Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
196-156
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ESP Change-out Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 3,790 feet 3,676 feet true vertical 3,110 feet N/A feet Effective Depth measured 3,676 feet feet true vertical 3,028 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)5-1/2" 17# / L-80 IBTM 1,961' 1,816' Packers and SSSV (type, measured and true vertical depth)N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: Senior Engineer: Senior Res. Engineer: Collapse N/A 5,300psi Burst N/A 9,440psi 777-8520 2. Operator Name Casing Conductor Length 80' 3,772'Production 20" 9-5/8" 3,097' MILNE PT UNIT F-58 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 600 Casing Pressure Tubing Pressure 0 N/A measured 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-460 2,168 Authorized Signature with date: Authorized Name: Ian Toomey itoomey@hilcorp.com 543 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-156 50-029-22706-00-00 Plugs ADL0025509 5. Permit to Drill Number: MILNE POINT / TERTIARY UNDEF WTRSP Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 00 113' 14,027 Oil-Bbl measured true vertical Packer Size N/A 2,424, 2,846 & 3,276 2,160, 2,443 & 2,742 (2) Versatrieve & Sump Packer WTRSP WAG 0 Water-Bbl MD 113' 3,772' TVD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:56 am, Jan 15, 2021 Chad Helgeson (1517) 2021.01.14 21:35:52 - 09'00' MGR18FEB2021 DSR-1/19/21 SFD 1/25/2021 RBDMS HEW 1/25/2021 _____________________________________________________________________________________ Revised By: TDF 1/14/2021 SCHEMATIC Milne Point Unit Well: MPU F-58 WSW Last Completed: 12/21/2020 PTD: 196-156 TD =3,790’(MD) / TD =3,110’(TVD) Orig. DF Elev.: 41.5’/ Orig. GL Elev.: 11.6’ 9-5/8” 3, 4 &5 14 11 12 13 16 20” 1& 2 10 4-1/2” NSCT x 5-1/2” IBT Crossover @ 31.05’ Min ID= 3.833 PBTD = 3,676’ (MD) / PBTD =3,028’(TVD) 6&7 15 1718 19 20 21 8 & 9 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 113' 9-5/8" Surface 47 / P-110 / BTCM 8.681 Surface 3,772 TUBING DETAIL 5-1/2” Tubing 17 / L-80 / IBTM 4.892 Surface 1,961’ JEWELRY DETAIL No Depth Item 1 1,848’ Bolt On Intake: HPINTARC HS 23T 2 1,849’ Discharge Head: B/O PMP 675 5.5X8 RND LONG CSG 3 1,850’ Pump 3: HPHVMARC 035 HC20000ARC 316SS HD/BAS S/N 4 1,868’ Pump 2: HPHVMARC 035 HC20000ARC 316SS HD/BAS 5 1,886’ Pump 1: HPTAR 22 HC20000 S/N: Z01H0072631 6 1,897’ Upper Tandem Seal: HSB3 UT FER EHL INV CUW AB PFSA DS 7 1,904’ Lower Tandem Seal: HSB3 UT FER EHL INV CUW AB PFSA DS 8 1,911’ Motor 2: HMIU 500hp /1,965V /153A - 417/1640 10R 9 1,933’ Motor 1: HMIU 500hp /1,965V /153A - 417/1640 10R 10 1,957’ Sensor / Centralizer: Bottom @ 1,961’ 10 2,424’ 9-5/8” HES Versatrieve Packer 11 2,454’ Safety Shear Sub,Min ID = 3.00” 12 2,457’ 5-1/2”, 20 ppf, N-80, LTC Blank Pipe; ID=4.778” 13 2,552’ 5-1/2” 0.12 Ga. Pre-Pack Screen, ID=4.778” 14 2,709’ 5-1/2” 0.12 Ga. Screen, ID=4.778” 15 2,846’ 9-5/8” HES Versatrieve Packer 16 2,877’ Safety Shear Sub,Min ID = 3.00” 17 2,879’ 5-1/2”, 20 ppf, N-80, LTC Blank Pipe; ID=4.778” 18 2,936’ 5-1/2” 0.12 Ga. Pre-Pack Screen, ID=4.778” 19 3,146’ 5-1/2” 0.12 Ga. Screen, ID=4.778” 20 3,276’ 9-5/8” HES Sump Packer set on e-Line 10/14/1996 PERFORATION DETAIL – Ref Log: Open hole MWD 10/14/96 Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Upper Prince Creek 2,558’ 2,614’ 2,250’ 2,288’ 56 10/15/1996 Open 2,614’ 2,666’ 2,288’ 2,322’ 52 10/15/1996 Open 2,666’ 2,728’ 2,322’ 2,364’ 62 10/15/1996 Open 2,728’ 2,740’ 2,364’ 2,372’ 12 10/15/1996 Open 2,740’ 2,752’ 2,372’ 2,380’ 12 10/15/1996 Open 2,752’ 2,770’ 2,380’ 2,392’ 12 10/15/1996 Open 2,770’ 2,782’ 2,392’ 2,400’ 12 10/15/1996 Open 2,782’ 2,800’ 2,400’ 2412’ 18 10/15/1996 Open 2,800’ 2,828’ 2,412’ 2431’ 28 10/15/1996 Open Lower Prince Creek 2,948’ 2,964’ 2,513’ 2524’ 16 10/15/1996 Open 2,994’ 3,060’ 2,544’ 2590’ 66 10/15/1996 Open 3,086’ 3,100’ 2,608’ 2617’ 14 10/15/1996 Open 3,110’ 3,270’ 2,624’ 2737’ 160 10/14/1996 Open 26gm Jumbo Jet charges @ 60 deg. phasing (w/ 0.74” EHD and 5.8” TTP) w/ 135 / 45 deg. phasing WELL INCLINATION DETAIL KOP 10°@ 702’ Max Hole Angle = 49 ° f/ 2,584’ Hole angle thru perfs= 48.2° TREE & WELLHEAD Tree CIW 4-1/16” 5M ‘FLS’ Wellhead 11”x 12” 5M FMC Gen 5 Unibore w/ two 2” 5M valves on side ports 11” x 4-1/8” 5M adapter and 11” x 4.5” tbg hng 4.5” NSCT threads top and bottom and 4” CIW-H GENERAL WELL INFO API: 50-029-22706-00-00 Drilled and Cased by Nabors 22E - 10/22/1996 Change out ESP by Nabors 4ES – 3/2/1997 Change out ESP by Nabors 4ES – 10/7/1998 Change out ESP by Nabors 4ES – 8/18/2003 Change out ESP by ASR#1 – 10/5/2016 & 2/22/2020 OPEN HOLE / CEMENT DETAIL 20” Cmt w/250 sx Arcticset 1 (Approx.) in a 24” Hole 9-5/8” 1,037sx PF ‘E’, 550sx Class ‘G’ in a 12-1/4” Hole GRAVEL PACK DETAIL Upper Zone: 8,100lbs of 20-40 Carbolite 10/20/1996 Lower Zone: 5,400lbs of 20-40 Carbolite 10/15/1996 Min. Gravel Pack Restriction = 3.00” Well Name Rig API Number Well Permit Number Start Date End Date MP F-58 LRS / ASR 50-029-22706-00-00 196-156 12/20/2020 12/22/2020 No operations to report. 12/19/2020 - Saturday PJSM, Ambient -30 deg. Continued winterizing cold spots on equipment. Flooded BOPE with FW and circulated air out. Performed shell Test 250/2500psi-good test. Performed BOPE Test per sundry 250/2500psi as following: Test 1 Annular, IBOP, C8, C9, C10 = GOOD TEST. Test 2 PIPE RAMS, TIW, C1, K1 = F/P ON TIW CYCLED AND RETESTED GOOD. Test 3 PIPE RAMS, TIW, HCR CHOKE, K2 = GOOD TEST. Test 4 PIPE RAMS, TIW, C5, C6, C9, K3 = GOOD TEST Test 5 PIPE RAMS, TIW, C4, C7, C11, K3 = GOOD TEST. Test 6 PIPE RAMS, TIW, C8, C10, C1, .C14. C15, K3 = GOOD TEST. Test 7 BLINDS, C-12, C-14, C-16 = GOOD TEST. Test 8 CHOKE BLED OFF. Tested Fire & Gas and Performed the Draw Down Test. 1 f/p was recorded. Witness waived by Jeff Jones on December 20, 2020 9:16 PM. Blew down lines and L/D Testing equipment. Loaded pits with 250bbls of 8.3 source water. Hooked up return line to tiger tanks. MIRU Crane. Fly Doyon Tongs and 5-1/2" handling tools to rig floor and RU same. PU Dry rod and pulled test plug. Found pressure underneath BPV. Circulate down tubing while taking returns out of the IA and to the return tank. See fluid at tank at 28 bbls away returns at 7.5ppg. SD at 53 bbls away, with Tbg on a vac pulled BPV. Continued circulating at 3bpm/300psi, SD pumping with returns at 8.3ppg. Pumped away 171bbls of 8.3 SW. Took 70% losses during circulation. Monitored well TBG/IA static. Sent returns to ORT for recycle. PU/MU Landing Jt into Hanger. Pulled stack over to center the hole. BOLDS. Pulled hanger to rig floor PUW 40K. De-complete Hanger and L/D same. Pull ESP cable to Spooler and tie into Spooler. POOH/w5 1/2", 17#, L-80, IBTM TBG. Pulling clamps and inspecting tbg on the way out. all look good. Break off discharge head, Lay Down Summit ESP. 1 pump out broken shaft. First pump out broken shaft. Baker arrive with ESP Completion assembly. Load of racks and Pick up first motor. Baker forgot to bring 7.25" Centralizer from shop when he picked up equipment. Prep rest of Equipment while wait for Centralizer. Double check all Modified 5.5" couplers have new seal rings. Begin Make up centralizer and service Motor, Make up and service the rest of ESP completion. Making up first pump at report time. 12/20/2020 - Sunday MIRU LRS, PT lines to 250-2,500psi. Pumped 15bbls of 60 deg 60/40 down tbg at 2bpm/100psi. SD pump. set BPV. Begin to spot well hut and mud boat. ND Well head, Spot in the rig. Tie onto BOPE with crane while prep hanger for BOPE test. found that the BPV has a slow leak coming from the outside seals on the BPV. sent Well head support to get tools to adjust BPV try to get it to seal and Lubricator in case not able to seal. Tool that was brought back did not fit the BPV installed. Set BOPE back down and NU Tree and Lubricator. Pull BPV found that seal was rolled over. Put new seal on and install with well head support. suck out the tree no visual leaks. pull tree no leaks. Set test plug in BPV. check lifting threads with X-over 4.5" NSCT 7.5 turns to make up. NU BOPE, Fly the work floor. Stand up the ASR. Set Rack pins, hang spooler sheave and run rope through. set the work floor stairs. NU Spacer spools. Lay containment, Set Catwalk Hook up BOPE lines and HCR lines. Functioned BOP, PU BOPE Testing equipment check temps on equipment. Took on 30bbls of fresh water in pits for testing. 12/21/2020 - Monday 12/18/2020 - Friday No operations to report. 12/16/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 12/17/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP F-58 LRS / ASR 50-029-22706-00-00 196-156 12/20/2020 12/22/2020 Hilcorp Alaska, LLC Weekly Operations Summary PJSM, Continue MU and servicing ESP assembly completed final service checks. MU discharge Head XO Pup Jt. TIH w/ New ESP on 5 1/2" 17# L-80 IBTM TBG to hanger depth. Clamping every joint and torqueing connection to 3,800psi. PU Landing Joint and Tbg Hanger with BPV Installed. Spaced out cable, made splice and terminated to penetrator. Hooked Umbilical Cord to Penetrator and Landed Completion with 34k down on Hanger. Final cable test was good. RILDS. END OF WELL WORK. Began RDMO ASR and associated equipment to stack on A Pad. Cleared Rig Floor. Disconnected Fire&Gas. RD winterization and Disconnected circulating lines and koomey lines. Soft Broke BOP Stack. RDMO pusher shack, pump, pits, catwalk and Conex's. 12/22/2020 - Tuesday 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Change-out 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 3,790'N/A Casing Collapse Conductor N/A Production 5,300psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WTRSP Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name:Ian Toomey Operations Manager Contact Email:itoomey@hilcorp.com Contact Phone: 777-8520 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Tubing MD (ft): COMMISSION USE ONLY Authorized Name: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 196-156 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 MILNE POINT / TERTIARY UNDEF WTRSP 50-029-22706-00-00 Hilcorp Alaska LLC Length Size 3,110' 3,676' 3,028' 775 3,676' MILNE PT UNIT F-58 20" 9-5/8"3,772' 1,976' TVD BurstMD Perforation Depth TVD (ft): Tubing Size: Tubing Grade: N/A 9,440psi3,097'3,772' 80' Authorized Signature: 11/14/2020 Perforation Depth MD (ft): See Schematic 17# / L-80 / IBTM N/A Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 113'113' 5-1/2" 2,424(MD)/ 2,160(TVD), 2,846(MD)/ 2,443(TVD) & 3,276(MD)/ 2,742(TVD) and N/A(2) 9-5/8" Versatrieve Pkr & Sump Pkr and N/A See Schematic Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 7:56 am, Oct 27, 2020 320-460 Chad A Helgeson 2020.10.26 16:38:08 -08'00' DSR-10/27/2020 X DLB10/27/2020 BOPE test to 2500 psi. MGR28OCT20 10-404 Comm 10/28/2020 dts 10/28/2020 JLC 10/28/2020 RBDMS HEW 11/12/2020 ESP Changeout Well: MPU F-58 Date: 10-16-20 Well Name:MPU F-58 API Number:50-029-22706-00-00 Current Status:Shut-in WSW [Failed ESP]Pad:F-Pad Estimated Start Date:November 14 th, 2020 Rig:ASR #1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:196-156 First Call Engineer:Ian Toomey (307) 777-8520 (O) (907) 903-3987 (M) Second Call Engineer:David Haakinson (307) 777-8343 (O) (307) 660-4999 (M) AFE Number:Job Type:ESP Swap Current Bottom Hole Pressure:1,020 psi @ 2,454’ TVD Measured Downhole SBHP (10/7/19) |4.34 PPG Maximum Expected BHP:1,020 psi @ 2,454’ TVD Reservoir Pressure Build-up |4.57 PPG MPSP:775 psi Gas Colum Gradient (0.1 psi/ft) Max Inclination 38° @ 1,823’ MD Max Dogleg:3.7°/100ft @ 973’ MD BPV Profile:4” CIW Type H Brief Well Summary: MPU F-58 was drilled and completed with a gravel pack in October 1996 as a Prince Creek water source well. The well has been worked over six times in its history with the last being February 2020. The ESP failed in September 2020 due to a suspected broken shaft. The well provides water for injection wells on F and L pads and is critical to main proper reservoir support for those wells in the Kuparuk and Schrader Bluff formations. Notes Regarding Wellbore Condition x The 9-5/8” casing was pressure tested to 2000 psi from 2,250’ MD on 10/4/16. x This well has no injection support. Objective: x Pull failed ESP/motor completion. Verify that the shaft is broken x Run new ESP completion. Pre-Rig Procedure: 1. RU LRS. 2. Kill the well with 8.3 ppg source water (volumes: tubing = 46 bbls & IA = 123 bbls) 3. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 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 4” HP BPV. ND Tree. Inspect the lift threads on the tubing hanger. Install the plug off tool into the BPV. 8. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. ESP Changeout Well: MPU F-58 Date: 10-16-20 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. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 5-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 12. RU to pull 5-1/2” ESP completion. 13. Pull the plug off tool, check for pressure under the BPV, if needed kill the well with 8.3 ppg source water and pull the BPV. 14. MU landing joint or spear. BOLDS, unseat the tubing hanger and pull to the rig floor. a. SO = 29K and PU = 38K when landed my ASR in 2020 in 8.3 ppg source water. 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. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 16. POOH and lay down the 5-1/2” tubing. 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. ESP Changeout Well: MPU F-58 Date: 10-16-20 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 Protectorlizer (4)Visually inspect on site and reuse Cannon clamps (45)Visually inspect on site and reuse Stainless steel band (1)Junk 17. PU, MU and RIH new ESP on 5-1/2”, 17#, L-80, IBTM tubing with new ESP cable. Set base of ESP assembly at ± 1,960’ 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. Crossover, 5-1/2” IBTM box X 5-1/2” LTC pin 18. PU and MU the 4-1/2” tubing hanger with 5-1/2” x 4-1/2” crossover. Make final splice of the ESP cable to the penetrator and ensure any control line ports are dummied off. 19. 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. 20. Set 4” HP BPV. Post-Rig Procedure: 21. RD mud boat. RD BOPE house. Move to next well location. 22. RU crane. ND BOPE. Install the plug off tool. 23. NU the tubing head adapter and NU 4-1/16” 5M tree. 24. PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 25. Pull the plug off tool and BPV. 26. RD crane. Move returns tank and rig mats to next well location. 27. Replace gauge(s) if removed. 28. Turn well over to production via handover form. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Blank RWO MOC Form _____________________________________________________________________________________ Revised By: TDF 2/28/2020 SCHEMATIC Milne Point Unit Well: MPU F-58 WSW Last Completed: 2/22/2020 PTD: 196-156 TD =3,790’(MD) / TD =3,110’(TVD) Orig. DF Elev.: 41.5’/ Orig. GL Elev.: 11.6’ 9-5/8” 2 &3 13 10 11 12 15 20” 1 9 4-1/2” NSCT x 5-1/2” IBT Crossover @ 31.05’ Min ID= 3.833 PBTD =3,676’ (MD) / PBTD =3,028’(TVD) 5&6 14 16 17 18 19 20 4 7 & 8 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 113' 9-5/8" Surface 47 / P-110 / BTCM 8.681 Surface 3,772 TUBING DETAIL 5-1/2” Tubing 17 / L-80 / IBTM 4.892 Surface 1,969’ JEWELRY DETAIL No Depth Item 1 1,847.7’ Discharge Head: B/O, 5 1/2" 8rd 675X, 416/420SS 2 1,848’ Pump: 675,SH20000,36S,12,1:2AR 3 1,866’ Pump: 675,SH20000,36S,INC,12,1:2AR 4 1,883.8’ Intake: 675P X513S, SS, High Strength Shaft 5 1,884’ Upper Tandem Seal: 513,LSLSL,AR BRG,INC,SB,HD,PREM 6 1,894’ Lower Tandem Seal: 513,LSLSL,AR BRG,INC,SB,HD,PREM 7 1,903’ Motor: 562,KMS2,UT,500HP,1800V,165.5A 8 1,934’ Motor: 562,KMS2,LT,500HP,1800V,165.5A 9 1,965’ Sensor / Centralizer: 125C,5KPSI,SS,1XPRES,2XTMP,2XVIB Bottom @ 1,969’ 10 2,424’ 9-5/8” HES Versatrieve Packer 11 2,454’ Safety Shear Sub,Min ID = 3.00” 12 2,457’ 5-1/2”, 20 ppf, N-80, LTC Blank Pipe; ID=4.778” 13 2,552’ 5-1/2” 0.12 Ga. Pre-Pack Screen, ID=4.778” 14 2,709’ 5-1/2” 0.12 Ga. Screen, ID=4.778” 15 2,846’ 9-5/8” HES Versatrieve Packer 16 2,877’ Safety Shear Sub,Min ID = 3.00” 17 2,879’ 5-1/2”, 20 ppf, N-80, LTC Blank Pipe; ID=4.778” 18 2,936’ 5-1/2” 0.12 Ga. Pre-Pack Screen, ID=4.778” 19 3,146’ 5-1/2” 0.12 Ga. Screen, ID=4.778” 20 3,276’ 9-5/8” HES Sump Packer set on e-Line 10/14/1996 PERFORATION DETAIL – Ref Log: Open hole MWD 10/14/96 Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Upper Prince Creek 2,558’ 2,614’ 2,250’ 2,288’ 56 10/15/1996 Open 2,614’ 2,666’ 2,288’ 2,322’ 52 10/15/1996 Open 2,666’ 2,728’ 2,322’ 2,364’ 62 10/15/1996 Open 2,728’ 2,740’ 2,364’ 2,372’ 12 10/15/1996 Open 2,740’ 2,752’ 2,372’ 2,380’ 12 10/15/1996 Open 2,752’ 2,770’ 2,380’ 2,392’ 12 10/15/1996 Open 2,770’ 2,782’ 2,392’ 2,400’ 12 10/15/1996 Open 2,782’ 2,800’ 2,400’ 2412’ 18 10/15/1996 Open 2,800’ 2,828’ 2,412’ 2431’ 28 10/15/1996 Open Lower Prince Creek 2,948’ 2,964’ 2,513’ 2524’ 16 10/15/1996 Open 2,994’ 3,060’ 2,544’ 2590’ 66 10/15/1996 Open 3,086’ 3,100’ 2,608’ 2617’ 14 10/15/1996 Open 3,110’ 3,270’ 2,624’ 2737’ 160 10/14/1996 Open 26gm Jumbo Jet charges @ 60 deg. phasing (w/ 0.74” EHD and 5.8” TTP) w/ 135 / 45 deg. phasing WELL INCLINATION DETAIL KOP 10°@ 702’ Max Hole Angle = 49 ° f/ 2,584’ Hole angle thru perfs= 48.2° TREE & WELLHEAD Tree CIW 4-1/16” 5M ‘FLS’ Wellhead 11”x 12” 5M FMC Gen 5 Unibore w/ two 2” 5M valves on side ports 11” x 4-1/8” 5M adapter and 11” x 4.5” tbg hng 4.5” NSCT threads top and bottom and 4” CIW-H GENERAL WELL INFO API: 50-029-22706-00-00 Drilled and Cased by Nabors 22E - 10/22/1996 Change out ESP by Nabors 4ES – 3/2/1997 Change out ESP by Nabors 4ES – 10/7/1998 Change out ESP by Nabors 4ES – 8/18/2003 Change out ESP by ASR#1 – 10/5/2016 & 2/22/2020 OPEN HOLE / CEMENT DETAIL 20” Cmt w/250 sx Arcticset 1 (Approx.) in a 24” Hole 9-5/8” 1,037sx PF ‘E’, 550sx Class ‘G’ in a 12-1/4” Hole GRAVEL PACK DETAIL Upper Zone: 8,100lbs of 20-40 Carbolite 10/20/1996 Lower Zone: 5,400lbs of 20-40 Carbolite 10/15/1996 Min. Gravel Pack Restriction = 3.00” _____________________________________________________________________________________ Revised By: IAT 10/15/2020 PROPOSED Milne Point Unit Well: MPU F-58 WSW Last Completed: 2/22/2020 PTD: 196-156 TD =3,790’(MD) / TD =3,110’(TVD) Orig. DF Elev.: 41.5’/ Orig. GL Elev.: 11.6’ 9-5/8” 2 &3 13 10 11 12 15 20” 1 9 4-1/2” NSCT x 5-1/2” IBT Crossover @ 31.05’ Min ID= 3.833 PBTD =3,676’ (MD) / PBTD =3,028’(TVD) 5&6 14 16 17 18 19 20 4 7 & 8 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 113' 9-5/8" Surface 47 / P-110 / BTCM 8.681 Surface 3,772 TUBING DETAIL 5-1/2” Tubing 17 / L-80 / IBTM 4.892 Surface ±1,969’ JEWELRY DETAIL No Depth Item 1 ±1,847’ Discharge Head: 2 ±1,848’ Pump: 3 ±1,866’ Pump: 4 ±1,883’ Intake: 5 ±1,884’ Upper Tandem Seal: 6 ±1,894’ Lower Tandem Seal: 7 ±1,903’ Motor: 8 ±1,934’ Motor: 9 ±1,965’ Sensor / Centralizer: Bottom @ ±1,969’ 10 2,424’ 9-5/8” HES Versatrieve Packer 11 2,454’ Safety Shear Sub,Min ID = 3.00” 12 2,457’ 5-1/2”, 20 ppf, N-80, LTC Blank Pipe; ID=4.778” 13 2,552’ 5-1/2” 0.12 Ga. Pre-Pack Screen, ID=4.778” 14 2,709’ 5-1/2” 0.12 Ga. Screen, ID=4.778” 15 2,846’ 9-5/8” HES Versatrieve Packer 16 2,877’ Safety Shear Sub,Min ID = 3.00” 17 2,879’ 5-1/2”, 20 ppf, N-80, LTC Blank Pipe; ID=4.778” 18 2,936’ 5-1/2” 0.12 Ga. Pre-Pack Screen, ID=4.778” 19 3,146’ 5-1/2” 0.12 Ga. Screen, ID=4.778” 20 3,276’ 9-5/8” HES Sump Packer set on e-Line 10/14/1996 PERFORATION DETAIL – Ref Log: Open hole MWD 10/14/96 Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Upper Prince Creek 2,558’ 2,614’ 2,250’ 2,288’ 56 10/15/1996 Open 2,614’ 2,666’ 2,288’ 2,322’ 52 10/15/1996 Open 2,666’ 2,728’ 2,322’ 2,364’ 62 10/15/1996 Open 2,728’ 2,740’ 2,364’ 2,372’ 12 10/15/1996 Open 2,740’ 2,752’ 2,372’ 2,380’ 12 10/15/1996 Open 2,752’ 2,770’ 2,380’ 2,392’ 12 10/15/1996 Open 2,770’ 2,782’ 2,392’ 2,400’ 12 10/15/1996 Open 2,782’ 2,800’ 2,400’ 2412’ 18 10/15/1996 Open 2,800’ 2,828’ 2,412’ 2431’ 28 10/15/1996 Open Lower Prince Creek 2,948’ 2,964’ 2,513’ 2524’ 16 10/15/1996 Open 2,994’ 3,060’ 2,544’ 2590’ 66 10/15/1996 Open 3,086’ 3,100’ 2,608’ 2617’ 14 10/15/1996 Open 3,110’ 3,270’ 2,624’ 2737’ 160 10/14/1996 Open 26gm Jumbo Jet charges @ 60 deg. phasing (w/ 0.74” EHD and 5.8” TTP) w/ 135 / 45 deg. phasing WELL INCLINATION DETAIL KOP 10°@ 702’ Max Hole Angle = 49 ° f/ 2,584’ Hole angle thru perfs= 48.2° TREE & WELLHEAD Tree CIW 4-1/16” 5M ‘FLS’ Wellhead 11”x 12” 5M FMC Gen 5 Unibore w/ two 2” 5M valves on side ports 11” x 4-1/8” 5M adapter and 11” x 4.5” tbg hng 4.5” NSCT threads top and bottom and 4” CIW-H GENERAL WELL INFO API: 50-029-22706-00-00 Drilled and Cased by Nabors 22E - 10/22/1996 Change out ESP by Nabors 4ES – 3/2/1997 Change out ESP by Nabors 4ES – 10/7/1998 Change out ESP by Nabors 4ES – 8/18/2003 Change out ESP by ASR#1 – 10/5/2016 & 2/22/2020 OPEN HOLE / CEMENT DETAIL 20” Cmt w/250 sx Arcticset 1 (Approx.) in a 24” Hole 9-5/8” 1,037sx PF ‘E’, 550sx Class ‘G’ in a 12-1/4” Hole GRAVEL PACK DETAIL Upper Zone: 8,100lbs of 20-40 Carbolite 10/20/1996 Lower Zone: 5,400lbs of 20-40 Carbolite 10/15/1996 Min. Gravel Pack Restriction = 3.00” Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: October 26th, 2020Subject: Changes to Approved Sundry Procedure for Well MP F-58Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAKPreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Operations Manager DatePrepared:Operations Engineer Date Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 09/18/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-58 (196-156) Multi Finger Caliper Log 01/10/2020 ANALYSIS FIELD DATA Please include current contact information if different from above. Received by the AOGCC 09/18/2020 PTD: 1961560 E-Set: 33959 Abby Bell 09/21/2020 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill erforate New Pool Repair Well Re-enter Susp Well Other: ESP Swap Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 3,790 feet 3,676 feet true vertical 3,110 feet N/A feet Effective Depth measured 3,676 feet feet true vertical 3,028 feet feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 113' 113' N/A N/A Production 3,772' 9-5/8" 3,772' 3,097' 9,440psi 5,300psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)5-1/2" 17# / L-80 / IBTC-MOD 1,969' 1,822' Packers and SSSV (type, measured and true vertical depth)N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WTRSP GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: David Haakinson Authorized Title:Operations Manager Contact Email:dhaakinson@hilcorp.com Date 3/19/2020 Contact Phone:777-8343Authorized Signature: Authorized Name: 5. Permit to Drill Number: 0 MILNE POINT / TERTIARY UNDEF WTRSPN/A measuredPlugs Junk Printed and Electronic Fracture Stimulation Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 319-584 2,100 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 measured ADL0025509 2,424, 2,846 & 3,276 2,160, 2,443 & 2,742 (2) Versatrieve & Sump Packer 960 500 MILNE PT UNIT F-58 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-156 50-029-22706-00-00 Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 2. Operator Name: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 00 Casing Pressure Tubing Pressure N/A 10,000 Oil-Bbl measured true vertical Packer WINJ WAG 0 Water-BblGas-Mcf Form 10-404 Revised 4/2017 Submit Original Only Digitally signed by Chad Helgeson DN: cn=Chad Helgeson, ou=Users Date: 2020.03.19 17:51:42 -08'00' Chad Helgeson By Samantha Carlisle at 1:38 pm, Apr 01, 2020 RBDMS HEW 4/2/2020 gls 4/7/20 SFD 4/2/2020 DSR-4/1/2020 _____________________________________________________________________________________ Revised By: TDF 2/28/2020 SCHEMATIC Milne Point Unit Well: MPU F-58 WSW Last Completed: 2/22/2020 PTD: 196-156 TD =3,790’(MD) / TD =3,110’(TVD) Orig. DF Elev.: 41.5’/ Orig. GL Elev.: 11.6’ 9-5/8” 2 &3 13 10 11 12 15 20 ” 1 9 4-1/2” NSCT x 5-1/2” IBT Crossover @ 31.05’ Min ID= 3.833 PBTD =3,676’ (MD) / PBTD =3,028’(TVD) 5&6 14 16 17 18 19 20 4 7 & 8 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 113' 9-5/8" Surface 47 / P-110 / BTCM 8.681 Surface 3,772 TUBING DETAIL 5-1/2” Tubing 17 / L-80 / IBTM 4.892 Surface 1,969’ JEWELRY DETAIL No Depth Item 1 1,847.7’ Discharge Head: B/O, 5 1/2" 8rd 675X, 416/420SS 2 1,848’ Pump: 675,SH20000,36S,12,1:2AR 3 1,866’ Pump: 675,SH20000,36S,INC,12,1:2AR 4 1,883.8’ Intake: 675P X513S, SS, High Strength Shaft 5 1,884’ Upper Tandem Seal: 513,LSLSL,AR BRG,INC,SB,HD,PREM 6 1,894’ Lower Tandem Seal: 513,LSLSL,AR BRG,INC,SB,HD,PREM 7 1,903’ Motor: 562,KMS2,UT,500HP,1800V,165.5A 8 1,934’ Motor: 562,KMS2,LT,500HP,1800V,165.5A 9 1,965’ Sensor / Centralizer: 125C,5KPSI,SS,1XPRES,2XTMP,2XVIB Bottom @ 1,969’ 10 2,424’ 9-5/8” HES Versatrieve Packer 11 2,454’ Safety Shear Sub,Min ID = 3.00” 12 2,457’ 5-1/2”, 20 ppf, N-80, LTC Blank Pipe; ID=4.778” 13 2,552’ 5-1/2” 0.12 Ga. Pre-Pack Screen, ID=4.778” 14 2,709’ 5-1/2” 0.12 Ga. Screen, ID=4.778” 15 2,846’ 9-5/8” HES Versatrieve Packer 16 2,877’ Safety Shear Sub,Min ID = 3.00” 17 2,879’ 5-1/2”, 20 ppf, N-80, LTC Blank Pipe; ID=4.778” 18 2,936’ 5-1/2” 0.12 Ga. Pre-Pack Screen, ID=4.778” 19 3,146’ 5-1/2” 0.12 Ga. Screen, ID=4.778” 20 3,276’ 9-5/8” HES Sump Packer set on e-Line 10/14/1996 PERFORATION DETAIL – Ref Log: Open hole MWD 10/14/96 Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Upper Prince Creek 2,558’ 2,614’ 2,250’ 2,288’ 56 10/15/1996 Open 2,614’ 2,666’ 2,288’ 2,322’ 52 10/15/1996 Open 2,666’ 2,728’ 2,322’ 2,364’ 62 10/15/1996 Open 2,728’ 2,740’ 2,364’ 2,372’ 12 10/15/1996 Open 2,740’ 2,752’ 2,372’ 2,380’ 12 10/15/1996 Open 2,752’ 2,770’ 2,380’ 2,392’ 12 10/15/1996 Open 2,770’ 2,782’ 2,392’ 2,400’ 12 10/15/1996 Open 2,782’ 2,800’ 2,400’ 2412’ 18 10/15/1996 Open 2,800’ 2,828’ 2,412’ 2431’ 28 10/15/1996 Open Lower Prince Creek 2,948’ 2,964’ 2,513’ 2524’ 16 10/15/1996 Open 2,994’ 3,060’ 2,544’ 2590’ 66 10/15/1996 Open 3,086’ 3,100’ 2,608’ 2617’ 14 10/15/1996 Open 3,110’ 3,270’ 2,624’ 2737’ 160 10/14/1996 Open 26gm Jumbo Jet charges @ 60 deg. phasing (w/ 0.74” EHD and 5.8” TTP) w/ 135 / 45 deg. phasing WELL INCLINATION DETAIL KOP 10°@ 702’ Max Hole Angle = 49 ° f/ 2,584’ Hole angle thru perfs= 48.2° TREE & WELLHEAD Tree CIW 4-1/16” 5M ‘FLS’ Wellhead 11”x 12” 5M FMC Gen 5 Unibore w/ two 2” 5M valves on side ports 11” x 4-1/8” 5M adapter and 11” x 4.5” tbg hng 4.5” NSCT threads top and bottom and 4” CIW-H GENERAL WELL INFO API: 50-029-22706-00-00 Drilled and Cased by Nabors 22E - 10/22/1996 Change out ESP by Nabors 4ES – 3/2/1997 Change out ESP by Nabors 4ES – 10/7/1998 Change out ESP by Nabors 4ES – 8/18/2003 Change out ESP by ASR#1 – 10/5/2016 & 2/22/2020 OPEN HOLE / CEMENT DETAIL 20” Cmt w/250 sx Arcticset 1 (Approx.) in a 24” Hole 9-5/8” 1,037sx PF ‘E’, 550sx Class ‘G’ in a 12-1/4” Hole GRAVEL PACK DETAIL Upper Zone: 8,100lbs of 20-40 Carbolite 10/20/1996 Lower Zone: 5,400lbs of 20-40 Carbolite 10/15/1996 Min. Gravel Pack Restriction = 3.00” Well Name Rig API Number Well Permit Number Start Date End Date MP F-58 Pump Truck 50-029-22706-00-00 196-156 2/15/2020 Future 2/14/2020 - Friday No operations to report. 2/12/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/13/2020 - Thursday No operations to report. MIRU ASR#1. Prep To Begin rolling into shell test while wait for state witness Austin McLeod;Test All Rams, annular and valves 250psi/low 2500psi/high chart 5 Min. as per sundry. T/IA=28psi/625psi. MIRU LRS, PT equipment to 250/3500psi-good test. Bullheaded 220 bbls 130 deg 2% KCL dn IA @ 5bpm/550psi followed by 2 bbls of 60/40. Swapped to Tbg and pumped 80 bbls of 130 deg 2% KCL @ 5bpm/650psi followed by 2 bbls of 60/40. Monitored well bleed T/IA 40psi/500psi. Bleed off gas from IA and tbg T/IA=Vac/0psi. Set the BPV and RDMO LRS. 2/15/2020 - Saturday Mobilizing ASR#1 to Location. 2/18/2020 - Tuesday 2/16/2020 - Sunday Mobilizing ASR#1 to Location. 2/17/2020 - Monday Bullheaded 220 bbls 130 Well Name Rig API Number Well Permit Number Start Date End Date MP F-58 Pump Truck 50-029-22706-00-00 196-156 2/15/2020 2/22/2020 2/21/2020 - Friday Held PJSM, Checked fluids and serviced rig. Cont TIH with 5-1/2" ESP Completion f/1,200' t/Hanger MD. Clamping cable every other joint. PU/MU Tbg Hanger spaced out cable and Made Penetrator Splice. Do final checks. Land Completion, PU wt. 38k, SO wt. 29K. RILDS, Total Jnts 45, Hanger+ KB, EOT @ 1,968.57'. Lined up to pump down IA. Pumped 107 bbls of 90 deg 2% KCL down IA @ 4bpm/500psi. SD pump and Blew lines dry. Well work completed on F-58. Start RD ASR and move to F-29. De-winterize and BD circulating lines. RD Pipe Shed racks, pipe handler and stairs, RD ASR #1. Move the Pump and tool skid out of the way MO F-58. Load up 11" BOP and bring out to F pad. BD 13-5/8" BOPE stack. wrap up CanRig and Comms. Sim-ops on F-29 set BPV test adapter to 5K good. set VR plug in IA. RD Bleed down trailer R&P shorthanded/w rig support. Start Crane operations, Fly the Work floor, ND 13-5/8" BOPE stack. RD work floor stairs, load up BOPE lines, Summit test ESP Penetrator, NU well head and test to 5k. Pulled BPV. 2/19/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Held PJSM and discussed daily activities to preform. Continued Tested BOPE as following: Rams 250-2,500psi , Valves 250- 2,500psi, Annular 250-2,500psi. Tested with 5-1/2" Test Joint. Preformed Koomey Drawdown and Gas Detection. 3 F/P were recorded K2 and C9 failed on high test, greased and cycled valves retested good. Greyloc connection leaked on the 1st tested tightened connection and retested good. The test was witness by AOGCC rep Austin Mcleod. LD BOP Testing Equipment and blow lines dry. PU tongs and 5-1/2" Handling Equip. Staged Centrilifts tools on rig floor. Hung sheave and Elephant Trunk. SFTY MTG, Crew change. Pick up T-Bar, Stab on and remove test PLG, Stab into BPV pressure underneath had to let bleed off. after Bleed off pull BPV. MU landing Jnt to X-Over subs to 4.5" NSTC. Had to Fine tune the carriage pressure on the rig. Rig now running smoothly. MU Landing Jnt to the tbg Hanger, Check IA Pressure and BOLDS, Pull TBG Hanger to the Surface, 39K PU Wt. Pull ESP cable and attach to the Sheave Rope, BO Tbg Hanger, LD Landing jnt and swap over to 5.5" Tbg handling Equipment. Lay down first jnt, decided that the catwalk needed to be adjusted because of the way the trough extensions were causing the joint being laid down to be unbalanced. took off the current extensions and added a 22.5 Degree angle extension to compensate for pivot point on trough. re-adjust the distance from the well house. Lay down 6 Jnts, tied ESP to the spooler, lay down 4 more joints when a hose on the back of the tool carrier blew. Secure the Well, Hunt down and replace the broken hydraulic line. 2/20/2020 - Thursday Held PJSM and discussed plan forward. Checked Fluids and serviced rig. MO the Pipe Shed to access Carriage with the Manlift. Laid containment and prep tools to repair primary hydraulic artery in carriage. Moved carriage in position for access through the inspection panel on the mast to make the repair. Repair the Rig Carriage and PT Good. Replace all access panels. Spot back in the Pipe shed and pipe racks. Begin LD 5-1/2" 17# L-80 IBTC-Mod TBG. Held PJSM and discussed daily activities. Checked fluids and serviced equipment. Cont POOH with 5-1/2" Tbg to ESP Assembly. Displaced every 15 jts with 2%KCL. Prep Rig Floor to LD ESP Assembly. LD ESP assembly. 2 pump section were hard to turn. Motor would only make a 1/2 turn and showed black burn makers. ESP cable looked good. Sent equipment to Centrilift Shop for pull inspection. Cleaned and clean rig floor. Staged Summit tools and equip racked and tallied Summit ESP assembly. Crew eat Lunch. PJSM with crew and summit. PU and serviced New Summit ESP assembly. Threaded new #1 cable thru Sheave and terminated. Equip check good. RIH/W ESP on 5-1/2" 17# L-80 IBTC-Mod TBG 20 Jnts torqueing to 3,800ft/lbs Clamping every collar. Test the Cable. Cont RIH/W ESP on 5-1/2" 17# L-80 IBTC-Mod TBG 20 Jnts torqueing to 3,800ft/lbs Clamping every collar. No operations to report. 2/22/2020 - Saturday No operations to report. 2/25/2020 - Tuesday 2/23/2020 - Sunday No operations to report. 2/24/2020 - Monday Hanger to the Surface, 39K PU Wt. The test was witness by AOGCC rep Austin Mcleod. Tested BOPE as following: Rams 250-2,500psi , t TIH with 5-1/2" ESP Completion f THE STATE °fALASKA Go VERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska (iii and Cas Conservation Commission Re: Milne Point Field, Tertiary Undefined WTRSP, Milne PT Unit F-58 Permit to Drill Number: 196-156 Sundry Number: 319-584 Dear Mr. Helgeson: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. ;e DATED this day of January, 2020. IBDMS±'JJAN 0 3 2020 PaC 'lV= DEC 2 0 2049 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 2n AAf, 9, ?Rn 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑� Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change -out Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilwrp Alaska LLC Exploratory ❑ Development ❑ Strafigraphic ❑ Service Q 196-156 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 S'c,4L,QAE wrpC� 50-029-22706-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No MILNE PT UNIT F-58 9. Property Designation (Lease Number): • 10. Field/Pool(s): ADL0025509 IMINE POINT/TERTIARY UNDEF WTRSP 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 3,790' 3,110' 3,676' 3,028' 68 3,676' N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 113' 113' N/A N/A Production 3,772' 9-5/8" 3,772' 3,097' 9,440psi 5,300psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade Tubing MD (ft): See Schematic See Schematic 5-1/2" 17# / L-80 / Mod Btrc 1,976' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): (2) 9-5/8" Versatrieve Pkr & Sump Pkr and N/A 2,424(MD)/ 2,160(TVD), 2,846(MD)/ 2,443(TVD) & 3,276(MD)/ 2,742(TVD) and N/A 12. Attachments: Proposal Summary 4 Wellbore schematic 71 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch MV' Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/15/2019 OIL ❑ WINJ ❑ Suspended ❑ GAS p WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: David Haakinson I Authorized Title: Operations Manager Contact Email: dhaakinsonebircorb.com Contact Phone: 777-8343 Authorized Signature: Date: 12/20/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test W/ Mechanical IntegrityE]�Test ❑ Location Clearance Other: k z.SU� �vS r; r'y�l �S� 3BDMS't 'JAN 0 31020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes No Subsequent Form Required: E] [q,-' APPROVED BY ^ Approved by: �� COMMISSIONER THE COMMISSION Date /o Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate U FHlwea Alaska, LLI ESP Change -Out Well: MPU F-58 Date: 12-20-19 Well Name: MPU F-58 API Number: 50-029-22706-00 Current Status: Shut-in WSW [Failed ESP] Pad: F -Pad Estimated Start Date: January 15`^, 2020 Rig: ASR #1 Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Max Dogleg: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-156 First Call Engineer: David Haakinson (307) 777-8343 (0) (307) 660-4999 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE Number: Job Type: ESP Swap Current Bottom Hole Pressure: 1,020 psi @ 2,454' TVD Measured Downhole SBHP (10/7/9) 14.34 PPG Maximum Expected BHP: 1,020 psi @ 2,454' TVD Reservoir Pressure Build-up 14.57 PPG MPSP: 68 psi Assuming 60/40 Methanol Freeze Protect Gradient to Surface (.388 psi/ft) Max Inclination 38° @ 1,823' MD Max Dogleg: 3.7°/100ft @ 973' MD BPV Profile: 4" CIW Type H Original RKB: 30' (Nabors 4ES) Brief Well Summary: MPU F-58 was drilled and completed with a gravel pack in October 1996 as a Prince Creek water source well The well has been worked over five times in its history with the last being October 2016. The ESP failed in December 2019 due to a downhole ground. The well provides water for injection wells on F and L pads and is critical to main proper reservoir support for those wells in the Kuparuk and Schrader Bluff formations. The ESP will be upsized from a 12,500 BPD pump to a 20,000 BPD pump to increase injection and injection - withdrawal ratios on F and L pads. Notes Regarding Wellbore Condition • The 9-5/8" casing was pressure tested to 2000 psig from 2,250' MD on 10/4/16 Obiective• • Pull failed ESP/motor completion. • Determine source of electrical ground. • Run new ESP completion. Pre -Rig Procedure: 1. RU LRS and PT lines to 3000 psi. 2. Pump 1.5x IA volume (220 bbls) with heated 8.4 ppg source -water down IA to formation. 3. Pump Tubing volume (45 bbls) of heated 8.4 ppg source -water down Tubing to formation. 4. Clear and level pad area in front of well. Spot rig mats and containment. 5. RD well house and flowlines. Clear and level area around well. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 7. RD Little Red Services. ESP Change -Out Well: MPU F-58 IIilcorp Alaska, Lb Date: 12-20-19 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. Brief RWO Procedure: 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. 11. Check for pressure and if 0 psi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ 8.4 ppg source -water prior to pulling BPV. 12. Set TWC. 13. Test BOPE to 250 psi Low/ 2,S�si High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5 -min). Record accumulator pre -charge pressures and c aii rests. Pa. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. C. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 5-1/2" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails a. Notify Operations Engineer (Hiicorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 15. Bleed any pressure off casing to returns tank. Pull TWC. Kill well w/ 8.4 ppg source -water as needed. 16. Rig up spoolers for ESP #2 RD cable. a. Baker Hughes representative should be onsite for ESP pull. 17. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2016 ESP completion was 39K lbs / SOF = 28K lbs (ASR #1). 18. Recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. a. Evaluate pulled tubing hanger for possible thread damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. 19. POOH and lay down the 5-1/2" tubing. Lay down ESP and motor. a. Look for a blow-out on the ESP cable. H Ilik.v Alaska, LL ESP Change -Out Well: MPU F-58 Date: 12-20-19 i. Electrically test all equipment b. Note any sand or scale inside or on the outside of the ESP on the morning report. c. Look for over -torqued connections from previous tubing runs. d. The completion has the following amount of clamps/guards: i. 48 Cannon Clamps ii. 4 Protectolizers e. Plan to re -run tubulars that are in good shape. Use thread protectors when laying down the 5-1/2" BTC -mod tubing. Replace bad joints as necessary. 20. PU new ESP, new #1 cable, and RIH on 5-1/2" 17# L-80 IBTC-Mod tubing. 21. Set base of ESP assembly at ± 1,960' MD. 22. Land tubing hanger. RILDS.' Lay down landing joint. Note slack -off weight on tally. 23. Set BPV. Post -Rig Procedure: 24. RD mud boat. RD BOPE house. Move to next well location. 25. RU crane. NO BOPE. 26. NU existing CIW 4-1/16" 5,000# tree and adaptor flange. 27. Pull BPV. Set TWC. 28. Test tubing hanger void to 500 psi low/5,000 psi high. Test tree to 5000 psig low / 5,000 psig high. 29. Pull TWC 30. RD crane. Move 500 bbl returns tank and rig mats to next well location. 31. Replace gauge(s) if removed. 32. Turn well over to production. RU well house and flowlines. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic R fiilcorp Alaska, LLC Orig. DF Elev.: 41.5'/Orig. GL Elev.: 11.6 TD = 3,79U(MD) / TD = 3,110'(TVD) PBTD = 3,676' (MD) / PBTD= 3,02&(T/D) SCHEMATIC WELL INCLINATION DETAIL KOP 10-@ 702' Max Hole Angle = 49 ° f/ 2,584' Hole angle thru perfs= 48.2° rN.. Z`y Milne Point Unit Well: MPU F-58 WSW Last Completed: 10/05/2016 PTD: 196-156 TREE & WELLHEAD Tree CIW 4-1/16" 5M'FLS' Wt/Grade/ Conn 11"x 12"5M FMC Gen 5 Unibore w/ two 2" SM valves on Wellhead side ports 11" x 4-1/8" 5M adapter and 11" x 4.5" tbg hng 20" 4.5" NSCTthreads top and bottom and 4" CIW-H OPEN HOLE / CEMENT DETAIL 20" Cmt w/250 sx Arcticset 1(Approx.) in a 24" Hole 9-5/8" 1 1,037sx PF 'E', 550sx Class 'G' in a 12-1/4" Hole CASING DETAIL Size Type Wt/Grade/ Conn ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surface 113' 9-5/8" Surface 47/ P-110/ Mod Btrc. 8.681 Surface 3,772 TUBING DETAIL 5-1/2" Tubing 17 / L-80 /Mod Btrc 4.892 Surface 2,369' JEWELRY DETAIL PERFORATION DETAIL- Ref LOe: Open hole MWD m/mMi; Sand h Item' Top (TVD) Btm (TVD)IFTDate Discharge Head' Status Pump: HVHVUAR' 2,558' 2,614' Pump: HVHVMAR' 2,288' Pump: w/ Integral IntakeHPHVLAR' V Open Upper Tandem Seal: H5B3DB UT M FER SB/SB PFSA 2,666' ' Lower Tandem Seal: HS83DB LT M SB/SB PFSA ' Motor: CL5 HMI' 2,666' Centralizer: Bottom @ 1,976' 9 2,424' 9-5/8" HES Versatrieve Packer 10 2,454' Safety Shear Sub, Min I0=3.00" 11 2,457' 5-1/2", 20 ppf, N-80, LTC Blank Pipe; ID=4.778" 12 2,552' 5-1/2" 0.12 Ga. Pre -Pack Screen, ID=4.778" 13 2,709' 5-1/2" 0.12 Ga. Screen, ID=4.778" 14 2,846' 9-5/8" HES Versatrieve Packer 15 2,877' Safety Shear Sub, Min 10=3.00" 16 2,879' 5-1/2", 20 ppf, N-80, LTC Blank Pipe; ID=4.778" 17 2,936' 0.12 Ga. Pre -Pack Screen, ID=4.778" 18 1 3,146' 5-1/2" 0.12 Ga. Screen, ID=4.778" 19 1 3,276' 9-5/8" HES Sump Packer set on a -Line 10/14/1996 PERFORATION DETAIL- Ref LOe: Open hole MWD m/mMi; Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD)IFTDate Status 2,558' 2,614' 2,250' 2,288' /15/1996 Open 2,614' 2,666' 2,288' 2,322' 0/15/1996 Open 2,666' 2,728' 2,322' 2,364' 0/15/1996 Open Upper Prince 2'728 2.740' 2,364' 2,372' /15/1996 Open Creek 2.740 2,752' 2,372' 2,380' /15/1996 Open2,752' 2,770' 2,380' 2,392' /15/1996 Open2,770' 2,782' 2,392' 2,400' /15/1996 Open2,782' 2,800' 2,400' 2412' /15/1996 Open2,804 2,828' 2,412' 2431' /15/1996 Open2,948' 2,964' 2,513' 2524' /15/1996 OpenLower Prince 2,994' 3,060' 2,544' 2590' /15/1996 OpenCreek 3086' 3,100' 2,608' 2617' /15/1996 Open3,110' 3,270' 2,624' 2737 10/14/1996 Open 26gm Jumbo Jet charges @ 60 deg. phasing (w/ 0.74" EHD and 5.8" TTP) w/ 135 /45 deg. phasing GRAVEL PACK DETAIL Upper Zone: 8,10016s of 20-40 Carbolite 10/20/1996 Lower Zone: 5,4001bsof 20-40 Carbolite 10/15/1996 Min. Gravel Pack Restriction = 3.00" GENERAL WELL INFO E -22706-00-00Cased by Nabors 22E -10/22/1996 ESP by Nabors 4E5 -3/2/1997 ESP by Nabors 4E5 -10/7/1998 ESP by Nabors 4E5 -8/18/2003ESP by ASR#1 -10/5/2016 Revised By: TDF 10/19/2016 n carp Alaska, LLC Orig. DF Elev.: 41.5!/ Ong. GL Elev.: 11.6' TD = 3,790'(MD) /TD= 3,110'(TVD) PBTD = 3,676' (MD) / PBTD = 3,OX(TVD) PROPOSED WELL INCLINATION DETAIL KOP 10°@ 702' Max Hole Angle = 49'f/ 2,584' Hole angle thru perfs= 48.2° Milne Point Unit Well: MPU F-58 WSW Last Completed: 10/05/2016 . PTD: 196-156 TREE & WELLHEAD Tree CIW 4-1/16"5M'FLS' Wt/Grade/Conn 11"x 12" 5M FMC Gen 5 Unibore w/ two 2" 5M valves on Wellhead side ports 11"x4-1/8" 5M adapter and 11"x4.5"tbg hng 20" 4.5" NSCT threads tap and bottom and 4" CI W -H OPEN HOLE / CEMENT DETAIL 20" Cmt w/250 sx Arcticset 1(Approx.) in a 24" Hole 9-5/8" 1,037sx PF'E', 550sx Class'G' in a 12-1/4" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surface 113' 9-5/8" Surface 47 / P-110/ Mod Btrc. 8.681 Surface 3,772 TUBING DETAIL 5-1/2' Tubing 17/L-80/Mod Btrc 1 4.892 Surface ±1,960' JEWELRY DETAIL No Depth Item 1 ±1,988' Discharge Head 2 ±1,890' Pump: 3 ±1,900' Pump: 4 ±1,910' Intake 5 ±1,920' - Upper Tandem Seal: 6 ±1,930' Lower Tandem Seal: 7 11,940' Motor 8 ±1,950' Motor: 9 ±1,958' Sensor/ Centralizer:Bottom@±1,960' 10 2,424' 9-5/8" HES Versatrieve Packer 11 2,454' Safety Shear Sub, Min ID=3.00" 12 2,457' 5-1/2", 20 ppf, N-80, LTC Blank Pipe; ID=4.778" 13 2,552' 5-1/2" 0.12 Ga. Pre -Pack Screen, ID=4.778" 14 2,709' 5-1/2'0.12 Ga. Screen, ID=4.778" 15 2,846' 9-5/8" HES Versatrieve Packer 16 2,877' Safety Shear Sub, Min ID=3.00" 17 2,879' 5-1/2", 20 ppf, N-80, LTC Blank Pipe; ID=4.778" 18 2,936' 5-1/2" 0.12 Ga. Pre -Pack Screen, ID=4.778" 19 3,146' 5-1/2" 0.12 Ga. Screen, ID=4.778" 20 3,276' 1 9-5/8" HES Sump Packer set on a -Line 10/14/1996 PERFORATION DETAIL - Ref Log: Open hole MWD 10/14/96 Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status 2,558' 2,614' 2,250' 2,288' 56 10/15/1996 Open 2,614' 2,666' 2,288' 2,322' 52 10/15/1996 Open 2,666' 2,728' 1,322' 2,364' 62 10/15/1996 Open Upper Prince 2,728' 2,740' 2,364' 2,372' 12 10/15/1996 Open Creek 2744 2,752' 2,372' 2,380' 12 10/15/1996 Open 2752' 2,770' 2,380' 2,392' 12 10/15/1996 Open 21770' 2,782' 2,392' 2,400' 12 10/15/1996 Open 2,782' 2,800' 2,400' 2412' 18 10/15/1996 Open 2,800' 2,828' 2,412' 2431' 28 10/15/1996 Open 2,948' 2,964' 2,513' 2524' 16 10/15/1996 Opjeo Lower Prince 2,994' 3,060' 2,544' 2590' 66 16/15/199fi Op Creek 3,086' 3,100' 2,608' 2617' 14 10/15/1996 Op 3,110' 3,270' 2,624' 2737' 160 10/14/1996 26gm Jumbo Jet charges @ 60 deg. phasing (w/ 0.74" EHE) and 5.8" TTP) w/ 135 / 45 deg. phasing GRAVEL PACK DETAIL Upper Zone: 8,1001bs 20-40 Carbolite 10/20/1996 Lower Zone: 5,40016s ofof 20-40 Carbolite 10/15/1996 Min. Gravel Pack Restriction =3.00" GENERAL WELL INFO API: 50-029-22706-00-00 Drilled and Cased by Nabors 22E -10/22/1996 Change out ESP by Nabors 4ES -3/2/1997 Change out ESP by Nabors 4ES -10/7/1998 -Change out ESP by Nabors 4ES -8/18/2003 Change out ESP by ASR#1 -10/5/2016 Revised By: TDF 12/20/2019 H noire q, %L,4.0 IJA, 11" BOPE Milne Point ASR Rig 1 BOPE 2019 BR or Pipe Rams UITSI 'es STATE OF ALASKA ALTA OIL AND GAS CONSERVATION COMSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon (J Plug Perforations [_[ Fracture Stimulate ❑ Pull Tubing[.J Operations shutdown U Performed: Suspend ❑ Perforate El Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill p Nforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ESP Swap ❑✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development ❑ Exploratory ❑ 196-156 3.Address: Stratigraphic❑ Service ❑✓ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22706-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025509 MILNE PT UNIT TER F-58 RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): OCT0 2016 N/A MILNE POINT/TERTIARY UNDEF WTRSP 11.Present Well Condition Summary: AOGCC Total Depth measured 3,790 feet Plugs measured 3,676 feet true vertical 3,110 feet Junk measured N/A feet 2,424,2,846& Effective Depth measured 3,676 feet Packer measured 3,276 feet 2,160,2,443& true vertical 3,028 feet true vertical 2,742 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 113' 113' N/A N/A Production 3,772' 9-5/8" 3,772' 3,097' 9,440psi 5,300psi Perforation depth Measured depth See Attached Schematic %7 s.. SCANNED MAR 124 d7: True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 5-1/2" 17#/L-80/BTC-Mod 1,976' 1,828' (2)Versatrieve Packers and SSSV(type,measured and true vertical depth) Sump N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 580 0 Subsequent to operation: 0 0 0 560 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑] Exploratory❑ Development[] Service ✓❑ Strattgraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas 0 WTRSP❑✓ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-441 Contact Paul Chan\, Email pchanAhilcorp.com Printed Name Bo York Title Operations Manager r Signature , " -~"'-- Phone 777-8345 Date 10/19/2016 Cy: /0—?-7—/6 , ("74-4 Form 10-404 Revised 5/2015 RBDMS LL—OCT 14 2016 Submit Original Only II . • Milne Point Unit Well: MPU F-58 WSW SCHEMATIC Last Completed:8/18/2003 Ham Alaska,LLC PT©: 196-156 TREE&WELLHEAD Orig.DF Elev.:41.5'/Orig.GL Elev.:11.6' Tree CIW 4-1/16"5M'FLS' k 11"x 12"5M FMC Gen 5 Unibore w/two 2"5M valves on 20' ;' Wellhead side ports 11"x 4-1/8"5M adapter and 11"x 4.5"tbg hng 4.5"NSCT threads top and bottom and 4"CIW-H 4-1/2"x5-1/2" WELL INCLINATION DETAIL Crossover ; KOP 10°@ 702' OPEN HOLE/CEMENT DETAIL Mn ID"3.83320" Cmt w/250 sx Arcticset 1(Approx.)in a 24"Hole Max Hole Angle=49°f/2,584' 9-5/8" 1,037sx PF'E',550sx Class`G'in a 12-1/4"Hole Hole angle thru perfs=48.2° CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm E 20" Conductor 91.1/H-40/N/A N/A Surface 113' 9-5/8" Surface 47/P-110/Mod Btrc. 8.681 Surface 3,772 TUBING DETAIL 5-1/2" Tubing 17/L-80/Mod Btrc 4.892 Surface 2,369' JEWELRY DETAIL No Depth Item 1 1886.7' Discharge Head 2 1,887 Pump:HVHVUAR 3 1,894' Pump:HVHVMAR 4 1,909' Pump:w/Integral Intake HPHVLAR 5 1,924' Upper Tandem Seal: HSB3DB UT M FER SB/SB PFSA 6 1,931' Lower Tandem Seal:HS83DB LT M SB/SB PFSA 7 1,939' Motor:CL5 HMI 8 1,974' Centralizer: Bottom @ 1,976' 9 2,424' 9-5/8"HES Versatrieve Packer 10 2,454' Safety Shear Sub, Min ID=3.00" 11 2,457' 5-1/2",20 ppf, N-80,LTC Blank Pipe;ID=4.778" 12 2,552' 5-1/2"0.12 Ga.Pre-Pack Screen,ID=4.778" 13 2,709' 5-1/2"0.12 Ga.Screen,I13=4.778" 14 2,846' 9-5/8"HES Versatrieve Packer 15 2,877 Safety Shear Sub, Min ID=3.00" 0 1 16 2,879' 5-1/2",20 ppf, N-80,LTC Blank Pipe;ID=4.778" 17 2,936' 5-1/2"0.12 Ga.Pre-Pack Screen,ID=4.778" 2,3&4 18 3,146' 5-1/2"0.12 Ga.Screen,ID=4.778" I , 19 3,276' 9-5/8"HES Sump Packer set on a-Line 10/14/1996 5&6 PERFORATION DETAIL-Ref Log: Open hole MWD 10/14/96 PSand Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 2,558' 2,614' 2,250' 2,288' 56 10/15/1996 Open 72,614' 2,666' 2,288' 2,322' 52 10/15/1996 Open . I fig;` 2,666' 2,728' 2,322' 2,364' 62 10/15/1996 Open 2,728' 2,740' 2,364' 2,372' 12 10/15/1996 Open 8 Upper Prince 2,740' 2,752' 2,372' 2,380' 12 10/15/1996 Open 9 Creek 2 752' 2,770' 2,380' 2,392' 12 10/15/1996 Open 110 2,770' 2,782' 2,392' 2,400' 12 10/15/1996 Open g, X12 2,782' 2,800' 2,400' 2412' 18 10/15/1996 Open 2,800' 2,828' 2,412' 2431' 28 10/15/1996 Open ;,13 2,948' 2,964' 2,513' 2524' 16 10/15/1996 Open # 1. ° �' I"14 Lower Prince 2,994' 3,060' 2,544' 2590' 66 10/15/1996 Open j15 Creek 3,086' 3,100' 2,608' 2617' 14 10/15/1996 Open El s 1iii iii' !v 1 i 6 3,110' 3,270' 2,624' 2737' 160 10/14/1996 Open f ' 6 26gm Jumbo Jet charges @ 60 deg.phasing(w/0.74"EHD and 5.8"TTP)w/135/45 deg.phasing 18 GRAVEL PACK DETAIL GENERAL WELL INFO ;19 Upper Zone:8,1001bs of 20-40 Carbolite 10/20/1996 API:50-029-22706-00-00 Lower Zone:5,400lbs of 20-40 Carbolite 10/15/1996 Drilled and Cased by Nabors 22E -10/22/1996 Min.Gravel Pack Restriction=3.00" Change out ESP by Nabors 4ES -3/2/1997 9-5/8" ' Change out ESP by Nabors 4ES -10/7/1998 Change out ESP by Nabors 4ES -8/18/2003 TD=3,790(MD)/TD=3,11t7(TVD) Change out ESP by ASR#1 -10/5/2016 PBTD=3,676'(MD)/PBTD=3,028'(TVD) Revised By:TDF 10/19/2016 s • : ',',, 2: 7 , , Hilcorp Alaska, LLC �' Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-58 ASR#1 50-029-22706-00-00 196-156 10/2/16 10/5/16 Daily Operations: 9/28/2016 -Wednesday No activity to report. 9/29/2016-Thursday No activity to report. 9/30/2016- Friday No activity to report. 10/1/2016-Saturday No activity to report. 10/2/2016-Sunday RU on F-58. Spot pits in place. Obtain Hot Work Permit from Pad Operator and perform welding on Rig Floor while sitting on trailer at edge of pad. ND Tree. NU BOPE. Set well cover& Rig floor over F-58. Release crane. Spot Wellsite trailers. Fill pits w/140°water w/ 1% KCL. SIMOPS: Obtain Hot Work Permit and perform welding in pits on new shale shaker. Move rig onto mud boat. Raise Derrick and pin same. Install Derrick anchors to rig.Torque up BOP flanges. Connect gas alarms, caliber&test same. Spot Catwalk. RU & install Accumulator lines. Fill 400 bbl. upright tank w/ 140°water w/ 1% KCL. Change Top Rams to 5-1/2" Solid body. Well head rep Remove BPV and Installed TWC Valve in Tubing Hanger. Fill Bop Stack W/Fresh Water,Shell Test Connections 250 to 2,500 psi (Good Test).Test Bop 250/2,500 psi 5Min Each,Annular 250/1,500 psi 5 Min Each Record Accumulator Pre Charge Pressures and Charted (AOGCC was notified of upcoming BOP test via website at 07:30 on 10-1-16.AOGCC Rep. Bob Noble Waived witness of Bop Test at 10:00 am on 10-2-2016). Safety Sundry Meeting with Rig Crew, Centrilift on MPF-58 Procedure. Well Head Rep Tee Bar Removed TWC Valve. Circulate Freeze Protection out of Well, Pump 10 bbl. Down Annuals, Change over Pump 25 bbl. Down Tubing Take Returns to Flow Back Tank(Total Returns to tank 20 bbl.) M/U Landing Joint RIH Screw into Hanger, BOLDS Open IA Psi=0 Pull hanger to the Rig Floor @ 43k Free Pull. Break out and Lay Down Landing Joint and Tubing Hanger,Tie ESP Cable to Spooler.Trip out of the Hole with 5-1/2" Tubing and ESP Assembly to 120 ft. 10/3/2016 Monday Continue to LD 5-1/2" ESP completion to ±1,500'.VMS Mechanic trouble shooting Rig engine error codes. Replaced EGR sensor and repaired an air leak on the intake.;Continue to LD 5 1/2" ESP completion. LD ESP pump and motor assembly.;Change top Rams to 2 7/8" x 5" VBR's.;Test rams w/3 1/2" test joint to 250 psi low, 2500 high for 5 charted min. each test.Test Annular w/3 1/2" test joint to 250 psi low, 1500 high for 5 charted min. each test.;Break and lay down 3.5 Test Joint, Open IA=0 Psi Bolds Pull and Remove Test Plug and Lay Down;Pick up 9-5/8 47#Casing Scraper, RIH 3-1/2 CS Hydrill Tubing to 2,300 ft. P/U/W=20K D/N/W=13k;Rig up to Circulate to Flow back Tank, Reverse Circulate with a pump Rate of 3.1 bpm @ 100 Psi Total 50 bbl. Pumped;Trip out of the hole Lay down 3-1/2 Tubing and 9-5/8 Casing Scraper;Load and Tally 9 x 4.75 Drill Collars on Pipe Rack;Pick and Make up 9-5/8 RTTS Packer& 9 x 4.75 Drill Collars, • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-58 ASR#1 50-029-22706-00-00 196-156 10/2/16 10/5/16 Dai!Operations:peratit r s: _ e� 21 ���11�1 �504PREP 10/4/2016-Tuesday RIH w/9-5/8" RTTS & (9) 4-3/4" DC's on 3-1/2" CS Hyd. workstring f/±300'to 2,250'. Set RTTS w/ 1 RH turn & 20k down wt. Fill hole w/7 bbls.Test 9-5/8" casing f/2,250' to surface w/2,000psi for 30 charted minutes. Good test. Bleed off pressure, open rams. Release RTTS. POH LD 66 jts of 3-1/2" RTS-8 workstring. LD (9) 4-3/4" DC's and RTTS. Change top rams f/2-7/8" X 5" to 5-1/2" solids.Test top 5-1/2" rams to 250psi low, 2,500psi high f/5 charted min. each test. Lay down Test Joint, Open IA=0 psi BOLDS Remove Test Plug. Load New ESP Pump Assembly on Cat walk, Load and Tally 5-1/2" Completion Tubing on Racks. Pick up and Service ESP Pump Assembly. RIH w/5-1/2" IBTC-Mod Tubing& ESP Completion Assembly. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-58 ASR#1 50-029-22706-00-00 196-156 10/2/16 10/5/16 Daily Operations: 10/5/2016 Wednesday Continue to RIH w/ ESP completion on 5-1/2" IBTC-Mod tubing to 1,940'. Change over to 4-1/2" handling equipment. PU 4- 1/2" x 11" tubing hanger& Landing Joint. Make cable penetrations through hanger.Test same. Land Hanger. Wellhead Rep. RILDS. Base of ESP at 1,976'. PUW 39k-SOW 28k. Set BPV. Break out Landing Joint and Lay Down. NOTE: AOGCC was notified of upcoming F-94 BOP Test via website at 11:13 hrs on 10-5-16. Well Rep Tee Bar and set TWC Valve in Hanger (Well Kill Operations on the MPF-94 IA-0 psi TBG=0 psi Install BPV). Electricians Disconnected Fire and Gas Alarms, Nipple Down Bope Stack to Four Bolts, Blow down all Service Lines and Disconnect. Break over and Lower Derrick, Move rig off Mud Boat, ASRC Crane Removed Mud Boat Rig Floor and Well House. SIMOPS: RU LRS on F-94.Test high Pressure lines to 3,100psi & return lines to 500psi. Begin pumping down tubing w/3-1/2bpm. Caught fluid at 14 bbls away. Observed returns at 42 bbls away (crude). Continue pumping&stage up to 4-1/2bpm, 2,100psi. Pump total of 650bbls w/425bb1s returns (50%crude/ Prod.) Remove Bop Stack Load on Trailer Installed Production Tree and Nipple up Tested Hanger Void to 5,000psi, Centrilift Conduct Final Checks on Equipment (Good Test.) 10/6/2016 -Thursday R No activity to report. 10/7/2016- Friday No activity to report. 10/8/2016-Saturday No activity to report. 10/9/2016-Sunday No activity to report. 10/10/2016- Monday No activity to report. 10/11/2016-Tuesday No activity to report. • , 8.OF TtJ y,9\\�1/yy-.�� THE STATE Alaska Oil and Gas g o-a��.a o f TA S1(AConservation Commission ittiti-=,---,-----:_,1-cf.-- �,,..,.--'"'-- 333 West Seventh Avenue ".,, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *' Main: 907.279.1433 oP 41,Ael‘ts' Fax: 907.276.7542 www.aogcc.alaska.gov Bo YorkSEP 3 0 2016 Operations Manager SC.A*EQ Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Tertiary Undefined WTRSP Pool, MPU F-58 Permit to Drill Number: 196-156 Sundry Number: 316-441 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, A/2;d, Cathy . Foerster Chair DATED this /61-day of September, 2016. RBDMS Lv qtr - 1 2016 0 • RECEIVED STATE OF ALASKA AU 2 6 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION 5 / 3///e APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 9 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 9 V Operations shutdown 9 Suspend ❑ Perforate ❑ Other Stimulate 0 Pull Tubing 0 • Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Swap - 9 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska LLC 1 Exploratory ❑ Development 9 196-156 " 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ � 6.API Number. Anchorage Alaska 99503 50-029-22706-00-00 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A. / Will planned perforations require a spacing exception? Yes ❑ No ❑., / MILNE PT UNIT TER F-58 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025509 . MILNE POINT/TERTIARY UNDEF WTRSP , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 3,790' 3,110' 3,676' 3,028' 100 3,676' N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 113' 113' N/A N/A Production 3,772' 9-5/8" 3,772' 3,097' 9,440psi 5,300psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(it): See Attached Schematic I See Attached Schematic 5-1/2" 17#/L-80/Mod Btrc 2,369 Packers and SSSV Type: Packerrs and SSSV MD(ft)and TVD(ft): (2)9-5/8"Versatrieve Pkr&Sump Pkr and N/A 2,424(MD)/2,160(TVD),2,846(MD)/2,443(TVD)&3,276(MDy 2,742(TVD)and N/A 12.Attachments: Proposal Summary 9 Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program 9 BOP Sketch O Exploratory 9 Stratigraphic 9 Development❑ Service 9 14.Estimated Date for 15.Well Status after proposed work: 9/9/2016 Commencing Operations: OIL 9 WINJ ❑ WTRSP 9 ' Suspended ❑ 16.Verbal Approval: Date: GAS 9 WAG 0 GSTOR ❑ SPLUG 9 Commission Representative: GINJ 9 Op Shutdown 9 Abandoned 9 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Paul Chan Email pchan@hilcorp.com Printed Name Bo York Title Operations Manager Signature ' ,' Phone 777-8345 Date 8126/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity 9 BOP Test Mechanical Integrity Test 9 Location Clearance 9 Other: 44.. 'Z,SCo Qt 1 Cao? `( szes.s i.0 \eSS t — 45i Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes 9 Nod Subsequent Form Required: 1O- 404 9404,,...$14---- -w('�/ APPROVED BY C04/,Approved by: / �," COMMISSIONER THE COMMISSION Date:/—/6 714.3 VA//f° NaQ 911111b RBDMS Lt---SEP - 1 2016 Submit Form and Form 10-403 Revised 11/2015 pLNALfor 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MPU F-58 Iiikor)Alaska,LLQ Date:8/26/2016 Well Name: MPU F-58 API Number: 50-029-22706-00 Current Status: Water[Failed ESP] Pad: F-Pad Estimated Start Date: September 9th, 2016 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-156 First Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Current Bottom Hole Pressure: 1,073 psi @ 2,500'TVDss (SBHPS 05/07/2016/8.25 ppg EMW) Maximum Expected BHP: 1,073 psi @ 2,500' TVDss (No new perfs being Added) r MPSP: 100 psi (SITP. Prince Creek Water supply well with 0.433 psi/ft gradient) Brief Well Summary: MPU F-58 was drilled and completed with a gravel pack in October 1996 as a Tertiary water source well. The well has had multiple ESPs installed: October 1996 (initial), March 1997, October 1998, and August 2003. The ESP has failed. Notes Regarding Wellbore Condition • Casing tested to 3,676' PBTD on 10/5/1996 to 3000 psi (pressure test after cementing operations). Objective: Pull failed ESP, pressure test casing, and run a new ESP. Brief RWO Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well.Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services and 500 bbl returns tank with choke manifold. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.45 ppg filtered water down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services. 8. Set BPV. RU crane. ND Tree. NU 11" BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. • • Well Prognosis Well: MPU F-58 Hilcorp Alaska,LLQ Date:8/26/2016 WO Rig Procedure: 10. MIRU Hilcorp ASR#1 WO Rig,ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.45 ppg filtered water prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/1,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 3-1/2" and 5-1/2"test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection,etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.45 ppg filtered water as needed. 15. MU landing joint or spear and recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 16. POOH and lay down the 5-1/2"tubing. Tubing may be re-used. Lay down failed ESP. f. Thread protectors required to lay down the 5-1/2" BTC-mod tubing. g. Replace bad joints of tubing as necessary. 17. RIH with scraper assembly to 2,300' MD on 3-1/2" workstring. Circulate the well clean. If needed, spot sized salt pill to control losses. POOH. 18. PU test packer and RIH to"'2,250' MD. Pressure test casing to 2,000 psi for 30 charted minutes. POOH and LD test packer and workstring. 19. PU new ESP and RIH on 5-1/2" 17#/ft L-80 mod-BTC tubing. Set base of ESP at± 1,960' MD 20. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO(Slack Off)weights on tally. 21. Set BPV. • Well Prognosis Well: MPU F-58 !Mewl)Alaska,LL' Date:8/26/2016 Post-Rig Procedure: 22. RD mud boat. RD BOPE house. 23. RU crane. ND BOPE. 24. NU existing 4-1/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 25. RD crane. Move 500 bbl returns tank and rig mats. 26. Replace gauge(s) if removed. 27. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Flow Diagram—FWD Circulating 6. Blank RWO MOC Form • Milne Point Unit Well: MPU F-58 WSW II • SCHEMATIC Last Completed: 8/18/2003 Mewl)Alaska,LLC PTD: 196-156 TREE&WELLHEAD Orig.DF Elev.:41.5'/Orig.GL Elev.:11.6' Tree CIW 4-1/16"5M'FLS' L 11"x 12"5M FMC Gen 5 Unibore w/two 2"5M valves on 20 Wellhead side ports 11"x 4-1/8"5M adapter and 11"x 4.5"tbg hng 4.5"NSCT threads top and bottom and 4"CIW-H OPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sx Arcticset 1(Approx.)in a 24"Hole 9-5/8" 1,037sx PF`E',550sx Class'G'in a 12-1/4"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" _ Conductor 91.1/H-40/N/A N/A Surface 113' 9-5/8" Surface 47/P-110/Mod Btrc. 8.681 Surface 3,772 TUBING DETAIL 5-1/2" Tubing 17/L-80/Mod Btrc 4.892 Surface 2,369' JEWELRY DETAIL No Depth Item 1 2,286' Upper Pump Type 35 Stage HC12500 2 2,304' Lower Pump Type 35 Stage HC12500 3 2,322' Tandem Seal Section 4 2,369' Motor 750 HP/4,160V/108A 5 k 2,424' 9-5/8"HES Versatrieve Packer 6 2,454' Safety Shear Sub,Min ID=3.00" I 1 7 2,457' 5-1/2",20 ppf, N-80,LTC Blank Pipe;ID=4.778" 8 2,552' 5-1/2"0.12 Ga.Pre-Pack Screen,ID=4.778" 9 2,709' 5-1/2"0.12 Ga.Screen,ID=4.778" 10 2,846' 9-5/8"HES Versatrieve Packer 11 2,877' Safety Shear Sub,Min ID=3.00" 12 2,879' 5-1/2",20 ppf, N-80,LTC Blank Pipe;ID=4.778" 13 2,936' 5-1/2"0.12 Ga.Pre-Pack Screen,ID=4.778" 14 3,146' 5-1/2"0.12 Ga.Screen,ID=4.778" I °! 15 3,276' 9-5/8"HES Sump Packer set on a-Line 10/14/1996 WELL INCLINATION DETAIL €; 1&2 KOP 10°@ 702' Max Hole Angle=49°f/2,584' ».' 1111 �' Hole angle thru perfs=48.2° 1° 4N: s' 3 i = ' PERFORATION DETAIL-Ref Log: Open hole MWD 10/14/96 $,i z Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status s } F.:4 2,558' 2,614' 2,250' 2,288' 56 10/15/1996 Open 2,614' 2,666' 2,288' 2,322' 52 10/15/1996 Open %' 2,666' 2,728' 2,322' 2,364' 62 10/15/1996 Open °, 2,728' 2,740' 2,364' 2,372' 12 10/15/1996 Open t' 5 Upper Prince 2,740' 2,752' 2,372' 2,380' 12 10/15/1996 Open 6 Creek 2,752' 2,770' 2,380' 2,392' 12 10/15/1996 Open y: III iii F'8 2,770' 2,782' 2,392' 2,400' 12 10/15/1996 Open * $ 2,782' 2,800' 2,400' 2412' 18 10/15/1996 Open . . 9 2,800' 2,828' 2,412' 2431' 28 10/15/1996 Open i_,; ro10 2,948' 2,964' 2,513' 2524' 16 10/15/1996 Open 12 Lower Prince 2,994' 3,060' 2,544' 2590' 66 10/15/1996 Open 13 Creek 3,086' 3,100' 2,608' 2617 14 10/15/1996 Open 3,110' 3,270' 2,624' 2737 160 10/14/1996 Open 114 26gm Jumbo Jet charges @ 60 deg.phasing(w/0.74"EHD and 5.8"TTP)w/135/45 deg.phasing HI III fib=HI N;ry GRAVEL PACK DETAIL GENERAL WELL INFO , ,1s sr Upper Zone:8,100Ibs of 20-40 Carbolite 10/20/1996 API:50-029-22706-00-00 �& Drilled and Cased byNabors 22E -10 22 t Lower Zone:5,4001bs of 20-40 Carbolite 10/15/1996 / /1996 9-5/8"41, * 4Min.Gravel Pack Restriction=3.00" Change out ESP by Nabors 4ES -3/2/1997 Change out ESP by Nabors 4ES -10/7/1998 TD=3,790'(MD)/TD=3,110'(TVD) Change out ESP by Nabors 4ES -8/18/2003 PBTD=3,676'(MD)/PBTD=3,028'(TVD) Revised By:PC 8/24/2016 • • • iti Milne Point ASR Rig 1 BOPE lid,orp 11n.1ky.1.1I 11" BOPE , , Stripping Head 1 3.98' ' Shaffer ° ii."_ 5000 i Iiir liiI liI !held UI lIti I 4.54' H 111111 C Iblibi7U ,.. I P N H VBR or Pipe Rams r. H i '.-1 11" 5000 ' ii ` H Blind 0®® -a itt non ti 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves r I 'lin Pilir I 1 t 2.00' : • o)i) .1 , , ,-1. I 111 11 l 111 i11JI' _ Manual Manual Manual HCR Updated 8/19/2015 • • MPU F-58 . EXISTING TREE/WELLHEAD Wellhead/Tree HilcorpAlaska,1.1,C Milne Point Unit Tree Cap ill It1 lit" 0!I X00,err .. Tree Valve 4-1/16" 5M nr°� 00 illi Ill b Tree Cross 4-1/16" 5M [F 4:11 Tree Valve 4-1/16" 5M SSV 4-1/16" 5M 0 Iftl_ _1p' I ' c , Tree Valve 4-1/16" 5M it.. (oma 4p0" In hod In ESP Cable I`I I`I Tubing Adapter _ - 1 (' .- Tubing Head lir-- Eat 11" 5M Top x 11" 5M Btm � � —�� D40 1E11 r l : ' il" 11, ■-j'.� no Ill • • C 1°u d 0 •>• se L L•k, m W .o > > Faa- go V'� 7 i3 m o R p - e L V u. > m .4 a V.r'. cn . I X Z"o g4Pal 0 m zpc 116 Q D0 on 9J I 0* ° to' 74U n r-. mo d G > -TV R J z o = e z 0wd > Y a z V; YO - > u . o z a wa 3 c3 -6 a 111' •••tal--Cm ..a w > c7 m o d .� z w ID m; 63 TIS VT) m ' Y M• V• l7 M H Y V = V v� m d V - _ _ m 0 G C O - o m - :A: a c a v ii cn II II II II II C.,) 3 3 3 3 3 TT . cn et1 0 It 5 .� z' v v a a n. a p. 5 4 v1 0 G. -Ti y -0 a 0 .c S a C 2 a i3 ii' N N N Y 4 O N re WV 0 G >, a0 2 O > N C-0 F-.. ♦ V c• Ia Q _ - z •0 Y ca ^ ` Z •o N V Y• , ~ N E o Y c 0r Z I- V Ill C CO - m 0 Y T A -cox ill', cp-C H I ce H F W N w N e m Q Y Y a F z it n:11� -I l__9N v J Y: ..1 • .1 • in} d H lD 2I- c7 n d H F- K d NQ 2 -{ I- -NJ- F -1 I-,—1 1_____. IooI• 23_1 4111 C- vim, - • • Cow g f � k 6 / J2 73 m / / 0 > g > 0 E o 0 2 .E 7 < \2 0. § o< ""- 6 E c o .g -0 0 O 7 m7, O 0 ,>.; f § = 0. \ E <0. " ._ _ 0 0 \• / 2c o• \ % = \ƒ 7 0- \ \ 0 > co % .§ 0 ■ o \ R R § 0 C• O \ Q yL. \ 5 w ± § Q Co = k 9 > 0 al m 11. = 0- / a \ 0 2 % / _ 20 0 la k 2 % § 2 E § a = G e 0 2\ \ 0 .0 a \ 0 C 0 Cl) \ CI) T 0 \ � k ° j CD 0- /� c 0 o < \ > CO LU a ° c + o % � al w qQ ~ 0 2 � o o ■ 0 U) o .2 CO40 k / / '.7 0 0. 0. a / 0 0 a S .. e S \ $ k -a E 0 a. 0 n o a o $ / CO < \ S bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder t c6 Alaska Oil and Gas Conservation Commission ( f 333 West 7 Avenue � Anchorage, Alaska 99501 �n 1"' � Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -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 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft Ibis ft gal MPF -01 1950450 50029225520000 10.2 WA 10.2 N/A 122.4 8/7/2011 MPF -02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/92011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 822011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/12011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/12011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF-33 2010620 50029226890000 23 Need top job MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF-37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF -41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 WA 13.6 8/1/2011 MPF-45 1950580 50029225560000 8 N/A 8 N/A 782 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 ••••••I,r MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 136 8/11/2011 MPF-66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF -69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF-81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF -83 2000930 50029229630000 12 N/A 12 N/A 13.6 8/32011 MPF-84B 2001760 50029229310200 1.2 N/A 12 N/A 102 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF-88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 12 N/A 102 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 RE: Milne Point K-pad water supply well MPK-34 (PTD #1961690)... e e Subject: RE: Milne Point K-pad watersµpply well M:PK.;.34 (PTD #1961690) and F-Pad water supply well~2, 21, 5~;i'aI1d 77 (PTDtF19p0700, #1961350,_~P~hd #1951360):.}i" From: "MPU, Well Operations Supe};Visôr" <welloperationsšupervisor@BP.côm> .. Date: Tl1u,29 Dec 2005 07:05:21 -0900,,\' To:Ï!ho~ås Mã~iT,cl.~~;'?1t9rt1~ rt1aundei@ad~in.s!,ate.ak. us> Thanks Tom! JRC ~ç^N~U;'L.) From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, December 29, 2005 6:50 AM To: MPU, Well Operations Supervisor Cc: MPU, Operations Manager; Jim Regg Subject: Re: Milne Point K-pad water supply well MPK-34 (PTD #1961690) and F-Pad water supply wells MPF-02, 21, 58, and 77 (PTD #1960700, #1961350, #1961560, and #1951360) Hi John, I did some checking as well. Your understanding regarding a regulatory requirement for SSV s on water supply wells is correct. There is no requirement to employ SSVs on such wells. Thanks for checking. Tom Maunder, PE AOGCC MPU, Well Operations Supervisor wrote, On 12/28/2005 6:12 PM: Hi Tom, As per our conversation yesterday, I am curious if we are required to have a functioning SSV on our water supply wells here at Milne Point. These wells produce from the Prince Creek and Ugnu formations and are not hydrocarbon producing. From what I can gather reading through the regulations, I can't see where we are required to have a functioning SSV on these wells, but wanted to check with you to make sure. The wells were equipped with SSVs when they were drilled, but we would like to remove the panels and use them elsewhere if they are not required on our source water wells. Our source water wells are not capable of unassisted flow and are produced with Electrical Submersible Pumps. These wells are equipped with pilots that will shut down the ESP if the flowline pressure drops below 500 psi (i.e. we develop a leak). Thanks for your help on this Tom and please don't hesisitate to let me know if you need any further information. Best Regards, John R. Cubbon MPU Well Operations Supervisor 1-907 -670-3330 1 of 1 12/29/20057:10 AM STATE OF ALASKA ALASK/( L AND GAS CONSERVATION C¢(' 41SSION REPORT OF SUNDRY WELL OPERATIONS Prince Creek Water Source 1. Type of Request: [] Abandon [] Suspend [] Operation Shutdown [] Pedorate [] Variance [] Othe~ ~ Alter Casing [] Repair Well [] Plug Perforations [] Stimulate ~ Time Extension Change Out ESP ~ Change Approved Program [] Pull Tubing [] Perforate New Pool [] Re-Enter Suspended Well [] Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. [] Development [] Exploratory 196-156 3. Address: [] Stratigraphic [] Service 6. APl Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22706-00-00 7. KB Elevation (ft): KBE = 41.10' 9. Well Name and Number: MPF-58 8. Property Designation: 10. Field / Pool(s): ADL 025509 Milne Point Unit / Prince Creek 11. Present well condition summary Total depth: measured 3790 feet true vertical 3110 feet Plugs (measured) N/A Effective depth: measured 3676 feet Junk (measured) N/A true vertical 3028 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 112' 112' Surface Intermediate Production 3743' 9-5/8" 3772' 3097' 9440 5310 Liner Perforation Depth MD (ft): 2558'- 3270' Perforation Depth TVD (ft): 2250'- 2737' Tubing Size (size, grade, and measured depth): 5-1/2', 17# L-80 2369' , Packers and SSSV (type and measured depth): 9-5/8" HES Versatrieve Packers 2424' & 2848' 9-5/8" HES Sump Packer 3276' i2. stimulation or Cement squeeze summary: Intervals treated (measured): i:~i?,' ~ii~;,~i/'~'"'"" :i?',',ii'.'~ ............ ':~ '"~' ~:!.,..~,, '~,~.~-~'~' 1.4 ....... ~:, .. ~.,,,.,, ~.i .,:',.. Treatment description including volumes used and final pressure: SEF' ~, ~ ~?.8t'.t~!~ ,l.,,~,.~,,~:,~ fl)it ,~;~ ~"",' '. ~''' ' 13. Representative Daily Avera, 0e Producti~'br Injectioil,~,~_~. ,,t_er~,; ~ Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing p,ressure Prior to well operation: Subsequent to operation: . ,,, .... 14. Attachments: 15. Well Class after proposed work: [] Copies of Logs and Surveys run [] Exploratory [] Development [] Service .,, ,,, [] Daily Report of Well Operations 16. Well Status after proposed work: [] Oil [] Gas [] WAG [] GINJ [] WlNJ [] WDSPL 17. I h~eby certify that the foregOing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.~. Exempt: I Contact Robert Odenthal, 564-4387 Printed Name Sondra Stewman Title TechnicalAssistant Dat~ C~ ~. ~(~'~, 564-4750 q,~I~l~-~ r a Stewman, Form 10-404 Revised 2/2003 BP EXPLORATION Page 1 of 1 Operations Summary Report Legal Well Name: MPF-58 Common Well Name: MPF-58 Spud Date: 10/3/1996 Event Name: WORKOVER Start: 8/17/2003 End: 8/18/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/18/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From- To Hours Task Code NPT Phase Description of Operations 8/17/2003 00:00 - 03:00 3.00 MOB N WAIT PRE Stand-by waiting the completion of laying plywood and rig :matts on the road between L-Pad and F-Pad. Delay in not having the road matted was due to most of the plywood in use on the Rig 9e rig move. 03:00 - 10:00 7.00 MOB P PRE Move Rig and Equipment from MPI-08 to MPF-58. 10:00 - 11:30 1.50 RIGU P PRE Spot Sub, Pits, Pipe Shed, and Camp. Spot Tiger Tank. 11:30 - 13:00 1.50 RIGU P PRE Raise and scope Derrick. 13:00 - 14:00 1.00 RIGU P PRE Take on filtered 8.7 lb/gal Brine in Rig Pits. Rig up lines to Production Tree and Tiger Tank. Accept Rig at 13:00 hrs. 14:00 - 15:00 1.00 WHSUR P DECOMP Pick-up Lubricator and pull BPV. Lay down same. 15:00 - 15:30 0.50 WHSUR P DECOMP Pressure test lines to 3500 psi, Ok. Hold PJSM & pre-spud mtg. 15:30 - 17:00 1.50 KILL P DECOMP Open well. SITP 0 psi, SI annulus pressure 220 psi. Circulate & kill well w/8.7 Ppg fluid. Pumped @ 4 BPm, 500psi. Monitor well, well dead. 17:00-17:30 0.50 WHSUR 3 DECOMP Set TWC & test same to 3500 psi. 17:30 - 18:30 1.00 WHSUR 3 DECOMP Bleed off hanger void & N/D X-mas tree. 18:30 - 20:00 1.50 BOPSUI; ~ DECOMP N/U BOPE. 20:00 - 21:00 1.00 BOPSUF ~ DECOMP Test BOPE. Perform full body test & function test. LP 250 psi; HP 3500 psi. L/D test equip. Right to wittness test waived by AOGCC...J. Chrisp. 21:00 - 21:30 0.50 WHSUR 3 DECOMP M/U lubricator. Pull TWC & L/D lubricator. 21:30 - 00:00 2.50 PULL 3 DECOMP BOLDS. Bleed off hanger void. Pull hanger to floor & L/D same. Pull & L/D 5 1/2" ESP Completion. 8/18/2003 00:00 - 01:30 1.50 PULL ~ DECOMP Con't to POOH & L/D 5 1/2" tubing. Had 4 bad jts. #s: 20,21,43,44. 01:30 - 03:30 2.00 PULL ~ DECOMP Break out & L/D ESP. Motor had shaft twisted off. Left 8 bands in hole from around the pump. Crew change. 03:30 - 04:00 0.50 PULL P DECOMP Clear and Clean Floor. Install new ESP Cable in Spooling Unit. 04:00 - 06:00 2.00 RUNCOI~' COMP Pick-up, inspect and service new ESP Assembly. Crew change. 06:00 - 08:30 2.50 RUNCO~ COMP PJSM Lub Rig. Continue to service ESP Assembly. 08:30 - 09:30 1.00 RUNCO~/P COMP Pull MLE over Sheave. Connect new cable to Motor and test. Good. 09:30- 13:00 3.50 RUNCO~/P COMP TIH with ESPAssembly as follows: ESP Assy, XO, 52 Jr5 1/2" 17 Ib/ft IBTC L-80 Tbg, XO, 4 Jts 5 1/2" 17 Ib/ft 8rd LTC L-80 Tbg, XO, XO, Pup Jt, and Tubing Hanger. 13:00 - 15:30 2.50 RUNCOkP COMP Make up Tubing Hanger. Install Penetrater. Cut ESP Cable and install Field Connector. Test. Good. 15:30 - 16:00 0.50 RUNCOI~F' COMP Land 5 1/2" ESP completion. RILDS. 16:00 - 16:30 0.50 RUNCOI~P COMP Set TWC & test same to 3500 psi. OK. 16:30 - 18:00 1.50 BOPSUR P COMP N/D BOPE. 18:00 - 19:00 1.00 WHSUR P COMP N/U X-mas tree. 19:00 - 19:30 0.50 WHSUR P COMP Pressure test tree to 5000 psi, OK. 19:30 - 20:00 0.50 WHSUR P COMP M/U lubricator & pull TWC. Install BPV. Secure well. RELEASE RIG @ 20:00 HRS. 20:00 - 00:00 4.00 RIGD P POST RDMO to J-01. Printed: 8/25/2003 9:06:10 AM STATE OF ALASKA ALASKA C,,_ AND GAS CONSERVATION COM~v,,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown []Stimulate E~ Plugging E~ Perforate [] Pull Tubing []Alter Casing I~J Repair Well [~ Other Change Out ESP 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2117' NSL, 2645' WEL, SEC. 6, T13N, R10E, UM At top of productive interval 2924' NSL, 3226' WEL, SEC. 6, T13N, R10E, UM At effective depth 3465' NSL, 3819' WEL, SEC. 6, T13N, R10E, UM At total depth 3520' NSL, 3877' WEL, SEC. 6, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KB) KBE = 41' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-58 9. Permit Number / Approval No. 96-156 10. APl Number 50-029-22706 11. Field and Pool Milne Point / Prince Creek 12. Present well condition summary Total depth: measured 3790 feet true vertical 3110 feet Effective depth: measured 3676 feet true vertical 3028 feet Casing Size Structural Conductor 82' 20" Surface 3743' 9-5/8" Intermediate Production Liner Plugs (measured) Junk (measured) ORISI AL Length Cemented M D TVD 250 sx Arcticset I (Approx.) 1037 sx PF 'E', 550 sx Class 'G' 112' 112' 3772' 3097' Perforation depth: measured true vertical 2558'-2828',2948'-2964',2994'-3060',3086'-3100',3110'-3270' 2250'-2431',2513'-2524',2544'-2590',2608'-2617',2624'-2737' Tubing (size, grade, and measured depth) 5-1/2" 17# L-80 Mod BTRC tubing to 2359' Packers and SSSV (type and measured depth) Gravel Pack Screen Assembly with two 9-5/8" HES Versatrieve packers at 2424' and 2846'; 9-5/8" HES sump packer at 3276' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: F--I Oil [] Gas F-1 Suspended Service Prince Creek Water Source 17. I hereby certify that the f~egoing i~ect to the best of my knowledge Signed Terrie Hubble ' I'~,~"'~-- Title Technical Assistant III Prepared By Name/Number: Date ~' ~'q¢ Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Progress Report Facility M Pt F Pad Well MPF-58 Page 1 Rig Nabors 4ES Date 10 February 99 Date/Time 05 Oct 98 06 Oct 98 07 Oct 98 10:00-18:00 18:00-22:00 22:00-01:00 01:00-03:30 03:30-05:00 05:00-06:00 06:00-10:30 10:30-11:30 11:30-12:30 12:30-14:30 14:30-17:30 17:30-00:30 00:30-03:30 03:30-06:00 06:00-08:00 08:00-13:30 13:30-15:30 15:30-17:30 17:30-18:00 18:00-20:00 20:00-22:00 Duration 8hr 4hr 3hr 2-1/2 hr 1-1/2 hr lhr 4-1/2 hr lhr lhr 2hr 3hr 7hr 3hr 2-1/2 hr 2hr 5-1/2 hr 2hr 2hr 1/2 hr 2hr 2hr Activity Rig moved 100.00 % Cleared Chicksan lines Fill pits with Seawater Circulated at 2360.0 ft Rigged down Xmas tree Rigged up BOP stack Installed BOP stack Tested Blind / Shear ram Serviced Blind / Shear ram Serviced Blind / Shear ram Tested BOP stack Laid down 2360.0 ft of Tubing Conducted slickline operations on Slickline equipment - Tool run Rigged up sub-surface equipment - ESP Rigged up sub-surface equipment - ESP Ran Tubing to 2360.0 ft (5-1/2in OD) Rigged down BOP stack Installed Xmas tree Tested Xmas tree Freeze protect well - 140.000 bbl of Diesel Rigged up High pressure lines PERMIT DATA T DATA PLUS 96-156 GR/CCL-SET ~170-3378 96-156 SR/CCL-PER~ ~28S0-3360 96-1S6 SR/CCL ~2-3671 96-156 GR/CCL-PERF ~.L/~450-2818 96-1s6 pDX-100/O~/CCL ~2400-330o /' 96-156 GR/CCL-PERF /2550-2819 96-156 CDR MD ~_L/i12-3788 96-156 CDR TVD ~112-3108 96-156 7537 ~m~CHL. CDR ~0-~0~ AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 09/15/98 RUN RECVD 1 10/23/96 1 10/23/96 1 10/23/96 1 10/23/96 1 10/23/96 1 10/23/96 ~MPLETION DATE DAILY WELL OPS R /0/ ~/~/ TO )~) /~/~ / Are dry ditch samples required? yes ~___~d received? Was the well cored? yes ~Analysis & description received? Are well tests required~\ yes ~_~Received? Well is in compliance ~' Initial COMMENTS FINAL 11/27/96 FINAL 11/27/96 1 11/27/96 ~o/~7 ~/ ~ /~ '? / STATE OF ALASKA ALASKA ,.)IL AND GAS CONSERVATION CO~v~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: E~Operation Shutdown []Stimulate i--~ Plugging [] Perforate [~ Pull Tubing [--]Alter Casing I--I Repair Well I~ Other Change Out ESP 2. Name of Operator BP Exploration (Alaska)Inc. !3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2117' NSL, 2645' WEL, SEC. 6, T13N, R10E, UM At top of productive interval 2924' NSL, 3226' WEL, SEC. 6, T13N, R10E, UM At effective depth 3465' NSL, 3819' WEL, SEC. 6, T13N, R10E, UM At total depth 3520' NSL, 3877' WEL, SEC. 6, T13N, R10E, UM Type o~]well: Development Exploratory [--I Stratigraphic [~ Service 6. Datum Elevation (DF or KB) KBE = 41' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-58 9. Permit Number / Approval No. 96-156 10. APl Number 50-029-22706 11. Field and Pool Milne Point / Prince Creek 12. Present well condition summary Total depth: measured 3790 feet true vertical 3110 feet Effective depth: measured 3676 feet true vertical 3028 feet Casing Length Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) Size MD TVD Cemented 82' 20" 250 sx Arcticset I (Approx.) 112' 112' 3743' 9-5/8" 1037 sx PF 'E', 550 sx Class 'G' 3772' 3097' Perforation depth: measured true vertical 2558'-2614'~2666'-2728'~274~'-2752'~277~'-2782'~28~~'-2828'~2948'-2964'~2994'-3~6~'~ 3086'-3100',3110'-3270' 225~'-2288'~2322'-2364'~2372'-238~'~2392'-24~~~~2412'-2431'~2513'-2524'~2544'-259~'~ 2608'-2617',2624'-2737' Tubing (size, grade, and measured depth) 5-1/2" 17# L-80 tubing to 2361' 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. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl - Gas-Mcf Water-Bbl Casing Pressure Ar~j(-~ressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [--1 Oil [] Gas I--1 Suspended ¢lPl lkiAI Service Prince Creek Water Source 17. I hereby certify that the foregoing is true andc, c,orrect Signed ~ -" ~ - il Tim Schofield 7~'¢1 .~1~~ Form 10-404 Rev. 06/15/88 to the best of my knowledge Title Senior Drillin~l Engineer Prepared By Name/Number: Kathy Campoamor, 564-5122 Submit In Duplicate SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPF-58 Rig Name: N-4ES AFE: 339040 Accept Date: 02/27/97 Spud Date: - Release Date: 03/01/97 Feb 27 1997 MIRU. Level derrick, install herculite & safe out equipment. Rig lines to tree & thrash tank & take on kill fluid. Rig accepted 02/27/97 @ 0500 hrs. Feb 28 1997 Cont to rig to tree & pump actuator open & bullhead down tubing. Well on vacuum. ND tree & NU BOP's & test same. Test waived by B. Foster with AOGCC. RU to pull ESP completion. Attempt to release packer with tension pull-was successful. Rig HES wireline truck & RIH & set plug in profile no-go in packer & psi to 3000 psi & bleed off & work packer. Did not release. Psi tubing & work & release packer. RIH with wireline & retrieve plug & work tubing to get returns. Spot Zanvis pill. LD hanger & 2 jts. Tubing. Circ & displace diesel. POOH, LD 5-1/2" tubing. Mar 1 1997 POOH with ESP completion laying down 5-1/2" tubing & pump assy. RU & run GR/JB on HES slickline to 2424' top of gravel pack two runs & rec 3 bands & run 2" bailer to 3606' & POOH & RD truck. RU for ESP completion. MU & service PHD & motor & find PHD & motor bad. LD same. Wait on motor. PU new motor #2 & check,ok. Service flat lead wrong, cut & splice new flat lead, Wrong coupling for pump to seal section. Look for correct coupling. Did not find, LD motor #2. Wait on motor. MU ESP assy & service. RIH with ESP assy on 5-1/2" tubing to hanger. Mar 2 1997 MU penetrator. Make ESP pig tail splice. Land hanger, RILDS, LD landing jt, set TWC. ND BOP & ND 5-1/2" rams & NU 3-1/2" rams. NU tree & test same. Pull TWC, set BPV, RU hard lines to tree & test. Freeze protect well with diesel. Blow down lines- unhook from tree. Secure well. Rig released 03/01/97 @ 2200 hrs. Page STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [--i Gas [] Suspended [--I Abandoned [~ Service Prince Creek Water Source 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 96-156 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 . 50-029-22706 4. Location of well at surface ? ,%,%-,~"~ .':'~T.%-." "~ , ~,,..¢r.~,'L~. ~0,~ f 9. Unit or Lease Name 2117' NSL, 2645' WEL, SEC. 6, T13N, R10E, UM ! .P, AT!: I ' Milne Point Unit top of productive interval ~ _/~.~_~_~ ' " ~', 10. Well Number At 2924' NSL, 3226' WEL, SEC. 6, T13N, R10E, UM ! ~'.~d_~ ..... ' ~" At total depth ..... , il 1. Field and Pool 3520' NSL, 3877' WEL, SEC. 6, T13N, R10E, UM ~- Milne Point / Prince Creek 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 41'I ADL 025509 12. Date Spudded 113. Date I.D. Reached I 14. Date Comp., Susp., or Aband. I15. Water depth, if offshore I 16. No. of Completions 10/3/96 10/4/96 10/22/96 N/A MSLI One 17. Total Depth (MD+TVD)3790 3110 FT1118' P'ug Back Depth (MD+TVD)I19' Directi°nal Survey 120' Depth where SSSV set 121' Thickness °f Permafr°st3676 3028 FT1 [~] Yes i--I No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR/CCL, GR/JB 23. CASlNG~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 30' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 47# P-110 29' 3772' 12-1/4" 1037 sx PF 'E', 550 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SiZE DEPTH SET (MD) PACK~"~"~/~t")¢:~ 4-1/2" Gun Diameter, 12 spf 5-1/2", 17#, L-80 2367' 2219-~' MD TVD MD TVD ' 2558'-2614' 2250'-2288' J ~'~' 2666'-2728' 2322'-2364' 26. ACID, FRACTURE, CEMENT SQdE~,, ETC. '"':T.-'-,, ~ ;, /,~ 2740'-2752' 2372'-2380' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATER ~nn,., _ 2770'-2782' 2392'-2400' 2800'-2828' 2412'-2431' Freeze protect with 167 bbt~/i~er~ 2948'-2964' 2513'-2524' Gravel pac, 2424'-2709' 8100# 20/40 Carbolite behind pipe°'' 2994'-3060' 2544'-2590' Gravel pac, 2846'-3276' 5400# 20/40 Carbolite behind pipe 3086'-3100' 2608'-2617' 3110'-3270' 2624'-2737' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) November 7, 1996I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate 29. ' Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Water Sands 2558' 2250' Base Water Sands 3270' 2737' · 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I hereby certify that the foregoing is trjue and ~rect to the best of my knowledge Signed~ (.-'"~ _ ~'.,~~, ' ' ~'~/'- ~/, ~ ~//~'~7 Tim Schofleld / /.,/y'~ _"~ ~4--~f_~? Title Senior Drilling Engineer Date MPF-58 ~/96-156 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. /Approval No. INSTRUCTIONS GENER.AL: This form is designed for submitting a complete and correct well completion report and Icg 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 $: 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 02 Oct 96 03 Oct 96 04 Oct 96 05 Oct 96 06 Oct 96 M Pt F Pad Progress Report Well MPF-58 Rig Nabors 22E Page Date Duration Activity 06:00-06:30 06:30-16:00 16:00-18:00 18:00-18:30 18:30-23:00 23:00-01:00 01:00-02:00 02:00-03:30 03:30-06:00 06:00-06:30 06:30-08:00 08:00-10:00 10:00-10:15 10:15-11:00 11:00-16:30 16:30-17:00 17:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-09:00 09:00-10:00 10:00-10:30 10:30-12:00 12:00-13:00 13:00-18:00 18:00-18:30 18:30-21:00 21:00-22:00 22:00-22:30 22:30-00:00 00:00-01:00 01:00-02:00 02:00-03:30 03:30-04:00 04:00-05:30 05:30-06:00 06:00-06:30 06:30-06:45 06:45-08:00 08:00-09:30 09:30-14:30 14:30-15:00 15:00-16:00 16:00-18:00 i8:00-18:45 18:45-19:15 19:15-19:45 1/2 hr Held safety meeting 9-1/2 hr Rig moved 100.00 % 2 hr Rigged up Divertor 1/2 hr Held safety meeting 4-1/2 hr Rigged up Divertor 2 hr Rigged up Handling equipment 1 hr Tested Divertor 1-1/2 hr Racked back HWDP 2-1/2 hr Made up BHA no. 1 1/2 hr Held safety meeting 1-1/2 hr Made up BHA no. 1 2 hr Drilled to 280.0 ft 1/4 hr Pulled out of hole to 80.0 ft 3/4 hr Made up BHA no. 1 5-1/2 hr Drilled to 698.0 ft 1/2 hr Repaired High pressure lines 1 hr Drilled to 720.0 ft 1/2 hr Held safety meeting 11-1/2 hr Drilled to 1999.0 ft 1/2 hr Held safety meeting 2-1/2 hr Drilled to 2567.0 ft 1 hr Circulated at 2567.0 ft 1/2 hr Flow check 1-1/2 hr Pulled out of hole to 90.0 ft 1 hr R.I.H. to 2567.0 ft 5 hr Drilled to 3416.0 ft 1/2 hr Held safety meeting 2-1/2 hr Drilled to 3790.0 ft 1 hr Circulated at 3790.0 ft 1/2 hr Flow check 1-1/2 hr Pulled out of hole to 120.0 ft 1 hr Serviced Top drive 1 hr R.I.H. to 3790.0 ft 1-1/2 hr Circulated at 3790.0 ft 1/2 hr Flow check 1-1/2 hr Pulled out of hole to 240.0 ft 1/2 hr Pulled BHA 1/2 hr Held safety meeting 1/4 hr Held drill (Spill) 1-1/4 hr Pulled BHA 1-1/2 hr Rigged up Casing handling equipment 5 hr Ran Casing to 3772.0 ft (9-5/8in OD) 1/2 hr Rigged down Casing handling equipment 1 hr Circulated at 3772.0 ft 2 hr Mixed and pumped slurry - 355.000 bbl 3/4 hr Displaced slurry - 269.000 bbl 1/2 hr Circulated at 1333.0 ft 1/2 hr Held safety meeting 19:45-22:30 2-3/4 hr Circulated at 1333.0 ft 22:30-23:30 1 hr Mixed and pumped slurry - 295.000 bbl 23:30-23:45 1/4 hr Displaced slurry - 99.000 bbl 23:45-00:15 1/2 hr Tested Casing 00:15-02:30 2-1/4 hr Cleared Flowline 02:30-04:30 2 hr Rigged down Divertor 1 10 May 97 Facility Date/Time M Pt F Pad Progress Report Well MPF-58 Rig Nabors 22E Page Date Duration Activity 04:30-06:00 06:00-06:30 06:30-06:45 06:45-10:15 10:15-10:30 10:30-11:00 11:00-12:00 12:00-16:00 16:00-17:00 Installed Wellhead integral components Held safety meeting Held drill (Abandonment) Installed Xmas tree Tested All tree valves Rigged down Casing handling equipment Serviced Top drive Laid out 5in drill pipe from derrick Serviced Block line 2 10 May 97 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPF-58 Rig Name: N-4ES AFE: 347052 Accept Date: 10/12/96 Spud Date: - Release Date: 10/22/96 Oct 13 1996 MIRU. Rig accepted 10/12/96 @ 0900 hrs. Check well for pressure, ok. ND tree & adapter spool. NU BOP stack, change pipe rams to 3-1/2". Attempt test BOP, test plug leaking, change test plug rubber-still leaking. Install tubing hanger with TWC valve. Blind shear rams leaking. Change out blind shear rams. Test BOP. Test all rams, lines & valves. Test hydril, kelly, upper & lower kelly valve, TIW & IBOP-ok. Install WB. MU BHA. TIH, PU 3-1/2" DP. Tag ES cementer. Displace diesel to tiger tank with source water. Drill ES cementer, wash down. POOH for casing scraper. PU casing scraper in BHA. Attempt TIH, casing scraper would not go into wellhead. Pull WB. Still would not go. Install WB. PU 3-1/2" DP, stand back in derrick while waiting on new scraper from Baker. MU 9-5/8" casing scraper, TIH. Oct 14 1996 Cont TIH with 9-5/8" casing scraper to PBTD. CBU-mud & cement to surface on bottoms up. Pump dirt magnet water, clean water, dirt magnet water followed by NaCL. Clean pits. Circ & filter completion fluid. POOH, stand back DP. LD BHA. Close blind rams. Test casing, ok. ND bell nipple. NU perf flange to hydril. RU Atlas WL. Test lubricator. RIH with GR/CCL to PBTD. Log to surface. Perforate Prince Creek formation with 4-1/2" casing guns at 12 spf, RDX big hole charge, 135/45 degree phasing. Perfed 3270'-3170'. Correlated to GR/CCL log run by Atlas. Oct 15 1996 Cont perforating with 4-1/2" guns at 12 spf. Total 14 gun runs. One did not fire, 4 shots did not fire. ND perf flange, NU bell nipple. RIH with 8-1/2" GR/JB to bottom. Recovered rubber & gun debris. RIH with second GR/JB run to 3400' - POOH JB clean. MU Halliburton 9-5/8" BWD sump packer- RIH, set sump packer at 3276'. Correlated to GR/CCL, POOH. RD Atlas WL unit. Change pipe rams to 5-1/2" & test. Install WB. PU Halliburton Gravel Pack Assembly. MU crossover tool. Page Oct 16 1996 MU Halliburton 9-5/8" Versatrieve Packer, TIH with 5-1/2" tubing. Tag sump packer at 3276' - space out. Drop 2" ball, pressure up & set packer at 2846'. Test annulus. Shear off packer and reverse out ball. Test lines, pickle tubing & reverse out. Perform injectivity test. Estimate circulating pressure - pump Gel pad followed by slurry 20/40 carbolite, followed by NaCL slowed to 2 bbls/min with sand 6 bbls from tool- stayed in squeeze position entire job. Screened out with 5440# sand behind pipe, stress pack to 1600 psi. Reverse out two tubing volumes - stress pack with rig, pressure up to 1500 psi. Pack did not bleed off, cycle tool, stress to 1500, pack still did not bleed off. RD equpment. POOH, LD tubing & wash string. Change rams to 3-1/2" & test. TIH with JP Packer plug - set in 9-5/8" Versa Packer at 2825' & test. Circ & filter completion fluid. POOH with JP plug retrieving tool. RU Atlas WL unit, test lubricator-ok. Perforate with 4-1/2" casing guns 12 spf with RDX big hole charge 2828'-2782'. Correlated to GR/CCL Icg dated 10/14/96. Oct 17 1996 Cont perforate with 4-1/2" guns. Upper interval 2558'-2828', total 170' not continuous- all shots fired, 3 misfire runs. RIH with 8-1/2" GR/JB, set down at 2837' Recovered gun debris. Ran JB until clean, total 4 runs. RD Atlas WL, NU bell nipple. TIH with JP plug retrieving tool with 3-1/2" DP to 2825'. Reverse circulate out sand & gun debris off plug until clean returns. POOH with plug, LD DP. Change rams to 5-1/2". MU upper Gravel Pack Assy with 3-1/2" wash pipe inside. TIH, PU 5-1/2" tubing to 2100'. Oct 18 1996 Finish TIH with Gravel Pack Assy, tag isolation packer at 2825'. Space out with 30', 5- 1/2" pup jts. MU Frac valve. Drop 2" ball & circulate down, pressure up & set upper zone 9-5/8" Versa Packer at 2423'. Test backside, pressure up & shear ball. Pressure tubing & PU tubing string & shear off of packer with 14000# over string weight. Reverse out ball. Test lines with BJ. Perform injectivity test. Est circulation rate. Gravel Pack with Gel pad followed by sand slurry with 20/40 carbolite, gel pad behind - all pumped at 5 bpm, slowed to 2 bbls/min & switch to NaCL (sand 7 bbls from tool). Cont pumping until screened out at 1600 psi. Screened out with3 bbls sand slurry behind pipe, bled to 500 psi- stress pack to 1600 psi with one additional sand slurry behind pipe. Approx. 1200# of sand behind pipe. Reverse out excess sand to slop tank with two tubing volumes. Restress pack with rig pump to 1500 psi. Stress pack second time to 1500 psi. Pack will not circulate - Gravel Pack pumped in squeeze position. POOH, LD 5-1/2" tubing & 3-1/2" wash string. FlU Atlas WL unit. FIlH with GFI/CCL, PDK tool to 3300'. Log lower & upper Gravel Pack. POOH. RD Atlas, evaluate Icg. Upper zone gravel pack poor. Change pipe rams to 3-1/2" -Icad pipe shed with BHA. MU fishing assy #1, TIH PU 3-1/2" DP. Tag upper GP packer at 2402'. Latch packer with retrieving tool - pull free. POOH with fish. Page 2 Oct 19 1996 Finish POOH with 9-5/8" Versa Gravel Pack packer. Recovered all of Gravel Pack Assy. Pulled seals out of isolation packer.. MU 8-1/2" bit, TIH to 2675'. Reverse circulate & work down to isolation packer at 2825'. Cont reverse circ & filter completion fluid - 60 NTU returns due to rust. POOH, LD BHA. PU JP plug & TIH set plug in isolation packer 2825'. Spot sand on top of plug - POOH. ND bell nipple. NU perf flange to top of hydril. RU Atlas WL, test lubricator. Perf with 4-1/2" casing guns 12 spf big hole charge. Perforate 2800'-2782',2770'-2752',2740'-2728',2666'-2614'. Oct 20 1996 Finish perforating. Last run 2626'-2614' with 4-1/2" guns @ 12 spf. RIH with 8-1/2" GR/JB to isolation packer 2846' Run JB until clean. RD Atlas. ND perf flange, NU bell nipple. TIH with JP plug retrieving tool. Reverse circ down to plug at 2825'. Retrieve plug. POOH. Pull WB, set test plug. Test BOP. Test all rams, lines & valves. Test hydril, kelly, upper & lower kelly valves, TIW & IBOP. Witness of BOP test waived by Mr. Foster of AOGCC. Install WB. MU Gravel Pack Assy with 3-1/2" wash string. PU 9-5/8" Versa Packer. Found packer slip partial set for unknown reason. LD packer & wait on new packer for Halliburton. MU 9-5/8" Versa packer & TIH with Gravel Pack assy on 3-1/2" tubing. Tag isolation packer & verify with snap latch. Space out, drop 2" ball. Set packer with 3000 psi. Test annulus to 2500 psi, shear off with 2500 psi & 4K pull. Oct 21 1996 Test lines to 4000 psi. Pickle tubing. Perform injectivity test. Est circ rate thru screen. Gravel pack with HEC gel pad, 20/40 carbolite, gel pad behind. Pump job, all in squeeze position. Screened out sand slurry behind pipe, stress pack two times & reverse out two tubing volume. Restress pack with rig pump, pressure up & bled. 3600# sand behind pipe. Allow gel to break & sand to fall. Restress pack with rig pump. Est circ thru screen. Wait on more 20/40 frac sand. Repack with HEC gel pad, 20/40 sand slurry, gel pad behind, NaCL, circulated down gravel-slowed & went to squeeze position with sand 7 bbls above tool. Screen out at 1680 psi with 5 bbls of sand behind pipe. Stress pack & reverse out. Restress pack to 1500 psi, bled to 400 psi. Total 5100# sand behind pipe. Allow gel to break & sand to fall. Restress pack. Est circ. Re-gravel pack with HEC gel pad, 20/40 carbolite slurry, NaCL. Went to squeeze position, increased rate. Screened out, stress pack & reverse out. Restress pack to 1500 psi bled to 400 psi. Total 8100# sand behind pipe. POOH, LD tubing & gravel pack tool string. RU Otis slickline unit, RIH with swedge & tag bottom-POOH. TIH with DP out of derrick. POOH, LD DP. Pull WB. Change rams to 5.5" & test. RU to run completion. Page Oct 22 1996 MU & service ESP. Make splice above & below packer. RIH with ESP completion. Ran total 55 jts., 17# L-80 Imp BTC tubing. MU hanger. Make splice at tubing hanger pig tail. Land tubing, set TWC & test. ND BOP stack, NU FMC adapter spool, NU CIW tree. Test adapter spool, test tree with diesel. Freeze protect well by pumping down annulus, taking returns up tubing. Oct 23 1996 Drop ball, pressure up to 3500 psi, set packer & test tubing. Test annulus, all ok. Set BPV, secure well, clean pits. Tubing & annulus freeze protected with diesel to pump. Rig released 10/22/96 @ 0900 hrs. Page 4 ANNULAR INJECTION DATA ENTRY SCREEN Asset Mib.~ .......................................... Rig Name ~.sb.Qr~..~, ............................. Inj Well Name ~..P..~.:.7..D. ..................................... Sur Csg Dep 7..~..1.~. ................ Cumulative Data Legal Desc ~.I.J]~.'.bI~..~9.1.'.~.EI~.~.e~..{L.T..1.3~,.B.1.QE .................................... Research Permit End ....... .~:.~.7.:~.7. ........ ............................... Permit Start ........ ~.:.1.7.:.9.~. ....... Rig :completion ~ FormatiOn . Intermittant Final Well Total MudJCtg Wash ~ :FlUidS: :: i :F~uids: FreeZe.· i. Freeze ........ .~.~,~ ................ .t~,.z~ ................... z~. .................................... : ...... i ....... i .............................. .'[~.~ ....................... ~.~. ............ Daily Data iMPF-66 108/26/96 i100 i 30 130 3 1500 Open 1996 Summary iMPF-66 i08/27/96 il,300 i t j 11,300 3 1300 Open iMPF-66.:~08/28/96 i140 i I ,I 140 3 1300 Open iMPF-66 ~08/29/96 i370 i ! i 370 3 1300 Open iMPF-66 i, 08/30/96 i200 i ~ i 200 3 1300 Open iMPF-66 i08/31/96 1490 i ~ ~ I I 490 ~3 '1300 !Open iMPF-66 i09/01/96 i350 ~ i i 350 3 1300 Open iMPF-66 i09/02/96 i355 i ! 355 3 1300 Open ~ ~ ~ I I 402 3 1300 Open iMPF'66 i09/03/96 1402 iMPF'66 i09/04/96 i® i i 1 60 3 1300 Open iMPF-66 !09/05/96 i485 i J~ 485 3 1300 Open iMPF-66 109/06/96 i155 !] 155 2.5 1300 Open iMPF-66 i09/07/96 i135 i, 135 2.5 1300 Open !MPF-66 i09/08/96 i80 i 80 2.5 1250 Open iMPF'66 i09/09/96 i245 i'ii , 245 4 1450 Open !MPF-66 i09/10/96 i35 ~ ' i 35 3 1350 Open CMPF-66 i09/11/96 i95 i I ! 95 3 1350 Open iMPF-66 i09/12/96 i190 i i i 190 !2.5 '1350 Open iMPF-66 109/13/96 1145 ~ ' i 145 2.5 1350 Open ilMPF'66 ~109/14/96 ~i240 iii .i 240 2.5 1400 Open iMPF-66 i09/15/96 i215 i I 215 2.5 1400 Open iMPF-66 ~09/16/96 i225 ! i ] 225 3 1450 Open iMPF'66 i09/17/96 i220 J i--------~ 220 3 1400 OPen _ _. iMPF-66 i09/18/96 1190__! ___~, 190 2.5 1250 Open iMPF-66 i09/19/96 1220 220 2.5 1250 Open iMPF-66 '~09/20/96 1510 i 510 2.5 1450 Open i i iMPF-66 i09/21/96 i200 75i 275 2.5 1450 Open iMPF-66 !09/22/96 i300 i80 iMPF'66 ~09/23/96 i300 i90 i J 1880 2.5 1450 Open ~ ; , ~ , I 390 2.5 1450 Open !MPF-66 i09/24/96 1760 ! j j 760 2.5 1450 Open iMPF-66 i09/25/96 i540 180 i J 620 2.5 1450 Open !MPF-66 i09/26/96 i770 i50 j J 820 3 !1500 Open iMPF'66 109/27/969 i280 i i I 280 3 1500 Open iMPF'66 i09/28/96 i200 i i j 200 3 1500 Open ,iMPF'66 ~i09/29/96 1160 i I ! 160 3 1500 Open iMPF-66 i09/30/96 1550 i260 i-~--J' I 60 870 3 1500 o ~en iMPF'58 110/05/96 1939 i 30 969 3 1500 Open iMPF-58 ! 10/06/96 i ! 70 70 1.5 1200 Open iMPF'62 i 10/28/95 i125 ! i t !125 11995 Summary iMPF-62 i10/29/95 i130 i ' ! 130 iMPF-62 i10/30/95 i2,038 i J J 2,038 iMPF'62 i10/31/95 1190 i J J 190 iMPF'62 111/01/95 i250 i J j 250 iMPF-62 il 1/02,/95 i600 i j J 600 iMPF-62 i11/03/95 i140 I I 140 iMPF-62 il 1/04/95 1235 j j. ] 235 ~iMPF'62 ~il 1/05/95 ~i1,535 ! j j 1,535 iMPF-62 il 1/06/95 il ,300 ! ! j 1,300 iMPF-62 i11/07/95 i100 i100 j I 56 256 Open Anadrill Anadrill/Schlumberger Survey Report WELL INFORMATION TD Date: Client: Field: Well Name: Permanent datum: Depth measured from: Elevation of kelly bushing: Elevation of rig floor: Elevation of ground level: Magnetic Declination: Grid Convergence: Total Correction: 71£ IN POINT :\Icasured Depth: True Vertical Depth: Inclination: Azimuth: N/S displacement: E/W displacement: Azimuth fl'om rotory table to target: Measured Station Vertical Depth Interval Depth (ft) (ft) (ft) 0.00 0.00 0.00 112.00 112.00 112.00 157.50 45.50 157.50 248.10 90.60 248.10 340.90 92.80 340.88 431.00 90.10 430.88 514.70 83.70 514.35 614.10 99.40 613.18 702.00 87.90 700.09 787.00 85.00 783.36 879.80 92.80 873.17 972.70 92.90 961.63 1068.68 96.00 1051.59 1166.22 97.50 1141.54 1260.80 94.60 1227.22 5-Oct.-97 BP Exploration Milne point MPF-58 Mean Sea Level RKB 41.10 41.10 11.60 28.09 0.00 28.O9 0.00 0.00 0.00 0.00 0.00 0.00 311.00 Target Station Station Section Inclination Azimuth (ft) (deg) (deg) 0.00 0.00 0.00 0.00 0.00 0.00 0.05 0.36 19.20 0.33 0149 14.30 1.76 1.86 345.20 Latitude (NFS) fit) 0.00 0.00 0.13 0.78 2.62 5.23 3.28 339.70 6.45 10.72 5.22 337.90 12.23 20.38 7.05 333.70 21.88 32.37 10.05 335.00 33.67 47.96 13.04 334.20 49.03 Departure (E/-W) (ft) 0.00 0.00 0.05 0.24 -0.05 ORiGiNAL -1.32 -3.58 -7.99 -13.62 -20.93 Displac ment at Azimuth (ft) (deg) 0.00 0.00 0.00 0.00 0.14 19.20 0.81 16.87 2.62 358.90 69.62 16.07 331.50 69.75 -31.62 96.30 19.48 330.20 94.50 -45.45 128.09 21.36 328.50 123.30 -62.55 164.08 24.01 327.30 155.12 -82.57 202.68 26.13 326.10 188.59 -104.62 6.58 348.45 12.74 343.67 23.30 339.95 36.32 337.98 53.31 336.89 76.58 335.62 104.86 334.31 138.26 333.10 175.73 331.97 215.67 330.98 Dog Leg Severity (deg/hf) 0.00 0.00 0.79 0.15 1.56 1.60 2.32 1.89 3.42 3.52 3.35 3.70 2.05 2.77 2.29 Anadrill Schlumberger Page 1 6/18/97 Mcasured Station Vertical Target Station Station Latitude Departure Displac Depth Interval Depth Section Inclination Azimuth (N/-S) (E/-W) at Azi (ft) (ft) (ft) (ft) (deg) (deg) (ft) (ft) (ft) 1354.21 93.40 1310.59 243.21 27.74 327.40 223.81 -127.70 257.68 1446.40 92.20 1391.27 286.23 30.41 325.30 260.92 -152.44 302.19 1541.90 95.50 1473.64 333.01 30.38 325.70 300.74 -179.81 350.40 1635.77 93.90 1553.51 380.79 33.07 325.50 341.48 -207.71 399.69 1730.49 94.70 1631.68 432.52 35.64 325.50 385.51 -237.98 453.05 1823.14 92.60 1706.01 1918.65 95.60 1782.02 2013.99 95.30 1858.40 2108.54 94.50 1933.16 2201.99 93.50 2003.79 485.92 541.89 596.95 652.97 712.81 37.58 37.09 36.37 39.03 42.85 326.00 326.30 325.60 324.80 321.90 431.16 479.31 526.54 573.98 623.08 -269.05 -301.35 -333.25 -366.24 -402.85 508.22 566.17 623.14 680.87 741.96 ment muth (deg) 330.29 329.70 329.12 328.69 328.31 328.04 327.84 327.67 327.46 327.12 2299.00 97.00 2073.48 779.30 45.28 319.40 675.21 -445.64 809.01 326.58 2393.05 94.10 2139.37 846.07 45.86 315.10 724.52 -491.24 875.36 325.86 2490.43 97.30 2205.69 917.18 48.21 311.90 773.49 -542.89 945.00 324.94 2583.90 93.50 2267.76 987.11 48.61 311.40 819.96 -595.15 1013.18 324.03 2676.22 92.30 2329.08 1056.09 48.13 312.10 865.90 -646.62 1080.69 323.25 2770.36 94.20 2392.28 1125.92 2863.80 93.40 2455.41 1194.73 2959.13 95.30 2520.33 1264.48 3050.13 91.00 2582.94 1330.49 3146.24 96.10 2649.70 1399.59 312.40 312.60 312.30 312.70 312.10 312.40 312.40 312.50 313.20 312.10 313.10 313.10 3241.11 94.90 2716.75 1466.73 3336.65 95.50 2785.51 1532.99 3429.25 92.70 2851.89 1597.67 3521.98 92.70 2917.60 1663.02' 3616.54 94.50 2985.07 1729.17 912.87 959.37 1006.46 1051.07 1097.68 1142.83 1187.52 1231.19 1275.66 1320.50 1365.09 1402.35 3711.33 94.80 3053.23 1795.02 Projected Su~eyto TD 3790.00 78.70 3109.98 1849.52 -698.32 -749.07 -800.55 -849.24 -900.28 -949.99 -998.93 -1046.67 -1094.61 -1143.28 -1191.77 -1231.59 47.59 47.36 46.76 46.29 45.70 1149.34 1217.17 1286.02 1351.28 1419.65 1486.12 1551.80 1615.97 1680.92 1746.65 1812.12 1866.39 44.39 43.51 45.02 44.70 44.19 43.86 43.86 322.58 322.02 321.50 321.06 320.64 320.26 319.93 319.63 319.37 319.11 318.88 318.71 Dog Leg Severity (deg/hf) 1.57 3.37 0.21 2.87 2.71 2.12 0.55 0.87 2.86 4.56 3.08 3.32 3.41 0.59 0.77 0.62 0.29 0.67 0.61 0.76 1.40 0.92 1.63 0.63 0.98 0.81 0.00 Anadrill Schlumberger Page 2 6/18/97 State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Howard Okland 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 19-Oct-96 i"Well Name Services Bluelines R/F Sepia !Film MPF-66 A GR/CCL 1 1i iiMPF-66 A STATIC PRESSURE 1 1 i,MPF-66 A i!MPF-58 iiMPF-58 !iMPF-58 !!~V1PF-58 GR/CCL PERF GR/CCL SET SRVS GR/CCL PERF GR/CCL GR/CCL PERF 1 1 !iMPF-58 PDK/GR/CCL 1, 1 0 ~MPF-58 GR/CCL PERF 11 1 0 ,, Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. TONY KNOWLE$, GOVERNOR ALASI~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 13, 1996 Tim Schofield, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Well Name Company Permit # Surf Loc Btmhole Loc Milne Point Unit MPF-58 BP Exploration (Alaska), Inc. 96-156 2116'NSL, 2644'WEL, Sec 06, T13N, R10E, UM 3477'NSL, 3834'WEL, Sec 06, T13N, R10E, UM Dear Mr Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of injection wells must be demonstrated under 20 AAC 25.412 and 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and 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 tests. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. cD~iidrmWan ohnston ~ BY IORD~MMiSSION dlf/encl c: Dept of Fish & Game, Habitat Sect - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork I~Drill r-IRedrill Ilb. Typeofwell CIExploratory I-IStratigraphicTest r-IDevelopment Oil [] Re-Entry [] Deepen~ [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 15. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 43' Milne Point / Prince Creek 3. Address 16. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025509 4. Location of well at surface 17. Unit or Properly Name 11. Type Bond (See 20 AAC 25.025) 2116' NSL, 2644' WEL, SEC. 6, T13N, R10E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 2880' NSL, 3150' WEL, SEC. 6, T13N, R10E MPF-58 At total depth 9. Approximate spud date Amount $200,000.00 3477' NSL, 3834' WEL, SEC. 6, T13N, R10E 09/15/96 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 355023, 1317'I No Close Approach 2560 3730' MD / 3055' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 300' Maximum Hole Angle 4,5 o Maximum surface 1061 psig, At total depth (TVD) 3055' / 1366 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld .80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 3699' 31' 31' 3730' 3055' 1169 sx PF'E', 542 sx'G', 150 sx PF'E' 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 MD TVD Structural Conductor Surface Intermediate ,. , ~, i:',. Production !~ ~, Liner !-:i' ':;':: ri t~ :'- r- t. r; '.-:' (',~ Perforation depth: measured ' ~ .... "' :'" !;" ¢' true vertical i:',.'.t,.:;:".'. ..... - -`:!:; i".;; ;:;-' ' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Robertson, 564-5159 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the fo~,egoing is trye and ~elrrect to the best of my knowledge Signed ,.-~ TimSchofield Title Senior Drilling Engineer Date ~// Commission Use Only · Permit Number I APl Numbe~/ I Approval Date I See cover letter ~,-, )[~-fe I 50- 0~-~0 ~O '"00 I ?-/~- '"'~'¢¢I forother requirements Conditions of Approval: Samples Required [] Yes [;~ No Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures i--lYes I~ No Directional Survey Required ~' Yes [] No Required Working Pressure for DOPE ~ 2M; ' 3M", [] 5M; [] 10M; [] 15M Other: .. 9h~al Signed By by order of Approved By ,m~iri W ,inhnst0rl Commissioner the commission Date ~_.-/~ .-~,~ Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Contact' James E. Robertson 5 6 4- 5 I 5 9 Drilling J Well Name: IMP F-58 I Well Plan Summary IType of Well (producer or injector)' JPrince Creek SourceI Water Producer Surface Location: 2116 NSL 2644 WEL Sec 06 T13N R10E UM., AK Target Location: 2880 NSL 3150 WEL Sec 06 T13N R10E UM., AK Bottom Hole 3477 NSL 3834 WEL Sec 06 T13N R10E UM., AK Location: IAFE Number: 1337052 J I Rig: J Nabors 22-E IEstimated Start 115SEP96 I IOperating days t°Date: complete: IMD: 13'730' I JTVD: J3'055'Ibkb IWell Design (conventional, slimhole, etc.)' IKBE' 143' JMilne Point Ultra Slimhole MONOBORE' 9-5/8", 40# CASING TO TD Formation Markers' Formation Tops MD TVD (bkb) base permafrost 2 0 46 1 86 3 Target 2441 21 43 T3 2441 21 43 Prince Creek 'A' 2 6 95 2 32 3 Prince Creek 'B' 2 93 5 2 493 Prince Creek 'C' 311 9 2 62 3 Prince Creek 'D' 3 2 7 4 2 73 3 Total Depth 3 7 3 0 3 05 5 Casinq/Tubing Pro! ram' Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btrc 3699 31/31 3730/3055 Internal yield pressure of the 9-5/8", 40# casing is 5750 psi. Worst case surface pressure would occur with a full column of gas from TD, assuming a normal pressure gradient of 8.6 ppg. Maximum anticipated surface pressure in this case would be 1061 psi, well below the internal yield pressure rating of the 9-5/8" casing. Logging Program' Open Hole Logs: Surface MWD Directional. LWD GR/RES Intermediate N/A Final N/A Cased Hole Logs: N/A Mudloggers are NOT required for this well. Mud Pro~lram: Special designconsiderations J I I None-SPUD MUD Surface Mud Properties' I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 1 00 1 5 8 1 0 9 8 to to to to to to to 9.0 50 35 1 5 30 1 0 1 5 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss N/A N/A N/A N/A N/A N/A N/A to to to to to to to N/A N/A N/A N/A N/A N/A N/A 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: 13oo' I IMaximum H°le Angle: I450 I Close Approach Well' (No Shut Ins) Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. 1. The base of the Permafrost for all wells located in the Milne Point Unit is _+1,850' TVD. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 2. There are _+26 wells on Milne Pt. 'F' Pad. There may be additional unidentified wells within one quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 3. The wastes to be disposed of during drilling operations can be defined as "DRILLING WASTES". 4. The cement design for this well ensures that annular pumping into hydrocarbon zones will not Occur. . 2 , . , . . . , MP F-58 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head and top job nipple 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/production hole as per directional plan. Run Directional MWD from surface to TD and run Gamma Ray/Res LWD from surface to TD. Run 9-5/8", 47# casing. Spaceout ES Cementer to be at 1300' md. Perform 2 Stage cement job to cement 9-5/8" casing Test casing to 3000 psig. ND diverter, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. DRILLING HAZARDS AND RISKS: See the updated Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for information on the No Point#1 (F-46), and review recent wells drilled on F Pad. Most of the trouble time on recent wells has been due to equipment mechanical problems with the surface equipment, rather than formation drilling problems. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. Close Approach: There are no close approaches associated with the drilling of MP F-58. Lost Circulation: There has not been any appreciable amount of lost circulation in surface hole on any of the F Pad wellls to date. Stuck Pipe Potential: Well MPF-53 was stuck coming out on the shod trip at surface casing point. Proir to this incident there was only minor indications that the gravel and coal were present, It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed. Subsequent fishing operations were not successful and a very expensive BHA was lost in the hole from 2516 - 3342. Formation Pressure: The maximum expected pore pressure for this well is 8.6 ppg EMW (1271 psi @ 2843' TVD). There has been no injection in this region, therefore the reservoir pressure should not exceed this estimate. MP F-58 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON 2 STAGE CEMENT JOB CASING SIZE: 9-5/8" CIRC. TEMP 60 deg F at 2840' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder + CELLO-FLAKES WEIGHT: 12.0 ppg STAGE1 LEAD APPROX NO SACKS: 606 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. STAGE2 LEAD APPROX NO SACKS: 563 THICKENING TIME: Greater than 4 hrs at 50° F. STAGE1 LEAD CEMENT: ANUULAR VOLUME FROM TOP OF TAIL CEMENT TO 500' ABOVE STAGE COLLAR AT 1300' MD+ 200% EXCESS. STAGE2 LEAD CEMENT: ANUULAR VOLUME FROM STAGE COLLAR TO SURFACE + 200% EXCESS TAIL CEMENT TYPE: Premium G ADDITIVES: WEIGHT: APPROX #SACKS: 0.2% CFR-3,0.2% HALAD-344, 2.0% CaCI2 + CELLO-FLAKES 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 5 4 2 THICKENING TIME: Greater than 4 hrs at 50° F. FLUID LOSS: 100-150 cc FREEWATER: 0 TAIL CEMENT FROM TD TO 200' TVD ABOVE TOP OF PRINCE CREEK +30% EXCESS WELLHEAD STABILITY CEMENT TYPE: Permafrost E WELLHEAD STABILITY CEMENT WILL BE PUMPED IF THERE ARE CEMENT RETURNS TO SURFACE AND THEN CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX NO SACKS: 150 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on from 300' md above target sand to 300' md below target sand (15 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 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUMES: I , The Tail Slurry volume is calculated to cover from TD to 200' TVD above the top of the TARGET SAND +30% excess. . The STAGE1 Lead Slurry volume is anuular volume from top of tail cement to 500' above the top of the STAGE COLLAR at 1300' md + 200% excess. STAGE2 Lead Slurry volume from STAGE COLLAR at 1300' md to surface + 200% excess. 3. 80'md 9-5/8", 40# capacity for float joints. , Wellhead stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the wellhead. Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPF-58(PS) Field ........ : MILNE POINT, F-PAD Computation..: Minimum Curvature Units ........ : FEET. Surface Lat..: 70.50809063 N ~ :ace Long.: 149.65703515 W LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord Legal Description Surface ...... : 2116 FSL 2644 FEL S06 T13N R10E UM 541917.60 6035568.83 TARGET...~ .... : 2880 FSL 3150 FEL S06 T13N R10E UM 541405.00 6036330.00 BBL.' ......... : 3477 FSL 3834 FEL S06 T13N R10E UM 540714.63 6036923.32 STATION IDENTIFICATION 1/100 BUILD 2/100 3/lOO · PROPOSED WELL PROFILE MEAS INCLN DIRECTION VERT-DEPTHS SECT DEPTH ANGLE AZIMUTH TV'D, SUB-S DIST 0 0.00 300 0.00 400 1.00 5OO 3.OO 600 5.00 0.00 0 -43 0.00 300 257 329.41 400 357 329.41 500 457 329.41 600 557 0 0 1 4 11 i ANADRILL · Prepared ..... : 09/04/96 Vert sect az.: 311.00 KB elevation.: 43.00 ft Magnetic Dcln: +27.908 (E) Scale Factor.: 0.99990200 Convergence..: +0.32330950 AKA-DFC APPROVED FOR PERMITTING ON LY PLAN COORDINATES-FROM STATE-PLANE TOOL DL/ WELLHEAD X Y FACE 100 0.00 N 0.00 E 541917.60 6035568.83 0.00 0.00 N 0.00 E 541917.60 6035568.83 0.00 0.75 N 0.44 W 541917.15 6035569.58 HS 1.00 3.76 N 2.22 W 541915.36 6035572.57 HS 2.00 9.76 N 5.77 W 541911.78 6035578.56 HS 2.00 700 8.00 329.41 699 656 800 11.00 329.41 798 755 900 14.00 329.41 895 852 1000 17.00 329.41 992 949 1100 20.00 329.41 1086 1043 21 37 58 83 113 19.50 N 33.71 N 52.34 N 75.34 N 102.66 N 11.53 W 541905.96 6035588.27 HS 3.00 19.93 W 541897.48 6035602.42 HS 3.00 30.94 W 541886.37 6035620.99 HS 3.00 44.54 W 541872.64 6035643.91 HS 3.00 60.68 W 541856.35 6035671.13 HS 3.00 1200 23.00 1300 26.00 329.41 1179 1136 329.41 1270 1227 148 187 134.20 N 79.33 W 541837.52 6035702.57 HS 3.00 169.90 N 100.43 W 541816.23 6035738.14 HS 3.00 U (Anadrill (c)96 MPF58P5 3.0b.03 1:06 PM P) MPF-58 (P5) 09/04/96 Page 2 PROPOSED WELL PROFILE STATION IDENTIFICATION IlK · -- DEPTH ANGLE 1400 29.00 1500 32.00 1600 35.00 1700 38.00 1800 41.00 MEAS INCLN DIRECTION VERT-DEPTHS SECT AZIMUTH TVD SUB-S DIST 329.41 1359 1316 231 329.41 1445 1402 279 329.41 1529 1486 332 329.41 1609 1566 388 329.41 1686 1643 448 COORDINATES-FROM STATE-PLA~_ TOOL DL/ WEL~ X Y' FACE 100 209.64 N 123.92 W 541792.51 6035777.75 HS 3.00 253.33 N 149.74 W 541766.44 6035821.29 HS 3.00 300.84 N 177.82 W 541738.10 6035868.63 HS 3.00 352.04 N 208.09 W 541707.55 6035919.65 HS 3.00 406.79 N 240.45 W 541674.88 6035974.22 HS 3.00 k. 3/100 BUILD CURVE 3/100 E.D 3/100 CURVE BASE PERMAFROST curve 4/l°O END 4/100 CURVE 1900 44.00 1938 45.13 2007 45.13 2026 45.07 2046 45.07 2066 45.07 2100 44.95 2200 44.77 2300 44.88 2319 44.94 329.41 1760 1717 512 329.41 1787 1744 538 329.41 1835 1792 584 328.60 1849 1806 597 328.60 1863 1820 610 '328.60 1877 1834 624 326.68 1901 1858 647 321.02 1972 1929 716 315.34 2043 2000 786 314.26 2057 2014 799 464.94 N 274.82 W 541640.18 6036032.17 HS 3.00 487.69 N 288.27 W 541626.61 6036054.84 3.00 529.80 N 313.16 W 541601.49 6036096.80 97L 0.00 541~53 N 320.21 W 541594.37 6036108.49 3.00 553.43 N 327.47 W 541587.04 6036120.35 0.00 565.70 N 334.96 W 541579.49 6036132.58 96L 0.00 586.01 N 347.83 W 541566.51 6036152.81 94L 4.00 642.92 N 38940 W 541524.62 6036209.48 90L 4.00 695.42 N 436.37 W 541477.36 6036~61.71 86L 4.00 704.97 N 445.99 W 541467.68 6036271.21 4.00 CURVE 4/100 2383 44.94 2400 44.93 END 4/100 CURVE 2441 44.94 T-3 2441 44.94 TARGET ************* 2441 44.94 U~ A PRINCE UNIT B PRINCE UNIT C PRINCE UNIT D PRINCE BASE UNIT D 2695 44.94 2935 44.94 3119 44.94 3274 44.94 3430 44.94 9-5/8" CASING POINT TD 3730 44.94 3730 44.94 (Anadrill (c)96 MPF58P5 3.0b.03 1:06 PM P) 314.26 2102 2059 844 313.32 2114 2071 856 311.00 2143 2100 885 311.00 2143 2100 885 311.00 2143 2100 885 736.60 N 478.44 W 541435.06 6036302.65 91L 0.00 744.73 N 486.93 W 541426.52 6036310.73 90L 4.00 764.13 N 508.35 W 541405.00 6036330.00 4.00 764.13 N 508.35 W 541405.00 6036330.00 4.00 764.13 N 508.35 W 541405.00 6036330.00 4.00 311.00 2323 2280 1065 881.96 N 643.90 W 541268.80 6036447.06 311.00 2493 2450 1234 993.25 N 771.92 W 541140.16 6036557.61 311.00 2623 2580 1364 1078.35 N 869.82 W 541041.79 6036642.15 311.00 2733 2690 1474 1150.36 N 952.66 W 540958.56 6036~13.69 311.00 2843 2800 1583 1222.37 N 1035.50 W 540875.32 6036785.22 0.00 0.00 0.00 0.00 0.00 311.00 3055 3012 1795 1361.39 N 1195.43 W 540714.63 6036923.32 3IT'U09-----305~_? 1795 1361 39 N 1195.43 W 540714.63 6036923.32 ANADRILL AKA-DPC APPROVED FOR PERMITTING ON PLANp 0.00 0.00 Sep.-04-g6 14:41 Anadrill DPC 907 344 2160 P.04 I" SHARED SERVICES DRILLING · i i · ill i i NPF-58 (P5) VERTICAL SECTION VIEW _ , ANAD~iLL AKA-DPC S~ction ~[: 3~.00 ''~--.,,..,..-~A[>l>l>t%~/Cn ' TVD Scale.' $ inch = 400 feet - Oep Scale.' ! inch = 400 feet <I<B> o-- ,FCIR PI~RMI'¥TiI~ G Drawn ' 09/04/96 , ()NL~' ~oo. ~_. p,.AN..~ s.. ~,.-,~! . ' ~nadr i l l ~ ...... ,/ --- . .. ~,~.~umuFruer - ' l _ 400-- C Marker Identification MD BKB SECTN INCLN A) KB 0 0 0 0,00 B) KOP/BUILD ~/~00 300 300 0 0.00 C) BUILD 2/100 400 400 1 ~.00 600-- D ....... D) BUILD 3/~00 600 BO0 l~ §.00 E) END 3/~00 BUILD ~g3B ~787 §3B F) CURVE 3/~00 2007 ~B3§ §84 800-- ~ ..... G) END 3/~00 CURVE 20~B ~849 §97 4§ 07 H) CURVE 4/~00 206B ~877 B24 45,07 'I) E~ 4/~00 CURVE 23~9 20~7 799 44.94 J) C~VE 4/~00 23B3 2~02 844 44.94 I K) END 4/100 CURVE 244~ 2143 885 44.94 B ~000 .... ~ L) fARGET NNNMItl~MMMM~ 244J 8543 885 44,94 ~K M) 9-5/8' CASING POINT 3730 3055 17~ 44.94 B i200--- N) TO 3730 3055 1795 44,94 1~0 ....... ~~-~ ....... 2~ . ............ ' 2000 , 2200 ..... i ......... ................ ~4°°- 2800 -~ 3000- ~ _ .......... 3200 . 0 200 400 600. 800 ~000 -i200 I400 1600- ~800 2000 2200 2400 ~800 (~)1 [c)~~ 3.~,03 ~44 ~ m . -- . '. Sep-04-96 14:41 Anadrill DPc 907 344 2160 P.05 " I" i SH~J::iIED SERVTCE'S DRTL TNG m i i i i m i Im i .~,..r .,.,~,~c~.~o,, .n .~ ~, MPF-58 (P5) A) KB 0 0 hi '0 E ' KOP/BUILDi/IO0 300 o, o E ~ PLAN VIEW BUILD 3/t00 600 i0 N 6 X ' ' ~ E~ 3/100 BUILD t938 488 N 288 W CLOSURE ' 1812 feet at Azimuth 318.71 Fl C~ B/lO0 2007 530 N 3~3 W G) ENO ~/lO0 C~VE ~0~6 54~ N 3~0 W ' DECLINATION.' +27.908' (E) H) CURVE' 4/100 20~ ~6 N 335 W SCALE · 1 inch = 300 feet I) END 4/100 CURVE 2319 705 N 446 H J) C~VE 4/t00 2383 737 N 478 W DRAWN · 09/04/96 ~1 E~ 4/t00 CURVE ~44~ 764 N 50B W L) TARGET NttNNMXNNtNtH 2441 764 N 50B W .) g-5/B" CASZNG POINT 3730 '[36~ N ~ig5 . N) TO 3730 ' 13Si N 1195 H ~nadPj]] SchJu~bePgeP i ANADRILL A~-DPC APPROVED .............. It ~ I)~ ~ ll~)lk IA rUKrcKr~l I i I~ --~65o .., r~~ ~ ~ 15oo · .- , _: ,i_ ....... 1350 · ' ~ , 1200 ...... ' ' 1050 '~ TARGET (Radius 200 feet ) ~~ ~~ ' g00 ' ' '~~l ~ ~ 600 ........... ~ ....... 450 m ~ m '' 300 . ' : '__ 150 ~ ]gs0 1800 I650 1500 t350 i200 1050 g00 750 600 450 300 150 0 ~50 ~odrlll (c}~ ~ 3.~.'1 ~dn ~ Pt , · WELL PERMIT. CHECKLIST FIELD & POOL ~-~ ~' I ~(.3 INIT CLASS COMPANY ~ ~ ~ WELL NAME. GEOL AREA. ADMINISTRATION -ENGINEERING 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 wfthout conservation order ....... (~ N 12. Permit can be issued without administrative approval .... ~ N 13. Can permit be approved before 15-day wait. ........ ~) N PROGRAM: exp n dev [] reddl n servXwellbore seg [] ann. disposal para req [] UNIT# II ~ ~' (~ ON/OFF SHORE ...... ,. REMARKS A~Pd'~ D,~TE "GEOLOGY 14. Conductor string provided ................... (~N 15. Surface casing protects all known USDWs .......... ~ N 16. CMT vol adequate to circulate on conductor & surf csg . . . r,,..y~' N,J~ /___ _" 17. CMT vol adequate to tie-in long string to surf cscj ..... '~".--Y----N 18. CMT will cover all known productive horizons ......... (~ N b/ ~ · 19. Casing designs adequate for C, T, B & permafrosL ..... FTtY~ N _ _ 20. Adequate tankage or reserve piL ............... L_~ N __ 21. If a re-drill, has a 10-403 for abndnmnt been approved .... ~ ~,,-~'~'" 22. Adequate wellbore separation proposed ............ Y~ N 23. If diverter required, is it adequate ................ ~ N 24. Ddlling fluid program schematic & equip list adequate .... ......................... 26. BOPE press rating adequate; test to ~V'/r,~' psig. ~[~ N " 27. Choke manifold complies w/APl RP-53 (M~y¢84) ....... ~N 28. Work will occur without operation shutdown .......... Qf_.,PN 29. Is presence of H2S gas probable ............... Y N 30. Permit can be issued w/o hydrogen sulfide measur~-~'-'~ 31. Dam presented on potential ovemress~ ..... ,Y,, N 32. Seismic analysis of shali~ ........... ,Y,, N 33. Seabed condi~ff-shore) ............. .Y. N 34. Co phone for weekl~ progress, repo~.. ...... Y N lexp~oratary ono,'J GEOLOGY: ENGINEERING: COMMISSION: JDH ~-~ Comments/Instructions: HOW4~ - A.~FORM,S"x:hddist rev 4~6 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. V 2 -? 1996 Gas Co~s, Comrnis~ior~ * ALASKA COMPUTING CENTER . ****************************** * ............................ ....... SCHLUMBERGER ....... . ............................ ****************************** COMPANY NAIViE : B.P. EXPLORATION WELL NAME : MPF-58 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22706-00 REFERENCE NO : 96357 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-NOV-1996 15:42 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/11/26 ORIGIN : FLIC REEL NAME : 96357 CONTINUATION # : PREVIOUS REEL : COf~dENT : BP EXPLORATION (ALASKA), MILNE POINT MPF-58, API #50-029-22706-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE · 96/11/26 ORIGIN . FLIC TAPE NAME : 96357 CONTINUATION # : 1 PREVIOUS TAPE : C024~ENT : BP EXPLORATION (ALASKA), MILNE POINT MPF-58, API #50-029-22706-00 TAPE HEADER MILNE POINT MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: BIT RUN 1 96357 DENNETT TOM A. WELL CASING RECORD 1ST STRING 2ND STRING MPF-58 500292270600 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES 26-NOV-96 BIT RUN 2 BIT RUN 3 6 13N 10E 2165 2608 41.10 41.10 11.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12. 250 20. 000 112.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-NOV-1996 15:42 3RD STRING PRODUCTION STRING REMARKS: Well drilled 03-OCT through 05-0CT-96 with CDR only. Ail data was collected in a single bit run. Log was depth shifted to WA marked line GR logged 14-0CT-96. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION · O01CO1 DATE · 96/11/26 MAX REC SIZE : 1024 FILE TYPE : LO I~ST FILE : FILE HEADER FILE~BER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH MWD 57.5 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 88888.0 3646.5 3639.5 3633 5 3630 0 3610 5 3596 0 3566 5 3556 0 3548.5 3542.5 3534.5 3522.5 3502.0 3495.5 3493.0 3464.0 3444.0 STOP DEPTH 3804.0 .......... EQUIVALENT UNSHIFTED DEPTH 88904.0 3662.5 3655.5 3650.0 3647.0 3628.5 3612 5 3584 0 3572 0 3562 0 3556 5 3551 0 3538.5 3519.0 3511.0 3509.0 3480.0 3457.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3419.5 3411.5 3400.5 3391.5 3369.5 3358.5 3344.5 3340.0 3334.5 3324.0 3304.0 3280.5 3249.5 3227.0 3176.5 3150.5 3134.0 3121.0 3089.5 3076.0 3046.0 3034.0 3028.0 3010.5 3002.5 2993.5 2984.5 2979.0 2962.5 2956.0 2928.0 2918 0 2910 0 2893 5 2889 5 2883 5 2809 0 2770 5 2746 5 2742, 0 2727.0 2716.5 2702.5 2686.0 2657.0 2613.5 2607.5 2602.0 2585.5 2550.0 2542.0 2522.0 2495.0 2476.5 2428.5 3432.5 3424 0 3414 0 3405 0 3383 0 3371 5 3357 5 3354 0 3349 0 3337 5 3318 5 3295 0 3266 0 3243.5 3191.5 3166.0 3149.0 3137.5 3104.5 3091.0 3061.0 3047.5 3038.5 3023.0 3015.0 3006.5 2996.0 2992.0 2975.5 2970.0 2942.5 2932.0 2927.5 2908.0 2902 5 2895 5 2823 0 2784 5 2760 5 2755 5 2741 5 2730 5 2717.0 2697.0 2669.0 2626.0 2621.5 2612.5 2598.0 2563.0 2555.0 2535.0 2509.0 2492.0 2441.5 26-NOV-1996 15:42 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 2416.5 2405.0 2389.5 2336.0 2307.5 2287.0 2278.5 2262.0 2249.5 2228.5 2190.5 2181.0 2175.5 2170.0 2136.0 2108.5 2095.5 2035.0 2008.5 1964.5 1944.0 1937.5 1904.0 1890.0 1866.5 1845.0 1835.0 1828.0 1811.0 1801.0 1791.0 1771.5 1764.0 1754.5 1729.0 1701.0 1657.0 1640.5 1608.0 1594.5 1583.5 1557.5 1529.0 1525.5 1498.5 1487.5 1473.5 1472.0 1467.5 1456.0 1453.0 1433.5 1409.0 1387.5 1369.5 2430.0 2421.0 2407.0 2352.5 2323.5 2300.5 2292.5 2273.0 2261 0 2240 5 2200 5 2191 5 2185 0 2181 0 2146 5 2120 0 2107.0 2046.0 2019.0 1975.5 1955.5 1947.5 1913.5 1900.5 1877.0 1854.5 1846.0 1839.0 1822.0 1812.0 1802.0 1783.0 1774.0 1765.0 1739.0 1709.5 1666.0 1649.5 1617.5 1603.5 1591.5 1564.0 1537.5 1534.0 1508.5 1498.5 1483.5 1480.5 1475.0 1467.5 1465.0 1448.0 1422.5 1404.0 1386.5 26-NOV-1996 15:42 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 1351.5 1344 5 1332 0 1327 0 1320 0 1301 5 1279 5 1267 5 1254 0 1238 5 1235.5 1219.5 1203.5 1182.0 1173.0 1166.0 1158.5 1142.0 1121.5 1107.5 1086.0 1073.0 1058.0 1043.5 1006.5 980.5 963.0 935.5 923.0 886.5 883.5 865.0 856.0 776.5 769.0 759.0 718.5 693.0 685.5 673.5 668.5 646.5 643.0 635.5 614.0 609.5 603.0 582.5 568.5 561.0 550.0 536.5 517.5 487.0 479.5 1368.0 1360.5 1347.0 1337.5 1330.5 1310.5 1288.5 1276.5 1263.5 1246.5 1244.5 1228 5 1213 0 1190 0 1180 0 1173 5 1167 0 1150.5 1130.0 1117.0 1093.5 1081.0 1065.0 1051.0 1014.0 988.0 969.5 943.5 931.0 900.0 896.5 879.5 870.0 791.5 781.0 769.5 730.0 703.0 696.0 686.0 680.5 659.0 655.5 650.0 631.0 625.0 619.0 596.0 578.5 572.0 560.0 547.0 525.0 494.0 487.0 26-NOV-1996 15:42 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-NOV-1996 15:42 PAGE: 474.5 456.5 447.5 437.0 426.0 416.0 385.0 379.5 364.5 352.0 303.5 291.5 267.0 245.0 242.5 233.5 226.5 216.5 212.5 202.5 186.0 170.0 155.0 150.0 137.0 116.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: 482 5 463 5 453 5 443 5 433 5 422 5 393 0 386 0 370 5 358.5 312.0 302.0 276.5 252.0 249.0 242.0 231.0 219.0 214.0 204.0 188.0 172.0 157.5 153.0 140.0 118.5 102.5 BIT RUN NO. MERGE TOP MERGE BASE .............................. The depth adjustments shown above reflect the MWD GR to the GR logged by Atlas. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-NOV-1996 15:42 PAGE: 7 TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT NA O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OH~MNA O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OH~4NA O0 000 O0 0 1 1 1 VRA MWD OhY4~NA O0 000 O0 0 1 1 1 VRP MWD OHFk4NA O0 000 O0 0 1 1 1 DER MWD OH~4~NA O0 000 O0 0 1 1 1 ROP MWD FPHR NA O0 000 O0 0 1 1 1 GR MWD GAPI NA O0 000 O0 0 1 1 1 FET MWD HR NA O0 000 O0 0 1 1 1 4 68 0000000000 GR GR GAPI NA O0 000 O0 0 1 1 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 ** DATA ** DEPT. 3804.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 254.335 GR.MWD -999.250 FET.MWD -999.250 GR.GR -999.250 DEPT. 3000.000 RA.MWD 11.620 RP.MWD 13.245 VRA.NK~D 11.658 VRP.MWD 13.500 DER.MWD 12.849 ROP.MWD 295.089 GR.MWD 21.717 FET. MWD 0.145 GR.GR 17.134 DEPT. 50.000 R3I.MWD -999.250 RP.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD -999.250 GR.MWD -999.250 FET. MWD -999.250 GR.GR 8.811 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-NOV-1996 15:42 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 96/11/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION . O01CO1 DATE · 96/11/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0. 5000 FILE SOY~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH ............................ MWD 54.5 3788.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ 05-0CT-96 4.0 4.1 MEMORY 3788.0 55.0 3788.0 90 0.0 48.0 TOOL NTJMBER RGS8044 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-NOV-1996 15:42 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 12.250 112.0 BOREHOLE CONDITIONS MUD TYPE: SPUD MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S) : 49.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2.1 O0 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: ************ RUN1 ************* DRILLED INTERVAL 112' - 3788' HOLE ANGLE AT TD = 43.86 DEG @ 3788' RES TO BIT: 46.69'; GR TO BIT: 57.1' DATA FROM DO~NHOLE MEMORY, V4.1 SOFTWARE $ LIS FORMAT DATA 75.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-NOV-1996 15:42 PAGE: 10 TYPE REPR CODE VALUE .............................. 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT NA O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 OP~4~ NA O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW1 OH~ NA O0 000 O0 0 2 1 1 4 68 0000000000 ATVR LW1 OH~ NA O0 000 O0 0 2 1 1 4 68 0000000000 PSVR LW1 OH~ NA O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 OH~I NA O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW1 F/HR NA O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI NA O0 000 O0 0 2 1 1 4 68 0000000000 TAB LW1 HR NA O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 3804. 000 ATR.LW1 -999.250 PSR.LW1 -999.250 ATVR.LW1 PSVR. LW1 -999. 250 DER. LW1 -999. 250 ROPE. LW1 - 999. 250 GR. LW1 TAB. LW1 -999. 250 DEPT. 3000.000 ATR.LW1 10.456 PSR.LW1 11.551 ATVR.LW1 PSVR.LW1 11.507 DER.LW1 11.274 ROPE.LW1 437.148 GR.LW1 TAB. LW1 O . 145 DEPT. 54.500 ATR.LW1 -999.250 PSR.LW1 -999.250 ATVR.LW1 PSVR.LW1 -999.250 DER.LW1 -999.250 ROPE.LW1 -999.250 GR.LW1 TAB. LW1 -999. 250 -999.250 -999.250 10. 519 26. 849 -999.250 7.130 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 0 O1 CO1 DATE : 96/11/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-NOV-1996 15:42 PAGE: 11 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/11/26 ORIGIN : FLIC TAPE NAME : 96357 CONTINUATION # : 1 PREVIOUS TAPE : CO~fENT · BP EXPLORATION (ALASKA), MILNE POINT MPF-58, API #50-029-22706-00 **** REEL TRAILER **** SERVICE NAM~ : EDIT DATE : 96/11/26 ORIGIN · FLIC REEL NAME : 96357 CONTINUATION # : PREVIOUS REEL : CO~4ENT : BP EXPLORATION (ALASKA), MILNE POINT MPF-58, API #50-029-22706-00
