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Home My WebLink About190-0921. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Install Kil String 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 4,750 feet N/A feet true vertical 4,271 feet N/A feet Effective Depth measured 4,659 feet feet true vertical 4,184 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 / EUE 8rd 3,015' 2,713' DLH Hydraulic Ret 7" HES 'VTA' Ret Packers and SSSV (type, measured and true vertical depth) 7" 'AWD' Sump 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 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 4,000, 4,191 & 4,398 3,554, 3,667 & 3,934 3,520psi 7,240psi4,741' 4,262' Burst 1,730psi Collapse 740psi 2,020psi 5,410psi Casing Conductor 4,741' 2,633'Surface Production 13-3/8" 9-5/8" 7" 105' 2,633' measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-092 50-029-22067-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025906 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT I-03 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 105' 0 Size 105' 2,399' 000 0 00 0 322-316 & 322-587 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Brian Glasheen Brian.Glasheen@hilcorp.com 907-564-5277 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 11:44 am, Dec 15, 2022 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2022.12.15 07:45:19 -09'00' David Haakinson (3533) By Grace Christianson at 3:54 pm, Dec 02, 2024 WCB 2-11-2025 DSR-12/16/24 _____________________________________________________________________________________ Revised By: TDF 12/5/2022 SCHEMATIC Milne Point Unit Well: MP I-03 Last Completed: 9/8/2016 TD =4,750 (MD) / TD = 4,271’(TVD) 13-3/8” Orig. KB Elev.: 70.0’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 35.0’ (Nabors 27E) 7” 7 5 9 9-5/8” 1 & 2 PBTD = 4,659’ (MD) / PBTD = 4,184’(TVD) N Sands O Sands8 Squeeze Perfs: 2,060’ to 2,062’ 6 3 4 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / N/A 12.459 Surface 105' 0.1545 9-5/8" Surface 36 / K-55 / Btrc. 8.765 Surface 2,633’ 0.0773 7" Production 26 / L-80 / Btrc 6.151 Surface 4,741’ 0.0382 TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surf 3,015’ 0.0058 PERFORATION DETAIL Schrader Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NA Sand 4,260’ 4,280’ 3,802’ 3,821’ 20 2/23/1991 Open NB Sand 4,292’ 4,304’ 3,832’ 3,844’ 12 2/23/1991 Open NC Sand 4,322’ 4,328’ 3,861’ 3,867’ 6 2/23/1991 Open NE Sand 4,344’ 4,378’ 3,882’ 3,915’ 34 2/23/1991 Open OA Sand 4,424’ 4,455’ 3,959’ 3,988’ 31 2/23/1991 Open OB Sand 4,486’ 4,510’ 4,018’ 4,041’ 24 2/23/1991 Open ‘N’ Sands Perfs: 24SPF & 24GM. ‘O’ Sands Perfs: 5SPF & 37GM WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 37 deg. @ 3,170’ TREE & WELLHEAD Tree WKM 2-9/16”5M Wellhead WKM 11” 5M w/ 2-7/8” 8rd Tree Top Connection 2-1/2” “H” Profile GENERAL WELL INFO API: 50-029-22067-00-00 Drilled and Cased by Nabors 27 - 11/14/1990 ESP Completion – 3/7/1991 ESP RWO by Nabors 4ES – 10/5/1995 ESP RWO by Nabors 5S – 12/14/1997 ESP RWO by Nabors 4ES – 7/30/2002 RWO & Replace Screens by Nabors 4ES – 5/6/2003 ESP/ HT Changeout by Nabors 4ES – 10/7/2006 ESP RWO by Nabors 3S – 5/2/2009 ESP Changeout by Doyon 16 – 4/5/2013 Straddle Pckr/ ESP Changeout Nordic 3 - 5/3/2015 ESP Changeout by ASR#1 – 9/18/2016 Install Kill String by ASR#1 – 12/14/2022 OPEN HOLE / CEMENT DETAIL 13-3/8” 485sx Permafrost “C” 9-5/8”247sx of Class “E”, 942 sx of Class “G” in a 12.25” Hole 7” 307sx of 15.8 ppg Class “G” a 8.5” Hole STIMULATION DETAIL Interval: 4,424’ to 4,510’’ – 26,802 lbs. 16/20 mesh Propant JEWELRY DETAIL No Depth Item 1 3,998’ Top of 3-1/2” Blank Pipe, Seal Assembly 2 4,000’ DLH Hydraulic Retrievable Packer 3 4,037’ 3-1/2” X Nipple, ID = 2.810” 4 4,191’ 7” HES “VTA” Retrievable Packer 5 4,234’ 3-1/2” HES 250 Micron Poroplus Screens (4-Joints) – Bottom @ 4,359’ 6 4,422’ HES Collet Guide & Seal Assembly 7 4,398’ 7” Otis “AWD” Sump Packer (4.0”ID) 8 4,415’ 3-1/2” Otis X-Nipple (2.313” ID) 9 4,426’ WLEG Well Name Rig API Number Well Permit Number Start Date End Date MP I-03 LRS 50-029-22067-00-00 190-092 11/8/2022 11/15/2022 11/4/2022 - Friday No operations to report. 11/2/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 11/3/2022 - Thursday No operations to report. T/I/O= 1200/1200/0 Well Kill (pre rig)RU PT 3000psi all hard line and lrs equip, FTN/CV passed. Bleed gas off Tubing and IA Pumped 10 bbls diesel down Tubing, Pumped 40 bbls Source Water down Tubing taking returns up IA into tank, Shut in Tubing, Pumped 10 bbls diesel down IA, Pumped 270 bbls Source Water down IA, Bleed IA pressure off to tank, Set BPV, Pump 1bbl 60/40 freeze protect surface lines, Final WHP= 0/0/0 No operations to report. 11/5/2022 - Saturday No operations to report. 11/8/2022 - Tuesday 11/6/2022 - Sunday No operations to report. 11/7/2022 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP I-03 ASR#1 & LRS 50-029-22067-00-00 190-092 11/8/2022 11/15/2022 POOH w/ 7" scraper assy. on 3-1/2" work string. F/ 2,414' T/ 213'. Pumping 10 BPH for hole fill. L/D scraper assy. 6x DC, HYD jars, Bumper sub , Scraper, & BIT. Inspected all components, no excess wear. 213'. Clean & clear floor. M/U test packer DL retrievable. RIH w/ test packer on 3-1/2" work string. F/ 213' T/ 3,976'. Pumping 20 BPH for hole fill. Tag 5k dw on lower completion. P/U & space out for testing casing. R/U to pump dw backside. Test casing to 2,000 psi at 3,947' COE. Hold test for 30 charted mins. Test bleeding dw 100 psi in 5 mins. "bump" test 3x time. Bad test. Pull up hole & re-test. Small leak on blind ram doors out weep hole. Vendor ran in packing & sealed leak. Test casing to 2000 psi at 3942' COE (fail). Test casing to 2000 psi at 3905' COE (fail). Test casing to 2000 psi at 3,897' COE (fail). Test casing to 2000 psi at 3,880' COE (fail). Test casing to 2000 psi at 3,778' COE (fail). Test surface manifold & BOP valves. Good test. Decision made to pull up 200' then 500 ' interval s. Test casing to 2000 psi at 3,505' COE (fail). Test casing to 2000 psi at 3,025' COE (fail). Test casing to 2000 psi at 2,513' COE (fail). Test casing to 2000 psi at 1,949' COE (fail). 11/12/2022 - Saturday 11/11/2022 - Friday Slick line RIH w/ 3.5" profile brush, unable to get on depth. POOH & R/D slick line. Air breaks on unit frozen. Apply heat to move unit off location. Prep for 7" scraper run. Re-spot pipe racks. Load racks w/ 3-1/2" work string & tally. P/U & M/U 7' scraper assy. as per fishing rep. Tri cone bit , scraper, bumper sub, Jars, 6x 4.25" DC's T/ 213'. Con't RIH w/ 7" scraper assy. W/ 3-1/2" work string. F/ 213' T/ 3815'. Pumping 10 BPH for hole fill. Rig service. Down Time, Trouble shoot rack pin sensor in derrick. Sensor preventing top drive movement. Stab TIW & continue to trouble shoot. Con't RIH w/ 7" scraper assy. F/ 3,815' T/ 3975'. Pumping 10 BPH for hole fill. Tag at 3,975' w/ no RKB correction actual depth. Tag 2x w/ 10 k dw. M/U TIW & head pin, Line up to pump "conventional". Circulate & reciprocate w/ pumping. at 3 BPM w/ 330 psi. Pump a total of 214 bbls for 2x BU. Losses during circulation =21 bbls. Returns consisted of crude & source water. POOH w/ 7" scraper assy. on 3-1/2" work string. F/ 3,975' T/ 2,414'. Pumping 10 BPH for hole fill. 11/9/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Begin testing BOPE as per approved sundry. AOGCC waived witness to test. Test at 250 psi low & 2500 psi high. F/ 5/5 Charted min on each test. Preform accumulator drawdown test. Rig down testing line & B/D. Fill gas buster, line up for Well work operations. Prep for BPV pull. P/U tee bar. 11/10/2022 - Thursday Service rig, Check fluids on rig. Rig up ESP sheave & cable trunk. P/U tee bar, pull CTS plug & BPV. Well on vac. P/U & M/U landing jt to hanger. BOLDS. Unseat hanger w/ 38k P/U wt. No drag, pull hanger to floor & B/O. Pump 5 BPH to well. POOH W/ ESP completion F/ 3,979' T/ 620'. L/D & inspect 2-7/8" 6.5# L-80 EUE pipe to rack. Pump 5 BPH to well. Con't POOH W/ ESP completion F/ 620' T/ 51'. L/D & inspect 2-7/8" 6.5# L-80 EUE pipe to rack. Pump 5 BPH to well. One jt above xn nipple pipe coming out packed off with sand. L/D ESP. ESP packed full of sand. OOH, Pump 30 bbls to well. No returns. Clean & clear floor. Remove all clamps & ESP hardware from floor. Prep for slick line. Remove pipe racks for spotting slick line truck. Clamp count inaccurate to original tally. 374 5' cc / Original listed = 375. 76 half clamps / Original listed = 70. Spot in Slick line & R/U. M/U slick line tools J/B & 6.1" GR. Pump 30 bbls to well, return seen at surface. Obtain loss rate. Loss rate 24 BPH. Continue operations Pumping 10 BPH. RIH W/ SL tools. Pumping 10 BPH to well. 6.1 GR & JB to 3995' SLM. Tag at 3975' SLM. POOH w/ JB & GR. Inspect contents of JB. Small amount of scale. Gauge ring intact & full gauge. RIH W/ 2.813" profile brush. Pumping 10 BPH to well. Test casing to 2000 psi at 3,897' COE (fail). Test casing to 2000 psi at 3,880' COE (fail). Test casing to 2000 psi at 3,778' COE (fail). Test surface manifold & BOP valves. Good test. Decision made to pull up 200' then 500 ' interval s. Test casing to 2000 psi at 3,505' COE (fail). Test casing to 2000 psi at 3,025' COE (fail). Test casing to 2000 psi at 2,513' COE (fail). Test casing to 2000 psi at 1,949' COE (fail). Begin testing BOPE as per approved sundry. AOGCC waived witness to test. Test at 250 psi low & 2500 psi high BOLDS. Unseat hanger w/ 38k P/U wt. No drag, pull hanger to floor POOH W/ ESP completion F/ 3,979' T/ 620'. L/D & inspect 2-7/8" 6.5# L-80 EUE pipe to rack. Pump 5 BPH to well. Con't POOH W/ ESP completion F/ 620' T/ 51'. Well Name Rig API Number Well Permit Number Start Date End Date MP I-03 ASR#1 & LRS 50-029-22067-00-00 190-092 11/8/2022 11/15/2022 Hilcorp Alaska, LLC Weekly Operations Summary Set 2.5" BPV in hanger M/U landing joint/hanger to string landed hanger to RKB then RILDS, S/B RDMO. N/U tree/adapter test void 500 low 5 min 5K high 10 min TEST GOOD, pulled BPV and secured well. T/I/O= 0/0/0 Freeze Protect (Post RWO) Pumped 63 bbls criesel down IA and 22 bbls criesel down TBG. Tags hung. Final Whp's= 350/360/0. Begin mobilizing all equipment & rig to MPU K-37, Bleed down accumulator, disconnect lines. Rig down spools. Remove fluid from pits. Rig down tubing equipment. RDMO. Rig down pump lines, Lower Mast and Secure to Carrier. Move Carrier. Disassembly BOPE stack into individual components to transport for maintenance. With Crane support, Fly the rig floor onto transport trailer. N/U tree, test adapter flange to 500 psi f/ 5 min & 5000psi f/ 10 min (Good test). 11/15/2022 - Tuesday 11/13/2022 - Sunday POOH w/ test packer on 3-1/2" work string F/ 1,949' T/ 194'. Pumping 20 BPH for hole fill. L/D 6x DC's & test packer. Inspect packer slight vertical gouging in top & bottom elements. Middle element in good condition. P/U AS1X test packer & 6x DC's. T/ 194'. RIH w/ test packer on 3-1/2" work string F/ 194' T/ 1,950'. Pumping 20 BPH for hole fill. Test casing to 2,000 psi at 1950' COE. Test bleeding dw 100 psi in 5 mins. "bump" test 2x time. Bad test. Pull up hole & re-test. POOH w/ test packer on 3-1/2" work string F/ 1,950' T/ 1,450'. Pumping 20 BPH for hole fill. Test casing to 2,000 psi at 1,450' COE. Test bleeding dw 100 psi in 5 mins. Bad test. Pull up hole & re-test. POOH w/ test packer on 3-1/2" work string F/ 1,450' T/ 750'. Pumping 20 BPH for hole fill. Test casing to 2,000 psi at 750' COE. Test bleeding dw 100 psi in 2 mins. Bad test. Pull up hole & re-test. POOH w/ test packer on 3-1/2" work string F/ 750' T/ 224'.Pumping 20 BPH for hole fill. Test casing to 2,000 psi at 224' COE. Test bleeding dw 100 psi in 2 mins. Bad test. Pull up hole & re-test. POOH w/ test packer on 3-1/2" work string. Surface L/D drill collars. Pumping 20 BPH for hole fill. M/U 1 JT top test packer. RIH T/ 28' & test. Test casing to 2,000 psi at 28' COE. Good test. Hold for 30 min. Thermal expansion noticed with low volume of test. High cellar temperature. Slight pressure increase on chart. POOH w/ test packer T/ Surface L/D drill collars & packer. Inspected (good). Prep to run kill string Rack & tally 2-7/8" 6.5# L -80 EUE tubing. Change over handling equipment. RIH w/ 2-7/8" 6.5# L-80 EUE tubing. Kill string. T/ 2,983'. Pumping 15 BPH for hole fill. Land hanger & RILDS. P/U wt = 17k. S/O wt = 13k. Test void to 500 psi low f/ 5 mins. 5000 psi high f/ 5 mins (good test). 11/14/2022 - Monday RIH w/ 2-7/8" 6.5# L-80 EUE tubing. Kill string Test casing to 2,000 psi at 1950' COE. Test bleeding dw 100 psi in 5 mins. "bump" test 2x time. Bad test. Pull up hole & re-test. POOH w/ test packer on 3-1/2" work string F/ 1,950' T/ 1,450'. Pumping 20 BPH for hole fill. Test casing to 2,000 psi at 1,450' COE. Test bleeding dw 100 psi in 5 mins. Bad test. Pull up hole & re-test. POOH w/ test packer on 3-1/2" work string F/ 1,450' T/ 750'. Pumping 20 BPH for hole fill. Test casing to 2,000 psi at 750' COE. Test bleeding dw 100 psi in 2 mins. Bad test. Pull up hole & re-test. POOH w/ test packer on 3-1/2" work string F/ 750' T/ 224'.Pumping 20 BPH for hole fill. Test casing to 2,000 psi at 224' COE. Test bleeding dw 100 psi in 2 mins. Bad test. Pull up hole & re-test. POOH w/ test packer on 3-1/2" work string. Surface L/D drill collars. Pumping 20 BPH for hole fill. M/U 1 JT top test packer. RIH T/ 28' & test. Test casing to 2,000 psi at 28' COE. Good test. Hold for 30 min. Land hanger & RILDS 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Run New 5.5" & 4.5" Casing Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Install Reverse Circ JP 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 4,750 feet N/A feet true vertical 4,271 feet N/A feet Effective Depth measured 4,659 feet feet true vertical 4,184 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2 / L-80 / EUE 8rd 3,671' 3,252' D&L Hydrotrieve Iso D&L Perm Hyd DLH Hyd Ret HES VTA Ret Packers and SSSV (type, measured and true vertical depth) Otis AWD Sump 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 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: Plugs Junk measured measured 218' 3,505'3,948' 4,741' 2,633' 13-3/8" 9-5/8" 7" 105' 2,633' TVD 4,741' N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025906 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT I-03 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-092 50-029-22067-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC 220 Size 105' 2,399' 13 3,32810 0 00 276 0 4-1/2" 6,390psi 3,520psi 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 129 Gas-Mcf MD 105' Production Casing Conductor Surface Intermediate Production true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 7,240psi 8,430psi 4,262' Collapse 740psi 2,020psi 5,410psi 7,500psi Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 907-564-5277 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 323-367 N/A Brian Glasheen Brian.Glasheen@hilcorp.com 3,572, 3,835, 4,000, 4,191, 4,398 3,167, 3,400, 3,554, 3,736, 3,934 3,730' 5-1/2" 3,730' 3,304' 7,740psi Length Burst 1,730psi Water-BblOil-Bbl measured Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 7:50 am, Jul 24, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.07.23 16:45:14 - 08'00' Taylor Wellman (2143) RBDMS JSB 072524 WCB 11-7-2024 DSR-7/29/24 _____________________________________________________________________________________ Revised By: TDF 7/11/2024 SCHEMATIC Milne Point Unit Well: MP I-03 Last Completed: 6/28/2024 TD =4,750 (MD) / TD = 4,271’(TVD) 13-3/8” Orig. KB Elev.: 70.0’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 35.0’ (Nabors 27E) 7” 15 13 17 9-5/8” 9&10 5-1/2” x 4-1/2” Crossover @ 3,729’ 1 PBTD = 4,659’ (MD) / PBTD = 4,184’(TVD) N Sands O Sands16 Squeeze Perfs: 2,060’ to 2,062’ 14 11 12 2 3 4 5 6 7 8 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / N/A 12.615 Surface 105' 0.1545 9-5/8" Surface 36 / K-55 / Btrc. 8.921 Surface 2,633’ 0.0773 7" Intermediate 26 / L-80 / Btrc 6.276 Surface 4,741’ 0.0382 5-1/2” Production 17 / L-80 / R3 TSH W511 4.892 Surface 3,730’ 0.0232 4-1/2” Production 12.6 / L-80 / TXP-BTC 3.958 3,730’ 3,948’ 0.0152 TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / EUE 8rd 2.992 Surface 3,671’ 0.0087 PERFORATION DETAIL Schrader Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NA Sand 4,260’ 4,280’ 3,802’ 3,821’ 20 2/23/1991 Open NB Sand 4,292’ 4,304’ 3,832’ 3,844’ 12 2/23/1991 Open NC Sand 4,322’ 4,328’ 3,861’ 3,867’ 6 2/23/1991 Open NE Sand 4,344’ 4,378’ 3,882’ 3,915’ 34 2/23/1991 Open OA Sand 4,424’ 4,455’ 3,959’ 3,988’ 31 2/23/1991 Open OB Sand 4,486’ 4,510’ 4,018’ 4,041’ 24 2/23/1991 Open ‘N’ Sands Perfs: 24SPF & 24GM. ‘O’ Sands Perfs: 5SPF & 37GM WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 37 deg. @ 3,170’ TREE & WELLHEAD Tree WKM 2-9/16”5M Wellhead WKM 11” 5M w/ 2-7/8” 8rd Tree Top Connection 2-1/2” “H” Profile GENERAL WELL INFO API: 50-029-22067-00-00 Drilled and Cased by Nabors 27 - 11/14/1990 ESP Completion – 3/7/1991 ESP RWO by Nabors 4ES – 10/5/1995 ESP RWO by Nabors 5S – 12/14/1997 ESP RWO by Nabors 4ES – 7/30/2002 RWO & Replace Screens by Nabors 4ES – 5/6/2003 ESP/ HT Changeout by Nabors 4ES – 10/7/2006 ESP RWO by Nabors 3S – 5/2/2009 ESP Changeout by Doyon 16 – 4/5/2013 Straddle Pckr/ ESP Changeout Nordic 3 - 5/3/2015 ESP Changeout by ASR#1 – 9/18/2016 Install Kill String by ASR#1 – 12/14/2022 Install 5.5”x4.5” Comp and 3.5” Rev Circ JP ASR#1 – 6/28/2024 OPEN HOLE / CEMENT DETAIL 13-3/8” 485sx Permafrost “C” 9-5/8”247sx of Class “E”, 942 sx of Class “G” in a 12.25” Hole 7” 307sx of 15.8 ppg Class “G” a 8.5” Hole STIMULATION DETAIL Interval: 4,424’ to 4,510’’ – 26,802 lbs. 16/20 mesh Propant JEWELRY DETAIL No Depth Item 1 3,486’ 3-1/2” Viking Sliding Sleeve 2 3,572’ 5-1/2” x 3-1/2” D&L Hydratrieve. ISO Packer 3 3,630’ 3-1/2” X-Nipple w/ RHC-M – 2.813” ID 4 3,641’ 3-1/2” Muleshoe – Btm @ 3,671’ 5 3,775’ 4-1/2” NCS Multi-Cycle HP2 FRAC Sleeve 6 3,835’ 7” x 4-1/2” D&L PERM. HYD. ISO Packer 7 3,897’ 4-1/2” X-Nipple w/ RHC-M – 3.813” ID 8 3,906’ Muleshoe – Btm @ 3,945’ 9 3,998’ Top of 3-1/2” Blank Pipe, Seal Assembly 10 4,000’ DLH Hydraulic Retrievable Packer 11 4,037’ 3-1/2” X Nipple, ID = 2.810” 12 4,191’ 7” HES “VTA” Retrievable Packer 13 4,234’ 3-1/2” HES 250 Micron Poroplus Screens (4-Joints) – Bottom @ 4,359’ 14 4,422’ HES Collet Guide & Seal Assembly 15 4,398’ 7” Otis “AWD” Sump Packer (4.0”ID) 16 4,415’ 3-1/2” Otis X-Nipple (2.313” ID) 17 4,426’ WLEG Well Name Rig API Number Well Permit Number Start Date End Date MP I-03 ASR#1 50-029-22067-00-00 190-092 6/15/2024 6/30/2024 Slickline OOH, 3-1/2" PX Plug body set 4,037' SLM. Set Prong in plug body. Pressure up 300psi on TBG to ensure prong is set, POOH. Pressure test TBG/Plug/BTM of Packer to 2000psi - Good. Attempt to dump sand/sluggits on plug, unsuccessful. Pull Prong. Rig accepted @ 18:00 6/15/2024. Pump 40bbls 8.4ppg Source down IA, monitor well - static. Begin testing BOPE 250/2500psi as per Sundry. 6/15/2024 - Saturday Continue RIH w/ 5-1/2",17#,L, TSH-511 R3 Land Hanger placing Muleshoe at 3,947' ORKB. RILDS. Drop B&R, fill TBG & IA. Perform passing MIT-T 3,600psi. Slickline recovered B&R, RHC-M. Multiple attempts to set TTP. Brush X-Nipple @ 4,037' SLM. RIH w/ 3-1/2" PX Plug body. 6/18/2024 - Tuesday 6/16/2024 - Sunday Finish testing BOPE 250/2500psi as per approved sundry. Witness waived by AOGCC. Pull CTS, BPV. Tubing static. Install Landing joint w/ hose and TIW. BOLDS. Pull Hanger to the floor. Broke free 19K. PUW 19K. POOH W/ 2-7/8" EUE Kill string. P/U M/U Lower completion BHA, Change handling equipment to 5-1/2". RIH w/ 5-1/2",17#,L, TSH-511 R3 F/ 414' - T/2,772' pumping 1x displacement. 6/17/2024 - Monday 6/14/2024 - Friday No operations to report. 6/12/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 6/13/2024 - Thursday No operations to report. BOLDS. Pull Hanger to the floor. Broke free 19K. PUW 19K. POOH W/ 2-7/8" EUE Kill string RIH w/ 5-1/2",17#,L, TSH-511 R3 F/ 414' - T/2,772 Continue RIH w/ 5-1/2",17#,L, TSH-511 R3 Land Hanger placing Muleshoe at 3,947' ORKB. RILDS. Drop B&R, fill TBG & IA. Perform passing MIT-T 3,600psi. Slickline recovered B&R, RHC-M. Finish testing BOPE 250/2500psi as per approved sundry. Witness waived by AOGCC Well Name Rig API Number Well Permit Number Start Date End Date MP I-03 ASR#1 50-029-22067-00-00 190-092 6/15/2024 6/30/2024 6/21/2024 - Friday POOH w/ bailer. Dump bailer empty. B/D tools. Rig down SL tools & equip. Rig service. Work on rig exhaust system & def. Down time due to Work on rig exhaust system & def. P/U & M/U frac sleeve shifting BHA. RIH w/ Frac shifting BHA on 2-7/8" PH6 workstring. Locate sleeve w/ 3K overpull. Circ 2-7/8" X 5-1/2" annulus clean. Spot vis pill. Shift frac sleeve open w/ 3K overpull and 200psi down tubing. Circ 5-1/2" X 7". Get pump rates R/U cementers. Pressure test lines. Found leak. bled off, tighten. good test. Cement as per detail. Ending with cement in place at 18:20 6-21-24. Shift frac sleeve closed. Bleed off & check sleeve closure. (frac sleeve closed). Break down cementing equip. Reverse circ out cement in workstring. Pump a total of 60 bbls until returns clean. While pumping monitored 7 x 5-1/2" IA no pressure change (sleeve remains closed) RIH w/ 2 joints of 2-7/8" PH-6 to 3,838' & reverse out 24' above PX- plug. No change in returns. No cement present. Remove contaminated fluid from cuttings tank & pits. Flush & B/D lines. Line up to trip out. POOH w/ frac shifting BHA F/ 3,838' T/ 2,693' Laying down pipe. 6/19/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continue projects around rig and location while STBY for Slickline. P/U M/U bailer. RIH Slick line OOH. recovered approx 2 cup of sluggets. Clean out bailer. RIH W/ slick line and attempt to pull plug from 3-1/2" tubing. No success. M/U plug for 4-1/2 tubing and RIH Plug set in 4-1/2 X nipple @ 3,897'. M/U prong and RIH Prong set. POOH w/ setting tool. Attempt to pressure test PX plug to 2,000 psi. Bleed off& purge surface lines. Pressure test 2x. All failing tests. Decision made to pull PX plug & inspect. POOH OOH w/ PX plug inspect. All seals intact. Change tools to retrieve PX- plug body. PX plug body FREE, POOH. OOH W/ PX-PLUG BODY, UPPER PACKING STACK DAMAGED. RIH w/ QC, 4.5" X-LINE, 3.813" PX PLUG (aluminum/brass), SD @ 3,768' SLM, ATTEMPT TO WORK PAST FOR 15 MIN, UNABLE TO GET BY, POOH 6/20/2024 - Thursday Attempt to set 4.5" X-LOCK IN X-NIP at 3,893' SLM, after two attempts. Run 4.5" brush, & 3.805 GR. RIH & set 4.5" px-plug body in x-nip at 3,893' SLM. POOH. M/U p-prong. RIH & set in px-plug body in X- Nip at 3,893'. Test to 2000 psi. (good). POOH, Load dump bailer w/ sluggets. dump bail 4x = 10 gals of sluggets on top of p-prong for 13' above prong = 3,875' slm. Cont. POOH w/ frac shifting BHA F/ 2,693' Well taking correct displacement. L/D BHA & inspect. All components intact & functional. Install TWC & pressure test to 2,000 psi. Good test. N/D flow & spacer spools. PJSM, N/D BOP stack & attach slings to bails. Lift with top drive & install new tubing spool. Set BOP stack on tubing spool. Extended time torquing new tubing spool due to clearance issue. Install koomie hoses. Re-install spacer & flow spools. Attach flow line. Function test BOPE. Pull TWC in 5-1/2" hanger. Install hanger in tubing spool with TWC. RILDS. Open new IA. Monitor 5-1/2" while prepping for BOPE test. Test BOPE as per approved sundry. AOGCC waived witness to test. Down time. Service rig. Trouble shooting codes on rig. Change wiring harness for Def. system. Clear codes. De-rate code cleared. Test BOPE as per approved sundry. AOGCC waived witness to test. Test to 250 psi low & 2500 psi high f/ 5/5 charted mins. 6/22/2024 - Saturday RIH w/ Frac shifting BHA on 2-7/8" PH6 workstring. Locate sleeve w/ 3K overpull. Circ 2-7/8" X 5-1/2" annulus clean. Spot vis pill. Shift frac sleeve open w/ 3K overpull and 200psi down tubing. Circ 5-1/2" X 7". Get pump rates R/U cementers. Pressure test lines. Found leak. bled off, tighten. good test. Cement as per detail. Ending with cement in place at 18:20 6-21-24. Shift frac sleeve closed. Bleed off & check sleeve closure. (frac sleeve closed). Break down cementing equip. Reverse circ out cement in workstring. Pump a total of 60 bbls until returns clean. Lift with top drive & install new tubing spool Test BOPE as per approved sundry. AOGCC waived witness to test. Well Name Rig API Number Well Permit Number Start Date End Date MP I-03 ASR#1 50-029-22067-00-00 190-092 6/15/2024 6/30/2024 Hilcorp Alaska, LLC Weekly Operations Summary RIH w/ LIB. Tag 4x POOH. OOH w/ LIB. Good indication of tag on prong. L/D SL tools & equip. N/D flow & spacer spools. R/U shooting flange. Install TWC in 5-1/2" hanger. P/U SL PCE. Test SL PCE to 2,500 psi high for 5 charted min. RIH to pull prong. Unable to latch on. POOH Reconfigure tool string. RIH. continue to latch and when jarring up. JD is shearing. POOH. Reconfigure tool string to JD shear down. RIH. Latch on to prong. Jar for 45 mins. Sheared JD down. POOH OOH with tools. Cut 100' of SL & RE-TIE RIH. Latch on to prong. Jar 5 mins, observed free travel up, see weight increase, POOH OOH w/ P- PRONG. RIH w/ 3'' Slick line BAILER. Set down at 3,877' SLM, WORK TOOL 20 MIN, POOH OOH w/ TOOLS, 2 cups of slugetts. No definitive markings on flapper btm switch over to ball btm. RIH cont bailing. RIH w/ slick line bailer, tag at 3,860' slm, work tools. pooh ooh w/ bailer. 2 cups uncured cement swap tool string & smaller bailer. RIH w/ bailer bha tag at 3,863' slm, work tools. pooh ooh w/ bailer. recovered full bailer of cement & sluggets. Continue making mutilply bailer run all increasing in depth & decreasing in volume of sluggets recovers. All showing no indications of prong tag. RIH tag at 3,880' POOH w/ no sluggets recovered, tattletale marks on bailer shoe showing smooth & flat, Indication of prong tag. Run LIB to confirm. RIH w/ LIB on SL. 6/25/2024 - Tuesday 6/23/2024 - Sunday WELLHEAD: Set two way check, N/D BOP stack and lift with top drive and install new tubing spool, Set BOP stack on tubing spool and torque connections. Pump plastic in the packing and test 500 low 3500 high 5/10 min (good test). Set test hanger for BOP test with two way check and RILDS. Test BOPE as per approved sundry. AOGCC waived witness to test. Test to 250 psi low & 2500 psi high f/ 5/5 charted mins. Found blinds leaking from weep hole. Mobilize BOP rep to location. SIMOPS Replace DEF doser pump on rig. BOP rep replace mud seals on blinds. Blinds still leaking from weep hole. Blow down bop and prep to change seals. BOP rep replaced seals. configured seals and shims differently. shut doors. prep to test. Good test. Cont. testing BOPE as per approved sundry. AOGCC waived witness to test. Test to 250 psi low & 2500 psi high f/ 5/5 charted mins L/D test tools. Line up gas buster & manifold for well operations. Monitor IA & Pull TWC. Well static. P/U landing joint engage hanger in tubing spool. BOLDS. Pull hanger & L/D. R/U slick line tools & equip. P/U slick line BOPE for plug pull. M/U bailer BHA. & RIH. 6/24/2024 - Monday BOLDS. Pull hanger & L/D Well Name Rig API Number Well Permit Number Start Date End Date MP I-03 ASR#1 50-029-22067-00-00 190-092 6/15/2024 6/30/2024 Pressure up to set PKR & MIT TBG at 4100 psi for 30 min. (good) Charted. Bleed TBG to 1400 psi. Pressure up IA to 3800 psi & hold for 30 min. MIT (good) Charted. Rig released. WELLHEAD; M/U tubing hanger to landing joint then to string, land hanger to RKB and RILDS and set packer and BPV. NU Tree/Adaptor, test void 500 low 5000 high 5/10 min (good test). Pulled BPV with T-Bar and secured well. 6/29/2024 - Saturday 6/28/2024 - Friday Cont. RIH w/ GS spear on 2-7/8" PH-6 P110 pipe T/ 3,998' Kelly Up, obtain parameters. Latch in PX plug. P/U 5K over for 3X. Increase to 15K over. Allow Jars to hit w/ 15k. Over pull after jar hit 22K over. Set dw 4K & P/U. Plug traveling up hole. Cont. up hole for 5', W/ 15K overpull pump at 1 BPM w/ 1400 psi. Observed wt fall off to 5 k over up weight. S/O able to travel 8' pass XN profile. POOH. Well taking fluid , at 12 BPH. B/D kelly hose. POOH w/ PX plug laying down 2-7/8" PH-6 to Pipe shed. F/ 3,980' Pump double displacement. At BHA, L/D 3" GS spear. Fish on. Remove PX plug from GS spear. Clean & clear rig floor. Change handling equip. for completion over to 3-1/2" P/U Jet pump completion. Mule shoe, X-nipple, 3-1/2" JT, Tri point 5.5" X 3-1/2" Retrievable PKR, 2 JTS, viking SS. RIH w/ Jet pump completion on 3-1/2" 9.3# L-80 EUE T/ 3,629' Pump double displacement. Obtain parameters. P/U & M/U hanger. Land hanger on depth Setting end of JP completion at 3,669'. RILDS. Line up to reverse in 1% KCL CIB. HOLD PJSM. Reverse in 25 bbls of 1% KCL CIB at 2 BPM w/ 650 psi. Followed by 30 bbls of FP diesel at 2 BPM w/ 700 psi. Well taking fluid. Off pump IA & TBG 0 psi. Drop ball & rod. Fill TBG w/ 2 bbls. Pressure up to set PKR & MIT TBG to 4100 psi. Hold for 30 mis. 6/26/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Cont. RIH w/ 3'' Slick line pump bailer. Jar down to each 3,876' SLM. Work tools. POOH. OOH w/ tools recovered 2 cups sluggets. Clean bailer RIH. RIH w/ 3'' Slick line pump bailer. Set down at 3,880' SLM. Work tools. Slickline drum transmissions slipping. POOH slowly. Mobilize GS spear to rig. OOH w/ tools Begin rigging down PCE. Remove all SL tools & equip. from rig. N/U spacer & flow spools. P/U & M/U GS spear BHA. RIH w/ GS spear on 2-7/8" PH-6 P110 pipe. Code 99 blue in field. Stand down, All clear. Cont. RIH w/ GS spear on 2-7/8" PH-6 P110 pipe T/ 3,858' Wash dw f/ 3,858' T/ 3,883' Pressure increase while latching to PX body. F/ 400 psi to 600 psi. Shut dw pumps. Work up in 2k increments to 17k overpull = 46K. Set down on Plug w/ 1K. Free travel of 30K showing slight wt increase. Monitor well & B/D kelly hose. Begin POOH w/ PX plug laying down 2- 7/8" PH-6 to Pipe shed. 1 hr down time due to engine derate code. for DEF system. Cont. POOH w/ PX plug laying down 2-7/8" PH-6 to Pipe shed. F/ 3.600' Well taking correct displacement. AT BHA. Pull BHA. no fish. Indications of latch on GS spear. Decision made with OE to RIH w. same assy. RIH w/ GS spear on 2-7/8" PH-6 P110 pipe. 6/27/2024 - Thursday Cont. RIH w/ GS spear on 2-7/8" PH-6 P110 pipe T/ 3,853' Well taking correct displacement. Wash dw to 4-1/2" PX plug body. Latch into plug body w/ 4K DN. Over pull 12k 4x ensure latched up. Over pull up to 16K. Set down & pressure up. Pressure up to 2000 psi. P/U seeing 7k to 12 k drag. POOH w/ 4-1/2" PX plug. B/D kelly hose. POOH w/ PX plug laying down 2-7/8" PH-6 to Pipe shed. F/ 3,880' Well taking correct displacement. At BHA, L/D 4" GS spear. Fish on. Remove PX plug & 4" GS spear from rig floor. Clean & clear rig floor. P/U & M/U 3" GS spear BHA FOR 3-1/2" PX, plug retrieval. RIH w/ GS spear on 2-7/8" PH-6 P110 T/ 3,935' Well taking correct displacement. S/O wt = 18K Pressure up IA to 3800 psi & hold for 30 min. MIT (good) RIH w/ Jet pump completion on 3-1/2" 9.3# L-80 EUE T/ 3,629' Pump double displacement. Obtain parameters. P/U & M/U hanger. Land hanger on depth Setting end of JP completion at 3,669'. RILDS. Drop ball & rod. Fill TBG w/ 2 bbls. Pressure up to set PKR & MIT TBG to 4100 psi. Hold for 30 mis. MIT-IA to 3750 psi is a COA on Sundry 323-367. -WCB Well Name Rig API Number Well Permit Number Start Date End Date MP I-03 ASR#1 50-029-22067-00-00 190-092 6/15/2024 6/30/2024 Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. No operations to report. 7/2/2024 - Tuesday 6/30/2024 - Sunday WELL SHUT-IN ON ARRIVAL. APPLY 700psi TO IA. SHIFT VIKING -SS OPEN AT 3,486' MD W/ 3-1/2" 42BO (See positive pressure change). PULL BALL & ROD, 3-1/2" RHC FROM X-NIPPLE AT 3,629' MD. SET 3" JETPUMP (ratio: 11C, screen) SHOCK ABSORBER, DUAL SPARTEK GAUGES (start time 6-30-24 @ 1600, gauges:77465/79164, sample rate: 5 mins/720 days IN VIKING-SS AT 3,486' MD. WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED. 7/1/2024 - Monday PULL BALL & ROD, 3-1/2" RHC FROM X-NIPPLE AT 3,629' MD. SET 3" JETPUMP 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Run New 5.5" & 4.5" Casing Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Install Reverse Circ JP 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 4,750'N/A Casing Collapse Conductor 740psi Surface 2,020psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Brian Glasheen Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Brian.Glasheen@hilcorp.com 907-564-5277 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 6.5# / L-80 / EUE 8rd 3,015' 7/6/2023 DLH Hyd. Ret., 7" HES VTA Ret. & 7" AWD Sump and N/A 4,000 MD/ 3,554 tvd, 4,191 MD/ 3,667 TVD & 4,398 MD/ 3,934 TVD and N/A See Schematic See Schematic 2-7/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 190-092 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22067-00-00 Hilcorp Alaska LLC SCHRADER BLUFF OIL N/A C.O. 477.05 MILNE PT UNIT I-03 Length Size Proposed Pools: 105' 105' TVD Burst PRESENT WELL CONDITION SUMMARY 4,271' 4,659' 4,184' 1,164 N/A 105' 13-3/8" MILNE POINT MD 1,730psi 3,520psi 7,240psi 2,399' 4,262' 2,633' 4,741' 9-5/8" 7" 2,633' 4,741' Perforation Depth MD (ft): Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:19 pm, Jun 30, 2023 323-367 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.06.30 12:12:25 - 08'00' Taylor Wellman (2143) DSR-7/6/23 10-404 MDG 7/3/2023 SAME *BOPE pressure test to 2500 psi. * Approved for reverse circulating jet pump. * 30 minute charted inner casing pressure test to 3750 psi after setting production tubing packer. * SSV on IA and production tubing. High low trip pressures on SSVs as described in program. * SSV closure on IA will initiate closure within 2 minutes on SSV on production tubing and visa versa. * Quadrennial MIT-IA to 3650 psi. 1,164 MGR07JUL2023GCW 07/07/2023 07/07/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.07 10:50:56 -08'00' RBDMS JSB 071123 Convert to JP Well: MPU I-03 Well Name:MPU I-03 API Number:50-029-22067-00-00 Current Status:SI Oil Well (failed ESP)Pad:I-Pad Estimated Start Date:July 6th, 2023 Rig:ASR #1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:190-092 First Call Engineer:Brian Glasheen 9075451144 Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) AFE Number:TBD Job Type:Convert to JP Current Bottom Hole Pressure:1,569 psi @ 4,041’ TVD Downhole Gauge: (10/21/21) |7.5 PPG Maximum Expected BHP:1,569 psi @ 4,041’ TVD Downhole Gauge: (10/21/21) |7.5 PPG MPSP:1,164 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 37° @ 3,170’ MD Max Dogleg:4.14°/100ft @ 3,800’ MD Brief Well Summary: The Milne Point I-03 well was drilled as a Schrader Bluff development well that TD’d at 4,750’ and ran and cemented 7” casing in November 1990. Post Completion while injecting fluids down the 9-5/8” x 7” annulus communication from the 9-5/8” to the 13-3/8” was identified. RIH set a bridge plug at 2,102’ MD, perforated the 7” CSG form 2,060’ – 2,062’ (10 shots, 4 spf). Pumped 92 BBLS 15.2 ppg CMT with cement to surface at 75 bbls slurry pumped. The well was initially completed with an ESP. This and subsequent ESPs failed and were replaced in 1995, 1997, 2002, 2003, 2006, 2009, 2013, 2015 and 2016. In 2015 a hole in the 7” CSG was identified and isolated with a seal assembly and packer set at 3,998’ MD. The most recent pump failed December 21, 2020. In 2022 ASR attempted to convert I-03 to a jet pump producer. However during the casing test, a small leak was found between 28’ and 224’ MD. Notes Regarding the Well & Design o ASR installed kill string 11/14/22. o Small leak in 7’’ casing between 28’ and 224’ MD. Bled off 100 psi in 5 mins at 2000 psi Objective: x Pull kill string. x Run new 5.5’’ casing and cement to surface. x Run new 3-1/2” reverse circulating JP completion. Planned SSV Pilot Settings and MIT Schedule x Power fluid SSV high pressure trip will not exceed 3650 psi x Power fluid SSV low pressure trip will be set to 50 percent of header pressure x Production SSV high pressure trip not to exceed 650 psi x Production SSV low pressure trip not to be below 75 psi Convert to JP Well: MPU I-03 Well Support- 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 3. Pressure test lines to 3,000 psi. 4. Circulate at least one wellbore volume with source or produced water 8.4 ppg down tubing, taking returns up casing to 500 bbl returns tank.. 5. RD Little Red Services and reverse out skid. 6. RU crane. Set CTS BPV. ND Tree. NU BOPE. RD Crane. 7. NU BOPE house. Spot mud boat. RWO Procedure: 8. MIRU Hilcorp ASR #1, ancillary equipment and lines to returns tank. 9. Test BOPE to 250/2,500 psi and annular to 250/2,500 psi. a. Notify the AOGCC 24 hours in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test VBR’s and annular with 2-7/8” and 4-1/2” test joints. d. Test Fixed ram’s and annular with 5-1/2’’ test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 10. RU to pull 2-7/8” kill string. 11. Pull the CTS Plug, check for pressure under the BPV, if needed kill the well with KWF and pull the BPV. 12. MU the landing joint to the tubing hanger, BOLDS and unseat the tubing hanger. a. String PU = 17K SO=13k weights with ASR in 2022. 13. Pull the hanger to the rig floor. Lay down the landing joint and tubing hanger. a. Inspect the tubing hanger and note any corrosion or damage. 14. POOH laying down the 2-7/8” tubing. a. Pull out all visually bad joints and mark for disposal b. Note any corrosion, sand, scale, damage or over torqued connections on the tubing. 15. PU and MU the following 5-1/2’’ casing completion: Convert to JP Well: MPU I-03 Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Lb/ft Material Notes 4-1/2''10'WLEG 12.6 L-80 Pick up 40' from tagging top of T2 at 3996 4-1/2''40 Joint 12.6 L-80 4-1/2''10'Pup Joint 12.6 L-80 4-1/2''3'X nip with RCH 12.6 L-80 4-1/2''10'Pup Joint 12.6 L-80 4-1/2''40 Joint 12.6 L-80 4-1/2''10'Pup 12.6 L-80 4-1/2'' 7” X 4-1/2” Packer 12.6 L-80 Set Packer ~3850 ' MD 4-1/2''10'Pup 12.6 L-80 4-1/2'' 40’ 1 joint 12.6 L-80 4-1/2''6'Pup Joint 12.6 L-80 4-1/2''NCS Frac sleeve 11.2 L-80 4-1/2''10'Pup Joint 12.6 L-80 4-1/2'' 1 joint 17 L-80 4-1/2''10' XO 5.5'' to 4.5'' Joint 12.6 L-80 5-1/2''Joints 17 L-80 5-1/2''Space out PUPS 17 L-80 5-1/2'' 1 joint 17 L-80 5-1/2''PUP 17 L-80 5-1/2''Tubing Hanger 17 L-80 16. Space out and land the 5-1/2” tie back in the existing tubing spool. 17. RILDS. Lay down landing joint. 18. Drop ball and rod and complete loading the 5-1/2’’ tie back and hydraulically set the packer as per manufacturers setting procedure. 19. MIT 5-1/2’’ casing to 3600 psi ( Power fluid pressure test) 20. RU SL and pull ball a rod and RHC. RDMO 21. SL RIH and Set 3-1/2’’ PX plug in 4,037 MD. 22. SL RIH dump sand or beads on top of plug. RDMO SL. 23. Pressure test TTP to 2000 psi 24. Make up NCS sleeve shifting BHA + drill collar(s) on 2-7/8’’ workstring and TIH to sleeve to cement tieback to surface. a. See cementing appendix. 25. After sleeve is closed, pressure test the 5-1/2’’ casing to 2000 psi to verify sleeve is closed a. Assuming the pressure test passed in step 23. b. Open the 7” x 5-1/2” casing valve to verify 5-1/2” primary packoff integrity. 26. If TTP passed MIT-T 5-1/2’’casing POOH move to step 28. Contingency: 27. If TTP failed: Convert to JP Well: MPU I-03 a. Pull a few joints of workstring OOH then set a storm packer below the wellhead and test to 500psi. 28. Set TWC and pressure test to 2000 psi. 29. Confirm no flow, then break BOP stack and stack new tubing spool with secondary packoff. 30. Test packoffs to 3,500psi. 31. NU BOPs, Test break to 2,500 psi, then pull TWC. 32. Pull storm packer if used in step 27. 33. PU and MU the following Tubing completion: Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Lb/ft Material Notes 3.5''10'WLEG L-80 3.5''30 Joint 6.5 L-80 3.5''10'Pup Joint 6.5 L-80 3.5''3'3-1/2'' X nip with RHC 6.5 L-80 3.5''10'Pup Joint 6.5 L-80 3.5''30 1 joint 6.5 L-80 3.5''10'Pup joint 9.2 L-80 3.5'' 5-1/2'' X 3-1/2'' Packer 9.2 L-80 Hal Packer set ~ 3550' MD 3.5''10'Pup Joint 9.2 L-80 3.5'' 1 joint 9.2 L-80 3.5'' 1 joint 9.2 L-80 3.5''10'Pup Joint 9.2 L-80 3.5''Sliding sleeve 9.2 L-80 3.5''10'Pup Joint 9.2 L-80 3.5''Joints 9.2 L-80 3.5''Space out PUPS 9.2 L-80 3.5'' 1 joint 9.2 L-80 3.5''PUP 9.2 L-80 3.5''Tubing Hanger 9.2 L-80 34. Space out and land the hanger. a. Note PU (Pick Up) and SO (Slack Off) weights on tally. 35. RILDS. Lay down landing joint. 36. Pump 25 bbls 1% KCL with Corrosion inhibitor down the IA. Taking returns up TBG. Convert to JP Well: MPU I-03 37. This is to protect the area between the packer and Sliding Sleeve. While taking returns up the TBG 38. Pump an additional 40 bbls of diesel freeze protect down the IA to land inhibitor between Sliding Sleeve and the packer while taking returns up the TBG. 39. Rig up jumper to TBG to allow 20 bbls of FP to swap from IA to TBG. 40. Drop ball and rod and complete loading tubing with FP and hydraulically set the packer as per manufacturers setting procedure 41. Pressure up and test the tubing to 3000 psi for MIT-T with 0 psi on the IA. Bleed off the tubing to 1000psi. Test the IA to 3750 psi for MIT-IA (This will serve as the PF MOASP pressure test). Record and notate all pressure tests (30 minutes) on chart. 42. Set BPV. 43. RDMO ASR. Non Sudried Work Post-Rig Procedure: 44. RU slickline, pressure test the lubricator to 250 psi low/ 2,500 psi high 5 min each. 45. RIH Pull the ball & rod and RHC plug body. 46. Pull PX plug at 4037’ MD 47. Open Sliding Sleeve 48. Install 12B Jet pump with gauges below. 49. RD slickline. Operations-Convert well on Surface to a Reverse Circulating Jet Pump producer. 1. MU surface lines from injection header to well. a. Pressure test lines at existing water injection header pressure (3,600 psi) Attachments: 1. Cementing Appendix 2. NCS sleeve shifting steps 3. Diagram of new tubing spool to be stacked 4. As-built Schematic 5. Proposed Schematic 6. BOP stack sketch Convert to JP Well: MPU I-03 1. Cementing Appendix: Objective: Planning to cement 7” x 5-1/2” annulus to surface to repair a hole in the 7”. Well conditions: Hole in the 7” production casing between 28-240’. Small leak bleeding off 100 psi in 5 mins at 2000 psi. Therefore should expect minimal losses to the leak with the 15.3ppg cement. Capacity Volume to NCS sleeve @ ~3,854’ 2-7/8” workstring 0.00524 bbl/ft 20 bbl 7” x 5-1/2” annulus 0.0089 bbl/ft 34 bbl 5-1/2” x 2-7/8” annulus 0.0152 bbl/ft 58 bbl Surface to surface volume down 2-7/8” workstring and up 7” x 5-1/2” annulus = 54bbl Steps: 1. Circulate a gel pill inside the 5-1/2” x 2-7/8’’ annulus to be above the sleeve and assist in reversing out. 2. Shift NCS sleeve open per vendor recommendation. a. It should have shear pins installed requiring a total force of per vendor reccomendation down to open. This is light enough that slacking off the workstring should open the sleeve, however it is possible to pressure up the backside of the workstring to help shift the sleeve. 3. Circulate a bottoms up taking returns from the 7” x 5-1/2” annulus casing valve, and verify 1 for 1 returns. 4. Cement the 7” x 5-1/2” annulus with the following: a. 10bbl fresh water b. 10bbl mudpush c. 54 bbl 15.3ppg Glass G cement (20 bbl excess) d. 10bbl fresh water spacer e. Displace with 9 bbls 1 percent KCL leaving 1 bbls of cement to reverse out. 5. Slow rate once cement reaches surface, and choke back returns if possible in an attempt to squeeze cement in to the leak. Contingency: 6. If no cement returns are seen at surface, bullhead (or circulate) 18 bbl of diesel down the 7” x 5-1/2” annulus to freeze protect to ~2000MD. 7. Shift sleeve closed with strait pull, per vendor. 8. Bleed off pressure from 5-1/2”X 2-7/8’’ workstring annulus to verify sleeve is closed. a. Pressure should bleed off very quickly and if it does not bleed off quick sleeve is likely still open and we need to pressure up to keep cement from swapping. 9. RU to start reversing out. 10. Begin reversing out at max rate and drop 10-20’ below NCS sleeve while reversing out. a. Consider running to top of 3.5’’ tubing at 3,998 while reversing out. 11. Perform 2 bottoms up before POOH. 12. POOH Convert to JP Well: MPU I-03 2. NCS sleeve shifting steps 1. Locate the Target Frac Sleeve 1.1. RIH 20 ft below the target sleeve. Pick up to the target frac sleeve and locate the sleeve by a measured overͲpull of tubing weight. Mark the tubing at the locate depth. 1.2. Pull through the sleeve to confirm sleeve position. Pull up and lay down the joint of tubing if necessary 1.3. Repeat Step 1.1 to stop at the marked sleeve depth. 2. Set the Packer 2.1. Space out as necessary to achieve a floor height connection for the tubing cementing head. 2.2. The packer is set to isolate the current zone from the well below the BHA. 2.3. Engage the setting slips. 3. Pressure Test the Packer 3.1. A pressure test is performed to ensure that the packer is set and holding pressure. 4. Shift the Sleeve Open 4.1. Frac sleeves are shifted open to expose the frac ports to the formation. By pumping down the tubing at controlled rates the annulus above the packer pressures up. When the pressure above the packer reaches the correct force, the sleeve shifts open. 5. Pull the Sleeve Closed 5.1. Picking up on the SFC BHA when in compression set mode cycles the packer into tension set mode. In tension set mode, the packer grips and closes the sleeve while pulling out of hole. 6. Cycle BHA to Pull Out of Hole Mode 6.1. The SFC BHA is cycled into POOH mode to pick up past the current sleeve. Convert to JP Well: MPU I-03 3. Diagram of new tubing spool to be stacked _____________________________________________________________________________________ Revised By: TDF 12/5/2022 SCHEMATIC Milne Point Unit Well: MP I-03 Last Completed: 9/8/2016 TD =4,750 (MD) / TD = 4,271’(TVD) 13-3/8” Orig. KB Elev.: 70.0’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 35.0’ (Nabors 27E) 7” 7 5 9 9-5/8” 1 & 2 PBTD = 4,659’ (MD) / PBTD = 4,184’(TVD) N Sands O Sands8 Squeeze Perfs: 2,060’ to 2,062’ 6 3 4 1 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / N/A 12.459 Surface 105' 0.1545 9-5/8" Surface 36 / K-55 / Btrc. 8.765 Surface 2,633’ 0.0773 7" Production 26 / L-80 / Btrc 6.151 Surface 4,741’ 0.0382 TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surf 3,015’ 0.0058 PERFORATION DETAIL Schrader Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NA Sand 4,260’ 4,280’ 3,802’ 3,821’ 20 2/23/1991 Open NB Sand 4,292’ 4,304’ 3,832’ 3,844’ 12 2/23/1991 Open NC Sand 4,322’ 4,328’ 3,861’ 3,867’ 6 2/23/1991 Open NE Sand 4,344’ 4,378’ 3,882’ 3,915’ 34 2/23/1991 Open OA Sand 4,424’ 4,455’ 3,959’ 3,988’ 31 2/23/1991 Open OB Sand 4,486’ 4,510’ 4,018’ 4,041’ 24 2/23/1991 Open ‘N’ Sands Perfs: 24SPF & 24GM. ‘O’ Sands Perfs: 5SPF & 37GM WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 37 deg. @ 3,170’ TREE & WELLHEAD Tree WKM 2-9/16”5M Wellhead WKM 11” 5M w/ 2-7/8” 8rd Tree Top Connection 2-1/2” “H” Profile GENERAL WELL INFO API: 50-029-22067-00-00 Drilled and Cased by Nabors 27 - 11/14/1990 ESP Completion – 3/7/1991 ESP RWO by Nabors 4ES – 10/5/1995 ESP RWO by Nabors 5S – 12/14/1997 ESP RWO by Nabors 4ES – 7/30/2002 RWO & Replace Screens by Nabors 4ES – 5/6/2003 ESP/ HT Changeout by Nabors 4ES – 10/7/2006 ESP RWO by Nabors 3S – 5/2/2009 ESP Changeout by Doyon 16 – 4/5/2013 Straddle Pckr/ ESP Changeout Nordic 3 - 5/3/2015 ESP Changeout by ASR#1 – 9/18/2016 Install Kill String by ASR#1 – 12/14/2022 OPEN HOLE / CEMENT DETAIL 13-3/8” 485sx Permafrost “C” 9-5/8”247sx of Class “E”, 942 sx of Class “G” in a 12.25” Hole 7” 307sx of 15.8 ppg Class “G” a 8.5” Hole STIMULATION DETAIL Interval: 4,424’ to 4,510’’ – 26,802 lbs. 16/20 mesh Propant JEWELRY DETAIL No Depth Item 1 3,998’ Top of 3-1/2” Blank Pipe, Seal Assembly 2 4,000’ DLH Hydraulic Retrievable Packer 3 4,037’ 3-1/2” X Nipple, ID = 2.810” 4 4,191’ 7” HES “VTA” Retrievable Packer 5 4,234’ 3-1/2” HES 250 Micron Poroplus Screens (4-Joints) – Bottom @ 4,359’ 6 4,422’ HES Collet Guide & Seal Assembly 7 4,398’ 7” Otis “AWD” Sump Packer (4.0”ID) 8 4,415’ 3-1/2” Otis X-Nipple (2.313” ID) 9 4,426’ WLEG _____________________________________________________________________________________ Revised By: TDF 6/2/2023 PROPOSED Milne Point Unit Well: MP I-03 Last Completed: 9/8/2016 TD = 4,750 (MD) / TD = 4,271’(TVD) 13-3/8” Orig. KB Elev.: 70.0’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 35.0’ (Nabors 27E) 7” 15 13 17 9-5/8” 9 & 10 5-1/2” x 4-1/2” Crossover @ ±3,722’ 1 PBTD = 4,659’ (MD) / PBTD = 4,184’(TVD) N Sands O Sands16 Squeeze Perfs: 2,060’ to 2,062’ 14 11 12 2 3 4 5 6 7 8 1 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / N/A 12.615 Surface 105' 0.1545 9-5/8" Surface 36 / K-55 / Btrc. 8.921 Surface 2,633’ 0.0773 7" Intermediate 26 / L-80 / Btrc 6.276 Surface 4,741’ 0.0382 5-1/2” Production 17 / L-80 / R3 TSH W511 4.892 Surface ±3728’ 0.0232 4-1/2” Production 12.3 / L-80 / Btrc 3.958 ±3728’ ±3,956’ 0.0152 TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / EUE 8rd 2.992 Surface ±3,653’ 0.0087 PERFORATION DETAIL Schrader Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NA Sand 4,260’ 4,280’ 3,802’ 3,821’ 20 2/23/1991 Open NB Sand 4,292’ 4,304’ 3,832’ 3,844’ 12 2/23/1991 Open NC Sand 4,322’ 4,328’ 3,861’ 3,867’ 6 2/23/1991 Open NE Sand 4,344’ 4,378’ 3,882’ 3,915’ 34 2/23/1991 Open OA Sand 4,424’ 4,455’ 3,959’ 3,988’ 31 2/23/1991 Open OB Sand 4,486’ 4,510’ 4,018’ 4,041’ 24 2/23/1991 Open ‘N’ Sands Perfs: 24SPF & 24GM. ‘O’ Sands Perfs: 5SPF & 37GM WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 37 deg. @ 3,170’ TREE & WELLHEAD Tree WKM 2-9/16”5M Wellhead WKM 11” 5M w/ 2-7/8” 8rd Tree Top Connection 2-1/2” “H” Profile GENERAL WELL INFO API: 50-029-22067-00-00 Drilled and Cased by Nabors 27 - 11/14/1990 ESP Completion – 3/7/1991 ESP RWO by Nabors 4ES – 10/5/1995 ESP RWO by Nabors 5S – 12/14/1997 ESP RWO by Nabors 4ES – 7/30/2002 RWO & Replace Screens by Nabors 4ES – 5/6/2003 ESP/ HT Changeout by Nabors 4ES – 10/7/2006 ESP RWO by Nabors 3S – 5/2/2009 ESP Changeout by Doyon 16 – 4/5/2013 Straddle Pckr/ ESP Changeout Nordic 3 - 5/3/2015 ESP Changeout by ASR#1 – 9/18/2016 Install Kill String by ASR#1 – 12/14/2022 OPEN HOLE / CEMENT DETAIL 13-3/8” 485sx Permafrost “C” 9-5/8”247sx of Class “E”, 942 sx of Class “G” in a 12.25” Hole 7” 307sx of 15.8 ppg Class “G” a 8.5” Hole STIMULATION DETAIL Interval: 4,424’ to 4,510’’ – 26,802 lbs. 16/20 mesh Propant JEWELRY DETAIL No Depth Item 1 ±3,470’ 3-1/2” Sliding Sleeve 2 ±3,550’ 5-1/2” x 3-1/2” Packer 3 ±3,600’ 3-1/2” X-Nipple w/ RHC 4 ±3,643’ 3-1/2” WLEG – Btm @ 3,653’ 5 ±3,788’ 4-1/2” NCS Frac Sleeve 6 ±3,850’ 7” x 4-1/2” Packer 7 ±3,893’ 4-1/2” X-Nipple w/ RHC 8 ±3,946’ WLEG – Btm @ ±3,956’ 9 3,998’ Top of 3-1/2” Blank Pipe, Seal Assembly 10 4,000’ DLH Hydraulic Retrievable Packer 11 4,037’ 3-1/2” X Nipple, ID = 2.810” 12 4,191’ 7” HES “VTA” Retrievable Packer 13 4,234’ 3-1/2” HES 250 Micron Poroplus Screens (4-Joints) – Bottom @ 4,359’ 14 4,422’ HES Collet Guide & Seal Assembly 15 4,398’ 7” Otis “AWD” Sump Packer (4.0”ID) 16 4,415’ 3-1/2” Otis X-Nipple (2.313” ID) 17 4,426’ WLEG Updated 6/26/2023 11” BOPE INTEGRATED 11'͛-5000 INTEGRATED 4.30'INTEGRATED 11" - 5000 2-7/8" x 5" VBR Blind 11'͛- 5000 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManual Stripping Head ManualManual 5-1/2" Pipe Ram Milne Point ASR 11” BOP w/ Jacks 05/17/2017 Milne Point ASR 11” BOP (Triple) 6/26/2023 1 Regg, James B (OGC) From:Russell Gallen - (C) <Russell.Gallen@hilcorp.com> Sent:Friday, November 11, 2022 4:17 AM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Alaska NS - ASR - Well Site Managers Subject:MPU i-03 initial BOPE test. Attachments:i-03 BOPE test report (initial ).xlsx Thank you. Regards, Russell Gallen ASR DSM, Mobile: 907-529-7202 Office: 907-685-1266 russell.gallen@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Milne Pt Unit I-03PTD 1900920 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:ASR 1 DATE:11/10/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1900920 Sundry #322-587 Operation:Drilling:Workover:x Explor.: Test:Initial:x Weekly:Bi-Weekly:Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1164 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2 7/8" x 5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"P Time/Pressure Test Result HCR Valves 1 2 1/16"P System Pressure (psi)3000 P Kill Line Valves 2 2 1/16"P Pressure After Closure (psi)1850 P Check Valve 0 NA 200 psi Attained (sec)17 P BOP Misc 0 NA Full Pressure Attained (sec)53 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 / 2256 PSI P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 24 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:4.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 11/08/22 12:29 Waived By Test Start Date/Time:11/10/2022 0:30 (date)(time)Witness Test Finish Date/Time:11/10/2022 5:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Hilcorp Tested w/ 2-7/8" test joint & 3-1/2" test joint. Bottle pre-charge = 1000 PSI C.Pace / J. Werlinger Hilcorp Alaska LLC S.Heim / R. Gallen MPU I-03 Test Pressure (psi): askans-asr-toolpushers@hilcorp.co ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022)2022-1110_BOP_Hilcorp_ASR1_MPU_I-03          J. Regg; 12/5/2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOP - Hilcorp ASR1 Date:Monday, December 5, 2022 12:07:43 PM Attachments:2022-1110_BOP_Hilcorp_ASR1_MPU_I-03.pdf Milne Pt Unit I-03 (PTED 1900920) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage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y Anne Prysunka at 10:09 am, Oct 05, 2022 'LJLWDOO\VLJQHGE\'DYLG +DDNLQVRQ '1FQ 'DYLG+DDNLQVRQ RX 8VHUV 'DWH 'DYLG+DDNLQVRQ 6)' '65 %23(WHVWWRSVL $SSURYHGIRUIRUZDUGFLUFXODWLQJMHWSXPS ,QMHFWLRQWXELQJ669KLJKSUHVVXUHWULSQRWWRH[FHHGSVL ,QMHFWLRQWXELQJ669ORZSUHVVXUHWULSQRWWREHORZHUWKDQSVL ,$669KLJKSUHVVXUHWULSQRWWREHORZHUWKDQSVL 669FORVXUHRQ,$ZLOOLQLWLDWHZLWKLQPLQXWHVRIFORVXUHRQ669RQLQMHFWLRQWXELQJDQGYLVDYHUVD 4XDGUHQQLDO0,7,$WRSVL $SSURYHGYDULDQFHWR$$&F669RQSURGXFLQJ,$ZLOOQRWEHLQYHUWLFDOUXQRIWKHWUHH 0*52&7*&: Jessie L. 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ϯͲϭͬϮ͟yEŝƉƉůĞ͕/сϮ͘ϴϭϬ͟ ϭϰ ϰ͕ϭϵϭ͛ ϳ͟,^͞sd͟ZĞƚƌŝĞǀĂďůĞWĂĐŬĞƌ ϭϱ ϰ͕Ϯϯϰ͛ ϯ͘ϱ͟,^ϮϱϬDŝĐƌŽŶWŽƌŽƉůƵƐ^ĐƌĞĞŶƐ;ϰͲ:ŽŝŶƚƐͿʹŽƚƚŽŵΛϰ͕ϯϱϵ͛ ϭϲ ϰ͕ϰϮϮ͛ ,^ŽůůĞƚ'ƵŝĚĞΘ^ĞĂůƐƐĞŵďůǇ ϭϳ ϰ͕ϯϵϴ͛ ϳ͟KƚŝƐ͞t͟^ƵŵƉWĂĐŬĞƌ;ϰ͘Ϭ͟/Ϳ ϭϴ ϰ͕ϰϭϱ͛ ϯ͘ϱ͟KƚŝƐyͲEŝƉƉůĞ;Ϯ͘ϯϭϯ͟/Ϳ ϭϵ ϰ͕ϰϮϲ͛ t>' BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗,ϱͬϭϵͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW/ͲϬϯ >ĂƐƚŽŵƉůĞƚĞĚ͗ϵͬϴͬϮϬϭϲ dсϰ͕ϳϱϬ;DͿͬdсϰ͕Ϯϳϭ͛;dsͿ ϭϯͲϯͬϴ´ KƌŝŐ͘<ůĞǀ͗͘ϳϬ͘Ϭ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϯϱ͘Ϭ͛ Z<ʹ,ĂŶŐĞƌ͗ϯϱ͘Ϭ͛;EĂďŽƌƐϮϳͿ ϳ͟ ϵͲϱͬϴ͟ Wdс ϰ͕ϲϱϵ͛;DͿͬWdсϰ͕ϭϴϰ͛;dsͿ 16DQGV 26DQGV 6TXHH]H3HUIV ¶WR¶ ϭ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ W& ϭϯͲϯͬϴΗ ŽŶĚƵĐƚŽƌ ϱϰ͘ϱͬ<ͲϱϱͬEͬ ϭϮ͘ϰϱϵ ^ƵƌĨĂĐĞ ϭϬϱΖ Ϭ͘ϭϱϰϱ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϯϲͬ<ͲϱϱͬƚƌĐ͘ ϴ͘ϳϲϱ ^ƵƌĨĂĐĞ Ϯ͕ϲϯϯ͛ Ϭ͘Ϭϳϳϯ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬƚƌĐ ϲ͘ϭϱϭ ^ƵƌĨĂĐĞ ϰ͕ϳϰϭ͛ Ϭ͘ϬϯϴϮ dh/E'd/> ϯͲϭͬϮ͟ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬhϴƌĚ ϯ͘ϰϮϯ ^ƵƌĨ ϯ͕ϵϴϮ͛ Ϭ͘ϬϬϱϳϵ WZ&KZd/KEd/> ^ĐŚƌĂĚĞƌ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚ ƵƐ E^ĂŶĚ ϰ͕ϮϲϬ͛ ϰ͕ϮϴϬ͛ ϯ͕ϴϬϮ͛ ϯ͕ϴϮϭ͛ ϮϬ ϮͬϮϯͬϭϵϵϭ KƉĞŶ E^ĂŶĚ ϰ͕ϮϵϮ͛ ϰ͕ϯϬϰ͛ ϯ͕ϴϯϮ͛ 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KďũĞĐƚŝǀĞ͗ x WƵůůϮͲϳͬϴ͟^WĐŽŵƉůĞƚŝŽŶ͘ x ZƵŶŶĞǁϯͲϭͬϮ͟ĨŽƌǁĂƌĚĐŝƌĐƵůĂƚŝŶŐ:WĐŽŵƉůĞƚŝŽŶ͘ x ,ŝůĐŽƌƉůĂƐŬĂ͕>>ƌĞƋƵĞƐƚƐĂǀĂƌŝĂŶĐĞƚŽϮϬϮϱ͘Ϯϲϱ;ĐͿ;ϭͿƚŽŽƉĞƌĂƚĞĂƐƵƌĨĂĐĞƐĂĨĞƚǇǀĂůǀĞ;^^sͿ ƚŚĂƚŝƐŶŽƚůŽĐĂƚĞĚŝŶƚŚĞǀĞƌƚŝĐĂůƌƵŶŽĨƚŚĞƚƌĞĞŽŶDŝůŶĞWŽŝŶƚhŶŝƚ;DWhͿǁĞůů/ͲϬϯ;WdηϭϵϬͲϬϵϮͿ WƌĞͲZŝŐWƌŽĐĞĚƵƌĞ͗ ϭ͘ Zh>Z^ƉƵŵƉƚƌƵĐŬĂŶĚWdůŝŶĞƐƚŽϮ͕ϱϬϬƉƐŝ͘ Ϯ͘ ŽŶƚĂĐƚƚŚĞŽƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌƚŽƌĞǀŝĞǁƚŚĞǁĞůů<ŝůůƉůĂŶǁŝƚŚƵƉĚĂƚĞĚd'ĂŶĚ/ƉƌĞƐƐƵƌĞƐ͘/ŶŝƚŝĂů ƉůĂŶǁŝůůďĞƚŽĐŝƌĐƵůĂƚĞĂƚůĞĂƐƚϭϱϬ>^ƐŽƵƌĐĞǁĂƚĞƌ ϴ͘ϯƉƉŐ ĚŽǁŶƚŚĞƚƵďŝŶŐĂŶĚƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉ ƚŚĞ/ƚŽĂϱϬϬďďůƌĞƚƵƌŶƚĂŶŬ͘ĨƚĞƌŽďƚĂŝŶŝŶŐ ϴ͘ϯƉƉŐ ƐŽƵƌĐĞǁĂƚĞƌƚŽƐƵƌĨĂĐĞ͕ƐŚƵƚŝŶƚŚĞd'ĂŶĚ ďƵůůŚĞĂĚϮϬ>͛ƐĚŽǁŶƚŚĞ/ƚŽƚŚĞĨŽƌŵĂƚŝŽŶ;>ŝŵŝƚƵůůŚĞĂĚƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞƚŽϳϬϬƉƐŝǁŝƚŚϴ͘ϯƉƉŐ ĨůƵŝĚͿ͘ŽŶƚĂĐƚƚŚĞŽƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌǁŝƚŚƌĞƐƵůƚƐ͘ Ă͘ dƵďŝŶŐsŽůƵŵĞс͘ϬϬϱϴďƉĨΎϯ͕ϳϳϲ͛сϮϭ͘ϵďďůƐ ŽŶǀĞƌƚƚŽ:W tĞůů͗DWh/ͲϬϯ ď͘ ŶŶƵůĂƌsŽůƵŵĞс͘ϬϯϬϮďƉĨΎϯ͕ϳϳϲ͛сϭϭϰďďůƐ ϯ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ Ă͘ &ƌĞĞǌĞƉƌŽƚĞĐƚŝƐƵƉƚŽƚŚĞĚŝƐĐƌĞƚŝŽŶŽĨƚŚĞtĞůůƐŝƚĞ^ƵƉĞƌǀŝƐŽƌĚĞƉĞŶĚŝŶŐŽŶƚŝŵŝŶŐĨŽƌĂƌƌŝǀĂůŽĨ ƚŚĞ^Z͘;EŽƚĞ͗/ĨƚŚĞǁĞůůŝƐĨƌĞĞǌĞƉƌŽƚĞĐƚĞĚƚŚĞǁĞůůŬŝůůƉƵƚŝŶƉůĂĐĞǁŝůůďĞůŽƐƚ͘Ϳ ϰ͘ Z>Z^͘ ϱ͘ ůĞĂƌĂŶĚůĞǀĞůƉĂĚĂƌĞĂŝŶĨƌŽŶƚŽĨǁĞůů͘^ƉŽƚƌŝŐŵĂƚƐĂŶĚĐŽŶƚĂŝŶŵĞŶƚ͘ ϲ͘ ZǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐ͘ůĞĂƌĂŶĚůĞǀĞůĂƌĞĂĂƌŽƵŶĚǁĞů ů͘ ϳ͘ ZhĐƌĂŶĞ͘^ĞƚWs͘EdƌĞĞ͘^Ğƚd^WůƵŐ͘/ŶƐƉĞĐƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌůŝĨƚƚŚƌĞĂĚĂŶĚŶŽƚĞĂŶǇĚĂŵĂŐĞ͘ ϴ͘ Ehϭϭ͟KW͘ZƌĂŶĞ͘ ϵ͘ ^ƉŽƚŵƵĚďŽĂƚ͘ ZtKWƌŽĐĞĚƵƌĞ͗ ϭϬ͘ D/Zh,ŝůĐŽƌƉ^Zηϭ͕ĂŶĐŝůůĂƌǇĞƋƵŝƉŵĞŶƚĂŶĚůŝŶĞƐƚŽƌĞƚƵƌŶƐƚĂŶŬ͘ ϭϭ͘ dĞƐƚϭϭ͟KWƚŽϮϱϬͬϮ͕ϱϬϬƉƐŝĂŶĚĂŶŶƵůĂƌƚŽϮϱϬͬϮ͕ϱϬϬƉƐŝ͘ Ă͘ EŽƚŝĨǇƚŚĞK'ϮϰŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨKWƚĞƐƚ͘ ď͘ ŽŶĨŝƌŵƚĞƐƚƉƌĞƐƐƵƌĞƐƉĞƌƚŚĞ^ƵŶĚƌǇŽŶĚŝƚŝŽŶƐŽĨĂƉƉƌŽǀĂů͘ Đ͘ dĞƐƚsZ͛ƐĂŶĚĂŶŶƵůĂƌǁŝƚŚϮͲϳͬϴ͟ĂŶĚϯͲϭͬϮ͟ƚĞƐƚũŽŝŶƚƐ͘ Ě͘ ^ƵďŵŝƚƚŽK'ĐŽŵƉůĞƚĞĚϭϬͲϰϮϰĨŽƌŵǁŝƚŚŝŶϱĚĂǇƐŽĨKWƚĞƐƚ͘ ϭϮ͘ ZhƚŽƉƵůůϮͲϳͬϴ͟^WĐŽŵƉůĞƚŝŽŶ͘ ϭϯ͘ WƵůůƚŚĞd^WůƵŐ͕ĐŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞƵŶĚĞƌƚŚĞWs͕ŝĨŶĞĞĚĞĚŬŝůůƚŚĞǁĞůůǁŝƚŚ<t&ĂŶĚƉƵůůƚŚĞWs͘ ϭϰ͘ DhƚŚĞůĂŶĚŝŶŐũŽŝŶƚƚŽƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͕K>^ĂŶĚƵŶƐĞĂƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ Ă͘ ^ƚƌŝŶŐWhсϯϲ<͕ůĂƐƚƉƵůůĞĚǁŝƚŚ^ZŝŶϮϬϭϲ͘ ϭϱ͘ WƵůůƚŚĞŚĂŶŐĞƌƚŽƚŚĞƌŝŐĨůŽŽƌ͘>ĂǇĚŽǁŶƚŚĞůĂŶĚŝŶŐũŽŝŶƚĂŶĚƚƵďŝŶŐŚĂŶŐĞƌ͘ZhƚŽƉƵůů^WĐĂďůĞ ŽǀĞƌƐŚĞĂǀĞƐƚŽƐƉŽŽůŝŶŐƵŶŝƚƐ͘ Ă͘ /ŶƐƉĞĐƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌĂŶĚŶŽƚĞĂŶǇĐŽƌƌŽƐŝŽŶŽƌĚĂŵĂŐĞ͘ ϭϲ͘ WKK,ůĂǇŝŶŐĚŽǁŶƚŚĞϮͲϳͬϴ͟ƚƵďŝŶŐƐƉŽŽůŝŶŐ^WĐĂďůĞͬŚĞĂƚƚ ƌĂĐĞůŝŶĞƚŽϮ͕ϰϬϬ͛DĂŶĚƌĞŵŽǀŝŶŐĂůů ũĞǁĞůƌǇĂƐŝƚƉƌĞƐĞŶƚƐŝƚƐĞůĨ Ă͘ WƵůůŽƵƚĂůůǀŝƐƵĂůůǇďĂĚũŽŝŶƚƐĂŶĚŵĂƌŬĨŽƌĚŝƐƉŽƐĂů ď͘ EŽƚĞĂŶǇĐŽƌƌŽƐŝŽŶ͕ƐĂŶĚ͕ƐĐĂůĞ͕ĚĂŵĂŐĞŽƌŽǀĞƌƚŽƌƋƵĞĚĐŽŶŶĞĐƚŝŽŶƐŽŶƚŚĞƚƵďŝŶŐǁŝƚŚĂƐƐŽĐŝĂƚĞĚ ĚĞƉƚŚƐĂŶĚ^WĐŽŵƉŽŶĞŶƚƐŽŶƚŚĞŵŽƌŶŝŶŐƌĞƉŽƌƚ͘ 7XELQJKDQJHU &OHDQGRSHDQGUHVWRFN 7XELQJ 3XSMRLQWV &OHDQGRSHDQGUHVWRFN *DVOLIW0DQGUHOV1LSSOH &OHDQGRSHDQGUHVWRFN (63HTXLSPHQW3RZHU&DEOH &HQWULOLIWWRWDNHSRVVHVVLRQIRULQVSHFWLRQDQG WHDUGRZQ 7RWDO'XDO&ODPSV &OHDQDQGUHVWRFN 6LQJOH&ROODU&ODPSV &OHDQDQGUHVWRFN 3XPS3URWHFWROL]HUV &OHDQDQGUHVWRFN )ODW*XDUGV &OHDQDQGUHVWRFN &URVV&ROODU&ODPSV &OHDQDQGUHVWRFN ŽŶǀĞƌƚƚŽ:W tĞůů͗DWh/ͲϬϯ 3XPS&ODPSV &OHDQDQGUHVWRFN %DQGV &OHDQDQGUHVWRFN ϭϳ͘ Z^WƉƵůůŝŶŐĞƋƵŝƉŵĞŶƚ͘ ϭϴ͘ Zh^>ĂŶĚZ/,ǁŝƚŚϳ͟WĂĐŬĞƌĚƌŝĨƚĂŶĚƚĂŐdϮŽŶͬŽĨĨĐŽŶŶĞĐƚŽƌ;/ŶǀĞƌƚĞĚŽǀĞƌƐŚŽƚͿĂƚϯϵϵϲ͚D ϭϵ͘ WKK, ϮϬ͘ Z/,ǁŝƚŚϯͲϭͬϮddWĂŶĚƐĞƚƉůƵŐŝŶŶŝƉĂƚϰϬϯϲ͛D Ϯϭ͘ WƌĞƐƐƵƌĞƚĞƐƚĐĂƐŝŶŐƚŽϮϬϬϬƉƐŝ;ϭ͘ϮƉƐŝΎDK^WƉůƵƐ^&ͿZĞĐŽƌĚĂŶĚŶŽƚĂƚĞƉƌĞƐƐƵƌĞƚĞƐƚ;ϯϬŵŝŶƵƚĞƐͿ ŽŶĐŚĂƌƚ͘ ϮϮ͘ WƵůůddWZDK^> Ϯϯ͘ 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ůĂŶĚŝŶŚŝďŝƚŽƌďĞƚǁĞĞŶ^ůŝĚŝŶŐ^ůĞĞǀĞĂŶĚƚŚĞƉĂĐŬĞƌǁŚŝůĞƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉƚŚĞd'͘ ϲ͘ ^ǁĂƉƚŽƉƵŵƉŝŶŐĚŽǁŶƚŚĞd'ƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉƚŚĞ/ĂŶĚWƵŵƉϭϴďďůƐŽĨ&W͘ ϳ͘ ƌŽƉďĂůůĂŶĚƌŽĚĂŶĚĐŽŵƉůĞƚĞůŽĂĚŝŶŐƚƵďŝŶŐǁŝƚŚ&WĂŶĚŚǇĚ ƌĂƵůŝĐĂůůǇƐĞƚƚŚĞƉĂĐŬĞƌĂƐƉĞƌ ŵĂŶƵĨĂĐƚƵƌĞƌƐƐĞƚƚŝŶŐƉƌŽĐĞĚƵƌĞ ϴ͘ WƌĞƐƐƵƌĞƵƉĂŶĚƚĞƐƚƚŚĞƚƵďŝŶŐƚŽϯϳϱϬƉƐŝĨŽƌD/dͲdǁŝƚŚϭϬϬϬƉƐŝŽŶƚŚĞ/;dŚŝƐǁŝůůƐĞƌǀĞĂƐƚŚĞ W&DK^WƉƌĞƐƐƵƌĞƚĞƐƚͿ͘ůĞĞĚŽĨĨƚŚĞƚƵďŝŶŐƚŽϭϬϬϬƉƐŝ͘dĞƐƚƚŚĞ/ƚŽϮϬϬϬƉƐŝĨŽƌD/dͲ/͘ ZĞĐŽƌĚĂŶĚŶŽƚĂƚĞĂůůƉƌĞƐƐƵƌĞƚĞƐƚƐ;ϯϬŵŝŶƵƚĞƐͿŽŶĐŚĂƌƚ͘ ϵ͘ ^ĞƚWs͘ ϭϬ͘ ZDK^Z͘ WŽƐƚͲZŝŐWƌŽĐĞĚƵƌĞ͗ Ϯϰ͘ ZhƐůŝĐŬůŝŶĞ͕ƉƌĞƐƐƵƌĞƚĞƐƚƚŚĞůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϮ͕ϱϬϬƉƐŝŚŝŐŚϱŵŝŶĞĂĐŚ͘ Ϯϱ͘ Z/,ƉƵůůďůĂŶŬƐůĞĞǀĞ͘ Ϯϲ͘ Z/,WƵůůƚŚĞďĂůůΘƌŽĚĂŶĚZ,ƉůƵŐďŽĚǇ͘ Ϯϳ͘ /ŶƐƚĂůůƚŚĞϯ͛͛ƐƚĂŶĚŝŶŐǀĂůǀĞ Ϯϴ͘ /ŶƐƚĂůůϭϮ:ĞƚƉƵŵƉ͘ Ϯϵ͘ ZƐůŝĐŬůŝŶĞ͘ KƉĞƌĂƚŝŽŶƐͲ ŽŶǀĞƌƚǁĞůůŽŶ^ƵƌĨĂĐĞƚŽĂ &KZtZŝƌĐƵůĂƚŝŶŐ:ĞƚWƵŵƉƉƌŽĚƵĐĞƌ͘ ϭ͘ DhƐƵƌĨĂĐĞůŝŶĞƐĨƌŽŵŝŶũĞĐƚŝŽŶŚĞĂĚĞƌƚŽǁĞůů͘ Ă͘ WƌĞƐƐƵƌĞƚĞƐƚůŝŶĞƐĂƚĞǆŝƐƚŝŶŐǁĂƚĞƌŝŶũĞĐƚŝŽŶŚĞĂĚĞƌƉƌĞƐƐƵƌĞ;ϯ͕ϲϬϬƉƐŝͿ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ KWƐƚĂĐŬƐŬĞƚĐŚ SVLIXOOGLIIHUHQWLDOSUHVVXUHPJU %LHQQLDO0,77DQG0,7,$PLQXWHFKDUWHGWHVW5HVXOWVWR$2*&& BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗,ϱͬϭϵͬϮϬϮϮ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW/ͲϬϯ >ĂƐƚŽŵƉůĞƚĞĚ͗ϵͬϴͬϮϬϭϲ dсϰ͕ϳϱϬ;DͿͬdсϰ͕Ϯϳϭ͛;dsͿ ϭϯͲϯͬϴ´ KƌŝŐ͘<ůĞǀ͗͘ϳϬ͘Ϭ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϯϱ͘Ϭ͛ Z<ʹ,ĂŶŐĞƌ͗ϯϱ͘Ϭ͛;EĂďŽƌƐϮϳͿ ϳ͟ ϵͲϱͬϴ͟ Wdс ϰ͕ϲϱϵ͛;DͿͬWdсϰ͕ϭϴϰ͛;dsͿ +HDW7UDFHIURP VXUIDFHWR¶ 16DQGV 26DQGV 6TXHH]H3HUIV ¶WR¶ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ W& ϭϯͲϯͬϴΗ ŽŶĚƵĐƚŽƌ ϱϰ͘ϱͬ<ͲϱϱͬEͬ ϭϮ͘ϰϱϵ ^ƵƌĨĂĐĞ ϭϬϱΖ Ϭ͘ϭϱϰϱ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϯϲͬ<ͲϱϱͬƚƌĐ͘ ϴ͘ϳϲϱ ^ƵƌĨĂĐĞ Ϯ͕ϲϯϯ͛ Ϭ͘Ϭϳϳϯ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬƚƌĐ ϲ͘ϭϱϭ ^ƵƌĨĂĐĞ ϰ͕ϳϰϭ͛ Ϭ͘ϬϯϴϮ dh/E'd/> ϮͲϳͬϴ͟ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϰϰϭ ^ƵƌĨ ϯ͕ϵϴϮ͛ Ϭ͘ϬϬϱϳϵ WZ&KZd/KEd/> ^ĐŚƌĂĚĞƌ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ E^ĂŶĚ ϰ͕ϮϲϬ͛ ϰ͕ϮϴϬ͛ ϯ͕ϴϬϮ͛ ϯ͕ϴϮϭ͛ ϮϬ ϮͬϮϯͬϭϵϵϭ KƉĞŶ E^ĂŶĚ ϰ͕ϮϵϮ͛ ϰ͕ϯϬϰ͛ ϯ͕ϴϯϮ͛ ϯ͕ϴϰϰ͛ ϭϮ ϮͬϮϯͬϭϵϵϭ KƉĞŶ E^ĂŶĚ ϰ͕ϯϮϮ͛ ϰ͕ϯϮϴ͛ ϯ͕ϴϲϭ͛ ϯ͕ϴϲϳ͛ ϲ ϮͬϮϯͬϭϵϵϭ KƉĞŶ E^ĂŶĚ ϰ͕ϯϰϰ͛ ϰ͕ϯϳϴ͛ ϯ͕ϴϴϮ͛ ϯ͕ϵϭϱ͛ ϯϰ ϮͬϮϯͬϭϵϵϭ KƉĞŶ K^ĂŶĚ ϰ͕ϰϮϰ͛ ϰ͕ϰϱϱ͛ ϯ͕ϵϱϵ͛ ϯ͕ϵϴϴ͛ ϯϭ ϮͬϮϯͬϭϵϵϭ KƉĞŶ K^ĂŶĚ ϰ͕ϰϴϲ͛ ϰ͕ϱϭϬ͛ ϰ͕Ϭϭϴ͛ ϰ͕Ϭϰϭ͛ Ϯϰ ϮͬϮϯͬϭϵϵϭ KƉĞŶ ͚E͛^ĂŶĚƐWĞƌĨƐ͗Ϯϰ^W&ΘϮϰ'D͘ ͚K͛^ĂŶĚƐWĞƌĨƐ͗ϱ^W&Θϯϳ'D t>>/E>/Ed/KE d/> <KWΛϱϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϯϳĚĞŐ͘Λϯ͕ϭϳϬ͛ dZΘt>>, dƌĞĞ t<DϮͲϵͬϭϲ͟ϱD tĞůůŚĞĂĚ t<Dϭϭ͟ϱDǁͬϮͲϳͬϴ͟ϴƌĚdƌĞĞdŽƉ ŽŶŶĞĐƚŝŽŶϮͲϭͬϮ͟͞,͟WƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϬϲϳͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϮϳͲϭϭͬϭϰͬϭϵϵϬ ^WŽŵƉůĞƚŝŽŶʹϯͬϳͬϭϵϵϭ ^WZtKďǇEĂďŽƌƐϰ^ʹϭϬͬϱͬϭϵϵϱ ^WZtKďǇEĂďŽƌƐϱ^ʹϭϮͬϭϰͬϭϵϵϳ ^WZtKďǇEĂďŽƌƐϰ^ʹϳͬϯϬͬϮϬϬϮ ZtKΘZĞƉůĂĐĞ^ĐƌĞĞŶƐďǇEĂďŽƌƐϰ^ʹϱͬϲͬϮϬϬϯ ^Wͬ,dŚĂŶŐĞŽƵƚďǇEĂďŽƌƐϰ^ʹϭϬͬϳͬϮϬϬϲ ^WZtKďǇEĂďŽƌƐϯ^ʹϱͬϮͬϮϬϬϵ ^WŚĂŶŐĞŽƵƚďǇŽǇŽŶϭϲʹϰͬϱͬϮϬϭϯ ^ƚƌĂĚĚůĞWĐŬƌͬ^WŚĂŶŐĞŽƵƚEŽƌĚŝĐϯͲϱͬϯͬϮϬϭϱ ^WŚĂŶŐĞŽƵƚďǇ^ZηϭʹϵͬϭϴͬϮϬϭϲ KWE,K>ͬDEdd/> ϭϯͲϯͬϴ͟ ϰϴϱƐǆWĞƌŵĂĨƌŽƐƚ͟͞ ϵͲϱͬϴ͟ ϮϰϳƐǆŽĨůĂƐƐ͕͟͞ϵϰϮƐǆŽĨůĂƐƐ͞'͟ŝŶĂϭϮ͘Ϯϱ͟,ŽůĞ ϳ͟ ϯϬϳƐǆŽĨϭϱ͘ϴƉƉŐůĂƐƐ͞'͟Ăϴ͘ϱ͟,ŽůĞ ^d/Dh>d/KEd/> /ŶƚĞƌǀĂů͗ϰ͕ϰϮϰ͛ƚŽϰ͕ϱϭϬ͛͛ʹϮϲ͕ϴϬϮ ůďƐ͘ϭϲͬϮϬŵĞƐŚWƌŽƉĂŶƚ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭϭϰϳ͛^dϮ͗ϮͲϳͬϴ͟ǆϭ͟'>DϮ͘ϴϳϱ͟ǆϭ͟<DD'>D<ͲƵŵŵǇϭϮͲϮϳͲϮϬϮϬ Ϯϯ͕ϳϳϲ͛^dϭ͗ϮͲϳͬϴ͟'>DϮ͘ϴϳϱ͟ǆϭ͟<DD'>D;ŵƉƚǇͿϭϮͲϮϳͲϮϬϮϬ ϯ ϯ͕ϵϭϳ͛ ϮͲϳͬϴ͟yEWƌŽĨŝůĞ ;Ϯ͘ϮϬϱ͟EŽͲ'ŽWĂĐŬŝŶŐŽƌĞ/Ϳ ϰ ϯ͕ϵϮϴ͛ 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ϮϭͬϭϲϱD<ŝůů>ŝŶĞsĂůǀĞƐ ϮϭͬϭϲϱDŚŽŬĞ>ŝŶĞsĂůǀĞƐ ,ZDĂŶƵĂůDĂŶƵĂůDĂŶƵĂů ^ƚƌŝƉƉŝŶŐ,ĞĂĚ STATE OF ALASKA AllIIKA OIL AND GAS CONSERVATION COIASION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate1 �� ❑ Pull Tubing u Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate Q Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well Q Re-enter Susp Well❑ Other: ESP Changeout D 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development❑✓ Exploratory ❑ 190-092 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22067-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 MILNE PT UNIT SB I-03 RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Schrader Bluff Oil Pool OCT 10 2016 11.Present Well Condition Summary: Total Depth measured 4,750 feet Plugs measured N/A feet true vertical 4,271 feet Junk measured N/A feet 3,998,4,191 & Effective Depth measured 4,659 feet Packer measured 4,398 feet 3,047,3,667& true vertical 4,184 feet true vetibat 3,934 feet Casing Length Size MD TVD Burst Collapse Conductor 105' 13-3/8" 105' 105' 1,730psi 740psi Surface 2,633' 9-5/8" 2,633' 2,399' 3,520psi 2,020psi Production 4,741' 7" 4,741' 4,262' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic S �ED FEB 3 Gv �AHf 1 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 3,964' 3,537' DLH Hydraulic Retrievable 7"HES'VTA'Retrievable Packers and SSSV(type,measured and true vertical depth) 7"'AWD'Sump N/A See Above N/A 12.Stimulation or cement squeeze summary: 47.25 BBL -12.5%Scale Inhibitor Intervals treated(measured): 4,260'to 4,510' 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 0 440 0 Subsequent to operation: 97 13 29 270 215 14.Attachments(required per 20 AAC 25.970,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development❑ Service ❑ Strabgraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL U 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: 316-440 Contact Stan Porhola Email sporholatc�hilcorp.com 5 Printed Name Bo York Title Operations Engineer Signature Phone 777-8345 Date 10/5/2016 6—//-1 4RBDMS Ul1 0 2016 ;I Form 10-404 Revised 5/2015 l 0/0 Submit Original Only • • Milne Point Unit II Well: MP 1-03 SCHEMATIC Last Completed:9/8/2016 Hiker.Alaska,lad: TREE&WELLHEAD OPEN HOLE/CEMENT DETAIL Tree WKM 2-9/16"5M 13-3/8" 485sx Permafrost"C" Wellhead WKM 11" 5M w/2-7/8"8rd Tree Top 9-5/8" 247sx of Class"E",942 sx of Class"G"in a 12.25"Hole Connection 2-1/2""H"Profile 7" 307sx of 15.8 ppg Class"G"a 8.5"Hole Orig.KB Elev.:70.0'/Orig.GL Elev.:35.0' CASING DETAIL RKB-Hanger:35.0'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm BPF 4 , 13-3/8" Conductor 54.5/K-55/N/A 12.459 Surface 105' 0.1545 133/8„ 9-5/8" Surface 36/K-55/Btrc. 8.765 Surface 2,633' 0.0773 ( 1 7" Production 26/L-80/Btrc6.151 Surface 4,741' 0.0382 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 3,982' 0.00579 WELL INCLINATION DETAIL ;1 KOP @ 500' Max Hole Angle=37 deg.@ 3,170' I\ .., 9-5/8' a JEWELRY DETAIL Squeeze Perfs: 2,06G to 2,062' No Depth Item 1 147' ST 2:2-7/8"x 1"GLM 2.875"x 1"KBMM GLM(BK-Orifice Valve Set) 2 3,776' ST 1:2-7/8"GLM 2.875"x 1"KBMM GLM(BK-Dummy Valve Set) 3 3,917' 2-7/8"XN Profile(2.205"No-Go Packing Bore ID) 4 3,928' Discharge Head:FPHVDIS Heat Trace from 5 3,929' Pump:119FLEX10,Model-PMSXO sufaceto2,40J , 6 3,952' Gas Separator:GRSFTXARH6 7 3,957' Upper Tandem Seal:GSB3DBUT SB/SB PFSA 8 3,964' Lower Tandem Seal:GSB3DBUT SB/SB PFSA 9 3,971' Motor CL5:MSP3-200 10 3,978' Centralizer w/XT-150 Phoenix Sensor-Bottom @ 3,982' 11 3,998' DLH Hydraulic Retrievable Packer 12 4,006' Top of 3-1/2"Blank Pipe,Seal Assembly 13 4,191' 7"HES"VTA"Retrievable Packer IIII 2 14 4,234' 3.5"HES 250 Micron Poroplus Screens(4-Joints)-Bottom @ 4,359' 15 4,422' HES Collet Guide&Seal Assembly 16 4,398' 7"Otis"AWD"Sump Packer(4.0"ID) 17 4,415' 3.5"Otis X-Nipple(2.313"ID) 18 4,426' WLEG s PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status N Sands 4,260' 4,280' 3,802' 3,821' 20 2/23/1991 Open 4 N Sands 4,292' 4,304' 3,832' 3,844' 12 2/23/1991 Open lr` 5 N Sands 4,322' 4,328' 3,861' 3,867' 6 2/23/1991 Open N Sands 4,344' 4,378' 3,882' 3,915' 34 2/23/1991 Open >s OSands 4,424' 4,455' 3,959' 3,988' 31 2/23/1991 Open 5f 0 Sands 4,486' 4,510' 4,018' 4,041' 24 2/23/1991 Open ,1&8 'N'Sands Perfs:24SPF&24GM. '0'Sands Perfs:5SPF&37GM ``-1 STIMULATION DETAIL 9 Interval:4,424'to 4,510"-26,802 lbs.16/20 mesh Propant j 41, 1a GENERAL WELL INFO _ 11 API:50-029-22067-00-00 I` ,12 Drilled and Cased by Nabors 27 -11/14/1990 pg rF ESP Completion-3/7/1991 ESP RWO by Nabors 4ES-10/5/1995 tat$ _ ESP RWO by Nabors 5S-12/14/1997 ESP RWO by Nabors 4ES-7/30/2002 v 14 } RWO&Replace Screens by Nabors 4ES-5/6/2003 N Sands ESP/HT Changeout by Nabors 4ES-10/7/2006 15 ESP RWO by Nabors 3S-5/2/2009 16 Mt = ESP Changeout by Doyon 16-4/5/2013 18 E}0 Sands Straddle Pckr/ESP Changeout Nordic 3 -5/3/2015 7'a ‘. ESP Changeout by ASR#1-9/18/2016 TD=4,750(MD)/TD=4,271'(1VD) Revised By:TDF 10/5/2016 PBTD=4,659'(MD)/PBTD=4,184'(TVD) • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-03 ASR 50-029-22067-00-00 190-092 9/14/16 9/18/16 Daily Operations: lGP _ IV!IIt'I 'Illi l G 9/14/2016-Wednesday Nipple down Production Tree (AOGCC was notified of right to witness BOP test @ 16:39 PM on 9-13-2016). Accept rig at 12:00 Noon. Nipple up BOPs. Set well cover on MPI-03, Set rig floor. Spot Wellsite trailer&Office Trailer& Change house. Move rig on to Mud Boat, raise Derrick& Pin, Install Derrick anchors to Rig.Torque up BOP Flanges, connect gas alarms & test same,Spot Cat Walk Rig up and Install Accumulators Lines to Bop Stack,take on fluids @ 21:00. Bleed small amount of pressure off from below BPV, dry rod in TWC. Torque up BOP Flanges/bolts, choke & kill lines. Electrician connect gas alarms &test same, Spot Cat Walk Rig up and Install Accumulators Lines to Bop Stack.Test BOPE.Test 2-7/8"x.5"1LB2Ls_.t/ 250psi low, 2,500psi high f/5 charted mins each. (Good Test)Test Annular element t/250psi low, 1,500psi high f/5 charted mins each. (Good Test). Perform accumulator pre-charge test (Good test),AOGCC Rep Brian Bixby waived witness to BOPE test on (09/13/2016 @ 17:45). Perform Well 1-03 pre-spud/Sundry meeting w/rig crew. 9/15/2016-Thursday Hang ESP cable sheave &elephant trunk hose. Pull TWC, make up landing joint to tubing hanger, monitor back side, back out LDS, Pull Hanger to Rig Floor with 3612_Lay down Hanger& landing joint.TOOH, Laying down 2-7/8"tubing completion. total of 121 joints. Lay down ESP assembly. 10' Pup on top of discharge head was full of formation sand. Clean and clear rig floor,strap and tally 2-7/8" 6.5ppf 8rd EUE work string, strap and verify scraper cleanout BHA#1, ID, OD, and length, M/U BHA and run up t/rig floor on pipe skate. RIH w/scraper cleanout BHA f/surface t/3,998'md, lightly tag hydraulic retrievable pkr @ 3,998'md, no signs of scale or obstruction on TIH. R/U t/circulate down work string, utilizing head pin on tubing stump, circulate at 3 bpm f/4bbls prior t/catching pressure, pressure increase t/400psi before falling off t/250psi, increase pump rate t/3.5bpm and pump pressure remains constant @ 250psi,wellbore drinking fluid faster than rig is able t/pump so we are unable t/circulate the wellbore, shut down pump and blow down lines. Rig crew lunch break,tool push monitor wellbore. R/U and pull scraper cleanout BHA f/3,998'md t/3,000'md laying down 2-7/8" , having issue w/ catwalk/pipeskate alignment.Adjust catwalk/pipeskate alignment 1/smoother operation,continue t/L/D 2-7/8"work string f/3,000'md t/surface. SIMOPS, load and strap 1.66" BTS-8 TBG on catwalk/pipe rack. 9/16/2016-Friday Make up 1.6 BTS-8 mule shoe,TIH with 22 joints of BTS-8 tubing work string,TIH with 2-7/8"tubing to 4469'.Take weight at 4,469'. Set down w/5k. No progress. RU swivel to circulate. PUW 24k-SOW 18.5k. Break circulation and wash down w/ 2 bpm, 530 psi.Taking 500 to 1k down weight and washing off easily. Wash f/4,469'to 4,532' (at 40 bbls away, observed returns). Continue circulation to assess returns from wellbore. 3.75 bpm, 2,100 psi. Circulation pushing away 2bbls f/every 3bbls pumped. Decision t/stop circulation and attempt t/reverse circulate. R/U and reverse circulate, once again losing 2bbls f/every 3bbls pumped. Decision t/stop circulating. RIH t/tag fill,fill found at 4,599'md.TOOH t/desired scale inhibition depth of 4,260'md.4th joint out of hole pulled wet. Decision t/get into 7" CSG (3,998'md) prior t/attempting circulation. R/U mud bucket in prep t/TOOH t/3,998'md.TOOH f/4,509'md t/3,998'md w/Muleshoe BHA#2, R/U and attempt t/reverse circulate 15 bbls, no returns,swap circulation paths and attempt t/circulate down workstring, pressure up t/3,500psi, no success. Bleed off pressure and prep t/continue TOOH t/surface w/Muleshoe BHA#2.TOOH w/ Muleshoe BHA#2 f/3,998'md t/surface. Sand found in joint#2 of 2-7/8" workstring. 110 41, Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-03ASR 50-029-22067-00-00 190-092 9/14/16 9/18/16 Daily Operations: 9/17/2016-Saturday Continue to POH LD 1.66: work string(packed off w/sand). Clean/Clear rig floor. Swap handling equipment over to 2-7/8". PU 2-3/8" EUE Muleshoe, XO. RIH PU 125 jts. 2-7/8"tubing to 3919'. RU to pump down tubing. Pump tubing volume. Test of lines to 2,500psi. Close annular and bullhead down tubing w/56.4 bbls preflush w/7.5% WAW5206 mutual solvent followed by 47_25 bbls of squeeze fluid w/-12. %SCW4004 Scale Inhibitor. Initial pump rate/pressure=4 bpm, 675psi. Final =4 bpm, 1,000psi. Line up to rig pump. Bullhead down tubing w/389 bbls of filtered seawater, 3-1/2 bpm, 900 psi. Pumps off. Monitor tubing pressure for 15 min. Initial pressure =550 psi. Final =400 psi. Bleed pressure off slowly and monitor fluid returned to pits (34 bbls). Break circulation and pump tubing volume (28 bbls)to balance fluids ;POOH w/2- 7/8" 6.5ppf work string f/3,919'md t/surface. Clean and clear rig floor, blow down lines, pull ESP cable over sheave, n. perform PJSM w/rig crew and Baker Centerlift rep f/running ESP completioM/U Baker Centerlift ESP completion as per Baker rep and RIH. RIH w/Baker Centerlift ESP completion on 2-7/8" 6.5ppg 8rd EUE tubing as per completion tally. On joint#47, R/U and begin running heat trace line w/completion t/surface. 9/18/2016-Sunday Continue to RIH w/ ESP completion on 2-7/8" 6.5 lb L-80 EUE tubing f/±2,000'to 3,936'. PU hanger per Wellhead Rep. Make penetrations through hanger and splice per Centrilift Rep. Land hanger on seat and verify placement by 5 foot marking into the well, as well as watching for alignment pins on tubing spool to J TBG hanger into place. Wellhead Rep, RILDS and set BPV. Place adapter and tree on 1-03 wellhead. Wellhead Rep.Tree &Void to 500 psi low, 5000 psi high f/5 min. each test. Centrilift Rep. ran final checks. OK. 9/19/2016- Monday No activity to report. 9/20/2016-Tuesday No activity to report. 1111 • Aw\\ 1y7:.6. THE STATE Alaska Oil and Gas fv 4-- �� of LASKA Conservation Commission ils : 4- -_l 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 T "ti 'P Main: 907.279.1433 A ;S� Fax: 907.276.7542 www.aogcc.alaska.gov Bo Operations Manager SCOW J�t`J e I LI!, Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB I-03 Permit to Drill Number: 190-092 Sundry Number: 316-440 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, jl Cathy . Foerster Chair gf DATED this i day of September, 2016. RBDMS L L SEP - 1 2016 • • RECEIVED STATE OF ALASKA AUG 2 601 ALASKA OIL AND GAS CONSERVATION COMMISSION 07 S 1 s 1 /4, APPLICATION FOR SUNDRY APPROVALS AOG 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well 0 . Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate 0.. Pull Tubing 0 • Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: ESP Changeout 0. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ' Exploratory ❑ Development 0. 190-092 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22067-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 " Will planned perforations require a spacing exception? Yes El No 0 / MILNE PT UNIT SBI-03 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 ' Milne Point Field/Schrader Bluff Oil Pool . 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): 4,750' • 4,271' - 4,659' - 4,184' • 1,042 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 105' 13-3/8" 105' 105' 1,730psi 740psi Surface 2,633' 9-5/8" 2,633' 2,399' 3,520psi 2,020psi Production 4,741' 7" 4,741' 4,262' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic/ See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 3,979 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): DLH Hydraulic Retrievable,7"HES'VTA'Retrievable&7"'AWD'Sump • 3,998(MD)/3,047(TVD),4,191(MD)/3,667(TVD)&4,398(MD)/3,934(TVD)and N/A Packer and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development Q N Service ❑ 14.Estimated Date for 15.Well Status after proposed work: • Commencing Operations: 9/15/2016 OIL 0 ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhola 5T'15 Email sporhola(a7hilcorp.com Printed Name/" Bo York Title Operations Manager Signature '.,' Phone 777-8345 Date 8/25/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ --� �L�! Other: `2_ 00`2_ 00ry yam' LS W �fLs`>',.1{ Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: '0 — 404 RBDMS t BSEP - 1 2016 APPROVED BY Approved by: P COMMISSIONER THE COMMISSION Date:9— /_ i1.3 / ..Gf1 �1� Mme. Ili 1� ofi 1 e�N Submit Form and Form 10-403 Revised 11/2015 r I oA alid for 12 months from the date of approval. Attachmentss in Duplicate • • Well Prognosis • Well: MPU 1-03 Iiileorp Alaska,Lb Date:8/25/2016 Well Name: MPU 1-03 API Number: 50-029-22067-00 Current Status: SI Oil Well [Failed ESP] Pad: I-Pad Estimated Start Date: September 15th, 2016 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190-092 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Current Bottom Hole Pressure: 1,442 psi @ 4,000' TVDss (Last BHP measured 8/24/2016) Maximum Expected BHP: 1,442 psi @ 4,000' TVDss (No new perfs added, EMW= 6.93 ppg) MPSP: 1,042 psi (0.10 psi/ft gas gradient) Brief Well Summary: �` S �M The Milne Point 1-03 well was drilled as a Schrader Bluff development well that TD'd at 4,750' and ran and cemented 7" casing in November 1990. The well was initially completed with an ESP. This and subsequent ESPs failed and were replaced in 1995, 1997, 2002, 2003, 2006, 2009, and 2013. The most recent pump failed March 3, 2015. There most recent casing pressure test performed from 4,020' to 1,500psi indicated good casing to surface on 3/31/2015. The test at 4,054' indicated a casing leak. It is the intent of this workover to isolate this leak. No additional casing tests will be performed during this workover.There are minimal observed scale issues, most failures are related to solids production. Source of sand issues may be addressed with the isolation of the casing leak.A caliper was run on the upper 1,000' of 7" casing during the March 2015 RWO and found no issues. A RWO in May 2015 added an additional packer above the screen assembly to isolate the casing leak and ran the current ESP assembly that failed May 2016. Notes Regarding Wellbore Condition • Casing tested to 1,500 psi down to 3,998' MD (DLH Packer) on 5/01/2015.°' • A recent test of solids recovered from this well identified calcium carbonate scale. 4- CD -310A" A Pa-Y-Ev- S t o CZ—CQ . • . t` 1 Objective: Pull failed ESP (failed May 2016), cleanout the screen assembly, pump scale inhibitor 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. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea 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 and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD Crane. • • Well Prognosis • Well: MPU 1-03 Ili'corp Alaska,LLi Date:8/25/2016 9. NU BOPE house. Spot mud boat. 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/8.5 ppg sea 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 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8"test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg sea 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 2-7/8"tubing. Tubing may be re-used. Replace bad joints as necessary. 17. Lay down failed ESP. Collect samples of any solids and test for scale. 18. RIH with 7" 26#scraper assembly to -3,998' MD (packer top) on 2-7/8" tubing. Circulate the well clean. 19. If needed, spot sized salt pill to control losses. POOH and LD tubing. 20. MU 1.660" muleshoe -or-2-1/4" mill, 1-11/16" motor,jars and RIH 22 jts of 1.660" 3.02# BTS-8 small tubing. 21. MU crossover from 1.660" BTS-8 x 2-7/8" EUE tubing. INE • • Well Prognosis • Well: MPU 1-03 Hileorp Alaska,Lb Date:8/25/2016 22. RIH to ^'4,659' MD on 2-7/8"tubing. Circulate the well clean (cleanout inside of 3-1/2" screens). a. Min ID is 2.970" at seal assembly(4,422'). b. Min ID is 2.992" thru screens (3 blank,4 screen jts). c. Min ID is 3.880" above screens (7" VTA Packer ID). 23. If needed, spot sized salt pill to control losses. 24. PU to—4,260' MD. Mix and pump 52.5 bbl of pre-flush (7.5% mutual solvent WAW5206),42.0 bbl of squeeze (12.5%scale inhibitor SCW4004), and 380 bbl of displacment water. POOH and LD tubing (Scale Inhibitor Treatment]. 25. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP at±3,950' MD. 26. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 27. Set BPV. 28. Rig down ASR#1. Post-Rig Procedure: 29. RD mud boat. RD BOPE house. Move to next well location. 30. RU crane. ND BOPE. 31. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 32. RD crane. Move 500 bbl returns tank and rig mats to next well location. 33. Replace gauge(s) if removed. 34. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. FWD Circ to Kill Tank Flow Diagram 6. REV Circ to Kill Tank Flow Diagram 7. Bleed to Pits Flow Diagram 8. Blank RWO MOC Form . • • Milne Point Unit II Well: MP 1-03 SCHEMATIC Last Completed: 5/3/2015 Hamra Alaska,LLC PTD: 190-092 TREE&WELLHEAD OPEN HOLE/CEMENT DETAIL Tree WKM 2-9/16"5M 13-3/8" 485sx Permafrost"C" Wellhead WKM 11" 5M w/2-7/8"8rd Tree Top 9-5/8" 247sx of Class"E",942 sx of Class"G"in a 12.25"Hole Connection 2-1/2""H"Profile 7" 307sx of 15.8 ppg Class"G"a 8.5"Hole Orig.KB Elev.:70.0'/Orig.GL Elev.:35.0' CASING DETAIL RKB-Hanger:35.0'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm BPF Al 1 13-3/8" Conductor 54.5/K-55/N/A 12.459 Surface 105' 0.1545 9-5/8" Surface 36/K-55/Btrc. 8.765 Surface 2,633' 0.0773 13-3/8" 7" Production 26/L-80/Btrc 6.151 Surface 4,741' 0.0382 t TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 2.347 Surf 3,979' 0.00579 WELL INCLINATION DETAIL KOP@500' Max Hole Angle=37 deg.@ 3,170' 9-5/8" A lk" JEWELRY DETAIL Squeeze Perfs: 2,060'to 2,062' No Depth Item 1 119' ST 2:2-7/8"GLM 2.875"x 1"KBMM GLM(BK-Orifice Valve Set 5/03/15) 2 3,749' ST 1:2-7/8"GLM 2.875"x 1"KBMM GLM(BK-Dummy Valve Set 5/31/16) 3 3,890' 2-7/8"XN Profile(2.205"No-Go Packing Bore ID) 4 3,901' Discharge Head Heat Trace from 4 3,902' Centrilift ESP:P4 surface to 2,500' 5 3,915' Gas Separator 6 3,920' Tandem Seal Section 7 3,933' ESP Motors(60 HP each) 8 3,942' Centralizer w/XT-150 Phoenix Sensor-Bottom @ 3,946' 9 3,998' DLH Hydraulic Retrievable Packer 10 4,006' Top of 3-1/2"Blank Pipe,Seal Assembly 11 4,191' 7"HES"VTA"Retrievable Packer 12 4,234' 3.5"HES 250 Micron Poroplus Screens(4-Joints)-Bottom @ 4,359' 2 13 4,422' HES Collet Guide&Seal Assembly 14 4,398' 7"Otis"AWD"Sump Packer(4.0"ID) 15 4,415' 3.5"Otis X-Nipple(2.313"ID) 16 4,426' WLEG PERFORATION DETAIL r ,3 " Kuparuk Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status N Sands 4,260' 4,280' 3,802' 3,821' 20 2/23/1991 Open I 1 N Sands 4,292' 4,304' 3,832' 3,844' 12 2/23/1991 Open N Sands 4,322' 4,328' 3,861' 3,867' 6 2/23/1991 Open N Sands 4,344' 4,378' 3,882' 3,915' 34 2/23/1991 Open 0 Sands 4,424' 4,455' 3,959' 3,988' 31 2/23/1991 Open ' :11: '5 0 Sands 4,486' 4,510' 4,018' 4,041' 24 2/23/1991 Open 6 'N'Sands Perfs:24SPF&24GM. '0'Sands Perfs:5SPF&37GM a STIMULATION DETAIL a_~ 7 Interval:4,424'to 4,510"-26,802 lbs.16/20 mesh Propant n, 8 GENERAL WELL INFO 9 API:50-029-22067-00-00 ,10 Drilled and Cased by Nabors 27 -11/14/1990 ESP Completion-3/7/1991 ESP RWO by Nabors 4ES-10/5/1995 ESP RWO by Nabors 5S-12/14/1997 11.. r _ ESP RWO by Nabors 4ES-7/30/2002 12% N Sands RWO&Replace Screens by Nabors 4ES-5/6/2003 ESP/HT Changeout by Nabors 4ES-10/7/2006 13 ,. ,p ESP RWO by Nabors 3S-5/2/2009 14 15' ;''7-I1 ESP Changeout by Doyon 16-4/5/2013 16 }O Sands Straddle Pckr/ESP Changeout Nordic 3 -5/3/2015 7"a y Created By:STP 6/07/2016 TD=4,750(MD)/TD=4,271'(1VD) PBTD=4,659'(MD)/PBTD=4,184'(1VD) • Well:Milne Point Unit PROPOSED Last Completed: Proposed uiicorrr kl:�4a.l,1A: PTD: 190-092MP1-03 TREE&WELLHEAD OPEN HOLE/CEMENT DETAIL Tree WKM 2-9/16"5M 13-3/8" 485sx Permafrost"C" Wellhead WKM 11" 5M w/2-7/8"8rd Tree Top 9-5/8" 247sx of Class"E",942 sx of Class"G"in a 12.25"Hole Connection 2-1/2""H"Profile 7" 307sx of 15.8 ppg Class"G"a 8.5"Hole Orig.KB Elev.:70.0'/Orig.GL Elev.:35.0' CASING D ETAI L RKB-Hanger:35.0'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm BPF L13-3/8" Conductor 54.5/K-55/N/A 12.459 Surface 105' 0.1545 9-5/8" Surface 36/K-55/Btrc. 8.765 Surface 2,633' 0.0773 13-3/8" 7" Production 26/L-80/Btrc 6.151 Surface 4,741' 0.0382 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 2.347 Surf 3,950' 0.00579 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle=37 deg.@ 3,170' 9-5/8" "a e JEWELRY DETAIL Squeeze Perfs: 2,060'to2,062' No Depth Item 1 120' ST 2:2-7/8"GLM 2.875"x 1"KBMM GLM(BK-Orifice Valve Set Planned) 2 3,750' ST 1:2-7/8"GLM 2.875"x 1"KBMM GLM(BK-Dummy Valve Set Planned) 3 3,890' 2-7/8"XN Profile(2.205"No-Go Packing Bore ID) 4 3,901' Discharge Head Heat Trace from 4 3,902' Centrilift ESP:P4 or FLEX10 suface to 2,E00' 5 3,915' Gas Separator 6 3,920' Tandem Seal Section 7 3,933' ESP Motors(60 HP each) 8 3,949' Centralizer w/XT-150 Phoenix Sensor-Bottom @ 3,950' 9 3,998' DLH Hydraulic Retrievable Packer 10 4,006' Top of 3-1/2"Blank Pipe,Seal Assembly 11 4,191' 7"HES"VIA"Retrievable Packer 12 4,234' 3.5"HES 250 Micron Poroplus Screens(4-Joints)-Bottom @ 4,359' : 2 13 4,422' HES Collet Guide&Seal Assembly 14 4,398' 7"Otis"AWD"Sump Packer(4.0"ID) 15 4,415' 3.5"Otis X-Nipple(2.313"ID) 16 4,426' WLEG PERFORATION DETAIL 3 t`4Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status p a N Sands 4,260' 4,280' 3,802' 3,821' 20 2/23/1991 Open N Sands 4,292' 4,304' 3,832' 3,844' 12 2/23/1991 Open N Sands 4,322' 4,328' 3,861' 3,867' 6 2/23/1991 Open N Sands 4,344' 4,378' 3,882' 3,915' 34 2/23/1991 Open 0 Sands 4,424' 4,455' 3,959' 3,988' 31 2/23/1991 Open jj Ii ''5 OSands 4,486' 4,510' 4,018' 4,041' 24 2/23/1991 Open 6 'N'Sands Perfs:24SPF&24GM. '0'Sands Perfs:5SPF&37GM 4L a STIMULATION DETAIL 7 Interval:4,424'to 4,510"-26,802 lbs.16/20 mesh Propant J VIII 8 GENERAL WELL INFO 9 API:50-029-22067-00-00 LSA ,10 Drilled and Cased by Nabors 27 -11/14/1990 ESP Completion-3/7/1991 ESP RWO by Nabors 4ES-10/5/1995 ESP RWO by Nabors 5S-12/14/1997 11:10RIgAft ESP RWO by Nabors 4ES-7/30/2002 RWO&Replace Screens by Nabors 4ES-5/6/2003 12 - = N Sands ) liill ESP/HT Changeout by Nabors 4ES-10/7/2006 13 L ESP RWO by Nabors 3S-5/2/2009 14 15 ' ESP Changeout by Doyon 16-4/5/2013 16 =}OSands Straddle Pckr/ESP Changeout Nordic 3 -5/3/2015 7 11, Downhole Revised:Proposed Created By:STP 8/24/2016 TD=4,750(MD)/TD=4,271'(1VD) PBTD=4,659'(MD)/PBTD=4,184'(TVD) • • Milne Point ASR Rig 1 BOPE 1lik*"1' "444.1.11' 11" BOPE Stripping Head ( 1 3.98' ' - / 3 Shafer iio_lit iiiiiiltiiii111 i_ If r ,--tiI C C ► -V 1 r4 N 4.54' G,.. + VBR or Pipe Rams N--n H / 11"-5000 —Fd Blind \ \ `_11 ii rn Tilt 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves en . �11� y Q200 1 'II( 'I 's I41 , :�c ° • r 1 IC il■iii■liillii.lil'! 1 1 CI 1 Manual Manual __ Manual HCR Updated 8/19/2015 . 1i • • MPU 1-03 EXISTING TREE/WELLHEAD Wellhead/Tree Milne Point Unit Hilcorp Alaska,LLC Iffe a.1 In any $ ' Lcu - 2 9/16" CIW 5M Swab Valve III.. 121 w . ,, iii ,. art 2 9/16" CIW 5M Wing Valve O ,€ 2 9/16" CIW 5M SSV with Baker actuator " !' - ,(S_� - 2 9/16" CIW 5M Master Valve o ' 0 'so ONO ir1 . 11"x 2 9/16" CIW 5M I ' "1 ESP Tbg Adapter 11" x11"FMC 5MEd , Tubing Head ,IF•i -- EEL-- 1 11111111 1 i-.' ! 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Y Z . �� 6) IT) biJ m Y 0 61 0 0V• QQQQ `� = (..1 V m a u 1f yT 00m 0 a m IIt NQ 83 Ln u I T 0 0 R C C_ 0 N . a _e 0 L L\ u z ,,, O o K = ,, W = u Q N a S.^ x o m �'••4. a — m t, " ] t: u v — I < ,uignl < I0 � II=I II ='I ,. ., n \� a IV m! Y.,' . C 1 V1 'fir' Ci H a N T8 o 0 Z F 7 U C m m O cnfl< H I K H H 7 Y m O Y V A Z -004 2 yy Qx9N Y .14 .04 M kn Y C7 a ~ z = a z a a o 2 —XI— H I- O. 7 E u 01 01 a 1SYl 3 u T 7 0 . • • ca L{L U > C C'D j7 H a xc. m a .41 ® g Z�p m I N R 2S .077, o OTS 9TH a ❑ m U a N00 J L a ca o z 2 V V a+ w ', u , O N z W ZD in 6) TT) VD 7 VI U M � w �Y V U m n V . CO G CO O CO ul a In cm BJN8 V C J N u C ' J @ N O. Y O L U 0 o w K W j i Uc.°)"' i 0 R pt =o 0 m a-00:1-1 8uignl liii I ` 1 111 ^ Ia O ® Y ry m , a a Lea =, I+' Y r .C+ V O 8 ix uGV mO Qt`Q< HI H �7 Y mO v1 1 FOY$ . Z�y�� 2 Y$ 9Npp —I I- G 1 1Y I H O a 1— R ? a —I H za H O ti1__ 2 —i-s-i- H I- 0. C V u N K V H • 0 = a) s.' d > ca a) v0 oar U (7, c U c0 Qaa.0.a o . U) C CD Ts U) 1Cm = >, E Q , L ^-, W C L DQ v O• L 2 a) O' 0 L O- 0- a A as m 0) r o & caa cnc a.) ca m.0 C U (B N L p UE L a) 0 Q V -0 o_ p c > c� a) 2 = ' Q P. co Q L L a • 3 0 C) d a, 0 3 00 d CO y CO a) L ,o Q O pL. Ear 0- a) U C 0 -0 6) .i O a)_CI L al 3 C Uco C d }� = i- n5 C .- 7 E) -a U 0 W 0 U) G1 > L O O a Q °' CO m O. L C� L O Q (a > �+ 0 m N oo co . C L o p . V1 N U) fa O Eco _ XO 06 ^r '—' 03 C K c L a) �, 'd Qi a) CC K O O a) U) L c � y Q U o• > CO ii Q it O F a oU Z a) E 2 as „cm Q V o in in Q � Q 2 STATE OF ALASKA ALA KA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations LI Fracture Stimulate U Pull TubingU U 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 Change-out ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 190-092 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22067-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 . MILNE PT UNIT SBI-03 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Schrader Bluff Oil Pool • 11.Present Well Condition Summary: Total Depth measured 4,750 • feet Plugs measured N/A flit E C E I VED true vertical 4,271 . feet Junk measured N/A feet 3,998,4,191 & SEP 2 5 2015 Effective Depth measured 4,659 feet Packer measured 4,398 feet 3,552,3,667& AOGCC true vertical 4,184 feet true vertical 3,943 feet Casing Length Size MD TVD Burst Collapse Conductor 105' 13-3/8" 105' 105' 1,730psi 740psi Surface 2,633' 9-5/8" 2,633' 2,399' 3,520psi 2,020psi Production 4,741' 7" 4,741' 4,262' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic feet WO True Vertical depth See Attached Schematic feet 30 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 3,981' 3,536' 7"DLH Hyd.Ret. 3,998/3,552 7"HES VTA Ret. 4,191/3,667 Packers and SSSV(type,measured and true vertical depth) 7"Otis AWD Sump N/A 4,398/3,943 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 0 0 Subsequent to operation: 151 15 15 240 198 14.Attachments(required per 20 AAC 25 070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development - Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL 1 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ ' SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-233 Contact Stan Porhola Email sporhola(C hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature '��,„'� Phone 777-8412 Date 9/25/2015 74_A4-1/14,-"t..---- /0-1171—/S—' Form 10-404 Revised 5/2015 ,0 (6% (�RBDMS SEP 2 9 2015 Submit Original Only • • • Milne Point Unit Well: MP 1-03 SCHEMATIC Last Completed: 5/3/2013 Hileorp Alaska,LLC PTD: 190-092 CASING DETAIL Orig.KB Elev.:37' Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 54.5/K-55/N/A 12.615 Surface 105' "cl ,�vr 5 { L- 7" 9-5/8" Surface 36/K-55/Btrc. 8.921 Surface 2,633' V Production 26/L-80/Btrc 6.276 Surface 4,741' 133/8 4 '1TUBING DETAIL +�F 2-7/8" Tubing 6.5/L-80/EUE 2.441 Surf 3,981' • ;'41-rr JEWELRY DETAIL ;moi: No Depth Item • 1 1 121' GLM • 2 3,784' GLM 95/8"' \ is 3 3,924' XN-Nipple (2.25"No-go ID) ePars: 4 3,937' Pump 2,060'to 2,062 5 3,949' Gas Separator 6 3,954' Tandem Seal Section 7 3,968' Motor 8 3,976' Centralizer w/Phoenix Sensor-Bottom @ 3,981' 9 3,998' DLH Hydraulic Retrievable Packer Heat Trace from 10 4,006' Top of 3-1/2"Blank Pipe,Seal Assembly surface to 2,500 11 4,191' 7"HES"VTA"Retrievable Packer 12 4,234' 3.5"HES 250 Micron Poroplus Screens(4-Joints)-Bottom @ 4,359' 13 4,422' HES Collet Guide&Seal Assembly 14 4,398' 7"Otis"AWD"Sump Packer(4.0"ID) 15 4,415' 3.5"Otis X-Nipple(2.313"ID) 16 4,426' WLEG PERFORATION DETAIL 2 Kuparuk Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status Sands 4,260' 4,280' 3,802' 3,821' 20 2/23/1991 Open N Sands 4,292' 4,304' 3,832' 3,844' 12 2/23/1991 Open N Sands 4,322' 4,328' 3,861' 3,867' 6 2/23/1991 Open c, N Sands 4,344' 4,378' 3,882' 3,915' 34 2/23/1991 Open 44 kilr IN 3 0 Sands 4,424' 4,455' 3,959' 3,988' 31 2/23/1991 Open r1 ‘ 0 Sands 4,486' 4,510' 4,018' 4,041' 24 2/23/1991 Open a 'N'Sands Perfs:24SPF&24GM. '0'Sands Perfs:SSPF&37GM OPEN HOLE/CEMENT DETAIL 13-3/8" 485sx Permafrost"C" 'e 4 9-5/r 247sx of Class"E",942 sx of Class"G"in a 12.25"Hole 7" 307sx of 15.8 ppg Class"G"a 8.5"Hole ei lli 15 o) milt1 ass. ,`,s WELL INCLINATION DETAIL KOP@500' Max Hole Angle=37 deg.@ 3,170' S 'N 7 TREE&WELLHEAD -- Tree WKM 2-9/16"5M z 8 "' WKM 11" 5M w/2-7/8"8rd Tree Top P Wellhead 49 Connection 2-1/2""H"Profile 1 STIMULATION DETAIL A Interval:4,424'to 4,510"-26,802 '� lbs.16/20 mesh Propant 11 L _ GENERAL WELL INFO 12 ,,NSards API:50-029-22067-00-00 Drilled and Cased by Nabors 27 -11/14/1990 13 , , ESP Completion-3/7/1991 140' 111,15 - ;z ESP RWO by Nabors 4ES-10/5/1995 7 1,,,y 16 i l 0 SandsESP RWO by Nabors 5S-12/14/1997 • ESP RWO by Nabors 4ES-7/30/2002 TD=4,750(MD)/TD=4,271'(TVD) RWO&Replace Screens by Nabors 4ES-5/6/2003 PBTD=4,659'(MD)/PBTD=4,184'(TVD) ESP/HT Changeout by Nabors 4ES-10/7/2006 ESP RWO by Nabors 3S-5/2/2009 ESP Changeout by Doyon 16-4/5/2013 Created By:TDF 9/24/2015 Straddle Pckr/ESP Changeout Nordic 3 -5/3/2015 ! I Hilcorp Alaska, LLC „ii,.orp ,,:,ska.LL( Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP 1-03 50-029-22067-00-00 190-092 4/30/2015 5/3/2015 Daily Operations: 4/29/15-Wednesday No operations to report. 4/30/15-Thursday MOB from J-09 MIRU accept rig.Spot tanks, berm cellar,set camp, offload SW 8.5#140°, pull BPV, hammer up hard linew to kill tank. PT all lines 250/2,500psi.Tubing on light vac. Pump 200bbl 8.5#SW down annulus 88 bbls returned.Set BPV. 5/1/15-Friday ND tree NU BOP Pull BPV Install TWC.Test BOPs,greasing and cycling all systems. Post N2 job,valve maintenace .,performed.Test 250/3,000psi BOPE, 250/2,500psi Annular,Accumulator drawdown performed all good. Rig Code 8 time 1.5 hours. Remove TWC Install landing jt. POOH LD tbg hanger. PJSM POOH from 4,054'and Strap 2-7/8 tbg LD joint 88 Galled threads c/o collar on jt 89. PU MU Straddle Assy consisteing of seal assy with no go, 1 ea 8'3.5"9,2#pup, 16' pup, w/jts 3.5"9.2#L-80 EUE tbg, 1 XN nipple preloaded with RA plug 1 jt tbg, 1 DLH hydraulic retrievable packer, 12' PJ and 1 T2 On off tool.Total BHA length 186'. RIH with pipe from derrick 2-7/8" L-80 EUE 128 jts and tag up on GP packer @ 4,177.5' (3' high)verify tally and jt count. Locate and check seal aseembly 3 times drop in of 3.54'to no go verified with pump pressure and weight. Dro_p_bar to closeRA_plg. Pressure up to 3,500psi after seeing packer shear @ 1,250psi. Set packer an wait 30 minutes. Bleed off,test annulus to 1,500psi all good. Release off packer and LD top single,well is flowing,Stab TIW monitor well 15 minutes still flowing. Reverse circulate almost immediate gassy crude to surface circ 1 tbg volume still crude and gassy. Continue circulation to kill tank still intermiitent strong stringers gassy clean crude.SI / well and monitor pressue SITP 50psi SICP 60psi.Order 9.2#brine not enough fluid on location to displace oil and kill (friili+� well.;Recover 138 bbls oil NO losses Monitor well order 9.2#brine. 6 5/2/15-Saturday Monitor well, has gone static rod is assummed to be back in plug.Off-load 250 bbls 9.3#heavy fluid. Water back fluid to 9.2 ppg brine and displace hole to kill tank. Blow down all line prepare to trip.TOOH with 2-7/8"tbg Hole static. Rig up Dutch Riser and Halliburton S/I pressure test Lubricator and riser to 500psi. RIH and retrieve bar well on slight vacuum. RIH retrieve plug two attempts before retrieval heavy oil fluid level appears to be about 3,700'. Fill Hole with 26 bbls 9.2+ NaCI. Puts fluid level @ 678'. Est BHP 1,600psi.Slip n'Cut drilling line. PU MU ESP assy&sercive same. Install lower ESP connector and Test cable. RIH with 14 stands and a double MU bottom of heat trace,test Cables all OK. RIH w/2-7/8" EUE L-80 tbg ESP and heat trace to"2,200' 5/3/15-Sunday Continue running ESP and Heat Trace completion on 2-7/8" EUE L-80 6.5#tbg. RIH and tag straddle packer @ 3,998' PU LD 2 singles Install hanger w 10' pup.Clamps used 391 ea 5'dual channel,4 protectolizers, 27 cross collar, 77 dual channel cross collar, 2 pump clamps 2 flat guards, 2 bands. Splice and Meg check ESP and Heat Trace Cables Land tubing, LD landing jt Install BPV. Depths Hanger w 10' pup, 2 jts tbg pup,GLM @121', pup, 116 jts tbg, pup GLM @ 3,784', pup,4 jts tbg,XN @ 3,924', head @ 3,936' pump @ 3,937',gas separator @ 3,949', U Tseal @ 3,954', Motor @ 3,968', Pump mate @ 3,976' EOT @ 3,981'. Run in lock down screws. ND BOPE. NU tree.Test all breaks and void 250/5,000psi. RDMO BPV is still in well. 5/4/15-Monday No operations to report. 5/5/15-Tuesday No operations to report. I-- .t, OF To,• �\ 7 THE STATE Alaska Oil and Gas �'4i °'ALASKA Conservation Commission ,=i:#114,-,--_ -_-*_-_-,--_:- =- — 333 West Seventh Avenue '" *h„ 1 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALA6Y'� Fax: 907.276 7542 www.aogcc.alaska.gav Chris Kanyer SCA" � APR 2 7 201a. Operations Engineer ' 09 Hilcorp Alaska, LLC " I O 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB I-03 Sundry Number: 315-233 Dear Mr. Kanyer: 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/ /.4(.„.4) (4..... ..._ Cathy P 7 oerster Chair DATED this day of April, 2015 Encl. 3-`a-l�1�� RECEIVED STATE OF ALASKA (54— OW APR 2 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request. Abandon 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 9 .,,3- Change Approved Program 0 Suspend 9 . Plug Perforations 9 Perforate 9 Pull Tubing 9 . . Time Extension ❑ Operations Shutdown 9 Re-enter Susp.Well 9 Stimulate 9 Alter Casing 9 Other: ESP Changeout 9. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ' Exploratory 9 Development 9 • 190-092 • 3.Address: Stratigraphic 9 Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22067-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477 Will planned perforations require a spacing exception? Yes 9 No 2/ MILNE PT UNIT SB 1-03 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 . Milne Point Field/Schrader Bluff Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 4,750 _ 4,271 - 4,659 - 4,184 ' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 105' 13-3/8" 105' 105' 1,730psi 740psi Surface 2,633' 9-5/8" 2,633' 2,399' 3,520psi 2,020psi Intermediate Production 4,741' 7" 4,741' 4,262' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic I See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 4,054' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 7"HES'VTA'Retrievable&7"'AWD'Sump Packer and N/A - 4,191(MD)/3,667(TVD)&4,398(MD)/3,934(TVD)and N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program 9 BOP Sketch ❑✓ Exploratory 9 Stratigraphic 9 Development 0 Service 9 14.Estimated Date for 15.Well Status after proposed work: ' Commencing Operations: 4/30/2015 Oil ❑., Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 9 Commission Representative: GSTOR 0 SPLUG El 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyer@hilcorp.com Printed Name Chris Chris Kanyer Title Aerations Engineer Signature am Phone 777-8377 Date 4/20/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31,5-233 Plug Integrity ❑ BOP Test 127 Mechanical Integrity Test 9 Location ct ,--., 6 Clearance� 9 1 111 Other: .L 3000 Ps-" g c)r al7,70--- �0--- rAM JP / Spacing Exception Required? Yes 0 No (JQ Subsequent Form Required: 1 (.. —1404 APPROVEDMM SY 1-- .3 f/S Approved by: Y i/ COMMISSIONER THE COMMISSION Date: l� u 4K6 112.2.1kS 4� -[•�/J OR4G444nAt. ��; Submit Form and Form 10-403 -� ised 10/2012) for 12 months from the date of approval. Attachments n Du licate RRDMS�\ APR 2 4 2015 Well Prognosis Well: MPI-03 Ililcoru Alaska,Lb Date:4/20/2015 Well Name: MPI-03 API Number: 50-029-22067-00-00 Current Status: SI Producer Pad: I Pad Estimated Start Date: April 30, 2015 Rig: Nordic 3 Reg.Approval Req'd? April 29, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190-092 First Call Engineer: Chris Kanyer (907)777-8377 (0) (907) 250-0374 (M) Second Call Engineer: Bo York (907)777-8345 (0) (907)727-9247 (M) AFE Number: 1550807 Current Bottom Hole Pressure: — 1,247 psi @ 4,000' TVD (Last BHP measured 3/16/2015) Maximum Expected BHP: — 1,247 psi @ 4,000' ND (No new perfs being added) Max.Allowable Surface Pressure: 0 psi (Based on actual reservoir conditions and water cut of 8% (0.339psi/ft)with an added safety factor of 1000'TVD of oil cap) Brief Well Summary: H. itl Sl2 C A o/c The Milne Point 1-15 well was drilled as a Schrader Bluff development well that TD'd at 4,750' and ran and cemented 7" casing in November 1990. The well was initially completed with an ESP.This and subsequent ESPs failed and were replaced in 1995, 1997, 2002, 2003, 2006, 2009, and 2013.The most recent pump failed March 3, 2015. There most recent casing pressure test performed from 4,020' to 1,500psi indicated good casing to surface on 3/31/2015. The test at 4,054) indicated a casing leak. It is the intent of this workover to isolate this leak. No additional casing tests will be performed during this workover. There are minimal observed scale issues, most failures are related to solids production. Source of sand issues may be addressed with the isolation of the casing leak. A caliper was run on the upper 1,000' of 7" casing during the March 2015 RWO and found no issues. No subsidence issues expected. Notes Regarding Wellbore Condition Current well status is shut in oil producer. Possible subsidence issues suspected. " RWO Objective: Pull ESP, run casing caliper, perform cleanout,test casing, & run 2-7/8" ESP completion. V Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Attempt to circulate well with 8.5ppg seawater and monitor well. 3. ND tree, NU 11" BOPE and test to 250psi low/3,099psi high, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 4. 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.) Well Prognosis Well: MPI-03 Ililcorp Alaska,LL Date:4/20/2015 a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 5. Unseat hanger and pull 2-7/8" kill string from 4,054'to surface and lay down same. 6. RIH with straddle assembly(3-1/2", seal assembly,tubing, & retrievable packer), locate into the upper gravel pack packer at 4,191', set upper retrievable straddle packer at+/-4,000'. POOH with setting tool. 7. MU and RIH with ESP with gas separator on 2-7/8" 8RD EUE L-80 tubing [to be replaced if necessary]. Set ESP at+/-3,980'. Land tubing hanger. 8. ND BOP, NU and tree. 9. RDMO workover rig and equipment. 10. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit . ti Well: MP 1-03 • SCHEMATIC Last Completed: 4/5/2013 Illilcora Alaska,LLC PTD: 190-092 CASING DETAIL Orig.KB Elev.:37' Size Type Wt/Grade/Conn ID Top Btm 1 t, o: , �,;i 13-3/8" Conductor 54.5/K-55/N/A . 12.615 Surface 105' r;I + 9-5/8" Surface 36/K-55/Btrc. 8.921 Surface 2,633' X3/8" " 7" Production 26/L-80/Btrc 6.276 Surface 4,741' Fa '' TUBING DETAIL fti 4. 2-7/8" Tubing 6.5/L-80/Btrc 2.441 Surf 4,054' N .•, N, ` JEWELRY DETAIL i 'k : l _/441... No Depth Item 1 4,191' 7"HES"VTA"Retrievable Packer X s 2 4,234' 3.5"HES 250 Micron Poroplus Screens(4-Joints)-Bottom @ 4,359' 9-5/8"` 3 4,422' HES Collet Guide&Seal Assembly Squeeze Perfs: 2,060'to 2,067 4 4,398' 7"Otis"AWD"Sump Packer(4.0"ID) 5 4,415' 3.5"Otis X-Nipple(2.313"ID) 6 4,426' WLEG PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status N Sands 4,260' 4,280' 3,802' 3,821' 20 2/23/1991 Open N Sands 4,292' 4,304' 3,832' 3,844' 12 2/23/1991 _ Open N Sands 4,322' 4,328' 3,861' 3,867' 6 2/23/1991 Open N Sands 4,344' 4,378' 3,882' 3,915' 34 2/23/1991 Open O Sands 4,424' 4,455' 3,959' 3,988' 31 2/23/1991 Open O Sands 4,486' 4,510' 4,018' 4,041' 24 2/23/1991 Open 'N'Sands Perfs:24SPF&24GM. '0'Sands Perfs:SSPF&37GM OPEN HOLE/CEMENT DETAIL 13-3/8" 485sx Permafrost"C" 9-5/8" 247sx of Class"E",942 sx of Class"G"in a 12.25"Hole 7" 307sx of 15.8 ppg Class"G"a 8.5"Hole i I; WELL INCLINATION DETAIL K; KOP @ 500' Max Hole Angle=37 deg.@ 3,170' A TREE&WELLHEAD Tree _ WKM 2-9/16"5M II 3 Wellhead WKM 11" 5M w/2-7/8"8rd Tree Top i, Connection 2-1/2""H"Profile w STIMULATION DETAIL I" I, Interval:4,424'to 4,510"-26,802 r, lbs.16/20 mesh Propant GENERAL WELL INFO API:50-029-22067-00-00 NOTE:Casing Drilled and Cased by Nabors 27 -11/14/1990 V ‘ leak somewhereESP Completion-3/7/1991 't, , between 4,020' ESP RWO by Nabors 4ES-10/5/1995 to Gravel Packer ESP RWO by Nabors 55-12/14/1997 1 @4,191' ESP RWO by Nabors 4ES-7/30/2002 I,' r RWO&Replace Screens by Nabors 4ES-5/6/2003 T ESP/HT Changeout by Nabors 4ES-10/7/2006 1 1 ESP RWO by Nabors 3S-5/2/2009 a ESP Changeout by Doyon 16-4/5/2013 2 N Sands 3 i 4r - i''•' '7 I 0 Sands • 7' 6 Al TD=4,750(MD)/TD=4,271'(TVD) PBTD=4,659'(ND)/PBTD=4,184'(TVD) Created By:TDF 4/20/2015 Milne Point Unit Well: MP 1-03 • PROPOSED Last Copleted: 4/5/2013 Ililcorp Alaska,LLC PTD: 190-0m92 CASING DETAIL Orig.KB Elev.:37 Size Type Wt/Grade/Conn ID Top Btm �,y� a 13-3/8" Conductor 54.5/K-55/N/A 12.615 Surface 105' 4 i '.k`r:A d 9-5/8" Surface 36/K-55/Btrc. 8.921 Surface 2,633' `' * 7" Production 26/L-80/Btrc 6.276 Surface 4,741' ]33/8" I TUBING DETAIL a,s 1 - �t. 2-7/8" Tubing 6.5/L-80/Btrc 2.441 Surf ±3,980' >, , ,✓. JEWELRY DETAIL 1 '•.$.fix No Depth Item 1 ±135' GLM k R\ l 2 ±3,756' GLM 9-5/8"`' \ N 3 ±3,898' XN-Nipple (2.25"No-go ID) squeezeF�fs: 4 ±3,940' Pump 2,060 to 2,C62 5 ±3,956' Gas Separator 6 ±3,961' Tandem Seal Section 7 ±3,975' Motor 8 ±3,978' Centralizer w/Phoenix Sensor-Bottom @v 9 ±4,000' Packer 10 ±4,000' Top of 2-7/8"Blank Pipe 11 4,191' 7"HES"VTA"Retrievable Packer 12 4,234' 3.5"HES 250 Micron Poroplus Screens(4-Joints)-Bottom @ 4,359' 13 4,422' HES Collet Guide&Seal Assembly 14 4,398' 7"Otis"AWD"Sump Packer(4.0"ID) 15 4,415' 3.5"Otis X-Nipple(2.313"ID) 16 4,426' WLEG PERFORATION DETAIL 2 Kuparuk Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status N Sands 4,260' 4,280' 3,802' 3,821' 20 2/23/1991 Open N Sands 4,292' _ 4,304' 3,832' 3,844' 12 _ 2/23/1991 Open N Sands 4,322' 4,328' 3,861' 3,867' 6 2/23/1991 Open ; I A N Sands 4,344' 4,378' 3,882' 3,915' 34 2/23/1991 Open 0 Sands 4,424' 4,455' 3,959' 3,988' 31 2/23/1991 Open 3 t* 0 Sands 4,486' 4,510' 4,018' 4,041' 24 2/23/1991 Open 'N'Sands Perfs:24SPF&24GM. '0'Sands Perfs:5SPF&37GM OPEN HOLE/CEMENT DETAIL c, 7 13-3/8" 485sx Permafrost"C" } 4 9-5/8" _ 247sx of Class"E",942 sx of Class"G"in a 12.25"Hole 7" 307sx of 15.8 ppg Class"G"a 8.5"Hole 5 I,6 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle=37 deg.@ 3,170' 7 • + .'�'l."► TREE&WELLHEAD Ai, /45" Tree WKM 2-9/16"SM 8 sf`'° Wellhead WKM 11" 5M w/2-7/8"8rd Tree Top ' 9Connection 2-1/2""H"Profile t0STIMULATION DETAIL Interval:4,424'to 4,510"-26,802 L 'iL, lbs.16/20 mesh Propant 11 Iii GENERAL WELL INFO 1 NSands API:50-029-22067-00-00 1 Drilled and Cased by Nabors 27 -11/14/1990 13, ,- ESP Completion-3/7/1991 14r "5a 111' ' - ESP RWO by Nabors 4ES-10/5/1995 16 DSands ESP RWO by Nabors 55-12/14/1997 ESP RWO by Nabors 4ES-7/30/2002 TD=4,750(MD)/TD=4,271'(TVD) RWO&Replace Screens by Nabors 4ES-5/6/2003 PBTD=4,659'(MD)/PBTD=4,184'(TVD) ESP/HT Changeout by Nabors 4ES-10/7/2006 ESP RWO by Nabors 3S-5/2/2009 ESP Changeout by Doyon 16-4/5/2013 Created By:TDF 4/20/2015 11" BOP Stack � O Or iiiii Hydril 11" 5M , iiiii 1 - OD L co 2 3/8" Rams Shafferj ,004 11" 5M 2 7/8-5.5 0121) variables — Hydril — MO 11" 5M O Blinds 7 Optional valve port 4 C i 1 01..*4.›,, 1 i 0 \:46011F:_ C STATE OF ALASKA AL._..A OIL AND GAS CONSERVATION COMM. ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well Lf Plug Perforations L] Perforate U Other L Run Killstring Performed: Alter Casing ❑ Pull Tubing❑., Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: ` 5.Permit to Drill Number: . Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 190-092 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-029-22067-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 MILNE PT UNIT SBI-03 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Schrader Bluff Oil Pool 11.Present Well Condition Summary: Total Depth measured 4,750 feet Plugs measured N/A feR C E l V E D true vertical 4,271 feet Junk measured N/A feet APR 2 1 2015 Effective Depth measured 4,659 feet Packer measured 4,191'&4,398' feet true vertical 4,184 feet true vertical 3.667'&3,934' feet AOGCC Casing Length Size MD TVD Burst Collapse Structural Conductor 105' 13-3/8" 105' 105' 1,730psi 740psi Surface 2,633' 9-5/8" 2,633' 2,399' 3,520psi 2,020psi Intermediate Production 4,741' 7" 4,741' 4,262' e APR 5,410psi Liner 6ii APR 2 7 N Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 4,054'(MD) 3,605'(TVD) 7"HES'VTA 4,191'(TVD)/3,667'(MD) Packers and SSSV(type,measured and true vertical depth) 7"'AWD'Sump 4,398'(MD)/3,934'(TVD) N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 218 54 14 280 200 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development E Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas 0 WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-161 Contact Chris Kanyer Email ckanverahilcorD.com Printed Name Chris Kanyer Title Operations Engineer Signature ,/‘ , Phone 907-777-8377 Date 4/20/2015 74 L(23 r 5 RBDMS1\ t P9 2 2 2015 Form 10-404 Revised 10/2012 Submit Original Only • 7 ‘/2-4(//i 14Milne Point Unit Well: MP 1-03 SCHEMATIC Last Completed: 4/5/2013 Hilcorp Alaska,LLC PTD: 190-092 CASING DETAIL Orig.KB Elev.:37' Size Type Wt/Grade/Conn ID Top Btm t i 1 ` - a ` a 13-3/8" Conductor 54.5/K-55/N/A 12.615 Surface 105' d 1. l 9-5/8" Surface 36/K-55/Btrc. 8.921 Surface 2,633' �3/g" riAkA, • .� , ' . 7" Production 26/L-80/Btrc 6.276 Surface 4,741' 4. a * TUBING DETAIL K X 44,1'` ; 2-7/8" Tubing 6.5/L-80/Btrc 2.441 Surf 4,054' ' ''t , JEWELRY DETAIL 9 No Depth Item piii , 1 4,191' 7"HES"VIA"Retrievable Packer t ► 2 4,234' 3.5"HES 250 Micron Poroplus Screens(4-Joints)-Bottom @ 4,359' 9.5/8'"4 3 4,422' HES Collet Guide&Seal Assembly 4 4,398' 7"Otis"AWD"Sump Packer(4.0"ID) 2,060'to 2,062' 5 4,415' 3.5"Otis X-Nipple(2.313"ID) 6 4,426' WLEG PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status N Sands 4,260' 4,280' 3,802' 3,821' 20 2/23/1991 Open N Sands 4,292' 4,304' 3,832' 3,844' 12 2/23/1991 Open N Sands 4,322' 4,328' 3,861' 3,867' 6 2/23/1991 Open N Sands 4,344' 4,378' 3,882' 3,915' 34 2/23/1991 Open O Sands 4,424' 4,455' 3,959' 3,988' 31 2/23/1991 Open 0 Sands 4,486' 4,510' 4,018' 4,041' 24 2/23/1991 Open 'N'Sands Perfs:24SPF&24GM. '0'Sands Perfs:5SPF&37GM OPEN HOLE/CEMENT DETAIL 13-3/8" 485sx Permafrost"C" 9-5/8" 247sx of Class"E",942 sx of Class"G"in a 12.25"Hole 7" 307sx of 15.8 ppg Class"G"a 8.5"Hole WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle=37 deg.@ 3,170' i is TREE&WELLHEAD Tree _ WKM 2-9/16"5M k•"1/21 Wellhead WKM 11" 5M w/2-7/8"8rd Tree Top Connection 2-1/2""H"Profile I. 1 STIMULATION DETAIL Interval:4,424'to 4,510"-26,802 Z* lbs.16/20 mesh Propant GENERAL WELL INFO API:50-029-22067-00-00 "' Drilled and Cased by Nabors 27 -11/14/1990 ~ Casing ESP Completion-3/7/1991 leak somewhere t between 4,020' ESP RWO by Nabors 4ES-10/5/1995 1 to Gravel Packer ESP RWO by Nabors 5S-12/14/1997 @4,191' ESP RWO by Nabors 4ES-7/30/2002 • RWO&Replace Screens by Nabors 4ES-5/6/2003 S ESP/HT Changeout by Nabors 4E5-10/7/2006 t ESP RWO by Nabors 35-5/2/2009 ESP Changeout by Doyon 16-4/5/2013 2 1 N Sands 44, 4O . # ' ' tt 5OSalds r'44 6 t-Ip TD=4,750(MD)/TO=4,271'(TVD) PBTD=4,659'(M))/PBTD=4,184'(TVD) Created By:TDF 4/20/2015 Hilcorp Alaska, LLC Hi,,.,,,.,,,tlas a.,.,.,: Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP1-03 50-029-22067-00-00 190-092 3/29/2015 Future Daily Operations: 3/25/15-Wednesday No operations to report. 3/26/15-Thursday No operations to report. 3/27/15-Friday No operations to report. 3/28/15-Saturday No operations to report. 3/29/15-Sunday MIRU Accept Rig. Run hardline to kill tank. Remove BPV,tie in pump line. PT hardline 250psi low/2,500psiHigh.SITP 100,SICP 200psi. Blow down tubing and annulus to zero in<10 minutes. Pump tbg volume 22 bbl w/8.5 ppg 140° Saltwater. Diesel in returns after 17 bbls.Monitor well total volume pumped 223 bbls,total recovery 121 bbls oil/water/diesel mix. 112 bbls lost or hole fill.Annlus on good vacuum.Tbg on light vac. Install BPV. ND tree BU BOPE shell Test OK 3/30/15-Monday PJSM. Proceed with BOP test waived 600 hrs 3/29 by AOGCC Rep. Herrara.Test BOPE 250psi low/3,000psi high.Test annular 250psi low/2,500psi high. Perform accumulator draw down. LD test joint,pull TWC well still on vacuum. Install landing JT. Back out lockdowns. PU to 80K hanger free no resistance. PU to floor decomplete hanger, ESP and heat trace.Thread cables and heat trace through sheave to spooler. POOH with 2-7/8" completion with 3,500'° heat trace and remainder ESP completion. Hot Spot in cable about 637'burnt through.After LD lower GLM pipe was wet and full of sand slurry to the ESP assembly.All coated and filled with sand,motor had been packed off on OD with sand.No evidence of scale on ESP assy or cable.Total LD bad pipe was 31 joints. Bad caliper IDs,and 1 cross thread.Offload bad pipe onload replacement pipe strap and drift. RU slick line and PDS Caliper. RIH w caliper to 1,000'.Misrun bad data, rerun caliper to 1,000', log 7"casing,good data. LD caliper and RD slickline. PU MU muleshoe 7"26# scraper assy 13' and 2-7/8" tubing from derrick 3,002.83'PU 34 jts new 2-7/8"tbg RIH to 4,100'. No tags.Total new pipe charged to well 34 jts. Rig up pump lines and pump down annulus 15bbls before catching reverse circulation.Circ 50 bbls reverse returns crude oil no solids,no sand.Swap to conventional circulate and pump 13 bbl,soap solvent pill ICP 150psi 2 bpm pump 1/2 tubing volume ease choke closed to bullhead solvent/soap to GP @ 4,191' @ 530 psi 2 BPM. Monitor well annulus on vacuum.Tubing on vacuum 89 bbls lost total estimate 15 bbls of that reverse out oil and fluid to cuttings box. 3/31/15-Tuesday PJSM. POOH w scraper full recovery all looks good.Build 100 bbls 8.5#NaCI with 18 sx NaCl. PU 7"26#RTTS packer RIH to 4,057'.Set packer,fill Hole 33 bbls 8.5#NaCI.Attempt to test communication with tubing,verify packer set and repeat. Release packer and reset with element @ 4,020'Test to 1,500psi for 30 minutes and chart.There is a hole in the casing below 4,020 and above GP @ 4,191'.Open bypass bleed off test release packer POOH. BOLD packer.Service rig. Run kill string to 4,054', 129 jts. Install BPV.ND BOPE,service hanger for String only, NU tree and test Void 250psi low/5,000psi high. Begin moving equipment to MPL-04. Prepare rig for move. t','', ''' of�//;14- ,s� THE STATE Alaska Oil and Gas w\��\ 1�: - _��_ �, ALASKIA. Conservation Commission _ __ E itt - = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS'' Fax: 907.276.7542 www.aogcc.alaska.gov �f Cts ,, ,�. �c b ', :, ^ /1 Chris Kanyer �`ae� \ (vl)b CPI ¢ Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB I-03 Sundry Number: 315-161 Dear Mr. Kanyer: 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, --76 P 4_,...,,,te..,_ , Cathy P.v erster Chair DATED this' day of March, 2015 Encl. • RECEIVED • STATE OF ALASKA MAR 2 3 201 � ALASKA OIL AND GAS CONSERVATION COMMISSION 3025 /_S APPLICATION FOR SUNDRY APPROVALS AOGC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well❑� • Change Approved Program 0 Suspend❑ Plug Perforations ❑ Perforate a Pull Tubing Q , lime Extension 0 Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate 0 Alter Casing❑ Other. ESP Changeout 0, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC . Exploratory ❑ Development 0, 190-092 3.Address: Stratigraphic a Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22067-00-00. 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 477 Will planned perforations require a spacing exception? Yes ❑ No ❑., i MILNE PT UNIT SB I-03• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 ' Milne Point Field/Schrader Bluff Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 4,750 • 4,271 . 4,659 • 4,184 - N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 105' 13-3/8" 105' 105' 1,730psi 740psi Surface 2,633' 9-5/8" 2,633' 2,399' 3,520psi 2,020psi Intermediate Production 4,741' 7" 4,741' 4,262' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic .' See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 4,107 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 7"HES'VTA'Retrievable&7"'AWD'Sump Packer and N/A '4,191(MD)/3,667(TVD)&4,398(MD)/3,934(TVD)and N/A - 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic❑ Development❑✓ - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/28/2015 Oil ❑., • Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned a Commission Representative: GSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyer@hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature XPhone 777-8377 Date 3/23/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1 _, Le Plug Integrity 0 BOP Test Lj' Mechanical Integrity Test ❑ Location Clearance ❑ \ Other: .1,-- 3000 t,,,.: &'0 e 'r- C /4i-St c,o5`J Spacing Exception Required? Yes ❑ No 137 Subsequent Form Required: `©•-Y 67 //l��/ APPROVED BY Approved by:/ �.,t �_ ( __ COMMISSIONER THE COMMISSION Date:3, 2s —/S �-r5 i?I% Slay C '( Il�Z ! — Submit Form and Form 10-4.' vised10/2012) AI��VVValpVtfrNEAfL12 months from the datqof aov Attachm in Duplicate 3-zs-/5 RBDMS Uct APR - 1 ?mc Well Prognosis Well: MPI-03 Hilcorp Alaska,LL, Date:3/23/2015 Well Name: MPI-03 API Number: 50-029-22067-00-00 Current Status: SI Producer Pad: I Pad Estimated Start Date: March 28, 2015 Rig: Nordic 3 Reg.Approval Req'd? March 27, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190-092 First Call Engineer: Chris Kanyer (907) 777-8377 (0) (907)250-0374 (M) Second Call Engineer: Bo York (907)777-8345 (0) (907)727-9247 (M) AFE Number: 1550807 Current Bottom Hole Pressure: — 1,247 psi @ 4,000' TVD (Last BHP measured 3/16/2015) Maximum Expected BHP: — 1,247 psi @ 4,000' TVD (No new perfs being added) Max.Allowable Surface Pressure: 0 psi (Based on actual reservoir conditions and water cut of 8% (0.339psi/ft)with an added safety factor of 1000' TVD of oil cap) r! Brief Well Summary: The Milne Point 1-15 well was drilled as a Schrader Bluff development well that TD'd at 4,750' and ran and cemented 7" casing in November 1990. The well was initially completed with an ESP.This and subsequent ESPs failed and were replaced in 1995, 1997, 2002, 2003, 29,06, 2009, and 2013. The recent pump failed March 3, 2015.There is no recent casing pressure test performed and one will be completed during this workover. There are minimal observed scale issues, most failures are related to solids production. A caliper was run on the upper 1,000' of 7" casing in April 2013.Another caliper will be run over this interval. Notes Regarding Wellbore Condition Current well status is shut in oil producer. Possible subsidence issues suspected. RWO Objective: Pull ESP, run casing caliper, perform cleanout,test casing, & run 2-7/8" ESP completion. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Attempt to circulate well with 8.5ppg seawater and monitor well. 3. ND tree, NU 11" BOPE and test to 250psi low/3,000psi high,annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 4. 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(Hilcojp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) Well Prognosis Well: MPI-03 Hilcorp Alaska,LL Date:3/23/2015 d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 5. Unseat hanger and pull 2-7/8" ESP completion from 4,107'to surface and lay down same. 6. RIH with slickline memory casing caliper to+/-1,000', POOH and log to surface. 7. RIH with tapered cleanout BHA and circulate well clean to+/-4,550'. POOH with same. . C5"8. RIH and set test packer at+/-4,000'. (,,tilt 9. Perform a charted casing pressure test to 1,500psi for 30min. Bleed off pressure and POOH with same. 10. MU and RIH with ESP with gas separator on 2-7/8" 8RD EUE L-80 tubing [to be replaced if necessary]. Set ESP at+/-4,100'. Land tubing hanger. 11. ND BOP, NU and tree. 12. RDMO workover rig and equipment. 13. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic II Milne Point Unit Well: MP 1-03 SCHEMATIC Last Completed: 4/5/2013 Moore Alaska,LLC PTD: 190-092 CASING DETAIL Orig.KB Elev.:37' Size Type Wt/Grade/Conn ID Top Btm %� �'," _ 1, t 13-3/8" Conductor 54.5/K-55/N/A 12.615 Surface 105' �' }� � yj �' 9-5/8" Surface 36/K-55/Btrc. 8.921 Surface 2,633' 13-3/8" a ,p - 1 .",*,1, 7" Production 26/L-80/Btrc 6.276 Surface 4,741' •%' , - TUBING DETAIL %y- t` � 2-7/8" Tubing 6.5/L-80/Btrc 2.441 Surf 4,107' y . * JEWELRY DETAIL i w;4 c r;1,' = t ,R 14 A. _ No Depth Item ,� 1 135' Camco 2-7/8"x 1"Sidepocket KBMM GLM %. : 2 3,876' Camco 2-7/8"x 1"Sidepocket KBMM GLM 95/8"' - 3 4,018' HES 2-7/8"XN-Nipple (2.25"No-go ID) 1 S`l 'eiPerfs � 4 4,060' Centrilift Pump:141 P6 PMSXD 2,060'to 2,062 \-.....--.......-----/ 5 4,076' Gas Separator -Model:GRSFTX AR H6 6 4,081' Tandem Seal Section:GSD3DBUT SBG/SB PFSA 7 4,095' Centrilift Motor:MSPI 84HP,2,210 Volt,23 amp/Rerated to 60HP,2,05OVolt,18 amp Heet Traoefi°n' 8 4,103' Centralizer w/Phoenix XT-150 Sensor-Bottom @ 4,107' surface to 3,417 9 4,191' 7"HES"VTA"Retrievable Packer 10 4,234' 3.5"HES 250 Micron Poroplus Screens(4-Joints)-Bottom @ 4,359' 11 4,422' HES Collet Guide&Seal Assembly 12 4,398' 7"Otis"AWD"Sump Packer(4.0"ID) , 13 4,415' 3.5"Otis X-Nipple(2.313"ID) 14 4,426' WLEG PERFORATION DETAIL / Kuparuk Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status 2 N Sands 4,260' 4,280' 3,802' 3,821' 20 Open N Sands 4,292' 4,304' 3,832' 3,844' 12 Open N Sands 4,322' 4,328' 3,861' 3,867' 6 Open Ial 3 N Sands 4,344' 4,378' 3,882' 3,915' 34 Open m _A 0 Sands 4,424' 4,455' 3,959' 3,988' 31 Open ,,± I 0 Sands 4,486' 4,510' 4,018' 4,041' 24 Open OPEN HOLE/CEMENT DETAIL i 4 13-3/8" 500 sks Permafrost"C" ' 9-5/8" 416 bbls of Permafrost"E"w/5#/sk Gilsonite in a 12.25"Hole Tr •,,,5 63 bbls of 15.8 ppg Class"G"w/.2%CFR-3,.4%Haled 344& ' - 7 .03%LWLin a 8.5"Hole 6 WELL INCLINATION DETAIL :A ilig KOP @ 500' '' ,i 7 Max Hole Angle=37 deg.@ 3,170' r Slit `Y TREE&WELLHEAD ' 'I. 8 .* Tree WKM 2-9/16"SM x WKM 11" 5M w/2-7/8"8rd Tree Top Wellhead Connection 2-1/2""H"Profile y STIMULATION DETAIL Interval:4,424'to 4,510"-26,802 lbs.16/20 mesh Propant 1 1 GENERAL WELL INFO * 9 - ._ API:50-029-22067-00-00 .' Drilled and Cased by Nabors 27 -11/14/1990 10 }N Sails ESP Completion-3/7/1991 '•; ESP RWO by Nabors 4ES-10/5/1995 12r. ''-,#''- ESP RWO by Nabors 5S-12/14/1997 1314 ;�3- SandsO Ss ESP RWO by Nabors 4ES-7/30/2002 7 RWO&Replace Screens by Nabors 4ES-5/6/2003 TO=4,750(M))/TD=4,271'(TVD) ESP/HT Changeout by Nabors 4ES-10/7/2006 PBTD=4,659'(MD)/PBTD=4,184'(1VD) ESP RWO by Nabors 3S-5/2/2009 ESP Changeout by Doyon 16-4/5/2013 Created By:TDF 3/20/2015 Milne Point Unit Well: MP 1-03 14 PROPOSED Last Completed: 4/5/2013 Hilcorp Alaaka,LLC PTD: 190-092 CASING DETAIL Crig.KB Elev.:37 Size Type Wt/Grade/Conn ID Top Btm I ,a , E 13-3/8 " Conductor 54.5/K-55/N/A 12.615 Surface 105' 9-5/8" Surface 36/K-55/Btrc. 8.921 Surface 2,633' 13-3/8" Oi A r r, ,, 7" Production 26/L-80/Btrc 6.276 Surface 4,741' t' 4 1t1; TUBING DETAIL %),,._.C. ' 2-7/8" Tubing 6.5/L-80/Btrc 2.441 Surf 4,107' `a` 4+ hi. JEWELRY DETAIL �. • No Depth Item 1 ±135' GLM 2 ±3,876' GLM 95/8"� 3 ±4,018' XN-Nipple (2.25"No-go ID) 2,060'to 2,067 4 ±4,060' Pump 5 ±4,076' Gas Separator 6 ±4,081' Tandem Seal Section 7 ±4,095' Motor Heat Trace fiorri 8 ±4,098' Centralizer w/Phoenix Sensor-Bottom @ 4,100' surface to±2,500' 9 4,191' 7"HES"VTA"Retrievable Packer 10 4,234' 3.5"HES 250 Micron Poroplus Screens(4-Joints)-Bottom @ 4,359' 11 4,422' HES Collet Guide&Seal Assembly 12 4,398' 7"Otis"AWD"Sump Packer(4.0"ID) 13 4,415' 3.5"Otis X-Nipple(2.313"ID) 14 4,426' WLEG PERFORATION DETAIL i Kuparuk Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status 2 N Sands 4,260' 4,280' 3,802' 3,821' 20 Open N Sands 4,292' 4,304' 3,832' 3,844' 12 Open N Sands 4,322' 4,328' 3,861' 3,867' 6 Open I 3 N Sands 4,344' 4,378' 3,882' 3,915' 34 Open E .� 0 Sands 4,424' 4,455' 3,959' 3,988' 31 Open 44 A 0 Sands 4,486' 4,510' 4,018' 4,041' 24 Open , OPEN HOLE/CEMENT DETAIL •4 13-3/8" 500 sks Permafrost"C" 9-5/8" 416 bbls of Permafrost"E"w/5#/sk Gilsonite in a 12.25"Hole 5 7„ 63 bbls of 15.8 ppg Class"G"w/.2%CFR-3,.4%Halad 344& .03%LW Lin a 8.5"Hole .6 WELL INCLINATION DETAIL KOP @ 500' �. 44 7 Max Hole Angle=37 deg.@ 3,170' 'w TREE&WELLHEAD 8 .' Tree WKM 2-9/16"SM ,a WKM 11" 5M w/2-7/8"8rd Tree Top "' Wellhead Connection 2-1/2""H"Profile 3, STIMULATION DETAIL u A Interval:4,424'to 4,510"-26,802 '1 lbs.16/20 mesh Propant C 41 A GENERAL WELL INFO 9 tiff '*. API:50-029-22067-00-00 7. Drilled and Cased by Nabors 27 -11/14/1990 10 }N Sands ESP Completion-3/7/1991 ESP RWO by Nabors 4ES-10/5/1995 12» '=' „: t b ESP RWO by Nabors 55-12/14/1997 �,i 13 ` }O Sands ESP RWO by Nabors 4ES-7/30/2002 7,%4 14 " RWO&Replace Screens by Nabors 4ES-5/6/2003 ID=4,750(MD)/TD=4,271'(TVD) ESP/HT Changeout by Nabors 4ES-10/7/2006 PBTD=4,659'(MD)/PBTD=4,184'(1VD) ESP RWO by Nabors 35-5/2/2009 ESP Changeout by Doyon 16-4/5/2013 Created By:TDF 3/20/2015 11" BOP Stack r i 111111 O iii ii Hydril 11" SM . ,i i ii.a / =4 4 Shaffer 2 7/8-5.5 variables CMC--__(_\ 11" 5M .^O Blinds c j- \, ,Ii6L______/ - ii' '"�-- �� tG• G1 � � :' 'i - t e, , 0 i. dt i . . 11"5M Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ] ~O'-~q~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA [] [] Diskettes, No. Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by:~Bren TO RE-SCAN Notes: Vincent Nathan Lowell Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd .11 STATE OF ALASKA AKA OIL AND GAS CONSERVATION C ISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS APR 2 4 2013 1. Operations Performed: AOGCO ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 190 - 092 3. Address: ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 22067 - 00 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025906 MPI -03 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 11. Present well condition summary: Total depth: measured 4750' feet Plugs:(measured) None feet true vertical 4271' feet Junk: (measured) None feet Effective depth: measured 4659' feet Packer: (measured) 4191', 4398' feet true vertical 4184' feet Packer: (true vertical) 3736', 3934' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13 -3/8" 35' - 115' 35' - 115' 1740 750 Surface 2598' 9 -5/8" 35' - 2633' 35' - 2399' 3520 2020 Intermediate Production 4706' 7" 35' - 4741' 35' - 4262' 7240 5410 Liner SCANNED JUL 0 8 2013 Perforation Depth: Measured Depth: 4260' - 4378', 4424' - 4510' feet True Vertical Depth: 3802' - 3915', 3959' - 4041' feet Tubing (size, grade, measured and true vertical depth): 2 - 7/8 ", 6.5# L - 4107' 3656' Packers and SSSV (type, measured and true vertical depth): (Screen Assembly) 7" HES VTA Retrievable Packer, 4191', 4398' 3736', 3934' 7' Otis AWD Sump Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 125 56 4 250 197 Subsequent to operation: 135 56 3 270 201 14. Attachments: ❑Copies of Logs and Surveys run 15. WeII Class after work: ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service ® Daily Report of Well Operations 16. Well Status after work: ® Oil ❑ Gas ❑ WDSPL ® Well Schematic Diagram ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact: David Bjork, 564 -5683 NIA Email: David.Bjork @bp.com Printed ame Jo La j] M Title: Drilling Technologist Signatur : Phone: 564 -4091 Date: 4/131 i 3 bit Oi S ( t Submit Original Only Form 10-404 v' ed 10/2012 i B Mg A g 8 r 11/- 9 Y . • 'North Atreerkca ALASKA $› • ration Summary Report Common Well Name: MPI -03 AFE No Event Type: WORKOVER (WO) Start Date: 3/30/2013 End Date: 4/2/2013 X4 -00XF6 -E:RIG (1,255,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date/Time: 11/5/1990 12:00:00AM , Rig Release: 4/2/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING @54.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/30/2013 00:00 - 01:00 1.00 MOB P PRE PJSM, WITH CREW FOR RIG MOVE - FUNCTION TEST MOVING SYSTEM - RAISE CELLAR DOORS, REMOVE CUTTINGS TANK 01:00 - 03:00 2.00 MOB P PRE WSL PRESENT, PAD OPERATOR NOTIFIED - PULL OFF OF WELL MPI -07 AND POSITION RIG ON PAD - LAY RIG MATS AROUND MPI -03 - SPOT AND SHIM RIG OVER WELL MPI -03 - SET CUTTINGS TANK - RIG ACCEPTED ON MPI -03 AT 03:00 ON 3/30/2013 03:00 - 03:30 0.50 MOB P DECOMP HOLD RIG EVACUATION DRILL - ALL PERSONEL ON LOCATION ARRIVED AT THE MUSTER AREA INCLUDING TRUCK DRIVERS - PAD OPERATOR WAS ALSO NOTIFIED - AAR WAS HELD, DISCUSSED EGRESS ROUTES OUT OF THE RIG 03:30 - 06:00 2.50 WHSUR P DECOMP PJSM, R/U WELL KILL MANIFOLD AND CIRCULATING LINES TO TREE - M/U HARD LINE TO FLOW BACK TANK AND TEST TANK ALARM - SPOT FUEL AND CHANGE TRAILERS 06:00 - 07:30 1.50 WHSUR P DECOMP PJSM, RU CIRCULATING EQUIPMENT. - RU HARD LINE TO FLOW BACK TANK - BLOW THRU LINE WITH AIR. - R/U KILL MANIFOLD IN CELLAR. - CIRCULATING LINE TO WELL HEAD. - WARM LINE AND FILL TO TEST WITH DIESEL. - PRESSURE TEST PER DOYON SOP. - 250 / 3,500 PSI FOR 5 CHARTED MIN. PASSED. - TEST HI -LEVEL ALARM ON FLOW BACK TANK. 07:30 - 08:00 0.50 WHSUR N WAIT DECOMP WAIT ON KWF TO ARRIVE PRIOR TO PULLING BPV. - DUE TO TRUCK DRIVERS / TRUCK AVAILABILITY. 08:00 - 10:00 2.00 WHSUR P DECOMP TAKE ON 8.5 PPG HEATED SEAWATER. PJSM, WITH MPU DSM TO PULL BPV. - P/U DSM LUBRICATOR. RU TEST HOSES. - TEST LUBRICATOR TO 250 / 3500 PSI FOR 5 CHARTED MIN. EACH. - PULL BPV WITH TESTED LUBRICATOR. SITP = 500 PSI. SICP = 500 PSI - L/D LUBRICATOR PER DSM REPS. I � WSL HAVE FACE TO FACE WITH PAD OPS TO CLOSE OUT WELL WORK TRANSFER PERMIT" OF MPI -07. Printed 4/15/2013 9:54:47AM • • Moth Aixter"ic:a ALASKA -BP' ° Pag% ` . , . . Operation "Summary "Report Common Well Name: MPI -03 1 AFE No Event Type: WORKOVER (WO) Start Date: 3/30/2013 End Date: 4/2/2013 X4 -00XF6 -E:RIG (1,255,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date/Time: 11/5/1990 12:00:00AM Rig Release: 4/2/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING (g54.50usft (above Mean Sea Level) Date From - To I Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 12:30 2.50 WHSUR P DECOMP PJSM. , WELL KILL WITH 8.5 PPG HEATED SEAWATER I - WSL / TOOL PUSHER VERIFY VALVE I ALIGNMENT. -SITP = 500 PSI, SICP = 600, SIOA = 0 PSI - BLEED GAS FROM IA F/ 600 T/ 250 PSI IN 7 MIN. SITP = 70 PSI 1- NO FLUID RETURNS. - PUMPED 25 BBLS 8.5 PPG SEAWATER AT 3 ! BPM WITH '0' PSI DOWN THE TBG THRU CHOKE SKID TO FLOW BACK TANK. I - ICP = '0' PSI - FCP = 10 PSI BULL HEAD ON THE FLY, 10 BBLS KWF I DOWN THE TBG AT 3 BPM / 200 PSI. I MONITOR WELL SHUT IN FOR 5 MINUTES. ! - SITP AFTER 5 MINUTE = '0' - SICP = HOLDING AT 60 PSI. PUMPED 40 BBLS DEEPCLEAN PILL(SOAP) FOLLOWED BY 200 HEATED 8.5 PPG I SEAWATER - AT 3- 5 BPM DOWN THE TBG THRU CHOKE i I SKID TO FLOW BACK TANK. ' 1- FLUID TO SURFACE AFTER -3 BBLS PUMPED. - ICP = 3 BPM / 400 PSI. 5 BPM / 600 PSI. i - WATER CUT RETURNS AFTER -150 BBLS PUMPED. - TOTAL OF 240 BBLS KWF PUMPED TILL I CLEAN RETURNS AT SURFACE, STOP PUMP. i MONITOR FULL 30 MINUTES -TBG AND IA ONAVACUUMAFTER4 MINUTES. WELL IS DEAD. - TOTAL LOSSES DURING WELL KILL (152 BBLS KWF) - 10 BBLS BULLHEAD PLUS 142 BBLS KWF. - SENT 113 BBLS OF CRUDE TO MPU I RECYCLE. 12:30 13:00 I 0.50 WHSUR P DECOMP PJSM, RIG DOWN KILL MANIFOLD. - BLOW DOWN ALL CIRCULATING LINE. I - RIG DOWN CIRCULATING LINES & KILL MANIFOLD ,- R/U SECONDARY KILL LINE. 13:00 - 14:00 1.00 WHSUR P DECOMP I PJSM WITH WELL SUPPORT AND RIG CREW TO SET TWC - M/U LUBRICATOR & TEST WITH DIESEL - 250 PSI LOW AND 3500 PSI FOR 5 MINS EACH , CHARTED 1 - SET TWC I - L/D LUBRICATOR. 1 14:00 - 15:00 1.00 WHSUR P DECOMP - PERFORM ROLLING TEST BELOW TWC I - PUMP DOWN IA © 3.5 BPM AND 500 PSI FOR 110 MINS, CHARTED - 58 BBLS KWF PUMPED, 4 BBLS BLED BACK - TEST TWC FROM ABOVE, 250 PSI LOW & I 1 1 3500 PSI HIGH FOR 5 MINS EACH , CHARTED Printed 4/15/2013 9:54:47AM • • ;Operation Summary Report Common Well Name: MPI -03 AFE No Event Type: WORKOVER (WO) Start Date: 3/30/2013 End Date: 4/2/2013 X4 -00XF6 -E:RIG (1,255,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date/Time: 11/5/1990 12:00:00AM Rig Release: 4/2/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING @54.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 16:30 1.50 WHSUR P DECOMP R/U BOPE TEST EQUIPMENT - R/U 2 7/8" AND 4" TEST JOINTS AND FLOOR VALVES - GREASE / SERVICE CHOKE, PREP CELLAR FOR N/U BOP, POSITION WELL KILL SKID INTO PLACE 16:30 - 17:00 0.50 WHSUR P DECOMP PJSM, RIG SERVICE - COMPLETE DERRICK / CROWN / TOP DRIVE INSPECTIONS 17:00 - 17:30 0.50 WHSUR P DECOMP PJSM, N/D TREE - CAMERON HAND BLED DOWN TUBING HEAD ADAPTOR - N/D 2 9/16" CAMERON TREE - CHECK HANGER THREADS = 2 7/8" 8RD THREADS, 8.5 RH TURNS 17:30 - 19:30 2.00 BOPSUR P DECOMP PJSM, NIPPLE UP BOPE - N/U 13 -5/8" 5M BOPE STACK. - INSTALL TURNBUCKLES AND FLOW NIPPLE. - RE- ENERGIZE ACCUMULATOR SYSTEM. - R/U TEST EQUIPMENT 19:30 - 00:00 4.50 BOPSUR P DECOMP PJSM, TEST THREE PREVENTER BOPE AND RELATED EQUIPMENT - TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES - TEST ANNULAR WITH 2 7/8" TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES EACH, CHARTED - TEST 2 7/8" X 5" VARIABLE RAMS WITH 2 7/8" AND 4" TEST JOINT, 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST BLIND RAMS, FLOOR VALVES, AND CHOKE MANIFOLD TO 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST WITH FRESH WATER. - NO FAILURES. - BOB NOBLE OF AOGCC WAIVED STATES RIGHT OF WITNESS FOR BOPE TEST - MAINTAIN CONTINUOUS HOLE FILL TO THE IA DURING TEST @ -21 BPH , 8.5 PPG SEAWATER 3/31/2013 00:00 - 00:30 0.50 BOPSUR P DECOMP PJSM, MAKE SPCC AND EQUIPMENT CHECKS - PERFORM ACCUMULATOR DRAW DOWN TEST - R/D BOP TEST EQUIPMENT - STATIC LOSS RATE = 26 BPH 00:30 - 01:00 0.50 j WHSUR P DECOMP PJSM, P/U DSM LUBRICATOR - DRAIN BOP AND M/U OFF SET LUBRICATOR TO HANGER 01:00 - 03:00 2.00 WHSUR P DECOMP M/U DSM LUBRICATOR AND TEST SAME - 250 / 3500 PSI, 5 MIN CHARTED - PULL TWC, R/D DSM LUBRICATOR Printed 4/15/2013 9:54:47AM f • • NC Ft met1+a- ALASKA -BP aim4 t'8 O Summary Report Common Well Name: MPI -03 AFE No Event Type: WORKOVER (WO) Start Date: 3/30/2013 I End Date: 4/2/2013 X4 -00XF6 -E:RIG (1,255,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date/Time: 11/5/1990 12:00:00AM Rig Release: 4/2/2013 Rig Contractor DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING @54.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) I (usft) 03:00 - 03:30 0.50 WHSUR P DECOMP MU 2 -7/8" EUE LANDING JOINT WITH FOSV TO I 1 TBG HANGER. - BOLDS PER CAMERON REP I- WSL VERIFY NO TRAPPED PRESSURE UNDER TBG HANGER. I - PULL TBG HANGER OFF SEAT @ 75K I INCLUDES 40K TOP DRIVE WT. 1 I - PUWT = 75K, SOWT = 70K - CENTRILIFT REP CONDUCT CONDUCTIVITY TEST ON ESP AND HEAT TRACE - PULL HANGER AND REMOVE FLAT GUARDS I AND BANDS ON FIRST FULL JOINT - CUT ESP CABLE AND HEAT TRACE AT I 1 CLAMP AT BOTTOM OF FIRST FULL JT _ - POSITION SLICK JOINT ACROSS BOPE 03:30 - 04:00 ( 0.50 PULL P ,, DECOMP CLOSE ANNULAR AND PUMP ONE TUBING 1 VOLUME, 25 BBLS 8.5PPG SEAWATER, DOWN TUBING, 3 BPM = 370 PSI - TAKE RETURNS THRU GAS BUSTER j 1- PUMPED 8.5 BBLS BEFORE GETTING RETURNS - WSL / DRILLER VERIFY VACUUM AND NO TRAPPED PRESSURE, OPEN ANNULAR. - MONITOR WELL, WELL IS ON A VACUUM I I - MAINTAIN CONSTANT HOLE FEED AT 21 BPH, WITH NO RETURNS 04:00 - 05:00 1.00 I PULL P I DECOMP PJSM, HANG ESP SHEAVE AND ESP TRUNK i - BLOW DOWN CHOKE MANIFOLD AND DRAIN 1 GAS BUSTER - R/U CENTRILIFT EQUIPMENT 05:00 - 05:30 0.50 PULL P i DECOMP I PJSM, PULL 2 7/8" EUE ESP COMPLETION AND HEAT TRACE - PULL ESP COMPLETION FROM 4109' MD. - STAND BACK TBG IN DERRICK. 05:30 - 15:00 9.50 PULL 1 N SFAL DECOMP ROPE ATTACHED TO ESP CABLE PARTED AT SHEAVE. DROPPED ESP CABLE - 50' TO RIG FLOOR. - WSL ON RIG FLOOR AT THE TIME. - ALL PERTINENT NOTIFICATIONS MADE BY WSL AND TOOLPUSHER. 1 - M/U FOSV. - INSPECT ESP SHEAVE. 1 - MR WITH WSL, TOOLPUSHER, AND RIG I I CREW. DEVELOPED PLAN TO RESTRING LINE TO SPOOLING UNIT. I- BP SAFETY PERSONNEL CALLED OUT TO i RIG. I ■ INVESTIGATION TEAM ASSEMBLED. TRACTION #IR- 4388531 _ 15:00 - 16:30 1.50 PULL P DECOMP PJSM, DISCUSSED PLAN FORWARD. WSL, DDI SUPERINTENDENT, TOOLPUSHER, RIG CREW IN ATTENDANCE. I - RESTRING ESP CABLE OVER SHEAVE USING DRILL LINE SNAKE ANCHORED TO 1 CABLE. 1 � - BOTH CABLES WERE HAND PULLED OVER I SHEAVE INTO TRUNK. - ATTACH ESP / HEAT TRACE TO REELS IN SPOOLING UNIT. Printed 4/15/2013 9:54:47AM • • on 3u mrr�ary- Rep Common Well Name: MPI -03 AFE No Event Type: WORKOVER (WO) Start Date: 3/30/2013 End Date: 4/2/2013 X4 -OOXF6 -E:RIG (1,255,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name/No.: DOYON 16 Spud Date/Time: 11/5/1990 12:00:00AM Rig Release: 4/2/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING @54.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 00:00 7.50 PULL P DECOMP PJSM, POOH WITH 2 7/8" 6.5# EUE 8 RD ESP COMPLETION WITH HEAT TRACE - FROM 4109' TO ESP PUMP AND MOTOR ASSY AT 45' - HEAT TRACE WAS RAN TO BOTTOM OF JOINT 108, 3569' CLAMPS RECOVERED: - 6' FLAT GUARDS = 544 - 4' FLAT GUARDS = 34 - SS BANDS = 1532 - OA =0PSI - 24 HOUR FLUID LOSS = 475 BBLS - MAINTAIN CONSTANT HOLE FEED TO IA= 20 BPH 8.5 PPG, 120 DEGREE SEAWATER 4/1/2013 00:00 - 02:00 2.00 PULL P DECOMP PJSM, MAKE SPCC AND EQUIPMENT CHECKS - L/D ESP PUMP AND MOTOR ASSY - POSSIBLE CAUSE FOR FAILURE = MOTOR GROUNDED AND CABLE SHORTED OUT 02:00 - 03:00 1.00 PULL P DECOMP PJSM, CLEAR CLEAN RIG FLOOR - CEN FLOOR OF ALL TO LAMPS AND EQUIPMENT - CLEAN RIG FLOOR - R/D ESP SHEAVE AND TRUNK -LOSS RATE =18BPH 03:00 - 06:30 3.50 EVAL P DECOMP PJSM WITH SWS SLICK -LINE CREW. - R/U DUTCH RISER SYSTEM. - MAINTAIN HOLE FILL THRU KILL LINE. - SPOT WIRE LINE UNIT. R/U PDS TOOL 06:30 - 08:30 2.00 EVAL P DECOMP PJSM, RIH WITH CALIPER LOG. - RIH WITH SWS LOGGING TOOLS TO 1000' MD. - PERFORM CALIPER LOG TO SURFACE USING PDS TOOL. - DOWN LOAD LOGGING DATA. WSL DISCUSS WITH RWO TOWN TEAM. 08:30 - 09:00 ! 0.50 EVAL P DECOMP ! PJSM, RIG DOWN SWS / PDS LOGGING TOOLS. - LAY DOWN DUTCH RISER. - CLEAR RIG FLOOR. _ 09:00 - 11:00 2.00 RUNCOM P RUNCMP PJSM, RIG UP TO RUN COMPLETION. - HANG ESP SHEAVE IN DERRICK - MOBILIZE CANNON CLAMPS TO RIG FLOOR AND ORGANIZE. - MAKE DUMMY RUN WITH TBG HANGER PER ! CAMERON REP. WSL VERIFY "J -IN" OF HANGER AND I MEASURE ALIGNMENT PIN = 15/16" 11:00 - 12:00 1.00 RUNCOM P RUNCMP PJSM, MAKE UP ESP MOTOR SECTIONS AND SERVICE PER CENTRALIFT REP. - MAINTAIN CONTINUOUS HOLE FILL @ 18 BPH. LOSSES TO WELL KWF = 221 BBLS. Printed 4/15/2013 9:54:47AM • • • N S ar#h "�rnef� = P1t.A kA. = on $ bp+ rats Summary Report Common Well Name: MPI -03 AFE No Event Type: WORKOVER (WO) Start Date: 3/30/2013 End Date: 4/2/2013 X4- 00XF6 -E:RIG (1,255,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name/No.: DOYON 16 Spud Date/Time: 11/5/1990 12:00:00AM Rig Release: 4/2/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING i54.50usft (above Mean Sea Level) Date From - To Hrs Task Code 1 NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 14:00 2.00 RUNCOM P RUNCMP PJSM, MAKE UP MOTOR ASSEMBLY. - CONTINUE TO PREP MOTOR / PUMP ASSEMBLY PER CENTRILIFT REP. - PULL ESP POTHEAD AND CABLE OVER SHEAVE TO RIG FLOOR. CENTRILIFT REP MAKE CONNECTIONS TO MOTOR ASSEMBLY. ! I - CHECK CONDUCTIVITY PRIOR TO RIH. 14:00 - 00:00 10.00 RUNCOM P RUNCMP RIH WITH 2 7/8" 6.5# EUE 8 RD TUBING ESP COMPLETION FROM DERRICK. - RIH FROM SURFACE TO 2745' MD - BEGIN HEAT TRACE ON JOINT #23, OR #104 FROM SURFACE AT 3355' - TUBING TORQUE = 2300 FT /LBS. USE BEST O LIFE 2000 PIPE DOPE ON EVERY CONNECTION. - INSTALL CANNON CLAMPS ON EVERY COLLAR ON THE FIRST 9 JOINTS, THEN EVERY OTHER JOINT THEREAFTER - CHECK ESP CABLE CONDUCTIVITY EVERY 2000' 1- CHECK HEAT TRACE CONDUCTIVITY EVERY 1000' - PUMP 5 BBLS TO FLUSH THRU PUMP AT .50 BPM / 1900 PSI. AT 2000' - MAINTAIN CONTINUOUS HOLE FILL c - 20 BPH. - OA = 0 PSI - 24 HOUR FLUID LOSS = 407 BBLS 4/2/2013 00:00 - 06:00 6.00 RUNCOM P RUNCMP PJSM, MAKE SPCC AND EQUIPMENT CHECKS RIH WITH 2 7/8" 6.5# EUE 8 RD TUBING ESP COMPLETION WITH HEAT TRACE FROM DERRICK. - RIH FROM 2745' TO 4084' MD. - TUBING TORQUE = 2300 FT /LBS. USE BEST O LIFE 2000 PIPE DOPE ON EVERY CONNECTION. - CHECK ESP CABLE CONDUCTIVITY EVERY 2000' - CHECK HEAT TRACE CONDUCTIVITY EVERY 1000' - PUMP 5 BBLS TO FLUSH THRU PUMP AT .50 BPM / 1900 PSI. BEFORE P/U LAST GLM AT 13866' M/U WKM HANGER TO LANDING JT. AND 1 FOSV AND ORIENT PER CAMERON REP - MAINTAIN CONTINUOUS HOLE FILL @ 18 BPH. 516 - 5' DUAL CHANNEL CANNAON CLAMPS 103 - 2' DUAL CHANNEL CANNON CLAMPS 4 -4" CANNON PUMP CLAMPS 1 - HALF CLAMP !3 -SS BANDS 116 - 2' SINGLE CHANNEL CANNON CLAMPS 1 4 - PROTECTALIZERS 2 - FLAT GUARDS � 1 LOSSES TO WELL 184 BBLS KWF. Printed 4/15/2013 9:54:47AM B or8i Mica � ALASKA - P pe tt • ; , ra on Summary Report Common Well Name: MPI -03 AFE No Event Type: WORKOVER (WO) Start Date: 3/30/2013 End Date: 4/2/2013 1 X4 -OOXF6 -E:RIG (1,255,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date/Time: 11/5/1990 12:00:00AM Rig Release: 4/2/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING @54.50usft (above Mean Sea Level) Date 1 From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 09:00 3.00 RUNCOM P RUNCMP PJSM, CONNECT HEAT TRACE TO HANGER. - INSTALL HEAT TRACE ON BOTTOM OF JOINT 23 - CHECK HEAT TRACE AND ESP CONDUCTIVITY - BOTTOM OF HEAT TRACE WILL BE AT 3417' MD 09:00 - 09:30 0.50 RUNCOM P RUNCMP PJSM, LANDING 11" TBG HANGER. CAMERON REP, WSL, CENTRALIFT REP IN ATTENDANCE. - LAND HANGER PER CAMERON REP - PU WT = 72K, SOW = 75K. INCLUDING 40K TOP DRIVE WT. - HANGER SET AT 4107' MD. - WSL VERIFY TBG HANGER " J -IN " WHEN LANDED. - RUN IN LOCK DOWN SCREWS PER _ + CAMERON REP. LD LANDING JOINT. 09:30 - 10:30 1.00 WHSUR P RUNCMP - CAMERON REP INSTALL 2 -1/2" TYPE'H' TWC - .PERFORM 500 PSI ROLLING PRESSURE TEST FROM BELOW TWC / HANGER. - 4 BPM @ 500 PSI FOR 10 CHARTED MIN. PASSED. - 55 BBLS PUMPED, 12 BBLS BLEED BACK. - TEST FROM ABOVE TWC, 250 / 3500 PSI, 5 MIN, CHARTED. PASSED. - MAINTAIN CONTINUOUS HOLE FILLAT -18 BPH W/ 8.5# KWF. 10:30 - 11:30 1.00 BOPSUR P RUNCMP PJSM, N/D 13 -5/8" 5M BOP - N/D 13 5/8" BOPE - REMOVE FLOW NIPPLE AND TURNBUCKLES. - LOTO KOOMY AND REMOVE HOSES. - SET BACK BOP STACK - MAINTAIN CONTINUOUS HOLE FILLAT - 18 BPH 8.5 PPG KWF. 11:30 - 14:30 3.00 WHSUR P RUNCMP PJSM, N/U 2 9/16" 5M CAMERON PRODUCTION TREE / ADAPTER. - CAMERON REP CLEAN AND INSPECT TBG HANGER VOID. - N/U TREE AND ADAPTER PER CAMERON REP. - PRESSURE TEST ADAPTER VOID - 250 PSI FOR 5 CHARTED MINUTES, PASSED. - 5000 PSI FOR 30 CHARTED MINUTES. PASSED. i I - PRESSURE TEST PRODUCTION TREE WITH DIESEL. - 250 / 5000 PSI, BOTH 5 MINUTES CHARTED. PASSED. - WITNESSED BY WSL. Printed 4/15/2013 9:54:47AM • • • North AtT1111 i1M - ALASKA - BP 6 t n Summary Report Common Well Name: MPI -03 AFE No Event Type: WORKOVER (WO) Start Date: 3/30/2013 End Date: 4/2/2013 X4 -00XF6 -E:RIG (1,255,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date/Time: 11/5/1990 12:00:00AM Rig Release: 4/2/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING @54.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 17:00 2.50 WHSUR P RUNCMP PJSM, R/U AND TEST DSM LUBRICATOR - TEST 250 / 3500 PSI, FOR 5 CHARTED MINUTES. - PULL TWC - RETEST LUBRICATOR, INSTALL 2 -1/2" TYPE 'H' BPV. - PERFORM 500 PSI ROLLING TEST FROM BELOW. - 3 BPM / 500 PSI, 46 BBLS PUMPED. - 2 BBLS BLED BACK. - R/D DSM LUBRICATOR 17:00 - 17:30 0.50 RIGD P POST PJSM, BLOW DOWN ALL CIRCULATING LINES AND ASSOCIATED EQUIPMENT. - RD CELLAR LINES. - CLEAN PITS AND SURFACE EQUIPMENT 17:30 - 21:00 3.50 RIGD P POST PJSM, R/U LITTLE RED SERVICES TO FREEZE PROTECT WELL - PUMP 75 BBLS DEAD CRUDE DOWN IA, 2 BPM = 950 PSI, PUMP OFF FINAL PRESSURE ON IA =450 PSI - PUMP 15 BBLS DEAD CRUDE DOWN TUBING, 0 .5 BPM = 1750 PSI, PUMP OFF FINAL PRESSURE ON TUBING = 250 PSI - EQUALIZED FREEZE PROTECT LEVEL AT 2537 MD - CONTINUE TO CLEAN PITS DURING FREEZE PROTECT - RIG CREW PREP FOR RIG MOVE I j - FLUID LOSSFOR THE DAY = 282 BBLS 8.5 SEAWATER - RELEASED RIG FROM MPI -03 FOR MOVE TO MPJ -09 AT 21:00 HRS, 4 -02 -2013 WAIT FOR PRE -RIG WORK AND PAD PREP ON MPJ -09 PRIOR TO MOVING Printed 4/15/2013 9:54:47AM TREE: 2 9/16" 5M WKM MPI -03 Orig. - SL = 72' (NABORS 27E) WELLHEAD: 11" 5M WKM w/ Orig. KB - GL = 37' (NABORS 27E) 2 -7/8" 8rd TREE TOP CONNECTION 2 1/2" "H" Profile. Camco 2 -7/8" x 1" ( 135' 13 3/8 ", 48 # /ft, I 115 sidepocket KBMM GLM Squeeze perfs: - 2,060' - 2,062' 9 5/8 ", 36 # /ft, J -55 Butt. I 2,633' I KOP @ 500' Centrilift Heat trace installed 3417' to Surface Max. Hole angle @ 37 deg. @ 3170' Camco 2 -7/8" x 1" sidepocket KBMM GLM 3,876' 2 - 7/8 ", 6.5 ppf, L - 80 EUE 8 rd ( drift ID = 2.347 ", Cap. =.0058 bpf) HES 2 - 7/8" XN Nipple ( 2.25" No - Go) 1 4018' 7" 26 ppf, L -80, Butt. casing, ( drift ID = 6.276 ", cap. = 0.0383 bpf ) 4,060' Pump:141 -P6 PMSXD PUMP 4,060` Gas Separator - GRSFTX AR H6 4,076' Centrilift Tandem Seal Section ( 4,081' Model GSD3DBUT SB /SB PFSA Centrilift Motor: MSPI 84 HP I 4,095` - 2210 VOLTS / 23 AMP Rerated to / 60hp /2050v / 18a N SAND PERFORATION SUMMARY Centralizer with Phoenix XT -150 Sensor 4103' SIZE SPF INTERVAL TVD .II 24 4,260' - 4,280' 3,801' - 3,820' 24 4,292' - 4,304' 3,832' - 3,843' 24 4,322' - 4,328' 3,860' - 3,866' 24 4,344' - 4,378' 3,882' - 3,915' 24 spf , 24 gm PM_ 7" HES "VTA' Retrievable Pkr 14,191' I=111•1 - 0 SAND PERFORATION SUMMARY I = - 3.5" HES 250 micron poroplus screens SIZE SPF INTERVAL TVD I MIMI (4- Joints) 1 4,234' - 4,359' 5 4,424' - 4,455' 3,958' - 3,988' - 5 4,486' 4,510' 4,017' 4,040' - HES Collet guide & seal assem. 1 4,422' 5 spf , 37 gm � 7" Otis "AWD" Sump Pkr (4.0" ID) 4,398' 3.5" Otis X- Nipple ( 2.313" id) 4,415' WLEG 4,426' 7" Shoe 14,741' 1 DATE REV. BY COMMENTS MILNE POINT UNIT 3/7/91 Completed- Conoco 10/5/95 12/14/97 07/30/02 ESP RWO WELL 1 -03 5/06/03 REH RWO 4 S /0 ESP /HT Screens 4 -es API NO: 50- 029 -22067 5/2/09 REH ESP RWO - Nabors 3S 4/05/13 B. Kruskie Doyon 16 BP EXPLORATION (AK) STATE OF ALASKA A~ OIL AND GAS CONSERVATION C011~SION REP6RT OF SUNDRY WELL OPERATIONS ~A~~ S/a~ o~ ~~ !~ AY 1 5 ~ ~ (~ ~3 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ~~i~ih~r~~Ande6e~lss ^ Alter Casing ®Pull Tubing , ^ Perforate New Pool ^ Waiver ®Other Anchorage ^ Change Approved Program ^ Operation Shutdown Change Out ESP - ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. . ®Development ^ Exploratory 190-092 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22067-00-00 - 7. KB Elevation (ft): 70 0 9. Well Name and Number: MPI-03 , 8. Property Designation: 10. Field /Pool(s): _ ADL 025906 , Milne Point Unit ! Kuparuk River Sands 11. Present well condition summary Total depth: measured 4750 - feet true vertical 4271 - feet Plugs (measured) None Effective depth: measured 4659 feet Junk (measured) None true vertical 4184 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 115' "°1'15' 1740 750 Surface 2598' 9-5/8" 2633' 2399' 3520 2020 Intermediate Production 4671' 7" 4741' 4262' 7240 5410 Liner ~~~`` t ~ 1~~ ~. 4} ~~~~ Perforation Depth MD (ft): 4260' - 4510' Perforation Depth TVD (tt): 3802' - 4041' 2-7/8", 6.5# L-80 4110' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Gravel Pack screen assembly with 7" HES VTA Versa- 4191' Trieve Packer and 7" Otis AWD Sump packer 4398' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 380 0 Subsequent to operation: 138 32 5 290 288 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram -® Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N!A if C.O. Exempt: Contact Mehrdad Nadem, 564-5941 N/A Printed Name ondra Stewman Title Drilling Technologist Prepared By Name/Number: 'gnature Phone 564-4750 Dat '~ Sondra Stewman, 564-4750 Form 1 rev Submit Original Only o~~~~~~ d3t! TREE: 2-9/16" - 5M WKM M P I ~O~ Orig. - SL = 72' (NABOBS 27E) WELLHEAD: 11" 5M WKM w/ Orig. KB - GL = 37' (NABOBS 27E 2-7/8" 8rd TREE TOP CONNECTIO 2 1/2" "H" Profile. 13 3/8", 48#/ft, Camco 2-7/8" x 1" 139' I sidepocket KBMM GLM Squeeze perfs: - 2,060' - 2,062' 9 5/8", 36#/ft, J-55 Butt. 2,633' KOP @ 500' Max. Hole angle @ 37 deg. @ 3170' Centrilift Heat trace installed 3,450' to Surface 2-7/8", 6.5 ppf, L-80 EUE 8rd ( drift ID =2.347", Cap. =.0058 bpf) 7" 26 ppf, L-80, Butt. casing, ( drift ID = 6.276", cap. = 0.0383 bpf ) N SAND PERFORATION SUMMARY SIZE SPF INTERVAL TVD 24 4,260' - 4,280' 3,801' - 3,820' 24 4,292' - 4,304' 3,832' - 3,843' 24 4,322' - 4,328' 3,860' - 3,866' 24 4,344` - 4,378' 3,882` - 3,915' 24 spf , 24 gm O SAND PERFORATION SUMMARY SIZE SPF INTERVAL TVD 5 4,424' - 4,455' 3,958' - 3,988' 5 4,486' - 4,510' 4,017' - 4,040' 5spf,37gm DATE REV. BY COMMENTS 3/7/91 Completed-Conoco 10/5/95 12/14/97 07/30/02 ESP RWO 5/06/03 1 MDO R H RWO & Replace Screens 4-es R HT 5/2/09 REH ESP RWO -Nabors 3S Camco 2-7/8" x 1" ' sidepocket KBMM GLM 3,911 HES 2-7/8" XN-Nipple (2.25" No-Go) 4,052' Centrilift Pump: SXD 124-P4 4,065' Gas Separator - GRSFTX AR H6 4,079' Centrilift Tandem Seal Section 4 085' Model GSB3DBUT/LT SB/SB PFSA , Centrilift Motor: KMH 76 HP 4,098' 1360 VOLTS/34 AMP Berated to KMH-A / 55hp /1259v/26a Centrilift Pump mate 4106' 7" HES "VTA" Retrievable Pkr 4,191' ' 3.5" HES 250 micron poroplus screens ( 4-Joints) 4,234' - 4,359' HES Collet guide & seal assem. 4,422' 7" Otis "AWD" Sump Pkr (4.0" ID) 4,398' 3.5" Otis X-Nipple (2.313" id) 4,415' WLEG 4,426` 7" Shoe 4,741` MILNE POINT UNIT WELL 1-03 API NO: 50-029-22067 BP EXPLORATION (AK) • MPI-03 Well History Date Summary • 03/21/09 CTU #5 w/ 1.75" OD CT. MIRU CTU. MU and RIH SLB 2.0" JSN. Tag ESP at 4061' CTM. Jet from top of tag to surface. Recieve Well fluid on return tank. Continue washing until there are clean returns on tank. Pull to surface washing tubing. RBIH and spot 11.4 bbls 10% DAD acid on the ESP. Attempt to squeeze acid through ESP; unable to establish infectivity. Hold 2500 psi WHP and let acid soak. Attempt to start pump; Pump will run, but will not surface fluids. Bump ESP. ESP will still not surface fluids. Confer with MP PE and Centrilift. Circulate acid OOH. Job continued on WSR 03/22/09. 03/22/09 CTU #5 w/ 1.75" OD CT. Freeze protect wellbore. Pull to surface. Elect not to run tubing punch as per MP PE. RDMO CTU. Job complete. 03/23/09 Flush production line w/ 2 bbls 60/40 meth, 3 bbls 90" diesel, & 2 bbls 60/40 meth. Flush test line w/ 2 bbls 60/40 meth, 3 bbls 90* diesel, & 2 bbls 60/40 03/27/09 "*"WELL S/I ON ARRIVAL*"" (prep rwo ) RIH WITH 2.5 OK-1, 1 1/4" JD, TO PULL STA #1 03/28/09 PULL BK-DGLV FROM 3910' MD »»»»POCKET LEFT OPEN««««< RAN DUAL SPARTEK GUAGES PER PROGRAM (SEE LOG) 03/28/09 T/1= 50/400/0 Freeze protect tubing with 15 bbls diesel. Pumped 15 bbls down TBG, Final WHP's 300/550/0 "Valve position C~ departure- Swab, Wing, SSV= SI /Master, IA & OA=Open" 04/06/09 MPU Well ST Demobed, removed Well house, SET BPV, flushed the flowlines, removed flowlines. C/O wing valve from actuated to a manuel, installed blinds and removed foundation. Note: There was a charge of $12724.12 for the Lubricator Yoke for MPU for rig work overs, per MPU Wells OP CORD Rc,b Handv. 04/30/09 T/I/O=0/0/0 Assist Nabors 3S Acid Treatment/ Job has been cancelled per PE. RDMO to next job. 05/02/09 MPU well ST Rehook, Set foundation flow lines were TQ to spec. well house set ,Used triplex to PT flowlines test and production to 1150 psi with diesel ,then bleed pressure down to zero. NOTE: BPV removed ~. 05/03/09 T/I/0=0/0/0 Freeze protect Tbg and IA. post RWO. Pump 15 bbls crude down Tbg. Pump 65 bbls crude ~ down IA FWHP=O/0/0 Master and IA open. OA under Ice. Wing, Swab, and SSV closed. ~~ Page 1 of 1 • BP EXPLORATION Operations Summary Report Legal Well Name: MPI-03 Common Well Name: MPI-03 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 3S Date. ', From - To Hours Task Code', NPT __ 4/26/2009 03:00 - 06:00 _ 3.00 MOB X WAIT 06:00 - 10:00 4.00 RIGD P 10:00 - 14:00 4.00 MOB P 14:00 - 16:30 I 2.501 MOB I P 16:30 - 18:00 I 1.501 MOB I P 18:00 - 00:00 ~ 6.00 MOB ~ P 4/27/2009 100:00 - 02:00 I 2.001 RIGD I P 02:00 - 04:00 2.00 RIGD P 04:00 - 07:30 3.50 RIGD P 07:30 - 09:30 ~ 2.00 ~ W HSUR ~ P 09:30 - 11:30 2.00 I W HSUR I P 11:30 - 16:30 I 5.001 KILL I P 16:30 - 17:30 1.00 WHSUR P 17:30 - 19:00 1.50 WHSUR P Start: 4/27/2009 Rig Release: 5/2/2009 Rig Number: Page 1 of 4 ~ Spud Date: 11 /5/1990 End: 5/2/2009 Phase Description of Operations PRE Wait on trucks to move rig from C-01 to I-03. Maintenance rig. (Trucks unavailable due to other rigs moving at same time). Make move with fewer trucks than normal. PRE Scope down and lower Derrick, RD camp units for move. PRE Move Rig camp and support units and Pipe shed from MPC-Pad to MPI-Pad. Spot units in place. PRE Move Rig Carrier off MPC-01, WSL and Pad operator present at 1500 hrs. PRE Move Rig carrier and pits from MPC-Pad to MPI-Pad, on location at 16:30 hrs. Set mats under camp, spot BOP'S behind well. PRE Dry spot carrier over well, pull off and set mats and herculite. Set kill manifold in cellar. Spot carrier over well. (Pad operator and WSL witnessed). Spot pipe shed and pits. PRE Secure stairs and hand rails on complexes. Connect service lines and electrical lines. Service crown and perform derrick inspection. PRE Build berm for upright tank and spot tank in berm. Raise and scope derrick up. PRE Reposition (level) carrier over well. Rig accepted at 0730 hrs 4/27/2009. DECOMP PU/MU and test lubricator with diesel to 500 psi. Pull BPV. s u ing = 50, IA=500, A=0 psi. DECOMP RU kill manifold to Tree and hard fine to Tiger tank. Pressure test surface lines to 3,500 psi and hard line to Tiger tank to 500 psi. DECOMP Held crew pre-kill meeting. Bleed IA from 500 to 430psi, tubing to 0 psi. Circulate 25 bbls heated 8.45 ppg seawater down the tubing up the IA through the choke to the Tiger tank. Shut-in 15 minutes 0 psi on tubing and 50 psi on IA. Open the choke and continue to circulate 151 bbls seawater down the tubing up the IA through the choke to the Tiger tank. Reverse circulate 155 bbls seawater down the IA up the tubing through open choke to the Tiger tank at 3 bpm / 240 psi. Lost 83 bbls to formation. Tubing and IA on a slight vacuum. DECOMP D rod TWC with Cameron wellhead tech. DECOMP Pressure test TWC from above to 3,500_psi for 10 charted minutes. Test from below to 500 psi for 10 charted minutes pumping 2.5 BPM used 37 bbls to obtain test. Blow down 19:00-21:00 I 2.001 WHSURIP 21:00 - 00:00 ~ 3.00 ~ BOPSUF( P 4/28/2009 ~ 00:00 - 04:00 ~ 4.00 ~ BOPSUf~ P 04:00 - 06:00 2.00 BOPSUF( P 06:00 - 12:30 6.50 BOPSU N lines. DECOMP N/D tree and adapter flange. LDS in = 3", LDS out = 3-1/2", Alignment pin in = 3/4", out = 1-3/4". Make up UJ to x-o and make dummy run to 22.50' and mark UJ. (8-1/2 turns) DECOMP Slide BOP craddle into cellar. (Due to close proximity to flow lines). Raise BOP'S from craddle and set DSA and N/U BOP'S. DECOMP Continue N/U BOP'S. Hook up koomey lines, turn buckles, and riser. Gravity feed IA with seawater C~? 6 bbls per hour during N/U. DECOMP Function test BOPE and conduct initial BOPE test 250 psi low / 3 500 si hi h. HCR choke valve failed. DECOMP Remove failed HCR choke valve and replace with new rebuild valve from Nabors yard. Printed: 5/11/2009 10:32:25 AM • BP EXPLORATION Page 2 of 4 Operations Summary Report Legal Well Name: MPI-03 Common Well Name: MPI-03 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 3S bate From - To Hours Task. Code NPT Spud Date: 11/5/1990 Start: 4/27/2009 End: 5/2/2009 Rig Release: 5/2/2009 Rig Number: Phase Description of Operations 4/28/2009 12:30 - 18:00 8:00 - 19:00 19:00 - 20:00 5.50 .00 1.00 BOPSU OPSU WHSUR P P P DECOMP ECOMP DECOMP Conduct initial BOPE test 250 psi low / 3,500 psi high. Test with 2-7/8" test joint on 2-7/8" x 5" VBR and annular preventer. Test witnessed by Nabors Tourpusher. AOGCC rep Bob Noble waived the state's right to witness on 4-27-09 at 1800 hrs and again at 0600 4-28-09. Gravity feed IA with seawater C~3 6 bbls per hour during test. Crew change and make pre-tour inspections. Blown down lines and void BOP stack. MU and test O so Lo so /lubricator with diesel to 500 si. Pull TWC with well support techs. Tubing on a vacuum. 20:00 - 21:00 1.00 WHSUR P DECOMP MU landing joint with TIW safety valve and circulating hose and screw into tubing hanger. 21:00 - 23:30 2.50 W HSUR P DECOMP Circulate 193 bbls seawater down the tubing at 3 bpm / 230 psi through the choke to Pits. Obtain returns after oumoina 34 bbls, lost 24 bbls during circulation. Tubing and IA on a slight vacuum. 23:30 - 00:00 0.50 WHSUR P DECOMP Cameron wellhead techs BOLDS. Pull tubing hanger with 42 000 PUW. 4/29/2009 00:00 - 00:30 0.50 PULL P DECOMP Hang ESP cable trunk in Derrick. 00:30 - 01:30 1.00 PULL P DECOMP BO/LD landing joint and tubing hanger. Remove ESP /Heat Trace Penetraters from tubing hanger. 01:30 - 04:30 3.00 PULL P DECOMP POH and UD 13 joints, 10' pup and one GLM. Snake ESP and Heat Trace cable over double sheave in Derrick and attach to reel in spooling unit. 04:30 - 06:00 1.50 PULL P DECOMP Continue to POH with ESP /Heat Trace and stand in Derrick, with continuous hole fill and a loss rate of -15 bph. 06:00 - 07:00 1.00 PULL P DECOMP Clean and clear Rig floor. 07:00 - 07:30 0.50 PULL P DECOMP Service Rig. 07:30 - 13:00 5.50 PULL P DECOMP Continue to POH to the end of Heat Trace at 3,465'. 13:00 - 15:00 2.00 PULL P DECOMP Snake Heat Trace over sheave in Derrick to spooling unit. Clean and clear Rig floor. 15:00 - 16:00 1.00 PULL P DECOMP Continue to POH. Total of 127 joints, two GLM's, XN. Recovered 16 -LaSalle clamps, 545- Eft and 33 -Oft Flat guards, Bands. 16:00 - 17:00 1.00 PULL P DECOMP BO / LD and drain ESP pump and motor assembly. Pump locked up. 17:00 - 18:30 1.50 PULL P DECOMP Held meetings with both crews along with the Nabors and ADW superintendents and the Nabors 3S rig leadership team. Discussed overall performance of the rig and the current economic challenges. 18:30 - 19:00 0.50 PULL P D ECOMP Crew change, perform pre-tour check. 19:00 - 20:30 1.50 PULL P D ECOMP Continue to BO / LD ESP assembly. 20:30 - 22:30 2.00 PULL P D ECOMP Clean and clear Rig floor, remove Centrilift tools and PU 1-1/4" C S H dril i e handlin a ui ment to Ri floor. 22:30 - 00:00 1.50 CLEAN P C LEAN PU / MU 1-1/4 "mule shoe and 20 joints of C S H dril i e. 4/30/2009 00:00 - 01:00 1.00 CLEAN P C LEAN Continue to PU / MU 20 joints of 1-1/4" C S Hydril pipe. 01:00 - 04:00 3.00 CLEAN P C LEAN RIH with 1-1/4" Mule shoe stinger on 2-7/8" tubing from Derrick to 4204' MD. PUW = 26,000K, SOW = 24,000K. 04:00 - 05:30 1.50 CLEAN P C LEAN PU singles from pipe shed and tag at 4,510' MD. Lay down 1 joint of 2-7/8" tubing. 05:30 - 07:30 2.00 CLEAN P C LEAN Reverse circulate a 15 bbl Flow-vis sweep at 2 bpm / 240 psi at 4,485' MD. Establish rate and pressure at 1 bpm / 130 psi as well so we have baseline pressures and rates. Average losses Printed: 5/11/2009 10:32:25 AM • BP EXPLORATION Page 3 of 4 Operations Summary Report Legal Well Name: MPI-03 Common Well Name: MPI-03 Spud Date: 11/5/1990 Event Name: WORKOVER Start: 4/27/2009 End: 5/2/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/2/2009 Rig Name: NABOBS 3S Rig Number: Date .From - To I Hours Task Code N'PT ~ Phase Description of Operations 4/30/2009 05:30 - 07:30 2.00 CLEAN P CLEAN Burin reverse circulation were -30 bbls per hour. Start getting the sweep back on surface after 133 bbls pumped. No fil_ I__r 07:30 - 10:00 2.50 CLEAN N CLEAN Monitor hourly loss rate while waiting on acid to arrive on location. First hourly loss rate was 10 bbls per hour. Next one observed at 6 bbls per hour. Consult with Anchorage Engineering on whether or not the acid job should be completed due to the well drinking and tagging at 4,510' (bottom most pert and 150' below the screens). Schlumberger acid truck delayed out of Prudhoe due to lack of drivers at C-Pad Warehouse. All drivers are out with de-watering projects due to spring break-up. Unsure when the acid may be ready, decision made to abort the acid iob by Anchoraae 10:00 - 14:30 4.50 CLEAN P CLEAN POOH with 1-1/4" Muleshoe stinger on 2-7/8" Tubing standing back in the Derrick. Maintain continuous hole fill with seawater while POOH and average loss rate of 10 bbls per hour. Break out and lay down 20 Joints of 1-1/4" CS Hydril Pipe and 1-1/4" Muleshoe. 14:30 - 15:00 0.50 CLEAN P CLEAN RD 1-1/4" Handling Equipment. Clear and clean Rig Floor. 15:00 - 16:30 1.50 BUNCO P RUNCMP PU Landing Joint and Hanger with Cameron reps. Perform dummy run of WKM hanger and land in wellhead. RILDS to confirm everything is OK. Pull the Hanger and lay down. Re-dress the Hanger. Lay down Landing Joint. 16:30 - 17:00 0.50 BUNCO P RUNCMP Hold pre-run completion safety meeting with the crew and Centrilift rep. 17:00 - 20:00 3.00 BUNCO P RUNCMP PU/MU service ESP motor and um assembl .Maintain continuous hole fill with seawater while RIH and average loss rate of 12 bbls per hour. 20:00 - 21:00 1.00 BUNCO P RUNCMP RIH from Derrick with ESP on 2-7/8", 6.5# I-80, 8rd, EUE tubing and start Heat trace Joint #19 RIH. LaSalle clamps installed on every joint until the start of heat trace on Joint #19 in the hole. 21:00 - 00:00 3.00 BUNCO RUNCMP Continue RIH from Derrick to 44 joints at 00:00 hours. Fill and flush pump with 10 bbls seawater at 0.4 spm / 1350 psi. 5/1/2009 00:00 - 12:30 12.50 BUNCO RUNCMP Continue RIH from Derrick with ESP on 2-7/8", 6.5# L-80, 8rd, EUE tubing from 44 joints. Maintain continuous hole fill with seawater while RIH and average loss rate of 10 bbls per hour. 94 joints ran at 0600 hours. Ran a total of 127 Joints of 2-7/8" Tubing. Perform final flush of ESP with 10 bbls of seawater down the Tubing at a rate of 0.4 bpm / 1,350 psi. 12:30 - 13:30 1.00 BUNCO P RUNCMP PUMU Tubing Hanger and Landing Joint. Align Hanger with Cameron rep. Install Penetrators with shipping caps. Establish final PUW = 40K ,SOW = 33K. 13:30 - 18:00 4.50 BUNCO RUNCMP Perform field connection splices of both the heat trace and ESP cables with Centrilift reps. 18:00 - 19:00 1.00 BUNCO RUNCMP Land tubing hanger and Cameron well head tech RILDS. BO/LD landing joint. 19:00 - 20:30 1.50 BUNCO P RUNCMP Dry rod TWC with Cameron welt head tech. Test TWC from above to 3,500 si for 10 charted minutes. Test from below with LRS by injecting 41 bbls seawater into formation at 2.3 b m / 500 si for 10 charted minutes. 20:30 - 00:00 3.50 BOPSU P RUNCMP Blow down lines and void BOP stack of fluid, ND BOPE and Printed: 5/11/2009 10:32:25 AM BP EXPLORATION Page 4 of 4 ~ Operations. Summary Report Legal Well Name: MPI-03 Common Well Name: MPI-03 Spud Date: 11/5/1990 Event Name: WORKOVER Start: 4/27/2009 End: 5/2/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/2/2009 Rig Name: NABOBS 3S Rig Number: i Hours Task Code- NPT Phase Description of Operations Date From -To ': - _ _ ' _ - -_- - - _ _ __ 5/1/2009 20:30 - 00:00 3.50 BOPSU P RUNCMP DSA. Lay down BOP into cradle and remove from cellar. 5/2/2009 00:00 - 01:30 1.50 WHSUR P WHDTRE NU production tree. 01:30 - 02:30 1.00 WHSUR P WHDTRE Cameron well head tech tested hanger void to 5,000 psi for 30 minutes. Test tree with diesel to 5,000 psi. Centrilift rep take final readings on both cables. ESP cable: phase to phase = 2.0 Ohms ,phase to ground = 4 Gig-Ohms ,intake pressure = 1536 psi ,intake temp = 69.7 degF ,motor temp = 69.4 degF. Heat trace cable: phase to phase = 3.8 Ohms ,phase to ground = 10 Meg-Ohms. 02:30 - 03:30 1.00 WHSUR P WHDTRE Wait on evaluation of final reading on Heat trace from Centrilift Anchorage Alliance coordinator. 03:30 - 04:30 1.00 WHSUR P WHDTRE Remove second annulus valve. 04:30 - 06:00 1.50 WHSUR P WHDTRE PU/MU and test lubricator to 500 psi with diesel. Pull TWC, se hours 5/2/2009. Printed: 5/11/2009 10:32:25 AM STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION ROPE Test Report Submit to: ' Contractor: Nabors Rig Rep.: G. Sweatt i J. Fritts Operator: BP Rep.: W. Hoffman / D. Rhodes Field/Unit 8. Well No.: MPU I - 03 Operation: Drlg: Test: Infial: X Test Pressure: Rams: 250/3500 Rig No.: 3S DATE: 4/28/2009 Rig Phone: 659-4487 Rig Fax: 659-4486 Op. Phone: 659-4485 Op. Fax: 659-4628 PTD ~ 1900920 Workover: X Explor.: Weeky: Bi-Weekly Annular: 250/3500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantify Test Result Location Gen.: P Well Sign P Upper Kelly 0 NA Housekeeping: P Dri. Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result CHOKE MANIFOLD: Annular Preventer 1 13 5/8 5m P Quantity Test Result Pipe Rams 1 2 7/8 X 5 P No. Valves 13 P Lower Pipe Rams 0 NA Manual Chokes 1 P Blind Rams 1 Blind P Hydraulic Chokes 1 P Choke Ln. VaMes 1 3118" 5m FP HCR Valves 1 21/16" 5m P ACCUMULATOR SYSTEM: Kill Line Valves 1 21/16" 5m P Time/Pressure Test ResuRk Check Valve 0 NA System Pressure 3000 P Pressure After Closure 1800 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 35 sec P Trip Tank P P Fula Pressure Attained 2 min 35 sec P Pit Level Indicators P P Bid Switch Covers: AN stations P Flow Indicator P P Nitgn. Bottles (avg): 2050 psi Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 1 Test Time: 6_5 Hours Components tested ALL Repair or replacement of ecment will be made with days.. Notify the North Slope Inspector 659-3607, fo~wnr wish written confrmation to Superviser at: Remarks: Choke HCR failed. replaced with new ~, test ok. 24 HOUR NOTICE GIVEN YES x NO Date 04!27/09 Time 6:00 est start 12:30 Finish BOP Test (for rigs) / v~.r'a~C~ws*% .~1~~ 'n~ ~~L BFL 11!14/07 ` By Bob Nobel Witness G.Sweatt f D.Rhodes Nabors 3S BOP Test MPU I - 03 4-28-2009 .xls r,» . STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COMrmlON REPORT OF SUNDRY WELL OPERATIONS RECE'VED c T 1 2 2006 & Gas Cons. Commission 1. Operations Performed: Ancnorage o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver ~ Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 190-092 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22067 -00-00 7. KB Elevation (ft): 70.0 9. Well Name and Number: MPI-03 8. Property Designation: 10. Field / Pool(s): ADL 025906 Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 4750 feet true vertical 4271 feet Plugs (measured) None Effective depth: measured 4659 feet Junk (measured) None true vertical 4184 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 115' 115' 1740 750 Surface 2598' 9-5/8" 2633' 2399' 3520 2020 Intermediate Production 4671' 7" 4741' 4262' 7240 5410 Liner 'ôQ!\N ~H:;jJ ~± r· i . '. ""\":.'''''''Ií¡iir':':'''Y \./ Perforation Depth MD (ft): 4424' - 4510' Perforation Depth TVD (ft): 3802' - 4041' 2-7/8",6.5# L-80 4110' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Gravel Pack screen assembly ~th.7:: HES VTA Versa- 4191' Trieve Packer and 7" Otis AWD Sump packer 4398' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 RBDMS BFt OCT 1 7 Z006 Printed Name Sondra Stewman Title Technical Assistant ~':'I~dY" ~ Prepared By Name/Number: . ignature I .,(L Ai.. ) J "i( Phone 564-4750 Date \O~lZ:-CCÇSondra Stewman, 564-4750 . . Form 10-404 Revised 04/2006 0 R , G \ N A L Submit Onglnal Only TREE: 2-9/16" - 5M WK WELLHEAD: 11" 5M WKM wi 2-7/8" 8rd TREE TOP CONNECTIO 2 1/2" "H" Profile. 13 3/8", 48#/ft, I 115' 1- 95/8", 36#/ft, J-55 Butt. I 2,633' I KOP @ 500' Max. Hole angle @ 37 deg. @ 3170' 2-7/8", 6.5 ppf, L-80 EUE 8 rd ( drift 10 =2.347", Cap. =.0058 bpf) 7" 26 ppf, L-80, Butt. casing, ( drift 10 = 6.276", cap. = 0.0383 bpf ) N SAND PERFORATION SUMMARY SIZE SPF INTERVAL TVD 3,801' - 3,820' 3,832' - 3,843' 3,860' - 3,866' 3,882' - 3,915' 24 4,260' - 4,280' 24 4,292' - 4,304' 24 4,322' - 4,328' 24 4,344' - 4,378' 24 spf , 24 gm o SAND PERFORATION SUMMARY SIZE SPF INTERVAL TVO 5 4,424' - 4,455' 3,958' - 3,988' 5 4,486' - 4,510' 4,017' - 4,040' 5 spf , 37 gm MPI-03 Ori - SL = 72' (NABORS 27E) Orig. B - GL = 37' (NABORS 27E Camco 2-7/8" x 1" sidepocket KBMM GLM 138' I Squeeze perfs: 2,060' - 2,062' Centrilift Heat trace installed 3,465' to Surface Cameo 2-7/8" x 1" sidepocket KBMM GLM 3,910' I HES 2-7/8" XN-Nipple (2.205" No-Go) 4,051' Centrilift Pump: SSD 146 400P6 4,065' Centrilift Tandem Seal Section I I Model GSB3DBFERHLSSCV H6SB/SB PFSA 4,085' GSB3DBFERHLSSCV H6SB/SB PFSA Centrilift Motor: KMHG 76 HP 1360 VOL TS/34 AMP I 4,098'1 I 4106' I Centrilift Pump mate 7" HES "VTA" Retrievable Pkr 14,191'1 3.5" HES 250 micron poroplus screens ( 4-Joints ) I 4,234' - 4,359' I HES Collet guide & seal assem. 7" Otis "AWD" Sump Pkr (4.0" ID) 3.5" Otis X-Nipple (2.313" id ) 14,422'1 4,398' 4,415' 4,426' WLEG 7" Shoe 14,741' I DATE REV. BY COMMENTS MILNE POINT UNIT 3/7/91 Completed-Conoco WELL 1-03 1 0/5/95 12/14/97 07/30/02 ESP RWO API NO: 50-029-22067 5/06/03 MOO RWO & Replace Screens 4-es 10/07/06 REH RWO 4ES C/O ESP/HT BP EXPLORATION (AK) .e /' . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-03 MPI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1 0/2/2006 Rig Release: 10/5/2006 Rig Number: 4ES Spud Date: 11/5/1990 End: 10/5/2006 10/2/2006 06:00 - 08:30 2.50 RrGD P PRE Scope down and Lower Derrick. Rig-down Pipe shed Pits and Camp. Received orders to move to MPI-03 instead of MPF-78. 08:30 - 10:00 1.50 MOB P PRE Move Rig and Modules from MPH-Pad to MPI-03 Well slot. 10:00 - 11 :30 1.50 MOB P PRE Lay Herculite and Rig Mats. Spot Sub Base over Well. 11 :30 - 12:30 1.00 MOB P PRE Continue rig-up. Spot Pipe shed, Pits, and Camp. Wait on additional equipment that had already been moved to MPF-78. 12:30 - 14:00 1.50 MOB P PRE Raise and scope Derrick. Take on hot Sea Water in Pits. Spot tiger Tank and lay lines. Accepted Rig at 14:00 hrs. 14:00 - 16:30 2.00 MOB P PRE Continue to take on hot Sea Water. 16:30 - 17:00 0.50 WHSUR DECOMP P/U lubricator & pull BPV. UD plug & lubricator. 17:00 - 17:30 0.50 WHSUR OECOMP Pressure test all kill lines & connections to 3500 psi. 17:30 - 18:00 0.50 PULL P DECOMP Hold PJSM & pre-tour mtg. Hold Pre-Spud mtg wi all hands. Review well kill procedures. 18:00 - 18:30 0.50 PULL P DECOMP Service rig. Inspect derrick. 18:30 - 20:00 1.50 KILL P DECOMP Kill well. SITP 1040 psi, SICP 1100 psi. Open well & bleed off pressure to 50 psi. Begin killing well. Pumped 3 BPM & increased to 5 BPM. Pressure 450 psi. IA 0 psi. Hit fluid after 98 bbls. Decreased pump to 4 BPM @ 530 psi. IA 210 psi. Had oil returns after 123 bbls. Pumped 150 bbls & still getting diesel returns. Con't pumping till 239 bbls. Getting 99% hot seawater returns. S/O. Tbg & IA bled down to 0 psi. Well dead. Recovered 138 bbls in Tiger tank. 20:00 - 20:30 0.50 KILL P DECOMP Monitor well, well dead. 20:30 - 21 :30 1.00 WHSUR P DECOMP Dry rod TWC in hanger by Cameron personnel. Test TWC from bottom, pumped 2 BPM & increased to 3BPM. for 10 min. Max. injection pressure 440 psi. Pressure up on top of TWC to 3700 psi & test for 10 min. Charted tests. RIO test equip. 21 :30 - 23:00 1.50 WHSUR P DECOMP Bleed off hanger void. N/D Tree & adapter flange. 23:00 - 00:00 1.00 BOPSU P DECOMP N/U DSA flange & BOPE. 10/3/2006 00:00 - 00:30 0.50 BOPSU P DECOMP N/U BOPE. 00:30 - 04:00 3.50 BOPSU P DECOMP RlU test equip. Test BOPE as per AOGCC I BP requirements. LP 250 psi. HP 3500 psi. BOP test witnessing waived by John Spaulding wi AOGCC. No failures. 04:00 - 05:00 1.00 WHSUR P DECOMP RID test equip.P/U lubricator & pull TWC. UD TWC & lubricator. 05:00 - 05:30 0.50 PULL P DECOMP M/U landing jt. Pull hanger to floor. Broke free wI 58K. P/U weight dropped to 47K. Break out & UD hanger. 05:30 - 06:00 0.50 PULL P DECOMP M/U circulating head. Break circulation 3 BPM @ 200 psi. Took 21 bbls to fill hole. Calc. FL @ 700'. Circulate bottoms up. 06:00 - 07:30 1.50 PULL P DECOMP Circulate Well at 3.0 bpm/200 psi. Monitor Well dead. Rig-down circulating equipment, Landing Joint, and tubing Hanger. 07:30 - 08:00 0.50 PULL P DECOMP Lub Rig. Inspect Derrick. Flow check Well = 12 bbls to fill. 08:00 - 14:00 6.00 PULL P DECOMP Trip-out with 2 7/8" ESP/HT Completion. Tubing looked good. Pulled 127 jts total. 14:00 - 17:30 3.50 PULL P DECOMP Inspect and lay down ESP Assembly. Pump was locked-up. Scale build-up on one side of ESP Assembly. Tally CS Hy-Drill Tubing 17:30 - 18:00 0.50 PULL P DECOMP Clear & clean rig floor. 18:00 - 18:30 0.50 PULL P DECOMP Service rig, Check PVT & inspect dderrick. 18:30 - 19:00 0.50 PULL P DECOMP Finish cleaning rig floor. Much heavy oil from completion. 19:00 - 20:30 1.50 PULL P DECOMP P/U & M/U BHA #1 as follows: Mule Shoe, 19 . 1 1/4" CS-HYO OP, XO, XO. TL = 611.34'. Printed: 10/9/2006 10:34:48 AM ,j . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-03 MPI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1 0/2/2006 Rig Release: 10/5/2006 Rig Number: 4ES Spud Date: 11/5/1990 End: 10/5/2006 10/3/2006 20:30 - 23:00 2.50 PULL P DECOMP RIH wI BHA #1 on stands of 2 7/8" DP. Tagged top of HES "VTA" Packer @ 4159' (32' high) Rotate string & drop thru. Con't to RIH & tagged fill @ 4616' (106' below bottom of "0" perfs). 23:00 - 23:30 0.50 PULL P DECOMP UD 3 singles & stand back 4 stands of tubing. M/U circulating head. 23:30 - 00:00 0.50 PULL P DECOMP Circulate well. 3 BPM @ 1100 psi. Had 100% oil returns initially. 10/4/2006 00:00 - 01 :00 1.00 PULL P DECOMP Con't to circulate & clean up well bore. Pumped 3 BPM @ 1100 psi. Pumped total of 170 bbls. Lost 17 bbl while circulating. 01 :00 - 02:00 1.00 PULL P DECOMP POOH & stand back 42 stands of 2 7/8" tubing. 02:00 - 03:00 1.00 PULL P DECOMP POOH & UD BHA # 1 BHA covered wi heavy black oil. 03:00 - 04:00 1.00 RUNCO RUNCMP Clear & clean rig floor. R/U to P/U ESP & run completion. 04:00 - 06:00 2.00 RUNCO RUNCMP P/U. M/U & service ESP. 06:00 - 06:30 0.50 RUNCO RUNCMP Finish servicing ESP Assembly. Attach ESP Cable to Motor and test. 06:30 - 07:00 0.50 RUNCO RUNCMP Service Rig. Organize Floor to run 2 7/8" ESPIHT Completion. 07:00 - 08:00 1.00 RUNCO RUNCMP Start running ESP Assembly and ESP Cable. 08:00 - 23:30 15.50 RUNCO RUNCMP Begin with Heat Trace Cable. Continue running 2 7/8" ESPIHT Completion. Ran 127 jts. 42 stands + 1 single. bottom of string @ 4110' Pump intake @ 4080'. Test heat trace every 1000'. Test ESP cable & clear pump every 2000'. Heat trace started @ bottom of 36th stand ( 3435'). 23:30 - 00:00 0.50 RUNCO RUNCMP Make field splice on ESP. 10/5/2006 00:00 - 04:00 4.00 RUNCO RUNCMP Finish making field splice to ESP & Make HT splice. Test same. 04:00 - 05:00 1.00 RUNCO RUNCMP Land tubing hanger & completion. RILDS. P/U wt = 44K 5/0 Wt = 39K. Used: 16 LaSalle Clamps, 2 Flat Guards, 5 Protectolizers. Heat Trace Used: 533 - 6" Flat Guards, 44 - 4' Flat Guards. 05:00 - 05:30 0.50 WHSUR P RUNCMP Dry Rod TWC in tubing hanger. 05:30 - 06:00 0.50 WHSUR P RUNCMP Test from top 3500 psi. Test from bottom 3 BPM @ 500 psi. 06:00 - 07:30 1.50 BOPSU P RUNCMP Nipple down BOP Stack. 07:30 - 08:30 1.00 WHSUR P RUNCMP Nipple -up Production Tree. 08:30 - 09:30 1.00 WHSUR P RUNCMP Test Hanger void and Production Tree to 5,000 psV30 minutes. Good test. Perform final ESP/HT checks. ESP Cable: 2.1 ohms PIP Balance. 2.8 Gigs. HT Cable: 4.0 ohms PIP Balance. 3.0 Gigs. PI = 1479 psi, TM = 73 degs F., TI = 74 degs F. 09:30 - 10:30 1.00 WHSUR P RUNCMP Pick-up Lubricator. Pull TWC. Lay down same. 10:30 - 11 :00 0.50 RIGD P RUNCMP Secure Cellar area. Release Rig at 11 :00 hrs. Printed: 10/9/2006 10:34:48 AM STATE OF ALASKA ~' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2945' SNL, 3816' WEL, SEC. 33, T13N, R10E, UM At top of productive interval 4559' SNL, 3270' WEL, SEC. 33, T13N, R10E, UM At effective depth 4671' SNL, 3240' WEL, SEC. 33, T13N, R10E, UM At total depth 4697' SNL, 3233' WEL, SEC. 33, T13N, R10E, UM Change Out ESP 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service X = 551555, Y = 6009450 X = 552116, Y = 6007839 X = 552147, Y = 6007727 X = 552154, Y = 6007704 6. Datum Elevation (DF or KB) KBE = 7O' 7. Unit or Property Name Milne Point Unit 8. Well Number MPI-03 9. Permit Number/ Approval No. 190-092 10. APl Number 50- 029-22067-00 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 4750 feet 4270 feet 4659 feet 4184 feet Length Size Structural Conductor 80' 13-3/8" Surface 2598' 9-5/8" Intermediate Production 4706' 7" Liner Plugs (measured) Junk (measured) Cemented MD TVD 485 sx Permafrost 'C' 115' 115' 247 sx Class 'E', 942 sx Class 'G' 2633' 2399' 307 sx Class 'G' 4741' 4262' Perforation depth: measured true vertical N Sands: 4260' - 4378' (four intervals); N Sands: 3801' - 3915' (four intervals) O Sands: 4424' - 4510' (two intervals) O Sands: 3959' - 4041' (two intervals) Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE tubing to 4144'. Packers and SSSV (type and measured depth) Gravel pack screen assembly wi7" Otis 'VST' Versa-Trieve packer at 4219'; 7" Otis 'AWD' Sump packer at 4422' 13. Stimulation or cement squeeze summary ~, ~ ~ ~-, ~ V ~ L) 14. Intervals treated (measured) Treatment description including volumes used and final pressure Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl JUN 0 6 2003 Alaska 0ii & Gas Cons. Commission Anchnraae Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service ~~: ;,,' 17. I hereby,,~~?, fore__nd correct to the best of my knowledge Si.clne~k, Sondra Ste'~[~.~,~/~.~-,~.._.~...._ Title TeCh'n3Cal ASsistant " Date "-'-'" ..... --'-'- - D I I I A IPrepared By Name/Number: S""on'~ra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 t.~ ,,, U~,~~. JU~ ~L ~ ~.O[~ Submit In Duplicate BP EXPLORATION Page 1 of 5 Operations Summa Report Legal Well Name: MPI-03 Common Well Name: MPI-03 Spud Date: 11/5/1990 Event Name: REENTER+COMPLETE Start: 5/1/2003 End: 5/7/2003 'Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/7/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 5/1/2003 11:00 - 12:30 1.50 MOB ~ PRE R/D. Scope & lower derrick. Prep to mobilize. 12:30 - 15:00 2.50 MOB ~ PRE Move off MPJ-21 & move on MPI-03. ,15:00 - 17:00 2.00 MOB ~ PRE Spot in rig, pipe shed & pit modules over well. Begin rigging up. 17:00 - 18:00 1.00 MOB ~ PRE Raise & scope up derrick. ACCEPTED RIG @ 1800 Hrs, 5/1/2003. 18:00 - 19:30 1.50 RIGU ~ DECOMP Spot in tiger tank. Hook up lines from tree to tank. R/U kill equip. 19:30 - 20:30 1.00 RIGU ~ DECOMP Finish rigging up equip. Take on 10.8 ppg NaBr completion fluid. Test lines to 2500 Psi, Ok. 20:30 - 22:30 2.00 KILL ~ DECOMP Hold PJSM / Spud mtg. SITP 70#, SICP 20#. Open well & circulate wellbore w/10.8 ppg NaBr @ 4 BPM, 650#. Bullhead 15 Bbls into wellbore. SI well & allow to hydocarbons to separate. Con't to circulate additional 35 Bbls till fluid cleared up. Monitor well, well dead & on vacuum. 22:30 - 00:00 1.50 WHSUR P DECOMP Set & test TWC to 1500#. N/D kill lines. N/D X-mas tree. 5/2/2003 00:00- 02:00 2.00 BOPSUF.P DECOMP N/U BOPE. 02:00 - 03:00 1.00 BOPSUF.P DECOMP Perform body test on BOP. Test all breaks, LP 250#, HP 2500#. Test koomey. BOP test witnessing waived by John Crisp w/AOGCC. 03:00 - 03:30 0.50 WHSUR P DECOMP P/U lubricator & pull TWC. L/D same. 03:30 - 04:00 0.50 WHSUR P DECOMP M/U landing joint. BOLDS. Pull hanger to floor. 42K up wt. 04:00 - 04:30 0.50 WHSUR P DECOMP Back out & L/D hanger. Tie ESP cable to reel. 04:30 - 08:30 4.00 PULL P DECOMP POOH w/ESP completion. 08:30 - 10:00 1.50 PULL P DECOMP Lay down pump/motor assembly. Twisted shaft. 2' of formation sand on top of pump. Fluid lost to hole since rig acceptance...(70) bbls. 10:00 - 11:00 1.00 PULL P DECOMP Clear/clean rig floor. 11:00 - 12:30 1.50 PULL P DECOMP Rig up Schlumberger E line. 12:30 - 13:00 0.50 PULL P DECOMP PJSM on running chemical cutter. Emphasis on staying clear of rig floor & cellar. Safe area identified. 13:00 - 15:00 2.00 PULL P DECOMP M/U & RIH w/12' x (1) wrap 80 grain primacord stringshot, CCL, & (2) 6'x 1 11/16" wt bars. Correlate depth & shoot f/ 4194' - 4206'. POOH, fired OK. Fluid level static @ 1000'. 15:00- 17:00 2.00 PULL P DECOMP M/U 2.625" chemical cutter, CCL, & (2) 6'x 1 11/16"wt bars. RIH & correlate. Fire cutter @ 4206'. Repeat firing sequence (3) times as no clear indication of firing seen at surface. POOH, note overpulling 15' - 20' above cut, (anchors). Work tool & free up. POOH w/cutter. Cutter misfired, blew anchors off & failed to get pressure to rupture discs. 17:00 - 19:30 2.50 PULL P DECOMP LID cutter & put together back up tool. RIH w/new cutter & correlate. Tie-in & make cut @ 4216'. Top of VST packer @ 4179'. Top of 4 1/2" pup @ 4190'. Top of 20' 3 1/2" blank JT @ 4204'. (all logger depths) Had good indication of firing lQ surface. POH w/tools. 19:30 - 20:30 1.00 PULL P DECOMP RID Schlumberger equip. 20:30 - 21:00 0.50 PULL P DECOMP M/U & install wear bushing. RILDS (2). 21:00 - 22:00 1.00 PULL P DECOMP M/U BHA #1. VST retrieving tool, x-o, bumper sub, jars & 9 DCs. RIH. 22:00 - 00:00 2.00 PULL P DECOMP P/U 3 1/2" DP lxl & RIH. Picked up 125 jts. 5/3/2003 00:00 - 00:30 0.50 PULL P DECOMP P/U 3 1/2" DP & RIH. Picked up 125 jts. Tag up on VST packer @ 4184' ( driller depth). 24' in on 125th jr. 00:30 - 01:00 0.50 PULL P DECOMP P/U circulating head & tag up. P/U 73K, S/O 58K. Engauge Printed: 5/12/2003 11:25:50 AM BP EXPLORATION Page 2 of 5 Operations Summary Report Legal Well Name: MPI-03 Common Well Name: MPI-03 Spud Date: 11/5/1990 Event Name: REENTER+COMPLETE Start: 5/1/2003 End: 5/7/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/7/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 5/3/2003 00:30 - 01:00 0.50 PULL ~ DECOMP VST packer & swallow to 4189'. P/U to 107K & packer came free (35K over). 01:00 - 03:00 2.00 PULL 3 DECOMP POOH & LID 11 Jts of DP. Con't to POOH & stand back DP. Did not recover packer. 03:00 - 05:00 2.00 PULL P DECOMP Redress retrieving tool & run back in hole. 05:00 - 05:30 0.50 PULL P DECOMP Tag up on VST packer. Swallow 5' & engauge lower dogs. P/U & work pipe. Alternate P/U & S/O. Fire jar 2 times, (25K over), & packer came free. Pull up 1 jt w/10/12K drag. allow rubbers to relax. 05:30 - 09:00 3.50 PULL P DECOMP POOH & LID excess DP, stand back remaing DP. 09:00 - 11:00 2.00 PULL P DECOMP Stand back collars, break down & lay down fish. Retrieved Otis "VST" Packer assembly complete, 11.51' of 4 1/2" LCT pup jt, x/o, & apprximately 12.5' of 3 1/2" J-55 8 rnd pup. 11:00 - 12:00 1.00 PULL P DECOMP M/U BHA to clean out gravel pack screens. 12:00 - 15:00 3.00 PULL P DECOMP RIH w/cleanout assembly. Take on 300 bbls of 9.9 ppg brine to dilute system back to 10.4 ppg. 15:00 - 17:30 2.50 CLEAN P DECOMP Wash down pumping 1 bpm @ 2700 psi, seeing no resistance, getting approximately 1/2 bpm returns. Work pipe up every 10' to ensure not getting trapped by sand. Tag hard obstruction 89' in from top of stub .... appoximately 14' into 3rd joint of screen, leaving 48' of unaccessed screen. 77K up wt, 60K down. 17:30 - 19:30 2.00 CLEAN P DECOMP Circulate well. Had Gas bubbles to surface. Circ@ 1.3 BPM, 2850#. SD well slowly stopped bubbling & hole started taking fluid. 19:30 - 21:00 1.50 CLEAN P DECOMP POOH w/BHA #3. 21:00 - 22:00 1.00 CLEAN P DECOMP LID BHA # 3. Clear & clean floor. 22:00 - 22:30 0.50 CLEAN P DECOMP M/U BHA #4. Overshot assy w/packoffto fish screens. ' 22:30 - 00:00 1.50 CLEAN P DECOMP RIH w/BHA # 4. 5/4/2003 00:00 - 01:30 1.50 CLEAN P DECOMP P/U kelly & circulare bottoms up 5 BPM, 925#. Latch onto fish w/overshot. Pull up to 50K overpull & work pipe. P/U 50K over hold & pump 25 Bbls sweep around. When sweep cleared bit weight dropped off & string popped free. 01:30 - 02:30 1.00 CLEAN P DECOMP Circulate well @ 5.5 BPm, 1000#. Watch returns. Did not see much gravel pack, mostly trash. Monitor well. fluid level slowly dropping. 02:30 - 03:00 0.50 CLEAN P DECOMP Set back kelly. Blow down lines. Prep to POOH. 03:00- 05:00 2.00 CLEAN P DECOMP POOH w/BHA#4. 05:00 - 06:30 1.50 CLEAN P DECOMP Recover & LID screens. Recovered 88.52' of fish, (approximately 80' of screens.) Left pin end looking up in hole. 06:30 - 07:30 1.00 CLEAN P DECOMP Pick up wash pipe BHA. 07:30 - 10:00 2.50 CLEAN P DECOMP RIH w/3 1/2" DP. Kelly up. 77K up wt, 60K down. 5 1/2 bpm @ 1750 psi. 10:00 - 13:30 3.50 CLEAN P DECOMP Wash down over screens, circulating periodic sweeps. Fluid loss rate remains negligible. Sand / fill back in sweep returns. Washed to 4388' DPM. 13:30-15:00 1.50 CLEAN DECOMP POOH w/ BHA # 5. 15:00 - 16:30 1.50 CLEAN DECOMP LID BHA #5, Wash pipe assy. 16:30 - 17:00 0.50 CLEAN DECOMP Clear & clean rig floor. 17:00 - 17:30 0.50 CLEAN DECOMP M/U BHA # 6, Overshot assy to fish remaining screens & seal assy. 17:30 - 19:00 1.50 CLEAN DECOMP RIH w/overshot assy. 19:00 - 20:00 1.00 CLEAN DECOMP Kelly up & break circulation. Circ @ 4 BPM, 400#. P/U 84K, S/O 60K, ROT 60K. Swallow 4' of fish w/overshot. P/U & work Printed: 5/12/2003 11:25:50 AM BP EXPLORATION Page 3 of 5 Operations Summa Report Legal Well Name: MPI-03 .Common Well Name: MPI-03 Spud Date: 11/5/1990 Event Name: REENTER+COMPLETE Start: 5/1/2003 End: 5/7/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/7/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 5~4~2003 19:00 - 20:00 1.00 CLEAN DECOMP up to 150k. (66k over). Weight slowly dropped off 20k (seals pulling out) & then fell to sting wt. P/U & monitor well. 20:00 - 21:00 1.00 CLEAN DECOMP Circulate bottoms up +20 bbls. 5.5 BPM @ 1300 to 1900 Psi. Monitor well. Gas bubbles to surface & fluid level dropping. Gas decreased. 21:00 - 23:00 2.00 CLEAN DECOMP POOH 10 stands & observe well. Well taking fluid. Set back kelly & blow down lines. Con't to POOH. 23:00 - 23:30 0.50 CLEAN DECOMP Pulled to collars, well started burping fluid out DCs. Annulus ' level dropping. Observe well & allow DCs to unload ( screens plugged & solution gas breaking out) Allow to equalize. 23:30 - 00:00 0.50 CLEAN DECOMP LID BHA & fish. Recovered remaining screens, seal assy & tailpipe assy w/WLEG. 5/5/2003 00:00 - 00:30 0.50 CLEAN P DECOMP Finish LID overshot assy & recovered screens, seal assy & tail pipe assy. Bottom 20' of screen plugged w/debris. 00:30 - 03:00 2.50 CLEAN P DECOMP M/U BHA # 7. Scraper run to clean out to packer. RIH & tag up on sump packer @ 4389'. 03:00 - 04:00 1.00 CLEAN ~ DECOMP R/U & reverse circulate. Circulated @ 40 BPM, 450#. Had formation sand in returns. Monitor well. 04:00 - 06:30 2.50 CLEAN ~ DECOMP LID 11 jts of DP & POOH. 06:30 - 07:30 1.00 CLEAN ~ DECOMP M/U cleanout BHA. 07:30 - 10:00 2.50 CLEAN ~ DECOMP RIH w/cleanout BHA to 4395', (below packer). 10:00 - 14:30 4.50 CLEAN ~ DECOMP Reverse circulate down f/4395' to 4617', reverse circulating @ 5.5 bpm / 1700 psi. Tag up hard @ 4617', unable to go deeper. Reverse circulate clean 10.4 ppg brine around. Total fluid loss while reverse circulating -- 100 bbls. 14:30 - 16:00 1.50 CLEAN ~ DECOMP POOH w/cleanout assembly. 16:00 - 18:00 2.00 CLEAN ~ DECOMP LID 4 3/4' DCs & BHA #8. 18:00 -21:30 3.50 BOPSUF.P DECOMP Pull wear bushing. Install test plug. Test BOPE as per reqirements. LP 250#, HP 3500#. Pull test plug & RID test equip. 24 hr notice given, witnessing of test waived by AOGCC Rep John Spaulding. 21:30 - 23:00 1.50 SANDOFIP COMP R/U & run Screen assy. as per program. Sump packer @ 4422'. Screens (125') from 4234 to 4359'. VTA packer 4190'. All depths OKB. 23:00 - 00:00 1.00 SANDOFIP 'COMP RIH w/screen assy on 3 1/2" DP. 5/6/2003 00:00 - 01:30 1.50~ SANDOI~IP COMP RIH w/VTA Packer and Screen Assembly on 3 1/2" DP to 4,398'. 01:30 - 03:30 2.00 SANDOI~IP COMP Spaced Out VTA Packer and Screen Assembly. Stabbed Seal Extension into Sump Packer. Dropped ball. Pressured Up and Set VTA Packer w/2,500 psi. Tested f/10 min, OK. Tested Annulus to 2,500 psi f/10 min, OK. Sheared Out of VTA Packer. ~VTA Packer - Screen Assembly Set As Follows: Item Length Depth Seal Assembly 6.85' 4,422.00' XO .69' 4,421.31' 2 Jts 3-1/2" Blank Pipe 61.45' 4,359.86' XO .66' 4,359.20' Printed: 5/12/2003 11:25:50 AM BP EXPLORATION Page 4 of 5 Operations Summary Report Legal Well Name: MPI-03 Common Well Name: MPI-03 Spud Date: 11/5/1990 Event Name: REENTER+COMPLETE Start: 5/1/2003 End: 5/7/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/7/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 5/6/2003 01:30 - 03:30 2.00 SANDOI~ P COMP 4 Jts 3-1/2" 250 Micron Screens 125.00' 4,234.20' XO .66' 4,233.54' 1 Jt 3-1/2" Blank Pipe 30.24' 4,203.30' XO .66' 4,202.64' Shear Sub Assembly 2.13' 4,200.51' XO .66' 4,199.72' 5-1/2" 17# LTC Pup Jt 2.52' 4,197.20' 7" V-I'A Packer Assembly 6.32' 4,190.88' 03:30 - 04:30 1.00 SANDOI~ ~ COMP Slipped 42' of Drilling Line. Adjusted Brakes. '04:30 - 08:30 4.00 SANDOI~ ~ COMP POOH and L / D 3-1/2" DP. 08:30 - 09:30 1.00 RUNCOI~' COMP Cleared and Cleaned Rig Floor. Rigged Up to Run 2-7/8" CompletiOn. Loaded Pump into Pipe Shed. 09:30 - 10:00 0.50 RUNCOI~ COMP Held PJSM on ESP Completion. Pulled Wear Bushing. 10:00 - 12:30 2.50 RUNCOr~ COMP M / U ESP Pump and Motor. Pulled MLE over Sheave. Plugged into Motor and Tested, OK. 12:30 - 14:00 1.50 RUNCOI~ COMP RIH w/ESP Assembly on 2-7/8" 6.5# L-80 8rd Tubing to 675'. ~Average M / U Torque 2,300 ft/lbs. Total of 19 jts Ran. 14:00 - 15:30 1.50 RUNCOI~ COMP M / U Heat Trace on Bottom of Jt #20. R / U Banding Tools to Run Heat Trace. 15:30 - 00:00 8.50 RUNCOI~ COMP RIH w/ESP Assembly w/Heat Trace on 2-7/8" 6.5# L-80 8'rd Tubing. Installed Flat Guards and Bands. 5/7/2003 00:00 - 04:30 4.50 RUNCOI~P COMP RIH w/ESP Assembly w/Heat Trace on 2-7/8" 6.5# L-80 8rd Tubing. Pumped Through and Flushed Pump Every 1000'. Average M / U Torque 2,300 fi: / lbs. Installed 2 F/G, 4 Protectors, 16 LaSalle Clamps, 540-6' Flat Guards, 50-4' Flat Guards and 1,808 Flat Bands. 04:30 - 05:00 0.50 RUNCOr I:) COMP M / U Tubing Hanger to Completion String. 05:00 - 09:30 4.50 RUNCOr F~ COMP Made Tubing Hanger Splices in ESP and Heat Trace Cables. Tested Splices, OK. 09:30 - 10:00 0.50 RUNCOkF) COMP Landed Tubing Hanger in Wellhead, RILDS. Broke Out and L / D 2-7/8" Landing Joint. Completion Equipment Set At The Following Depths: Item Length Depth PHD 1.97' 4144.09' Motor Model KMH 13.19' 4128.93' Seal Section 13.78' 4115.15' Standard Intake 0.87' 4114.28' Pump 19.01' 4095.27' Discharge Head 0.62' 4094.65' 2 7/8" 6.5# L80 8rd Pup Jt 10.00' 4084.65' 2-7/8" 6.5# L80 8rd Pup Jt 2.00' 4082.65' "XN" Nipple 1.00' 4081.65' 4-Jts 2-7/8" 6.5# L80 8rd Tbg 123.64' 3958.01' 2-7/8" 6.5# L80 8rd Pup Jt 10.02' 3947.99' 2-7/8" X 1" Camco GLM w/Dummy 6.65' 3941.34' 2-7/8" 6.5# L80 8rd Pup Jt 9.58' 3931.76' 15-Jts -2-7/8" 6.5# L80 8rd Tbg 466.42' 3465.34' 106-Jts 2-7/8" L80 8rd Tbg w/Ht Trce 3311.58' 153.76' 2-7/8" 6.5# L80 8rd Pup Jt 9.99' 143.77' 2-7~8" X 1" Camco GLM w/SO 6.68' 137.09' 2-7/8" 6.5# L80 8rd Pup Jt 9.40' 127.69' 3-Jts 2-7/8" 6.5# L80 8rd Tbg 92.56' 35.13' 2-7/8" 6.5# L80 8rd Pup Jt 10.00' 25.13' Printed: 5/12/2003 11:25:50 AM BP EXPLORATION Page 5 of 5 Operations Summary Report Legal Well Name: MPI-03 Common Well Name: MPI-03 Spud Date: 11/5/1990 Event Name: REENTER+COMPLETE Start: 5/1/2003 End: 5/7/2003 'Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/7/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 5/7/2003 09:30 - 10:00 0.50 RUNCOI~ COMP .2-7/8" 6.5# L80 8rd Pup Jt 3.79' 21.34' 'Tubing Hanger 0.64' 20.70' 10:00 - 10:30 0.50 RUNCOI~ COMP Held PJSM. Set TWC and Tested to 3,500 psi. 10:30 - 12:00 1.50 BOPSUF.P COMP Held PJSM. N / D BOPE. 12:00 - 14:00 2.00 WHSUR P COMP N / U Production Tree. Tested Adapter, Tubing Head and Tree to 5,000 psi. OK. F / C on ESP and Heat Trace Good. 14:00 - 15:00 1.00 WHSUR P COMP Held PJSM. R / U DSM, Pulled TWC, R / D DSM. Set BPV. Secured Well Released Rig at 1500 hrs, 05 / 07 / 03. Printed: 5/12/2003 11:25:50 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 70' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2945' SNL, 3816' WEL, SEC. 33, T13N, R10E, UM MPI-03 At top of productive interval 9. Permit Number / Approval No. 190-092 4559' SNL, 3270' WEL, SEC. 33, T13N, R10E, UM 10. APl Number At effective depth 50-029-22067-00 4671' SNL, 3240' WEL, SEC. 33, T13N, R10E, UM 11. Field and'Pool At total depth Milne Point Unit / Kuparuk River 4697' SNL, 3233' WEL, SEC. 33, T13N, R10E, UM Sands ,, 12. Present well condition summary Total depth: measured 4750 feet Plugs (measured) true vertical 4270 feet Effective depth: measured 4659 feet Junk (measured) true vertical 4184 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 13-3/8" 485 sx Permafrost 'C' 115' 115' Surface 2598' 9-5/8" 247 sx Class 'E', 942 sx Class 'G' 2633' 2399' Intermediate Production 4706' 7" 307 sx Class 'G' 4741' 4262' Liner Perforation depth: measured N Sands: 4260' - 4378' (four intervals); O Sands: 4424' - 4510' (two intervals) true vertical N Sands: 3801' - 3915' (four intervals) O Sands: 3959' - 4041' (two intervals) Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE tubing to 4142'. Packers and SSSV (type and measured depth) Gravel pack screen assembly w/7" Otis 'VST' Versa-Trieve packer at 4192'; 7" Otis 'AWD' Sump packer at 4422' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true an~l. correct to the best of my knowledge Signed Sondra Stewman j~.~ ~ Title Tec nical0 9 ( Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate , : i'Bp EXPLORATION Page 1 of 1 ~ OPerations: summary Report 'Legal Well Name: MPI-03 Common Well Name: MPI-03 Spud Date: 11/5/1990 Event Name: RECOMPLETION Start: 7/26/2002 End: 7/28/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 7/28/2002 Rig Name: NABORS 4 Rig Number: 4ES Date: l~From,TO i:Hours. TaSk i Code NpT Phase Description of Operations 7/26'2002 00:00 - 04:00 4.00iRIGU P I PRE MIIRU NABORS 4ES 04'00 ' , DECOMP RIG UP LINES ETC TO TREE & TEST FOR WELL KILL TAKE · 06:00 2.00j KILL I P I ON SEAWATER I 1.00 KILL I P. ! DECOMP RIG LUBRICATOR & PULL BPV 06:00 - 07:00 1 [07:00 10:30 I 3.50 KILL I P DECOMP CIRC WELL BORE WITH DIESEL & FOLLOW WITH HOT ~ WHSUR~P SEAWATER TO DISPLACE INFLUX I i 0.50 DECOMP SET TWC 10:30 - 11:00 1 11:00 - 12:00 I 1.00iWHSURiP DECOMP ~NIPPLE DN TREE 12:00 13:30 I 1.50 BOPSUR, P IDECOMP 'NIPPLE UP BOP l~ ! WITH AOGC i16:30-17:00 [ . BOPSU~P DECOMP PULLTWC 17:00 00:00 7.00 PULL [P ' DECOMP PULL ESP COMPLETION & LAY DN ALL TBG 3.00 PULL P 03:00 - 06:00 3.00 EVAL P DECOMP RIG HES SLICK LINE & RIH WITH SWEDGE & UNABLE TO ' FREE FALL IN 7" CSG. THOUGH TO BE HEAVY OIL POOH ' I & RIG DN SAME. !06:00 - 09:00 3.00! CLEAN N DPRB DECOMP RIH WITH TBG. TO CIRC OUT & WARM WELL BORE I .00 FLUIDS 09:00 - 10:00 1 CLEAN N DPRB DECOMP CIRCULATE & WARM WELL BORE(FINDING ON RETURNS WERE SMALL AMOUNT OF O L & UNIDENTIFABLE !1 50 [J 'I I REASON FOR TOOLS NOT TO FALL IN WELL BORE. ) ii ~#2 RIH WITH 2" BAILER & PULLED SAMPLE FORMATION ~ SAND . POOH RIG DN HES SLICK LINE. 11:30 - 13:00 [ 1. EVAL N DPRB I DECOMP POOH WITH TBG. 13:00 - 16:00 3.00 CLEAN N DPRB DECOMP WAIT ON TRUCKS TO GET AVAILABLE TO GET CLN-OUT ]I TOOLS TO RIG. 16'00 19:00 3.00 CLEAN N IDPRB DECOMP MU 1.25" CLN-OUTASSY. 11-JTS. WITH MULE SHOE & RIH I WITH SAME & RUN TO 4532' DID NOT IDENTIFY NO FILL. 19:00 - 19:30 0.501 CLEAN N DPRB DECOMP I REVERSE CIRC WELL BORE CLN RETURNS HAD TRAVIAL · AMOUNT OF DEBRI. 19:30 - 22:30 3.001 CLEAN iN DPRB DECOMP POOH & LAY DN CLN-OUT ASSY. r22:30 _ 00:00 1.50 RUNCOlVP ~ COMP I MU ESP ASSY. 7/28/2002 00:00 - 01:00 1.00 RUNCO"--i~p COMP MU ESP ASSY. ,01:00 - 02:30 1.50 RUNCO ! COMP RIH WITH ESP ASSY. 02:30 - 03:30 ] 1.00 RUNCOI~ ] COMP RIG UP HEAT TRACE EQUIPMENT TO BEGIN I COMP INSTALLATION OF HEAT TRACE. 03:30 - 08:00 2.50 RUNCOI~F~ CONTINUE TO RIH WITH ESP ASSY. , 06:00 - 10:00 4.00 RUNCOI~I~I SFAL COMP ARMOUR REPAIR ON ESP CABLE DUE TO( DAMAGE IN i I , SLIPS) & DURING CHECK FOUND HEAT TRACE TO BE I i BAD . / 110:00 - 13:00 3.00 PULL I N SFAL I COMP POOH REMOVING HEAT TRACE TO END OF HEATER. & . '1 I I i RIG DN HEAT TRACE. i13:00 - 14:30 1.50 RUNCON~ . COMP I RIH WITH ESP ASSY TO SETTING DEPTH @ 4142' '14:30 - 18:00 3.50 RUNCO~iP COMP i INSTALL HANGER & MAKE ESP CONNECTOR SPLICE & ~ I LAND HANGER & RILDS. 18:00 - 20:00 2.00 BOPSUF~P ! COMP NIPPLE DN BOP 20:00 22:00 2.00] WHSUR pI] COMP NIPPLE UP TREE & TEST SAME TO 5000 PSI. 22:00 00:00 2.001WHSUR P i COMP RIG LUB & PULL TWC & SECURE TREE AREA. RIG RELEASED @ 2359 HRS. 7/28/2002 Printed: 7/29/2002 4:40:39 PM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie HeUsser, Commissioner ~.0~ ~:pUenrvd~r~~~ DATE: April 22, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Milne Point Unit J& I Pads Sunday Af)ri122, 2001: I traveled to BPXs MPU J & I Pads and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 17 wells and 34 components with no failures. Lee Huime performed the testing today; he demonstrated good test procedures and was a pleasure to work with. I also inspected the well houses on these pads during the SVS testing. All the welihouses were very clean and the equipment appeared to be in excellent condition. Summary: i witnessed SVS testing at BPXs MPU J & I Pads. MPU J Pad, l'l~wells 22 components 0 failures MPU I Pad 6-wells 12 cornponents 0 failures 23 wellhouse inspections Attachment: SVS MPU J Pad 4-22-01 CS SVS MPU I Pad 4-22-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: Chuck Scheve Submitted By: 'ChUck Scheve" Date: Field/Unit/Pad: Milne Point / MPU / ! Pad Separator psi: LPS, 140 HPS 4/22/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, , .Ngmber ,Numbe,,r PSI, , PSI .... T,rip Code , Code Code, Passed GAS or ,C,Y, CLE I-01 19009O0 1-02' 19009i0 .... 140' 100 ..... 95 'p' "p ............. OIL 1-'03 1900920 " 140 100 951 P P " 0IL 1-04 1900930 140 100 95 P. P OIL 1-06 ~ 197'1950 140 '100 ' '95 P .... P .... OIL 1-07 1951510 140 100 95 P P OIL I'08 197'1920 'i40 100 ..... 95 "P 'P ' ~ 0I'L Wells: 6 Components: 12 Failures: 0 Failure Rate: 0.00% ~9o Day Remarks: RJF 1/16/01 Page 1 of 1 SVS MPU I Pad 4-22-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee Huim~ AOGCC Rep: Chuck Scheve · t Submitted By: ~Chuck SCheve Date: Field/Unit/Pad: Milne Point / MPU / J Pad Separator psi: LPS 140 HPS 4/22/01 _ Well Pemit Separ Set L~ Test Test T~t Date ~ WAG, G~J, Number Number PSi PSI . Trip Code Code Code passed .,GAS or.qYCLE J-0~A ~99~0 J-0~ "' 1900~0~n0 ~00~ 9~' 'PP.............. 0~U j-04 ' 1900980 ~ 140 100 ~5 ' P " ~ .......... OIL j-o~ " ~9~o9~o' 'ino loo '~' "~' ' 'P ........ oil J-O~ ~ ~409~0 ' ' i4o .... ioo ~:~ ..... P '" P" o~u J-07 ' ' 'i 9~0970 140 100 95 ..... P P ...... OIL J-0a~ .... ~99~70 '~no ~0o~ ' 9~~' ' ' P ' ' '0m J-09A ...... ~9~0 ..... ~0 ..... ~00 ~0.... P ..... P .......... Om J- 10 ....... 1941160 140 100 95 e P 0IL , , ,, , , ., ,, ,, , . , , , i , , , . ,, , .,, J-11 1941140 J, 12 ..... 19ki180 ...................... - , , , J-18 1972200 'I.'19X 1951700 ........... , , , ~ , ,, , ,, . , ,, , , ,~ i , ,, , . J-20 1972150 J'-21'" 1972000 140 .... 100 ' 95 P "e .......... 0IL J-22 .... 198i240 .... 140 '" 100'" 93~ '"P ' P ' ' OIL ,, , .... ., , t , i , , J-23 2001200 , , ,, , , , ~ , , , , ,,, , ,, ~ ,, . , ,,..,, , . ..,, , , , , , ,t , Wells: 11 Components: 22 Failures: 0 Failure Rate: 0.00% F190 oar Remarks: RJF 1/16/01 Page 1 ofl SVS MPU JPad 4-22-01 CS '"---- STATE OF ALASKA ALASKA L,,~. AND GAS CONSERVATION COIViiwlSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator BP Exploration (Alaska)Inc. [] Operation Shutdown []Stimulate [] Plugging I-~ Perforate [] Pull Tubing []Alter Casing [~ Repair Well I--]Other 5. Type of well: 6. [] Development I-q Exploratory 7. [] Stratigraphic [] Service 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2945' SNL, 3816' WEL, SEC. 33, T13N, R10E, UM At top of productive interval 4500 SNL, 3380' WEL, SEC. 33, T13N, R10E, UM At effective depth 4671' SNL, 3239' WEL, SEC. 33, T13N, R10E, UM At total depth 4746' SNL, 3311' WEL, SEC. 33, T13N, R10E, UM Datum Elevation (DF or KB) 69' Unit or Property Name Milne Point Unit 8. Well Number MPI-03 9. Permit Number / Approval No. 90-92 10. APl Number 50-029-22067 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 4750 true vertical 4270 Effective depth: measured 4659 true vertical 4184 Casing Length Size Structural Conductor 80' Surface 2598' Intermediate Production 4706' Liner feet Plugs (measured) feet feet Junk (measured) feet TVD 13-3/8" 485 sx Permafrost 'C' 115' 115' 9-5/8" 247 sx Class 'E', 942 sx Class 'G' 2633' 2399' 7" 307 sx Class 'G' 4741' 4262' Perforation depth: measured true vertical N Sands: 4260' - 4378' (four intervals); N Sands: 3796' - 3909' (four intervals) O Sands: 4424' - 4510' (two intervals) O Sands: 3953' - 4053' (two intervals) Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE to 4141'; XXX Packers and SSSV (type and measured depth) Gravel pack screen assembly w/7" Otis 'VST' Versa-Trieve packer at 4192'; 7" Otis 'AWD' Sump packer at 4422' 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 5. Attachments [] Copies of Logs and Surveys run [~ Daily Report of Well Operations 16. Status of well classifications as: [~ Oil I~ Gas [~ Suspended Service 17' I hereby certify that.~ reg°in,~s Ir~e~.,d c°rrect t° the best °f mY kn°wledgeSigned TerrieHubble~' /~//~ ~~,_.~ Title TechnicalAssistant III Prepared By Name/Number: Terrie Hu~'biel 564-4628 SUbmit In Duplicate~L~) Form 10-404 Rev. 06/15/88 Progress Report Facility M Pt I Pad Well MPI-03 Page 1 Rig ~ kl~~ ~.~ Date 10 February 99 Date/Time 07 Dec 97 06:00-18:00 18:00-21:00 21:00-22:00 22:00-23:00 23:00-00:30 08 Dec 97 00:30-02:00 02:00-03:00 03:00-04:30 04:30-06:00 06:00-09:00 09:00-09:30 09:30-15:30 15:30-20:00 20:00-23:00 23:00-01:00 09 Dec 97 01:00-03:00 03:00-06:00 06:00-08:00 08:00-12:00 12:00-12:30 12:30-16:00 16:00-18:00 18:00-22:00 22:00-22:30 22:30-02:00 10 Dec 97 02:00-03:30 03:30-04:00 04:00-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-09:30 09:30-10:00 10:00-10:30 10:30-11:00 11:00-13:00 13:00-16:00 16:00-18:00 18:00-06:00 11 Dec 97 06:00-18:00 18:00-22:30 22:30-00:00 12 Dec 97 00:00-01:30 01:30-04:00 04:00-05:30 05:30-06:00 06:00-09:00 09:00-09:30 09:30-10:00 10:00-11:00 11:00-11:30 11:30-12:00 12:00-13:00 13:00-14:00 Duration 12hr 3hr 1 hr lhr 1-1/2 hr 1-1/2 hr 1 hr 1-1/2 hr 1-1/2 hr 3 hr 1/2 hr 6hr 4-1/2 hr 3hr 2hr 2hr 3 hr 2hr 4hr 1/2 hr 3-1/2 hr 2 hr 4hr 1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr 2hr 1/2 hr 1-1/2 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 2hr 3hr 2hr 12hr 12hr 4-1/2 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 3hr 1/2 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 1 hr 1 hr Activity Rig moved 100.00 % Fill pits with Production fluids Installed Surface lines Tested Surface lines Lubricate well Circulated closed in well at 4020.0 ft Monitor wellbore pressures Circulated closed in well at 4020.0 ft Circulated closed in well at 4020.0 ft Circulated closed in well at 4020.0 ft Flow check Rigged up All functions Tested All functions Installed Tubing handling equipment Serviced Block line Rig waited · Equipment Retrieved Tubing hanger Installed Additional services Pulled Tubing in stands to 4095.0 ft Repaired Tubing handling equipment Rigged down sub-surface equipment - ESP Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Rig waited · Equipment R.I.H. to 649.0 ft Circulated at 649.0 ft R.I.H. to 2700.0 ft Held safety meeting R.I.H. to 4178.0 ft Laid down 863.0 ft of 2-7/8in OD drill pipe R.I.H. to 4168.0 ft Installed Circulating head R.I.H. to 4483.0 ft Circulated at 4483.0 ft Circulated at 4483.0 ft Washed to 4557.0 ft Circulated at 4557.0 ft Serviced Mud pump power end Serviced Mud pump power end (cont...) Washed to 4635.0 ft Circulated at 4635.0 ft Pulled out of hole to 4178.0 ft Reverse circulated at 4178.0 ft Pulled out of hole to 650.0 ft Pulled BHA Pulled BHA (cont...) Ran Tubing in stands to 1000.0 ft Reverse circulated at 1000.0 ft Ran Tubing in stands to 2000.0 ft Reverse circulated at 2000.0 ft Ran Tubing in stands to 3000.0 ft Reverse circulated at 3000.0 ft Ran Tubing in stands to 4462.0 ft Facility M Pt I Pad Progress Report Well MPI-03 Page 2 Rig (null) Date 10February99 Date/Time 13 Dec 97 14 Dec 97 14:00-15:30 15:30-19:00 19:00-19:30 19:30-21:30 21:30-23:30 23:30-03:00 03:00-06:00 06:00-20:00 20:00-00:00 00:00-02:00 02:00-04:00 04:00-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-10:30 10:30-11:00 11:00-11:30 Duration 1-1/2 hr 3-1/2 hr 1/2 hr 2hr 2hr 3-1/2 hr 3 hr 14hr 4 hr 2hr 2 hr 1-1/2 hr 1/2 hr 1/2 hr 1 hr 3hr 1/2 hr 1/2 hr Activity Reverse circulated at 4462.0 ft Pulled Tubing in stands to 4462.0 ft Held safety meeting Rigged up sub-surface equipment - Electrical submersible pumps Ran Tubing in stands to 1850.0 ft Rigged up sub-surface equipment - Other sub-surface equipment Ran Tubing in stands to 2415.0 ft Ran Tubing in stands to 2415.0 ft (cont...) Installed Electric cable Ran Tubing on landing string to 4140.0 ft Removed BOP stack Installed Xmas tree Tested Xmas tree Tested Xmas tree (cont...) Removed Hanger plug Freeze protect well - 80.000 bbl of Diesel Installed Hanger plug Rigged down Fluid system MEMORANDUM TO: David JohPe~, Chairman THRU: Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE' December 8, 1997 FILE NO: AW9JLHEE.DOC FROM' Lou Grimaldi,'/,,~ SUBJECT: Petroleum Ir~pector BOPE Test Nabors 5S MPU I-3 PTD Cf 9O-OO92 Monday, December 8, 1997' I traveled to BPX's well CfMPU I-3 and witnessed the initial BOPE test on Nabors Rig 5S The rig was not ready when i arrived and I toured the rig prior to the test. There have been many modifications made to this rig that have improved its worthiness. One of these is the new Choke manifold to Gasbuster line. This line had just been installed and although it appeared to have had much thought put into its design I noticed that there were eight hammer unions in the line that served no purpose other than to make the installation of the line easier. The location of these unions were not easily accessible if they would need to be tightened or have their packing changed. The test once started went well with no failures noted and it was evident that there is attention being paid to the maintenance of the BOP equipment. Summary: I witnessed the initial BOPE test on Nabors Rig 5S working over Well MPU I-3. Nabors 5S, 1218/97, Test time 3 hours, No failures -- Attachment: AW9JLHEE.XLS NON-Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initia Workover: X · DATE: 12/8/97 Nabors ~ Rig No. 5S PTD # 90-0092 Rig Ph.# 659-4456 BPX Rep.' Jessie New Rig Rep.: Mike Downey Set @ Location: Sec. 33 T. 13N R. 10E Meridian Umiat X Weekly Other MPUI-3 Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location OK Standing Order Posted Yes Well Sign OK Drl. Rig OK ' Hazard Sec. OK. FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F N/A N/A N/A N/A 1 250/5,000 P 1 250/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 1 250/2500 P 1 250/5,000 P N/A N/A N/A 1 250/5,000 P 1 250/5,000 P 2 250/5,000 P 1 250/5,000 P N/A N/A N/A CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 250/5,000 P 28 250/5,000 P P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure 3000 I P Pressure After Closure 2200I P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 24 sec. Trip Tank OK OK System Pressure Attained 1 minutes 22 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: O Remote: OK Flow Indicator OK OK Nitgn. Btl's: 4 ~ 3175 PSI Meth Gas Detector OK OK o Psig. H2S Gas Detector OK OK ' Number of Failures: ,'TeSt ;rime: ~.o ~'~'~'~'i ...... ~i~'i3'~'~"'~':vaive~ tested ~ ~ep~ir or 15,~pi~'~nt ~)i~ Failed Equipment will be made within 0 days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours.please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c- Database ,c - Trip Rpt File !; - Inspector FI-021L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Awgjlhee.xls Louis R. Grimaldi .,noco ]nc. Anchorage Division To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 [] Under Separate Cover Enclosed cord of Shipment of Confidential Information Date From Steve Davies Conoco Inc. 3201 C Street, Suite 200 June 10, 1993 Anchorage, Alaska 99503 (907) 564-7640 Via Petroleum Couriers Subject Quantity Contents C~\ I~L~ Final Drilling & Completion Report ~- ~--~-7 Core Analysis Report 1 ~..~E-.7 Sidewall Descriptions ~01' ~'? .~.-2 Final Drilling Report C~1,-_~ ,-~i-3 Final Drilling Report ¢~ 1~-~I ~-FI-4 Final Drilling Report (~:)'1~~!-1 Final Drilling Report ¢~1~ ~ ~, 1-2 Final Drilling Report C~~ ~ 1-3 Final Drilling Report I-3 No Whole Core or Sidewall Cores taken as noted on completion report. 1 1 ~ 1 ~-1 '~-2 I-4 Final Drilling Report ~-4A Core Analysis Report ~J-1 Final Drilling Report Core Analysis Report Core Description Report Final Drilling Report Completion History Final Drilling Report Final Drilling Report Final Drilling & Completion Report Final Drilling & Completion Report Final Drilling & Completion Report Core Description Report Core Analysis Report RECEIVED JUN 1 1 7993 oil & Gas cons. Commission Anchorage Transmittal Approved By Date Instructions: P~ease ack~vle;~ge ~ly by signing and returning second copy, RemarksReCeived By ~~~"~'~-~~-- Date Transmittal Copy Only To (~onoco Inc. Anchorage Division To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 [] Under Separate Cover Enclosed h~cord of Shipment of Confidential Information Date From Steve Davies Conoco Inc. 3201 C Street, Suite 200 Anchorage~ Alaska 99503 (907) 564-7640 Petroleum Couriers ,, ,S, ,u, bject Milne Point Well Log Magnetic Tapes I-2, I-3~ I-4~ I-4A~ J-l~ J-3~ J-4, L-7, L-8~ L-g Quantity Contents 1 each I-2 Magnetic Tape, {~DIT, APl. #50-029-22066, Log Date: 03-NOV-90, Ref #74175. I-3 Magnetic Tape. O.H.EDIT, APl #50-029-22067, Log Date: 12-NOV-90, Ref #74203. I-4 Magnetic Tape, O.H.EDIT, APl #50-029-22068, Log Date: 19-Nov-90, Ref #74208. I-4~ Magnetic Tape. J-1 Magnetic Tape. J-3 'Magnetic Tape. J-4 Magnetic Tape. L-7 Magnetic Tape. L-8 Magnetic Tape. L-9 Magnetic Tape. O.H.EDIT, APl #50-029-22068, Log Date: 2g-Nov-90, Ref #74229. Open Hole,APl #50-029-22070, Log Date: .13-Dec-90, Atlas Wireline & LIS listing. O.H.EDIT, APl #50-029-22072, Log Date: 27-Dec-91, Ref #74271 & US listing. O.H.EDIT, APl #50-029-22073, Log Date: 03-Jan-91, Ref #74276 & LIS Iisting.¢~O~¢~: O.H.EDIT, APl #50-029-22028, Log Date: 14-Feb-91, Ref #74350. Open Hole,APl #50-029-22074, Log Date: 17-Apr-91, Ref #74527 & LIS listing. C~O~ll:3O O.H.EDIT, APl #50-029-22075, Log Date: 28-Mar-91, Ref #74467. ¢[0_i,O RECEIVED MAY 0 5 1993 ~laska Oil & Gas Cons. Commission Anchorage **LIS listings not availabe for I-2, I-3, I-4, I-4A, L-7 & L-9. Verbal notification provided to H. Oakland. Waiver granted via phone conversation May 5, 1993. Signed By % Transmittal Approved By Date il~'structions: Please ackno~l~ge ~.~}~omptly by Signing and returning second copy. Received By Date May 5, 1993 Remarks Transmittal Copy Only To STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ? 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator CONOCO INC. 3. Address POUCH 340045,Prudhoe Bay, AK 99734 4. Location of well at surface 2945' FNL x 3816' FEL of Sec. 5. Type of Well: Development Exploratory Stratigraphic Service 33, T13N, R10E 6. Datum elevation (DF or KB) 69 7. Unit or Property name Milne Point Unit 8. Well number 1-3 At top of productive interval 4500' FNL x 3380' At effective depth At total depth 4746' FNL x 3311' FEL of Same Section FEL of Same Section 9. Permitnumber 90-92 10. APInumber 50--029-22067 11. Field/Pool Kuparuk River Field feet 12. Present well condition summary Total depth: measured 4750 feet true vertical 4270 feet Effective depth: measured _--F 5 feet true vertical _--F 5 feet Casing Length Size Structural Conductor 80 13- 3 / 8" Sudace 2598 9- 5 / 8" Intermediate Production 4706 7 Liner "N" Sand Perforation depth: measured 4260 - 4378 true vertical 3796 - 3909 485 247 942 307 Tubing (size, grade, and measured depth) 2-7 /8" - 6.5 # Plugs (measured) Junk (measured) Cemented Measured depth Packers and SSSV (type and measured depth) NONE sxs sxs sxs sxs Perm. C E+ G E I1011 4424 3953 L-80 @ 4095 115' 2633' 4741' Sand - 4510 - 4053 True vertical depth 115' 2399' 4261' 13. Attachments Description summary of proposal _% Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 3-1-90 16. If proposal was verbally approved Name of approver David Johnston 3-1-91 Date approved 15. Status of well classification as: Oil ~ ~<~ Gas__ Suspend,~d%-f:'~"r Service 17. I hereby certify that the foregoing is true _and correct to the best of my knowledge. n / Signed /~./~~/%~ FO ~ t~o ~.1S~l~ONd~ ~N~yF o, e ma n Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- /1 ~'zt v,,~; ~., J~ Approved by order of the Commission ORIGINAL SIGNED BY LONNtE C. SMITH JApproval No. ,~//..../'o~ ~' Form 10-403 Rev 06/15/88 ALASKA OIL AND ~AS ~NS~R~ATION COMMISSION 0 REPORT OF SUNDRY WELL OPERATIONS RIGIN AL 1. Operations performed: Opera',,on shutdown ~ Sl~mulale __ Plugg,r~ __ Pedorate __ Pull tubing __ Alter casir~' ~ Repair ~ X.. Cas ing Repair Other 2. Name of Operalor Conoco Inc. 3. Address POUCH 340045, Prudhoe Bay, Ak 99734 5. Type of Well: Developmen~ ~ Exploratory __ Stratigraphi¢ .__ Service --2 4. Location of well at surface 2945' FNL x 3816' FEL of At top of productive interval 4500' FNL x 3380' FEL of At effective depth A~ total depth 4746' FNL x 3311' FEL of Sec. 33, T13N, Same Section Same Section RiOE, U.M., NSB 12. Present well condition summary Tolal depth: measured 4750 true vertical 4 2 7 0 f~ feet Rugs(measured) 6. Datum elevation (DF ~ KB) 69 lea 7. Unit or Prope~y name Milne Point Unit 8. Well number I-3 9. Permit numbedapproval number 90-92 10. APl number ,50--029-22067 11. Field/Pool Kuparuk River Field Effec~ dep{h: measured i- 5 true vertical ± 5 feet feet Junk(measured) Casing Structural Conducl~ Surface lnlermediate Production Line' Perlo~a~n del~h: Length Size 80 13-3/5" 2598 9-5/8" 4706 7 "N" Sand measured 4260 - 4378 485 247 942 307 Cemented sxs Perm. C sxs E + sxs G sxs E Measured depth 115' 2633' 4741' "0" Sand 4424 - 4510 True vertical deplh 115' 2399' 4261' true~cal 3796 - 3909 3953 - 4053 (size, grade, and measured depth) 2- 7 / 8" - Packers and,SSS? type and measured depth) NONE 6.5¥/ - L-80 13. Stimulation o~ cement squeeze summary lnlenrals treated (measured) Treatment description including volumes used arx:l final pressure 4095 14. Prkx Io well operation Subsequent 1o operation .Represenlative DaVy Avera~ Production or Injection Data OiI-Bbl Gas-Md Waler-Bbl Casing Pressure N/A Tubing Pressure 15. Atlachments Copies of Logs and Surveys run Daily Report ol Well Operations 16. Slalus of well classification as: 0~1 ~ Gas __ Suspended __ Service hereby cedify thai the foreg .~ng is t~ue and correct to the best of n'y knowledge. S~;ned TitleSr. Production Foreman Date z SUBMIT IN DUPLICATE SUMMARY OF OPERATIONS: OPERATOR: Conoco Inc. WELL: MILNE POINT UNIT I-3 DATE TIME 2-28 3-1 3-1 3-1 3-1 3-1 3-1 3-1 3-1 2130-0030 0030-0100 0100-0330 0330-0430 0430-0630 0630-0700 0700-0900 900-930 930-1000 3-1 3-1 3-1 3-1 3-1 3-1 1000-1300 1300-1500 1500-1600 1600-1630 1630-1745 1745-1815 3-1 3-1 3-1 3-2 3-2 3-2 3-2 3-2 3-2 3-3 3-3 3-3 3-3 1815-1845 1845-2100 2100-2130 2130-0700 0700-0930 0930-2000 2000-2130 2130-2300 2300-2400 2400-0130 0130-0300 0300-0330 0500-1015 1015-1200 1200-2330 ACTIVITY TIH/RBP ON 3-1/2 DDDP & SET @ 2101 MD. PULL OUT OF RBP AND TEST RBP & CASING TO 1500 PSI - OK SPOT 4 SXSA OF SAND ON T/BP AND TAG T/SAND @ 2080~ POOH RU PERFORATING CO. HOLD PERFORATING SAFETY MEETING. RIH & PF 2060-2062 W/lO SHOTS. POOH. PUMP DOWN 7" CSG UP 7"/9-5/8" ANNULES. PUMP YELLOW PAINT DOWN 7"/9-5/8" TO EST. DEPTH HOLE. PAINT RETURN AFTER 1/2 BBL HOLE @ + 5' BENEATH WELLHEAD. MU EZSV TIH. SET EZSV @ 2010 INJECT DOWN DP UP ANNULUS AT 3.2 BPM & 350 PSI. HOLD PRE-JOB SAFETY MEETING TEST LINES AND RU VACUUM TRUCK. PUMP 500 SXS CKASS C PERMAFROST. SAN RETURNS UP 7/9-5/8 AFTER 408 SXS. P.U. TWO STANDS AND REVERSE OUT. POOH C&S DRILL LINE TIH & WOC TAG CMT @ 1907'. DRL CMT 1907-2013. TAG EZSV DRL ON EZSV MADE 3~ POOH PU NEW BIT & DC'S. TIH. TEST 7"/9-5/8". CAN INJECT @ 1300 PSI. TIH TO 2022 DRILL OUT EZSV AND DRILL CMT TO 2040 CIRC BOTTOMS UP MIX AND PUMP 35 SXS CLASS C DOWN 7"/9-5/8 ANNULUS. WOC. TOP OFF 7/9-5/8 W/20 GALS CLASS C PERMAFROST. WOC. 7/9-5/8 STAYED FULL. 3-3 3-3 3-3 2330-003O 0030-0130 0130-0430 0430-1430 DRILL CMT 2040-2080 CBU TEST 7" CSG TO 1500 PSI-OK CIRC. BOTTOMS UP AND POOH TIH, CIRC. SAND, LATCH RBP AND POOH Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 May 1, 1991 Mike Minder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Milne Point Unit H-Pad and I-Pad 10-407's Dear Mr. Minder: Enclosed you will find 10-407's for H-2, H-3, H-4, I-l, I-2, I-3, and I-4. These are overdue and were temporarily lost due to office and personnel changes. This problem was recently discovered and verbally reported to your office. Also you will find a 10-403 and 10-404 for a casing repair job that was done on the I-3 at the end of~the completion, verbal approval was given for the work, but the 10-403 and~ 10-404 forms were not filed. We apologize for the problems. We are currently reviewing all of our records for compliance. If you have any questions, call Van Heare or me at 659-6322. Best regards, Hal Stevens Senior Production Specialist cc well file . ~'~ STATE OF ALASKA -~- 0 ~:'~ ~ ~' i:'~ - ALASKA L.,_ AND GAS CONSERVATION CC /IlSSION ~",, ~ o J~ L WELL COMPLETION OR RECOMPLETION REPORT AND LOG -¢ 1. Status of Well OIL ~ GAS [] SUSPENDED ABANDONED L~ SERVICE Classification of Service Well 2. Name of Operator CONOCO INC. 3. Address , pouch 340045, Prudhoe Bay, Alaska 99734 2945' FNL, 3816' FEL, Sec. 33, T13N, R10E, At Top Producing Interval 4500' FNL, 3380' FEL, Sec. 33, T13N, R10E At Total Depth 4746~ FNL, 3311' FEL, Sec. 33, T13N, R10E 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 69' KB J ADL- 25906 12. Date Spudded 113. Date T.D. Reached 11/5/9o t 11/10/90 17. Total Depth (MD+TVD) ~18.Plug Back Depth (MD+TVD) 4750'M-D/4270' TV~ 4659 '~a;)/4180' TVI) 7. Permit Number 90-92 8. APl Number 5o-029-22067 9. Unit or Lease Name Milne Point Unit 10. Well Number ]:-3 11. Field and Pool Kuparuk River Field 14. Date Comp., Susp. or Aband. 1 15. Water Depth, if offshore 16. No. of Completions 3/7/91 I -- feet MSL 2 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost YES [] NO [] N/A feet MD Jr_F_ 1800 ' 22. Type Electric or Other Logs Run AMS, NGT, CNL, LDT~ D IL 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. '13-3/8" 48# ' 9-5/8" 36# 7" 26# GRADE H-40 SETTING DEPTH MD TOP I BOTTOM 35 'MD/TV~i 15MD/T~q J-55 35 'MD/T~2633 '/MD / L-80 35'MD/T:4741 'MD HOLE SIZE 30" 12-1/4" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. interval, size and number) SIZE "N" Sand 2-7/8" 4260-4280(20'),3796'TVD(TOP), 24SPF, 24GM 4292-4304(12'), 24SPF, 24GM 4322-4328(6'), 24SPF, 24GM 4344-4378(34'),3909'TVD(BOT), 24SPF, 24GM "0" Sand 4424-4455(31'),3953'TVD(TOP), 5SPF, 37GM 4486-4510(24'),4035'TVD(BOT)~ 5SPF~ 37GM 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Not Tested J Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF NA TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GA$-MCF Press. 24-HOUR RATE I~ 28. CORE DATA CEMENTING RECORD 485SX PermaFrost C 247SX Class E AMOUNT PULLED NONE NONE 942SX Class G 8-1/2" 307SX Class G NONE TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 4095' MD NON~ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) ~AMOUNT& KIND OF MATERIAL USED 4424,-4510,MD(,,o,r) 26~802¢t 16-20 Proppant 0-2062'(9-5/8"x7'I) 500SX Class "C"@15,2PPG 65SX "C" TOP-OFF WATER-BBL WATER-BBL CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate Top of ~. Sand l GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 4260' :i 3796' Top of "0" Sand ii 4424' 30. ~-ORMATION TESTS Include ~nterval tested, pressure data, ali fluids recovered and gravity, GOR, and time of each phase. NA 3953' 31. LIST OF ATTACHMENTS Plat, Gyro Survey ', hereby certify that the foregoing is true and correct to the best of my knowledge Signed · _ ,- '~ Title Sr. Prod. Foreman Date 4--2g--q1 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on ail types of lands and leases in Alaska. item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. item 28' If no cores taken, indicate "none" Form 10-407 I I' '1 I'1 '1 "1I 'll'lllll ' I'1111 111 ' NOTES: 1. STA"t% PLANF., COORDINATES ARE ZONE 4. 2, ALL 0EOOET]0 POSITIONS ARE BASEb ON N,A.D, 1927, 3. OFF.':;'ET':J TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSI"RONS, i PAD PROPOSED EXPANSION - ;/ PI § I-3. $ 87'25'1g" E Y 6,009,284.¢86 410.00" X 5,51,787,$89 ..",41LNE PT. VICINITY MAP .MILES LEGEND I EXISTING WELL O PROPOSED WELL AS-BUILT WELL DATA LOCATED WITHIN SECTION 33 T. 13 N., R. 10 E., U.M., ALASKA PLANT A.$.P. ZONE ~L LATITUDE SEC. LINE COORDS / COORDS LONGITUDE OFFSE'r~ I-1 N 1120.60 Y 6,009,445.29 70'26' 11.58¢'* 2951' FNL E 1380.46 X 551,675.16 14.9' 34° 4,~.261" 3696' FEL I-2 N 1120.4,7 Y 6,009,447.85 70' 26° 11.614," 2948' FNL E 1320.51 X 551,615.27 14.9' 34.' 45.019" 3756' FEL I-3 N1120.1a, Y 6,009,450.22 70' 26' 11.64,1' 2945' FNL E 1260,4.1 X 5§1,555.23 1¢9" 34.' 46.780' 3816' FEL I-4. N 1119,98 Y 6,009,4~52.80 70° 26' 11.670# 294,2' FNL £ 1199,66 X 551,~9+,$4 1~9' 3~' ~8.§61" ~876" FEL Sd~'VEYoR'S CEE Ti FI CA TE · I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED ND LICENSED TO PRACTICE LAND SURVEYING IN THE TATF.. OF' ALASKA, AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY DiR- ECT SUPERVISION.AND THAT ALL DIMENSIONS AND OTHER D'g'TAILS ARE CORRECT. "'~ ~-VI~'yF- D FOR: ..... (conoc@ DATE: 3-27-9'I ' ~"H~D:~N~ WELL CONDUCTOR AS-BUILTS ,lOB NO.: .9.o059 , 1 SCALE.: 1 - 300 --- . mill II Cio cl _ Milne Point I No. 3 COMPLETION HISTORY Kuparuk River - SBP - North Slope Borough, Alaska W.I. 1.0 Milne Point I No. 3 CONFIDENTIAL AFE 10-61-1257 Location: 2944' FNL, 3816' FEL, Sec. 33, T13N, R10E, U.M. NSB AK Location: Bottom hole, 4746' FNL, 3311' FEL, Sec. 33, T13N, R10E, U.M. Objective: 4662' MD - Schrader Bluff 02-20-91: MIRU. N/D tree; N/U BOP; install test plug. Rig accepted @ 1400 hrs 02-19-91. 02-21-91: Test BOPs. Annular preventer would not test. N/D ~OP & remove rubber f/ annular off of test plug, N/U BOP. P/U drillpipe. Mix dirt magnet. Reverse @ 5.5 bpm; make 1 additional complete circulation while filtering to 2 microns. POOH. 02-22-91: Replace Hydril rubber, Hydril representative inspected BOP - no problems found. Test BOP, bag leaking. Inspect packing element - inner bore shows large pieces breaking off of i.d. Break bolts @ wellhead flange, remove rubber. Replace packing element w/ a long-life Neoprene (Ser. #50-1157). Test to 3000 psi. R/U & run wt bars to 4632'. POOH. P/U GCT, calibrate, RIH. 02-23-91: P/U GCT, calibrate, RIh & log up, L/D GCT. R/U perf guns/GR/CCL. RIH, shoot 5 spf f/ 4510'-4506', & f/ 4486'- 4506'. POOH. RIH, tie-in w/ CCL f/ previous run. Spot guns & shoot f/ 4424'-4455'. R/D E/L. RIH w/ 3 jnt DP/Champ III/Jars/drill pipe. Attempted to set PKR @ 4218' - no success. POOH, found PKR had backed off where acme thread of bypass mandrel XOs to 3-1/2 IF. L.O.F. - 102', Est. T.O.F. 4536'. Waiting on O.shot. P/U O.Shot. RIH w/ O.Shot/Jars/4 DC/tagged fish @ 4533'. Work over fish; fish appears to be latched. 02-24-91: POOH slow w/ fish; hole taking fluid. L/D fish & P/U new PKR. RIH. Set PKR @ 4225'. Test PKR to 500 psi. Fire turbines, test lines to 8000 psi. Frac well. 02-25-91: Open bypass on PKR. Monitor pressure, csg pressure 0 psi. Reverse circulate bottoms up until clean brine returning. RIH to 4506' (Bottom perf 4510') PKR @ 4414' (Top perf 4424'). Reverse circulate bottoms up @ 1 bpm until clean brine returning. POOH. P/U hydrostatic bailer w/ dump valve. RIH, tagged sand @ 4590' (80' below bottom perf). Bailed down to 4638', P/U wait 15 min., RIH tagged fill @ 4620' - bailer not working. POOH to bailer. Well took 9 bbls. Retrieved 2 bbls sand; found spring loaded check stuck open w/ sand. Milne Point I No. 3 Completion History Page 2 02-26-91: Finish L/D bailer. R/U Schlum. RIH w/ 2.99 gauge ring & junk basket to 4420' - no obstructions. POOH. P/U sump PKR. RIH w/ sump PKR, set @ 4398'. POOH. P/U gun #1 w/ CCL. RIH, tie in w/ CCL, shoot 12 SPF, f/ 4358' - 4378'. POOH. RIH, tie in w/ CCL, shoot f/ 4344' - 4358' POOH RIH, tie-in w/ CCL, shoot f/ 4292' - 4304' & 4358'- 4378' RIH, tie in w/ CCL, shoot f/ 4292' - 4304', RIH, tie-in w/ CCL, shoot f/ 4260' - 4280' RIH w/ 3-3/8 unloaded gun & drift sump PKR. No ~bstructions, POOH, R/D W/L. P/U TCP assby. RIH w/ TCP guns. 02-27-91: RIH w/ TCP assby. Snap into sump PKR, spaceout guns. Guns 12 SPF for following intervals: 4260'-4280', 4292'-4304', 4322'-4328', 4344'-4378' Pressure test lines to 2500 psi; displace tbg w/ 27 bbls of diesel; set PKR. Press up annulus to 1500 psi; guns fired. Press up annulus to 1900 psi, Fas-Fil valve closed. Attempt to flow well - no success. Open PKR Bypass. Flow well - recovered 5.2 bbl/hr. Press up on tbg to 2100 psi to cycle APRM-2. Reverse out tbg, recovered diesel, contaminated brine, & crude. P/U out of sump PKR. Sting back into sump PKR- no obstructions. POOH. L/D TCP assby. P/U gravel pack tools. 02-28-91: M/U Otis PKR. RIH w/ gravel pack assby. Set PKR @ 4190'. Drop ball. Set PKR w/ 2800 psi, Shear out of mandrel w/ 1500 psi, shear out ball seat @ 4200 psi; test PKR to 1500 psi. Pump 12 bbl Sodium Bicarb @ 12-14 pH. Pump 10 bbl gel, pump 604 gal acid w/ super pickle followed by 11 bbls KCL. Reverse 70 bbls. Establish circulation in lower circ. position, shift to reverse. Gravel pack well. Pump 10 bbl prepad & 18 bbl of 8 ppg slurry @ 3 bpm. Pump 5 bbl post pad followed by 9.7 bbls displacement - screened out @ 3200 psi. Retest pack to 3000 psi. Wait on gels to break. Attempt to retest pack - no success. Establish rates: 2 bpm - 2200 psi, 1 bpm - 880 psi. Ship brine to Howco, pump 10 bbl pad & 5 bbl of 12 ppg slurry & 10 bbl post pad while holding 250 psi backpress. Shift to U.C. Pump 11.6 bbls disp. - screened out @ 5000 psi. Reverse out & wait on pack. 03-01-91: Wait on gels. Retest pack to 1500 psi - good test; R/D Howco. POOH. L/D drillpipe. R/U Schlumberger. GIH w/ gravel pack log (TDT/GR). Log gravel pack interval. OK. POOH w/ log. R/D Schlumberger. Begin injecting fluid down 9-5/8" x 7" annulus @ 66 spm, 650 psi. Pressure bled to 0. Found leak coming from inside 13-3/8" csg head. Suspect a hole in 9-5/8" csg. Move 2-7/8" tbg out of pipe shed. P/U 2100' 3-1/2" DP. Call out Halliburton bridge plug, EZSV. R/U to inject in I-4. Pump 380 bbls fluid followed by 50 bbls diesel. M/U bridge plug on drill pipe. TIH to 2100'. Milne Point I No. 3 Completion History Page 3 03-02-91: Finish TIH w/ bridge plug. Set @ 2102' MD. Pick up out of bridge plug. Pressure test plug & 7" csg to 1500 psi. OK. Drop 2 sx sand down 3-1/2" DP. Circ down for few minutes. Drop 2 additional sx down 3-1/2" DP. Circ down DP. Work pipe to get sand to bottom. Tag top of sand @ 2080'. POOH. R/U Schlumberger. Load guns. RIH & perforate 7" csg f/ 2060'- 2062' (10 shots @ 4 SPF). POOH w/ guns. All shots fired. R/U to establish injection rate. Pump down 7" csg @ 1.2 bpm. Observed flow coming out around 13-3/8" csg head. R/D Schlumberger. Pump 2 gals. yellow paint down 9-5/8" csg. Paint came back after 1/2 bbl pumped. Estimate hole is ± 5' below surface. M/U EZSV & TIH. Set EZSV @ 2010' R/U Halliburton cement trucks, lines. Establish injection rate down 3-1/2" DP, up 9-5/8" x 7" annulus. Pump 3.2 bpm @ 350 psi. Mix & pump 500 sx Class "C" Permafrost cement (47% over calculated amount) @ 15.2 ppg (92 bbls of slurry). Got cement returns to surface after pumping 75 bbls slurry. Displace cement down 3-1/2" DP w/ 7 bbls brine. Pull 2 stds DP & reverse circulate. POOH. P/U 6-1/8" bit, 2 junk baskets, 10 DC's & TIH to 1700'. WOC. 03-03-91: Wait on cement. RIH & tag cement @ 1907'. Displace brine w/ 8.4 ppg gel mud. Drill cement f/ 1907-2013'. Tag EZSV. Drill on EZSV. Made 2-3'. Bit stopped makingbrash°lee' POOH. Teeth on inner row of bit broken off. Retrieved & metal pieces out of junk basket. M/U new bit. TIH. R/U to pressure test cement job at surface. Established injection @ ± 1300 psi. 03-04-91: Finish TIH to 2022'. Drill remaining section of EZSV. Drill cement to 2040' (Perfs in 7" @ 2060-62'). Circ B/U. R/U Halliburton to 9-5/8" csg valve. Pressure test lines to 2000 psi. Pump into 9-5/8" valve. Got returns immediately in cellar through 13-3/8" csg head. R/U 2" line to 9-5/8" csg valve. Mix & pour 10 gals cement (Class "C" @ 15.8 ppg). R/U Halliburton pump to 9-5/8" x 7". Test lines. Mix & pump 3 bbls Class "C" Permafrost cement @ 15.2 ppg. Got cement returns in cellar. Vac truck rigged up to suck out of cellar. Mix & pump another 3 bbls Class "C" @ 15.2 ppg. Full returns in cellar. Shut down. Mix & pump 4 bbls of Class "C" @ 16 ppg. Cement level dropped. Mixed 5 gal of "C" @ 15.2 ppg. Pour down fluted 9-5/8" hgr & topped off. Mixed & poured approximately 20 gals cement inside 9,5/8" x 7" to top off. WOC. Cement level stayed full. Drill cement f/ 2040'- 2050'. Milne Point I No. 3 Completion History Page 4 03-05-91: Drill cement f/ 2050-2080'. Circ B/U. Test 7" csg to 1500 psi for 30 minutes. OK. RIH to 2080' , circ sand, wash sand to 2093'. Circ B/U. POOH. P/U overshot for bridge plug. M/U 2 junk baskets, csg scraper & TIH to 2093'. Wash sand to top of bridge plug @ 2102'. Latch on to bridge plug. Circ B/U to clean sand off bottom. Displace gel mud in hole w/ water. Circ twice to clean hole. Displace water w/ 8.6 ppg brine w/ 12% MeOH. POOH laying down drill pipe. L/D Halliburton tools, bridge plug. R/U & RIH to pull wear bushing. Change out 3-1/2" rams to 2-7/8". R/U to inject fluid down I-4 9-5/8" x 7" annulus. Test 2-7/8" rams to 5000 psi. Prepare to pick up ESP. P/U shroud for pump. P/U PSI section & check out. OK. P/U motor. Fill w/ oil. P/U protector, gas separator & pump. M/U all sections. Insert cable into outlet. 03-06-91: RIHw/pump. P/U 2 jts 2-7/8" tbg, AVA ported nipple, 127 jts 2-7/8", 6.4#, L-80, EUE 8rd. M/U tbg hgr, Splice ESP cable to lower pigtail. Land tbg hgr; M/U lockdown screws. Test hgr body seals to 5000 psi. N/D BOPs. N/U tree. Test tree to 5000 psi. Pull two-way check valve. Pump 60 bbls diesel down 7" x 2-7/8" annulus. Install BPV. Pump 12 bbls diesel down 2-7/8" tbg. R/U & pump 50 bbls diesel down I-4. Prepare to release rig. Rig Released @ 0130 hrs on 03/06/91. Operations suspended pending well test. OPERATOR: CONOCO MILNE POINT UNIT I-3 c/~/,~, / FINAL DRILLING REPORT'aJa's'kO0il ] ] /993 ' WELL: MPU I-3 FIELD: KUPARUK P'i:1~4662 MD CASING: 13 3/8" @ 105 9 5/8" @ 2633 7" @ 4741 CURRENT TD: 4750 PROGRESS: 0 DATE: Descsription of Operations: 11-06-90: 11-07-90: 11-08-90: 11-09-90: 11-10-90: 11-11-90: 11-12-90: 11-13-90: 11-14-90: 11-15-90: Move rig f/I-2 to I-3. Rig up. PU rig @ 1400 hrs 11-05-90. NU diverter. MU 12 1/4" Steerable BHA. Drill 105 to 177. Drill f/177 to 1411. Run single shot survey. Drill to 2168, Ream out dogleg, Drill f/2168 to 2640. C & C. Short trip. C & C. POOH. Run 4 arm caliper on E/L. Run 68 jts 9 5/8" csg, 36//, K-55, Butt. FS @ 2633. Circ. Circ and RECIP. Cement wi 416 BBI E Artic cmt @ 12.3 PPG & 52 BBL G @ 15.8 PPG. Disp same. Did not bump plug. Flowline plugged w/gelled cmt returns. Left 62 BBL cmt in csg. Clean out cmt f/flow line. ND diverter. NU BOP. Attempt to land BOP test plug. ND BOP. Repair tbg hgr alignment pin. NU. Test BOP's. MU 8 1/2" BHA. RIH.. Tag cmt @ 1683. Drill cmt 1683 to 2547. Test 9 5/8" csg to 1500 psi. Drill out float equip. Drill 2640 to 2660. Circ. Run leakoff test to 16.8 PPG EMW. POOH. MU steerable BHA & RIH. Drill 2660 to 3209'. Drill 3209 to 3683. Short trip. Drill to 4750. C & C. Short trip. C & C. POOH. RU E/L. RIH w/AMS-NGT-CNL-LDT-DIL. Stuck logging tools @ 4750 on initial pick up. Cut E/L. Strip over E/L w/DP. Circ. Latch fish. Pooh w/fish. LD tools. RIH w/8 1/2" bit. Circ. Short trip to shoe. Circ. Spot pill. POOH. Monitor well. Loosing 5 BPH. RIH. Spot pill. POOH to shoe. Observe well. Lost 15.8 BBL in 7 hrs. Lost only 3/4 BBL last hr. POOH. RU E/L. RIH w/AMS-NGT-CNL-LDT-DIL. Log well. RD E/L. RIH w/bit. C & C. POOH. LD DP & BHA. Run 117 jts, 4699', 26//, L-80, 7" BUTT csg. Circ & Recip. Cement w/63 BBL G cmt. Bump plug. FS @ 4741. FC @ 4660. Test csg to 1500 psi. Install packoff. Test same. ND BOP's. NU tree. Inject mud down annular. Freeze protect well. Finish cleaning pits. Release rig @ 0500 hrs 11-14-90 to I-4. Operations suspended until completion rig arrives. RIG RECEIVED: 11-05-90 SPUD DATE: 11-05-90 RIG: NABORS 27 DAYS: 9 / 8 FOREMAN: Rossberg DATE: 11-15-90 ORIGINAL SUB.$URFACE DIRECTIONAL ~URVEY F~UIDANCE [~]ONTINUOUS ~]OOL Company Well Name CONOCO INC. MILNE POINT UNIT I-3 (2944' FNL,3816' FEL,SEC 33,T1..~N,10E) Field/Location SCHRADER BLUFF~ NORTH SLOPE, ALASKA Job Reference No. 74382 Loaaed SCHWARTZ MICROFILMED °", Computed By: KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR CONOCO INC. MILNE POINT UNIT I-3 SCHRADER BLUFF NORTH SLOPE, ALASKA SURVEY DATE: 21-FEB-91 ENGINEER: SCHWARTZ METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation anO azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 18 DEG 36 MIN EAST COMPUTATION DATE: 26-FEB-91 PAGE 1 CONOCO INC. MILNE POINT UNIT I-3 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 21-FEB-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTh SECTION SEVERITY NORTH/SOUTm EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 100.00 100 200.00 200 300.00 299 400.00 399 500.00 499 600.00 599 700.00 698 800,00 797 900.00 894 0 O0 -70 O0 0 0 N 0 0 E O0 30 O0 130 99 229 99 329 96 429 65 529 85 628 31 727 70 824 O0 0 22 S 80 19 E O0 0 30 S 56 49 E 99 0 35 S 52 43 E 99 0 48 S 47 56 E 96 2 5 S 35 10 E 65 6 0 S 29 48 E 85 8 33 S 30 20 E 31 11 26 S 26 22 E 70 14 50 S 27 1 E 0 O0 0 14 0 65 1 41 2 39 4 45 11 80 24 15 41 29 63 71 0 O0 0 44 0 19 0 O0 031 2 22 2 50 3 24 2 78 4 02 0.00 N 0.06 S 0.24 E 0 0.36 S 0.97 E 1 0.91 S 1.73 E 1 1 64 S 2.63 E 3 332 S 4.10 E 5 9 82 S 7.82 E 12 20 71 S 14.18 E 25 36 05 S 22.34 E 42 56 31 S 32.40 E 64 0.00 E 0 O0 N 0 0 E 25 S 74 46 E 03 S 69 38 E 95 S 62 13 E 10 S 58 4 E 27 S 5O 59 E 55 S 38 32 E 10 S 34 24 E 41 S 31 48 E 97 S 29 55 E 1000.00 990 26 920 26 19 6 S 25 19 E 1100.00 1083 1200.00 1175 1300.00 1265 1400.00 1353 1500.00 1440 1600.00 1528 1700.00 1616 1800.00 1704 1900.00 1789 92 80 68 1013 68 22 37 S 22 9 E 128 32 02 1105 02 24 49 S 21 47 E 168 92 69 1195 69 25 55 S 20 25 E 211 07 67 1283 67 29 45 S 20 34 E 258 52 48 1370 48 29 25 S 19 50 E 308 13 14 1458 14 28 10 S 17 59 E 356.25 84 1546.84 27 11 S 16 17 E 402.41 31 1634.31 31 4 S 16 21 E 450.78 35 1719.35 32 0 S 16 0 E 503.35 4 23 3 95 0 84 531 0 45 1 69 1 76 091 3 O0 0 55 82.59 S 45.53 E 94 31 S 28 52 E 115.32 S 59.62 E 129 153.02 S 74.88 E 170 192.41 S 89.99 E 212 236.90 S 106.58 E 259 283.45 S 123.80 E 309 328.95 S 139.45 E 357 373.16 S 152.81 E 403 419.60 S 166.48 E 451 470.13 S 181.14 E 503 82 S 27 20 E 36 S 26 5 E 42 S 25 4 E 77 S 24 13 E 31 S 23 36 E 29 S 22 58 E 23 S 22 16 E 42 S 21 38 E 82 S 21 4 E 2000 O0 1874.29 1804 29 32 2 S 15 45 E 556.05 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1958.35 1888 O0 2041.81 1971 O0 2124.84 2054 O0 2206.92 2136 O0 2289.13 2219 O0 2371.75 2301 O0 2454.32 2384 O0 2535.73 2465 O0 2617.71 2547 35 33 24 S 17 17 E 610 19 81 33 31 S 17 37 E 665 84 34 26 S 17 47 E 720 92 34 53 S 17 30 E 778 13 34 28 S 16 48 E 835 75 34 9 S 15 56 E 891 32 34 56 S 13 53 E 947 73 35 42 S 13 40 E 1005 71 34 0 S 13 19 E 1062 26 98 10 01 30 58 44 47 1 32 0 27 0 55 1 79 041 0 0 1 0 1 520.91 S 195.49 E 556 38 S 20 34 E 572.84 S 210 89 E 610 625.39 S 227 39 E 665 678.47 S 244 39 E 721 732.90 S 261 72 E 778 82 787.29 S 278 53 E 835 63 841.34 S 294 39 E 891 86 895.86 S 308.87 E 947 74 952.27 S 322.64 E 1005 48 1007.93 S 336.07 E 1062 43 S 2O 13 E 45 S 19 59 E 14 S 19 49 E 23 S 19 39 E 11 S 19 29 E 36 S 19 17 E 61 S 19 1 E 44 S 18 43 E 48 S 18 26 E 3000 O0 2700 54 2630 54 34 42 S 13 59 E 1118.28 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2782 17 2712 O0 2862 44 2792 O0 2942 89 2872 O0 3023 83 2953 O0 3105 85 3035 O0 3189.87 3119 O0 3276.60 3206 O0 3366.52 3296 O0 3458.99 3388 17 35 49 S 15 23 E 1175.90 44 36 50 S 16 59 E 1235.48 89 36 3 S 17 58 E 1294.87 83 35 46 S 19 15 E 1353.58 85 33 49 S 19 30 E 1410.78 87 31 34 S 18 52 E 1464.99 60 28 0 S 21 8 E 1514.71 52 24 5 S 24 10 E 1558.28 99 20 36 S 25 41 E 1596.06 2 12 1062.41 S 349.14 E 1118 31 S 18 12 E 53 1118 32 S 363.63 E 1175 43 1175 43 1232 97 1287 58 1341 66 1392 43 1439 87 1480 88 1514 48 S 380.61 E 1235 23 S 398.17 E 1294 79 S 417.14 E 1353 75 S 436.16 E 1410 96 S 453.95 E 1465 78 S 470.70 E 1514 01 S 487.74 E 1558 53 S 503.65 E 1596 96 S 18 1 E 56 S 17 56 E 96 S 17 54 E 67 S 17 57 E 86 S 18 0 E 06 S 18 3 E 77 S 18 6 E 31 S 18 14 E 08 S t8 24 E CONOCO INC. MILNE POINT UNIT I-3 SCHRADER BLUFF NORTH SLOPE, ALASKA COMPUTATION DATE: 26-FEB-91 PAGE 2 DATE OF SURVEY: 21-FEB-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTt}RE' MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTfl/SO~JTm EAST/WEST DIST. AZIMUTh DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/ O0 FEET FEE7 FEE7 DEG MIN 4000.00 3553 20 3483 20 18 52 S 26 51 E 1629 29 4100.00 3648 4200.00 3743 43O0.00 3839 4400.00 3935 4500.00 4030 4600.00 4126 4700.00 4221 4741.00 4261 11 3578 63 3673 40 3769 09 3865 78 3960 40 4056 97 4151 16 4191 11 17 42 S 25 44 E 1660 63 16 50 S 22 10 E 1689 40 16 46 S 16 9 E 1718 09 16 54 S 14 55 E 1747 78 16 54 S 14 40 E 1776 40 17 4 S 14 14 E 1805 97 17 7 S 14 14 E 1835 16 17 7 S 14 14 E 1847 0 75 1544.59 S 518 49 E 1629.29 S 18 33 E 49 93 1 69 0 68 0 66 0 85 0 18 0 21 0 60 1572.77 S 532 64 1599.74 S 544 84 t626.99 S 553 07 1654.99 S 561 26 1683.06 S 569 31 1711.39 S 576 O0 1739.91 S 583 O0 1751.60 S 586 56 E 1660.49 S 18 42 E 71 E 1689.94 S 18 48 E 94 E 1718.70 S 18 48 E 62 E 1747.69 S 18 45 E 06 E 1776.66 S 18 41 E 40 E 1805.85 S 18 37 E 64 E 1835.19 S 18 33 E 60 E 1847.21 S 18 31 E COMPUTATION DATE: 26-FEB-91 PAGE 3 CONOCO INC. MILNE POINT UNIT I-3 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 21-FEB-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HOR]Z. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUI-r~ DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 0 O0 0 O0 -70 O0 0 0 N 0 0 E 0 O0 1000 O0 990 26 920 26 19 6 S 25 19 E 92 BO 2000 O0 1874 29 1804 29 32 2 S 15 45 E 556 05 3000 O0 2700 54 2630 54 34 42 S 13 59 E 1118 28 4000 O0 3553 20 3483 20 18 52 S 26 51 E 1629 29 4741 O0 4261 16 4191 16 17 7 S 14 14 E 1847 21 0 O0 0 O0 N 0.00 E 0 O0 N 0 C) E 4 23 82 59 S 45.53 E 94 31 S 28 52 E 1 32 520 91 S 195.49 E 556 38 S 20 34 E 2 12 1062 41 S 349.14 E 1118 31 S 18 12 E 0 75 1544 59 S 518.49 E 1629 29 S 18 33 E 0 O0 1751 60 S 586.60 E 1847 21 S lB 31 E COMPUTATION DATE: 26-FEB-91 PAGE 4 CONOCO INC. MILNE POINT UNIT I-3 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 21-FEB-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WES1 DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 70 O0 170 O0 270 01 370 01 470 03 570 20 670 86 772 t7 874 50 0 O0 70 O0 170 O0 270 O0 370 O0 470 O0 570 O0 670 O0 770 O0 870 O0 -70.00 0 0 N 0 0 E 0.00 0 15 S 73 20 E 100.00 0 29 S 63 12 E 200.00 0 33 S 53 14 E 300.00 0 43 S 50 20 E 400.00 1 31 S 39 29 E 500.00 5 22 S 29 20 E 600.00 7 42 S 30 30 E 700.00 10 41 S 26 56 E 800.00 13 54 S 26 32 E 0 O0 0 O6 0 46 1 17 2 O5 3 57 8 91 20 12 36 O0 57 45 0 O0 0 62 0 20 0 O0 0 27 1 76 2 52 2 29 2 62 3 5O 0.00 N 0.04 S 0.23 S 0.73 S 1.38 S 2.58 S 7.26 S 17. 16 S 31.27 S 50.67 S 0 O0 E 0 08 E 0 75 E 1 49 E 2 33 E 3 54 E 6 37 E 12 09 E 1995 E 29 55 E 0 O0 N 0 0 E 0 0 2 4 9 21 37 58 08 S 65 16 E 78 S 72 50 E 66 S 63 53 E 71 S 59 23 E 37 S 53 55 E 65 S 41 15 E O0 S 35 10 E 09 S 32 32 E 66 S 30 15 E 978 61 1085 1194 1304 1418 1533 1647 1760 1877 1994 970 O0 21 1070 ,47 1170 82 1270 82 1370 81 1470 31 1570 25 1670 19 1770 93 1870 900.00 18 19 O0 1000.00 22 5 O0 1100.00 24 49 O0 1200.00 26 12 O0 1300.00 29 49 O0 1400.00 28 56 O0 1500.00 27 27 O0 1600.00 29 23 O0 1700.00 32 0 O0 1800.00 31 57 S 26 7 E S 22 18 E S 21 52 E S 20 24 E S 20 32 E S 19 18 E S 16 42 E S 16 29 E S 16 6 E S 15 42 E 86 O0 122 71 166 60 213 22 267 87 324 62 378 29 430 73 491 28 553 35 3.61 3.77 0.73 5.54 0 34 1 56 1 82 5 69 0 59 1 17 76.42 S 110.13 S 57 150.87 S 74 194.43 S 90 245.66 S 109 298.99 S 129 350.00 S 145 400.35 S 160 458.52 S 177 518.31 S 194 42 56 E 50 E 124 03 E 168 74 E 214 86 E 269 32 E 325 99 E 379 82 E 431 80 E 491 75 E 553 87 47 S 29 7 E 23 S 27 34 E 05 S 26 8 E 56 S 25 I E 10 S 24 6 E 76 S 23 23 E 23 S 22 38 E 44 S 21 53 E 78 S 21 12 E 69 S 20 36 E 2113 96 1970 O0 1900 O0 33 24 2233 2354 2476 2597 2719 2842 2963 3085 3209 85 2070 97 2170 79 2270 88 2370 15 2470 O8 2570 01 2670 01 2770 44 2870 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 S 17 20 E O0 33 41 S 17 46 E 683 O0 35 0 S 17 41 E 752 O0 34 36 S 17 0 E 821 O0 34 9 S 15 57 E 890 O0 35 16 S 13 45 E 958 O0 35 10 S 13 40 E 1029 O0 34 2 S 13 31 E 1097 O0 35 36 S 14 59 E 1167 O0 36 46 S 16 56 E 1241 617 87 99 32 86 11 54 77 48 17 13 0.12 0.61 0.26 0.81 0.61 1 .45 2.15 1 .59 1 .85 1 .55 580 18 S 213 17 E 618 10 S 20 10 E 643 708 774 84O 906 976 1042 1109 1180 24 S 233 32 S 253 71 S 274 20 S 294 53 S 311 O0 S 328 13 S 344 88 S 361 89 S 382 08 E 684 93 E 752 71 E 821 07 E 890 50 E 958 40 E 1029 18 E 1097 34 E 1167 26 E 1241 17 S 19 55 E 46 S 19 43 E 97 S 19 31 E 18 S 19 17 E 56 S 18 58 E 77 S 18 36 E 50 S 18 17 E 22 S 18 2 E 22 S 17 56 E 3333 52 2970 O0 2900 O0 35 59 3456 3576 3692 3803 3911 4017 4122 4227 4331 59 3070 59 3170 54 3270 81 3370 76 3470 75 3570 96 3670 54 3770 97 3870 O0 3000 O0 3100 O0 3200 O0 3300 O0 34O0 O0 3500 O0 3600 O0 3700 O0 3800 oo 34 49 O0 32 15 O0 28 19 O0 23 58 oo 20 16 O0 18 43 O0 17 25 O0 16 43 O0 16 53 S 18 47 E 1314 58 S 19 28 E 1386 S 18 57 E 1452 S 20 48 E 1511 S 24 11 E 1559 S 25 53 E 1600 S 26 57 E 1634 S 25 12 E 1667 S 20 7 E 1697 S 15 28 E 1727 30 6O 25 82 17 95 36 87 93 1 69 2 76 2 84 4 10 3 O0 2 30 0 57 1 32 2 60 0 57 1250 94 S 404 38 E 1314 67 S 17 55 E 1318 1381 1436 1481 1518 1549 1579 1607 1635 66 S 427 24 S 449 55 S 469 43 S 488 26 S 505 70 S 521 03 S 535 16 S 547 99 E 1386 94 E 1452 43 E 1511 38 E 1559 45 E 1600 07 E 1634 53 E 1667 56 E 1697 38 S 17 59 E 67 S 18 3 E 30 S 18 6 E 85 S 18 15 E 18 S 18 25 E 95 S 18 35 E 37 S 18 44 E 88 S 18 49 E 89 S 556.46 E 1727.94 S 18 47 E COMPUTATION DATE: 26-FEB-91 PAGE 5 CONOCO INC. MILNE POINT UNIT I-3 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 21-FEB-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES ~ORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4436.49 3970.00 3900.00 16 53 S 14 56 E 1758.26 4541.00 4070.00 4000.00 17 0 S 14 38 E 1788.59 4645.62 4170.00 4100.00 17 7 S 14 14 E 1819.23 4741.00 4261.16 4191.16 17 7 S 14 14 E 1847.21 0.15 1665.24 S 564.35 E 1758.27 S 18 43 E 0.18 1694.63 S 572.08 E 1788.59 S 18 39 E 0.00 1724.40 S 579.71 E 1819.23 S 18 35 E 0.00 1751.60 S 586.60 E 1847.21 S 18 31 E CONOCO INC. MILNE POINT UNIT I-3 SCHRADER BLUFF NORTH SLOPE, ALASKA MARKER LAST READING GCT DRILLERS TD COMPUTATION DATE: 26-FEB-91 INTERPOLATED VALUES FOR CHOSEN HORIZONS DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: PAGE 6 21-FEB-91 70.00 FT SCHWARTZ SURFACE LOCATION : 2944' FNL & 3816' FEL, SEC33 T13N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4601.49 4741.00 4127.82 4057.82 4261.16 4191.16 1711.82 S 576.51 E 1751.60 S 586.60 E COMPUTATION DATE: 26-FEB-91 PAGE 7 CONOCO INC. MILNE POINT UNIT I-3 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 21-FEB-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: SCHWARTZ ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 2944' FNL & 3816' FEL, SEC33 T13N RIOE MARKER MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST LAST READING GCT DRILLERS TD 4601.49 4127.82 4057.82 1711.82 S 576.51 E 4741.00 4261.16 4191.16 1751.60 S 586.60 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 4741.00 4261.16 4191.16 1847.21 S 18 31 E SCHLUMBEROEF~ 13 1RECT I ONAL SURVEY COMPANY CONOCO i' NC. WELL MILNE POINT UNIT I-B FIELO SCHRADER BLUFF COUNTRY USA RUN ONE DATE LOOOEO 21 - FEB - 9i REFERENCE 74982 WELL' ,MPU I-3 (2944' FNL, 3816' FWL,SEC 33, T13N, iOE) N~TH ISO0 ~EF 1000 50O -SOO -lO00 -lSO0 -~000 -2500 -1500 Hb..,ZONTAL PROJECTION SCALE : I/S00 IN/FT -I000 -SO0 0 SO0 I000 ISO0 2000 2S00 E~Sl _944' FNL, 38'i6' FBL, SEC 33, .3N, IOE) VERTICAL PROJECTION - 1000 -600 0 ~00 10610 160b ,'uuu · .4-.b,:'-HL-L~-.LL.,LLLL.TZ~'.ZT..~, '.T.Z;:;T..%Z?:i i i:¢~ i ~ ~:~i-..H-~..-i..-;.--.-.?.r.f...r.L;-+..,..~.-.-.~...H...r...l...;...H: .......... ;...:..., ....... ~-..;...LL', .... .. z ..z -L- :...I" ! : i ~J,.. ! ~ ~ : .,L. ! ! [ : '%: .?-%, '~"'~--T-~: ?' :'"T~:-~-~-,-_~'*"?-'?-''? .............. ,-.*...+ ........... ~.....--* ...... * ...... ~ ....... ;.~.~ , ;...,. ~, ~ _$ .T ~ ? 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L ;...., : i ..... ~ ; ; ~ · i : ' ~ i [ ' i ; i I ; I ~ I i i ; ~ i PROJECTION ON VERTICAL PLANE 161. - 341. ~ig:l::ILED IN VERTICAL OEPTHS HORIZ SCALE = I/S00 IN/FT AOGCC GEOLOGICAL MATERIALS iNVENTORY' LiST PERiviiT # ~t~ COMPLETION DATE CO. CONTACT check off or list data ~'~" i~ is rcceivcd.*list received date for 407, if n~i reejuircd list as NR corc~ intc~ais core anaivs,is j~ d~ di~c. ~nt. wais ,., ' ' ,_ di~italdata ii LOG 'l-~,,/nlc' J RUN '"-" ,,~1, ER~fALo SCALE I Ir'L NO. [to thc nearest footJ [inchl100'] ~i CP~., ............... ~ ~, Ict~-,z~?z ....... 5 , -~ c0m~ . [ ,hqm - ~q !.5 .5 ..... j , ~, H, ~ ' ' "" ' '" " 131 i Il I I I I I I 111 '" ~ ..... I ~ I , ii i i TO: THRU: FROM: 'MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Smi~~/' DATE: March 28, 1991 Commissioner / ~ FILE NO: DA328 TELEPHONE NO: SUBJECT: BOPE Walk-thru Insp Conoco's MPU I-3 Permit No. 90-92 Kuparuk Rv Field Doug Amo~ Petroleum Inspector Th!lrsda¥ Feb,_28, 1993: I travelled this date from AAI's KRU to Conoco's MPU I-3 well to conduct a BOPE walk-thru inspection on Pool Arctic Rig 102. As the attached AOGCC BOPE walk-thru inspection report indicates, I found one non-compliance item. A hammer union in the line running from the choke manifold to the top of the gas buster was welded at the inlet and outlet but the hammer ring was not. I brought this to the attention of Conoco rep., Ben Kotava, and was assured that as soon as the pit system could be drained to remove the methonal base fluid, the hammer union ring would be welded. I noted this in my problems area of my change out notes for Harold Hawkins so that a follow-up inspection would be conducted. In summary, I conducted a BOPE walk-thru inspection at Conoco's MPU I-3 well on Pool Arctic Rig 102. I found one non-compliance item which will be corrected as soon as the mud system can be purged of the methonal based mud. Attachment. 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 STAi~E OF"A[ASKA ALASKA 01L AND GAS CONSERVAT I ON COMM I SS I ON BOPE Walk-Thru Inspection Report. OPERATION: Drlg Wkvr.,!/ UIC DATE: Location: Sec '?~ T \~L~,! R ~, M~-~. ~> Permit Location (gen'l) ~ Well ~gn A. pass fa~l n/a DIVERTER ~",:~'1~.-(~ ( ) ( ) fJrewa11 1. ( ) ( ) (~, l~ne sz & length 12. (~,~_ ( ) ( ) n~trogen power source (back-up) 2. ( ) ( ) (~,)'/l~ne conn& anchored 13 (~' ( ) ( ) condition (leaks~ hoses~ eta) 3. ( ) ( ) (~, bifurcated & dwn wind ~ ( ) ( ) (,):,.BO° targeted turns J D. pass f8~1 nj8 MUD SYSTEM 5. ( ) ( ) (~J/ vlvs: auto & s~multaneou8 ~ 1. ((- ( ) ( ) pit level floats installed ~:.annular pack-off 2 ( ) ( ) ( ) flow rate sensors ~.() () (~ . 7. ( ) ( ) (,?}x condition : 3. (~ ( ) ( ) mud gas separator ~. (~) .......( ) ( ) degasser B. pass fa~l n/a BOP STACK 5. ('~() ( ) separator b~pass 1. (~ ( ) ( ) wellhead flg wkg press G. (~ ( ) ( ) gas'sensor 2. (~>~ ( ) ( ) stack wkg press 7. (~ ( ) ( ) chke I n conn ~. (~ ( ) ( ) annular preventer 8. (~'-'() ( ) tr~p tank ~. (~,?~'~ ( ) ( ) p~pe rams 5. (;~}'~', ( ) (') bl~nd rams E. ~,fail n/a RIG FLOOR G. (~.~):,., ( ) ( ) s~ack anchored ~ 1. (~,.-~ ~ ( ) ke11~ cocks (upper,lower,IBOP) 7. (~)", ( ) ( ) chke/k~11 l~ne sz 2 (~ ( ) ( ) floor vlvs (dar~ vlv~ ball vlv) 8. (~-:)~' ( ) ( ) BO' ~urns targeted (chke & k~11 ln) ~. (~' ( ) ( ) ke11~ & floor vlv ~renches B. (>) ( ) ( ) HCR vlv8 (chke & kill) ~. (~.,) ...... ( ) ( ) driller's console (flow monitor~ 10. (~ ( ) ( ) manual vlvs (chke & k~11) flow rate indicator~ p~ level 11. ( ) (~ ( ) connections (flgd~ whd~ clmpd) ~nd~cators, gauges) 12. (~' ( ) ( ) dr1 spool 5. ( ....... ( ) ( ) kill sheet up-to-date 13. ('~'.,~ ( ) ( ) fio, nipple 6. (~ ( ) ( ) gas ~etection monitors 1~. (V~"[' ( ) ( ) flow monitor . (H S & methane) 15. (,~' ( ) ( ) control lines f~re protected 7. (~"'() ( ) hydr chke panel 8. (~"~') ( ) chke manifold C'. ~, 'fail n/a CLOSING UNITS 1. ( ) ( ) wkg press F. ~ fail g/a MISC EQUIPMENT 2. (~], ( ) ( ) fluid level 1. '( ) ( ) flare line ~. (~[', ( ) ( ) oprtg pres~ 2. (~-)'" ( ) ( ) vent line ~. (~/. ( ) ( ) press gauge~ 3. (~ ( ) ( ) 90° turns targeted 5 (~:)~/ ( ) ( ) sufficient vlvs ~. (~ ( ) ( ) (dwn ~trm choke lns) G (~ ( ) ( ) regulator bypass 5. (~)~ ,. ( ) ( ) reserve pit tankage 7. (~ ( ) ( ) ~-way vlvs (actuators) G. ('~] ( ) ( ) personnel protective equip avail 8. (~' ( ) ( ) bl~nd handle cover 7. (~ ( ) ( ) all dr1 site suprvs trained 9. (~/~ ( ) ( ) driller control panel for procedures 10. ('~ ( ) ( ) remote control panel (if apple) 8. ( ) . ( ) (~ H2S probe8 B. (~[;' ( ) ( ) r~g housekeeping RECORDS Date of last BOP'inSpection: Resulting failures: :~: ;- ~::?:~ Failures not corrected & why: '~ /~ / Date corrections will be completed: /~-~// ~ / ~ BOP test & results properly entered on daily record? .~. ~t'~:, ~ Inspector ~.0013 (rev O~/O~/B1) Date of last BOP test: Kill sheet current? SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 9'725 ! -21 '/5 PLEASE REPLY TO ,V, AR 0 $ 19§1 SCHLVMS£"OE" WELL SERVICES ?ouch 340069 ?rudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberger Gentlemen: Gravel Pack, Run 1, 2/28/91' Enclosed are 2, BLprints of the Casing Punch, Run 1, 3/1/91 Company CONOCO, Inc. ,on: '1 Well Milne Point Unit I-3 Field. Milne PoinWSchrader Bluff Additional prints ore being sent to: ! BL prints CONOCO, Inc. 600.North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER County~No.rth Slope State_, Alaska 1 BL prints, 1 RF Sepia CONOCO, Inc. 1000 South Pine Ponca City, OK 74603 Attn: Glenn Welch 7350RDW 1BL nrints, I RF Sepia OXY U:S.A., Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrol *(915/685-5898) 1BL prints, 1RF Sepia Chevron U.S.A., 11111 South Wilcrest Hosuton, TX 77099 Attn: Priscilla MacLeroy *(713/561-3652) Alask~ Oil & Gas Conserva~cion .Commission 3001 ..Porcupine Drive Anchora~e.-AK 99501 The film is returned to CONOCO, Ponca City. We appreciate the privilege of serving you. prints prints prints RECEI / n ~ v LI~ MAR 8 ]991 Very truly yours, SCHLUMBERGER WELL SERVICES Raymond N. Dickes DISTRICT MANAGER SWS-- 1327-F SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 I~LEASE REPLY TO FEB 2 T 1991 SC.LUUSE"~E. WELL SE.V,C~S Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberser Gentlemen: Enclosed are 2. B. Lprints of the Comp Eec, Run 1, 2/25/91 Company CONOCO, Inc. on: -I Well Milne Point Unit I-3 Field. Milne Pain, Schrader Bluff Additional prints ore being sent to: 1 BL nrints CONOC6, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER ~ounty North Slope State 1BL prints, 1RF Sepia CONOCO, Inc. 1OOO South Pine Alaska Ponca City,_..OK 74603 Attn: Glenn Welch 73§ORDW 1 BL prints, I RF Sepia OXY U.S.A., Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrel *(915/685-5898) 1BL prints, 1RF Sepia Chevron U.S.A. 11111 South Wilcrest Hosuton, TX 77099 Attn: Priscilla MacLeroy *(713/561-3652) Alas~;~fOil & Gas ConservatiOn C./~mmis~ion ... / 3~1 .POrcupine Drive ~chora[e. AK 99501 ~ttn: 3o~n B°vle The film is returned to CONOCO, Ponca City. We appreciate the privilege of serving you. prints ~prints prints Received by: Date: Very truly yours, SCHLUMBERGER WELL SERVICES Raymond N. Dickes DISTRICT MANAGER SW$--t327-F '~ CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 772S I'Z ' TS PLEASE REPLY TO FEB Z.~ ~J.~_l SC,LU,,E.~E, WELL SERVICES :~, ::i:'4.:i ii! ~ POuch 340069 ~" :' ;~/~:' ~'~} Prudhoe Bay, ~ 99734-0069 ~ttn: Bern~e/Shelloy Attention: Van Lineberger Gentlemen: Enclosed ore 2 BLprintsof the Perf, CGT, Run 1, 2/21/91 Company. CONOCO, [nc. on: Well Milne Point Unit I-3 Field Milne Point/Schrader Bluff Additional prints ore being sent to: ! BL _prints CONOCO, Inc. 600 North Dair~ Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER County North Slope State_ Alaska 1BL prints, 1RF Sepia CONOCO, Inc. 1000 South Pine Ponca Cit¥,..OK 74.603 Attn: Glenn Welch 736ORDW I BL mrints, 1RF Sepia OXY UiS.A., Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrel *(915/685-5898) 1BL prints, 1RF Sepia Chevron U.S.A. lllll South Wilcrest Hosuton, TX 77099 Att. n: Priscilla MacLero¥ *(713/561-3652) 1BL Alask~/O'~l & Gas Conser'*%.,~t:ionXk,. . Qo~i s ~ion, 3OzOl Porcupine Drive f~chorage, ~ 99501 / ~:: '~%e ~fii'~ n o CONOCO, Ponca City. We appreciate the privilege of serving you. prints ~prints prints Received by: Date: Very truly yours, SCHLUMBERGER WELL SERVICES Raymond N. Dickes DISTRICT MANAGER TO: THRU: FROM: MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Smit~) DATE: February 26, 1991 Commissioner FILE NO: LG228-3 TELEPHONE NO: SUBJECT: BOP Test Conoco MPU I-3 Milne Pt Unit Permit No 90-92 Louis R. Grimatdi//~ Petroleum-Inspector ~_~dne~dav 2/2/91: I witnessed a BOP test on Pool rig #102. The test went well with the exception of the annular preventer which failed to hold the test pressure. Upon examination of the element, it was found to have disintegrated. This was a strange occurance as the element was less than three weeks old and was the third replacement in as many months. Parts of the element have been sent to conoco's lab to try to determine possible causes. During the test of the choke manifold, I found a hammer union and a threaded connection had been added since my last inspection. I informed them that there are no threaded or hammer connections allowed on the choke system. These were removed and a blind flange was installed. The rig was generally in good shape as was the location. In summary: Pool 102 called me on 2/21/91 to inform me that the annular preventer was repaired and tested. At this point~ I approved Pool 102 to proceed with the completion. Attachment. 02-00lA (Rev. 6/89) 20/11/MEMOl.PM3 OPERATION: Dr1g / Wkvr Operator ~ g:>/-J ~::)C ~ LocaUo., Sec Drlg contrctr Location (general). ~.~ Well sign Housekeeping (general). Reserve pit STATE ~F ALASKA ALASKA OIL AND'C~A$ COHSERVATION COI~IISSiON BOPE Inspection Report .TEST: Initial. ~)~ Weekly Other Representative ~ ~-~'~/.L~,~ ~'~ ~,~ . ~ cas~na set a R~/~ e~p ~~ ACcuHu~TOR SYST~ NUO SYS'TEHS: Vt sual Trip tank P~ ~ao / I Flow monitor Gas detectors Audio BOPE STACK: Annular preventer ,, Pipe rams BI Ind rams Choke 1 ine valves HCR valve _ d~.~fZ ~ ~_~ Ktll ltne valves Check valve TEST RESULTS: _ Full charge pressure, Press after closure Upper, Ke Ily .Lower Ke I 1 y Ball type Choke'rman t fold psi, pst~ mtn -- miff pstg Pump Incr clos press 200 pstg Full charge press attained Controls: Naster Remote ~/~ BIi.nd switch cover KELLY AND FLOOR. SAFETY VALVES= ~ TeS,t pressure , ..r.. Test, pressure . -. / , Test pressure ,' / Test pressure // Test pressure Number ,val.ves Number flaages ..~_~ AdJus. table chokes Hydraulically operated choke Failures, Test time" 3 hrs · Repair or replacement of fatled equipment to be made wlehtn --- days. Noel fy the Inspector~ and follow wleh'written/FAXed verification to Commission office. Distribution= orig - AOGCC c - Operator c - Supervisor C.OOq (rev 05/10/~0) Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 January 9, 1991 Mr. Lonnie C. Smith Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Milne Point Unit Wells I-1, I-2, I-3 and I-4 Applications for Sundry Approvals Dear Mr. Smith: Attached are the Applications for Sundry Approvals (Form 403) requesting approval to complete the MPU wells I-1, I-2, I-3 and I-4 with a workover rig. If there are any questions pertaining to these wells please call me at 564-7625. Very truly yours, C. Van Lineberger Sr. Production Enginee~r cc: CVL, PMS, Sr. Production Foreman, I-1 thru I-4 Well Files STATE OF ALASKA ALASKA ,~L AND GAS CONSERVATION COMMISS. APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing Repair well Change approved program __ Name of Operator Conoco Inc. Operation shutdown __ Re-enter suspended well Plugging __ Time extention Stimulate X Pull tubing Variance . Perforate X Other X Address 3201 C Street, Suite 200 Anchorage, AK 99503 5. Type of Well: 6. 7. NSB AK Development Exploratory Stratigraphic Service Location of well at surface 2944' FNL, 3816' FEL, Sec. 33, T13N, R10E, U.M. At top of productive interval 4500' FNL, 3380' FEL, Sec. 33, T13N, R10E, U.M. At effective depth NSB AK At total depth 4746' FNL, 3311' FEL, Sec. 33, T13N, R10E, U.M. NSB AK Datum elevation (DF or KB) KB 35' AGL feet Unit or Property name Milne Point Unit 8. Well number I-3 9. Permit number 90 -92 10. APl number 50-029-22067 11. Reid/Pool Schrader Bluff 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 115' Surface 2633' Intermediate Production 4741' Uner Perforation Depth: measured 4750' feet 4265' feet true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Plugs (measured) feet Junk (measured) feet Size Cemented 13-3/8" Surface 9-5/8" Surface 7" T.O.C. @ 3000' Measured depth 115' 2633' 4741' True vertical depth 115' 2400' 4257' RECEIVED 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 2/91 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe Van Lineberger Title Sr. Production Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commission Date 1/9/91 L°cati°nclearance~~)~OV¢c~ C~O~)~] IAppr°va*N°' bY LONNIE C. SI~IITH _~ - _~ Commissioner Date 2-- Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MILNE POINT UNIT I-3 WELL PROPOSED COMPT~TION PROCEDURE - SUMMARY 1/7/91 - CVL NOTE: Hold frequent on site safety/environmental meetings prior to all potentially hazardous tasks. 1. MIRU on I-3 well. Test BOP's. 2. GIH w/ bit and scraper to PBTD. Reverse circulate well clean. 3. RU electric line. Run Gyro survey (if necessary). Correlate with open hole logs and perforate "0" sands at 5 SPF over 4424'-55' and 4486'-4510'. RD electric line. 4. GIH with squeeze packer and set above top perf. 5. MIRU frac equipment. Pressure test all lines. Pump frac job to stimulate "O" sand perf's. RD frac equipment. 6. Clean out proppant from wellbore, if necessary. 7. RU electric line and set gravel pack sump packer above "0" sand perf's and below proposed "N" sand perfs. 8. Perforate "N" sands at 12-24 SPF over 4260'-80', 4292'-4304', 4322'-28' and 4344'-78' utilizing electric line or tubing conveyed perforating (TCP). If TCP is used, apply 300 psi underbalance and allow well to flow for approximately 20 bbls. Kill well and POOH. 9. PU gravel pack assembly and GIH. pumps/blenders and test surface lines. packer. RU gravel pack Set gravel pack 10. Pickle workstring. Establish injection profile. Pump gravel pack. Stress test gravel pack and POOH. 11. PU and run electric submersible pump (ESP) on tubing. Freeze protect. ND BOP's and NU tree. 12. Leave well shut in until surface equipment installation is complete. C. Va_n L_inebe.~q~ Sr. ~rod. Engineer STATE OF ALASKA ALASKA OIL AN D GAS CONSERVATION COM MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown X' Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other __ 2. NameofOperator Conoco Znc. 3. Address 99503 3201C Street, Suite 200, Anchorage, AK T13N, RICE, T13N, RICE 4. Location of well at surface 2944' FNL, 3816' FEL, Sec. 33, At top of productive interval 4500' FNL, 3380' FEL, Sec. 33, At effective depth At total depth 4746' FNL, 3311' FEL, Sec. 33, T13N, RIOE 5. Type of Well: DevelOpment X Exploratory __ Stratigraphic __ Service __ U.M. NSB, AK 6. Datum elevation (DF or KB) KB 35' AGL 7. Unit or Property name Milne Point Unit 8. Well n~_mCer 9. Permitnumber 90-92 10. APInumber 50-- 029-22067 11. Field/Pool Schrader Bluff 12. Present well condition summary Total depth: measured true vertical 4750 feet 4265 feet Plugs (measured) Effective depth: measured feet true vertical feet Junk (measured) Casing Length Size Structural Conductor 115 ' 13-3/8''~ Surface 2633 ' 9-5/8" Intermediate Production 4741 ' 7" Liner Perforation depth: measured true vertical Cemented Surface Surface T.O.C. @ Measured depth True vertical depth 115' 115' 2633' 2400' 3000' 4741' 4257' RECEIVED Tubing (size. grade, and measured depth) Packers and SSSV (type and measured depth) DEC 1 1 199 Alaska 0il & 6as Cons. Comm'tssiO~ Anchorage 13. Attachments Description summary of proposal X: Shutdown drilling rig operations pending 14. Estimated date for commencing operation 2/91 16. If proposal was verbally approved Name of approver con Date approved Detailed operations program __ BOP sketch __ )letion with workover rig. 15. Status of well classification as: Oil X Gas __ Suspended __ Service 17. I hereby certify that the foregoin,,g is truce and correct to the best of m,./ knowledge. Signed ~'~~~~.~/,~,, ~ Title Sr. Drilling Engineer Steve Ross~er~ -- -,~-/ FOR COMMISSION USEONLY Conditions of approval: Notify Commissio¢/~o representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved Copy' Returned, ;¢__,~ ORIGINAL SIGNED BY I Z-I Approved by order of the Corhmission .1'"' LONNIE C. SMITH Commissioner Date 12/7/90 feet I Approval No.?¢ "-~,¢ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 7725 ! -2 ! 75 NOV ! 9 1990 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberg. er ~BE REPLY TO SCHLUMBERGER WELL SERVICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore_2_BL_prints of the Company CONOCO, Inc, . Well Milne Point llnit T-3 Field MJlne Point /gcbrader Bluff Additional prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 20!8 PER DIT-E, NGT, CNL(RAW),CNL(PORO), Run 2, 11/12/90 Cyberlook? Run 2: l]/lq/qO on: County North S_lope State . Alaska _l_BL__prints, I RF Sepia CONOCO: lnc~ 1000 .South Pine Ponca City, OK 74603 Attn: Log Library I BL prints, 1RF Sepia OXY U.S.A., Inc 6 Desta Drive Midland, TX 79710 Attn: .John Carrol *(915/685-56OO) _l_][b_prints, 1 RF Sepia Chevron U.S.A. ._.11111 South _Wjlcr~_.~t _ __ Hou.~t ~n~ _ T~wa.~ 77fiqq Attn: Priscilla MacLeroy .7713/561,3652 __ 1 BL r~rin'fg, 1 RF Sep a Ata§'k'a Oit,~ & ~Gas Conserva'~n Commission 3001 Porcupine Drive Attn: John Bo~le. ~,~ ' . . _ .~?'~ f: -~:~ The film is returned to Conoco, Log LJbrary, We appreciate the privilege of serving you. prints prints [iLk~L i V L prints NOV 2 1 l~qO Alaska 0ii & (;as Cons. {;0mmissi0n AnChorage Date: Very truly yours, SCHLUMBERGER WELL SERVICES SwS-- 1327-F .David M, Saalwaechter DISTRICT MANAGER SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 7725 I-2t 75 NOV 0 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention' Van Lineberger ~blE REPLY TO SCHLUMBERGER WELL ~RVICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed are_2_BL_prints of the :ompany CONOCO, Inc. BGT, Run 1, 11/07/90 on' ~'~Mell Milne Point Unit 1-03 Field. Milne Point /Schrader Bluff Additional prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn:. George Lamb - OF 2018 PER County North Slope State _l__BL__prints, 1RF Sepia CONOCO; Inc. 1000 South Pine Alaska Ponca City, OK 74603 _Attn: Log Library 1BL prints, 1RF Sepia OXY U.S.A., Iqc. 6 Pesta Drive Midland, TX 79710 Attn: ..John.Carrol *(915/685-5600) ~rints, 1RF Sepia Chevron U.S.A. =11111 South Wi]crest_ __Houstnn; Tow~ 77~qq Attn: Priscilla MacLeroy .*Z13/561-3652_ ///E~ prints, 1 RF Sepia~ Alaska 0il & Gas Conservat~pn -Commissi°n .3001 Porcupine Drive .~nchorage, AK 9.9501 ~ Jo~hn Boyle prints prints prints REC[IV[D ,~vv ,4 19~0 Gas Cons. Comi]lJss/ori The film is_returned to Conoco, Log Library. We appreciate the privilege of serving you. Received by: . Date: Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter DISTRICT MANAGER SW$-- 1327-F TO: THRU: . MEMORAN UM State of Alaska ALASKak OIL AND GAS CONSERVATION COMMISSION' Lonnie C. Smith Commissioner DATE: FILE NO: November 13, i990 JT.LG.113.1 TELEPHONE NO: SUBJECT: RIG/BOPE Inspection CONOCO MPU I-3 Nabors 27E FROM: Louis Grimaldi/~ Petroleum Inspector November 8, 1990: ~I d~d a RIG/BOPE inspection on Nabors 27-E and ~ound'n~ discr~L~encies Ail equipment appeared to be in a well maintained condition with the exception that the kill line was diconnected. I talked to the Conoco company rep. who informed me that they had been experiencing problems with the line freezing due to poor heating in the BOP bay. He showed me where they have new insulation and heater, s~en route and the problem would be remedied with one week. I discussed the importance of having the ability to pump into the annulus without delay. The companY rep agreed to keep the bolt and nut assembly for the hammer union. A hammer and proper sized wrench in a box by the kill line and a hand in the vicinity until the BOP bay temperature problem was remedied. In summary: The Nabors rig should have been winterized before the ambient temperature approached the freezing point. I also had the impression that it was standard practice to keep the kill line disconnected when problems of this type were encountered. (12/7/90) November 28, 1990: I traveled back to Nabor's 27-E to reinspect and found the!~'problem with the BOP bay to be corrected. 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 July 27, 1990 Telecopy: (907)276-7542 David L. Mountj oy Sr. Drilling Foreman Conoco Inc. 3201 C Street, Suite 200 Anchorage, Alaska 99503 Re~ "Milne Point Unit No. I-3 :Conoco inc, Permit No. 90- 92 Sur. Loc. 2944'F~L, 3816'FEL, Sec. 33, T13N, R10E, UM. Btmhole Loc. 4746'FNL, 3311'FEL, Sec. 33, T13N, R10E, Dear Mr. Mouutj oy: 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 Commission will advise you of those BOPE tests that it wishes to witness. Very truly your~_~ David W. Johnsto~ f Commissioner Alaska Oil and Gas Conservation Commission BY O~ER OF THE CO?~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o enc!. Depar~ent of Environmental Conservation w/o encl. STATE OF ALASKA ~_ ALASKA ,~IL AND GAS CONSERVATION ( MMISSION PERMIT TO DRILL la. Type of work Drill _~( Re-Entry - 20 AAC 25.005 Redritl 51 lb. Type of well. Exploratory 7-' Development Oil 2k Deepen r--I Stratigraphic Test ~ Service - Developement Gas - SingleZone.~ Multiple Zone 2. Name of Operator CONOCO INC. 3. Address Pouch 340045, Prudhoe Ba.¥. Al( 997.34 4. Location of well at surface 2944 FNL, 3816' FEL, SEC. 33, T13N, RIOE At top of productive interval U.M., NSB, AK 4500' FNL, 3380' FEL, SEC. 33, T13N, RIOE At total depth 4746' FNL, 3311' FEL, SEC. 33, T13N, RIOE 12. Distance to nearest 13. Distance to nearest well property line 534 feet 60'F/I-2 ~ 500' feet 16. To be completed for deviated wells Kickoff depth 500feet Maximum hole angle 370 18. Casing program size Hole Casing 5. Datum Elevation (DF or KB) KB 35' AGL feet 6. Property Designation ADL-25906 7. Unit or property Name MILNE POINT UNIT 8. Well number I-3 9. Approximate spud date OCTOBER 16, 1990 14. Number of acres in property 2560 10. Field and Pool KUPARUK RIVER FIELD , 11. Type Bond ~see 2o AAC 25.02S) BLANKET Number 8086-15-54 Amount $2O0,O0O 15. Proposed depth IMD and TVDI -1679'MD, .4.166 ' TVD'~et 17, Anticipated pressure (see 20 AAC 25.035 ce)(2)) Maximum surface 1900 psig At total' depth WVD) 2000 Setting Depth 12 1/z 8.5 Specifications Weight J Grade j Coupling j Lengtr 13 .3/R ~,R# IH-4nl wren J Rn, l 9 51/8 36# [ J-551 BTRS 12751 ARI:TIC GRADE! i 7 26# j L-,8.0I BTRS J4644' MD 35' 35' 35' Top JTVD 35' I J35' Bottom MD I TVD 11R, !!5' 1 4679't 4166' Quantity of cement (include stage data) ±485 SKS PERMAFROST +637 RKR PFRMAFRORT -- ±270 SKS CLASS G .... +50 SKS PERMAFROST +278 SKS CLASS 19. To be completed for Redrill, Re-entry, and Deepen O )erations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet DOWNSQUEEZE _+273 SKS PERMAFROST C +60 BBLS DEAD CRUDE Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True Vertical depth I t 11990 , measured RRi~hOI'8,I~ true vertical PII SKEICH X ~ 20. Attachments Fili,n,g fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch ~_ Drilling program ~ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ~ Seabed report ~ 20AAC25.050 requirements Hydrogen sulfide.measures ~ Yes ,,~'oNo Directional survey required 2~;'Yes oR?hq~ed working pressur___e for BOPE i~2M;~ ~_,.,,~ 3M; E3 5M; ~ 10M; ~ 15M Approved F0im 10-401 Rev. 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ' ~ ' ' Title SR. DRILLING FOREMANDate'- "/-,~'" Commission Use Only Permit Number J AP, number ] 79O[ See cover letter . ~20- .~2_ 50-- O,~'-- ~- ~-- O ~,~' _ for other requirements Conditions of approval Samples required ~ Yes ~ No Mud Icg r~q~Tred 12 Yes ~No ;2 No by order of the commission Date ~,/~?~8 Subm"il~ ir{ '~riplicale SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT I-3 Conoco Inc. P. O. Box 340045 Prudhoe Bay, Alaska 99734 I. Casing and Cementing Program ae The 13-3/8" conductor will be set at ±80' below the surface, then cemented to the surface with ±485 sacks of Permafrost Type "C". Be The 9-5/8" surface casing will be cemented with ±637 sacks of Permafrost "E" cement followed by ±270 sacks of Class "G" Cement. A top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The first stage will consist of ±50 sacks of Permafrost "E" cement pumped around the casing shoe followed by ±278 sacks of Class "G" cement. The secondary cement job will consist of ±273 sacks of Permafrost "C" cement followed by ±60 barrels of Arctic Pack pumped down the 7"x 9-5/8" annulus. II. Drilling Fluid Program ae 0' - 2786' 9.0 ppg freshwater spud mud. B. 2786' - 3933' 9.2 ppg low solids non-dispersed. C. 3933' - TD 9.4 low solids non-dispersed. III. Drilling Program Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River Field (Upper Cretaceous-West Sac). The mud system will be low solids, non-dispersed with a mud weight in surface hole of 9.0 ppg. Mud weight at TD will be 9.4 ppg. A 20", 2000 psi diverter will be installed on the 13- 3/8" conductor for drilling surface hole. A 13-3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure tests will be performed as per State Regulations. BOP's, choke manifold, upper and lower kelly safety valves will be tested to 500 psig and 5000 psig, the Hydril to 350 psig and 3500 psig. Casing will be pressure tested to 1500 psig. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is I-2 with a closure of 60 feet at a depth of 500'. The well will not be completed or tested at this time. ae Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. B® Drill a 12-1/4" surface hole to ±2500' TVD 2786' MD and set 9-5/8" casing. Ce Drill a 8-1/2" production hole to ±4166' TVD to 4679' MD and set 7" casing. TVD MD FORMATION BIT MUD WT YD PV VIS FL 0 0 Gravel 1-1-4 9.0 32 20 90 15 500 500 Sand/Clay 1-1-4 9.0 25 20 65 15 3215 3659 "K" Sand 1-1-4 9.2 25 15 35 10 3465 3933 "M" Sand 1-1-4 9.4 25 15 35 10 4163 4163 "N" Sand 1-1-4 9.4 25 12 35 05 4360 4360 "0" Sand 1-1-4 9.4 25 12 35 05 4466 4679 TD 1-1-4 9.4 25 12 35 05 *The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300 feet TVD, a Sundry Notice will be submitted. Ale~ka Oil & NOTES: ,STATE PLANE COORDINATI=8 ARE ZONE 4 2, ALL GEODETIC POSITION8 ARE BASED ON N.A.D, 1927 OI::FSET8 TO SECTION LINES ARE COMPUTED BASED ON PROTRACTS~:) VALUES O1:: THE SECTION CORNER POSTION$ . 'J MILN~ POINI' UNIT ~~W'~YIt eAY MILNE PT, VICINITY MAP 0 ~ I~ MILES ! I J L. I1~ O Od lie II __ L OC^TION IN ,SEC. 33, T13N, ELBE, UMI^T MERIDI^N ' "-' ~ -"~t '~"--~ '~-:~~ 1-31-2137'~'':i' '!~'~~!3~w ----12~,13944'i294e' ........ ~ "" ~ "' ~ STATE PLANE COORDINATES-ZoNE 4 ~ ¢ ~ b i-2 ~,OO*,447.40' *~,14.74' I PAD !-3 1-4 6,OO9.480.10' 6,009,462.80' 55~494.88' ,t= .170' ,, =~.4 8_O_.' =[=40'=_ ~ GEODETIC PO,SlTION8 NAD 1927 j ~ 2~ IT WELL NOR"I:H L^TITUDE ., W~ST, LoN~IT'~DE :I'L -' ... L~-i l-1-j j j, i-! 70'26'11.5787' 149'84'43,276' a lX(:.".:',':,:~:'.',','.:'.",;:',":?:; :,:./.'.'.'.!'.'..',.':;:?-,' :.',.~--~ 11 Il ~"~-.~ I-:2 70' 26'll,6093° 149' 84'46.084° 1-3 70° 26'11,6399° 149' 34'46.793' ~:;.'.' :,-,'..v.'.. :.v,.,._ ,' ;7:'.: "::, ,' :.' ;'.',,-, ;n -i ":"';"= ~'' ....'~-"-' I-4 70* 26'11.6705' 149' 84'48.~55° TYPICAL SECTION ..-, ,,,. . _ ..... ,,.:,,.,._,.,.,~_:_ .-- ~s~ ~,~ ............... \,,,_',,~ r,,~--~,-.~,/ . .'~.. r., ROBERT 8ELL ,;~',~ -,, ,., -- ~,, ,.,,,,,,,. .,,..,_ ¥~-(...~:... ...' %~ ._ _' ... ~c. '~.L Z:,--°'~' _. :,,~ _?..~, o,,? .~:: _ _ . · T13HRgE CHEVRON 7 AD~..-25509 2533 18 17' + 23 24 18 20 A. O4.-25514 2560 AC T13H R IOE CONOCO ET Al. ~) 4 ~ 2 ,10 11 T 12 ~ ADL-47'434 2580 AC 16 CHEVRON ADL-47433 ~ AC 13 T13NRllE CONOCO ET Al. 6' ADL-31971 1265 AC CONOCO' ET AL 7 8 CONOCO ET 18 AC ADL-25515 25.44 AC CACEVRON ~0 31 AD4..-25517 2235 AC 21 22 ADL-25516 &oL-~lSe4e t2eo AC 1280 AC ~ .co woc~? 4L ~ 23 24 ADL-47437' 2560 AC (~) CHEVRON 26 · 2S AOL-2S~ 18 19 2 ADL-47438 2544 CONOCO. 30 29 2560 AC,,ADL'28231, , 2555 AC, MILNE POINT UNIT D®not®e Irecl numbere To[el Af®l In Unit 35.7'44 Unit Boundiry 5/84 CONOCO ET AL, 21 22 39 ADL-315848 1280 AC .1280 AC EXHIBIT A MILNE POINT UNIT AREA Beeid on Umlal Metidlin,Alaeli O I 2 Mllee I _ ~ .... j Scala _ CONOCO INC,--NABORS RIO 27B 13-5/8" 561a08 BOP SYSTEM FIll Llne API 13-5/B' ~ API 13-5/8' APl 13-5/8' API 13-5/8' APl 13-5/I~' 5M × 11' ~ APl 1{.' 5M 1-1meaded Correction Flow Line AnnUlar Preventor Ram Ram Ram Choke Line: 3" 5000~ Manual Gate Valve & 3" HCR VALVE Kill Line: Two 3" 5000~ Manual. Gate Valves Tubing Spool w/ 2"-5000~t Side Outlets Casing Spool w/ 3"-5000~t Side Outlets 9-5/8" SurFace Casing 13-3/8" Conductor Casing 1, BOP STACK S:[ZE RATING MEETS APl RP53 & SPEC 6A FOR CLASS 5H 2, DOPE TO BE OPERATED EACH TRIP AND TESTED WEEKLY, 3, BOP HYDRAULIC CONTROL SYSTEM TO INCLUDE (5) STATION CONTROL HANIFOLD LOCATED REHOTE WITH 160 GALLON ACCUHULATOR, RESERVOIR UNIT, & AUXILIARY ENERGY SOURCE FOR SYSTEH ACTIVATION, ~r, MINIMUM ONE SET BLIND RAMS & TWO SETS APPROPRIATE PIPE RAMS, 5, CHOKE & KILL MANIFOLDS SHOWN SEPARATELY TO MEET APl RP 53 CLASS 5M REQUIREMENTS, KILL MANIFOLD FROM REI,~OTE HIGH PRESSURE PUMP ,NOTE: ~Ah:/OLD TO I~CLUO[ (51 S/ATI~ CONTROL ~ANIFO~ L~A~ED R[VOT[LY WITH 3~0 PSI ACCUMULATOR 160 G~. RESE~IR 8 AUX. E~ERGY SOURCE. SEA ~NTROL ~ANIF~ PLUS VARIABLE CHOKE ~NT~L TO BE ~:ATED ON RIG FLOOR. Z K[L & CHG~ WANIFOLDS ~ AEET ~W 5 KILL U~NIF~D SIZE-RATING 2'-5000 ~ CHOKE ~ANIFO~ SIZ[-RATING ~ FRC~ PU~IP REMOTE PRESSURE GAGE SENSOR ~ HYDR:ULIC CONTROLLED REMOTE OPERATED DRILLING SPOOr. RE.~OTE PRESSURE GAGE SENSOR ADJUSTABLE CHOKE ADJUSTABLE CHOKE CHOKE MAr;JFOLD -- VARIABLE CHOKE R.EM, OTE CCNTROL --.-. TO SHALE SHAKER t BLF_..E.D LINE TO ATMOSPHERIC TO PiT MUD/GAS SEPARATOR CHOKE G KILL ~,ANIFOLDS FOR ct'~/8'~ & 7" OD C,~SII';G BOP STACK BOP I,IAt, IFOLD LAYOUT - CONOCO, INC. , CONOCO, INC, MILNE POINT UNIT DIVERTER STACK FOR 13 3~8' CONDUCTOR FILL UP LIN[ ~ _ _ I _ A~f~4~ ~r QuiCK ¢O~q~tC.T ASStldBLY SAYCR 'SUB A$$tl,4BLY STARTI~O Iqt~g 1. The hydraulic control syst~ will be in accordance with API specifications and ~ requirements. ~. The HCR valve will open when the preventer closes. A singl~ 10" relief line will run off of the drilling spool HCR valve and will have a targeted d~nstream tee for downwind diversion. Valves on both sides of the te~ will b~ full opening and linked together to enablo on~ to always be open and the other to be closed. Ir~oId SAL AM&NCEqS .,~.~ ~ . HOLE FILL TAN~ I ' t MU0 CLEANER PUMPS FILL <q~ L .... ._J uuO M,,r H~$ I.J1 I i VA ~VL'J i pu~:.a 2 ~:~'P I PU~-° Z i~"" NABORS DqlLLNG LI:4TEC, i FLOw SHEET DEVELOF'MEN'F WELL WELL NAME: ~'-~'. I-3 15-Jan-90 CONDUCTOR SE-rTING DEPTH: SURFACE CASING SETTING DEPTH: INTERMEDIATE CASING SETTING DEPTH: PRODUCTION CASING DEPTH (OR TD): 80 2775 0 4662 DEPTH OPERATION: 0 I RIG MOVE: 0 ~ o RIG-UP; SET CONDUCTOR: (2,775) 3 DRL/SURVEY SURFACE HOLE: (2,775) 4 SURFACE HOLE LOGGING: (2,775) 5 CONDITIONING TRIP: (2,775) 6 RU/RUN SURFACE CASING: (o 775) 7 RU/CEMENT SURFACE CASING: (2,775) 8 CHNG BOPs; PU BHA; RIH: (2,875) 9 DRL OUT; TEST; TOOH; RIH: (o 875) 10 DRILL INTERMEDIATE HOLE: HOUR DAYS 6 12 49 0 9 6 9 9 0 0.25 O. 50 ~- 04 0.00 0 1° 0.39 0 '~5 O. O. 38 O. O0 CUM DAYS 0.25 0.75 ~.79 79 ? ~.55 ] 92 4.30 4.50 (2,875) 11 LOGGING OPERATIONS: 0 (2,875) 12 CONDITIONING TRIP: 0 (2,875) 13 RU/RUN INTERMEDIATE CASING: 0 (2,875) 14 RU/CEMENT INTERMEDIATE CASING: 0 (2,875) 15 CHNG BOPs; PU BHA; RIH 0 (2,875) 16 DRL OUT; TEST; TOOH; RIH 0 (4,662) 17 DRILL PRODUCTION HOLE: 42 (4,662) 18 CORING OPERATIONS: 0 (4,662) 19 LOGGING OPERATIONS (MWD ONLY): 0 (4~662) 20 CONDITIONING TRIP: 9 (4,662) 21RU/RUN PRODUCTION CASING: 14 (4,662) 22 RU/CEMENT PRODUCTION CASING: 5 (4,662) ~u.'~ RD DRLG RIG 12 (4,662) 2~ RU COMPLETION R~G: 1'~ (4,662). ~5 RD DRLG RIG 12 (4,662) 26 RU COMPLETION RIG: 12 (4,662) 27 RD DRLG RIG 12 (4,662) 28 RU COMPLETION RIG: 12 (4,662) 29 RD DRLG RIG 12 (4,662) S0 RU COMPLETION RiG: 12 O. O0 0.00 0. 0 0 0 .-00 0. O. O0 1.75 0. O. O0 O. ~ 0.19 0. ~0 O. ~0 0. ~0 0. ~0 4.30 4.30 4.-30 4.30 4.30 4.30 6.05 6.05 6.05 6.41 6.98 7.18 7.68 0.50 1.00 1.50 o ' 50 . -:.. (-) ? 50 · ...]' i RECEIVED '...,. -,. CONOCO. !ne. Pad [. ~/ellNo: :3 MI Ina Point Unit. Revised Proposal North SI ope, Al esl(a 1000 2000 3000 4000 RKB ELEVAT[ON~ 3S' KOP g 15 21 27' TVD:500 TMD:500 DEP=O BUILD 3 OEO PER I00 FT EOB TVD=1626 TMD=1704 DEP=367 MAXIMUM AN GLE 36 DEG 7' MI N 9 5/8" CSO PT TVD=2500 THD=2786 DEP-IO05 33 DROP 3 DEe 27 PER 1 O0 FT 21 BEGIN ANGLE DROP TVD=2993 TMD=3396 DEP=1364 K SNDS TVD=3215 TMD=3659 DEP=1504 TARGET / M SNDS TVD=3465 TMB=3933 BEP=1616 N SNDS TVD=3681 TffD=4163 DEP=1695 0 SNDS TVD=3866 TffD=4360 BEP=1762 TD / 7' LINER TVD=4166 TMD=4679 DEP=1871 5000 I I 1 000 2000 VERTICAL SECTION TARGET ANGLE 2O DEG HORIZONTAL SCALE 1 IN. PROJECTION = 1000 FEET CONOCO. Ir, c:. Pad [. Well No, :3 HI Ina Polni: Unl'l:. Revl~ed Proposal North Slope, Alaska SURFACE LOCATION, 2944' FHL. 3816' FEL SEC. 33, T13N. RIOE z 1000 1000 20OO 2000 1000 I WEST-EAST 0 I SURFACE 1000 I 2000 I TARGET / H S#DS TVD=3465 TND=3933 DEP=1616 SOUTH 1556 EAST 436 TARGET LOCATION, 4500' FNL. 3380' FEL SEC. 33. T13N. RI OE S 15 1616' DEG 39 MI N E 9TO TARGET) TD LOCATIONt 4Z4~' FNL. 3311' FEL SEC. 33. T13#. RIOE 28OO 2850 2900 2950 7000 3050 3100 3950 3900 3850 3800 3750 37'00 3650 3600 3550 .... I ! I I I I I i I / / / / /~ 900 / / )' 700 · 500 500 [700 \ \ ~900 \ \ \ \ '~ 1100 \ \ J i I I 3950 3900 3850 3800 ~°~O0 ~ 1100 ~°'gO0 I 3750 I 3700 I 3650 '"1 ~ :300 ~LIOO 3600 I 3550 2800 2850 2900 _ 2950 _ac' _ 3050 _ 3100 CHECK LIST FOR NEW WELL PER,fITS IT--nM APPROVE DATE (2 thru 8) (8) (3) Admin X~'~''' Z/~/~-j 9. thru' 13) ' 10. (10 :d 13)' 12. 13. (4) Cass '~~~ ~-~¢-70 (14 :h~ 22) (23 thru 28) (29 thru 31) (6) Add: ~z~.~,~. V-~-~ Geology: Engineering: _ DWJ ~--L CS BEW rev: 01/30/89 6.011. Company /z'--~.3~-_~ Lease & Well No. /~Z2~ YES NO Is the permit fee attached .......................................... ~ -- 2. Is well to' be located in a defined pool ............................. ~__ 3. Is well located proper distance from property line .................. 4. is well located proper distance from other wells .................... ~ 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is we!!bore plat included ................ ~_ 7. Is operator the oniy affected party ......... · ....................... 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. .X Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is c6nductor string provided ........................................ Will surface casing protect all zones reasonably expected to sez~e as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an ezisting we!lbore ............. Is old wei!bore abandonment procedure included on 10-403 ............ Is adequate weilbore separation proposed ............................ Is a dive:re: system required ....................................... Is the drilling fluid program schematic and list of equipment adequate,~ Are necessary diagrmm~ and descriptions of dive:re: and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~o~ psig .. Does the choke manifold comply w/AMI RP-53 (May 84) .................. Is the presence of H2S gas probable ............................. ~... ~or 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. ZTZAL ZO. U TZ [ 0N/O POOL CLASS STATUS AREA NO. SHORE , Additional Remarks:'