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Home My WebLink About197-1041. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP RWO Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,390 feet N/A feet true vertical 7,389 feet N/A feet Effective Depth measured 11,267 feet N/A feet true vertical 7,269 feet N/A feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5 / L-80 / EUE 8rd 10,893' 6,906' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): 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: 5,750psi 7,240psi11,350' 7,350' Burst 1,490psi Collapse 470psi 3,090psi 5,410psi Casing Conductor 11,350' 6,288'Surface Production 20" 9-5/8" 7" 112' 6,288' measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-104 50-029-22773-00-00 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: ADL0025509 & ADL0388235 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT F-09 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) 269 Gas-Mcf MD 112' 1100 Size 112' 4,305' 894 38019 0 00 365 323-236 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 Scott Pessetto scott.pessetto@hilcorp.com 907-564-4373 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 12:18 pm, Aug 29, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.08.29 07:51:11 - 08'00' Taylor Wellman (2143) WCB 4-9-2024 RBDMS JSB 083123 DSR-8/19/23 _____________________________________________________________________________________ Revised By: TDF 8/28/2023 SCHEMATIC Milne Point Unit Well: MP F-09 Last Completed: 7/27/2023 PTD: 197-104 TD =11,390(MD) / TD =7,389(TVD) 20” Two 7” x 21’ Marker Joints from 10,821’ to 10,863’ Orig. DF Elev.: 29’/ Orig. GL Elev.: 24.7’ DF to 7” Casing Hanger = 30.4’ (Nabors 22E) 7” 13 3 6 & 7 8& 9 10 & 11 9 9-5/8” 1 2 KUP A Sands PBTD =11,267’(MD) / PBTD =7,269’(TVD) 4 & 5 12 X X CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 6,288’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 11,350’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 10,893’ 3/8” Capstring Stainless Steel N/A Surface 10,893’ JEWELRY DETAIL No Depth Item 1 197’GLM #2: 2-7/8” x 1” Side Pocket w/ DSOV & BK Latch 2 10,643’GLM #1: 2-7/8” x 1” Side pocket,W/Dummy & BK Latch 3 10,763’ 2-7/8” XN-Nipple (2.205 No-go ID) 4 10,816’ Discharge Head: B/O PMP 513 2.87X8 EUE1040 5 10,816.6’ Zenith Ported Sub: S/A B/O PRESS PORT 513/538P PMP 6 10,817’ Pump 2: 538PMSXD 137 P17 M FER NO_PNT 7 10,836’ Pump 1: 538PMSXD 20 GINPSHH H6 STD_PNT 8 10,846’ Gas Separator: 538GM2T HV E V X MT HS FER STD_PN 9 10,851.5’ Intake: GPXARCINT FER H6 10 10,852’ Upper Tandem Seal: 513, GS3, B/B/L, SB, H6, PFSA, HL, FER, 12CRC 11 10,859’ Lower Tandem Seal: 513, GS3, B/B/L, SB, H6, PFSA, HL, FER, 12CRC 12 10,889’ Motor: 562XP series CS 350 HP /2440/88 _ 14R 13 10,892’ Sensor & Centralizer: Btm @ 10,893 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 10,937’ 10,951’ 6,949’ 6,962 14 7/19/1997 Open Kup. A Sands 10,955’ 10,975’ 6,966’ 6,986’ 20 7/12/1997 Open Kup. A Sands 10,979’ 11,007’ 6,989’ 7,017’ 28 7/19/1997 Open Kup. A1B Sands 11,007’ 11,030’ 7,017’ 7,039’ 23 7/23/2023 Open Kup. A1B Sands 11,034’ 11,038’ 7,043’ 7,043’ 4 7/23/2023 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,765 sks PF “E”,500 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 240 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 65 to 67 deg. f/ 3,900’ to 8,800’ Hole Angle through perforations = 14 deg. No DLS ग़4 deg./ 100’ TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME on top and 2-7/8” EU 8rd on bottom, 2.5” CIW BPV Profile GENERAL WELL INFO API: 50-029-22773-00-00 Drilled and Cased by Nabors 22E - 6/19/1997 Initial Perforations – 7/11/1997 ESPR WO w/ Nabors 5S – 3/6/1998 ESP RWO w/ Nabors 4-ES – 3/23/1998 ESP RWO w/ Nabors 4-ES – 6/19/1999 ESP RWO w/ Nabors 4-ES – 11/11/1999 ESP RWO w/ Nabors 4-ES – 11/15/2002 ESP RWO w/ Nabors 4-ES – 8/28/2008 ESP RWO w/ Nordic 3 – 4/11/2015 ESP RWO w/ ASR 1 – 7/27/2023 STIMULATION SUMMARY Frac – 104,066# of 16/20 carbolite behind pipe. Frac was designed for 159,000# - 7/15/1997 Well Name Rig API Number Well Permit Number Start Date End Date MP F-09 ASR#1 50-029-22773-00-00 197-104 7/17/2023 7/28/2023 Continue POOH w/ 2-7/8" ESP Completion F/8,040' - T/300' while pumping double displacement. L/D Pump assembly. Found upper Tandem Pump seized and packed with debris. Recovered: 177 CC Clamps, 1 Half Clamp, 4 Protectolizers, 1 Flat Guard. Pump 25 BBLS to fill hole, monitor for losses. R/D ESP handling and ancillary equipment. R/U to run 3-1/2" work string. Load Pipe Shed w/ 3-1/2" work string. Measure BHA components. Pump to fill hole = 13 bbls/hr losses or 339.78' CSG Vol. P/U and M/U Bit and Scraper BHA. No operations to report. 7/15/2023 - Saturday Rig accepted @ 08:30 7/17/2023;Preform shell test. test BOPs 250/2500 high as per approved sundry. test waived by AOGCC Brian Bixby. all pressure test passed. 1 F/P on H2S sensor in cellar. Electricians troubleshoot and changed out sensor. Sim Ops, spot spooler, take on brine, hang sheave and elephant trunk. Test Fire and Gas system - Good. Continue preparing to pull ESP Comp. Pull CTS Plug and BPV. Install Landing Joint, Pull Hanger w/ 86K. Found ESP Connector loose, inform Engineering of status. STBY for plan forward. Decision made to POOH w/ ESP. Continue OOH w/ ESP / 3/8" SS Cap. Tubing. POOH F/10,892' - T/10,242' while pumping double displacement. Continue POOH F/10,242' - T/8,572'. Catwalk Cable unraveling, install TIW and troubleshoot issue. Lock-out Catwalk to replace Cable. Pump 2bbls at 04:00. Service Rig. Continue POOH F/8,572' - T/8,130' while pumping double displacement. 7/18/2023 - Tuesday 7/16/2023 - Sunday No operations to report. 7/17/2023 - Monday 7/14/2023 - Friday No operations to report. 7/12/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 7/13/2023 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP F-09 ASR#1 50-029-22773-00-00 197-104 7/17/2023 7/28/2023 7/21/2023 - Friday Attempt to test casing at 10,000' to 1,650 psi. pressure went top 1,000 psi and bled to 50 psi. Bleed off pressure. release packer. POOH W/ test packer to 9,000'. Set test packer W/ 25K down on it. Attempt to test casing. Pressure bled off. observed pressure on workstring..Casing pressure bled down to 50 PSI. Bleed off remaining pressure. Release packer. POOH w/ workstring and test packer to 6,000'. Set test packer W/ 30K down on it. Attempt to test casing. Attemped to pressure up on casing. pumping @ 1 BPM 700 psi. observed pressure on workstring. Bleed of remaining pressure. Release packer. POOH T/ 3,000'. with test packer. Circulate and reciprocate packer. Set packer with 28K down. attempted to pressure up to 1,650 psi. pressure bled off to 50 psi. POOH T/ 510' COE. with test packer. Circulate packer. Set packer with 28K down. Pressure test to 1,650 psi. Hold for 15 mins good test. POOH F/ 510' to surface. Pump double displacement for trip. Inspect & C/O PKR. No external issues found. P/U & M/U AS1X PKR. RIH w/ 3-1/2" workstring and test packer F/ surface T/ 510'. Pump double displacement of pipe tripped in. Set test PKR at 510' COE w/ 15k dw on PKR. Test to 1800 psi. Hold for 10 mins (good test). RIH w/ 3-1/2" workstring and test packer F/ 510' T/ 3,003'. Pump double displacement of pipe tripped in. Set test PKR at 3,003' COE. Test to 1,800 psi. Hold for 10 mins (good test). RIH w/ 3-1/2" workstring and test packer F/ 3,003' T/ 4,330'. Pump double displacement of pipe tripped in. 7/19/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary RIH w/ 3-1/2" workstring and clean out BHA F/ 497' T/ 6,301' Pump single displacement for trip. Service rig, Check equip. fluid levels. RIH w/3-1/2" workstring and clean out BHA F/ 6,301' T/ 11,096'. P/U wt = 115K S/O wt = 42K. Wash dw stand # 272 T/ 11,104' at 5 BPM of 8.7 ppg NACL w/ 1,400 psi. No set down wt observed while washing down. Cont. to Circ F/ surf to surf. Losing ~ 12 bph. Small amount of silt to fine sand observed at shaker. Total volume pump = 450 bbls. Total loss 26.5 bbls. Shut dw pumps. monitor well, (well taking fluid) Pull stand # 272 "dry" P/U wt = 115k. & L/D. B/D kelly hose & circ lines. POOH w/ 3- 1/2" workstring and clean out BHA F/ 11,096' T/ 9,703'. Pump double displacement for pipe pulled. Service rig, Check equip. fluid levels. POOH w/ 3-1/2" workstring and clean out BHA F/ 9,703' T/ 3,429'. Pump double displacement for pipe pulled. 7/20/2023 - Thursday Cont. to POOH w/ 3-1/2" workstring and cleanout BHA F/ 3,429' T/ 496'. L/D BHA, 6 collars, jars, bumper sub, scraper, 7 joints of workstring, and Mill. Clean and clear rig floor. Pull BHA out from pipe shed. Load test packer. Rig service. check all fluids and equipment. Replace wrap on service loop wrap. P/U M/U 7" test PKR as per baker rep. RIH w/ 3-1/2" workstring and test packer F/ surface T/ 8,023'. Pump double displacement of pipe tripped in. Seeing returns while filling at 4,000' on. Rig service, Check equip. fluid levels. RIH w/ 3-1/2" workstring and test packer F/ 8,023' T/ 10,503'. Pump double displacement of pipe tripped in. M/U kelly hose. P/U joint # 263. Set Test PKR at 10,507' COE. Set 20K string wt on PKR. Test Casing t/ 1650 psi. Attempt to pressure up. Pump unable to pressure up to 1000 psi. Shut dw pump & monitor pressure. Bleeding to 0. Check surface lines. No leaks. OA showing 50 psi. Normal. Attempt to test w/ 27K wt on PKR. Release PKR, POOH F/ 10,507' T/ 10,000' Fill hole. Fill hole. Set Test PKR at 10,007' COE. Set 25K string wt on PKR. Well Name Rig API Number Well Permit Number Start Date End Date MP F-09 ASR#1 50-029-22773-00-00 197-104 7/17/2023 7/28/2023 Hilcorp Alaska, LLC Weekly Operations Summary RIH w/ 3-1/2" workstring and test packer F/ 4,330' T/ 8,528' Pump double displacement of pipe tripped in. Set test packer COE @ 8,528'. Fill IA. Test casing to 1,700 psi. for 10 min charted. Good test. Bleed off. Release packer. lay down kelly hose. RIH w/ 3-1/2" workstring and test packer F/ 8,528' T/ 10,528' Pump double displacement of pipe tripped in. Hook up kelly hose. P/U wt 88K S/O wt 41K. Set test packer COE 10,528. Fill backside and close VBRs. Pressure up IA to 1,800 psi for 30 charted min. Good test. Bleed off pressure. Release packer. POOH with workstring & test packer F/ 10,528' T/ 4,534' pumping double displacement for the pipe being pulled. Fill well w/ xx bbls. Secure well. Shut bag & close TIW. B/D pump & disconnect from pits. Move pits closer to well row to allow CDR 2 to pass. Stage & allow 2 modules to pass. Move pits back forward & reconnect pump lines. Check IA pressure, well on vac, Open well. Cont. t/ POOH w/ workstring & test packer F/ 4,534' T/ surface. Pumping double displacement for the pipe being pulled. L/D test PKR & inspect. (Good) 7/22/2023 - Saturday PU lower & upper tandem Seals. Fill with oil and connect pot head. Tie in MLE to Motor. Took weight in hanger bowl while RIH. P/U & inspect motor. No issue found. Test cable (good) Reposition & lower motor in hole. MU Intake Gas Separator, 2 Pumps, Ported Sub & Discharge Head, Applying clamps as per ALS Baker Rep. Ran in JT#1. Clear floor of Baker ESP install equipment. Final tests on ESP (passed). Cont. RIH w/ 2-7/8" ESP Completion F/ 87' T/ 855'. Testing ESP Cable every 1,000'. Service rig, Check equip. fluid levels. Hazard hunt. Cont. RIH w/ 2-7/8" ESP Completion F/ 855' T/ 5,217'. RIH at 60 FPM T/ 70 FPM. Testing ESP Cable every 1,000' Collar clamping every other joint. Upon megging ESP motor, found cable grounded, Troubleshoot test. Check motor gauge, not transmitting values. Prep to POOH. Service rig, Check equip. fluid levels. Hazard hunt. POOH w/ 2-7/8" ESP Completion F/ 5,217' T/ 1,300'. Testing ESP Cable every 1,000' Collar clamping every other joint. 7/23/2023 - Sunday M/U test joint, prep to test BOPs. Install 7" test plug. P/U test joint. lock in VBRs. fill stack with fresh water. preform shell test.. good test. Test BOPs 250/2500 psi as per approved sundry. AOGCC Guy Cook waived witness. 0 failures. Service Rig, check Equip. fluid levels. Rig down test equipment. N/D flow spools and spacer spools. N/U shooting flange. R/U E-line BOPE to shooting flange fill & trouble shoot leaks. Test E-line PCE. Change out multiply o-rings on otis connections due to leaks. Test E- line PCE to 250 psi low & 2,500 psi high f 5/5 charted mins. R/D testing equip. Disconnect quick test sub. Remove test plug f/ wellhead. Reconnect & test connection (good). P/U & M/U . CHD, DF GG, 23' of 3-1/8" Perf gun 6 SPF 60 deg phazing, 4' Blank & 4' of 3-1/8" Perf gun 6 SPF 60 deg phazing,. Fill well w/ 8 bbls. RIH w/ perf guns on E-line to 11,038'. Correlate w/ geo, + 4.5' to E-line depth & Shoot perfs as per sundry. CCL depth = 10,994' 13' to top shot from ccl, for top shot depth = 11,007'. Perf intervals = 11,007' to 11,030' & 11,034' to 11,038'. No pressure change on surface after perfing. Fill hole w/ 7 bbls. POOH w/ E- line spent perf guns. L/D E-line perf guns. All shots fired. L/D all E-line equip. M/U & N/U spacers spool & flow spool. Load ESP completion, Strap & tally. Spot in spooler. Run cables over sheaves. P/U ESP motor, attach chem. injection line & gauge line. Service motor. 7/24/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP F-09 ASR#1 50-029-22773-00-00 197-104 7/17/2023 7/28/2023 Hilcorp Alaska, LLC Weekly Operations Summary POOH /W 2-7/8 EUE and ESP. F/1,300' T/ 87'. Pumping double displacement for pipe and cable being pulled. Found broken SS band wedged in protectaliser on discharge head. No obvious damage to cable or MLE. Tested Cable. all tested good on surface. L/D ESP equipment. found 3 missing SS bands from motor. Decision was made to replace seals and splice new MLE. P/U and M/U seals. SIMOPS splice on new MLE to real. Decision was made to replace motor and cable. L/D seals and motor. Continue splicing MLE to new cable. New cable test good before beginning to splice on MLE. Mobilize new motor to location. Continue splicing MLE to new reel of cable. Crew clean and organize location. New motor on location. Start to P/U New Motor & service, PU lower & upper tandem Seals. Fill with oil and connect pot head. Tie in MLE to Motor Test cable (good) MU Intake Gas Separator, 2 Pumps, Ported Sub & Discharge Head, Applying clamps as per ALS Baker Rep. Ran in JT#1. Clear floor of Baker ESP install equipment. Final tests on ESP (passed). Cont. RIH w/ 2-7/8" ESP Completion F/ 87' T/ 2805'. Testing ESP Cable every 1,000' 7/25/2023 - Tuesday Well Name Rig API Number Well Permit Number Start Date End Date MPU F-09 ASR#1 50-029-22773-00-00 197-104 7/17/2023 7/28/2023 7/28/2023 - Friday WELLHEAD: M/U hanger to string baker spliced ESP cable to penatrator then M/U to hanger, terminated chemical line into hanger. Landed hanger to RKB of 16.65' RILDS set BPV S/B for RDMO. N/U tree/adapter test void 500 low 5000 high 5/10 min good test. Pulled BPV. Secured well. 7/26/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Cont. RIH w/ 2-7/8" ESP Completion F/ 2805' T/ 5,406'. Testing ESP Cable every 1,000'. RIH at 60 FPM. Service rig, check equip. fluid levels. Cont. RIH w/ 2-7/8" ESP Completion F/ 5,406' T/ 7,826'. Testing ESP Cable every 1,000'. RIH at 60 FPM. C/O reel in spooling unit. Perform reel to reel splice. Tested (good). Cont. RIH w/ 2-7/8" ESP Completion F/ 7,826' T/ 8,925'. Testing ESP Cable every 1,000'. RIH at 60 FPM. Splice landing at 8,051'. JT # 253 on tally. Service rig, check equip. fluid levels. Inspect skate. Cont. RIH w/ 2-7/8" ESP Completion F/ 8,925' T/ 10,859'. Testing ESP Cable every 1,000'. RIH at 60 FPM. P/U tubing hanger & M/U, prep to terminate ESP cable & chemical cap line to hanger. 7/27/2023 - Thursday Complete ESP hanger termination, Test ESP (good) Cap line termination complete. P/U wt = 79K S/O wt = 37K Land hanger. RILDS, Set BPV w/ tee bar. Remove all completion equip. from rig floor. R/D sheave & all rig support Equip. Rig released at 7- 27-2023 12:00. No operations to report. No operations to report. 7/29/2023 - Saturday No operations to report. 8/1/2023 - Tuesday 7/30/2023 - Sunday No operations to report. 7/31/2023 - Monday Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/31/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230731 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 22-06 50133205500000 205055 7/22/2023 YELLOW JACKET SCBL KU 22-6X 50133205800000 208135 6/23/2023 HALLIBURTON EPX KU 22-6X 50133205800000 208135 6/23/2023 HALLIBURTON MFC MPU F-09 50029227730000 197104 7/22/2023 YELLOW JACKET PERF SRU 213-15 50133206520000 215100 7/20/2023 YELLOW JACKET GPT/PLUG/PERF Please include current contact information if different from above. T37902PTD:205-054 T37903 T37903 T37904 T37905 YELLOWMPU F-09 50029227730000 197104 7/22/2023 PERFJACKET Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.01 10:13:43 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20230713 1634 APPROVAL to forego production packer - PTD 197-104 MPU F-09, Sundry 323-236 Date:Thursday, July 13, 2023 4:35:36 PM From: Rixse, Melvin G (OGC) Sent: Thursday, July 13, 2023 4:34 PM To: Scott Pessetto <Scott.Pessetto@hilcorp.com> Subject: RE: PTD 197-104 MPU F-09, Sundry 323-236 Scott, Hilcorp is approved to perform work under Sundry 323-236 with new BHPE of 8.35 PPG. This will allow the completion to be run without a production tubing packer. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Scott Pessetto <Scott.Pessetto@hilcorp.com> Sent: Thursday, July 13, 2023 10:41 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: PTD 197-104 MPU F-09, Sundry 323-236 Good Morning Mel, Yesterday an updated bottom hole pressure was obtained on MPU F-09. MPU F-09 SBHP - 7/12/23 Depth: 6,672’ TVD Pressure: 2,896 psi EMW PPG: 8.35 As stated in approved sundry # 323-236 we plan to remove the packer in compliance with CO 390A. The last casing test was completed on 4/10/2015 to 1,500 psi at 10,500’ MD. ASR1 will perform an updated charted casing test to 1,650 psi at a depth of 10,500’ MD / 6,528 TVD for 30 minutes. Scott Scott Pessetto | Milne Point | Operations Engineer | Hilcorp Alaska Office: 907-564-4373 | Cell: 801-822-2203 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP RWO 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,390'N/A Casing Collapse Conductor 470psi Surface 3,090psi 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: Contact Email: Contact Phone: Authorized Title: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Tubing Grade: Tubing MD (ft): 6.5#/ L-80/ EUE 8rd 10,892' 4/30/2023 N/A and N/A N/A and N/A See Schematic See Schematic 2-7/8" 6,288' 11,350' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 9-5/8" 7" MD 1,490psi 5,750psi 7,240psi 4,305' 7,350' 6,288' 11,350' Length Size Proposed Pools: 112' 112' TVD Burst PRESENT WELL CONDITION SUMMARY 7,389' 11,267' 7,269' 2,384 N/A 112' 20" MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 & ADL0388235 197-104 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22773-00-00 Hilcorp Alaska LLC KUPARUK RIVER OIL N/A C.O. 432D MILNE PT UNIT F-09 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 twellman@hilcorp.com 777-8449 Taylor Wellman Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-236 By Kayla Junke at 10:16 am, Apr 19, 2023 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.04.19 06:45:24 -08'00' David Haakinson (3533) MGR19MAY2023 DSR-4/20/23 BOPE test to 2500 psi. 432E 10-404 MDG 4/20/2023 * 8.8 PPGE reservoir pressure requires production packer on ESP per CO 390A * CO 390A allows packer completion to forego 8 year MIT-IA. * Production packer to be set and tested (MIT-IA to 2500 psi) before put on production. 2,384 GCW 05/24/23 JLC 5/24/2023 05/24/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.24 12:34:49 -05'00' RBDMS JSB 052523 ESP Change Out Well: MPU F-09 Date: 04/18/2023 Well Name:MPU F-09 API Number:50-029-22773-00-00 Current Status:Oil Well [Failed ESP]Pad:F-Pad Estimated Start Date:April 30, 2023 Rig:ASR #1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Darci Horner Permit to Drill Number:197-104 First Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Second Call Engineer:Scott Pessetto (907) 564-4373 (O) (801) 822-2203 (M) Current Bottom Hole Pressure: 3,051 psi @ 6,672’ TVD (SBHP Survey 4/13/23 / 8.80 ppg EMW) Maximum Expected BHP:3,051 psi @ 6,672’ TVD (SBHP Survey 4/13/23 / 8.80 ppg EMW) MPSP:2,384 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-09 was drilled, perforated, and fracture stimulated as a Kuparuk A sand producer in June 1997. The well has had a total of six ESP rig workovers in its history with the last occurring in 2015. The average run life of the last three pumps was 5.8 years. The well has historically been known for its scale deposition and locking of the pump shafts. The well was shut in on 01/12/2020 after an apparent shaft break. Notes Regarding Wellbore Condition x CO 390A: A packer is required on this ESP completion as the maximum anticipated reservoir pressure of 8.5 ppg EMW is more than 8.55 ppg EMW. A follow up BHP survey will be conducted to confirm prior to workover. If the BHP is confirmed below the 8.55ppg EMW and in conformance with CO 390A, no packer will be run and the completion will be adjusted to remove. x Last CSG Test (10,500’ – surface) 1,500 psi – 04/10/2015 x Offset Injector Support o L-33 offline o F-13 & L-15 online – all support additional producers in fault block Objective: Pull failed ESP, perforate the Kuparuk A1 sands and run a new ESP. Slickline (Non-sundried steps): 1. RU SL unit and pressure test PCE to 250psi/2,500psi high. 2. Run SBHPS to confirm BHP. 3. RD SL Unit. Pre-Rig Procedure: 4. Clear and level pad area in front of well. Spot rig mats and containment. 5. RD well house and flowlines. Clear and level area around well. 6. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 7. Pressure test lines to 3,000 psi. 8. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. 8.8 Bottom hole pressure of 8.8 ppg may require weighted brine to kill. -mgr ESP Change Out Well: MPU F-09 Date: 04/18/2023 a. Partial returns will probably be seen. After attempting circulation down the tubing, load the IA. 9. Confirm well is dead. Contact the operations engineer if freeze protection is needed depending on ASR #1 arrival. 10. RD Little Red Services and reverse out skid. 11. Set BPV. Brief RWO Procedure (Approved Sundry Required): 12. MIRU ASR #1, ancillary equipment and lines. 13. 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/ produced water. ND tree. Set CTS plug. 14. NU BOPE. 15. Test BOP to 250/2,500 psi for 5/5 min. Test annular to 250/2,500 psi for 5/5 min. a. Notify the AOGCC 24 hours in advance of BOP test. b. Test upper 2-7/8” x 5” rams with the 2-7/8” test joint. c. Confirm test pressures with Approved Sundry. d. Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug. e. Once BOPE test is complete, send a copy of the test report (10-424 form) to AOGCC and town engineer. 16. Bleed any pressure off casing to the returns tank. Pull CTS plug and check for pressure underneath the BPV. If needed lubricate out the BPV, if not pull the BPV. Kill well with produced water as needed. 17. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2015 ESP swap was 85 K lbs to free pipe, 70-75K up wt. after free. The current completion was landed with a PUW of 126k and slack off wt of 72k (Nordic 3 block weight not subtracted – estimated at 30k). 18. Recover the tubing hanger. 19. POOH and lay down the 2-7/8” tubing. Number all joints. Caliper data indicates the tubing is in good condition. Tubing and components will be re-used. Lay down failed ESP. a. Pull out all visually bad joints and mark for disposal. b. Look for over-torqued connections from previous tubing runs and junk them. c. 177 Cannon cross collar clamps, 1 cable guard, 3 protectrolizers, and 1 motor protector were installed. 20. MIRU e-line unit and pressure test lubricator to 250 psi low / 2500 psi high. 21. RIH with 3-3/8” HC gun assembly and perforate The Kuparuk A1B from 11034-11038’ and 11007- 11030’. a. Can run either two guns on switches or one long tandem gun with blank section. b. Correlate to log provided by town engineer or geologist. 22. POOH and RDMO e-line. 23. PU new ESP and RIH on 2-7/8” 6.5# L-80 tubing. Check electrical connections and cap string every 2,000’. a. Base of ESP at ± 10,890’ MD. Lubricate BPV if possibility of pressure below. -mgr Lubricate BPV if possibility of pressure below. -mgr ESP Change Out Well: MPU F-09 Date: 04/18/2023 a. ESP: centralizer (with foot valve for chemical injection in the centralizer), motor, seals, gas separator, pump sections. b. 1 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing c. 2-7/8” XN (2.205” No-Go) Nipple w/ RHC plug body installed d. 3-4 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing e. 2-7/8”x 1” Side-pocket GLM #1 with Dummy GLV f. Multiple joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing g. 2-7/8”x 1” Side-pocket GLM #2 with Dummy GLV h. 1 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing i. 2-7/8” x 7” ESP Packer j. 1 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing k. 2-7/8”x 1” Side-pocket GLM #3 @ ± 200’ MD with 0.25” OV l. ± 5 joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing 24. Land tubing hanger (Caution not to Damage Cable while landing the hanger). Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 25. Set BPV. Post-Rig Procedure: 1. ND BOP stack and NU existing 2-9/16” 5,000# tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 2. RD Doyon 14. Move to next well location. 3. Move 500 bbl returns tank and rig mats to next well location. 4. Replace gauge(s) if removed. 5. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic Production packer to be set and MIT-IA to 2500 psi (charted) before POP. - mgr _____________________________________________________________________________________ Revised By: TDF 2/11/2020 SCHEMATIC Milne Point Unit Well: MP F-09 Last Completed: 4/11/2015 PTD: 197-104 TD = 11,390(MD) / TD =7,389(TVD) 20” Two 7” x 21’ Marker Joints from 10,821’ to 10,863’ Orig. DF Elev.: 29’/ Orig. GL Elev.: 24.7’ DF to 7” Casing Hanger = 30.4’ (Nabors 22E) 7” 3 5 6 7 8 9 10 9-5/8” 1 2 3/8” SS Capstring KUP A Sands PBTD =11,267’(MD) / PBTD =7,269’(TVD) 4 9 X X CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 6,288’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 11,350’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 10,892’ 3/8” Cap String Stainless Steel N/A Surface 10,892’ JEWELRY DETAIL No Depth Item 1 170’ 2-7/8” x 1” KBMM GLM w/DV Set 1/13/2020 2 10,674’ 2-7/8” x 1” KBMM GLM w/Open Pocket 2/10/2020 3 10815’ 2-7/8” HES XN-Nipple (2.205 No-go ID) 4 10,8826.7’ 2-7/8” GPDIS Discharge Head EUE 8rd 5 10,827’ Pump SXD 137-P17 6 10,846’ Gas Separator GSTHVVX H6 7 10,852’ Tandem Seal Section – GSB3DBUT SB/SB PFSA & GSB3DBLT SB/SB PFSA CL5 8 10,865’ Motor – KMH 210hp, 2,145 volts and 59 amps 9 10,889’ Phoenix Sensor XT150 10 10,890’ 6 Fin Centralizer – Bottom @ 10,892’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 10,937’ 10,951’ 6,949’ 6,962 14 7/19/1997 Open Kup. A Sands 10,955’ 10,975’ 6,966’ 6,986’ 20 7/12/1997 Open Kup. A Sands 10,979’ 11,007’ 6,989’ 7,017’ 28 7/19/1997 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,765 sks PF “E”,500 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 240 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 65 to 67 deg. f/ 3,900’ to 8,800’ Hole Angle through perforations = 14 deg. No DLS ग़4 deg./ 100’ TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME on top and 2-7/8” EU 8rd on bottom, 2.5” CIW BPV Profile GENERAL WELL INFO API: 50-029-22773-00-00 Drilled and Cased by Nabors 22E - 6/19/1997 Initial Perforations – 7/11/1997 ESPR WO w/ Nabors 5S – 3/6/1998 ESP RWO w/ Nabors 4-ES – 3/23/1998 ESP RWO w/ Nabors 4-ES – 6/19/1999 ESP RWO w/ Nabors 4-ES – 11/11/1999 ESP RWO w/ Nabors 4-ES – 11/15/2002 ESP RWO w/ Nabors 4-ES – 8/28/2008 ESP RWO w/ Nordic 3 – 4/11/2015 STIMULATION SUMMARY Frac – 104,066# of 16/20 carbolite behind pipe. Frac was designed for 159,000# - 7/15/1997 _____________________________________________________________________________________ Revised By: TTW 4/18/2023 PROPOSED Milne Point Unit Well: MP F-09 Last Completed: 4/11/2015 PTD: 197-104 TD =11,390(MD) / TD =7,389(TVD) 20” Two 7” x 21’ Marker Joints from 10,821’ to 10,863’ Orig. DF Elev.: 29’/ Orig. GL Elev.: 24.7’ DF to 7” Casing Hanger = 30.4’ (Nabors 22E) 7” 13 5 7 8 9 10 9 12 9-5/8” 1 4 KUP A Sands PBTD =11,267’ (MD) / PBTD =7,269’(TVD) 6 11 X X 2 3 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 6,288’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 11,350’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±10,892’ 3/8” Capstring Stainless Steel N/A Surface ±10,892’ JEWELRY DETAIL No Depth Item 1 ±190’GLM #3: 2-7/8” x 1” KBMM GLM w/ 0.25” OV 2 ±2,000’2-7/8” x 7” ESP Packer 3 ±2,030’GLM #2: 2-7/8” x 1” KBMM GLM w/ Dummy Valve 4 ±10,655’GLM #1: 2-7/8” x 1” KBMM GLM w/ Dummy Valve 5 ±10,760’ 2-7/8” XN-Nipple (2.205 No-go ID) 6 ±10,800’ 2-7/8” Discharge Head 7 ±10,805 Pump: 137 Stage P17SXD 8 ±10,825’ Pump: 20 Stage GINPSHHSXD 9 ±10,845’ Gas Separator 10 ±10,855’ Tandem Seal Section 11 ±10,870’ Motor – 200 HP 12 ±10,885’ Sensor 13 ±10,890’ ESP Centralizer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 10,937’ 10,951’ 6,949’ 6,962 14 7/19/1997 Open Kup. A Sands 10,955’ 10,975’ 6,966’ 6,986’ 20 7/12/1997 Open Kup. A Sands 10,979’ 11,007’ 6,989’ 7,017’ 28 7/19/1997 Open Kup. A1B Sands 11,007’ 11,030’ 7,017’ 7,039’ 23 Future Future Kup. A1B Sands 11,034’ 11,038’ 7,043’ 7,043’ 4 Future Future OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,765 sks PF “E”,500 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 240 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 65 to 67 deg. f/ 3,900’ to 8,800’ Hole Angle through perforations = 14 deg. No DLS ग़4 deg./ 100’ TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME on top and 2-7/8” EU 8rd on bottom, 2.5” CIW BPV Profile GENERAL WELL INFO API: 50-029-22773-00-00 Drilled and Cased by Nabors 22E - 6/19/1997 Initial Perforations – 7/11/1997 ESPR WO w/ Nabors 5S – 3/6/1998 ESP RWO w/ Nabors 4-ES – 3/23/1998 ESP RWO w/ Nabors 4-ES – 6/19/1999 ESP RWO w/ Nabors 4-ES – 11/11/1999 ESP RWO w/ Nabors 4-ES – 11/15/2002 ESP RWO w/ Nabors 4-ES – 8/28/2008 ESP RWO w/ Nordic 3 – 4/11/2015 STIMULATION SUMMARY Frac – 104,066# of 16/20 carbolite behind pipe. Frac was designed for 159,000# - 7/15/1997 ] Milne Point Doyon 14 13-5/8” BOP Stack CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20230217 1417 Approval for Sundry(322-704) Revision3 - MPU F-09 (PTD 197-104) Procedure Revision Date:Friday, February 17, 2023 2:22:22 PM Attachments:MPU F-09 ESP Changeout Procedure Rev3 2-16-2023.pdf MP F-09 PROPOSED 2-17-2023.pdf Sundry_322-704_122022.pdf From: Rixse, Melvin G (OGC) Sent: Friday, February 17, 2023 2:21 PM To: Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com> Subject: 20230217 1417 Approval for Sundry(322-704) Revision3 - MPU F-09 (PTD 197-104) Procedure Revision Todd, Hilcorp is approved to add Eline perforating (with PCE) as per the attached Revision 3 procedure on approved Sundry 322-704. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Todd Sidoti <Todd.Sidoti@hilcorp.com> Sent: Friday, February 17, 2023 11:13 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MPU F-09 (PTD 197-104) Procedure Revision Hi Mel, Hilcorp received Sundry approval on an ESP workover for well MPU F-09 on 12-20-2022 (Sundry 332- 704). In the procedure are were supposed to be some additional Kuparuk sands perforated once the ESP is pulled. I have added the perforation steps to the program attached and the intervals are reflected in the proposed schematic. Is this sufficient for your review and approval or would you like me to take other action? Thanks Mel. Todd Todd Sidoti | Operations Engineer | Hilcorp Alaska | 907-632-4113 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. ESP Change Out Well: MPU F-09 Date: 02/16/2023 Revsion 2 Well Name: MPU F-09 API Number: 50-029-22773-00-00 Current Status: Oil Well [Failed ESP] Pad: F-Pad Estimated Start Date: March 5, 2023 Rig: ASR #1 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Darci Horner Permit to Drill Number: 197-104 First Call Engineer: Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) Current Bottom Hole Pressure: 2,733 psi @ 7,228’ TVD (DH Gauge – 1 year shut in / 7.3 ppg EMW) Maximum Expected BHP: 2,733 psi @ 7,228’ TVD (DH Gauge – 1 year shut in / 7.3 ppg EMW) MPSP: 2,010 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-09 was drilled, perforated, and fracture stimulated as a Kuparuk A sand producer in June 1997. The well has had a total of six ESP rig workovers in its history with the last occurring in 2015. The average run life of the last three pumps was 5.8 years. The well has historically been known for its scale deposition and locking of the pump shafts. The well was shut in on 01/12/2020 after an apparent shaft break. Notes Regarding Wellbore Condition • CO 390A: A packer is not required on this ESP completion as the maximum anticipated reservoir pressure of 8.5 ppg EMW is less than 8.55 ppg EMW. A follow up BHP survey will be conducted to confirm prior to workover. • Last CSG Test (10,500’ – surface) 1,500 psi – 04/10/2015 • Offset Injector Support o L-33 offline o F-13 & L-15 online – all support additional producers in fault block Objective: Pull failed ESP and run a new ESP. Slickline (Non-sundried steps): 1. RU SL unit and pressure test PCE to 250psi/2,500psi high. 2. Run SBHPS to confirm BHP. 3. RD SL Unit. Pre-Rig Procedure: 4. Clear and level pad area in front of well. Spot rig mats and containment. 5. RD well house and flowlines. Clear and level area around well. 6. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 7. Pressure test lines to 3,000 psi. 8. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. ESP Change Out Well: MPU F-09 Date: 02/16/2023 a. Partial returns will probably be seen. After attempting circulation down the tubing, load the IA. 9. Confirm well is dead. Contact the operations engineer if freeze protection is needed depending on ASR #1 arrival. 10. RD Little Red Services and reverse out skid. 11. Set BPV. Brief RWO Procedure: 12. MIRU ASR #1, ancillary equipment and lines. 13. 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/ produced water. ND tree. Set CTS plug. 14. NU BOPE. 15. Test BOP to 250/2,500 psi for 5/5 min. Test annular to 250/2,500 psi for 5/5 min. a. Notify the AOGCC 24 hours in advance of BOP test. b. Test upper 2-7/8” x 5” rams with the 2-7/8” test joint. c. Confirm test pressures with Approved Sundry. d. Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug. e. Once BOPE test is complete, send a copy of the test report (10-424 form) to AOGCC and town engineer. 16. Bleed any pressure off casing to the returns tank. Pull CTS plug and BPV. Kill well with produced water as needed. 17. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2015 ESP swap was 85 K lbs to free pipe, 70-75K up wt. after free. The current completion was landed with a PUW of 126k and slack off wt of 72k (Nordic 3 block weight not subtracted – estimated at 30k). 18. Recover the tubing hanger. 19. POOH and lay down the 2-7/8” tubing. Number all joints. Caliper data indicates the tubing is in good condition. Tubing and components will be re-used. Lay down failed ESP. a. Pull out all visually bad joints and mark for disposal. b. Look for over-torqued connections from previous tubing runs and junk them. c. 177 Cannon cross collar clamps, 1 cable guard, 3 protectrolizers, and 1 motor protector were installed. 20. MIRU e-line unit and pressure test lubricator to 250 psi low / 2500 psi high. 21. RIH with 3-3/8” HC gun assembly and perforate The Kuparuk A1B from 11034-11038’ and 11007- 11030’. a. Can run either two guns on switches or one long tandem gun with blank section. b. Correlate to log provided by town engineer or geologist. 22. POOH and RDMO e-line. 23. PU new ESP and RIH on 2-7/8” 6.5# L-80 tubing. Check electrical connections and cap string every 2,000’. a. Base of ESP at ± 10,890’ MD. ESP Change Out Well: MPU F-09 Date: 02/16/2023 a. ESP: centralizer (with foot valve for chemical injection in the centralizer), motor, seals, gas separator, pump sections. b. 1 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing c. 2-7/8” XN (2.205” No-Go) Nipple d. 3-4 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing e. Lower 2-7/8”x 1” Side-pocket GLM with Dummy GLV f. Multiple joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing g. Upper 2-7/8”x 1” Side-pocket GLM @ ± 200’ MD with 0.25” OV h. ± 5 joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing 24. Land tubing hanger (Caution not to Damage Cable while landing the hanger). Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 25. Set BPV. Post-Rig Procedure: 1. ND BOP stack and NU existing 2-9/16” 5,000# tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 2. RD Doyon 14. Move to next well location. 3. Move 500 bbl returns tank and rig mats to next well location. 4. Replace gauge(s) if removed. 5. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By: TCS 2/17/2023 PROPOSED Milne Point Unit Well: MP F-09 Last Completed: 4/11/2015 PTD: 197-104 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 6,288’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 11,350’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±10,892’ 3/8” Capstring Stainless Steel N/A Surface ±10,892’ JEWELRY DETAIL No Depth Item 1 ±190’ GLM #1: 2-7/8” x 1” KBMM GLM w/ 0.25” OV 2 ±10,655’ GLM #2: 2-7/8” x 1” KBMM GLM w/ Dummy Valve 3 ±10,760’ 2-7/8” XN-Nipple (2.205 No-go ID) 4 ±10,800’ 2-7/8” Discharge Head 5 ±10,805 Pump: 137 Stage P17SXD 6 ±10,825’ Pump: 20 Stage GINPSHHSXD 7 ±10,845’ Gas Separator 8 ±10,855’ Tandem Seal Section 9 ±10,870’ Motor – 200 HP 10 ±10,885’ Sensor 11 ±10,890’ ESP Centralizer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A 10,937’ 10,951’ 6,949’ 6,962 14 7/19/1997 Open Kup. A 10,955’ 10,975’ 6,966’ 6,986’ 20 7/12/1997 Open Kup. A 10,979’ 11,007’ 6,989’ 7,017’ 28 7/19/1997 Open Kup, A1B 11,007’ 11,030’ 7,016’ 7,039’ 23 TBD Open Kup, A1B 11,034’ 11,038’ 7,043’ 7,047’ 4’ TBD Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,765 sks PF “E”,500 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 240 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 65 to 67 deg. f/ 3,900’ to 8,800’ Hole Angle through perforations = 14 deg. No DLS ˃4 deg./ 100’ TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME on top and 2-7/8” EU 8rd on bottom, 2.5” CIW BPV Profile GENERAL WELL INFO API: 50-029-22773-00-00 Drilled and Cased by Nabors 22E - 6/19/1997 Initial Perforations – 7/11/1997 ESPR WO w/ Nabors 5S – 3/6/1998 ESP RWO w/ Nabors 4-ES – 3/23/1998 ESP RWO w/ Nabors 4-ES – 6/19/1999 ESP RWO w/ Nabors 4-ES – 11/11/1999 ESP RWO w/ Nabors 4-ES – 11/15/2002 ESP RWO w/ Nabors 4-ES – 8/28/2008 ESP RWO w/ Nordic 3 – 4/11/2015 STIMULATION SUMMARY Frac – 104,066# of 16/20 carbolite behind pipe. Frac was designed for 159,000# - 7/15/1997 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP RWO 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,390'N/A Casing Collapse Conductor 470psi Surface 3,090psi 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: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Tubing Grade: Tubing MD (ft): 6.5#/ L-80/ EUE 8rd 10,892' 1/15/2023 6,288' 11,350' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 9-5/8" 7" MD 1,490psi 5,750psi 7,240psi 4,305' 7,350' 6,288' 11,350' Length Size Proposed Pools: 112' 112' TVD Burst PRESENT WELL CONDITION SUMMARY 7,389' 11,267' 7,269' 2,010 N/A 112' 20" Milne Point STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 & ADL0388235 197-104 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22773-00-00 Hilcorp Alaska LLC Kuparuk River Oil N/A C.O. 432E MILNE PT UNIT F-09 N/A and N/A N/A and N/A See Schematic See Schematic 2-7/8" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY twellman@hilcorp.com 777-8449 Taylor Wellman Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Anne Prysunka at 12:33 pm, Dec 15, 2022 322-704 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2022.12.15 07:47:33 -09'00' David Haakinson (3533) X 2,010 BOPE test o 2500 psi. Approved per CO 390A for packerless completion. Reservoir pressure < 8.55 ppg. DSR-12/15/22MGR19DEC22 SFD 12/15/2022 DLB 12/15/2022 10-404 GCW 12/20/22 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.12.20 11:40:52 -09'00' RBDMS JSB 122222 ESP Change Out Well: MPU F-09 Date: 12/14/2022 Well Name:MPU F-09 API Number:50-029-22773-00-00 Current Status:Oil Well [Failed ESP]Pad:F-Pad Estimated Start Date:January 15, 2023 Rig:ASR #1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:197-104 First Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Second Call Engineer:Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) Current Bottom Hole Pressure: 2,733 psi @ 7,228’ TVD (DH Gauge – 1 year shut in / 7.3 ppg EMW) Maximum Expected BHP:2,733 psi @ 7,228’ TVD (DH Gauge – 1 year shut in / 7.3 ppg EMW) MPSP:2,010 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-09 was drilled, perforated, and fracture stimulated as a Kuparuk A sand producer in June 1997. The well has had a total of six ESP rig workovers in its history with the last occurring in 2015. The average run life of the last three pumps was 5.8 years. The well has historically been known for its scale deposition and locking of the pump shafts. The well was shut in on 01/12/2020 after an apparent shaft break. Notes Regarding Wellbore Condition x CO 390A: A packer is not required on this ESP completion as the maximum anticipated reservoir pressure of 8.5 ppg EMW is less than 8.55 ppg EMW. A follow up BHP survey will be conducted to confirm prior to workover. x Last CSG Test (10,500’ – surface) 1,500 psi – 04/10/2015 x Offset Injector Support o L-33 offline o F-13 & L-15 online – all support additional producers in fault block Objective: Pull failed ESP and run a new ESP. Slickline (Non-sundried steps): 1. RU SL unit and pressure test PCE to 250psi/2,500psi high. 2. Run SBHPS to confirm BHP. 3. RD SL Unit. Pre-Rig Procedure: 4. Clear and level pad area in front of well. Spot rig mats and containment. 5. RD well house and flowlines. Clear and level area around well. 6. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 7. Pressure test lines to 3,000 psi. 8. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. ,p 2,010 psi ESP Change Out Well: MPU F-09 Date: 12/14/2022 a. Partial returns will probably be seen. After attempting circulation down the tubing, load the IA. 9. Confirm well is dead. Contact the operations engineer if freeze protection is needed depending on ASR #1 arrival. 10. RD Little Red Services and reverse out skid. 11. Set BPV. Brief RWO Procedure: 12. MIRU ASR #1, ancillary equipment and lines. 13. 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/ produced water. ND tree. Set CTS plug. 14. NU BOPE. 15. Test BOP to 250/2,500 psi for 5/5 min. Test annular to 250/2,500 psi for 5/5 min. a. Notify the AOGCC 24 hours in advance of BOP test. b. Test upper 2-7/8” x 5” rams with the 2-7/8” test joint. c. Confirm test pressures with Approved Sundry. d. Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug. e. Once BOPE test is complete, send a copy of the test report (10-424 form) to AOGCC and town engineer. 16. Bleed any pressure off casing to the returns tank. Pull CTS plug and BPV. Kill well with produced water as needed. 17. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2015 ESP swap was 85 K lbs to free pipe, 70-75K up wt. after free. The current completion was landed with a PUW of 126k and slack off wt of 72k (Nordic 3 block weight not subtracted – estimated at 30k). 18. Recover the tubing hanger. 19. POOH and lay down the 2-7/8” tubing. Number all joints. Caliper data indicates the tubing is in good condition. Tubing and components will be re-used. Lay down failed ESP. a. Pull out all visually bad joints and mark for disposal. b. Look for over-torqued connections from previous tubing runs and junk them. c. 177 Cannon cross collar clamps, 1 cable guard, 3 protectrolizers, and 1 motor protector were installed. 20. PU new ESP and RIH on 2-7/8” 6.5# L-80 tubing. Check electrical connections and cap string every 2,000’. a. Base of ESP at ± 10,890’ MD. a. ESP: centralizer (with foot valve for chemical injection in the centralizer), motor, seals, gas separator, pump sections. b. 1 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing c. 2-7/8” XN (2.205” No-Go) Nipple d. 3-4 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing e. Lower 2-7/8”x 1” Side-pocket GLM with Dummy GLV f. Multiple joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing Risk assess to assure no pressure release below BPV. Lubricate if necessary. ESP Change Out Well: MPU F-09 Date: 12/14/2022 g. Upper 2-7/8”x 1” Side-pocket GLM @ ± 200’ MD with 0.25” OV h. ± 5 joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing 21. Land tubing hanger (Caution not to Damage Cable while landing the hanger). Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 22. Set BPV. Post-Rig Procedure: 1. ND BOP stack and NU existing 2-9/16” 5,000# tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 2. RD Doyon 14. Move to next well location. 3. Move 500 bbl returns tank and rig mats to next well location. 4. Replace gauge(s) if removed. 5. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 2/11/2020 SCHEMATIC Milne Point Unit Well: MP F-09 Last Completed: 4/11/2015 PTD: 197-104 TD = 11,390(MD) / TD =7,389(TVD) 20” Two 7” x 21’ Marker Joints from 10,821’ to 10,863’ Orig. DF Elev.: 29’/ Orig. GL Elev.: 24.7’ DF to 7” Casing Hanger = 30.4’ (Nabors 22E) 7” 3 5 6 7 8 9 10 9-5/8” 1 2 3/8” SS Capstring KUP A Sands PBTD =11,267’(MD) / PBTD =7,269’(TVD) 4 9 X X CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 6,288’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 11,350’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 10,892’ 3/8” Cap String Stainless Steel N/A Surface 10,892’ JEWELRY DETAIL No Depth Item 1 170’ 2-7/8” x 1” KBMM GLM w/DV Set 1/13/2020 2 10,674’ 2-7/8” x 1” KBMM GLM w/Open Pocket 2/10/2020 3 10815’ 2-7/8” HES XN-Nipple (2.205 No-go ID) 4 10,8826.7’ 2-7/8” GPDIS Discharge Head EUE 8rd 5 10,827’ Pump SXD 137-P17 6 10,846’ Gas Separator GSTHVVX H6 7 10,852’ Tandem Seal Section – GSB3DBUT SB/SB PFSA & GSB3DBLT SB/SB PFSA CL5 8 10,865’ Motor – KMH 210hp, 2,145 volts and 59 amps 9 10,889’ Phoenix Sensor XT150 10 10,890’ 6 Fin Centralizer – Bottom @ 10,892’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 10,937’ 10,951’ 6,949’ 6,962 14 7/19/1997 Open Kup. A Sands 10,955’ 10,975’ 6,966’ 6,986’ 20 7/12/1997 Open Kup. A Sands 10,979’ 11,007’ 6,989’ 7,017’ 28 7/19/1997 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,765 sks PF “E”,500 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 240 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 65 to 67 deg. f/ 3,900’ to 8,800’ Hole Angle through perforations = 14 deg. No DLS ग़4 deg./ 100’ TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME on top and 2-7/8” EU 8rd on bottom, 2.5” CIW BPV Profile GENERAL WELL INFO API: 50-029-22773-00-00 Drilled and Cased by Nabors 22E - 6/19/1997 Initial Perforations – 7/11/1997 ESPR WO w/ Nabors 5S – 3/6/1998 ESP RWO w/ Nabors 4-ES – 3/23/1998 ESP RWO w/ Nabors 4-ES – 6/19/1999 ESP RWO w/ Nabors 4-ES – 11/11/1999 ESP RWO w/ Nabors 4-ES – 11/15/2002 ESP RWO w/ Nabors 4-ES – 8/28/2008 ESP RWO w/ Nordic 3 – 4/11/2015 STIMULATION SUMMARY Frac – 104,066# of 16/20 carbolite behind pipe. Frac was designed for 159,000# - 7/15/1997 _____________________________________________________________________________________ Revised By: TDF 2/11/2020 PROPOSED Milne Point Unit Well: MP F-09 Last Completed: 4/11/2015 PTD: 197-104 TD =11,390(MD) / TD =7,389(TVD) 20” Two 7” x 21’ Marker Joints from 10,821’ to 10,863’ Orig. DF Elev.: 29’/ Orig. GL Elev.: 24.7’ DF to 7” Casing Hanger = 30.4’ (Nabors 22E) 7” 1 1 3 5 6 7 8 9 10 9-5/8 ” 1 2 KUP A Sands PBTD =11,267’ (MD) / PBTD =7,269’(TVD) 4 9 X X CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 6,288’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 11,350’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±10,892’ 3/8” Capstring Stainless Steel N/A Surface ±10,892’ JEWELRY DETAIL No Depth Item 1 ±190’GLM #1: 2-7/8” x 1” KBMM GLM w/ 0.25” OV 2 ±10,655’GLM #2: 2-7/8” x 1” KBMM GLM w/ Dummy Valve 3 ±10,760’ 2-7/8” XN-Nipple (2.205 No-go ID) 4 ±10,800’ 2-7/8” Discharge Head 5 ±10,805 Pump: 137 Stage P17SXD 6 ±10,825’ Pump: 20 Stage GINPSHHSXD 7 ±10,845’ Gas Separator 8 ±10,855’ Tandem Seal Section 9 ±10,870’ Motor – 200 HP 10 ±10,885’ Sensor 11 ±10,890’ ESP Centralizer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 10,937’ 10,951’ 6,949’ 6,962 14 7/19/1997 Open Kup. A Sands 10,955’ 10,975’ 6,966’ 6,986’ 20 7/12/1997 Open Kup. A Sands 10,979’ 11,007’ 6,989’ 7,017’ 28 7/19/1997 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,765 sks PF “E”,500 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 240 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 65 to 67 deg. f/ 3,900’ to 8,800’ Hole Angle through perforations = 14 deg. No DLS ग़4 deg./ 100’ TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME on top and 2-7/8” EU 8rd on bottom, 2.5” CIW BPV Profile GENERAL WELL INFO API: 50-029-22773-00-00 Drilled and Cased by Nabors 22E - 6/19/1997 Initial Perforations – 7/11/1997 ESPR WO w/ Nabors 5S – 3/6/1998 ESP RWO w/ Nabors 4-ES – 3/23/1998 ESP RWO w/ Nabors 4-ES – 6/19/1999 ESP RWO w/ Nabors 4-ES – 11/11/1999 ESP RWO w/ Nabors 4-ES – 11/15/2002 ESP RWO w/ Nabors 4-ES – 8/28/2008 ESP RWO w/ Nordic 3 – 4/11/2015 STIMULATION SUMMARY Frac – 104,066# of 16/20 carbolite behind pipe. 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dŚĞWhǁĞŝŐŚƚĚƵƌŝŶŐƚŚĞϮϬϭϱ ^WƐǁĂƉǁĂƐ ϴϱ <ůďƐ ƚŽĨƌĞĞƉŝƉĞ͕ϳϬͲϳϱ<ƵƉǁƚ͘ĂĨƚĞƌ ĨƌĞĞ͘ dŚĞĐƵƌƌĞŶƚĐŽŵƉůĞƚŝŽŶǁĂƐůĂŶĚĞĚǁŝƚŚĂ WhtŽĨ ϭϮϲŬĂŶĚ ƐůĂĐŬŽĨĨ ǁƚŽĨ ϳϮŬ ;EŽƌĚŝĐϯ ďůŽĐŬǁĞŝŐŚƚŶŽƚƐƵďƚƌĂĐƚĞĚ ʹ ĞƐƚŝŵĂƚĞĚĂƚϯϬŬͿ͘ ϭϵ͘ ZĞĐŽǀĞƌƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ ϮϬ͘ WKK,ĂŶĚůĂǇĚŽǁŶƚŚĞϮͲϳͬϴ͟ƚƵďŝŶŐ͘ EƵŵďĞƌĂůůũŽŝŶƚƐ͘ ĂůŝƉĞƌĚĂƚĂŝŶĚŝĐĂƚĞƐƚŚĞƚƵďŝŶŐŝƐŝŶ ŐŽŽĚĐŽŶĚŝƚŝŽŶ͘dƵďŝŶŐĂŶĚĐŽŵƉŽŶĞŶƚƐǁŝůůďĞƌĞͲƵƐĞĚ͘ >ĂǇĚŽǁŶ ĨĂŝůĞĚ^W͘ Ă͘ WƵůůŽƵƚĂůůǀŝƐƵĂůůǇďĂĚũŽŝŶƚƐ ĂŶĚŵĂƌŬ ĨŽƌĚŝƐƉŽƐĂů͘ ď͘ >ŽŽŬĨŽƌŽǀĞƌͲƚŽƌƋƵĞĚĐŽŶŶĞĐƚŝŽŶƐĨƌŽŵƉƌĞǀŝŽƵƐƚƵďŝŶŐƌƵŶƐ ĂŶĚũƵŶŬƚŚĞŵ͘ Đ͘ ϭϳϳ ĂŶŶŽŶ ĐƌŽƐƐ ĐŽůůĂƌ ĐůĂŵƉƐ͕ ϭĐĂďůĞŐƵĂƌĚ͕ϯ ƉƌŽƚĞĐƚƌŽůŝǌĞƌƐ͕ĂŶĚ ϭŵŽƚŽƌƉƌŽƚĞĐƚŽƌ ǁĞƌĞŝŶƐƚĂůůĞĚ͘ Ϯϭ͘ WhŶĞǁ^WĂŶĚZ/,ŽŶϮͲϳͬϴ͟ ϲ͘ϱη>ͲϴϬ ƚƵďŝŶŐ͘ ŚĞĐŬĞůĞĐƚƌŝĐĂůĐŽŶŶĞĐƚŝŽŶƐ ĂŶĚĐĂƉƐƚƌŝŶŐ ĞǀĞƌǇ Ϯ͕ϬϬϬ͛͘ Ă͘ ĂƐĞŽĨ^WĂƚцϭϬ͕ϴϵϬ͛D͘ Ă͘ ^W͗ĐĞŶƚƌĂůŝǌĞƌ ;ǁŝƚŚĨŽŽƚǀĂůǀĞĨŽƌĐŚĞŵŝĐĂůŝŶũĞĐƚŝŽŶŝŶƚŚĞĐĞŶƚƌĂůŝǌĞƌͿ͕ŵŽƚŽƌ͕ ƐĞĂůƐ͕ŐĂƐƐĞƉĂƌĂƚŽƌ͕ƉƵŵƉƐĞĐƚŝŽŶƐ͘ &RQVXOWZLWKDVVHWWHDPUHJDUGLQJSRVVLELOLW\RISUHVVXUHXQGHU%39DQGULVNIRUQRW OXEULFDWLQJ%39UHPRYDO ^WŚĂŶŐĞKƵƚ tĞůů͗ DWh &ͲϬϵ ĂƚĞ͗ ϬϯͬϭϴͬϮϬϮϮ ď͘ ϭ ũŽŝŶƚƐŽĨϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Đ͘ ϮͲϳͬϴ͟yE;Ϯ͘ϮϬϱ͟EŽͲ'ŽͿEŝƉƉůĞ Ě͘ ϯͲϰ ũŽŝŶƚƐ ŽĨϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ğ͘ >ŽǁĞƌϮͲϳͬϴ͟ǆϭ͟^ŝĚĞͲƉŽĐŬĞƚ'>DǁŝƚŚƵŵŵǇ'>s Ĩ͘ DƵůƚŝƉůĞ ũŽŝŶƚƐϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ő͘ hƉƉĞƌϮͲϳͬϴ͟ǆϭ͟^ŝĚĞͲƉŽĐŬĞƚ'>DΛц ϮϬϬ͛DǁŝƚŚϬ͘Ϯϱ͟Ks Ś͘ ц ϱ ũŽŝŶƚƐϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ ϮϮ͘ >ĂŶĚƚƵďŝŶŐŚĂŶŐĞƌ;ĂƵƚŝŽŶŶŽƚƚŽĂŵĂŐĞĂďůĞǁŚŝůĞůĂŶĚŝŶŐƚŚĞŚĂŶŐĞƌͿ͘>ĂǇĚŽǁŶůĂŶĚŝŶŐ ũŽŝŶƚ͘EŽƚĞWh;WŝĐŬhƉͿĂŶĚ^K;^ůĂĐŬKĨĨͿǁĞŝŐŚƚƐŽŶƚĂůůǇ͘ Ϯϯ͘ ^ĞƚWs͘ WŽƐƚͲZŝŐWƌŽĐĞĚƵƌĞ͗ ϭ͘ EKWƐƚĂĐŬĂŶĚ EhĞǆŝƐƚŝŶŐϮͲϵͬϭϲ͟ϱ͕ϬϬϬηƚƌĞĞͬĂĚĂƉƚĞƌĨůĂŶŐĞ͘dĞƐƚƚƵďŝŶŐŚĂŶŐĞƌǀŽŝĚƚŽϱϬϬ ƉƐŝůŽǁͬϱ͕ϬϬϬƉƐŝŚŝŐŚ͘WƵůůWs͘ Ϯ͘ ZŽǇŽŶ ϭϰ͘DŽǀĞƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ ϯ͘ DŽǀĞϱϬϬďďůƌĞƚƵƌŶƐƚĂŶŬĂŶĚƌŝŐŵĂƚƐƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ ϰ͘ ZĞƉůĂĐĞŐĂƵŐĞ;ƐͿŝĨƌĞŵŽǀĞĚ͘ ϱ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ZhǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ KW ^ĐŚĞŵĂƚŝĐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϮͬϭϭͬϮϬϮϬ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW&ͲϬϵ >ĂƐƚŽŵƉůĞƚĞĚ͗ϰͬϭϭͬϮϬϭϱ Wd͗ϭϵϳͲϭϬϰ dс ϭϭ͕ϯϵϬ;DͿͬdсϳ͕ϯϴϵ;dsͿ ϮϬ´ 7ZR´[¶ 0DUNHU -RLQWVIURP¶ WR¶ KƌŝŐ͘&ůĞǀ͗͘Ϯϵ͛ͬKƌŝŐ͘'>ůĞǀ͗͘Ϯϰ͘ϳ͛ &ƚŽϳ͟ĂƐŝŶŐ,ĂŶŐĞƌсϯϬ͘ϰ͛;EĂďŽƌƐϮϮͿ ϳ͟ ϵͲϱͬϴ͟ ϯͬϴ͟^^ĂƉƐƚƌŝŶŐ .83$6DQGV Wdс ϭϭ͕Ϯϲϳ͛;DͿͬWdсϳ͕Ϯϲϵ͛;dsͿ ; ; ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬ,ͲϰϬͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚƌĐ͘ ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ ϲ͕Ϯϴϴ͛ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬDŽĚƚĐ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϭϭ͕ϯϱϬ͛ dh/E'd/> ϮͲϳͬϴΗ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϰϰϭ ^ƵƌĨĂĐĞ ϭϬ͕ϴϵϮ͛ ϯͬϴ͟ ĂƉ^ƚƌŝŶŐ ^ƚĂŝŶůĞƐƐ^ƚĞĞů Eͬ ^ƵƌĨĂĐĞ ϭϬ͕ϴϵϮ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ ϭϳϬ͛ ϮͲϳͬϴ͟ǆϭ͟<DD'>Dǁͬs^ĞƚϭͬϭϯͬϮϬϮϬ Ϯ ϭϬ͕ϲϳϰ͛ ϮͲϳͬϴ͟ǆϭ͟<DD'>DǁͬKƉĞŶWŽĐŬĞƚϮͬϭϬͬϮϬϮϬ ϯ ϭϬϴϭϱ͛ ϮͲϳͬϴ͟,^yEͲEŝƉƉůĞ;Ϯ͘ϮϬϱEŽͲŐŽ/Ϳ ϰ ϭϬ͕ϴϴϮϲ͘ϳ͛ ϮͲϳͬϴ͟'W/^ŝƐĐŚĂƌŐĞ,ĞĂĚhϴƌĚ ϱ ϭϬ͕ϴϮϳ͛ WƵŵƉ^yϭϯϳͲWϭϳ ϲ ϭϬ͕ϴϰϲ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ'^d,ssy,ϲ ϳ ϭϬ͕ϴϱϮ͛ dĂŶĚĞŵ^ĞĂů^ĞĐƚŝŽŶʹ'^ϯhd^ͬ^W&^Θ'^ϯ>d^ͬ^W&^>ϱ ϴ ϭϬ͕ϴϲϱ͛ DŽƚŽƌʹ<D,ϮϭϬŚƉ͕Ϯ͕ϭϰϱǀŽůƚƐĂŶĚϱϵĂŵƉƐ ϵ ϭϬ͕ϴϴϵ͛ WŚŽĞŶŝǆ^ĞŶƐŽƌydϭϱϬ ϭϬ ϭϬ͕ϴϵϬ͛ ϲ&ŝŶĞŶƚƌĂůŝǌĞƌʹŽƚƚŽŵΛϭϬ͕ϴϵϮ͛ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉ͘^ĂŶĚƐ ϭϬ͕ϵϯϳ͛ ϭϬ͕ϵϱϭ͛ ϲ͕ϵϰϵ͛ ϲ͕ϵϲϮ ϭϰ ϳͬϭϵͬϭϵϵϳ KƉĞŶ <ƵƉ͘^ĂŶĚƐ ϭϬ͕ϵϱϱ͛ ϭϬ͕ϵϳϱ͛ ϲ͕ϵϲϲ͛ ϲ͕ϵϴϲ͛ ϮϬ ϳͬϭϮͬϭϵϵϳ KƉĞŶ <ƵƉ͘^ĂŶĚƐ ϭϬ͕ϵϳϵ͛ ϭϭ͕ϬϬϳ͛ ϲ͕ϵϴϵ͛ ϳ͕Ϭϭϳ͛ Ϯϴ ϳͬϭϵͬϭϵϵϳ KƉĞŶ KWE,K>ͬDEdd/> ϮϬΗ ŵƚǁͬϮϱϬƐŬƐŽĨƌĐƚŝĐƐĞƚ/ŝŶϮϰ͟,ŽůĞ ϵͲϱͬϴΗ ŵƚǁͬϭ͕ϳϲϱƐŬƐW&͕͟͞ϱϬϬƐǆůĂƐƐ͞'͟ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ŵƚǁͬϮϰϬƐŬƐůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϯϱϬ͛ DĂǆ,ŽůĞŶŐůĞсϲϱƚŽϲϳĚĞŐ͘Ĩͬϯ͕ϵϬϬ͛ƚŽϴ͕ϴϬϬ͛ ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϭϰĚĞŐ͘EŽ>^ग़ϰĚĞŐͬ͘ϭϬϬ͛ dZΘt>>, dƌĞĞ ϱD/tϮͲϵͬϭϲ͟ tĞůůŚĞĂĚ ϭϭ͟ǆϳͲϭͬϭϲ͟ϱD&D'ĞŶϱ͕ǁͬϮͲϳͬϴ͟&DdďŐ͘,ŶŐƌ͘ dďŐ,ŶŐƌ ϯ͟>,DŽŶƚŽƉĂŶĚϮͲϳͬϴ͟hϴƌĚŽŶďŽƚƚŽŵ͕Ϯ͘ϱ͟/tWsWƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϳϳϯͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϮϮͲϲͬϭϵͬϭϵϵϳ /ŶŝƚŝĂůWĞƌĨŽƌĂƚŝŽŶƐʹϳͬϭϭͬϭϵϵϳ ^WZtKǁͬEĂďŽƌƐϱ^ʹϯͬϲͬϭϵϵϴ ^WZtKǁͬEĂďŽƌƐϰͲ^ʹϯͬϮϯͬϭϵϵϴ ^WZtKǁͬEĂďŽƌƐϰͲ^ʹϲͬϭϵͬϭϵϵϵ ^WZtKǁͬEĂďŽƌƐϰͲ^ʹϭϭͬϭϭͬϭϵϵϵ ^WZtKǁͬEĂďŽƌƐϰͲ^ʹϭϭͬϭϱͬϮϬϬϮ ^WZtKǁͬEĂďŽƌƐϰͲ^ʹϴͬϮϴͬϮϬϬϴ ^WZtKǁͬEŽƌĚŝĐϯʹϰͬϭϭͬϮϬϭϱ ^d/Dh>d/KE^hDDZz &ƌĂĐʹϭϬϰ͕ϬϲϲηŽĨϭϲͬϮϬĐĂƌďŽůŝƚĞďĞŚŝŶĚƉŝƉĞ͘ &ƌĂĐǁĂƐĚĞƐŝŐŶĞĚĨŽƌϭϱϵ͕ϬϬϬηͲϳͬϭϱͬϭϵϵϳ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϮͬϭϭͬϮϬϮϬ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW&ͲϬϵ >ĂƐƚŽŵƉůĞƚĞĚ͗ϰͬϭϭͬϮϬϭϱ Wd͗ϭϵϳͲϭϬϰ dсϭϭ͕ϯϵϬ;DͿͬdсϳ͕ϯϴϵ;dsͿ ϮϬ´ 7ZR´[¶ 0DUNHU -RLQWVIURP¶ WR¶ KƌŝŐ͘&ůĞǀ͗͘Ϯϵ͛ͬKƌŝŐ͘'>ůĞǀ͗͘Ϯϰ͘ϳ͛ &ƚŽϳ͟ĂƐŝŶŐ,ĂŶŐĞƌсϯϬ͘ϰ͛;EĂďŽƌƐϮϮͿ ϳ͟ ϵͲϱͬϴ ͟ .83$6DQGV Wdс ϭϭ͕Ϯϲϳ͛ ;DͿͬWdсϳ͕Ϯϲϵ͛;dsͿ ; ; ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬ,ͲϰϬͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚƌĐ͘ ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ ϲ͕Ϯϴϴ͛ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬDŽĚƚĐ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϭϭ͕ϯϱϬ͛ dh/E'd/> ϮͲϳͬϴΗ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϰϰϭ ^ƵƌĨĂĐĞ цϭϬ͕ϴϵϮ͛ ϯͬϴ͟ ĂƉƐƚƌŝŶŐ ^ƚĂŝŶůĞƐƐ^ƚĞĞů Eͬ ^ƵƌĨĂĐĞ цϭϬ͕ϴϵϮ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ цϭϵϬ͛'>Dηϭ͗ϮͲϳͬϴ͟ǆϭ͟<DD'>D ǁͬϬ͘Ϯϱ͟Ks Ϯ цϭϬ͕ϲϱϱ͛'>DηϮ͗ϮͲϳͬϴ͟ǆϭ͟<DD'>D ǁͬƵŵŵǇsĂůǀĞ ϯ цϭϬ͕ϳϲϬ͛ ϮͲϳͬϴ͟yEͲEŝƉƉůĞ;Ϯ͘ϮϬϱEŽͲŐŽ/Ϳ ϰ цϭϬ͕ϴϬϬ͛ ϮͲϳͬϴ͟ŝƐĐŚĂƌŐĞ,ĞĂĚ ϱ цϭϬ͕ϴϬϱ WƵŵƉ͗ϭϯϳ^ƚĂŐĞWϭϳ^y ϲ цϭϬ͕ϴϮϱ͛ WƵŵƉ͗ϮϬ^ƚĂŐĞ'/EW^,,^y ϳ цϭϬ͕ϴϰϱ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ ϴ цϭϬ͕ϴϱϱ͛ dĂŶĚĞŵ^ĞĂů^ĞĐƚŝŽŶ ϵ цϭϬ͕ϴϳϬ͛ DŽƚŽƌʹϮϬϬ,W ϭϬ цϭϬ͕ϴϴϱ͛ ^ĞŶƐŽƌ ϭϭ цϭϬ͕ϴϵϬ͛ ^WĞŶƚƌĂůŝǌĞƌ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉ͘^ĂŶĚƐ ϭϬ͕ϵϯϳ͛ ϭϬ͕ϵϱϭ͛ ϲ͕ϵϰϵ͛ ϲ͕ϵϲϮ ϭϰ ϳͬϭϵͬϭϵϵϳ KƉĞŶ <ƵƉ͘^ĂŶĚƐ ϭϬ͕ϵϱϱ͛ ϭϬ͕ϵϳϱ͛ ϲ͕ϵϲϲ͛ ϲ͕ϵϴϲ͛ ϮϬ ϳͬϭϮͬϭϵϵϳ KƉĞŶ <ƵƉ͘^ĂŶĚƐ ϭϬ͕ϵϳϵ͛ ϭϭ͕ϬϬϳ͛ ϲ͕ϵϴϵ͛ ϳ͕Ϭϭϳ͛ Ϯϴ ϳͬϭϵͬϭϵϵϳ KƉĞŶ KWE,K>ͬDEdd/> ϮϬΗ ŵƚǁͬϮϱϬƐŬƐŽĨƌĐƚŝĐƐĞƚ/ŝŶϮϰ͟,ŽůĞ ϵͲϱͬϴΗ ŵƚǁͬϭ͕ϳϲϱƐŬƐW&͕͟͞ϱϬϬƐǆůĂƐƐ͞'͟ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ŵƚǁͬϮϰϬƐŬƐůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϯϱϬ͛ DĂǆ,ŽůĞŶŐůĞсϲϱƚŽϲϳĚĞŐ͘Ĩͬϯ͕ϵϬϬ͛ƚŽϴ͕ϴϬϬ͛ ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϭϰĚĞŐ͘EŽ>^ग़ϰĚĞŐͬ͘ϭϬϬ͛ dZΘt>>, dƌĞĞ ϱD/tϮͲϵͬϭϲ͟ tĞůůŚĞĂĚ ϭϭ͟ǆϳͲϭͬϭϲ͟ϱD&D'ĞŶϱ͕ǁͬϮͲϳͬϴ͟&DdďŐ͘,ŶŐƌ͘ dďŐ,ŶŐƌ ϯ͟>,DŽŶƚŽƉĂŶĚϮͲϳͬϴ͟hϴƌĚŽŶďŽƚƚŽŵ͕Ϯ͘ϱ͟/tWsWƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϳϳϯͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϮϮͲϲͬϭϵͬϭϵϵϳ /ŶŝƚŝĂůWĞƌĨŽƌĂƚŝŽŶƐʹϳͬϭϭͬϭϵϵϳ ^WZtKǁͬEĂďŽƌƐϱ^ʹϯͬϲͬϭϵϵϴ ^WZtKǁͬEĂďŽƌƐϰͲ^ʹϯͬϮϯͬϭϵϵϴ ^WZtKǁͬEĂďŽƌƐϰͲ^ʹϲͬϭϵͬϭϵϵϵ ^WZtKǁͬEĂďŽƌƐϰͲ^ʹϭϭͬϭϭͬϭϵϵϵ ^WZtKǁͬEĂďŽƌƐϰͲ^ʹϭϭͬϭϱͬϮϬϬϮ ^WZtKǁͬEĂďŽƌƐϰͲ^ʹϴͬϮϴͬϮϬϬϴ ^WZtKǁͬEŽƌĚŝĐϯʹϰͬϭϭͬϮϬϭϱ ^d/Dh>d/KE^hDDZz &ƌĂĐʹϭϬϰ͕ϬϲϲηŽĨϭϲͬϮϬĐĂƌďŽůŝƚĞďĞŚŝŶĚƉŝƉĞ͘ &ƌĂĐǁĂƐĚĞƐŝŐŶĞĚĨŽƌϭϱϵ͕ϬϬϬηͲϳͬϭϱͬϭϵϵϳ @ 0LOQH3RLQW 'R\RQ ´%236WDFN Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 09/18/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-09 (197-104) Multi Finger Caliper Log 02/04/2020 ANALYSIS FIELD DATA Please include current contact information if different from above. PTD: 1971040 E-Set: 33960 Received by the AOGCC 09/18/2020 Abby Bell 09/21/2020 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU F-09 Permit to Drill Number: 197-104 Sundry Number: 320-075 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Je rice Chair DATED this Aay of February, 2020. '3BDMS L11'^' FEB 14 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 RECEIVE® FEB 1 2020 O rs 2 19( 2a A0 CC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 2r Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change -out ❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development / Q Stratigraphic ❑ Service ❑ 197-104 , 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-22773-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D ' Will planned perforations require a spacing exception? Yes ❑ No MILNE PT UNIT F-09 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0388235*-ftpLcoZffg42q Milne Point Field / Kuparuk River 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): 11,390' 7,389' 11,267' 7,269' 1,582 WA WA Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' 1,490psi 470psi Surface 6,288' 9-5/8" 6,288' 4,305' 5,750psi 3,090psi Production 11,350' 7" 11,350' 7,350' 7,240psi 5,410psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 2-7/8" 6.5#/ L-80/ EUE 8 10,892' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A and N/A N/A and N/A 12. Attachments: Proposal Summary v Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑D Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/5/2020 OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: David Haakinson / Authorized Title: Operations Manager Contact Email: dhaakinson hll f om Contact Phone: 777-8343 Authorized Signature: Date: 2/11/2020 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: O ` Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Q G .rs Other: S��6 $ 80 i fe ABDMS�96--' FEB 2 4 2020 Post Initial Injection MIT Req'd? Yes ❑ No �,/ I y Spacing Exception Required? Yes ❑ No F Subsequent Form Required: G D — Y O APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: ' cl/yt< a—«-� (evR � Submit Form and Form 10-400 iud 4/2017 Approved applicatlo Is a i fo 2 RM, a date of approval. Attachments in Duplicate U flile.m Alaska, LG ESP Change -Out Well: MPU F-09 Date:02/11/2020 Well Name: MPU F-09 API Number: 50-029-22773-00 Current Status: Shut-in ESP Producer Pad: F -Pa Estimated Start Date: March 5th, 2020 Rig: Reg. Approval Req'd? Yes Date Reg. ApprovaRegulatory Contact: Tom Fouts Permit to Drill NuFirst Call Engineer: David Haakinson (907) 777-8343 (O4999 MReclvd: (M) Second Call Engineer: Wyatt Rivard (907) 777-8434 (08001 (M)AFE Number: 2050917 Job Type: Current Bottom Hole Pressure: Maximum Expected BHP: MPSP: Max Inclination Max Dogleg: BPV Profile: 2,526 psi @ 7,000' TVD 2,700 psi @ 7,000' TVD 1,582 psi 67° @ 6,800' to 7,200' MD 4.6°/100ft @ 7,260' MD 3" CIW Type H SBHP Survey (2/4/2020) 16.94 PPG PBU Extrapolation 17.42 PPG Gas Column Gradient (0.1 psi/ft) Brief Well Summary: MPU producer F-09 well was drilled, perforated, and fractured as a Kuparuk A -sand producer in June 1997. The well has had a total of six ESP rig workovers in its history with the last occurring in 2015. The average run life of the last three pumps was 5.8 years. The well has historically been known for it's scale deposition and locking of the pump shafts. The producer was shut-in on 01/12/2020 after an apparent motor shaft break. Notes Regarding Wellbore Condition • The 7" production casing passed an MIT to 1,500 psig on 4/9/15. o The test packer was set at 10,500' MD. Supporting Injectors: o F-13: Online, Injecting 1,100 BWPD. Well supports F-25, F-87, and L-28. o F-84: Shut in. Objective: • Pull 2-7/8" Tubing String, P17 ESP, and motor. • Install new Baker Hughes 200 HP motor, 137 -stage P17 ESP, and re -run 2-7/8" tubing. Pre -Rig Procedure: 1. RU LRS and PT lines to 3000 psi. 2. Order heated kill fluid to location. 3. Circulate 384 bbls of Heated 8.3 ppg source -water down tubing attempting to take returns up IA. a. If unable to gain returns, pump 62 bills of heated 8.3 ppg source water down tubing followed by 331 bbls of Heated 8.3 ppg source water down IA to formation. 4. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 5. RD Little Red Services. 6. Clear and level pad area in front of well. Spot rig mats and containment. 7. RD well house and flowlines. Clear and level area around well. N ]Iilcara Alaska, LG ESP Change -Out Well: MPU F-09 Date:02/11/2020 8. RU crane. Set BPV. ND Tree. Inspect the tubing hanger lift thread and note any damage. 9. NU BOPE. RD Crane. 10. NU BOPE house. Spot mud boat. Brief RWO Procedure: 11. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. 12. If needed, bleed off any residual pressure off the IA. Check for pressure and if 0 psi, pull BPV. If needed, kill well w/ 8.3 ppg source -water prior to pulling BPV. 13. Set TWC. 14. Test BOPE to 250 psi Low/ 2.500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 15. Contin,"n : If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. Jb. 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. 16. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/ 8.3 ppg source -water as needed. 17. Rig up spoolers for ESP #2 cable and 3/8" capillary tubing. a. Baker Hughes representative should be onsite for ESP pull. 18. MU landing joint or spear, BOLDS and PU on the tubing hanger. a. The PU weight = 126K and SO = 72K when landed by Nordic 3 with block weight of 65 b. If needed, circulate (long or reverse) pill with lubricant, source -water, and/or baraclean pill prior to laying down the tubing hanger. 19. Recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. H Hilmru Alaska, LL ESP Change -Out Well: MPU F-09 Date:02/11/2020 a. Evaluate pulled tubing hanger for possible damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. 20. POOH and lay down the 2-7/8" tubing spooling ESP cable. Lay down ESP and motor. a. Plan to dispose of the following joints and any other known damaged tubulars: i. Joints 12,59, and 103 ii. Send damaged tubing to G&I for washing and disposal. b. Note any sand or scale inside or on the outside of the ESP on the morning report. c. Look for over -torqued connections from previous tubing runs. d. The completion has the following amount of clamps/guards/cap-string: i. 177 Cannon Clamps ii. 4 LaSalle clamps iii. 1 Flat -Guard iv. 1 Armsterguard v. 3 Pump Protectolizers vi. 1 Motor Protectolizer vii. 10,957' of 3/8" capillary tubing. 1. Capillary String will not be re -run. e. Plan to run tubulars to same depth at which they were pulled. Shallow joints should be shallow on install. 21. PU new ESP and RIH on 2-7/8" 6.5# L-80 tubing. Set base of ESP assembly at± 10,890' MD. a. Base of ESP centralizer @ ± 10,890' MD �1 b. Motorgauge c. 200 HP Baker Hughes 562SP Motor d. Gas Separator e. Baker Hughes 20 stage GINPSH ESP f. Baker Hughes 137 stage P17 ESP g. Downhole gauge for discharge temperature and pressure. i. Connected with a jumper from the lower sensor. Does not require a separate tech -wire. h. 1 joint of 2-7/8", 6.5#, L-80, EUE 8rd tubing i. 2-7/8" XN (2.205" No -Go) Nipple j. 3 joints of 2-7/8", 6.5#, L-80, EUE 8rd tubing k. Lower 2-7/8"x 1" Side -pocket GLM with Dummy GLV I. ± 336joints 2-7/8", 6.5#, L-80, EUE 8rd tubing m. Upper 2-7/8"x 1" Side -pocket GLM @ ± 200' MD with 0.25" OV n. ± 4 joints 2-7/8", 6.5#, L-80, EUE 8rd tubing 22. PU and MU the tubing hanger with landing joint. 23. Land the tubing hanger and RILDS. Lay down landing joint. Note slack -off weight on tally. 24. Set TWC. 25. RDMO ASR. ESP Change -Out Well: MPU E-09 na �oai k,,LL Date:02/11/2020 Post -Rig Procedure: 26. RD mud boat. RD ROPE house. Move to next well location. 27. RU crane. ND ROPE. 28. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 29. Pull TWC. 30. RD crane. Move returns tank and rig mats to next well location. 31. Replace gauge(s) if removed. 32. Turn well over to production. RU well house and flowlines. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic Orig. DF Elev.: 29'/ Ong. GL Elev.: 24.7 TD = 11,390(MD) / TD= 7,389(ND) PBTD=11,267' (MD) / PBTD = 7,26Y(TVD) SCHEMATIC Milne Point Unit Well: MP F-09 Last Completed: 4/11/2015 PTD: 197-104 TREE & WELLHEAD Tree SM CIW 2-9/16" Wellhead 11" x 7-1/16" 510 FMC Gen 5A, w/ 2-7/8" FMC Tbg. Hngr. Tbg Hngr 3" LH ACME on top and 2-7/8" EU 8rd on bottom, 2.5" CIW BPV Profile OPEN HOLE / CEMENT DETAIL 2 0" Cmt w/ 250 sks of Arcticset I in 24" Hole 9 0" Cmt w/ 1,765 sks PF 00 sx Class "G" in 12-1/4" Hole 7" Cmt w/ 240 sks Class "G" in 8-1/2" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surface 112' 9-5/8" Surface 40/L-80/B[rc. 8.835 Surface 6,288' 7" Production 26/ L-80/ Mod Bic 6.276 Surface 11,350' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUESrd 2.441 Surface 10,892' 3/8" Cap String Stainless Steel N/A Surfare in_R9T WELL INCLINATION DETAIL KOP @ 350' MaxHole Angle = 65 to 67 deg. f/ 3,900' to 8,800' Hole Angle through perforations =14 deg. No DIS >4 deg./ 100' JEWELRY DETAIL No Depth Item 1 170' 2-7/8" x 1" KBMM GLM w/ DV Set 1/13/2020 2 10,674' 2-7/8" x 1" KBMM GLM w/ Open Pocket 2/10/2020 3 10815' 2-7/8" HES XN-Nipple (2.205 No-go ID) 4 10,8826.7' 2-7/8" GPDIS Discharge Head EUE 8rd 5 10,827' Pump SXD 137-P17 6 10,846' Gas Separator GSTHVVX H6 7 10,852' Tandem Seal Section -GSB3DBUT SB/SB PFSA &GSB3DBLT SB/SB PFSA CL5 8 10,865' Motor- KMH 230hp, 2,145 volts and 59 amps 9-1 10,889' Phoenix Sensor XT150 10 10,890' 6 Fin Centralizer - Bottom @ 10,892' STIMULATION SUMMARY Frac -104,066tt of 16/20 carbolate behind pipe. Frac was designed for 159,000# - 7/15/1997 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status ip. A Sands 10,937' 10,951' 1 6,949' 6,962 14 1 7/19/1997 Open ip. A Sands 10,955' 10,975' 6,966' 6,986' 20 7/12/1997 Open p. A Sands 10,979' 11,007' 6,989' 7,017' 28 7/19/1997 Open GENERAL WELL INFO API: 50-029-22773-00-00 Drilled and Cased by Nabors 22E - 6/19/1997 Initial Perforations -7/11/1997 ESPR WO w/ Nabors 5S-3/6/1998 ESP RWO w/ Nabors 4 -ES -3/23/1998 ESP RWO w/ Nabors 4 -ES -6/19/1999 ESP RWO w/ Nabors 4 -ES -11/11/1999 ESP RWO w/ Nabors 4 -ES -11/15/2002 ESP RWO w/ Nabors 4 -ES - 8/28/2008 ESP RWO w/ Nordic 3-4/11/2015 Revised By: DAH 2/11/2020 K cars Alaska. LLC Orig. DF Elev.: 29/ Orig. GL Elev.: 24.7 TD=11,390(MD) /TD= 7,3&%TVD) PBTD=11,267 (MD) / PBTD= 7,269MM) Milne Point Unit Well: MP F-09 PROPOSED SCHEMATIC Last Completed: 4/11/2015 PTD: 197-104 TREE & WELLHEAD Tree SM CIW 2-9/16" ellhead W 11" x 7-1/16" 5M FMC Gen 5A, w/ 2-7/8" FMC Tbg. Hngr. Tbg Hngr 3" LH ACME on top and 2-7/8" EU 8rd on bottom, 2.5" CIW BPV Profile OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24" Hole 9-5/8" Cmt w/ 1,765 sks PF "E",500 sx Class "G" in 12-1/4" Hole 7" 1 Cmt w/ 240 sks Class "G" in 8-1/2" Hole CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surface 112' 9-5/8" Surface 40/L-80/Btrc. 8.835 Surface 6,288' 7" Production 1 26/L-80/Mod Btc 6.276 Surface 11,350' TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 10,892' WELL INCLINATION DETAIL KOP@ 350' Max Hole Angle = 65 to 67 deg. f/ 3,900' to 8,800' Hole Angle through perforations =14 deg. No DLS >4 deg./ 100' JEWELRY DETAIL No Depth Item 1 ±190' GLM #1: 2-7/8" x 1" KBMM GLM w/ 0.25" OV 2 ±10,655' GLM #2: 2-7/8" x 1" KBMM GLM w/ Dummy Valve 3 ±10,760' 2-7/8" XN-Nipple (2.205 No-go ID) 4 710,800' 2-7/8" Discharge Head 5 ±10,805 Pump: 137 Stage P17SXD 6 ±10,825' Pump: 20 Stage GINPSHHSXD 7 ±10,845' Gas Separator 8 ±10,855' Tandem Seal Section 9±10,874 7,017' Motor -200 HP 30 ±10,885' Sensor 11 ±10,890' ESP Centralizer STIMULATION SUMMARY Frac —104,066# of 16/20 carbolite behind pipe. Frac was designed for 159,000# - 7/15/1997 PERFORATION DETAIL nds Top (MD) Btm (MD) Top (ND) Btm (ND) FT Date Status 45ands 10,937' 10,951' 1 6,949' 1 6,962 1 14 1 7/19/1997 1 Open 4 Sands10,955' 975' 10,11,007' 6,966' 6,986' 20 7/12/1997 Open 4 Sands 30,979' 6,989' 7,017' 28 7/19/1997 Open GENERAL WELL INFO API: 50-029-22773-00-00 Drilled and Cased by Nabors 22E - 6/19/1997 Initial Perforations -7/11/1997 ESPR WO w/ Nabors 5S-3/6/1998 ESP RWO w/ Nabors 4 -ES -3/23/1998 ESP RWO w/ Nabors 4 -ES -6/19/1999 ESP RWO w/ Nabors 4 -ES —11/11/1999 ESP RWO w/ Nabors 4 -ES -11/15/2002 ESP RWO w/ Nabors 4 -ES -8/28/20D8 ESP RWO w/ Nordic 3 — 4/11/2015 Revised By: DAH 2/11/2020 11" BOPE Milne Point ASR Rig 1 BOPE 2019 Stripping Head 4.54' 8--�N I `'' u I I S 2-7/8" x 5" VBR 2 1/16 51V Kill Line Valves 2 1/16 5M Choke Line Valves HCR Manual Ma ual HCR Updated 5/14/2018 RECEIVED STATE OF ALASKA AL,- KA OIL AND GAS CONSERVATION COMh,1.,SION MAY 18 2015 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing L] Operations shutdown Li 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 El Exploratory ❑ 197-104 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22773-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0388235 MILNE PT UNIT KR F-09 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 11,390 feet Plugs measured N/A feet true vertical 7,389 feet Junk measured N/A feet Effective Depth measured 11,267 feet Packer measured N/A feet true vertical 7,269 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1,490psi 470psi Surface 6,288' 9-5/8" 6,288' 4,305' 5,750psi 3,090psi Intermediate ,.. __. ,. .. .- , ___._.. Production 11,350' 7" 11,350' 7,350' 7,240psi 5,410psi Liner Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet SEWED ;U N 0 1 2 15 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 10,892 6905 Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A • ` . - Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 164 60 1,171 260 _ 227 Subsequent to operation: 175 96 1,347 280 242 14.Attachments(required per 20 AAC 25 070,25.071,&25 283) 15.Well Class after work: Daily Report of Well Operations LI Exploratory❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Chris Kanyer Email ckanver C/.hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature 7 — _ --"4 ' Phone 777-8377 Date 5/15/2015 5-2t -/5 RBDMS d v" 1 9 2015 Form 10-404 Revised 5/2015 4 5'40f' Submit Original Only Milne Point Unit Well: MP F-09 14 SCHEMATIC Last Completed: 8/28/2008 Hilcorp Alaska,LLC PTD: 197-104 CASING DETAIL Orig.DF Elev.:29'/Orig.GL Elev.:24.7' Size Type Wt/Grade/Conn ID Top Btm DF to 7'Casing Hanger=30.4'(Nabors 22E) . rLI 20" Conductor 91.1/H-40/N/A N/A Surface 112' 20"j ti, 9-5/8" Surface 40/L-80/Btrc. 8.835 Surface 6,288' o. t• 7" Production 26/L-80/Mod Btc 6.276 Surface 11,350' ill'i 1 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 10,892' 3/8" Cap String Stainless Steel N/A Surface 10,892' JEWELRY DETAIL No Depth Item 1 170' 2-7/8"x 1"KBMM GLM w/DPSOV 9-5/8' 4 k 2 10,674' 2-7/8"x 1"KBMM GLM w/DGLV 3 10815' 2-7/8"HES XN-Nipple(2.205 No-go ID) 4 10,8826.7' 2-7/8"GPDIS Discharge Head EUE 8rd 5 10,827' Pump SXD 137-P17 6 10,846' Gas Separator GSTHVVX H6 7 10,852' Tandem Seal Section-GSB3DBUT SB/SB PFSA &GSB3DBLT SB/SB PFSA CL5 3/8"SS Capstring 8 10,865' Motor-KMH 210hp,2,145 volts and 59 amps 9 10,889' Phoenix Sensor XT150 10 10,890' 6 Fin Centralizer-Bottom @ 10,892' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.A Sands 10,937' 10,951' 6,949' 6,962 14 7/19/1997 Open Kup.A Sands 10,955' 10,975' 6,966' 6,986' 20 7/12/1997 Open 1 Kup.A Sands 10,979' 11,007' 6,989' 7,017' 28 7/19/1997 Open WELL INCLINATION DETAIL 111( KOP @ 350' Max Hole Angle=65 to 67 deg.f/ 3,900'to 8,800' Hole Angle through perforations=14 deg. No DLS>4 deg./100' OPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sks of Arcticset I in 24"Hole 9-5/8" Cmt w/1,765 sks PF"E",500 sx Class"G"in 12-1/4"Hole .1 i 7" Cmt w/240 sks Class"G"in 8-1/2"Hole 14 2 to TREE&WELLHEAD 1, ,, Tree 5M CIW 2-9/16" tr i 3 1 Wellhead 11"x 7-1/16"5M FMC Gen 5A,w/2-7/8"FMC Tbg.Hngr. ,, Tbg Hngr 3"LH ACME on top and 2-7/8"EU 8rd on bottom,2.5"CIW BPV Profile 41 all:; IB t'4 GENERAL WELL INFO 1.� ry,5 API:50-029-22773-00-00 j Drilled and Cased by Nabors 22E -6/19/1997 6 Initial Perforations-7/11/1997 TJoints or m 0,821' - .4 ESPR WO w/Nabors 5S-3/6/1998 lointsfrom10,821' A V to 10,863' i; In 3.7 ESP RWO w/Nabors 4-ES-3/23/1998 ESP RWO w/Nabors 4-ES-6/19/1999 s' a ESP RWO w/Nabors 4-ES-11/11/1999 .:8 ESP RWO w/Nabors 4-ES-11/15/2002 ',1l Mr ESP RWO w/Nabors 4-ES-8/28/2008 s t: II1 ', STIMULATION SUMMARY 4:3 10Frac-104,066#of 16/20 carbolite behind pipe. Frac was designed for 159,000#-7/15/1997 KLP A Sands i4 Y 6- TD=11,390(MD)/TD=7,389(1VD) PBTD=11,267(MD)/PBTD=7,269'(TVD) Revised By:TDF 5/15/2015 Hilcorp Alaska, LLC E,il,.,,,.,,Alaska,IAA: Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP F-09 50-029-22773-00-00 197-104 4/8/2015 4/11/2015 Daily Operations: 4/8/15-Wednesday MIRU.Accept rig.Spot tanks, berm cellar, MU hardline to kill tanks. Pull BPV,RU hoses and spotted cutting box. Loaded pit w/hot seawater,tested lines to 3,000psi-test ok.SITP 00i SICP 500psi,bled csg down to Upsi,started pumping hot seawater down tbg @ 3bpm and broke circ.at 55 bbbls.Continued circ. kill fliud with returns clean,SD pump,well on vac.Off loaded 3rd truck to pits and released truck.453 bbls pumped, 254 bbls returned, 199 bbls lost. Blew lines dry and disconnected from well,set the BPV and NU PT/NU BOP's and connected lines. Filled stack and performed shell test 250psi low/3,000psi high. One failure recorded, bonnet leaked on manifold choke valve#12. Replaced valve and re- tested ok.AOGCC witnessed BOPE test,annular 250psi low/2,500psi high,Valves 250psi IowJ3,000psi,high,rams 250psi low/3,000psi high, held and charted 5 mpt,gas detection and kommey drawdown-1 F/P recorded on manifold valve #6,greased and function valve-Test ok. Preped rig to POOH w/completion,opened csg pulled TWC and backed out lockdown pins. MU landing jt and pulled tbg hanger. Up weight 85k with 5k to10k drag. L/D tbg hanger. 4/9/15-Thursday Continued to POOH w/completion string and spooling cable.Tallied OOH, L/D GSM,xn nipple,1 jt pin end cross threaded, 2 jts bent.All other tbg looked ok.Off loaded new ESP equipment in pipe shed.Inspected and LD ESP, pump section froze up internal part damage.OD of ESP was clean, no soilds or trash in or around intake. PJSM. PU MU test pkr,TIH to 10,500'.Set pkr and tested csg to 1,500psi charted for 30 mins-test good. itelased prk TIH to 10,900' rev cir bottoms up no solids in returns.With returns clean SD pumps.TOOH w/test pkr. 4/10/15-Friday Continue TOOH w/test pkr and LD.Slip and cut drill line, Prep rig floor to Run ESP completion. PU, MU and service new ESP assembly.Sting new cable and Cap string over sheave. Make motor and cap connection.Test all cap string,check break @ 3,400psi. RIH w/new ESP on 2-7/8"8rd L-80 tbg with XN nipple and lower GLM,continue RIH check cable and cap every 2,000'. Found 10'section of bad capillary 2 kinks repaired with union splice, RIH to 9,128'.Changed spool and made cable splice at 9,128'.Completed splice and test-ok. PU upper GLM,continue RIH with ESP completion to hanger depth 10,891'. Depths are as follows: Hanger, Pup,4 jts 2-7/8 L-80 6.5#tbg,pup,GLM @170',334 jts tbg, pup GLM @10,674',4 jts tbg,XN Nipple@ 10,815', pup. Head @ 10,827',gas separator @ 10,846',Tandem Seals @ 10,852', Motor @ 10,865', EOT Centralizer 10,890'. 4/11/15-Saturday PU landing joint. Install hanger and penetrators.Test cable and cap string. Cut and splice cable connector and cap string,install same. Meg check connector. Land string SW 126K up 72k down. Run in lock down screws. ND BOP/NU tree.Orient tree.Test all breaks and void 250psi low/5,000psi high. RDMO Nordic 3 Release Rig 4/12/15-Sunday No operations to report. 4/13/15-Monday No operations to report. 4/14/15-Tuesday No operations to report. Dti OF T�� dw,.\\\I VP/ THE STATE Alaska Oil and Gas �� -=>__ „s„..„--,-- O Conservation Commission _ -_---.--7-4w f LA Ic;A S _ . t{x �_ = 333 West Seventh Avenue \TM GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF4LAS Fa;,. 907 276.7542 www aogcc alaska gcv Chris Kanyer 0 9- Operations Engineer 4 v Hilcorp Alaska, LLC ` �� ' f 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR F-09 Sundry Number: 315-197 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, Daniel T. Seamount, Jr. Commissioner DATED this i day of April, 2015 Encl. RECEIVED STATE OF ALASKA a P R 0 2 2 015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑, Change Approved Program 0 Suspend, Plug Perforations ❑ Perforate❑ Pull Tubing 0 Time Extension 0 Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other: ESP Changeout ❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC - Exploratory ❑ Development 0 - 197-104 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22773-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.432C 7 Will planned perforations require a spacing exception? Yes ❑ No 0 / MILNE PT UNIT KR F-09 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0388235 ' Milne Point Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY ✓ Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11,390 • - 7,389 - 11,267 ' 7,269 - N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 112' 20" 112' 112' 1,490psi 470psi Surface 6,288' 9-5/8" 6,288' 4,305' 5,750psi 3,090psi Intermediate Production 11,350' 7" 11,350' 7,350' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 10,893' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): t'At N/A and N/A N/A dnd Ntfk Ste. SUek1 c 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development❑., - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 42015 Oil Q • Gas 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: .4-7-/S WINJ ❑ GINJ ❑ WAG ❑ Abandoned 0 Commission Representative: 44 S-c ,,- -1-Z— GSTOR ❑ SPLUG LI17.I hereby certify that the foregoing is t e and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyer@hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature Phone 777-8377 Date 4/2/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 316 -W-7 Plug Integrity ❑ BOP Test Ig Mechanical Integrity Test ❑ Location Clearance ❑ Other: • ZOOS� SW ( 44A-5 PG /0Z�,c° S_ / Spacing Exception Required? Yes ❑ No li Subsequent Form Required: / (J— Y(f-/ .---7"--7 APPROVED BY Approved by: 0 , COMMISSIONER THE COMMISSION Date: 9� i, v� IN's-1 I //''�� A �� m k 4/-21--/.6 Submit Form and Form 1 - 03(Revised 10/2012 Approved ap ication is v II f�r 2lrt10 h�N y�,date of approval. Attachments in Duplicate RBDMS APR — 9 Nd15 v4.,----- V //''''��Lam. Well Prognosis Well: MPF-09 Micas')Alaska,LL, Date:4/3/2015 Well Name: MPF-09 API Number: 50-029-22773-00-00 Current Status: SI Producer Pad: F Pad Estimated Start Date: April 9, 2015 Rig: Nordic 3 Reg.Approval Req'd? April 8, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 197-104 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: 1550914 Current Bottom Hole Pressure: —2,227 psi @ 7,000' TVD (Last BHP measured 5/4/2014) Maximum Expected BHP: —2, 227 psi @ 7,000' TVD (No new perfs being added) Max.Allowable Surface Pressure: 0 psi (Based on actual reservoir conditions and water cut of 86% (0.425psi/ft)with an added safety factor of 1000' TVD of oil cap) Brief Well Summary: The Milne Point F-09 well was drilled as a Kuparuk development well that TD'd at a depth of 11,390' and ran and cemented 7" production casing in June 1997. The well was perforated and frac'd in the Kuparuk A sands and initially completed with an ESP in August 1997.This and subsequent ESPs were replaced in 1998,June1999, November 1999, 2002, and 2008. The most recent casing pressure test was performed after cementing the 7" casing on 6/18/1997.The most recent pump died on March 23, 2015.The well has remained shut in ever since. A downhole chemical injection line will be run as part of the new completion, due to known scaling issues in this well. No subsidence issues are expected in this well. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issue suspected. `' RWO Objective: Pull ESP& run 2-7/8" ESP completion with downhole chemical injection. Brief Procedure: Pull ESP, run casing scraper, pressure test casing, & run 2-7/8" ESP completion with downhole chemical injection. 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.) . ii Well Prognosis Well: MPF-09 Hilcorp Alaska,LL Date:4/3/2015 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 G��,r'I normal test procedure(floor valves,gas detection, etc.) ( 1 f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ /144 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 10,893'to surface and lay down same. 6. RIH with 7"cleanout BHA to+/-10,900'. POOH with same. 7. RIH and set test packer at+/-10,500' (within 500ft of open perforations). 8. Perform a charted casing pressure test to 1,500psi for 30min. Bleed off pressure and POOH with same. 9. MU and RIH with ESP with gas separator and 3/8"chemical injection line on 2-7/8"8RD EUE L-80 tubing [to be replaced if necessary]. Set ESP at+/-10,893'. Land tubing hanger. 10. ND BOP, NU and tree. 11. RDMO workover rig and equipment. 12. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit Well: MP F-09 PROPOSED Last Completed: 8/28/2008 llilcurp Alaska,LLC PTD: 197-104 CASING DETAIL Orig.DF Elev.:29'/Orig.GL Elev.:24.7' DF to 7'Casing Hanger=30.4'(Nabors 22E) Size Type Wt/Grade/Conn ID Top Btm 20' Conductor 91.1/H-40/N/A N/A Surface 112' 2p►f I • a 9-5/8" Surface 40/L-80/Btrc. 8.835 Surface 6,288' 7" Production 26/L-80/Mod Btc 6.276 Surface 11,350' t TUBING DETAIL �� 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface ±10,893' 3/8" Cap String Stainless Steel N/A Surface ±10,893' < JEWELRY DETAIL No Depth Item1 ±170' 2-7/8"x 1"KBMM GLM w/DPSOV 9-5/g 2 ±10,683' 2-7/8"x 1"KBMM GLM w/DGLV 3 ±10794' 2-7/8"HES XN-Nipple(2.205 No-go ID) 4 ±10,834' 2-7/8"GPDIS Discharge Head EUE 8rd 5 ±10,835' Pump SXD 137-P17 6 ±10,854' Gas Separator GRSFTX AR HS(400 Internals) 7 ±10,859' Tandem Seal Section-GSB3DBUT SB/SB PFSA &GSB3DBLT SB/SB PFSA 3/8"SSCarstnng 8 ±10,873' Motor-KMH 190hp,2,415 volts and 48 amps 9 ±10,889' Pumpmate Sensor 10 ±10,891' 6 Fin Centralizer-Bottom @±10,893' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status Kup.A Sands 10,937' 10,951' 6,949' 6,962 14 7/19/1997 Open Kup.A Sands 10,955' 10,975' 6,966' 6,986' 20 7/12/1997 Open Kup.A Sands 10,979' 11,007' 6,989' 7,017' 28 7/19/1997 Open WELL INCLINATION DETAIL KOP @ 350' Max Hole Angle=65 to 67 deg.f/ 3,900'to 8,800' Hole Angle through perforations=14 deg. No DIS>4 deg./100' OPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sks of Arcticset I in 24"Hole 9-5/8" Cmt w/1,765 sks PF"E",500 sx Class"G"in 12-1/4"Hole <' 7" Cmt w/240 sks Class"G"in 8-1/2"Hole 's 2 TREE&WELLHEAD , ,• », Tree _ 5M CIW 2-9/16" 1 3 Wellhead 11"x 7-1/16"5M FMC Gen 5A,w/2-7/8"FMC Tbg.Hngr. IF. Tbg Hngr 3"LH ACME on top and 2-7/8"EU 8rd on bottom,2.5"CIW BPV Profile N.4 '..j. GENERAL WELL INFO A q,5 API:50-029-22773-00-00 1 Drilled and Cased by Nabors 22E -6/19/1997 T 7"x21'NFarka ;[- i'6 Initial Perforations-7/11/1997 Jantsfran 10,821' ESPR WO w/Nabors SS-3/6/1998 to 10,863 ` 7 ESP RWO w/Nabors 4-ES-3/23/1998 } iia ..'n i i\ ESP RWO w/Nabors 4-ES-6/19/1999 � ESP RWO w/Nabors 4-ES-11/11/1999 8 ESP RWO w/Nabors 4-ES- 1!. . ESP RWO w/Nabors 4-ES-8/28/2008 v g 'y I N I ,i STIMULATION SUMMARY +" 10 '4. � Frac-104,066#of 16/20 carbolite behind pipe. Frac was designed for 159,000#-7/15/1997 KLPASands i 7" 6.. TD=11,390(MD)/TD=7,389(TVD) PBTD=11,267'(MD)/PBTD=7,269'(1VD) Revised By:TDF 4/2/2008 11" BOP Stack r ‘ O O 111111 Hydril 11" 5M IIL°.-{a *IA Shaffer - 2 3/8" Rams .J. _OM C1210 11" 5M* 1 2 7/8-5.5— _ variables — Hydril a°10 11" 5M Blinds . *. e . Optional valve port cipiumil;i, ii; 1 1 /!?- C-it • AM. A t 1 1 iur,,,, , ) [t liri44: 1 I. i ' lie , , . , \„:„. ,, , rp * 0't /I 1 C ,J.J Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday,April 07, 2015 3:44 PM To: 'Chris Kanyer' Cc: Tom Fouts Subject: RE: MPF-09 10-403 API#50-029-22773-00-00 PTD#197-104 Chris, Your explanation for the short notice is understandable.You have verbal approval to move to F-pad to do the ESP swap on well F-09. I noted in your sundry application that this well needs a casing pressure test as it hasn't been tested since 1997. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guv.schwartz@alaska.gov). From: Chris Kanyer [mailto:ckanver@hilcorq.com] Sent:Tuesday,April 07, 2015 3:33 PM To: Schwartz, Guy L(DOA) Cc: Tom Fouts Subject: MPF-09 10-403 API#50-029-22773-00-00 PTD#197-104 Importance: High Guy, As discussed,we request verbal approval for the sundry submitted for the MPF-09(API#50-029-22773-00-00 PTD#197- 104) RWO.This ESP failed on March 23,2015. Due to the proximity to L pad,which we are currently on,we would like to make the shorter rig move and repair this well.We are also impaired by the road closures on the haul road,so we are trying to minimize diesel usage with the shorter move. We are also adding a single ram to our BOP stack(see attached schematic)on this and future wells.This will aid in our stack height issues and give more flexibility to run a 2-3/8"work string when we are on wells that need liner cleanouts. This will not be necessary on MPF-09, but we are taking the opportunity to add it prior to our rig move.This configuration was already part of our earlier sundry submittal. Please let me know if you have any questions. Chris Kanyer I Operations Engineer Ililrnrh tlie.ka.1.T.(, ckanyer@hilcorp.com 1 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. File Number of Well History File PAGES TO DELETE Complete RESCAN n Color items - Pages: GraYScale, halftones, pictures, graphs, charts- Pages: Poor Quality Odginal- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type -OVERSIZED .Logs of vadous kinds Other COMMENTS: Scanned by: ~~~"-"~- D'are~ Nalflan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: /s/ • i bp BP Exploration (Alaska) Inc. h ° Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 SLANNEn December 30, 2011 FED 1 7 2WWa 1q7/L/ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission i 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator . 0 I BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 102 N/A 122.4 8/72011 MPF -02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 13 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 WA 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 18 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top job MPF -34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 02 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF -45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NA/ 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF-69 1951250 50029225860000 0.8 N/A 08 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF -81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF -83 2000930 50029229630000 12 N/A 1.2 N/A 13.6 8/3/2011 MPF -84B 2001760 50029229310200 1.2 N/A 12 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 12 N/A 10.2 8/32011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 WA 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 - STATE OF ALASKA ArASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS y~G~ 8 1. Operations Performed: ~~ ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 197-104 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22773-00-00 - 7. KB Elevation (ft): 41 00 ~ 9. Well Name and Number: . MPF-09 8. Property Designation: 10. Field /Pool(s): , ADL 388235 ~ Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 11390 - feet true vertical 7389 ~ feet Plugs (measured) None Effective depth: measured 11267 feet Junk (measured) None true vertical 7269 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1490 470 Surface 6256' 9-5/8" 6288' 4305' 5750 3090 Intermediate Production 11320' 7" 11350' 7350' 7240 5410 Liner o~'cr~~d~ JG~f Z~~~ Perforation Depth MD (ft): 10937' - 11007' Perforation Depth TVD (ft): 6949' - 7017' 2-7/8', 6.5# L-80 10893' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl. Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 Subsequent to operation: 310 164 784 380 259 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory t ®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 Mackie Derrick, 5645891 puq Printed a ndra Stewman Title Drilling Technologist Si lure Prepared By Name/Nwnber PhoneS~'t " ~i ~ S ~ Date - -vb Sondra Stewman 564-4750 Form 10-404 Revised 0412006 ~ ~ ~ ~ '~ ~ ~ ~ .~ 2008 Submit Original O'I~S ] S •~ R F ~ {2 Tree: 2 9/16" 5M CIWw MPU F-09 Orig. DF Elev. = 29.0 (N 22E) Wellhead: 11" x 7" 5M FMC Gen 5 Orig. GL Elev. = 12.0' Tba. Hna.:2 7/8" x 7" CIW, w/ 3" LH I DF To 7" csg. hng. = 30.4' (N 22E Acme lifting threads, 2 7/8" 8rd on 20" 91.1 ppf, H-40 115' KOP C~3 350' Max. hole angle = 65 to 67 deg fJ 3900' to 8800' Hole angle thru' perfs = 14 deg NoDLS>4de ./100' 9 5/8", 40 ppf, L-80 Btrc. 6288' 2 7/8" 6.5 ppf, L-80, 8rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Mod. Btrc. prod. casing ( drift ID = 6.151 ", cap.. 0.0383 bpf Two 7" x 21' marker joints from 10,821' to 10,863' and Stimulation Summary Frac- 104,066# of 16/20 carbolite behind pipe. Frac was designed for 159,000# 07/15/97. Perforation Summary Ref loa: mid-serf = 6975' tvd Size PF Interval VD) 'A' sands 3-3/8" 6 10937'-10951' 6942'-6955' 3-3/8" 6 10955'-10975' 6959'-6979' 3-3/8" 6 10979'-11007' 6983'-7009' Cameo 2 7/8" x 1 " 170, sidepocket KBMM GLM Cameo 2 7i8" x 1 " 10,683' sidepocket KBMM GLM HES XN-Nipple (2.205") 10,794` Centrilift SXD ESP 137-P17 10,834` Centrilift Gas Separator 10 854` GRSTX AR H6(400 internals) , Centrilift Tandem seal section 10,859` GSB3DBUT/LT SB/SB PFSA Centrilift KMH Motor, 10,872' 190 hp motor, 2415 v. / 48 amp . Pumpmate 10,889` 7" float collar (PBTD) 11,267' m -" -~~ 7" float shoe 11,350' m DATE REV. BY COMMENTS MILNE POINT UNIT 06/19/9] I 0]/„/9] JBF I Drilletl antl Casetl by Nabors 22E WELL F-09 03/06/98 06/19!99 MDO MDO ESP RWO 5S 3/23/98 ESP RWO 4ES ESP RWO ! 11/11/9 ESP RWO 4ES API NO: 50-029-22773 11/15/02 Mf70 ESP RWO 4-ES 8/28/08 REH ESP RWO 4ES BP EXPLORATION (AK) • BP AMERfCA Page 1 of 3 Operations Summary Report Legal Well Name: MPF-09 Common Well Name: MPF-09 Spud Date: 8/23/2008 Event Name: WORKOVER Start: 8/23/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/28/2008 Rig Name: NABORS 4ES Rig Number: ~ I I i Description of Operations Date From - To Hours Task Code NPT Phase 8/24/2008 12:30 - 14:30 2.00 RIGD P PRE Rig down rig and components. PJSM. Scope down and lay over derrick. 14:30 - 18:00 3.50 MOB P PRE Wait on truck to move rig. 18:00 - 21:00 3.00 MOB P PRE Move rig & componets from MPF-86 to MPF - 09. Berm up area around rig. 21:00 - 23:00 2.00 MOB P PRE Raise & scope up rig. R/U rig & equip. ACCEPT RIG ~ 23:00 hrs. 23:00 - 00:00 1.00 RIGU P DECOMP R/U rig equip. Take on hot 2% KCI brine. R/U lines to tree & Tiger tank. 8/25/2008 00:00 - 01:00 1.00 WHSUR P DECOMP P/U lubricator & pressure test to 500 psi. Pull BPV & UD same. 01:00 - 02:00 1.00 WHSUR P DECOMP Hold weekly safety meeting w/ all hands. Review most recent Slope incidents. Stress last 2 4es incidents & discuss 8 Golden Rules. 02:00 - 03:00 1.00 KILL P DECOMP Test lines to 3500 psi. Open well. SITP 720 psi, SICP 840 psi. Bleed off tubing/annulus to 20 psi. 03:00 - 05:30 2.50 KILL P DECOMP Kill well as follows: Pump 3 BPM & caught fluid ~ 1750' Con't to pump ~ 4 BPM. Took 42 bbls to circulate. ATP = 1050 psi, IAP increased to 280 psi & then dropped to 70 psi. Pumped total of 488 bbls. Recovered 310 bbls in Tiger tank. S/D & tubing pressure dropped to 0 psi & then went on vacuum. IAP went to 0 psi in 5 min. Well dead. 05:30 - 06:00 0.50 KILL P DECOMP Monitor well. R/D kill lines. 06:00 - 08:30 2.50 WHSUR P DECOMP FMC wellhead tech. dry rod set TWC and verified proper travel into han er rofile. P/T TWC from above to 3500- si nd minutes each. Charted both tests. 08:30 - 10:00 1.50 WHSUR P DECOMP Nipple down tree. inspect tubing hanger top thread and screw 3" LH Acme XO in 7 turns. Threads O.K. 10:00 - 12:00 2.00 BOPSU P DECOMP NU ROPE. 12:00 - 15:30 3.50 BOPSU P DECOMP BOPE er BP/AOGCC re uirements: 250-psi LO/3500-psi Hi. Tested 2-7/8" x 5" VBR's and annular preventer with 2-7/8" test joint. Tested all choke manifold valves, manual kill and choke valves, kill and choke HCR valves, test spool valve and Koomey test. 15:30 - 17:00 1.50 WHSUR P DECOMP Makeup Lopso-Opso w/3" LH Acme XO and screw into tubing hanger. Make up lubricator to Lopso-Opso and P/T lubricator to 500-psi. MPU Well Support pull TWC. UD lubricator and Lopso-Opso. 17:00 - 18:00 1.00 PULL P DECOMP Make up 3-1/2" DP landing joint with closed TIW valve and 3" LH Acme XO. Screw into tubing hanger. BOLDS. Unland hanger w/85K upweight. Dragging 75K-90K while hoisting hanger to floor. Open TIW valve. Tubing on vacuum. Breakout tubing hanger and lay down landing joint and TIW valve. 18:00 - 19:00 1.00 PULL P DECOMP Cut off ESP cable & band to tubing pup. P/U & single in w/ 7 jts to 11088'. Notify town engineer of depth. POOH & UD 7 singles. 19:00 - 20:30 1.50 PULL P DECOMP Cut & slip 107' of drilling line. 20:30 - 23:00 2.50 PULL P DECOMP Circulate bottoms up. Pumped 4 BPM ~ 1100 psi. Pumped total of 531 bbls. Lost 106 bbls while circulating. Had gas(~394 bbls) & oil to surface during circulation, continued pumping until well was clean. 23:00 - 00:00 1.00 PULL P DECOMP POOH & stand back 2 7/8" ESP com letion. Spool up ESP cable. Printed: 9/8/2008 11:12:08 AM • • BP AMERICA Page 2 of 3 Operations Summary Report Legal Well Name: MPF-09 Common Well Name: MPF-09 Spud Date: 8/23/2008 Event Name: WORKOVER Start: 8/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/28/2008 Rig Name: NABOBS 4ES Rig Number: Date 'From - To Hours i Task Code NPT Phase . Description of Operations 8/26/2008 00:00 - 03:30 3.50 PULL P DECOMP Con't to POOH & stand back 2 7/8" ESP completion. Spool up ESP cable. POOH & stand back 60 stands of 2 7/8' tubing. Filling hole with double steel displacement. 03:30 - 04:30 1.00 PULL P DECOMP Change out reels in spooling unit. 04:30 - 06:00 1.50 PULL P DECOMP Con't to POOH & stand back 2 7/8" completion. Spool up ESP cable. 06:00 - 06:30 0.50 PULL P DECOMP Pre-tour crew change meeting. Daily derrick inspection, PVT checks and rig service. 06:30 - 08:00 1.50 PULL P DECOMP Con't to POOH & stand back 2 7/8" completion. Spool up ESP cable. 08:00 - 12:00 4.00 PULL P DECOMP Centrilift disassemble and inspect ESP BHA. _ Lay down ESP BHA. Fill hole with 15-Bbls/hr. while changing out ESP. Lay down ESP cable containment trunk. Changeout cable reels in spooler. Recovered 342 jts. 2-7/8" EUE 8RD. tubing, 2 ea. 2-7/8" x 1 GLM's, 4 ea. 10' 2-7/8" EUE 8RD. pups jts. & 1 ea. XN nipple. Also recovered 178 Lasalle cable clamps, 5 protectorlisers and 3 flat guards. Filled hole with 25-Bbls. at 13:30-hrs. indicatin that fluid level is at 833' from surface. 12:00 - 15:30 3.50 BUNCO RUNCMP Centrilift assemble and service ESP BHA per running order. Pull ESP cable over cable sheave. Centrilift connect ESP motor lead cable to motor and make initial checks. 15:30 - 17:00 1.50 BUNCO RUNCMP RIH with 2-7/8" ESP com letion tubin from derrick. Install Lasalle cross coupling cable clamps on first 9 joints and then every other coupling for remainder of completion. Also install Lasalle clamps on every tubing pup connection except for tubing pup directly below tubing hanger. RIH w/20 stands and stopped for Centrilift to make electrical checks. Bad electrical readings downhole per Centrilift. 17:00 - 18:00 1.00 BUNCO DFAL RUNCMP OH w /ESP completion to troubleshoot electrical failure. Inspect cable while POH. No damage or anomalies noted with ESP cable. 18:00 - 18:30 0.50 BUNCO DFAL RUNCMP Pre-tour crew change meeting. Perform daily derrick inspection, PVT checks and rig service. 18:30 - 19:30 1.00 BUNCO DFAL RUNCMP Continue POH w/ ESP completion troubleshooting electrical failure. Inspect cable while POH. No damage or anomalies noted with ESP cable. 19:30 - 20:30 1.00 BUNCO DFAL RUNCMP Centrilift tech test ESP motor on rig floor -good test. Pull ESP cable to spooling unit and test -good test. 20:30 - 00:00 3.50 BUNCO DFAL RUNCMP Test splice from ESP cable to motor lead -test failed Test motor lead -test aile iscuss situation with town and decide to replace motor lead. Test new motor lead -good test. Centrilift tech splice new motor lead onto ESP cable. 8/27/2008 00:00 - 00:30 0.50 BUNCO DFAL RUNCMP Centrilift tech continue splicing motor lead to ESP cable. 00:30 - 02:00 1.50 BUNCO DFAL RUNCMP Fill hole at 4-BPM / 80-psi. Pump 23-bbls to get returns, indicating fluid level at -600'. Pull ESP cable ove-i'L'iSre sheave. Centrilift techs service ESP motor. Attach new motor lead and ESP cable to pump and test -good test. 02:00 - 10:00 8.00 BUNCO RUNCMP RIH with 2-7/8" ESP com k. Install asa a cross coupling cable clamps on first 9 joints and then every other coupling for remainder of completion. Also install Lasalle clamps on every tubing pup connection except for tubing pup directly below tubing hanger. RIH to 500' and Centrilift run ESP electrical tests -good test. Continue to test Printed: 9/8/2008 11:12:08 AM • BP AMERICA Page 3 of 3 Operations Summary Report Legal Well Name: MPF-09 Common Well Name: MPF-09 Spud Date: 8/23/2008 Event Name: WORKOVER Start: 8/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/28/2008 Rig Name: NABOBS 4ES Rig Number: Date ~ From - To ~ Hours Task Code NPT Phase '~ Description of Operations 8/27/2008 102:00 - 10:00 8.00 BUNCO RUNCMP ESP every 2000' and pump through ESP. Fill hole at rate of 10:00 - 13:00 I 3.00 13:00 - 17:00 I 4.00 17:00 - 18:00 I 1.001 RU 18:00 - 19:00 1.00 RU 19:00 - 19:30 0.50 RU 19:30 - 20:30 I 1.001 WHSUR I P 20:30 - 22:00 I 1.501 WHSUR I P 22:00 - 00:00 I 2.001 WHSUR I P 8/28/2008 100:00 - 02:00 I 2.001 WHSUR I P 15-BPH while running completion. RUNCMP Centrilift made reel to reel ESP cable splice. Filled hole with 28-Bbls. 8.4-ppg fluid. RUNCMP Resume RIH with 2-7/8" ESP completion installing Lasalle cable clamps on every second tubing coupling. Ran 178 lasalle clamps, 5 protectorlisers and 3 Armstergards. RUNCMP Make up landing joint w/closed TIW valve and tubing hanger to tubing string. FMC install wellhead penetrator in tubing hanger. Centrilift make up field attachable cable connector and connect to wellhead penetrator. RUNCMP Lan to ' P/U Wt. = 82K, S/O Wt. = 44K. RUNCMP Open TIW valve to check for pressure. No pressure. Break and lay down 3-1/2" OP landing joint w/XO. RUNCMP FMC wellhead tech d rod set TWC and verified proper travel into tubing hanger profile. P/T TWC from above to 1000-psi for 10 charted minutes and from below to 1000-psi for 10 charted minutes. Bullheaded 58-Bbls. fluid to formation while testing TWC from below. Drain stack in preparation for ND. RUNCMP PJSM on ND BOP stack and NU production tree. Blow down all lines. ND BOP stack and stand back on traveling pedestal. Centrilift tech test ESP prior to NU production tree. RUNCMP PJSM on NU production tree. NU production tree. Milne Pt pad operator on location and requested modification to the orientation of the swab valve. Orientation adjusted and API seal ring replaced. Centrilift perform final checks to ESP. All checks are satisfactory. FMC tech test hanger void to 5000-psi for 30 minutes -good test. Pump open SSV. Test tree to 5000-psi and hold for 10-minutes. RUNCMP PU Well support lubricator and test to 500-psi -good test.. Pull TWC with lubricator. Well on vac. Lubricate in BPV and test below to 500-psi for 10-charted minutes. Pump at 34-SPM to maintain test pressure. Bullheaded 39-Bbls of fluid to formation while testing BPV from below. Secure well and cellar. "Release Rig at 0200-hrs." Printed: 9/8/2008 11:12:08 AM _THE MATERIAL UNDER v/-/lS cov~/~ nAs ON OR BEFORE P E W M ATE IA L UNDER TH IS M ARK ER C:LO~M. DOC ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other ESP Changeout 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 41' [] Exploratory 7. Unit or Property Name 3. Address I-'1 Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service '4. Location of well at surface 8. Well Number 1759' NSL, 2766' WEL, SEC. 6, T13N, R10E, UM MPF-09 At top of productive interval 9. Permit Number / Approval No. 197-104 3301' NSL, 4641' WEL, SEC. 1, T13N, R9E, UM 10. APl Number At effective depth 50-029-22773-00 3317' NSL, 4717' WEL, SEC. 1, T13N, R9E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 3325' NSL, 4744' WEL, SEC. 1, T13N, R9E, UM Sands 12. Present well condition summary Total depth: measured 11390 feet Plugs (measured) true vertical 7389 feet Effective depth: measured 11267 feet Junk (measured) true vertical 7269 feet Casing Length Size Cemented MD TVD Structural Conductor 78' 20" 250 sx Arcticset I 112' 112' Surface 6256' 9-5/8" 1765 sx PF 'E', 500 sx Class 'G' 6288' 4305' Intermediate Production 11320' 7" 240 sx Class 'G' 11350' 7350' Liner Perforation depth: measured 10937'- 10951', 10955'- 10975', 10979'- 11007' true vertical 6949' - 6962', 6966' - 6986', 6989' - 7017' RBBMS BFL Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 10893' Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary ~, r' Intervals treated (measured) DEC 2 5 2002 Treatment description including volumes used and final pressure .~laska 0il & (~as An~hora~e "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 , ' litle Technical ^ssistant Date~./~' ~)~'~_., Pr~t~r~ Blt ~arn~lVumt~r: ,.,qon~r~ St~wm~n, ~4-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicatec .~ Legal Well Name: MPF-09 Common Well Name: MPF-09 Spud Date: Event Name: WORKOVER S~: 11/12D002 End: Contractor Name: NABORS A~S~ DRILLING I Rig Release: 11/14D002 Rig Name: NABORS 4ES Rig Number: 4ES 11/12/2002 06:00 - 14:00 8.00 MOB P PRE MI/RU ~BORS 4ES & SAME OUT EQUIPMENT. 14:00 - 17:00 3.00 KILL P DECOMP PULL BPV & RIG LINES TO TREE & TEST SAME TO 3500 PSI. 17:00 - 20:00 3.00 KILL P DECOMP SITP=790 PSI. SICP=760 PSI. ClRC WELL BORE INFLUX OUT WITH S~WATER. & MONITOR SAME. 20:00 - 20:30 0.50 WHSUR P DECOMP SET ~C & TEST TO 3500 PSI. 20:30 - 21:30 1.00 WHSUR P DECOMP BLEED VOID ON TREE & ND SAME. 21:30- 00:00 2.50 BOPSU~ P DECOMP NIPPLE UP BOP'S 11/13/2002 00:00 - 03:00 3.00 BOPSU~ P DECOMP PRESSURE TEST BOP'S TO 250/3500 & TEST WAIVED BY CHUCK SHEVE WITH AOGC. 03:00 - 03:30 0.50 WHSUR P DECOMP RIG LUBRICATOR & PULL ~C. 03:30 - ~:30 1.00 PULL P DECOMP PULL HANGER TO FLOOR & ~Y DN SAME & CHECK OUT ESP.. 04:30 - 12:00 7.50 PULL P DECOMP POOH WITH ESP COMPLETION 12:00 - 13:30 1.50 PULL P DECOMP ~Y DN ESP & INVESTIGATE SAME. 13:30 - 17:00 3.50 RUNCO~ P COMP MU ESP ASSY.. 17:00 - 00:00 7.00 RUNCO~P COMP RIH WITH ESP ASSY. 11/14D002 00:00 - 06:00 6.00 RUNCO~P COMP RUN COMPLETION & CIRC. THROUGH PUMP EVERY 2000' & CHECK CABLE, 06:00 - 09:00 3.00 RUNCO~P COMP MU HANGER & ~KE EFT CONNECTOR & ~ND HANGER & RILDS. & SET ~C & TEST 09:00 - 10:30 1.50 BOPSUF P COMP NIPPLE DN BOP'S 10:30 - 12:00 1.50 WHSUR P COMP NIPPLE UP TREE & TEST TO 5000 PSI. & SET BPV. & REL~SE RIG ~ 1200 HRS. 11-14-2002 Printed: 11/18/2002 3:57:58 PM STATE OF ALASKA ALASKA .... ,L AND GAS CONSERVATION CO~MISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Pull Tubing []Alter Casing [] Repair Well [] Other 2. Name of Operator 15. Type of well: IX] Development BP Exploration (Alaska) Inc. I I-q Exploratory I-] Stratigraphic [--I Service 4. Location of well at surface 1759' NSL, 2766' WEL, SEC. 6, T13N, R10E, UM At top of productive interval 3301' NSL, 4641' WEL, SEC. 1, T13N, R9E, UM At effective depth 3317' NSL, 4717' WEL, SEC. 1, T13N, R9E, UM At total depth 3325' NSL, 4744' WEL, SEC. 1, T13N, R9E, UM [] Perforate ESP Changeout 6. Datum Elevation (DF or KB) KBE: 41' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-09 9. Permit Number / ApprovalNo. 197-104 10. APl Number 50-029-22773 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present wellcondition summary Totaldepth: measured 11390 feet true vertical 7389 feet Effective depth: measured 11267 feet true vertical 7269 feet Casing Length Structural Conductor Surface Intermediate Production Liner Size 78' 20" 6256' 9-5~" 11320' 7" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I 1765 sx PF 'E', 500 sx Class 'G' 240 sx Class 'G' MD TVD 112' 112' 6288' 4305' 11350' 7350' Perforation depth: measured true vertical 10937'-10951', 10955'-10975', 10979'-11007' 6949'-6962', 6966'-6986', 6989'-7017' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 10887' Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Anchorage. Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ./r~A a ~/ ~ TerrieHubble "~&//~l~(/. Title TechnicalAssistantlll Prepared By Name/Number: Date I ~ '0~'9~) ~ Terrie Hubble, 564-46__28_~ I ~ Submit In Duplicate"--~?~ Form 10-404 Rev. 06/15/88 Facility Date/Time 10 Nov 99 11 Nov 99 Progress Report M Pt F Pad Well MPF-09 Rig Nabors 4ES Page 1 Date 30 November 99 00:00-06:00 00:00-06:00 06:00 06:00-09:00 06:00-09:00 09:00 09:00-11:00 09:00-11:00 11:00 11:00-13:00 11:00-13:00 13:00 13:00-16:00 13:00-16:00 16:00 16:00-18:00 16:00-16:30 16:30 16:30-18:00 18:00 18:00-20:00 18:00-20:00 20:00 20:00-22:00 20:00-22:00 22:00 22:00-23:00 22:00-23:00 23:00 23:00-06:00 23:00-06:00 06:00 06:00-09:30 06:00-09:30 09:30 09:30-02:45 09:30-22:30 22:30 22:30-02:00 Duration 6hr 6 hr 3hr 3 hr 2hr 2 hr 2 hr 2 hr 3 hr 3hr 1/2 hr 1-1/2 hr 2 hr 2 hr 2hr 2 hr 1 hr lhr 7 hr 7hr 3-1/2 hr 3-1/2 hr 17-1/4 hr 13hr 3-1/2 hr Activity Move rig Rig moved 75.00 % At well location - Slot Move rig (cont...) Rig moved 100.00 % At well location ~ Slot Derrick management Rigged up High pressure lines rig tiger tank * lines to tree & take on sea h20 Equipment work completed Wellhead work Retrieved Hanger plug & install hcr vale on annulus & test hard lines to 3000 psi Equipment work completed Well control Circulated closed in well at 10757.0 ft pre-well kill meeting & circ. influx from well with sea h20 & monitor same (static) Hole displaced with Seawater - 150.00 % displaced Wellhead work Installed Hanger plug & test to 2500 psi. Equipment work completed Rigged down Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack RECEIVED 1999 Equipment work completed Test well control equipment ~ 011& 058 00115' Tested BOP stack ~tIl~ test waived by John Spaulding with aogc Pressure test completed successfully - 3500.000 psi Wellhead work Removed Hanger plug Equipment work completed Pull Single completion, 2-7/8in O.D. Pulled Tubing in stands to 9425.0 ft pull hanger to floor & check out & pooh with esp completion Stopped: To hold safety meeting Pull Single completion, 2-7/8in O.D. (cont...) Pulled Tubing in stands to 9425.0 ft Finish pooh & lay dn esp assy & desander found very little sand in trap s Completed operations Run Single completion, 2-7/8in O.D. Pulled Tubing in stands to 11876.0 ft Mu ESP & service & rih w/same Make mid-line splice & mu hanger Completed operations Serviced ESP Make eft connection to hanger ( 2.5 hours manufacturing bushing to make penetrator work) Facility M Pt F Pad Progress Report Well MPF-09 Page Rig Nabors 4ES Date 2 30 November 99 Date/Time 12 Nov 99 02:00 02:00-02:45 02:45 02:45-04:00 02:45-04:00 04:00 04:00-05:00 04:00-05:00 05:00 05:00-06:00 05:00-06:00 06:00 Duration 3/4 hr 1-1/4 hr 1-1/4 hr 1 hr 1 hr 1 hr 1 hr Activity Equipment work completed Installed Tubing hanger Tie-down bolts energised Nipple down BOP stack Removed BOP stack Equipment work completed Wellhead work Installed Xmas tree install tree & test to 5000 pis. Equipment work completed Wellhead work Installed Hanger plug Pull TWC & Set BPV & Secure Tree & cellar Equipment work completed RECEIVED 1999 Alaska ~ a Gas Go~s. Commission PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 07/19/99 RUN RECVD 97-104 97-104 97-104 97-104 97-104 97-104 97-104 97-104 97-104 97-104 97-104 97-104 97-104 GR/CCL 7766 7778 DGR/EWR4-MD DGR/CNP/SLD-MD DGR/CNP/SLD-TVD DGR/EWR4-TVD MMS SRVY MWD SRVY ~-11231 ~'"~CHL~ ~DC/GR/CCL ~r~'PERRY MPT/GR/EWR/CNP/RHOB ~/1'12-11890 ~4294-7382 ~/4294-7382 ~SPERRY 0-6184.62 ~PERRY 0-11390. GYRO ~TI SHOT ~YRODATA 0-11200. STAT TEM PRES ~'i0750-11150 7/1~/~7 PERF ~0850-11150 7/12/97 PERF ~10937-11007 7/18/97 10-407 ~COMPLETION DATE DAILY WELL OPS Are dry ditch samples required? yes ~_?nd received? Was the well cored? yes ~..Analysis & description received? Are well tests required? es ~Received? Well is in compliance ~.-~ Initial COMMENTS FINAL 08/07/97 1 08/07/97 1,2 08/20/97 FINAL 08/27/97 FINAL 08/27/97 FINAL 08/27/97 FINAL 08/27/97 09/26/97 09/26/97 09/26/97 FINAL 11/05/97 FINAL 11/05/97 FINAL 11/05/97 @ ~l~lq?/ @ ~ I~?1 T D BOX -- STATE OF ALASKA ALASKA"u~fL AND GAS CONSERVATION CO~IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown []Stimulate [] Plugging [~ Perforate [~ Pull Tubing []Alter Casing [] Repair Well [~ Other ESP Changeout 2. Name of Operator 15. Type of well: 6. BP Exploration (Alaska)Inc. I [] Development I--I Exploratory 7. 3. Address I~ Stratigraphic P.O. Box 196612, Anchorage, Alaska 99519-6612 []Service 4. Location of well at surface 8. 1759' NSL, 2766' WEL, SEC. 6, T13N, R10E, UM 9. At top of productive interval 3301' NSL, 4641' WEL, SEC. 1, T13N, R9E, UM At effective depth 3317' NSL, 4717' WEL, SEC. 1, T13N, R9E, UM At total depth 3325' NSL, 4744' WEL, SEC. 1, T13N, R9E, UM Datum Elevation (DF or KB) KBE = 41' Unit or Property Name Milne Point Unit Well Number MPF-09 Permit Number / Approval No. 97-104 10. APl Number 50-029-22773 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 11390 feet Plugs (measured) true vertical 7389 feet Effective depth: measured 11267 feet Junk (measured) true vertical 7269 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 78' 20" 6256' 9-5/8" Cemented 250 sx Arcticset I 1765 sx PF 'E', 500 sx Class 'G' 11320' 7" 240 sx Class 'G' MD TVD 112' 112' 6288' 4305' 11350' 7350' Perforation depth' measured 10937' - 10951 ', 10955' - 10975', 10979' - 11007' true vertical 6949' - 6962', 6966' - 6986', 6989' - 7017' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 11103' Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary ECE' * lVE Intervals treated (measured) dull 24 i999 Treatment description including volumes used and final pressure Alasb 0il & Gas Cons, Commissior~ Anchorage 14. Prior to well operation: Subsequent to operation' Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 5. Attachments J 1 [~ Copies of Logs and Surveys run I [] Daily Report of Well Operations 6. Status of well classifications as: [] Oil [~ Gas [~ Suspended Service 17. I hereby certify that the f.~egoi_ng is true and correct to the best of my knowledge Signed ~ Terrie Hubble ""~~ ., Title Technical Assistant III Prepared By Name/Number: Date O(~.O'~C/' '~t~' Terrie Hubble, 564-4628 ~, ~ ~n ~uplicate,~ Form 10-404 Rev. 06/15/88 Progress Report Facility M Pt F Pad Well MPF-09 Page 1 Rig ~ ~.S ~1~ Date 23 June 99 Date/Time 15 Jun 99 12:00-13:00 13:00-21:00 21:00-00:00 16 Jun 99 00:00-03:00 03:00-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-09:00 09:00-12:00 12:00-13:30 13:30-02:00 17 Jun 99 02:00-05:00 05:00-06:00 06:00-06:30 06:30-08:30 08:30-11:30 11:30-14:00 14:00-16:00 16:00-18:00 18:00-21:00 21:00-23:00 23:00-01:30 18 Jun 99 01:30-06:00 06:00-10:00 10:00-11:30 11:30-13:00 13:00-15:00 Duration 1 hr 8 hr 3 hr 3hr 1 hr 1/2 hr 1-1/2 hr 1/2 hr 2-1/2 hr 3 hr 1-1/2 hr 12-1/2 hr 3 hr lhr 1/2 hr 2hr 3 hr 2-1/2 hr 2 hr 2 hr 3hr 2hr 2-1/2 hr 4-1/2 hr 4 hr 1-1/2 hr 1-1/2 hr 2hr Activity Rigged down Drillfloor / Derrick Rig moved 100.00 % Rigged up High pressure lines Circulated closed in well at 11267.0 ft Installed Hanger plug Removed Xmas tree Installed BOP stack Held safety meeting Installed BOP stack Tested BOP stack Retrieved Hanger plug Pulled Tubing in stands to 10826.0 ft Conducted slickline operations on Slickline equipment - Tool run Rigged up sub-surface equipment - ESP Held safety meeting Installed ESP Rigged down sub-surface equipment - ESP Installed ESP Ran Tubing in stands to 2167.0 ft Serviced Completion string handling equipment Rig waited: Assessed situation Ran Tubing in stands to 6000.0 ft Serviced ESP Ran Tubing in stands to 10865.0 ft Installed Tubing hanger Rigged down BOP stack Installed Xmas tree Freeze protect well - 15.000 bbl of Diesel MEMORANDUM TO: David jo~~, Chairman THRU: Blair Wondzell, .¢~ P. I. Supervisor ~/-z~t State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 13, 1997 FILE NO: awolfmef, doc FROM: John Spaulding,~,,,_.~ SUBJECT: Petroleum InspCr BOPE Test Nabors 22E BPX / Milne Point Unit MPU F-09 PTD 97-104 Friday June 13, 1997: I traveled to BPX's Milne Point Unit to witness the BOPE Test on Nabors 22E. The AOGCC BOPE Test Report is atteched for reference. The test went well with no failures observed. Thhe area around the rig is quite congested, but is well layed out allowing good access to both the rigs that are on location. Summary' I witnessed the BOPE Test on; Nabors 22E, test time 3 hours, 0 failures Attachments: awolfmef, xls X Unclassified Confidential (Unclassified if document removed) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8" Test: Initial X Workover: Nabors Rig No. 22E PTD # BPX / SSD Rep. MPF-09 Rig Rep.: Set @ 6,280'md Location: Sec. Weekly Other DATE: 6/13/97 97-104 Rig Ph.# 659-4454 Tom England Rod Klepsig 6 T. 13N R. IOE Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location yes ~.ing Order Posted yes BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve FLOOR SAFETY VALVES: Well Sign yes Upper Kelly / IBOP Drl. Rig ok Lower Kelly / IBOP Hazard Sec. yes - Ball Type , Inside BOP Quan. Test Press. P/F 1 300/3,000 P 1 500/5,000 P I 500/5,000 P 1 500/5,000 P I 500/5,000 P 1 500/5,000 P 2 50O/5,00O P NA MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok Test Quan. Pressure P/F I 500/5,000 P I 500/5,000 P I 500/5,000 P I 500/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 17 Test Pressure P/F 500/5,000 P 36 500/5,000 P 2 P Func~oned Func~oned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 8~2050 avg. 3,150 I P 1,600 P minutes 35 sec. minutes 49 sec. yes Remote: yes Psig. TEST RESULTS Number of Failures: 0 ,Test Time: 3.0 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within 0 ~ Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-021 L (Rev.12/94) AWOLFMEF.XLS 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 99519-6612 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 4. Location of well at surface 1759' NSL, 2766' WEL, SEC. 6, T13N, R10E, UM At top of productive interval 3394' NSL, 4501' WEL, SEC. 1, T13N, R9E, UM At effective depth 3413' NSL, 4576' WEL, SEC 1, T13N, R9E, UM At total depth 3419' NSL, 4603' WEL, SEC. 1, T13N, R9E, UM ESP Changeout r5. Type of well: ~], Development L_[Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 41' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-09 9. Permit Number / Approval No. 97-104 10. APl Number 50-029-22773 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 Length Stru ctu ral Conductor Surface Intermediate Production Liner 11390 feet Plugs (measured) 7389 feet 11267 feet Junk(measured) 7269 feet Size Cemented 78' 20" 6256' 9 5/8" 250 sx Arcticset I 1765 sx PF 'E', 500 sx Class 'G' 11320' 7" 240 sx Class 'G' MD TVD 112' 112' 6288' 4305' 11350 7350' Perforation depth: measured 10937', 10951', 10955'- 10975', 10979'- 11907' true vertic~ 6908' 921', 6925' - 6945', 6948' - 6976' Tubing (size, grade, and measured depth) 2 7/8", 6.5 lb. L-80 set at 10826' Packers and SSSV (type and measured depth) RECEIVED MAR 24 !998 Alaska Oil & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Avera.qe Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoin,g is true and correct to the best of my knowledge Signed Jea:nn ' ~¢'~' -/z.,/Zx':_ , ~) Title Staff Technical Assistant Prepared By Name/Number: Date Z~/) ~//'~'? Jeanne L. H~as, 5~4/-5225 Facility Date/Time 25 Feb 98 26 Feb 98 27 Feb 98 28 Feb 98 01 Mar 98 02 Mar 98 M Pt F Pad Progress Report Well MPF-09 Rig Nabors 5S Page 1 Date 09 March 98 06:00-06:30 06:30-21:00 21:00-22:00 22:00-23:00 23:00-00:00 00:00-02:00 02:00-05:00 05:00-06:00 06:00-06:30 06:30-10:00 10:00-11:00 11:00-12:00 12:00-14:30 14:30-17:30 17:30-18:00 18:00-18:15 18:15-19:30 19:30-22:30 22:30-23:00 23:00-23:30 23:30-00:00 00:00-01:00 01:00-06:00 06:00-06:15 06:15-10:00 10:00-13:30 13:30-15:00 15:00-21:00 21:00-22:00 22:00-23:00 23:00-01:00 01:00-04:30 04:30-05:30 05:30-06:00 06:00-08:00 08:00-16:00 16:00-20:00 20:00-03:30 03:30-06:00 06:00-06:15 06:15-14:00 14:00-16:30 16:30-18:00 18:00-18:15 18:15-19:00 19:00-23:30 23:30-00:30 00:30-01:30 01:30-06:00 06:00-06:15 06:15-07:00 07:00-09:00 09:00-12:00 12:00-13:00 Duration 1/2 hr 14-1/2 hr lhr lhr lhr 2hr 3hr lhr 1/2 hr 3-1/2 hr lhr 1 hr 2-1/2 hr 3hr 1/2 hr 1/4 hr 1-1/4 hr 3 hr 1/2 hr 1/2 hr 1/2 hr 1 hr 5hr 1/4 hr 3-3/4 hr 3-1/2 hr 1-1/2 hr 6 hr 1 hr 1 hr 2 hr 3-1/2 hr 1 hr 1/2 hr 2 hr 8hr 4 hr 7-1/2 hr 2-1/2 hr 1/4 hr 7-3/4 hr 2-1/2 hr 1-1/2 hr 1/4 hr 3/4 hr 4-1/2 hr 1 hr 1 hr 4-1/2 hr 1/4 hr 3/4 hr 2 hr 3 hr 1 hr Activity Held safety meeting Rig moved 100.00 % Retrieved Hanger plug Monitor wellbore pressures Circulated at 10801.0 ft Circulated at 10801.0 ft Circulated at 10801.0 ft Circulated at 10801.0 ft Held safety meeting Circulated at 10801.0 ft Installed Hanger plug Removed Xmas tree Installed BOP stack Tested All rams Rigged up Lubricator Held safety meeting Rig waited: Equipment Rigged down Wellhead connector Removed Hanger plug Pulled Tubing on retrieval string to 10846.0 ft Flow check Rigged down Tubing hanger Pulled Tubing in stands to 3600.0 ft Held safety meeting Pulled Tubing in stands to 0.0 ft Conducted slickline operations on Slickline equipment - Tool run Made up BHA no. 1 R.I.H. to 10965.0 ft Reverse circulated at 10965.0 ft Rigged up Swivel Installed Swivel Reverse circulated at 10988.0 ft Reverse circulated at 11005.0 ft Rigged down Swivel Rigged down Swivel Reverse circulated at 11195.0 ft Reverse circulated at 11195.0 ft Pulled BHA Rigged up sub-surface equipment - ESP Held safety meeting Ran Tubing in stands to 8100.0 ft Installed ESP Ran Tubing in stands to 10205.0 ft Held safety meeting Ran Tubing in stands to 10826.0 ft Space out tubulars Removed BOP stack Installed Xmas tree Displace treatment Held safety meeting Removed Hanger plug Backflow Conducted slickline operations on Slickline equipment - Retrival run Fished at 10777.0 ft Facility Date/Time 03 Mar 98 04 Mar 98 05 Mar 98 06 Mar 98 M Pt F Pad Progress Report Well MPF-09 Page 2 Rig Nabors 5S Date 09 March 98 13:00-15:30 15:30-18:00 18:00-19:00 19:00-20:00 20:00-23:00 23:00-00:00 00:00-01:30 01:30-05:30 05:30-06:00 06:00-06:15 06:15-08:00 08:00-10:30 10:30-11:30 11:30-18:00 18:00-18:15 18:15-22:00 22:00-23:30 23:30-02:00 02:00-03:00 03:00-06:00 06:00-06:15 06:15-07:00 07:00-17:00 17:00-18:00 18:00-18:15 18:15-00:15 00:15-04:30 04:30-06:00 06:00-06:15 06:15-13:00 13:00-16:00 16:00-16:30 16:30-18:00 18:00-18:15 18:15-20:30 20:30-22:00 22:00-23:00 23:00-02:30 02:30-04:30 04:30-06:00 06:00-06:15 06:15-08:00 08:00-11:00 11:00-14:30 14:30-16:30 16:30-18:00 18:00-18:15 18:15-19:30 19:30-21:00 21:00-06:00 Duration 2-1/2 hr 2-1/2 hr 1 hr lhr 3hr lhr 1-1/2 hr 4hr 1/2 hr 1/4 hr 1-3/4 hr 2-1/2 hr 1 hr 6-1/2 hr 1/4hr 3-3/4 hr 1-1/2 hr 2-1/2 hr 1 hr 3 hr 1/4 hr 3/4 hr 10hr 1 hr 1/4 hr 6 hr 4-1/4 hr 1-1/2 hr 1/4 hr 6-3/4 hr 3 hr 1/2 hr 1-1/2 hr 1/4hr 2-1/4 hr 1-1/2 hr 1 hr 3-1/2 hr 2 hr 1-1/2 hr 1/4 hr 1-3/4 hr 3 hr 3-1/2 hr 2 hr 1-1/2 hr 1/4 hr 1-1/4 hr 1-1/2 hr 9 hr Activity Fished at 10768.0 ft Conducted slickline operations on Slickline equipment - Retrival run Pulled out of hole to 0.0 ft Washed to 10776.0 ft Conducted slickline operations on Slickline equipment - Retrival run Installed Hanger plug Removed Xmas tree Installed BOP stack Pulled Tubing on retrieval string to 10804.0 ft Held safety meeting Monitor wellbore pressures Rigged up Tubing handling equipment Repaired Draw works Pulled Tubing in stands to 10826.0 ft Held safety meeting Pulled Tubing in stands to 4210.0 ft Rigged down sub-surface equipment - ESP Ran Tubing to 3000.0 ft (2-7/8in OD) Circulated at 3000.0 ft Ran Tubing in stands to 10600.0 ft Held safety meeting Ran Tubing in stands to 11190.0 ft Circulated at 11190.0 ft Laid down 665.0 ft of Tubing Held safety meeting Pulled Tubing in stands to 10526.0 ft Installed ESP Pulled Tubing in stands to 1435.0 ft Held safety meeting Ran Tubing in stands to 10422.0 ft Installed Other sub-surface equipment Ran Tubing in stands to 10737.0 ft Installed Other sub-surface equipment Held safety meeting Ran Tubing to 10823.0 ft (2-7/8in OD) Removed BOP stack Installed Xmas tree Removed Xmas tree Rigged up BOP stack Laid down 0.0 ft of Tubing Held safety meeting Laid down 0.0 ft of Tubing Installed Other sub-surface equipment Serviced Tubing hanger Removed BOP stack Rigged up Xmas tree Held safety meeting Tested Xmas tree Circulated at 2200.0 ft Rig moved 50.00 % GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11525 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 11/5/97 Well Job # Log Description Date BL RF Sepia LIS Tape MPC-6 (.,~1 ~ WATER FLOW LOG/TDTP-GR/CCL 970615 I 1 MPU C-8 t,~.~ C_-. TDT WATER FLOW LOG 970927 I 1 MPU C-10 I~,L~ ~ WATER FLOW LOG W/RST INVERTED 970911 I 1 MPE-10 , TUBING PUNCHER 970928 I 1 MPU E-22, 'TUBING LEAK DETECTION LOG 970702 I 1 MPU E-22 ~ TUBING PATCH RECORD 97071 9 1 1 MPU F-09 ~ PERFORATING RECORD 970712 I 1 MPU F-09 ~, STATIC TEMP/PRESS SURVEY 970712 I 1 MPU F-09' PERFORATING RECORD 97071 9 1 1 F-41 , CHEMICAL CUTTER 970820 1 1 F-41 · CHEMICAL CUTTER 970829 1 1 MPU F-73' PERFORATION RECORD 970815 I 1 MPG-09 · RFT 970702 I 1 MPH-11 ~ RFT 970903 I 1 MPU J-2 ~ I(~. WATER FLOW LOG/TDT-GR 970726 I 1 MPU J-09 ~[(...-- JETCUTTER RECORD 970807 1 1 MPK-43A · GAMMA RAY CORRELATION LOG 971 024 I 1 UPU L-9 [),1 ~ WATER FLOW LOG/TDTP-GR/CCL 970614 I 1 MPU L-32 ~ GAMMA RAY CCL TCP CORRELATION LOG 970515 1 1 MPL-33 , TUBING CONVEYED PERF TIE-IN GR-CCL 971 010 I 1 MPL-33 ' TIE-IN GR-CCL 971 014 1 1 ., - 99' JO't qo.c Lo ~q.l©~ (~o - lot .. clq, c~5- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 .... STATE OF ALASKA ,.-_ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil F-I Gas [-I Suspended I--~ Abandoned [-I Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-104 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22773 4. Location of well at surface ? .r:~:':':: ;'-~..: ~. '~ 9. Unit or Lease Name 1759' NSL, 2766' WEL, SEC. 6, T13N, R10E, UM¢~ !,;~,q ~; ,, i Milne Point Unit At top of productive interval 3301' NSL, 4641' WEL, SEC. 1, T13N, R9E, UM 10. Well Number "-,~iFi~ i MPF-09 At total depth __ .~Z~. ...... ! 11. Field and Pool 3325' NSL, 4744' WEL, SEC. 1, T13N, R9E, UM .................. Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 41'I ADL 388235 12. Date Spudded6/8/97 113' Date T'D' Reached I 14' Date C°mp" Susp" °' Aband'115' water depth' if OffshOre 116' NO' Of cOmpletiOns6/16/97 7/20/97 N/A MSLI One 17. Total Depth (MD+TVD)I18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 11390 7389 FTI 11267 7269 FTI [~]Yes F-INo N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR/CCL, Gyro, LWD, EMMS 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP Bo~roM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1 Cf H-40 34' 112' 24" ;250 sx Arcticset I (Approx.) 9-5/8" 40Cf L-80 32' 6288' 12-1/4" 1765 sx PF 'E', 500 sx Class 'G' 7" 26Cf L-80 30' 11350' 8-1/2" 2.40 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 2-7/8", 6.ECf, L-80 10868' N/A MD TVD MD TVD 10937'-10951' 6949'-6962' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 10955'-10975' 6966'-6986' 10979'-11007' 6989'-7017' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 75 bbls diesel Frac 'A' Sands 104418Cf 16/20 Carbolite behind pipe 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) August 11, 1997I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 07-01-80 :~S%bmit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Kuparuk 'B' 10911' 6924' Top Kuparuk 'A' 10942' 6954' Top Kuparuk A3 10950' 6961' Top Kuparuk A2 10966' 6977' Top Kuparuk A1 10990' 7000' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAIvord ~ ~ .(~ Title Senior Drilling Engineer Date MPF-09-- 97-104 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23.' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 21: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 07 Jun 97 08 Jun 97 09 Jun 97 10 Jun 97 11 Jun 97 12 Jun 97 13 Jun 97 M Pt F Pad Progress Report Well MPF-09 Rig Nabors 22E Page Date 19:00-02:00 02:00-06:00 06:00-09:30 09:30-11:30 11:30-16:30 16:30-17:00 17:00-17:30 17:30-18:00 18:00-06:00 06:00-15:00 15:00-16:00 16:00-16:30 16:30-17:30 17:30-18:00 18:00-23:30 23:30-00:00 00:00-06:00 06:00-07:00 07:00-11:30 11:30-12:00 12:00-14:00 14:00-06:00 06:00-11:00 11:00-13:00 13:00-16:30 16:30-17:00 17:00-19:00 19:00-21:00 21:00-21:30 21:30-01:00 01:00-02:30 02:30-03:45 03:45-04:00 04:00-06:00 06:00-12:30 12:30-14:30 14:30-15:30 15:30-16:30 16:30-16:45 16:45-19:00 19:00-20:45 20:45-21:00 21:00-21:30 21:30-23:00 23:00-02:30 02:30-03:45 03:45-04:00 04:00-06:00 06:00-06:15 06:15-11:30 11:30-14:30 14:30-15:00 15:00-18:00 18:00-19:00 Duration 7hr 4hr 3-1/2 hr 2hr 5hr 1/2 hr 1/2 hr 1/2 hr 12 hr 9hr lhr 1/2 hr lhr 1/2 hr 5-1/2 hr 1/2 hr 6hr lhr 4~1/2 hr 1/2 hr 2hr 16hr 5hr 2hr 3-1/2 hr 1/2 hr 2hr 2hr 1/2 hr 3-1/2 hr 1-1/2 hr 1~1/4 hr 1/4 hr 2hr 6-1/2 hr 2hr lhr lhr 1/4 hr 2-1/4 hr 1-3/4 hr 1/4hr 1/2 hr 1~1/2 hr 3-1/2 hr 1-1/4 hr 1/4 hr 2hr 1/4 hr 5-1/4 hr 3hr 1/2 hr 3hr lhr Activity Rig moved 100.00 % Rigged up Divertor Rigged up Divertor (cont...) Made up BHA in derrick Made up BHA no. 1 Held safety meeting Tested Divertor Circulated at 112.0 ft Drilled to 1303.0 ft Drilled to 2543.0 ft (cont...) Circulated at 2543.0 ft Pulled out of hole to 1112.0 ft Serviced Top drive R.I.H. to 2543.0 ft Drilled to 3497.0 ft Circulated at 3497.0 ft Drilled to 4070.0 ft Circulated at 4070.0 ft Pulled out of hole to 1112.0 ft Serviced Top drive R.I.H. to 4070.0 ft Drilled to 5880.0 ft Drilled to 6303.0 ft (cont...) Circulated at 6303.0 ft Pulled out of hole to 1112.0 ft Serviced Top drive R.I.H. to 6303.0 ft Circulated at 6303.0 ft Dropped EMMS survey barrel Pulled out of hole to 230.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 9-5/8in (1800.0 ft OD) Ran Casing to 6288.0 ft (9-5/8in OD) (cont...) Circulated at 6288.0 ft Mixed and pumped slurry - 334.000 bbl Displaced slurry - 471.000 bbl Functioned DV collar Circulated at 2009.0 ft Mixed and pumped slurry - 450.000 bbl Displaced slurry - 152.000 bbl Rigged down Cement head Rigged down Casing handling equipment Rigged down Divertor Installed Casing head Tested Casing head Rigged up BOP stack Rigged up BOP stack (cont...) Tested BOP stack Retrieved BOP test plug assembly Installed Wear bushing Made up BHA no. 2 Singled in drill pipe to 2009.0 ft 1 24 September 97 Facility Date/Time 14 Jun 97 15 Jun 97 16 Jun 97 17 Jun 97 18 Jun 97 19 Jun 97 M Pt F Pad Progress Report Well MPF-09 Page 2 Rig Nabors 22E Date 24 September 97 19:00-19:30 19:30-21:00 21:00-22:00 22:00-22:30 22:30-23:00 23:00-23:45 23:45-00:00 00:00-00:30 00:30-01:00 01:00-06:00 06:00-22:30 22:30-00:00 00:00-02:30 02:30-03:30 03:30-04:30 04:30-06:00 06:00-06:00 06:00-09:00 09:00-11:00 11:00-11:45 11:45-12:30 12:30-22:30 22:30-00:30 00:30-02:30 02:30-05:30 05:30-06:00 06:00-07:30 07:30-12:30 12:30-13:30 13:30-18:30 18:30-20:00 20:00-21:00 21:00-23:00 23:00-23:15 23:15-00:30 00:30-02:30 02:30-02:45 02:45-06:00 06:00-09:30 09:30-10:00 10:00-14:30 14:30-15:00 15:00-18:00 18:00-18:45 18:45-20:00 20:00-21:00 21:00-21:30 21:30-22:30 22:30-00:00 00:00-02:30 02:30-03:30 03:30-03:45 03:45-05:30 05:30-06:00 Duration 1/2 hr 1-1/2 hr lhr 1/2 hr 1/2 hr 3/4 hr 1/4 hr 1/2 hr 1/2 hr 5hr 16-1/2 hr 1-1/2 hr 2-1/2 hr lhr lhr 1-1/2 hr 24 hr 3hr 2hr 3/4 hr 3/4 hr 10hr 2hr 2hr 3hr 1/2 hr 1-1/2 hr 5hr lhr 5hr 1-1/2 hr lhr 2hr 1/4 hr 1-1/4 hr 2hr 1/4 hr 3-1/4 hr 3-1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 3hr 3/4 hr 1-1/4 hr lhr 1/2 hr lhr 1-1/2 hr 2-1/2 hr lhr 1/4hr 1-3/4 hr 1/2 hr Activity Drilled installed equipment - DV collar Singled in drill pipe to 4396.0 ft R.I.H. to 6201.0 ft Circulated at 6201.0 ft Tested Casing Drilled installed equipment - Landing collar Drilled to 6325.0 ft Circulated at 6325.0 ft Performed formation integrity test ~ Drilled to 6895.0 ft Drilled to 8990.0 ft (cont...) Circulated at 8990.0 ft Pulled out of hole to 6230.0 ft Serviced Top drive Serviced Block line R.I.H. to 8990.0 ft Drilled to 10448.0 ft Drilled to 10607.0 ft (cont...) Circulated at 10607.0 ft Pulled out of hole to 8550.0 ft R.I.H. to 10607.0 ft Drilled to 11420.0 ft Circulated at 11420.0 ft Flow check Pulled out of hole to 6250.0 ft Serviced Crown block R.I.H. to 11420.0 ft Circulated at 11420.0 ft Flow check Pulled out of hole to 1100.0 ft Pulled BHA Downloaded MWD tool Pulled BHA Removed Wear bushing Worked on BOP - Top ram Rigged up Casing handling equipment Held safety meeting Ran Casing to 7in (2600.0 ft OD) Ran Casing to 6250.0 ft (7in OD) (cont...) Circulated at 6250.0 ft Ran Casing to 11350.0 ft (7in OD) Rigged up Cement head Circulated at 11350.0 ft Mixed and pumped slurry - 49.000 bbl Displaced slurry - 432.000 bbl Tested Casing Rigged down Cement head ~,,~,,~,~ Rigged down Casing handling equ¢~ Installed Seal assembly Removed BOP stack Installed Adapter spool Tested Adapter spool Installed Xmas tree Tested Xmas tree Facility Date/Time Progress Report M Pt F Pad Well MPF-09 Rig Nabors 22E Page Date 06:00-06:30 06:30-08:00 08:00-19:00 Duration 1/2 hr 1-1/2 hr llhr Activity Removed Hanger plug Installed Hanger plug Laid out 5in drill pipe from derrick 3 24 September 97 PRUDHOE BAY, ALASKA TO: FROM: Well Name: I MPU F-09 Main Category: IDRLG Sub Category: ICOMPLETE / EL Operation Date: 17/11/97 Hendrix Date: 17/13/97 Bundy OBJECTIVE: Perform the pre-rig E-Line completion work including; correlation log, gyro, perforations, and static bottom hole pressure. JOB LOG 7/11/97 WELL CONDITIONS: SIWHP= 0 psig O73O 1100 1400 1800 1900 1930 Rig up SWS. RIH with GR/CCL/GYRO. Logging Gyro. At TD (11,231 '). POH logging GR/CCL/GYRO. OOH. Rig down SWS. Secure well for the evening. 7/12/97 0700 0900 1030 1100 1110 1245 1255 1315 1325 1330 1600 Rig up SWS. Safety meeting, discuss job. Call for radio silence. Pressure test lubricator w/triplex. Bottom BOP 'O' ring leaked. Change out. PT lubricator w/diesel to 3000 psig. PT - good. RIH with 3 3/8" (20') gun/CCL. CCL to top shot is 2.50'. Tie -in to short joints at 10,806'. Correction (+6'). RIH to 11,100'. Pull tie-in log to 10,950'. Tie-in is good. RIH to 11,100'. Pull tie-in log. Park CCL at 10,952.5' putting the top shot at 10,955'and the bottom shot at 10,975' (perf depths correlated to lithology on LWD log). Fire gun. Good indications at surface. Log off, CCL failed after gun shot, no post-shoot collars. No increase in sudace pressure. POH. OOH. All shots fired. Lift radio silence. MPU F-09, Gyro/Perf/Static con't, page 2 183O 2000 2010 2025 2105 2110 2230 2300 RIH with Press/Temp/GR/CCL to 11,050'. Pull up logging initial tie-in. Correction (+16'). RIH to 11,100'. Pull up logging GR/CCL. Tie-in good. Position Pressure/Temperature at 10,965' (mid-perfs). End P/T survey. ISIBHP= 2986 psia, ISIBHT= 170 deg F, SIWHP = 0 psig POH. OOH. Rig down SWS. Secure well. TD Tagged at 11,231' mdBKB. Diesel Used 12 bbls Methanol Used [0 MILNE POINT, ALASKA TO: Hendrix FROM: Matthew Linder WELL# F-09 Main Category: Drilling Sub Category: Frae of A sands. Operation Date: 07/15/97 I I Objective: DS will perform a casing frac on the 'A' sands using 159000 lbs of 16/20 carbolite. Operation: Rigged up DS frac equipment and tree saver. Pressure test all equipment to 9000 psi. DATA FRAC: BPM Pressure Total bbls 09:01 Breakdown of formation 40 2261 50 09:03 Data frac 40 2216 120 09:06 Flush 40 2193 200 09:11 Slow rate 5 2101 60 09:18 Inc. rate 40 2687 140 09:22 Shut down for ISSIP 0 2412 N/A ISSIP = 1753 psi. Frac gradient = .69 Notes: At shut down to determine ISSIP wellbore pressure was very slow bleeding off. We really never saw a good indication of the frac closing. Consulted Anchorage. Decided to go with planned frac design. FRAC: BPM Pressure Stage bbls 10:35 Pad 40 2311 110 10:38 Slow rate 5 1657 60 10:47 Inc rate 40 2339 40 10:48 1# 40 2312 132 10:52 2#_ 40 2362 21 10:52 3# 40 2389 31 10:53 4# 40 2435 40 10:54 5# 40 2486 47 10:55 6# 40 2605 54 10:57 7# 40 2724 59 10:58 8# 40 2660 63 11:00 9# 40 2554 66 11:01 10# 40 2495 357 11:10 Flush 40 2321 156 11:14 Screen out 0 5876 Conclusion: Screened out with 10# sand on perfs. 104,418# of sand behind pipe. 76,104~ sand left in casing. Screen out happened very quickly almost like we broke through a bridge or fraced through a zone. Estimate sand top at 7150'. Rigged down frac equipment and secured tree. Total fluid pumped I 1806 bbls I I I SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPF-09 Rig Name: N-4ES AFE: 347086 Accept Date: 07/16/97 Spud Date: - Release Date: 07/20/97 July 17 1997 MIRU. Scope & raise derrick & safe out equipment, berm & level up. Rig accepted 07/16/97 @ 2000 hrs. Check psi on well & ND tree & NU BOP's & test. Test waived by Chuck Sheve with AOGCC. Rig floor & load shed with 3-1/2" pipe & PU & RIH with same. Circ out diesel cap. Cont RIH with 3-1/2" DP. July 18 1997 Cont PU 3-1/2" DP. Rev circ @ 5470' taking proppant returns to TT. Cont PU 3-1/2" DP & rev circ out proppant every 300'-500' from 5470'-8977'. Rev circ & wash proppant f/8977' t/10968'. Lots of Carbolite. PU kelly & work through perfs. Cont to rev out carbolite. July 19 1997 Cont to clean carbolite out of 7" casing & rev hole clean @ 11262'. POOH to above perfs. Perform casing wash until NTU below 50. Cut drlg line. POOH, LD DP. ND flowline & NU shooting flange & rig SWS. Hold safety meeting. Run #1, RIH & get on depth & perf f/10979' t/11007', 6 spf. Run #2 & get on depth & perf f/10937' t/10951 ', 6 spf. POOH with SWS gun #2. July 20 1997 RD SWS. ND perf flange & NU flow nipple. Pull wear ring, set wear ring. Set test plug. ND 3-1/2" rams & NU 2-7/8" rams & test per policy. RU floor & spooling unit. MU & service ESP. RIH with ESP completion. Make mid-line splice. Cont RIH with ESP completion. MU hanger & splice ESP cable. Land tubing, RILDS & set TWC. RILDS & ND BOP's. NU tree & test. July 21 1997 releasedRig lines to07/20/97tree & test@ 0900 & freeZehrs, protect well to 2000' with diesel & secure~tree.:..~.~ ¢~ Page SPE .'-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING MILNE POINT / MPF-09 500292277300 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/30/97 DATE OF SURVEY: 061697 MWD SURVEY JOB NUMBER: AK-MM-70172 KELLY BUSHING ELEV. = 41.00 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -41.00 112.00 112.00 71.00 209.62 209.62 168.62 303.37 303.37 262.37 395.40 395.38 354.38 0 0 N .00 E .00 .00N .00E .00 0 0 N .00 E .00 .00N .00E .00 0 19 S 63.09 E .34 .13S .25E -.27 0 27 N 2.37 W .73 .13N .48E -.43 1 41 N 35.54 W 1.44 1.60N .33W .68 486.59 486.54 445.54 577.80 577.73 536.73 664.30 664.21 623.21 762.00 761.83 720.83 852.18 851.86 810.86 1 7 N 29.62 W .64 3.47N 1.55W 2.30 0 50 N 26.29 W .31 4.84N 2.29W 3.33 1 38 N 57.12 W 1.17 6.08N 3.61W 4.90 2 58 N 65.70 W 1.40 7.88N 7.09W 8.70 3 31 N 62.99 W .64 10.1iN 11.69W 13.69 943.57 943.03 902.03 1032.11 1031.24 990.24 1127.61 1126.20 1085.20 1224.79 1222.60 1181.60 1318.50 1315.39 1274.39 4 24 N 76.70 W 1.41 12.19N 17.62W 19.94 5 21 N 83.21 W 1.24 13.46N 25.04W 27.45 6 43 N 89.14 W 1.57 14.08N 35.06W 37.35 7 49 S 89.19 W 1.14 14.07N 47.36W 49.33 8 15 N 86.79 W .76 14.35N 60.46W 62.14 1414.28 1409.94 1368.94 1509.73 1503.73 1462.73 1605.02 1596.91 1555.91 1700.38 1689.69 1648.69 1794.72 1781.19 1740.19 10 0 N 78.00 W 2.33 16.47N 75.47W 77.24 11 22 N 75.86 W 1.48 20.49N 92.71W 94.94 12 42 N 74.79 W 1.43 25.54N 111.93W 114.81 13 59 N 75.14 W 1.34 31.25N 133.20W 136.81 14 12 N 76.28 W .38 36.92N 155.47W 159.79 1890.27 1873.54 1832.54 1986.52 1965.57 1924.57 2081.86 2055.17 2014.17 2177.38 2143.26 2102.26 2273.14 2229.61 2188.61 15 31 N 77.38 W 1.40 42.49N 179.34W 184.30 18 28 N 77.10 W 3.07 48.71N 206.77W 212.43 21 27 N 77.17 W 3.14 55.96N 238.50W 244.98 24 1 N 78.61 W 2.74 63.68N 274.60W 281.89 27 10 N 78.07 W 3.30 72.05N 315.11W 323.24 2368.54 2313.23 2272.23 2461.17 2392.05 2351.05 2560.63 2474.27 2433.27 2656.80 2551.47 2510.47 2751.87 2625.38 2584.38 30 21 N 78.13 W 3.34 81.51N 360.03W 369.13 33 0 N 76.58 W 2.98 92.18N 407.48W 417.77 35 27 N 75.66 W 2.53 105.62N 461.78W 473.69 37 43 N 76.00 W 2.36 119.64N 517.35W 531.00 40 11 N 75.35 W 2.63 134.44N 575.25W 590.75 2846.72 2696.84 2655.84 2940.27 2765.05 2724.05 3037.97 2833.61 2792.61 3131.28 2896.23 2855.23 3228.32 2958.34 2917.34 42 1 N 77.08 W 2.27 149.27N 635.80W 653.09 44 19 N 77.91 W 2.54 163.12N 698.28W 717.08 46 31 N 78.99 W 2.38 177.04N 766.45W 786.63 49 10 N 78.55 W 2.86 190.51N 834.29W 855.75 51 13 N 77.46 W 2.28 206.02N 907.19W 930.27 SPE~ -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPF-09 500292277300 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/30/97 DATE OF SURVEY: 061697 MWD SURVEY JOB NUMBER: AK-MM-70172 KELLY BUSHING ELEV. = 41.00 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3324.62 3017.25 2976.25 53 20 3418.07 3071.57 3030.57 55 34 3513.20 3124.07 3083.07 57 25 3610.64 3175.19 3134.19 59 16 3706.24 3222.69 3181.69 61 8 N 77.25 W 2.21 222.69N 981.51W N 78.99 W 2.83 238.33N 1055.91W N 79.00 W 1.96 253.47N 1133.77W N 80.06 W 2.10 268.53N 1215.32W N 78.95 W 2.20 283.65N 1296.88W 1006.43 1082.43 1161.69 1244.53 1327.39 3800.60 3267.03 3226.03 62 47 3895.41 3309.27 3268.27 64 16 3990.39 3349.35 3308.35 65 48 4084.83 3388.23 3347.23 65 34 4181.06 3428.36 3387.36 65 8 N 79.45 W 1.82 299.25N 1378.69W N 78.10 W 2.02 315.77N 1461.93W N 76.69 W 2.09 334.57N 1545.95W N 76.74 W .25 354.35N 1629.71W N 77.30 W .69 373.99N 1714.93W 1410.60 1495.41 1581.50 1667.56 1755.03 4276.65 3468.89 3427.89 64 41 4371.40 3508.50 3467.50 65 52 4465.84 3547.21 3506.21 65 43 4561.55 3587.08 3546.08 65 1 4658.46 3626.79 3585.79 66 34 N 75.82 W 1.48 394.11N 1799.13W N 76.30 W 1.34 414.84N 1882.66W N 75.65 W .65 435.72N 1966.24W N 76.44 W 1.05 456.70N 2050.67W N 75.89 W 1.68 477.84N 2136.50W 1841.59 1927.65 2013.78 2100.78 2189.16 4753.60 3664.29 3623.29 66 4849.14 3701.89 3660.89 66 4945.33 3740.49 3699.49 66 5040.38 3778.73 3737.73 66 5135.44 3816.56 3775.56 66 59 39 1 32 33 N 74.53 W 1.38 500.16N 2221.03W N 75.02 W .58 523.23N 2305.78W N 74.68 W .74 546.25N 2390.82W N 76.33 W 1.68 568.03N 2475.06W N 76.26 W .07 588.69N 2559.78W 2276.56 2364.33 2452.39 2539.37 2626.58 5228.75 3854.25 3813.25 65 47 5326.49 3894.80 3853.80 65 10 5422.01 3934.21 3893.21 66 5 5516.11 3972.37 3931.37 66 3 5611.56 4011.03 3970.03 66 9 N 75.69 W 1.00 609o37N 2642.60W N 74.80 W 1.04 632o02N 2728.59W N 75.99 W 1.48 653.95N 2812.78W N 76.92 W .90 674.10N 2896.40W N 75.65 W 1.22 694.79N 2981.18W 2711.93 2800.82 2887.80 2973.81 3061.07 5706.39 4049.80 4008.80 65 35 5801.84 4089.60 4048.60 65 7 5895.00 4129.22 4088.22 64 33 5989.67 4168.88 4127.88 65 54 6085.37 4208.10 4167.10 65 41 N 76.38 W .92 715.70N 3065.15W N 76.57 W .52 735.99N 3149.50W N 76.19 W .71 755.85N 3231.45W N 76.25 W 1.44 776.32N 3314.93W N 76.18 W .23 797.12N 3399.71W 3147.60 3234.35 3318.67 3404.62 3491.91 6178.05 4245.10 4204.10 6227.72 4264.33 4223.33 6328.23 4304.10 4263.10 6423.92 4343.69 4302.69 6519.79 4383.30 4342.30 67 13 67 13 66 10 64 56 66 15 N 76.24 W 1.65 817.37N 3482.22W N 77.25 W 1.88 827.87N 3526.80W N 77.54 W 1.08 848.02N 3616.88W N 78.04 W 1.37 866.44N 3702.01W N 76.70 W 1.87 885.53N 3787.19W 3576.86 3622.66 3714.96 3802.05 3889.34 SPEi -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING MILNE POINT / MPF-09 500292277300 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/30/97 DATE OF SURVEY: 061697 MWD SURVEY JOB NIIMBER: AK-MM-70172 KELLY BUSHING ELEV. = 41.00 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6615.68 4421.97 4380.97 6710.13 4460.51 4419.51 6808.30 4501.45 4460.45 6904.05 4540.37 4499.37 6998.39 4577.48 4536.48 66 11 N 77.03 W .32 905.48N 3872.64W 65 38 N 77.76 W .91 924.29N 3956.79W 65 4 N 79.70 W 1.89 941.73N 4044.28W 66 57 N 77.39 W 2.96 959.12N 4130.01W 66 42 N 76.99 W .47 978.35N 4214.58W 3977.09 4063.31 4152.47 4239.90 4326.63 7093.99 4615.54 4574.54 7188.87 4654.24 4.613.24 7283.88 4693.27 4652.27 7378.82 4731.91 4690.91 7474.46 4770.02 4729.02 66 22 N 77.13 W .38 997.98N 4300.05W 65 29 N 76.84 W .97 1017.49N 4384.45W 65 59 N 75.93 W 1.02 1037.88N 4468.64W 65 58 N 76.53 W .58 1058.52N 4552.86W 67 3 N 74.41 W 2.32 1080.53N 4637.76W 4414.33 4500.96 4587.57 4674.29 4761.96 7569.11 4807.24 4766.24 7663.12 4844.98 4803.98 7759.16 4884.53 4843.53 7854.14 4924.25 4883.25 7948.70 4962.57 4921.57 66 38 N 76.98 W 2.53 1102.03N 4722.06W 66 1 N 77.12 W .66 1121.33N 4805.97W 65 19 N 77.57 W .84 1140.50N 4891.36W 65 13 N 75.50 W 1.98 1160.59N 4975.25W 66 58 N 74.91 W 1.94 1182.66N 5058.82W 4848.95 4935.05 5022.56 5108.82 5195.22 8044.15 5000.17 4959.17 8139.86 5038.60 4997.60 8235.32 5077.75 5036.75 8330.07 5115.88 5074.88 8426.17 5153.64 5112.64 66 37 N 74.71 W .40 1205.65N 5143.49W 66 1 N 74.52 W .66 1228.90N 5228.00W 65 33 N 75.03 W .69 1251.77N 5312.00W 66 59 N 73.90 W 1.87 1275.00N 5395.56W 66 44 N 74.34 W .49 1299.18N 5480.56W 5282.90 5370.49 5457.50 5544.15 5632.43 8521.62 5191.55 5150.55 8616.86 5229.93 5188.93 8710.95 5268.73 5227.73 8806.34 5308.75 5267.75 8899.87 5348.63 5307.63 66 26 N 73.82 W .59 1323.21N 5564.80W 66 1 N 75.47 W 1.65 1346.29N 5648.84W 65 16 N 74.55 W 1.19 1368.46N 5731.64W 65 5 N 75.77 W 1.18 1390.63N 5815.33W 64 25 N 76.87 W 1.28 1410.64N 5897.53W 5719.92 5807.02 5892.69 5979.23 6063.83 8994.70 5391.72 5350.72 9091.88 5439.92 5398.92 9186.64 5490.84 5449.84 9281.70 5545.82 5504.82 9376.91 5604.55 5563.55 61 30 N 78.98 W 3.66 1428.33N 5980.11W 59 1 N 81.87 W 3.63 1442.39N 6063.30W 55 57 N 82.03 W 3.25 1453.58N 6142.41W 53 22 N 80.95 W 2.87 1465.04N 6219.10W 50 27 N 79.97 W 3.16 1477.45N 6292.99W 6148.27 6232.47 6312.05 6389.33 6464.10 9472.19 5666.85 5625.85 9568.77 5733.43 5692.43 9663.70 5802.14 5761.14 9756.85 5872.58 5831.58 9851.70 5947.13 5906.13 47 51 N 78.74 W 2.90 1490.75N 6363.83W 44 58 N 78.50 W 3.00 1504.55N 6432.40W 42 16 N 78.67 W 2.84 1517.51N 6496.60W 39 26 N 79.46 W 3.10 1529.08N 6556.42W 36 55 N 80.15 W 2.69 1539.46N 6614.11W 6536.10 6606.02 6671.48 6732.36 6790.90 SPEt.._.~-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING MILNE POINT / MPF-09 500292277300 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/30/97 DATE OF SURVEY: 061697 MWD SURVEY JOB NUMBER: AK-MM-70172 KELLY BUSHING ELEV. = 41.00 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 9947.40 6025.09 5984.09 33 57 N 78.04 W 3.35 1549.92N 6668.59W 6846.33 10041.55 6104.11 6063.11 31 52 N 76.71 W 2.35 1561.09N 6718.51W 6897.47 10137.97 6187.22 6146.22 29 2 N 76.94 W 2.94 1572.23N 6766.09W 6946.34 10233.53 6272.20 6231.20 25 21 N 75.55 W 3.91 1582.58N 6808.51W 6990.01 10328.36 6359.02 6318.02 22 2 N 76.62 W 3.52 1591.77N 6845.51W 7028.12 10422.44 6447.07 6406.07 19 10 N 75.05 W 3.12 1599.84N 6877.62W 7061.23 10517.84 6537.72 6496.72 17 5 N 75.33 W 2.18 1607.43N 6906.31W 7090.90 10612.43 6628.26 6587.26 16 31 N 75.34 W .59 1614.36N 6932.78W 7118.24 10708.35 6720.43 6679.43 15 37 N 76.57 W 1.00 1620.81N 6958.54W 7144.81 10803.50 6812.23 6771.23 14 51 N 75.88 W .83 1626.77N 6982.84W 7169.82 10897.10 6902.81 6861.81 14 19 N 75.06 W .62 1632.68N 7005.67W 7193.39 10994.18 6996.97 6955.97 13 50 N 74.97 W .49 1638.78N 7028.48W 7217.00 11089.88 7089.98 7048.98 13 22 N 75.77 W .52 1644.47N 7050.27W 7239.51 11185.01 7182.54 7141.54 13 19 N 76.78 W .25 1649.69N 7071.62W 7261.48 11280.52 7275.53 7234.53 13 2 N 77.51 W .35 1654.54N 7092.85W 7283.27 11326.98 7320.81 7279.81 12 50 N 77.48 W .43 1656.79N 7103.01W 7293.67 11390.00 7382.26 7341.26 12 50 N 77.48 W .03 1659.83N 7116.68W 7307.68 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7307.68 FEET AT NORTH 76 DEG. 52 MIN. WEST AT MD = 11390 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 283.20 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 11,390.00' MD SPE~ .~__~i PAGE 5 -SUN DRILLING SERVICES ANCHOR_AGE ALASKA SHARED SERVICES DRILLING MILNE POINT / MPF-09 500292277300 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/30/97 DATE OF SURVEY: 061697 JOB NUMBER: AK-MM-70172 KELLY BUSHING ELEV. = 41.00 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -41.00 .00 N .00 E 1000.00 999.27 958.27 13.11 N 22.06 W 2000.00 1978.34 1937.34 49.67 N 210.98 W 3000.00 2807.48 2766.48 171.78 N 739.40 W 4000.00 3353.29 3312.29 336.59 N 1554.48 W .00 .73 .73 21.66 20.93 192.52 170.86 646.71 454.19 5000.00 3762.65 3721.65 559.27 N 2439.07 W 6000.00 4173.09 4132.09 778.56 N 3324.09 W 7000.00 4578.12 4537.12 978.68 N 4216.02 W 8000.00 4982.66 4941.66 1194.96 N 5104.39 W 9000.00 5394.26 5353.26 1429.21 N 5984.68 W 1237.35 590.63 1826.91 589.56 2421.88 594.98 3017.34 595.46 3605.74 588.40 10000.00 6068.83 6027.83 1556.04 N 6697.16 W 11000.00 7002.62 6961.62 1639.15 N 7029.83 W 11390.00 7382.26 7341.26 1659.83 N 7116.68 W 3931.17 325.43 3997.38 66.21 4007.74 10.37 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPEt -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPF-09 500292277300 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/30/97 DATE OF SURVEY: 061697 JOB NUMBER: AK-MM-70172 KELLY BUSHING ELEV. = 41.00 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 41.00 41.00 141.00 141.00 241.00 241.00 341.00 341.00 -41.00 .00 N .00 E .00 .00 N .00 E 100.00 .00 N .00 E 200.00 .21 S .41 E 300.00 .44 N .45 E .00 .00 .00 .00 .00 .00 .00 .00 .00 441.04 441.00 400.00 541.06 541.00 500.00 641.08 641.00 600.00 741.15 741.00 700.00 841.30 841.00 800.00 2.69 N 1.10 W 4.36 N 2.05 W 5.72 N 3.05 W 7.44 N 6.10 W 9.80 N 11.09 W .04 .04 .06 .02 .08 .02 .15 .07 .30 .15 941.54 941.00 1041.91 1041.00 1142.51 1141.00 1243.36 1241.00 1344.38 1341.00 900.00 1000.00 1100.00 1200.00 1300.00 12.16 N 17.46 W 13.57 N 25.95 W 14.10 N 36.81 W 14.03 N 49.89 W 14.56 N 64.17 W .54 .24 .91 .37 1.51 .60 2.36 .86 3.38 1.02 1445.82 1441.00 1547.75 1541.00 1650.23 1641.00 1753.26 1741.00 1856.51 1841.00 1400.00 1500.00 1600.00 1700.00 1800.00 17.61 N 80.83 W 22.34 N 100.00 W 28.16 N 121.61 W 34.49 N 145.59 W 40.52 N 170.53 W 4.82 1.44 6.75 1.93 9.23 2.48 12.26 3.03 15.51 3.24 1960.67 1941.00 2066.67 2041.00 2174.91 2141.00 2285.98 2241.00 2400.88 2341.00 1900.00 2000.00 2100.00 2200.00 2300.00 46 54 63 73 85 .93 N 198.96 W .74 N 233.16 W .48 N 273.64 W .27 N 320.91 W .00 N 376.23 W 19.67 4.17 25.67 5.99 33.91 8.25 44.98 11.06 59.88 14.90 2519.79 2441.00 2643.57 2541.00 2772.32 2641.00 2906.65 2741.00 3048.77 2841.00 2400.00 2500.00 2600.00 2700.00 2800.00 99 117 137 158 178 .75 N 438.83 W .68 N 509.49 W .77 N 588.01 W .20 N 675.30 W .55 N 774.18 W 78.79 18.91 102.57 23.77 131.32 28.75 165.65 34.33 207.77 42.12 3200.64 2941.00 3364.88 3041.00 3544.65 3141.00 3744.25 3241.00 3970.03 3341.00 2900.00 3000.00 3100.00 3200.00 3300.00 201 229 258 290 330 .33 N 886.13 W .64 N 1013.26 W .52 N 1159.78 W .02 N 1329.57 W .29 N 1527.87 W 259.64 51.87 323.88 64.24 403.65 79.77 503.25 99.60 -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPF-09 500292277300 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/30/97 DATE OF SURVEY: 061697 JOB NUMBER: AK-MM-70172 KELLY BUSHING ELEV. = 41.00 FT. OPERATOR: BP EXPLOP~ATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTA_NGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TV/D VERTICAL DIFFERENCE CORRECTION 4211.13 3441.00 3400.00 4450.74 3541.00 3500.00 4694.21 3641.00 3600.00 4946.58 3741.00 3700.00 5196.43 3841.00 3800.00 379.99 N 1741.55 432.31 N 1952.90 485.84 N 2168.31 546.55 N 2391.92 602.09 N 2614.03 W W W W W 770.13 141.10 909.74 139.62 1053.21 143.46 1205.58 152.37 1355.43 149.85 5438.76 3941.00 3900.00 5685.09 4041.00 4000.00 5922.42 4141.00 4100.00 6167.44 4241.00 4200.00 6417.57 4341.00 4300.00 657.66 N 2827.64 711.14 N 3046.31 761.76 N 3255.49 815.05 N 3472.72 865.25 N 3696.38 1497.76 142.33 1644.09 146.33 1781.42 137.33 1926.44 145.02 2076.57 150.12 6662.78 4441.00 4400.00 6905.66 4541.00 4500.00 7156.96 4641.00 4600.00 7401.14 4741.00 4700.00 7653.33 4841.00 4800.00 915.12 N 3914.63 959.44 N 4131.46 1010.88 N 4356.18 1063.27 N 4572.69 1119.34 N 4797.26 W W W W W 2221.78 145.21 2364.66 142.89 2515.96 151.29 2660.14 144.19 2812.33 152.19 7894.09 4941.00 4900.00 8145.76 5041.00 5000.00 8394.17 5141.00 5100.00 8644.09 5241.00 5200.00 8882.20 5341.00 5300.00 1169.67 N 5010.37 1230.34 N 5233.20 1291.24 N 5452.25 1352.53 N 5672.92 1407.02 N 5882.00 W W W W W 2953.09 140.76 3104.76 151.67 3253.17 148.40 3403.09 149.92 3541.20 138.11 9093.94 5441.00 5400.00 9273.56 5541.00 5500.00 9433.23 5641.00 5600.00 9579.44 5741.00 5700.00 9715.56 5841.00 5800.00 1442.63 N 6065.04 1464.02 N 6212.63 1485.19 N 6335.22 1506.04 N 6439.77 1524.13 N 6530.30 W W W W W 3652.94 111.74 3732.56 79.62 3792.23 59.67 3838.44 46.21 3874.56 36.12 9844.04 5941.00 5900.00 9966.58 6041.00 6000.00 10084.68 6141.00 6100.00 10198.80 6241.00 6200.00 10308.86 6341.00 6300.00 1538.68 N 6609.57 1552.14 N 6679.08 1566.20 N 6740.27 1578.85 N 6793.73 1590.02 N 6838.26 3903.04 28.47 3925.58 22.55 3943.68 18.10 3957.80 14.12 3967.86 10.06 10416.01 6441.00 6400.00 10521.28 6541.00 6500.00 10625.72 6641.00 6600.00 10729.71 6741.00 6700.00 10833.27 6841.00 6800.00 1599.30 N 6875.55 1607.69 N 6907.29 1615.31 N 6936.43 1622.15 N 6964.14 1628.63 N 6990.25 W W W W W 3975.01 7.15 3980.28 5.27 3984.72 4.44 3988.71 4.00 3992.27 3.56 SPE}. -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPF-09 500292277300 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/30/97 DATE OF SURVEY: 061697 JOB NUMBER: AK-MM-70172 KELLY BUSHING ELEV. = 41.00 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 10936.52 6941.00 6900.00 1635.19 N 7015.09 W 3995.52 3.25 11039.53 7041.00 7000.00 1641.60 N 7038.96 W 3998.53 3.01 11142.32 7141.00 7100.00 1647.44 N 7062.03 W 4001.32 2.79 11245.07 7241.00 7200.00 1652.81 N 7085.05 W 4004.07 2.75 11347.69 7341.00 7300.00 1657.79 N 7107.50 W 4006.69 2.61 11380.00 7372.50 7331.50 1659.34 N 7114.51 W 4007.50 .81 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPER.~ .-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION MILNE POINT / MPF-09 500292277300 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/17/97 DATE OF SURVEY: 061197 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70176 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 O0 -41.30 133.31 133.31 92.01 223.81 223.81 182.51 314.31 314.30 273.00 404.81 404.79 363.49 COURS INCLN DG MN 0 0 0 26 0 16 0 44 1 17 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST N .00 E .00 .00N .00E S 42.82 E .33 .38S .35E S 57.43 E .21 .76S .78E N 32.33 W 1.10 .39S .65E N 36.24 W .63 .93N .26W VERT. SECT. .00 - .43 -.93 -.72 .47 495.31 495.27 453.97 585.81 585.77 544.47 676.31 676.23 634.93 766.81 766.64 725.34 857.31 856.99 815.69 0 32 0 45 2 7 2 59 3 35 N 31.92 W .83 2.13N 1.10W N 47.21 W .30 2.90N 1.77W N 68.59 W 1.60 3.92N 3.77W N 73.38 W .98 5.20N 7.59W N 71.64 W .68 6.77N 12.54W 1.56 2.38 4.56 8.57 13 .75 947.81 947.25 905.95 1033.48 1032.57 991.27 1138.87 1137.30 1096.00 1234.40 1232.03 1190.73 1330.22 1326.89 1285.59 4 38 5 39 7 6 7 41 8 31 N 85.61 W 1.59 7.94N 18.88W N 87.74 W 1.21 8.38N 26.55W S 87.56 W 1.46 8.30N 38.25W S 88.76 W .64 7.91N 50.56W N 83.98 W 1.37 8.52N 64.03W 20.19 27.76 39.14 51.03 64.29 1425.74 1421.07 1379.77 10 36 1521.19 1514.78 1473.48 11 16 1616.58 1608.03 1566.73 12 58 1710.96 1699.85 1658.55 13 48 1806.44 1792.57 1751.27 13 48 N 77.55 W 2.46 ll.16N 79.66W N 75.98 W .75 15.31N 97.29W N 75.85 W 1.79 20.19N 116.72W N 76.74 W .90 25.36N 137.96W N 77.51 W .19 30.44N 160.17W 80.10 98.22 118.25 140.10 162.89 1902.32 1885.12 1843.82 16 26 1997.59 1975.78 1934.48 19 18 2093.27 2065.33 2024.03 21 52 2189.01 2153.16 2111.86 24 59 2278.57 2233.24 2191.94 28 11 N 78.73 W 2.76 35.57N 184.66W N 77.85 W 3.03 41.52N 213.29W N 78.52 W 2.69 48.40N 246.24W N 79.17 W 3.26 55.75N 283.60W N 78.61 W 3.59 63.49N 322.93W 187.90 217.14 250.78 288.83 328.90 2379.08 2320.58 2279.28 31 6 2474.82 2401.48 2360.18 33 30 2570.33 2479.99 2438.69 35 52 2665.67 2556.07 2514.77 38 12 2760.17 2629.12 2587.82 40 30 N 77.65 W 2.93 73.74N 371.58W N 76.89 W 2.54 85.02N 421.47W N 77.03 W 2.49 97.28N 474.42W N 77.07 W 2.45 l10.15N 530.39W N 77.10 W 2.42 123.55N 588.79W 378.60 429.75 484.10 541.53 601.45 2855.97 2700.86 2659.56 42 29 2951.75 2770.33 2729.03 44 30 3047.48 2836.96 2795.66 47 15 3142.98 2900.46 2859.16 49 21 3238.73 2961.47 2920.17 51 28 N 77.85 W 2.14 137.30N 650.75W N 78.90 W 2.25 150.57N 715.32W N 79.22 W 2.88 163.61N 782.80W N 79.48 W 2.20 176.78N 852.87W N 78.70 W 2.31 190.75N 925.31W 664.91 730.80 799.47 870.70 944.43 ~ ~ SPEA ,~ PAGE 2 -SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION MILNE POINT / MPF-09 500292277300 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/17/97 DATE OF SURVEY: 061197 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70176 KELLY BUSHING ELEV. = 41.30 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3334.45 3019.48 2978.18 53 53 N 78.96 W 2.53 205.50N 999.98W 1020.49 3429.76 3074.42 3033.12 55 41 N 79.61 W 1.97 219.97N 1076.49W 1098.28 3525.44 3127.10 3085.80 57 29 N 79.26 W 1.91 234.61N 1154.99W 1178.05 3621.14 3177.23 3135.93 59 19 N 79.67 W 1.96 249.52N 1235.13W 1259.47 3715.10 3223.90 3182.60 61 5 N 79.14 W 1.94 264.52N 1315.27W 1340.92 3810.97 3268.91 3227.61 62 53 N 78.89 W 1.89 280.65N 1398.35W 1425.50 3906.77 3311.38 3270.08 64 27 N 77.65 W 2.00 298.11N 1482.41W 1511.32 4001.75 3351.16 3309.86 66 0 N 76.95 W 1.76 317.07N 1566.54W 1597.55 4097.28 3390.45 3349.15 65 25 N 76.90 W .60 336.76N 1651.36W 1684.63 4192.78 3430.56 3389.26 64 54 N 76.47 W .68 356.72N 1735.70W 1771.30 4287.61 3471.40 3430.10 64 4 N 76.60 W .89 376.65N 1818.93W 1856.88 4381.92 3511.05 3469.75 66 12 N 75.59 W 2.46 397.21N 1901.97W 1942.42 4477.69 3550.31 3509.01 65 23 N 75.46 W .85 419.05N 1986.55W 2029.75 4573.37 3590.43 3549.13 65 1 N 75.63 W .42 440.73N 2070.66W 2116.59 4668.06 3628.94 3587.64 66 58 N 75.39 W 2.07 462.38N 2154.40W 2203.06 4763.65 3666.33 3625.03 66 58 N 75.35 W .04 484.60N 2239.52W 2291.01 4859.38 3704.23 3662.93 66 22 N 75.04 W .70 507.06N 2324.50W 2378.88 4954.51 3742.69 3701.39 65 56 N 75.07 W .46 529.51N 2408.57W 2465.84 5050.00 3780.94 3739.64 66 50 N 75.63 W 1.09 551.64N 2493.21W 2553.31 5145.60 3818.95 3777.65 66 17 N 75.30 W .65 573.65N 2578.12W 2641.00 5241.27 3857.95 3816.65 65 35 N 73.92 W 1.50 596.83N 2662.34W 2728.29 5336.74 3897.72 3856.42 65 9 N 73.61 W .54 621.09N 2745.67W 2814.96 5430.82 3936.46 3895.16 66 12 N 75.99 W 2.56 643.56N 2828.39W 2900.62 5526.46 3975.03 3933.73 66 13 N 76.03 W .05 664.71N 2913.31W 2988.13 5621.17 4013.35 3972.05 66 2 N 75.07 W .95 686.32N 2997.18W 3074.71 5716.95 4052.75 4011.45 65 22 N 75.82 W 1.00 708.26N 3081.68W 3161.99 5812.18 4092.96 4051.66 64 39 N 75.35 W .87 729.75N 3165.28W 3248.29 5907.02 4133.93 4092.63 64 9 N 76.93 W 1.60 750.23N 3248.32W 3333.81 6002.72 4174.43 4133.13 65 47 N 74.30 W 3.02 771.78N 3332.29W 3420.49 6089.00 4210.01 4168.71 65 30 N 75.46 W 1.26 792.29N 3408.17W 3499.04 6184.62 4248.23 4206.93 67 22 N 75.46 W 1.96 814.29N 3492.99W 3586.65 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3586.65 FEET AT NORTH 76 DEG. 52 MIN. WEST AT MD = 6184 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 283.20 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD LAST SURVEY STATION AT 6,184.62' MD SPE5 .... -SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE 3 BP EXPLORATION MILNE POINT / MPF-09 500292277300 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/17/97 DATE OF SURVEY: 061197 JOB NUMBER: AK-EI-70176 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .00 .00 -41.30 .00 N .00 E .0 1000.00 999.26 957.96 8.25 N 23.25 W .7 2000.00 1978.05 1936.75 41.69 N 214.07 W 21.9 3000.00 2804.32 2763.02 157.12 N 748.93 W 195.6 4000.00 3350.45 3309.15 316.71 N 1564.98 W 649.5 .74 21.21 173.73 453.87 5000.00 3761.24 3719.94 540.21 N 2448.70 W 1238.7 6000.00 4173.31 4132.01 771.11 N 3329.90 W 1826.6 6184.62 4248.23 4206.93 814.29 N 3492.99 W 1936.3 589.21 587.93 109.70 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE~ <j. PAGE 4 -SUN DRILLING SERVICES ANCHOR_AGE ALASKA BP EXPLORATION MILNE POINT / MPF-09 500292277300 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/17/97 DATE OF SURVEY: 061197 JOB NUMBER: AK-EI-70176 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -41.30 41.30 41.30 .00 141.30 141.30 100.00 241.30 241.30 200.00 341.31 341.30 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .43 S .39 E .00 .00 .80 S .85 E .00 .00 .09 S .47 E .01 .01 441.33 441.30 400 541.34 541.30 500 641.35 641.30 600 741.44 741.30 700 841.59 841.30 800 .00 .00 .00 .00 .00 1.59 N .75 2.50 N 1.34 3.44 N 2.56 4.82 N 6.32 6.46 N 11.60 W .03 .02 W .04 .01 W .05 .01 W .14 .08 W .29 .15 941. 84 941.30 1042.25 1041. 30 1142 . 90 1141 . 30 1243 . 75 1241 . 30 1344. 79 1341.30 9O0 1000 1100 1200 1300 .00 .00 .00 .00 .00 7.91 N 18.40 8.41 N 27.41 8.28 N 38.75 7.89 N 51.81 8.74 N 66.18 W .54 .25 W .95 .41 W 1.60 .65 W 2.45 .85 W 3.49 1.04 1446.32 1441.30 1548.23 1541.30 1650.72 1641.30 1753.65 1741.30 1856.78 1841.30 1400.00 1500.00 1600.00 1700.00 1800.00 11.98 N 83.36 16.59 N 102.42 22.06 N 124.15 27.69 N 147.87 33.09 N 172.51 5.02 1.54 6.93 1.91 9.42 2.49 12.35 2.93 15.48 3.13 1961.18 1941.30 2067 . 44 2041 . 30 2175 . 95 2141.30 2287 . 74 2241.30 2403 .28 2341.30 1900 2000 2100 2200 2300 .00 .00 .00 .00 .00 39.09 N 201.84 46.50 N 236.97 54.72 N 278.24 64.36 N 327.22 76.41 N 383.79 19.88 4.40 26.14 6.26 34.65 8.51 46.44 11.79 61.98 15.54 2522.64 2441.30 2646.87 2541.30 2776.19 2641.30 2911.10 2741.30 3053.89 2841.30 2400 2500 2600 2700 2800 .00 .00 .00 .00 .00 91.02 N 447.26 107.55 N 519.06 125.87 N 598.93 145.08 N 687.40 164.49 N 787.42 81.34 19.35 105.57 24.23 134.89 29.32 169.80 34.91 212.59 42.79 3206.35 2941.30 3371.48 3041.30 3551.86 3141.30 3751.11 3241.30 3977.49 3341.30 2900.00 3000.00 3100.00 3200.00 3300.00 185.79 N 900.47 211.23 N 1029.35 238.77 N 1176.88 270.46 N 1346.23 312.07 N 1544.95 265.05 52.46 330.18 65.13 410.56 80.37 509.81 99.25 636.19 126.39 PAGE 5 SPEi.__j.-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION MILNE POINT / MPF-09 500292277300 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/17/97 DATE OF SURVEY: 061197 JOB NUMBER: AK-EI-70176 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 4218.11 3441.30 3400.00 362.09 N 1758.00 W 776.81 4456.05 3541.30 3500.00 414.11 N 1967.50 W 914.75 4699.66 3641.30 3600.00 469.71 N 2182.54 W 1058.36 4951.10 3741.30 3700.00 528.70 N 2405.56 W 1209.80 5200.98 3841.30 3800.00 586.66 N 2627.09 W 1359.68 140.61 137.94 143 . 61 151.43 149.88 5442.82 3941.30 3900.00 646.22 N 2839.04 W 1501.52 5689.48 4041.30 4000.00 702.14 N 3057.46 W 1648.18 5924.03 4141.30 4100.00 753.77 N 3263.23 W 1782.73 6166.60 4241.30 4200.00 810.12 N 3476.90 W 1925.30 6184.62 4248.23 4206.93 814.29 N 3492.99 W 1936.39 141.84 146.66 134.56 142.57 11.09 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST .20 FOOT MD (FROM MINIMUM CURVATURE) POINTS B.P. EXPLORATION F PAD, WELL NO. MPF-09 MILNE POINT FIELD, ALASKA Gyro Multishot Survey Inside 7" CASING Survey date: 11 -JULY, 1997 Job number :A0797GCE414 ORIGINAL CONTENTS JOB NUMBER :A0797GCE414 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION , SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER- A0797GCE414 Tool 777 was run in WELL# MPF-09 on SCHLUMBERGER 3/8" wireline inside CASING. The survey was run without problems. SURVEY CERTIFICATION SHEET JOB NUMBER: A0797GCE414 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: A0797GCE414 CLIENT: B.P. EXPLORATION RIG: SCHLUMBERGER LOCATION: F PAD, ALASKA WELL: MPF-09 LATITUDE: 70.505 N LONGITUDE: 149.5 W SURVEY DATE: 11, JULY, 1997 SURVEY TYPE : GYRO CONTINUOUS MULTISHOT IN 7" CASING DEPTH REFERENCE: 41.0' MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 11200' SURVEY TIED ONTO: NA SURVEY INTERVAL: 0-11200' APl NUMBER: 050-029-22766 TARGET DIRECTION: 283.20 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. INRUN SURVEY LISTING A Gyr oda t a D i r e c t i on a i Survey for B.P. EXPLORATION F PAD, WELL NO. MPF-09 MILNE POINT FIELD, ALASKA Job Number: A0797GCE414 Run Date: Il-Jul-97 11:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 41 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 283.200 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i r e c t i ona i Survey ~.p. EXPLORATION PAD, WELL NO. MPF-09 4ILNE POINT FIELD, ALASKA Iob Number: A0797GCE414 Page 4EASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 0.0 100.0 201.0 300.0 401.0 0.00 0.00 0.0 .10 25.29 100.0 .26 123.93 201.0 .23 349.65 300.0 1.31 333.56 401.0 0.0 0.00 0.0 0.0 -.0 .10 .1 25.3 - .2 .29 .3 83.3 - .4 .45 .4 76.5 .4 1.08 1.3 354.1 0.00 N 0.00 E .08 N .04 E .03 N .26 E .10 N .41 E 1.33 N .14 W 501.0 600.0 701.0 801.0 901.0 1.09 324.73 501.0 .99 323.32 600.0 2.33 295.13 700.9 3.21 295.11 800.8 3.72 289.09 900.6 1.9 .29 3.4 339.1 3.2 .11 5.1 333.9 5.9 1.51 7.7 323.1 10.6 .88 12.2 312.4 16.6 .63 18.0 305.6 3.14 N 1.20 W 4.59 N 2.25 W 6.16 N 4.63 W 8.20 N 9.00 W 10.45 N 14.60 W 1002.0 1100.0 1201.0 1301.0 1401.0 4.97 279.88 1001.3 6.15 273.00 1098.9 7.59 269.01 1199.1 8.11 271.31 1298.2 9.50 278.89 1397.0 24.2 1.41 25.2 299.2 33.6 1.38 34.1 292.9 45.4 1.51 45.5 287.2 58.7 .60 58.7 283.3 73.8 1.81 73.9 281.7 12.28 N 22.00 W 13.28 N 31.42 W 13.45 N 43.50 W 13.49 N 57.15 W 14.93 N 72.35 W 1501.0 1601.0 1701.0 1802.0 1901.0 11.08 283.45 1495.4 12.28 284.12 1593.3 13.80 283.64 1690.7 14.10 282.90 1788.8 15.82 281.52 1884.4 91.7 1.78 91.7 281.6 111.9 1.20 112.0 282.0 134.5 1.53 134.5 282.3 158.8 .34 158.9 282.5 184.4 1.78 184.4 282.4 18.44 N 89.85 W 23.27 N 109.51 W 28.67 N 131.42 W 34.26 N 155.11 W 39.64 N 180.09 W 1950.0 2000.0 2050.0 2100.0 2150.0 16.81 281.69 1931.4 18.76 281.92 1979.0 19.99 282.23 2026.2 21.65 282.07 2072.9 22.65 281.69 2119.3 198.1 2.03 198.2 282.4 213.4 3.89 213.4 282.3 230.0 2.48 230.0 282.3 247.8 3.31 247.8 282.3 266.6 2.01 266.6 282.3 42.41 N 193.57 W 45.54 N 208.52 W 49.01 N 224.74 W 52.75 N 242.11 W 56.63 N 260.56 W A Gyro da t a D i r e c t i ona i Survey ~.p. EXPLORATION PAD, WELL NO. MPF-09 4ILNE POINT FIELD, ALASKA Iob Number: A0797GCE414 Page 4EASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2200.0 24.69 280.94 2165.1 2250.0 25.99 281.22 2210.2 2300.0 27.96 281.76 2254.8 2350.0 29.37 281.80 2298.7 2400.0 31.00 282.18 2341.9 286.7 4.13 286.7 282.2 308.1 2.62 308.1 282.1 330.7 3.95 330.8 282.1 354.7 2.82 354.8 282.1 379.8 3.29 379.9 282.1 60.56 N 280.24 W 64.68 N 301.24 W 69.20 N 323.47 W 74.09 N 346.94 W 79.32 N 371.53 W 2450.0 32.24 282.41 2384.5 2500.0 33.45 282.87 2426.5 2550.0 34.90 282.97 2467.8 2600.0 35.92 283.08 2508.6 2650.0 37.15 282.88 2548.8 406.0 2.48 406.1 282.1 433.1 2.48 433.2 282.1 461.2 2.91 461.3 282.2 490.2 2.04 490.3 282.2 520.0 2.47 520.0 282.2 84.90 N 397.14 W 90.84 N 423.60 W 97.11 N 450.97 W 103.64 N 479.20 W 110.33 N 508.21 W 2700.0 38.40 282.76 2588.3 2750.0 39.82 282.63 2627.1 2800.0 40.67 282.52 2665.2 2850.0 41.92 282.12 2702.8 2900.0 42.84 281.63 2739.7 550.6 2.50 550.7 282.3 582.1 2.84 582.2 282.3 614.4 1.71 614.5 282.3 647.4 2.54 647.5 282.3 681.1 1.97 681.2 282.3 117.12 N 124.05 N 131.08 N 138.12 N 145.06 N 538.07 W 568.84 W 600.37 W 632.61 W 665.59 W 2950.0 44.26 280.78 2776.0 3000.0 45.02 280.43 2811.6 3050.0 46.70 280.11 2846.4 3100.0 47.77 280.08 2880.3 3150.0 49.11 279.83 2913.5 715.6 3.06 715.7 282.2 750.6 1.60 750.8 282.2 786.5 3.41 786.6 282.1 823.1 2.14 823.3 282.0 860.5 2.69 860.7 281.9 151.75 N 158.21 N 164.61 N 171.04 N 177.51 N 699.38 W 733.91 W 769.21 W 805.35 W 842.20 W 3200.0 50.00 279.82 2945.9 3250.0 51.19 279.95 2977.7 3300.0 52.25 279.83 3008.6 3350.0 53.52 279.67 3038.8 3400.0 54.55 279.58 3068.2 898.5 1.79 898.7 281.8 937.0 2.38 937.3 281.7 976.2 2.13 976.6 281.7 1016.0 2.56 1016.4 281.6 1056.4 2.06 1056.9 281.5 184.00 N 190.63 N 197.37 N 204.12 N 210.88 N 879.70 W 917.76 W 956.42 W 995.72 W 1035.62 W A Gyr oda t a D i r e c t i on a i Survey ~.P. EXPLORATION PAD, WELL NO. MPF-09 ~ILNE POINT FIELD, ALASKA lob Number: A0797GCE414 Page ~EASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 3450.0 55.69 279.48 3096.8 3500.0 56.64 279.39 3124.6 3550.0 57.61 279.42 3151.7 3600.0 58.52 279.38 3178.2 3650.0 59.49 279.54 3203.9 1097.3 2.29 1097.9 281.4 1138.8 1.91 1139.4 281.4 1180.7 1.94 1181.3 281.3 1223.0 1.82 1223.8 281.2 1265.8 1.97 1266.6 281.2 217.67 N 224.48 N 231.34 N 238.27 N 245.32 N 1076.07 W 1117.04 W 1158.47 W 1200.33 W 1242.61 W 3700.0 60.51 279.95 3228.9 3750.0 61.26 280.10 3253.3 3800.0 62.27 280.09 3276.9 3850.0 63.05 280.26 3299.9 3900.0 64.00 280.79 3322.2 1309.0 2.14 1309.9 281.1 1352.6 1.52 1353.6 281.1 1396.6 2.02 1397.6 281.1 1441.0 1.61 1442.0 281.0 1485.7 2.12 1486.8 281.0 252.65 N 260.25 N 267.97 N 275.82 N 284.00 N 1285.28 W 1328.30 W 1371.66 W 1415.38 W 1459.38 W 3950.0 64.48 281.55 3343.9 4000.0 65.68 282.11 3365.0 4050.0 65.84 282.30 3385.5 4100.0 65.49 282.34 3406.1 4150.0 65.27 282.47 3426.9 1530.7 1.67 1531.8 281.0 1576.0 2.61 1577.1 281.0 1621.6 .47 1622.7 281.1 1667.1 .71 1668.3 281.1 1712.6 .51 1713.7 281.1 292.72 N 302.02 N 311.66 N 321.38 N 331.14 N 1503.56 W 1547.94 W 1592.51 W 1637.01 W 1681.40 W 4200.0 65.01 282.53 3448.0 4250.0 64.73 282.66 3469.2 4300.0 64.39 282.76 3490.7 4350.0 64.80 282.81 3512.1 4400.0 65.99 282.84 3532.9 1758.0 .52 1759.1 281.2 1803.2 .62 1804.3 281.2 1848.4 .69 1849.4 281.2 1893.5 .83 1894.6 281.3 1939.0 2.36 1940.0 281.3 340.96 N 350.83 N 360.77 N 370.76 N 380.85 N 1725.70 W 1769.87 W 1813.92 W 1857.96 W 1902.29 W 4450.0 65.82 283.11 3553.4 4500.0 65.42 283.23 3574.0 4550.0 65.10 283.39 3594.9 4600.0 65.04 283.46 3616.0 4650.0 66.00 283.40 3636.7 1984.6 .60 1985.7 281.4 2030.2 .81 2031.2 281.4 2075.6 .71 2076.6 281.4 2120.9 .16 2121.9 281.5 2166.4 1.92 2167.4 281.5 391.10 N 401.47 N 411.93 N 422.46 N 433.03 N 1946.77 W 1991.11 W 2035.30 W 2079.40 W 2123.66 W A Gyr oda t a D i r e c t i ona i Survey J.P. EXPLORATION PAD, WELL NO. MPF-09 ~ILNE POINT FIELD, ALASKA ;ob Number: A0797GCE414 4EASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 4700.0 66.88 283.64 3656.7 4750.0 66.92 283.91 3676.3 4800.0 66.87 283.98 3695.9 4850.0 66.58 284.02 3715.7 4900.0 66.17 283.99 3735.7 4950.0 66.03 284.11 3756.0 5000.0 65.93 283.71 3776.3 5050.0 66.56 283.25 3796.5 5100.0 66.62 283.41 3816.3 5150.0 66.41 283.64 3836.3 5200.0 66.10 283.76 3856.4 5250.0 65.52 283.95 3876.9 5300.0 65.30 284.11 3897.7 5350.0 65.15 284.13 3918.6 5400.0 65.46 283.28 3939.5 5450.0 66.19 282.58 3960.0 5500.0 65.95 282.70 3980.3 5550.0 66.03 282.84 4000.6 5600.0 66.11 282.83 4020.9 5650.0 65.96 283.01 4041.2 5700.0 65.66 283.05 4061.7 5750.0 65.23 283.04 4082.5 5800.0 65.06 283.06 4103.5 5850.0 64.63 283.22 4124.8 5900.0 64.39 283.46 4146.3 2212.3 2258.3 2304.2 2350.2 2396.0 2441.7 2487.3 2533.1 2579.0 2624.9 2670.6 2716.2 2761.7 2807.1 2852.5 2898.1 2943.8 2989.5 3035.2 3080.9 3126.5 3172.0 3217.3 3262.6 3307.7 1.82 2213.2 281.6 .49 2259.1 281.6 .16 2305.1 281.7 .60 2351.0 281.7 .82 2396.7 281.7 .36 2442.4 281.8 .76 2488.1 281.8 .51 2533.8 281.9 .32 2579.7 281.9 .60 2625.5 281.9 .65 2671.3 281.9 .22 2716.8 282.0 .53 2762.3 282.0 .29 2807.7 282.0 .67 2853.1 282.1 .93 2898.7 282.1 .51 2944.4 282.1 .31 2990.0 282.1 .17 3035.7 282.1 .45 3081.4 282.1 .61 3127.0 282.1 .86 3172.5 282.2 .34 3217.9 282.2 .91 3263.1 282.2 .65 3308.2 282.2 Page HORIZONTAL COORDINATES feet 443.74 N 454.69 N 465.77 N 476.88 N 487.96 N 499.06 N 510.04 N 520.71 N 531.28 N 542.01 N 552.85 N 563.77 N 574.79 N 585.87 N 596.64 N 606.84 N 616.84 N 626.94 N 637.09 N 647.30 N 657.59 N 667.85 N 678.09 N 688.38 N 698.80 N 2168.23 W 2212.90 W 2257.53 W 2302.10 W 2346.55 W 2390.89 W 2435.22 W 2479.72 W 2524.37 W 2568.96 W 2613.43 W 2657.71 W 2701.82 W 2745.84 W 2789.98 W 2834.43 W 2879.03 W 2923.57 W 2968 13 W 3012 67 W 3057.10 W~ 3101 40 Wi~::~' 3145 60 3189 67 ,~.~ A Gyro da t a D i r e c t i on a i Survey t.P. EXPLORATION ~ PAD, WELL NO. MPF-09 IILNE POINT FIELD, ALASKA [ob Number: A0797GCE414 Page ~EASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 5950.0 64.45 283.31 4167.9 6000.0 65.60 283.10 4189.0 6050.0 65.74 283.10 4209.6 6100.0 65.67 283.05 4230.2 6150.0 65.91 282.74 4250.7 3352.8 .30 3353.3 282.2 3398.1 2.34 3398.6 282.2 3443.7 .28 3444.2 282.2 3489.3 .18 3489.8 282.2 3534.9 .74 3535.4 282.3 709.24 N 719.59 N 729.92 N 740.23 N 750.41 N 3277.46 W 3321.58 W 3365.96 W 3410.35 W 3454.80 W 6200 6250 6300 6350 6400 .0 67.27 282.35 4270.5 .0 67.18 282.15 4289.9 .0 65.89 282.42 4309.8 .0 65.91 282.35 4330.2 .0 65.32 282.12 4350.9 3580.8 2.82 3581.2 282.3 3626.9 .42 3627.3 282.3 3672.7 2.62 3673.2 282.3 3718.3 .13 3718.8 282.3 3763.9 1.25 3764.4 282.3 760.37 N 770.15 N 779.91 N 789.70 N 799.35 N 3499.59 W 3544.64 W 3589.45 W 3634.03 W 3678.54 W 6450 6500 6550 6600 6650 .0 64.66 282.01 4372.0 .0 65.44 282.62 4393.1 .0 66.14 282.86 4413.6 .0 66.15 282.78 4433.8 .0 66.07 282.66 4454.1 3809.2 1.32 3809.7 282.3 3854.5 1.91 3855.0 282.3 3900.1 1.46 3900.6 282.3 3945.8 .14 3946.4 282.3 3991.5 .27 3992.1 282.3 808.82 N 818.49 N 828.55 N 838.69 N 848.76 N 3722.85 W 3767.14 W 3811.61 W 3856.20 W 3900.80 W 6700 6750 6800 6850 6900 .0 65.77 282.71 4474.5 .0 65.35 282.43 4495.2 .0 65.11 282.16 4516.1 .0 65.16 282.11 4537.1 .0 66.82 284.25 4557.5 4037.2 .62 4037.7 282.3 4082.7 .98 4083.2 282.3 4128.1 .69 4128.6 282.3 4173.5 .13 4174.0 282.3 4219.1 5.12 4219.7 282.3 858.78 N 868.68 N 878.35 N 887.88 N 898.30 N 3945.33 W 3989.76 W 4034.12 W 4078.47 W 4122.93 W 6950.0 66.97 284.22 4577.1 7000.0 66.83 283.97 4596.7 7050.0 66.38 283.41 4616.6 7100.0 66.23 283.18 4636.7 7150.0 65.94 282.97 4656.9 4265.1 .30 4265.6 282.3 4311.1 .52 4311.6 282.3 4357.0 1.37 4357.5 282.3 4402.8 .52 4403.2 282.4 4448.5 .69 4448.9 282.4 909.61 N 920.81 N 931.67 N 942.20 N 952.54 N 4167.51 W 4212.12 W 4256.70 W 4301.26 W 4345.78 W A Gyr oda t a D i r e c t i ona i Survey ~.P. EXPLORATION ? PAD, WELL NO. MPF-09 ~ILNE POINT FIELD, ALASKA Sob Number: A0797GCE414 Page 4EASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 7200.0 65.31 282.75 4677.6 7250.0 65.63 283.01 4698.3 7300.0 66.04 283.31 4718.8 7350.0 66.01 283.12 4739.1 7400.0 65.80 282.97 4759.5 4494.0 1.32 4494.5 282.4 4539.5 .80 4540.0 282.4 4585.1 .98 4585.6 282.4 4630.8 .35 4631.3 282.4 4676.5 .50 4676.9 282.4 962.68 N 972.82 N 983.21 N 993.65 N 1003.96 N 4390.18 W 4434.52 W 4478.94 W 4523.42 W 4567.89 W 7450.0 66.63 283.59 4779.7 7500.0 66.98 283.79 4799.4 7550.0 66.80 283.58 4819.0 7600.0 66.38 283.12 4838.9 7650.0 66.06 282.79 4859.0 4722.2 2.01 4722.7 282.4 4768.2 .79 4768.6 282.4 4814.1 .52 4814.6 282.4 4860.0 1.19 4860.5 282.4 4905.8 .88 4906.2 282.4 1014.47 N 1025.34 N 1036.23 N 1046.82 N 1057.09 N 4612.42 W 4657.07 W 4701.75 W 4746.40 W 4790.99 W 7700.0 65.80 282.52 4879.4 7750.0 65.39 282.40 4900.1 7800.0 64.97 282.51 4921.1 7850.0 65.15 283.88 4942.1 7900.0 65.38 284.17 4963.1 4951.4 .73 4951.9 282.4 4997.0 .85 4997.4 282.4 5042.3 .85 5042.8 282.4 5087.7 2.52 5088.1 282.5 5133.1 .69 5133.5 282.5 1067.09 N 1076.91 N 1086.70 N 1097.05 N 1108.05 N 4835.53 W 4879.99 W 4924.30 W 4968.44 W 5012.50 W 7950.0 66.93 284.90 4983.3 8000.0 66.91 284.83 5002.9 8050.0 66.55 284.70 5022.6 8100.0 66.18 284.62 5042.7 8150.0 66.06 284.46 5062.9 5178.8 3.37 5179.2 282.5 5224.8 .13 5225.2 282.5 5270.7 .76 5271.1 282.5 5316.5 .75 5316.8 282.5 5362.2 .39 5362.5 282.6 1119.53 N 1131.33 N 1143.03 N 1154.63 N 1166.11 N 5056.77 W 5101.23 W 5145.65 W 5189.96 W 5234.22 W 8200.0 65.89 284.22 5083.3 8250.0 65.46 284.06 5103.9 8300.0 66.12 284.18 5124.4 8350.0 67.08 284.09 5144.2 8400.0 66.99 283.97 5163.7 5407.9 .55 5408.2 282.6 5453.4 .90 5453.7 282.6 5499.0 1.33 5499.3 282.6 5544.9 1.92 5545.2 282.6 5590.9 .29 5591.2 282.6 1177.42 N 1188.55 N 1199.68 N 1210.88 N 1222.05 N 5278.46 W 5322.64 W 5366.87 W 5411.37 W 5456.03 W A Gyro da t a D i r e c t i ona i Survey ~.P. EXPLORATION ? PAD, WELL NO. MPF-09 ~ILNE POINT FIELD, ALASKA Iob Number: A0797GCE414 Page ~EASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 8450.0 8500.0 8550.0 8600.0 8650.0 66.61 283.56 5183.4 66.62 283.35 5203.3 66.37 282.89 5223.2 66.33 282.49 5243.3 65.88 282.33 5263.5 5636.9 1.07 5637.2 282.6 5682.8 .38 5683.0 282.6 5728.6 .98 5728.9 282.6 5774.4 .74 5774.7 282.6 5820.1 .96 5820.4 282.6 1232.98 N 1243.66 N 1254.07 N 1264.13 N 1273.95 N 5500.67 W 5545.30 W 5589.95 W 5634.64 W 5679.28 W 8700.0 8750.0 8800.0 8850.0 8900.0 65.52 282.18 5284.1 65.18 281.99 5305.0 65.13 281.74 5326.0 64.89 281.63 5347.1 64.51 281.47 5368.5 5865.7 .76 5866.0 282.6 5911.1 .77 5911.4 282.6 5956.5 .46 5956.8 282.6 6001.8 .52 6002.1 282.6 6047.0 .81 6047.3 282.6 1283.62 N 1293.13 N 1302.46 N 1311.64 N 1320.69 N 5723.82 W 5768.25 W 5812.65 W 5857.03 W 5901.32 W 8950.0 9000.0 9050.0 9100.0 9150.0 64.14 281.05 5390.1 61.96 280.55 5412.8 61.37 279.98 5436.5 59.20 278.66 5461.3 58.31 278.39 5487.2 6092.0 1.06 6092.3 282.6 6136.5 4.45 6136.9 282.6 6180.5 1.54 6180.9 282.6 6223.8 4.91 6224.2 282.6 6266.4 1.84 6266.9 282.5 1329.49 N 1337.84 N 1345.69 N 1352.73 N 1359.06 N 5945.52 W 5989.29 W 6032.60 W 6075.44 W 6117.72 W 9200.0 9250.0 9300.0 9350.0 9400.0 56.01 277.79 5514.4 55.06 277.80 5542.6 53.30 278.66 5571.9 51.98 279.21 5602.2 50.32 280.07 5633.6 6308.3 4.70 6308.7 282.5 6349.3 1.91 6349.8 282.5 6389.7 3.78 6390.3 282.4 6429.3 2.79 6429.9 282.4 6468.2 3.57 6468.8 282.4 1364.98 N 1370.57 N 1376.37 N 1382.54 N 1389.06 N 6159.30 W 6200.15 W 6240.27 W 6279.53 W 6317.92 W 9450.0 9500.0 9550.0 9600.0 9650.0 48.79 280.56 5666.0 47.99 280.84 5699.2 46.20 280.77 5733.3 44.85 280.58 5768.3 43.24 280.71 5804.3 6506.2 3.16 6506.8 282.4 6543.5 1.64 6544.2 282.4 6580.1 3.59 6580.8 282.4 6615.8 2.71 6616.5 282.4 6650.5 3.24 6651.2 282.4 1395.87 N 1402.81 N 1409.67 N 1416.28 N 1422.70 N 6355.35 W 6392.09 W 6428.06 W 6463.12 W 6497.28 W A Gyro da t a D i r e c t i ona i Survey ½.P. EXPLORATION ? PAD, WELL NO. MPF-09 4ILNE POINT FIELD, ALASKA Iob Number: A0797GCE414 Page 4EASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. H O R I Z O N T A L COORDINATES feet 9700.0 42.05 280.66 5841.0 9750.0 39.87 280.21 5878.8 9800.0 39.22 279.73 5917.3 9850.0 37.25 279.89 5956.6 9900.0 36.67 279.69 5996.6 6684.3 6717.1 6748.9 6779.7 6809.8 2.37 6685.1 282.3 4.39 6717.8 282.3 1.45 6749.6 282.3 3.93 6780.6 282.3 1.19 6810.6 282.3 1428.98 N 1434.92 N 1440.43 N 1445.71 N 1450.82 N 6530.57 W 6562.80 W 6594.15 W 6624.64 W 6654.27 W 9950.0 34.07 281.54 6037.3 10000.0 33.29 282.38 6078.9 10050.0 32.00 283.44 6121.0 10100.0 31.41 283.42 6163.6 10150.0 28.99 282.91 6206.8 6838 6866 6893 6919 6944 .7 .4 .4 .6 .8 5.63 6839.5 282.3 1.81 6867.2 282.3 2.82 6894.2 282.3 1.18 6920.5 282.3 4.87 6945.6 282.3 1456.14 N 1461.88 N 1467.90 N 1474.01 N 1479.74 N 6682.71 W 6709.84 W 6736.13 W 6761.69 W 6786.18 W 10200.0 27.79 283.23 6250.8 10250.0 25.01 284.08 6295.6 10300.0 24.01 283.85 6341.1 10350.0 21.88 282.34 6387.1 10400.0 20.56 283.97 6433.7 6968 6990 7011 7031 7049 .6 .8 .5 .0 .1 2.43 6969.4 282.3 5.61 6991.6 282.3 1.99 7012.4 282.3 4.43 7031.8 282.3 2.89 7049.9 282.3 1485.11 N 1490.35 N 1495.36 N 1499.78 N 1503.89 N 6809.33 W 6830.93 W 6851.06 W 6870.04 W 6887.66 W 10450.0 19.00 285.54 6480.8 10500.0 17.79 285.33 6528.2 10550.0 16.86 284.82 6575.9 10600.0 16.66 284.19 6623.8 10650.0 16.38 283.97 6671.7 7066 7081 7096 7111 7125 .0 .8 .7 .1 .3 . 29 7066.8 282.3 43 7082.6 282.3 89 7097.5 282.3 54 7111.9 282.3 56 7126.1 282.3 1508.20 N 1512.40 N 1516.27 N 1519.88 N 1523.34 N 6904.03 W 6919.24 W 6933.61 W 6947.57 W 6961.36 W 10700.0 15.96 283.45 6719.8 10750.0 15.37 283.68 6767.9 10800.0 14.99 283.56 6816.2 10850.0 14.75 284.49 6864.5 10900.0 14.43 285.06 6912.9 7139.2 7152.7 7165.8 7178.6 7191.2 90 7140.0 282.3 18 7153.5 282.3 76 7166.6 282.4 68 7179.4 282.4 70 7192.0 282.4 1526.64 N 1529.81 N 1532.89 N 1536.00 N 1539.21 N 6974.89 W 6988.01 W 7000.74 W 7013.19 W 7025.37 W A Gyroda t a D i r e c t i ona i Survey I.P. EXPLORATION PAD, WELL NO. MPF-09 ~ILNE POINT FIELD, ALASKA lob Number: A0797GCE414 Page 4EASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. H O R I Z O N T A L COORDINATES feet 10950.0 14.27 284.41 6961.3 11000.0 14.01 284.49 7009.8 11050.0 13.81 283.81 7058.3 11100.0 13.40 283.57 7106.9 11150.0 13.36 283.01 7155.6 7203.6 .46 7204.4 282.4 7215.8 .50 7216.6 282.4 7227.8 .52 7228.6 282.4 7239.6 .83 7240.4 282.4 7251.2 .27 7251.9 282.4 1542.37 N 1545.41 N 1548.35 N 1551.14 N 1553.80 N 7037.35 W 7049.18 W 7060.84 W 7072.26 W 7083.53 W 11200.0 13.39 282.80 7204.2 11220.0 13.31 282.52 7223.7 7262.8 .11 7263.5 282.4 7267.4 .53 7268.1 282.4 1556.38 N 1557.39 N 7094.80 W 7099.31 W Final Station Closure: Distance: 7268.13 ft Az: 282.37 deg. A Gyro da t a D i r e c t i ona i Survey for B.P. EXPLORATION F PAD, WELL NO. MPF-09 MILNE POINT FIELD, ALASKA Job Number: SUB414 Run Date: il-Jul-97 11:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 41 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 283.200 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyr oda t a D i r e c t i ona i Survey .P. EXPLORATION ' PAD, WELL NO. MPF-09 [ILNE POINT FIELD, ALASKA 'ob Number: SUB414 Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. H O R I Z O N T A L COORDINATES feet -41 100 200 300 400 .0 .0 .0 .0 .0 0.00 0.00 0.0 .16 65.34 141.0 .25 215.13 241.0 .67 343.12 341.0 1.22 330.03 441.0 0.0 0.00 0.0 0.0 -.1 .18 .3 48.8 -.3 .35 .4 80.5 - .0 .71 1.3 189.2 1.0 .77 3.4 348.1 0.00 N 0.00 E .06 N .13 E .06 N .32 E .60 N .30 W 2.05 N .56 W 500 600 700 800 900 .0 .0 .0 .0 .0 1 . 05 324 . 16 541 . 0 1.53 311.86 641.0 2.68 295.12 741.0 3.41 292.69 841.0 4 . 22 285 . 40 941 . 0 2.4 .22 5.1 337.0 4.3 .68 7.7 329.5 7.8 1.26 12.2 318.8 13.0 .78 18.0 309.6 19.7 .94 25.2 303.0 3.72 N 1.62 W 5.23 N 3.22 W 6.98 N 6.38 W 9.11 N 11.25 W 11.18 N 17.57 W 1000 1100 1200 1300 1400 .0 .0 .0 .0 .0 5.45 277.08 1041.0 6.76 271.32 1141.0 7.81 269.98 1241.0 8.71 274.59 1341.0 10.21 280.93 1441.0 28.0 1.40 34.1 296.6 38.6 1.44 45.5 290.5 51.0 1.12 58.7 285.5 65.3 1.12 73.9 282.6 81.8 1.80 91.7 281.6 12.68 N 25.83 W 13.35 N 36.50 W 13.47 N 49.27 W 14.11 N 63.74 W 16.50 N 80.18 W 1500 1600 1700 1800 1900 .0 .0 .0 .0 .0 11.64 283.76 1541.0 13.02 283.88 1641.0 13.95 283.26 1741.0 15.04 282.14 1841.0 17.20 281.74 1941.0 101.1 1.51 112.0 281.8 123.0 1.36 134.5 282.1 147.0 .92 158.9 282.4 172.8 1.12 184.4 282.4 201.2 2.40 213.4 282.4 20.69 N 99.01 W 25.91 N 120.23 W 31.54 N 143.56 W 37.20 N 168.75 W 43.04 N 196.57 W 2000.0 2100.0 2200.0 2300.0 2400.0 20.52 282.18 2041.0 23.61 281.33 2141.0 27.35 281.59 2241.0 30.97 282.18 2341.0 33.96 282.90 2441.0 235.6 2.75 247.8 282.3 276.1 3.02 286.7 282.2 323.7 3.54 330.8 282.1 379.3 3.28 379.9 282.1 443.0 2.63 461.3 282.1 50.19 N 230.24 W 58.50 N 269.90 W 67.80 N 316.58 W 79.21 N 371.02 W 93.04 N 433.21 W A Gyroda t a D i r e c t i ona I Survey ½.P. EXPLORATION PAD, WELL NO. MPF-09 ~ILNE POINT FIELD, ALASKA Iob Number: SUB414 Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. H 0 R I Z O N T A L COORDINATES feet 2500.0 2600.0 2700.0 2800.0 2900.0 36.92 282.92 2541.0 40.13 282.59 2641.0 42 . 89 281 . 60 2741 . 0 46.44 280.16 2841.0 49.87 279.82 2941.0 514.2 2.39 520.0 282.2 593.9 2.43 614.5 282.3 682.3 2.01 715.7 282.3 780.9 3.13 786.6 282.1 892.7 1.93 898.7 281.8 109.04 N 126.62 N 145.29 N 163.62 N 183.01 N 502.61 W 580.35 W 666.76 W 763.76 W 874.00 W 3000.0 3100.0 3200.0 3300.0 3400.0 53.60 279.66 3041.0 57.23 279.41 3141.0 60.88 280.02 3241.0 64.42 281.44 3341.0 65.09 282.51 3441.0 1019.0 2.52 1056.9 281.6 1164.1 1.93 1181.3 281.3 1330.6 1.83 1353.6 281.1 1524.7 1.73 1531.8 281.0 1742.9 .51 1759.1 281.2 204.62 N 228.62 N 256.42 N 291.55 N 337.71 N 998.69 W 1142.06 W 1306.60 W 1497.65 W 1711.03 W 3500.0 3600.0 3700.0 3800.0 3900.0 65 . 92 282 . 94 3541 . 0 66.19 283.45 3641.0 66 . 13 284 . 02 3741 . 0 66.34 283.67 3841.0 65.51 283.23 3941.0 1957.0 1.67 1985.7 281.3 2176.3 1.90 2213.2 281.5 2407.9 .70 2442.4 281.8 2635.6 .61 2671.3 281.9 2855.8 1.69 2898.7 282.1 384.90 N 435.33 N 490.85 N 544.56 N 597.37 N 1919.85 W 2133.24 W 2358.10 W 2579.43 W 2793.17 W 4000.0 4100.0 4200.0 4300.0 4400.0 65.96 283.01 4041.0 64.45 283.40 4141.0 65.79 282.89 4241.0 65.60 282.23 4341.0 66.12 282.74 4441.0 3080.4 .4.5 3081.4 282.1 3296.6 .72 3308.2 282.2 3513.4 .47 3535.4 282.3 3742.1 .72 3764.4 282.3 3962.0 .19 3992.1 282.3 647.19 N 696.24 N 745.61 N 794.74 N 842.26 N 3012.17 W 3222.79 W 3433.85 W 3657.28 W 3872.01 W 4500.0 4600.0 4700.0 4800.0 4900.0 65.47 282.52 4541.0 66.17 283.13 4641.0 65.99 283.11 4741.0 66.35 283.09 4841.0 65.14 283.81 4941.0 4182.1 1.08 4219.7 282.3 4412.5 .56 4448.9 282.4 4635.0 .37 4676.9 282.4 4864.9 1.15 4906.2 282.4 5085.2 2.43 5088.1 282.5 889.86 N 944.41 N 994.61 N 1047.91 N 1096.48 N 4086.92 W 4310.77 W 4527.53 W 4751.11 W 4966.04 W A Gyr oda t a D i r e c t i ona i Survey ~.P. EXPLORATION F PAD, WELL NO. MPF-09 ~ILNE POINT FIELD, ALASKA 3ob Number: SUB414 Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 5000.0 66.21 284.63 5041.0 5100.0 66.92 284.11 5141.0 5200.0 66.34 282.53 5241.0 5300.0 64.96 281.66 5341.0 5400.0 60.97 279.75 5441.0 5312.7 .75 5316.8 282.5 5537.4 1.83 5545.2 282.6 5769.2 .77 5774.7 282.6 5988.7 .50 6002.1 282.6 6188.3 2.15 6224.2 282.6 1153.66 N 1209.07 N 1262.99 N 1308.99 N 1346.96 N 5186.27 W 5404.14 W 5629.58 W 5844.24 W 6040.34 W 5500.0 55.11 277.80 5541.0 5600.0 49.97 280.18 5641.0 5700.0 45.90 280.73 5741.0 5800.0 42.05 280.66 5841.0 5900.0 38.03 279.83 5941.0 6346.9 2.07 6349.8 282.5 6476.8 3.47 6506.8 282.4 6588.0 3.40 6616.5 282.4 6684.3 2.37 6685.1 282.3 6767.5 2.94 6780.6 282.3 1370.24 N 1390.61 N 1411.13 N 1428.98 N 1443.61 N 6197.77 W 6326.44 W 6435.78 W 6530.54 W 6612.52 W 6000.0 34.00 281.62 6041.0 6100.0 31.72 283.43 6141.0 6200.0 28.05 283.16 6241.0 6300.0 24.01 283.85 6341.0 6400.0 20.32 284.21 6441.0 6841.1 5.29 6867.2 282.3 6905.7 2.05 6920.5 282.3 6963.3 2.97 6969.4 282.3 7011.5 2.00 7012.4 282.3 7051.7 2.95 7066.8 282.3 1456.64 N 1470.77 N 1483.92 N 1495.35 N 1504.56 N 6685.10 W 6748.12 W 6804.19 W 6851.04 W 6890.20 W 6500.0 17.54 285.19 6541.0 6600.0 16.56 284.12 6641.0 6700.0 15.70 283.55 6741.0 6800.0 14.87 284.04 6841.0 6900.0 14.34 284.68 6941.0 7085.8 2.29 7097.5 282.3 7116.2 .55 7126.1 282.3 7145.2 1.02 7153.5 282.3 7172.4 .72 7179.4 282.4 7198.4 .56 7204.4 282.4 1513.43 N 1521.12 N 1528.04 N 1534.49 N 1541.04 N 6923.09 W 6952.52 W 6980.68 W 7007.14 W 7032.33 W 7000.0 13.88 284.05 7041.0 7100.0 13.37 283.18 7141.0 7182.7 13.31 282.52 7223.7 7223.6 .52 7228.6 282.4 7247.7 .44 7251.9 282.4 7267.4 .53 7268.1 282.4 1547.30 N 1553.00 N 1557.39 N 7056.67 W 7080.15 W 7099.31 W Final Station Closure: Distance: 7268.13 ft Az: 282.37 deg. 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: A0797GCE414 TOOL NUMBER: 777 MAXIMUM GYRO TEMPERATURE: 77.45 C MAXIMUM AMBIENT TEMPERATURE: 80.0 C MAXIMUM INCLINATION: 67.27 AVERAGE AZIMUTH: 282.37 WIRELINE REZERO VALUE: N/A REZERO ERROR/K: N/A CALIBRATION USED FOR FIELD SURVEY: 2040 CALIBRATION USED FOR FINAL SURVEY: 2040 PRE JOB MASS BALANCE OFFSET CHECK: -.26 POST JOB MASS BALANCE OFFSET CHECK~: USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES -.40 UPON ARRIVAL AT RIG: O.K. UPON COMPLETION OF SURVEY: O.K. UPON RETURN TO ATLAS O.K. BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING MWD 11089 13.38 284.23 7090 1645 -7051 FINAL SURVEY 11100 13.40 283.57 7106 1551 -7072 FUNCTION TEST JOB NUMBER: A0797GCE414 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 1901 15.73 15.73 15.73 15.73 15.73 AZIMUTH M.D. ft 1 2 3 4 5 1901 281.52 281.58 281.57 281.48 281.37 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: A0797GCE414 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 777 GYRO SECTION DATA SECTION POWER SECTION BACKUP TOOL No. 767 GYRO SECTION DATA SECTION POWER SECTION A0169 C0111 C0112 A0103 C0089 C0086 COMPUTER A0349 POWER SUPPLY PRINTER A0079 INTERFACE A0143 COMPUTER A0222 POWER SUPPLY PRINTER A0029 INTERFACE A0055 A0085 A0107 WIRELINE COMPANY: CABLE SIZE: 3/8" SCHLUMBERGER RUNNING GEAR SCHLUMBERGER HOUSING W/ROLLERS IN COMBO W/GR CCL TOTAL LENGTH OF TOOL: 28' MAXIMUM O.D.: 5.5 INCHES TOTAL WEIGHT OF TOOL: 700 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: A0797GCE414 THURSDAY, 07/10/97 22:00 FINISH POOL 7 24:00 CHECK TOOL, O.K., JOB TOMORROW A.M. FRIDAY, 07/11/97 06:00 07:00 10:45 11:15 11:30 14:45 17:45 18:45 20:00 TO LOCATION ARRIVE LOCATION MU TOOL, RU SCHLUMBERGER PU GYRO. MU LUBRICATOR. START INRUN SURVEY SURVEY CONTINUOUS TO 11220' RUN GR/CCL WITH GYRO TO 1900' RIG DOWN RETURN TO ATLAS, CHECK TOOLS, PROCESS ENDICOTT SURVEY SATURDAY, 7/12/97 07:00 09:00 10:30 12:00 16:00 TO ENDICOTT W SDI 3-17B/M-31 RESULTS PROCESS MPF-09 RESULTS TO MILNE POINT WITH SURVEY RETURN TO ATLAS FLY TO ANCHORAGE ON ALASKA AIR W-ELL LOG TRANSMITTAL To: State of Alaska August 27, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~? MWD Formation Evaluation Logs - MPF-09, RE: AK-MM-70172 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPF-09: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22773-00 1 Blueline 1 Rev. Folded Sepia 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22773-00 1 Blueline 1 Rev. Folded Sepia 2" x 5" MD Neutron and Density Logs: 50-029-22773-00 1 Blueline 1 Rev. Folded Sepia 2" x 5" TVD Neutron and Density Logs: 50-029-22773-00 1 Blueline 1 Rev. Folded Sepia AUG 2 7 1997 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company CI I~! I I_1_ I N ~S S ~:: !:1 ~/I r' ~::: S WELL LOG TRAINSNHTTAL -- To: State of Alaska / August 20, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MPF-09 AK-MM-70172 MWD Formation Evaluation Logs - The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted LIS Tape with verification listing. APl#: 50-029-22773-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company -- GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11223 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 8/6/97 Well Job # Log Description Date BL RF Sepia LIS Tape ,, MPU F-09 ~:~ ~L~ ~ 97323 GPJCCL PDC 97071 1 I I 1 ., ..... , , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: A t,,,t (..,;, 0 '(l,) ,.:)"! Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received b~/L _.,,/)(.~)l..¢t _),..-~ TONY KNOWLE$, GOVERNOR ALASI & OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 6, 1997 Tim Schofield Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Milne Point Unit MPF-09 BP Exploration (Alaska) Inc Permit No 97-104 Sur. Loc.' 1759'NSL, 2766'WEL, Sec. 6: T13N, R10E, UM Btmhole Loc: 3433'NSL, 4776'WEL. Sec. 1, TI3N, R9E, UM Dear Mr. Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill docs not exempt you from obtaining additional permits required by law from other govemmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission max, witness the test. Notice mav be given bx' contacting the Commission petroleum field inspector on the North Slope pager at - -- johns o, BY iORD~MISSION dlf;'enclosures Department of Fish & Game. Habitat Section w,o encl. Department ct' lZnvinonunent Consen'ation w;o encl. STATE OF ALASKA ALASKA G,= AND GAS CONSERVATION COMr,~SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI []Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 41.5' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 388235 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1759' NSL, 2766' WEL, SEC. 6, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 3410' NSL, 4675' WEL, SEC. 1, T13N, RgE, UM MPF-09 At total depth 9. Approximate spud date Amount $200,000.00 3433' NSL, 4776' WEL, SEC. 1, T13N, RgE, UM 06/08/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 355018, 1847'I No Close Approach 1920 11541' MD/7452' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 700' Maximum Hole Angle 66.86° Maximum surface 2804 psig, At total depth (TVD) 7025' / 3506 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btm 6330' 31' 31' 6361' 5325' 1466 sx PF 'E', 444 sx Class 'G' 8-1/2" 7" 26# L-80 Btrc-Mod 11511' 30' 30' 11541' 7452' 240 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations· Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate ~ Production ~,~ Liner '"'AL Perforation depth: measured ~j¥~,~,S¥~80ii true vertical " /~';~- .... -¢" 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25·050 Requirements Contact Engineer Name/Number: James Robertson, 564-5159 Prepared By Name/Number: Kathy Campoamor, 564-5122 21 I hereby certify that / · the foregoing i,s trge and c)o, rrect to the best of my knowledge T~m So~ofiad C.~. ~r.u,; ~, Title Senior Drilling En~lineer Date / ¢om~is$io. Use Only Permit Number I APl Number Approval Date I See cover letter ¢ ~'~-./,"f__.) ~ 50- O ~. ~'-. 2~ ~ '~ ..'~,.~ (,'3- ~o- ¢) ~ for other requirements Conditions of Approval: Samples Required []Yes ,]~'No Mud Log Required []Yes J~No Hydrogen Sulfide Measures []Yes~No Directional Survey Required ,l~Yes [] No Required Working Pressure for BOPE []2M; []3M; ~5M; []10M; [] 15M Other: 0dginal Signea ~ by order of Approved By David W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: I Well Name: James E. Robertson IMP F-09 I Well Plan Summary 564-5159 IType of Well (producer or injector): KUPARUK PRODUCER Surface Location: 1759 FSL 2766 FEL Sec 06 T13N R10E UM., AK Target Location: 3410 FSL 4675 FEL Sec 01 T13N R09E UM., AK Bottom Hole Location: 3433 FSL 4776 FEL Sec 01 T13N R09E UM., AK I AFE Number: 1337086 Estimated Start Date: I 08JUN97 I I MD: 111,541' I I Rig: I Nabors22E I Operating days to complete: I TVD: 17,452 bkb I I KBE: 14~.5' 112 IWell Design: Milne Point Ultra Slimhole Longstring 9-5/8", 40# Surface X 7", 26# I Longstring I Formation Markers: Formation Tops MD TVD (bkb) .... base permafrost 1804 1792 NA 5448 3962 Top of Schrader Bluff Sands (8.3 ppg) Seabee Shale 6211 4262 Base of Schrader Bluff Sands (8.3 ppg) HRZ 10645 6587 High Resistivity Zone .-'.u~.,__~_;~-~ ~, ~,,. MK-19 10831 6767 Top Kuparuk 10976 6907 Kuparuk Cap Rock Target Sand -Target 11142 7067 Target Sand (9.6 ppg) Total Depth 11541 7452 Cl ~, Casin~/'l'ubing Program: Hole ,~ize - Csg~ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112 / 112 12 1/4" 9-5/8" 40# L-80 btm 6330 31/31 6361 / 5325 8-1/2" 7" 26# L-80 btm- 11511 30/30 11541 / 7452 mod Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at +7025 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3506 psi (9.6 ppg EMW) is ?_9O~-psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface Intermediate Final Cased Hole Logs: MWD Directional surface to TD. LWD Gamma Ray/Resistivity surface to TD N/A MWD Directional and LWD Triple Combo CDR/CDN (GR/RES/Dens/Neu). N/A Mudloggers are NOT required for this well. Mud Program: I Special design considerations I None-SPUD MUD I Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.4 150 35 15 30 10 15 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 35 6 3 7 8.5 6-12 to to to to to to to 10.0 50 20 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi WP. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1700' Maximum Hole Angle: Close Approach Well: 66.86 NONE Disposal: Cuffings Handling: Cuttings and drilling waste fluids should be hauled to the ball mill at CC-2A or to Milne Point 'A' Pad pit for temporary storage during breakup. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. . 2. 3. 4. 5. . . 11. 12. 13. 14. 15. MP F-09 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU and function test 20" diverter. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD and LWD GR/Res from surface to TD. Run and cement 9-5/8" casing. ND 20" diverter. NU and test 13-5/8" BOP. MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 20' of new formation. Perform LEAKOFF TEST. If LOT EMW is less than 12.5 ppg contact appropriate superintendent. Drill 8.5" hole to TD as per directional plan. Run and Cement 7", 26#, L-80, Buttress-Modified casing. Displace cement with completion fluid and enough diesel to cover from the base of permafrost to surface. Test casing to 3500 psig for 30 min. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. MIRU completion rig. NU & Test BOPE to 5000 psig. Complete well with 2-7/8" tubing. Install Surface Lines and Wellhouse and turn well over to production. DRILLING HAZARDS AND RISKS: See the updated Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for information on F pad and review recent wells drilled on F Pad. Most of the trouble time on recent wells has been due to equipment mechanical problems with the surface equipment, rather than formation drilling problems. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. Close Approach: There are no close approaches associated with the drilling of MP F-09. Lost Circulation: There has not been any appreciable amount of lost circulation on any of the F Pad wells to date. Stuck Pipe Potential: Well MPF-53 was stuck coming out on the short trip at surface casing point. Prior to this incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed. If significant gravels are encountered stop and raise funnel viscosity to 150 cp viscosity immediately. Formation Pressure: The expected pore pressure for this well is 9.6 ppg EMW (3,506 psi @ 7,025' TVD). There has been no injection in this region therefore the reservoir pressure should not exceed this estimate and may in fact be somewhat depleted. MP F-09 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 60 deg F at 2840' TVDSS. SPACER: 75 bbls water. STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder + CELLO-FLAKES (1/4 lb/sack) 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 600 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM TOP OF TAIL TO STAGE COLLAR @ 2000' MD (200' TVD BELOW BASE OF PERMAFROST) +30% EXCESS. STAGE1 TAIL CEMENT TYPE: ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: PREMIUM 'G' 0.2% CFR-3 + 0.20% HALAD-344 + CELLO-FLAKES 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 444 THICKENING TIME: Greater than 4 hrs at 50° F. 100-150 cc FREE WATER: 0 TAIL CEMENT FROM TD TO 100 FEET TVD ABOVE TOP of Schrader Bluff + 30% EXCESS + 82'md 9-5/8", 40# capacity for float joints. STAGE2 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg 866 SACKS YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. ANUULAR VOLUME FROM STAGE COLLAR AT 2000' MD TO SURFACE+ 200% EXCESS. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY WITH APPROVEL OF APPROPRIATE SUPERINTENDENT IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing (15 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacedmud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. MP F-09 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140° F BHST 170° F at 7040' TVDSS. SPACER: 20 bbls fresh water 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: FLUID LOSS: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 240 SACKS THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: . 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 21 joints of 7" casing (42). This will cover ±300' above the KUPARUK Sand. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacedmud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: Single stage cement job is calculated to cover 1000 FT MD above the Kuparuk 'C' Sand with 30% excess. 15:27' 907.-344-2160 ANADRILL· PAGE 86 SHARED SERVICES ' 'O'R'iLLING !1 i PF-09 (P6) VERTICAL SECTION i · Section' a.t: 283,41 TVD 'Scale,: 1 inch -- t600 feet VIEW Oep SCa]e' 1 inch = 1600 feet ) ~-- . '- /nadpill Schlumberger D i ' · ' -. Marker Identification MD BKB 5ECTN INCLN I __..~~ ..... '__ . ~.~'~..p~ ~I'KB " 0 - 0 o o.oo ' B) KOP/BUILO t/~00 700 700 -0 0.00 -~ [1 [~ t,5/t00 C~gv[ 177~ t7fi5 1~ 14.08 : Fl BUILD 2.5/100 1900 18B5 16~ t5.73 ~ _ ~ 61 ENO ~.5/t00 BUILD 3945 337t t~66 66.86 ~ ' H) g-5/8' CASING POINT 6361 4320 3687 66.8B ' I) DROP 3/i00 Bal6 53a5 6037 56.86 - - J) END 3/t00 DROP 10645 6586 7131 t5.00 ~{ I i ! I I i K) TARGET 11142 7066 7259 15,00 . .. , ¢5::-- = :: : :''"' ~ IniI IIIII II~IInIIIIIIInI.. IInII~IIIIInnlII~!'InII~ -- - . L .-. FZAqI'Rli i ~ DA~.gPC N()T APPR( )V~[~'~ ~ , E~ ECL T,n~.l . . . · . ,, , ,, ,, . C~naeri]] (c)g? NPFO~P6 3.0C 223 P~ PI . _. 800 1600 2400 3200 ' 4000- 4800 5600 6400 72 SectiOn Departure - .[' SHARED 14arker Ident i ficat ion MD A) KB 0 B) KOP/BU]LD 1/IOO 700 C) BUILD 1.5/t00 BO0 D) CURVE 1.5/100 1300 E) EN{) 1.5/i00 CURVE 1774 F) BUILD 2.5/i00 1900 G) END 2.5/10.0 BUILD 3945 H) 9-5/8" CASING POIN1 §361 I) DRDP 3/t00 8916 J) END. 3/t00 []fi0P I0645 K) fARGET t t142 L) 7" CASING PO[Nf t154! H) fO t t541 SER i i i ~/S 0S 75 7N 310 N 825 N i370 N 1624 N .1[]3 N 1577 N 1677 N VICES. DRIL[IING' E/~. OE OE ~3~ iB3 t433 3594 58791 6944 ANADR~LL 7069 7169 '7t6g AKA-DPC FEASibiLiTY ^PP OVS EXECUTION PLANe ~ AnadrJ ] ]. Sch]umberger ii im m MPF-09 (P6) PLAN VIEW i i m CLOSURE "7363 feet at Azimuth 2B3.]7 DECLINATION' +28.013 (E) SCALE '' 1 inch = 1000 feet DRAWN · 20 Hay 1997 ! · .I IARGEI (Radius 200 fe~ t} _ · . I 8500 8000 7500 7000 6500 6000 5500 5000 4500 4000 3500 3000 2500 2000 i500 fO00 500 0 500 <- ~ST' EAST -> ({tnadr)]l (c)97 NPFOgP6 3.0C 3~Z3 P~4 ~ *'El, 0 "0 G") ITl sP EXPLORATION (ALASKA) ANCHORAGE, ALASKA FAX # (907) 564-5193 TELEC_OPY C_OVER SHEET TO: COMPANY: LOCATION: Bob Crandall AOGCC Anchora~le -- I FAX #: 276-7542 FROM: LOCATION: PAGES TO FOLLOW: 3 COMMENTS: .Kathy ca .m_p_o. am0r. .... SHARED SERVICES DRILLING ANCHORAGE, ALASKA PHONE #: 564-5122 DATE: $-2-97 Per your request, this Is the letter which explains the segregation of ADL355023. This should help for & MPL-33i Permit To Drill applications. If you have any otl questions, please give me a call. IF YOU DO NOT RECEIVE ALL PAGES, OR HAVE ANY PROBLEM$~ PLEASE CALL THE FOLLOWING NUMBER; (907) $64-$122 DEPAR~~ OF NATURA2L VIS/ON OF OIL AND GAS CBRTIFIBD MAIL $3474 & 534?$ RETURN RF_K215IPT REQUESTED MAY 9 1997 ARCO Alaska, Ina. Attn: Land Manag~ P,O, Box 100360 Anchorage, AK 99~I0-0360 DECISION · Oil & Om Leas~ , ' ADL 35.'i023 ' ' Kuparuk River Unit · Tract 122 BP Bxploration (Alaska) Ir)e, Attn: Land Managor- Alaska P.O, Box 196612 900 E, Benson Blvd. Anchorage, AK 99519-6612 : Oil & Gas Lease : ADL 388235 : K, uparuk Rivor Unit : Tract 122 : " Milne Point Unit LEASE SEGREGATED MILNB POrNT UNIT EXPANDF. D , i ~.i ~'.~ 2 1997 CONT~CTION OF ME,NE PO~ UN~ DE~~D .~aa~ 9il ,&(ias '""' ' , 'Oil and gas I~m~ ADL B55023 was issued effe;five Sune 1, 1983 with a pfimwy te~ oF ten y~ars. Tho le~g w~ eommitt~ in its entirely lo ~he Kup~k Riwr Unit (~U) and inco~orat~d in pan into ~ Kupamk P~ieipafing A~a (KPA) upon ~heir S~ond ~xpansions, eff~tiw $ua~ I, 198~, Th~ le~e w~ ;xtondgd indefinitely in a~gord~e~ wifl~ the ~U Agr~m~nt and p~agraph 4b of ~e lease, Addition6 a;mag~ w~ lneo~ra~d into the KPA upon its Four~ Expansion, =ff~ctive December 1, 1990. ' On July 8, 1996. application w~ made to the Director, Division of Oil sad Oas for "Approval of Assignment, Contraction of Kupamk Riv,r Unit and Expansion of Milno Point Unit" by ARCO Alask~ Inc. (ARCO) ~ lessee and ~U Operator ~d BP Exploratio~ (Alaska) Inc. ~q Milne Point Unit (MPU) Operator, In d~at application, thc subject lands w,m rcquest~ to be I) ~e~gat~ from oil and gm lease ~L 355023 2) resigned from ~CO Almk~ Inc. to BP Exploration (Alaska) Inc. (BP), et al 3) contracted out of ~e ~U and ~) committed to the MPU with its p~nding eontramion d~ferred, Tho subject lands were identifi,d m: and E~hanc, Nafuea! Rerourves for Present and Fulure Ala~kai~t" ~0',4 9II205@ql0@I0 '0bi X¥fl $~ '8 'II0 ^I(I/~iN(I~ 0018 l~d JUM ' '97 02:58PM BP EXPLORATIOM 3~023~g.d¢¢ T. I3 N., R. 9 E., U.M. Section 1: All; 640 acres Section 2: N !/2, SEI/4; 480 acres Section 11: NE 1/4; 160 acres S~tion 12: Ail; 640 acres Containiog i,920,00 acres, more or'less. By Decision dated November 18, 1996, thc Director approved the expansion of the MPU and the commitment of the ,ubj~t lands to the unit with d~fen'al of eonttamion of those lands from the MPU until December 31, I997. By Decision dated November 25, I996, the Director approved the ~$ignmcnt of ARCO's working interest in the ~ubj~t lands to ~P, ot al, The aubj~ lands wc~ aegmemcd within oil and g~ le~, ~L 355023 ~ Segments I and A. ~,. In accordanc~ with paralraph 18 of the I~ase and I 1 AAC 82.610, the subject lands (~egments 1 and A) are hereby s,vered from oil and gas lease ADL 355023 and [qsigned ~L 388235. ~e lands rem~ning in ~il and gas lease ADL 555023 following th, segregation T. 1~ N., R, 9 I5,, U.M. S~tion 2;' SW1/4; I60 acres S~tion 3: All; 640 acres Section 4: All; 640 acres Section 8: Ail, excluding all tide and submerged lands and USS t,275; 55 acre~ Section 9: All; 640 acr,s S~tion 10: All; 640 acres S~fion 11: ~ l/a, S 1/2; 480 acres Containing 3,255.00 acres, more or less, Stat, of Alike oli and gas lease ADL 355023 remains extend=d in a~ordance with the KRU Agreement and paragraph 4b of the lease. The lease remains committed in its entirety to the K.R.U and in part to the KPA, Tl~e pocti6n of tho lea~ within the KPA is described as follo~ws: T. 13 N,, R, 9 E,, U.M. , ' ~ '''-~ L ?,~ Section 3: All; ~0 'd ~T,l~Ol~gqL091, O 'ON Section 4: All; 640 aclx~s Section 8: AlL excluding all tide and submerged lands .nd USS 4275; 55 acres Section 9: All; 640acres Section 10: All; 640 acl~s Section l I; NW l/d, $W1/4~ 320 acres Containing 2,935.00 aere~, more or less. The lands included in oiI and gas lease ADL 388235 as a result of The segregation are: T. 13 Iq., R, 9 I~,, U.M. MPU Tract 22 $~;tion 1: AlIi 6a0acres Section 2: NI/2, $EI/4; 480acres Section 11: NI~l/4; 160 acres Section 1~: All; 640 acre~ v Containing 1,9110.00 acres, more or less. State of Alaska oil and gas lease ADL 388235 retains the same effective dale and primary term as the original lease. The lease is committed in its entirety to the MPU & KRU and is extended in accordance wiih the MPU & KRU Agreements and paragraph 4b of the lett~e. A de~ision regarding ~e contraction of the KRU u to the subject land~ is still p~nding. If you have any questions regarding this decision, please call Pinle Bates '-,t (907) 269.8810. Kenneth A, Boyd Director ce: Mike Kotowski, Units Manager 1~0 'd BI~0EgSL0$I0 'ON X~J WELL PERMIT CHECKLISToo Fi~.,,o & POOL $' ~£/~" c~ INi~ ~LASS ~P~j~ PROGRAM: expo dev~'redrlO serve wellbore segF! ann disp para req[] ON/OFF SHORE f-'~ ) ADMINISTRATION 1..Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............ 5. Well located proper distance from drlg unit boundary. . 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. 10. Operator has appropriate bond in force ........ 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. . 13. Can permit be approved before 15-day wait ....... ENGINEERING · N N N N N N N N N REMARKS 3.4. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. . Y~,~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. N 21. If a re-drill, has a 10-403 for abndnmnt been approved..~~/~~ 22. Adequatewellboreseparationproposed .......... 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~~ psig. Y~_ N , ~' 27. Choke manifold complies w/API RP-53 (M~y ~ ..... ~ N PS' 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/N 32. Seismic analysis of shallow gas zones ......... ./~ N 33. Seabed condition survey (if off-shore) ....... / Y N 34. Contact name/phone for weekly progress reports . . ~. . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISS ION.~ Comments/Instructions: © ,q HOWldlf- A:\FORMS\cheklist rev 01/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Tue Aug 12 12:25:31 1997 Reel Header Service name ............. LISTPE Date ..................... 97/08/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Scientific Tape Header Service name ............. LISTPE Date ..................... 97/08/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Scientific Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 1 AK-MM-70172 GRIFFIN ANGLEN Date MPF-09 500292277300 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 12-AUG-97 MWD RUN 2 AK-MM-70172 PIEPER ANGLAN 6 13N 10E 1759 2766 .00 29.00 12. O0 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 12.250 9.625 6288.0 8.500 11390.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). 4. STABILIZED LITHO DENSITY (SLD) TOOL WAS NOT TURNED ON IN ORDER TO SAVE BATTERY POWER FROM 6228'MD, 4265'TVD TO 7366'MD, 4727'TVD. 5. ALL MWD RUNS REPRESENT MPF-09 WITH API# 50-029-22773-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF l1390'MD, 7382'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY EXTRA SHALLOW SPACING). SESP = SMOOTHED PAHSE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME FOR RESISTIVITY SENSOR. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED BULK DENSITY (COMPENSATED). SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NEUTRON LOG DATA: HOLE SIZE = 8.5" MUD FILTRATE SALINITY = 800 PPM. MUD WEIGHT = 8.5 - 9.8 PPG. FORMATION WATER SALINITY = 14545 PPM. FLUID DENSITY = 1.0 G/CC. MATRIX DENSITY = 2.65 G/CC. LITHOLOGY = SANDSTONE. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH GR 47.5 ROP 111.0 FCNT 6182.0 NCNT 6182.0 NPHI 6182.0 FET 6259.0 RPD 6259.0 RPM 6259.0 RPS 6259.0 RPX 6259.0 PEF 7353.5 DRHO 7353.5 RHOB 7353.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 47.5 1910.0 1912.5 1915.5 1918.5 1923.0 1933.0 1936.0 1986 0 1989 5 2087 0 2277 5 2279 0 2322 0 2326 0 2328 5 2384 0 2459 0 2468 0 2539 5 2558 5 2580.5 2585.5 2587.5 2598.5 GR 50.5 1913.0 1917.0 1920.0 1923.5 1928.0 1941.0 1944.5 1991.5 1994.0 2092.5 2284.0 2286.0 2331.0 2333.5 2334.5 2389.5 2466.5 2476.0 2546.5 2565.0 2587.5 2591.5 2593.5 2606.0 STOP DEPTH 11320 5 11384 5 11274 5 11274 5 11274 5 11300 5 11300.5 11300.5 11300.5 11300.5 11309.0 11309.0 11309.0 EQUIVALENT UNSHIFTED DEPTH -- 2719.5 2731.0 2863.5 2907.5 2911 0 2946 5 2956 5 3009 5 3030 0 3073 0 3076 5 3080 5 3145 0 3366 0 3369 0 3385 0 3388 5 3401.0 3413.5 3665 .~0 3667.5 3672.5 3704.0 3717.0 3786.5 3851.5 3908.5 3912.5 4003.5 4011 0 4043 0 4047 0 4265 5 4276 0 4838 0 4964 5 4970 5 4974 0 5015 0 5057 5 5234 5 5488 5 5498 0 5508 5 6273 0 6275 5 7422 5 7425 5 9445 5 9450 5 9523 5 9820 0 9823 0 10252 0 10441 0 10454 0 10475 5 10481 0 10482 5 10523 5 2726.5 2737.5 2871.5 2915.0 2920.0 2953.0 2961.5 3015.5 3036.5 3080.5 3083.5 3089.0 3150.0 3372.0 3375.0 3392.0 3394.5 3410.0 3419.5 3668.0 3672.5 3678.5 3711.5 3723.0 3793 0 3857 0 3915 0 3919 0 4008 5 4017 0 4047.0 4052.5 4273.0 4284.0 4848.0 4974.0 4981.0 4984.0 5025.5 5066.0 5241.5 5499.0 5508.5 5520.0 6283.5 6286.0 7435.5 7438.5 9456.5 9461.0 9533.0 9832.5 9836.0 10264.5 10454.5 10465.5 10488.5 10493.5 10495.0 10534.5 10531.0 10572.0 10631.0 10634.0 10764.5 10898.0 10901.5 10941.5 10953.5 10956.0 10964.5 10977.5 10980.0 11037.0 11117.0 11138.0 11384.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 10543.0 10583.5 10644.5 10647.5 10777.5 10909.5 10912.0 10953.5 10967.5 10969.0 10977.0 10989.5 10992.5 11050.0 11122.5 11143.5 11390.0 BIT RUN NO MERGE TOP MERGE BASE 1 112.0 6303.0 2 6303.0 11390.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHM- 4 1 68 RPS MWD OHM- 4 1 68 RPM MWD OHM- 4 1 68 RPD MWD OHM- 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CTS/ 4 1 68 FCNT MWD CTS/ 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam First Reading Last Reading DEPT 47.5 11384.5 ROP 6.4181 2538.28 GR 8.3759 229.02 RPX 0.0705 55.0868 RPS 0.1042 50.0377 RPM 0.2848 2000 RPD 0.1409 2000 FET 0.2629 63.6444 NPHI 17.417 81.6198 NCNT 2136 3736.76 FCNT 402 1043 RHOB 2.1302 2.9013 DRHO -0.144 0.5111 PEF 1.5748 9.0097 5716 22675 222.816 22525 70.7122 22547 2.87959 10084 2.93918 10084 3.6268 10084 8.91888 10084 1.5662 10084 42.4112 10186 2680.3 10186 636.124 10186 2.35797 7912 0.0327796 7912 2.19501 7912 47.5 111 47.5 6259 6259 6259 6259 6259 6182 6182 6182 7353.5 7353.5 7353.5 11384.5 11384.5 11320.5 11300.5 11300.5 11300.5 11300.5 11300.5 11274.5 11274.5 11274.5 11309 11309 11309 First Reading For Entire File .......... 47.5 Last Reading For Entire File ........... 11384.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 50.5 6239.5 ROP 114.0 6303.0 $ LOG HEADER DATA DATE LOGGED: il-JUN-97 SOFTWARE SURFACE SOFTWARE VERSION: 4.96 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 5.46 MEMORY 6303.0 112.0 6303.0 .0 67.4 TOOL NUMBER P0747CG8 12.250 12.3 SPUD 9.00 63.0 9.0 8OO 5.5 .000 .000 .000 .000 30.6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 50.5 6303 3176.75 12506 GR 8.3759 111.189 53.3863 12379 ROP 10.4968 896.382 245.636 12379 First Reading 50.5 50.5 114 Last Reading 6303 6239.5 6303 First Reading For Entire File .......... 50.5 Last Reading For Entire File ........... 6303 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR FCNT NCNT NPHI ROP FET RPD RPM RPS RPX PEF DRHO RHOB $ 2 .5000 START DEPTH 6134.0 6193 0 6193 0 6193 0 6199 0 6270 0 6270 0 6270 0 6270.0 6270.0 7366.5 7366.5 7366.5 STOP 1132 1128 1128 1128 1139 1130 1130 1130 1130 1130 1131 1131 1131 DEPTH 6.0 0.0 0.0 0.0 00 60 60 60 60 60 45 45 45 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... 16-JUN-97 4.96 5.46 MEMORY 11390.0 6303.0 11390.0 12.8 67.1 TOOL NUMBER P0742CRDGP6 P0742CRDGP6 P0742CRDGP6 P0742CRDGP6 8.500 8.5 LSND 9.80 46.0 9.2 8OO 5.5 1.700 1.091 1.400 2.100 62.2 Datum Specification Block sub-type...0 Name DEPT GR RPX RPS RPM RPD NPHI ROP FET FCNT NCNT RHOB DRHO PEF Service Order Units Size Nsam Rep FT 4 1 68 MWD 2 AAPI 4 1 68 MWD 2 OHMM 4 1 68 MWD 2 OHMM 4 1 68 MWD 2 OHM~ 4 1 68 MWD 2 OHMM 4 1 68 MWD 2 P.U. 4 1 68 MWD 2 FT/H 4 1 68 MWD 2 HOUR 4 1 68 MWD 2 CNTS 4 1 68 MWD 2 CNTS 4 1 68 MWD 2 G/CC 4 1 68 MWD 2 G/CC 4 1 68 MWD 2 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DEPT GR RPX RPS RPM RPD NPHI ROP FET FCNT NCNT RHOB DRHO PEF Min Max Mean Nsam 6134 11390 8762 10513 31.5477 229.02 90.9058 10385 0.0705 55.0868 2.88558 10073 0.1042 50.0377 2.94506 10073 0.2848 2000 3.63203 10073 0.1409 2000 8.8299 10073 17.417 81.6198 42.3983 10175 6.4181 2538.28 195.942 10383 0.2629 63.6444 1.56491 10073 402 1043 636.146 10175 2136 3736.76 2680.6 10175 2.1302 2.9013 2.35794 7897 -0.144 0.5111 0.0328067 7897 1.5748 9.0097 2.19478 7897 First Reading 6134 6134 6270 6270 6270 6270 6193 6199 6270 6193 6193 7366.5 7366.5 7366.5 Last Reading 11390 11326 11306 11306 11306 11306 11280 11390 11306 11280 11280 11314.5 11314.5 11314.5 First Reading For Entire File .......... 6134 Last Reading For Entire File ........... 11390 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/08/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/08/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * . ****************************** . ............................ . ....... SCMLUAIBERGER ....... . ............................ . ****************************** RECEIVED AUG 07 1997 Alm~a Oil & Gas Cons. Commission A~chorage COMPANY NAME : BP EXPLORATION (AI~SKA) WELL NAME : MPU F- 09 FIELD NAME : MILAYE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292277300 REFERENCE NO : 97323 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUL-1997 15:11 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/07/29 ORIGIN : FLIC REEL NAM~ : 97323 CONTINUATION # : PREVIOUS REEL : COf4MENT : BP EXPLORATION, MILNE POINT, MPF-09, API #50-029-22773-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/07/29 ORIGIN : FLIC TAPE NAME : 97323 CONTINUATION # : 1 PREVIOUS TAPE : CO~94ENT : BP EXPLORATION, MILNE POINT, MPF-09, API #50-029-22773-00 TAPE HEADER MILNE POINT CASED HOLE WIRELINELOGS WELL NA~E: MPU F-09 API~ER: 500292277300 OPERATOR: BP EXPLORATION (ALASKA) LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 29-JUL-97 JOB NUFiBER: 97323 LOGGING ENGINEER: YON OPERATOR WITNESS: BUNDY SURFACE LOCATION SECTION: 6 TOWNSHIP: 13N RANGE: iOE FNL: FSL: 1759 FEL: 2766 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 41.00 DERRICK FLOOR: 41.00 GROUND LEVEL: 12.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 6. 500 7. 000 26. O0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUL-1997 15:11 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH ....... THIS TAPE CONTAINS THE CASED HOLE LDWG EDIT FOR BP EXPLORATION WELL MPF-09. THIS LOG IS THE PRIMARY DEPTH CONTROL FOR THE WELL. MARKED LINE WAS USED FOR DEPTH CONTROL. $ $ PAGE: **** FILE HEADER **** FILE NAlCIE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~BER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~ff~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11292.5 1901.5 $ CURVE SHIFT DATA - PASS TO PASS (f4~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH ....... REMARKS: THIS FILE CONTAINS THE CLIPPED MAIN PASS FOR LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUL-1997 15:11 PAGE: THE GR/CCL LOG. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022488 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH GR GAPI 1022488 O0 000 O0 0 1 1 1 4 68 0000000000 TENS GR LB 1022488 O0 000 O0 0 1 1 1 4 68 0000000000 CCL GR V 1022488 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11292.500 GRCH. GR 40.909 TENS.GR 1356.000 CCL.GR DEPT. 1901. 500 GRCH. GR 34. 027 TENS. GR 1196. 000 CCL. GR O. 013 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUL-1997 15:11 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 97/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 1 DEPTH INC~: 0.5000 FILE SU~FLARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11292.5 1901.5 GRCH $ LOG HEADER DATA DATE LOGGED: Il-JUL-97 SOFTWARE VERSION: 8C0- 609 TIME LOGGER ON BOTTOM: 1400 Il-JUL-97 TD DRILLER (FT) : 11266.0 TD LOGGER (FT) : 11231.0 TOP LOG INTERVAL (FT) : 1901.5 BOTTOM LOG INTERVAL (FT) : 11231.0 LOGGING SPEED (FPHR): 5400.0 DEPTH CONTROL USED (YES/NO): YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GAIV~/~A RAY SAH-E 963 GR GAM~A RAY AH-GYRO GR GAM~A RAY PGGC 126 $ BOREHOLEAND CASING DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUL-1997 15:11 PAGE: OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 6.500 11350.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) '. FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: THIS IS THEMAIN DEPTH REFERENCE FOR THIS WELL MARKED LINE WAS USED FOR DEPTH CONTROL. SPERRY-SUN MWD 17-JUN-97 USED AS REF ONLY. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUL-1997 15:11 PAGE: TYPE REPR CODE VALUE 7 65 8 68 O. 5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1022488 O0 000 O0 0 2 1 1 4 68 0000000000 GR PS1 GAPI 1022488 O0 000 O0 0 2 1 1 4 68 0000000000 TENS PSl LB 1022488 O0 000 O0 0 2 1 1 4 68 0000000000 CCL PS1 V 1022488 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11292.500 GR.PS1 40.909 TENS.PSI 1356.000 CCL.PS1 O. 013 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 97/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAM~ : EDIT DATE : 97/07/29 ORIGIN : FLIC TAPE NAME : 97323 CONTINUATION # : 1 PREVIOUS TAPE : CO~ENT : BP EXPLORATION, MILNE POINT, MPF-09, API #50-029-22773-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUL-1997 15:11 PAGE: **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/07/29 ORIGIN : FLIC REEL NAM~ : 97323 CONTINUATION # : PREVIOUS REEL : COMFiEAUf : BP EXPLORATION, MILNE POINT, MPF-09, API #50-029-22773-00