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Home My WebLink About194-095Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 05/17/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU J-06 (PTD 194-095) PERF 05/03/2022 Please include current contact information if different from above. PTD:194-095 T36625 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.18 09:53:55 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Alaska NS - ASR - Well Site Managers To:Regg, James B (OGC);DOA AOGCC Prudhoe Bay;Brooks, Phoebe L (OGC) Subject:Hilcorp ASR MPU J-06 BOPE Test 5-2-22 Date:Tuesday, May 3, 2022 12:16:51 AM Attachments:Hilcorp ASR MPU J-10 BOPE Test 5-02-22.xlsx Hilcorp test discriptions.pdf EXTERNAL .msg Some people who received this message don't often get email from alaskans- asrwellsitemanagers@hilcorp.com. Learn why this is important Thank You The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 038- 37' ILOHQDPHLQFRUUHFWVKRXOGEH-MPU J-10 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:ASR 1 DATE: 5/2/22 Rig Rep.: Rig Phone: 685-1266 Operator: Op. Phone:685-1266 Rep.: E-Mail Well Name: PTD #11940950 Sundry #322-087 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:2352 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2 1/16"P Inside Reel valves 0NA HCR Valves 1 2 1/16"P Kill Line Valves 2 2 1/16"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)3125 P CHOKE MANIFOLD:Pressure After Closure (psi)1825 P Quantity Test Result 200 psi Attained (sec)18 P No. Valves 16 P Full Pressure Attained (sec)62 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4x2280 P CH Misc 0NA ACC Misc 1NA Test Results Number of Failures:0 Test Time:4.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 05/01/2022 05:00 Waived By Test Start Date/Time:5/2/2022 20:00 (date) (time)Witness Test Finish Date/Time:5/3/2022 0:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Hilcorp Annular closure time = 27 sec. D Shultz, J. Haberthur Hilcorp Alaska S. Hiem / S. Menapace MPU J-06 Test Pressure (psi): skaNS-ASR-Well Site Managers@hilcorp.c Form 10-424 (Revised 02/2022) 2022-0502_BOP_Hilcorp_ASR1_MPU_J-10 9 9 9 9 9 9 9 9 9 9 9 9 -5HJJ Annular closure time = 27 sec. BOPE Test Chart – Hilcorp ASR 1 MPU J-06 (PTD 1940950) 5/2/2022 From:Rixse, Melvin G (OGC) To:Brian Glasheen Subject:20220425 1444 APPROVED REVISION PTD1940950, Sundry 322-087 MPU J-06 ESP Swap Perforate Date:Monday, April 25, 2022 2:49:00 PM Attachments:image004.png image002.png MPU J-06 ESP Changeout_TCP Add Procedure Revision 25APR202 2BPG Yellow Jacket Shooting flange.docx Brian, Hilcorp is approved to perform work under sundry 322-087 as per the revision attached. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Brian Glasheen <Brian.Glasheen@hilcorp.com> Sent: Monday, April 25, 2022 11:52 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: PTD1940950, Sundry 322-087 MPU J-06 ESP Swap Perforate Mel, I believe I was able to answer all questions below and updated the attached procedure. 1. Please describe your shooting flange in your procedure. a. b. Yellow Jacket 7” shooting flange with 7’’ quick test sub. 2. Please describe how your shooting flange will be anchored. a. Will be anchored to the top of the BOP stack. 3. Please describe your pressure test for your PCE equipment when utilizing Eline. a. Pressure test to 300psi low and 2,800psi high b. Not a Dutch riser but the shooting flange in the below pic. c. 4. Please describe your contingency kill procedure if you are underbalanced after shooting perforations. a. Contingency- If well can not be kill with ASR pumps. Rig up auxiliary equipment to allow wells kill at 7+ BPM b. Bull head 1.5 tubing vol of 8.8 ppg NaCl c. Establish fill rate and maintain hole fill 5. Do you have pump capacity for that with ARS #1? (Rule of thumb for 7” bullhead kill will be 7 bpm I believe.) a. Yes - Rig up auxiliary equipment to allow wells kill at 7+ BPM Brian Glasheen Operations Engineer 907-545-1144 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, April 21, 2022 3:39 PM To: Brian Glasheen <Brian.Glasheen@hilcorp.com> Subject: [EXTERNAL] RE: PTD1940950, Sundry 322-087 MPU J-06 ESP Swap Perforate Brian, 1. Please describe your shooting flange in your procedure. 2. Please describe how your shooting flange will be anchored. 3. Please describe your pressure test for your PCE equipment when utilizing Eline. 4. Please describe your contingency kill procedure if you are underbalanced after shooting perforations. 5. Do you have pump capacity for that with ARS #1? (Rule of thumb for 7” bullhead kill will be 7 bpm I believe.) Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Brian Glasheen <Brian.Glasheen@hilcorp.com> Sent: Thursday, April 21, 2022 11:34 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: FW: PTD1940950, Sundry 322-087 MPU J-06 ESP Swap Perforate Mel, Here is MPJ-06 the well I was talking about. Thanks for looking. Brian Glasheen Operations Engineer 907-545-1144 From: Brian Glasheen Sent: Monday, April 18, 2022 5:29 PM To: melvin.rixse@alaska.gov Subject: PTD1940950, Sundry 322-087 MPU J-06 ESP Swap Perforate Mel, I am taking over for Dave Gorm. We have a RWO coming up that I was looking to simplify. Would you approve the changes in red? Not changing any perf intervals. But I was planning to use ELINE only, not a work string and use a Shooting flange for pressure control when shooting. I feel this will save us a lot of time and money. Thanks Brian Glasheen Operations Engineer 907-545-1144 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. ESP Changeout Well: MPU J-06 Well Name: MPU J-06 API Number: 50-029-22493-00 Current Status: Shut-in [Failed ESP] Pad: J-Pad Estimated Start Date: April 21st, 2022 Rig: ASR #1 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 194-095 First Call Engineer: Brian Glasheen 907-545-1144 Second Call Engineer: Taylor Wellman (907) 777-8449 (O) (907)-947-9553 (M) AFE Number: Job Type: ESP Changeout Current Bottom Hole Pressure: 3,052 psi @’ 7,000 TVD SBHP Survey 1/15/2022| 8.4 ppg Maximum Expected BHP: 3,052 psi @’ 7,000 TVD SBHP Survey 1/15/2022| 8.4 ppg (Est. pressure mid perf. interval - 3,045 psi @ 6,889 TVD) MPSP: 2,352 psi Gas Colum Gradient (0.1 psi/ft) Max Inclination 45.6° @ 5,392’ MD Max Dogleg: 4°/100ft @ 3,119’ MD BPV Profile: 2-1/2” CIW Type H Brief Well Summary: MPU J-06 was drilled in 1994 using Nabors 22E and completed in the Kuparuk A and B sands. The well has had multiple ESP changeouts since 1994, (Nabors 4ES in 2000, Nabors 4ES in 2003, Nabors 4ES in 2006, Nabors 3S in 2006, 2008 using Nabors 3S, and most recent ESP change with ASR in 2015. The current ESP failed due to downhole grounding on 6/27/2021. Notes Regarding Wellbore Condition • The 7” casing was pressure tested to 2,700 psi with 8.5ppg brine from 8,290’ MD on 9/21/2015. • Offset injectors with status: o J-11 – SI on 06/29/2021 Objective: • Pull failed ESP completion. • TBG Conveyed Perforation add with Stimulation Sleeves. • Run new ESP completion. Pre-Rig Procedure: 1. RU LRS. 2. Kill the well with 8.8 ppg NaCl (volumes: tubing = 46 bbls & IA = 235 bbls). a. TBG Circ. Point – 7,779’ MD (6,467’ TVD) b. Bullhead 25 BBL’s down the IA to perfs, limit surface pressure to 800 psi. c. 8.8 KWF provides ~145 psi overbalance for trip margin. 3. Confirm well is dead. 4. RD LRS. 5. Clear and level pad area in front of well. Spot rig mats and containment. 6. RD well house and flowlines. Clear and level area around well. 7. RU crane. Set CTS Valve. ND Tree. Inspect the lift threads on the tubing hanger. Install the plug off tool into the CTS Valve. 8. NU 11” BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. ESP Changeout Well: MPU J-06 RWO Procedure: 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. 11. Test BOPE to 250/2,500 psi, annular to 250/2,500 psi. a. Notify AOGCC 24 hours in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test VBR ram on 2-7/8” test joint. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 12. RU to pull 2-7/8” ESP completion. 13. Pull the plug off tool, check for pressure under the CTS valve, if needed kill the well with 8.8 ppg NaCl and pull the CTS valve. 14. MU landing joint or spear. BOLDS, unseat the tubing hanger and pull to the rig floor. a. PU Wt. 64 K-lbs last pull with ASR 9/19/2015 15. Lay down the landing joint and tubing hanger. RU to pull ESP cable over the sheaves to the spooling unit. a. Inspect the tubing hanger and note any damage. If any damage is found, contact well head specialist for redress or replacement. 16. POOH and lay down the 2-7/8” tubing. Visually inspect the TBG checking the pins/boxes, plan to reuse the TBG replacing any bad joints. Lay down ESP and motor. a. Note any corrosion, sand or scale on the tubing with associated depths and ESP components on the morning report. b. Look for over-torqued connections from previous tubing runs. c. If any joint(s) appear suspect of damage to threads or tubing, send to G&I for disposal and replace with new. d. SL was not able to pull the DMV from the GLM at 7,804’ MD, replace with a new GLM from inventory, send the pulled GLM to the shop for inspection. Equipment Disposition Tubing hanger Visually inspect on site and reuse Tubing & Pup joints Visually inspect on site and reuse ESP equipment/Power Cable Centrilift to take possession for inspection and teardown Protectorlize Visually inspect on site and reuse Cannon clamps Visually inspect on site and reuse GLM Visually inspect replace with used/new inventory Flat guard Visually inspect on site and reuse 17. If scale is observed external of the ESP and TBG, review with operations Engineer the need for a casing scraper run. 18. Verify the well is static. 19. RU Yellow Jacket 7” shooting flange with 7’’ quick test sub. ESP Changeout Well: MPU J-06 a. b. Anchor to the top of the BOP stack c. Install 6’’ test plug or hanger with TWC. d. Rig up ELINE PCE e. Pressure test to 300psi low and 2,800psi high f. Break 7’’ quick test sub connection g. Pull 6’’ test plug or hanger with TWC. 20. RIH with ELINE and drift well with DUMY guns to 8400’ MD. POOH 21. PU 75’ of’ 3-3/8”, 6 SPF guns with Stimulation sleeves (max OD: 4.63” – centralizers) or 2-7/8”,2-3/4”, 2” Guns 22. MU guns to RIH with ELINE and install shooting flange for pressure control while shooting. 23. Verify the well is static. 24. Perf the below interval a. Contact Geologist - Katie Cunha – 907-564-4786 to confirm correlation depth. i. Perforation Interval: 8,313’ – 8,388’ MD (75’) – Kuparuk B-silts 25. Flow check the well. Confirm the well is dead, Bull head to kill the well as needed. (Note: B-silts anticipated to be normal pressured 8.5 ppg equivalent.) a. Contingency- If well can not be kill with ASR pumps. Rig up auxiliary equipment to allow wells kill at 7+ BPM b. Bull head 1.5 tubing vol of 8.8 ppg NaCl c. Establish fill rate and maintain hole fill 26. POOH 27. PU 78’ of’ 3-3/8”, 6 SPF guns with Stimulation sleeves (max OD: 4.63” – centralizers) or 2-7/8”,2-3/4”, 2” Guns 28. MU guns to RIH with ELINE and install shooting flange for pressure control while shooting. 29. Verify the well is static. ESP Changeout Well: MPU J-06 30. Perf the below interval a. Contact Geologist - Katie Cunha – 907-564-4786 to confirm correlation depth. i. Perforation Interval: 8,235’ – 8,313’ MD (78’) – Kuparuk B-silts 31. Flow check the well. Confirm the well is dead, Bull head to kill the well as needed. (Note: B-silts anticipated to be normal pressured 8.5 ppg equivalent.) a. Contingency- If well cannot be kill with ASR pumps. Rig up auxiliary equipment to allow wells kill at 7+ BPM b. Bull head 1.5 tubing vol of 8.8 ppg NaCl c. Establish fill rate and maintain hole fill 32. POOH. RDMO ELINE 33. PU, MU and RIH new ESP on 2-7/8”, 6.5#, L-80, EUE 8rd tubing with new ESP cable and 3/8” Cap String. Set base of ESP assembly at +/- 8,048’ MD. a. Motor centralizer b. Motor gauge unit c. ESP motor d. Lower tandem seal e. Upper tandem seal f. Pump g. Ported discharge head h. Bolt on discharge head i. 1 joint 2-7/8” TBG j. 2-7/8” XN Nipple k. 1 joint 2-7/8” TBG l. 2-7/8” GLM m. XX Joints 2-7/8” TBG n. 2-7/8” GLM @ +/- 150’ MD o. X Joints 2-7/8” TBG 34. PU and MU the 2-7/8” tubing hanger. Make final splice of the ESP cable to the penetrator, connect 3/8” Cap string, and ensure any control line ports are dummied off. 35. Land tubing hanger with extreme caution to avoid damaging the ESP cable or penetrator. RILDS. Lay down landing joint. Record PU and SO weights on the tally and WellEZ. 36. Set 2.5” CTS Valve. Post-Rig Procedure: 37. RD mud boat. RD BOPE house. Move to next well location. 38. RU crane. ND BOPE. Install the plug off tool. 39. NU the tubing head adapter and NU 2-9/16” 5M tree. 40. PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 41. Pull the plug off tool and BPV. 42. RD crane. Move returns tank and rig mats to next well location. 43. Replace gauge(s) if removed. 44. Turn well over to production via handover form. RU well house and flowlines. ESP Changeout Well: MPU J-06 Attachments: 1. As-built Schematic 2. Proposed Schematic 3. 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/ĨƐĐĂůĞŝƐŽďƐĞƌǀĞĚĞǆƚĞƌŶĂůŽĨƚŚĞ^WĂŶĚd'͕ƌĞǀŝĞǁǁŝƚŚŽƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌƚŚĞŶĞĞĚĨŽƌĂĐĂƐŝŶŐ ƐĐƌĂƉĞƌƌƵŶ͘ ϭϴ͘ sĞƌŝĨǇƚŚĞǁĞůůŝƐƐƚĂƚŝĐ͘ ϭϵ͘ Whϭϱϯ͛ϯͲϯͬϴ͕͟ϲ^W&dƵďŝŶŐŽŶǀĞǇĞĚWĞƌĨŽƌĂƚŝŽŶŐƵŶƐǁŝƚŚ^ƚŝŵƵůĂƚŝŽŶƐůĞĞǀĞƐ;ŵĂǆK͗ϰ͘ϲϯ͟ʹ ĐĞŶƚƌĂůŝǌĞƌƐͿ͘/ŶƐƚĂůůƚŚĞďĂůůĚƌŽƉĨŝƌŝŶŐŚĞĂĚƐŝǌĞĚĨŽƌϱͬϴ ͟ďĂůůǁŝƚŚĂŶŽͲŐŽĂďŽǀĞƚŚĞďĂůůƐĞĂƚ͘/ŶƐƚĂůů ĂZŵĂƌŬĞƌƐƵďĂďŽǀĞĨŽƌĚĞƉƚŚĐŽƌƌĞůĂƚŝŽŶǁŝƚŚĞͲůŝŶĞŝŶƚŚĞd'͘ 5HYLHZZHOOKLVWRU\WRGHWHUPLQHZKHWKHUWRGU\URGRUOXEULFDWH%39UHPRYDO ^WŚĂŶŐĞŽƵƚ tĞůů͗DWh:ͲϬϲ ϮϬ͘ ZĞǀŝĞǁǁŝƚŚƚŚĞKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌĂŶĚƉĞƌĨŽƌĂƚŝŽŶŐƵŶƌĞƉƌĞƐĞŶƚĂƚŝǀĞƚŚĞƌĞƋƵŝƌĞĚƚƌŝƉƉŝŶŐ ƉƌĂĐƚŝĐĞƐĂŶĚƌƵŶƐƉĞĞĚƐƉƌŝŽƌƚŽd/,͘ Ϯϭ͘ d/,ǁŝƚŚƚŚĞdWŐƵŶƐǁŝƚŚϮͲϳͬϴ͟ǁŽƌŬƐƚƌŝŶŐƚŽΕϴ͕ϰϴϴ͛D͘ ϮϮ͘ sĞƌŝĨǇƚŚĞǁĞůůŝƐƐƚĂƚŝĐ͘ Ϯϯ͘ ZhͲůŝŶĞĂŶĚZ/,ǁŝƚŚĂ'ĂŵŵĂƚŽŽůƚŽůŽŐĨƌŽŵƚŚĞƚŽƉŽĨƚŚĞdWŐƵŶƐƵƉ͘^ĞŶĚĂĐŽƉǇŽĨƚŚĞůŽŐƚŽ ƚŚĞ'ĞŽůŽŐŝƐƚĂŶĚKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌƚŽĐŽŶĨŝƌŵĚĞƉƚŚĐŽƌƌĞůĂƚ ŝŽŶ͘ Ϯϰ͘ WKK,ZͲůŝŶĞ͘ Ϯϱ͘ ^ƉĂĐĞŽƵƚƚŚĞdWŐƵŶƐƉĞƌƚŚĞĐŽƌƌĞůĂƚŝŽŶƌƵŶ͘;ŽŶƚĂĐƚ'ĞŽůŽŐŝƐƚͲ<ĂƚŝĞƵŶŚĂʹϵϬϳͲϱϲϰͲϰϳϴϲƚŽ ĐŽŶĨŝƌŵĐŽƌƌĞůĂƚŝŽŶĚĞƉƚŚͿ͘ Ă͘ WĞƌĨŽƌĂƚŝŽŶ/ŶƚĞƌǀĂů͗ϴ͕Ϯϯϱ͛ʹϴ͕ϯϴϴ͛D;ϭϱϯ͛Ϳʹ<ƵƉĂƌƵŬͲƐŝůƚƐ Ϯϲ͘ ƌŽƉƚŚĞϱͬϴ͟ďĂůů͕ĂůůŽǁƚŝŵĞĨŽƌƚŚĞďĂůůƚŽĚƌŽƉ͘WƌĞƐƐƵƌĞƵƉƚŚĞd'ƉĞƌƚŚĞŐƵŶƌĞƉ͛ƐƐƉĞĐŝĨŝĐĂƚŝŽŶƐ ƚŽĨŝƌĞƚŚĞŐƵŶƐŽŶĐĞƚŚĞďĂůůŝƐŽŶƐĞĂƚ͘ Ϯϳ͘ ĨƚĞƌĨŝƌŝŶŐƚŚĞŐƵŶƐ͕ĐŽŶĨŝƌŵĐŝƌĐƵůĂƚŝŽŶĚŽǁŶƚŚĞd'͘ Ϯϴ͘ &ůŽǁĐŚĞĐŬƚŚĞǁĞůů͘ŽŶĨŝƌŵƚŚĞǁĞůůŝƐĚĞĂĚ͕ĐŝƌĐƵůĂƚĞƚŽŬŝůůƚŚĞǁĞůůĂƐŶĞĞĚĞĚ͘;EŽƚĞ͗ͲƐŝůƚƐ ĂŶƚŝĐŝƉĂƚĞĚƚŽďĞŶŽƌŵĂůƉƌĞƐƐƵƌĞĚϴ͘ϱƉƉŐĞƋƵŝǀĂůĞŶƚ͘Ϳ Ϯϵ͘ WKK,ůĂǇŝŶŐĚŽǁŶƚŚĞdWŐƵŶƐ͘ŽŶĨŝƌŵĂůůƐŚŽƚƐĨŝƌĞĚ͘ ϯϬ͘ Wh͕DhĂŶĚZ/,ŶĞǁ^WŽŶϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐǁŝƚŚŶĞǁ^WĐĂďůĞĂŶĚϯͬϴ͟ĂƉ^ƚƌŝŶŐ͘ ^ĞƚďĂƐĞŽĨ^WĂƐƐĞŵďůǇĂƚнͬͲϴ͕Ϭϰϴ͛D͘ Ă͘ DŽƚŽƌĐĞŶƚƌĂůŝǌĞƌ ď͘ DŽƚŽƌŐĂƵŐĞƵŶŝƚ Đ͘ ^WŵŽƚŽƌ Ě͘ >ŽǁĞƌƚĂŶĚĞŵƐĞĂů Ğ͘ hƉƉĞƌƚĂŶĚĞŵƐĞĂů Ĩ͘ WƵŵƉ Ő͘ WŽƌƚĞĚĚŝƐĐŚĂƌŐĞŚĞĂĚ Ś͘ ŽůƚŽŶĚŝƐĐŚĂƌŐĞŚĞĂĚ ŝ͘ ϭũŽŝŶƚϮͲϳͬϴ͟d' ũ͘ ϮͲϳͬϴ͟yEEŝƉƉůĞ Ŭ͘ ϭũŽŝŶƚϮͲϳͬϴ͟d' ů͘ ϮͲϳͬϴ͟'>D ŵ͘ yy:ŽŝŶƚƐϮͲϳͬϴ͟d' Ŷ͘ ϮͲϳͬϴ͟'>DΛнͬͲϭϱϬ͛D Ž͘ y:ŽŝŶƚƐϮͲϳͬϴ͟d' ϯϭ͘ WhĂŶĚDhƚŚĞϮͲϳͬϴ͟ƚƵďŝŶŐŚĂŶŐĞƌ͘DĂŬĞĨŝŶĂůƐƉůŝĐĞŽĨƚŚĞ^WĐĂďůĞƚŽƚŚĞƉĞŶĞƚƌĂƚŽƌ͕ĐŽŶŶĞĐƚ ϯͬϴ͟ĂƉƐƚƌŝŶŐ͕ĂŶĚĞŶƐƵƌĞĂŶǇĐŽŶƚƌŽůůŝŶĞƉŽƌƚƐĂƌĞĚƵŵŵŝĞĚŽĨĨ͘ ϯϮ͘ >ĂŶĚƚƵďŝŶŐŚĂŶŐĞƌǁŝƚŚĞǆƚƌĞŵĞĐĂƵƚŝŽŶƚŽĂǀŽŝĚĚĂŵĂŐŝŶŐƚŚĞ^WĐĂďůĞŽƌƉĞŶĞƚƌĂƚŽƌ͘Z/>^͘>ĂǇ ĚŽǁŶůĂŶĚŝŶŐũŽŝŶƚ͘ZĞĐŽƌĚWhĂŶĚ^KǁĞŝŐŚƚƐŽŶƚŚĞƚĂůůǇĂŶĚtĞůů͘ ϯϯ͘ ^ĞƚϮ͘ϱ͟d^sĂůǀĞ͘ WŽƐƚͲZŝŐWƌŽĐĞĚƵƌĞ͗ ϯϰ͘ ZŵƵĚďŽĂƚ͘ZKWŚŽƵƐĞ͘DŽǀĞƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ ϯϱ͘ ZhĐƌĂŶĞ͘EKW͘/ŶƐƚĂůůƚŚĞƉůƵŐŽĨĨƚŽŽů͘ ^WŚĂŶŐĞŽƵƚ tĞůů͗DWh:ͲϬϲ ϯϲ͘ EhƚŚĞƚƵďŝŶŐŚĞĂĚĂĚĂƉƚĞƌĂŶĚEhϮͲϵͬϭϲ͟ϱDƚƌĞĞ͘ ϯϳ͘ WdƚŚĞƚƵďŝŶŐŚĂŶŐĞƌǀŽŝĚƚŽϱϬϬͬϱ͕ϬϬϬƉƐŝ͘WdƚŚĞƚƌĞĞƚŽϮϱϬͬϱ͕ϬϬϬƉƐŝ͘ ϯϴ͘ WƵůůƚŚĞƉůƵŐŽĨĨƚŽŽůĂŶĚWs͘ ϯϵ͘ ZĐƌĂŶĞ͘DŽǀĞƌĞƚƵƌŶƐƚĂŶŬĂŶĚƌŝŐŵĂƚƐƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ ϰϬ͘ ZĞƉůĂĐĞŐĂƵŐĞ;ƐͿŝĨƌĞŵŽǀĞĚ͘ ϰϭ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶǀŝĂŚĂŶĚŽǀĞƌĨŽƌŵ͘ZhǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ KW^ĐŚĞŵĂƚŝĐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϭͬϳͬϮϬϮϮ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh:ͲϬϲ >ĂƐƚŽŵƉůĞƚĞĚ͗ϵͬϮϭͬϮϬϭϱ Wd͗ϭϵϰͲϭϵϱ dс ϴ͕ϴϬϬ͛;DͿͬdсϳ͕ϯϮϰ͛;dsͿ ϭϯͲϯͬϴ´ &ůĞǀ͗͘ϲϲ͘Ϭ͛ͬ'>ůĞǀ͗͘ϯϲ͘ϱ͛;EĂďŽƌƐϮϮͿ ϳ͟ ´6WDJH&ROODU ¶ ϵͲϱͬϴ͟ .83%6DQGV +ROHVSXQFKHGLQ WXELQJ#¶ Wdс ϴ͕ϳϯϱ͛;DͿͬWdсϳ͕Ϯϲϴ͛;dsͿ .83$6DQGV )LOO#¶ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ ϭϯͲϯͬϴΗ ŽŶĚƵĐƚŽƌ ϱϰ͘ϱͬ<ͲϱϱͬW ϭϮ͘ϰϱϵ ^ƵƌĨĂĐĞ ϭϭϮΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬd ϴ͘ϲϳϵ ^ƵƌĨĂĐĞ Ϯ͕ϱϭϭ͛ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬE^ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϴ͕ϳϴϬ͛ dh/E'd/> ϮͲϳͬϴΗ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴZ Ϯ͘ϰϰϭ ^ƵƌĨ ϴ͕ϬϱϮ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭϭϯϴ͛'>D Ϯ ϳ͕ϴϬϰ͛ '>D ϯ ϳ͕ϵϳϲ͛ ϮͲϳͬϴ͟yEEŝƉƉůĞ͕Ϯ͘ϮϱϬ/ ϰ ϳ͕ϵϴϳ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ ϱ ϳ͕ϵϴϴ͛ WƵŵƉ^ĞĐƚŝŽŶ ϲ ϴ͕ϬϬϲ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ ϳ ϴ͕ϬϭϮ͛ dĂŶĚĞŵ^ĞĂů^ĞĐƚŝŽŶ ϴ ϴ͕ϬϮϱ͛ DŽƚŽƌ͕ϭϵϱ,W͕ϮϭϰϱsŽůƚ͕ϱϮĂŵƉ ϵ ϴ͕Ϭϰϴ͛ WƵŵƉŵĂƚĞǁͬϲ&ŝŶĞŶƚƌĂůŝǌĞƌʹŽƚƚŽŵΛϴ͕ϬϱϮ͛ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉ͘^ĂŶĚƐ ϴ͕ϯϯϬ͛ ϴ͕ϯϯϴ͛ ϲ͕ϵϭϰ͛ ϲ͕ϵϮϮ͛ ϴ ϴͬϮϲͬϭϵϵϰ KƉĞŶ <ƵƉ͘^ĂŶĚƐ ϴ͕ϰϭϴ͛ ϴ͕ϰϴϴ͛ ϲ͕ϵϵϬ͛ ϳ͕Ϭϰϳ͛ ϳϬ ϴͬϭϵͬϭϵϵϰ KƉĞŶ KWE,K>ͬDEdd/> ϭϯͲϯͬϴΗ ϮϱϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϮϰ͟,ŽůĞ ϵͲϱͬϴΗ ϰϴϴƐǆW&͕͟͞ϮϱϬƐǆůĂƐƐ'ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ϭϱϬƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞΛ^ƚĂŐĞŽůůĂƌ ϮϱϬƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞΛ^ŚŽĞ t>>/E>/Ed/KEd/> <KWΛϭ͕ϱϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϰϱ͘ϲĚĞŐ͘Ăƚϱ͕ϯϵϮ͛ DĂǆ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϯϭĚĞŐ͘ dZΘt>>, dƌĞĞ ϱD/tϮͲϵͬϭϲ͟ tĞůůŚĞĂĚ ϭϭ͟ǆϭϭ͟ϱD&D'ĞŶϲ͕ǁͬϮͲϵͬϭϲ͟&DdďŐ͘ ,Őƌ͕͘ϯ͟>,͘ĐŵĞƚŚƌĞĂĚϮ͘ϱ͟/t,WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϰϵϯͲϬϬͲϬϬ KƌŝŐ͘ŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϮϮͲϭϵϵϰ ^WZtKǁͬEĂďŽƌƐϰͲ^ʹϮϬϬϬ ^WZtKǁͬEĂďŽƌƐϰͲ^ʹϮϬϬϯ ^WZtKǁͬEĂďŽƌƐϰͲ^ʹϮϬϬϲ ^WZtKǁͬEĂďŽƌƐϯ^ʹϮϬϬϲ ^WZtKǁͬEĂďŽƌƐϰͲ^ʹϮϬϬϴ ^WZtKǁͬ^ZϭʹϵͬϮϮͬϮϬϭϱ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗,ϮͬϮϮͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh:ͲϬϲ >ĂƐƚŽŵƉůĞƚĞĚ͗ϵͬϮϭͬϮϬϭϱ Wd͗ϭϵϰͲϭϵϱ dс ϴ͕ϴϬϬ͛;DͿͬdсϳ͕ϯϮϰ͛;dsͿ ϭϯͲϯͬϴ´ &ůĞǀ͗͘ϲϲ͘Ϭ͛ͬ'>ůĞǀ͗͘ϯϲ͘ϱ͛;EĂďŽƌƐϮϮͿ ϳ͟ ´6WDJH&ROODU ¶ ϵͲϱͬϴ͟ 3URSRVHG .83 %6DQGVDQG 6LOWV Wdс ϴ͕ϳϯϱ͛;DͿͬWdсϳ͕Ϯϲϴ͛;dsͿ .83$6DQGV )LOO#¶ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ ϭϯͲϯͬϴΗ ŽŶĚƵĐƚŽƌ ϱϰ͘ϱͬ<ͲϱϱͬW ϭϮ͘ϰϱϵ ^ƵƌĨĂĐĞ ϭϭϮΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬd ϴ͘ϲϳϵ ^ƵƌĨĂĐĞ Ϯ͕ϱϭϭ͛ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬE^ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϴ͕ϳϴϬ͛ dh/E'd/> ϮͲϳͬϴΗ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴZ Ϯ͘ϰϰϭ ^ƵƌĨ цϴ͕ϬϱϮ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ цϭϯϴ͛ '>D Ϯ цϳ͕ϴϬϰ͛ '>D ϯ цϳ͕ϵϳϲ͛ ϮͲϳͬϴ͟yEEŝƉƉůĞ͕Ϯ͘ϮϱϬ/ ϰ цϳ͕ϵϴϳ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ ϱ цϳ͕ϵϴϴ͛ WƵŵƉ^ĞĐƚŝŽŶ ϲ цϴ͕ϬϬϲ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ ϳ цϴ͕ϬϭϮ͛ dĂŶĚĞŵ^ĞĂů^ĞĐƚŝŽŶ ϴ цϴ͕ϬϮϱ͛ DŽƚŽƌ ϵ цϴ͕Ϭϰϴ͛ ^ĞŶƐŽƌǁͬϲ&ŝŶĞŶƚƌĂůŝǌĞƌʹŽƚƚŽŵΛцϴ͕ϬϱϮ͛ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ 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Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 2/17/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU J-06 (PTD 194-095) 24 Arm Caliper 01/16/2022 Please include current contact information if different from above. 37' (6HW Received By: 02/17/2022 By Abby Bell at 12:07 pm, Feb 17, 2022 STATE OF ALASKA ALIPIA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations Li Fracture Stimulate Li Pull Tubing u Operations shutdown LI- 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-out ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development Q Exploratory ❑ 194-095 • 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22493-00 ' 7.Property Designation(Lease Number): '8.Well Name and Number: ADL 315848 • MILNE PT UNIT KR J-06 " 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL POOL ' 11.Present Well Condition Summary: Total Depth measured 8,800 • feet Plugs measured 8,735feeR E true vertical 7,324 • feet Junk measured 8,544(Fill) feet OCT 16 2815 Effective Depth measured 8,544 feet Packer measured N/A feet true vertical 7,101 feet true vertical N/A feet O GCC Casing Length Size MD ND Burst Collapse Conductor 112' 13-3/8" 112' 112' Surface 2,511' 9-5/8" 2,511' 2,462' 5,750psi 3,090psi Production 8,780' 7" 8,780' 7,307' 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 8,052' 6,682' 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: 153 0 1,272 290 232 Subsequent to operation: 101 0 1,236 160 251 14.Attachments(required per 20 AAC 25.070..25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development EI • Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ ' SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-524 Contact Stan Porhola Email sporholat hilcorp.com Printed Name //J�� Stan Porhola Title Operations Engineer Signature .).s p Phone 777-8412 Date 10/8/2015 /J0 1°/"IRB-DMCl ICT 2 12015 Form 10-404 Revised 5/2015 Submit Original Only • • Milne Point Unit • 14 Well: MPU J-06 SCHEMATIC Last Completed: 9/21/2015 Hilcorp Alaska,LLC PTD: ,94-1 04-o't S `-- CASING DETAIL =Elev.:66.0'/GL Elev.:36.5'(Nabors 22E) Size Type Wt/Grade/Conn Drift ID Top Btm 13-3/8" Conductor 54.5/K-55/PE 12.459 Surface 112' 1 i t ( } -, Ll 9-5/8" Surface 40/L-80/BTC 8.679 Surface 2,511' �" V 7" Production 26/L-80/NSCC 6.276 Surface 8,780' 8" • TUBING DETAIL 1,1 1 2-7/8" Tubing 6.5/L-80/EUE 8RD 2.441 Surf 8,052' '"` JEWELRY DETAIL No Depth Item I i ;a 1 138' GLM 2 7,804' GLM -5/8"le 3 7,976' 2-7/8"XN Nipple, 2.250 ID 4 7,987' Discharge Head 5 7,988' Pump Section `i A 6 8,006' Gas Separator ?' g* 7 8,012' Tandem Seal Section 8 8,025' Motor,195HP,2145 Volt,52 amp ri 9 8,048' Pumpmate w/6 Fin Centralizer-Bottom @ 8,052' '' PERFORATION DETAIL 4 Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status 1 Kup.B Sands 8,330' 8,338' 6,914' 6,922' 8 8/26/1994 Open 4. Kup.A Sands 8,418' 8,488' 6,990' 7,047' 70 8/19/1994 Open 14 WELL INCLINATION DETAIL NKOP@1,500' 7 Stage Colla- Max Hole Angle=45.6 deg. at 5,392' 5,013' Max Hole Angle through perforations=31 deg. ;e it OPEN HOLE/CEMENT DETAIL tilv 44 to 2 13-3/8" 250 sx of Arctic set I in 24"Hole .',4 9-5/8" 488 sx PF"E",250 sx Class G in 12-1/4"Hole 'i t7„ 150 sx Class"G"in 8-1/2"Hole @ Stage Collar 250 sx Class"G"in 8-1/2"Hole @ Shoe w I 13 >),j TREE&WELLHEAD .),4 Tree 5M CIW 2-9/16" 1 1 11"x 11"5M FMC Gen 6,w/2-9/16"FMC Tbg. 4 Wellhead Hgr.,3"LH.Acme thread 2.5"CIW H BPV profile r► 11. 5 GENERAL WELL INFO rri:c ,6 API:50-029-22493-00-00 '+ tar, ' 7 Orig.Completion by Nabors 22E-1994 z ESP RWO w/Nabors 4-ES-2000 a•' ESP RWO w/Nabors 4-ES-2003 i to, y,,8 ESP RWO w/Nabors 4-ES-2006 at �, ESP RWO w/Nabors 35-2006 9 9 ESP RWO w/Nabors 4-ES-2008 c. ,d ESP RWO w/ASR1-9/22/2015 .0. A kt t S" 91 j^�}KUP B Sands R' }KUP A Sands 14 TD=8,800'(MD)/TD=7,324'(1VD) 'BTD=8,735'(MD)/PBTD=7,268'(TVD) 'sed 8y:STP 10/8/2015 • 410 Hilcorp Alaska, LLC it.k.S't?`' „i,,.,,,.f,Alatska.LEA, Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPJ-06 50-029-22493-00-00 194-095 9/17/2015 9/22/2015 Daily Operations: 9/16/15-Wednesday No operations to report. 9/17/15-Thursday PJSM. ND Tree, NU BOPE, Move rig in (1/2 rate)from E-20. PJSM RU Lil Red SICP 600psi SITP 600psi Blow well down to 0 PSI all gas. Reverse circ 240 bbl 8.5 ppg catch fluid @ 1,500'continue pump gain 35%partial returns recover 85 bbls 0/W Mix.Shut down pump let tubing slug till dead, Pump 50 bbls seawater down tbg. Install BPV. PJSM ND Tree NU BOPE,Set well house. MIRU and spot tank raise derrick. Drop derrick re-align well house and re-enforce rig mats for settling. Resume RU ops. 9/18/15-Friday PJSM,continue RU, EQP&Total alarms up, P/T 3500 psi,Test&chart BOPE to 250/3000 psi,Annular 250/2500 psi, perform accumulator draw down test. Continue RU, pull TWC,install landing joint, pump 20 bbl 150° 8.5#sea water down tbg, prior to pumping down csg blow down annulus 50 psi, pump 100 bbls hot 8.5#sea water caught returns @ 46 bbls.Total pumped 121 bbls, loss of 83 bbls. Both sides on vacuum. PJSM, MU landing joint, Pull hanger 64K&LD . Continue POOH,^'4000'. 9/19/15-Saturday PJSM, POOH & LD GLM,continue POOH, BO/LD 2nd GLM, BO/LD ESP, 131 clamps/5 motor clamps/3 flat bars,fill hole w/ 4 bbl every 1/2 hr. MU 7"scraper assy 13.25 OAL, continue RIH,fill hole every 1/2 hr.for 37 jt, continue RIH, PJSM crew change RIH to 8,510', reverse circulate 158 bbl,caught psi @ 56 bbls, 158bbl in 30bbl out, minimal oil no sand. Pull 10 jnts,set up-calibrate&testing power swivel modifications 9/20/15-Sunday PJSM.Test and calibrate power swivel,establish cushion sub works well, PU XK-90 verify torque issue remains. PU and RIH tag fill@ 8544'. POOH BO/LD scraper. Rig service. PJSM. PU/MU 7" RTTS packer w/circ valve OAL 15.36' length to center element 11.95'. RIH with RTTS and set packer seals @ 8,290'wt 32K set 20K on pkr. Fill annulus w/27 bbl.8.5o g sw. P/T csg to 2,700 psi chart for 30 Minutes 6 psi_loss. Bleed off, r&r 2-1/16" 5M casing valve and companion flange. Test same to 2,700 psi same as casing test. Bleed off. 9/21/15-Monday PJSM, open bypass, release pkr. POOH, BO/LD RTTS pkr,elements are fine. PU and service ESP;PJSM, RIH, "'8450'. 9/22/15-Tuesday PJSM, RIH,splice cable, Land hanger, LD landing jt,set lock downs, Depths as following: Hanger, Pup,4 jts 2-7/8" L-80 6.5#tbg, pup,GLM 138', 243 jts tbg, pup GLM @7,804', 4 jts tbg,XN Nipple@ 7,976', pup. Head @ 7,987',Seals @ 8,012', Motor@ 8,025', Phoenix gauge 8,048', EOT Centralizer @ 8,052'. 60K Pull--38K slack off.Set BPV. RDMO ND BOP NU tree. Move to 1-08A. • • Schwartz, Guy L (DOA) GrLi'o'/ O From: Stan Porhola <sporhola@hilcorp.com> Sent: Monday,August 31, 2015 10:23 AM To: Schwartz, Guy L(DOA) Subject: RE:J-06 (PTD 194-095) ESP swap Sundry (#315-524) Guy, Please withdraw the original sundry 315-497 for MPU J-06. Stan �R From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, August 31, 2015 9:50 AM To: Stan Porhola Subject: 3-06 (PTD 194-095) ESP swap Sundry (# 315-524) Stan, We received an new sundry for MPU J-06 with updates ...the changes look like mainly to have a rolling test contingency for the BOPE pressure test. It would be cleaner to request a withdraw of the original sundry 315-497 and go completely off the new sundry for the wellwork(use 315-524) . Please send an email requesting a withdraw for the original sundry 315-497. 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). 1 V OF Th. • 4,w\�� I�j,�s,8 THE STATE Alaska Oil and Gas „ -=-2, -,..-._7,4 of Conservation Commission s ALAS] çJ\��# - -t4:::--.f 333 West Seventh Avenue U , GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \T� ".--� Main: 907.279.1433 OF ALAS.- Fax: 907.276 7542 www.aogcc.alaska gov Stan Porhola I a 0 J Operations Engineer l i 1 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 --__ Anchorage, AK 95503 `"'w'-- Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB J-06 Sundry Number: 315-524 DEQ 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 4 Chair Si- DATED t DATED this J) day of August, 2015 Encl. RBDMS SSP 0 2 2015 RECEIVED STATE OF ALASKA AUG 26 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ PuN Tubing 2 Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ !Ai Iter Casing ❑ Change Approved Program 2, Plug for Redrill❑ Perforate New Pool ❑ Repair Well V Re-enter Susp Well 0 Other. ESP Change Out Q• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory ❑ Development 2 ' 194-095 . 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22493-00 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 J-06 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 315848 ' MILNE POINT/KUPARUK RIVER OIL POOL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 8,800 ' 7,324 - 8,735 ' 7,268 ' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 13-3/8" 112' 112' Surface 2,511' 9-5/8" 2,511' 2,462' 5,750psi 3,090psi Intermediate Production 8,780' 7" 8,780' 7,307' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic/ See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8RD 8,027' 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 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑i Exploratory ❑ Stratigraphic❑ Development❑Q • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/11/2015 Commencing Operations: OIL ❑, ' WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: 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 sporholaahilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature Phone 907-777-8412 Date 146/S- COMMISSION USE ONLY 1 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3k5" S2-I4 Plug Integrity ❑ BOP Test U Mechanical Integrity Test ❑ Location Clearance ❑ Other: ?,4.) 5c 60 P ( ties = / g J Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /c . f O q APPROVED BY Approved by: i°49COMMISSIONER [ THE COMMISSION Date: g. 3/_ 6s 54.2-775 /'1 i"1 1 r1 1 w I A I fl� `v11411S- Submit Form and Well Prognosis Well: MPU J-06 llikorp Alaska,LL Date:8/26/2015 Well Name: MPU J-06 API Number: 50-029-22493-00 Current Status: SI Oil Well [ESP] Pad: J-Pad Estimated Start Date: September 11th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 194-095 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: 2,303 psi @ 7,000' TVD (Last BHP measured 7/22/2012) Maximum Expected BHP: 2,303 psi @ 7,000' TVD (No new perfs being added) I Max.A Towable Surf Pressure: 0 psi (Based on SBHP taken 7/2 and water cut 4 :/3-241 ?c of 50% (0.385psi/ an added safety factor 3a3 ' of 1,000' of oil cap) Brief Well Summary: ((•,%3 MPU J-06 was drilled in 1994 using Nabors 22E and completed in the Kuparuk A and B sands. The well has had multiple ESP changeouts since 1994, (Nabors 4ES in 2000, Nabors 4ES in 2003, Nabors 4ES in 2006, Nabors 3S in 2006, and the most recent was an ESP changeout in 2008 using Nabors 3S to run a new ESP. Notes Regarding Wellbore Condition • Casing last tested to unknown psi for down to 8,735' on 7/28/1994. • Found fill at 8,582' during a rig WO while pulling a failed ESP with Nabors 3S in 2008. Objective: Jt.kO Y):74)1') The purpose of this work/sundry is to pull the existing failed ESP and run a new ESP. Brief Procedure: WO Rig Procedure: 7 1< 1. Circulate well with 8.4 ppg lease water down tubing and fill casing. � 2. RU crane. Set BPV. ND Tree. NU 11" BOPE. 3. MIRU Hilcorp ASR#1 WO Rig. 4. Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/ 1 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. 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 11 Well Prognosis Well: MPU J-06 HHcorp Alaska,LL) Date:8/26/2015 c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 6. Bleed any pressure off tubing and casing. Pull BPV. 7. MU landing joint(3" LH acme hanger thread) and pull over string weight (previous rig string weight 72k UWT with Nabors 3S includes top drive weight) on tubing hanger to confirm free. 8. POOH. Lay 2-7/8"tubing on the pipe rack(utilize as workstring). 9. PU RTTS and RIH w/2-7/8" tubing/workstring. 10. Set RTTS at+/-8,280' MD (50' above top perf). Test casing to 2 500 psi for 30 min. 11. Release RTTS. POOH. LD RTTS. Lay down 2-7/8"tubing/workstring. 12. MU 6-1/8" bit and junk baskets and RIH to +/-8,582'. 13. Cleanout fill to +/-8,735'. 14. Circulate bottoms up x 2 with 8.4 ppg lease water. 15. POOH. Lay down bit and junk baskets. Lay down 2-7/8" tubing. 16. PU new 475 series ESP and RIH with new 2-7/8" 8RD EUE L-80 tubing. 17. Set base of ESP at+/-8,050' (Pump intake around +/-8,010'). Land tubing hanger. 18. Lay down landing joint. Set BPV. ND BOPE. NU existing 2-7/8" 5,000#tree. Pull BPV. 19. Set TWC. Test tubing hanger to 250/5,000 psi. Test tree to 250/5,000 psi. Pull TWC. 20. RD Hilcorp ASR#1 WO Rig. 21. Replace IA x OA pressure gauge if removed (7" x 9-5/8"). 22. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic Milne Point Unit • ti Well: MPU J-06 SCHEMATIC Last Completed: 9/16/2008 Ililcorp Alaska,LLC PTD: 194-195 CASING DETAIL Df Elev.:66.01 GL Elev.:36.5'(Nabors 22E) Size Type Wt/Grade/Conn Drift ID Top Btm 4 13-3/8" Conductor 54.5/K-55/PE 12.459 Surface 112' s^ p r 9-5/8" Surface 40/L-80/BTC 8.679 Surface _ 2,511' }! 7" Production 26/L-80/NSCC 6.276 Surface 8,780' 133/8 '� TUBING DETAIL 9 1 '4 2-7/8" Tubing 6.5/L-80/EUE 8RD 2.441 Surf 8,027' %. JEWELRY DETAIL n. .% No Depth Item 1 1 141' GLM 9-5/8" Y 2 7,809' GLM _ 3 7,952' 2-7/8"XN Nipple, 2.250 ID 4 7,965' Discharge Head ii.; i5 7,966' Pump Section 6 7,985' Gas Separator , 7 7,990' _ Tandem Seal Section �y 8 8,003' Motor,195HP,2145 Volt,52 amp 9sC 9 8,023' Pumpmate w/6 Fin Centralizer—Bottom @ 8,029' PERFORATION DETAIL �a 4 J Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status Kup.B Sands 8,330' 8,338' 6,914' 6,922' 8 8/26/1994 Open A Kup.A Sands 8,418' 8,488' 6,990' 7,047' 70 8/19/1994 Open WELL INCLINATION DETAIL T Stale Collar KOP @ 1,500' 5,013' Max Hole Angle=45.6 deg. at 5,392' Max Hole Angle through perforations=31 deg. r 14 OPEN HOLE/CEMENT DETAIL ti , 2 13-3/8" 250 sx of Arcticset I in 24"Hole i / 9-5/8" 488 sx PF"E",250 sx Class G in 12-1/4"Hole 9 9 150 sx Class"G"in 8-1/2"Hole @ Stage Collar ' 7250 sx Class"G"in 8-1/2"Hole @ Shoe a:, w, at 1 i 3 il IV 14 �+4y TREE&WELLHEAD Tree 5M CIW 2-9/16" w.P4 11"x 11"5M FMC Gen 6,w/2-9/16"FMC Tbg. a Wellhead 1.1 1 0 5 Hngr.,3"L.H.Acme thread 2.5"CIW H BPV profile s GENERAL WELL INFO 7 API:50-029-22493-00-00 yr " Orig.Completion by Nabors 22E-1994 ; r' ESP RWO w/Nabors 4-ES—2000 lIT �<8 ESP RWO w/Nabors 4-ES—2003 691 ESP RWO w/Nabors 4-ES—2006 wA ;t, ESP RWO w/Nabors 35—2006 :w ,w A ESP RWO w/Nabors 4-ES—2008 V io Y A 1 r 4 }Kll'B Saws >' AF,.. }KUP A Sands Fill @8,582 44 i. yfft:tt TD=8,800'(MO)/TD=7,324'(1VD) PBTD=8,735'(MD)/PBTD=7,268'(TVD) Revised By:STP 8/12/2015 Milne Point Unit Well: MPU 1-06 PROPOSED SCHEMATIC Last Completed: Proposed Ililcorp Alaska,LLC PTD: 194-195 CASING DETAIL DF Elev.:66.0/GL Elev.:36.5'(Nabors 22E) Size Type Wt/Grade/Conn Drift ID Top Btm A :o Lt. 13-3/8" Conductor 54.5/K-55/PE 12.459 Surface 112' ;+ 9-5/8" Surface 40/L-80/BTC 8.679 Surface 2,511' 111 0 k" 7" Production 26/L-80/NSCC 6.276 Surface 8,780' 133/8' _i!. TUBING DETAIL t 2-7/8" Tubing 6.5/L-80/EUE 8RD 2.441 Surf 8,050' 1 JEWELRY DETAIL )e i,t} No Depth Item t"� 1 1 _ 150' GLM 9-5/8"6 I>r 2 7,800' GLM 3 7,950' 2-7/8"XN Nipple, 2.250 ID 4 _ 7,986' Discharge Head NA 5 7,987' . Pump Section * 6 8,006' Gas Separator v7 8,011' Tandem Seal Section 1 8 8,024' Motor,195HP,2145 Volt,52 amp 9 o 9 8,044' Pumpmate w/6 Fin Centralizer—Bottom @ 8,050' 'e- s• PERFORATION DETAIL rj Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status 1 J Kup.B Sands 8,330' 8,338' 6,914' 6,922' 8 8/26/1994 Open 04 A Kup.A Sands 8,418' 8,488' 6,990' 7,047' 70 8/19/1994 Open 1'' • WELL INCLINATION DETAIL T Stage Collar KOP @ 1,500' 5,013 Max Hole Angle=45.6 deg. at 5,392' Max Hole Angle through perforations=31 deg. "4.1 2 OPEN HOLE/CEMENT DETAIL 13-3/8" 250 sx of Arcticset I in 24"Hole 9-5/8" 488 sx PF"E",250 sx Class G in 12-1/4"Hole 9 ,' 7„ 150 sx Class"G"in 8-1/2"Hole @ Stage Collar 4 250 sx Class"G"in 8-1/2"Hole @ Shoe v. 5• = 3 �� TREE&WELLHEAD ,ti 1 Tree 5M CIW 2-9/16" 4Wellhead 11"x 11"5M FMC Gen 6,w/2-9/16"FMC Tbg. 5 Hngr.,3"L.H.Acme thread 2.5"CIW H BPV profile H 8 GENERAL WELL INFO g 7 API:50-029-22493-00-00 4. Orig.Completion by Nabors 22E-1994 i* ESP RWO w/Nabors 4-ES—2000 4 _ ®8 ESP RWO w/Nabors 4-ES—2003 9 % ESP RWO w/Nabors 4-ES—2006 .. ESP RWO w/Nabors 35—2006 s -;: ESP RWO w/Nabors 4-ES—2008 14 y t _}KUP B Sax's ' }KUP A Sands JJ Fill @8,735 i..a ria,' tie VA'. 4 TD=8,8W(M))/TD=7,324'(1VD) PBTD=8,735'(MD)/PBTD=7,268'(TVD) Revised By:STP 8/26/2015 Milne Point 2015 ASR Rig 1 11 i�..,� ,��,�� Knight Oil Tools BOP 1 11 11" BOPE Stripping Head 3.98' ' Shaffer 4 11"- 5000 imir til I11 III lii iii i 1 111 l!I"I11 I11 I11 ;. - 4.54' (imilfid CI _U piuU$.i..: 2 7/8-5 variables r _ I 11" 5000 111:-MPHIL —= Blind ilk 111111i lii iii iii 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves I!L 'pip' ili !pi 2.00' Fix r e . 4 L, . rti ' ' r ,ti ; trIIO• 111 iii Iii lii til'! - ii - . Manual Manual Manual HCR Updated 8/19/15 Schwartz, Guy L (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Monday,August 31, 2015 10:23 AM To: Schwartz, Guy L (DOA) Subject: RE:J-06 (PTD 194-095) ESP swap Sundry (# 315-524) Guy, SCANNED SEP 1 6 2015 Please withdraw the original sundry 315-497 for MPU J-06. Sta n From: Schwartz, Guy L(DOA) [nailto:guy.schwartz@alaska.gov] Sent: Monday, August 31, 2015 9:50 AM To: Stan Porhola Subject: J-06 (PTD 194-095) ESP swap Sundry (# 315-524) Stan, We received an new sundry for MPU J-06 with updates ...the changes look like mainly to have a rolling test contingency for the BOPE pressure test. It would be cleaner to request a withdraw of the original sundry 315-497 and go completely off the new sundry for the wellwork(use 315-524) . Please send an email requesting a withdraw for the original sundry 315-497. 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(Guy.schwartz@alaska.gov). cow SEP 0 8 2015 of TitTHE STATE Alaska Oil and Gas • \\ 1777.ice s� g.rn��a of/\ J J j\ J(j\ Conservation Commission t 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 11010- Main 907.279 1433 O ALAS Fax: 907 276 7542 www aogcc alaska gov Stan Porhola scoot, `' n3 Operations Engineer 5 Hilcorp Alaska, LLC q 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Unit, Kuparuk River Oil Pool, KR J-06 Sundry Number: 315-497 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, c/1--•„. Cathy P. oerster Chair DATED this/�" day of August, 2015 Encl. RECEIVED STATE OF ALASKA AU G 13 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 0ki `? l 15 APPLICATION FOR SUNDRY APPROVALS OGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑✓ • Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing 0 Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well 2. Re-enter Susp Well ❑ Other. ESP Change Out 0. 2.Operator Name: 4.Current Well Class: 5.Permit to Dril Number Hilcorp Alaska,LLC Exploratory ❑ Development 0 • 194-095 - 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22493-00 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 0 No 0 1 MILNE PT UNIT KR J-06 • 9.Property Designation(Lease Number): 10.Field/Pool(s) ADL 315848 - MILNE POINT/KUPARUK RIVER OIL POOL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 1 8,800 . 7,324 . 8,735 - 7,268 - N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 112' 13-3/8" 112' 112' Surface 2,511' 9-5/8" 2,511' 2,462' 5,750psi 3,090psi Intermediate Production 8,780' 7" 8,780' 7,307' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic J See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8RD 8,027' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A and N/A 1 N/A and N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development E• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 8/20/2015 Commencing Operations: OIL El • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: 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@hilcoro.com Printed Name Stan Porhola Title Operations Engineer Signature Phone 907-777-8412 Date -A47t �Q\ S i ?// S- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: $15 - y9—t Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: /4- 300. ES dor j cS'1`- ( /44/ _., tit'fa----L-L... ) Spacing Exception Required? Yes ❑ No LJ Subsequent Form Required: I c)-4i0`1 APPROVED BY Approved by:‘;_eAs :;6,1....t.„.14......„ COMMISSIONER THE COMMISSION Date: F�7—/ O Rr[iGaiNtAll:Ild �� iy/« q�t S----- Y17.1 S Submit Form and Form 10-403 Revised 5/2015 for 12 months frj tof approvaK Attach is in Duplicate "9'70 RBDMS- AUG 19 2015 Well Prognosis Well: MPU J-06 Hilcorp Alaska,LL Date:8/12/2015 Well Name: MPU 1-06 API Number: 50-029-22493-00 Current Status: SI Oil Well [ESP] Pad: J-Pad Estimated Start Date: August 19th,2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 194-095 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: 2,303 psi @ 7,000'TVD (Last BHP measured 7/22/2012) Maximum Expected BHP: 2,303 psi @ 7,000'ND (No new perfs being added) Max.Allowable Surf Pressure: 0 psi (Based on SBHP taken 7/22/2012 and water cut of 50% (0.385psi/ft)with an added safety factor Air-. of 1,000'ND of oil cap) Brief Well Summary: MPU J-06 was drilled in 1994 using Nabors 22E and completed in the Kuparuk A and B sands. The well has had multiple ESP changeouts since 1994, (Nabors 4ES in 2000, Nabors 4ES in 2003, Nabors 4ES in 2006, Nabors 3S in 2006, and the most recent was an ESP changeout in 2008 using Nabors 3S to run a new ESP. Notes Regarding Wellbore Condition • Casing last tested to unknown psi for down to 8,735'on 7/28/1994. • Found fill at 8,582' during a rig WO while pulling a failed ESP with Nabors 3S in 2008. Objective: The purpose of this work/sundry is to pull the existing failed ESP and run a new ESP. , Brief Procedure: WO Rig Procedure: 1. Circulate well with 8.4 ppg lease water down tubing and fill casing. 2. RU crane.Set BPV. ND Tree. NU 11" BOPE. 3. MIRU Hilcorp ASR#1 WO Rig. 4. Test to 250 psi Low/3,22Eg 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. 5. Bleed any pressure off tubing and casing. Pull BPV. 6. MU landing joint(3" LH acme hanger thread)and pull over string weight(72k UWT Nabors 3S includes top drive weight)on tubing hanger to confirm free. 7. POOH. Lay 2-7/8"tubing on the pipe rack(utilize as workstring). 8. PU RTTS and RIH w/2-7/8"tubing/workstring. 9. Set RTTS at+/-8,280' MD(50'above top perf).Test casing to 2,500 psi for 30 min. 10. Release RTTS. POOH. LD RTTS. Lay down 2-7/8"tubing/workstring. 11. MU 6-1/8" bit and junk baskets and RIH to+/-8,582'. Well Prognosis Well: MPU J-06 Hilcorp Alaska,LL Date:8/12/2015 12. Cleanout fill to+/-8,735'. 13. Circulate bottoms up x 2 with 8.4 ppg lease water. 14. POOH. Lay down bit and junk baskets. Lay down 2-7/8"tubing. 15. PU new 475 series ESP and RIH with new 2-7/8"8RD EUE L-80 tubing. 16. Set base of ESP at+/-8,050' (Pump intake around+/-8,010'). Land tubing hanger. 17. Lay down landing joint.Set BPV. ND BOPE. NU existing 2-7/8" 5,000#tree. Pull BPV. 18. Set TWC.Test tubing hanger to 250/5,000 psi.Test tree to 250/5,000 psi. Pull TWC. 19. RD Hilcorp ASR#1 WO Rig. 20. Replace IA x OA pressure gauge if removed (7"x 9-5/8"). 21. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic Milne Point Unit . II Well: MPU J-06 SCHEMATIC Last Completed: 9/16/2008 Ilileurp Alaska,IAA] PTD: 194-195 CASING DETAIL DF Elev.:66.07 GL Elev.:36.5'(Nabors 22E) Size Type Wt/Grade/Conn Drift ID Top Btm Ff 13-3/8" Conductor 54.5/K-55/PE 12.459 Surface 112' 9-5/8" Surface 40/L-80/BTC 8.679 Surface 2,511' 7" Production 26/L-80/NSCC 6.276 Surface 8,780' 13-3/8 TUBING DETAIL III 1 r. 2-7/8" Tubing 6.5/L-80/EUE 8RD 2.441 Surf 8,027' ;. JEWELRY DETAIL No Depth Item 1 141' GLM 9-5/g • 1 2 . 7,809' GLM 3 7,952' 2-7/8"XN Nipple, 2.250 ID 4 _ 7,965' Discharge Head 5 7,966' Pump Section ' 6 7,985' Gas Separator 7 7,990' Tandem Seal Section 8 , 8,003' Motor,195HP,2145 Volt,52 amp 9 8,023' Pumpmate w/6 Fin Centralizer—Bottom @ 8,029' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.B Sands 8,330' 8,338' 6,914' 6,922' 8 8/26/1994 Open Kup.A Sands 8,418' 8,488' 6,990' 7,047' 70 8/19/1994 Open CCN WELL INCLINATION DETAIL 7"Stage cellar KOP @ 1,500 5,013' Max Hole Angle=45.6 deg. at 5,392' Max Hole Angle through perforations=31 deg. 2 , OPEN HOLE/CEMENT DETAIL 13-3/8" 250 sx of Arcticset I in 24"Hole 9-5/8" 488 sx PF"E",250 sx Class G in 12-1/4"Hole 7„ 150 sx Class"G"in 8-1/2"Hole @ Stage Collar { } 250 sx Class"G"in 8-1/2"Hole @ Shoe I 1 3 TREE&WELLHEAD Tree 5M CIW 2-9/16" a_ 1 4 11"x 11"5M FMC Gen 6,w/2-9/16"FMC Tbg. Wellhead 5 Hngr.,3"L.H.Acme thread 2.5"CIW H BPV profile irri 6 GENERAL WELL INFO i '7 API:50-029-22493-00-00 Orig.Completion by Nabors 22E-1994 ESP RWO w/Nabors 4-ES—2000 8 ESP RWO w/Nabors 4-ES—2003 Z9 1 ESP RWO w/Nabors 4-ES—2006 ESP RWO w/Nabors 3S—2006 -A ESP RWO w/Nabors 4-ES—2008 }' . 'y g}KIP B Sands = 1 KUPA Sands Fill©8,582 q iiii TD=8,8W(MD)/TD=7,324'(TVD) PBTD=8,735'(MD)/PBTD=7,268'(TVD) Revised By:STP 8/12/2015 Milne Point Unit . 11 Well: MPU J-06 • PROPOSED SCHEMATIC Last Completed: Proposed H;lcorp Alaska,LL,: PTD: 194-195 CASING DETAIL DF Elev.:66.0/GL Elev.:36.5'(Nabors 22E) Size Type Wt/Grade/Conn Drift ID Top Btm F 13-3/8" Conductor 54.5/K-55/PE 12.459 Surface 112' ,j 9-5/8" Surface 40/L-80/BTC 8.679 Surface 2,511' 7" Production 26/L-80/NSCC 6.276 Surface 8,780' 13-3/8 TUBING DETAIL 1 7 1/8' Tubing 6.5/L-80/EUE 8RD 2.441 Surf "" JEWELRY DETAIL No Depth Item 1 150' GLM 9-5/8, • 1 2 7,800' GLM 3 7,950' _ 2-7/8"XN Nipple, 2.250 ID 4 7,986' Discharge Head 5 7,987' _ Pump Section • 6 8,006' Gas Separator • 7 8,011' Tandem Seal Section 8 8,024' Motor,195HP,2145 Volt,52 amp 9 8,044' Pumpmate w/6 Fin Centralizer—Bottom @ 8,050' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.B Sands 8,330' 8,338' 6,914' 6,922' 8 8/26/1994 Open Kup.A Sands 8,418' 8,488' 6,990' 7,047' 70 8/19/1994 Open WELL INCLINATION DETAIL 7'Stage CdIar KOP @ 1,500' 5,013' Max Hole Angle=45.6 deg. at 5,392' Max Hole Angle through perforations=31 deg. 2 OPEN HOLE/CEMENT DETAIL 13-3/8" 250 sx of Arcticset I in 24"Hole 9-5/8" 488 sx PF"E",250 sx Class G in 12-1/4"Hole 7„ 150 sx Class"G"in 8-1/2"Hole @ Stage Collar 250 sx Class"G"in 8-1/2"Hole @ Shoe 1:I 3 .. TREE&WELLHEAD Tree 5M CIW 2-9/16" t_ _a r 4 11"x 11"5M FMC Gen 6,w/2-9/16"FMC Tbg. ^ Wellhead 5 Hngr.,3"L.H.Acme thread 2.5"CIW H BPV profile ' 6 GENERAL WELL INFO 7 API:50-029-22493-00-00 ` Orig.Completion by Nabors 22E-1994 ESP RWO w/Nabors 4-ES—2000 8 ESP RWO w/Nabors 4-ES—2003 a9 ' ESP RWO w/Nabors 4-ES—2006 ESP RWO w/Nabors 3S—2006 ESP RWO w/Nabors 4-ES—2008 -KUP B Sands =}KUPASands h'i Fill @8,582 '' `1 ant7"'•'3,�F e TD=8,800'(MD)/TD=7,324'(TVD) PBTD=8,735'(MD)/PBTD=7,268'(TVD) Revised By:STP 8/12/2015 Milne Point 2015 ASR Rig 1 ‘1 4.s �� Knight Oil Tools BOP 11" BOPE Stripping Head r r 3.98' Hydril GK 11"-5000 111 I11 Ill Ill Ill lil I!I 11711r111 CbU 4.54' - - 2 7/8-5 variables SMI �, 11 -5000 Blind 1111 I11 Iil 111 21/16 5M Kill Line Valves 11 21/16 5M Choke Line Valves —OP, 1011 111 111111 III 1111 2.00' L • 41) Ill Ill'Ill ill III'! € Manual Manual Manual HCR Updated 7/23/15 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I~ ~ -O::~File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds Other COMMENTS' Scanned by: Bevedy~ Vincent Nathan Lowell Date: (¢- [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 51.AftitiNED FEB 2 3 ZOIa December 30, 2011 017 5 /',, Mr. Tom Maunder Y QVJ Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPJ -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPJ -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 -. �. BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPJ -Pad 9/5/2011 Corrosion Vol. of cement Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped Final top of cement date inhibitor sealant date ft bbls ft gal MPJ - 01A 1991110 50029220700100 Sealed Conductor NA NA NA NA NA MPJ -02 1900960 50029220710000 Sealed Conductor NA NA NA NA NA MPJ -03 1900970 50029220720000 Sealed Conductor NA NA NA NA NA MPJ-04 1900980 50029220730000 Sealed Conductor NA NA NA NA NA MPJ -05 1910950 50029221960000 Dust Cover NA NA NA 3.4 9/5/2011 - "'7 1 ' MPJ-06 1940950 50029224930000 4 NA 4 NA 8.5 8/21/2011 MPJ -07 1910970 50029221980000 3.8 NA 3.8 NA 3.4 8/21/2011 MPJ -08A 1991170 50029224970100 18 NA Need top job MPJ-09A 1990114 50029224950100 Sealed Conductor NA NA NA NA NA MPJ -10 1941100 50029225000000 Sealed Conductor NA NA NA NA NA MPJ -11 1941140 50029225020000 Sealed Conductor NA NA NA NA NA MPJ -12 1941180 50029225060000 Sealed Conductor NA NA NA NA NA MPJ -13 1941260 50029225080000 1 NA 1 NA 3.4 8/21/2011 MPJ -15 1991070 50029229520000 Dust Cover NA NA NA 5.1 9/5/2011 MPJ -16 1951690 50029226150000 1.8 NA 1.8 NA 11.1 8/20/2011 MPJ -17 1972080 50029228280000 0.8 NA 0.8 NA 8.5 9/5/2011 MPJ -18 1972200 50029228340000 1.3 NA 1.3 NA 17.0 9/5/2011 MPJ -19A 1951700 50029226070100 2.2 NA 2.2 NA 15.3 8/20/2011 MPJ -20A 2001850 50029228320100 5.8 NA 5.8 NA 65.5 9/5/2011 MPJ -21 1972000 50029228250000 3.5 NA 3.5 NA 28.1 8/20/2011 MPJ -23 2001200 50029229700000 0.8 NA 0.8 NA 10.2 11/1/2009 MPJ -24 2001490 50029229760000 Open Flutes - Treated MPJ -25 2040730 50029232070000 1 NA 1 NA 8.5 8/21/2011 MPJ -26 2040640 50029232050000 1.2 NA 1.2 NA 11.9 8/20/2011 STATE OF ALASKA A~ OIL AND GAS CONSERVATION CO~SSION REPORT OF SUNDRY WELL OPERATIONS OC-~ ~ ~ 2008 1. Operations Performed: AI~C~141'~~£ ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re- nter spended 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 194-095 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22493-00-00 - 7. KB Elevation (ft): 66 9. Well Name and Number: MPJ-06 8. Property Designation: 10. Field /Pool(s): ADL 315848 ~ Milne Point Unit / Kuparuk River Sands ' 11. Present well condition summary Total depth: measured 8800 ' feet true vertical 7324 feet Plugs (measured) None Effective depth: measured 8735 feet Junk (measured) None true vertical 7268 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 112' 112' 2730 1130 Surface 2482' 9-5/8" 2511' 2462' 5750 3090 Intermediate Production 8741' 7" 8780' 7307' 7240 5410 Liner ~. ~~~~~ Perforation Depth MD (ft): 8330' - 8488' Perforation Depth TVD (ft): 6915' - 7052' 2-7/8", 6.5# L-80 8029' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 Subsequent to operation: 276 53 996 340 329 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 Mackie Derrick, 564-5891 N/q Printed Name Sondra Stewman Title Drilling Technologist ff Prepared By Name/Number ,~ D ~"~ '~~ Signa ure Phone ate l Sondra Stewman 564-4750 Form 10-404 vised 04/2006 r`; 4~'JJ f a~ Submit Original Only ~D is . Z 5~. ~b Tree: 2 9/16" - 5M Wellhead: 11" 5M FMC Gen 6 Tba. Hna: 2 7/8" x 11" FMC w/ 3" LH ACME and 2.5" CIW H BPV profile 13-3/8" K-55 54.5 #!ft I 9-5/8", 40#/ft,L-80, Btrs Csg 2,511' 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift ID = 2.347", cap. = 0.00592 I I KOP Q 1200' Max. hole angle = 45 deg. 3500'-7~ Hole angle thru' perfs = 30 deg I 7" 26 ppf, L-80, NSCC production (drift ID = 6.151", cap. = 0.0383 bl I PERFORATING SUMMARY Ref I nn~ C;R-CCI !OR/15/9dl Size s f Perforation and tvc 3-3/8 6 8330' • 8338' 6914'-i 3-3/8 6 8418' - 8488' 6990'= Tag fill @ 8582' MD by Nabors 3S Orig. KB Elev. = 46.67 (N 22E) Orig. GL Elev. = 17.00 DF To Tbg. Spool = 46.6; Cameo 2 7/8" x 1" ' sidepocket KBMM GLM 14t imco 2 7/8" x 1 " lepocket KBMM-2 GLM 7,eos' /8" XN-Nipple (2.25" ID) 7,952' 'DIS pump discharge head ntrilift Pump Model: SXD T 137 P17 7 965 ype: - , ndem Gas Separator 7685 7SFTXAR 400 series ~dem Seal Sections B3DBUT/LT AB/AB PFSA/FSA CL5 7990 Ir- 228 hp KMH 2305v/60a ted to 95 HP KME-1 2145V/52A 8003' Pumpmate XTO Sensor 8023' ~dard 6 fin centralizer 8027' PBTD 8735' 7", 26#/ft, L-80 BTRC gg00' Date By Comments 09/07/94 02-06-95 JJM RRW COIL COMPLETION CT-ESP RE-COMPLETION MILNE PAINT UNIT 11/20/00 MDO ESP RWO remove coil comp. Nabors 4-ES WELL J-06 1/15/03 MAS ESP RWO remove LLC valve Nabors 4-ES API NO: 50-029-22493 09/06/06 REH ESP RWO Nabors 4ES 12/10/06 REH ESP RWO Nabors 3S 9/16/08 REH ESP RWO -Nabors 3S B•P•X. (ALASKA) INC. MPJ-06 • BP AMERICA Page 1 of 2 Operations Summary Report Legal Well Name: MPJ-06 Common Well Name: MPJ-06 Spud Date: 9/11/2008 Event Name: WORKOVER Start: 9/11/2008 End: 9/17/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/17/2008 Rig Name: NABOBS 3S Rig Number: Date From - To I Hours Task ~, Code NPT Phase Description of Operations 9/13/2008 17:00 - 19:00 2.00 RIGD P PRE RD, scope down and lower Derrick. 19:00 - 21:30 2.50 RIGD P PRE Move pipe shed away from sub, jack down Carrier, PJSM with Peak truck crew, prep units for move. Move Carrier off MPH-04 with Pad operator, NAD Toolpusher and BP/WSL present at 20:30 hours 21:30 - 22:30 1.00 MOB P PRE Move Rig units off MPH-Pad to MPJ-Pad 22:30 - 00:00 1.50 MOB P PRE Spot BOP Stack behind MPJ-06. Line up Carrier with well. 9/14/2008 00:00 - 01:00 1.00 MOB P PRE Move Camp from MPH-Pad to MPJ-Pad. Remove old lifting rings from BOP stack. 01:00 - 03:00 2.00 MOB P PRE Spot carrier over Well with Pad operator, NAD Toolpusher and BP/WSL present at 01:00 hours. Lay mats and level Carrier. Spot pipe shed and Pits. 03:00 - 06:00 3.00 MOB P PRE PJSM-Raise and scope Mast. Pull and hook up electrical lines. Hook up steam and water lines, put steam around rig. Spot Tiger tank. Rig accepted at 06:00 hours 9/14/2008.; 06:00 - 09:30 3.50 KILL P DECOMP Rig up lines to tree for circulation well kill. Load pits with 8.45 # SW. Complete RU on rig. 09:30 - 10:30 1.00 KILL P DECOMP Test hardline to Tiger tank - 500 psi. Close choke, test upstream to 2500 psi. PUMU lubricator. Test to 500 psi. Pult BPV. WHP's: 520 / 500 / 100 - T/ IA / OA. 10:30 - 15:00 4.50 KILL P DECOMP Bleed IA from 500 psi to 250 psi. Circulate 50 Bbls of SW taking returns. Close choke and Bullhead 25 Bbls f~ 2 BPM / 380 psi. Strap tank with 45 Bbls of returns. Open choke and circulate 480 Bbls of 8.5 #/gal SW. Clean returns. 375 Bbls returns. Losses of 100 Bbls. Flowcheck well. Tubing and IA_ on Vacuum. 15:00 - 15:30 0.50 WHSUR P DECOMP Dry rod TWC. Test from above to 3500 si and chart for 10 minutes. 15:30 - 18:00 2.50 WHSUR P DECOMP John Crisp with AOGCC waived State's right to witness BOPE testing. ND Tree 18:00 - 23:00 5.00 WHSUR P DECOMP NU 7-1/16" X 13-5/8" flanged spool. PU BOP stack from shipping cradle and NU. 23:00 - 00:00 1.00 BOPSU P DECOMP Function test BOPE equipment. Grease choke manifold and all valves. Prep floor. 9/15/2008 00:00 - 04:00 4.00 BOPSU P DECOMP Pressure test BOPE to 250 / 3500 psi against the TWC with 2-7/8" test joint, - ,per egu ations. Test witnesse by NAD toolpusher and BP/ WSL. 04:00 - 08:00 4.00 WHSUR P DECOMP PU New Opso Lopso, break out pup joint and MU 3" LH Acme. MU and test lubricator to 500 psi and pull TWC, LD Lubricator and Opso Lopso. 08:00 - 09:00 1.00 PULL P DECOMP MU landing joint, BOLDS, pull tubing hanger. PUW = 70K 09:00 - 10:00 1.00 EVAL P DECOMP Pump 68 bbls seawater down tubing, and hang cable trunk in Derrick. LD landing joint with 3" LH Acme XO. 10:00 - 12:00 2.00 EVAL P DECOMP P11 / RIH with 2-7/8" Tubinq from pipe shed from 8 016' MD_ and taq fill with 18 full additional joints of Tubin = 8,582' M~. This gives 94' of rathole below the bottom pert. Confer with Anchorage Engineering on tag depth and plan forward. 12:00 - 22:30 10.50 PULL P DECOMP POOH with existin 2-7/8" ESP Completion laying down the 18 Joints back in the Pipe Shed and standing back the remainini Tubing in the Derrick. Maintain co`nfinuous o e fill with seawater while POOH. Average hourly loss rate = 4 bph. LD and replace 4 bad joints. 22:30 - 00:00 1.50 PULL P DECOMP Break out and lay down ESP assembly. Recovered 3 = Printed: 9/30/2008 11:55:48 AM • Page 2 of 2 Operations Summary Report Legal Well Name: MPJ-06 Common Well Name: MPJ-06 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 3S Date 'From - To II Hours I, Task Code NPT Spud Date: 9/11 /2008 Start: 9/11 /2008 End: 9/17/2008 Rig Release: 9/17/2008 Rig Number: Phase Description of Operations 9/15/2008 22:30 - 00:00 1.50 PULL P DECOMP Flatguards, 132 =LaSalle clamps, 5 Protectolizers. 9/16/2008 00:00 - 01:00 1.00 PULL P DECOMP Continue to break out and lay down ESP assembly. Motor spins free, Pump is locked-up. 01:00 - 02:00 1.00 PULL P D ECOMP Clean and clear rig floor. 02:00 - 03:00 1.00 PULL P DECOMP Change out spools in Spooler and snake over sheave in Derrick. Load new ESP motor and pump into pipe shed. Milne Point PE's dressed GLM's in pipe shed. 03:00 - 05:30 2.50 BUNCO RUNCMP PU / MU ESP pump and motor assembly from Wipe shed. Fill hole every hour - 5 BPH loss rate. 05:30 - 13:30 8.00 BUNCO RUNCMP F3JH with 2-7/8". 6. - d Tubina ESP Completion from the Derrick. Maintain continuous hole fill with seawater while RIH. Utilizing Best-O-Life Pipe Dope and make up torque of 2,300 ft-Ibs. Stopping every 2,000 ft to check the pump and cable. Fill the Tubing with seawater and flush the pump at a rate of 0.75 bpm / 1,100 psi. 35 stands (70 Jts) in at 0900 hrs. 100 stands (200 Jts) in at 1200 hrs. 13:30 - 18:30 5.00 BUNCO RUNCMP Stop with 235 Joints in the hole due to not enough ESP Cable on the Spool. Have extra reel delivered to location. Perform reel to reel splice with Centrilft reps. Hold safety meeting with Nabors Drilling Superintendent, Toolpusher, BP WSL and Rig Crew. Maintain continuous hole fill with seawater while in the meeting and splicing the reels. 18:30 - 19:30 1.00 BUNCO RUNCMP Resume RIH with 2-7/8" Tubing from the Derrick. 19:30 - 20:00 0.50 BUNCO RUNCMP Fill the Tubing with seawater and flush the pump final time with 10 bbls at a rate of 0.50 BPM / 520 psi. 20:00 - 20:30 0.50 BUNCO RUNCMP MU landing joint and tubing hanger with FMC rep. 20:30 - 22:30 2.00 BUNCO RUNCMP Centrilift make ESP penetrator splice. 22:30 - 23:00 0.50 BUNCO RUNCMP Land tubing hanger, SOW = 54K, PUW = 72K, FMC tech 23:00 - 00:00 1.00 BUNCO RUNCMP FMC tech d rod TWC, test TWC to 3,500 psi from above for 10 charted minutes. LD landing joint. 9/17/2008 00:00 - 04:00 4.00 BOPSU P RUNCMP Blow down fill lines and drain BOPE stack. ND BOPS and place in shipping cradle. ND 7-1/16" X 13-5/8" flange by flange spool. Clean pits. 04:00 - 06:00 2.00 WHSUR P RUNCMP NU 7-1/16" tubing head adaptor and Tree. Test hanger void to 5,000 psi for 30 minutes. 06:00 - 07:00 1.00 WHSUR P RUNCMP Pre-tour checks, service the Rig. Fill the Tree with diesel and pressure test to 5,000 psi. Centrilift perform final checks: phase to phase = 3.2 ohms, phase to ground = 1 Gig-ohm, bottomhole pressure = 2,910 psi, Temp at motor = 159.6 degF, Temp at intake = 159.5 degF. 07:00 - 08:00 1.00 WHSUR P RUNCMP PUMU Lubricator with Well Su ort Techs. Pressure test to 500 si wi _ "H" TWC and set BP LD Lubricator. Secure the Tree and Cellar. The Rig was released at 0800 hrs on 9/17/2008. Printed: 9/30/2008 11:55:48 AM • STATE C}F ALAS1tA 11/14107 OIL AND GAS CONSERVATION COII~NIISSION BaPE Test Report sub~~t ~: Contractor: Nabors Rig No.: 3S DATE: 9/15/2008 Rig Rep.: Gene Sweatt / R. Bjorhus Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: Bp Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: J. Menke ! D. Rhodes Field/Unit & Well No.: MP J-06 PTl7 # ?9r48,S5f3 Operatiorr. Drlg: Workover. x Explor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250!3500 Annular:. 250/3500 Valves: 250/3500 TEST QATA MISC. INSPECTIONS: Test Result Test Resutt Location Gen.: P We4! 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 i 3 518 5000 P Pipe Rams 1 2 718 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind P Choke Ln. Valves 1 3118" 5000 P HCR Valves 2 3 118" 5000 P Kill Line Valves 1 2 1116" 5000 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 0 NA Lower Kelly 0 NA Bail 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 Test Result System Pressure 3100 P Pressure After Closure 1800 P 200 psi Attained 30sec P Fug Pressure Attained 145 P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 1900 Test Results Number of Failures: II_ Test Time: 4 Hours Repair or replacement of equipment witi be made within Inspector 659-3607, foflaw with written confirmation to Supervises at: Remarks: Tested with 2 7/8" test ioirrt against Two way check 24 HOUR NOTICE GIVEN YES X NO _ Date 09113108 Time 15:00 Test start 0:00 Finish BOP Test (for rigs) BFL 11/14/07 ~~° Sir ~: ~ 2008 Components tested ALL days. Notify the North Slope By Witness John Nabors 3s BOP Test MP J-06 9-15-2008.x1s I STATE OF ALASKA~.Qb RECEIVED ALAS Oil AND GAS CONSERVATION COM.O,;l- DEC 1 8 2006 REPORT OF SUNDRY WELL OPERATIONS AI k D·' . as a J & Gas Cons. Commission rage o Re-Enter Suspended Well ~ Other Change Out ESP . 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P,O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: 99519-6612 o Plug Perforations 0 Stimulate o Perforate New Pool 0 Waiver o Perforate 0 Time Extension 4. Well Class Before Work: 5. Permit To Drill Number: ~ Development 0 Exploratory 194-095 - o Stratigraphic 0 Service 6. API Number: 50-029-22493-00-00 ~ Repair Well ~ Pull Tubing o Operation Shutdown 66 ADL 315848 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Length Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 8800 7324 8735 7268 80' 2482' 8741' 9, Well Name and Number: MPJ-06 . 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 13-3/8" 112' 112' 2730 1130 9-518" 2511' 2462' 5750 3090 7" 8780' 7307' 7240 5410 9. {f''ti M ,) 8330' - 8488' 6915' - 7052' 2-7/8",6.5# L-80 8027' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): None Treatment description including volumes used and final pressure: 13. Oil-Bbl Re resentative Dail Avera e Production or In'ection Data Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory 0 Development 0 Service ~ Daily Report of Well Operations 16. Well Status after proposed work: ~ Well Schematic Diagram ~ 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. Sundry Number or N/A if C.O. Exempt: Contact Bryan McLellan, 564-5516 Title Technical Assistant Sign ure Form 10-404 Revised 04/20l) R , GIN A, L Prepared By Name/Number: Date l1- - ''''¡'~CXo Sandra Stewman 564-4750 Submit Original Only . Tree: 2 9/16" - 5M Wellhead: 11" 5M FMC Gen 6 MPJ-06 Tba. Hna: 27/8" x 11" FMC w/2 71P¡' NSCT T&B and 2.5" CIW H BPV profile 13-3/8" K-55 54.5 #/ft [=:§QJ 9-5/8", 40#/ft,L-80, 6trs Csg I 2,511' I 27/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift ID = 2.347", cap. = 0.00592 bpf) KOP @ 1200' Max. hole angle = 45 deg. 3500'-7400' Hole angle thru' perfs = 30 deg 7" 26 ppf, L-80, NSCC production casing (drift ID = 6.151", cap. = 0.0383 bpf) PERFORATING SUMMARY Rei. Log: GR-CCL (08/15/94) Size s I Perforation md tvd 3-318 6 8330' - 8338' 6914'-6922' 3-318 6 8418' - 8488' 6990'-7047' PBTD 8735' 7", 26#111, L -80 BTRC 8800' Date 09/07/94 02-06-95 11/20/00 1/15103 09/06/06 12/10/06 By JJM RRW MOO MAS REH REH Comments COIL COMPLETION CT-ESP RE-COMPLETION ESP RWO remove coil com . ESP RWO remove LLC valve ESP RWO Nabors 4ES ESP RWO Nabors 3S Nabors 4-ES Nabors 4-ES . Orig. KB Elev. = 46.67 (N 22E) Orig. GL Elev. = 17.00 DF To Tbg. Spool = 46.6~ Cameo 2 7/8" x 1" sidepocket KBMM GLM Cameo 2 7/8" x 1" sidepocket KBMM GLM 2-7/8" XN-Nipple (2.25" 10) GPPOIS pump discharge head Centrililt Pump Model: SXO Type: 137P17 Tandem Gas Separator GRSFTXAR 400 series ~ ~ ~ ~ ~ Tandem Seal Section - 513 series r:::::::-l GSB30BUTJABHSNPFSA ~ 228 HP KMH 2305V/60A Motor 7993' 'rerate to 195 HP 2145V/52A KME-' Pumpmate XTO Sensor ~ Standard 6 lin centralizer ~ MILNE POINT UNIT WELL J-06 API NO: 50-029-22493 B.P.X. (ALASKA) INC. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-06 MPJ-06 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 12/2/2006 Rig Release: 12/7/2006 Rig Number: 3S Spud Date: 7/19/1994 End: 12/2/2006 00:00 - 00:30 0.50 MOB P PRE Continue Safety Stand Down. 00:30 - 04:00 3.50 MOB P PRE Prepare for Rig move to MPJ-06. 04:00 - 21 :00 17.00 MOB N PRE WOW to lower Derrick. Winds gusting to 35 mph on location. Nabors 3S requires < 25 mph to lower Derrick. 21 :00 - 00:00 3.00 MOB P PRE Wind died down. Lower Derrick and RD Nabor 3-S. RDMO 12/3/2006 00:00 - 06:00 6.00 MOB P PRE Mave Carrier, Pipe Shed and Camp from F-Pad to J- Pad. 06:00 - 10:00 4,00 MOB P PRE Move Rig and Pits from F-Pad to J-Pad. 10:00 - 14:30 4.50 MOB P PRE Set Rig Mats & Herculite. Spot Pits and Rig. Berm up Rig 14:30 - 18:00 3.50 MOB P PRE Raise and scope Derrick. 18:00 - 00:00 6.00 MOB P PRE Accept Rig @ 18:00 hrs. Hook up circulating lines to tree and Tiger Tank and Test lines. 12/4/2006 00:00 - 01 :00 1.00 MOB P PRE Continue RU Hardline to Tiger Tank and Test. 01 :00 - 02:00 1.00 DHB P DECOMP RU lubricator to tree and pull BPV 02:00 - 02:30 0.50 KILL P DECOMP RU to bleed off Pressure and circulate Seawater. 02:30 - 05:30 3.00 KILL P DECOMP PJSM. TBG Pressure- 610 psi, CSG Pressure- 650 psi, OA pressure- 250 psi. Start bleeding off gas to Tiger Tank, Bled down TBG pressure to 550 psi. Start pumping 100 bbls Seawater dawn TBG taking returns to Tiger Tank @ 2 bpm/ 360 psi. Shut down to swap circulating lines. 05:30 - 11 :30 6.00 KILL P DECOMP Reverse Circulate 480-Bbls @ 4 BPM @ 720 psi while taking returns to the Tiger Tank until retums were clean, TBG Pressure @ 3.2 bpm/420 psi with well full of seawater. Shut down and monitor for 1 hour. TII/O/=230/230/500 11 :30 - 16:00 4.50 KILL P DECOMP Bleed OA to 50 psi. Swap lines to circulate, Continue monitoring well. MI sending out 9.4 ppg brine for well kill. Phase 2 at Milne Point. Wait for both vac trucks to be loaded so they can caravan from MI to location. 16:00 - 18:00 2.00 KILL P DECOMP Load pits with brine. PIT lines to 2500 psi. Pulsation dampener failed during pressure test. Troubleshoot failure. 18:00 - 23:00 5.00 KILL N DECOMP Repair pump's pulsation dampener. 23:00 . 00:00 1.00 KILL P DECOMP PIT surface lines and blow down, 12/5/2006 00:00 - 02:30 2.50 KILL P DECOMP PJSM on Well Killing operation. SITp· 230 psi, SICP- 200 psi. Start circulating kill weight fluid (9.5 ppg) ICP- 560 psi @ 3 bpm wI 230 psi CSG pressure. FCP- 420 psi @ 3 bpm with kill weight fluid at the bit. Continue circulating until 9.5 ppg returns, FCP- 490 psi @ 3 bpm, 330 bbls pumped in total. Lost 30 bbls to formation during circulation. 02:30 - 03:30 1.00 KILL P DECOMP Shut in well and monitor pressures. SITP- 0 psi, SICP- 0 psi. Open well to monitor, CSG and TBG on slight vac. Well Dead. 03:30 - 04:30 1.00 KILL P DECOMP RU and set TWC. Test TWC to 3500 psi from above. 04:30 - 07:00 2.50 WHSUR P DECOMP ND Tree, 07:00 - 17:00 10.00 BOPSU P DECOMP N/U BOPE 17:00 - 00:00 7.00 BOPSU P DECOMP PJSM - Function test BOPE. Hoses incorrectly hooked up. Troubleshoot and rig properly. Begin BOPE testing 250 psi low, 3500 test high. Jeff Jones - AOGCC waived witness test. Leak developed through tattletale weep hole in bottom of pipe ram door assembly indicating pipe ram piston primary seal packing leaking. PUMU 2-7/8" Test Joint and close 2-7/8" x 5-1/2" VB Rams. Pressure up to 3500 psi. leak stops. Bled pressure off and repressured to 250 psi and leak resumed. Decision made to replace ram door before completing BOPE testing. Tested choke manifold valves while awaiting arrival of Printed: 12111/2006 1:42:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-06 MPJ-06 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 12/2/2006 Rig Release: 12/7/2006 Rig Number: 3S Spud Date: 7/19/1994 End: pipe ram door assembly. Tested choke manifold valves while awaiting arrival of pipe ram door assembly. 01 :30 - 03:30 WAIT DECOMP Waiting on replacement pipe ram door assembly to arrive on wellpad, 03:30 - 06:00 RREP DECOMP PJSM - Rigging lines and lifting equipment to move pipe ram door assembly into rig cellar. Replacing pipe ram door assembly. 06:00 - 11 :30 RREP DECOMP Change out pipe ram door with new o-rings I seals etc. Re-install rams. Re-rig choke line and other valving which had been removed. MPU Well Support shot fluid level with echometer. Sonic FL in IA @ 150'. Rig up and gravity feed IA with 3 Bbls 9.5-ppg brine. Fluid level by volume is 100-ft. Calculated kill weight fluid overbalance is 49,4-psi. 11 :30 - 12:00 0.50 BOPSU N RREP DECOMP Function test all BOPE components. 12:00 - 18:00 6.00 BOPSU P DECOMP Resume pressure testing of BOPE wI 250 psi and 3500 psi. Complete BOPE testing. 18:00 - 22:00 4.00 PULL P DECOMP PJSM. Rig up floor. Clear rig floor of all personnel. Perform derrick inspection and ice removal from derrick. PUMU Lopso-Opso and lubricator to pull TWC. Drift TWC through XO on Lopso-Opso - tight fit. MPU Well Support personnel pull TWC. Had to use rig tugger to pull TWC through XO on Lopso-Opso. SITP = O-psi, SICP = O-psi. UD lubricator. BOLD Lopso-Opso. 22:00 - 00:00 2.00 PULL P DECOMP PUMU 3-1/2" IF DP landing joint with floor safety valve. MU 3-1/2" IF x 3" LH Acme BxP XO to landing joint. Screw landing joint into top hanger thread. FMC serviceman BOLDS, Unland Tubing Hanger and hoist to floor. PUW = 65K, Note: Upon seeing Tubing Hanger at floor, FMC serviceman points out that lockdown screws are not engaging compression ring on top of hanger in proper area. Centrilift serviceman disconnect lower field attachable ESP Cable connector from wellhead penetrator and measure electrical resistance readings downhole. Readings unbalanced and low. Centrilift serviceman cut lower field attachable ESP cable connector from downhole cable and measure electrical resistance readings downhole. Resistance readings now balanced and normal. Electrical fault in lower field attachable ESP Cable connector. Set Landing joint back in mouse hole. BOLD 10' Tubing pup joint. Cut ESP Cable aff below cable splice located 8' below Tubing Hanger. Centrilift measure electrical resistance readings in downhole ESP Cable. Readings all normal. Fill hole w/3-Bbls. 9.5-ppg brine. 12/7/2006 00:00 - 05:00 5.00 RUNCO RUNCMP PUMU landing joint/Tubing Hanger. Centrilift serviceman assemble new field attachable ESP Cable connector to downhole ESP Cable. FMC install new hanger penetrator and reconnect ESP Cable. FMC supply machined shim ring for top of Tubing Hanger to allow adequate energization of hanger packing ring. 05:00 - 06:00 1.00 RUNCO RUNCMP Land Tubing Hanger. PU w1 of 65K. RILOS. Dry rod inTWC. Test TWC to 1000-psi from above for 10 charted minutes 06:00 - 17:00 11.00 BOPSU P RUNCMP PU 3 1/2" joint with "swizzle stick" and wash stack. Nipple down BOPE. Printed: 12/11/2006 1:42:55 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-06 MPJ-06 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 12/2/2006 Rig Release: 12/7/2006 Rig Number: 3S Spud Date: 7/19/1994 End: 12/7/2006 17:00 - 20:00 3.00 WHSUR P RUNCMP NU 2 9/16" 5M Tree and test Tree and void to 5000-psi. Centrilift perform final electrical checks. Good results, PUMU Lubricator. Pull TWC. Set BPV. UD Lubricatar. Secure cellar. Inspect well pad area around rig and release rig @ 2300-hrs. RDMO MPJ-06. prepare to move to GPS W-29i. WOW. Wind speed +30-MPH at 90 degrees to derrick. Max. wind speed allowable to lay derrick over = 30-MPH. 12/8/2006 20:00 - 21 :30 21 :30 - 22:30 22:30 - 23:00 23:00 - 00:00 00:00 - 06:00 1.50 WHSUR P 1.00 WHSUR P 0.50 DEMOS P 1.00 DEMOS P 6.00 DEMOB P RUNCMP RUNCMP POST POST POST Printed: 12/11/2006 1:42:55 PM RECe:\Vt::U . STATE OF ALASKA ALA Oil AND GAS CONSERVATION COMelON OCT 0 4 2006 REPORT OF SUNDRY WELL OPERATIONS 0·, & G S Cons Commission ,~'aska I a . . 1. Operations Performed: n. v o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver 181 Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 194-095 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22493-00-00 7. KB Elevation (ft): 66 9. Well Name and Number: MPJ-06 8. Property Designation: 10. Field / Pool(s): ADL 315848 Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 8800 feet true vertical 7324 feet Plugs (measured) None Effective depth: measured 8735 feet Junk (measured) None true vertical 7268 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 112' 112' 2730 1130 Surface 2482' 9-5/8" 2511' 2462' 5750 3090 Intermediate Production 8741' 7" 8780' 7307' 7240 5410 Liner DO,,,, SCJitNNEn NO\! Ü 2: 2. ì\jU Perforation Depth MD (ft): 8330' - 8488' Perforation Depth TVD (ft): 6915' - 7052' 2-7/8",6.5# L-80 8026' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Dailv Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 101 39 355 390 356 Subsequent to operation: 0 0 0 350 0 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory o Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o 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 Howard West, 564-5471 Printed Name Sondra Stewman Title Technical Assistant %~~Z'Cf\··~ Prepared By Name/Number: Phone 5CcC['(J ¡Sf) Date ¡O~ (ÌI.+-O(p Sondra Stewman, 564-4750 Form 10-404 Revised 04/20"06 ~~I~IIVI",", gn, U L í () 5 Z006 Submit Original Only ORIGINAL . Tree: 29/16" - 5M Wellhead: 11" 5M FMC Gen 6 M P J -06 Tbo. Hno: 27/8" x 11" FMC w/2 7/8" NSCT T&B and 2.5" CIW H BPV profile 13-3/8" K-55 54.5 #/ft L:§QJ 9-5/8", 40#/ft,L-80, Btrs Csg I 2,511' I 27/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift 10 = 2.347", cap. = 0.00592 bpf ) KOP @ 1200' Max. hole angle = 45 deg. 3500'-7400' Hole angle thru' perfs = 30 deg 7" 26 ppf, L-80, NSCC production casing (drift 10 = 6.151", cap. = 0.0383 bpf) PERFORATING SUMMARY Ref. Log: GR-CCL (08115/94) Size s f Perforation md 3-318 6 8330' - 8338' tvd 6914'-6922' 6990'-7047' 3-318 6 8418' - 8488' PBTD 8735' 7", 26#11I, L -80 BTRC 8800' Date 09/07/94 02-06-95 11/20/00 1115/03 09/06/06 B JJM RRW MDO MAS REH Comments COIL COMPLETION CT-ESP RE-COMPLETION ESP RWO remove coil compo ESP RWO remove LLC valve ESP RWO Nabors 4ES Nabors 4-ES Nabors 4-ES . Orig. KB Elev. = 46.67 (N 22E) Orig. GL Elev. = 17.00 OF To Tbg. Spool = 46.6~ Cameo 2 7/8" x 1" sidepocket KBMM GLM Cameo 2 7/8" x 1" side pocket KBMM GLM 2-718" XN-Nipple ( 2.25" 10 ) GPPOIS pump discharge head CentrìlHt Pump Model: SXD Type: 137P17 Tandem Gas Separator GRSFTXAR 400 series ~ ~ ~ ~ ~ Tandem Seal Section - 513 series r:=::--l GSB30BUTIABHSNPFSA ~ 228 HP KMH 2305V160A Motor 8001' 'rerate to 195 HP 2145V/52A KME-' Pumpmate XTO Sensor ~ TVO 6653' Standard 6 fin centralizer MILNE POINT UNIT WELL J-06 API NO: 50-029-22493 ~ B.P .X. (ALASKA) INC. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rjg Name: MPJ-06 MPJ-06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 9/3/2006 9/5/2006 Spud Date: 7/19/1994 End: 9/5/2006 9/3/2006 03:00 - 04:30 1.50 RIGD P PRE 04:30 - 06:00 1.50 MOB P PRE 06:00 - 07:30 1.50 RIGU P PRE 07:30 - 09:00 1.50 RIGU P PRE 09:00 - 10:00 1.00 KILL P DECOMP 10:00 - 11 :30 1.50 KILL N SFAL DECOMP 11 :30 - 12:00 0.50 KILL P DECOMP 12:00 - 12:30 0.50 KILL P DECOMP 12:30 - 13:00 0.50 WHSUR P DECOMP 13:00 - 16:30 3.50 KILL P DECOMP 16:30 - 17:00 0.50 WHSUR P DECOMP 17:00 - 18:00 1.00 WHSUR P DECOMP 18:00 - 20:30 2.50 BOPSU DECOMP 20:30 - 00:00 3.50 BOPSU DECOMP 9/4/2006 00:00 - 00:30 0.50 BOPSU P DECOMP 00:30 - 01 :00 0.50 WHSUR P DECOMP 01 :00 - 02:00 1.00 PULL P DECOMP 02:00 - 04:30 2.50 PULL P DECOMP 04:30 - 06:00 1.50 PULL P DECOMP 06:00 - 06:30 0.50 PULL P DECOMP 06:30 - 09:30 3.00 PULL P DECOMP 09:30 - 11 :00 1.50 PULL P DECOMP 11 :00 - 12:00 1.00 PULL P DECOMP 12:00 - 14:30 2.50 RUNCO RUNCMP 14:30 - 19:30 5.00 RUNCO RUNCMP 19:30 - 22:00 2.50 RUNCO RUNCMP 22:00 - 23:00 1.00 RUNCO RUNCMP 23:00 - 00:00 1.00 RUNCO RUNCMP RD Sub Base and other modules. Scope and lower Derrick. Begin moving Rig Components to MPJ-06. Spot Rig Sub Base, Pipe shed, and Pits. Raise and scope Derrick. Take on 2% KCL in Pits. Accept Rig at 09:00 hrs. Spot Tiger Tank. Lay Lines. IA valve on wellhead is leaking. Wait on Grease Crew. Grease Crew grease and service IA valve. Function valve. Now holding pressure. Repeat pressure test. Still holding pressure (500 psi behind valve). Continue to rig-up line to IA valve. Pressure test Lines at 250/3500 psi. Pick-up Lubricator. Pull BPV. Lay down same. PJSM for Well Kill Operations. Bleed Gas. Pump down tubing and take returns to Tiger Tank at 3 4 bpm/560 - 600 psi. Continue circulating until returns were clean. Pumped a total of 475 bbls. Monitor well, both sides on a vac. Set TWC with FMC representative. Attempt to test from below by pumping 20 bbls, no pressure seen. Test from above to 1,000 psi for 10 mins - charted. ND Adapter Flange and Tree with FMC representative. Inspect Hanger threads and they are 3" LH Acme. Pre-tour safety meeting. NU BOPE. PJSM. Test BOPE per BP/AOGCC Requirements to 250 psi low and 3,500 psi high. The state's right to witness the test was waived by John Crisp. Drain BOP Stack and RD Test Equipment. RU Lubricator and pull TWC with Well Support Tech. The Tubing is on a vac. RD Lubricator. MU Landing Joint. BOLDS with FMC rep. IA is on a vac. Screw Landing Joint into Hanger (Hanger threads are 3" Left Hand Acme). Pull on Hanger and came free at 80K. Pull Hanger to the Rig Floor with 76K up weight. Cut ESP Cable with Centrilift rep and pull over Sheave. Lay down Hanger and Landing Joint. POOH with existing 2 7/8" ESP Completion. Stand back all Joints of 2 7/8" Tubing in the Derrick. Double displace well with 2% KCL while POOH. PJSM. Cut and slip 84' of Drilling Line. Lub Rig. Inspect Derrick. Check PVT Alarms. Finish tripping out with 2 7/8" tubing and failed ESP Assembly. Lay down ESP Assembly (bad cable...several places where the cable was blown-out). Load ESP sections in shipping boxes. Clear and clean floor. Make-up and service new ESP Assembly. Pull ESP Cable over sheave. Attach cable to motor and test. Trip in with new ESP Assembly and 2 7/8" Tubing. Note installed a new XN-Nipple with a 2.250" No-Go. With 3 stands of Tubing left (9 Joints) , had to stop to make reel to reel splice. Continue RIH with new ESP Assembly on 2 7/8" Tubing. Final P/U Wt = 71 K , SIO Wt = 50K. Ran a total of 132 LaSalle Clamps, 5 Protectolizers and 3 Flat Guards. Make up Hanger and install Penetrator. Begin making field connector splice. Printed: 9111/2006 11:50:14AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rjg Name: MPJ-06 MPJ-06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rjg Release: Rjg Number: 9/3/2006 9/5/2006 Spud Date: 7/19/1994 End: 9/5/2006 Finish making field connection and check conductivity of cable and ESP - good. 01 :00 - 01 :30 0.50 RUNCO RUNCMP Land Tubing Hanger with FMC representative. RILDS. 01 :30 - 06:00 4.50 WHSUR P RUNCMP PU T-Bar and set TWC with FMC representative. Attempt to test from above and not able to get a test to 1,000 psi. PU Lubricator and pull TWC. Set 2nd TWC - no joy. PU Lubricator and pull TWC. Set 3rd TWC - no joy. Functioned all LOS and Gland Nuts to ensure seal. Attempt to test again - no joy. Suspect Hanger is culprit. Pick-up Lubricator and pull TWC. Prep to pull Tubing Hanger to floor and inspect. 06:00 - 07:30 1.50 WHSUR P RUNCMP Pick-up Landing Joint. Pull Tubing Hanger to floor to inspect. Disconnect ESP Cable, pulled ESP Penetrator, pulled Dummie Penetrator. Found no reason visiually why TWClTubing Hanger would not hold pressure. Make-up new Tubing Hanger. Install new ESP and Dummie Penetrators. 07:30 - 08:00 0.50 WHSUR P RUNCMP Re-connect ESP Cable and re-test. Good test. 08:00 - 09:00 1.00 WHSUR P RUNCMP Set TWC and test from top at 1200 psi for 10 minutes. Good test. Unable to test TWC from the bottom side. No recordable wellhead pressure (Well on vacuum). 09:00 - 09:30 0.50 WHSUR P RUNCMP Rig down test equipment. Drain BOP Stack. Blow down Lines. 09:30 - 11 :00 1.50 BOPSU P RUNCMP Nipple-down BOP Stack, Test Spool, and Dual Flange Adaptor. 11 :00 - 12:00 1.00 WHSUB P RUNCMP Nipple-up Adaptor flange and Production Tree. 12:00 - 14:30 2.50 WHSUB P RUNCMP Pressure test Hanger Seal to 5,000 psi. However, pressure kept bleeding oft. Pulled Tree to inspect Hanger Seal. Install Tree. Re-torque lock-down screws. Re-test Hanger Seals to 5,000 psi x 10 minutes. Good test. Centrilift performed final ESP Check as follows: 3.2 Bal, Intake pressure 2449 psi, Motor Temp 169.3 degs, Intake Temp 177.1 degs. 733 Meg Ohms. 14:30 - 15:30 1.00 WHSUB P RUNCMP Pick-up Lubricator and pull TWC. Lay down same. Set BPV. Attempt to test BPV. No Wellhead pressure, Well on vacuum. 15:30 - 16:00 0.50 RIGD P RUNCMP Secure Cellar. Release Rig at 16:00 hrs. Prep to RDMO. Printed: 911112006 11 :50:14 AM 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 = 66' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2402' NSL, 2066' EWL, SEC. 28, T13N, R10E, UM X = 552106, Y = 6014800 MPJ-06 At top of productive interval 9. Permit Number / Approval No. 194-095 982' NSL, 1053' EWL, SEC. 21, T13N, R10E, UM X = 551057, Y = 6018653 10. APl Number At effective depth 50-029-22493-00 1128' NSL, 1012' EWL, SEC. 21, T13N, R10E, UM X = 551015, Y = 6018798 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 1159' NSL, 1004' EWL, SEC. 21, T13N, R10E, UM X = 551006, Y = 6018829 Sands 12. Present well condition summary Total depth: measured 8800 feet Plugs (measured) true vertical 7324 feet Effective depth: measured 8735 feet Junk (measured) Lost 108 Bands and 5 Flat Guards (RWO, 11/00) true vertical 7268 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 13-3/8" 250 sx Arcticset I (Approx.) 112' 112' Surface 2482' 9-5/8" 488 sx PF 'E', 250 sx Class 'G' 2511' 2462' Intermediate Production 8741' 7" 400 sx Class 'G' 8780' 7307' Liner Perforation depth: measured 8330' - 8338', 8418' - 8488' true vertical 6915' - 6922', 6991' - 7052' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, tubing to 8023' Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Averaae Production or Injection Data OiI-Bbl ~as-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 certify ~ing is true and_._cerrect to the best of my knowledge Signed Sondr~S~tewman '~~~ ~ Technical Assistant Date l'"') ~-- I ~ (-") 2j Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 srlr. -JlS BFL FEB 21 ?.00.3 ,%CA~NNIE~.~. !~/~,~ ~ " ' ~ t ~ (~;) ~l~it In Duplicate BP EXPLORATION Page 1 of 4 Operations Summa Report Legal Well Name: MPJ-06 Common Well Name: MPJ-06 Spud Date: 7/19/1994 Event Name: WORKOVER Start: 1/6/2003 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/13/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 1/6/2003 12:00 - 13:00 1.00 MOB P PRE PJSM. SCOPE DOWN & LAY OVER DERRICK. 13:00 - 16:00 3.00 MOB P PRE MOVE RIG COMPONENTS F/MPE-06 TO MPJ-06. 16:00 - 19.00 3.00 MOB P PRE SPOT SUB, MUD PIT MODULE & PIPE SHED. 19.00 - 21:00 2.00 MOB P PRE PJSM RAISE & SCOPE UP DERRICK. RIG UP RIG ACCEPTED @ 21:00 HRS 01-06-2003. 21:00 - 00:00 3.00 KILL P DECOMP PJSM P/U LUBRICATOR, PULL BPV. SlTP 550 PSI, SICP 550 PSI. RIG UP TO KILL WELL. TAKE ON 130 DEGREE SEAWATER. TEST LINES TO 3500 PSI, OK. 1/7/2003 00:00 - 00:30 0.50 KILL P DECOMP PJSM:DISCUSS WELL KILL OPS W/ALL ASSOCIATED PERSONEL, EMPHASIS ON AWARENESS/COMMUNICATION, & MONITORING OF LINES. 00:30 - 03.00 2.50 KILL P DECOMP CIRCULATE DOWN TUBING @ 4.5 BPM, 950 PSt, TAKING RETURNS THRU CHOKE TO TIGER TANK. MOSTLY OIL W/ LITTLE GAS BACK CIRC 352 BBLS & DIVERT CLEAN RETURNS TO MUDPITS. BULLHEAD (5) BBLS @ 2 BPM / 400 PSI INTO FORMATION.., (LLC VALVE LEAKING OR PARTIALLY OPEN). MONITOR WELL...VACUUM BOTH SIDES. 03:00 - 03:30 0.50 BOPSUF P DECOMP SET 2 WAY CHECK & TEST @ 2500 PSI, OK. 03:30 - 05:00 1.50 BOPSUF P DECOMP NIPPLE DOWN TREE & REMOVE FROM CELLAR. 05:00 - 09:30 4.50 BOPSUF P DECOMP NIPPLE UP 13 5/8" x 5M BOPE & ADAPTER FLANGE. 09'30 - 17:30 8.00 BOPSUF P DECOMP PERFORM FULL TEST ON BOPE. INVESTIGATE & ISOLATE SLOW LEAK, LEAKING BY 2 WAY CHECK. PULL 2 WAY CHECK, INSPECT & RUN NEW ONE. (1) FAILURE, MANUAL CHOKE VALVE. DRAWDOWN TEST ON ACCUMULATOR & TEST KELLY. AOGCC STATE REP JEFF JONES WITNESSED ALL TESTING. 17:30 - 22'00 4.50 BOPSUF P DECOMP RECONFIGURE VALVES IN CELLAR & CHANGE OUT BAD CHOKE VALVE AND TEST. 22'00 - 23:30 1.50 PULL P DECOMP PULL TWC WITH LUBRICATOR.SLIGHT BLOW ON TUBING.PUMPED 20 BBLS DOWN TUBING AND MONITORED. L/D LUBRICATOR. 23:30 - 00.00 0.50 PULL P DECOMP M/U LANDING JOINT AND BACKOFF LOCK DOWN SCREWS. PULL HANGER TO THE FLOOR (65k). L/D HANGER. 1/8/2003 00:00 - 00:30 0.50 PULL P DECOMP M/U LANDING JOINT AND BACKOFF LOCK DOWN SCREWS. PULL HANGER TO THE FLOOR (65k). L/D HANGER. 00:30 - 05:00 4.50 PULL P DECOMP PJSM. POOH, STAND BACK 2 7~8" TBG & SPOOL UP ESP CABLE. RECOVERED ALL ESP CLAMPS. WELL STABLE. 05:00 - 09:30 4.50 PULL P DECOMP INSPECT AND L/D ESP ASSEMBLY. L/D PUMP ASSEMBLY. PUMP (20) BBLS TO FILL HOLE. FLUID LEVEL APPROXIMATELY 60' DOWN FROM ROTARY TABLE. 09:30 - 11:00 1.50 FISH P INTERV M/U FISHING / CLEAN OUT BHA #1. 11.00 - 18:00 7.00 FISH P INTERV PICK UP 3 1/2" DP & RIH W/FISHING BHA. 18:00 - 19:00 1.00 FISH P INTERV CLEAN RIG FLOOR. 19:00 - 21:00 2.00 FISH P INTERV RIH W/3 5" DRILL PIPE AND P/U KELLY. TAGGED AT 8265' MD (4ES KB) 21:00 - 22:30 1.50 FISH P INTERV P/U 30'. CIRCULATED HOLE CLEAN. RECOVERED 94 BBLS OF OIL/SEAWATER. 22:30 - 00:00 1.50 : FISH P INTERV ROTATE AND WORK DOWN OVER LLCV TO 8267' MD REVERSE CIRCULATE WHILE P/U OFF OF LLCV. 13P EXPLORATION Page 2 of 4 Operations Summa Report Legal Well Name: MPJ-06 Common Well Name: MPJ-06 Spud Date: 7/19/1994 Event Name: WORKOVER Start: 1/6/2003 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/13/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 1/8/2003 22:30 - 00:00 1.50 FISH P INTERV BREAKDOWN AND SET KELLY BACK 1/9/2003 00:00 - 04:00 4.00 FISH P INTERV POH. BREAK OUT AND LAY DOWN BHA#1. NO BANDS RECOVERED. 04:00 - 04:30 0.50 FISH P INTERV M/U BHA #2. OVERSHOT W/4" GRAPPLE TO CATCH (3.97") FISHNECK ON LLC VALVE. 04:30 - 06.00 1.50 FISH P INTERV RIH. 06:00 - 06:30 0.50 FISH P !INTERV SERVICE & LUBRICATE RIG. 06:30 - 08:30 2.00 FISH P INTERV CONTINUE IN HOLE W/3 1/2" DP. TAG FISH @ 8268' 08'30 - 10:00 1.50 FISH P INTERV KELLY UP. 135K UP WT, 92K DOWN WT & 11OK ROTATING WT. SET DOWN ON FISH NUMEROUS TIMES, SEEING OVERPULLS TO 150-155K, & FISH SLIPPING OFF. ROTATED DOWN OVER & WORKED TO ACHIEVE BITE W/ OVERSHOT. SET UP TO 40K ON FISH. PUMP PRESSURE INCREASED FROM 2 BPM / 800 PSI TO 2 BPM / 1500 PSI, PICKED UP & PRESSURE REMAINED OPT TO POOH & SEE WHAT WE CRAMMED IN THERE. 10:00 - 10:30 0.50 FISH P INTERV POOH. PULLING WET. 10'30 - 11:00 0.50 FISH P ]INTERV DROP BAR & OPEN PUMPOUT SUB. 11.00 - 14:00 3.00 FISH P INTERV POOH. 14'00 - 15:30 1.50 FISH P INTERV BREAK DN BHA. RECOVERED (2) FLAT GUARDS, & SECTION OF FLAT GUARD INSIDE OVERSHOT GRAPPLE, BELIEVE THIS CAUSED GRAPPLE TO SLIP OFF FISH. OPT TO RERUN OVERSHOT. 15'30 - 17:00 1.50 FISH P INTERV CLEAN AND CLEAR RIG FLOOR. W/O RUNNING TOOL. 17.00 - 18:00 1.00 FISH P INTERV P/U AND M/U BHA #3. OVERSHOT DRESSED W/4" GRAPPLE. 18:00 - 20:30 2.50 FISH P ~INTERV RIH. TAGGED FISH 8268' MD. 20:30 - 21:30 1.00 FISH P INTERV KELLY UP 135K UP WT, 92K DOWN WT & 110K ROTATING WT. SET DOWN ON FISH NUMEROUS TIMES, NO ENGAGEMENT OF FISH ROTATED DOWN OVER & WORKED TO ACHIEVE BITE W/OVERSHOT. SET UP TO 40K ON FISH. PUMP PRESSURE WAS 800 PSI @ 2 BPM. NO OVERPULLS OR OVERPRESSURES. 21.30 - 23:30 2.00 FISH P INTERV POH WITH 3 1/2"DP AND BHA #3. 23'30 - 00:00 0.50 FISH P INTERV SLIP AND CUT DRILL LINE. 1/10/2003 00.00 - 00:30 0.50 FISH P INTERV SLIP AND CUT DRILL LINE. 00:30 - 02:30 2.00 FISH P INTERV CONT TO POH W/DP AND BHA #3. BIO BHA #3 (NO RECOVERY). 02:30 - 03:00 0.50 FISH P INTERV M/U BHA #4, BURN SHOE..6.125" OD, 4.75" ID. 03'00 - 07:00 4.00 FISH P INTERV RIH W/BHA #4. TAG UP 9' IN ON JT # 255 @ 8267'. 07.00 - 10:00 3.001 FISH P !INTERV PICK UP KELLY. 140K UP WT, 94K DOWN, 105 K ROTATING WT. CIRC RATE 4.5 BPM @ 1000 PSI, 12K WOB. ROTARY TORQUE 8000-10,000 FT/LBS. PUMP 30 BBL N-VIS SWEEPS AS NEEDED INITIAL LOSS RATE APPROXIMATELY 50 BBLS / HR, BUT DROPPED SlGNICANTLY TO LESS THAN 5 BBLS / HR AFTER 1-2 HRS OF MILLING. SOME FINE METAL COMING BACK OVER SHAKER. MILL TO 8269'. 10.00 - 16:00 6.00 FISH P INTERV CONTINUE MILLING TO 8270'. LENGTH OF LLC VALVE APPROX 58". LAST 10' IS 5.7" OD. MILLING SLOWING DOWN @ 8271', AND VERY LITTLE FOOTAGE MADE FROM 13'00 HRS TO 15:30. SUSPECT K ANCHOR MAY BE SPINNING. USE VARIOUS TECHNIQUES, BUT NOT Printed 1/14/2003 2 50 21 PM SCANNED ~AR :~. 0 2003 ~ BP EXPLO~TION: Page 3 of 4 Operations Summary Report Legal Well Name: MPJ-06 Common Well Name: MPJ-06 Spud Date: 7/19/1994 Event Name: WORKOVER Start: 1/6/2003 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/13/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT PhaSe Description of Ope[ations 1/10/2003 10:00 - 16:00 6.00 FISH P INTERV MAKING ANY HOLE & NOT SEEING ANY DOWNHOLE TORQUE. 8.5 HRS TOTAL TIME ON MILL. 16:00 - 20.00 4.00 FISH P INTERV BRK OFF KELLY. MONITOR WELL, LOSS RATE PICKED UP. POOH, OVERDISPLACING PIPE, WELL STABLE. 20:00 - 21 00 1.00 FISH P INTERV BRK OFF SHOE. APPROXIMATELY 6-8" OF LLC VALVE PROTRUDING FROM END OF SHOE. RECOVERED 53" OF LLC VALVE AND MAYBE 1-2 QUARTS OF MILLED METAL IN JUNK SUBS. M/U NEW MILL, 4.75" ID, 6.125" OD. 21'00 - 00.00 3.00 FISH P INTERV RIH W/BHA # 5. 1/11/2003 00:00 - 00'30 0.50 FISH P INTERV CONTINUE IN HOLE W/BHA #5 TO MILL PKR. TAG UP @ 8271'. 00:30 - 05:00 4.50 FISH P INTERV PICK UP KELLY. 137K UP WT, 92K DOWN WT, 105K ROTATING WT. CIRCULATING @ 4.5 BPM / 1000 PSI. 7000-11,000 FT / LBS OF TORQUE ON BOTTOM. 5-10K WOB. SEEING TORQUE SPIKES @ 8273'. POPPED FREE 05:00 - 07:00 2.00 FISH P INTERV PUSH PACKER TO 8291' & CIRCULATE BOTTOMS UP @ 4 BPM, LOSING 20 BBLS PER HOUR W/CIRCULATING. 07:00 - 08:00 1.00 FISH P INTERV SINGLE IN TO 8391' TAG UP HARD. 08:00 - 11:30 3.50 FISH P INTERV POOH W/MILLING ASSEMBLY.., SOME OVERPULLING AT THE ONSET, WORK THRU PERF AREA. 11:30 - 13:30 2.00 FISH P INTERV L/D MILL, SMALL AMOUNT OF METAL IN JUNK SUBS PICK UP 5 7/8" OVERSHOT DRESSED W/4.75" GRAPPLE. M/U FISHING BHA. 13:30 - 16:00 2.50 FISH P INTERV RIH W/FISHING BHA ON 3 1/2" DP. 16'00 - 16:30 0.50 FISH P INTERV PICK UP KELLY. 136K UP WT, 85K DOWN, 105K ROTATING. 4 BPM / 800 PSI, TAG TOP OF FISH @ 8391' & SET DOWN 10K. PICK UP & ROTATE OVER @ 50 RPM, SEE OVERSHOT DROP OVER FISH, ROTATE DOWN TO 8396' & KICK OUT ROTARY TABLE. SET DOWN 30K & PICK UP, SEE OVER PULLS TO 165K 16:30 - 21:00 4.50 FISH P INTERV POOH W/FISHING ASSMEBLY & FISH. 21:00 - 23:00 2.00 FISH P INTERV BREAK OUT & LAY DOWN FISH, RECOVERED PACKER, SCREENS & TAILPIPE, 25 62'. M/U 6 1/8" BIT & CLEANOUT BHA. 23:00- 00:00 1.00 CLEAN P INTERV RIH W/CLEANOUT BHA. 1/12/2003 00:00 - 02:30 2.50 CLEAN P INTERV CONTINUE IN HOLE W/CLEANOUT BHA. TAG FILL, (HARD) @ 8419'. 02:30 - 06:00 3.50 CLEAN P INTERV KELLY UP & CLEANOUT TO 8550', WASHING / ROTATING DOWN & THEN REVERSING OUT @ 5 BPM / 950 PSI. LOSING 30 BBLS / HR WHILE REVERSING. 06:00 - 10:30 4.50 CLEAN P INTERV CONTINUE TO CLEANOUT, TAG UP HARD @ 8711', PBTD. LOSS RATE W/REVERSE CIRCULATING DROPPING TO 15-20 BPH. 10:30 - 13:30 3.00 CLEAN P INTERV PUMP 50 BBLS HI VIS SWEEP & REV CIRC @ 3 BPM / 500 PSI. STD BACK KELLY & BLOW DOWN LINES. 12.30 - 22:00 9.50 CLEAN P INTERV PJSM BREAK OFF KELLY & POOH LAYING DOWN DP. 22.00 - 23'00 1.00 CLEAN P INTERV CLEAR / CLEAN RIG FLOOR. PREP TO RUN ESP COMPLETION STRING. 23 00 - 00:00 1.00 RUNCO~ ~P COMP PJSM ON RUNNING COMP STRING. RIG UP SPOOLING UNIT. 1/13/2003 00:00 - 03:30 3.50 RUNCO~ ~P COMP M/U CENTRILIFT PUMP ASSEMBLY & ESP CABLE, ATTACH, TEST & SECURE, OK 03.30 - 06.00 2.50 RUNCO~ ~P COMP RIH W/2 7/8", 6.5~, EUE 8 RND COMPLETION STRING & Printed 1/14/2003 2 50 21 PM SCANNED MAR 1 0 2003 BP EXPLORATION Page 4 of 4 Operations Summ-a Report Legal Well Name: MPJ-06 Common Well Name: MPJ~06 Spud Date: 7/19/1994 Event Name: WORKOVER Start: 1/6/2003 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/13/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 1/13/2003 03:30 - 06:00 2.50 RUNCO~ P COMP ESP CABLE. WELL STABLE. 06:00 - 06:30 0.50 RUNCO~ P COMP LUBRICATE / SERVICE RIG. 06:30 - 11:30 5.00 RUNCOI~ P COMP RCONTINUE IN HOLE W/ESP COMP STRING, CHECKING ESP EVERY 2000' 11:30 - 13:30 2.00 RUNCOI~ P COMP PICK UP HANGER, INSTALL PENETRATOR, Aq-FACH FIELD CONNECTION, PLUG IN & TEST, OK. 13:30 - 14:30 1.00 RUNCOI~ P COMP LAND HANGER, RILDs. SET 2 WAY CHECK & TEST TO 3500 PSI, OK. 14:30 - 16:30 2.00 WHSUR P COMP NIPPLE DOWN BOPE. 116:30 - 20:00 3.50 WHSUR P COMP NIPPLE TREE. TEST VOID & TREE / 5000 PSI, OK. PERFORM FINAL TEST ON ESP CABLE, OK. PULL 2 WAY CHECK, SET BPV. SECURE WELL. RIG RELEASED @ 2000 HRS 1/13/2003. Printed 1/14/2003 2 5021 PM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Julie Heusser, Commissioner Tom Maunder, P. i. Supervisor FROM' Chuck Scheve; SUBJECT: Petroleum Inspector DATE: April 22, 2001 Safety Valve Tests Milne Point Unit J &l Pads ,Sunday April 22, 2001.' ! traveled to BPXs MPU J & I Pads and witnessed the semi annual safety valve system testing. As the attaChed AOGCC Safety Valve System Test Report indicates I witnessed the testing of 17 wells and 34 components with no failures. Lee Hulme performed the testing today; he demonstrated good test procedures and was a pleasure to work with. I also inspected the well houses on these pads during the SVS testing. All the welihouses were very clean and the equipment appeared to be in excellent condition. Summary: I Witnessed SVS testing at BPXs MPU J & I Pads. MPU J Pad, 11:Wells 22 components 0 failures MPU I Pad 6~Wells '!2 components 0 failures 23 wellhouse inspections Attachment: SVS MPU J Pad 4-22-01 CS SVS MPU I Pad 4-22-01 CS X UnClassified Confidential (Unclassified if doc. removed ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: Chuck Scheve Submitted By: 'Chuck Scheve Date: Field/Unk/Pad: Milne Point / MPU / I Pad Separator psi: LPS 140 HPS 4/22/01 sss Well Pemit Separ Set L~ Test Test Test Date ~, WAG, .Number Number PSI PSI Trip, Code Code Code Pass~ GAS or CYCLE I-O1 1900'900 ' ' ' 1-02 1900910 140~ 100 95 P P ' " OIL 1-03 '1900920 140 100 95 ' P P OIL , , , ,, , , , I-~ 190~30 140 1 O0 95 P P OIL 1-06 197'1950 140 1 O0 ~ 95 P P ..... OIL i'-07 ~9515i0 ~40 106 95" P ' 'P OIL 1-08 19~1920 140~ 100 95 P P ........ , , , ., ,, , , , . , , ,, , ,, Wells: 6 Components: 12 Failures: 0 Failure Rate: 0.00% E]~o var Remarks: RJF 1/16/01 Page 1 of 1 SVS MPU I Pad 4-22-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit~ad: Milne Point / MPU / J Pad Separator psi: LPS 140 HPS 4/22/01 i:~':"~:~'~-~:~ ~-?~/~" ~ :"~~ ¢~':<?''~:~'~:~'~-t~: {-~"~i~::'~---~-:"~-~?-~"~i ~'~ ~:'::' ~:~:'~'~i~:'-:~'' 'i'~"?'~"~:~-f ~ ~ ' ~ ': '~:~i '~: ': '- ....... ' i i i i i Well Permit Separ Set L/P Test Test Test Date ou, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCL~ J-01A 1991110 140 100 95~ P P ' OIL J-03 ' ' 1900970 140 100 ' 95 'P P" ' OIL ~-'04 ' ' 1900980 ' 140 100 ' 95! P i~ .... OIL J-05 1910950 140 100 95: P P OIL J-06 1940950 140 100 125 P P OIL , ,, ,, ,, , , , , ,, , , , , , ,, J-07 1910970 140 100 95 P P OIL , J-08A 1991170 140 100 95 P P OIL J-09A 1991140 140 100 110 P P OIL , J- 10 1941100 140 100 95 P P OIL J-11 1941140 J'12 1941180 J'-lS' 1972200 ' ' , , J-19A 1951700 J-2'o ' 1~;/2150 "' J-21 1972000 140 100I, " 95 P P " '0IL j-22 1981240 140 '" 100 95 'P ' P ' OIL J-23 2001200 , ,, , Wells: 11 Components: 22 Failures: 0 Failure Rate: 0.00% U1 oo var Remarks: RJF 1/16/01 Page 1 ofl SVS MPU JPad 4-22-01 CS 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: 66' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2402' NSL, 2066' EWL, SEC. 28, T13N, R10E, UM MPJ-06 At top of productive interval 9. Permit Number / Approval No. 194-095 982' NSL, 1053' EWL, SEC. 21, T13N, R10E, UM 10. APl Number At effective depth 50-029-22493-00 1128' NSL, 1012' EWL, SEC. 21, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 1159' NSL, 1004' EWL, SEC. 21, T13N, R10E, UM Sands 12. Present well condition summary Total depth: measured 8800 feet Plugs (measured) true vertical 7324 feet Effective depth: measured 8735 feet Junk (measured) Lost 108 Bands and 5 Flat Guards (RWO, 11/00) true vertical 7268 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 13-3/8" 250 sx Arcticset I (Approx.) 112' 112' Surface 2482' 9-5/8" 488 sx PF 'E', 250 sx Class 'G' 2511' 2462' Intermediate Production 8741' 7" 400 sx Class 'G' 8780' 7307' Liner Perforation depth: measured 8330' - 8338', 8418' - 8488' true vertical 6915' - 6922', 6991' - 7052' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, HS-70 coil tubing to 7845' with ESP to 7889' Packers and SSSV (type and measured depth) Baker FB-1 packer at 8251'; Camco LLC valve at 8246' 13. Stimulation or cement squeeze summary Intervals treated (measured) ? E ~ 0 ~/ ~ 0 01 Treatment description including volumes used and final pressure Alaska Oil ~: (5~s" .... ,.,0~.. ()or~ln!issioF, ~,.nchorage 14. Representative Daily Averaqe Production or Injection Data Oil-Bbl Gas-Mcr 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 [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~/~~, ~ Title TechnicalAssistant Date 0~-1~)(.¢""'(~)t Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate OPeratiOns Summary Report Alaska 0ii & Gas Cons, Commission ,An~h0ra_qe Legal Well Name: MPJ-06 Common Well Name: MPJ-06 Spud Date: 7/19/1994 Event Name: REPAIR Start: 11/15~2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 4ES Rig Number: t :S~b~ : ~ : ; Date::::;: :: Erom:~::~o;::Hours::;Task::t:~::+:,~;:Phase: : Description of Operations 11/15/2000 14:00 - 18:00 4.00 MOB PRE . Scope down and lower derrick, move off MPU J-20 Location 18:00 - 20:30 2.50 MOB PRE ;Move rig from MPU J-20 to MPU J-06. Spot sub, pits ,and pipe shed. Burm rig. 20:30 - 22:00 1.50 MOB PRE Raise and Scope Derrick. Rig accepted at 22:00 HRS 11-15-00 22:00 - 23:59 1.98 MOB PRE Spot and burro Tiger Tank. Rig Up lines to tree and tiger tank. 11/16/2000 00:00 - 01:30 1.50 WHSUR DECOMP Bull BPV and Fill pits with 8.4 ppg seawater 01:30-04:00 2.50 WHSUR IDECOMP Test lines to 2,500 psi. 1125 psi tbg/1760 annulus. Killwellat3bpmat 100 psi final 5.8 bpm at 1350 psi. Bullheaede influx of 26 bbls. Pumped 400 bbls of seawater before observing returns. Circulated 30 bbls of crude oil to tiger tank. :04:00 - 04:30 0.501 WHSUR DECOMP Monitored well and observed both annulus and tubing on a vacuum. 04:30 - 05:00 0.50 WHSUR DECOMP Set TWCV and tested to 3,500 psi 05:00 - 06:30 1.50 WHSUR DECOMP Nipple down Tree 06:30 - 11:30 5.00 WHSUR DECOMP Nipple Up Adapter Spools and BOPE. Changed Blind rams to Blind Shear rams. Install Bell nipple. Rig Up to test. 11:30 - 14:30 3.00 BOPSUF DECOMP Test BOPE to 250 psi / 3,500 psi, Annular to 2,500 psi. Test witnessed by Jeff Jones of AOGCC 14:30 - 15:30 1.00 BOPSUF DECOMP Drain stack and blow down lines. Make up Lubricatorand pull lubricator. Laydown same. Shoot Fluid level and find fluid at 2,600' from surface. 15:30 - 18:00 2.50 BOPSUF DECOMP Make up landing joint. Held Pre Job safety meeting with all crews, Centrilift, Co-Rep, Toolpushers. Discussed rigging up and pulling of coiled tubing. Rigged up to pull Coiled Tubing 18:00 - 18:30 0.50 PULL DECOMP Pulled hanger to the rig floor. Pick up weight 75 K. Break out and laid down same. 18:30 - 21:00 2.50 PULL DECOMP POH and cut 2 7/8" coiled tubing in 17' pieces. Laid down same Shooting Fluid levels every 500'. Pumping double calculated tubing displacement while pulling out of the hole. 21:00 - 21:30 0.50 PULL DECOMP Crew Change-Held Pre Job safety meeting with all crews, Centrilift, Co-Rep, Toolpushers 21:30 - 23:59 2.48 PULL DECOMP POH and cut 2 7/8" coiled tubing in 17' pieces. Laid down same Shooting Fluid levels every 500'. Pumping double calculated tubing displacement while pulling out of the hole .Maintaining fluid level at 2,500' from surface. 11/17/2000 00:00 - 15:00 15.00 PULL DECOMP POH and cut 2 7/8" coiled tubing in 17' pieces. Laid down same Shooting Fluid levels every 500'-900'. Maintaining fluid level at 2,500 ' from surface. Pumping double calculated tubing displacement while pulling out of the hole. 15:00 - 16:00 1.00 PULL DECOMP Worked Pipe inthrough tight spot at 2,612'. Recovering 50% of flat bands. 16:00 - 20:00 4.00 PULL DECOMP POH and cut 2 7/8" coiled tubing in 17' pieces. Laid down same Shooting Fluid levels every 900'. Maintaining fluid level at 2,500 ' from surface. Pumping double calculated tubing displacement while pulling out of the hole. Pulling tubing slowly and working pipe on each section Continue to recover 2 7/8" Coiled tubing and ESP cable. No bands recovered since 2,600'. 20:00 - 21:00 1.00 PULL DECOMP Worked Pipe inthrough tight spot at 2,400'. Recovering 0% of flat bands. Pulled 15K over string weight. Pumped 20 bbls. of EP Lube Pill down annulus. Worked pipe free. 21:00 - 23:59 2.98 PULL DECOMP POH and cut 2 7/8" coiled tubing in 17' pieces. Laid down same Pumping double calculated tubing displacement while pulling out of the hole. Pulling tubing slowly and working pipe on each section. Continue to recover 2 7/8" Coiled tubing and ESP cable. No bands Printed: 11/28/2000 8:54:10 AM /~nnhnr~?. Legal Well Name: MPJ-06 Common Well Name: MPJ-06 Spud Date: 7/19/1994 Event Name: REPAIR Start: 11/15/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 4ES Rig Number: :DAte :::i :iFro~:~o H~urs] 1 ~cS°udbe ase: ~ i i 7 i: ~::i: t: ::: i Description of Operations 11/17/2000 21:00 - 23:59 2.98 PULL DEGOMP recovered since 2,600'. POH to 1,800' 11/18/2000 00:00 - 03:30 3.50 PULL DECOMP POH and cut 2 7~8" coiled tubing in 17' pieces. Laid down same Pumping double calculated tubing displacement while pulling out of the hole. Pulling tubing slowly and working pipe on each section. Continue to recover 2 7~8" Coiled tubing and ESP cable. No bands recovered since 2,600'. POH to 1,462' 03:30 - 04:30 1.00 PULL DECOMP Work thru tight spot at 1,462' pump 20 bbl EP LUBE Pill 04:30 - 08:30 4.00 PULL DEOOMP POH and cut 2 7/8" coiled tubing in 17'-18' pieces. Laid down same Pumping double calculated tubing displacement while pulling out of the hole. Pulling tubing slowly and working pipe on each section. Continue to recover 2 7/8" Coiled tubing and ESP cable. No bands recovered since 2,600. POH w/CT to 800'. 08:30 - 11:00 2.50 PULL DEOOMP Tubing pulled tight, pulled 55k and slack off weight, pumped 20 bbls of EP Mud Lube and worked 150' of ESP cable out of the hole. Tubing pulled free. 11:00 - 14:00 3.00 PULL DEOOMP POH and cut 2 7/8" coiled tubing in 17'-18' pieces. Laid down same Pumping double calculated tubing displacement while pulling out of the hole. Pulling tubing slowly and working pipe on each section. Continue to recover 2 7~8" Coiled tubing and ESP cable. No bands recovered since 2,600. POH w/CT and Pump to Surface. 14:00 - 15:30 1.50 PULL DEOOMP Inspect and LD ESP. Lost 195 Flat bands in the Hole and 9 Flat Guards. 15:30- 16:00 0.50 CLEAN DEOOMP Clear rig floor 16:00 - 17:00 1.00 CLEAN DEOOMP Rig Up Halliburton Slickline Unit. Held Pre Job Safety meeting with Rig crews and Halliburton. 17:00 - 00:00 7.00 CLEAN DEGOMP Tool string: 2 1/8" 3.5" rollers, rs,qc,8',kj,6',kj,oil jars,lss,qc. Rih w/ 6" wire grab w/wire laced thru it to 22' sim, pooh w/bunch of bands. Rih w/same to 24' sim, pooh w/same 'take wire off. Rih w/6" wire grab to 31' sim, pooh w/7' piece of flat guard. Rih w/same to 32' sim, pooh w/bands & pump cable. Rih w/6" junk basket to 2482' set down ,pooh w/metal pieces. Rih w/6" wire grab to 3236' sim, pooh mit Rih w/6" junk basket to 3241' sim.pooh w/metal debris. Rih w/same to 3248' sim, pooh w/large piece of flat guard. Rih w/same to 3248' sim, pooh w/some bands. 1111912000 00:00 - 04:30 4.50 CLEAN DEOOMP Rih w/same to 3248' sim, pooh w/1 band. Rih w/6" wire grab to 3250' sim, pooh mit Rih w/6" junk basket to 3250' sim, pooh mit. Rib w/same to 3248' sim, brought pump on @ 8 bpm worked to 4020' sim, pooh w/full junk basket of metal fiat guard & pieces of cable. Rib w/same to 5925' sim, pooh w/? full junk basket of same. Rih w/same to 8100' sim, pooh w/3 bands. Rih w/same to 8100'sim, pooh w/small pieces of metal. Recovered a total of 87flat bands with wireline and 2 flat guards. 108 fiat guards left in the hole and 5 fiat guards left in the hole. Fluid level at 2,300' indicated with slick line. 04:30 - 05:00 0.50 CLEAN DEGOMP Rig down Halliburton Slick line unit 05:00 - 06:30 1.50 RUNCOI~I COMP Rig up to run ESP and install ESP cable spool 06:30 - 09:30 3.00 RUNCOI~ COMP picked up ESP, Attach Cable and test 09:30 - 16:30 7.00 RUNCOI~I COMP RIH with ESP and 2 7/8" Tubing to 7,134' 16:30 - 19:30 3.00 RUNCOI~I COMP Make Splice in ESP cable at 7,134' 219 Joints in Hole Printed: 11/28/2000 8:54:10 AM ' ' · ' . ' BP EXPLORATION Page 3 of 3 . , . . _- oPerationS Summary Report Legal Well Name: MPJ-06 Common Well Name: MPJ-06 Spud Date: 7/19/1994 Event Name: REPAIR Start: 11/15/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 4ES Rig Number: · Date ' FrOm -'T° HOUrs ': Task '"S:c~e Phase Description of Operations 11/19/2000 19:30 - 21:00 1.50 RUNCOI~ COMP RIH with ESP and 2 7/8" Tubing to 7878'. 245 joints in the hole 21:00 - 21:30 0.50 RUNCOI~I COMP Make up Hnager to Landing joint 21:30 - 23:00 1.50 RUNCOI¥~ COMP Make field connector splice for hanger, connect field connector to hanger and test. 23:00 - 23:59 0.98 RUNCOI~I COMP Land hanger and Run In Lock Down Screws. Set TWCV and test to 2,500 psi. Lay down Landing Joint and X-O 11/20/2000 00:00 - 02:00 2.00 RUNCOI~I COMP Nipple down BOP 02:00 - 03:30 1.50 RUNCOI~I COMP Change tubing head adapter and NU Tree 03:30 - 04:00 0.50 RUNCOI~I COMP Test Hanger Void and tree to 5,000 psi 04:00 - 06:00 2.00 RUNCOI~I COMP Pick Up Lubricator Pull TWCV Set BPV Secure tree and cellar area. Released rig at 06:00 Hrs 11-20-00 ?'-', ;. :.--~ c , ............ Alaska ()il ~: G,.$..~; Cc.,-i.:;, ,Cumrnission Anchorage Printed: 11/28/2000 8:54:10 AM oN oP- (Seoi o,.:j'i ca 'i k~ater'~'a'i S ;[iavent:or'y D,~:~'lze; 08/08/96 F'ER~alT DATA T DATA._F'LUS itL.IN DATE......I:~ ECVD 9~-~-095 ~6 T 8687~---6980 CH/GR/CCL '1 '10.,,"0B/9ti. 9~+-.--095 ~85 T 8815'-.-2~3a. OH/CDR/ADN ~ 1 ' "' 9~--'-'095 ~OP R 07/1~-~09/0~,-/9a- 11/'0~/9~, 9~+"~095 .... EY R 112-~8800 '11/'0~[/'9~ 9/-~----095 ~'4 L 2500---8800 1 10/' 1 98--~095 Cq/DC TVD L 2t~00~-7~ O0 comp 12//'19/'9/~ 9~.----095 ~L. [..8260'~--8600 1 09/0'1/9h. 98-.-095 CCL L 82/,0-8659 1 10/05/ 9/+.-095 ~C[. L 8200~-8~60 I 10/05/9h 9a---~095 ~3, R L 2500~8700 1 '10/' 9/-¢.~-095 ~R/'DC TVD L 2~00.--7~00 comp 12/' 1 94--'--095 ¢/'CCL L 7000-~8687 1 09/"01/'9/~ Ape (:ir'y d'¥tch samp'l es r'equ'i r'ed? yes "ece~' w;ct;'" ~-es no ~,/,ms 'the ~/e'i '1 cor'ed? yes ~~a'J ys~'s & descr"¥~ved~ Ape ~,/e'i 'i tests r'equ~'ned? yes ~ce~'ved? ~e:~ ~",,~ C O~J ~ E N T S STATE OF ALASKA AL-ASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Pull tubing × Alter casing __ Repair well __ Perforate__ Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2401' NSL, 3215' WEL, SEC. 28, T13N, RIOE At top of productive interval 982' NSL, 1045' EWL, SEC. 21, T13N, RIOE At effective depth At total depth 1159' NSL, 995' EWL, SEC. 21, T13N, RIOE 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 66' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number MPJ-06 9. Permit number/approval number 94-95/Cons. Order #347 10. APl number 50- 029-22493 11. Field/Pool Prudhoe Bay Field~Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 880O 7324 8735 7268 Size feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth RECEIVED M/XR -2 1995 Alaska. 0il & Gas Cons. Commission Anch0r[" Tubing (size, grade, and measured depth) 2-7/8" HS-70 coil tubing to 7845' w/ ESP to 7889' MD Packers and SSSV (type and measured depth) Baker FB-1 Packer @ 8251'MD; Camco LLC valve @ 8246' MD 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-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run ] Daily Report of Well Operations X I Oil x Gas Suspended 17. I hereby certify that ~tl//e_.fo'r, egejn.cc,.s true and¢~orrect to the best of my knowledge. Signed / "~ k...._ t._..,-~_.v___~.~ % Title Drillin~l En~lineer Supervisor Form 10-404 Rev 06/1 ~(88 ¢lP!GlklA! Service SUBMIT IN DUPLIC/ATE(~ BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MPU J-06 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 01/11/95 06:00 SPUD: RELEASE: 01/21/95 01:00 OPERATION: DRLG RIG: WO/C RIG: NABORS 4ES 01/11/95 ( 1) TD: 8800 PB: 8735 01/12/95 ( 2) TD: 8800 PB: 8735 01/13/95 ( 3) TD: 8800 PB: 8735 01/14/95 ( 4) TD: 8800 PB: 8735 MIRU MW: 0.0 PREPARE FOR RIG MOVE TO J-06 SCOPE AND LOWER DERRICK + MATT BRIDGE. MOVE RIG COMPONENTS TO H-PAD. WAIT ON PREPWORK ON J-06 AND WIRELINE WORK ON J-09 BEFORE BEING ABLE TO MOVE ONTO J-06. MOVE SUB FROM H-PAD TO J-PAD AND BACK OVER J-06. CALL OUT SUSTEMS PEOPLE TO REMOVE LIGHT POLE FROM J-12 WELL HOUSE TO ALLOW SUB TO COCK OVER ENOUGH TO LET PIPE SHED CLEAR CABLE TRAY EXTENDING ONTO PAD. PREP TO PU BHA MW: 0.0 SPOT SUB, PITS AND PIPE SHED F/ 30' WELL CENTERS. RAISE AND SCOPE DERRICK. BERM RIG AND FUEL TANK. TAKE ON 10# NACL BRINE. RU OFFSET FLOWLINE. CHECK WELL DEAD. ND DRY HOLE TREE. NU BOPE AND FLOWLINE. PULL 7" FLASE BOWL AND BPV. SET 11" TEST PLUG. RU TO TEST BOPE. TEST BOPE. REPLACED BONNET GASKET AND TIGHTENED I CHOKE MANIFOLD FLANGE. LOAD PIPE SHED W/ 3.5" DP AND BHA. PREP FLOOR TO PU DP. POH W/ FTA #1 MW: 0.0 SERVICE RIG. STRAP AND PU FTA #1. RIH W/ 3.5" DP TO 500' SLM AND DRIFT. DISPLACE DIESEL CAP W/ 10# BRINE. ATTEMPT TO RIH. TAGGED UP ON ICE @ +/- 420' WASH DOWN W/ SINGLES F/ 520 - 680'. RIH PICKING UP 3.5" DP. SLM AND DRIFT. TAG HARD FILL @ 8200'. REVERSE CIRC AND CLEAN OUT F/ 8200 - 8259'. TAGGED SHOULDER ON LLCV @ 8259'. PUMP 2 - 2- BBL XANVIS SWEEPS. LIGHT CARBOLITE RETURNS. CONTINUE REVERSING WHILE HEATING FLUID TILL 110 DEGREES RETURNS. 140 DEGREES IN PITS. POH W/ FTA #1. RIH W/ FTA #3 MW: 0.0 SERVICE RIG. FINISH POH AND LD FTA #1. RECOVERED +/- 25 SS BANDS. MU FTA #2 W/ J-LATCH TOOL. RIH TO 500'_ CHANGE FLOW METER POSITION IN FLOW LINE. RIH TO 8239'. REVERSE CBU. CONTINUE REVERSING & RAISE TO 10#. WASH DN TO FISH @ 8259' ATTEMPT TO LATCH-UP, COULD NOT LATCH. START POH W/ FTA #2. DRIFT STRING. SLIP 42' DRLG LINE. FINISH POH DRILLING STRING. LD FTA #2. SHOE INDICATED WE'D BEEN DOWN TO TOP OF J-LATCH BUT NOT OVER IT. BOTTOM MARKED UP LIKE BANDS STILL AROUND LATCH. MU FTA #3. START RIH. OEIGtI",iAL WELL : MPU J-06 OPERATION: RIG : NABORS 4ES PAGE: 2 01/15/95 ( 5) TD: 8800 PB: 8735 01/16/95 (6) TD: 8800 PB: 8735 01/17/95 ( 7) TD: 8800 PB: 8735 01/18/95 (8) TD: 8800 PB: 8735 01/19/95 ( 9) TD: 8800 PB: 8735 RIH W/ FTA #5 MW: 0.0 SERVICE RIG. FINISH RIH W/ FTA #3. REVERSE CIRC DOWN TO FISH @ 8259'. REVERSE CIRC AND WORK PIPE TO CATCH JUNK. REVERSE CIRC CSG VOLUME. POH AND LD FTA #3. RECOVERED SEVERAL SMALL PIECES OF SS BAND. MU FTA #4 AND RIH TO 8231'. CIRC. HEAT BRINE TO 110 DEGREE OUT W/ HOLT OIL TRUCK TAG FISH @ 8259' LATCH LLCV. RELEASE ANCHOR W/ 30 TURNS TO RIGHT. CBU. MONITOR WELL, STATIC. POH. LD LLCV AND FTA #4. STRAP AND MU FTA #5. START RIH. CBU MW: 0.0 FINISH RIH W/ FTA #5. CUT 90' AND SLIP 42' DRLG LINE. SERVICE RIG. FINISH RIH TO +/- 8230' CBU. MILL ON PKR F/ 8264 - 8267'. PKR DROPPED. PU 3 JTS. TAG TOP OF FISH @ 8334' BREAK CIRC. PUMP 40 BBL XANVIS SWEEP. CIRC. POH. LD FTA #5. CLEAN JUNK BASKETS. MU FTA #6. RIH. WORK ON OS ON FISH. SLIGHT INDICATION OF FISH. CBU. REVERSE FILL @ 8368' MW: 0.0 FINISH CBU/ MONITOR WELL - STATIC. POH. LD FISH AND TOOLS. SCREEN HAD TWO HOLES. ONE T-SHAPED, 2" X 2" X .5", 8" DOWN FROM TOP; AND ONE 1.25" X .5", AT BOTTOM EDGE OF SCREEN. MU FTA #7. SERVICE RIG. RIH. TAG FILL @ 8358' REVERSE CBU. ATTEMPT TO REVERSE FILL. WASHED +/- 3' AND STOPPED WASHING. COULD NOT GET FILL TO WASH DOWN. PU KELLY. WASH AND ROTATE TO 8372'. STAND BACK KELLY. REVERSE AND WASH F/ 8358 TO 8361'. COULD NOT WASH DEEPER. REVERSE CBU. POH. LD 6" MILL AND BIT SUB. MU FTA #8. RIH TO 8359'. REVERSE FILL F/ 8359 - 8368' CIRC WELL CLEAN MW: 0.0 ATTEMPT TO WASH CARBOLITE F/ 8368'. MAKING MO HEADWAY REVERSING OR PUMPING THE LONG WAY. POH. LD MULE SHOE AND CSG SCRAPER. MU FTA #9 AND START RIH. SLIP 42' DRLG LINE. SERVICE RIG. RIH. WASH AND REAM F/ 8368 - 8662' PUMP 20 BBL XANVIS SWEEP AND CBU EVERY 60' FLUID LOSSES ANYWHERE F/ 0 TO 40 BPH. RECIPROCATE AND ROTATE WHILE CBU. PUMP AND DISPLACE 40 BBL XANVIS SWEEP AROUND. HEATING BRINE WHILE CIRCULATING. POH W/ MULE SHOE MW: 0.0 CIRC TO CLEAN OUT AND HEAT BRINE. MONITOR WELL, STABLE. POH. LD MILL AND JUNK BASKETS. MU TIW VALVE, PUMP DOWN SUB AND KELLY. FLUSH OUT BOP STACK. RIH TO 8662' REVERSE CIRC. REVERSE 2- 40 BBL SWEPPS WHILE RECIPROCATING PIPE. STILL GETTING SMALL AMOUNT OF SAND BACK. POH TO 8310'. REVERSE CIRC. WELL CLEAN. NO SAND RETURNS. MONITOR WELL, STATIC. POH W/ 3.5" MULE SHOE. I!AL RECEIVED IvlAR -' 2 i995 Ai.~ka Oil & Gas Cor~s, Commisuior~ Anchor~ ', WELL : MPU J-06 OPERATION: RIG : NABORS 4ES PAGE: 3 01/20/95 (10) TD: 8800 PB: 8735 01/21/95 (11) TD: 8800 PB: 8735 FREEZE PROTECT WELL MW: 0.0 FINISH POH W/ FTA #10. LD TOOLS AND DC. SERVICE RIG. MU BAKER 'FB-i' PKR W/ 20', .020 GAUGE SCREEN, & 'XN' NIPPLE W/ 'PXN' PLUG INSTALLED. RIH ON 3.5" DP TO 8280'. PKR @ 8251' DROP SETTING BALL. SET PACKER. SHEAR OFF. PU 10'. REVERSE CIRC. POH. LD PACER RUNNING TOOL. STRAP AND MU CAMCO LLCV, ANCHOR AND RUNNING TOOL. CROWN-O-MATIC NOT WORKING. REPAIR SAME. RIH W/ LLCV ON 3.5" DP TO 8251'. STING INTO PACKER W/ ANCHOR. SET DOWN 7K. SHEAR OFF LLCV W/ 10K OVER ST WT. LD 3 JTS. REVERSE CIRC. MIX 40 BBL XANVIS SWEEP. REVERSE 40 BBL SWEEP FOLLOWED W/ 40 BBL BRINE, FOLLOWED BY NEW 10# NACL/NABR. DISPLACE WELL TO NEW PLUID. START FREEZE PROTECTING TO 1200'. RELEASE RIG MW: 0.0 FREEZE PROTECT DP AND ANNULUS. MONITOR WELL, STABLE. CUT 84' AND SLIP 42' DRLG LINE. LD 3.5" DP. DISPLACE DIESEL OUT OF HOLE. LD 3.5" DP TO 600' FREEZE PROTECT DP AND ANNULUS W/ 19 BBLS DIESEL. FINISH LD DP AND LLCV SET TOOL. PULL WEAR RING. INSTALL HANGER. RILDS. INSTALL BPV. ND BOPE. NU 7 1/16" DRY HOLE TREE. TEST, OK. RELEASE RIG @ 0100 HRS ON 1/21/95. SIGNATURE: (drilling superintendent) DATE: Gas Gons. Commissiort Anchor[ ro: Rossberg FROM: Fox / Whitlow / Hildreth OPERATION' UPU J-06 Rerun 2 7/8" CT-ESP Completion LOCATION' ANCHORAGE DATE: 02-03-95 I MAIN CATEGORY: IIDRLG IISUB CATEGORY: IICTU Completion I[ I AFE NUMBER" II 0 0 2 SII II II I Top Of LLCV (ft): II 8246 Feet II Bottom of LLCV (ft) II 8280 Feet DATE IITIME I OPERATION 2/3/95 0800 Road Equipment to Milne Point Well J-06. 0945 Held Safety Meeting at Office. 11 00 Spotting Equipment 1230 90 Ton Crane on Location, Set Wellhouse over wellhead, set back two 16k deadman. 1500 RU 7 1/16" BOP Stack and set two heaters in the wellhouse. 1700 Spotted DSR skid and RU hoses to BOP stack. Connect Generator and hook up to wellhouse. Make up guy lines and spot crane 1800 Make-up work window 21 00 MI and spot 4907 Float and position Op's Cab. Make up Hydraulic lines and run electric lines to work window. Start to heat working window 2/4/9 5 0030 Start to switch 2 7/8" reel and Icad Reel # 3-27 on reel stand. 0130 Hold safety meeting on location with BPX and Nowcam Personnel 0200 Pick up Reel # 4-29 off reel stand, Approx 4000' of 2 7/8" CT with 90 Ton Crane and set reel on lowboy. 0400 Prep CT stub in Level Wind /Double blocked) 0430 Pickup Reel #3-27, [Rerun from J-06 original CT Completion]. Set reel in reel stand, Release Crane and rotate spool to install connector. Secure reel and dress stub on reel for CT connector. 0556 Install Reels chain Connector, Position the two CT ends and install the snake. 0620 Pull test the CTC and snake using 800 psig Reel pressure {Good test). 0625 Crew Change out, Pull out test joint out of mOP's and charge Accumulator system, Hold Safety Meeting. 0725 Function Test BOPs and fix Small Hyd Leak. Spot MPU Triplex and called for Diesel to PT. Spot cable spooling trailer. 0830 Pressure tested pipe Rams 300/3500 psi 5 min) and Hydril to 300 / 2000 psig 5 min), Released Pressure 091 8 Remove test joint and pressure test blinds to 300psi. Low & High pressure leak. Blind Ram Element is leaking. Lower FL in the BOP's. 1030 Replacing the Blind Elements 1145 Pressure Test Blinds at (300 / 3500 psig) 5 min OK. RU to start assembling the Centrilift Pump. 1 245 Prep Motor / seals and take fluid samples. RU Motor and Seal and conduct Dielectric Test on Samples. Measuring the Injecton Head for town and RM. 1400 Fluid failed dielectric test, Purge seal section, re-test dielectric - OK, Perform pump QC checks. 1700 Make-up flat cable, band flat cable trays. 1750 Pick-up BHA [discharge head, pups, GLM and CTC]. 1810 Lower BHA in hole with picker, band ESP cable every 15 ft. 1 900 Attempt to repair weight indicator, elec teck on location, repair wiring. Unable to fix electronics 2200 Pick up injector head with 90 ton crane and set on work window. Use new stabbing pin. 2/5/95 0030 Bolt injector head to work window, run CTC through head, check inserts for damage - OK. 0220 Press test little red line, pump 2 bpm at 500 psi with 90 deg MEOH. PUMP 64 BBLS. Press test CT with 2000 psi, internal connector held press OK. 0350 Makeup coiled tubing connector to BHA. Pull test with 20 K, Press test with 2000 psi. - OK. 0455 Set Coil at RKB and set counters at zero ft with CT at false bowl. Electric counter not working. 0530 Start running coiled tubing in hole, banding every 20 ft. 0600 Running pipe, 380 ft in hole. Rig up MEOH trailer to take displ returns fr&mrJ, n~ 0615 Crew Change out at 580'. Changed ot banders. The New ones are not ~al"TtJts~g~(}n~s~/e 0630 TIH banding at 20 ft intervals.(26ft/min) MP J-06, CT-ESP RE-COMPLETION 1 February 15, 1995 MAP, -'2 1995 PAGE i.}JJ & Gas Cons. Commission Anch0r~ JDATE IITIME I OPERATION 2/5/95 0700 TIH at 1100' at/38 ft/min) 071 5 TIH at 1450 at ( 56 ft/min) Changed out banders. The New one is not crimping the bands correctly and the tension is not running uniformly 0732 TIH at 1880 at/48 ft/min) 0738 2000' Check ESP cable (4.7¢z 6) to 6i & 6.5 k Ez ) OK, Cleanout the horse head of scale material left on the pipe after it was pulled on the original completion. 0755 TIH at 48 ftm Check flow in the Tiger tank / No Flow) 081 6 2520 ft ( 25 ft/min average with banding) Below 2000' the CT is clean of material. 0850 3420 ft (Average 26 Ft / rain) 0909 4000' ft Pick wt = 44,000# Hyd Pressure results) (Average = 30 ft/min TIH) Check Cable at 4000' 10.1 .Q Cable to Ground and 5.2 ~ ~ to E~. No flow. Fixed Rack Depthometer in the Cps. Cab. 0957 TIH from 4000'. 1021 4800' TIH at an average speed of 33 FPM. 1053 5800' TIH at an average of 31 FPM 1100 Wt Check at 6000' PUW = 58,000# off Hydraulic Inj. Pressure. Check Cable OK 1127 6640 ' TIH at an average of 31 ft/min. 1 152 Stopped at 7420' and closed the back door on the injector head. 121 0 TIH with CT 1225 Stopped at 7770' / 7850' and set slips. 1235 Drill hole and drained CT through mud bucket, Install collar clamp and cut CT. 131 5 Cut CT and dress ends, Install Tubing Hanger and landing pups. RU to pull test CTC. Pull tested CTC to 80,000#. PU weight = 56,000# Hyd Press. 1446 Set Slips and start to install ESP Cable to the Pentrator. 1545 Pressure test Internally the Pups joints, FMC's Hanger and Nowcam's CTC to 2000 psig above the slips with Little Red Hot Oil Service. 1555 Continue installing ESP Cable to the Pentrator. 1745 Finished Installing ESP to Pentrator and tested, Unset slips and set hanger at top of window. Set counter and set pup in the slips. Crew change out. 1 820 Hanger penetrator about 90 degrees different from when tbg was pulled, set slips, loosen lower coiled tbg connector, rotated landing string above connector 90 deg. Penetrator now in correct position. 1 930 Tighten CT connector, re-pressure test landing string to 2000 psi. OK. 2040 RIH with tbg hanger on landing string. Set slips. Drain fluid from CT. Slow to drain. 221 0 Run out CT, Run out internal CTC through injector head and down to work floor. Cut and lay out sections of CT, Cut CT above internal conn. and dress end of CT make-up CTC. 2330 LANDED CT HANGER, Run in lock down screws. Cut CT above landing joints, back out 12 turns. 02- 0 6 001 0 Pull landing string out of stack with hoist. 0040 Run 2-way check valve thru stack. Close blind/shear rams and press test tubing hanger to 3500 psi. - OK. 01 30 Unbolt injector head, pick head off with crane, set on back of 4907 float. Wind = 20 mph, no problem. 0230 Pick work window and set on trailer with 90 ton crane [wind = 22 mph] - No problem. 0400 Disconnect Hyd. control lines to BOPs, Nipple down BOP stack, VAC hardline from BOPs to tiger tank, Pick BOPs and set in cradle. 0520 Prep empty reel to change out with full reel, for next CT completion. Job Completed. MP J-06, CT-ESP RE-COMPLETION February 15, 1995 -'2 995 Gas Cons. 60mmissi0n Anchor~ PAGE 2 OPERATIONS SUMMARY 02-03-95 1. MIRU CTC COMPLETION EQUIPMENT, RUN CENTRILIFT PUMP ON COILED TUBING STRING PULLED PREVIOUSLY FROM WELL, RUN NEW ESP CABLE. O2-04-95 2. RAN CENTRILIFT TYPE 146 GC-1200 SERIES 513, MODEL GPMT PUMP W/TANDEM SEAL SECTION AND MODEL KME1, SERIES 562, 100 HP MOTOR SECTION AND CENTRILIFT CHECK VALVE. RAN CAMCO TYPE KBMG GAS LIFT MANDREL W/1" POCKET AND DCK GAS LIFT VAVE WITH DCK LATCH IN PLACE. SHEAR SET FOR 3500 PSI TBG TO CASING SHEAR PRESSURE. 3. RAN 6.3 FLAT CABLE GUARDS INCLUDING 38 FLAT GUARD BANDS. RAN 392 PREFORMED BANDS TO BAND ESP TO CT. 02-05-95 4. RAN 7775.40 FT OF CT, 2 7/8" 5.46#, HS-70 COILED TUBING, [2.495" ID.]. BAND ESP CABLE EVERY 20 FT. HUNG STRING OFF WITH FMC 7 1/16" X 2 7/8" TUBING HANGER. 5. BOTTOM OF PUMP ASSEMBLY SET AT 7,889.23 FT BKB. 6. TBG AND ANNULUS FILLED WITH 10.0 PPG BRINE. 7. RIGGED DOWN CTU COMPLETION EQUIPMENT. 02-06-95 8. NIPPLED UP 2 9/16" TREE AND FMC ADAPTOR SPOOL. PRESSURE TEST WITH MPU TRIPLEX. CTC PUMP AND BHA SUMMARY II ITEM Ii MAX OD II ID II Length II Top [bottom to top] (IN) (IN) (FT) (FT) PRESS GAUGE [PHD 21A-02619] 4.50 NA 1.957887.28 MOTOR, 100 bp, [21k-51276, 2145/27] 5.62 NA 11.70 7875.58 SEAL SECTION, [GST-DB, 31G-57230] 5.13 NA 12.61 7862.97 PUMP AND INTAKE [01G-71757, 146 GC1200] NA 17.68 7845.29 DISCHARGE HEAD 4.40/5.15 2.40 0.50 7844.79 2 7/8" EUE 8 RD. PUP JOINT 3.66 2.441 2.23 7842.56 CENTRILIFT CHECK VALVE 3.70 NA 0.41 7842.15 2 7/8" EUE 8 RD PUP JOINT 3.66 2.441 10.45 7831.70 2 7/8" EUE 8 RD PUP JOINT 3.66 2.441 10.48 7821.22 2 7/8" KBMG GLM W/DCK-2T [3500 PSI SHEAR] 4.70 2.371 6.67 7814.55 2 7/8" EUE 8 RD PUP JOINT 3.66 2.441 2.87 7811.68 2 7/8" CT CONNECTOR. 4.23 2.38 1.95 7809.73 2 7/8" COILED TUBING 2.875 2.495 7775.40 34.33 2 7/8" CT CONNECTOR. 4.23 2.38 1.95 32.38 2 7/8" EUE 8 RD PUP JOINT 3.66 2.441 4.22 28.16 FMC TBG hanger [to lock down screws] 6.95 2.441 0.66 27.50 RKB to hanger lock down screws [RKB=30 ft AGL] 27.50 FT cor. 0.00 BOTTOM OF PUMP ASSEMBLY [FT BKB] 7~889.23 MP J-06, CT-ESP RE-COMPLETION February 15, 1995 RECEIVED i'viAF{ -- 2 !995 PAGE3 ~.~ka. 0il & Gas Cons. Commission FLUIDS PUMPED BBLS. 64 MEOH /WATER 60/40 4 Diesel 68 TOTAL MPU J-06 RE-COMPLETION JOB NOTES 1. WEIGHT INDICATOR DID NOT WORK. [THIS PROBLEM IS STILL BEING WORKED]. 2. INTERNAL CONNECTOR WORKED WELL, PRESSURE TESTED TO 2000 PSI -OK. 3. REMOVE UP SLIPS IN WORK WINDOW, WE DON'T USE THEM AND THEY COULD CATCH UP ON SOMETHING. 4. SHORTEN INJ. HEAD STABBING GUIDE BY 4-6 INCHES, IT WAS TO LONG, THE FRAME LANDED ON IT, HAD TO REMOVE GUIDE, TO LAND INJ. HEAD. 5. NEED TO REPAIR ELECTRONIC DEPTH INDICATOR [ELEC. TECH COMING TODAY]. 6. NEED TO EXTEND COPPER GROUNDING STRAP ON GENERATOR BY 40 FT TO ALLOW SPOTTING GENERATOR FURTHER AWAY FROM SKID, LESS CONJESTION. MP J-06, CT-ESP RE-COMPLETION February 15, 1995 · RECEIVED R.T. -GL = 30 FT TREE: 2-9/16"/5000 psi / (SSV ACTUATOR) MAX DEV -- 45.6 MEG WELLHEAD: 7-1/16" / 5000 psi / FMC @ MD = 5382 9-5/8", 40#/ft,L-80, Btrs Csg 2,511 f ~ 5.46 #/FT, HS-70CM 2.44" ID 2-7/8" GLM , CAMCO KBMG No. MD-BKB TVD-ss #1 7815' 7779' ~ ~ PUMP CHECK VALVE 7,842' ~ ESP PUMP/SEALS/MOTOR/GAUGE MAX OD 5.62", PRESS GAUGE AT 7,889' CAMCO LLC VALVE 8,246' W/ BKR SEAL ASSEMBLY & PATCH LATCH 22 FT LONG [ 20 GAUGE ] ~ · ~" 3-1/2" XN NIPPLE 8,278' PERFORATING SUMMARY · Ref. Log: GR-CCL (08/15/94) 2.813" ID, 2.75" NO-GO [PXN PLUG] = -' WLEG 8,280' CO SIZE SPF INTERVAL STATUS Atlas 3-3/8 6 8330'- 8338' Open Atlas 3-3/8 6 8418' - 8488' Open RECEIVED MAR -'-2 1995 · ',;, ~,~--/.iii & Gas Cons. Commission Anchor~ PBTD 8735' I '."'."'.",.",.%.%:',." ,1 "' ,1 '",1 ,',,i ¢, ,1 ,",,i ,~,1 ,~,1 7", 26#/ft, L-80 BTRC 8800' '~ '~ ~" ~ x ,, x .¢ 1,.' .,' ..' ¢' ¢' ..' .¢ Date By Comments MILNE POINT WELL' J-06 09/07/94 JJM COIL COMPLETION 02-06-95 RRW CT-ESP RE-COMPLETION COMPLETIONDIAGRAM B.P. EXPLORATION (ALASKA)INC. ORIGINAL 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) Januaw 19,1995 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data--DEPTH CORRECTED (;:DR ~, ADH was sent to:~ for well MPJ-06, Job # 94278 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape .Sta-t~f Alaska -~ Alaska Oil & Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Drive 501 OXY USA, Inc Attn: Erma Galindo P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape SerK Certified Mail P 905 127 766 Please Note' The wrong MWD gamma ray was on the original tape. The correct MWD gamma ray was used for making the blueline prints. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 Schlumberger Courier: Date Delivered: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPOR~ROAD ANCHORAGE, ALA~ 99518-11 Received By: MEMORANDUM TO' David Joh~''/ THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE- January 11, 1995 Blair Wondzell, P. I. Supervisor FROM: Bobby Fos~'~--~ SUBJECT: Petroleum Inspector FILE NO: AWPIAKCD.doc BOPE Test - Nabors 4ES BPX - MPU - J-06 PTD # 94-95 Kuparuk River Field Wednesday, January 11, 1995: I traveled this day to BPX's MPU well J-06 and witnessed the BOPE test on Nabors rig 4ES. The test began at 10:00 PM and was completed at 2:30 AM -1/12/95. As the attached AOGCC BOPE Test Report shows there were 2 failures. A flange leaked on the choke manifold and a door gasket leaked on the pipe rams. Both items were repaired and retested OK. The location was clear and all extra equipment was stored in the proper bins and racks. The rig crew was in the process of installing a new flow line, but the rig Was still clean. I would also like to note that this rig is now equipped with electronic digi tai gages on the hydraulically controlled choke operational panel. These gauges are very easy to read even at Iow pressures. Summary: i witnessed the BOPE test on Nabors rig 4ES working over BPX's MPU well J-06. Test time 4.5 hours - 2 failures. Attachment: AWPIAKCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial Workover: X NABORS Rig No. 4ES PTD # 94-95 BPX Rep.: MP J-06 Rig Rep.: Set @ 8778' Location: Sec. X Weekly Other DATE: 1/11/95 Rig Ph.# 65g-2235/34 TOM ANGLEN DA N HEB ER T 28 T. 13N R. IOE Meridian U MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N lA Well Sign OK Drl. Rig OK BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F f 300/3,000 P 1 500/5,000 P I 500/5,000 P I 500/5,000 P 2 500/5,000 P 1 5OO/5, OOO P N/A MUD SYSTEM: Visual Alarm Trip Tank N lA NO Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 500/5,000 P f 500/5, OO0 P f 500/5,000 P I 500/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 500/5,000 P 26 500/5,000 P I P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 6 @ 2050 3,000 J P 1,950 P 0 minutes 23 sec. minutes 7 sec. YES Remote: YES Psig. Number of Failures: 2 ,Test Time: 4.5 Hours. Number of valves tested 17 'Repair or'R~i~'men{ of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Failures: Door gasket on pipe rams leaked - replaced and retested. A flange on the choke manifold leaked - thightened and retested. Distribution: orig-Well 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: Witnessed By: BOBBY D. FOSTER FI-021L (Rev. 7/t9) AV~/PIAKCD.XLS 500 W. International Airport Road Anchorage, Alaska 99518-1199 (907) 562-7669 December 19, 1994 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the LWD DEPTH CORRECTED CDR & ADN TVD for well MPJ-06, Job # 94375 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 ~ska /" Alaska Oil & Gas Conservation Comm. ( Attn: Larry Grant ~. 3001 Porcupine Drive '~Anchorage, Alaska 99501 3 Bluelines 1 Film 1 Blueline '-.~,.. -'"~~ 1 RFolded Sepia ~ OXY USA, Inc Attn: Erma Galindo P.O. Box 50250 Midland, Texas 79710 1 Blueline 1 RFolded Sepia Sent Certified Mail P 676 541 382 PLEAS SIGNING AND RETURNING ONE COPY EACH TO- '~ BP EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 Schlumberger Courier: Date Delivered: Received By: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,v~MISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 12. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 94-95 '3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 $0-029-22493 '~.. Location of well at sudace r. ..... 9. Unit or Lease Name ~' Mi/ne Point Unit 2401' NSL, 3215' WEL, SEC. 28, T13N, RIOE: .., /~ ~ , i At Top Producing Interval :i~~'/?./~ ~/~--~ 'il= · ' lO. WellNumber 982' NSL, 1045' EWL, SEC. 21, T13N, RIOE i : and Pool At Total Depth ........... '~'" ; I Kuparuk River Sands 1159' NSL, 995' EWL, SEC. 21, T13N, RIOE 5. Elevation in feet (indicate KB, DF, etc.) ~. Lease Designation and Serial No. KBE = 66' J ADL 315848 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 7/19/94 7/25/94 9/7/94I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ~20. Depth where SSSV set [21. Thickness of Permafrosl 8800' MD/7324' TVD 8735' MD/7268' TVD YES [] NO []I LLLV @ 8290' feet MD ! 1800' (Approx.) 22. Type Electric or Other Logs Run GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 54.5# K-55 32' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 29' 2511' 12-1/4" 488 sx PF "E"/250 sx "G" 7" 26# L-80 39' 8780' 8-1/2" 400 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MDI PACKER SET (MD/ Gun Diameter 3-3/8" 6 spt MD TVD ~ ; F.~ ~ :. ~ :'~~ 2-7/8", L-80 8098' 8290' 8410'-8470' 698457037' ~ ", '~ ~ [ ~ t \ ~'~ Coil Tubing 8318'-8326' 6905'-6911' '~ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 9/10/94 I Flowing- ESP Date of Test Hours Tested PRODUCTION FOR OIL-BBL SAS-MCF WATER-BBL CHOKE SIZ~_. IGAS-OIL RATIO i'EST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-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. R£C£ V£D [qOV - 4 1994 A!~s~ ~Jit & Gas Cons. C0mrnissi0ft Anchor[ Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS r ,.~RMATION TESTS NAME - Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Top Zone C 8426' 6932' Top Zone B 8426' 6932' Top Zone A 8501' 7064' RECEIYED 31. LIST OF ATTACHMENTS Anchorc 32. i hereby certify that the foregoing is true and correct to the best of my knowledge Sig ned * '~J~-~ -~'~.,, Title Dri/linoEnoineerSuoerv[sor Date -/"_' - INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 MP J-06 07/18/94 MOVE RIG FROM C-22 TO J-06. 07/19/94 MOVE TO J-06 AND RU. NU DIVERTER. CHANGE SUB ON TOP DRIVE TO 5". PU HWDP AND STAND BACK, TESTED DIVERTER. ACCEPTED RIG @2300 HR'S ON 07/18/94. 07/20/94 2530' PU BHA AND MIXED SPUD MUD. CHANGED OUT MUD MOTOR. DRILLED ICE PLUG F/40-129'. POH AND PU DC'S. RIH. DRILLED F/129-282'. PU LAST OF BHA. DRILLED F/282-1468'. CBU AND SHORT TRIPPED. NO PROBLEMS. DRILLED F/1468-2530'. CBU. DROPPED EMS AND POH FOR WIPER TRIP. 07/21/94 2,530' POH TO JARS AND RECOVERED EMS. RIH, NO PROBLEMS. CIRC AND CONDITIONED MUD FOR CASING JOB. POH AND LD BHA. RU AND RAN 63 JTS 9 5/8" 40# L80 BTC CASING. CIRC. TESTED LINES. DROPPED BOTTOM PLUG. RU AND DID TOP JOB, RD HOWCO. ND DIVERTER AND NU BOP. TESTED BOPE. 07/22/94 4,531' FINISHED TEST AND CENTERED BOP, NU FLOW LINE. INSTALLED WEAR BUSHING. PU BHA, MUD MOTOR HAD GRAVEL IN ROTOR THAT REQUIRED CLEANING. RIH PU E DP, TAGGED FC @2424'. CIRC AND TESTED CASING. DRILLED OUT SHOE TRACK AND DRILLED TO 2540'. CBU AND DID FIT, 13 PPG EMW. DRILLED F/2540-3584'. CBU AND SHORT TRIPPED. NO PROBLEM. DRILLED FROM 3584-4531'. CONTROLLED RATE TO 60 FPH. CBU AND SHORT TRIPPED. 07/23/94 5,592' FINISHED SHORT TRIP, NO PROBLEM. DRILLED F/4534-4909'. CBU. DROPPED EMS AND POH, RECOVERED EMS AND LD MOTOR. PU BIT AND TURBINE, CHANGED BEARING, SERVICED MWD. SERVICED TOP DRIVE. RIH TO 4830', REAMED TO 4909' PRECAUTIONARY. DRILLED F/4909-5592'. ~.~,~.~ 0~'~ & Gas Cons. Commission ~' Anchor[ ~' 07/24/94 8,055' DRILLED F/5592-5972'. SHORT TRIPPED 11 STANDS, NO PROBLEMS. DRILLED F/5972-7012'. SHORT TRIPPED 11 STANDS, NO PROBLEMS. DRILLED F/7012-8055'. CIRC OUT SWEEP. WIPER TRIP POH. 07/25/94 8,800' POH WIPER TRIP TO SHOE, NO PROBLEMS. SERVICED TOP DRIVE. RIH. DRILLED F/8055-8535'. LOST PUMP PRESSURE AND RIH. DRILLED FROM 8535-8800'. CIRC OUT SWEEP. 07/26/94 8,800' POH TO SHOE SLM, NO PROBLEM. RIH. CIRC AND COND MUD. POH LD DP. SPOTTED LCM PILL. POH, LD JARS AND BHA. CLEARED FLOOR, CHANGED RAMS, PULLED WEAR RING, RU TO RUN CSG. RAN 207 JTS CASING, CBU AT SHOE. 07/27/94 8,800' RU CMT HEAD AND CIRC. MIXED AND PUMPED FIRST STAGE CEMENT JOB, BUMPED PLUG AND OPENED PORTS ON STAGE COLLAR. LOST 44 BBL'S MUD. CIRC BU X 2, MIXED AND PUMPED STAGE 2 CMT JOB DISPLACED AND BUMPED PLUG CLOSED PORTS AND CHECKED FLOATS AND COLLAR. ND BOP AND SET SLIPS, CUT CASG AND INSTALLED PACKOFF, NU BOP, CHANGED RAMS TO 3 1/2". TESTED PACKOFF. CHANGED SUB ON TOP DRIVE, TESTED BOP, INSTALLED WEAR RING, XO BAILS. PU BHA AND RIH PU 3 1/2" DP TO 4990' TAGGED CMT. CUT DRLG LINE AND ADJUSTED BRAKE. DRILLED HARD CMT TO STAGE COLLAR @5013', DRILLED STAGE COLLAR. RIH PU 3 1/2" DP. 07/28/94 8,800' FINISH RIH W/BIT AND SCRAPER. PU 3 1/2" DP. TAG F/C @8735'. TEST CASING. PUMP LO-HI VIS SWEEPS FOLLOWED BY FILTERED 8.4 SOURCE WATER. FINAL PRESSURE 650 PSI. POH. LD 3 1/2" DP. REPAIR PIPE SKATE. FINISH POH L/D 3 1/2" DP AND 6 DC'S. FREEZE PROTECT 7" CASING. PULL WEAR RING AND INSTALL FALSE BOWL HANGER WITH BPV. L/D MOUSE HOLE AND N/D BOPE. N/U TREE AND CHANGE TOP DRIVE TO 5". TEST TREE AND FREEZE PROTECT ANNULUS W/60 BBL'S DIESEL. BREAK MODULES AND PREPARE TO MOVE TO J-09. RELEASE RIG @0430 HR'S ON 07/28/94. R£C£1¥rcD ~\~s[;~ 0[1 & Gas Cons. 6ommission Anchor~ BPX MILNE POINT DALLY WELL ACTIVITY REPOR1- PROJECT: ~c41/ ,~,f~V .... ]SERVICECO: ~-~v~c~ , UN~ O~E~ I ~~ ~" .~PV ~~ ~-~o. ~" ~$~ V'~'~. I I , i I I ! i i ..... ... .. , I , ! _ , i i l i '~ R FC,~iVED , I. iqn'~',,¥ -~-, i~~. J j Anchor: RESULTS: J ~¢~ (~~ . ' II ~ ~ $ [~ ~--~J $ SE~CE PERSONNEL: BPX MILNE POINT DALLY WELL ACTIVITY REPORT i , . ,. t i'~u~ ' ~ ......... I a~,~da Oii & Gas Cons. Commission ,. , r~__ RESULTS: ...... - - C~T SUM~ o~SSV ~' , ~ ..... ~~, ~V: , I . i == , ~i"TOTALS * 5~0~? SUP~SOR; ., H:\GROUP\PRODUCTI~PSWELLS\LOTU S~CTiVRPT. WK1 BPXA-MILNE POIN'I DALLY WELL Ab clVITY REPORT PROJECT: ,~r-.e-~, ~:>,,,,o ~' .~¢.1"-. .. . [sERVIcE CO: /_..,'~/.~..,~¢~.,,~ ?NIT# ~O % RO'l~l""i TO :1.-- ...... ACTIVITY I , . ........ . ,. ..,. -~' I il ....... . " ' .... I ' - ir l¢ · ' · --- .t-~,~.,o,, ii ,4,'~J .... 2;..',,' ' - Lo ,.,.~L? ~,'-~ ~, o o _._ , ,; .... j...¢ r s,/, '//3 I I , , .... .- ~ ...... .- , , ..... · ' .......................... f\g~LI ¥ ~ ..... 'i ...... "~ ... t ~ ....... ~'~,..,V 4 'i9'"~. , ~ Ii · , . I 't ~".r,.,$F.a, L;H'"' d~" uas" O0ils. C0lJiJ'nission . . . ...... : . . - .--. COST SUMM~ SCSSV: OPEN CLOS~ 1BPV: IN ~T . p,.;.~./..... '7'~, ~o~ Ji ..... * ~.~,v,o~ ~s_~_~.¢? ~ ~ ~,-~ ~1 .......... S ' S ENGINER: 3 '~ ~ . ~o,~. ,, ";'~~' ~u~,~o~: -~~;,~o: . ' H: ~G ROU P\PROD UC'f'N\PSWFt_LS\LOTU S~ACTI VRPT. WK1 BPX MILNE POINT DALLY. WELL AC I IVITY REPORT .~O.~CT:.,. ~F. "B" ~~ ~¢r.~'~'~.IS~"v'C~ CO; A~~ 1815' . . t ' L] '/ ";' '] . _ _ ~? ;"" " , ~, ,;~,~s~;a O~[ & Gas Cons. O0rrimissiOn ~ _. .- ~' ' ¢ ' ,.~ .... , ~ -- $ [ $ .... ........ -. ...... ,= s , 'i!TOTAkS .... $ ~UPERVISOR: O.,Fo~, ., H:\GROU P\P ROD U CTN~ SWEU_S~..OTUS~,ACTi VRPT. W K1 -,,,~OCO INC. · ILY WELL ACTIVITY REPORT J DAYSCUM/PLAN: ACTIVITY AT REPORT TIME: FROM I TO ~ , , , H0URSI *C~V~ .T/. ALASKA TEMP/WC: / =F I CURRENTDEPTH: MD RIG S~ PERPORMANCE ALL DAILY COSTS PI~ DAYSW~OUTI , I ,, , S PL~ DESC. I Y~ T© I J S COST SUMMARY DALLY CUMU~TIVE ENVIRONMENTAL INCIDENTS $ PR~IOUSTOTAL $ $ DAYS WITHOUT $ P~NNED $ $ Y~R TO DATE g TROUB~ $ $ _ ~ ~ , ~ST BOPE TEST $ TOTAL $ $ ~PE TE~T DUE $ AFE COST A~CC VlSlT? $ EST. FINAL ENGINEER , ]SUPERVISOR _,,-'X MILNE POINT ~-' DALLY WELL AC"=-VITY REPORT , , PROJ, ECT,: T,c',,~ ~"Y_.l,..z_ T_..t.,x T,.ACO.-,~L~, , !SERVICE~: ~m~ UNIT~ FROM ~ TO i- " .... , i~ i .... - , , ~ ., , . , , , ,, , } ' '' ' 4 ' ' _ .... J [] ' ~XT ~ . __, . , ~ ,~ . ,. . { ........ Anchor: .. -" i '~ '" ,., o~ ~uu o~ c~ O~E W~ ~c~ C~ ~oo ~~ $ ~q~ ,~ $ PLUG/ISg~ON: .... $ ,, . $ SERVICE PERSONNEL: " $ .... $ ENGINEER: H:\GROUP\PRODUCTN~PSWEi_LS\LOTUS~,CTIVRPT. WK1 oPX MILNE POINT DALLY WELL AC'"'--'/ITY REPORT , , PROJECT: ,L_.~A~L ,..~',,~A.//'~ , ISERVICE .C,Q: O~EC~VE: V~~. ,. FROM , , ~ ~' . . , / ~ , ,, . I ,--~ ~t~ m j jJ ~=~N~ O~t'& Gas Cons. Commission ..... > , ........ , , ,, H:\GROUP\PRODUCTN~PSWEIIS\LOTUS~,CTIVRPT.WK1 /~"YW~r~ To: ROSSBERG Location: ANCHORAGE From: Parker i Melvan Date: 9/3/94 Well: MPJ-06 Operation: Set Liguid Level Control Valve Main ,: DRLG Sub Cate, ,: Corn Well Status: Shut In : 700 : 0 : 0 15.00 RU Nowcarh 4,9.05. Run li'ne~ and choke to open top tanK. ...... _ 17,30 PO flanged lubric~to..r., pump-in ,sub,"and .,BOP, 19.00 PU CT C~nne~or. Pump 40 Bbl. Sea WAter thru c0il et max, ~at~ to ¢.lear a~y Carbo-lite from coil. PU ]ars, HydreJulic Dis- connect, check valves, centralizer,,s~ Liquid Level Control Valve. 21.00 Pressure test' io 4000 pal. LubrJcator flange leaking, Tig'hten, re-test':~o 4000 psi; ........ · 1 . , . ! ' ] i _1. i 22.00 Till with tool strin,q: ~3.27 WeigJ~t check( at 8000'--17,0(~0# up. 5',000# down, WHP 850 Psi. (increased'from run~in~3'coil into diesel columr~) 23.36 Tag pk¢'@ 8295 etd, Stack out 5000 #. PU and slacl< off t.,,wice, PU to about 20,000 up wt, broke back. 23.¢0 8'It dwn again. Pu. to 20,000#. Looks ok, Puil to 25,000. Jars went off. N.,o movement,. Pull up to 2,8~000, No movenl~)rlt. .;23,45 Set dwn and co'ck jars. Pick up. Begi.n. workin~l..$hea, r pins to shear off running tool. 23.49 She,~ed off w/:~;;d iar.!!ek. Pu t0,8150. W~P dropped as we pulis.d, up from' 850 to 500 psi.' 2;3.~'3 Bleed off,°asing pres,,_sure to pit. Wait and perform tlow check. . ..... j[~- ~'r' ~ ! ~ i r' r~ 23.56 ,Stop blee, din~ @ 200 pal to see,if we are g.etting well,,entrv. "~- b %, b I ¥ L t.,/ 23.59 Csg bled, to zero. Stream dropPed off to zero.. Wait and monitor.' ...... "" .,, 00,2.e..Begin circ. og! dsl & sea wtr @ 1.5,,bpm, , ,. , ?'~ 0 V - '! ]99 d Oil & Gas Cons. Commission .... PUMP I"CblL I WEL'[. '"- ' '" " TIME DEPTH RATE 01 .~-3 ' 8144 .... 1.5 " 1550 ' 0 " b.e/g, in C~'OH @ 40 fpm'~hile cont: c!,r~. Brine. 50 bbi abo~'e tools. 02.01 -I '64.07 '0 ". ~ Filters. plugged. Stop coil & p, ump. Change filters. 02.36 6407 1.5 1880 0 Resume p~ ullin,q & pu.,rnpin_q 04.28 1350" 1.48 2050 " Well,pressure ballanced-no dete~able losses. Continue disp!acel~nt. '0,~.14 0 1.48/0 At surface. RD/$e.c, ure Wel'l ' 07,0~ .._ ' , .. Leave loca,Uon. .. "' , .... ' igged up ~49~5 w/fJ~'e riser bbl0w bOP's, pU L~O wi Ssa'Is, 'Running t~ol, cen't~'~li~.ers, disco;re;ct, and'jars. Lat~ch~d into packer and pull tested LLC i 1,000 lbs. Jarred 3 times to shear running tool. Bled casing pressure from 850 to 0. psi. No leaking bv LLC. Picked up 150 ft above LLO and circulated hole to 10.1 ppg brine @ 1.5 bpm to reduce mixing. ~--i .... . FLUIDS PUMPED , "", Ii 390 bi~i' ' [ 10.1 i~Pg brine.- .... ,. , ' ........ ' ' ~, ' '- .[ ......... ' .... ' BOT+oM HbL~' A~;SEMB L~Y ....... '" ' I~" I , ' -"' '" " i:o. "O.D. LENGTi:I ITEM (From,Bottom Up), , (Inch,)_ {Inc,,hes)) (Feet) I m Baker Seal Assembly w/Latch ....... 4.0,0 3.00 2.09 .. 3 1/2" 8 Fid. X N~ct X-over 2.85 3.80 1.69 3'~5" LLC-2 (Liquid,Level ~;'0ntrol V~lve) w/running too! ' .., , ' 5.~1 "6.46 2 7/8~"FIo~ Couplings (4 ea.) w/centralizers ..... -' _. , ' ........ 2.._35 5.7.5. 2 3/8" Reg. Box X 2 7/8" 8 Rd Pi,ri. x-over 1.00 ., 3.125 0.82 _. Baker Hydraulic Dis-Connect .. ...0.80 ..3.;375 1,53.. _Dailey Jars (Qpen) _ .. 1.250 3.12,5 Baker Dual Check Valve 1,00 3.125 1.55 Baker Coil T .ubing Connector 1.00 3,125 0.96 ...... TOTAL BHA LENG'I;H §9.41 .. To: ROSSBERG Location: ANCHORAGE From: Parker/Melvan Date: 4 September, '94 Well: MP d~06 Operation: COil Tubing Completion Main ~: DRLG - AFE330025 Sub Cate ,: WellSle, tus: ,Shutine ' 0 ' 0 · 0 84.00 Rig up Nowc~lm 4'~07. Se~ 7 1/16" BOP and CT WindOw ~ec£10n, Me'ye and ~ay I~ne~ to open top tank. Set ~deadmen" a~d ~trtnp ~uy. wires. Spot unit and i~smll coil ~ubing re~l. Spot generator house. S~ Accumulator house and run lines to BOP. 17.00 Te~t BOPE, Test Pipe Rams, Btind/Ghear Rams, Blind Rams to 400 psi and 4000 psi. Test Hydril to 1500 psi. spot ESP r~l house. Stab 2 7/8" Coil Tubing staAer joint into Injector Head. Stab coil into in~e~or head while testin9 BOP's. 20.00 Finish. stabbing, pipe. s~ing, hy~rauli~..~nd., a~ line~., t° work"~indo~. .. . H~ng window. ~arps. spot ESP ~t. ... 2~.~ ~rep ESP equipment while finishing rig up, . 22.~ Pick uP P-gabg~mtr, intake. Pedorm all motor ~A on' floor. PU pu'~p section & ~olt on Same, 'Altered'to ru~ pipe dwn cut off ~- 25 ft. Pipe bounfl up in head. Inspect same. D~scovered insed slipped out and wedged between blocks, Also ~ chewed. ,. up another one a. litte.. Repla~ ~me. Cut off~5 ft. In,peet t~e rest of the blocks..~ 9~ 0¥.3o "' ' ' ...... _. l~t join~ w/pump hd. Fill motor se~ls. RU Lil Red and prep to fill/flush coil, 03.~ PU ,cab,la a~d sheav~e. Rig up sheave, to wo/k win~ow w/~%a~les~, ,~ ........ 05.2~ Flush coil w/70 Obi MEOH. Returns Clean. ~ ..... 06t38 PU ~HA and pl'uB in motor. Strap f~at cpble to,,B~A. ' ...... 10.45 BoSom' GLM Picked up. Begin picking up Injec~o~ Head. Used 55' ~ fl~t cable and splice over to round ~a~je, Used 9 protective trays over tlpt cable. 13.45 lnst~ll Coil Tub'~gg Connector and p~ll test t0 90,00~ ,.~'" ,~ ' , '~ ' .. 13.50 Pressure test Coil and OOmp}etion s~ring ~0 1000 14.07 S~aff ,ip hole w~oil Tubing Inslalling band, on ESP cabl~,~e~ 27. Shutdown °ve~ 1/000' to cl'~u~EOnms'ot E8F Cable. le.4= ~an~ crimping tool broke dwn. Backup also broken. Try to repair one ~o get going again. Connect r~l valve to hop's ~o take MEOH returns from coil. Manliff als.9 ~uit- Call out mechpgic. RU ladder. '21.00 Bander fixed, Mq.nlift fu~l tra%~er pump out. Cont: runnigg,coll, t~ and find r~lace~nt m~glift. ,~, , Zl,2~ Pull test 44,000 lb. ' " IT [L ' ' I L 23.~ 699~ oo;J depth. One'small scar .)O pip.'nOt sgrious.,. Pull test 48',000 lbs. 01.05 7872 CTD. At cut point. Ch.~k ~able. Unable, to pick UP' C6il I~e~tor hea~ not w6rking properly. 03.20 Bleed dwn system pressure. R~b~t system. No change. Go over diagram~ to tr~Ce brake sys[em on head. ~ ' 06.~ ~ear i~tO one Pilot valve. Found long slive~ d rubber, Rem~e ~ame. ~ead worked momentarily then q~t again. Problem mu~t arise from junk in the circulatb~ hydraulic system. Cont. work on head while waiting of ~eaW lift sub. "09.00 Hydraulic.blockage re~ified. ~unctli~n te~'~rake and puli:up aCtiOn. RIH'to 7872 ' O.K~. Hqt ~p ~oil an~.~repare }0 cut'.' 10.~7 qut co~l tubiqg, install Coil ~ubing COn~e~or and .Up~r GLM..r. r .... 11,21 Pdll test to 60, O0O~. Rig up tO pressure te~t. ,, , , 12.54 Pre~sure test ~ 1000 psi. j4_30 Plck.(pg up 10' Pupjt.. Bo. it ring in ~oEom of CTU Window failed allo~ing window a~d Inje~or Hffad to~ to fr°~t_ 18.27 Rig up second 90 ton ~r~ne on li~ing eyes in ~°rK win~ow to stabilize window, ~'9,15 Set I~jectOr He~d'off w/'q~ne. Rig up to ru~ tubin-~,w/orane.=r ' 21.15 Pick' up 2- 10' ~up its on 30 ~ ~nning joint w/slip elevator~, Lo~r in[o Work winnow ah~ make up ~ame. Run in hole. w/ ' puPS- String weight 55,.~0¢ ..... ._21.3~ MU banggr and running t~t t° 16 ~ of STL pups/XO/3Q~ft joint., ~U hanger pup~ tO_,st~ing. ,, . 22.!5 Begin making cable ~plice wi pig/ail. o~.~8 ~nd.?ubin~ H~ng~r. Break out'lanain9 jts~,Be~in ~iggin~dow~., P~ hanger w/FMC pump. , .... . r .i I ~ ~ ~ , Gas C0~s. commission Anchor: 0PERA~I~3N'$' suMM~RY , Ran Centri-Liff t~'e GC-1200 ~-eries 513 primp w/Mg~'~I KME, Serie's 562 10~' h.pl Motor section an'~ CentriLiff'Check Valve 2 its. (63') above pump discharge. Plan Camco type KBMG Gas Lift Mandrel w/1" pocket and Dummy Gas Lift Valve in place I Jr. (31') above Check Valve. Ran 7872' 2 7/8" 5.46# HS-70 Coil Tubing (2.49.5" I.D.). Ran Camco KBM~ Gas Lift Mandrel w/1" pocket and Dummy Ge~ Lift Valve in place 38' below ground level. Hung string off in FMC 7 1/1 X 2 7/8" Tubing Hanger. Bottom of pump assembly at B100' RKB. Ran 9 flat cable guards including 45 flat guard bands. Ran 397 preformed bands to fasten cable to coiled tubing. Inner annulus filled with 10.1 ppg brine. Dummy gas lift valves in 13oth mandrele. T_r_ee nippled up with 2 way check in hanqer. , .._ iii, .. ii. ,= . irl, T I · I ..- I iiiII .- I IIl i I BO'I-rOM HOLE ASSBMBLY 11 ' ' , , , [ ~ III. · ~ ~ ' I ~ =~ ~ I II MAX C~.I~. 'I',D. '"'LEN~iTH ,, , ,, ITEM .. ,,, (Inches) (Inc_h_es)) (Feet) P- Gauge -.,, ,_, , 5.13 NA 1.95' ' Motqr ~, ' ,, ' ' 5.6;~" NA 11.05 . Seal Section .... 6.13 NA 1'~.6 'Pure. P & Intal~e ...... ~ 3.55 ...... NA '- 19.15 2 Jr. 2 7/8" 6.5# L-80 EUE 8 Rb. Tub).n~ " ,_, ' ..... 3.5,5 ,,2.4;4~ 63.o2' Cen,trilift (~t~eck .V...alve ...... 5.13 NA 0.42 I Jt. 2_ 7/8" 6.5# L-80 8 Rd. Tubing 3.55 ......... 2.441 31.58 '[.ower GLM ~sembly w/pu~ Joint. below and Coil Tubin.~,Connector iq,top. " 4.~ ' 2.441 "11.60 ;~-7/8" .Coiled thai. .. 2.875 2.495 7872.00 Top G, LM assembl¥,wJ'2.2' pup by 2.-7/8 coil,..connector. ' , 4.7 -'- 2.4,,41 12.05 ,,Three 10 It p~Uj3S. 3.55 2. ,~H. 1 30_68 Hanger w,/pup it. (to !.ock ~vn screws) ...... ' .... , ,,,6.95 2..~41 6.50 __R.KB to hanger lock dwn screws "' 27.35 Total Len,qth ....... ', . , ' .... .," 8099.§5' ~:~...,,~,s~/,a' rOi~ & G~ Cor~ Commission Anchor; COMPANY BP WELL NAM~ MPJ-06 LOCATi£~ ! MiLNE ~%~iBT L[<~TiON~ ~ A~SKA WAGNFTiC D£CLiNATIC~: 2S,97 DATE: ~.-JUL-94 W~LL '~'~ ..... WELL HEAl: LCCATiC~N: LAT(H/-S) 0+~0 l:m i:.N POiNT(TiP) : TRUE V:?.T D:F'TH 1!2.00 349,45 MICROFILMF. RECEIVED /"./0 V -' ~, 1994 A!asi~a Oil a Gas Con~. Commission Anct~or~. i?. i i '7.-, ,~ ?,% ,": r, :/'.,, ::, 7:.66 35 ~.,, ""_4- 450 ~i: IM-_:,, · des :). :-,::, ': 7 C. ~ :1.; ._~: , i ! 3-:.,. ~.7 ::'R--2, ~'."-' 63.6, 72?.: 2~ .---;,: 543:19 73:4 636~6~' ?2:6 72'; ?: 7 9!2,54 -[:- + .-' ~. ........ ,v'" U ~-:-V ! !: .-"v -i,'-' ~ r: ~-9 93,20 . . -.: ...... _,. '..' -.-, ~c 54: ~ ,'..:c, v:.,,_ 34 -0,6-6 0,52 44,.44 12z', 7C, ".14,47 ?'.'.-' ,. 2". 1005 :lO i i00:63 ~ %0'-' ~-.. t-, 0,7i 0,50 1667,24 ~._. ,j,.: ~, ._:,_. ii,=~, ~,i'.? .:;,:;u ,. 8/ i:,72 (.,,05' .,.._.l~, ...,,_,r:"-- 5,41 ._',ia,._',: ....... !7,7(.,' -~:74 _ i.:,,'o,:"' "'"~' 7,87 --.o~,,.,¢,.. .,.=. 26,70 -10,0:' 4!,56 9,92 '::'-'-*-~"; · . ._- ..... ~'~ "d'- ' -'% ~'; .:--.' :ce- !-'-,~i 3!6,4! 5Z,5S ::,4:s, ,06 337,4,.' 333 "'" 32'?, 4'.? i ,3 2,16 ...-..-.~ 2037:53 .......... L£10 + 70 .... ..._. 6_',Vi: 13 ?_.,, ,~c:. '-= '"'= '" 2!2.70 A8.48 -~7,01 :--. ~.-:', JV .- ........ '.;'5,2:': tA .... :,,._.'-':~, 3!4,75 87,50 -A..< 124.35 2';:,,73 316,45 l lO,CA: -88.51 154,24 ~"zo, x~.,~ .,_,, -:~v, :::,.. --- i35,87 -it2,72', 322,7.'.' '.-_-21,13 '-_-.i?, 7-: L+." ; i .: 7 (:,.6.5 Z448~34 2645,64 2740,5! 19~7 2405,8~ i~7,3 25S2,50 94,6 2750,31 ~5_,,7.-. '-:64.40 '~: 15' · '-' i 7 * LC 319.17 315',75 i,.7:: £,./i 424,8! '.;'8,43 S;:i:91 374,95 ~.-,_-,t.., - -...hi , ?..',& .... ='.~, ^, 2:::..... ._'-.! ,~ i. "-" J ~., ,:, c:-'-'" 4,, C:,~9... ~,ii '"::, ~-' 7': --,,'". :- r.,-': r.; ..-,.,,., + ._.~, O-;: +..' £ C;~,¢: +/:,-:: .:AY :'--:.-' ~-~ ..?--' ,t.,y .~'_;I, ~,_ 4:07 __ : ,77 349S,~3 3570,71 3680,!6 3779,37 55,7 · _~_ . 6/0.y4 /'zi,:= ..... ~,.,.*:; ~46,,)'? -375,71 784.22 39,0~- .... = '= ' ' " "*= "": ="~ !4 72'.'_' 77~,76 62i', 24 ..,.~.- ,, .... ?%.47 337,65 2,61 2.16 1,27 i,17 ft it --.,%%' -. ~' 4 · -.--.., v :-,- ,. ?5,3 4 f~,,t-'S ,04 '.-5."..4.-: ~ 374! ~!51:i2, -'.-.-7-..I ~?=..4, :A':: q: ,A ...... .. ft ':.-'65',5~ !i59~02 !~S, 2.5'-: C_TATi:3N ~i~JTH LATITUDE de:., de: ft ~.li~.U?E 9e<q 335+ 27 ~t- .'.r_- · 2..2.6 ~ v_:' (.-:,5! i 4350~6~ 95+9 77N,75 ~ ~m~-: ~, - ..... 4?li,0a ??,0 4.395,4i ...... ,.~ ,-,-~ ~'~ ,u.'" !214, ,55 ~ ~'~,'.:,-~' ~'"",'.;'2 ~'~ ~ i275,0~ .... *~0 .~.~ = !5~4,74 40,06 351,!i ,~.,.,~'~'~ '" ~4~ ~! 40.49 350,10 i172,2~ .... :-- ~£,~' ~...~:...~ ._.~7.' r~,L ~: i~,' 2, i0 , ._: 7.- 53:30~ ? '.:-.:~27 4,'5-73,79 o-_,., L, .-'-_,92,0 4738,32 54F_.7, ~,:.~ :',= r. O.':= r.-: ¢.~ 7,..: + '..~. ~:'..Y -~, '..' --'- .,_,.._,,,v_, '.;'3+'?4;.771 :" 5,~7,5. ~ ~.-v =:. ........ -~-: 197i,02 45,5~: 350,15 2104,92 ~,7~.. .... o~,,~-~' ....2023,,, 2!72,i7 44,92 ~*~:~c ,~, ~: ~09n,02.... -59,7,54 ~:' .... -' 241 '"'- -A07~77 ic~ ~: ~4~-'" ..... - . + ~'..: -$2~,5,5 2ii?,44 1,4! 73+3! 2239~38 44~37 349,2! 2i56,09 2305,!0 44,45 347,W 222,5,42 2372,75 2~c.,3,77 ~:,L~ ... ........ ~. 2315,5¥ -$?T,64 2452,24 343.47 -7il,A';' 251,5 9'4 ~" ~ _ . ~ ~C ,_:.. ;5.247,40 94.';' 534'.:.- 647_--4,.£.& 94,4 5466:73 ' ;"'~ :~ ',.4 '.~,.,i. ~ + :.' L.. , 2763,85 2827+74, 43,70 346,70 43,76 ~8.17 2005,2'3 -726,3a 256i,93 ?13,66 -755,36 ':~ ~,4'?=, ~ 343 .~,.~5 ....... -/oc:,g4 Z776,.,'b ,. -78! ,,~0 2840 ,~8 344,02 0 ,'5.-0 0,4? '_,! .k ~- + .: '..; .-- ~, 69(:,4 ~ 62 91,: ,57'9:~,5'? 95,0 5-:!9~,7'? 7?5,32 95,7 2890,70 42,68 347,53 2792,6! 2954,70 42,97 349,4& 2855,54 3062,~0 43,62 347,17 I £ ..: rr 7191,07 9'5.7 7~..~. ~--. '5'4,3 6i05,35 : ~. ~..w, '.'..- / .-"cO, ,t,d 7_:-,-'-_': 747523~. 94,7 ,-'.,243,57 7=..71 -,~ :.--~ ,/,~ '.$'A,4 3215,00 43,95 34~,75 3ii0,5! 3345,34 43,36 ~?,0i 3238,48 3410,39 43,37 347,74 ~¢:':?,2~ 3~76,07 42,58 34?,73 3366,63 -A82.A3 to:, Al 5;44,7~ -~';'~.74 .q42;,:'_>4 .5~4 e9 · _-..,,., . . . , ...~ -9')S,57 '3487,08 344,'~0 ._~ 0,77 0, !6 (,,5'1 345.0~ 245,1'3 345,:5 E45,~0 l ,, .;_',7 1,37 95,7 6749~00 61,6 704~,57 343 o~ 4i65,30 29,50 S~,4,&8 4037,64 -1070,06 4i77,02 ,'"...', 500 W. International Airport Road Anchorage, Alaska 99518-1199 (907) 562-7669 October 14, 1994 TO: BP Exploration (Alaska) Inc. Petrotectlnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the I. WD DEPTH CORRECTED CDR & ADN for well MPJ-06 , Job # 94278 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape 1 Depth Shift Monitor Plot 3 Bluelines 1 Film Returning CDR, ADN, CDR & ADN - TVD Field Film State of Alaska : Alaska Oil & Gas COnservation Comm. _ Attn: Larry Grant 3001{'Porcupine Drive Anchk~.r.~ge, Alaska 99501 1OHLISTaPe ~---.. 1 Blueline 1 RFolded Sepia _. OXY USA, Inc Attn: Erma Galindo P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline 1 RFolded Sepi~ ~,, l/c,., Oc'-f. / ,., ' ~ 4/4~k~ "1994 or~ge' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA)INC. PE'fROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE. ALASKA 99519-6612 SCI-ILUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 Schlumberger Courier: Date Delivered: Received By: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 29 September 1994 RE: ~. Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 MARKED LINE GR TAPE 1 GAMMARAY TAPE LISTER 1 MARKED LINE GR TAPE 1 GAMMARAY TAPE LISTER ECC No. Run # 1 6258.00 Run # 1 Run # 1 6259.00 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 /~ Att~/ Rodney D. Paulson Date ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 31 August 1994 RE: Transmittal of Data ECC #: 6259.02 Sent by: ANCHORAGE EXPRS Data: NONE Dear Sir/Madam, Reference: BP MPJ-06 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films,: CCL/PACKR FINAL BL CCL/PERF FINAL BL CCL/PACKR RF SEPIA CCL/PERF RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchors ,AK 99518 ~~Date: K Please sign and return to: Petrotechnieal Data Center BP Exploration (Alaska) 900 East Benson Boulevard Anchorage, AlaSka 99508 Received by Dste ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 29 August 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ECC No. ~,~ ~PJ-06~ 1 PFC/PERF FINAL BL Run # 1 6259.01 1 PFC/PERF RF SEPIA Run # 1 -06 1 GR/CCL FINL.RF SEPIA 1 GR/CCL FINAL BL 1 GR/CCL FINAL BL 1 GR/CCL RF SEPIA Run # 1 Run # 1 6259.00 Run # 1 6260.00 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street RECEIVED Anchorage, AK 99518 ~ ~~ney D. Paulson SEp 0 ] 1994 Received b~f~. ///~~/// //~,~ ~ Dat,,.~r~ Alaska Oil & Gas Oons. Commission Please sign and return to: Petrotechnical Data Center BP Exploration (Alaska) 900 East Benson Boulevard Anchorage, Alaska 99508 Received by ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 14, 1994 Adrian Clark, Drlg Engr Supv BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Company Permit # Surf Loc Btmhole Loc Milne Point Unit MPJ-06 BP Exploration (Alaska) inc 94-95 2401 'NSL, 3215'WEL, Sec 28, T13N, R10E, UM 1198'NSL, 4242'WEL, Sec 21, T13N, R10E, UM Dear Mr Clark: Enclosed is the approved application for permit to ddll 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 ddlling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) 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. Yours very truly, Commissioner BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redril'll-Illb. Type of well. Exploratoryl-] Stratigraphic Testi-i Development Oil[] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 66 feet Milne Point Unit- Kuparuk River 3. Address 6. Property Designation P. O. Box 196~f2. Anchorage. Alaska 99519-6612 ADL 315848 4. Location of well at surface .7. Unit or property Name 11. Type Bond(see 20 ,~c 2s.o2~) 2401' NSL, 3215r WEL, SEC. 28, T13N, RIOE Milne Point At top of productive interval 8. Well number Number IO05' NSL, 4200' WEL, SEC. 21, T13N, RIOE MPJ-06 2S100302630-277 At total depth 9. Approximate spud date Amount 1198r NSL, 4242' WEL, SEC. 21, T13N, RIOE 7/15/94 $200,000.00 !12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15, Proposed depth (MD a,d'rvD) property line ADL 25509-1198 feet No close approach feet 2560 8951'MD/7430' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.o35 Kickoff depth ~5oo feet Maximum hole an9le,~3.~2 o Maximum surface 3330 psig A1 total depth (TVD) 8800'/4390 p$i~ 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) 24" 13-3/8" 54.5t/ K-55 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 401/ L-80 BTRC 2582' 31' 31' 2613' 2570' 488sxPF"E"/250sx"G"/250sx"C" 8-1/2" 7" 261/ L-80 BTRC 8921' 30' 30' 8951' 7430' ! 400 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductorRECEIVED Surface Intermediate ProductionJUL 1 2 1994 Liner Perforation depth: measured /~)aski~ 0il & Gas Cons. C0mmissi0n true vertical Anchorage 20. Attachments Filth9 fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l~l Drilling fluid program [] Time vs depth plot [] Refraction analysis l-I Seabed reportl-'] 20 AAC 25.050 requirements[Z] Signed . _ Tit le Dr#ling En~7ineer Supervisor Date Commission Use Only Permit Number IAPI number lApp al date ISee cover letter '~'c/.._ ~ ~'~ J5 0- ~ ?_..'~- 2- % ~ 3J .~v_ [' (-¢' - ~' ~:[ Jfor other requirements Conditions of approval Samples required [] Yes UNo Mud log required []Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required I~ Yes [] No Required working pressure for BOPE 1'-12M; I-'I3M; ,i~M; i-I10M; g15~1; Other: OFIIGINAL SIGNED BY by order of Approved by RUSSELL A. DOUGLASS Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in trip%icate I Well Name: IMPJ-06 Well Plan Summary I Type of Well (producer or injector): I Producer ISurface Location: Target Location: Bottom Hole Location: 2401' NSL 3215' WEL Sec 28 T13N R10E UM., AK. 1005' NSL 4200' WEL Sec 21 T13N R10E UM., AK. 1198' NSL 4242' WEL Sec 21 T13N R10E UM., AK. I AFENumber: 1330025 Estimated Start Date: ] July 15, 1994 I Rig: [ Nabors 22E Operating days to complete: [ 10 IM~: 1 8951' I ITVD' 17430' bkbl [ KBE: [ 66' I Well Design (conventional, slimhole, etc.): I Milne Point Ultra Slimhole 7 Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1821' 1820' MA 6105' 3550' NA 4249' 3880 OA 4523' 4080' OB 4578 4120' OG 4783' 4270' HRZ 7965' 6595 Top Kup 8209' 6790' Top C Sand 8339' 6900' Target 8558' 7090' Total Depth 8951' 7430' Casing/Tubin: Program: Wt/Ft Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 13 3/8" 54.5# K-55 Weld 80 32/32 112/112 12 1/4" 9 5/8" 40g L-80 btrc 7-582 31/31 2613/2570 8 1/2" 7" 26g L-80 btrc ~8921 30/30 8951/7430 :: ;~' '~' >~~ ~//~/~¢ wo~i~'d occur Internal yield pressure of the 7" 26g casing is 7240 psi. worst case surface pressure with a full column of gas to the reservoir at 7100 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3550 psi is 2850 psi, well below the internal yield pressure rating of the 7" cas~ng. ,.. ,. C IV D JUL 1 2 1994 Alaska Oil & Gas Cons. Commission Anchorage Logging Prog I Open Hole Logs: Surface Intermediate Final I Cased Hole Logs: ram: None None GR/RES/DIR across Schrader Bluff. LWD GR/Resistivity/Neutron/Density, Possible RET across Kuparuk. GR/CCL will be mn by production. CBL run only if necessary. A gamma ray log will be obtained from surface to TD. Mud Logging is not required. Mud Program: I Special design considerations I None- LSND freshwater mud i Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.6 90 35 15 30 10 15 Intermediate Mud Properties: N/A ] Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: [ Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 tO tO tO tO tO tO tO 10.4 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: I ~500' IMaximum Hole Angle: Close Approach Well: I R FCFIVED (No ShutIns) ,Jill_ 2 1994 Gas Cons. CommJssio~ Anchorage MPJ-06 Proposed Summary of Operations , . , , . . , , 10. 11. 12. 13. Drill and Set 13-3/8" Conductor. Weld a starting head on conductor. Prepare' location for rig move. MIRU Nabors 22E drilling rig. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole and run and cement 9-5/8" casing. This hole section will be logged LWD with DPR (Res/Gr). ND 20" Diverter, NU and Test 13-5/8" BOPE. RIH w/PDC bit on a turbine, Test 9-5/8" casing to 3500 psig, Drill out float equipment and 10 feet of new formation, Perform a LOT. Drill 8.5" hole to TD, POOH, and Run and Cement 7" casing. This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). RIH while PU 3-1/2" drill pipe with 7" 26# tandem bit and scraper to PBTD and perform a casing wash while filtering brine to 2 micron absolute. POOH L/D 3-1/2" drill pipe. Freeze protect the well. ND BOPE, NU and Test Tree. Set BPV. RDMO Nabors 22E drilling rig to drill MPC-21. Well will be completed with Coil Tubing deployed ESP. RECEIVED JUL 1 2 ]994 Alaska fJII & 6as Cons. Commission Anchorage <KB> B 4000 6000 6500- 7000- PRUDHOE BAY Imm m m m m m m m ! DR ILL I NS GROUP _ . 1500 ,~--, 7500 ............ i _. BO00 :: ........ .;' I .... 0 500 ~00( pJ-O6 VERTICAL SECTION Section at' 350.68 TYD Scale.' J inch = lO00 feet Bep Scale.' J inch = 1000 feet Brawn · 07/06/94 ,4nad/"jll $ch./umb£rger VIE~ Marker Identification MD 8KB SECTN ll~CLN A) KB 0 0 0 0.00 B) KOP BUILD 2.5/100 1500 1500 0 0,00 C) 9-5/B" CASING 2613 2570 210 27.84 U) END OF 2,5/~00 BUILD 26~5 2578 210 27,87 E) START 2.5/J00 CURVE 2750 269~ 260 27.87 F) END DF 2.5/~00 CURVE 3793 3548 820 43,12 5) START 2.5/~00 DROP 7B33 6496 358~ 43,18 Ht END OF 2.5/~00 DROP 8358 69~7 3893 30.00 I) --- KUPA~UK TGT --- 8558 7090 3993 30.00 dj TO 895~ 7430 4189 30.00 2000 2500 3000 Section Oepar ~.ure ~ 3500 4000 4500 5000 5500 6000 6500 PRUDHOE "'BAY DRI · i . . _ iii .._ m ~arker Identification HB N/S E/~ A). K8 0 0 0 8)' KOP 5UILD 2.5/~00 J500 0 0 C}; S-5/'8' CASING. ~6~ ~8I O)! END OF 8.5/100 BU)LO 25t5 ~8i ~94 E) START 2.5/~00 CURVE 2750 284 24~ F) ~NB OF 2,5/~00 CURVE 3793 752 45! 6) START 2.5/J00 DROP 7833 3477 -H) END OF 2,5/J00 OROP 8358 3785- ~) --- KUPARUK TGT --- 8538 3883 995 d; TD 895~ 4077 ~027 _LING -'GROUP HPJ-06 (P2) PLAN VZEH ___ CLOSURE · 4204 feet a~ Azimuth 345.86 DECL~NATZON.' 30.000 E SCALE ' ~ ~nc~ = BOO feet DRAWN ' 07/06/94 . _ ,4haUt J l] SchJumbenger __ laska Oi & Oas C,~ns. Comnlission i Anchmau6 , ;I J ' [ I ' 5~00 ;4800 4400 4000 3600 3200 2800 2400 2000 JCO0 J200 800 400 0 400 <- WEST' EAST -> MPJ-06 WELL 9-5/$" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE' 9-5/8" CIRC. TEMP 50 deg F at 2500' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE' ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS' 488 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 2.0% CaCI2 WEIGHT: 15.8 ppg APPROX #SACKS' 250 FLUID LOSS: 100-150 cc YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME' Greater than 4 hrs at 50° F. o E C E IV E D TOP JOB CEMENT TYPE' Permafrost C ADDITIVES: Retarder WEIGHT: 15.6 ppg YIELD: 0.96 cu ft/sk. JdL 12 19 4 Gas Cons. Commission Anchorage MIX WATER: 3.7 gal/sk APPROX NO SACKS' 250 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 10 joints of casing (10 required). 2. 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 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME' 1. The Tail Slurry volume is calculated to cover 500' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. MPJ-06 7" PRODUCTION CEMENT PROGRAM- CASING HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL' CIRC. TEMP: 140° F BHST 170 deg F at 7040' TVDSS. SPACER' 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu fl/sk APPROX # SACKS: 250 -_ FLUID LOSS: < 50cc/30 min @ 140° F MIX WATER: 5.0 gal/sk THICKENING TIME: 3 112- 4 112 hrs @ 140° F FREE WATER' 0cc @ 45 degree angle. STAGE il CEMENT JOB ACROSS THE SCHARADER BLUFF SANDS- CIRC. TEMP' 60o F BHST 80 deg F at 7040' TVDSS. SPACER' 75 bbls fresh water. RECEIV£D LEAD C:;EMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: NONE Type E Permafrost JUL 12 1994 &l~$ka 0il & Gas Cons. Commission Anchorage YIELD:2.17 ft3/sx MIX WATER' 11.63 gal/sk THICKENING TIME: Greater than 4 hfs at 50° F. TAIL (~EMENT TYPE' Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344, 2.0% CaCI2 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 150 FLUID LOSS' 100-150 cc MIX WATER: 5.0 gal/sk THICKENING TIME: 4 hours @ 50 FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4"Straight Blade Rigid Centralizers-- two per joint on the bottom 21 joints of 7" Casing (43total). This will cover 300' above the C Sand. 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 4800' - 4250' to cover the Schrader Bluffs Sands (12 Total). 3. Run one 7"x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7"x 8-1/4"Straight Blade Rigid Centralizers needed is 56. 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 8-10 bpm. Batch mixing is .not necessary. CEMENT VOLUME' 1, Stage I cement volume is calculated to cover 1000' md above the LKi with 30% excess. 2. Stage 2 cement volume is calcualted to cover from the OG base to the to 500' above the NA Top with 30% excess. WELL PERMIT CHECKLIST F E .D . POO . , L5 UNIT# PROGRAM: exp [] dev~ redrll [] /] ~ ~.-~ ON/OFF SHORE serv [] ADMINISTRATION APPR 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N ' 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval. . N 13. Can permit be approved before 15-day wait ....... N ENGINEERING APPR 14. Conductor string provided ............... Y~ N 15. Surface casing protects all known USDWs ........ '~ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~Y~ N 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. Drilling fluid program schematic & equip list adequate .(~ N 25. BOPES adequate ..................... ~ N 26. BOPE press rating adequate; test to ~~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of ~2S gas probable ............. Y GEOLOGY ? 30. Permit can be issued w/o hydrogen sulfide measures .... Y pM 31. Data presented on potential overpressure zones ..... Y/N 32. Seismic analysis 9f shallow gas zones .......... y N ~_//~, 33. Seabed condition survey (if off-shore) ........ ~ N 34. Contact name/phone for weekly progress reports . . . ~ Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: O ^'~n - A:~FORMS~cheklist tm/03/94 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. MPJ - 06 MILNE POINT Run 1: 16 - AUG - 1994 GR/CCL Cased Hole WESTERN ATLAS 6980 t687 Atlas Wireline Services Tape Subfile'2 is type: LIS TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPJ - 06 500292249300 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 23-SEP-94 6259.00 K. RICHARDS D. ROBERTSON 28 13N 10E 2401 3215 46.67 17.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 13.375 120.0 3RD STRING 9.625 2511.0 PRODUCTION STRING 7.000 8780.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH GRCH $ EQUIVALENT UNSHIFTED DEPTH GR/CCL Cased Hole. REMARKS: 40.00 26.00 *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 WAS NOT DEPTH SHIFTED SINCE PASS 1 IS THE DEPTH REFERENCE FOR THIS WELL. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY MPU TOOL CODE START DEPTH STOP DEPTH GRCH 6982.0 8688.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS MPU CURVE CODE: PASS NUMBER: BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS). NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPJ - 06 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 4 2 TENS GR 68 1 LB 4 4 66 264 36 0 4 66 264 36 0 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 41 Tape File Start Depth = 8690.000000 Tape File End Depth = 6982.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 10252 datums Tape Subfile: 2 127 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY MPU TOOL CODE START DEPTH STOP DEPTH GRCH 8480.0 8688.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS MPU CURVE CODE GRCH PASS NUMBER: 1 ......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH 8483.5 8484.5 8484.0 8486.0 8486.0 8488.0 8487.0 8488.5 8487.5 8489.0 8536.0 8536.5 8541.5 8542.0 8601.5 8601.0 8603.5 8603.0 8604.5 8603.5 8606.0 8605.0 8606.5 8606.0 8607.5 8607.0 8608.5 8607.5 8669.0 8670.5 8670.0 8671.5 8671.0 8672.0 8677.0 8678.0 8678.0 8678.5 8680.0 8680.5 8680.5 8681.0 REMARKS: PASS 2 (REPEAT PASS). / ? ?MATCH2A. OUT $ CN : BP EXPLORATION WN : MPJ - 06 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 66 264 36 0 4 4 66 264 36 0 * DATA RECORD (TYPE# 0) Total Data Records: 1014 BYTES * Tape File Start Depth = 8690.000000 Tape File End Depth = 8480.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1264 datums Tape Subfile: 3 58 records... Minimum record length: 18 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6981.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 8689.0 16-AUG-94 FSYS REV. J001 VER. 1.1 1946 16-AUG-94 8735.0 8688.0 6981.0 8687.0 2400.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR SBAR SINKER BAR CCL CASING COLLAR LOC. GR GAMMA RAY $ TOOL NUMBER 2324NA 1311XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 8780.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): DIESEL & WATER .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): .0 BASE NORmaLIZING WINDOW (FT): .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 1 (MAIN PASS). $ CN : BP EXPLORATION WN : MPJ - 06 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TTEN GR 68 5 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 1 LB 4 4 21 990 60 6 4 26 165 19 6 4 76 115 41 1 4 10 579 41 1 4 10 579 41 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 163 Tape File Start Depth = 8689.000000 Tape File End Depth = 6981.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 51251 datums Tape Subfile: 4 237 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8477.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 8689.0 16-AUG-94 FSYS REV. J001 VER. 1.1 1935 16-AUG-94 8735.0 8688.0 6981.0 8687.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR SBAR SINKER BAR CCL CASING COLLAR LOC. GR GAMMA RAY $ TOOL NUMBER 2324NA 1311XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .O0O 8780.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): DIESEL & WATER .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): .0 BASE NORMALIZING WINDOW (FT) : .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 2 (REPEAT PASS). $ CN : BP EXPLORATION WN : MPJ - 06 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TTEN GR 68 5 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 1 LB 4 4 21 990 60 6 4 26 165 19 6 4 76 115 41 1 4 10 579 41 1 4 10 579 41 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 21 Tape File Start Depth = 8689.000000 Tape File End Depth = 8477.500000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6347 datums Tape Subfile: 5 95 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS 94/ 9/14 01 **** REEL TRAILER **** 94/ 9/14 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 14 SEP 94 ll:05a Elapsed execution time = 3.68 seconds. SYSTEM RETURN CODE = 0 15:46 PAGE: : ac i;×pl,uiktA"'iOf~ (ALAS~,A), hlbt!g POINT, '~zPJ-06, 50- 129-22493-00 B T T R U ~{ 10 ~; 24,!3 t 32i5 250 " c~qn :',~:5r-' ~;',:17 :~.:,,PbT:i.'!.iL'.'.[: RE$Z~TTV!TY, PAGE: 253 . 0 2534.0 PgGEI lq-,~A~,i'-!gq5 i5:46 PAGE: PAGE: 5 AOi:., 8~ ~' b~TT 70.45117256 [',~ bO~':~ J. 49. 574~7401 pr' A'v ~:~A~4 8~A L ~ F D ~ A P D ~, 'T,. 4 6.6 7 E~ 6 ~:i: 46,67 EOF eT ~6,67 EGL P'"I' 17, TnD FT 8800.6 T r, L, ~ T 8 8 0 O. 6 TrI ~T 2534. D~D ct~3 I0.4 R~S n ~-,~ ~4 r,: 2.27 ,,~>.. ~.., ,, B~T ~E~F 155. Field Yame Well ~ame ~PI Serial ;'~umber Field Location Sect~om Township ~aDge County State er Province ~ation Latitude Gong~tude Permanent datum Elevation of Permanent Datum 5o~ ~easured From ~bove Permanent Datum ~levatlo, of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Oeoth - Logger Bottom bog Interval TOD [,00 InterVal Drilling, Fluid Density ~eslst~v~tv of ~ud SamPle ~ud Sample TemPerature Resisti. vltY of :~ud Filtrate $ ~ud Filtrate Sammle Temperatu .Bottom Hole Temperature PAGE: ChlUmher{~:r. /~-.'~.~<~. ~o~,'Li,. r',~,.. ¢~'~nt~r... . PA~g~ DEPT. 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MWD .2.387 36,4(,0 ~ .alO 2.410 ~OBU.MWD 34.~(!n RA.MWD 0.653 ~OP.MWD 2,404 ROBU.MWD 2,404 DRBO.MWD 0,5B3 ROP,MWD 2.423 POBU,!~tWD 3~.900 PA,NWD 0.~55 ROP.M~D 2.408 ROBO,MWD 2.422 DRMO,MWO 41..2U0 RA.~WD O.fi9~ ROP.~WD 2.487 0.!13 2.293 903,931 2.443 0.111 2.312 24~.930 2.472 0.233 2.579 !76.91g 2.444 0.122 2.672 t. 97.795 2 89 2. 525 140.580 2.404 0.123 2.657 210.497 2.437 o.:t02 2,417 200.694 7.472 0.099 2.551. 14~.~50 2.4!15 0.!15 197.795 RP,~wD RP.~:WD ROBR.~WD PEF.~WD RP.~wD RP.UWD GR,mWO ROBR.~WD PEF.~WD RP,MwD ROBP.~WO RP.}~'~D GR.~WD ROBR.~wD PEF,~D RP,~WD GR,~WD ROBP.~WD GR.~WD PEF.Y~D 2 460 2:837 2,231 122.133 2.442 2.776 2.241 103.268 2.472 2.860 2 508 113:930 OO5 2,572 105.351 2.46~4 5.5 7 2:-. 557 91.225 7.40 2-611 573 2.415 2,847 2,401 I:07,:13.4 ,3 89 2', 609 2,552 93,572 2 420 2 949 2 670 87 5'59 !n,-J.Ar'.t-!gq5 i5:46 2.3~4 ROBU.MHD 0.315 RNP,~WD 2.387 2.433 4~.200 0,419 ROP,MWD 2.345 2.338 0.390 ROP'~WD 0,~67 ROP,MWD 2.3412 DR}lO. dl~lt) (",, 65:3 ROP.'~,!wD 4 n, 200 ~ ~. ;?t W O 0.4 t~ !. [;: 0 P. ~,.! t4 D 2.417 0.115 2.711 187.354 2.409 0.~07 2.769 380.330 2.446 0.093 2.860 289.560 2.417 0.114 2 058 72:289 2 402 2 704 2,38? 0.!,21 2.751 105.a85 2. :704 282.!05 2.368 0.143 2.582 87.900 2.382 0.!.36 2.787 !7~.305 RP.UwD RP.~WD GR.M~O RP.~WD G~.~WD RP.~WD ROBR,MWD PE~.~WD PEF,~WD RP,~WD ROBR.~WD RP.u~D ROBR,~WD RP,~WD GR.~WD PAGE: 10 :429 710 2.710 94.050 2 427 . 2.643 2.773 94.463 2.368 3 026 2:753 99.340 2.367 2,732 2.869 93,918 357 99..813 2.3 8 491~ I:773' 1 O0 '774 496 2 '664 98,240 664 2 58 2.. 3 37 2,626 2 .. 757 90,990 11 o. 644 2.~23 2.~72 35.400 0.515 2.3o9 aOBU.aWO 9.309 QRHO.~WD 41.4OO RA.~WD O,4~7 ROP.aWD 1.525 !,364 ~.404 .118 2.995 303.60~ 2 ~43 O:100 1.183 250.444 2.333 0.070 3.532 38~.362 2.437 0.088 3.399 276.511 2 309 3.052 265.646 2.253 0.080 3.374 200.347 2 26 I olios 4,471 41 2.293 0,1,20 5~.497 2.279 O. 1.43 3 507 64:841 ROBR.~WD RP.~WD ROBR.~n PEF.~D RP.~WD ROB~.~WO PEF.MWD RP.~WD ROBR.~WD pgr.~wp RP.~WD ROBR.M~D PE~.~wg RP.~WO ROBR.~WD RP.~WD RP.~WD 2.354 2.508 2.950 95.350 2.343 2.873 1.622 100.599 2.333 2.794 3.408 87.877 2,441 3.264 3.083 91,461 2 ' 309 2.. 597 3- 201 89'502 2 ,, 265 '271 1'303 81;374 2,169 2'576 4.200 67,895 222 567 499 2.312 2.421 3.342 89.629 12 %3.~uO PA.!4WD ~.270 AOP.HWO 2.4 26 2.!53 7. ~ 46 2.343 PO~U.~fiND 2.]7! DRHO.MWO 2~.~00 RA.~iWD 1.23q ROP.~WD !,.955 ROBO.MWD !.947 50.900 PA.MND 0.220 2.309 ROBU.MWD 2.327 DRHO.qWD 4:!.700 RA.MWD 0.71.! ROP,MWD 2.0~7 ~OBU.MWD 2.092 DRHO.MWD 42.7~i0 RA.~WD n.118 ROP.~WD ~.791 RO~U,MWD 1,.Be4 DRHO. MWD 0,~10 EOP.I4WP !.995 ROBU.MWD 2.O34 DRMO.~WD 0.106 ROP.MWD 2.01! POgd.~WO 2.004 DRHO.MwD 50.700 2.219 0.143 3.751 44.706 2.119 0.13) 4.093 58.63~ 2. 365 0 13t 46.079 1 .O5l 0.155 10 839 283:392 2 315 4.704 254.414 2. 479 642.217 !.616 0.121 22.342 631.561 1.989 0.156 24.273 535.142 2.017 0.1.23 14.aoB 340.7i0 RP.UW9 GR.~D ROBR.~D RP.~wO G~.~WO ROBR.~WD PEP.~wD RP.MWD GR.~wD ROBR.MwD PEF.,ND RP.UWO ROBR.MWD RP.~WD GR.~WD ROBP.MWD PEF.MWD RP.~WD GR.UWD ROBR.~D PEF.~D RP.~WD GR.~WD ROBR.~WD PEF.~WD RP.~WD GR.~WD ROBP.~WD RP.~WD 2.335 2.668 4 2,2]9 2.484 4,084 76.252 2.370 3.089 10.112 52.238 2.036 1:173 25i4g0 26 406 329 :3~0 205 2.050 1,g36 2'340 52.252 t 869 I O86 25 25O 22 798 99 54'608 ~ 2:, 244 140 1: 5. I 36 36.585 PAGE: 13 kOP.qWD DRHO,MwD ?OP.~WO ROBU.MWD DRHO.FiWD DA.MWD DnHO.~WD D~HO.MWD DRHO.MWD RDP.HWD POBIJ.MW9 RDP.MWD ROBU.HWO DRHO.MWD NOP.MWD PA,~WD 2.!11 0.087 ~.009 2.043 0.194 19.678 207.008 2 1.76 6.256 267.794 1.996 n.164 ~.130 192.~17 !08 o:o61 268 42J:26~ !.637 -0.041 6..354 456.852 2.084 0.114 9',~9~ 417'319 2.166 0.110 7.84t 265.664 J,.704 0.174 i0.875 290.325 ROBR.~WD PEP.~D RP.~D GR.U~D PEF.mWD RP.~WD ROBR.UWD PEF,mWD RP.~WD ROBR.~WD PEF.~D RP.~WD ROBR.M~D PEF.M~D RP.~{WD PEF,~WD GR,m~D RDBR,~D RP,~'WP GR,:~WD GR.~:wD 2.103 1.721 7.425 42.906 2.043 1.384 33.493 26.012 2.176 2.306 5.969 76~759 8 5~8 33:160 45 7., 976 .59.898 I, 641 1~,237 6.060 39,352 ' 11:1 ~'239 5; 748 68'833 2.' 223 2'035 7' 063 79.074 1.,.686 1-036 10 905 47 687 ~AGE= 14 0.315 ROP.~D 1.939 ~OBU.NWD 1.951 D~gO.M~D 0.295 ROP.~wD ~.590 0.235 13.~21 634.054 2.126 0.090 9.252 334.129 1.910 0.145 13.866 483.857 DFPT. 24o9. ,~- ~ c..! 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Peoth - Logger Bottom Log Interval. Too Log Interval Dr~l,liD Fluid Denslt¥ ~eslstl~itV °~ Mud ample MudSample Temperature Resistivity of MUd Fllt:rate.$ ~ud Filtrate SamPle Temperatu gotto~ Hole Temperature 15:4,6 PAGE: PAGE: 18 ~I.: , .,, ,,'t~.:: ':; 0 C I C 3 ,.:. (~ t'L, n 0 n ."' ! C ! ':') 0 r'; O 0 00 GtC ~ :)n O C'O On (; ! C 3 t} n r"t (: C U 0 . .! ~ i.) 0 C.: [, r? (j 0 i .~: U n r', 0 q V 0 : ,1t:,,i'~ ;)0 nO0 i ~r., ;:,, :.) ;, t"~ 0 ,') (; n -, . . .., .~ 0 2 i 1. 4 68 0000000000 u 2 ~ I 4 68 0000000000 0 2 ! I 4 68 0000000000 () 2 ! ! 4 68 O00OO00000 g 2 ! I ~ 68 oooonooooo o 2 1 1 4 68 O000000OO0 0 2 1 ~ 4 68 0000000000 0 2 ! J 4 68 o0000OO000 u 2 t ! 4 6~ 0000000000 0 2 1 ! 4 68 0000000000 O 2 1 1 4 68 0000000000 0 2 !. I 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 I I 4 68 O000oO0000 ~ 2 1 1 4 68 0000000000 0 2 1 ! 4 68 0000000000 0 2 ! ! 4 68 0000000000 0 2 1 I 4 68 0000000000 DFP?. ROBI,,I,:~! DEP~. DFPT. DE?. [.,.4 ! 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LW! l!.llO D~RoLW! 16,702 2.064 DPHI,b!~I 037 ROBR.LWI ~'431 DCAb~LW1 2©.3~0 I')~R,LW1 26.613 ).05~ PPNI.bWl 2.083 ~OBR.BN1 0,395 gCAb.b~! i4,5~6 DER.GWl 35.375 25..600 2.262 1.406 4.127 31.400 2.188 1.541 3.120 2'5.500 2.272 1.647 4.049 16.900 2.376 0.914 7.004 24 400 0.797 6.196 47.200 !.938 !.704 2.489 57,300 1.503 3.251 9.:766 39.600 2,097 ~.064 19.673 38.8 O0 2 054 o: 14.177 TAB.I, Wl TNPM.LWl TAB.LW1 DRHO.I.,hl. ROBB..LWl TNPM.I,,wl TAR.I.,,Wl TNPH.LWI TAB.LWl ROBF., L,W ~ TNp!"T:I,,Wl TAB.LWJ DRHO. l,~: 1 ROBB.LW~ T)~)PH'Lwt, TAB.bWl ROBB.bWl TNPN.LW!, DPHO,L~I TNPH.T, Wl TA~.LW1 DRHO,LWI YAB.LW1, PAGE: !9 0.133 2.283 49.300 1.431 0.137 2,287 47,300 2.389 O. 126 1,201 0,115 2,438 2 16 42. 300 0. 419 0.i76 2.047 50.300 0.398 o'os sl: O, 130 143 40O 0,133 0,13! 2,085 47:.,700 0.136 IS Tane ¥~rfflcatJon 2O I)FPT. 2.!2! OFH!.b~;1 ?.!36 ~U~R.LWl 0.47~ DCab. LWl 8.7oP DER.LW1 ~7.!24 ~.058 DPHI.LW! ~ n3o PN~R.L'~I 0.52~ nC~L.bWl 21.1~n DER.LW! ?.1~9 DPHI.LW1 2.~,85 POBR.LW1 1.4qo DCAL.LW1 7.~49 DER.LwI 53.075 ~.?15 DPMI.LNI 2.~i5 ~OgR.h!gi 0.536 DCaL,.bWl i0,302 DF~.LWl 56.572 2.130 9PHI.LWl 2.~30 ~OBB.LWl 0.509 DC~L.LWl 7.~TM DER.Lw1 ~7.~45 2.037 DPHI.bW1 2.037 ROBR.bWI 0.614 9CAb.bW1 7.317 DER,bwt 57.38~ 1.9~9 DPHI.I~W1 1.9C:9 ~OBR.LW1 0.5~6 9.~b4 D~R.Lw1 2.!19 DPHI,LWI 2.~i9 POBR,LwI 0'.517 DCAL.bW! 9.82~ DKR,Lw! ~.~b7 POBR.LWI (~ ~':q DCAL.LWl g.~i DER.LW! 79.737 31.400 2.124 1.060 9.181 39.400 2.066 0.508 20.803 30.30o 2.172 0.867 7.760 31.600 5 10.22~ 35.400 2 ~30 . 470 39. 100 ~.037 ~.,247 496 49.100 ! .969 .,..772 33.100 9.986 26 000 2::1186 1. 043 9.926 ROBB.L~1 ~rNPH.LWi TAR.LW1 DRHO.LW! ROBS.LWl TAB.L~ DRHO.LW1 ROBB.LW! TNPH.LWI TAB.Lw~ DRHO.!,W] ROB~.I,Wl TNPH.I, Wl TAB.I, W1 DRHO.LNI ROBB.LW~ TNPH.Lw! ROBB.!.iW1 TAB.LW! DRHO.LN1 ROB~.LWl TAB.LW~ 0,103 2,176 41,400 0.125 0.101 2.088 46.300 0,142 0,131 2.218 48,300 0.135 O. 097 ~00 '133 O. i24 2,130 50. BO0 0,132 o' os 2.037 5 3 .. 3 0 0 0.278 0,~92 l'' 69 55'~000 0,304 1 ! 9 46' 300 0.392 0. 083 520700216 0~7~ i fi--JA~.~- t 995 15:a6 PAGE: 21 D E, P ?. 306. t:, 1 ~ l.P3'] i.)P~ii.b!:~l 49.7'00 !.fiSg POaR.b~il 1.911 O.a~? ~Cab.b;'~l 2.229 9.~bq i)FR.L~I 10.05] .i7.~1~ 1.90a DpNI.LWl 40.700 ~.040 ~OP.R,LWl 1.905 0.437 DCAL.L~41 1.577 1.2.K23 UER.DW[ 13.441 ~9.02~ 1.776 DPHI.L~I1 0.500 1,995 ~OBR.L~I 1.675 -999.P50 DC~L,LWl 0.~89 !.,~.234: [)ER.LWl 0.089 i6.¢37 -99~.250 DPHI.Lwl -999 250 -99~.25o ROP, R.LWl. -999:250 -q99,~50 ~CAL,LwI -999.'250 -999.25n D~R,LW1 -999.~50 -990.250 -999.?S0 DPHI..Lwl -_~99 250 -099.250 DCAL,bwt -999 250 -999.25~ DER,LW1 -999:250 -999,250 DRHO.I, wl ROBB.E:w~ TNPN.[,wl TA~.L~! TNP~.LW~, TAg. LW~ ROBB.I.,,~I T~PH.LW! TAB.LW~ DRHO.LW1 ROBB.L~ TNPN,LW1 TAB.LW! 0.121 2,144 55,200 0,400 0.159 1,931 55,400 0.344 0,072 1.884 59.000 0,287 -0' 660 1,601 60,200 -999,250 -999]· 250 -999,250 52'100 -999'250 :999"250 999,250 ' 9 9 9.. :25 0 '999,250 "'are 15:46 22 Curves and loq meaaer ~at-a for each hit run in separate - ~ .... . -,- ~:i~ ' :t' LOG ~'A r,:' r~ TOP . , ~ , &j .,, .... > ,: ,, 25-dUb-94 :,O¢os 20.4 FAST 2,5 ~E~OPY 8~00 6 4 9 o 6: o 8800.6 !00 40.0 .... ;:: .... .G 8.5 0 0 250 9.0 1. 0,4 0 files. Ig ~'ame Ver~f:ica. t.J. on ;,i~tlr',~ chlomber~r A~e.S<~ Co~-t]~}t~,nc.', Center I~-J~.!~,-I9O,5 15:4,6 PAGE: !,55.0 2.27O 6~.0 2.440 69.0 SANDSTONE 2.65 T~BLE TYP? ~ AP I ~'.~ 50-02g-2249]-00 FI. 24oi. ~.!,Sb & 3215 STA~ ~LASKA LAT'! 70,45117256 b~ hOt.;~C i49.57~740~ E~F FT 46.67 Well ~ame API Serisl Number Field Location Section Township Range County State or Province Marion Latitude bo.nq~tude Perihanent datum Blevatton of Permanent Datu~ bo~ ~easured From Above Permanent Datum Elevation o~ Kelly Bushin~ ~levatio~ of Derrick Floor Elevation of Ground 5evel I,~ Taoe V~rif~catior~ PAGE: 24 ............................................ Total. . nept~ - ~r~ller ''''' .... Total OeDth - Lo~ger Bottom Loq Interval TOD Lo. Interval Drilling Fluid Density Resistivity o~ Mud Sample ~ud Sample Temperature Pesistlv~tY of Mud Filtrate S ~ud Filtrate Sample Temperatu Bottom Role Temperature 25 ........................ - b ..J ~ 65 PT 1! 66 14 REPR R CgS,,S COOLS (HEX) 68 0000o00000 68 0000000000 68 o000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 :0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 DEPT. ~800.900 P:;r~:.DW2 -999.250 DPHI.LW2 PE~.f.:W? -999.25{} Pi'}E[).L~*!2 -99q.2~0 ~OBR.LW2 :ROBI,,.[.,~,,9 -Vo9,2~"':' ~ARU ""' .............~. . . .~.,'~:',2 -qgq.250 DC~L.LW2,. ~T~,:.,,~2 -999.250 PSR.L:X2 -999.250 DER,hW2 ROpF.Lw? in3,72~ CR.t.,~,!2 '-999.250 D9~0.1.~2 -999.250 ROBB.LW2 :999,250 TNPH.LW2 999.~50 TAB,LW2 -999.250 DRHO.I, W2 -999.250 -999.250 2.517 TAB.I.,W2 -999*250 -999'2'50 -999.'250 -999.250 999,. 250 · 999.. 250 999,250 0.728 le-d&~'.~-!9q5 1.5:46 PAGE: 26 2.491 DPHI.bW2 ..! .80P OC.a b. b~'2 !i2.2i6 2.405 DPHI.LW2 2.a55 ~OBR.LW2 5.400 bC~b.bW2 3.009 DER.LW2 96,~54 2.407 nPFIi. UW2 2.41.3 t~O~R.bw2 p."t g5 DCAU.bW2 5. J. O2 DER. L!,:2 ~3 .ou,~ 2.433 2.439 2.303 6.~44 e8.o3o 2.393 PPNi.bW2 2.3~4 POBR.LW2 2.760 DC~b.bW2 1.970 O~a.[.,~2 117.1©~ 2.454 DPHI.laW2 2.4.82 ROBR.hW2 3.093 DC~L.bW2 1.984 DER,bW2 ~29.099 2.373 DPHI.UW2 2.372 POBR.LW2 1,315 DER.bW2 2.4,52 DPHI.DW2 2,505 POBR.DW2 1.164 DCAL.L~2 2.448 DER.Bw2 !54,000 12.200 2.488 0.392 2.496 1~.000 2.434 0.770 3.040 16.400 ~.431 0.712 5.107 17.400 2.429 0.267 6.n18 17.500 2 440 0:883 2.020 15 3OO 0.586 9~'029 20 500 1. 9o 0.474 1.324 i7.500 2.454 0.317 2.353 2~.400 2.391 0.243 !.920 gOBB.I,w2 D~HO.t, W2 ROBB.LW2 T~PH.LW2 TAB.LW2 DRHO.Lh2 RnBB.L~2 TNPH.L~2 TAF.LW2 DRHO.!,W2 ROBB.LW~ TP!P~.L~ DRHO.I,W2 ROBB.LW2 TNPH.LW2 TAB.LW2 DRHO.!..,N2 ROBB.Lw2 TNPN.LW2 TAB.L~2 ROBB.LW2 TNP~.LW2 TAB.LW~ DRHO,LW2 ROBB.LW2 TNP~,LW2 ROBB.LW2 TNPH.I, W2 0.096 2.474 31.500 0.965 0,151 2.436 38,100 4.190 0.1~3 2.437 29.600 1.617 0.102 2 423 29:300 1.236 0.147 2.489 3~.:900 2,525 37'800 1.958 2,402 46,400 7.615 O. i 27 2,4 4 7 43,200 0.5 81 0'* 085 2'344 50. 500 0'622 :1 g-,J ~-~r~!- ! 905 I5:46 2.d18 POBR.Lt42 2.194. UC~L.LW2 9.0bO DFR.LW2 155.013 2.39! DP~I.LW2 2.396 ~OBR.LW2 1,5~0 DCAL.LV:2 1.49n DER.LW2 !.u4.nS~ 2.4.99 POBR.bW2 !..079 PC~L.LW2 ?.o7q DFR.BW2 1.33.510 2.437 DPHI.D~2 O.Oe9 nClb.bW2 2.437 [)FR,bW2 94.333 2.491 DP~I.LW2 2.4~5 ~O~R.LW2 2.744 DER.bW2 t25.014 2.434 DP~i..b:g2 2'4~4 ROBR,BW2 !.076 DClb. Lw2 2.393 DER,LW2 2.408 DP[!I.LW2 2.40~ POBR.L~!2 1,2!3 DCAL.L~2 2.66~ DEB.LW2 2.410 DPiqI,LW2 2.445 POBR,LW2 !.925 DCaL,bW2 2.431 DER.LW2 93.52! 17 200 DRHO.!.,w2 2."412 ROB~.LW? 0.501 TNPH.I, W2 1 .936 '~AB.LW2 1R.O00 D~HO.I,,W2 2.409 ROOB.L~2 0.39~ TNPN.I,,W2 1.523 TAB.[,~2 13.000 DRHO.LW2 2.471 ROBB.LW2 0.495 T~PH.I,W2 ~.096 ~AB.L~2 15.500 DRHO.LW2 2.444 ROBB.LW2 0.481 T~PH,LW2 2.440 TAR.LW2 8.900 DRHO.LW2 ~.521 ROBB.!.;W2 0 740 TNPH.I.,W2 5 200 DRHO.LW2 440 ROBB.[.,W2 l~ 499 TNPH.LW2 2.416 TAR.LW2 445 TAR.~W2 16 '700' 0. 699., TNPN. L:w2 PAGE: 27 0.103 2,400 45.500 0.7~1 0.087 2.394 40,600 0.528 0,117 2.503 32.700 0.432 0.107 2.417 36.600 0.333 099 ,4 5 2 , 800 300 0.536 404 ,37,.700 438 0' 109 2,425 33.400 0'710 IS Ta~e v~rii-4c~t.~om [lstir~o z ............... 2 12.3~7 226.,. 1 n,~<~ c:~. i,., ~,,. ,: 995 15: 46 2.4e5 ~PHI.b:~2 2.a7! 1.246 DC~L.LW2 2.49g DFR.bW2 J~7.47n ~.4OJ DPNI.LW2 ?.ale) ROBR.LW2 0.963 2.3~1 D~R.LW2 2.42~ DPMI.L~!2 O.~B6 DC~b. Lw2 2.201 DKR.BW2 9P.~25 0.9i7 nCAL.LW2 ?.60g DER.Lw2 9P.655 2.419 DPH!.bw2 2.~29 ~OBR.b~2 !,.1i, 7 DC~L.Lw2 2.59~ DER.Lw2 ~2,329 2.404 DPHi. LW2 2.429 ¢OBR.bW2 0.775 DCAb. LW2 2.612 DER.LW2 87.600 2.405 OPHI.b~2 2.377 ~OBR.DW2 0.675 DC~L..LW2 2.703 DKR.LW2 ~g.612 394 BPNI.LW2 '41,2 ~n~p BW2 0.689 DC~L.LW2 2.~'~3 DKR.bW2 96.291 2.383 DE~I.LW2 2.a17 POBR.LW2 t.~90 DC~L.bW2 2.56~ DE:R.bW2 10~.226 17.700 2.423 0.520 2.509 16.300 2.440 0.571 2.382 16.200 2.421 0.587 ~.247 1~.500 .404 0.478 2.631. gO0 418 2:667 18..700 2.412 0.370 2.601 20.900 7.401 0.090 2.8t3 2 ~.. 600 1.04 2.880 i 9 100 ~:397 0.60.8 ~.557 ROBB.LW2 TNPH.LW2 TAB.LW2 DRHO.I, w2 ROB~.Lw2 TNPg.LW2 TAB.LW2 ROBB.LW2 TNP~.L~2 TAB.L~2 ORHO.I.,W2 ROBB.LW2 TAB.LW2 DRHO.LW2 ROBB.LW2 TNPH.L~2 TAB.LW2 DP. HO. ROBB.LW2 TNpH'LW2 TAB. LW2 D~HO.LW2 ROBB,b~2 TNPH,LW2 TAB.LW2 D~ HO. L ~2 ROBB. LW2 T~P~.LW2 TAB. L, W2 DRHO.L~:2 TNPH.I, W2 PAG£I 28 0-115 40.200 0.608 0.096 2.416 36.700 0.442 122 0,109 2., 435 · 000 0'I02 2.441 35,300 0,806 0:*107 2,41.5 3~.. 400 .439 4~:04g04 o' x o 7 2'389 .. 800 3:496 ,. 0.124 2.430 39.:500 0.731 IS *aee '¢~riti. cat!on ? istJt~o 1~--J~,:'-.1995 15:46 PAGE: 29 2.35! ~OSR.LW2 2.3F! DP;II.LW2 ~.425 ~P~r.bw2 0.q94 DC~L.LW2 2.558 DFR.L'~2 90.0U7 9.346 t~PHi.LW2 2.3'19 ~O~R.LW2 1.105 nCAL.LW2 3,272 DER, L, W2 89.205 2.330 DPHI.LW2 2'354 9OgR.bW2 0.7o6 DC~L.LW2 2.7~0 DE~.LW2 ~7.~06 2.322 ~PHI.LW2 ?.367 ROBR.LW2 1.101 DChh,bw2 2.4~2 DKR.DW2 95.~59 - 2.32~ DPHI bw2 0,935 OCAh. LW2 3.449 DER.hW2 ~8.720 2.325 DPHI.LW2 2,398 ROBR.LW2 0.~74 UC~L.hW2 3.39~ DER.hW2 77.902 ?.303 DPHi.bW2 2.303 POBR.LW2 0.950 DChL.LW2 2.73~ DER.bW2 95.3o4 22.!00 2.355 1.399 2.~75 20.600 2.381 0,276 2,673 21.5o0 2.388 0.342 2.557 .40~ 3.266 23.000 2,322 0.170 ~.784 .[:9oo 0 669 2~458 600 0.219 3. 476 22. 400 3.427 2,3 600 2i:303 0 O00 ~768 T~,!PH. L.W2 TAB.LW2 ORHO.t, w2 ROOB.LW2 T~PH.LW2 ROBR.bW2 T~PH.I,W2 TAB.L~2 D~HO.bW2 ROBR,LN2 TNPH.LW2 DRBO.LW2 ROBB.LW2 TNPH.L~2 DRHO.Lw2 TNPH,LW9 TAB,,LW2 DRHO.LW2 ROBB LW2 TAB. !,,W2 ROBB.LW2 TAg,LW2 0.137 2.363 44.600 0.385 0.096 2387 38i300 0 297 0.123 2.348 41. 200 0:536 O8 36 800 0 315 :o:8 ~40 40 300 :.: 28.2 45,900 0'6]~ O: :I16 2': 24 37,600 O, 413 0,115 2 ,' 313 36,500 0,503 o,o4o 2,303' 43; 600 0,494 3O ** E~,,:'E,, (;m mAYA 2.!98 UPMi.L~2 !.!o~ ~CAL.L¢2 2.6U~ DFa.bW2 79.!20 ?.Pl? OP~I.bW~ 2.2i2 PS~R.LW2 -990.250 DCAb.bW2 3.431 DER.bW2 73.?~3 2.1¢3 nPWI.bW2 2.1!.1 ~OBR.bw2 -q99.PbO DC~L,~w2 -99o.25~ DFR.LW2 -990.250 -99q.250 PORR.bW2 -999.250 DCAL.SW2 -q99.2bO DER,bW2 -999.250 29.700 2.198 0,000 2.561 30.100 ORHO.Lw? 2.212 ROBB.I.,W2 0.000 TNPH.LW~ 3.442 TAB.LW2 29.400 D~HO.LW2 2.156 ROBR.LW2 ].297 T~PH.LW~ -99q.250 TAB.!,.,W2 -999.~50 DRHO.LW2 -999.250 ROBB.LW2 -99~.250 T~P~.LW2 -999.250 TAR.L~ 0'035 2.198 53.300 0.657 0.055 2.212 47.200 '999.250 0.113 2,254 50.200 -999.250 -999"250 -999.250 -999.250 -999.250 M Or .b ~',;! E P 01 ,,x! T, ~PJ-06, 50-029-22493-00 PAGE~