bbls at a rate of 1 bpm / 370 psi. 170 Joints in the hole at 0800 hrs. Stop with 215 Joints in the hole and flush the pump at 1 bpm / 400 psi. 11:00 - 15:00 4.00 BUNCO RUNCMP Perform reel to reel splice with Centrilift reps. Clear and clean the Rig Floor and Pipe Shed while waiting on the splice to be completed. 15:00 - 20:30 5.50 BUNCO RUNCMP Resume RIH with ESP Completion on 2-7/8" Tubing from the Pipe Shed maintaining 15 bph fill rate with source water. Flush the pump with 10 bbls of source water. Final flush pressure was 410 psi at 1 bpm. Ran a total of 173 LaSalle Clamps, 5 Protectolizers and 3 Flat guards. 20:30 - 22:00 1.50 BUNCO RUNCMP M/U and orient tubing hanger. Install penetrators and make penetrator splice. 22:00 - 22:30 0.50 BUNCO RUNCMP Establish parameters, up weight 76,000#, down weight 50,000#. Land hanger and RILDS. Torque LDS to 450 fUlbs. 22:30 - 23:30 1.00 BUNCO RUNCMP B/O and L/D landing joint. Dry rod in TWC with FMC wellhead tech. Test TWC from above to 3 500 psi for 10 minutes. Good 23:30 - 00:00 0.50 BOPSU P RUNCMP Blow down lines, drain BOP stack and remove flow riser. 8/5/2008 00:00 - 01:30 1.50 BOPSU P RUNCMP N/D BOPE and lay over in cradle. 01:30 - 03:30 2.00 WHSUR P RUNCMP N/U Tree. Test hanger void, flange and penetrator seals to 5,000 psi as per FMC procedure. Test tree to 5,000 psi with diesel for 10 minutes. Good test. 03:30 - 05:00 1.50 WHSUR P RUNCMP Make final check on ESP, phase to phase 3.4, 627 megs, and bhp = 2924 psi. P/U lubricator and test to 500 psi for 5 minutes. Pull TWC and install BPV. Printed: 8/25/2008 2:08:54 PM BP EXPLORATION Page 8 of 8 Operations Summary Report Legal Well Name: MPK-30 Common Well Name: MPK-30 Spud Date: 10/19/1996 Event Name: WORKOVER Start: 7/24/2008 End: 8/5/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/5/2008 Rig Name: NABOBS 3S Rig Number: Date From - To 'Hours Task Code NPT Phase Description of Operations 8/5/2008 05:00 - 06:00 1.00 WHSUR P RUNCMP Secure Tree and cellar. Rig Released at 06:00 hours on 8/5/2008. Printed: 8/25/2008 2:08:54 PM STATE OF ALASKA 1/14/07 OIL AND GAS CONSERVATION COM~IIISSION BOPS Test Report sul~it to: Contractor: Nabors Rig No. Rig Rep.: J. GreeofJ.Fritts Rig Phone: Operator; BP Op. Phone: Rep.; W. Hoffman /B. Burson 3S 65~--448 659-4485 DATE: $11/2008 Rig Fax: 659-4486 Op. Fax: 659-462$ Field/Unit 8~ Well No.: MP K~0 PTD # Operation: Drlg: Workover x Test: Initial: Weekly: x Test Pressure: Rams: 250/3500 Annular. 250!3500 TEST DATA MISC. INSPECTIONS: Test Result Test Result Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13 5/8 3000 P Pipe Rams i 2 718 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 31/8" 5000 P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA MUD SYSTEM: V'~sual Test Atarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Explor.: Bi-Weekly Valves: 250/3500 FLOOR SAFETY VALVES: Quantify test Result Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Irde BOP 1 P CHOKE MANIFOLD: Quantity Test Result Na Valves 13 P Manual Chokes 1 P HydrauNCC Chokes 1 P Pressure After Closure 1800 P 200 psi Attained 30sec P Full Pressure Attained 1 min 56 sec P Blind Switch Govers; All stations P Nitgn. Bathes (avg); 1975 ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Test Results Number of Failures: 0 Test Time: 4_5 Hours Components tested ALL Repair or replacemerrt of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at: Remarks: Tested w/ 2 718 test point 8< 31/2" test ioint against Test Ptug / Bope test was allowed to be moved up due to tool aroblems per t AOGCC )Jeff Jones. 24 HOUR NOTICE YES X NO Date 08/01/08 Time 0630HRS start 1900 his Finish BOP Test (for rigs) BFL 11/14107 ~~1~1~~ AUG ~ ~: ZpQ$ By _ Jeff Jones Witness J. Fritts/B. Burson Nabors 3s BOP Test MP K-30 8-1-08.x1s STATE OF ALASKA w 11/14107 OIL AND GAS CONSERVATION C0IUIMISSION BOPS Test Report Submit to: Contractor: Nabors Rig No.: 3S DATE: 7/26/2008 Rig Rep.: G.Sweatt/J.Fritts Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: BP Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: W. Hoffman /D.Rhodes Field/Unit 8. Well No.: MP K-30 PTU ~°` Operation: Drlg: Workover: x Explor.: Test: Initlal: x Weeky: Bi-Weekly t Pressure: Rams: 250/3500 Annular. 250/3500 Valves: TEST DATA MISC. INSPECTIONS: Test Result Test Result FLOOR SAFETY VALVES: Quantii Test Result Upper Kelly 0 NA Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P t-Lazard Sec. P Standing Order Posted P BOP STACK: Quantity Size lest Result Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 718 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind P Choke Ln. Valves 1 31/8" 5000 P HCR Valves 2 3 1!8" 5000 P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA Lower Kelly 0 NA Batt Type 1 P Inside BOP 1 P CHOKE MANIFOLD; Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure System Pressure 3000 Pressure After Closure 1700 MUD SYSTEM: Visual Tes# Alarm Test 200 psi Attained 31sec Trip Tank P P Full Pressure Attained 1 min 53 sec Pit Level Indicators P P Blind Switch Covers: All stations Flow Indicator P P Nitgn. Bottles (avg}: 2000 Test Result P P P P P Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 0 Test Time: 4 Hours. Components tested ALL Repair or replacement of equipment w~l be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at Remarks: Tested w/ 2 7/8 test ioint & 3 1/2" test joint against 2 way check valve 24 HOUR NOTICE GIVEN YES X NO Waived By Bob Noble Date 07/24/08 Time 1OOOHRS Witness J. Fritts/D.Rhodes Test start 0100 hrs Finish 0500 hrs ~~~N~?~~ AUO D ~ 2008 BOP Test (for rigs) BFL 11/14/07 Nabors 3s BOP Test MP K-30 7-26-08.x1s • Page 1 of 2 Maunder, Thomas E (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, November 05, 2007 10:10 AM To: Maunder, Thomas E (DOA) Subject: RE: MPK-30 (196-1f>~) Attachments: MPK-30 07-09-07.pdf; MPK-30 07-10-07.pdf; MPK-30 07-11-07.pdf; MPK-30 07-12-07.pdf Here you go... Have a great day! ~ ~~ ~~ ~~ ~~ C~IC~ s! ~ .:x 2(~~f Terrie From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Saturday, November 03, 2007 12:59 PM To: Hubble, Terrie L Subject: RE: MPK-30 (196-168) Terrie, I have just reviewed the 404 for the successful workover completed in early October. Regarding the failed work attempt with Nabors 3S in July, could you please send in the summaries for that work? Email is fine, I will just attach them to this 404. Thanks in advance. ~I ]~~,~ Tom Maunder, PE AOGCC From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Wednesday, October 10, 2007 8:21 AM To: Maunder, Thomas E (DOA) Subject: RE: MPK-30 Hi Tom, The attempt at a workover in Juiy was unsuccessful. They were unable to pull the tubing. A freepoint was run to determine where to cut the tubing (deep) and then the rig moved off. haven't read the non-rig work that occurred after that, but it will be reported on the Report of Sundry for this (successful) workover. Does that help? Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, October 10, 2007 8:07 AM To: Hubble, Terrie L Subject.: RE: MPK-30 Hi Terrie, In the information you have sent, I noticed that MPK-30 also had an ESP workover completed in July. Did the 11/5/2007 • Page 2 of 2 • pump not start? Thanks, Tom From: Hubble, Terrie L [maiito:Terrie.Hubble@bp.com] Sent: Wednesday, October 10, 2007 7:45 AM To: Maunder, Thomas E (DOA); McMains, Stephen E (DOA) Subject: Workover Rpt to AOGCC Hi Guys, ...trying to get caught up from being on vacation. Terrie 11/5/2007 STATE OF ALASKA ,~ R~~~ V ED ALA• OIL AND GAS CONSERVATION COM~ION ~ ~ 1~ ~ 0 2007 REPORT OF SUNDRY WELL OPERATIONS .Masks bil ~ C>~s Cons. Commiss~ot~ 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended 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 196-168 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22711-00-00 7. KB Elevation (ft): KBE = 56.95' - 9• Well Name and Number: MPK-30 - 8. Property Designation: 10. Field /Pool(s): ADL 375132 Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 11145 ~ feet true vertical 7306 - feet Plugs (measured) N/A Effective depth: measured 11041 feet Junk (measured) N/A true vertical 7257 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' Surface 6621' 9-5/8" 6652' 4908' 6870 4760 Intermediate Production 11094' 7" 11122' 7295' 7240 5410 Liner Perforation Depth MD (ft): 10588' - 10748' Perforation Depth TVD (ft): 7025' - 7111' 2-7/8", 6.5# L-80 10471' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" HES Versatrive with two 4-1/2" Poroplus screen 10546' assemblies at 10596' and 10695' 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: 232 47 3928 20 229 Subsequent to operation: 0 0 0 0 0 14. Attachments: ^ Copies of Logs and Surveys run 15. WeN 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 Aras Worthington, 564-4102 N/A Printed Namg .Sondra Stewma Title Drilling Technologist Prepared By Name/Number: Si ature ~ ^-~-__ Phone 564-4750 Date ~°2~j'(~ Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 ^ ~ ~ I ~ Submit Original Only K ~ L ~ ~ ~~. ~~u ~>~ ~ 200 , ~4~ ~, • . BP EXPLORATION Dai ly Operations Report Page 1 of Operator: BP EXPLORATION Rig: NABORS 3S Report: 1 Well: MPK-30 Event: WORKOVER Date: 7/9/2007 Field: MILNE POINT Well T e: DEVELOPMENT Current Well Status Depth MD: (ft) Casing Size: (in) Costs in: USD Rig Accept: 15:12 7!6/2007 Est. TVD: (ft) Casing (MD): (ft) Daily Mud: Rig Release: Progress: (ft) Next Casing Size: (in) Cum. Mud: Spud Date: 10!19/1996 Auth Depth: 11,041.0 (ft) Next Casing (MD): (ft) Daily Well: WX Date: Hole Size: 8.500 (in) Next Casing (TVD): (ft) Cum. Well: Elev Ref: SEA LEVEL DOUDFS/Target: //5.00 Geologist: KB Elev: 57.50 (ft) Engineer. Frank Roach Tot. Personnel: 25 Supervisor: Frazier/Stiem Program: Cost Ahead: 0 USD, Days Ahead: 0.00 Weather: + 39 deg, 20 mph N Current Status: Waiting on additional seawater to finish well kill operations. 24hr Summary: MIRU. Pull BPV. Displace well w/ 8.4 ppg hot seawater. Call for additional kill fluid @ 0500 hrs. 24hr Forecast: Set TWC. N U BOPE. POOH w12-7/8" ESP completion. Comments: No Accidents. No Incidents. No Spills. Acce t ri 2100 hrs 07/09/07. HSE & Welt Control Days Since Last DAFWC: 0 All Free Days: 0 Last Csg Test Press.: Last BOP Press. Test: Next BOP Press. Test: Last Safety Meeting: No. Stop Cards: Regulatory Agency Insp: Non-compliance Issued: Pump Slow Pump Rates (Circ} Slow Pump Rates (Choke) Slow Pump Rates (Kill) TVD: (ft) Stroke Rate Pressure() Stroke Rate Pressure() Stroke Rate Pressure() EMW: (ppg) MAASSP: (psi) Test Pressure: (psi) Kick Tolerance: Kick Volume: O erational Parameters ROP Daiiy: Rotating Weight: Daily Bit Hrs: (hr) Pum p St atus - Dnl lmg and Ris er ROP Cum.: Pick Up Wt.: Daily Sliding Hrs: 0.00 (hr) Pump Type Eff. Strokes Liner Size Circ. Rate WOB (min): Slack Off Wt.: Cum. Bit Hrs: Q Q () (} WOB (max): Circ. Rate Riser: RPM Min.: Circ. Rate Hole: Ann. Vel. Riser: (ft/min) RPM DH: Circ. Off Bottom: Ann. Vel. DC: (ft/min) Torq. on Bottom: Circ. On Bottom: Ann. Vel. DP: (ft/min) Tor .off Bottom: Jar Hrs since Ins ect: O erations Summa From-To Hrs Phase 1-ask Activity Code NPT Operation Op. Depth (hr) 02:00-06:00 4.00 POST RIGD RD P R/D Primary Unit. 06:00-08:00 2.00 POST RIGD WAIT P Wait for trucks to come from Peak after GO. Allow Milne Point personnel to C/O 08:00-10:00 2.00 PRE MOB MOB P Move Primary Unit, Pits, and Pipe Shed away from MPL-06. 10:00-12:00 2.00 PRE MOB MOB P Move to Milne Point K-Pad. 12:00-16:00 4.00 PRE MOB MOB P Layout Herculite. Move Carrier, Pits, and Pipe Shed onto MPK-30. 16:00-21:30 5.50 PRE RIGU RU P R/U Primary Unit. M/U electric lines and fluid lines. Spot Tiger Tank and R/U Hardline. Accept rig @ 2100 hrs 07/09/07. 21:30-00:00 2.50 DECOM DHB PLUG P RU lines to tree to kill well. Pull BPV w/ lubricator. IA = 250 psi / T = 200 psi. C(~~ Punted: 7/10!2007 5.52:24 AM • BP"EXPLORATION Dai ly Operations Report Page ~ ~f Operator: BP EXPLORATION Rig: NABORS 3S Report: 2 Well: MPK-30 Event: WORKOVER Date: 7/10/2007 Field: MILNE POINT Well T e: DEVELOPMENT Current Well Status' Depth MD: (ft) Casing Size: (in) Costs in: USD Rig Accept: 15:12 7/6/2007 Est. TVD: (ft) Casing (MD): (ft) Daily Mud: Rig Release: Progress: (ft) Next Casing Size: (in) Cum. Mud: Spud Date: 10/19/1996 Auth Depth: 11,041.0 (ft) Next Casing (MD): (ft) Daily Well: WX Date: Hole Size: 8.500 (in) Next Casing (TVD): (ft) Cum. Well: Elev Ref: SEA LEVEL DOL/DFS/Target: //5.00 Geologist: KB Elev. 57.50 (ft) Engineer: Frank Roach Tot. Personnel: 25 Supervisor: Frazier/Mabeus Program: Cost Ahead: 0 USD, Days Ahead: 0.00 Weather: +38 deg, 8 MPH NE Winds, +31 WC Current Status: Circulate Hole Volume 24hr Summary. Circulate and Kill Well, Monitor and Set TWC, Test TWC, Test CSG Pack Off, N/D Tree, N/U BOPE and Test 24hr Forecast: Pull TWC, Circ Well Volume, Pull HGR, Pull ESP Comp Comments: No Accidents. No Incidents. No Spills. Acce t ri 2100 hrs 07/09/07. HSE & Well Control Days Since Last DAFWC: 0 All Free Days: 0 Last Csg Test Press.: (psi) Last BOP Press. Test: 7/10/2007 Next BOP Press. Test: 7/17/2007 Last Safety Meeting: 7/10/2007 No. Stop Cards: Regulatory Agency Insp: N Non-compliance Issued: N Pump Slow Pump Rates (Circ) Slow Pump Rates (Choke) Slow Pump Rates (Kill) TVD: (ft) Stroke Rate Pressure() Stroke Rate Pressure() Stroke Rate Pressure() EMW: (PP9) MAASSP: (psi} Test Pressure: (psi) Kick Tolerance: (ppg) Kick Volume: (bbl) O erational Parameters ROP Gaily: Rotating VVeight: Daily Bit Hrs: (hr} Nu mp St atus- Gnl ling and Ris er ROP Cum.: Pick Up Wt.: Daily Sliding Hrs: 0.00 (hr) Pump Type Eff. Strokes Liner Size Circ. Rate WOB (min): Slack Off Wt.: Cum. Bit Hrs: Q () Q Q WOB (max): Circ. Rate Riser: RPM Min.: Circ. Rate Hole: Ann. Vel. Riser: (ft/min) RPM DH: Circ. Off Bottom: Ann. Vel. DC: (ft/min} Torq. on Bottom: Circ. On Bottom: Ann. Vel. DP: (ft/min) Tor ,off Bottom: Jar Hrs since Inspect: (hr) ~ eratlOnS $Umma From-To Hrs Phase Task Activity Code NPT Operation Op. Depth (hr) 00:00-01:30 1.50 DECOM KILL RU P Flnish RU hardline to Tiger tank & pressure test to 1000 psi. Pressure test choke and kill lines to 3500 psi. 01:30-02:30 1.00 DECOM KILL CIR P Circulate 65 bbls of 8.4 ppg hot seawater down tubing to Tiger tank@ 3.5 bpm ! 770 psi w1 full returns. 02:30-03:00 0.50 DECOM KILL BULLHD P Bullhead 30 bbls of 8.4 ppg hot seawater down tubing into formation@ 3 bpm ! 930 psi. Shut in well and monitor pressures for 15 minutes. IA = 290 psi, T = 0 psi. 03:00-05:00 2.00 DECOM KILL CIR P Circulate 450 bbls of 8.4 ppg hot seawater down tubing to Tiger tank@ 3.5 bpm. Lost 183 bbls during displacement (+30 bbls during bullheading). Crude and gas in returns after450 bbls pumped (310 bbls calculated displacement). Shut well in w/ 30 bbls remaining in pits. IA has not been flushed. Tubing is on a strong vac. 05:00-06:00 1.00 DECOM KILL CIR N Wait on additional seawater to arrive. 06:00-07:00 1.00 DECOM WHSU TSTPRS P Test Casing Packoffs to 5000 psi for 30 minutes per FMC. Good test. Wait on seawater. 07:00-07:30 0.50 DECOM KILL WAIT N Hang Sheave and R/U Geronimo Line. ~~5 Printed: 7/11/2007 5:59:03 AM • BP EXPLORATION Daily Operations Report Paget of Operator: BP EXPLORATION Rig: NABORS 3S Report: 2 Well: MPK-30 Event: WORKOVER Date: 7/10/2007 Field: MILNE POINT Well T e: DEVELOPMENT ~ erat1011S $UmmB From-To Hrs Phase Task Activity Code NPT Operation Op. Depth (hr) 07:30-10:00 2.50 DECO KILL CIR P Circulate 209 Bbls of seawater at 3.5 BPM at 900 psi until retums came back clean. Lost 56 bbls to the formation during circulation. Monitor well for 30 minutes. T/IA =vac/vac. 10:00-11:30 1.50 DECO DHB INSTAL P Dry rod TWC in per FMC. Test TWC from below to 400 psi for 5 charted minutes. Unable to reach desired 1000 psi test due to injection rate of4 BPM at 400 psi. Lost 20 Bbls to formation. Test TWC from above to 3500 psi for 10 charted minutes with IA (on vac) open. Test from above is good. 11:30-13:30 2.00 DECOM WHSU ND P Blowdown and break all lines to Tree. PJSM. Test 7" Casing Pack Off (past). N/D Tree. Inspect Hanger and MIU 3-1/2" IF box x 3" LH ACME crossover with 9-1/3 turns. 13:30-17:30 4.00 DECOM BOPSU NU P PJSM. N/U BOPE. R/U Choke and Kill Lines. Install Riser and Flowline. Install Turnbuckles and tighten. 17:30-19:30 2.00 DECOM BOPSU RU P Function test BOPE. Crew change out. Make Pre-Tour inspections. Install Koomey hoses, Kill hoses, secure and Gean cellar. Fill Stack w/ water. Flush and Purge air from Choke. 19:30-00:00 4.50 DECOM BOPSU TSTPRS P Test BOPE to 250 si low ressure and 3,500 psi high pressure. Each test was held for 5 minutes. AOGCC witness of test was watve by Lou Grimaldi. Test was witnessed by Nabors Tool Pusher and BP WSL Test 1-Choke Valves 1, 2, Blind Rams, and HCR Kill Test 2- Choke Valves 3, 4, 5, 6, and Manual Kill Test 3- Choke Valves 7, 8, and 9 Test 4- Choke Valves 10 and 11 Test 5- Choke Valves 12 and 13 Test 6- HCR Choke Test 7-Annular, Manual Choke and Dart Valve Test 8-Outside Test Valve and TIW Valve Test 9- Inside Test Valve Test 10- Pipe Rams with 2-7/8" Test Joint AccumulaterTest- 3000 psi Starting Pressure. After Actuation- 1700 psi. First 200 psi recovery- 24 seconds. Full recovery- 1 minute and 38 seconds. 4 Nitrogen Bottles at 1950 psi. 06:00 U date From-~o Hrs Phase Task Activity Code NPT Operation Op. Depth (hr) 00:00-01:00 1.00 DECOM DHB RU P Suck out stack. R/U DSM Equipment. 01:00-03:30 2.50 DECOM DHB PLUG P R/U Opso Lopso with crossover and M/U to Hanger. M/U Lubricator to Opso Lopso. Pull TWC. IA on a vac and T on slight vac. 03:30-04:30 1.00 DECO DHB P R/U circulation line from IA to Choke. 04:30-06:00 1.50 DECO DHB P Circulate STS with seawater while at 3.5 BPM at 770 psi. Losing - 40 BPH while circulating. Took retums to Tiger Tank until well cleaned up then took returns throup_ h to the Pits Materials / Consum tion It?m ~ Units ~ Usage On Hand Item I Units Us~igc nip, I land DIESEL ~ GAL ' 570 7840 Personnel Company No. Hours Company No. Hours Company No. Hours BP 1 12.00 AK PETROLEUM CONTRACT 1 12.00 NABORS 2 12.00 NABORS 19 12.00 DOYON 1 12.00 M-I DRILLING FLUIDS 1 12.00 Cumulative Phase Breakdown Planned Change of Scope Total Total Cost Phase Prod % Total NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total Hours USD DECOMP 25.00 94.3% 1.50 5.7% 26.50 23,822.00 POST 6.00 100.0% 6.00 PRE 13.50 100.0% 13.50 80,853.00 TOTALS 44.50 96.7% 1.50 3.3% 0.00 0.0% 0.00 0.0% 0.00 0.0% 0.00 0.0% 46.00 104,675.00 a '~l~s Printed: 7/11/2007 5:59:03 AM • • BP EXPIORATlON Dai ly Operations Report Page 1 of 2 Operator: BP EXPLORATION Rig: NABORS 3S Report: 3 Well: MPK-30 Event: WORKOVER Date: 7/11/2007 Field: MILNE POINT Well T e: DEVELOPMENT Current WeN Status Depth MD: (ft) Casing Size: (in) Costs in: USD Rig Accept: 15:12 7/6/2007 Est. TVD: (ft) Casing (MD): (ft) Daily Mud: Rig Release: Progress: (ft) Next Casing Size: (in) Cum. Mud: Spud Date: 10/19/1996 Auth Depth: 11,041.0 (ft) Next Casing (MD): (ft) Daily Well: WX Date: Hole Size: 8.500 (in} Next Casing (TVD): (ft) Cum. Well: Elev Ref: SEA LEVEL DOUDFS/Target: //5.00 Geologist: KB Elev: 57.50 (ft) Engineer: Frank Roach Tot. Personnel: 25 Supervisor: Frazier/Mabeus Program: Cost Ahead: 0 USD, Days Ahead: 0.00 Weather: +39 deg, 5 MPH W Winds, +36WC Current Status: Running SWS Free Point Determination on cline 24hr Summary. Pull TWC, Circulated Hole Volume, Sting Landing Joint into HGR, BOLDS, Attempt to Pull HGR to Floor, Completion Stuck, Circulate, Circulate EP Mud Lube Sweep, Attempt to Pull Completion w! No Success, Call Out and RU SWS Free Point Determination 24hr Forecast: Determine Free Point, Land Completion, TWC, ND BOPE, NU Tree Comments: No Accidents. No Incidents. No Spills. HSE 8~ Well Control Days 5mce Last DAFWC: 0 All Free Days: 0 Last Csg Test Press.: (psi) Last BOP Press. Test: 7/10/2007 Next BOP Press. Test: 7/17/2007 Last Safety Meeting: 7/11/2007 No. Stop Cards: Regulatory Agency Insp: N Non-compliance Issued: N Pump Slow Pump Rates (Girt) Slow Pump Rates (Choke) Slow Pump Rates (Kill) TVD: (ft) Stroke Rate Pressure() Stroke Rate Pressure() Stroke Rate Pressure() EMW: (pp9) MAASSP: (psi) Test Pressure: (psi) Kick Tolerance: (ppg) Kick Volume: bbl) O erational Parameters ROP Daily: Rotating Weight Daily Bit Hrs: (hr) Pu mp St atus- Dril ling and Ris er ROP Cum.: Pick Up Wt.: Daily Sliding Hrs: 0.00 (hr) Pump Type Eff. Strokes Liner Size Circ. Rate WOB (min): Slack Off Wt.: Cum. Bit Hrs: Q Q Q () WOB (max): Circ. Rate Riser: RPM Min.: Circ. Rate Hole: Ann. Vel. Riser: (ft/min} RPM DH: Circ. Off Bottom: Ann. Vel. DC: (ft/min) Torq. on Bottom: Circ. On Bottom: Ann. Vel. DP: (ft/min) Torq. off Bottom: Jar Hrs since Inspect: (hr) O erations'Summa From-To Hrs Phase Task Activity Lode NPT Operation Op. Depth (hr) 00:00-01:00 1.00 DECOM DHB RU P Suck out stack. R/U DSM Equipment. 01:00-03:30 2.50 DECO DHB PLUG P R/U Opso Lopso with crossover and M/U to Hanger. M/U Lubricator to Opso Lopso. Pull TWC. IA on a vac and T on slight vac. 03:30-04:30 1.00 DECO PULL CIR P R/U circulation line from IA to Choke. 04:30-07:00 2.50 DECO PULL CIR P Circulate 455 Bbls seawater at 3.5 BPM at 770 psi. Losing - 40 BPH while circulating. Took returns to Tiger Tank until well cleaned up then took returns through to the Pits 07:00-11:00 4.00 DECO PULL PUL P P/U Landing Joint and M/U to Hanger. Check IA pressure. BOLDS. Attempt to pull Hanger to Floor. P/U to free Han er = 85k-Ibs. P/U after anger is free continues to increase. Stop POH at P/U = 120k-Ibs. Hanger traveled at total of 74" with a P/U of 120k-Ibs (ExGuding Block weight). Unable to POH any further. Circulate at 4 BPM and 350 psi. Attempt to POH while circulating. Unable to POH any further than 74". Attem t numerous times to pull free, atl unsuccessful. Fully able to lower Printed: 7/1212007 6:02:04 AM ~P EXPLORATION Daily Operations Report Page 2 of 2 Operator: BP EXPLORATION Rig: NABORS 3S Report: 3 Well: MPK-30 Event: WORKOVER Date: 7/11/2007 Field: MILNE POINT Well T e: DEVELOPMENT O erations Summa From-To Hrs Phase Task Activity Code NPT Operation Op. Depth (hr) 07:00-11:00 4.00 DECOM PULL PUL P Hanger and re-land. 11:00-14:00 3.00 DECOM PULL CIRREV P Spot EP Mud Lube around ESP. Reverse Circulate in 50 Bbls of EP Mud Lube at 3 BPM and 280 psi. Chase Mud Lube with 253 Bbls of Seawater by Reverse Circulating @ 3 BPM and 280 psi. Shut in Tubing and Bullhead 15 Bbls of seawater at 3 BPM and 300 psi. Bleed OA from 230 psi to 0 psi. Bullheaded down IA at 4 BPM and 380 psi. Saw no communication to OA. 14:00-18:00 4.00 DECO PULL PUL P Attempt to POH with completion Still unable to POH any further than 74". Attempt to POH while circulating, no success. Fully able to lower Hanger and re-Iand.Bleed OA from 230 psi to 0 psi. Bullheaded down IA at 4 BPM and 380 psi. Saw no communication to OA. Consult with town. Decision made to Free Point via SLB E-Line. 18:00-21:00 3.00 DECOM PULL WAIT C Call out SWS e-line for running point determination Wait on SWS 21:00-23:30 2.50 DECO PULL RU C SWS arrived on location. PJSM with rig crew and SWS. Spot wireline units. Bring SWS tools and equipment to rig floor. Space out landing joint. 23:30-00:00 0.50 DECO PULL RU C Locate positions to hang sheaves in derrick. 06:00 U date From-To Hrs Phase Task Activity Code NPT Operation Op. Depth (hr) 00:00-03:00 3.00 DECO PULL RU C Space out landing joint. R/U SWS Sheaves in pipe shed, derrick, and floor. R/U SWS equipment for running a-line. 03:00-06:00 3.00 DECOM FISH DIAG C Run SWS Free Point Determination First checks showed free @ 2000' and 4000'. <Materials / Consum tion Item ~ --- Units Usage ', On Hand -- -- - Rein Units Usage ~ On Hind __ _ _ - - DIESEL GAL 450 7390 Personnel Company No. Hours Company No. Hours Company No. Hours BP 1 12.00 AK PETROLEUM CONTRACT 1 12.00 NABORS 2 12.00 NABORS 19 12.00 DOYON 1 12.00 M-I DRILLING FLUIDS 1 12.00 Cumulative Phase Breakdown Planned Change of Scope Total Total Lost Phase Prod % Total N PT % Total WOW % Total Prod % Total NPT % Total WOW % Total Hours USD DECOMP 43.00 85.1% 1.50 3.0% 6.00 11.9% 50.50 52,185.00 POST 6.00 100.0% 6.00 PRE 13.50 100.0% 13.50 80,853.00 TOTALS 62.50 89.3% 1.50 2.1 % 0.00 0.0% 6.00 8.6% 0.00 0.0% 0.00 0.0% 70.00 133.038.00 Remarks uaily fuel use = 751 gals Daily fluid Toss = 301 bbls Total fuid loss = 356 bbls PJSM held prior to each new operation. PVT aVarms checked and derrick inspection completed at start of each tour. Printed: 7/12/2007 6:02:04 AM • BP EXPLORATION ~al ~~/ ~p@CatlO'IlS Rep01't Page 1 of Operator: BP EXPLORATION Rig: NABORS 3S Report: 4 Well: MPK-30 Event: WORKOVER Date: 7/12/2007 Field: MILNE POINT Well T e: DEVELOPMENT Current Well Status Depth MD: (ft) Gasing Size: (in) Costs in: USD Rig Accept: 15:12 7/6/2007 Est. TVD: (ft) Casing (MD): (ft) Daily Mud: Rig Release: Progress: (ft) Next Casing Size: (in) Cum. Mud: Spud Date: 10/19/1996 Auth Depth: 11,041.0 (ft) Next Casing (MD): (ft) Daily Well: WX Date: Hole Size: 8.500 (in) Next Casing (TVD): (ft) Cum. Well: Elev Ref: SEA LEVEL DOUDFS/Target: //5.00 Geologist: KB Elev: 57.50 (ft) Engineer. Frank Roach Tot. Personnel: 25 Supervisor: FrazierlMabeus Program: Cost Ahead: 0 USD, Days Ahead: 0.00 Weather: +38 deg, 8 MPH NE Winds, +31 WC Current Status: Moving to F-Pad 24hr Summary: Run Free Point, Land HGR, ND BOPE, NU Tree, Set BPV, RDMO 24hr Forecast: Move to F-81, MIRU, Kill Well Comments: No Accidents. No Incidents. No Spills. Release Rig @ 22:00 hrs. NSE 8~ Well Control Days Since Last DAFWC: 0 All Free Days: 0 Last Csg Test Press.: (psi) Last BOP Press. Test: 7/10/2007 Next BOP Press. Test: 7/17/2007 Last Safety Meeting: 7/12/2007 No. Stop Cards: Regulatory Agency Insp: N Non-compliance Issued: N Pump Slow Pump Rates (Circ) Slow Pump Rates (Choke) Slow Pump Rates (Kill) TVD: (ft) Stroke Rate Pressure() Stroke Rate Pressure() Stroke Rate Pressure() EMW: (ppg) MAASSP: (psi) Test Pressure: (psi) Kick Tolerance: (ppg) Kick Volume: (bbl) O erational Parameters ROP Daily: Rotating Weight Daily Bit Hrs: (hr) Pum p St atus- Dril ling and Ris er ROP Cum.: Pick Up Wt.: Daily Sliding Hrs: 0.00 (hr) Pump Type Eff. Strokes Liner Size Circ. Rate WOB (min): Slack Off Wt.: Cum. Bit Hrs: Q () Q () WOB (max): Circ. Rate Riser: RPM Min.: Circ. Rate Hole: Ann. Vel. Riser: (ft/min) RPM DH: Circ. Off Bottom: Ann. Vel. DC: (ft/min) Torq. on Bottom: Circ. On Bottom: Ann. Vel. DP: (ft/min) Torq. off Bottom: Jar Hrs since Inspect: (hr) O erations Summa From-to Hrs Phase Task Activity Code NPT Operation Op. Depth (hr) 00:00-03:00 3.00 DECO PULL RU C Space out landing joint. R/U SWS Sheaves in pipe shed, derrick, and floor. R/U SWS equipment for running a-line. 03:00-13:00 10.00 DECOM EVAL LOG C Run SWS Free Point Determination First checks showed free @ 2000' and 4000'. Determined completion is stuck between 7,875' MD and 8,000' MD (+/- 2' after tie into GLM @ 10,213' MD). Log indicates that the best cut depth would be-7,000' MD. POH w/ E-Line. R/D E-Line. 13:00-15:30 2.50 DECOM DHB INSTAL P Land Hanger and RILDS. Set TWC w/ Dry Rod. Test from below by bullheading at 4 BPM and 240 psi. Test to 1000 psi from above. Both tests charted. 15:30-18:00 2.50 DECOM BOPSU ND P PJSM. N/D BOPE. Place BOPE stack on Stump and UD in Craddle. Remove from Cellar. 18:00-19:00 1.00 DECOM BOPSU NU P Spot and N/U Adapter Flange and Tree. 19:00-21:00 2.00 DECO BOPSU TSTPRS P R/U and Test Adapter Flange to 5000 psi, good test. R/U and test Tree to 5000 psi, good test. 21:00-21:30 0.50 DECOM BOPSU RD P R/D testing equipment. R/U DSM lubricator and pull TWC. Set BPV. R/D DSM. ~Y «~5.. Printed. 7113/2007 1:11'.47 AM r~ L • BP EXPLORATION.` Page 1 of 3 Qperations Summary Report Legal Well Name: MPK-30 Common Well Name: MPK-30 Spud Date: 10/19/1996 Event Name: WORKOVER Start: 10/2/2007 End: 10/12/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/7/2007 Rig Name: NABORS 4ES Rig Number: Date !From - To ~ Hours,.. Task I Code I NPT I Phase I Description of Operations 10/3/2007 00:00 - 02:00 2.00 RIGD P PRE R/D equip. Scope down & Lower derrick. 02:00 - 03:00 1.00 RIGD P PRE R/D & pull rig, pits & pipe shed off well. 03:00 - 06:00 3.00 MOB P PRE Move from MPE-30A to MPK-30. Move is - 5 miles. Move Rig, Pipe Shed & Pits. 06:00 - 08:00 2.00 MOB P PRE PJSM. Spot sub, pits, pipe shed & camp. Raise & scope derrick. Rig accepted @ 08:00 hrs, 10/03/2007. 08:00 - 10:30 2.50 KILL P DECOMP PJSM. Hook up lines to tiger tank, take on heated seawater. 10:30 - 11:30 1.00 KILL P DECOMP PJSM. P/U lubricator, pressure test to 500psi, OK. Pull BPV, I/A = 10'psi, tbg = 0 psi. on uc pre i sa ety meeting. 11:30 - 12:00 0.50 KILL P DECOMP PJSM. Pressure test lines to 1000 / 3500 psi, OK. 12:00 - 14:30 2.50 KILL P DECOMP PJSM. Circulate heated seawater down tubing & up I/A, thru choke & to tiger tank @ 4 bpm / 1150 psi to clean sewater returns, 575 bbls pumped. 14:30 - 15:30 1.00 WHSUR P DECOMP PJSM. Monitor well, tbg & I/A on vacuum. Set two way check & test @ 1000 psi, charted, OK. 15:30 - 17:00 1.50 WHSUR P DECOMP PJSM. Nipple down tree. 17:00 - 19:30 2.50 BOPSU P DECOMP N/U BOPE, Choke & kill lines. M/U test jt. 19:30 - 23:00 3.50 BOPSU P DECOMP Pressure test BOP as per BP/AOGCC rquirements. LP 250 psi, HP 3500 si. Had 1 Fail, then pass valve. BOP test witnessing waived by Lou Grimaldi w/ AOGCC. 23:00 - 00:00 1.00 BOPSU P DECOMP P/U lubricator & test same to 500 psi. 10/4/2007 00:00 - 01:00 1.00 BOPSU P DECOMP Pull TWC. L/D lubricator &TWC. 01:00 - 01:30 0.50 PULL P DECOMP M/U landing jt into hanger w/ 9 turns. BOLDS. R/U circulating hose. 01:30 - 03:00 1.50 PULL P DECOMP Mix 1 bbl of EP Mud Lube in 39 bbls of seawater. Pump & spot EP ML pill out tubing & Up to -7000'. Pumped 3 BPM @ 620 psi. Pumped 150 bbls. 03:00 - 06:00 3.00 PULL P DECOMP Work string up to 125K. Had 60" stretch (a) 120K & 68" (a~ 125K. Con't to work pipe & circulate bottoms up. ,I~osina 30 bbls/hr while circulating @ 3 BPM - 18% losses. E-line on the way should be on location after crew change. 06:00 - 10:00 4.00 PULL P DECOMP PJSM. Nipple up shooting flange, begin rigging up E line, plan forward change, rig down E line & let them stand by, nipple down shooting flange. Develop plan forward for acid job. Suspect tubing is being restrained by scale ... calcium carbonate. 10:00 - 17:00 7.00 PULL P DECOMP Wait on Schlumberger acid. Order shower, dirty vacuum truck, another load of seawater. Reland tubing, RILDs, test packoff @ 5000 psi / 30 minutes, good test. Establish injection rate of 3 bpm / 110 psi, & 4 bpm / 225 psi, OK. 17:00 - 18:00 1.00 PULL P DECOMP Schlumberger acid pumpers on location, spot up same. . 18:00 - 18:30 0.50 PULL P DECOMP Crew change. Inspect derrick. Check PVT alarms. 18:30 - 20:30 2.00 PULL P DECOMP Con't to R/U acidizing equip. Spot in trucks. Set & fill portable shower, 20:30 - 21:30 1.00 PULL P DECOMP Hold PJSM w/ all hands. Review acidizing procedure, assign tasks to specific personnel & discussed acid hazards w/ MSDS sheets. Pump 6 bbis, fill lines & Pressure test to 4000 psi. 21:30 - 00:00 2.50 PULL P DECOMP Acidize wellbore & completion w/ 126 bbis of 15% DAD HCI acid. Pumped @ 3 BPM. Pressure increased from 0 to 250 psi. Swapped to seawater & con't to pump 85 bbis @ 3 BPM, pressure increased from 250 to 350 psi. Slowed pump to 2 BPM & pumped 120 bbis. Pressure increased from 230 to 265 psi. S/D ISIP 150 psi. Printed: 10/25/2007 1:23:27 PM • BP EXPLORATION Page 2 of 3 `. Operations Summalry Report Legal Well Name: MPK-30 Common Well Name: MPK-30 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Date from - To ~ Hotjrs Task I Code NPT Spud Date: 10/19/1996 Start: 10/2/2007 End: 10/12/2007 Rig Release: 10/7/2007 Rig Number: Phase I Description of.Operations 10/5/2007 100:00 - 00:30 I 0.501 PULL P 00:30 - 01:30 I 1.001 PULL I P 01:30 - 02:30 I 1.00 I PULL I P 02:30 - 03:00 I 0.501 PULL I P 03:00 - 03:30 I 0.501 PULL I P 03:30 - 05:00 I 1.501 PULL I P 05:00 - 06:00 1.00 PULL P 06:00 - 14:00 8.00 PULL P 14:00 - 15:30 1.50 PULL P 15:30 - 17:00 1.50 PULL 17:00 - 17:30 0.50 CLEAN P 17:30 - 18:00 I 0.50 CLEAN ( P 18:00 - 18:30 0.50 CLEAN P 18:30 - 20:30 2.00 CLEAN P 20:30 - 00:00 3.50 CLEAN P 10/6/2007 00:00 - 05:00 5.00 CLEAN P 05:00 - 06:00 1.00 CLEAN P 06:00 - 08:00 2.00 CLEAN P 08:00 - 15:00 7.00 CLEAN P 15:00 - 16:30 1.50 CLEAN P 16:30 - 17:00 0.50 CLEAN P 17:00 - 18:00 1.00 CLEAN P 18:00 - 18:30 0.50 CLEAN P 18:30 - 19:00 0.50 RUNCO 19:00 - 22:30 3.50 RUNCO 22:30 - 00:00 I 1.501 RU 110/7/2007 100:00 - 04:30 I 4.501 RUNCO DECOMP Allow acid to soak & spend for 30 min. Pressure dropped from 150 psi to 40 psi. DECOMP Flush acid by bullheading down annulus w/ 125 bbls of seawater. Pumped 2 BPM, pressure increased from 230 psi to 360 psi.. SI annulus. ISIP 240 psi. Pump down tubing & clear w/ 10 bbls of seawater. Pumped 2 BPM, pressure increased from 510 to 530 psi. ISIP 310 psi. DECOMP Monitor both sides after equalizing. SI pressure. Pressure dropped from 190 psi to 30 psi in 1 hr. 5. min 150 psi, 10 min 120 psi. 30 min 70 psi. DECOMP Bleed off pressure from 30 psi to 0 psi.Open well. Flowed back -5 bbls. M/U landing jt into hanger. BOLDS. DECOMP P/U & pull hanger to floor w/ 75K .ESP cable had parted @ the plug & was wadded up above 1st LaSalle clamp. Back out & L/D hanger & landing jt. DECOMP Rig down E-line equip from floor. Clean & clear floor. R/U to pull ESP completion. Re-spot spooling unit. DECOMP POOH & stand back 2 7/8" ESP completion. DECOMP PJSM. Continue to POOH w/ 2 7/8" EUE 8 rnd tbg & ESP cable, standing back tubing, spooling up cable & double displacing w/ seawater. Cable is slipping through clamps, so clamps will be trashed and new ones used to run new ESP completion. Recovered 170 clamps, nothing lost down hole. DECOMP Break out & L/D ESP. DECOMP Clear & clean rig floor. DECOMP P/U running tool. Install Wear bushing. Run in 4 lock down screws. L/D running tool. DECOMP R/U floor to run 3 1/2" DP. DECOMP Crew Channge. Inspect derrick. Check PVT alarms. DECOMP P/U, tally, & M/U BHA #1 to clean out wellbore as follows: Mule Shoe, 8 jts PAC DP, XO, XO, Csg Scraper, Bit Sub, Bumper Sub, Jars, 6 - DCs. TL = 460.85'. DECOMP P/U 3 1/2" DP 1x1 &RIH w/ BHA #1....150 jts in hole. DECOMP P/U 3 1/2" DP 1x1 & RIH w/ BHA#1. P/U 324jts. DECOMP Go thru toa of Versatrieve ~c~L( 10.r,QR,1_ DECOMP PJSM. Tag up @ 10,704'. Up wt 125K, down wt 92k. Make up head pin circulating ose, close annular and bring on pump @ 4 bpm / 250 psi. Reverse circulate down to clean out tail pipe. Tag hard 10,754', PXN plu Reverse circulate to clean returns, see fine sand / sluggits across shaker. Cleaned up OK. DECOMP PJSM. Break off headpin, open annular, POOH & LDDP DECOMP PJSM. L/D collars & BHA. Clear /clean rig floor. DECOMP P/U running tool, pull Wear Bushing. L/D same. DECOMP Clear & clean rig floor. DECOMP Crew change. Inspect derrick. Check PVT alarms. RUNCMP Load ESP to floor. R/U to run 2 7/8" completion. RUNCMP M/U & service ESP. Pull MLE over sheave. Plug in ESP cable. Test same. RUNCMP RIH w/ ESP on stands of 2 7/8" tubing. Pump thru ESP & check cable every 2000'. 1 BPM @ 450 psi. M/U connections to 2300 ft-Ibs. RIH w/ 17 stands. RUNCMP Con't to RIH w/ ESP on stands of 2 7/8" tubing. Pump thru ESP Printed: 10/25/2007 1:23:27 PM A C, .7 BP EXPLORATION Page 3 of 3 .Operations Summary;Report Legal Well Name: MPK-30 Common Well Name: MPK-30 Spud Date: 10/19/1996 Event Name: WORKOVER Start: 10/2/2007 End: 10/12/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/7/2007 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase. Description of Operations 10/7/2007 00:00 - 04:30 4.50 RUNCO RUNCMP & check cable every 2000'. 1 BPM @ 450 psi. MU tubing connections to 2300 ft-Ibs. Ran in hole w/ 80 stands 04:30 - 08:00 3.50 RUNCO RUNCMP Make reel to reel splice in ESP cable @ 7800'. 08:00 - 10:30 2.50 RUNCO RUNCMP PJSM. Continue in hole w/ ESP completion. Up wt 74K, down wt 50K. 10:30 - 12:30 2.00 RUNCO RUNCMP PJSM. M/U hanger, make final connection w/ ESP cable & test, OK. 12:30 - 13:00 0.50 RUNCO RUNCMP PJSM. Land hanger, RILDs. 13:00 - 14:00 1.00 RUNCO RUNCMP PJSM. Set two way check, test from the top @ 3500 psi, 10 minutes, OK. Test from below, pumping into formation @ 4 bpm / 250 psi, OK. 14:00 - 15:00 1.00 BOPSU P RUNCMP PJSM. N/D BOPE. 15:00 - 17:00 2.00 WHSUR P RUNCMP PJSM. N/U tree. Test hanger void @ 5000 psi / OK. Test tree to 4500 psi, OK. Make final test on ESP cable, OK. 17:00 - 18:00 1.00 WHSUR P RUNCMP Secure well & cellar. Release rig @ 18:00 hrs. RDMO. Printed: 10/25/2007 1:23:27 PM Tree: 2 9/16" - 5M FMC •~ " ~ pU K-30 (Kup.) Wellhead: 11" x 7" 5M FMC Gen 5a w/ 2 7/8" WKM Tubing Hanger , w/ 3° L.H. Acme Threads , 2.5" CIW H BP ~ '~' 20" 91.1 ppf, H-40 115' KOP @400' Max. hole angle = 57 to 62 deg. f/ 3650 to11,041' (PBTD) Hole angle thru' parts = 58 deg 9 5/8", 47 ppf, 6653' btm 44 jts. P-110 Btrc. i next 6 jts. L-80 Mod. Strc. top 109 jts L-80 NSCC '~ Two 21' x 7" sFtort joints ~', f/ 10,255'-10,29T wlm. 2 7/8" 6,5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btrc. prod. casing ( drift ID = 6.151 ", cap. = 0.0383 bpf ; Mid-pert ND = 7075' Mid-pert MD = 10681' PBTD TVD = 7316 PBTD MD = 11041' Stimulation Summary none (selectively perforated rather than frac packed) Pertoration Summary Ref los7: 11/25/96 GR/CCL Size SPF Interval TVD Kup'C' Sand 4.5" 5 10,588`-10,658' 7024'-7063' Kup 'B' Sand 4.5" 5 10,704'-10,748' 7088`-7111' 11/27/96 JBF Initial ESP completion by Nabors 06/15/98 M. Linder RWO Screens added/ Pig tail pull & 04/05/02 B. Haseb RWO Nabors 4ES 05/05/04 . Cubbon RWO Nabors 4ES 10/6/07 REH ESP RWO- 4ES C . DF Elev. = 57.5' (N 22E) Orig. GL Elev. = 28.0' DF Ta 7° csg. hng. = 28.5' (N 22 Camco 2-7/8" x 1' ~ 37' sidepocket KBMM GLM 9 5/8" Howco 'ES' 2479' Cementer Camco 2-7/8" x 1" 10,211' sidepodcet KBMM GLM 2-7/8' XN nipple 10,364' {ID 2.205") Pump, 156 Stg. GC2900, 10,408` Model - GPMTAR 1:1 Bolton Intake 10,427' Intake 6,925' TVD Tandem Seal Section 10,428' ?AOdel GS63 DB UT/LT ll K6 PFS AFLAS/HSN Motor, 266 HP, 2345 volt, 10,442` 69 amp, 562 Series KMH PumpMate w/6 fln Centralizer 10,$67 Note: Screens cut out on 4/13/00 r' HES Versatrieve pkr. 10546' 4.5"125 Micron Poroplus 10596' screen 12.6# Ll blank pipe 10658'- 10694' 4.5"125 Micron Poroplus 10695' screen 12.6# Ll 4.5" HES XN nipple w/ 10767' PXN Plug W/LEG 10778' 7" float collar (PBTD) 11041' 7" float shoe 11122' MILNE POINT UNIT WELL K"30 API NO: 50-029 22711 BP EXPLORATI©N (AK) '~'- Scblumbepger ¡Ci(o -I(O~ R,ECEIVE[) 07/27/07 NO. 4346 Alaska Data & Consulting Services 2525 Gambel! Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth JUL. 3 0 zom ¡\laska Oil & Gas Cons. Con Anchorage 1 NED AUG 0 1 Z007 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Well Job# Loa DescriDtion Date BL Color CD 3-25/L-27 11686762 STATIC PRESSURE SURVEY 07/09/07 1 4-18/S-30 11813062 STATIC PRESSURE SURVEY 07/10/07 1 2-50/U-08 11676953 LDL 07/13/07 1 1-61/Q·20 11695066 SBHP SURVEY 07/13/07 1 3-41/K-39 11846795 WFL & PRESS GRADIENT 07/17/07 1 1-41/0-23 11695068 INJECTION PROFILE 07/24/07 1 3-41/K-39 11846795 IPROF & JEWELRY 07/16/07 1 L 1-09 11626109 LDL 06/27/07 1 02-30B 11626108 LDL 06/25/07 1 H-07A 11637346 LDL 06/30/07 1 12-0SA 11638649 FPIT 07/04/07 1 12-12A 11661162 MEM STATIC TEMP/JEWELRY 07/05/07 1 P2-08 11686761 STATIC PRESSURE SURVEY 07/05/07 1 17-02 11745227 MEM GLS 07/10/07 1 09-11 11686765 STATIC PRESSURE SURVEY 07/11/07 1 X-19B 11801075 LDL 06/19/07 1 MPK-30 11676952 FPIT 07/12/07 1 11-08 11813061 STATIC PRESSURE SURVEY 07/07/07 1 03-14A 11849926 BHP SURVEY 07/25/07 1 01-16 11630486 PROD PROFILE 06/28/07 1 MPH-17 11813063 CBL & IMAGE LOG 07/21/07 1 01-15A 11849924 USIT 07/20/07 1 02-30B 11813058 USIT 07/04/07 1 MPJ-24 11638647 USIT 06/29/07 1 E-101 11630488 PRODUCTION PROFILE 06/30/07 1 G-18A 11209612 MCNL 07/19/06 1 1 . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambel! Street. Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Received by: gC£> ) STATE OF ALASKA ALAS, .' OIL AND GAS CONSERVATION COMM. )ION REPORT OF SUNDRY WELL OPERATIONS Alask~ Oi¡ & Gas Cons. CommiS$UHi 1. Operations Abandon D Repair Well D Plug Perforations D Stimulate 0 Other c:f'nchoraQt\ Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development P Exploratory C .J..,96-1680 3. Address: P.O. Box 196612 Stratigraphic Service 6. Af5'1 Num.Þ,e~: Anchorage, AK 99519-6612 50-029-22711-00-00 7. KB Elevation (ft): 9. Well Name and Number: I'~\J[:I V I::U OCT 1 0 2005 56.95 KB MPK-30 ADL-375132 11. Present Well Condition Summary: 10. Field/Pool(s): MILNE POINT Field/ KUPARUK RIVER OIL Pool 8. Property Designation: Total Depth measured 11145 true vertical 7306.37 teet feet Plugs (measured) Junk (measured) None None Effective Depth measured 11041 true vertical 7256.65 teet feet Casing Conductor Surface Production Liner Length 84 6623 11092 232 Size 20" 91.5# H-40 9-5/8" 47# L-80 7" 26# L-80 4-1/2" 12.6# L-80 MD 31 - 115 30 - 6653 30 - 11122 10546 - 10778 TVD Burst Collapse 31 - 115 1490 470 30 - 4908.02 6870 4760 30 - 7295.37 7240 5410 7000.51 -7126.79 8430 7500 Perforation depth: Measured depth: 10588 - 10658 True Vertical depth: 7024.54 - 7063.24 10704 - 10748 7087.92 - 7111.16 $(;ANNE[) NOV 0 8 2005 Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 20 - 10472 Packers and SSSV (type and measured depth) 4-1/2" HES Versatrieve Packer 10546 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: see attached fluid summary T/I/O 900/550/50 13. RBDMS BFL 0 CT ] 1. 2005 250 Representative Daily Average Production or Injection Data Gas-Met I Water-Bbl I Casing Pressure SHUT - IN 104 I 2374 I 15. Well Class after croposed work: Exploratory r Development P 16. Well Status after proposed work: Oil P Gas r WAGr Tubing pressure Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 50 900 Service r x GINJ r WINJ r WDSPLr 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 Sharmaine Vestal Printed Name Sharmaine Vestal ~ , I Signatu~~ ~&J Title Data Mgmt Engr Phone 564-4424 Date 9/29/2005 Form 10-404 Revised 04/2004 ,,-\ ~'\ ~ r'~, t\, At I. r.,,\ l : ~". t '\' \ . \ .' l \.". l ., '- Submit Original Only ",..i ) ) MPK-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 9/11/2005 T/I/O=550/550/50 Acid Treatment. Pumped 10 bbls 7.5% HCL Acid, 3 bbls meoh, and 52 bbls crude down tbg. Final WHP=900/550/50 FLUIDS PUMPED BBLS 10 7.50/0 HCL 52 Crude 3 MeOH 65 TOTAL ~ STATE OF ALASKA ~ ALASKÁ .L AND GAS CONSERVATION CC.. .J1ISSION REPORT OF SUNDRY WELL OPERATIONS <. 1. Operations Performed: 0 Abandon 0 Alter Casing D~ Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 0 Suspend 181 Repair Well 181 Pull Tubing 0 Operation Shutdown 0 Perforate 0 Plug Perforations 0 Stimulate 0 Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: IBI Development 0 Exploratory 0 Stratigraphic Test 0 Service 0 Waiver 181 Other 0 Time Extension Change Out ESP 0 Annular Disposal 5. Permit To Drill Number 196-168 6. API Number: 50-029-22711-00-00 99519-6612 KBE = 56.95' 8. Property Designation: ADL 375132 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 6621' Intermediate Production 11094' Liner 11145 7306 11041 7257 Perforation Depth MD (ft): Perforation Depth TVD (ft): 9. Well Name and Number: MPK-30 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands feet feet Plugs (measured) N/A feet Junk (measured) N/A feet Size MD TVD 20" 112' 112' 9-5/8" 6652' 4908' 7" 11122' 7295' Burst Collapse 6870 4760 7240 5410 2-7/8",6.5# RECE\VED MAY 2 8 2004 AIa8ka 01\ & Gal Cons. eommieston L-80 Anc:honage 10474' 10588' - 10748' 7025'-7111' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 7" HES Versatrive with two 4-1/2" Poroplus screen assemblies at 10596' and 10695' 10546' Treatment description including volumes used and final pressure: RBDMS BFL JUN 0 3 2004 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run IBI Daily Report of Well Operations IBI Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure 15. Well Class after proposed work: 0 Exploratory IBI Development 0 Service 16. Well Status after proposed work: IBI Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sandra Stewman ~~~~Äc~vQ.I f'- Form 10-404 Revised 12/2003 Title Technical Assistant C-, Prepared By Name/Number. Phone \ Ï\ 5,~7p~ I A 'Date C ) "18-Ùi...\Sondra Stewman, 564-4750 OKib\¡\J .. ~ 1"'"'"'\ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-30 MPK-30 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/4/2004 Rig Release: 5/5/2004 Rig Number: 4ES Spud Date: 10/19/1996 End: 5/5/2004 l1av~k "'i'/,""' . . 5/212004 16:00 - 18:00 2.00 MOB P PRE PJSM. Scope down & layover derrick. 18:00 - 00:00 6.00 MOB P PRE PJSM. Move rig & rig componenets from MP K-33 to MP K-30. Rig up. Raise & scope up derrick. 5/3/2004 00:00 - 01 :00 1.00 KILL P DECOMP Rig Accepted @ 0001 hrs, 05/03/2004. Rig up lines to tiger tank & tree. 01 :00 - 02:00 1.00 KILL P DECOMP PJSM. Take on 130 deg seawater & pull BPV. SITP = 490 psi, SICP = 630 psi. 02:00 - 06:00 4.00 KILL P DECOMP PJSM. Commence killing well. Circulate @ 4 bpm I 600 psi down tbg, 60 bbls. Shut down, monitor. Tbg to 0 psi. No returns up IIA. Pump 5 bbls down IIA @ 2 bpm 1250 psi. Blockage in super choke, line up on manual choke. Pump down tbg @ 4 bpm 1700 psi, oil in returns up \lA. With 20 bbls away, seawater returns up IIA. Bullhead 16 bbs down tbg @ 2 bpm I 650 psi. Resume circulating @ 3 bpm 1700 psi, 500 bbls. Monitor well. 06:00 - 07:00 1.00 KILL P DECOMP PJSM. Circulate @ 2-3 bpm, 250-550 psi, losing approximately 1 bpm to formation. 07:00 - 07:30 0.50 KILL P DECOMP Monitor well. Both sides dead. 07:30 - 08:00 0.50 WHSUR P DECOMP PJSM. Set two way check valve. 08:00 - 10:00 2.00 WHSUR P DECOMP PJSM. N/D existing tree. 10:00 - 13:00 3.00 BOPSUP P DECOMP PJSM. N/U BOPE. Change out kill line after discovering source of blockage during well kill was in kill line. 13:00 - 16:00 3.00 BOPSUP P DECOMP PJSM. Conduct full BOPE test. Witnessing of test waived by AOGCC State Rep John Spaulding. No failures. 16:00 - 17:00 1.00 WHSUR P DECOMP M/U lubricator & extension. Pull TWC. UD lubricator. 17:00 - 19:00 2.00 WHSUR P DECOMP M/U landing it. BOLDS. P/U hanger wI 96K. Hanger free. Circulate bottoms up. 3 BPM @ 600 psi. Had gas to surface. Took 41 Bbls to break circulation. Lost total of 73 bbls to fill & circulate out gas. Monitor well, well dead. 19:00 - 19:30 0.50 PULL P DECOMP Pull hanger to floor, disconnect ESP cable & UD landing jt & hanger. 19:30 - 20:00 0.50 PULL P DECOMP Attach ESP cable to spooler. 20:00 - 23:00 3.00 PULL P DECOMP POOH w/2 7/8" tubing. to 5483'. 23:00 - 23:30 0.50 PULL P DECOMP Change out spools on spooling unit. 23:30 - 00:00 0.50 PULL P DECOMP Con't to POOH wI 2 7/8" tubing. 5/4/2004 00:00 - 02:00 2.00 PULL P DECOMP Con't to POOH & stand back 2 7/8" tubing. Pulled 109 stands + 2 GLMs. 02:00 - 04:30 2.50 PULL P DECOMP UD pump & motor. Test same. outside of ESP was scaled up. 04:30 - 05:30 1.00 PULL P DECOMP Clear & clean rig floor. Rlu to M/U new ESP & RIH wI 2 7/8" tubing. 05:30 - 08:00 2.50 RUNCOMP COMP P/U & M/U ESP. Service & test same. Pull ESP cable over sheave & plug into pump & test. 08:00 - 14:00 6.00 RUNCOfI.tP COMP RIH wI ESP on 2 7/8" tubing. Test & pump thru pump every 2000'. 14:00 - 17:30 3.50 RUNCOMP COMP Make reel to reel splice @ 8000'. Test same. 17:30 - 19:00 1.50 RUNCOMP COMP Finish RIH wI completion. P/U 77K, S/O 43K. 19:00 - 19:30 0.50 RUNCOMP COMP P/U landing jt & M/U into hanger. Install penetrator in hanger. 19:30 - 21 :30 2.00 RUNCOMP COMP Make field connection in ESP cable. Test & M/U into penetrator. Land hanger & RILDS. Install TWC. 21 :30 - 23:00 1.50 BOPSUP P COMP N/D BOPE. 23:00 - 00:00 1.00 WHSUR P COMP N/U X-mas tree. Test void to 5000 psi. Test tree to 5000 psi. Make final ESP check. 5/5/2004 00:00 - 01 :00 1.00 WHSUR COMP P/U lubricator, Pull TWC. Install BPV. UD lubricator. clean Printed. 5/10/2004 9:21:31 AM - " I"'""'- 1"'"'"'\ , . ~ . ~ ' . .~. ." . , " Be;, E><,!:~~~I~Jl,Q~ ' "ti QP ~"§.\1~m m@'~Y,RefJ:ort:,,:L ~~;I,; :,:,;':~:J~);;;:;Li~::;:J:'::;, ::;\;;!~~~¿:i~~,i::~},::(y;! Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-30 MPK-30 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/4/2004 Rig Release: 5/5/2004 Rig Number: 4ES Spud Date: 10/19/1996 End: 5/5/2004 NPr 5/5/2004 00:00 - 01 :00 1.00 WHSUR COMP cellar secure welL... RELEASE RIG @ 0100 hrs. Printed: 5/10/2004 921 31 AM '. _. Tree: 29/16" - 5M FMC ¡""""\ M U Wellhead: 11" x 7" 5M FML- ",en 5a P K-30 (Kup.) wI 2 7/8" WKM Tubing Hanger, wI 3" LH. Acme Threads, 2.5" CIW H BPV profile . - 20" 91.1 ppf, H-40 115' I' KOP @ 400' Max. hole angle = 57 to 62 deg. fl 3650 to11 ,041' (PBTD) Hole angle thru' perfs = 58 deg 95/8",47 ppf, 16653' btm 44 its. P-110 Btrc. next 6 its. L-80 Mod. Btrc. top 109 its L-80 NSCC Two 21' x 7" short joints f/10,255'-10,297' wlm. I~ 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift 10 = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btrc. prod. casing (drift 10 = 6.151", cap. = 0.0383 bpf) Mid-perf TVD = 7075' Mid-perf MO = 10681' PBTD TVD = 7316 PBTO MO = 11041' Stimulation Summary none (selectively perforated rather than frac packed) Perforation Summary Ref loq: 11/25/96 GRlCCL Size SPF Interval TVD Kup 'C' Sand 4.5" 5 10,588'-10,658' 7024'-7063' Kup 'B' Sand 4.5" 5 10,704'-10,748' 7088'-7111' Ori~ Elev. = 57.5' (N 22E) Orig. - - Elev. = 28.0' OF To 7" csg. hng. = 28.5' (N 22E) Camco 2-7/8" x 1" I I sidepoeket KBMM GLM 139' 0 9 5/8" Howco 'ES' Cementer I 2479' , Cameo 2-7/8" x 1" side pocket KBMM GLM 110,213' I 2-7/8" XN nipple (102.205") 110,356 1 110,398'1 110,414'1 Pump, 156 Stg. GC2900, Model- GPMTAR 1:1 Bolt on Intake Intake 6,925' TVD Tandem Seal Section I ' 1 Model GSB3 DB UT/L T IL H6 PFS 1 0,446 AFLAS/HSN Motor, 266 HP, 2345 volt, 69 amp, 562 Series KMH 110,469' I PumpMate w/6 fin Centralizer 110,472' 1 Note: Screens cut out on 4/13/00 L :¿::;;: 7" HES Versatrieve pkr. I 10546' I - 4.5"125 Micron Poroplus I 10596' I screen 12.6# LT 0 - blank pipe 10658'- 10694' - 4.5"125 Micron Poroplus I 10695' I screen 12.6# LT ~ 4.5" HES XN nipple wi I 10767' I PXN Plug W/LEG I 10778' I ..4n TI . 7" float collar (PBTD) I 11041' I 7" float shoe I 11122' I DATE REv. BY COMMENTS 11/27/96 JBF Initial ESP completion by Nabors 4E~ 06/15/98 M. Linder - AWO Screens addedl Pig tail pull & lanJ 04/05/02 B. Hasebe RWO Nabors 4ES 05/05/04 J. Cubbon RWO Nabors 4ES -, MILNE POINT UNIT WELL K-30 API NO: 50-029-22711 BP EXPLORATION (AK) -. """ 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 Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 56.95' [] Exploratory 7. Unit or Property Name 3. Address I"! Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3605' NSL, 1965' WEL, SEC. 3, T12N, R11E, UM MPK-30 At top of productive interval 9. Permit Number / Approval No. 196-168 443' NSL, 4079' EWL, SEC. 2, T12N, R11E, UM 10. APl Number At effective depth 50- 029-22711-00 251' NSL, 4415' EWL, SEC. 2, T12N, R11E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 211' NSL, 4502' EWL, SEC. 2, T12N, R11E, UM Sands 12. Present well condition summary Total depth: measured 11145 feet Plugs (measured) true vertical 7306 feet Effective depth: measured 11041 feet Junk (measured) true vertical 7257 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 6621' 9-5/8" 1500 sx Trinity Lite Wate, 750 sx PF 6652' 4908' Intermediate Production 11094' 7" 245 sx Class 'G' 11122' 7295' Liner RECEIVED Perforation depth: measured 10588'-10658', 10704'-10748' ~,P~ true vertical 7024'- 7063', 7087'- 7111' ~(~ Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE tubing to 10467' Packers and SSSV (type and measured depth) 7" HES Versatrive packer at 10546' with two 4-1/2" Poroplus screen assemblies at 10596' and 10695'; 4-1/2" HES XN nipple with PXN plug at 10767' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-abl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby cert~going is true an_d correct to the best of my knowledge Signed s(:~ra-~ '""'~ 'Stewman~jY'~~~..~__, Title Technical Assistant Date ('._-"'~ ~---. ~.~ ~ ~-..~ ? ~,.. ! ,~.,Pr~,,aredByName/Nurnber: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate LORATiON Page1 of 1 mma Report Legal Well Name: MPK-30 Common Well Name: MPK-30 Spud Date: 10/19/1996 Event Name: WORKOVER Start: 4/3/2002 End: 4/4/2002 Contractor Name: NABORS Rig Release: 4/4/2002 Rig Name: NABORS 4ES Rig Number: 4 Date ~Erom - To ~Hours Activity !Cod~NPT_~Phase:; Description of Operations 4/3/2002 00:00 - 06:00 6.00 RIGU P PRE MI/RU / SAFE OUT EQUIPMENT/RIG ACCEPT @ 0600 HRS. 04/03/2002 06:00 - 08:30 2.50 KILL P DECOMP RIG UP WELL KILL EQUIPMENT & TAKE ON SEAWATER. & TEST TO 3500 PSI. 08:30 - 11:00 2.50 KILL P DECOMP CIRC. INFLUX FROM WELL BORE. & MONITOR SAME. 11:00 - 11:30 0.50 WHSUR P DECOMP SET TWC 11:30- 12:30 1.00 WHSUR P DECOMP NIPPLE DN TREE. 12:30- 14:30 2.00 BOPSUF P DECOMP NIPPLE UP BOP 14:30 - 15:30 1.00 BOPSUF P DECOMP TEST BOP (BODY TEST ONLY & FUNCTION) TO 3500 PSI. (TEST WITNESSED BY JOHN SPAULDING WITH AOGC) 15:30 - 17:00 1.50 BOPSUF; P DECOMP RIG LUBRICATOR & PULL TWC. ~17:00 - 18:00 1.00 PULL P DECOMP MU LANDING JT. & PULL HANGER TO FLOOR & LAY DN SAME. 18:00 - 20:00 2.00 PULL P DECOMP POOH WITH ESP COMP. 20:00 - 20:30 0.50 PULL P DECOMP ~CUT SPLICE & CHANGE SPOOLS 20:30- 00:00 3.50 PULL P DECOMP POOH WITH ESP COMP. 4/4/2002 00:00 - 02:00 2.00 PULL P DECOMP POOH WITH ESP ASSY. 02:00 - 03:30 1.50 PULL P DECOMP LAY DN ESP ASSY. 03:30 - 04:30 1.00 PULL P DECOMP CLEAR & CLN RIG FLOOR. & PREP FOR TRIP IN HOLE 04:30 - 06:00 1.50 RUNCO~ P COMP MAKE UP & SERVICE ESP ASSY. 06:00 - 08:30 2.50 RUNCOr P COMP RIH WITH ESP ASSY. 08:30 - 11:00 2.50 RUNCOI~ COMP MAKE SPLICE ESP CABLE 11:00 - 12:30 1.50 RUNCOF~ COMP RIH WITH ESP.TO 7140' 12:30 - 14:30 2.00 RUNCOP~ COMP TROUBLE SHOOT ESP (BAD READING IN TEMP. ) 14:30 - 16:30 2.00 RUNCOP~ COMP RIH WITH ESP ASSY TO HANGER DEPTH. 16:30 - 17:00 0.50 RUNCOP~ COMP MAKE UP HANGER & PULL ESP CABLE OVER SHEAVE. 17:00 - 19:30 2.50 RUNCOP~ COMP MAKE EFT CONNECTOR & LAND HANGER & RILDS & SET TVVC. 19:30 - 20:00 0.50 RUNCOI~ COMP TEST TWC TO 2500 20:00 - 21:30 1.50 BOPSUF P COMP NIPPLE DN BOP 21:30 - 22:30 1.00 WHSUR P COMP NIPPLE UP TREE.& TEST TO 5000 PSI, 22:30 - 23:00 0.50 WHSUR P COMP RIG LUBRICATOR & PULL TWC & SET BPV. 23:00 - 00:00 1.00 WHSUR P COMP RIG DN CELLAR EQUIPMENT LINES ETC. & SECURE AREA. RIG RELEASED @ 2359 HRS. 04/04/2002 Printed: 4/8/2002 1:27:15 PM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2001 M p I A T W E IA L U N D ER TH IS M ARK I~ I< C:LORI~iFILM~DOC .... STATE OF ALASKA ' ALASKA ..,IL AND GAS CONSERVATION CO, .... IlSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: i--]Operation Shutdown []Stimulate [] Plugging []Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3605' NSL, 1965' WEL, SEC. 3, T12N, R11E At top of productive interval 443' NSL, 4079' EWL, SEC. 2, T12N, R11E At effective depth 251' NSL, 4415' EWL, SEC. 2, T12N, R11E At total depth 211' NSL, 4502' EWL, SEC. 2, T12N, R11E 12. Present well condition summary Total depth: measured 11145 feet true vertical 7306 feet Effective depth: measured 11041 feet true vertical 7257 feet Casing Length Size Structural Conductor 80' 20" Surface 6621' 9-5/8" Intermediate Production 11094' 7" Liner Perforation depth: measured true vertical 5. Type[~ well: Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 56.95' 7. Unit or Property Name Milne Point Unit Plugs (measured) Junk (measured) 8. Well Number MPK-30 9. Permit Number / Approval No. 196-168 10. APl Number 50- 029-22711 11. Field and Pool Milne Point Unit / Kuparuk River Sands Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE tubing to 10449' Packers and SSSV (type and measured depth) 7" HES Versatrive packer at 10546' with two 4-1/2" Poroplus screen assemblies at 10596' and 10695'; 4-1/2" HES XN nipple with PXN plug at 10767' 13. Stimulation or cement squeeze summary See Attachment ~ Intervals treated (measured) Treatment description including volumes used and final pressure '~,'..~ 0 ~ 2.00,) ~ke Oil & Gas C~s. Commis~ Anchor~e 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Prior to well operation: Subsequent to operation: 15. Attachments I 16. Status of well classifications as: [] Copies of Logs and Surveys run I F21 c~i~ [] Daily Report of Well Operations ! .... [] Gas [] Suspended 17.1 hereby ce/~ that th/~foregoi~ is true an~l correct to the best of my knowledge Signed ~ ~ ANGELA~. SORRENTINO Title Surveillance Engineer Prepared By Name/Number: Casing Pressure Tubing Pressure Service Form 10-404 Rev. 06/15/88 Submit In Duplica~, ORIGINAL 7024'-7063', 7087'-7111' 10588'-10658', 10704'-10748' Cemented MD TVD 250 sx Arcticset I (Approx.) 112' 112' 1500 sx Trinity Lite Wate, 750 sx PF 'E' 6652' 4908' 245 sx Class 'G' 11122' 7295' MPK-$0 DESCRIPTION OF WORK COMPLETED ,Stimulation Operation 02/12/00 A Mud Acid Treatment was performed using the following fluids: SUMMARY Rig up DS Rig up to tree and pressure test surface equipment to 3500 psi. Start down tubing with 36 Bbls of 7.5% HCI preflush start off at 2 bpm. at 680 psi. annulus pressure started at 500 psi. increased rate to 3 bpm. continue swapped to 9% Mud acid 120 Bbl treatment, tubing pressure 1126 psi. continued at 3 bpm. tubing slowly increasing, at 27 Bbls into the treatment ( 63 Bbl total ) there was a pressure break back from 1351 psi to 1168 psi. annulus pressure was 800 psi. continue pumping at 3 bpm. pumped total of 129 Bbls of mud acid. Start on 188 Bbls of 3% NH4Cl ( 120 Bbl overflush - 68 tbg. displacement ) annulus at 1000 psi. continue at our 3 Bpm. annulus built to a maximum of 1480 psi. treatment complete. RD DS. RU HB&R rig up to annulus, Fluid shot indicated 77 Bbls would fill the annulus started down annulus @ 1 Bpm. at 850 psi. pumped 77 Bbls RD HB&R RU HB&R and freeze protect the top 2000' with 12 Bbls of diesel. Fluids Pumped BBLS. Description 188 3% NH4Cl 129 9% Mud Acid 60 7.5% HCL 12 Diesel 389 Total --'. STATE OF ALASKA ' ALASKA C ._ AND GAS CONSERVATION COM~,.SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: I--IOperation Shutdown 1-1Stimulate [] Pull Tubing [] Alter Casing 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3605' NSL, 1965' WEL, SEC. 3, T12N, R11E At top of productive interval 443' NSL, 4079' EWL, SEC. 2, T12N, R11E At effective depth 251' NSL, 4415' EWL, SEC. 2, T12N, R11E At total depth 211' NSL, 4502' EWL, SEC. 2, T12N, R11E [] Plugging [] Perforate .' ',;;i':.:;;': ¢'.':: '-' ~i~::~ !.:;;~-: .;, ;. ;(:.¢';:,..-:? [] Repair Well [] Other Chanqe Out ESP & Add;S'are..e. ns 5. Type of well: [] Development I--I Exploratory I--I Stratigraphic []Service 6. Datum Elevation (DF or KB) KBE = 56.95' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-30 9. Permit Number / Approval No. 96-168 10. APl Number 50-029-22711 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11145 feet Plugs (measured) 7306 feet 11041 feet Junk (measured) 7257 feet ORIGINAL Length Size Cemented M D TVD 80' 20" 250 sx Arcticset I (Approx.) 112' 112' 6621' 9-5/8" 1500 sx Trinity Lite Wate, 750 sx PF 'E' 6652' 4908' 11094' 7" 245 sx Class 'G' 11122' 7295' Perforation depth: measured 10588' - 10658', 10704' - 10748' true vertical 7024' - 7063', 7087' - 7111' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE tubing to 10449' Packers and SSSV (type and measured depth) 7" HES Versatrive packer at 10546' with two 4-1/2" Poroplus screen assemblies at 10596' and 10695'; 4-1/2" HES XN nipple with PXN plug at 10767' 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 Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 5. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil I--I Gas [] Suspended Service 17. I hereby certify that the,loregoin~jis tr~ ,an.d correct to the best of my knowledge Signed TerrieHubble~.j~,/~ ' -,. _ ~ L,~ Title Technical Assistant III Prepared By Name/Number: Date Terrie 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Facility M Pt K Pad Progress Report Well MPK-30 Page Date 1 10 February 99 Date/Time 08 Jun 98 09 Jun 98 10 Jun 98 11 Jun 98 12 Jun 98 13 Jun 98 14 Jun 98 06:00-13:30 13:30-14:30 14:30-16:30 16:30-18:00 18:00-23:30 23:30-00:00 00:00-00:30 00:30-03:30 03:30-06:00 06:00-07:00 07:00-09:30 09:30-10:00 10:00-11:00 11:00-18:00 18:00-21:00 21:00-22:00 22:00-05:00 05:00-06:00 06:00-06:15 06:15-11:30 11:30-15:30 15:30-00:00 00:00-06:00 06:00-06:15 06:15-07:30 07:30-09:30 09:30-15:30 15:30-17:30 17:30-19:00 19:00-23:30 23:30-06:00 06:00-13:00 13:00-15:00 15:00-20:00 20:00-04:00 04:00-05:00 05:00-06:00 06:00-06:15 06:15-07:00 07:00-09:00 09:00-11:00 11:00-11:30 11:30-16:00 16:00-00:00 00:00-02:30 02:30-04:00 04:00-05:00 05:00-06:00 06:00-08:00 08:00-09:00 09:00-10:00 10:00-11:30 11:30-13:00 13:00-14:30 Duration 7-1/2 hr lhr 2hr 1-1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 3hr 2-1/2 hr lhr 2-1/2 hr 1/2 hr lhr 7hr 3hr lhr 7hr lhr 1/4 hr 5-1/4 hr 4hr 8-1/2 hr 6hr 1/4 hr 1-1/4 hr 2hr 6hr 2hr 1-1/2 hr 4-1/2 hr 6-1/2 hr 7hr 2hr 5hr 8hr lhr lhr 1/4 hr 3/4 hr 2hr 2hr 1/2 hr 4-1/2 hr 8hr 2-1/2 hr 1-1/2 hr lhr lhr 2hr lhr lhr 1-1/2 hr 1-1/2 hr 1-1/2 hr Activity Rig moved 100.00 % Rig moved 100.00 % Rigged up Draw works Removed Hanger plug Circulated at 10362.0 ft Installed Hanger plug Removed Xmas tree Rigged up All rams Tested All rams Tested All rams Removed Hanger plug Retrieved Tubing head spool Pulled Tubing in stands Pulled Tubing in stands Pulled Tubing in stands Pulled Tubing in stands Ran Tubing in stands to Pulled Tubing in stands Held safety meeting Pulled Tubing in stands Rig waited · Equipment Fished at 10698.0 ft Pulled out of hole to 6000.0 ft Held safety meeting Pulled out of hole to 0.0 fi Laid down fish R.I.H. to 10730.0 ft Washed to 10769.0 ft R.I.H. to 11041.0 ft Circulated at 11041.0 ft Pulled out of hole to 0.0 fi to 0.0 ft to 8000.0 ft to 10457.0 ft to 10457.0 ft 10698.0 ft to 800.0 ft to 0.0 ft Conducted electric cable operations Conducted electric cable operations Rigged up sub-surface equipment - Other sub-surface equipment Ran Tubing in stands to 10524.0 ft Space out tubulars Functioned Hydraulic packer Held safety meeting Set packer at 10546.0 ft with 1850.0 psi Circulated at 10540.0 ft Pulled Tubing in stands to 7300.0 ft Serviced Drillfloor / Derrick Pulled Tubing in stands to 0.0 ft Installed ESP Installed Electric cable Ran Tubing in stands to 10414.0 ft Installed Tubing hanger Installed Electric cable Installed Electric cable Installed Tubing hanger Removed BOP stack Installed Xmas tree Rig waited · Service personnel Freeze protect well - 2.000 bbl of Diesel Progress Report Facility M Pt K Pad Well MPK-30 Page 1 Date 10 February 99 Date/Time 29 Jun 98 30 Jun 98 06:00-06:15 06:15-08:30 08:30-15:00 15:00-16:00 16:00-17:00 17:00-19:00 19:00-20:30 20:30-22:30 22:30-06:00 06:00-06:15 06:15-07:00 07:00-08:30 08:30-13:30 13:30-15:00 Duration 1/4 hr 2-1/4 hr 6-1/2 hr lhr lhr 2hr 1-1/2 hr 2hr 7-1/2 hr 1/4 hr 3/4 hr 1-1/2 hr 5hr 1-1/2 hr Activity Held safety meeting Rig moved ~00.00 % Circulated at 10334.0 ft Installed Hanger plug Installed BOP stack Tested BOP stack Installed Hanger plug Retrieved Tubing hanger Repaired ESP Held safety meeting Removed BOP stack Installed Xmas tree Rig waited: Equipment Freeze protect well - 82.000 bbl of Oil PERMIT DATA 96-168 96-168 96-168 96-168 96-168 96-168 96-168 96-168 96-168 96-168 96-168 96-168 96-168 AOGCC Individual Well Geological Materials Inventory T DATA PLUS .......................... PERF ~0000-11012 GR/CCL ~6650-11012 ADN-TVD ~_~4850-7302 ADN-MD ~L~'6675-11145 CDR-MD L~-112-11145 CDR-TVD ~L 112-7302 7548 ~CHLUM CDR/ADN DIR SRVY .~S~HLUM 112.-11145. MULTI SHOT SRVY ~PERRY 0-6675 MULTI SHOT SRVY ~ERRY 0-11145 cc~ .~.--~80-10412 PHOTON/GR ~'0560-10820 PDK/GR/CCL ~L/10560-10820 Page: 1 Date: 11/05/98 RUN RECVD FINAL 12/13/96 FINAL 12/13/96 2 12/13/96 2 12/13/96 FINAL 12/13/96 FINAL 12/13/96 1,2 12/13/96 05/16/97 05/16/97 05/16/97 FINAL 06/15/98 FINAL 06/25/98 FINAL 06/25/98 10-407 ._~OMPLETION DATE /t/.~.~/~/ DAILY WSLL OPS ~ /'3/?""7/:i~/ TO )~/a~*,~/~/ Are dry ditch samples required? yes ~d received? Was the well cored? yes ~~alysis description received? Are well tests required? yes ~~eceived?;=~. yes- ..... Well is in compliance Ini%ial CO~ENTS yes .no_ ..... yes, STATE OF ALASKA ALASKA uIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [~ Pull Tubing i--]Alter Casing [] Repair Well [] Other ESP Changeout 6. Datum Elevation (DF or KB) KBE = 56.95' 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3605' NSL, 1965' WEL, SEC. 3, T12N, R11E 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-30 9. Permit Number / Approval No. 96-168 10. APl Number 50- 029-22711 At top of productive interval 443' NSL, 4079' EWL, SEC. 2, T12N, R11E At effective depth 192" NSL, 4406' EWL, SEC.2, T12N, R11E At total depth 146' NSL, 4486' EWL, SEC. 2, T12N, R11E 1. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 11145 feet true vertical 7306 feet Effective depth: measured 11041 feet true vertical 7256 feet Casing Length Size Structural Conductor 80' 20" Surface 6621' 9 5/8" Intermediate Production Liner 11094' 7" Plugs (measured) Junk (measured) Cemented MD TVD 250 sx Arcticset 1 (Approx.) 112' 112' 1500 sx Trinity Lite Wate, 750 sx 6652' 4880' PF 'E' 245 sx Class 'G' 11122' 7267' Perforation depth: measured true vertical 10588' - 10658', 10704' - 10748' (Subsea) 6968' - 7006', 7031' - 7054' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 10381' ORIGiNAl.. Packers and SSSV (type and measured depth) 7" HES Versatrieve packer at 10546' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ~.~aska 0il 8~ .,. · · ' 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 [--I Copies of Logs and Surveys run [~,Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service i17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~_~2-~ ~ /*~¢'~'¢¢~-- Title Staff Technical Assistant Date Prepared By Name/Number: Jeanne L. Haas, 564-5225 Facility M Pt K Pad Progress Report Well MPK-30 Page 1 Date 15 July 98 Date/Time 29 Jun 98 30 Jun 98 06:00-06:15 06:15-08:30 08:30-15:00 15:00-16:00 16:00-17:00 17:00-19:00 19:00-20:30 20:30-22:30 22:30-06:00 06:00-06:15 06:15-07:00 07:00-08:30 08:30-13:30 13:30-15:00 Duration 1/4 hr 2-1/4 hr 6-1/2 hr lhr lhr 2hr 1-1/2 hr 2hr 7-1/2 hr 1/4 hr 3/4 hr 1-1/2 hr 5hr 1-1/2 hr Activity Held safety meeting Rig moved 100.00 % Circulated at 10334.0 ft Installed Hanger plug Installed BOP stack Tested BOP stack Installed Hanger plug Retrieved Tubing hanger Repaired ESP Held safety meeting Removed BOP stack Installed Xmas tree Rig waited: Equipment Freeze protect well - 82.000 bbl of Oil State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 21-Jun-98 Transmittal of Final Prints. Please sign and return copy to the following: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 and BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 _. Well Name Services Bluelines R/F Sepia Film ctk,, \~'~ MPK-30 PDK/GR GRAVEL PACK 1 1 MPK-30 PHOTON/GR 1 1 GR/CCL SET SERVICE 1 1 ~I~' O3\ MPL-37 GR/CCL PERF 1 1 ~q. ~7.3 MPH-08 GR/CCL PERF 1 1 Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate F-I Plugging [] Perforate [~Pull Tubing []Alter Casing [] RepairWell [~Other ESP Changeout 2. Name of Operator BP Exploration (Alaska) Inc. 3. ",~ddress P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3605' NSL, 1965' WEL, SEC. 3, T12N, R11E 5. Type of well: [~ Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 56.95' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-30 9. Permit Number / Approval No. 96-168 10. APl Number 50- 029-22711 At top of productive interval 443' NSL, 4079' EWL, SEC. 2, T12N, R11E At effective depth 192" NSL, 4406' EWL, SEC.2, T12N, R11E At total depth 146' NSL, 4486' EWL, SEC. 2, T12N, RllE 11. Field and Pool Milne Point Unit/Kuparuk River Sands 12. Present well condition summary Total depth: measured 11145 feet true vertical 7306 feet Effective depth: measured 11041 feet true vertical 7256 feet Casing Length Size Structural Conductor 80' 20" Surface 6621' 9 5/8" Intermediate Production Liner 11094' 7" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset 1 (Approx.) 1500 sx Trinity Lite Wate, 750 sx PF 'E' 245 sx Class 'G' MD TVD 112' 112' 6652' 4880' 11122' 7267' Perforation depth: measured true vertical 10588' - 10658', 10704' - 10748' (Subsea) 6968' - 7006', 7031' - 7054' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 10381' Packers and SSSV (type and measured depth) 7" HES Versatrieve packer at 10546' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Subsequent to operation: 15. Attachments [-q Copies of Logs and Surveys run [~Daily Report of Well Operations 17. I hereby certify that the foregoing is tr~ect to the best of my knowledge Signed ~ ~ /~r rieL. Haas - Title Staff Technical Assistant 16. Status of well classifications as: [~ Oil [] Gas I--I Suspended Casing Pressure Tubing Pressure Prepared By Name/Number: Service Date Jeanne L. Haas, 564-5225 Facility M Pt K Pad Progress Report Well MPK-30 Page 1 Rig Nabors 5S Date 18 June 98 Date/Time 08 Jun 98 09 Jun 98 10 Jun 98 11 Jun 98 12 Jun 98 13 Jun 98 14 Jun 98 06:00-13:30 13:30-14:30 14:30-16:30 16:30-18:00 18:00-23:30 23:30-00:00 00:00-00:30 00:30-03:30 03:30-06:00 06:00-07:00 07:00-09:30 09:30-10:00 10:00-11:00 11:00-18:00 18:00-21:00 21:00-22:00 22:00-05:00 05:00-06:00 06:00-06:15 06:15-11:30 11:30-15:30 15:30-00:00 00:00-06:00 06:00-06:15 06:15-07:30 07:30-09:30 09:30-15:30 15:30-17:30 17:30-19:00 19:00-23:30 23:30-06:00 06:00-13:00 13:00-15:00 15:00-20:00 20:00-04:00 04:00-05:00 05:00-06:00 06:00-06:15 06:15-07:00 07:00-09:00 09:00-11:00 11:00-11:30 11:30-16:00 16:00-00:00 00:00-02:30 02:30-04:00 04:00-05:00 05:00-06:00 06:00-08:00 08:00-09:00 09:00-10:00 10:00-11:30 11:30-13:00 13:00-14:30 Duration 7-1/2 hr lhr 2hr 1-1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 3hr 2-1/2 hr lhr 2-1/2 hr 1/2 hr lhr 7hr 3hr lhr 7hr lhr 1/4 hr 5-1/4 hr 4hr 8-1/2 hr 6hr 1/4 hr 1-1/4 hr 2hr 6hr 2hr 1-1/2 hr 4-1/2 hr 6-1/2 hr 7hr 2hr 5hr 8hr lhr lhr 1/4 hr 3/4 hr 2hr 2hr 1/2 hr 4-1/2 hr 8hr 2-1/2 hr 1-1/2 hr lhr lhr 2hr lhr lhr 1-1/2 hr 1-1/2 hr 1-1/2 hr Activity Rig moved 100.00 % Rig moved 100.00 % Rigged up Draw works Removed Hanger plug Circulated at 10362.0 ft Installed Hanger plug Removed Xmas tree Rigged up All rams Tested All rams Tested All rams Removed Hanger plug Retrieved Tubing head spool Pulled Tubing in stands to 0.0 ft Pulled Tubing in stands to 8000.0 ft Pulled Tubing in stands to 10457.0 ft Pulled Tubing in stands to 10457.0 ft Ran Tubing in stands to 10698.0 ft Pulled Tubing in stands to 800.0 ft Held safety meeting Pulled Tubing in stands to 0.0 ft Rig waited · Equipment Fished at 10698.0 ft Pulled out of hole to 6000.0 ft Held safety meeting Pulled out of hole to 0.0 ft Laid down fish R.I.H. to 10730.0 ft Washed to 10769.0 ft R.I.H. to 11041.0 ft Circulated at 11041.0 ft Pulled out of hole to 0.0 ft Conducted electric cable operations Conducted electric cable operations Rigged up sub-surface equipment - Other sub-surface equipment Ran Tubing in stands to 10524.0 ft Space out tubulars Functioned Hydraulic packer Held safety meeting Set packer at 10546.0 ft with 1850.0 psi Circulated at 10540.0 ft Pulled Tubing in stands to 7300.0 ft Serviced Drillfloor / Derrick Pulled Tubing in stands to 0.0 ft Installed ESP Installed Electric cable Ran Tubing in stands to 10414.0 ft Installed Tubing hanger Installed Electric cable Installed Electric cable Installed Tubing hanger Removed BOP stack Installed Xmas tree Rig waited · Service personnel Freeze protect well - 2.000 bbl of Diesel State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 12-Jun-98 Transmittal of Final Prints. Please sign and return copy to the following: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 and BP Exploration (Alaska)Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 ~/ell Name Services dfq- ~,~.o /~PG-13 SBT/GR/CCL '~ ~v1PG-13 CCL/GR PERF, PACKER Bluelines R/F Sepia Film 1 1 1 1 ,~"7. /?6, iMPH-13 MPH-13 /'MPH-13 CCL PERF 1 1 CCL PERF 1 1 GR/CCL DEPTH REF 1 1 /fV~PH-13 ~15''-~ !2o /MPI-05 P,/~ INJ PROFILE 1 1 STATIC PRESS SRVY 1 1 ct~. ~'~'5 /MPB-25 ~/¢_... INJ PROFILE ~r,, / q, g ~PK-30 CCL PERF /¢'VIPH-13 1 1 GR/CCL PERF, PACKER 1 1 1 1 GR/CCL PERF 1 1 GR/CCL PERF Received by: ~ Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ;..! ,, ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG .. ., ,*-.~:,r~P ." 1. Status of Well Classifica~fC¥i of ~r~i.Ce..W..ell. [] Oil F-I Gas [--I Suspended i--I Abandoned I--~ Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 96-168 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22711 4. Location of well at surface ~"~,:.&~; ~ ~-~,r:~ ~:~.,~'' ~' ~' ; 9. Unit or Lease Name 3605' NSL, 1965' WEL, SEC. 3, T12N, R11E i.2',-. '.~"" ~-'- !~I' Milne Point Unit At top of productive interval ~/-//,~-'~-~'--~i ' 10. Well Number 443' NSL' 4079' EWL' SEC' 2' T12N' R11E i ~/'~'r-'~:'" -i '~ .~~i MPK-30 At total depth .-~----~.'~'.i ~_. . . . 11. Field and Pool 211' NSL, 4502' EWL, SEC. 2, T12N, R11E ...................... ¢ Milne Point Unit/Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 56.95'I ADL 375132 12. Date Spudded 113. Date T.D. Reached ! 14. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 10/19/96I 10/31/96! 11/26/96I N/A MSLI One 17. Total Depth (MD+TVD) 118. P,ug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost 11145 7306 FTI 11041 7256 FTI [~Yes I~NoI N/AMDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, EMS, GR/CCL, eR/JR 23. CASING, LINER AND CEMENTING RECORD ~ I~ I ~ I I ~i t'~ L CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 47# P110/L-80 31' 6652' 12-1/4" 1500 sx Trinity Lite Wate, 750 sx PF 'E' 7" 26# L-80 28' 11122' 8-1/2" 245sxClass'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 2-7/8", 6.5#, L-80 10489' N/A MD TVD MD TVD 10588'- 10658' 7024'-7063' 10704'-10748' 7087'-7111' 126. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 72 bbls diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) December 1, 1996I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PER~OD I Flow Tubing Casing Pressure CALCULATEB O~L-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers Marker Name Measured Depth True Vertical Depth Top Kuparuk 10354, KC 1 6833' 10585' LCU 6941' 10661, Top Kuparuk B7 7007' 10691' 7023' Formation Tests Include interval tested, pressure data, all fluids and and time of each phase. Summary of Daily Drilling Reports, Surveys Y certify that the foregoing i'"'-'~s Signed MPK-30 ORIGINAL COrrect to~ 96-168 ineer ~,,a~ No. Prepared By Name/Number: Kathy Campoamor, 564-5122 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. I?EM 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. I'rEM 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. h'EM 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 Cementing and the location of the cementing tool. I'rEM 27: Method of Operation: Other-explain. Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, ITEM 28: If no COres taken, indicate, , none . Form 10-407 Rev. 07-01-80 Facility Date/Time 17 Oct 96 18 Oct 96 19 Oct 96 20 Oct 96 21 Oct 96 22 Oct 96 23 Oct 96 M Pt K Pad Progress Report Well MPK-30 Rig Nabors 22E Page Date Duration Activity 19:00-21:00 21:00-21:30 21:30-01:00 01:00-03:00 03:00-06:00 06:00-06:30 06:30-12:00 12:00-18:00 18:00-00:00 00:00-03:00 03:00-03:30 03:30-04:00 04:00-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-13:00 13:00-14:30 14:30-18:00 18:00-18:30 18:30-23:30 23:30-00:30 00:30-03:30 03:30-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-16:30 16:30-18:00 18:00-18:30 18:30-19:15 19:15-20:15 20:15-21:00 21:00-06:00 06:00-06:30 06:30-10:30 10:30-14:30 14:30-18:00 18:00-18:30 18:30-19:00 19:00-20:00 20:00-21:00 21:00-21:30 21:30-22:00 22:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-05:00 05:00-06:00 06:00-06:30 06:30-09:30 09:30-16:30 2hr 1/2 hr 3-1/2 hr 2hr 3hr 1/2 hr 5-1/2 hr 6hr 6hr 3hr 1/2 hr 1/2 hr 2hr 1/2 hr 1/2 hr 1/2 hr 5-1/2 hr 1-1/2 hr 3-1/2 hr 1/2 hr 5hr lhr 3hr lhr 1/2 hr lhr 1/2hr 1/2 hr 9-1/2 hr 1-1/2 hr 1/2 hr 3/4 hr lhr 3/4 hr 9hr 1/2 hr 4hr 4hr 3-1/2 hr 1/2 hr 1/2 hr lhr lhr 1/2 hr 1/2hr 8hr 1/2 hr 11-1/2 hr 1/2 hr 10-1/2 hr lhr 1/2 hr 3hr 7hr Rigged down High pressure lines Held safety meeting Rig moved 20.00 % Rig moved 40.00 % Rig moved 50.00 % Held safety meeting Rig moved 100.00 % Rigged up Fluid system Serviced Divertor Rigged up Divertor Held safety meeting Tested Divertor Made up BHA no. 1 Held safety meeting Made up BHA no. 1 Tested Fluid system Drilled to 630.0 ft Repaired Shaker discharge line Drilled to 950.0 ft Held safety meeting Drilled to 1674.0 ft Repaired Shaker discharge line Drilled to 2056.0 ft Circulated at 2056.0 ft Pulled out of hole to 1000.0 ft Serviced Top drive Held safety meeting R.I.H. to 2056.0 ft Drilled to 3293.0 ft Circulated at 3296.0 ft Held safety meeting Pulled out of hole to 1675.0 ft Serviced Top drive R.I.H. to 3296.0 ft Drilled to 4060.0 ft Held safety meeting Drilled to 4632.0 ft Repaired Top drive motor Drilled to 4853.0 ft Held safety meeting Drilled to 5013.0 ft Circulated at 5013.0 ft Pulled out of hole to 3296.0 ft Serviced Crown block R.I.H. to 5013.0 ft Drilled to 5681.0 ft Held safety meeting Drilled to 6369.0 ft Held safety meeting Drilled to 6675.0 ft Circulated at 6675.0 ft Held safety meeting Circulated at 6675.0 ft Pumped out of hole to 2080.0 ft 1 10 May 97 Facility Date/Time 24 Oct 96 25 Oct 96 26 Oct 96 27 Oct 96 28 Oct 96 M Pt K Pad Progress Report Well MPK-30 Rig Nabors 22E Page Date Duration Activity 16:30-04:00 04:00-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-09:00 09:00-10:00 10:00-11:00 11:00-11:30 11:30-13:00 13:00-13:30 13:30-18:00 18:00-18:30 18:30-05:30 05:30-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-11:30 11:30-14:30 14:30-15:30 15:30-16:30 16:30-19:30 19:30-20:00 20:00-00:00 00:00-00:30 00:30-02:00 02:00-06:00 06:00-06:30 06:30-10:00 10:00-11:30 11:30-12:30 12:30-13:30 13:30-22:00 22:00-01:00 01:00-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-10:00 10:00-10:30 10:30-18:00 18:00-18:30 18:30-19:00 19:00-00:00 00:00-02:00 02:00-04:00 04:00-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-12:30 11-1/2 hr 2hr 1/2 hr 1/2 hr lhr lhr lhr lhr 1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr 1/2hr llhr 1/2 hr 1/2hr 1-1/2 hr lhr 2-1/2 hr 3hr lhr lhr 3hr 1/2 hr 4hr 1/2hr 1-1/2 hr 4hr 1/2 hr 3-1/2 hr 1-1/2 hr lhr lhr 8-1/2 hr 3hr 2-1/2 hr lhr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 7-1/2 hr 1/2 hr 1/2 hr 5hr 2hr 2hr 2hr 1/2 hr 2-1/2 hr 1/2 hr 3hr Backreamed to 565.0 ft Pulled BHA Held safety meeting Pulled BHA Serviced Top drive Made up BHA no. 2 R.I.H. to 400.0 ft Reamed to 495.0 ft R.I.H. to 1800.0 ft Reamed to 2200.0 ft R.I.H. to 2900.0 ft Reamed to 3500.0 ft Held safety meeting Reamed to 6675.0 ft Circulated at 6675.0 ft Held safety meeting Circulated at 6675.0 ft Pulled out of hole to 3800.0 ft Backreamed to 2800.0 ft Pulled out of hole to 0.0 ft Functioned downhole tools at 0.0 ft Serviced Block line R.I.H. to 3420.0 ft Pulled out of hole to 2870.0 ft Reamed to 3800.0 ft Pulled out of hole to 2870.0 ft R.I.H. to 6675.0 ft Circulated at 6675.0 ft Held safety meeting Pulled out of hole to 250.0 ft Pulled BHA Serviced Drillfloor / Derrick Rigged up Casing handling equipment Ran Casing to 6652.0 ft (9-5/8in OD) Circulated at 6652.0 ft Mixed and pumped slurry - 294.000 bbl Circulated at 2481.0 ft Wait on cement Held safety meeting Wait on cement Circulated at 2478.0 ft Wait on cement Circulated at 2478.0 ft Ran Drillpipe to 1250.0 ft (1-1/4in OD) Held safety meeting Circulated at 2478.0 ft Circulated at 2478.0 ft Mixed and pumped slurry - 60.000 bbl Mixed and pumped slurry - 290.000 bbl Laid down 1250.0 ft of Drillpipe Held safety meeting Laid down 1250.0 ft of Drillpipe Laid down 31.0 ft of Casing Rigged down Divertor 2 10 May 97 Facility Date/Time 29 Oct 96 30 Oct 96 31 Oct 96 01 Nov 96 M Pt K Pad Progress Report Well MPK-30 Page 3 Rig Nabors 22E Date 10 May 97 Duration Activity 12:30-15:30 15:30-19:00 19:00-20:00 20:00-21:00 21:00-00:00 00:00-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-08:30 08:30-09:30 09:30-10:30 10:30-12:00 12:00-12:30 12:30-13:00 13:00-18:00 18:00-18:30 18:30-23:30 23:30-00:30 00:30-01:00 01:00-01:30 01:30-06:00 06:00-06:30 06:30-11:15 11:15-11:30 11:30-18:00 18:00-18:30 18:30-19:00 19:00-20:00 20:00-21:30 21:30-22:30 22:30-00:00 00:00-06:00 06:00-06:30 06:30-09:45 09:45-11:15 11:15-13:15 13:15-14:30 14:30-16:30 16:30-16:45 16:45-18:00 18:00-18:30 18:30-19:00 19:00-20:30 20:30-22:00 22:00-23:00 23:00-01:30 01:30-04:00 04:00-06:00 06:00-06:30 06:30-07:00 07:00-07:15 07:15-08:15 08:15-09:00 3hr 3-1/2 hr lhr lhr 3hr 4hr 1/2 hr 1-1/2 hr 1/2 hr 2hr lhr lhr 1-1/2 hr 1/2 hr 1/2hr 5hr 1/2 hr 5hr lhr 1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 4-3/4 hr 1/4 hr 6-1/2 hr 1/2 hr 1/2 hr lhr 1-1/2 hr lhr 1-1/2 hr 6hr 1/2 hr 3-1/4 hr 1-1/2 hr 2hr 1-1/4 hr 2hr 1/4 hr 1-1/4 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr lhr 2-1/2 hr 2-1/2 hr 2hr 1/2 hr 1/2 hr 1/4 hr lhr 3/4 hr Rigged up BOP stack Tested BOP stack Installed Wear bushing Serviced Top drive Made up BHA no. 4 R.I.H. to 2478.0 ft Drilled installed equipment - Cementing packer R.I.H. to 4000.0 ft Held safety meeting R.I.H. to 6564.0 ft Circulated at 6564.0 ft Tested Casing Drilled installed equipment - Float collar Circulated at 6695.0 ft Performed formation integrity test, 13,0 f£o0 ~/~ Drilled to 7386.0 ft Held safety meeting Drilled to 8246.0 ft Circulated at 8246.0 ft Pulled out of hole to 6652.0 ft R.I.H. to 8246.0 ft Drilled to 8818.0 ft Held safety meeting Drilled to 9469.0 ft Held drill (Kick while drilling) Drilled to 10134.0 ft Held safety meeting Drilled to 10226.0 ft Circulated at 10226.0 ft Pulled out of hole to 6600.0 ft Serviced Top drive R.I.H. to 10226.0 ft Drilled to 10588.0 ft Held safety meeting Drilled to 10889.0 ft Circulated at 10889.0 ft Drilled to 11145.0 ft Circulated at 11145.0 ft Pulled out of hole to 6627.0 ft Held drill (Fire) Serviced Block line Held safety meeting Serviced Top drive R.I.H. to 11145.0 ft Circulated at 11145.0 ft Took EMS survey at 11030.0 ft Pulled out of hole to 5140.0 ft Laid down 3950.0 ft of 5in OD drill pipe Pulled BHA Held safety meeting Pulled BHA Held drill (H2S) Worked on BOP - Top ram Rigged up Casing handling equipment Facility M Pt K Pad Progress Report Well MPK-30 Rig Nabors 22E Page Date 4 10 May 97 Date/Time 02 Nov 96 09:00-09:15 09:15-18:00 18:00-18:30 18:30-18:45 18:45-19:15 19:15-20:30 20:30-21:30 21:30-22:00 22:00-02:30 02:30-04:15 04:15-05:15 05:15-06:00 06:00-06:15 06:15-06:30 06:30-06:45 06:45-07:15 07:15-10:00 10:00-11:00 11:00-13:00 13:00-15:00 15:00-15:30 Duration 1/4hr 8-3/4 hr 1/2 hr 1/4 hr 1/2 hr 1-1/4 hr lhr 1/2 hr 4-1/2 hr 1-3/4 hr lhr 3/4 hr 1/4hr 1/4 hr 1/4 hr 1/2hr 2-3/4 hr lhr 2hr 2hr 1/2 hr Activity Held safety meeting Ran Casing to 6200.0 ft (7in OD) Held safety meeting Held drill (Spill) Ran Casing to 6650.0 ft (7in OD) Circulated at 6650.0 ft Repaired Casing handling equipment Held safety meeting Ran Casing to 11122.0 ft (7in OD) Circulated at 11122.0 ft Mixed and pumped slurry - 51.000 bbl Displaced slurry - 422.000 bbl Displaced slurry - 422.000 bbl (cont...) Held safety meeting Held drill (Abandonment) Tested Casing Rigged down Casing handling equipment Worked on BOP - Top ram Rigged down BOP stack Installed Xmas tree integral components Tested All tree valves SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPK-30 Rig Name: N-4ES AFE: 347048 Accept Date: 11/23/96 Spud Date: - Release Date: 11/26/96 Nov 24 1996 MIRU. Move A-Pad to K-Pad. RU, rig accepted 11/23/96 @ 1700 hrs. Take on water in pits. Rig hard line to annulus & tiger tank. Test 7" casing. ND CIW 2-9/16, 5000# tree. Pull tubing hanger. NU BOP stack, change rams to 2-7/8". Test BOP. Test all rams, lines & valves. Test hydril. Test upper & lower kelly valves, TIW & IBOP, ok. Finish loading pipe shed with 2-7/8" tubing - strap & drift. MU 6-1/8" bit, 7" casing scraper & TIH on 2-7/8" tubing. Nov 25 1996 Cont TIH picking up 2-7/8" tubing. Displace out diesel cap to tiger tank. Finish TIH picking up 2-7/8" tubing to PBTD. Reverse CBU - no fill on bottom. Pump casing wash, reciprocating tubing. LD 20 jts of tubing, POOH stand back 110 stands for completion. NU perforation flange. RU Schlumberger, test lubricator. RIH with GR/CCL on 20' of 4-1/2" casing guns w/51 RDX charge, 5 spf, 60 degree phasing. Log with GR/CCL 11040'-10000'. Perforate Kuparuk B sand 10748' to 10728', POOH. No fluid loss. Correlated to GR/CCL Icg dated 11/25/96. Nov 26 1996 Finish perforating Kuparuk B sand 10748'-10704' & Kuparuk C sand 10658'-10588'. Perf with 4-1/2" casing guns, 5 spf. All shots fired. Correlated to GR/CCL Icg. RIH with 5.95" GR/JB set down at 11030' - 19' fill on bottom, POOH. RD SWS. ND perf flange, NU bell nipple. Pull WB. MU & service ESP. RIH with 2-7/8" tubing from derrick- 7000' in hole @ 0600 hrs. Nov 27 1996 Cont RIH with ESP completion on 2-7/8" tubing. MU tubing hanger. Ran total 329 jts tubing - one ESP cable splice. Make ESP cable splice at tubing hanger. Land tubing. Set TWC & test. ND BOP stack, NU tubing adapter spool. NU CIW tree. Test tree & pack off, ok. Install BPV. RU lines & test. Freeze protect annulus with 60 bbls diesel bullheaded. Freeze protect tubing with 12 bbls diesel bullheaded. RD lines. Secure well. Rig released 11/26/96 @ 2000 hrs. Page RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE PT/MPK-30 500292271100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 103196 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60156 KELLY BUSHING ELEV. = 56.95 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -56.95 171.36 171.35 114.40 262.10 262.08 205.13 353.51 353.47 296.52 444.51 444.43 387.48 0 0 0 46 0 50 1 23 2 1 N .00 E .00 .00N .00E N 31.40 W .45 .99N .60W N 25.15 W .12 2.10N 1.20W N 10.00 E .94 3.80N 1.29W N 18.09 E .74 6.43N .60W .00 -1.00 -2.06 -2.96 -3.61 535.37 535.23 478.28 625.30 625.07 568.12 716.40 716.02 659.07 808.16 807.51 750.56 899.29 898.29 841.34 19 42 46 57 6 N 19.74 E .34 9.69N .53E N 24.88 E .49 13.34N 2.04E N 21.04 E 1.19 18.08N 4.01E N 20.08 E 1.30 24.62N 6.46E N 19.45 E .18 32.14N 9.16E -4.19 -4.62 -5.16 -6.15 -7.39 994.09 992.80 935.85 1089.70 1088.22 1031.27 1184.98 1183.34 1126.39 1278.71 1276.95 1220.00 1374.32 1372.48 1315.53 3 45 3 26 3 12 2 37 1 58 N 17.33 E 1.45 39.08N 11.49E N 18.48 E .34 44.79N 13.33E N 22.13 E .33 49.96N 15.24E N 20.64 E .63 54.40N 16.98E N 16.26 E .71 58.02N 18.21E -8.68 -9.81 -10.62 -11.22 -11.88 1469.99 1468.12 1411.17 1565.39 1563.49 1506.54 1660.31 1658.23 1601.28 1756.17 1753.37 1696.42 1851.62 1847.18 1790.23 0 42 1 56 4 46 9 7 12 4 N 24.95 E 1.33 60.14N 18.93E S 64.72 E 2.18 59.98N 20.64E S 52.67 E 3.06 56.89N 25.25E S 48.67 E 4.55 49.45N 34.14E S 48.87 E 3.08 37.89N 47.34E -12.27 -10.69 -5.16 6.21 23 34 1947.16 1940.55 1883.60 2042.55 2033.18 1976.23 2138.21 2124.84 2067.89 2232.41 2213.82 2156.87 2328.19 2303.07 2246.12 12 15 18 20 22 24 11 1 20 10 S 49.16 E .36 24.61N 62.62E S 52.50 E 3.04 10.29N 80.30E S 58.00 E 3.38 5.18S 102.80E S 65.24 E 3.52 19.76S 130.02E S 68.91 E 2.37 33.24S 162.00E 43 12 65.50 92 66 123.55 158 07 2423.14 2390.32 2333.37 2518.95 2476.95 2420.00 2614.28 2561.52 2504.57 2709.66 2644.35 2587.40 2805.54 2726.08 2669.13 24 14 26 17 28 38 30 45 32 16 S 67.65 E 2.24 47.10S 196.75E S 65.44 E 2.36 63.40S 234.25E S 63.75 E 2.59 82.28S 273.95E S 61.69 E 2.46 103.96S 315.92E S 61.10 E 1.63 127.95S 359.92E 195 21 235.93 279 82 327.04 377.16 2899.89 2805.11 2748.16 2995.60 2883.67 2826.72 3091.50 2960.02 2903.07 3187.21 3033.36 2976141 3282.70 3103.24 3046.29 33 55 35 43 38 43 41 11 44 42 S 60.38 E 1.79 153.15S 404.86E S 58.60 E 2.16 180.90S 451.93E S 59.73 E 3.22 210.62S 501.75E S 60.32 E 2.61 241.32S 555.00E S 60.99 E 3.70 273.19S 611.71E 428.68 483.29 541.26 602.71 667.76 St RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE PT/MPK-30 500292271100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 103196 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60156 KELLY BUSHING ELEV. = 56.95 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3377.92 3168.70 3111.75 3472.75 3229.97 3173.02 3568.53 3287.16 3230.21 3664.08 3338.65 3281.70 3759.19 3387.25 3330.30 48 24 S 62.09 E 3.99 306.11S 672.49E 51 5 S 60.80 E 3.00 340.71S 736.05E 55 33 S 60.94 E 4.67 378.10S 803.14E 59 12 S 62.08 E 3.94 416.47S 873.87E 59 20 S 61.93 E .20 454.85S 946.05E 736.88 809.25 886.05 966.52 1048.27 3855.06 3436.14 3379.19 3950.75 3484.86 3427.91 4046.38 3533.42 3476.47 4141.96 3581.63 3524.68 4237.42 3629.03 3572.08 59 20 S 61.83 E .09 493.72S 1018.79E 59 26 S 61.25 E .53 532.97S 1091.19E 59 31 S 61.04 E .21 572.73S 1163.34E 59 53 S 60.25 E .80 613.19S 1235.27E 60 33 S 59.59 E .93 654.72S 1306.97E 1130.73 1213.09 1295.47 1377.99 1460.82 4332.31 3675.83 3618.88 4428.07 3723.00 3666.05 4523.59 3770.63 3713.68 4619.61 3820.62 3763.67 4713.67 3872.07 3815.12 60 20 S 59.31 E .34 696.68S 1378.06E 60 37 S 59.27 E .30 739.24S 1449.71E 59 32 S 61.35 E 2.21 780.24S 1521.62E 57 42 S 62.14 E 2.04 819.05S 1593.82E 55 57 S 62.57 E 1.89 855.58S 1663.56E 1543.33 1626.61 1709.38 1791.34 1870.06 4808.42 3925.48 3868.53 4904.07 3980.29 3923.34 4999.48 4034.47 3977.52 5094.21 4087.22 4030.27 5189.98 4140.60 4083.65 55 24 S 61.95 E .80 892.00S 1732.82E 54 39 S 62.18 E .80 928.72S 1802.07E 56 7 S 61.54 E 1.63 965.76S 1871.31E 56 11 S 61.25 E .26 1003.43S 1940.39E 56 3 S 61.62 E .35 1041.45S 2010.23E 1948.31 2026.68 2105.20 2183.89 2263.40 5285.43 4192.66 4135.71 5381.03 4242.97 4186.02 5476.39 4291.92 4234.97 5571.89 4341.53 4284.58 5667.38 4393.10 4336.15 57 49 S 61.18 E 1.88 1079.75S 2080.45E 58 40 S 60.73 E .98 1119.21S 2151.52E 59 32 S 60.89 E .92 1159.12S 2222.96E 57 51 S 60.23 E 1.87 1199.22S 2294.01E 56 46 S 59.97 E 1.15 1239.27S 2363.69E 2343.39 2424.68 2506.51 2588.09 2668.43 5762.93 4444.26 4387.31 5858.46 4493.59 4436.64 5954.14 4542.79 4485.84 6049.68 4592.50 4535.55 6145.24 4642.50 4585.55 58 28 S 59.53 E 1.81 1279.92S 2433.38E 59 21 S 59.56 E .93 1321.38S 2503.91E 58 45 S 60.63 E 1.14 1362.30S 2575.03E 58 32 S 60.39 E .31 1402.46S 2646.05E 58 22 S 59.84 E .52 1443.03S 2716.66E 2749.09 2830.86 2912.90 2994.47 3075.89 6240.62 4693.36 4636.41 6334.89 4743.67 4686.72 6430.19 4793.53 4736.58 6525.64 4843.02 4786.07 6621.07 4891.70 4834.75 57 9 S 60.00 E 1.28 1483.47S 2786.47E 58 19 S 59.55 E 1.29 1523.60S 2855.35E 58 35 S 59.93 E .45 1564.52S 2925.51E 58 55 S 60.60 E .69 1605.00S 2996.38E 59 43 S 60.72 E .85 1645.21S 3067.93E 3156.55 3236.23 3317.43 3399.02 3481.10 SP .~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 BP EXPLORATION MILNE PT/MPK-30 500292271100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 103196 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60156 KELLY BUSHING ELEV. = 56.95 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATE DEGREES DG/100 NORTH/SOUTH EAST/WEST S VERT. SECT. 6765.66 4965.20 4908.25 6861.11 5014.16 4957.21 6956.84 5063.45 5006.50 7051.49 5112.50 5055.55 7147.12 5162.31 5105.36 59 59 58 58 58 10 5 55 39 33 S 64.19 E 2.10 1702.79S 3178.31E S 64.61 E .39 1738.19S 3252.20E S 64.40 E .27 1773.51S 3326.28E S 64.40 E .27 1808.49S 3399.28E S 65.83 E 1.28 1842.84S 3473.33E 3605.57 3687.38 3769.32 3850.15 3931.60 7242.86 5212.44 5155.49 58 16 7338.33 5262.71 5205.76 58 10 7433.77 5313.71 5256.76 57 13. 7529.31 5365.70 5308.75 56 49 7624.81 5418.18 5361.23 56 30 S 66.20 E .44 1876.00S 3547.85E S 65.67 E .49 1909.09S 3621.96E S 64.82 E 1.25 1942.87S 3695.21E S 64.56 E .47 1977.14S 3767.67E S 65.49 E .88 2010.83S 3839.99E 4012.89 4093.79 4174.27 4254.28 4333.90 7720.05 5470.98 5414.03 56 9 7815.71 5524.18 5467.23 56 16 7911.56 5577.53 5520.58 56 5 8007.01 5630.73 5573.78 56 9 8102.75 5684.05 5627.10 56 9 S 63.49 E 1.78 2044.96S 3911.52E S 64.82 E 1.16 2079.62S 3983.06E S 65.58 E .69 2113.02S 4055.35E S 64.72 E .75 2146.32S 4127.26E S 65.51 E .68 2179.79S 4199.39E 4413.02 4492.42 4571.87 4650.94 4730.28 8197.95 5736.82 5679.87 56 30 8292.16 5788.60 5731.65 56 48 8387.67 5840.89 5783.94 56 47 8483.30 5893.33 5836.38 56 41 8578.68 5945.24 5888.29 57 21 S 63.25 E 2.00 2214.05S 4270.82E S 62.24 E .95 2250.09S 4340.78E S 63.16 E .81 2286.74S 4411.80E S 63.41 E .24 2322.69S 4483.24E S 62.08 E 1.36 2359.33S 4554.36E 4809.39 4888.06 4967.96 5047.88 5127.86 8674.14 5996.75 5939.80 57 8767.53 6047.02 5990.07 57 8859.69 6096.18 6039.23 57 8954.25 6146.06 6089.11 58 9048.83 6195.64 6138.69 58 19 32 58 21 24 S 62.07 E .03 2396.98S 4625.37E S 62.23 E .27 2433.75S 4694.96E S 60.62 E 1.56 2471.03S 4763.41E S 60.57 E .40 2510.47S 4833.40E S 61.26 E .62 2549.62S 4903.78E 5208.23 5286.93 5364.87 5445.20 5525.74 9139.68 6243.16 6186.21 58 30 9232.08 6291.27 6234.32 58 43 9326.76 6340.13 6283.18 59 7 9421.01 6388.38 6331.43 59 16 9516.81 6438.45 6381.50 57 42 S 61.48 E .24 2586.72S 4971.75E S 61.28 E .30 2624.50S 5041.00E S 61.81 E .64 2663.14S 5112.30E S 61.88 E .17 2701.34S 5183.68E S 61.42 E 1.70 2740.12S 5255.55E 5603.17 5682.06 5763.15 5844.11 5925.77 9609.76 6487.86 6430.91 58 4 9702.60 6536.57 6479.62 58 37 9798.21 6585.96 6529.01 59 10 9893.69 6636.05 6579.10 57 31 9988.63 6686.73 6629.78 57 55 S 61.28 E .42 2777.87S 5324.64E S 62.01 E .89 2815.40S 5394.19E S 62.45 E .71 2853.54S 5466.62E S 61.88 E 1.80 2891.49S 5538.50E S 62.01 E .44 2929.25S 5609.34E 6004.50 6083.53 6165.39 6246.65 6326.93 S~ RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE PT/MPK-30 5oo2922711oo NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 103196 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60156 KELLY BUSHING ELEV. = 56.95 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10083.88 6738.72 6681.77 55 53 S 62.34 E 2.16 2966.50S 5679.90E 10178.18 6791.44 6734.49 56 7 S 62.60 E .33 3002.64S 5749.23E 10272.88 6844.73 6787.78 55 22 S 61.20 E 1.45 3039.51S 5818.28E 10368.45 6898.87 6841.92 55 36 S 61.65 E .45 3077.18S 5887.44E 10422.00 6929.26 6872.31 55 15 S 61.74 E .67 3098.08S 5926.27E 6406.71 6484.88 6563.15 6641.90 6686.00 10462.80 6952.55 6895.60 55 7 S 61.78 E .30 3113.93S 5955.78E 10558.64 7007.53 6950.58 54 51 S 61.75 E .29 3151.07S 6024.94E 10654.00 7060.82 7003.87 57 11 S 60.03 E 2.87 3189.55S 6094.01E 10748.29 7111.06 7054.11 58 24 S 60.66 E 1.41 3229.03S 6163.35E 10841.61 7159.14 7102.19 59 33 S 61.19 E 1.32 3267.89S 6233.24E 6719.49 6797.99 6877.06 6956.83 7036.81 10937.26 7206.57 7149.62 60 58 S 61.89 E 1.62 3307.46S 6306.26E 11000.26 7236.91 7179.96 61 26 S 61.76 E .74 3333.53S 6354.93E 11145.00 7306.12 7249.17 61 26 S 61.76 E .00 3393.69S 6466.92E 7119.86 7175.06 7302.18 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7303.30 FEET AT SOUTH 62 DEG. 18 MIN. EAST AT MD = 11145 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 118.69 DEG. TIE-IN SURVEY AT SURFACE 0.0' MD PROJECTED SURVEY AT 11,145.00' MD RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE PT/MPK-30 500292271100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 103196 JOB NUMBER: AK-EI-60156 KELLY BUSHING ELEV. = 56.95 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -56.95 .00 N .00 E 1000.00 998.70 941.75 39.45 N 11.61 E 2000.00 1992.00 1935.05 16.90 N 71.88 E 3000.00 2887.24 2830.29 182.24 S 454.12 E 4000.00 3509.90 3452.95 553.37 S 1128.37 E .00 1.30 1.30 8.00 6.70 112.76 104.76 490.10 377.34 5000.00 4034.76 3977.81 965.96 S 1871.69 E 6000.00 4566.58 4509.63 1381.53 S 2609.20 E 7000.00 5085.74 5028.79 1789.48 S 3359.61 E 8000.00 5626.82 5569.87 2143.84 S 4121.99 E 9000.00 6170.06 6113.11 2529.60 S 4867.32 E 965.24 475.14 1433.42 468.18 1914.26 480.84 2373.18 458.91 2829.94 456.76 10000.00 6692.77 6635.82 2933.77 S 5617.85 E 11000.00 7236.79 7179.84 3333.43 S 6354.73 E 11145.00 7306.12 7249.17 3393.69 S 6466.92 E 3307.23 477.29 3763.21 455.98 3838.88 75.67 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. St RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE PT/MPK-30 500292271100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 103196 JOB NUMBER: AK-EI-60156 KELLY BUSHING ELEV. = 56.95 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -56.95 56.95 56.95 .00 156.96 156.95 100.00 256.97 256.95 200.00 356.99 356.95 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .82 N .50 W .01 .01 2.04 N 1.17 W .02 .01 3.89 N 1.28 W .04 .02 457.04 456.95 400.00 557.11 556.95 500.00 657.22 656.95 600.00 757.42 756.95 700.00 857.79 856.95 800.00 6.85 N .46 W .09 .05 10.52 N .82 E .16 .08 14.70 N 2.67 E .27 .10 20.60 N 4.98 E .47 .20 28.66 N 7.93 E .84 .37 958.16 956.95 900.00 1058.37 1056.95 1000.00 1158.55 1156.95 1100.00 1258.69 1256.95 1200.00 1358.78 1356.95 1300.00 36.83 N 10.78 43.00 N 12.74 48.59 N 14.68 53.54 N 16.66 57.51 N 18.07 E 1.21 .38 E 1.42 .21 E 1.60 .17 E 1.74 .14 E 1.83 .09 1458.82 1456.95 1400.00 1558.85 1556.95 1500.00 1659.02 1656.95 1600.00 1759.80 1756.95 1700.00 1861.61 1856.95 1800.00 60.01 N 18.87 60.08 N 20.44 56.96 N 25.17 49.07 N 34.57 36.51 N 48.91 E 1.87 .04 E 1.90 .03 E 2.07 .17 E 2.85 .78 E 4.66 1.81 1963.97 1956.95 1900.00 2067.23 2056.95 2000.00 2172.06 2156.95 2100.00 2278.41 2256.95 2200.00 2386.54 2356.95 2300.00 22.21 N 65.44 6.34 N 85.63 10.61 S 112.03 26.46 S 144.54 41.38 S 182.85 7.02 2.36 10.28 3.26 15.11 4.82 21.46 6.35 29.59 8.13 2496.64 2456.95 2400.00 2609.08 2556.95 2500.00 2724.32 2656.95 2600.00 2842.06 2756.95 2700.00 2962.69 2856.95 2800.00 59.29 S 225.26 81.18 S 271.71 107.51 S 322.52 137.40 S 377.01 170.89 S 435.52 39 52 67 85 105 .69 10.10 .13 12.44 .37 15.24 .11 17.75 .74 20.62 3087.58 2956.95 2900.00 3218.85 3056.95 3000.00 3360.33 3156.95 3100.00 3516.72 3256.95 3200.00 3699.82 3356.95 3300.00 209.39 S 499.65 251.72 S 573.34 299.97 S 660.94 357.63 S 766.37 430.84 S 901.00 130.63 161.90 203.38 259.77 342.87 24.89 31.27 41.48 56.39 83.10 .RY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE BP EXPLORATION MILNE PT/MPK-30 500292271100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 103196 JOB NUMBER: AK-EI-60156 KELLY BUSHING ELEV. = 56.95 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3895.87 3456.95 3400.00 4092.81 3556.95 3500.00 4294.15 3656.95 3600.00 4496.60 3756.95 3700.00 4686.66 3856.95 3800.00 510.29 S 1049.73 592.15 S 1198.34 679.75 S 1349.53 769.09 S 1501.20 845.27 S 1643.69 E 438.92 96.05 E 535.86 96.95 E 637.20 101.33 E 739.66 102.46 E 829.71 90.06 4863.72 3956.95 3900.00 5039.81 4056.95 4000.00 5219.27 4156.95 4100.00 5407.93 4256.95 4200.00 5600.86 4356.95 4300.00 913.35 S 1772.96 981.72 S 1900.76 1053.01 S 2031.61 1130.44 S 2171.56 1211.40 S 2315.31 E 906.77 77.05 E 982.87 76.10 E 1062.32 79.46 E 1150.98 88.65 E 1243.91 92.94 5787.20 4456.95 4400.00 5981.44 4556.95 4500.00 6172.80 4656.95 4600.00 6360.17 4756.95 4700.00 6552.62 4856.95 4800.00 1290.41 S 2451.21 E 1373.75 S 2595.37 E 1454.82 S 2736.95 E 1534.50 S 2873.90 E 1616.34 S 3016.51 E 1330.25 86.33 1424.49 94.25 1515.85 91.36 1603.22 87.37 1695.67 92.45 6749.54 4956.95 4900.00 6944.24 5056.95 5000.00 7136.85 5156.95 5100.00 7327.41 5256.95 5200.00 7513.32 5356.95 5300.00 1696.71 S 3165.87 E 1768.85 S 3316.54 E 1839.25 S 3465.34 E 1905.27 S 3613.50 E 1971.39 S 3755.58 E 1792.59 96.92 1887.29 94.70 1979.90 92.61 2070.46 90.56 2156.37 85.91 7694.86 5456.95 5400.00 7874.66 5556.95 5500.00 8054.10 5656.95 5600.00 8234.42 5756.95 5700.00 8417.00 5856.95 5800.00 2035.62 S 3892.79 2100.35 S 4027.47 2162.99 S 4162.64 2227.73 S 4297.98 2297.82 S 4433.70 E 2237.91 81.54 E 2317.71 79.81 E 2397.15 79.43 E 2477.47 80.33 E 2560.05 82.58 8600.38 5956.95 5900.00 8786.03 6056.95 6000.00 8975.01 6156.95 6100.00 9166.08 6256.95 6200.00 9359.54 6356.95 6300.00 2367.89 S 4570.50 2441.02 S 4708.78 2519.15 S 4848.79 2597.47 S 4991.53 2676.43 S 5137.10 E 2643.43 83.38 E 2729.08 85.65 E 2818.06 88.97 E 2909.13 91.08 E 3002.59 93.46 9551.43 6456.95 6400.00 9741.74 6556.95 6500.00 9932.63 6656.95 6600.00 10116.39 6756.95 6700.00 10294.39 6856.95 6800.00 2754.12 S 5281.24 2831.08 S 5423.70 2906.97 S 5567.47 2979.00 S 5703.75 3048.04 S 5833.79 E 3094.48 91.89 E 3184.79 90.31 E 3275.68 90.89 E 3359.44 83.76 E 3437.44 77.99 Si .RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE PT/MPK-30 500292271100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 103196 JOB NUMBER: AK-EI-60156 KELLY BUSHING ELEV. = 56.95 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 10470.49 6956.95 6900.00 3116.92 S 5961.34 E 3513.54 76.11 10646.89 7056.95 7000.00 3186.59 S 6088.84 E 3589.94 76.40 10837.29 7156.95 7100.00 3266.09 S 6229.98 E 3680.34 90.39 11042.16 7256.95 7200.00 3350.95 S 6387.35 E 3785.21 104.88 11145.00 7306.12 7249.17 3393.69 S 6466.92 E 3838.88 53.67 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS St RY-SUN DRILLING SERVICES ANCHOR3AGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE POINT/MPK-30 500292271100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 102696 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60152 KELLY BUSHING ELEV. = 57.50 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -57.50 171.36 171.35 113.85 262.10 262.08 204.58 353.51 353.47 295.97 444.51 444.43 386.93 0 0 N .00 E .00 .00N .00E 0 46 N 31.40 W .45 .99N .60W 0 50 N 25.15 W .12 2.10N 1.20W 1 23 N 10.00 E .94 3.80N 1.29W 2 1 N 18.09 E .74 6.43N .60W .00 -1.00 -2.06 -2.96 -3.61 535.37 535.23 477.73 625.30 625.07 567.57 716.40 716.02 658.52 808.16 807.51 750.01 899.29 898.29 840.79 2 19 N 19.74 E .34 9.69N .53E 2 42 N 24.88 E .49 13.34N 2.04E 3 46 N 21.04 E 1.19 18.08N 4.01E 4 57 N 20.08 E 1.30 24.62N 6.46E 5 6 N 19.45 E .18 32.14N 9.16E -4.19 -4.62 -5.16 -6.15 -7.39 994.09 992.80 935.30 1089.70 1088.22 1030.72 1184.98 1183.34 1125.84 1278.71 1276.95 1219.45 1374.32 1372.48 1314.98 3 45 N 17.33 E 1.45 39.08N 11.49E 3 26 N 18.48 E .34 44.79N 13.33E 3 12 N 22.13 E .33 49.96N 15.24E 2 37 N 20.64 E .63 54.40N 16.98E 1 58 N 16.26 E .71 58.02N 18.21E -8.68 -9.81 -10.62 -11.22 -11.88 1469.99 1468.12 1410.62 1565.39 1563.49 1505.99 1660.31 1658.23 1600.73 1756.17 1753.37 1695.87 1851.62 1847.18 1789.68 0 42 N 24.95 E 1.33 60.14N 18.93E 1 56 S 64.72 E 2.18 °59.98N 20.64E 4 46 S 52.67 E 3.06 56.89N 25.25E 9 7 S 48.67 E 4.55 49.45N 34.14E 12 4 S 48.87 E 3.08 37.89N 47.34E -12.27 -10.69 -5.16 6.21 23.34 1947.16 1940.55 1883.05 2042.55 2033.18 1975.68 2138.21 2124.84 2067.34 2232.41 2213.82 2156.32 2328.19 2303.07 2245.57 12 24 S 49.16 E .36 24.61N 62.62E 15 11 S 52.50 E 3.04 10.29N 80.30E 18 1 S 58.00 E 3.38 5.18S 102.80E 20 20 S 65.24 E 3.52 19.76S 130.02E 22 10 S 68.91 E 2.37 33.24S 162.00E 43.12 65.5O 92.66 123.55 158.07 2423.14 2390.32 2332.82 2518.95 2476.95 2419.45 2614.28 2561.52 2504.02 2709.66 2644.35 2586.85 2805.54 2726.08 2668.58 24 14 S 67.65 E 2.24 47.10S 196.75E 26 17 S 65.44 E 2.36 63.40S 234.25E 28 38 S 63.75 E 2.59 82.28S 273.95E 30 45 S 61.69 E 2.46 103.96S 315.92E 32 16 S 61.10 E 1.63 127.95S 359.92E 195.21 235.93 279.82 327.04 377.16 2899.89 2805.11 2747.61 2995.60 2883.67 2826.17 3091.50 2960.02 2902.52 3187.21 3033.36 2975.86 3282.70 3103.24 3045.74 33 55 S 60.38 E 1.79 153.15S 404.86E 35 43 S 58.60 E 2.16 180.90S 451.93E 38 43 S 59.73 E 3.22 210.62S 501.75E 41 11 S 60.32 E 2.61 241.32S 555.00E 44 42 S 60.99 E 3.70 273.19S 611.71E 428.68 483.29 541.26 602.71 667.76 Si .RY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE POINT/MPK-30 500292271100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 102696 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60152 KELLY BUSHING ELEV. = 57.50 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3377.92 3168.70 3111.20 3472.75 3229.97 3172.47 3568.53 3287.16 3229.66 3664.08 3338.65 3281.15 3759.19 3387.25 3329.75 48 51 55 59 59 24 5 33 12 20 S 62.09 E 3.99 306.11S 672.49E S 60.80 E 3.00 340.71S 736.05E S 60.94 E 4.67 378.10S 803.14E S 62.08 E 3.94 416.47S 873.87E S 61.93 E .20 454.85S 946.05E 736.88 809.25 886.05 966.52 1048.27 3855.06 3436.14 3378.64 3950.75 3484.86 3427.36 4046.38 3533.42 3475.92 4141.96 3581.63 3524.13 4237.42 3629.03 3571.53 59 20 59 26 59 31 59 53 60 33 S 61.83 E .09 493.72S 1018.79E S 61.25 E .53 532.97S 1091.19E S 61.04 E .21 572.73S 1163.34E S 60.25 E .80 613.19S 1235.27E S 59.59 E .93 654.72S 1306.97E 1130.73 1213.09 1295.47 1377.99 1460.82 4332.31 3675.83 3618.33 4428.07 3723.00 3665.50 4523.59 3770.63 3713.13 4619.61 3820.62 3763.12 4713.67 3872.07 3814.57 60 20 60 37 59 32 57 42 55 57 S 59.31 E .34 696.68S 1378.06E S 59.27 E .30 739.24S 1449.71E S 61.35 E 2.21 780.24S 1521.62E S 62.14 E 2.04 819.05S 1593.82E S 62.57 E 1.89 855.58S 1663.56E 1543.33 1626.61 1709.38 1791.34 1870.06 4808.42 3925.48 3867.98 4904.07 3980.29 3922.79 4999.48 4034.47 3976.97 5094.21 4087.22 4029.72 5189.98 4140.60 4083.10 55 54 56 56 56 24 39 7 11 3 S 61.95 E .80 892.00S 1732.82E S 62.18 E .80 928.72S 1802.07E S 61.54 E 1~63 965.76S 1871.31E S 61.25 E .26 1003.43S 1940.39E S 61.62 E .35 1041.45S 2010.23E 1948.31 2026.68 2105.20 2183.89 2263.40 5285.43 4192.66 4135.16 5381.03 4242.97 4185.47 5476.39 4291.92 4234.42 5571.89 4341.53 4284.03 5667.38 4393.10 4335.60 57 49 58 40 59 32 57 51 56 46 S 61.18 E 1.88 1079.75S 2080.45E S 60.73 E .98 1119.21S 2151.52E S 60.89 E .92 1159.12S 2222.96E S 60.23 E 1.87 1199.22S 2294.01E S 59.97 E 1.15 1239.27S 2363.69E 2343.39 2424.68 2506.51 2588.09 2668.43 5762.93 4444.26 4386.76 5858.46 4493.59 4436.09 5954.14 4542.79 4485.29 6049.68 4592.50 4535.00 6145.24 4642.50 4585.00 58 28 59 21 58 45 58 32 58 22 S 59.53 E 1.81 1279.92S 2433.38E S 59.56 E .93 1321.38S 2503.91E S 60.63 E 1.14 1362.30S 2575.03E S 60.39 E .31 1402.46S 2646.05E S 59.84 E .52 1443.03S 2716.66E 2749.09 2830.86 2912.90 2994.47 3075.89 6240.62 4693.36 4635.86 6334.89 4743.67 4686.17 6430.19 4793.53 4736.03 6525.64 4843.02 4785.52 6621.07 4891.70 4834.20 57 9 58 19 58 35 58 55 59 43 S 60.00 E 1.28 1483.47S 2786.47E S 59.55 E 1.29 1523.60S 2855.35E S 59.93 E .45 1564.52S 2925.51E S 60.60 E .69 1605.00S 2996.38E S 60.72 E .85 1645.21S 3067.93E 3156.55 3236.23 3317.43 3399.02 3481.10 SI RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 BP EXPLORATION (ALASKA) INC MILNE POINT/MPK-30 500292271100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 102696 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60152 KELLY BUSHING ELEV. = 57.50 FT. OPERATOR: BP EXPLORATION 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. 6675.00 4918.88 4861.38 59 43 S 60.72 E .00 1667.99S 3108.56E 3527.67 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3527.79 FEET AT SOUTH 61 DEG. 46 MIN. EAST AT MD = 6675 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 118.69 DEG. TIE-IN SURVEY AT 0.0' MD PROJETED SURVEY AT 6,675.00' MD .RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE POINT/MPK-30 500292271100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 102696 JOB NUMBER: AK-EI-60152 KELLY BUSHING ELEV. = 57.50 OPERATOR: BP EXPLOP~ATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -57.50 .00 N .00 E 1000.00 998.70 941.20 39.45 N 11.61 E 2000.00 1992.00 1934.50 16.90 N 71.88 E 3000.00 2887.24 2829.74 182.24 S 454.12 E 4000.00 3509.90 3452.40 553.37 S 1128.37 E .0O 1.30 1.30 8.00 6.70 112.76 104.76 490.10 377.34 5000.00 4034.76 3977.26 965.96 S 1871.69 E 6000.00 4566.58 4509.08 1381.53 S 2609.20 E 6675.00 4918.88 4861.38 1667.99 S 3108.56 E 965.24 475.14 1433.42 468.18 1756.12 322.69 THE CALCULATION PROCEDURES A_RE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. Si [RY-SUN DRILLING SERVICES ANCHOP~AGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE POINT/MPK-30 500292271100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 102696 JOB NUMBER: AK-EI-60152 KELLY BUSHING ELEV. = 57.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -57.50 57.50 57.50 .00 157.51 157.50 100.00 257.52 257.50 200.00 357.54 357.50 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .83 N .50 W .01 .01 2.04 N 1.17 W .02 .01 3.90 N 1.27 W .04 .02 457.59 457.50 400.00 557.66 557.50 500.00 657.77 657.50 600.00 757.97 757.50 700.00 858.34 857.50 800.00 6.87 N .45 W .09 .05 10.55 N .83 E .16 .08 14.73 N 2.68 E .27 .10 20.63 N 5.00 E .47 .20 28.70 N 7.94 E .84 .37 958.72 957.50 900.00 1058.93 1057.50 1000.00 1159.10 1157.50 1100.00 1259.24 1257.50 1200.00 1359.33 1357.50 1300.00 36.86 N 10.80 43.04 N 12.75 48.62 N 14.69 53.57 N 16.67 57.53 N 18.07 E 1.22 .38 E 1.43 .21 E 1.60 .17 E 1.74 .14 E 1.83 .09 1459.37 1457.50 1400.00 1559.40 1557.50 1500.00 1659.57 1657.50 1600.00 1760.36 1757.50 1700.00 1862.17 1857.50 1800.00 60.02 N 18.87 60.07 N 20.46 56.93 N 25.20 49.01 N 34.64 36.44 N 49.00 E 1.87 .04 E 1.90 .03 E 2.07 .17 E 2.86 .78 E 4.67 1.82 1964.54 1957.50 1900.00 2067.81 2057.50 2000.00 2172.64 2157.50 2100.00 2278.99 2257.50 2200.00 2387.14 2357.50 2300.00 22.13 N 65.54 6.24 N 85.76 10.70 S 112.19 26.54 S 144.72 41.48 S 183.08 E 7.04 2.36 E 10.31 3.27 E 15.14 4.83 E 21.49 6.35 E 29.64 8.15 2497.25 2457.50 2400.00 2609.71 2557.50 2500.00 2724.96 2657.50 2600.00 2842.72 2757.50 2700.00 2963.36 2857.50 2800.00 59.41 S 225.51 81.31 S 271.98 107.67 S 322.81 137.57 S 377.32 171.10 S 435.86 E 39.75 10.11 E 52.21 12.45 E 67.46 15.25 E 85.22 17.76 E 105.86 20.65 3088.28 2957.50 2900.00 3219.59 3057.50 3000.00 3361.15 3157.50 3100.00 3517.63 3257.50 3200.00 3700.90 3357.50 3300.00 209.61 S 500.03 251.96 S 573.77 300.25 S 661.48 357.99 S 767.00 431.28 S 901.81 E 130.78 24.92 E 162.09 31.31 E 203.65 41.56 E 260.13 56.48 E 343.40 83.26 St RY-SUN DRILLING SERVICES ANCHOP~AGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE POINT/MPK-30 500292271100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 102696 JOB AKIMBER: AK-EI-60152 KELLY BUSHING ELEV. = 57.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTA/qGUL~ COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3896.94 3457.50 3400.00 510.73 S 1050.55 E 439.44 96.05 4093.90 3557.50 3500.00 592.61 S 1199.16 E 536.40 96.96 4295.26 3657.50 3600.00 680.25 S 1350.37 E 637.76 101.36 4497.69 3757.50 3700.00 769.54 S 1502.02 E 740.19 102.43 4687.65 3857.50 3800.00 845.64 S 1644.41 E 830.15 89.96 4864.67 3957.50 3900.00 913.71 S 1773.65 E 907.17 77.02 5040.80 4057.50 4000.00 982.11 S 1901.48 E 983.30 76.14 5220.26 4157.50 4100.00 1053.40 S 2032.33 E 1062.76 79.46 5408.99 4257.50 4200.00 1130.89 S 2172.35 E 1151.49 88.72 5601.90 4357.50 4300.00 1211.83 S 2316.07 E 1244.40 92.91 5788.25 4457.50 4400.00 1290.86 S 2451.98 E 1330.75 86.35 5982.50 4557.50 4500.00 1374.19 S 2596.16 E 1425.00 94.25 6173.85 4657.50 4600.00 1455.27 S 2737.72 E 1516.35 91.35 6361.22 4757.50 4700.00 1534.95 S 2874.67 E 1603.72 87.37 6553.69 4857.50 4800.00 1616.79 S 3017.30 E 1696.19 92.47 6675.00 4918.88 4861.38 1667.99 S 3108.56 E 1756.12 59.93 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS Schlumberger ANADRILL Survey Report Client: BP Field: MILNE PT. Well Name: MPK-30 Permanent datum MSL Depth measured from Elevation of kelly bushing Elevation of drill floor Elevation of ground level Magnetic Declination Grid Convergence Total Correction AFE 337048 TIE IN POINT Measured depth True vertical depth N/S disp (-ye for S) E/W disp (-ye for W) 28.05 DEG 0.00 DEG 28.05 DEG Final SVY.ASCII FILE 31-OCT-96 13:52:30 56.95 FT 56.95 FT 27.50 FT Job No. 39014 112.00 FT Inclination 0.00 DEG 112.00 FT Azimuth 0.00 DEG 0.00 FT Azimuth from rotary table 0.00 FT to the target 118.69 DEG Page 001 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET DEPTH DEPTH SECTION FT FT FT FT 112.0 0.00 112.00 0.00 224.3 112.30 224.30 -0.53 314.6 90.30 314.59 -1.25 407.5 92.90 407.46 -1.80 436.2 28.70 436.14 -1.95 527.1 90.90 526.97 -2.35 617.6 90.50 617.39 -2.62 709.3 91.70 708.94 -3.07 741.4 32.10 740.96 -3.33 830.2 88.80 829.46 -4.34 922.1 91.90 921.04 -5.55 1013.1 91.00 1011.79 -6.72 1108.1 95.00 1106.58 -7.78 1203.7 95.60 1202.01 -8.55 1296.9 93.20 1295.09 -9.15 1392.5 95.60 1390.62 -9.84 1488.5 96.00 1486.60 -9.78 1583.4 94.90 1581.45 -7.10 1679.3 95.90 1677.07 0.01 1773.7 94.40 1770.50 13.10 1870.0 96.30 1864.94 31.52 1967.8 97.80 1960.28 52.92 2061.2 93.40 2050.55 76.60 2155.7 94.50 2140.66 104.98 2250.6 94.90 2229.79 137.50 2346.7 96.10 2318.68 173.74 2442.2 95.50 2405.77 212.71 2537.7 95.50 2491.45 254.75 2632.6 94.90 2574.90 299.90 2728.8 96.20 2657.89 348.55 2823.8 95.00 2738.33 399.08 STATION INCLN. DEG 0.00 0.61 1.15 1.82 2.06 2.41 2.55 3.83 4.37 5.05 4.53 3.86 3.75 3.25 2.53 1.61 0.91 2.72 5.88 10.38 12.14 13.62 16.10 18.96 21.25 23.39 25.07 27.32 29.55 31.22 33.05 AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH N/-S E/-W CEMENT DEG FT FT FT DEG 0.0 0.00 0.00 0.00 0.00 326.9 0.50 -0.33 0.60 326.90 9.3 1.80 -0.44 1.85 346.17 19.4 4.11 0.20 4.11 2.76 20.6 5.02 0.53 5.05 6.04 23.5 8.30 1.87 8.51 12.68 25.8 11.86 3.50 12.37 16.45 22.3 16.53 5.55 17.44 18.57 21.7 18.66 6.41 19.73 18.96 20.0 25.48 9.00 27.02 19.46 19.1 32.71 11.57 34.69 19.48 18.0 39.02 13.69 41.35 19.34 20.0 44.98 15.74 47.65 19.29 22.4 50.42 17.85 53.48 19.49 20.1 54.79 19.56 58.18 19.64 12.2 58.09 20.57 61.62 19.50 64.1 59.74 21.54 63.50 19.83 116.4 59.07 24.23 63.84 22.31 128.9 54.97 30.10 62.67 28.70 130.6 46.39 40.32 61.47 40.99 130.1 34.22 54.66 64.4 9 57.95 129.3 20.31 71.43 74.26 74.13 125.1 5.89 90.54 90.73 86.28 119.0 -9.09 114.70 115.06 94.53 112.3 -23.09 144.10 145.94 99.10 111.6 -36.73 177.95 181.70 101.66 113.7 -51.84 214.11 220.29 103.61 115.6 -69.44 252.40 261.78 105.38 117.4 -89.62 292.83 306.23 107.02 118.6 -112.48 335.78 354.12 108.52 119.8 -137.14 379.88 403.88 109.85 Page 1 DLS D/HF 0.00 0.54 0.90 0.77 0.85 0.40 0.19 1.41 1.69 0.78 0.57 0.74 0.18 0.54 0.78 1.01 1.32 2.40 3.42 4.77 1.83 1.52 2.89 3.59 3.42 2.24 1.98 2.51 2.52 1.85 2.04 Final SVY.ASCII FILE Schlumberger ANADRILL Survey Report 31-OCT-96 13:52:30 Page 002 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 2917.0 93.20 2815.75 450.94 34.61 121.0 -163.40 424.62 454.98 111.05 1.82 3012.9 95.90 2893.51 507.01 37.02 120.6 -192.13 472.83 510.37 112.11 2.52 3109.1 96.20 2969.02 566.58 39.54 120.0 -222.19 524.28 569.42 112.97 2.65 3205.2 96.10 3041.35 629.83 42.80 119.4 -253.52 579.23 632.28 113.64 3.42 3301.4 96.20 3110.03 697.17 46.08 118.9 -286.32 638.05 699.35 114.17 3.43 3396.7 95.30 3174.30 767.52 49.09 118.6 -320.15 699.73 769.49 114.59 3.17 3491.3 94.60 3233.87 840.98 52.83 119.2 -355.66 764.04 842.76 114.96 3.98 3588.2 96.90 3289.69 920.16 56.81 118.3 -393.73 833.47 921.79 115.29 4.18 3682.0 93.80 3339.37 999.71 59.22 117.5 -430.95 903.78 1001.27 115.49 2.67 3776.7 94.70 3387.96 1080.96 59.04 116.8 -468.04 976.11 1082.52 115.62 0.66 3873.0 96.30 3437.46 1163.53 59.10 117.2 -505.55 1049.71 1165.10 115.72 0.36 3969.7 96.70 3487.05 1246.54 59.20 118.3 -544.20 1123.18 1248.07 115.85 0.98 4065.2 95.50 3535.99 1328.55 59.15 118.4 -583.14 1195.35 1330.01 116.01 0.10 4160.9 95.70 3584.57 1410.99 59.83 118.7 -622.55 1267.77 1412.38 116.15 0.76 4255.8 94.90 3632.17 1493.09 59.96 119.0 -662.16 1339.68 1494.39 116.30 0.31 4351.2 95.40 3679.66 1575.83 60.33 118.7 -702.09 1412.15 1577.05 116.44 0.47 4447.3 96.10 3727.55 1659.15 59.89 118.1 -741.71 1485.44 1660.32 116.53 0.71 4541.1 93.80 3775.48 1739.77 58.65 117.6 -779.38 1556.73 1740.93 116.60 1.40 4637.7 96.60 3827.18 1821.34 56.64 116.8 -816.68 1629.30 1822.52 116.62 2.20 4732.1 94.40 3879.67 1899.77 55.80 117.4 -852.43 1699.15 1900.98 116.64 1.03 4826.1 94.00 3933.04 1977.13 55.01 117.7 -888.21 1767.75 1978.35 116.68 0.88 4922.9 96.80 3988.39 2056.53 55.23 118.1 -925.37 1837.93 2057.74 116.72 0.41 5017.9 95.00 4042.04 2134.93 56.01 118.2 -962.36 1907.06 2136.12 116.78 0.83 5113.3 95.40 4095.38 2214.02 55.99 118.2 -999.74 1976.76 2215.19 116.83 0.02 5209.3 96.00 4148.69 2293.86 56.55 118.3 -1037.53 2047.09 2295.01 116.88 0.59 5303.8 94.50 4199.96 2373.23 57.73 118.6 -1075.34 2116.88 2374.36 116.93 1.28 5399.4 95.60 4250.21 2454.57 58.86 118.8 -1114.40 2188.22 2455.65 116.99 1.20 5494.5 95.10 4299.74 2535.75 58.36 118.4 -1153.26 2259.50 2536.80 117.04 0.64 5590.4 95.90 4351.21 2616.66 56.71 118.8 -1191.99 2330.54 2617.68 117.09 1.76 5686.8 96.40 4404.00 2697.31 56.89 119.9 -1231.53 2400.85 2698.28 117.16 0.97 5781.7 94.90 4454.71 2777.50 58.51 120.3 -1271.76 2470.24 2778.39 117.24 1.74 5877.4 95.70 4504.68 2859.11 58.54 119.2 -1312.26 2541.10 2859.93 117.31 0.98 5972.9 95.50 4554.78 2940.41 58.18 117.9 -1351.12 2612.52 2941.22 117.35 1.22 6069.1 96.20 4605.63 3022.07 58.00 118.8 -1389.89 2684.38 3022.86 117.37 0.82 6164.8 95.70 4656.72 3102.99 57.47 118.7 -1428.81 2755.33 3103.76 117.41 0.56 6260.4 95.60 4708.24 3183.51 57.30 119.7 -1468.10 2825.62 3184.25 117.45 0.90 6353.7 93.30 4757.94 3262.46 58.33 119.8 -1507.28 2894.18 3263.15 117.51 1.11 6449.3 95.60 4808.02 3343.88 58.49 119.1 -1547.32 2965.09 3344.54 117.56 0.65 6544.8 95.50 4857.70 3425.44 58.82 119.5 -1587.23 3036.21 3426.06 117.60 0.50 6587.1 42.30 4879.45 3461.71 59.28 119.9 -1605.21 3067.72 3462.31 117.62 1.36 6726.4 139.30 4950.57 3581.48 59.32 118.4 -1663.55 3172.33 3582.05 117.67 0.93 6821.9 95.50 4999.48 3663.50 59.07 118.1 -1702.37 3244.58 3664.07 117.69 0.38 6917.5 95.60 5048.62 3745.50 59.07 117.5 -1740.62 3317.12 3746.07 117.69 0.54 7012.6 95.10 5097.73 3826.91 58.75 117.1 -1777.97 3389.49 3827.51 117.68 0.49 7108.2 95.60 5147.44 3908.52 58.58 116.3 -1814.66 3462.44 3909.15 117.66 0.74 Page 2 Final SVY.ASCII FILE Schlumberger A_NADRILL Survey Report 31-OCT-96 13:52:30 Page 003 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 7204.0 95.80 5197.58 3990.10 58.30 117.1 -1851.34 3535.36 3990.77 117.64 0.77 7299.5 95.50 5247.79 4071.31 58.27 117.2 -1888.41 3607.65 4072.01 117.63 0.09 7394.3 94.80 5298.04 4151.66 57.71 117.0 -1925.03 3679.21 4152.39 117.62 0.62 7490.2 95.90 5349.74 4232.42 57.04 118.9 -1962.88 3750.56 4233.15 117.63 1.81 7585.2 95.00 5401.65 4311.98 56.72 117.8 -2000.66 3820.58 4312.71 117.64 1.03 7680.8 95.60 5454.37 4391.73 56.35 118.4 -2038.22 3890.93 4392.46 117.65 0.65 7776.1 95.30 5507.23 4471.02 56.27 119.1 -2076.36 3960.45 4471.74 117.67 0.62 7872.0 95.90 5560.54 4550.74 56.20 117.6 -2114.22 4030.61 4551.45 117.68 1.30 7967.8 95.80 5613.77 4630.38 56.28 117.9 -2151.30 4101.09 4631.10 117.68 0.27 8063.6 95.80 5666.99 4710.01 56.23 116.5 -2187.71 4171.94 4710.75 117.67 1.22 8159.1 95.50 5719.88 4789.50 56.52 118.0 -2224.12 4242.63 4790.26 117.66 1.34 8252.3 93.20 5771.01 4867.42 56.94 119.3 -2261.48 4311.01 4868.17 117.68 1.25 8349.2 96.90 5823.86 4948.63 56.95 118.9 -2300.98 4381.97 4949.37 117.70 0.35 8444.4 95.20 5875.91 5028.34 56.76 117.9 -2338.90 4452.09 5029.07 117.72 0.90 8539.4 95.00 5927.63 5108.02 57.27 118.6 -2376.61 4522.28 5108.75 117.72 0.82 8635.2 95.80 5979.42 5188.62 57.29 120.0 -2416.06 4592.57 5189.32 117.75 1.23 8728.3 93.10 6029.54 5267.06 57.57 119.0 -2454.69 4660.85 5267.74 117.77 0.95 8821.8 93.50 6079.58 5346.04 57.72 119.7 -2493.40 4729.70 5346.69 117.80 0.65 8915.4 93.60 6129.04 5425.49 58.48 119.7 -2532.77 4798.72 5426.11 117.83 0.81 9010.3 94.90 6178.64 5506.38 58.49 120.1 -2573.10 4868.86 5506.96 117.86 0.36 9101.3 91.00 6226.12 5584.00 58.62 119.2 -2611.51 4936.33 5584.56 117.88 0.86 9194.3 93.00 6274.42 5663.47 58.79 119.2 -2650.28 5005.70 5664.01 117.90 0.18 9286.9 92.60 6322.18 5742.80 59.12 119.0 -2688.86 5075.02 5743.33 117.92 0.40 9381.1 94.20 6370.27 5823.79 59.48 120.1 -2728.81 5145.48 5824.29 117.94 1.07 9477.7 96.60 6420.06 5906.56 58.48 119.2 -2769.76 5217.42 5907.03 117.96 1.31 9570.9 93.20 6469.18 5985.75 57.91 120.4 -2809.12 5286.15 5986.20 117.99 1.25 9664.0 93.10 6518.15 6064.90 58.61 119.4 -2848.59 5354.79 6065.33 118.01 1.18 9759.7 95.70 6567.61 6146.83 59.16 118.6 -2888.31 5426.45 6147.25 118.02 0.92 9855.4 95.70 6617.25 6228.65 58.35 118.3 -2927.29 5498.38 6229.06 118.03 0.89 9950.3 94.90 6667.35 6309.24 57.91 119.3 -2966.11 5569.01 6309.65 118.04 1.01 10045.7 95.40 6718.68 6389.66 57.00 117.7 -3004.49 5639.67 6390.06 118.05 1.71 10140.0 94.30 6770.57 6468.38 56.22 118.0 -3041.27 5709.29 6468.79 118.04 0.87 10233.4 93.40 6822.92 6545.73 55.61 118.6 -3077.94 5777.40 6546.15 118.05 0.84 10328.9 95.50 6876.89 6624.52 55.57 119.0 -3115.89 5846.44 6624.93 118.06 0.35 10422.5 93.60 6929.91 6701..65 55.41 118.8 -3153.17 5913.96 6702.05 118.07 0.25 10519.7 97.20 6985.34 6781.50 55.06 119.0 -3191.76 5983.87 6781.89 118.08 0.40 10614.9 95.20 7039.16 6860.02 56.09 119.7 -3230.25 6052.32 6860.40 118.09 1.24 10709.2 94.30 7090.35 6939.19 58.15 119.9 -3269.61 6121.03 6939.55 118.11 2.19 10803.6 94.40 7139.33 7019.87 59.34 120.3 -3310.08 6190.85 7020.20 118.13 1.31 10899.8 96.20 7187.35 7103.20 60.77 119.8 -3351.82 6263.00 7103.51 118.15 1.55 10994.3 94.50 7232.80 7186.04 61.73 119.6 -3392.86 6334.97 7186.33 118.17 1.03 11056.4 62.10 7261.90 7240.89 62.39 119.5 -3419.92 6382.69 7241.18 118.18 1.07 Survey projected to TD 11145.0 88.60 7302.96 7319.39 62.39 119.5 -3458.58 6451.02 7319.66 118.20 0.00 Page 3 Schlumberger- GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) December 12, 1996 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the LWD Depth Corrected CDR/ADN, CDR/ADN-TVD for well MPK-30, Job Cf 96370 was sent to: BP Exploration (Alaska)Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 1 OH LIS Tape 3 Bluelines 1 Film I Depth Shift Disp lay State of Alaska Alaska Oil & Gas Conservation Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 I OH LIS Tape 1 Bluelines 1 RFolded Sepia OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 1 OH LIS Tape 1 Bluelines I RFolded Sepia Sent Certified Mail Z 777 937 511 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 CEtVED Date Delivered: DEC t $ t996 AJsCa 041 & Gas C~ns. Comm~ssmn Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by: GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO, 10642 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 12/13/96 Well Job # Log Description Date BL RF Sepia LIS Tape MPK-30 GAMMA RAY/COLLAR LOG 961 1 25 I ' 1 MPK-30 PERFORATION RECORD 9 61 1 2 5 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by: ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: David Johnstoz// Chairman ~ Blair Wondzell, ~1~~ P. !. Supervisor FROM: Chuck Scheve, ~ -~ SUBJECT: Petroleum Inspector DATE: FILE NO: October 28, 1996 awokj2dd.doc BOPE Test Nabors 22E PTD # 96-168 Monday October 28, 1996: ! traveled to BPX's MPU K-30 Well being drilled by Nabors Rig 22E and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE test report show~ the test lasted 2.5 hours with 1 failure. The control for the hydraulic choke wouldn't function. This was repaired before drilling out. The rig was clean and all related equipment appeared to be in good working order. The location though very crowded was well organized. Summary: I witnessed the initial BOPE on Nabors rig 22E test time 2.5 hours 1 failure. Attachment: awokj2dd X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: X Drlg Contractor: Operator: Well Name: Casing Size: g 5/8 Test: Initial X 10/28/96 Workover: DATE: Nabors Rig No. 22E PTD # g6-168 Rig Ph.# BPX Rep.: Jimmy Pyron MPU-K-30 Rig Rep.: Leonard Schiller Set @ 6,652 Location: Sec. 3 T. 12N R. 11E Meddian Umiat Weekly Other 659-4446 Test MISC. INSPECTIONS: Location Gen.: OK Well Sign YES Housekeeping: OK (Gen) Drl. Rig OK ~ PTD On Location YES ~ Hazard Sec. TES Standing Order Posted YES ~' -- FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. P/F I P P Pressure 250/5,000 250/5,000 250/5,000 250/5,000 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 1 250/3000 P 1 250/5,000 P I 250/5,000 P f 250/5,000 P I 250/5,000 P 2 250/5,000 P I 250/5,000 P N/A 250/5,000 N/A CHOKE MANIFOLD: No. Valves 18 No. Flanges Manual Chokes 1 Hydraulic Chokes I Test Pressure P/F 250/5,000 P 36 250/5,000 P Functioned Func§oned P F/P ACCUMULATOR SYSTEM: System Pressure 3,000 ] P Pressure After Closure 1,500 I P MUD SYSTEM: VLsual Alarm 200 psi Attained After Closure minutes 25 Trip Tank OK OK System Pressure Attained 3 minutes 15 Pit Level Indicators OK OK Blind Switch Covers: Master: OK Remote: Flow Indicator OK OK Nitgn. Btl's: 8 Bottles~ Meth Gas Detector OK OK 2000 PSI Average Psig. H2S Gas Detector OK OK sec. sec. OK Number of Failures: '/ ~' ,Test Time: 2.5 Hours. Number of valves tested 26 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. 276-7S42 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 REMARKS: GOOD TEST Distribution: odg-Weli File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: W~tnessed By: Chuck Scheve F1.021L (Rev. 12/94) AWOKJ2DD.XLS MEMORANDUM TO: THRU: Blair Wondzeii, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 27, 1996 FILE NO: gwokjldd. DOC FROM: Chuck Scheve, c' -~ SUBJECT: Petroleum Inspector Surface cement Job MPU K-30 PTD#96-168 Sunday October 27,1996: I received a call from Jimmy Pyron,Shared Services Drilling Foreman, informing me that they were unable to get cement to surface on the Milne Point K-30 Well. This 12.25' surface hole had been drilled to a depth of 6675' MD 4924' TVD. A good deal of hole problems were encountered throughout this hole section. The 9.625" casing was run to 6652' with a stage collar at 2800'. The first stage cement job consisting of 294bbls of 13.2 ppg. Trinity Lite Wate cement was pumped. This is the calculated volume from TD to the stage collar plus 30%. After 380 bbis of displacement was pumped/returns were lost. Calculated displacement is 480 bbls. The plug was b~umped _ and the stage collar openec~ but they were ~1 unable to circulate. -/-/z~ '/--h~ $-~'¢ c-~l(°'~ At this point I was notified of the situation and informed of BPXs intention to attempt to run 1.25" pipe into the annulus and reestablish circulation through the stage collar. When ! arrived on location the crew had just started picking up the 1.25"pipe. The annulus was circulated at 400' intervals with 10 ppg mud displacing the 10.7 ppg mud that was in the hole. At a depth of 1250' the 1.25" pipe tagged up and could be run no deeper. An attempt was made at this point to establish circulation through the stage collar but was unsuccessful. After discussing the situation with Blair Wondzeil/approval was given to cement the well. The cement job was performed in two stages. The top job was pumped from a depth of 1250' and required 290 bbis of permafrost cement. Calculated volume at this depth is 98 bbls. Then 60bbls of 13.2 ppg Trinity Lite Wate was squeezed through the stage collar at 2800'. 1U/Z~/9~ B'NI U~:U4 ~'A~ 915 §~5 5931 gc~wa~d J. Beh~, Jr. ;~ss~t T~amLeader Heavy Otl Tea~a Western P~glon RECEIVED OCT 2. 199t A]flskg. Oil & G~s COilS. COffiff~JSSJO~ Anchorage OXY USA INC. Box .50250, Midland, TX 79710 Phone 915 685-5673 FA3( 915 685-5931 October 24, 1996 Alaska Oil and Gas Conservation Commission FAX No. 907 276-7542 Attention: Mr- Bob Crandall Reference: Application for Spacing Exception For the Miine Foint K-30 Well Dear Mr. Crandall: OXY USA Inc., as affected party, has no objection to the drilling of the Milne Point K-30 Well as proposed in Lance Spenc~r's request to you. Should you have any questions, please give me a call at 915 685-5673. Thank you. EJB/esm Respectfully, ~-.~-~' /.2~..~':~--- Ed Behm, Jr. Asset Team Leader Heavy Oil Team An Occidental Oil and Gas company N~~arGd rJl~.ing BP Exploration/Arco To: Am: From', SubJec~ October 21, 1996 Alaska Oil & Gas Conservation Commission Blair Wondzell Kathy Campoamcr Technical Assistant MPK-30 Proposed change to casing setting depths and cement Permit #96-168, APl #50-029-22711 i am submitting the attached Form 10-403 requesting a change in the casing setting depths and cement volumes, as follows; Original Approved: 9-5/8", 40# surface casing set at 3796' MD / 8559' TVD Cement.Volumes: 915 sx PF 'E', 840 sx 'G', 150 sx PF 'E' 7", 26# production casing set at 11248' MD / 7358' TVD Cement Volumes: 576 sx'G' RECEIVED Proposed Change: OCT 2_1 1996 9-5/8", 47# surface casing set, a! 6468' MD / 484,.3. ~ TVD Alaska 011 & Gas Cons. commissi0~ Cement Volumes: 914 sx PF E, 1460 sx ..Trinity L~te Wats, 150 sx I:~e~rage 7' , 26# production casing set at 11133' MD / 7298' TVD Cement Volumes: 576 sx 'G' Thank you for your assistance, Kathy Campoamor STATE OF ALASKA ' ALASKA. .AND GAS CONSERVATION COMM,. ~ION APPLICATION FOR SUNDRY APPROVAL [_; Abandon [] Suspend L.I Plugging ~ T~rne Extension ~ Perforate 1. Type of Request:/-1A/t~r Casing [] Repair Well ~ Pull Tubing ~ Variance [] Other [] Change A~proved Prc~Iranl [] Operalioll Shutdown [] Re-Enmr Suspended Well ,'-_18tlrnulate 2. Name of Operator -- -15. Type of well; 6. Datum Elevation (DF or'KB) BP Exploration (Alaska) Inc. I ~ Development Plan RTE -- 57.5' ~] Exploratory 7. Unit or Property Name 3, Address [] Stratlgraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 []Service 4. Location of well Et surface 3605' NSL, 1965' WEL, SEC. ,3, T12N, R11E At top of productive Interval 339' NSL, 1160' WEL, SEC, 2, T12N, RllE At effective depth N/A At total depth 123' NSL, 757' WEL, SEC. 2, TI2N, P, I1E Present well condition summary Total depth: measured feet true vertical feet Effective depth: measured feet true vertical feet Pluge (measured) Junk (measured) 8. Well Number MPK-30 -G.- P-~-r~h-it Number 96-168 10. APl Number 50.029.22711 11, Field and Pool Milne Point Unit / Kuparuk River Sands 30! i GIi",IAL Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) RECEIVED OCT ?-1 199 Alaska Oil & (}as Cons. Commission Anchorage Packers and $SSV (type and measured depth) 13. Attachmente 4. Estimated date for commencing operation 10/21 [] Description summary of proposal [] Detailed operations program [] BOP sketch 1,~. Statue of well classifications as: [] Oil [] Gas [] Suspended Service ' Prepared By Name/Numl~ec Kathy Campoarnor, 564-5122 16. If proposal was verbally approved Name of ~prover Date approved Contact Engineer Name/Number: James Robertaon, 5~4-5159 17, I hereby certify that the foregoing is We and ccirfpct to the best of my knowledge Signed . ,., ' ' LS/2- ~~ '~"/'~ %,~~ Title Senior Drilling Engineer Date Conditions of Approval: Notify CommissiOn so representative may witness Plug integrity ~ BOP Test //' , Location c~earance .... Me~hanica~ Integrity Teat __ Subsequent form required 10-..~0"7' I Original Signed ,,..,.'; . order of the Commission David W, ,lflhnstn~, Commissioner Brute Approved by Form 10-403 Rev, 08/1~/88 Submit In Triplicate Approved Copy Returned .. OCT 21 Shared Services Drilling Contact: Lance Spenc,,er 564-5042 I Well Name: IMP K-30 I Well Plan Summery - Proposed casing depth/cement change l.Type of Well (producer or [Kuparuk Producer .~_nJ?ctor): ! Surface Location; lYe,-get Loa~tion: Bottom Hole Location: 3605 N@L 1965 WEL Sec 0~3 T12N R11E UM.~ AK 339 NSL 1160 WEL Sec 02 T12N R11E,,UM,~ _AK 123 NSL ~,~/WEL Sec 02 T12N R11E UM., AK Number:. J337048 Rig: I Nab0~s ~--E "I Estimated Start Date: 19 Oct 96I ~ompiete:lOperating days to i 1 3 , I etc.)' _ ............. Formation Markers: .... F-o-r~-ati0n Tops .. M D _TVD '(~'~b) ,. .Base Permafrost 1,81o 1,809 8.3 ppg, 78.1 p.s.!__,. NA 5.-§0'~ ' 452.0 .... 8.3 Pp¢I~ 1951 CA ., 6~14_4 4647 8,3 PPi;Ir 2006 psi CB 6,253 4705 8.3 PPgt 203! psi.. Base OB 6131 3 4,737 8.3 pp~, 204§_ps! TopHRZ- 10~012 6~703 8.6 ppg~ 2998 psi _ B~e HRZ i 0,1 8.2. 6,793 6,0 p_p_~_3~0_3.8 .psi _.T_.KLB 10,295 6~853 ,10 ppg~ 3065 psi TKUP/UD 10,511 .... 6,968 10 pp~ .3_6.24 psi 'I-KUC 10,61 4 71023 i0.0 ppg, 3652 psi TKC1/'I'ARGET 1(~',718 7~078 10.0 ppg, 3681 psi TKUB/B8 ; 1~0L7.9__8__' 7,121 10.0 pp~, 3703 psi TKB7 10,826 7~136 10.0 PPIg~ 37_11 psi -~ot~i-~epth ......... ±11~133 ±7;358 10.0 ppg, 382.6 p. si .... Casing/Tubing Program; Hole Csg/ WtiFt Grade c°n~i size Tbg O.D. MD/TVD MDITVD . 2__4_"_ 20" 91.1# 1~'~'~3 ' w-el-~- 80 32/32 112/112 12 1/4, 9-5/8, 47# L.'~" - btr~-'-6432 31/3~ L..8.1/2. 7, 26# L-80 btrc 11103 30/30 11133/7298 FIRST ATT~EMPT T~_T_.Q_DJE._EP SET_CASING ON A HYDRATE PAD. FOLLOW ALL BEST_P_I3_A_C_TJLC_ES T_O MIN_IMIZE IMPACT OF HYDRATES. DO NOT DI~[LL_B_E_Y_O_H.D 4_0_9_5~YlD UNTIL DRILLING _SUP_EBINTENDENT HAS BEEN CONSULT_ED_, The internal yield pressure of the 7" 26# casing is 7240 psi, The deepest anticipated gas should occur no deeper than 1he oil water contact which is expected below the B7 sand at + 7125 'rVDS~ In thls instance, thls worst case suff~ce pressure would occur with a full column cf gas from the reservoir from a depth of ±712~ TVDSS, The maximum 'anticipated surface pressure in this case assuming a reservoir pressure of 3705 psi is 3126 psi, well below the internal yield pressure rating of the 7" casing. MP K-30(Kup) Well Plan PAGE5 LJBI$ Oct96 OCT 21 '96 03:12PM ~P EXP" ~ATIOH Proposed Summary of Operations for MP K-aO(Kuparul<) Review Pre-Spud Che{3kllst RP-Surfaoe Hole V1,0 pages 1-3. prior to spud. Drill and set the 20" Conductor. Weld on an FMC landing ring for the FMC Gan 5A Wellhead onto the conductor as well as a nipple to aid in performing potential wellhead stability cement job. 2. Prepare location for rig move. 3~ MIRU Nabors 22E drilling rig, NOTIFY' THE AOGCC OF AN UF~OMIIVG DIVERTER TEST Review RP.$urface Hole VI.0 pages 1,3, prior to spud, ! NU and test the 20" D/verier system. Build the Spud Mud. Ensure that the diverter is in~talled, Inspected and tested as per AOGCC specifications and is approved by an AOGCC supervisor. Hold a pre spud meeting w/th Co. Rep,, Too/pusher, Rig Crew on tour, Mud Engineer, MWD personnel and other key service performs! as per SSD Drilling Policy, pg, 17, Rev 2,0, Marc/? 1995, Advise the Rig Team to proceed with Ex. tr_ejT~e. Cautip.__n pr/or to and while drilling the hydrate interval and make them aware of the preventative measures designed to manage the hydrates ~afely. Drill a 12-1/4" surface hole as per directional plan. Call Drilling Superintendent before drilling past 409!~'MD. OC~ 7_ ~ '~99g Run Directional/CDR MWD from surface to 12-1/4" TD, Alaska Oil & Gas Cons. Commission Run the 9-5/8" casing and perform the TWO STAGE ~ement Job, Anchorage NOTE: IF SHALLOW SETTING SURFACE CASING~ THE PROGRAM WILL BE DIFFERENT FROM THAT USED FOR DEEP SET CAI~ING. DO NOT CALL OUT THE TAIL CEMENT UNTIL THE CASING POINT !$ KNOWN. Prior to running casing and cementing review the RP-Surface Hole V1.0 pages 1-3. IVO77FY AOGCC OF UPCOMING BOPE TEST Ffecipro~ate pipe prior to and while cementing as per RP, Notify the drilling superintendent Immediately if reciprocation is not possible prior to pumping cement in order to discuss remedial options, Complete the surface casing cementing check list. Perform the TWO STAGE cement job with Halliburton ES type H cementer placed at 2500 ft. ~e follows: . a. Pump 10 bbls. of fresh water to clear the cement lines. b. While performing any high pressure testing make sure that all personnel are safely positioned away from the rig floor and in all areas were the High Pressure lines are laid. o, Test the cement lines to 3500 psig. d. Bleed the pressure from all lines and then Icad the By Pass Cement Plug (bottom plug), e. Pump the bottom plug from the cement head with 10 bbls of Fresh Water, f. Shut down and Icad the shut off plug. g. Pump 70 bbls of NSCI spacer weighted to the same as the mud Add dye in the spacer to help in Identifying returns h. Pump first stage as per the g-5/8" Cement Program, Incorporate "C, elloflakes" in the First Stage slurry First Stage Lead Cement Volume Utilize large flow area float shoe i, Drop the top plug. j. Verify that the positive indicator clearly shows that the top plug left the cement head, k. Switch to the rig pumps and displace the cement at 10-14 bpm When the top plug catches up wilh the cement. Displace with wa~er followed by enough mud to fill the casing down to the ES Cementer. This will allow the annulus to be circulated with mud before the second stage Job is carried out, 1. When the top plug (shut off plug) approaches the landing collar (+/- 5 bbls) reduce the pump rate to 3 bpm, m. Continue displacing the cement until the plug is bumped, Adjust the displacement rate such that ti~e pumping pressure does not exceed 2000 pslg. Once the plug is bumped slowly release the pressure and check the floats for pressure lo~s. MP K-30(Kup) Well Plan PAGE15 LJSl$ Octg6 __ OCT ~1 '9~ 03:13PM BP EXP ..... ~ATIOH P.5 If the floats do not hold, then maintain 1500 pslg on the casing for at least 4 hours and then rechect~ to floats for pressure loss, m. After suoeessfully checking the floats, bleed off ali the pressure and load the closing plug for the ES cementer before shearing the ES tool open. n. Pressure up and shear the ES cementer, Halliburton will advise SSD of the recommended shear pressure for the ES cementer. h7 case the ES Cementer does not open hydraulically, there is an opening bomb a variable. At high weilbore angles pushing the bomb to bottom with dr#/pipe may be required. o. Mix and pump e. dye pill to determine an annular volume. Measure the number of strokes required to circulate out the dye pill to the surface. ff possible estimate the annular volume based on the dye pill bottoms up strokes If this estimated cement volume is equal fo or greater than the 250% excess as proposed notify the Drilling Superintendent. p. Ciroulate and condition the hole for a minimum of 4 hours before pumping the second ~,tage. Make preparations fo handle cement to $[lrface on the first stage circulation, q. Pump a 70 bbls NSCI weighted spacer. r. Pump the Second Stage Lead cement slurry as per the ~)-5/8" Cement Program until cement returns are circulated to the surface. j~_O. NOT A D D_~.JEJ..L_O_F_L,~KE IN S E C_O~ID ,~_TA G E C E_ M ~_L_U~. Add dye to the first few barrels of the second stage lead cement slurry in order to help detect surface returns t, Drop the ES cementer closing plug. u, Displace the plug to the ES Cementer with water at 10-14 bpm. v, Pressure up and shear the ES Cementer closed, Bleed off the pressure and confirm that the cementer is closed, Make preparations to handle cement to surface on the second stage circulation w, After pressure ohecking the ES Cemente~', drain and flush the BOPE stack with water via the annulus valve, x. Back out the landing joint and then Rig Down the cementers and the casing crew. y. NOTIFY THE AOGCC OF AN UPCOMING BOPE TEST. , . . ND 20" Diverter, NU and Test 13-5/8" BOP Prior to drilling our review RP-.For Production Hole Long String VI.0 pages 1-3. Drill the 8-1/2" hole section. MU a PDC bit on an extended power section medium speed motor, with Directional MWD and L WD CDR/CDN (GR/RES/Dens/Neu), RIH, Drill out the Float Equipment and 10' of new formation. Perform a Leak Off Test as per Recommended Practices Manual, Record pressure versus cumulative volume for LOT test for the well file. If the LOT does not yield and equivalent mud weight of at least 12,5 ppg Immediately notify the drilling Superintendent. I0. Drill 8.§" hole to TD as per dlrectional plan. Hold a "Pre-Reservoir" meeting approximately 24 hfs prior to penetrating the Kuparuk Reservoir, Attendants should include Co, Rep., Toolpusher, Rig Crew on tour, Mud Engineer, MWD personnel and other key service personnel as per $$D Drilling Policy, pg, 20~ Rev 2.0, March 1995. At the top of the Kuparuk (D Shale) cap rock weight up the mud system to 9.9-10.0 ppg, Drill the Kuparuk D Shale cap rock as well as the all the Kuparuk sands. The mud weight wi//gradually Increase before exi#ng tile Kuparuk Sands before entering the Miluvech Shale. Sufficient footage ia required such that there Is a minimum of 150' of production rat hole when the 7" casing is run between the base of the Kuparuk B Sand (~.- 10,795') and the PBTD. 1 1, Run and Cement the 7" Casing, MP K-30(Kup) Well Plan PAGE16 LJS15 Oct96 OCT £~ '96 03: ].4PM BP EXF L'ATIOH P.6 Prior to running casing and cementing review RP-For Production Hole Long String V1,0 pages 1-3. The current recommendation Is to J~uck up two 20' marker joints to make a 40' joinf and position 120' above the top of the Kuparuk. Displace cement w#h 8,4 ppg source water and enough diesel to cover from tl~e base of permafrost to surface (+-2100' MD). 1. Test easing to 3000 psig. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED, NO77FYAOGCC OF U~ING BOPE TEST . ND BOPE and 11" drilling spool, NU tubing spool and dry hole tree, Test Tree. Freeze protect annulus and note on morning report. Secure well, Release rig. 3, RDMO Nabors 22E MP K-30(Kup) Well Plan PAGE 17 l..JSl5 Oct96 OCT £1 MP K-30(Kuparuk) g-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON TWO STAGE DEEP SET CEMENT JOB CASING SIZE; SPACER: 70 bbls NSCI Spacer weighted to mud weight,, FIRST STAGE CEMENT TYPE: TRINITY LITE WATE ADDITIVES:, 0.75% HALAD, 0,2%CFR3, 2.0% CaCI2,15#/SK FLOCELE "Cello-Flakes" WEIGHT: APPROX NO SACKS: 13.2 ppg YIELD: 1,3:~ ftS/sx MIX WATER: 7.66 gal/sk I 2 4 8 THICKENING TIME: Greater than 4 hrs at 50° F. The estimated first stage lead cement volume is equivale, nt to the total depth ~ lh~/' surface hole to the E8 Cementer + 80% Exce,s + shoe joint volume. R E C ~ D ,,r,tRECIPROCATIONstage. of the CA~ING STRING is required WHILE CEMENZ,~0C1. ' ?gf~" SECOND STAGE LEAD CEMENTTYPE; Type E Permafrost Alaska Oil & Gas Cons Anchorag8 ADDITIVES: None WEIGHT: 12,0 ppg APPROX NO SACKS: g I 4 YIELD;2.17 ft3/sx MIX WATER: 11,63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. No. sacks based on 250% excess, however cement must be pumped until returns are seen at surface, TAIL CEMENT TYPE; TRINITY LITE WATE ADDITIVES:. 0,75% HALAD, 0,2%CFR3, 2.0% CaCI2 WEIGHT: 13,2 ppg APPROX NO SACKS; 2 I 2 YIELD; 1.a2 ft'9/sx MIX WATER: 7,65 gai/sk THICKENING TIME: Greater than 4 hrs at {;0° F, Volume is based on filling annulus from ES cementer at 2500' to the base of the Permafrost at 1810' with 30%excess. .~/V_.jELJ. HEAD_ S_T_AB_I.LLT_Y CE_IVlE_E_~~, Permafrost E NOTE,. The WELLHEAD STABILITY CEMENT WILL BE PUMPED IF THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. ADDITIVES: None WEIGHT; 12.0 ppg YIELD:2,17 ft3/sx APPROX NO SACKS: lS0 Sacks MIX WATER; 11.63 gal/sk CENTRALIZER PLACEMENT: 1. Install one(l) Straight Blade TURBULATOR Centralizers per joint of 9-5/8" casing on bottom 15 joints of casing (required). 2, Install one(l) Straight Blade TURBULATOR Centralizers per Joint of 9-5/8" casing on from 2000-2800 feet joints of ca~ing (required). Place all centralizers in middle of joints u~ing stop collate, OTHER CONSIDERATIONS;Perform l~b tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job, Ensure thickening times are adequate relative to pumping jot- requirement. Displace et 12 - 15 bpm, Mix slurry on the fly -- batch mixing Is ~lot tleces~a MP K-30(Kup) Well Plan PAGE18 LJSI$ O~tg$ TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 16, 1996 Adrian Clark Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPK-30 BP Exploration (Alaska) Inc. Permit No: 96-168 Sur. Loc. 3605~NSL, 1965'WEL, Sec. 3, T12N, R11E, UM Btmhole Loc. 1232qSL, 757'WEL, Sec. 2, T12N, R11E, UM Dear Mr. Clark: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Approval for annular injection is contingent on the operator's submittal of an Application for Sundry Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and any diagnostic logs that were run. The documentation submitted should include a CQL or a valid LOT to assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental C onsm-vation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork I~Drill I-IRedrill Ilb. Type ofwell nExploratory I-IStratigraphic Test I~Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone i2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 57.5' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 375132 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3605' NSL, 1965' WEL, SEC. 3, T12N, R11E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 339' NSL, 1160' WEL, SEC. 2, T12N, R11E MPK-30 At total depth 9. Approximate spud date Amount $200,000.00 123' NSL, 757' WEL, SEC. 2, T12N, R11E 10/05/96 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 375133, 4523'I No Close Approach 2560 11248' MD / 7358' TVD 16. To be completed for deviated wells 117. Anticipated pressure (see 20 AAC 25.035 (e)(2)} Kick Off Depth 1400' Maximum Hole Angle 58.5° Maximum surface 3125 psis, Attotal depth (TVD) 7125' / 3705 psis 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1Cf H-40 Weld 80' 32' 32' ' 112' 112' 2~50 sx Arctic,~,e~ (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 3796' 31' 31' 3796' 3559~¢. ~8"4"sx PF 'E',.C~2t~'x 'G', 150 sx PF 'E' 8-1/2" 7" 26cf L-80 Btrc 12324' 30' 30' 11248' 7358'// 576 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~'r5'-5~ ~F'~ ~/c~_~,. ~ ,~j~ Present well condition summaryi'~'~ f~!~ I ~, ! Total depth: measured feet Plugs(measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner · .. Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Dive.er Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAO 25.050 Requirements Contact Engineer Name~Number: James Robe/Cson, 564-5159 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the f_~o_r~.¢ng..Js, true and c.e'rrect to the best of my knowledge SteveShuitz~'~~~~%' '- Title Senior Drilling Engineer Date · ~% Commission Use Only Permit Number '~1^~'"~e~ I Approval Date I See cover,etter ~,,~-,,,,/~ ~' 50- ~..~.-~_~;: --' ~ ~.. ,~/// //,0 -'"/~, ~ ~'~. for other requirements ConditionsofApproval: SamplesRequired [-l~Sys~No MudkogRequired OYes _~No Hydrogen Sulfide Measures [] No Directional Survey Require0 ~'Yes [] No Required Woddng Pressure for BOPE [] 2M; [] 3M; Other: i Approved By drlglllal Signed By Commissioner the commission Date Form 10-401 Rev. 12-01-85 ~' ..... ~' Submit In Triplicate Shared Services Drilling Contact: Lance Spencer" 5 64- 5 0 4 2 I Well Name: IMP K-30 Well Plan Summary IType of Well (producer or injector)' IKuparuk Producer Surface Location: 3605 NSL1965WELSec03T12N RllE UM.,AK Kuparuk Target 339 NSL1160 WEL Sec 02 T12N R11E UM.,AK Location: Bottom Hole 123 NSL 757 WEL Sec 02 T12N R11E UM., AK Location: I AFE Number: 1337048 I I Rig: I Nabors 22-E .. IEstimated Start 118 OCT96 Date: IOperating days to I 1 3 complete: IMD: 111'133' I ITVD' 17'298' Ibkb JKBE' 158'5 Milne Point Ultra Slimhole Longstring 9- IWell Design (conventional, slimhole, I etc.)' 5/8", 40# Surface X 7", 26# Longstring Formation Markers: Formation Tops MD TVD (bkb) Base Permafrost 1,81 0 1,809 8.3 ppg, 781 psi NA 5,905 4520 8.3 ppg, 1951 psi CA 6,1 44 4 64 7 8.3 ppg, 2006 psi CB 6,253 4705 8.3 ppg, 2031 psi Base OB 6,31 3 4,7 3 7 8.3 ppg, 2045 psi TopHRZ 10,012 6,703 8.6 ppg, 2998 psi Base HRZ 1 0,1 8 2 6,7 9 3 8.6 ppg, 3038 psi TKLB 10,295 6,853 10 ppg, 3065 psi TKUP/UD 10,511 6,968 10 ppg, 3624 psi TKUC 10,614 7,023 10.0 ppg, ..3652 psi TKCl/TARGET 10,718 7,078 10.0 ppg, 3681 psi TKUB/B8 10,798 7,121 10.0 ppg, 3703 psi TKB7 10,825 7,135 10.0 ppg, 3711 psi Total Depth +1 1,1 33 +7,358 10.0 ppg, 3826 psi Casin~/Tubin~ Pro.( ram: Hol; (~sg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 1 12/1 12 12 1/4" 9-5/8" 40# L-80 btrc 3796 31/31 4095/3558 8- 1/2" 7" 2 6 # L-80 btrc 12324 30/30 11133/7298 The internal yield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the B7 sand at + 7125 TVDSS In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +7125 'rVDSS. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3705 psi is 3125 psi, well below the internal yield pressure rating of the 7" casing. -' Logging Program: I Open Hole Lo =:I Surface MWD Directional surface to TD. Intermediate N/A Final Cased Hole Logs: IMWD Directional and LWD (GR/CDR/CDN). N/A N/A Mud Logging Mudloggers are NOT required for this well. Mud Program: Special design considerations Special attention should be given to, gravel, clay, hydrate, and coal intervals in the surface hole. Running gravel, sticky clays below the permafrost, gas gut mud due to hydrate formation, excessive fill on connections, tight coal sections and stuck pipe have been encountered in previous surface holes on K-Pad. Prior to spudding a complete review of the K-Pad drilling hazards is required. Preventative measures such as more frequent short trips, viscosity and mud weight control, Iow mud temperatures, controlled drilling rates, and lower flow rates should be employed to mitigate problems and lost time in the'surface hole. HYDRATES Hydrates are present on K-Pad but can be managed if the proper precautions are taken in advance. The mud weight should be at 11 ppg by 2000 feet and if necessary weighted up in 0.5 ppg increments as required. Use the coldest available mix water possible at or below 60° F to minimize warming effects and the resulting gas liberation while drilling this interval. Controlling the flow rates between 450-600 gpm is also required. However, with the lower flow rates need to minimize hydrate formation particular attention should be given to problems associated with hole cleaning - tight connections and fill. Downhole motors will be selected with this flow restriction in mind (8" or 7- 3/4" motors are recommended). In addition controlling the drilling rate to 100 feet per hour as well as increasing the mud viscosity at 200 sec/qt and the weight at 11 ppg before drilling below the base of the permafrost has minimized the potential problems which can occur while drilling hydrate formations. Lecithin shall also be utilized to control gas dissociation from hydrates. Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss $.6 100 15 8 10 9 8 to to to to to to to 11.0 50 35 1 5 30 1 0 1 5 Intermediate Mud Pro)erties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid ( P P G ) Viscosity Point gel gel Loss 9.0 40 1 0 3 7 8.5 6 - 8 to to to to to to to 11.0 50 15 10 20 9.5 4-5 .. Well Control: Well control equipment consisting of pipe rams, blind rams, and annular preventer will be installed and shall be capable of operating to 5000 psi working pressure. The BOPE and diverter systems shall be capable of handling the maximum anticipated surface pressures Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: KOP: 300' Maximum Hole Angle: 58.89° Close Approach Well: (No Shut In Wells ) High Angle Nudge, Build and Hold Profile Max Dog Leg during variable build 3 deg/100' M D BKB VS INCL KB 0 0 0 ~' 0 KOP/Nudge 1/100 300 300 0 0 Drop 1/100 900 899 - 6 6 KOP Build 2/100. 1500 1498 - 1 2 0 End 2/100 build. 1770 1767 1 5.4 Build 3.0/100. 1870 1867 10 5.4 End 3.0/100 build. 3620 3305 897 57.89 9-5/8" Csg. point. 4095 3558 1299 57.89 Target 10718 7077 6909 57.89 TD/7" Csg point. 11133 7298 7261 57.89 Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. 1. The base of the Permafrost for all wells located in the Milne Point Unit is _+1,850' TVD. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 2. There are _+10 wells on Milne Pt. 'K' Pad. quarter mile distance from the subject well. located within one mile of the project area. There may be additional unidentified wells within one There are no domestic or industrial water use wells 3. The wastes to be disposed of during drilling operations can be defined as "DRILLING WASTES". The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. , . . , , , . , , 10. 11. 12. 13. 14. 15. 16. 17. 18. MP K-30(Kup) Proposed Summary of Operations Review Pre-Spud Checklist RP-Surface Hole VI.0 pages 1-3. prior to spud. Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5A Wellhead on conductor as well as a nipple to aid in performing potential wellhead stability cement job. Prepare location for rig move. MIRU Nabors 22E drilling rig. Review RP-Surface Hole VI.0 pages 1-3. prior to spud. .. NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisior. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Advise Rig Team to proceed with Extreme Caution prior to and while drilling the hydrate interval. Run Directional MWD from surface to 12-1/4" TD. Review RP-Surface Hole VI.0 pages 1-3. prior to spud Run 9-5/8" casing. Space out ES Type H Cementer to 1300'. Perform Two Stage cement. Complete the surface casing cementing check list. ND 20" Diverter, NU and Test 13-5/8" BOP MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 10' of new formation. Perform LO to a maximum of 12.5 ppg as per Recommended Practices Manual. Record pressure versus cumulative volume for LOT test for the well file. Drill 8.5" hole to TD as per directional plan. Sufficient .footage should be drilled. A minimum of 150' of production rat hole in the 7" casing between between the base of the Kuparuk B sand and PBTD is required. Run and Cement 7" Casing. Insure that a short joint or an RA tag is run in the 7" casing approximately three joints above the top of the Kuparuk. Displace cement with 8.4 ppg source water and enough diesel to cover from the base of permafrost to surface (+-2100' MD). Test casing to 3000 psig. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 22E. Review Recommended Practice for Running Tubing Std Tbg Rng V3.2 Review Milne Point Unit ESP Running Recommended Practice RP: Run DBR/JDP -5-26/94 Version 0.0 ESP/PKR: MIRU Nabors 4ES. ND dry hole tree, NU & Test BOPE to 5000 psig. PU and RIH with clean out assembly on 2-7/8" tubing. Cleanout to PBTD. Displace hole with 10.4 ppg kill weight brine. PU and RIH with perforating guns on electric line ( The perforating proceedure will be distributed later with the selected perforation intervals once they are determined). POOH with perforating guns on E-line. PU and RIH with 2-7/8" EUE 8RD tubing with GC 4100 Electric Submersible Pump (ESP) Completion.. Set 2 way check. ND BOPE and test tree. Pull two way check, freeze protect, set BPV, close valves. Test tree 1 9. RDMO Nabors 4ES completion rig. DRILLING HAZARDS AND RISKS: HYDRATES K-02, K-05, K-17, K-25, K-38, K-39 and encountered hydrates while drilling the surface hole. Severly gas cut mud, excessive connection gas, flow on connections and other problems can occur while during the surface hole on K-Pad and are directly attributed to gas hydrates. In addition problems can develop as a result of measures designed to lessen to effects gas. It is important to recognize what problems might develop while fighting gas hydrates and have plans in place to mininimize them. Plans should be made in advance prior to spudding the surface hole to midigate to potential risks and minimize the nonproductive time involved in managing hydrates. The measures are necessary to lessen to effects of gas hydrates: Increased mud weights Low drilling fluid temperatures Reduced ROP's for control drill rates Controled ciriculating and drilling fuild rates Utilization of "Lecithin" " Close Approaches There are no close approaches associated with the drilling of MP K-30 however tolerance lines should be carefully monitored and deviations from the proposed wellpath minimized.. Water Injection Currently no water injection wells are present on MP K-Pad Annular Injection Currently annular injection is not permitted for MP K-02, MP K-05, MP K-17, MP K-25, MP K-38, MP K-39. Cascade# 1, or Cascade #la. Annular injection is not allowed in MP K-02, MP K-05, MP K-17, MP K-25, MP K-38, MP K-39 because the qualifying criteria as per SSD SOP:Annulus Injection ver 4.0 June 5, 1996 pg 13 are not satisified. A total of 19,608 bbls were injected into the K-17 annulus. Gas Injection Currently no gas injection wells are present on K-Pad Lost Circulation: K-05 experienced lost circulation while drilling the 12-1/4" ~urface hole at 2250 Md. K-02 , K-05 experienced losses while circulating to condition mud while runninng 7" csg K-05 experienced lost circulation while cementing 7" csg. In every instance losses were minimized by reducing flow rate and conditioning the mud. Stuck Pipe Potential: Running gravels (K-17, K-38), sticky clays (K-02, K-05, K-38, K-39) and coal sections(K- 17) presented tight hole and bridging in (K-17, K-25, K-38),and stuck pipe (K-17 ) while driling the 12 1-4" surface hole. Excessive amounts of reaming were required wile drilling K- 17 and K-25). While running 9-5/8" casing the flowing problems experienced: K-05, hole packing off, tight hole and bridging K-2, K-39. The 9-5/8" casing was stuck in K-05. These problems in some instances were greatly exagerated because of measures taken to manage the gas hydrate problems. Increased torque and drag have been experienced after drilling into Kuparuk so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Formation Pressure: KUPARUKSAND 7000' TVD 3600 PSI" 9.9 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the B7 sand at _+ 7125 TVDSS In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of _+7125 TVDSS. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3705 psi is 3125 psi, The maximum expected pore pressure for this well is 10.0 ppg EMW (3,705 psi @ 7,125' TVDss). There has been injection in this region from MP K-17, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point K-Pad Data Sheet prepared by Pete Van Dusen for information on K pad and review recent wells drilled on K Pad. MP K-30(Kuparuk) 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON TWO STAGE CEMENT JOB CASING SIZE' 9-5/8" CIRC. TEMP 60 deg F at 2840' TVDSS. SPACER: 70 bbls NSCI Spacer weighted to 12 ppg equivalent mud weight... FIRST STAGE LEAD CEMENTTYPE: Type E Permafrost ADDITIVES: .15#/SK FLOCELE "Cello-Flakes" WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: 2 5 8 THICKENING TIME: Greater than 4 hrs at 50° F. The estimated first stage lead cement volume is equivalent to the annular volume calculated from the total depth of the surface hole to the base of the Permafrost + 30% Excess + shoe joint volume. TAIL CEMENT TYPE:_ Premium G ADDITIVES: 2.0% CaCI2 +.15#/SK FLOCELE "Cello-Flakes" WEIGHT: 15.8 ppg YIELD:l.15 ft3/sx MIX WATER: 5.0 gal/sk APPROX #SACKS: 8 4 0 THICKENING TIME: Greater than 4 hrs at 50° F. The estimated first stage tail cement volume is equivalent to the annular volume calculated .. from the base of the Permafrost to the ES Cementer located at 1300' MD+ 250% Excess. SECOND STAGE LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: None WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: 9 I 4 THICKENING TIME: Greater than 4 hrs at 50° F. The objective of the Surface Ceme~tt. is to insure that cement is circulated to surface. Cement shall be pumped until such time as cement is circulated to surface. Arrangements should be made to insure that sufficient cement is available so that continuos cementing can occur uninterrupted until cement is circulated to surface. Dye shall be introduced into the mud after the first stage and into the cement of the second stage in order to obtain an estimate of annular capacity to that additional cement can supplied if required and adequate excess has been pumped. Once an adequate volume of cement has been circulated to surface immediately begin displacement with The estimated second stage lead cement volume is equivalent to the annular volume calculated from surface to the ES Cementer located at1300' and 250% EXCESS. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: The WELLHEAD STABILITY CEMENT WILL BE PUMPED IF THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. ADDITIVES: None WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 Sacks RECIPROCATION of the CASING STRING is required WHILE CEMENTING. CENTRALIZER PLACEMENT: 1. Install one(l) Straight Blade TURBULATOR Centralizers per joint of 9-5/8" casing on bottom 10 joints of casing (required). 2. Install one(l) Straight Blade TURBULATOR Centralizers per joint of 9-5/8" casing on from 2000-2500 feet joints of casing (required). Place all centralizers in middle of joints using stop collars. .. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: The objective of the Surface Cement is to insure that cement is circulated to surface. Cement shall be pumped until such time as cement is circulated to surface. Arrangements should be made to insure that sufficient cement is available so that continuos cementing can occur uninterrupted until cement is circulated to surface. Dye shall be introduced into the mud after the first stage and into the cement of the second stage in order to obtain an estimate of annular capacity to that additional cement can supplied if required and adequate excess has been pumped. 1. The estimated first stage tail cement volume is equivalent to the annular volume calculated from the base of the Permafrost to the ES Cementer located at 1300' MD and 250% Excess. 2. The estimated first stagelead cement volume is equivalent to the annular volume calculated from the total depth of the surface hole to the base of the Permafrost, 30% Excess and the shoe joint volume. .. 3 The second stage lead cement volume is equivalent to the annular volume calculated from surface to the ES Cementer located at1300' and 250% EXCESS. 4. Capacity of 83'md 9-5/8", 40#casing for float joints. Wellhead stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the wellhead. .. MP K-30(Kuparuk) Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON Single STAGE CEMENT JOB across the KUPARUK and Schrader Bluff intervals: CIRC. TEMP' 115° F SPACER: 50 bbls fresh water BHST 120° F at 7040' TVDSS. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 12.25 ppg APPROX # SACKS: FLUID LOSS: 0.2% CFR-3, 30#/sk Silicalite , 1.25% Halad 344 YIELD: 2.81 cu ft/sk MIX WATER' 16.0 gal/sk 576 SACKS THICKENING TIME: 4 1/2 hrs @.-140° F < 49cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: Run two the 7"x 8-1/4" Straight Blade Rigid Centralizers. per joint on the from TD to 300' above the Kuparuk. Run one the 7" x 8-1/4" Turbulators per joint 300' above and 300' below the Schrader Bluff approximately 5605-6613' md, (+-25 Turbulators). Run one (1) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 10 bpm. Batch mixing is not necessarY. Cement shall be displace above the top of the Schrader Bluff however this well is not a planned injection well therefore a Cement Bond Log is not required. CEMENT VOLUME' , Single stage cement volume is calculated to cover 500 FT MD above the NA Top + 30% excess. Anadrill Schlumberger AlaSka District 111i East 80th Avenue. Anchorage, A~ .99518 (907). 349-4511 Fax 344-2160 · DIRECTIONAL. WELL PId~N for S~ARED SERVICES DRILLING Well ......... : MPX-30(P¢) Field ........ : MILLE POI~TT, KPAD Computation,.: Minimum Curvature Units ........ : FEET Surface Lat.,: 70.42561044 N Surface ~ong'.z 149.31066696 ~ LOCATIONS.-'/tLASKA Zone: Legal Descr£ption X,Coord _.,_-~ Sur[ace ...... : 3604 FSL 1965 FEL 584592,27 _~ T~GET ....... z 590719.00. ,--7~ BH~ .......... , 591029.67 S03 T12N R11E. UM 339 FSUl~60 ~EL S0~ T12~ ~11~ U~ 170 FSL 851 FEL S02 T12N R11E U M 4 . , Y-Coord 6005741.29 6002548.00 6002382.'53 PROPOSED WELL PROFILE mm{{m{~mmmmmmmmmmmw~ !m~m{,mmm m~mmmm STATION M~ASURED INCI/~ ID~%~TTIFICAT~ON DEPTH ~I~NGLE mmmmmmmmmmmtmmmmm,mmm .mmmmumwm mmmmmu o~oo xo~/~E 1/~oo ~oo.oo o.oo 400.00 1.00 500.00 2.00 600.00 3.00 . , tm'mmtmmmm m m~ ! m DiREc~IO~ ~TIC~-~EPTas AZIM~ ~ su~-sEa mm mmmm mmm mmmmmmmm m o.oo 0.oo -57.~o 0.00 300.'00 242.50 18.00 399.99 342,49 18.00 499.96 442.46 18,00 599.86 542.36 SECTION DEPART 0.00 0.00 ~0.16 -0.65 -1.46 Prepared ..... : 02 Oct 1996 Vert sect az.: 118.69 'l~ elevatton.~ 57.50 ft Magnetic'Dcln: .28.046 (E) Scale Factor..~ 0.99990813' Convergence,,~ +0,64949815 ANADRILL AKA-DPC APPROVED FOR PERMITTING mmmmmmmmmmm.mmmmmmm~mm COORDINATES-FROM A/d~SKA zOne 4 WELLHEAD X Y FACE 100 mmmmmmmmmm mmmmmmmmmm mmmmmm~mm mmmmmmmmmm m~mm mmmm 0.0~0 ~ 0.00 E 584592.~? 6005741.29 90R 0.00 0.00 N 0.00 ~ 584592.~? 6005741.~9 ?~R 0.00 0.83 W 0.27 E 584592.$] 600574~.12 ?~R 1.00 3.32 N 1.08 E 584593,31 6005744.62 72R 1,00 7.47 N 2.43 E 584594.61 6005748.78 72R 1.00 . ONL. Y PLAN # TOOL DL/ DROP 1/100 700.00 4.00 B00.00 5.00 900,00 6.00 1000.00 :5.00 1100.00 4.00 18.00 699.68 642.16 18.00 799.37 94'1,87 18.00 898.90 841.40 18.00 998.44 940.94 , 18.00 1098.13 1040.63 -2.59 -4.04 -S.B2 -7.60 -9.06 13.27 N 4~31 E 584596.43 6005754,61 72R 1.00 20.74 N 6.74 E 584598.77 6005762.10 72R 1.00 29.85 N 9.70 E 584601.63 6005771.25 LS 1.00 36.97 N 12.66 E 584604.49 6005780.39 72R 1.00 46.43 N 15.09 E 584606.83 6005787.88 72R 1.00 1200.00 3.00 1300.00 2.00 1B.O0 1197.95 1140.45 18.00 1297.85 1240.35 -10.19 -11.00 52.23 N 16.97 E 584608.65 6005793.71 72R 1.00 S6.38 N 18.32 E 584609.95 6005797.87 72R 1.00 (Anadrill (c)96 MPK30P4 3.0b,06 9:15 AM P) ~ 0 0 .h ( '0 MPK-30 (P4) STATION MEASURED INCLN IDENTIFICATION DEPTH ANGLE {{{mmmmmmmmmmmmmmmm{ mm{mmmmm mmmmm' 1400.00 ~!.00 '. BUILD 2/100 1500.00 0.00 1600.00 2.00 1700.00 4.00 END 2/100 BUILD 1770,00 S.40 BASE PERMAFROST BUILD 3/100 Z 1810.2'7 5.40 187o.o0 5',4o 1900.00 6..30 2000.00' 9.30 2100~00 12.30 2200.00. 15.30 :300.00 18.3'0 2400.00 21.30 2500.00 24.30 2600.00 27.30 2700,00 30.30 2800.00 33.30 '2900.'00 36.30 3000.00 39.30 3100.00 42.30 3200.00 45.30 3300.00 48.30 3400.00 51.30 3500.00 S4.30 3600.00 S7.30 3/100 ,O~,.D 3~19.81 57.89 8904.90 57.89 .PROPOSED WELL PROFILE mmmmmm~mm DIRECTION AZIMUTH mummmummm 18.00 0.oo 118,69 118.69 118.69 mmmmmmmm~mmm~m{mm VERTICAL-DEPTHS TVD ,SUB-SEA m m mmm m m~m~ ~ m ~ 1197.81 '1440,3i 1597,79 1540.29 1697.65 1640,15 1767.41 1709,91 118.69 118.69 118.69 118.69 118'.$9 ~807.50 1780.00 1866.9~ 1809.46 18'96.81 1839,.31 ~998.m7 ,1938.3~ 2094.09 2036.59 118.69 2191.19 118,.69 2286'.91 118,69 2380.99 2133,69 , 2229.41 2323..49 '118.$9 2673.17 24i5.67 118,69 2563.19 2505.6'9 ,. 118.69 2650.81 2593.31 118.69 2735.79 2678.29 118.69 2817.89 2760.39 , 118.69 2896.90 .2839.40 118.69 2972.59 '2915.09 118.69 3044.76 118.69 3113.20 118.69 3177.74 118.'69 3238.20 118.69 3294.40 2987.26 3055.70 3120.24 3180.70 3236.90 3247.51 3500.00 4462.00 118.69 3305.01 ,, 118.69 3SS?.SO 118.69 4519.50 sECTION DEPART -11.48 -11~64 '9.90 -4 1,07 4.86 10,48 .13..54 27.11 '45.84 '6.9 70 98.59 132.46 171.21 262.90 315.59 372.65 433.94 499.27 02 Oct 1996 58,87 N 19.13 E 59,70 N 19.40 E 58.86 N 20.93 E 56.35 N 25.52 E 53.60 N 30.55 E 51.78 N 33.88 49.08 N 38.81 47.61 N, 41.49 41.10 N 53.39 32.10 N 69.83 20.68N 90.75E 6.'78 N 116.~o 9.48 S 145.82 28.08 s 179.81 48.97 S 217.98 72.10 S 260.24 97.39 S .306146 124.79 S 356.52 154,21 S 410.'28 185,57 S 467.59 568.48 218.80 S 528.30 641.37 253.79 S 592.24 717.74 290.45 S 659.24 797.38 328.69. S 729.10 880.08 368.39 S 801.65 896.81 376.42'S 816.32 2832.43 1305.65 S 2514.31 Page 2 ALASKA Zone 4 X Y 584610,73 6005800.37 584610.99 6005801.20 584612.53 6005800.38 584617.15 6005797.92 .584622.21 6005795.23 884625.ss 6008783.45 884630.51 6005790.80 884633.21~008789.37 584645.19 6005782.99 584661.72 60057~4.18 584682.77 6005762.97 S84708.28 6005749.38 584738.17 6005733.46 584772.37 6005715.25 564810.77 6005694,80 584853.28 6005672,15 5848'99.78 6005647.39 584950.15 6005620.56 585004.23 6005591.76 5850,61.89 6005561,O5 585122.97 6005528.52 585187.30 6005494.25 585254.70 6005458.36 585324.98 6005420.92 585397.97 6005382.05 585412.73 6005374.19 S~S76~8~ 6006~'85.63 587120.99 6004464.35 TOOL FACE 90R 29R 29R 29R ~S DL/ 100 1,00 1.00 2.OO 2.00 2.00 HS 0.00 HS 0.00 HS 3.00 HS 3.00 HS 3.00 RS 3.00 HS 3.00 HS 3,00 HS 3,00 HS 3.00 HS 3.00 lis 3,00 IIS 3.00 HS 3.00 HS 3.00 HS 3.00 H$ 3.00 HS 3.00 lis 3.00 HS 3.00 3.00 o. oo 0.00 . (Anadrill (c)96 MPK30P4 3.0b.06 9:15 AM P) MPK-30(P4] STATION MEASURED INCLN IDENTIFICATION DEPTH ANGLE ~m~emmmemmmmmmmmmmmm mmmmmmmm mmmmmm OA 6143.85 57.89 '. OB 6252.98 57.89 BASE OB 6313.19 57.89 THRZ 10012.27 57.89 8~RZ 10181.61 57.89 TLB 10'294.50 57.89 TKITP/UD 10510.88 57.89 Tk'UC 10614.36 57.89 TARGET 10717.84 57.89 TKC1 10717..84 57.89 T~S? 10825.09 57.a9 T~B6 10883.42 57.89 ?KB5 10921.05 57.09 TEe4 10986.90 57.89 PROPOSED WELL PROFILE m~mmsmm m~mmmmsmmmmmmmmmm DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA mmmmmmmmm mmmmmmmm mmlemllm 118.69 4646.50 4589.00 118.69 4704.50 4647.00 118.69 4736.50 4679.00 118.69 6702.50 6645.00 118.69 6792.50 6735.00 mmmm~mm! SECTION DEPART 3034.'84 3127.28 3178.28 6311.66 6455.10 118.69 6852.50 6795,00 6550.73 118.69 6967.50 6910.00 6734.01 118.69 7022.50 6965.00 6821.67 118.69 7077.50 7020.00 6909.33 118.69 7077.S0 7020.00 6909.33 118.69 7120.50 7063.00 118.69 7134.50 7077.00 118.69 7165,S0 7108.00 118.69 7185.S0 7128.00 118.69 7220.50 7163.00 6977.86 7000.17 7049.58 7081.46 7137.24 02 Oct 1996 Page ~{m{m~mm!~ m m m mmmmm~ COORDINATES-FROM WELLHEAD mmmmmm{mmm m ,, 1402.82 S 2691.87 1447.19 s 2772.96 1471.68 s 2a~7.70 2975.91 $ 5566.40 3044.77 s 5692.23 m~mmm~mmmmmmmm~mmm ALASKA Zone 4 ¥ mmmmemm~m m{~mmmmmm S87299.~2 6004369.20 587381.21 600432'5.75 587426.22 6004101.78 590191.54 6002828.93 590318.13 ~002761.51 3090.68 S 5776.12 3178.67 S ~936.90 3220.75 S 6013.80 3262.83 S 6090.70 3262.83 $ 6090.70 590402.52 6002716.56 590564.28 6002630.41 590641.64 6002589.20 590719.006002548.00 590719.00 6002S48.00 3295.73 S 3306.44 S 3330.i6 S 3345.46 S 3372.24 S 6'150.81 E 590779.45.6002515.?9 6170.39 E 590799.17 6002505.30 6213.73 E S90842.78 6002482.07 ~41.69 E .,590870.91 6002467.09 6290.63 E S90920.14 6002440..87 m m~mm m ~m FACE lO0 HS 0.00 ~S 0.00 HS 0.00 HS 0.00 HS 0.00 RS O. 00 HS O. O0 HS O. O0 HS 0. O0 HS O. O0 HS 0.00 ~S 0.00 HS 0.00 HS 0.00 RS 0.00 '' O 0 c+ '. O' 0 W > ). .,.h TKB3 11043.3S 57.89 TKB2 11090139 57.89 CASING POINT 11133.42 57.89 11133.4'2 57.89 TKB1 TKITA (Anadrill (c)96 MPK30P4 3.0b. 06 9:15 AM' P) 118.69 7250.S0 7193.00 118.69 7275.S0 7218.00 118.69 7298.37 7240.87 118,69 7298.37 7240.87 7300.50 7243.00 7330.50 7273.00 7185.05 7224.90 7261.35 7261.35 .. 3395.20 S 6332.57 3414.33 $ 6367.52 3431.82 S /6399.50 34~1.52 s. 63m9.so 590962.34 6002418.40 590997.50 6002399.67 591029.67 6002382.S3 591029.67 6002382.S3 HS 0.00 HS 0.00 0.00 0.00 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY .... PLAN # .,,V .. .( tO O~ 0 Oct-D2-96 o 03:33P An~~--~-'~- ill DPC 344 2160 P. 05 ..... SHARED SE V'ICE'b' DRILLING' " .. i · · I I I I III· I I II ] I J mil I I I I~ MPK-30 (p4) i ANADRILL AKA-DPC VERTICAL SECT'I0~ VIEW ' APPROVED FOR PERMITTING Sect)on at: TVD Scale' I inch = ~200 fee~ ON LY Oep'Scale.: ! inch : ~200 feet 8 '~,.!. _ ...... .j /nadrj ]] Schlumberger C Marker Identification ~ BKB: ~CTN INCLN " Al KB 0 0 0 0.00 O ~' B) KOP/~ J/~O0 ~0 300 0 0.00 CJ DR~ J/l~ ~ 8gg~'. -6 6.00 , ~ ~ D) ~ILD 2/100 1~0 t498 -12 0.00 - ~~]'~r ~ E) END 2/100 BUILD J770 ~767 ~ 5.40 FJ BUILD 3/100 1870 1867 10 5.40 .. , G) EB 3/100 ~ILD . ~20 3~5. 897 57.89 MI' 9-5/8' CASING ~INT 4095 3558, 1299 57.89 I) TARGET 10758 7077':' 6909 57.89 J) 7' CASING ~INT 1~133 7~8. 726~ 57.89 ~. K) TO 11133 7298' 7261 57.89 , . -- -. -~--- m- ~~ =,~.~-. , ., j- , ' ...... NJi~iiiil liiii iili!iililiilili iilililililjiliii iiiiiiliiil;ililiiiilit'jiii~ ~ ~ ..... ~ ~ .... ~ ...... , .... . . . . ~.,~ ,~.,..~.- (AnaOrili (c)96 MPK3OP4 3.00.06 ~: t5~' P) 0 600 t200 JSO0 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 , ~ 'oec~. ion. D.epar,ture .... 0ct-'02-96 03:33P Ana~rill DPC __~ SHA~D 'S~VI~ES 344 2160 P. 06 , DRILL'I'NG" Marker, Identification MD BKB SECTN INCLN ( A) lARGET ,07,8 7077 6gog 57.Bg MPK-30 P4 c~"~ T.~' ~.s~.~,.o~., ,,~"'~ ~ ~7~' ~.,~'~ VERTICAL SECTION VIEW - . m Section at: 118.69 IVD Scale.- ~ inch = t00 feet~ ~o-- ~ ] Oeo Scale.' ~lnch = ~00 feet , Bpa~n ..... · O~ Oct 19 - . ' "- i .... i~ i ..... Ana¢r i l I Schlumberger ~ ~ , , ,,: , . 10-- , . ~ .. o:% .. APF ROVED .....; - " '~ FO. R BBRMi ~ J l''''~j~,~ 0--- ~ " -'" " . - , .... . . . .... I ,-~~ -~ ..... ~. -~.~ .. .... .__..,_. =._, ,.~ .... I -~.~~~. . . . _ . I ' ' ' , . ~ . ....... 0 ~650 ~700 ~750 2Boo ~850 ~0 ~9so 3000 ~50 3~00 3~ 3800 3e50 3300 ~ Section Departure 2600 l 0ct~02-96 03:33P An~rill DPC 344 2160 ii Po07 'SHARED 'SERVICE~ DRT'I~E'ING" Marker Identification Al T~RGET 8) 7" CASING ~INT C] TD · HD BKB SECTN INCLN 10718 7077 6g0g 57.89 1]t33 7298 7261 57.89 tJt33 7298 726] 57.89 I l I I I I I Ill MPK-30 (P4] VERTICAL SECTION VIEW II I ii il i i Section at: 118.69 TVD Sca]e · I inch : 200 feets Dep Sca]e · 1.inch : 200'feet IAnadnJ ]1 Schlumbbrger. --i i { l # ANAD~ ILL }:,~ ~KA-DP~: FI)R P [RM TTH4G . , . - .., .. .~ ' N ~)N L' :. .L .... .......... . ~ .............. ~ *~.~ . '~- ~ ............................ ...... 'Z~ ' fo~ -. ...... - . 'T~cT - ~ ...... ~1 ~ ~ ~ 1 ' .~' . 'T~ ~n~- - ~ ......... ~ . I ~-~-~-- ~ ~. .-. --1 ~_~__~-_: ........... -. ............ ~ ............ ~ ............ ~r-~ ..... ::::: .,~-~ ..... t ::T:7,~ .... -~' ~ ,- ......... -=_~ ....... . --,.- ...................... ,,~-~I. - - ~- ':::~ ..... . . i ' ~ ..... ~ .... , ..... ;. . , 6200 6300 6400 6500 6600 6700 6800 6900 7000 7 t00 72.00 7300 7400 7500 7600 , , , S, ection O,epartur,e, , CAnadrill (cl~ ~3~4 3.0~.06 ~. t6 ~ PJ " SHARED SERVICES DRILLING · /nadrj)] Schlumberger ~ MPK-30 (P4) PLAN VIEW I ' : ~DECLINATION.: +28.046 (E) ]sCALEi..;.'..: ! inch = 800 feet o .... ~ mD ! , ' ...... Marker Identification HO N/S E/~ Al KB 0 0 N 0 E B) KOP/NuDGE i/lO0 300 0 N 0 E 0 ..... , C} DROP l/lO0 900 30 N lO E .... ' .... ' "D) BUILD. 2/100 1500 60 N 19 E E} ENO 2/I00 BUILD 1770 54 N 31 E F} BUILD 3/t00 t870 49 N 39 E 0 , , G) END'3/IO0 BUILD ' 3620 376 $ 8t6 E ~, ..... ' 9-5/8" CASING POINT 4095 570 S I169 E ' ~ ~I TARGET ,i07,8 3263S 609i E -- J) 7" CASING POINT ii133 343~S 6399E 3 . .... .................... .~ K} TO i,.,33 3432S 6399E ~ . I J ANAl]RILL AKA-DI C ~.'.*nGE* I, adjus ,0 .. ONi,,Y 400 0 400 BOO ~2no mnn ~nnn 3ann ~onn '3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 <- WEST' EAST -> .2O feet {~naOr'~il (CJ~ ~K:)OP4 3.(}0.06 9:15 ,~M In] 0 ri' '0 I 0 '1 BP EXPLORATION 900 East Benson Boulevard Anchorage, Alaska 99519-6612 (907)561-5111 October 4, 1996 David W. Johnston, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 RE: Request of Exemption to Provisions of 20AAC 25.055 and Conservation Order 173 Rule #3 for MP K-30. Dear Commissioner Johnston, BP Exploration (Alaska), Inc. hereby applies for an exemption to the provisions of 20 AAC 25.055 and Conservation Order 173 Rule #3 for MP K-30 Well (the well), for which the following is proposed: 1. Surface Location: 3604 NSL 1965 WEL Sec 03 T12N R11E UM., AK 2. Kuparuk Target Location: 339 NSL 1160 VVEL Sec 02 T12N R11E UM., AK 3. Bottom Hole Location: 123 NSL 757 WEL Sec 02 T12N R11E UM., AK The owners and operator of all governmental quater sections directly and diagonallly offsetting the proposed location of the well are BP Exploration (Alaska), inc., and Occidental Petroleum. The plat required by the regulation is attached as Exhibit 1. The verification required by the regulation is attached as Exhibit 2. Copies of the notification to the owners and operators, as well as the required information with respect to the mailing are attached in the package designated as Exhibit 3. Thank you for you assistance in this matter. Please direct any questions to Tom Niswander at 564-5472. cc BPX OXY BP EXPLORATION 900 East Benson Boulevard Anchorage, Alaska 99519-6612 (907)561-5111 October 4, 1996 Bob Crandall Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Subject: Application requesting Spacing Exemption for MP K-30 to provisions of 20 AAC 25.055 and Conservation Order 173 Rule #3. Dear Mr. Crandall, The MP K-30 well is a planned producer into the Kuparuk River Formation in the SE/4 of Sec 2 T12N, R11E within ADL lease 375132. The MP K-30 well is a planned producer into the Kuparuk River Formation in the BP Exploration (Alaska), Inc. hereby applies for an exemption to the provisions of 20 AAC 25.055 and Conservation Order 173 Rule #3 for MP K-30 Well (the well), for which the following is proposed: 1. Surface Location: 3604 NSL 1965 VVEL Sec 03 T12N R11E UM., AK 2. Kuparuk Target Location: 339 NSL 1160 WEL Sec 02 T12N R11E UM., AK 3. Bottom Hole Location: 123 NSL 757 VVEL Sec 02 T12N R11E UM., AK The well MP K-30 is planned as a high angle producer to be completed with an electrical submersile pump. The surface location of MPK-30 located in the NE/4 of Sec 3 which is within ADL lease 375133. The target and bottom hole locations are located in the SE/4 of Sec 2 which is within ADL lease 375132 as indicated in the enclosed exhibits. The proposed target and bottomhoile locations are within the SE/4 of Sec 2 T12N, R11E but are in close proximity to the eastern and southern bounddes of this quater section. The spacing requirements of 20 AAC 25.055 and Conservation Order 173 Rule #3 do not allow without exemption the drilling of a well closer than 500 feet to any quater section line. This request for exemption is being sought to allow for the optimum placement of the well MPK-30 within a fault block of the Kuparuk River formation within the SE/4 of Section 2. The owners and operator of all governmental quarter sections directly and diagonallly offsetting the proposed target and bottom hole location of the well are BP Exploration (Alaska), Inc., and Occidental Petroleum. The plat required by the regulation is attached as Exhibit 1. The verification required by the regulation is attached as Exhibit 2. Copies of the notification to the owners and operators, as well as the required information with respect to the mailing are attached in the package designated as Exhibit 3. As indicated by the information enclosed in Exhibit 1, Exhibit 2, and Exhibit 3 we verify these facts to be true and that the plat portrays the pertinent and required data. We also feel that this adresses the requirements of the provisions in 20 AAC 25.055 and Conservation Order 173 Rule #3. " Thank you for you assistance in this matter. Please direct any qu~st, Eion. Q.s~to, Tom Niswander at 564-5472. Respectfully, Lance Spencer cc BPX OXY ,,, l N COR SEC 3 &2 3,2,10,11" Well K-30 Target co X=590719 Y=6002548 Well K-30 Bottom Hole Location X=591030 Y=6002383 1159 · '-'" 851 N COR SEC 2 & 1 "SEC 2, 1, 11, 12 " 25' MP K-02 Bottomhole + /X'O~ '5'7 MP K-05 -t- Bottomhole MP I(-IS ,.~ '- '.; MP K-17 Target mi Bottomhole / ,_.v~ K. r,,- ! a, _!_ , ~. Do~tomrlole -- -t- ~ Ca,ica, le 1 ascade la :2.. ~Bottor hole B ~ttomhole '--' , MP K-25 .-t- "-~ Well K-30 Bottomhole ~.. Target MP K-38 '~. X=59071 9 Bottomhol~ ~ ...'~. Y=6002541 MP K-37 / Z6,~/. Bottomhole ,~6'b'O,, \© Well K-30 ~ ~D v ,~,~ Bottom Hole Location X=591030 [)'6'o,~' '~..~ arge~ Y=6002383 I ~'¢~O,, M~p K.34 ,z, u 5715 Bottomhole MP K-13 N COR SEC 4 & 3 Target --¢' MP K-13 N COR SEC 3 & 2 N COR SEC 2 & 1 NE SEC 1 Bottomhole MP K-17 I~oltornll(~lo + -t- Bottomhole Cascade 1 MP K-25 Bottomhole MP K-38 ' ~ Bottomhole Wall K-30 77~7~~ Target · o-o~ ~ X=590719 MP K-37 . -u 00', ~~8 Bottomhole ' + d ' "~Well K-30 . ~-- ,, ,, ZSEC 2, 1, 11, 12" "E SEC 1 12" "SEC 4, 3, 9, 10 "SEC 3, 2, 10, 11 Bottom Hole Location ~ ' ' ' ' X=591030~ ' Y=6002383 ~ ~ MP K-34 - Bottomhole ,. ,L.. ¢ dj ' "SEC 9, I0, 16, 15 .... SEC 10, 11, 15, 14 " SEC 11, 12, 14, 13" "E SEC 12, 13" MILNE POINT UNIT T14N-R11E T12N-RllE 0 0.5 1 Mile 0 0.5 1 2 KM UTM6/NAD27 Leases Current to 5/31/95 T13N-R11E bs12661.dgn PRUDHOE BAY AND KUPARUK RIVER UNITS T13N-R11E ~,~ ~-...~ ~p ~- _ _~ ~gA~; ~~ O~ USA '~ ~ ~-, ~ ", .::~ ; ~ w:h'~ '~' .: L. %) ~ ~ ~ ~,~ '-.t~ -. ~ - '~ ~ {~ ~i i ~ ~ ¢~ 1~/'~¢ h :, :' ;" . ..... , -. -. ~4~?~~ ~ ~ ~-~/~ I': '; : ': - :~ ..... ,' ' -- ~ '- - UNIT ' ': ; ~: ;%::: _'-':_2 h'-~- ' ~t h- ~: "V:'->~-<~:'..;-'-' ' ~ .... ARCO.~;~,. - -' ' [~, 6 [~- E~E~ '- - - I -:.;'~ ~",? '.,.__'~_-~_.~:-_--,_.'j~ 53-27:84 ";'"'" :2 -:' ~ ~ ~ ~ ~ ~' L :j ., T11N-R11E 1:63,360 0 0.5 I Mile 0 0.5 1 2 Leases Current to 5/31/95 T12N-R 11E ~-2661 .dgn . 'oK'L ADL-028232/j ~ ~I [ ,,BeUen ^DL-$75133 100% hydrocarbon column at 7110 tvdss OWC: Cl sand ~B7 sand approx. I mile Target Locations for production wells K-C and K-D BSM 10/95 C Prudhoe-01 BP/Oxy ADL #380110 K Pad location ~ 7025-7045 tvdss OWC ~ 7045 tvdss OWC ~ 7110 tvdss OWC ADL I ! ADI #028232 i ADL #02~233 Initial Development Area Cascade K Pad BSM 5/8/96 OCT 09 ~9~ 05:45PM BP EXPLORATIOM BP EXPLORATION (ALASK: PRUDHOE BAY, ALASKA FAX # (907) $64-5193 P.1 TO.' COMPANY: LOCATION' Dianna Fleck AOGCC Anchorage · FAX #: 276-7542 FROM: Kathy Campoamor __. SHARED SERVICES DRILLING LOCATION: ANCHORAGE, ALASKA PHONE #: 564-5122 PAGES TO FOLLOW: 1 COMMENTS: DATE: 10-9-96 Dianna, please see that this is put with MPK-30 (one of the permits I dropped off last night to you). It belongs with attachment. (or page #) #19. This actually shows postmark for the certified mail requirement to Oocidental Petroleum. Any questions, give me a call. Thanks[ IF YOU DO NOT RECEIVE ALL PAGES, OR HAVE ANY PROBLEMS, PLEASE CALL THE FOLLOWING NUMBER: (907) $64-5122 Receipt for Certified Mail (~{ ~",,~ No Itlsurance Cover~g~ Provided Do not use for Ir~t {See Reverse Spe~-i~l TOTAL Po~m~e { POSlmark O~ RECEIVED OCT 1 0 Alaska 0il & (-?as Con& SENDER: · Complete items 1 and/or 2 for.additional services. · Complete items 3, and 4a & b. ® Print your name and address on the reverse of this form so that we can returil/this card to you. · Attach this form to the front of the mailpiece, or on the back if space does not permit. ® Write °'Return Receipt Requested" on the mailpiece below the article numbe~ · The Return Receipt will show to whom the article was delivered and the date delivered. 3. Article Addressed to: 5. Signature (Addressee) 6. Signature (Agent) PS Form 3811, December 1991 I .also wish to receive the following services (for an extra fee): 1. [] Addressee's Address 2. "[] Restricted Delivery Consult postmaster for'fee:- ' . 4a. Article Number ,,. 4b. Service Type .t [] Registered '"' [] Insured' ":" ": " J]~]~[_l Certified []COD:. '~ I. Express Mail :. [] R~turn ReceiPt for ............. Merchandise-.'.:..,' '. 7;'-:Date of Deliver -..- .. !:', :. ':? ::i,',".'."; :" ",::.: i:':"~.:':~::. " :, '-'.' :,".'' i':~':".:': ' ~' ..~ . o '. :'" -- . '. , .: ,~.. _,~-~,'.,.:,,I 8, Addressee's Address (Only if requested ~ :: ~ and fee is paid) ~U.S. GPO: 1993--352-714 DOMESTIC RETURN RECEIPT ~§~ ,'o,en '009~ uzo=~ Sd BP EXPLORATION 900 East Benson Boulevard Anchorage, Alaska 99519-6612 (907)561-5111 October 4, 1996 Occidental Petroleum Ed Behm 6 Desta Drive Suite 6000 Midland, TX RE: Request for Spacing Exemption for MP K-30 to provisions of 20 AAC 25.055 and Conservation Order 173 Rule #3. Dear Mr. Behm Pursuant to the provisions and requirements of 20 AAC 25.050 (b) BP Exploration (Alaska) Inc. hereby gives notice of a request to the Alaska Oil and Gas Conservation Commission for an exemption to the provisions of 20 AAC 25.055(a) 1, 20 AAC 25.055 and Conservation Order 173 Rule #3 for MP K-30 Well (the well). Specifically, the exemption location applied for will be as followed:: 1. Surface Location: 2. Kuparuk Target Location: 3604 NSL 1965 VVEL Sec 03 T12N R11E UM., AK 339 NSL 1160 VVEL Sec 03 T12N R 11E UM., AK 3. Bottom Hole Location: 123 NSL 757 VVEL Sec 02 T12N R11E UM., AK A copy of the request is attached. Very truly yours, enc. RECEIVED EXHIBIT2 VERIFICATION OF APPLICATION FOR SPACING EXCEPTION MILNE POINT K-30 L. SPENCER, Drilling Operations Engineer, BP Exploration (Alaska) Inc., does hereby verify the following: 1. I am acquainted with the application submitted for the drilling of Milne Point K-30 Well. .. 2. I have reviewed the application submitted for the exemption to 20 AAC 25.055, Conservation order 173 Rule #3 and all the facts therein are true. 3. I have reviewed the plat attached as exhibit 1 and it correctly protrays pertinent and required data. DATED at Anchorage, Alaska this 9~ day of ~"~_--~jO~.-/ , 1996. STATE OF ALASKA THIRD JUDICIAL DISTRICT SUSCRIBED AND SWORN TO before me this (..~-~ ~-¢ , 1996. d'-~day of .. NOTARY PUBLIC IN AND FOR ALASKA My commission expires: My Commission Expires March 12, 2000 WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION · .ENGiNEERiNG -' ' G~__~.OI_OGY AP~R DATE INIT CLASS ~,'~~ .;'2'"'4::>.~ .~/ GEOL AREA ~? ,'"'> UNIT# .,,//~/;, ,/~. ON/OFF SHORE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique we~ name and number ................ 4. Well located in a defined pool ................. 5. Well located proper distance from dflg unit boundary .... 6. Well loc~_ t~ proper distance from ol~er we~s ........ 7. Sufficient acreage avaJl~le in drilDng unit. ......... 8. If deviated, is weiibore plat inctuded ............. 9. Operator only affected party .................. 10. Operator has appropriate bond in force ........... 11. Permit can be issued without conserva~on order ..... 12. Permit can be issued without administrative approval . . 13. Can permit be approved before 15-day wail ....... N ' ~" N ~---.~. 14. Conductorstfing provided .................. .~--'N 15. Surface ca~ng protects ail known USDWs ......... ~ N 16. CMT vol adequate to circulate on conductor & surf csg . . . (_Y~I 17. CMT vol adequate to ~-in long s~ng to surf c. sg ....... Y ( 18. CMT will cover ail known produc~ve horizons ........ 19. Casing designs adequate for C, T, B & pe~t. ..... 20. Adequate tankage or reserve pi[. .............. 21. If a re-drill, has a 10..403 for abndnmnt been approved. 22. Adequate wellbore separation proposed. 23. If diverter required, is it adequate .......... 24. Ddlling fluid program schemsfic & equip list adequate .... 25. BOPEs adequate ....................... 26. BOPE press rating adequate; test to ~'C>~ psig. 27. Choke manifold complies w/APl RP-53 (May 84). 28. Work will occur wil~out operation shutdown ......... N 29. Is presence of H2S gas probable N 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on Petentiai overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. Y~N ..... 33. Seabed condition survey (if off-shore) ........... ~ N 34. Contact name/phone for weekly progress reports .... .,~.. Y N ~dxpForatary only] GEOLOGY: RPC~ ENGINEERING: COMMISSION: JDH ~ v- TAB Comments/Instructions: HOW/ID- A.-'~ORMS'che~ rev,uS6 ..... Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. RECEIVED DEC 1 3 1996 * ALASKA COMPUTING CENTER * . * ****************************** . ............................ * * ....... SCHLUMBERGER ....... * . ............................ * COMPANY NAME : B.P. EXPLORATION WELL NAME : MPK-30 FIELD NAME : MILNE POINT BOROUGH · NORTH SLOPE STATE · ALASKA API NUMBER : 50-029-22711-00 REFERENCE NO : 96370 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : B.P. EXPLORATION WELL NAME : MPK-30 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22711-00 REFERENCE NO : 96370 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 11:31 PAGE: **** REEL H~ER **** SERVICE NAIViE : EDIT DATE : 96/12/ 9 ORIGIN : FLIC REEL NAME : 96370 CONTINUATION # : PREVIOUS REEL : COI~4~NT : B.P. EXPLORATION, MILNE POINT MPKK-30, API #50-029-22711-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/12/ 9 ORIGIN : FLIC TAPE NAME : 96370 CONTINUATION # : 1 PREVIOUS TAPE : COI~TENT . B.P. EXPLORATION, MILNE POINT MPKK-30, API #50-029-22711-00 TAPE HEADER MILNE POINT MWDLOGS WELL NA~E: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NOW~ER: LOGGING ENGINEER: OPERATOR WITNESS: SO-RFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL : FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1 ST STRING 2ND STRING MPK-30 500292271100 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES 9-DEC-96 BIT RUN1 96370 BOSSE PYRON BIT RUN2 ........ 96370 BOSSE PYRON BIT RUN 3 3 12N liE 3605 1965 57.50 57.50 28.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 112.0 8.500 9.625 6640.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 11:31 3RD STRING PRODUCTION STRING Well drilled 19-OCT through O1-NOV-96 with CDR/ADN. All data was collected in two bit runs. ADN curve names in LDWG are as follows: ROMB= max. rotational bottom quadrant density, ROBB/ROBU/ROBL/ROBR = bottom, upper, left, and right quadrant density, DRHB/DRHU/DRHL/DRHR= quadrants as above for delta rho, PEB/PEU/PEL/PER = quadrants as above for PEF, I{DIA/VDIA = horizontal and vertical hole diameters. Also, ROBB=RHO1, ROBU=RH02, ROBL=RH03 , ROBR=RH03 . $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .00i SERVICE : FLIC VERSION · O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 66.0 11147.0 BASELINE DEPTH .............. 88888.O 11001.5 10995.5 10989.5 10984.0 10982.0 10964.5 10953.5 10948.5 10941.0 10932.0 10926.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... 88889.0 11002.5 10995.5 10989.5 10983.5 10981.5 10964.0 10953.5 10949.0 10940.5 10931.5 10928.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10919.0 10861.0 10836.0 10800.0 10772.5 10756.5 10740.0 10719.0 10710.0 10702.5 10682.5 10666.0 10656.0 10642.5 10630.5 10621.5 10613.5 10610.0 10602.0 10587.5 10582.5 10576.0 10574.5 10570.0 10559.0 10551.5 10541.0 10531.0 10501.5 10492.5 10467.5 10445.5 10433.5 10426.5 10424.0 10421.5 10418.5 10410.0 10403.0 10398.5 10379.0 10370.0 10359.5 10352.5 10340.0 10331.0 10326.5 10302.0 10291.5 10278.5 10267.5 10254.5 10248.0 10241.5 10233.0 10917.5 10859.5 10835.0 10802.0 10775 5 10758 5 10741 5 10721 0 10710 5 10703 5 10685 0 10666.0 10656.5 10643.0 10630.5 10621.5 10613.5 10612.0 10600.5 10587.0 10582.5 10576.5 10575.0 10571.0 10557.5 10550.0 10539.0 10530.0 10500.5 10490.5 10466.5 10444.0 10432.5 10427.5 10423.5 10422.0 10418.0 10407. 0 10402.0 10396.5 10377.0 10367.5 10358.0 10350.0 10337.0 10330.0 10324.0 10299.5 10289.5 10276.0 10265.0 10251. 0 10245.5 10239.0 10227.0 9-DEC-1996 11:31 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 10207 0 10192 5 10166 5 10151 5 10139 0 10121 5 10113 5 10103.5 10098.0 10055.0 10046.0 10039.5 10031.5 10023.5 10002.5 9969.0 9955.0 9941.0 9933.0 9912.0 9892.5 9881.5 9859.5 9846.5 9826.0 9819.0 9810.0 9797.0 9787.5 9781.5 9776.0 9730 0 9719 0 9708 0 9695 5 9685 0 9678 0 9650.5 9591.0 9578.5 9544.0 9517.0 9497.5 9484.0 9480.0 9471.0 9448.5 9424.0 9405.5 9403.0 9398.0 9356.0 9337.0 9328.5 9320.0 10204.0 10191.5 10165.5 10148.5 10135.0 10119.0 10111.0 10100.5 10094.0 10051.5 10043.0 10037.0 10027.5 10022.0 9999 0 9965 5 9952 0 9938 0 9930 0 9909 5 9887 0 9877 5 9854.5 9837.5 9822.0 9815.0 9807.5 9794.5 9783.5 9779.0 9773.0 9727.5 9716.5 9704.5 9694.0 9683.0 9675.5 9647.5 9588.0 9576.5 9541.5 9514.5 9494.5 9481.0 9477.0 9468.5 9445.5 9420.0 9402.0 9398.0 9394.0 9354.5 9334.5 9325.5 9316.0 9-DEC-1996 11:31 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9309 5 9300 0 9247 0 9212 5 9183 0 9170 0 9133 5 9114.5 9070.0 9007.5 8975.0 8960.5 8951.5 8940.0 893 O. 5 8894.5 8846.5 8824.5 8810.5 8800.5 8750.0 8722.0 8662.0 8405.5 8377.0 8323.0 8310.5 8273.5 8166.0 8117.0 8084.5 8069.0 7998.5 7985.0 7948.0 7906.0 7897.5 7868.0 7824.0 7767.5 7732.5 7714.5 7692.5 7676.0 7664.0 7650 0 7643 0 7590 0 7531 0 7480 5 7456 5 7447 5 7371,5 7349 5 7198.0 9307.0 9296.5 9242.5 9208.5 9178.0 9165.0 9129.0 9108.5 9064.0 9002.5 8970.0 8956.0 8946.5 8936.5 8929.0 8897.0 8845.5 8820.5 8805.5 8799.0 8748.5 8721.0 8656.5 8399.5 8372.0 8320.0 8307.5 8270.5 8159.0 8109.0 8077.0 8060.0 7990 5 7976 5 7942 5 7904 5 7895 5 7864 5 7819.0 7762.0 7727.0 7709.5 7686.0 7669.0 7658.5 7644.0 7638.0 7582.0 752 6.0 7473.0 7447.0 7435.0 73 63.5 7349.0 7190.0 9-DEC~1996 11:31 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 11:31 PAGE: 7154 5 7130 5 7085 0 7064 5 7053 5 7001 0 6994 0 6974 5 6964 0 6953 0 6936.5 6918.5 6895.0 6869.5 6845.5 6792.5 6763.5 6708.5 6672.5 6666.5 6662.0 6637.5 112.0 $ ~iERGED DATA SOURCE LDWG TOOL CODE .............. $ REMARKS: 7145.0 7124.0 7078.0 7056.0 7045.5 6993.0 6985.0 6963.5 6955.5 6943.0 6925.0 6908.0 6886.5 6862.0 6837.5 6786.0 6756.5 6702.0 6668.0 6660.5 6655.0 6630.5 112.0 BIT RUN NO. MERGE TOP MERGE BASE 1 66.0 6675.0 2 6675.0 11147.0 The depth adjustments shown above reflect the MWD GR to the PDC GR logged by SWS. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 11:31 PAGE: TYPE REPR CODE VALUE 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 039014 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 039014 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0H~039014 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD 0H~I039014 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OHMM039014 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~fl~039014 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 039014 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 039014 O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 039014 O0 000 O0 0 1 1 1 4 68 0000000000 RHO1 MWD G/C3 039014 O0 000 O0 0 1 1 1 4 68 0000000000 RH02 MWD G/C3 039014 O0 000 O0 0 1 1 1 4 68 0000000000 RH03 MWD G/C3 039014 O0 000 O0 0 1 1 1 4 68 0000000000 RH04 MWD G/C3 039014 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 039014 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 039014 O0 000 O0 0 1 1 1 4 68 0000000000 DCALMWD IN 039014 O0 000 O0 0 1 1 1 4 68 0000000000 CALAMWD IN 039014 O0 000 O0 0 1 1 1 4 68 0000000000 CALS MWD IN 039014 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 039014 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH PDC GAPI 039014 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11147.000 FET.MWD -999.250 RA.MWD -999.250 RP.MWD VRA.MWD -999.250 VRP.MWD -999.250 ROP.MWD 233.686 GR.MWD RHOB.MWD -999.250 RHO!.MWD -999.250 RHO2.MWD -999.250 RHO3.MWD RHO4.MWD -999.250 DRHO.MWD -999.250 PEF.MWD -999.250 DCAL.MWD CALA.MWD -999.250 CALS.MWD -999.250 NPHI.MWD -999.250 GRCH. PDC -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 11:31 PAGE: DEPT. 11000. 000 FET. MWD VRA . MWD 5. 302 VRP. MWD RHOB.MWD 2. 454 RHO1 .MWD RH04 . MWD 2. 471 DRHO . MWD CALA . MWD 8. 668 CAL S . MWD DEPT. 10000. 000 FET.MWD VRA . MWD 2. 605 VRP. MWD RHOB.MWD 2. 433 RHO1 .MWD RH04 . MWD 2. 446 DRHO . MWD CALA.MWD 8. 446 CALS.MWD DEPT. 9000. 000 FET. MWD VRA . MWD 3.104 VR P . MWD RHOB . MWD 2.503 RHO1. MWD RH04 .MWD 2. 493 DRHO. MWD CALA . MWD 8. 677 CAL S . MWD DEPT. 8000. 000 FET.MWD VRA . MWD 2. 461 VRP. MWD RHOB.MWD 2. 427 RHO1 .MWD RH04 .MWD 2. 445 DRHO.MWD CALA . MWD 8. 935 CALS . MWD DEPT. 7000. 000 FET.MWD VRA . MWD 3. 722 VRP. MWD RHOB. MWD 2.372 RHO1. MWD RHO4 .MWD 2.284 DRHO.MWD CALA . MWD 9. 025 CAL S . MWD DEPT. 6000. 000 FET. MWD VRA . MWD 1 . 540 VR P . MWD RHOB.MWD -999. 250 RHO1 .MWD RH04 .MWD -999. 250 DRHO.MWD CALA . MWD -999. 250 CAL S . MWD DEPT. 5000. 000 FET.MWD ~. MWD 3. 751 VRP. MWD RHOB.MWD -999. 250 RHO1 .MWD RH04 .MWD -999. 250 DRHO.MWD CALA . MWD -999. 250 CAL S . MWD DEPT. 4000. 000 FET.MWD VRA . MWD 7. 192 VRP . MWD RHOB.MWD -999.250 RHO1.MWD RH04 .MWD -999. 250 DRHO.MWD CALA . MWD - 999.250 CAL S . MWD DEPT. 3000. 000 FET.MWD VRA . MWD 11. 975 VR P . MWD RHOB.MWD -999. 250 RHO1 .MWD RH04. MWD -999. 250 DRHO. MWD CALA.MWD -999.250 CALS.MWD 0.300 RA . MWD 5. 645 ROP. MWD 2.464 RH02. MWD O . O10 PEF. MWD 8. 668 NPHI.MWD O. 728 RA.MWD 3.297 ROP.MWD 2. 453 RH02. MWD O . 019 PEF. MWD 8. 446 NPHI.MWD 5.537 200. 221 2. 418 2. 708 31. 700 2. 604 219. 494 2. 420 4. 327 39. 600 0.209 RA.MWD 3.188 3.429 ROP.MWD 138.229 2.518 RHO2.MWD 2.485 0.055 PEF.MWD 3.497 8.735 NPHI.MWD 37.200 0.444 RA.M~D 2.468 2.567 ROP.MWD 650.159 2.430 RHO2.MWD 2.427 0.024 PEF.MWD 2.767 8.468 NPHI.MWD 34.700 0.167 RA . MWD 3. 602 ROP. MWD 2. 323 RH02 . MWD O. 043 PEF.MWD 9.195 NPHI.MWD 0.306 RA.MWD 1.564 ROP.MWD -999.250 RHO2.MWD -999.250 PEF.MWD -999.250 NPHI.MWD 3.707 272.713 2.252 2.446 33.200 1.327 360.545 -999.250 -999.250 -999.250 4.013 RA.MWD 3.714 3.716 ROP.MWD 312.905 -999.250 RHO2.MWD -999.250 -999.250 PEF.MWD -999.250 -999.250 NPHI.MWD -999.250 0.594 RA.MWD 7.502 ROP.MWD -999.250 RHO2.MWD -999.250 PEF.MWD -999.250 NPHI.MWD 0.713 RA.MWD 12.059 ROP.MWD -999.250 RHO2.MWD -999.250 PEF.MWD -999.250 NPHI.MWD 7.002 122.441 -999.250 -999.250 -999.250 12.285 225.230 -999.250 -999.250 -999.250 RP.MWD GR. MWD RH03. MWD DCAL . MWD GRCH. PDC RP.MWD GR. MWD RH03. MWD DCAL . MWD GRCH. PDC RP.MWD GR. MWD RH03. MWD DCAL . MWD GRCH. PDC RP.MWD GR.MWD RHO3.MWD DCAL.MWD GRCH. PDC RP.MWD GR. MWD R H 0 3 . MWD DCAL . MWD GRCH. PDC RP.MWD GR. MWD RH03 . MWD DCAL . MWD GRCH. PDC RP.MWD GR. MWD RH03. MWD DCAL . MWD GRCH. PDC RP.MWD GR. MWD RH0 3 . MWD DCAL . MWD GRCH. PDC RP.MWD GR. MWD R H 0 3 . MWD DCAL . MWD GRCH. PDC 5.781 72.404 2.458 0.215 42.357 3.330 154.312 2.406 0.253 109.552 3.423 90.507 2.422 0.322 52.641 2.575 73.575 2.455 0.201 52.351 3.619 64.886 2.291 0.754 55.638 1.520 72.775 -999.250 -999.250 -999.250 3.583 70.676 -999.250 -999.250 -999.250 7.530 116.230 -999.250 -999.250 -999.250 12.160 87.138 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 11:31 PAGE: DEPT. 2000.000 FET.MWD VRA.MWD 1.597 VRP.MWD RHOB.MWD -999.250 RHO1.MWD RHO4.MWD -999.250 DRHO.MWD CALA.MWD -999.250 CALS.~rD DEPT. 1000.000 FET.MWD VRA.MWD 3.846 VRP.I~WD RHOB.PFWD -999.250 RHO1.MWD RHO4.MWD -999.250 DRHO.MWD CALA.MWD -999.250 CALS.MWD DEPT. 66.000 FET.MWD VRA.MWD -999.250 VRP.MWD RHOB.MWD -999.250 RHO1.MWD RHO4.MWD -999.250 DRHO.MWD CAI~A.IffWD -999.250 CALS.I~WD 4. 022 RA . MWD 1. 825 ROP.MWD -999. 250 RH02. MWD - 999.250 PEF. ~ -999. 250 NPHI. MWD 0.423 RA.MWD 3.942 ROP.MWD -999.250 RHO2.MWD -999.250 PEF.MWD -999.250 NPHI.MWD -999.250 RA.MWD -999.250 ROP.MWD -999.250 RHO2.M~D -999.250 PEF.MWD -999.250 NPHI.MWD 2.025 RP.MWD 243.226 GR.MWD -999.250 RHO3.MWD -999.250 DCAL.MWD -999.250 GRCH. PDC 3.908 RP.~4WI) 249.166 GR.MWD -999.250 RHO3.MWD -999.250 DCAL.MWD -999.250 GRCH. PDC -999.250 RP.MWD -999.250 GR.MWD -999.250 RHO3.MWD -999.250 DCAL.MWD -999.250 GRCH. PDC 2.457 98.522 -999.250 -999.250 -999.250 3.875 60.312 -999.250 -999.250 -999.250 -999.250 22.775 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION · O01CO1 DATE ' 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE ~BER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUI~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 11:31 PAGE: 10 MWD 14.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : O1 -NOV- 96 6675.0 IDEAL 4.0 MEMORY 11145.0 66.0 11145.0 50 0.0 59.3 TOOL NUMBER CDR8 044 12.250 112.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10. 20 MUD VISCOSITY (S) : 42.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~ff4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2.100 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 20000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): DRILLED INTERVAL 112' - 6675' CDR ONLY RES TO BIT: 53.10'; GR TO BIT: 63.68' ************ RUN2 ************* DRILLED INTERVAL 6675'- 11145' CDR/ADN RES TO BIT: 54.35'; GR TO BIT: 64.77' REMARKS: 75.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 11:31 PAGE: 11 NEUT TO BIT: 112.15'; DENS TO BIT: 108.02' DATA FROM DOWNHOLE MEMORY, V4.1C SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 039014 O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 0tk4~039014 O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW1 0P~4~039014 O0 000 O0 0 2 1 1 4 68 0000000000 ATVR LW1 OH~M039014 O0 000 O0 0 2 1 1 4 68 0000000000 PSVR LW1 OPff4M039014 O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 OHNIM039014 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW1 F/HR 039014 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 039014 O0 000 O0 0 2 1 1 4 68 0000000000 TABR LW1 039014 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 11:31 PAGE: 12 DEPT. 6675. 000 ATR. LW1 PSVR. LW1 -999.250 DER. LW1 TABR. LW1 -999. 250 DEPT. 6000. 000 ATR. LW1 PSVR . LW1 1 . 397 DER. LW1 TABR . LWl O . 3 O1 DEPT. 5000. 000 ATR. LW1 PSVR. LW1 3. 423 DER. LW1 TABR. LW! 3. 986 DEPT. 4000. 000 ATR. LW1 PSVR . LW1 7. 730 DER . LW1 TABR. LW1 O. 492 DEPT. 3000. 000 ATR. LW1 PSVR. LW1 12.840 DER. LW1 TABR . LW1 O . 710 DEPT. 2000. 000 ATR. LW1 PSVR . LW1 3. 506 DER. LW1 TABR. LW1 O . 217 DEPT. 1000.000 ATR.LW1 PSVR.LW1 3.504 DER.LW1 TABR.LW1 0.422 DEPT. 14. 500 ATR. LW1 PSVR . LW1 -999.250 DER. LW1 TABR. LW1 -999. 250 -999. 250 PSR. LW1 -999. 250 ROPE. LW1 1.387 PSR. LWI 1. 396 ROPE. LW1 3. 563 PSR. LW1 3. 477 ROPE.LW1 7. 228 PSR. LW1 7. 475 ROPE. LW1 13. 426 PSR.LW1 13. 039 ROPE. LW1 1. 573 PSR. LW1 1. 975 ROPE. LW1 3. 911 PSR. LW1 3. 808 ROPE. LW1 -999. 250 PSR. LW1 -999. 250 ROPE. LW1 -999.250 ATVR.LW1 -999.250 12. 885 GR.LW1 -999.250 1.403 ATVR. LW1 315. 752 GR. LW1 3. 435 A TVR . LW1 173 . 070 GR. LW1 7. 578 ATVR. LW1 131. 387 GR. LW1 12. 933 ATVR. LW1 230. 761 GR. LW1 2.719 ATVR. LW1 199. 995 GR. LW1 3. 759 ATVR. LW1 233. 760 GR. LW1 -999.250 ATVR.LW1 - 999.250 GR. LW1 1.369 74.150 3.454 91.322 7.345 108.714 12.721 84.635 2.898 93.918 3. 414 58. 282 -999.250 22.860 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 11:31 PAGE: 13 **** FILE H~ER **** FILE NAME : EDIT .003 SERVICE .FLIC VERSION ·O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE IgZTMBER 3 RAW ~fWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 6539.0 11147.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR ADN NEUT./DENS. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: O1 -NOV-96 IDEAL 4.0 MEMORY 11145.0 66.0 11145.0 60 59.0 59.3 TOOL NUMBER ........... RGS 022 ADN 045 12.250 112.0 LSND 10.20 42.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 11:31 PAGE: 14 MUD CHLORIDES (PPM) : 800 FLUID LOSS (C3): RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2.100 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: ************ RUN1 ************* DRILLED INTERVAL 112' - 6675' CDR ONLY RES TO BIT: 53.10'; GR TO BIT: 63.68' ************ RUN2 ************* DRILLED INTERVAL 6675'- ll145'CDR/ADN RES TO BIT: 54.35'; GR TO BIT: 64.77' NEUT TO BIT: 112.15'; DENS TO BIT: 108.02' DATA FROM DOWNHOLE MEMORY, V4.1C SOF~gARE $ LIS FORMAT DATA 75.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 112 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 11:31 PAGE: 15 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 039014 O0 000 O0 0 3 1 1 4 68 0000000000 ATR LW2 0tflv2~039014 O0 000 O0 0 3 1 1 4 68 0000000000 PSR LW2 OPff4M039014 O0 000 O0 0 3 1 1 4 68 0000000000 ATVR LW2 OH~ff4039014 O0 000 O0 0 3 1 1 4 68 0000000000 PSVR LW2 0H~039014 O0 000 O0 0 3 1 1 4 68 0000000000 DER LW2 OPff4M039014 O0 000 O0 0 3 1 1 4 68 0000000000 ROPE LW2 F/HR 039014 O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI 039014 O0 000 O0 0 3 1 1 4 68 0000000000 TABR LW2 039014 O0 000 O0 0 3 1 1 4 68 0000000000 ROMB LW2 G/C3 039014 O0 000 O0 0 3 1 1 4 68 0000000000 ROBB LW2 G/C3 039014 O0 000 O0 0 3 1 1 4 68 0000000000 ROBU LW2 G/C3 039014 O0 000 O0 0 3 1 1 4 68 0000000000 ROBL LW2 G/C3 039014 O0 000 O0 0 3 1 1 4 68 0000000000 ROBR LW2 G/C3 039014 O0 000 O0 0 3 1 1 4 68 0000000000 DRHB LW2 G/C3 039014 O0 000 O0 0 3 1 1 4 68 0000000000 DRHU LW2 G/C3 039014 O0 000 O0 0 3 1 1 4 68 0000000000 DRHL LW2 G/C3 039014 O0 000 O0 0 3 1 I 4 68 0000000000 DRHR LW2 G/C3 039014 O0 000 O0 0 3 1 1 4 68 0000000000 PEB LW2 039014 O0 000 O0 0 3 1 1 4 68 0000000000 PEU LW2 039014 O0 000 O0 0 3 1 1 4 68 0000000000 PEL LW2 039014 O0 000 O0 0 3 1 1 4 68 0000000000 PER LW2 039014 O0 000 O0 0 3 1 1 4 68 0000000000 CALNLW2 IN 039014 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH LW2 PU 039014 O0 000 O0 0 3 1 1 4 68 0000000000 DCALLW2 IN 039014 O0 000 O0 0 3 1 1 4 68 0000000000 HDIA LW2 IN 039014 O0 000 O0 0 3 1 1 4 68 0000000000 VDIA LW2 IN 039014 O0 000 O0 0 3 1 1 4 68 0000000000 RPM LW2 RPM 039014 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11146.500 ATR.LW2 -999.250 PSR.LW2 -999.250 ATVR.LW2 PSVR.LW2 -999.250 DER.LW2 -999.250 ROPE.LW2 233. 686 GR.LW2 TABR.LW2 -999.250 ROMB.LW2 -999.250 ROBB.LW2 -999.250 ROBU. LW2 ROBL.LW2 -999.250 ROBR.LW2 -999.250 DRHB.LW2 -999.250 DRHU. LW2 DRHL.LW2 -999.250 DRHR.LW2 -999.250 PEB.LW2 -999.250 PEU. LW2 PEL. LW2 -999. 250 PER. LW2 -999. 250 CALN. LW2 -999. 250 TNPH. LW2 DCAL.LW2 -999.250 t~DIA.LW2 -999.250 VDIA.LW2 -999.250 RPM. LW2 DEPT. 11000. 000 ATR. LW2 5. 703 PSR. LW2 5. 729 ATVR. LW2 PSVR. LW2 5. 643 DER. LW2 5. 721 ROPE. LW2 200. 022 GR. LW2 TABR. LW2 O. 299 ROMB. LW2 2. 484 ROBB. LW2 2. 481 ROBU. LW2 ROBL.LW2 2. 455 ROBR.LW2 2. 486 DRHB.LW2 O. 016 DRHU. LW2 DRHL.LW2 O. 049 DRHR.LW2 O. 047 PEB.LW2 2. 795 PEU. LW2 PEL.LW2 2. 847 PER.LW2 2. 988 CALN. LW2 8. 500 TNPH.LW2 DCAL. LW2 O. 245 HDIA. LW2 8. 849 VDIA. LW2 8. 668 RPM. LW2 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5.304 75.980 2.407 0.058 3.134 32.100 49.480 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 11:31 PAGE: 16 DEPT. 10000. 000 ATR. LW2 PSVR . LW2 3.203 DER. LW2 TABR. LW2 O. 710 ROMB. LW2 ROBL. LW2 2.477 ROBR. LW2 DRHL . LW2 O . 045 DRHR . LW2 PEL . LW2 3. 605 PER. LW2 DCAL. LW2 O. 296 HDIA. LW2 DEPT. 9000. 000 ATR. LW2 PSVR . LW2 3. 583 DER. LW2 TABR.LW2 O. 406 ROM~.LW2 ROBL. LW2 2. 451 ROBR. LW2 DRHL . LW2 O . 042 DRHR. LW2 PEL . LW2 2. 875 PER. LW2 DCAL. LW2 0.477 HDIA. LW2 DEPT. 8000. 000 ATR. LW2 PSVR. LW2 2. 692 DER. LW2 TABR . LW2 O . 428 ROMB . LW2 ROBL. LW2 2.466 ROBR. LW2 DRHL . LW2 O . 077 DRHR . LW2 PEL . LW2 3 . 034 PER . LW2 DCAL. LW2 0 . 125 HDIA. LW2 DEPT. PSVR. LW2 TABR . LW2 ROBL. LW2 DRHL. LW2 PEL . LW2 DCAL. LW2 7000. 000 3 214 0 429 2 354 0 091 3 205 0 593 A TR . LW2 DER. LW2 ROMB. LW2 ROBR . LW2 D RHR . L W2 PER. LW2 HD IA . LW2 DEPT. 6539. 000 ATR. LW2 PSVR . LW2 - 999.250 DER. LW2 TABR. LW2 -999. 250 ROMB. LW2 ROBL. LW2 -999. 250 ROBR. LW2 DRHL. LW2 -999. 250 DRHR. LW2 PEL. LW2 - 999. 250 PER. LW2 DCAL. LW2 -999. 250 HDIA. LW2 2. 474 PSR . LW2 2. 865 ROPE. LW2 2. 480 ROBB. LW2 2. 467 DRHB.LW2 O. 043 PEB.LW2 3 . 990 CALN. LW2 8. 424 VDIA. LW2 3.188 PSR.LW2 3. 440 ROPE. LW2 2. 501 ROBB. LW2 2. 472 DRHB.LW2 0.112 PEB.LW2 3.040 CALN. LW2 8. 492 VDIA. LW2 2. 509 PSR. LW2 2. 632 ROPE. LW2 2. 379 ROBB. LW2 2. 448 DRHB.LW2 0. 055 PEB. LW2 3.169 CALN. LW2 8. 423 VDIA. LW2 2. 883 PSR. LW2 3. 083 ROPE. LW2 2. 385 ROBB. LW2 2. 403 DRHB.LW2 O . 108 PEB . LW2 3. 442 CALN. LW2 9.185 VDIA. LW2 -999. 250 PSR. LW2 -999. 250 ROPE. LW2 -999. 250 ROBB. LW2 - 999.250 DRHB. LW2 -999. 250 PEB. LW2 -999. 250 CALN. LW2 - 999. 250 VDIA. LW2 3.242 222. 206 2.460 O. 013 3. 715 8.500 8. 424 3. 611 144. 000 2. 472 O. 009 3. 406 8.500 8. 425 2. 716 646. 112 2. 426 O. 047 3.356 8.500 8. 953 3.219 273. 253 2. 363 O. 028 2. 925 8.500 9. 402 -999.250 -999.250 -999.250 -999.250 -999.250 8.500 -999.250 A TVR . LW2 GR. LW2 ROBU. LW2 DRHU. LW2 PEU. LW2 TNPH. LW2 RPM. LW2 A TVR . L W2 GR. LW2 ROBU. LW2 DRHU. LW2 PEU. LW2 TNPH. LW2 RPM. LW2 ATVR. LW2 GR. LW2 ROBU. LW2 DRHU. LW2 PEU. LW2 TNPH. LW2 RPM. LW2 ATVR. LW2 GR. LW2 ROBU. LW2 DRHU. LW2 PEU. LW2 TNPH. LW2 RPM. LW2 A TVR. LW2 GR. LW2 ROBU. LW2 DRHU. LW2 PEU. LW2 TNPH. LW2 RPM. LW2 2.541 139.891 2.457 0.093 5.077 45.400 52.838 3.202 97.770 2.412 0.111 2.983 37.500 55.217 2.534 77.959 2.425 0.083 3.221 33.200 54.404 3.320 62.747 2.315 0.152 3.254 37.200 54.717 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS~Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 11:31 PAGE: 17 **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 96/12/ 9 ORIGIN : FLIC TAPE NAME : 96370 CONTINUATION # : 1 PREVIOUS TAPE : CO~2~ENT : B.P. EXPLORATION, MILNE POINT MPKK-30, API #50-029-22711-00 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 96/12/ 9 ORIGIN : FLIC REEL NAME : 96370 CONTINUATION # : PREVIOUS REEL : CO~4ENT . B.P. EXPLORATION, MILNE POINT MPKK-30, API #50-029-22711-00 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP Swap Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,145 feet N/A feet true vertical 7,306 feet N/A feet Effective Depth measured 11,041 feet N/A feet true vertical 7,257 feet N/A feet 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 R2 10,427' 6,932' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: 323-285 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 88 Gas-Mcf MD 112' 280 Size 112' 4,908' 2613 3507 0 00 207 measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-168 50-029-22711-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0375132 & ADL0375133 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT K-30 Plugs Junk measured LengthCasing Conductor 11,122' 6,652'Surface Intermediate 20" 9-5/8" 7" 112' 6,652'6,870psi 7,240psi11,122' 7,295' Burst N/A Collapse N/A 4,760psi 5,410psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 7:57 am, Aug 17, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.08.17 07:34:10 - 08'00' Taylor Wellman (2143) RBDMS JSB 081723 WCB 4-8-2024 DSR-8/18/23 _____________________________________________________________________________________ Revised By: TDF 8/16/2023 SCHEMATIC Milne Point Unit Well: MPU K-30 Last Completed: 7/15/2023 PTD: 196-168 TD =11,145’ (MD) / TD = 7,306’(TVD) 20” DF Elev.: 57.5’/ GL Elev.: 28’ (Nabors 22E) DF to 7” Casing Hanger = 28.5 7” 13 9-5/8” Howco ES Cementer 9-5/8” PBTD =11,041’(MD) / PBTD= 7,257’(TVD) 5, 6 & 7 8&9 12 1 2 3 & 4 10 & 11 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40E / N/A N/A Surface 112' 0.355 9-5/8" Surface 47 / L-80 / NSCC. 8.679 Surface 4,544’ 0.0732 9-5/8" Surface 47 / L-80 / Btrc. 8.679 4,544’ 4,796’ 0.0732 9-5/8" Surface 47 / P-110 / Btrc. 8.679 4,796’ 6,652’ 0.0732 7" Production 26 / L-80 / Btrc 6.276 Surface 11,122’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE R2 2.441 Surf 10,427’ 0.00579 JEWELRY DETAIL No Top (MD) Item 1 137’ GLM #2: 2-7/8” x 1” Side Pocket, w/ DSOV & BK Latch 2 10,166’ GLM #1: 2-7/8” x 1” Side Pocket, w/Dummy & BK Latch 3 10,255’ XN-Nipple - Min ID 2.205 NO-GO 4 10,307’ VIGILANT PORTED PRESSURE SUB: HEAD 2-7/8'' 5 10,308’ Discharge Head: Bolt-on 2.87X 8RND EUE400X, 416SS 6 10,309’ Pump #3: PMP 400, SF2250, 124S, INC,15,1:1AR, SHB, TS3 7 10,331’ Pump #2: PMP 400, SF2250, 124S, INC,15,1:1AR, SHB, TS3 8 10,352’ Pump #1: PMP 400, SF2250, 124S, INC,15,1:1AR, SHB, TS3 9 10,374’ Gas Separator: GS,400,TDM,H2X,SS, INC,D15 10 10,379’ Upper Tandem Seal: 400 SERIES, BPBSL, INCONEL SHAFT, SLUB, HD 11 10,388’ Lower Tandem Seal: 400 SERIES, BPBSL, INCONEL SHAFT, SLUB, HD 12 10,396’ Motor: 456 series FMS2 240 HP /3,040V /56A, 16 13 10,422’ Motor Gauge and Centralizer – Bottom @ 10,427’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C 10,588’ 10,658’ 7,024’ 7,063’ 70 11/26/2015 Open Kup. B7 10,704’ 10,748’ 7,088’ 7,111’ 44 11/25/1996 Open Ref Log: 11/25/1996 GR/ CCL – 4.5”/ 5 SPF OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I in 24” Hole 9-5/8" 1,500 sx Trinity Lite Wate, 750 sx PF “E”, in 12-1/4” Hole 7” 245 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = 57 to 62 deg. f/ 3,650’ to 11,041 Max Hole Angle through perforations = 58 deg. TREE & WELLHEAD Tree 5M CIM 3-1/18” Wellhead 11” x 11” 5M FMC Gen 6, w/ 4-1/16” FMC Tbg. Hngr., L.H.Acme thread 4”CIW H BPV profile GENERAL WELL INFO API: 50-029-22711-00-00 Orig. Completion by Nabors 4-ES - 11/27/1996 RWO Screens added / Pig Tail Pull & Land – 6/15/1998 RWO w/ Nabors 4-ES – 4/5/2002 & 5/5/2004 ESP RWO w/ Nabors 4-ES – 10/6/2007 ESP RWO & Replace Screens w/ Nabors 3S – 8/3/2008 ESP RWO & Replace Screens w/ Nabors 4-ES – 8/15/2010 ESP RWO w/ Doyon 16 – 8/5/2011 & 1/13/2014 TTC/ ESP Change-out w/ Nordic #3 – 12/16/2015 ESP Swap w/ ASR#1 – 5/3/2016 ESP Swap w/ ASR#1 – 7/15/2023 Well Name Rig API Number Well Permit Number Start Date End Date MP K-30 ASR #1 50-029-22711-00-00 196-168 7/10/2023 7/16/2023 7/7/2023 - Friday No operations to report. 7/5/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 7/6/2023 - Thursday No operations to report. Continue POOH w/ 2-7/8" ESP Completion from 3,136' to Discharge Head while pumping double displacement. L/D ESP Pumps: Top Pump seized, Middle Pump free, Bottom Pump seized, all seals were ok, tested good electrically - Full of Scale / Sand. RECOVERED: 325 CC Clamps, 3 Splice Clamps, 1 Half Clamp & 7 Pump Clamps. (Drill) Fire int the Pits - 2min 45sec. Clean work areas. Clear Pipe Racks. Load BHA and Work String. Tally Pipe. Prepare Handling equipment for Scraper Assy. M/U Bit & Scraper BHA (OAL=210.70'): 6-1/8" Junk Mill (6.125" OD), 7" Scraper (5.375" OD), Bit Sub (4.250" OD), 4-1/4" Bumper Sub, 4- 1/4" Oil Jars (6ea) & 4-1/4" Drill Collars. RIH w/ Bit/Scraper to 10,298' MD PUW=99K, SOW=45K. Fluid losses for Tour: 44 BBLS. EOT PVT: 202 BBLS. Drill Tabletop - Kick While Tripping. Continue RIH to 10,498' MD. PUW=100K, SOW=45K Screw in w/ Quill, hook up Kelly Hose. Check pump line up. Begin pumping down Work String while monitoring for returns. Work up to 3bpm @ 140psi. After 37BBLS away, catch pressure and increase pressure. Final pump pressure 400psi @ 3bpm. Pump 91BBL total (Work String Vol.) Shut down pump and break Kelly. Well on Vac. POOH from 10,498'. PUW=97K to 8,416'. Pump double displacement while POOH. POOH from 8,300' MD to 5,970' MD. No operations to report. 7/8/2023 - Saturday Begin BOP Pressure tests. Witness waived by AOGCC rep. Austin McLeod. Move in equipment and maintenance while P/T. Continue testing BOPs and annular to 250 Low/ 2,500 High, lay out containment for ESP spooling. BOP Pressure testing complete, Blow down stack. Shut down and check fluids. Hang ESP Sheave and hook up air spooler. Wellhead crew pull CTS Plug and BPV. TBG on a slight vac. M/U Landing joint w/ Kelly hose attached, BOLDS. Pull Hanger off seat at 80K Up PUW=90K. Break out and LD Hanger. Route lines through Sheave. POOH w/ 2-7/8" EUE ESP completion. From 126' to 1,635' Pipe had heavy Scale. Cont. POOH, very light to no scale from 1,635' to 3,074'. Recovered 100 OTC Clamps, 1 Splice Clamp. Cont. POOH from 3,074' to 5,100'. 7/11/2023 - Tuesday 7/9/2023 - Sunday No operations to report. 7/10/2023 - Monday BOLDS. Pull Hanger off seat at 80K Up PUW=90K. Break out and LD Hanger. Route lines through Sheave. POOH w/ 2-7/8" EUE ESP completion. From 126' to 1,635' Pipe had heavy Scale. Cont. POOH, very light to no scale from 1,635' to 3,074'. Recovered 100 OTC Clamps, 1 Splice Clamp. Cont. POOH from 3,074' to 5,100'. Continue POOH w/ 2-7/8" ESP Completion from 3,136' to Discharge Head while pumping double displacement. L/D ESP Well Name Rig API Number Well Permit Number Start Date End Date MP K-30 ASR #1 50-029-22711-00-00 196-168 7/10/2023 7/16/2023 7/14/2023 - Friday RIH w/ CCL, Firing Head, 40' x 6spf Guns w/ Bullnose to 10,677'. Multiple attempts made to get past 10,677' ELMD. Discussions with engineer and geologist, decision was made to POOH and run ESP. Hold PJSM with E-line crew and rig crew for POOH, lay down guns and rig down E-Line. POOH w/ e-line guns. Lay down guns, rig down E-line. N/D shooting flange. N/U flow spool and bird bath. Crew held fire drill with AAR. Pull test hanger. clear guns from pipe shed. start loading pipe shed and catwalk with jewelry and ESP equipment. Shut down operations for Code 99 RED on L-pad. crew clean and organize floor and location. Code 99 red all clear. load pipe shed with remaining ESP equipment. Run motor lead and cap line through sheave on ground. Hang ESP sheave. Hold pre-job w/ crew and Summit reps for picking up ESP equipment. Start P/U M/U and service ESP equipment as per Summit rep. Remove and replace bolts on elevators using safety wire. Change out slips. RIH w/ 2-7/8" Summit ESP Completion from surface to 1,454' MD testing every 1000'. Clamped every connection for the first 10JTS, top of even numbered Joints after. Clamp Count in hole: 3 Motor Clamps, 2 Seal Clamps, 6 Pump Clamps & 1 Splice Clamp. 30 Cross Coupling. Crew change. Shut down and check fluids. Continue RIH w/ 2-7/8" ESP Completion from 1,454' to 2,010' MD testing every 1000'. Continue RIH w/ 2-7/8" ESP Completion from 2,010' to 2,990' MD testing every 1000'. Continue RIH w/ 2-7/8" ESP Completion from 2,990' to 3,900' MD testing every 1000' 7/12/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continue POOH w/ Bit and Scraper from 5,970' to 2,150'. Having issues with the Skate/Catwalk. POOH w/ bit and scraper F/ 2,150' T/ 210'. Swap handling equipment. lay down BHA. 6 collars, jars, bumper sub, scraper, and mill. Swap handling equipment. Pull BHA out of pipe shed. Load pipe shed and tally joints. Load test packer into pipe shed. Replace broken parts on Pipe Skate. Replace broken parts on Pipe Skate. P/U and M/U 7" Yellow Jacket Test Packer. RIH w/ 7" Test Packer on 3-1/2" Work String to 2,790' MD. Continue RIH w/ 7" Test Packer on 3-1/2" Work String from 2,790' to 7,097' MD. Perform Kick while tripping Drill, Shut Annular, Stand-down for Safety discussion with T.Wellman. Continue POOH. 7/13/2023 - Thursday Continue RIH w/ 7" Yellow Jacket Packer on 3-1/2" Work String from 7,820' MD to 9,500'. P/U 88K S/O 42K. Rig up kelly hose. swivel into joint. Set packer @ 9,501'. Fill IA with 57 BBLs of 8.5 SW. Close annular and bring pressure up to 3150 psi. pressure starting to bleed down indicating air in system. Bleed down. open up annular and circulate air out. close annular and pressure up to 3190 psi for 30 min charted. good test. Pump 20 BBLs down workstring, Release packer. work torque out . monitor well. Swivel out of joint. lay down kelly hose and blow lines dry. POOH W/ 3-1/2 workstring and test packer from 9,500' to Surface while pumping double pipe displacement. Lay Down Test Packer - all intact. Switch Elevators to 2.875" square shoulder and prep Hanger w/ TWC for pressure testing shooting flange and W/L PCE. Land Hanger, RILDS. Pull Bird Baths and Flow Spools for installation of Shooting Flange. Rig up shooting flange, E-Line PCE. Hold PJSM for Rigging up and Gun safety. Review phone and radio silence until ~200' in the hole. Reviewed Pressure test hazards and non-essential personnel away from hazard areas. Bring on 40BBLS of fresh water for Pressure Tests. Pressure Test against Tubing Hanger / TWC, E-Line PCE - 250 low, 2500 High - good test, blow down lines. Assemble 40' x 6spf Guns. Turn off all cell phones and radios. Arm firing head. RIH w/ CCL, Firing Head, 40' x 6spf Guns w/ Bullnose to 3,200' RIH w/ 2-7/8" Summit ESP Completion from surface to 1,454' MD testing every 1000'. Clamped every connection for the first 10JTS, top of even numbered Joints after. Clamp Count in hole: 3 Motor Clamps, 2 Seal Clamps, 6 Pump Clamps & 1 Splice Clamp. 30 Cross Coupling. Crew change. Shut down and check fluids. Continue RIH w/ 2-7/8" ESP Completion from 1,454' to 2,010' MD testing every 1000'. Continue RIH w/ 2-7/8" ESP Completion from 2,010' to 2,990' MD testing every 1000'. Continue RIH w/ 2-7/8" ESP Completion from 2,990' to 3,900' MD testing every 1000' Multiple attempts made to get past 10,677' ELMD Assemble 40' x 6spf Guns. Turn off all cell phones and radios. Arm firing head. RIH w/ CCL, Firing Head, 40' x 6spf Guns w/ Bullnose to 3,200' Well Name Rig API Number Well Permit Number Start Date End Date MP K-30 ASR #1 50-029-22711-00-00 196-168 7/10/2023 7/16/2023 Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. Continue RIH w/ 2-7/8" ESP Completion from 3,990' to 6,429' MD testing every 1000'. Summit test cable and preform reel to reel splice. Continue RIH w/ 2-7/8" ESP Completion from 6,429' to 10,366' MD testing every 1000'. Splice landed on bottom of joint 210. it will be at 3,654' in the hole. P/U Hanger, install TIW and Kelly Hose to Landing Joint. Prepare for Hanger Penetrator connection. Cut and affix 3/8" SS Capillary Tubing to Hanger. Measure and cut ESP Cable at Penetrator. Assemble Connector as per manufacturer's instructions. Connect Cable Connector to Penetrator and test - All readings are good. Connect Ambilocal to top of Penetrator and retest. (good). Center Hanger in Riser, blow down lines, land Hanger, RILDS. FINAL PUW = 80K. FINAL SOW = 38K. ESP Test after landed - good. FINAL CLAMPS: 3 Motor Clamps, 2 Seal Clamps, 6 Pump Clamps, 2 Splice Clamp, & 175 OTC Clamp. Install BPV, remove Landing Joint. RDMO K-30. 7/15/2023 - Saturday No operations to report. 7/18/2023 - Tuesday 7/16/2023 - Sunday WELLHEAD: BOP stack pulled, clean hgr void, new RX54 gasket and seal subs. Land tree/adapter, torque to spec and test 500/5000 (PASS). Pull Bpv with Tbar, all valves in closed position. 7/17/2023 - Monday Continue RIH w/ 2-7/8" ESP Completion from 3,990' to 6,429' MD testing every 1000'. Summit test cable and preform reel to reel splice. Continue RIH w/ 2-7/8" ESP Completion from 6,429' to 10,366' MD testing every 1000'. Splice landed on bottom of joint 210. it will be at 3,654' in the hole. P/U Hanger, install TIW and Kelly Hose to Landing Joint