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196-192
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ESP Change-out Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 18,430 feet N/A feet true vertical 7,554 feet N/A feet Effective Depth measured 18,295 feet N/A feet true vertical 7,428 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 17,975' 7,157' 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 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 3,090psi Burst N/A 5,750psi 7,240psi 777-8333 20" 9-5/8" 7" 4,489' 7,519' 5,410psi Casing Conductor Length 78' 9,872' 18,372' Surface Production MILNE PT UNIT KR F-54 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 155 Gas-Mcf 380 Casing Pressure Tubing Pressure 38 N/A measured 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-379 359 Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com 400 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-192 50-029-22726-00-00 Plugs ADL025509 & ADL0355021 5. Permit to Drill Number: MILNE POINT / KUPARUK RIVER OIL Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 292 Representative Daily Average Production or Injection Data 3371,179 1,539 Oil-Bbl measured true vertical Packer Size N/A WINJ WAG 72 Water-Bbl MD 112' 9,904' 18,402' TVD 112' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:38 am, Oct 14, 2020 Chad A Helgeson 2020.10.14 12:25:54 -05'00' MGR15OCT2020 SFD 10/15/2020 ,ADL 355018 DSR-10/15/2020 SFD 10/18/2020RBDMS HEW 11/25/2020 _____________________________________________________________________________________ Revised By: TDF 10/13/2020 SCHEMATIC Milne Point Unit Well: MPU F-54 Last Completed: 9/26/2020 PTD: 196-192 TD =18,430’ (MD) / TD = 7,554’(TVD) 20” Fill @ 18,295’ Washed down on 3/4/2005 KB Elev.: 41.2’/ GL Elev.: 12.1’ 7” 3 5 6 7 8 9 10 9-5/8 ” 1 2 MIN ID= 1.875” @ 17,833’ KUP Sands PBTD =18,319’(MD) / PBTD = 7,460’(TVD) 4 9 Capstring 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 9,904’ 7" Production 26 / L-80 / Btc Mod 6.276 Surface 18,402’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8RD 2.441 Surface 17,975’ 3/8” Capstring Stainless Steel N/A Surface 17,975’ JEWELRY DETAIL No Depth Item 1 119’ STA #1: 2-7/8” x 1” GLM w/ DSOV 2 17,832’ AVA Sleeve with Blanking Plug installed 3 17,854.9’ Discharge Head: PMP 400 4 17,855’ Ported Sub: PRESS PORT 400P PMP 5 17,856’ Pumps 4: 134 FLEX17.5 400PMSXD 6 17,880’ Pumps 3: 135 FLEX17.5 400PMSXD 7 17,903’ Pumps 2: 136 FLEX17.5 400PMSXD 8 17,927’ Pumps 1: 045 G12 400PMSXD 9 17,935’ Gas Separator: 538GSTHVEV 10 17,941’ Intake: Model GPINT FER H6 11 17,942’ Upper T-Seal: GSBDB SB/AB PFSA 12 17,949’ Lower T-Seal: GSBDB SB/AB PFSA 13 17,956’ Motor: 562XP 225Hp/ 2,715V/ 51A 14 17,971’ Centralizer– Btm @ ±17,975’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. Sands 18,064’ 18,072’ 7,233’ 7,239’ 8 3/5/2005 Open Kup. Sands 18,078’ 18,090’ 7,245’ 7,255’ 12 3/5/2005 Open Kup. Sands 18,097’ 18,117’ 7,260’ 7,277’ 20 4/1/1997 Open Kup. Sands 18,117’ 18,127’ 7,277’ 7,286’ 10 2/1/1997 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 2,052sks PF “E”, 860 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 300 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 74 to 78 deg. f/ 3,780’ to 16,000’ Hole Angle through perforations = 32 deg. TREE & WELLHEAD Tree 5M FMC 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr., 3” LH ACME on top and 2-7/8” EU 8rd on bottom, 2.5” CIW BPV Profile GENERAL WELL INFO API: 50-029-22726-00-00 Drilled and Cased by Nabors 22E - 1/19/1997 Completed with ESP by Nabors 4ES – 4/8/1997 ESP RWO w scalecaps by Nabors 4-ES – 10/22/1998 ESP RWO w/ Nabors 4ES – 1/15/2000 ESP RWO and Perf Add w/ Nabors 4ES – 3/6/2005 ESP RWO w/ Nabors 3S – 7/21/2008 ESP RWO w/ Doyon 16 – 12/6/2012 ESP RWO w/ Doyon 16 – 11/24/2014 ESP RWO w/ ASR – 9/08/2016 ESP RWO w/ ASR – 9/26/2020 Well Name Rig API Number Well Permit Number Start Date End Date F-54 ASR#1 50-029-22726-00-00 196-192 9/21/2020 9/26/2020 9/18/2020 - Friday No operations to report. 9/16/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/17/2020 - Thursday No operations to report. Fill IA with another 20 bbls of Source Water. Attempt to POH with completion and see 145k-lbs again. Fill IA with 40 bbls of Source Water. Attempt to POH with completion and see 145k-lbs again. Land Hanger. RILDS. Call and wait for NXS. Circulate 40 bbls of Source water with 3% NXS down tubing followed by 215 bbls of Source Water at 4 BPM and 1,500 psi. Caught returns at 100 bbls away. Lost a total of 7 bbls during circulation. NXS pill has swept the IA from 17,800' to ~ 13,000'. BOLDS. Pull Hanger and see 145k-lbs P/U weight. RIH and land Hanger. Pull Hanger and ESP completion comes free at approximately 142k-lbs. P/U is 118k-lbs. once free. Test ESP cable. Good readings from surface to ESP. L/D Landing Joint and Hanger. Cut ESP cable and retest. Cable is bad. Completion must be pulled. Pull ESP cable over the sheave. POH w/ 2-7/8" ESP completion while laying down singles . Pumping displacement every 15 joints. 41 joints out at 15:30. Continue POH w/ 2- 7/8" ESP completion while laying down singles. Pumping displacement every 15 joints. 345 joints out at 04:30. No operations to report. 9/19/2020 - Saturday MIRU ASR. Finish R/U BOPE. Perform successful BOPE shell test. Notify AOGCC representative for witness. Instructed to continue with BOPE test and he would witness when he arrived on location. Complete successful BOPE test and draw down with AOGCC witness. Tested BOPE to 250 psi low and 2,500 psi high. Tested annular to 250 psi low and 2,500 psi high. Tested w/ 2-7/8" test joint. IA and Tubing on Vac. Pull BPV. M/U 3" LH Acme crossover to 2-7/8" Landing Joint. M/U to Hanger. BOLDS. Unland Hanger at 105k-lbs P/U weight. POH and see 145k-lbs. when Hanger approaches Rig Floor. Work pipe up and down and make no progress. Land Hanger and attempt again. See 145k-lbs again. Fill IA with 20 bbls of Source Water. Attempt to POH with completion and see 145k-lbs again. 9/22/2020 - Tuesday 9/20/2020 - Sunday No operations to report. 9/21/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date F-54 ASR#1 50-029-22726-00-00 196-192 9/21/2020 9/26/2020 9/25/2020 - Friday PJSM with crew, emphasis on planning and conducting work. Recognized crew for diligence that led to today being the 5- year anniversary for No Recordables for this rig but that is also a time to reflect on the last recordable and what we can do to work safely. RIH with ESP completion on 2-7/8" 6.5# L-80 EUE tubing from 6,480'. Test ESP cable every ~1,000', place clamps on every joint due to 70°+ inclination from 3740' MD. Continue to RIH with ESP completion on 2-7/8" 6.5# L-80 EUE tubing from 6,480'. Test ESP cable every ~1,000' and place clamps on every joint. Safety meeting with crew to discuss continuing to RIH with completion and weather conditions. Discuss with night crew the 5-year anniversary for no recordables and what the team can do to continue to keep working safely. Continue to RIH with ESP completion on 2-7/8" 6.5# L-80 EUE tubing from 6,480'. Test ESP cable every ~1,000' and place clamps on every joint up to Jt 460. install clamps on every other joint from 462 to landing completion. Make ESP splice at 14,257' md. Make splice at 14,257' md. Splice is located ~ 20' in on joint #460. Continue RIH with ESP completion on 2-78' 6.5# L-80 EUE tubing from 14,257' md. Clamp ESP cable every other joint to landing completion. Continue hole fill @ 10 bbl/hr. 9/23/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Conduct crew safety meeting, emphasis on pipe handling, icy conditions. POH and lay down singles of 2-7/8" 6.5# L-80 EUE tubing. Continue to POH with 2-7/8" 6.5# L-80 EUE tubing. Total 567 jts laid down. Lay down ESP completion. Recovered 570 Canon clamps, 1,141 pins, 1 half clamp, 12 pump clamps, 4 protectolizers, 2 flat clamps. Clear and clean rig floor. Fill well with 45 bbls. RD and move spooler in preparation for rigging up E-Line unit. Move pipe and jewelry out of area, place in bunks for removal. Crew change out. PJSM on rigging up for E-line, running in new completion. Conduct service walkarounds. Nipple up shooting flange and pick up E-line lubricator. PJSM with E-line crew and rig crew before picking up perforating BHA. Check tools and M/U perforating BHA. PT E-line lubricator to 250 psi/1,700 psi. RIH with Pollard E-line perforating BHA. BHA stopped at 3,750' elmd. Pump max rate with rig pumps 6 bpm @ ~ 400psi. Catch fluid at 130 bbls pumped and approximately 3,380' md. Pumping pressure increased to 1,350 psi and rate dropped to 4 bpm. Continue trying to pass 3,750' elmd. Make slow progress and stop again at 3,890' elmd. Unable to RIH. Call engineer and discuss options. Decide to cut short perforating. POH. POOH and rig down E-line. Lay down guns, lubricator and nipple down shooting flange. Clean and clear rig floor. Install ESP cable spools in spooler trainer and spot. Stage new ESP and prepare to P/U. Begin M/U new ESP pump. Load pits with 1% KCL w/NXS. 9/24/2020 - Thursday Safety meeting with crew, emphasis on making up the ESP assembly. Discussed pinch points, swinging weight, bad weather. Conduct equipment checks and location walk around. MU new ESP Assembly: Centralizer, Zenith Motor Gauge, 225 HP Motor, Lower and Upper Tandem Seals, Intake, Gas Separator, 4 Pumps, Ported Sub and Discharge head. MU AVA sleeve with Blanking Plug installed. Test 3/8" Capillary Line to 3,000 psi. MU and RIH with the ESP Assembly on 2-7/8" 6.5# L-80 EUE 8 RD tubing. Place Cannon clamp on every joint. Test ESP cable every ~1,000'. Pre-tour safety meeting to discuss MU and RIH with completion string. Crew changeout. Continue RIH with ESP Assembly on 2-7/8" 6.5# L-80 EUE 8RD tubing. Test ESP Cable every ~1,000. Make splice at 5,911' (jt 186). Complete ESP cable splice at 5,911' (jt 186). Continue RIH with ESP Assembly on 2-7/8" 6.5# L-80 EUE 8RD tubing. Safety meeting with crew. Emphasis on landing completion, movement of equipment, slick conditions. RIH with ESP assembly on 2-7/8" 6.5# L-80 EUE tubing. Top GLM placed at 118' MD. Pick up hanger, terminate ESP Cable and Capillary string at surface, test. ESP completion set at 17,974' MD. SOW = 38k, last hookload 52k, buoyed hanging weight in 8.35 ppg source water 105k. Well Secure. 9/26/2020 - Saturday Well Name Rig API Number Well Permit Number Start Date End Date F-54 ASR#1 50-029-22726-00-00 196-192 9/21/2020 9/26/2020 Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. No operations to report. 9/29/2020 - Tuesday 9/27/2020 - Sunday No operations to report. 9/28/2020 - Monday STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I. Supry J I BOPE Test Report for: MILNE PT UNIT F-54 - Comm Contractor/Rig No.: Hilcorp ASR 1 PTD#: 1961920 ' DATE: 9/22/2020 ' Inspector Adam Earl Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: R. Burnett Rig Rep: M. Beshea inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopAGE200925144851 Rams: Annular: Valves: MASP: Type Test: [NIT ' 320-379 250/2500 ` 250/2500 '250/2500 1630 - Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: P/F Upper Kelly P/F NA Visual Alarm Time/Pressure P/F Location Gen.: P_, - Trip Tank NA _ _ NA_ System Pressure 3000 P - Housekeeping: P Pit Level Indicators P P Pressure After Closure 1300 P - PTD On Location P Flow Indicator P P 200 PSI Attained 28 P - Standing Order Posted P Meth Gas Detector P_-' _ __-P_ " Full Pressure Attained _ 106_ - P - Well Sign P H2S Gas Detector P P Blind Switch Covers: All Stations P Drl. Rig _P- MS Misc 0 NA Nitgn. Bottles (avg): 4_*_�2331 P Hazard Sec. P ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: Quantity Quantity P/F Upper Kelly 0 NA Lower Kelly - 0 - _ NA Ball Type --- 1 ' P - Inside BOP 1 ------------------ -P FSV Misc 0 NA BOP STACK: Quantity Quantity Size P/F Stripper _- 0 _ _ NA _ Annular Preventer 1 13 5/8 P #1 Rams - 1 27/8X5 P _'- #2 Rams 1 blind P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA - Choke Ln. Valves 1 - 31/8 FP HCR Valves _1 -31/8 Kill Line Valves 2 3 1/8 P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 1 - Test Results Remarks: C1 had to be functioned passed retest good test CHOKE MANIFOLD: Quantity P/F No. Valves 16 - P . Manual Chokes - I P Hydraulic Chokes 1- P " CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves - 0 NA Test Time 4 - -to 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Change-out 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 18,430'N/A Casing Collapse Conductor N/A 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 Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 9/24/2020 2-7/8" Perforation Depth MD (ft): See Schematic MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT KR F-54 N/A and N/A N/A and N/A See Schematic 78'20" 9-5/8" 7" 9,872' N/A 18,372' 5,750psi 7,240psi 4,489' 7,519' 9,904' 18,402' 7,428'1,630 N/A 112'112' 6.5# / L-80 / EUE 8rd TVD Burst 17,957' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025509 & ADL0355021 196-192 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22726-00-00 Hilcorp Alaska LLC C.O. 432D Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size 7,554'18,295' dgorm@hilcorp.com COMMISSION USE ONLY Authorized Name: Authorized Signature: 9/15/2020 Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Chad A Helgeson 2020.09.17 11:14:44 -08'00' By Samantha Carlisle at 8:45 am, Sep 18, 2020 320-379 10-404 MGR18SEP20 BOPE test to 2500 psi. Per CO 390 A no packer will be required because reservoir pressure is less than 8.55 ppg gradient. ADL035518 DLB DSR-9/18/2020 X DLB X DLB DLB 09/18/2020 X Comm. 9/18/2020 dts 9/18/2020 JLC 9/18/2020 RBDMS HEW 9/21/2020 Well Prognosis Well: MPU F-54 Date: 09/17/2020 Well Name:MPU F-54 API Number:50-029-22726-00 Current Status:ESP Producer [Failed ESP]Pad:F-Pad Estimated Start Date:September 24 th, 2020 Rig:ASR 1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:196-192 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number: Job Type:ESP Change Out Current Bottom Hole Pressure: 2,350 psi @ 7,233’ TVD (9/15/2020 / 6.3 ppg EMW) Maximum Expected BHP:2,350 psi @ 7,233’ TVD (9/15/2020 / 6.3 ppg EMW) MPSP:1,630 psi (0.1 psi/ft gas gradient) Offset Injector:MP F-42 Brief Well Summary: MPU F-54 was drilled and completed in January 1997 as a Kuparuk River formation producer. The first ESP was installed April 1997. F-54 has had multiple ESPs installed: October 1998, January 2000, March 2005, July 2008, December 2012, November 2014, and July 2016. The ESP failed September 12th, 2020. Notes Regarding Wellbore Condition x Casing tested to 3,500 psi for 30 minutes down to 9,920’ MD on 12/04/2012 x CO 390A: A packer is not required on this ESP completion as the reservoir pressure is less than 8.55 ppg EMW. Objective: Pull failed ESP and run a new ESP. Add perforations in Lower A1. Install Cap String from ESP to surface. Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with source water down tubing, taking returns up casing to 500 bbl returns tank. (Notify engineer if circulation cannot be achieved and record the volume to establish circulation.) 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. NOTE: Add perfs. DLB 09/18/2020 Well Prognosis Well: MPU F-54 Date: 09/17/2020 Brief RWO Procedure: 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ source water prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/ source water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2016 ESP swap was 115 K lbs (ASR 1) b. The PU weight during the 2014 ESP swap was 80K lbs. c. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 16. 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. 17. POOH and lay down the 2-7/8” tubing. Tubing will be cleaned and disposed. Lay down failed ESP. 18. RU EL unit/Lubricator and pressure test to 250psi low 3,500 psi high. 19. MU perforating tool string with 3-3/8”, 6spf, 60 deg phasing guns. 20. RIH (pump down if needed) and correlate gun run to reference log. (Contact Ops. Engineer confirm correlation depths). * *If any concerns that pore pressure will exceed hydrostatic, consider running kill string for perforating. Well Prognosis Well: MPU F-54 Date: 09/17/2020 21. Perforate gun run as per Table 1: MP F-54 Proposed Perf Gun Runs. POOH Gun Run # Perf Top Perf Bottom Perf Length 1 ±18,127’ ±18,154’ 27’ Total 27 Table 1: MP F-54 Proposed Perf Gun Runs a. Note any CSG pressure change. 22. RD E-line. 23. PU new ESP and 3/8” Cap string (run cap string from the centralizer on the ESP) and RIH on new 2- 7/8” tubing. Set base of ESP at ± 17,961’ MD. a. Upper GLM @ ± 141’ w/ SO b. AVA Sleeve @ 17,833’ MD c. Base of ESP @ ± 17,961’ MD 24. Land tubing hanger. RILDS. Lay down landing joint. Note SO (Slack Off) weights on repots. 25. Set BPV. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU existing 2-9/16” 5,000# tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Replace gauge(s) if removed. 6. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Blank RWO Changes Form _____________________________________________________________________________________ Revised By: TDF 10/19/2016 SCHEMATIC Milne Point Unit Well: MPU F-54 Last Completed: 9/04/2016 PTD: 196-192 TD =18,430’ (MD) / TD = 7,554’(TVD) 20” Fill @ 18,295’ Washed down on 3/4/2005 KB Elev.: 41.2’/ GL Elev.: 12.1’ 7” 3 5 6 7 8 9 10 9-5/8 ” 1 2 MIN ID= 1.875” @ 17,833’ KUP Sands PBTD =18,319’(MD) / PBTD = 7,460’(TVD) 4 9 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surf 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.679 Surf 9,904’ 7" Production 26 / L-80 / Btc Mod 6.151 Surface 18,402’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8RD 2.347 Surf 17,958 JEWELRY DETAIL No Depth Item 1 129’ 2-7/8” x 1” KBMM GLM w/ DSOV 2 17,833’ AVA Sleeve (ID= 1.875) seals OD =2.31 3 17,848’ Discharge Head FPDIS 4 17,849’ Pumps: Type 134FLEX17.5 (3) – Bottom @ 17,919’ 5 17,919’ Gas Separator 6 17,922’ Upper Tandem Seal Section 7 17,929’ Lower Tandem Seal Section 8 17,936’Motor #MSP1-250 9 17,953’ Phoenix Pumpmate XT150 10 17,955’ Centralizer (OD= 5.850) – Btm @ 17,957’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. Sands 18,064’ 18,072’ 7,233’ 7,239’ 8 3/5/2005 Open Kup. Sands 18,078’ 18,090’ 7,245’ 7,255’ 12 3/5/2005 Open Kup. Sands 18,097’ 18,117’ 7,260’ 7,277’ 20 4/1/1997 Open Kup. Sands 18,117’ 18,127’ 7,277’ 7,268’ 10 2/1/1997 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 2,052sks PF “E”, 860 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 300 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 74 to 78 deg. f/ 3,780’ to 16,000’ Hole Angle through perforations = 32 deg. TREE & WELLHEAD Tree 5M FMC 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr., 3” LH ACME on top and 2-7/8” EU 8rd on bottom, 2.5” CIW BPV Profile GENERAL WELL INFO API: 50-029-22726-00-00 Drilled and Cased by Nabors 22E - 1/19/1997 Completed with ESP by Nabors 4ES – 4/8/1997 ESP RWO w scalecaps by Nabors 4-ES – 10/22/1998 ESP RWO w/ Nabors 4ES – 1/15/2000 ESP RWO and Perf Add w/ Nabors 4ES – 3/6/2005 ESP RWO w/ Nabors 3S – 7/21/2008 ESP RWO w/ Doyon 16 – 12/6/2012 ESP RWO w/ Doyon 16 – 11/24/2014 ESP RWO w/ ASR – 9/08/2016 _____________________________________________________________________________________ Revised By: TDF 9/14/2020 PROPOSED Milne Point Unit Well: MPU F-54 Last Completed: 9/04/2016 PTD: 196-192 TD =18,430’ (MD) / TD = 7,554’(TVD) 20” Fill @ 18,295’ Washed down on 3/4/2005 KB Elev.: 41.2’/ GL Elev.: 12.1’ 7” 3 5 6 7 8 9 10 9-5/8” 1 2 MIN ID= 1.875” @ 17,833’ KUP Sands PBTD = 18,319’ (MD) / PBTD = 7,460’(TVD) 4 9 Capstring 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 9,904’ 7" Production 26 / L-80 / Btc Mod 6.276 Surface 18,402’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8RD 2.441 Surface ±17,961’ 3/8” Capstring Stainless Steel N/A Surface ±17,961’ JEWELRY DETAIL No Depth Item 1 ±129’ GLM w/ DSOV 2 ±17,833’ AVA Sleeve 3 ±17,848’ Discharge Head 4 ±17,849’ Pumps: 5 ±17,919’ Gas Separator 6 ±17,922’ Upper Tandem Seal Section 7 ±17,929’ Lower Tandem Seal Section 8 ±17,936’ Motor 9 ±17,953’ Sensor 10 ±17,955’ Centralizer– Btm @ ±17,957’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. Sands 18,064’ 18,072’ 7,233’ 7,239’ 8 3/5/2005 Open Kup. Sands 18,078’ 18,090’ 7,245’ 7,255’ 12 3/5/2005 Open Kup. Sands 18,097’ 18,117’ 7,260’ 7,277’ 20 4/1/1997 Open Kup. Sands 18,117’ 18,127’ 7,277’ 7,286’ 10 2/1/1997 Open Kup. Sands ±18,127’ ±18,154’ ±7,286’ ±7,309 27 Future Future OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 2,052sks PF “E”, 860 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 300 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 74 to 78 deg. f/ 3,780’ to 16,000’ Hole Angle through perforations = 32 deg. TREE & WELLHEAD Tree 5M FMC 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr., 3” LH ACME on top and 2-7/8” EU 8rd on bottom, 2.5” CIW BPV Profile GENERAL WELL INFO API: 50-029-22726-00-00 Drilled and Cased by Nabors 22E - 1/19/1997 Completed with ESP by Nabors 4ES – 4/8/1997 ESP RWO w scalecaps by Nabors 4-ES – 10/22/1998 ESP RWO w/ Nabors 4ES – 1/15/2000 ESP RWO and Perf Add w/ Nabors 4ES – 3/6/2005 ESP RWO w/ Nabors 3S – 7/21/2008 ESP RWO w/ Doyon 16 – 12/6/2012 ESP RWO w/ Doyon 16 – 11/24/2014 ESP RWO w/ ASR – 9/08/2016 Milne Point ASR Rig 1 BOPE 2020 Updated 1/09/2020 13-5/8” BOPE 4.48' 4.54' 2.00' 4.30'13-5/8" - 5000 2-7/8" x 5" VBR 13-5/8'͛- 5000 Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head TREE / WELLHEAD Milne Point MP F-54 9/16/2020 STATE OF ALASKA ALIIIA OIL AND GAS CONSERVATION COM,SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations U Fracture Stimulate ❑ Pull Tubing Li Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate El Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other: ESP Change-out ❑✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development ❑ Exploratory❑ 196-192 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22726-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED ADL025509&ADL0355021 MILNE PT UNIT KR F-54 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): OCT 2 0 2016 N/A MILNE POINT/KUPARUK RIVER OIL �r tr 11.Present Well Condition Summary: AOcc Total Depth measured 18,430 feet Plugs measured N/A feet ((�� true vertical 7,554 feet Junk measured N/A feet Effective Depth measured 18,295 feet Packer measured N/A feet true vertical 7,428 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 112' 112' N/A N/A Surface 9,872' 9-5/8" 9,904' 4,489' 5,750psi 3,090psi Production 18,372' 7" 18,402' 7,519' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCA" Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 17,957' 7,142' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 340 0 Subsequent to operation: 483 103 1,190 260 264 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development0 Service Q Stratigraphic ❑ Copies of Logs and Surveys Run LI 16.Well Status after work: Oil 0Gas ❑ WDSPL El Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ sUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-396 `\�� Contact Paul Chan \� Email pchan(p hiIcorp.com Printed Name Bo York Title Operations Manager Signature r" --."`✓-- Phone 777-8345 Date 10/19/2016 '` RBDMS L(-OCT 2 4 Z0 Form 10-404 Revised 5/2015 Submit Original Only • Milne Point Unit Well: MPU F-54 11 • SCHEMATIC Last Completed:9/04/2016 Ham Alaska,LLC PTD: 196-192 KB Elev.:41.2GL Elev.:12.1' TREE&WELLHEAD '/ Tree 5M FMC 2-9/16" Wellhead 11"x 7-1/16"SM FMC Gen SA,w/2-7/8"FMC Tbg.Hngr.,3"LH 20,4 it.. ACME on top and 2-7/8"EU 8rd on bottom,2.5"CIW BPV Profile OPEN HOLE CEMENT DETAIL 10 1 20" Cmt w/250 sks of Arcticset I in 24"Hole 9-5/8" Cmt w/2,052sks PF"E",860 sx Class"G"in 12-1/4"Hole , li 7" Cmt w/300 sks Class"G"in 8-1/2"Hole 1,.' CASING DETAIL 3 Size Type Wt/Grade/Conn Drift ID Top Btm �5/g.% �• 20" Conductor 91.1/H-40/N/A N/A Surf 112' 9-5/8" Surface 40/L-80/Btrc. 8.679 Surf 9,904' ' 7" Production 26/L-80/Btc Mod 6.151 Surface 18,402' e TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8RD 2.347 Surf 17,958 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle=74 to 78 deg.f/3,780'to 16,000' Hole Angle through perforations=32 deg. JEWELRY DETAIL No Depth Item 1 129' 2-7/8"x 1"KBMM GLM w/DSOV 2 17,833' AVA Sleeve(ID=1.875)seals OD=2.31 3 17,848' Discharge Head FPDIS 4 17,849' Pumps: Type 134FLEX17.5(3)-Bottom @ 17,919' 5 17,919' Gas Separator 6 17,922' Upper Tandem Seal Section 7 17,929' Lower Tandem Seal Section 8 17,936' Motor#MSP1-250 9 17,953' Phoenix Pumpmate XT150 10 17,955' Centralizer(OD=5.850)-Btm @ 17,957' PERFORATION DETAIL '` Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status Kup. Sands 18,064' 18,072' 7,233' 7,239' 8 3/5/2005 Open MIN ID=1.875" :* lis Kup. Sands 18,078' 18,090' 7,245' 7,255' 12 3/5/2005 Open @17,833' ).) 2 0 Kup. Sands 18,097' 18,117' 7,260' 7,277' 20 4/1/1997 Open * w Kup. Sands 18,117' 18,127' 7,277' 7,268' 10 2/1/1997 Open V Ys 3 GENERAL WELL INFO 4 API:50-029-22726-00-00 Drilled and Cased by Nabors 22E -1/19/1997 Ili P4,5Completed with ESP by Nabors 4ES-4/8/1997 ESP RWO w scalecaps by Nabors 4-ES-10/22/1998 id 7 ESP RWO w/Nabors 4ES-1/15/2000 «a ESP RWO and Perf Add w/Nabors 4ES-3/6/2005 g ESP RWO w/Nabors 35-7/21/2008 ESP RWO w/Doyon 16-12/6/2012 S ','9 ESP RWO w/Doyon 16-11/24/2014 1. I' ESP RWO w/ASR-9/08/2016 10 14 Fill @18296 Washed damn 1 KUP Sands on 3/4/2005 d 7"jw TD=18,430'(MD)/TD=7,554'(1VD) PBTD=18,319'(MD)/PBTD=7,460'(1VD) Revised By:TDF 10/19/2016 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Mp F-54 CTU 50-029-22726-00-00 196-192 8/2/16 9/8/16 Daily Operations: 6., 4 '. 7/27/2016-Wednesday No activity to report. 7/28/2016 -Thursday No activity to report. 7/29/2016 - Friday No activity to report. 7/30/2016-Saturday No activity to report. 7/31/2016-Sunday No activity to report. 8/1/2016- Monday No activity to report. 8/2/2016-Tuesday MIRU HAL 1.75 CTU Mast. Perform BOP test.Test good. Stand back injector for night. Secure well. Return in morning to perform operation. No Activity- Daylight Coil work only. On site. PJSM. Prepare to RIH to perform cleanout operation. Stab on well. PT 250/3,500psi. Correct CT depth to KB. Start depth is-4'. Open SSV and install fusible cap. ® • fit Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number _ Well Permit Number Start Date End Date MP F-54 CTU 50-029-22726-00-00 196-192 8/2/16 9/8/16 Daily Operations: 8/3/2016-Wednesday Open Well to 0 psi SIWHP and RIH with 1.75" OD CTC, MHA, WT BAR, DJN -OAL= 7.94'. Take returns thru choke to tiger tank-0 WHP/350 IAP. Start pumping .5 bpm down coil at 3,000' RIH.Tagged at 17,890' CTM, no restrictions encountered. Unable to get deeper. Increase pump rate to 1.1 bpm, pump 5 bbl gel sweep. Wt CK's- 2,85078.4k, 5,810710.5k, 8,500716.3k, 12,5201/20.6k, 15,000724k, 17,700731.4. POOH chasing returns. PU WT off bottom was 26k. Tag up. Shut in well. L/D Hal BHA. MU Statewide fishing string- 1.75" OD Dimple CTC, 1.695" OD DBPV, 1.7" accel, wt bar,jars, hyd disco (.5" ball/3300 psi), 2" OD XO, 2.13" OD hyd GS. OAL= 18.97' with iso sleeve OAL will be 21.04'. Pull test CTC to 30k. PT tools 200/3,500psi. Stab on well. PT to 250/3,500psi. Open swab and LMV. SSV open with fusible cap installed. RIH with 2.5 GS. WT Ck at 17,0007 32k. Start pumping and jet from 17,723'to 17,879' CTM (tag depth). PU to 17,851' CTM. RBIH dry and latch sleeve at 17,878', set down 5k. PU to 40k (8k over pull). Wt broke over and PUH (35.8k)to 17,510'. RBIH, set down same at 17,879' CTM, set down 5k, PU to 38k and PUH to 17,800'. Establish injection down backside of coil 1 bpm. POOH. While POOH, Freeze protect well with 15 bbls 60/40 meth, pumping down backside of coil.At surface, shut in well. Pop off. Isolation Sleeve recovered. L/D fishing tools. Stand back injector and BOPE. Night cap installed on well. Remove fusible cap, close SSV. Well Secure. Secure CT equipment for night. Leave location. No Activity- Daylight coil work only. 8/4/2016-Thursday RDMO Halliburton CTU equipment. 8/5/2016- Friday No activity to report. 8/6/2016-Saturday No activity to report. 8/7/2016-Sunday No activity to report. 8/8/2016- Monday No activity to report. 8/9/2016-Tuesday No activity to report. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-54 ASR 50-029-22762-00-00 196-192 8/2/16 9/8/16 Daily Operations: 8/31/2016-Wednesday No activity to report. 9/1/2016-Thursday No activity to report. 9/2/2016- Friday No activity to report. 9/3/2016-Saturday No activity to report. 9/4/2016-Sunday Move Misc. Rig Equipment from MPK Pad to MPF Pad, Rig up on MPF-54, Spot Mud Tank, raise stairs, Set Wellsite trailer, Start ND of Production Tree. 9/5/2016- Monday ND Production Tree,Verify hanger threads, Nipple up BOPs. AOGCC was notified of right to witness BOP Test on 9-3-2016 @ 22:38 hrs. Set Rig floor, Back in Rig on Mud Boat, Raise Derrick, secure Derrick& Pin, Set Stairs, Rig up Cat walk, install Koomey lines to BOP, install Circulating hoses& choke & kill lines to BOP. Connect Gas alarms& Calibrate and Test alarms, (AOGCC, Chuck Scheve waived witness for BOP Test on 9-5-16 @ 12: 39 PM.) Rig up &Test BOPs per AOGCC requirements, Tested with 2-7/8" Test joint,Tested to 250/2,500psi,Test Annular 250/2,500psi 5 Min each Test,Tested Accumulator, Record Pre-Charge Pressures R/D Test Equipment Same. Held Sundry Meeting with Crew MPF-54. Well Head Rep Tee Bar TWC Valve From Hanger. Hang ESP Sheave and E-Trunk in Derrick, Make up Landing Joint. RIH. Make up in Hanger, BOLDS. Open IA PSI=0;Pulled Hanger to the Rig Floor, Unseated at 98k Free Pull at 115k. Break and Lay down Landing Joint.Trip out of the hole lay down 2-7/8" Tubing 180 Joints out. Currently @ 12,300'. 9/6/2016-Tuesday Service Rig, Check Fluid in all Equipment. Continue to TOOH, Laying Down 2-7/8" Tubing, replaced Jts 80-170) Layed down Total of 434 Joints, Currently @ 4,400ft. Installed TIW Valve. Roads and Pads Pulled ESP Spooler Forward to Changed out Reels in Spooling unit. Continue to TOOH, Laying Down 2-7/8" Tubing From 13,540 ft to 17,961 ft.Total jts 571. Break and lay down ESP Pump Assembly, No solids seen in Pump discharge head. Pump shaft would not rotate. Change out ESP Reels in Spooling Unit, Tally 300 joints on Pipe Rack. • I Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-54 ASR 50-029-22762-00-00 196-192 8/2/16 9/8/16 Daily Operations. .0, 9/7/2016-Wednesday Make up &service ESP Assembly, Make up 10' Pup &AVA sub. Waited on Centrilift to deliver Pump clamps.TIH with New ESP Assembly& 2-7/8"Tubing, to ( 9,180 ft.) (291 joints) Check cable continuity each 2,000'. Reel to Reel Cable Splice, Load and Tally 2-7/8" Tubing on Racks. 9/8/2016-Thursday Reel to Reel Cable Splice, Load and Tally 2-7/8" Tubing on Racks. Continue to TIH with New ESP Assembly& 2-7/8" Tubing, F/( 9,180 ft.) Check cable continuity each 2000'. Make up Landing joint into Hanger, Install Penetrator and Align with Flow Line (Ran 567 Total Joints). Make Penetrator ESP Cable Splice on Tubing Hanger. Land Hanger RILDS, Break out and Lay down Landing Joint, P/U/W=114k S/O/W= 15k.Well Head Rep Tee Bar Install TWC Valve;Electricians Disconnected Fire and Gas Alarms, Blow down and Disconnect all Lines, Remove ESP Sheave and Hoses from Derrick, Prep Rig Floor and Derrick For Rig Down. Break over Lower Derrick onto Carrier Drove ASR Rig to VMS Shop on A-Pad to have the Radiator Changed out and Engine oil Leak Fixed. Peak Hauling Cat Walk, Stairs Pipe Racks Mise. Rig Equipment to MP H-Pad, Roads and Pads Crane Assisted in the removal of the Rig Floor and Well House, Remove BOP, Install Production Tree,Test Hanger void at 500/5,000psi, Pull BPV. 9/9/2016- Friday No activity to report. 9/10/2016-Saturday No activity to report. 9/11/2016-Sunday No activity to report. 9/12/2016- Monday No activity to report. 9/13/2016-Tuesday No activity to report. • Wyk Fs4 Ptt (% Regg, James B (DOA) From: Brooks, Phoebe L (DOA) Sent: Thursday, September 15, 2016 3:30 PM 'P.m 1� 1511 To: Craig Smith - (C) l Cc: Regg,James B (DOA) Subject: RE: Revised Test Results Milne point MPF-54 Test Charts Attachments: Hilcorp ASR 1 09-05-16 Revised.xlsx I made a couple more revisions; since the number of failures now include 0 I changed the#1 Rams to reflect "P". I also changed the check valve test result to reflect "NA" (as the quantity was listed as 0). Please update your copy. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Sat4 ED J041. 7251"7 Phone: 907-793-1242 Fax: 907-276-7542 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Regg, James B (DOA) Sent: Thursday, September 15, 2016 3:12 PM To: Craig Smith - (C) Cc: Brooks, Phoebe L (DOA) Subject: RE: Revised Test Results Milne point MPF-54 Test Charts Attached report makes more sense to me—0 failures; made some edits to the remarks. Let us know if this is not correct. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Craig Smith - (C) [mailto:crsmith@hilcorp.com] Sent: Tuesday, September 13, 2016 8:36 PM 1 • Regg, James B (DOA); Brooks, Phoebe L (DOA) • Subject: Revised Test Results Milne point MPF-54 Test Charts Jim I hope this Clears things up A little Trapped air In pipe ram Cavity Not Sure, Did not Observe any Leaks Just a Pressure t/ Decrease on Test Chart Pressure Back up Held for 5min Thank You Craig R Smith Well Site Supervisor Hilcorp Alaska ASR RIG 1 O (907) 310-0243 C (208) 816-6803 2 • • ' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSIONrj �6`w BOPE Test Report Submit to: jim.reggCcr�.alaska.gov AOGCC.Inspectors alaska.00v phoebe.brooksac alaska.00v Contractor: Hilcorp Rig No.: ASR 1 - DATE: 9/5/16 - Rig Rep.: Darrel Bledsoe Rig Phone: 907-310-0243 Operator: Hilcorp Alaska Op. Phone: 208 816-6803 Rep.: Craig Smith E-Mail crsmith@hilcorp.com Well Name: MPU F-54 - PTD# 1961920 Sundry# 316-396 - Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250/2,500 - Annular: 250/2,500 Valves: 250/2,500 • MASP: 1639 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P - Well Sign P • Upper Kelly 0 NA Housekeeping P - Rig P • Lower Kelly 0 NA PTD On Location P - Hazard Sec. P • Ball Type 1 - P• Standing Order Posted P - Misc. NA Inside BOP 1 . P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 ' 11" P - Pit Level Indicators P P - #1 Rams 1 • 2-7/8"x 5" - P - Flow Indicator NA NA #2 Rams 1 - Blinds • P - Meth Gas Detector P P - #3 Rams 0 NA H2S Gas Detector P - P - #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 - 2 1/16" • P • Inside Reel valves 0 NA HCR Valves 1 - 2 1/16" - P - Kill Line Valves 2 - 2 1/16" - P - Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 2,900 P - CHOKE MANIFOLD: Pressure After Closure(psi) 1,700 - P • Quantity Test Result 200 psi Attained(sec) 12 • P - No.Valves 15 • P - Full Pressure Attained (sec) 55 - P ' Manual Chokes 1 - P - Blind Switch Covers: All stations Yes - Hydraulic Chokes 1 - P Nitgn. Bottles#&psi (Avg.): 4 @ 2,500 - P - CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 ' Test Time: 3.5 ' Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Tested with 2-7/8"Test Joint.Tested Gas Alarms and all good. Test#2-Trapped air pipe rams cavity, bleed off, pressure back up, held good(Pass); Test#3-ran out of test chart, bleed off pressure, replace chart with new one, pressure up to 3,000 psi for 5 min,tested good(Pass);Test#7-Leak on test pump bleeder valve, replaced,tested good(Pass). AOGCC Inspection I 24 hr Notice Yes Date/Time 9-3-2016 2238 pm Waived By Chuck Scheve Test Start Date/Time: 9/5/2016 16:00 (date) (time) Witness Test Finish Date/Time: 9/5/2016 19:30 Form 10-424(Revised 11/2015) Hilcorp ASR 1 09-05-16 Revised.xlsx • • • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regqaalaska.gov AOGCC.Inspectors a(�alaska.gov phoebe.brooks(a,alaska.gov Contractor: Hilcorp Rig No.: ASR 1 DATE: 9/5/16 Rig Rep.: Darrel Bledsoe Rig Phone: 907-310-0243 Operator: Hilcorp Alaska Op. Phone: 208 816-6803 Rep.: Craig Smith E-Mail crsmith@hilcorp.com Well Name: MPF-54 PTD# 196-192 Sundry# 16-396 Operation: Drilling: Workover: X Explor. Test: Initial: X Weekly: Bi-Wee y: Test Pressure(psi): Rams: 250/2,500 Annular: 250/2,500 V. yes: 250/2,500 MASP: 1639 MISC. INSPECTIONS: TEST DATA LOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P .pper Kelly 0 NA Housekeeping P Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Misc. NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 11" P Pit Level Indicators P P #1 Rams 1 2-7/8"x 5" FP? Flow Indicator NA NA 1./) #2 Rams 1 Blinds P Meth Gas Detector P P �,,, #3 Rams 0 NA H2S Gas Detector P P C^'` #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 N• #6 Rams 0 IA Quantity Test Result cr t., Choke Ln. Valves 1 2 1/16" P Inside Reel valves 0 NA `? HCR Valves 1 2 1/16" P (\c'-;)' \,� Kill Line Valves 2 2 1/16" P �'' Check Valve 0 P ACCUMULATOR SYSTEM: 1' BOP Misc FP' ti�i— Time/Pressure Test Result System Pressure(psi) 2,900 P CHOKE MANIFOLD: Pressure After Closure(psi) 1,700 P Quantity Test r esult 200 psi Attained(sec) 12 eco P No. Valves 15 P Full Pressure Attained(sec) 55set; P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles#&psi(Avg.): 4 @ 2,500 P CH Misc -4- G ,.P' &. ACC Misc 0 NA J j Test Results Number of Failures: ra' Test Time: 3_5 Hours Repair or replace -nt of equipment will be made within days. Notify t - AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Tested with 2-7 ;"Test Joint.Tested Gas Alarms and all good. 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Ski, b+ ,., 00 7 \ \ \ „------- --- c..-'-' ,.. / CI ><- O ' ',., ---.... ---------.__ -'-- .: __--- ---- 00 -* ,..-';> /7 0,,X Nc9A / ,,,, ._....------ .-- v ' .-.-•:.- , _..a_ ___.-- _ _00S_____., - -- - " -------(-_:- ----- ' "- - - --- _ S citgliCe 1C--htgi• Pcs 1 --P 4,Ptk -F—stc- P1 31'. OF T • • _,s' yy��,v THE STATE Alaska Oil and Gas e.,....--,..i..4,.. 7,,,,, Of/\ /` sKA Conservation Commission 'Witt _�y^- 333 West Seventh Avenue 11,11-11T111*- -'. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 vetif 'OF� n rP Main: 907.279.1433 LA`3 Fax: 907.276.7542 www.aogcc.alaska.gov Bo York SCANNED JAN 1 ` 2 b ly Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR F-54 Permit to Drill Number: 196-192 Sundry Number: 316-396 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, de-L P CathyFo . erster Chair DATED this �-y of August, 2016. RBDMS (,c- AUG 1 1 2016 • • RECEIVED JUL 27 2016 STATE OF ALASKA /YTS g'2-6/I0 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well D, Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q - Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC • Exploratory ❑ Development ❑✓ 196-192 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-22726-00-00 . 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 0 1 MILNE PT UNIT KR F-54 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 025509&ADL0355021 " MILNE POINT/KUPARUK RIVER OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 18,430' ' 7,554' ' 18,295' • 7,428' • 1,639 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 112' 112' N/A N/A Surface 9,872' 9-5/8" 9,904' 4,489' 5,750psi 3,090psi Production 18,372' 7" 18,402' 7,519' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: See Attached Schematic I See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 8,559 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 Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 8/9/2016 ❑ ❑ WDSPL ❑ Suspended CI Operations: OIL WINJ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Paul Chan Email pchan@hilcorp.com Printed Name BoYork Title Operations Manager Signature C 'Z. . Phone 777-8345 Date 7/27/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test Mechanical Integrity Test Location Clearance ❑ Other: -2 ps., 66P es t- Post Initial Injection MIT Req'd? Yes ❑ No ❑LTJ/ J �—,(,? ��� Spacing Exception Required? Yes ❑ No Subsequent Form Required: 1(5 '/O l ) APPROVED BY Approved by: P COMMISSIONER THE COMMISSION Date: e --4--/6 flit 1111!9 irk, 8.2-go ORIGINAL -0,/ . Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate RBDMS w PIM 1 1 7016 . • • Well Prognosis • Well: MPU F-54 Hi'carp Alaska,LL1 Date:07/27/2016 Well Name: MPU F-54 API Number: 50-029-22726-00 Current Status: Oil Well [Failed ESP] Pad: F-Pad Estimated Start Date: August 9th, 2016 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-192 First Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907)331-8228 (M) AFE Number: Current Bottom Hole Pressure: 2,349 psi @ 7,102' TVD (ESP PP 07/22/2016/6.36 ppg EMW) Maximum Expected BHP: 2,349 psi @ 7,102' TVD (No new perfs being added)/ MPSP: 1,639 psi (0.1 psi/ft gas gradient) Brief Well Summary: '` ! /VS 1-: '-'11&")11&w MPU F-54 was drilled and completed in January 1997 as a Kuparuk River formation producer. The first ESP was installed April 1997. F-54 has had multiple ESPs installed: October 1998, January 2000, March 2005, July 2008, December 2012, and November 2014. The ESP has failed. Notes Regarding Wellbore Condition • Casing tested to 3,500 psi for 30 minutes down to 9,920' MD on 12/04/2012 ©frci7\ e,/ i • CO 390A: A packer is not required on this ESP completion as the reservoir pressure is less than 8.55 \5� ppg EMW. Objective: Pull failed ESP and run a new ESP. Pre-Rig Procedure: 1. Clear and level pad area in front of well.Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house.Spot mud boat. • • Well Prognosis • Well: MPU F-54 Hilcory Alaska,LLQ Date:07/27/2016 Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. . 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg sea water prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. Gy c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8"test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor VAI/ the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) (;° d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection,etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg sea water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2014 ESP swap was 120K lbs(includes 49K lbs block weight). b. The PU weight during the 2012 ESP swap was 157K lbs after pumping 550 bbl 1%Safe Lube pill (includes 40K lbs block weight). c. If needed,circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. d. Contingency Casing Jack Procedure: If the tubing hanger will not come off seat or the ESP will not come off bottom after circulating lubricant, RU casing jacks as follows: i. PU Casing Jacks via the beaver slide and Tugger winches to rig floor t C wS ii. Set casing jacks on top of the BOP Annular with Tuggers. Connect Hydraulics and function test same. RU Casing jack Hydraulics to the ASR#1 control Panel. Set pressure relief high point 9:"/ iv. 100%Yield strength of 2-7/8", 6.5#, L-80= 145K lbs • • Well Prognosis • Well: MPU F-54 Hiicorp Alaska,LU Date:07/27/2016 v. Cycle jacks up and down to ensure proper function (dry run without being connected to hanger). 16. Reyover the tubing hanger. 4 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. 17. POOH and lay down the 2-7/8"tubing. Number all joints. Tubing will be re-used as noted. Lay down failed ESP. a. Tubing caliper run 11/2/14: replace joints 80—170. b. Replace bad joints of tubing as necessary. c. Look for over-torqued connections from previous Doyon 16 tubing runs. 18. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP at± 17,961' MD. a. Upper GLM @ ± 141'w/SO eb)` b. AVA sleeve @ 17889' c. Base of ESP @ ± 17,961' MD 19. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO(Slack Off)weights on tally. 20. Set BPV. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Replace gauge(s) if removed. 6. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic 5. Existing Tree/Wellhead 6. Blank RWO Changes Form • Milne PoiU Well: MPU un F-54nit n 0 • SCHEMATIC Last Completed: 11/24/2014 flacons Alaska.LLC PTD: 196-192 TREE&WELLHEAD KB Elev.:41.2'/GL Elev.:12.1' - Tree 5M FMC 2-9/16" a 11"x 7-1/16"5M FMC Gen 5A,w/2-7/8"FMC Tbg.Hngr.,3"LH 20 j , *i [i Wellhead ACME on top and 2-7/8"EU 8rd on bottom,2.5"CIW BPV Profile G OPEN HOLE/CEMENT DETAIL 11 1 / 20" Cmt w/250 sks of Arcticset I in 24"Hole 9-5/8" Cmt w/2,052sks PF"E",860 sx Class"G"in 12-1/4"Hole s* 7" Cmt w/300 sks Class"G"in 8-1/2"Hole ,. CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 9-5/8"4 ' 20" Conductor 91.1/H-40/N/A N/A Surf 112' �9c) t 9-5/8" Surface 40/L-80/Btrc. 8.679 Surf 9,904' 7" Production 26/L-80/Btc Mod 6.151 Surface 18,402' TUBING DETAIL 2-7/8" 1 Tubing 6.5/L-80/EUE 8RD 2.347 Surf 17,958 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle=74 to 78 deg.f/3,780'to 16,000' Hole Angle through perforations=32 deg. JEWELRY DETAIL No Depth Item 1 141' 2-7/8"x 1"KBMM GLM w/DSOV 2 17,889' AVA Sleeve(ID=1.875) 3 17,903.56' Discharge Head 4 17,904' 137-P17 SXD Pump 5 17,923' Gas Separator Coated GSTHVEVXH6 6 17,928' Upper Tandem Seal Section GSB3DBUT SB/SB PFSA 7 17,935' Lower Tandem Seal Section GSB3DBUT SB/SB PFSA CL5 8 17,942' Motor CL-5,MSP1-250 F,210HP,2380 Volt,53 amp 9 17,959' Phoenix Pumpmate 10 17,961' Centralizer(0D=5.850) PERFORATION DETAIL to Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup. Sands 18,064' 18,072' 7,233' 7,239' 8 3/5/2005 Open MINID=1.875" t 'f Kup. Sands 18,078' 18,090' 7,245' 7,255' 12 3/5/2005 Open @17889' 2 0Kup. Sands 18,097 18,117' 7,260' 7,277' 20 4/1/1997 Open a> a 3 Kup. Sands 18,117' 18,127' 7,277' 7,268' 10 2/1/1997 Open % GENERAL WELL INFO 4 API:50-029-22726-00-00 I I C 5Drilled and Cased by Nabors 22E -1/19/1997 6 Completed with ESP by Nabors 4ES-4/8/1997 ` ESP RWO w scalecaps by Nabors 4-ES 10/22/1998 `°7 ESP RWO w/Nabors 4ES-1/15/2000 'i ESP RWO and Perf Add w/Nabors 4ES-3/6/2005 8 ESP RWO w/Nabors 3S-7/21/2008 ESP RWO w/Doyon 16-12/6/2012 to.9 ESP RWO w/Doyon 16-11/24/2014 T 10 A Fill @18,295' yf IK[PSadS on 3/4/2005 7 S:a `� r TD=18,430'(MD)/TD=7,554'(WD) PBTD=18,319'(MD)/PBTD=7,4601WD) Revised By:TDF 7/22/2016 • Milnll:e PointMPU Unit We • PROPOSED Last Completed: 11/24/2014 1Hileorp Alaska,LLC PTD: 196-192 TREE&WELLHEAD KB Elev.:41.2'/GL Elev.:12.1' Tree 5M FMC 2-9/16" )' ;^ Wellhead 11"x 7-1/16"5M FMC Gen 5A,w/2-7/8"FMC Tbg.Hngr.,3"LH 20, '," IP ACME on top and 2-7/8"EU 8rd on bottom,2.5"CIW BPV Profile 3 OPEN HOLE/CEMENT DETAIL ;` 1e. 20" Cmt w/250 sks of Arcticset I in 24"Hole P3 9-5/8" Cmt w/2,052sks PF"E",860 sx Class"G"in 12-1/4"Hole 0 7" Cmt w/300 sks Class"G"in 8-1/2"Hole yi t` CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm ,: 20" Conductor 91.1/H-40/N/A N/A Surf 112' 9-5/8" le 9-5/8" Surface 40/L-80/Btrc. 8.679 Surf 9,904' 7" Production 26/L-80/Btc Mod 6.151 Surface 18,402' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8RD 2.347 Surf 17,958 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle=74 to 78 deg.f/3,780'to 16,000' Hole Angle through perforations=32 deg. JEWELRY DETAIL No Depth Item 1 ±141' 2-7/8"x 1"KBMM GLM w/DSOV 2 ±17,889' AVA Sleeve(ID=1.875) )i�1� 3 ±17,903.56' Discharge Head f 4 ±17,904' Pump 5 ±17,923' Gas Separator Y.' 6 ±17,928' Upper Tandem Seal Section 7 ±17,935' Lower Tandem Seal Section 8 ±17,942' Motor 9 ±17,959' Phoenix Pumpmate 10 ±17,961' Centralizer(OD=5.850)-Btm @±17,963' PERFORATION DETAIL .* y Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup. Sands 18,064' 18,072' 7,233' 7,239' 8 3/5/2005 Open MIN1�1.875" l` 1 Kup. Sands 18,078' 18,090' 7,245' 7,255' 12 3/5/2005 Open @17,889' 2 0, Kup. Sands 18,097' 18,117' 7,260' 7,277' 20 4/1/1997 Open k; Kup. Sands 18,117' 18,127' 7,277' 7,268' 10 2/1/1997 Open 9" F`3 x GENERAL WELL INFO 4 API:50-029-22726-00-00 il " Drilled and Cased by Nabors 22E -1/19/1997 ' II 5 6 Completed with ESP by Nabors 4ES-4/8/1997 ESP RWO w scalecaps by Nabors 4-ES-10/22/1998 7 ESP RWO w/Nabors 4ES-1/15/2000 ESP RWO and Perf Add w/Nabors 4ES-3/6/2005 8 ESP RWO w/Nabors 3S-7/21/2008 ESP RWO w/Doyon 16-12/6/2012 9 ESP RWO w/Doyon 16-11/24/2014 t, k'" 10 Fill @ 18,295 }Kl1P Sands Washed dotin on 3!4/2005 7" ". sti.° TD=18,430'(MD)/TD=7,554'(TVD) PBTD=18,319'(MD)/PBTD=7,460'(TVD) Revised By:TDF 7/26/2016 • • • • firMilne Point ASR Rig 1 BOPE 11.1,-orp ll t.1.4 I I t: 11" BOPE Stripping Head ( 1 3.98' °160Shaffer 11"- 5000 , II MU 1 t h 11 ! t .4- J41ltili 1. it 1 C1-74C11 -UFN 4.54' H r '0 H VBR or Pipe Rams /,____Al. 0 (-• . 1 b v 11" 5000 H b®® u i H Blind tin rhTSIn_U_l 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves 2.00' 0� t,o; > 1 . i0 Manual Manual Manual HCR Updated 8/19/2015 • • Choke Manifold ASR#1 11/01/2015 110,09, 11:,4, ,IJ.r: Digital t Reverse line back to Kill Manifold Pressure Readout C2 � � . C3 Digital Pressure Transmitter 1111111- w N 0 71.3 0� 0 0 From Choke Line Manual Choke (� 1 pIAge ) 0 00 i f�� 4 B Remote A i Choke C4 C5 C6 C7 .,.. , I r©,iv. c cad 1 0 ® 0 ( Qr+ Oaf s I -' i. � .--f C9 ` 4 All Valves 2" , : ---a Piper Series PB Ball Valves 6,170 psi Working 10,000 psi Tested C8 IC> C11 �le!�1 1- C10 111111110 - a�►J oaw,) a C13 C15 eTtN 0 t il 0 0 .. •o a4 p 0 C12 ,t'. ,.I L , `Q 0, RIM hl l �•'� C 14 � ( C16 lig t . CJ► itt To Panic Line ;– „�� � 1502 Union Outside ill, Iii End Capped i To Gas Buster • BHTA,Otis,2 9/16 5M 111 0 ... Mb MPF-54 EMI,M. WIIIIIIIIIIIIIIIIIIIIIIIIII Tubing hanger,FMC 7 X 2 Hu 1st 7/8&2"Y.;"'type 1-IBPV Pilliet. Valve,Swab,CIW, 0 ;fit:. profile 3"LH acme thread Top/2 7/3 EUE 3rd thread 2 9/16 5M HWO ii,IM e '''ci • Bottom _—, - — , ...low itt ill 07, ulli NW El • ei• s s s(>, 4111Vii E. •,:t'0',2',"," ;111. Mil. ".1111=1 OP' -• t, Valve,SSV,SSV,OW, s (° 2 9/16 5M FE,Baker oper, 0 ..,,,, ..... Artz_ I-4, MilliMINIMMI 0 - M11.11.11- 11- ll' E MI /I' : ®ø, ..j....''' Valve,Master,CIW, , H6rM1‘ 0 2 9/16 SM HWO,DO (rill . Adapter,FMC A-5-EC, M 7"5M rot fig btm X . 2 9/16 5M stdd top, de eih.4.-•, J -1.. 11"X 7"Tubing head,FMC Gen 5 akill E ii-I U= 1 11 = ra-. 1 : _ I , -,1 1lT-_- 11 I •I * ill If Casing head,FMC 11" Fig 110114-- All casing valves2 1/16 5M Top Ell= wir Ma 11 i 1- 1 8 __ __ ____ — i',,, '',.. — ! ',. :'-'1' •in .. ;11 _, . ,-) I 1.1 1 '..-00 1 -1 MI 1 ..v) II' 111111-1*-i € , All casing valves2 1/16 5M , — — 0 0 c cD CD 4 - 0 / / ƒ 2 o ca 6 0 ■ c ° 02 .0 0 < O. O. et § e < --- a E n o . _ (fl 73 00 Y >d / 0 f 0.. f \ « >, ,_ .- 0 \ 00 \ 7, Y07 2 f < 0_ ke = a) zo OZ Ie CO % •® 3 a \ / a a o 0 co co / i � ƒ CD _o / ° o 0 •a• / \ ■ = k/ M 0 O. \ \ Q % / k ' 70 0 k % 2 2 0 2 E § a. c G ® O 2 0 .R 0 a i 2 .0 0. 4 S / 2 »7 _ � # r Cr 0 j — \ \ ct k CD @ — e E . 0 O. kG m § m / 2 / co ■ w k ■ / o c § 0 oi & n .2 'Z. k o c 0 � I -) k \ / . .- a. � � .. � / / � / U c g • 23 0co I « ° 2 < STATE OF ALASKA E. JKA OIL AND GAS CONSERVATION CC. AISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑Abandon 0 Repair Well 0 Plug Perforations 0 Perforate 0 Re-Enter Suspended Well ❑Alter Casing ®Pull Tubing 0 Stimulate-Frac 0 Waiver ®Other ❑Change Approved Program 0 Operation Shutdown 0 Stimulate-Other 0 Time Extension Change out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic 196-192 3. Address. IN Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-22726-00-00 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 025509&355021 MPF-54 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s). Milne Point Unit/Kuparuk River Sands _ 11. Present well condition summary: RECEIVED Total depth: measured 18430' feet Plugs:(measured) None feet true vertical 7543' feet Junk:(measured) None feet DEC 1 9 2014 Effective depth: measured 18319' feet Packer: (measured) None feet (� true vertical 7448' feet Packer: (true vertical) None feet AOGCC Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 34'- 112' 34'- 112' 1490 470 Surface 9872' 9-5/8" 32'-9904' 32'-4489' 5750 3090 Intermediate Production 18372' 7" 30'- 18402' 30'-7519' 7240 5410 Liner SCANNED JAN 3 0 20 Perforation Depth Measured Depth: 18064'-18127' feet True Vertical Depth: 7233'-7286' feet Tubing(size,grade,measured and true vertical depth). 2-7/8",6.5# L-80 17963' 7147' Packers and SSSV(type,measured and true vertical depth): None None 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 203 35 746 300 236 Subsequent to operation: 0 0 0 450 0 14.Attachments. ❑Copies of Logs and Surveys run 15.Well Class after work. 0 Exploratory 0 Stratigraphic ® Development 0 Service 0 Daily Report of Well Operations 0 Well Schematic Diagram 16. Well Status after work: 0 Oil 0 Gas 0 WDSPL 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O Exempt: Contact Abby Warren,564-5720 Email:Abigail.Warren@bp.com N/A Printed Name: Joe Lastu w Title: Drilling Technologist Signature: Phone: 564-4091 Date: 124 g nil-- Form 10-404 Revised 10/2012 f—G`1—0-- kiSEbmit Original Only !� �z�3- RBDMBJAN - 4 2'115 North America-ALASKA-BP Page 1 of 7 Operation Summary Report Common Well Name:MPF-54 AFE No Event Type:WORKOVER(WO) Start Date:11/19/2014 End Date:11/24/2014 X4-010W0-E:(1,765,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:12/24/1996 12:00:OOAM Rig Release:11/24/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292272600 Active datum:ORIG KELLY BUSHING @31.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/19/2014 13:00 - 14:00 1.00 MOB P PRE PJSM,PREP FOR RIG MOVE -RDMO OFF MPF-94 _-FUNCTION MOVING SYSTEM AND ESD 14:00 - 14:30 0.50 MOB P PRE MOVE OFF OF MPF-94 14:30 - 16:00 1.50 MOB P PRE MOVE RIG TO CENTER OF PAD -REMOVE MATS FROM MPF-94 AND LAY MATS AROUND MPF-54 -POSITION RIG OVER MPF-54 AND SHIM IN PLACE FOR LEVEL 16:00 - 17:00 1.00 MOB P PRE MIRU CUTTINGS TANK,FUEL TRAILER AND CREW TRAILER -PREP FOR RIG ACCEPTANCE 17:00 - 18:30 1.50 WHSUR P DECOMP """"""ACCEPT RIG AT 17:00 HOURS ON MPF-54 I-RIG UP CIRCULATING LINES IN CELLAR TO KILL MANIFOLD AND TREE -WELL SUPPORT R/U HARD LINE TO FLOW BACK TANK -TAKE ON 9.2 PPG BRINE TO PITS 18:30 - 19:00 0.50 WHSUR P DECOMP TEST ALL CIRCULATING LINES FROM TREE TO FLOW BACK TANK -REVIEW PRESSURE CROSS CHECK LIST TEST 250/3500 PSI,5 MIN,CHART 19:00 - 20:00 1.00 WHSUR P DECOMP HOLD RIG EVACUATION FIRE DRILL -HOLD AAR AND PRE-SPUD MEETING AT SAFE BRIEFING AREA 20:00 - 00:00 4.00 WHSUR N WAIT DECOMP PLACE RIG ON WEATHER HOLD DUE TO PHASE CONDITION WEATHER -UNABLE TO GET FULL VOLUME OF BRINE TRUCKS NEEDED TO RIG -HANG ESP SHEAVE AND TRUNK -M/U TEST EQUIPMENT FOR UP-COMING BOP TEST -OA=0 PSI -IA=500 PSI TUBING=0 PSI,(BPV INSTALLED) 11/20/2014 00:00 - 04:00 4.00 WHSUR N WAIT DECOMP PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -PLACE RIG ON WEATHER HOLD DUE TO PHASE CONDITION WEATHER -UNABLE TO GET FULL VOLUME OF BRINE TRUCKS NEEDED TO RIG 04:00 - 06:00 2.00 WHSUR P DECOMP SUFFICENT KWF, 9.2 PPG BRINE IS ON LOCATION -PJSM,REVIEW PRESSURE CROSSCHECK -R/U WELL SUPPORT LUBRICATOR -TEST LUB,250/3500 PSI,5 MIN,CHART PULL BPV,R/D W/S LUB Printed 12/8/2014 10:46:14AM North America-ALASKA-BP Page 2 of 7 Operation Summary Report Common Well Name:MPF-54 AFE No Event Type:WORKOVER(WO) Start Date:11/19/2014 End Date:11/24/2014 X4-010WO-E:(1,765,000.00) Project Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:12/24/1996 12:00:OOAM Rig Release:11/24/2014 Rig Contractor DOYON DRILLING INC. UWI:500292272600 Active datum:ORIG KELLY BUSHING @31.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 12:00 6.00 WHSUR N WAIT DECOMP SHUT IN TUBING PRESSURE=450 PSI,SICP =500 PSI,0/A=0 PSI. -PHASE 3 DECLARED IN MILNE PT.SECURE WELLAND MINIMIZE EXPOSURE. -PERMISSION GIVEN TO PERFORM CREW CHANGE W/MILNE PT HEAVY EQUIPMENT AS CONVOY LEADER. NORMAL CREW CHANGE OUT AND(3) VACUUM TRUCKS ESCORTED TO MILNE PT. 12:00 - 19:00 7.00 WHSUR N WAIT DECOMP PJSM.HANDS DISCUSSED PHASE 3 PROTOCOL. -USING THE BUDDY SYSTEM,MINIMIZING WORK/RISK. -@ 16:45 HRS MILNE PT BASE CAMP CALLED TO INFORM US DOWN TO PHASE 2. REVIEWED JOURNEY MANAGEMENT PROCEDURE. ARRANGEMENTS MADE FOR VACUUM TRUCKS TO MOBILIZE BACK OUT THRU CH2MHILL. 19:00 - 00:00 5.00 KILLW P DECOMP PJSM FOR WELL KILL OPERATIONS -REVIEW PRESSURE CROSS CHECK LIST. RIG PRV SET @ 4200 PSI. '-TUBING=440 PSI,IA=500 PSI,OA=0 PSI -BLEED IA UNTIL FLUID RETURNS,FLUID RETURNS OBSERVED AFTER 2 MIN BLEED TIME -PUMP 110 BBLS,120 DEGREE 9.2 PPG BRINE DOWN TUBING,TAKING RETURNS OUT IA TO FLOW BACK TANK(FBT),3 BPM= 580 PSI FCP -SHUT IN AT CHOKE AND BULLHEAD 14 BBLS 9.2 PPG TO PERFS,3 BPM=1680 PSI FCP -PUMP 40 BBL 9.2 PPG BRINE WITH DEEP CLEAN SWEEP DOWN TUBING,RETURNS TO FBT -PUMP 772 BBLS(TOTAL 812 BBLS)OF 120 DEGREE 9.2 PPG BRINE DOWN TUBING, RETURNS OUT IA TO FBT,5 BPM=2570 PSI FCP -OBSERVED-575 BBLS CRUDE RETURNS, WILL SEND TO ORT -MONITOR WELL 30 MINUTES,WELL IS ON LOSSES -INITIAL STATIC LOSS RATE=24 BPH -TOTAL BRINE PUMPED=922 BBLS(NOT INCLUDING BULLHEAD) -TOTAL RETURNS=862 BBLS -TOTAL LOSS ON CIRCULATION=60 BBLS 9.2 PPG BRINE -OA=300 PSI -24 HOUR FLUID LOSS=60 BBLS,9.2 PPG BRINE 11/21/2014 00:00 - 00:30 0.50 KILLW P DECOMP BLOW DOWN AND R/D ALL CIRCULATING LINES R/U SECONDARY FILL LINE TO IA -STATIC LOSS RATE=28 BPH,9.2 PPG BRINE -MAINTAIN CONSTANT HOLE FILL AT 20 BPH, 9.2 PPG BRINE Printed 12/8/2014 10:46:14AM North America-ALASKA-BP Page 3 of 7 Operation Summary Report Common Well Name:MPF-54 AFE No Event Type:WORKOVER(WO) Start Date:11/19/2014 End Date:11/24/2014 X4-010W0-E:(1,765,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:12/24/1996 12:00:00AM Rig Release:11/24/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292272600 Active datum:ORIG KELLY BUSHING @31.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 00:30 - 02:00 1.50 WHSUR P DECOMP PJSM,R/U WELL SUPPORT LUBRICATOR -TEST LUB,250/3500 PSI,5 MIN,CHART -SET TWC,R/D LUB 02:00 - 03:00 1.00 WHSUR P DECOMP PERFORM ROLLING TEST BELOW TWC,5 MIN, 5 BPM=425 PSI,29 BBLS PUMPED AWAY -TEST TWC FROM ABOVE,250/3500 PSI,5 MIN,CHART 03:00 - 05:00 2.00 WHSUR P DECOMP j PJSM,DRAIN TREE,FMC REP BLEED HANGER VOID -N/D TREE AND SECURE IN CELLAR -CHECK HANGER THREADS,3"LH ACME 05:00 - 07:30 2.50 BOPSUR P DECOMP N/U 7 1/6"X 13 5/8"ADAPTER TO BOP N/U BOPE AND RELATED EQUIPMENT 07:30 - 09:00 1.50 BOPSUB P DECOMP PJSM.RIG UP TEST EQUIPMENT. -FUNCTION TEST PREVENTORS,FILL LINES AND BODY TEST. 09:00 - 14:00 5.00 BOPSUR P DECOMP PJSM.CONDUCT FULL TEST ON BOPE AND ✓ ASSOCIATED EQUIPMENT. p -REVIEW PRESSURE CROSS CHECK LIST. 1 TEST PUMP PRV SET @ 5500 PSI. (j PRESSURE TEST @ 250/3500 PSI,5 MIN EACH/CHARTED. -UTILIZE 2 7/8"AND 4"TEST JTS. -TEST ALL CHOKE VALVES AND SURFACE SAFETY VALVES. -PERFORM DRAWDOWN TEST ON ACCUMULATOR. -AOGCC STATE REP MATT HERRERA WITNESSED ALL TESTS. -(1)CHOKE VALVE FAILED AND REQUIRED GREASING AND PASSED,(FAIL/PASS). -ON ALL OTHER TESTS THERE WERE NO FAILURES. 14:00 - 14:30 0.50 BOPSUR P DECOMP PJSM.RIG DOWN ALL TEST EQUIPMENT. -DRAIN STACK AND BLOW DOWN LINES. 14:30 - 16:30 2.00 WHSUR P DECOMP PJSM.PICK UP OFF SET LUBRICATOR AND MAKE UP IN HANGER. -PRESSURE TEST LUBRICATOR @ 250/3500 PSI,5 MIN EACH/CHARTED,OK. -PULL TWO WAY CHECK VALVE AND LAY DOWN LUBRICATOR. 16:30 - 17:00 0.50 PULL P DECOMP M/U LANDING JOINT TO HANGER -WSL ENSURE NO PRESSURE UNDER HANGER -FMC REP BACK OUT LDS 17:00 - 17:30 0.50 PULL P DECOMP PULL HANGER OFF SEAT,ENSURE TUBING IS FREE=6'OF STRETCH -LOWER STRING TO WITHIN 3'OF LANDING -PUWT=120K,SOWT=85K -CLOSE ANNULAR,LINE UP ON CHOKE/GAS BUSTER 17:30 - 18:30 1.00 PULL P DECOMP PUMP ONE TUBING VOLUME,110 BBLS, DOWN TUBING TAKING RETURNS THRU GAS BUSTER -ESTABLISH SCR'S,THEN 5 BPM=2430 PSI -MONITOR WELL,WELL IS ON LOSSES,25 BBLS LOSS ON CIRCULATION 18:30 - 19:00 0.50 PULL P DECOMP L/D HANGER AND LANDING JOINT -BLOW DOWN LINES AND CHOKE Printed 12/8/2014 10:46:14AM North America-ALASKA-BP Page 4 of 7 Operation Summary Report Common Well Name:MPF-54 AFE No Event Type:WORKOVER(WO) Start Date:11/19/2014 End Date:11/24/2014 X4-010WO-E:(1,765,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:12/24/1996 12:00:00AM Rig Release:11/24/2014 Rig Contractor DOYON DRILLING INC. UWI:500292272600 Active datum:ORIG KELLY BUSHING @31.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 20:30 1.50 PULL P DECOMP P.U_LL2 7.&'6.5#EUE 8RD TUBING ESP_ __C.OMPLETION -F/17956'T/17709'MD -PULL ESP CABLE OVER SHEAVE AND ATTACH TO SPOOLING UNIT REEL 20:30 - 22:00 1.50 PULL P DECOMP CONTINUE PULL 2 7/8"6.5#EUE 8RD TUBING ESP COMPLETION -F/17709'T/15835 MD -MAINTAIN CONSTANT HOLE FILL=20 BPH LOSS 22:00 - 23:00 1.00 PULL P DECOMP 1 C/O SPOOLING UNIT REEL,22 STANDS OUT AT SPLICE 23:00 - 00:00 1.00 PULL P DECOMP 1CONTINUE PULL 2 7/8"6.5#EUE 8RD TUBING ESP COMPLETION -Fl 15835 T/14827'MD -C/O JOINT#96 -OA=40 PSI -LOSS RATE=20 BPH 1-24 HOUR FLUID LOSS=446 BBLS,9.2 PPG BRINE 11/22/2014 00:00 - 00:30 0.50 PULL P DECOMP 1PJSM,PERFORM SPCC AND EQUIPMENT •CHECKS 00:30 - 06:00 5.50 PULL P DECOMP CONTINUE PULL 2 7/8"6.5#EUE 8RD TUBING ESP COMPLETION -F/14827'T/6620'MD -MAINTAIN CONSTANT HOLE FILL=24 BPH LOSS RATE 06:00 - 11:00 5.00 PULL P DECOMP PJSM.CONTINUE TO POOH W/2 7/8"ESP COMPLETION. -SPOOLING UP ESP CABLE AND CONTINUOUS HOLE FILL. 11:00 - 11:30 0.50 PULL P DECOMP WELL CONTROL DRILL. -SIMULATE WELL KICK.SHUT IN WELL. -SHUT IN ACCORDING TO NEW BRIDGING DOCUMENT EFFECTIVE SEPT 2,2014. -SIMULATE SHUTTING IN AROUND ESP CABLE AND 2 7/8"TUBING WITH ANNULAR PREVENTOR. -WELL SHUT IN TIME,80 SECONDS.ALL HANDS ON STATIONS AND GOOD REPORTING REGARDING PIT VOLUME AND ACCUMULATOR PRESSURES. -WELL SHUT IN @ 11:07,REPORTED TO SUPERINTENDANT.2 BBL GAIN,SICP=75 PSI. -JAMES WILLINGHAM NOTIFIED BY SUPERINTENDANT @ 11:10 AM,BO YORK W/ HILCORP NOTIFIED @ 11:15 AM. -HSE MIKE POWELL NOTIFIED @ 11:20 AM. SITE CONTROL NOTIFIED DRILL SITE OPERATOR @ 11:15 AM. -GOOD RESPONSE BY CREW,GOOD AAR. ALL CREW MEMBERS AWARE OF NEW SHUT IN PROCEDURE. Printed 12/8/2014 10:46:14AM North America ALASKA-BP Page 5 of 7 Operation Summary Report Common Well Name:MPF-54 AFE No Event Type:WORKOVER(WO) Start Date:11/19/2014 End Date:11/24/2014 X4-010W0-E:(1,765,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:12/24/1996 12:00:00AM Rig Release:11/24/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292272600 Active datum:ORIG KELLY BUSHING @31.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 12:00 0.50 PULL P DECOMP CONTINUE TO POOH W/2 7/8"ESP COMPLETION AND ESP CABLE. -LOSS RATE STILL AT 23-24 BPH. - 290 BBLS OF 9.2 PPG BRINE LOST TO FORMATION LAST(12)HOURS. • 12:00 - 15:00 3.00 PULL P DECOMP PJSM.LAY DOWN PUMP AND MOTOR ASSEMBLY. '-RECOVERED(571)COLLAR CLAMPS AND(6) PROTECTORLIZERS,(4)FLAT GUARDS. 191 STANDS AND(1)SINGLE OF 2 7/8"EUE 8 RND TUBING. • 15:00 - 16:30 1.50 PULL P DECOMP PJSM,R/D ESP CABLE TRUNK AND EQUIPMENT -CLEAN/CLEAR RIG FLOOR • -BOX AND REMOVE OLD ESP PUMP AND MOTOR FROM PIPE SHED PREP NEW ESP MOTOR IN PIPE SHED REMOVE OLD ESP REELS FROM PIPE SHED, INSTALL NEW REELS 16:30 - 19:30 3.00 RUNCOM P RUNCMP PJSM,M/U AND SERVICE NEW ESP PUMP AMD MOTOR MOBILIZE EQUIPMENT AND PREP TO RUN COMPLETION 19:30 - 21:00 1.50 RUNCOM P RUNCMP PJSM,PULL ESP CABLE FROM SPOOLING UNIT,OVER SHEAVE TO RIG FLOOR -ATTACH ESP CABLE TO MOTOR,INSTALL CLAMPS AND PROTECTOLIZERS AND FLAT GUARDS• 21:00 - 00:00 3.00 RUNCOM P RUNCMP RIIN 2 7/8"6.5#EI IF 813D TUBING ESP_ .-.GQMPLETION AND AVA SLEEVE -F/59"T/1946'MD -INSTALL 1 CANNON CLAMP EVERY COLLAR -TEST ESP CABLE AND CAP TUBE EVERY 2000' -PUMP THRU TUBING EVERY 2000',1 BPM= 1560 PSI AT 1946'MD -OA=0PSI -LOSS RATE=19 BPH -24 HOUR FLUID LOSS=491 BBLS,9.2 PPG BRINE 11/23/2014 00:00 - 00:30 0.50 RUNCOM P RUNCMP PJSM,PERFORM SPCC AND EQUIPMENT CHECKS 00:30 - 05:30 5.00 RUNCOM P RUNCMP CONTINUE,RUN 2 7/8"6.5#EUE 8RD TUBING ESP COMPLETION -F/1946'T/7956'MD -INSTALL 1 CANNON CLAMP EVERY COLLAR -TEST ESP CABLE AND CAP TUBE EVERY 2000' -PUMP THRU TUBING EVERY 2000' 05:30 - 11:00 5.50 RUNCOM P RUNCMP PJSM.PERFORM REEL TO REEL SPLICE @ 7967'. -TEST CONDUCTIVITY,OK. Printed 12/8/2014 10:46:14AM North America-ALASKA-BP Page 6 of 7 Operation Summary Report Common Well Name:MPF-54 AFE No Event Type:WORKOVER(WO) Start Date:11/19/2014 End Date:11/24/2014 X4-010W0-E:(1,765,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:12/24/1996 12:00:00AM Rig Release:11/24/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292272600 Active datum:ORIG KELLY BUSHING @31.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:00 - 12:00 1.00 RUNCOM P RUNCMP PJSM.CONTINUE TO RIH W/ 2 7/8"EUE 8 RND ESP COMPLETION. -SPLICE LANDED ON A COLLAR.L/D THAT JT, PICK UP 4.78'PUP AND INSTALL BETWEEN JT I#258ă. -CONTINUE IN HOLE.LOSS RATE=15 BPH. -O/A=0 PSI,164 BBLS OF 9.2 PPG BRINE LOST TO WELL BORE LAST(12)HRS. -SPR=MP#1 11 SPM @ 2100 PSI @ 7967'. 12:00 - 12:30 0.50 RUNCOM P RUNCMP INSPECT RIG EQUIPMENT. -SERVICE RIG AND FLOOR EQUIPMENT/ 'PIPE SKATE. CHECK CROWN 0 MATIC,OK. 12:30 - 21:00 8.50 RUNCOM P RUNCMP PJSM.CONTINUE TO RIH W/2 7/8"EUE 8 RND TUBING AND ESP ASSEMBLY. -PUMP @ 1 BPM THRU TUBING,ESTABLISH CIRCULATION EVERY 2000'AND CHECK CONDUCTIVITY. -PUMPING @ 10 SPM @ 1870 PSI.INSTALL COLLAR CLAMPS ON EVERY COLLAR. 21:00 - 00:00 3.00 RUNCOM P RUNCMP PJSM.PERFORM REEL TO REEL SPLICE @ 15923' -TEST CONDUCTIVITY OA=0 PSI -LOSS RATE=14 BPH 24 HOUR FLUID LOSS=315 BBLS,9.2 PPG BRINE 11/24/2014 00:00 - 02:30 2.50 RUNCOM P RUNCMP PJSM.PERFORM REEL TO REEL SPLICE @ 15923' -TEST CONDUCTIVITY 02:30 - 05:00 2.50 RUNCOM P RUNCMP CONTINUE,RUN 2 7/8"6.5#EUE 8RD TUBING ESP COMPLETION -F/15923'T/17939'MD -M/U HANGER AND LANDING JOINT 05:00 - 07:00 2.00 ' RUNCOM P RUNCMP CENTRILIFT REP M/U FINAL ESP TERMINATION AT HANGER -DRAIN STACK 07:00 - 08:00 1.00 RUNCOM P RUNCMP LAND HANGER IN WELL HEAD,RUN IN LDS -PUWT=125K,SOWT=70K -FMC REP INSTALL TWC 08:00 - 09:00 1.00 WHSUR P RUNCMP PERFORM ROLLING TEST BELOW TWC,500 PSI,5 MIN -TEST TWC FROM ABOVE,250/3500 PSI,5 MIN,CHART 09:00 - 10:30 1.50 BOPSUR P RUNCMP BLOW DOWN CHOKE AND KILL LINES,DRAIN STACK -FLUSH TOP DRIVE,MUD PUMP AND SURFACE LINES WITH FRESH WATER AND BLOW DOWN 10:30 - 12:00 1.50 BOPSUR P RUNCMP PJSM,N/D BOP,REMOVE KOOMEY LINES 12:00 - 15:00 3.00 WHSUR P RUNCMP PJSM,N/U ADAPTERFLANGE_AND 2.9/1.6:'..__. FMC TREE -FMC REP TEST HANGER VOID,250/5000 PSI,30 MIN -TEST TREE,250/5000 PSI,5 MIN,CHART Printed 12/8/2014 10:46:14AM North America ALASKA-BP Page 7 of 7 Operation Summary Report Common Well Name:MPF-54 AFE No Event Type:WORKOVER(WO) Start Date:11/19/2014 • End Date:11/24/2014 X4-010WO-E:(1,765,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:12/24/1996 12:00:OOAM Rig Release:11/24/2014 Rig Contractor:DOYON DRILLING INC. UW:500292272600 Active datum:ORIG KELLY BUSHING©31.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 18:00 3.00 WHSUR P RUNCMP R/U WELL SUPPORT LUBRICATOR TO TREE, TEST 250/3500 PSI,5 MIN,CHART -PULL TWC,C/O RUNNING TOOLS,RE-TEST LUB SET BPV,R/D WELL SUPPORT 18:00 - 20:00 2.00 WHSUR P RUNCMP PJSM,R/U LRS HOT OIL.TEST LINES,250/ 3500 PSI,X-CHECK PRV SET AT 1600 PSI WHILE PUMPING -PUMP FREEZE PROTECT DEAD CRUDE,15 BBLS DOWN TUBING.1 BPM=1370 PSI, PRTECT TO 2533'MD PUMP 70 BBLS DOWN IA,1.5 BPM=620 PSI, PROTECT TO 2317'MD 20:00 - 21:00 1.00 WHSUR P RUNCMP R/D HOT OIL LINES AND EQUIPMENT R/D ALL LINES IN CELLAR,SECURE TREE, PREP FOR RIG MOVE -OA=0PSI -24 HOUR FLUID LOSS=170 BBLS,9.2 PPG BRINE -RELEASE RIG FROM MPF-54 AT 21:00 HOURS,11/24/14 Printed 12/8/2014 10:46:14AM Milne Point Unit Well: MPU F-54 SCHEMATIC Last Completed: 11/24/2014 Iiih•orp %Ia'k:,.l.ii PTD: 196-192 CASING DETAIL KB Elev.:41.2'/GL Elev.:12.1' Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surf 112' 27 9-5/8" Surface 40/L-80/Btrc. 8.679 Surf 9,904' 7" Production 26/L-80/Btc Mod 6.151 Surface 18,402' ( I 1 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8RD I 2.347 Surf I 17,958 JEWELRY DETAIL No Depth Item 1 141' 2-7/8"x 1"KBMM GLM w/DSOV 2 17,889' AVA Sleeve(ID=1.875) 9-5/8" e 3 17,903.56' Discharge Head 4 17,904' 137-P17 SXD Pump 5 17,923' Gas Separator Coated GSTHVEVXH6 6 17,928' Upper Tandem Seal Section GSB3DBUT SB/SB PFSA 7 17,935' Lower Tandem Seal Section GSB3DBUT SB/SB PFSA CL5 8 17,942' Motor CL-5,MSP1-250 F,210HP,2380 Volt,53 amp 9 17,959' Phoenix Pumpmate 10 17,961' Centralizer(OD=5.850) PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup. Sands 18,064' 18,072' 7,233' 7,239' 8 3/5/2005 Open Kup. Sands 18,078' 18,090' 7,245' 7,255' 12 3/5/2005 Open Kup. Sands 18,097' 18,117' 7,260' 7,277' 20 4/1/1997 Open Kup. Sands 18,117' 18,127' 7,277' 7,268' 10 2/1/1997 Open WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle=74 to 78 deg.f/3,780'to 16,000' Hole Angle through perforations=32 deg. OPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sks of Arcticset I in 24"Hole 9-5/8" Cmt w/2,052sks PF"E",860 sx Class"G"in 12-1/4"Hole 7" Cmt w/300 sks Class"G"in 8-1/2"Hole TREE&WELLHEAD Tree 5M FMC 2-9/16" Wellhead 11"x 7-1/16"5M FMC Gen SA,w/2-7/8"FMC Tbg.Hngr.,3"LH IM 2 ACME on top and 2-7/8"EU 8rd on bottom,2.5"CIW BPV Profile J 3 GENERAL WELL INFO API:50-029-22726-00-00 4 Drilled and Cased by Nabors 22E -1/19/1997 5 Completed with ESP by Nabors 4ES-4/8/1997 ESP RWO w scalecaps by Nabors 4-ES-10/22/1998 { s ESP RWO w/Nabors 4ES-1/15/2000 L J ESP RWO and Perf Add w/Nabors 4E5-3/6/2005 ESP RWO w/Nabors 35-7/21/20008 8 ESP RWO w/Doyon 16-12/6/20012 ESP RWO w/Doyon 16-11/24/20014 ti 9 NOTE: 10 Need Cementing Report to Establish Tops KUP Sands TD=18,430'(MD)/TD=7,554'(TVD) PBTD=18,319'(MD)/PBTD=7,460'(TVD) Created By:TDF 12/19/2014 I 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 Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type 'OVERSIZED [] .Logs of vadous kinds Other COMMENT~: '. Scanned bY: sever~j M~r~.D~r~ TO RE-SCAN Notes: STATE OF ALASKA RECEIVED •SKA OIL AND GAS CONSERVATION C MISSION r REPORT OF SUNDRY WELL OPERATIONS DEC 2 7 2012 1. Operations Performed: GCC ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Change out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic - 196 - 192 3. Address: ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50. 029 - 22726 - 00 - 00 7. Property Designation (Lease Number): „ 8. Well Name and Number: — ADL 355021 MPF - 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Kupar River Sands 11. Present well condition summary: Total depth: measured 18430' feet Plugs:(measured) None feet true vertical 7543' feet Junk: (measured) None feet Effective depth: measured 18319' feet Packer: (measured) None feet true vertical 7448' feet Packer: (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1490 470 Surface 9872' 9 -5/8" 9904' 4489' 5750 3090 Intermediate Production 18372' 7" 18402' 7519' 7240 5410 Liner SCANNED JAN 16 2013 Perforation Depth: Measured Depth: 18064' - 18127' feet True Vertical Depth: 7233' - 7286' feet Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.5# L -80 17958' 7143' Packers and SSSV (type, measured and true vertical depth): None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 442 104 816 270 214 Subsequent to operation: 428 102 703 100 229 14. Attachments: ❑Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service ® Daily Report of Well Operations 16. Well Status after work: " ® Oil ❑ Gas ❑ WDSPL Well Schematic Diagram ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact: David Bjork, 564 -5683 Email: David.Bjork @bp.com N/A Printed me: Joe Last jai Title: Drilling Technologist Signature r t P one: 564 -4091 Date: f242.1 //2.. .,k m , mit Original Only Form 10-404 v' ed 10/2012 � c, �: ; g. /— Sub g y • • Common Well Name: MPF -54 AFE No Event Type: WORKOVER (WO) Start Date: 11/30/2012 End Date: X4- 00WVR- E:DRILL (1,800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/24/1996 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °30'28.886 "6 Long: 0149°39'25.843'W Active Datum: ORIG KELLY BUSHING @31.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/30/2012 00:00 - 02:00 2.00 MOB P PRE PJSM, RIG MOVE - JACK RIG UP, REMOVE SHIMS - PULL OFF OF MPF -87A - STAGE RIG AT END OF PAD 02:00 - 04:30 2.50 MOB P PRE POSITION MATS AROUND AND UNDER RIG - STAGE WELL EQUIPMENT AROUND WELL CHANGE OUT SPACER SPOOL ON BOP TO ACCOMMODATE MPF -54 WELL HEAD 04:30 - 05:30 1.00 MOB P - PRE PJSM, ON MOVING RIG OVER WELL - •VF RIC; OVFR WFI I . MPE-54 05:30 - 08:30 3.00 MOB P PRE SHIM RIG, LOWER STAIRS, CLEAR WALKWAYS AND EGRESS ROUTES - SPOT CUTTINGS TANK AND CREW TRAILER - SPOT FUEL TRAILER AND M/U LINES TO RIG - HARDLINE CREW - SPOT FLOW BACK TANK AND M/U HARDLINE TO CELLAR - R/U WELL KILL CHOKE MANIFOLD AND CELLAR CIRCULATING LINES - RIG ACCEPTED AT 08:00 HRS 08:30 - 09:00 0.50 KILLW P DECOMP HOLD RIG EVACUATION DRILL - ALL PERSONAL ON THE PAD RESPONDED IN A TIMELY FASHION, INCLUDING TRUCK DRIVERS - AAR HELD POST DRILL, H2S EMERGENCY ROLES AND INDIVIDUAL RESPONSIBILITY DISCUSSED 09:00 - 10:30 1.50 KILLW P DECOMP PJSM, ON WELL KILL - FILL PITS WITH 11.0 PPG BRINE - FILL AND TEST WELL KILL MANIFOLD AND RELATED LINES - 250 / 3500 PSI, 5 MIN, CHARTED, BLOW DOWN LINES 10:30 - 12:00 1.50 WHSUR P DECOMP PJSM WITH WELL SUPPORT - R/U DSM LUBRICATOR, M/U BPV RETRIEVING TOOLS - TEST LUBRICATOR TO 250 / 3500 PSI, 5 MIN, CHARTED 12:00 13:00 1.00 WHSUR P ■- DECOMP PULL BPV - R/D DSM LUBRICATOR AND TOOLS - CLEAR RIG FLOOR Printed 12/17/2012 2:16:29PM ��. YISSSSSSS.SsaSS. ;SSAY syStr% SSSSS; ''`SASS.V.S Sy ,044,4 v e Common Well Name: MPF -54 AFE No Event Type: WORKOVER (WO) Start Date: 11/30/2012 End Date: X4- OOWVR- E:DRILL (1,800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/24/1996 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °30'28.886 "6 Long: 0149°39'25.843'W Active Datum: ORIG KELLY BUSHING @31.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 15:30 2.50 KILLW P DECOMP PJSM, REVIEW WELL KILL PROCEDURE WITH ALL INVOLVED - INITIAL PRESSURES, TUBING = 650 PSI, IA = 700 PSI - BLEED OFF GAS FROM 650 PSI TO 200 PSI - SAW FLUID RETURNS IN 60 SECONDS PUMP 105 BBLS OF 9.2 PPG BRINE DOWN TUBING AT 4 BPM = 1800 PSI - HOLDING CASING PRESSURE CONSTANT, 50 - 100 PSI OVER SICP. - TAKE RETURNS FROM IA, THRU KILL MANIFOLD AND MANUAL CHOKE TO FLOW BACK TANK - CLOSE IA AND BULLHEAD 30 BBLS DOWN TUBING TO FORMATION, 3.5 BPM = 1800 PSI - OPEN IA AND PUMP 200 BBLS DOWN TUBING, TAKING RETURNS TO FLOW BACK TANK, 3 BPM = -1000 PSI - PUMPS OFF, SHUT IN WELL, OFF LOAD FLUID FROM FLOW BACK TANK 15:30 - 17:00 1.50 KILLW P DECOMP OFF LOAD 279 BBLS FROM FLOW BACK TANK - PUMPED 300 BBLS TO TANK, RETUNED 279 BBLS = 21 BBLS LOSS TO WELL BROUGHT ON PUMP HOLDING 50 -100 PSI OVER SICP ON CHOKE. - ESTABLISHED FINAL CIRCULATING PRESSURE, 900 - 950 PSI @ 3 BPM. 17:00 - 19:00 2.00 KILLW P DECOMP PUMP 300 BBLS 9.2 PPG BRINE DOWN TUBING TAKING RETURNS TO TANK - 3 BPM = 925 PSI - PUMPS OFF, SHUT IN WELL, OFF LOAD FLUID FROM FLOW BACK TANK 19:00 - 20:30 1.50 KILLW P DECOMP OFF LOAD 250 BBLS FROM FLOW BACK TANK - PUMPED 300 BBLS TO TANK, RETUNED 250 BBLS = 50 BBLS LOSS TO WELL 20:30 22:00 1.50 KILLW P DECOMP PUMP 300 BBLS 9.2 PPG BRINE DOWN TI, IBING TAKING RETURNS TO TANK - 3 BPM = 925 PSI - PUMPS OFF, SHUT IN WELL, OFF LOAD FLUID FROM FLOW BACK TANK 22:00 - 22:30 0.50 KILLW P DECOMP MONITOR WELL FOR 30 MINUTES - BOTH TUBING AND IA ARE ON A VAC. LOSSING FLUID - OFF LOAD 279 BBLS FROM FLOW BACK TANK - PUMPED 300 BBLS TO TANK, RETUNED 279 BBLS = 21 BBLS LOSS TO WELL - TOTAL FLUID LOSS DURING CIRCULATION = 92 BBLS 22:30 - 23:30 1.00 KILLW P DECOMP BLOW DOWN AND RIG DOWN CIRCULATING LINES - R/U SECONDARY KILL LINE TO IA FOR CONSTANT HOLE FILL AND MONITORING DURING OPS 23:30 - 00:00 0.50 WHSUR P DECOMP R/U DSM LUBRICATOR - MOBILIZE WELL SUPPORT TOOLS TO RIG FLOOR - OA = 270 PSI - 24 HOUR FLUID LOSS = 164 BBLS Printed 12/17/2012 2:16:29PM d 2- 6 i rk Common W ell N MPF -54 A F E No Event Type: WORKOVER (WO) Stt D: 11/30/2012 End X4 WVR E (1,800,000.00 ) Project: Milne Point Site: ar M apt: F Pad Date: Rig Name /No.: DOYON 16 Spud Date/Time: 12/24/1996 12:00:OOAM Rig -OO Release: Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °30'28.8"6 Long: 0149 °39'25.843"W @ ( Date From - To Hrs 31.10ft Task above Mean Code Sea Level) NPT NPT Depth Phase Description of 86 Operations (hr) (ft) 12/1/2012 00:00 - 01:30 1.50 WHSUR P DECOMP M, Active Datum: ORIG KELLY BUSHING SAFETY AND SPCC CHECKS - PJS TEST LUBRICATOR, 250 / 3500 PSI, 5 MIN, CHARTED SET TWC - SF LUBRICATOR AND TOOLS 01:30 - 03:30 2.00 WHSUR P DECOMP PJSM, TEST TWC PERFORM ROLLING TEST ON TWC FROM BELOW, 500 PSI, 10 MIN, CHARTED - 31 BBLS PUMPED @2-3 BPM B P TEST TWC FROM ABOVE, 250 / 3500 PSI, 5 MIN, - BLOW DOWN, R/D LINES 03:30 - 05:00 1.50 WHSUR P DECOMP JSM, NIPPLE DbWN TREE ED AND ADAPTER LANGE - FMC CHARTED REP INSPECTED WELL HEAD AND A HANGER i PPH MADE DUMMY'RUN WITH 3" LH ACME HREADED SSOVER S =83/4 ORKING TURNS 05:00 - 06:00 1.00 BOPSUR P DECOMP HEIGH PREVENTOR BO CLEAN UP THRAS O WE H BO 7" X 11" SPAC S POOL 06:00 08:00 2.00 BOPSUR P DECOMP PJSM, N/U BOP, DISCUS WT TS AND HANDLING OF TOOLS N/U 13 3/8" 4 EOP STACK TOP TO BOTTO = ANNULAR , 2 7/8" X 5" VARIABLE PIPE RAMS, BLIND -SHEAR RAMS, LTS MUD CROSS, 2 7/8" X 5" VARIABLE PIPE RAMS 08:00 - 10:00 2.00 BOPSUR P DECOMP FUNCTION ALL RAMS - R/U TEST EQUIPMENT - M/U FLOOR VALVES AND TEST JOINTS - FILL SM BOP STACK AND ALL LINES WITH FRESH WATER 10:00 - 19:00 9.00 BOPSUR P DECOMP PJ, BOPS AND RELATED EQUIPMENT �L) - TEST BOPS ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES TEST ANNULAR WITH 2 7/8" TEST JOINT TO 250 PSI LOW, 3500 PGH, 5 MINUTES EACH, CHARTED - TEST UPPER AND LOWER 2 7/8" X 5" VARIABLE RAMS WITH 2 7/8" AND 4" TEST N, 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST BLIND RAMS, FL HI OOR VALVES, CHOKE MANIFOLD TO 2 ) ! ( ;i 11: 1: 1:: 50 PSI, 3500 PSI, 5 MIN, CHARTED Ti_ ESRESH WATER - PERFORM WITH ACCUMULATOR SI DRAW DOWN EST T JEFF T JONES F OF AOGCC A E WITNESSED BOP TEST MAINTAIN CONTINUOLUUS LOSS HOLE FILL AND TO THE : A DUG , FLUID = 11 BPH 19:00 - 21:00 2.00 BOPSUR P DECOMP /D ALL RIN BOP TEST EQUIPMENT B REAK OUT AND TEST LID TEST JOINTS FLOOR VALVES MPLETE DERRICK AND CROWN PERFORM INSPECO CTION URF IN - BLOW DOWN ALL SACE LINES, DRA GAS BUSTER Printed 12/17/2012 2:16:29PM r2 �; ri o Common Well Name: MPF -54 AFE No Event Type: WORKOVER (WO) Start Date: 11/30/2012 End Date: X4- 00WVR- E:DRILL (1,800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/24/1996 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °30'28.886 "6 Long: 0149 °39'25.843 "W Active Datum: ORIG KELLY BUSHING @31.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 22:30 1.50 PULL P DECOMP PJSM, MOBILIZE SHEAVE AND HANDLING TOOLS TO RIG FLOOR - TROUBLESHOOT TOP DRIVE WITH "NOV" REP. 22:30 - 00:00 1.50 WHSUR P DECOMP PJSM, PULLING TWC - VAC FRESH WATER OUT OF BOP STACK R/U DSM LUBRICATOR, TEST 250 / 3500 PSI, 5 MIN, CHART - ATTEMPT TO PULL TWC = UNSUCCESSFUL - R/D - PULL OFF -SET LUBRICATOR - EVACUATE FLUID FROM BOP STACK - OA =80 PSI 24 HOUR FLUID LOSS= 179 BBLS 12/2/2012 00:00 - 02:00 2.00 WHSUR P DECOMP PJSM, PULLING TWC VAC OUT BOP STACK - OBSERVE DEBRIS ON TOP OF TWC - FLUSH AND VAC OFF TOP OF TWC - M/U OFF -SET LUBRICATOR TO HANGER - TEST LUBRICATOR 250 / 3500 PSI, 5 MIN, CHART PULL TWC UD OFF -SET LUBRICATOR - CLEAR RIG FLOOR OF WELL SUPPORT TOOLS 02:00 - 02:30 0.50 WHSUR P DECOMP M/U LANDING JOINT TO 3" LH ACME CROSSOVER - MOBILIZE CENRILIFT TOOLS TO RIG FLOOR 02:30 - 03:30 1.00 PULL P DECOMP PJSM ON PULLING HANGER TO RIG FLOOR - M/U LANDING JOINT TO HANGER - WSL ENSURED NO PRESSURE ON IA - FMC REP BACKED OUT LOCK DOWN SCREWS - ATTEMPT TO PULL HANGER TO RIG FLOOR - HANGER PULLED OFF SEAT, AND STRING • STRETCHED —9' TO MAX OVER PULL OF 150K - 40K BLOCK WT + 110K MAX OVERPULL = 150K - yyQBKED PIPE 5 TIMES = NO MOVEMENT - RE -LAND HANGER AND FMC REP RILDS - UD LANDING JOINT 03:30 - 07:30 4.00 PULL P DECOMP PJSM, R/U TO CIRCULATE DOWN TUBING, TAKING RETURNS FROM IA THRU GAS BUSTER TO PITS - CBU AND SPOT 40 BBL SAFE -LUBE PILL IN ANNULUS NEAR BOTTOM AT 17883' - 3.5 BPM = 1330 PSI 07:30 - 08:30 1.00 PULL P DECOMP MONITOR WELL, WELL ON LOSSES - SUCK OUT BOP, M/U LANDING JOINT, FMC REP BOLDS - ATTEMPT TO PULL HANGER TO RIG FLOOR - PULL 9.5 FEET, PULLING 150K MAX PULL, UNSUCCESSFUL - RE -LAND HANGER, FMC RILDS - L/D LANDING JOINT Printed 12/17/2012 2:16:29PM • � �� ,. ., , � � . t j a r e ,„44101, 4 Common Well Name: MPF -54 AFE No Event Type: WORKOVER (WO) Start Date: 11/30/2012 End Date: X4- 00WVR- E:DRILL (1,800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/24/1996 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °30'28.886 "6 Long: 0149°39'25.843'W Active Datum: ORIG KELLY BUSHING @31.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 12:30 4.00 PULL P DECOMP MONITOR WELL AND MIX SAFE -LUBE INTO ACTIVE SYSTEM - CIRCULATE 550 BBLS OF 9.2 PPG BRINE WITH 1% SAFE -LUBE - 3.5 BPM = 1300 PSI OA = 250 PSI 12:30 - 13:00 0.50 PULL P DECOMP PUMPS OFF, MONITOR WELL, WELL ON LOSSES M/U LANDING JOINT TO HANGER W/ FLOOR VALVE ON TOP OF LND JT. - FMC BACK OUT LOCK DOWN SCREWS. - 2 7/8" TUBING FLOOR VALVE ON RIG FLOOR. 13:00 - 15:30 2.50 PULL P DECOMP PJSM, PULL HANGER OFF SEAT - PULL UP TO 157K MAX - PULL HANGER TO RIG FLOOR - ATTEMPT TO SLACK OFF = TAKING WEIGHT, UNABLE TO GO DOWN - UD LANDING JOINT AND HANGER - LOS W DOWN AND R/D SURFACE LINES - M/U FLOOR VALVE FOR SAFETY JOINT AND PLACE IN PIPE SHED 15:30 - 00:00 8.50 PULL P DECOMP POOH, 2 7/8" EUE 6.5# 8 RD ESP COMPLETION AND STAND BACK IN DERRICK - LAY DOWN JOINTS 100 THRU 155 - CONTINUE POOH AND STAND BACK IN DERRICK -LOSS RATE =8BPH - 24 HOUR FLUID LOSS = 226 BBLS OA = 80 PSI 12/3/2012 00:00 - 01:00 1.00 PULL P ®_ DECOMP PJSM, SERVICE RIG AND TOP DRIVE - MAKE SAFETY AND SPCC CHECKS 01:00 - 10:00 9.00 PULL P DECOMP POOH. 2 7/8" EUE 6.5# 8 RD ESP COMPLETION AND STAND BACK IN DERRICK - FROM 9309' TO 101', CONTINUOUS HOLE FILL, LOSING 4 - 5 BPH. - MONITOR WELL F/ 10 MINUTES, WELL STABLE. - CONTINUE TO POOH TO SURFACE & TERMINATE ESP CABLE. 10:00 - 12:00 2.00 PULL P DECOMP PJSM. U D PUMP / MOTOR ASSEMBLY. MOTOR IS BURNT. - 73 BBLS 9.2 PPG BRINE LOST TO WELL BORE LAST (12) HRS. -O /A= 90 PSI @11:30 HRS. - RECOVERED 292 LASALLE CLAMPS - RECOVERED 3 FLAT GUARDS - RECOVERED 5 PROTECTRALIZERS. 12:00 - 13:00 1.00 PULL P ■ DECOMP PJSM. FINISH LAYING DOWN ESP PUMP/ MOTOR ASSEMBLY. - CLEAR / CLEAN RIG FLOOR. 13:00 14:00 1.00 PULL P ■- DECOMP P EVE. RIG DOWN ESP TRUNK & SHING. Printed 12/17/2012 2:16:29PM '.g .sw s•• Common Well Name: MPF -54 AFE No Event Type: WORKOVER (WO) Start Date: 11/30/2012 End Date: X4- 00WVR- E:DRILL (1,800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/24/1996 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °3028.886 "6 Long: 0149°39'25.843'W Active Datum: ORIG KELLY BUSHING ©31.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 19:00 5.00 CASING N RREP DECOMP NOV REP AND ELECTRICIAN TROUBLE SHOOT TOP DRIVE. - ABLE TO GET TOP DRIVE TO REPEAT MALFUNCTION TWICE. - INSPECT AND TROUBLE SHOOT. 19:00 - 00:00 5.00 CASING P DECOMP PJSM WITH HALLIBURTON REP M/U 7" CHAMP PACKER - RIH ON 2 7/8" TUBING FROM DERRICK, FROM SURFACE TO 7032' MD - PUWT = 62K, SOWT = 60K - OA =90 PSI - 24 HOUR FLUID LOSS = 104 BBLS 12/4/2012 00:00 - 02:30 2.50 CASING P DECOMP PJSM, PERFORM SAFETY AND SPCC CHECKS - CONT. RIH WITH 7" CHAMP PACKER ON 2 7/8" TUBING FROM DERRICK - FROM 7032' TO 9920' MD 02:30 - 03:00 0.50 CASING P DECOMP EST. SPR'S, 30 SPM = 370 PSI, 40 SPM = 630 PSI - PUMP 5 BPM = 1390 PSI, RECIPROCATE PIPE 5X SET 7" CHAMP PACKER AT 9920' - SET 20K DOWN WEIGHT ON PACKER - PURGE LINES, FILL STACK - CLOSE UPPER PIPE RAMS 03:00 - 04:00 1.00 CASING P DECOMP - MIT -IA, TEST 7" 26# CASING - TEST TO 3500 PSI, 30 MINUTES, CHARTED, / GOOD TEST ✓y - TEST SATISFIED WELLBORE INTEGRITY Oy TESTING CRITERIA CALCULATOR 'f _ ` _ ' 1 3 ' - NOTIFIED WTL WITH RESULTS AND RECIEVED AUTHORIZATION TO PROCEED - BLED PRESSURE OFF, UNSEAT PACKER - MONITOR WELL 10 MINUTES, WELL IS ON LOSSES - STATIC LOSS RATE = 4 BPH 04:00 - 05:30 1.50 CASING P DECOMP PJSM, SLIP AND CUT D /LINE - SET TOP DRIVE IN SLIPS, REMOVE GUARDS, POSITION HANDS - CUT AND SLIP 80 FEET - CHECK DEADMAN, TEST CROWN -O- MATIC, GREASE AND SERVICE DRAW WORKS 05:30 - 12:00 6.50 CASING P DECOMP PJSM. POOH W/ 2 7/8" TUBING AND CHAMP PACKER. - FROM 9920' TO SURFACE - UD CHAMP PACKER - CONTINUOUS HOLE FILL - WELL TAKING APPROXIMATELY 3 - 4 BPH OVER CALCULATED HOLE FILL - OA =60 PSI 12:00 - 13:00 1.00 CASING P DECOMP CLEAN AND CLEAR RIG FLOOR - SERVICE TOP DRIVE - P/U BUSHING PULLER AND PULL WEAR BUSHING Printed 12/17/2012 2:16:29PM Common Well Name: MPF -54 AFE No Event Type: WORKOVER (WO) Start Date: 11/30/2012 End Date: X4- 00WVR- E:DRILL (1,800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/24/1996 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °30'28.886 "6 Long: 0149°39'25.843'W Active Datum: ORIG KELLY BUSHING @31.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 14:30 1.50 RUNCOM P RUNCMP PJSM ON RIG UP AND RUN ESP COMPLETION - HANG AND SECURE ESP SHEAVE IN DERRICK - R/U ISPE RUN AND ESP NC ABLE CT FROM SPOOLING SPOOLING UNIT UNIT THROUGH SHEAVE TO RIG FLOO R 14:30 - 17:00 2.50 RUNCOM P RUNCMP_ M/U ESP ASSEMBLY PER CENTRILIFT REP - M/U AND SREVICE MOTOR AND PUMP 17:00 - 20:30 3.50 RUNCOM P RUNCMP SPLICE MOTOR LEAD ON ESP CABLE - MEG TEST AND M/U TO MOTOR ASSY - INSTALL PROTECOLIZERS AND FLAT GUARD CLAMPS 20:30 - 00:00 3.50 RUNCOM P RUNCMP RIH WITH 2 7/8" 6.5# EUE 8 RD TUBING ESP COMPLETION - RIH F/ SURFACE TO 1420' - TUBING TORQUE = 2300 FT /LBS - INSTALL CANNON CLAMPS ON EVERY COLLAR - CHECK CONTINUITY EVERY 2000' - PUMP 5 BBLS TO FLUSH THRU PUMP AT 1/2 1 BPM, EVERY 2000', NOT TO EXCEED 3000 PSI MAINTAIN CONTINUOUS HOLE FILL - LOSS RATE = 3 BPH -OA =50 PSI - 24 HOUR FLUID LOSS = 82 BBLS 12/5/2012 00:00 - 00:30 0.50 RUNCOM P RUNCMP PJSM, MAKE SAFETY AND SPCC CHECKS - SERVICE RIG AND SKATE 00:30 - 09:00 8.50 RUNCOM P RUNCMP RIH WITH 2 7/8" 6.5# EUE 8 RD TUBING -ES2-. COMPLETION - RIH FROM 1420' TO 7786' MD - TUBING TORQUE = 2300 FT /LBS - INSTALL CANNON CLAMPS ON EVERY COLLAR - CHECK CONTINUITY EVERY 2000' PUMP 5 BBLS TO FLUSH THRU PUMP AT 1/2 BPM, EVERY 2000', NOT TO EXCEED 3000 PSI - MAINTAIN CONTINUOUS HOLE FILL - 3 -4 BPH STATIC LOSS RATE. - LOST IN WELL: ONE 5" PIN FROM A 2 -7/8" CANNON CABLE CLAMP. 09:00 - 12:30 3.50 RUNCOM P RUNCMP CENTRILIFT REP PERFORM REEL TO REEL SPLICE ON ESP CABLE AT 7786' MD - CHECK CONDUCTIVITY OF CABLE AND RELOAD ESP REEL IN SPOOLING UNIT. - PUMP5BBLSKWFAT1 BPM /390 PSI TO FLUSH PUMP. INSPECT / SERVICE TOP DRIVE AND POWER TONGS. Printed 12/17/2012 2:16:29PM 04, � � /' < Y e A No Common Well Name: MPF -54 Event Type: WORKOVER (WO) Start Date: 11/30/2012 End Date: X4- OOWVR- E:DRILL (1,800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/24/1996 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °30'28.886 "6 Long: 0149 °39'25.843 "W Active Datum: ORIG KELLY BUSHING @31.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:30 - 21:30 9.00 RUNCOM P RUNCMP CONTINUE TO RUN ESP COMPLETION ON 2 -7/8" TBG FROM DERRICK. - F/ 7786' MD T/ 15465' MD - ENCOUNTERED TIGHT SPOT AT 14531' MD - WORKED PIPE 2X, PASSED THRU WITH 6K DRAG ON DOWN STROKE NOTIFIED TOWN ENGINEER OF TIGHT SPOT, CONTINUED RIH - TUBING TORQUE = 2300 FT /LBS - INSTALL CANNON CLAMPS ON EVERY COLLAR - CHECK CONTINUITY EVERY 2000' - PUMP 5 BBLS TO FLUSH THRU PUMP AT 1/2 BPM, EVERY 2000', NOT TO EXCEED 3000 PSI - MAINTAIN CONTINUOUS HOLE FILL 21:30 - 00:00 2.50 RUNCOM P RUNCMP CENTRILIFT REP PERFORM REEL TO REEL SPLICE ON ESP CABLE AT 15465' MD CHECK CONDUCTIVITY OF CABLE AND RELOAD ESP REEL IN SPOOLING UNIT. - PUMP 5 BBLS KWF AT 1 BPM / 1680 PSI TO FLUSH PUMP. -OA =70 PSI - 24 HOUR FLUID LOSS = 24 BBLS 12/6/2012 00:00 - 00:30 0.50 RUNCOM P RUNCMP PJSM, MAKE SAFETY AND SPCC CHECKS - CONT. ESP REEL TO REEL CABLE SPLICE - CHECK CONDUCTIVITY, GOOD 00:30 - 03:30 3.00 RUNCOM P - RUNCMP CONTINUE TO RUN ESP COMPLETION ON 2 -7/8" TBG FROM DERRICK. - F/ 15465' MD T/ 17934' MD - INSTALL CANNON CLAMPS ON EVERY COLLAR - CHECK CONTINUITY EVERY 2000' - PUMP 5 BBLS TO FLUSH THRU PUMP AT 1/2 BPM, EVERY 2000', NOT TO EXCEED 3000 PSI - MAINTAIN CONTINUOUS HOLE FILL 03:30 - 04:00 0.50 RUNCOM P RUNCMP MAKE UP LANDING JOINT, FOSV AND CROSSOVER - M/U LANDING JOINT TO HANGER - M/U HANGER TO TUBING STRING AND ORIENT PER FMC REP - PUWT = 113K, SOWT = 76K 04:00 - 05:30 1.50 RUNCOM P RUNCMP CENTRILIFT REP CUT ESP CABLE AND PERFORM TIE IN TO PENETRATOR - SPOOL REMAINDER OF ESP CABLE BACK TO SPOOLING UNIT. 05:30 - 06:00 0.50 RUNCOM P RUNCMP _ LAND TBG HANGER - FMC REP RILDS @ 17,957' MD - PU WT = 113 K, SO WT = 76K (INCLUDES TOP DRIVE WT =40K) - CANNON CLAMPS = 571 - PROTECTOLIZERS = 5 - FLAT GUARDS = 3 06:00 - 06:30 0.50 WHSUR P RUNCMP LAY DOWN LANDING JOINT AND FOSV. - FMC REP INSTALL TWC. Printed 12/17/2012 2:16:29PM �;�: p as 7• Common Well Name: MPF -54 AFE No Event Type: WORKOVER (WO) Start Date: 11/30/2012 End Date: X4 -OOWVR E:DRILL (1,800,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/24/1996 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °30'28.886 "6 Long: 0149 °3925.843 "W Active Datum: ORIG KELLY BUSHING @31.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 - 08:00 1.50 WHSUR P RUNCMP PERFORM ROLLING TEST BELOW TWC - 1.6 BPM / 500 PSI FOR 10 CHARTED MIN. PASSED. - 250 PSI / 3500 PSI PRESSURE TEST FROM ABOVE - BOTH TEST 5 MIN CHARTED. PASSED. DRAIN BOP STACK. 08:00 - 09:30 1.50 BOPSUR P RUNCMP .EISM.N/D-BOPE_. - REMOVE FLOW NIPPLE AND TURNBUCKLES. - LOTO KOOMY AND REMOVE HOSES. - REMOVE 13 -5/8" BY 7- 1/16" SPOOL. - SET BACK BOP STACK. 09:30 - 12:30 3.00 WHSUR P RUNCMP FMC REP INSPECT HANGER. - N/U 7- 1/16" 5M ADAPTOR AND 2- 9/16" 5M TREE. - PRESSURE TEST HANGER VOID TO 250 PSI F/5 CHARTED MIN. PASSED. - AND 5000 PSI F/ 30 CHARTED MIN. PASSED. 12:30 - 13:30 1.00 WHSUR P RUNCMP PJSM, TREE TEST. PRESSURE TEST 2- 9/16" 5M PRODUCTION TREE`. 250 PSI / 5000 PSI, CHARTED BOTH TEST F/ 5 MIN. PASSED. - TESTED W/ DIESEL. 13:30 - 17:00 3.50 WHSUR P RUNCMP PJSM, PULL TWC - M/U DSM LUBRICATOR. - PRESSURE TEST LUBRICATOR 250 / 3500 PSI F/ 5 CHARTED MIN. PASSED. - PULL TWC. - RETEST LUBRICATOR. - INSTALL BPV. - WTL AND RWO SUPERINTENDENT VISIT TO RIG. - 24 HRS NOTICE FOR BOP TEST ON MPF -61, E- MAILED TO AOGCC. - AOGCC REPLIED TO E -MAIL. STATES RIGHT OF WITNESS WAIVED BY CHUCK SCHEVE @15:19 HRS. 17:00 - 17:30 0.50 WHSUR P RUNCMP PERFORM ROLLING TEST FROM BELOW BPV - 1.5 BPM = 500 PSI,10 MIN, CHARTED - BLEED OFF PSI, 6.7 BBLS BACK TO PITS -OA =70 PSI 17:30 - 18:00 0.50 WHSUR P RUNCMP BLOW DOWN ALL CELLAR AND SURFACE LINES - R/D ALL CELLAR LINES - PREP CELLAR FOR RIG MOVE 18:00 - 20:00 2.00 WHSUR P RUNCMP SECURE TREE AND WELLHEAD - CLOSE ALL VALVES ON TREE AND INSTALL REQUIRED GAUGES - COMPLETE CLEANING PITS - REMOVE CUTTINGS TANK, FUEL TRAILER AND CHANGE TRAILER - 22 HOUR FLUID LOSS = 69 BBLS - PJSM FOR RIG MOVE - RELEASE RIG AT 20:00 HOURS Printed 12/17/2012 2:16:29PM Tree: 2- 9/16" 5M F F-54 Orl�F Elev. = 41.2 (N 22E) Wellhead 11" x 7" FMC Gen. 5A M P U �� Orig. GL Elev. = 12.10' Tubing Hanger:TC- B- EC -HT. 7- 1/16" / r DF To Csg. spool= 29.7 ' (N 22E) x 2 -7/8" w/ 8rd bot. 3" ACME LH 0 top. CIW -H BPVT. 0 20" 91.1 ppf, H -40 112' 0 0 Camco 2 7/8" x 1" 142' KOP 500' % sidepocket KBMM GLM Max. hole angle = 74 to 78 deg. f/ 0 3780' to 16,000' % 0 HES 9 5/8" ES" Cementer 1,299' Hole angle thru' perfs = 32 deg. 0 % . • 9 5/8 ", 40 ppf, L -80 Btrc. 9903' I • - k 0 L 7" 26 ppf, L-80, Btrc. prod. casing, 0 1 ' drift ID = 6.151", cap. = 0.0383 b f / t i ' AVA Ported sleeve ( 1.875 id) 17,840' 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg. ( drift ID = 2.347 ", cap. = 0.00592 bpf) $ f.4 Centrilift Pump 17,885' SXD 119 -P23 / SXD 41 -P23 II Centrilift Gas Separator 17,909' k GRSFTXAR H6 j ` 1 Centrilift Tandem Seal Section r e GSB3DBUT /LT SB /SB PFSA 17,914' Stimulation Summary ` Centrilift MSP -1 / 360 HP ' DS Frac 3 / 31 / 97 #16/20 carb. . 2650v / 77 amp Motor 17'928 164.# M Behind pipe. Mt Perforation Summary Pumpmate XTO 17,954' Ref log: GR/CCL Marked line 1/31/97 OT I 11 Centrilift 6 -Fin Centralizer 17,956' Size SPF Interval (TVD) Bottom 4.5" 6 18,117'- 18,127' (7243' - 7268') Marker joints 17,828' - 17,870' 3 -3/8" 6 18,097'- 18,117' (7260'- 7277') 3 -3/8" 6 18,064`- 18,072' (7233` - 7240') 3 -3/8" 6 18,078`- 18,090' (7245`- 7255') '- 7345' tvd 7" float collar (PBTD) 18,319' 7" float shoe 18,402' DATE REV BY COMMENTS MILNE POINT UIT 04/08/97 MDO ESP Completion 4ES 10/22/98 MDO ESP RWO w/ scalecaps 4ES WELL F -54 • 1/15/00 GMH ESP RWO 4ES 3/6/2005 JRC ESP RWO with Add Perfs API NO: 50 -029 -22726 7/21/08 REH ESP RWO by Nabors 3S 12/06/12 B. Bixby ESP RWO by Doyon 16 BP EXPLORATION (AK) • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 w ` December 30, 2011 Mr. Tom Maunder l c6 - fq, a- Alaska Oil and Gas Conservation Commission ' " Y C7 x -- 57-f 333 West 7 Avenue f �_ 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, . v Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) 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 1 ft bbls ft gal 1 MPF -01 1950450 50029225520000 10.2 N/A 102 N/A 122.4 8/7/2011 MPF-02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF -06 1960020 50029226390000 1.2 N/A 12 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 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 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 8/112011 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 3 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/12011 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 NN 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 08 N/A 8.5 , 7/312011 MPF-69 1951250 50029225860000 0.8 N/A 08 N/A 8.5 8/42011 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 02 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 -840 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 9/12011 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 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 _ 8/11/2011 -~~~ STATE OF ALASKA 99-08 } ALA~OIL AND GAS CONSERVATION COM~ON REPORT OF SUNDRY WELL OPERATIONS ~~, r:l;r ;~ ~~~~~ 1. Operations Performed: ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing , ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 196-192 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22726-00-00' 7. KB Elevation (ft): 41 60', 9• Well Name and Number: . MPF-54 8. Property Designation: 10. Field /Pool(s): , ADL 355021 ~ Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 18430 - feet true vertical 7543 ' feet Plugs (measured) N/A Effective depth: measured 18319 feet Junk (measured) 17870' - 17828' true vertical 7448 feet Casing Length Size MD TVD Burst Collapse Structural .,.. Conductor 78' 20" 112' 112' 1490 470 Surface 9872' 9-5/8" 9904' 4489' 5750 3090 Intermediate Production 18372' 7" 18402' 7519' 7240 5410 Liner Q~~.~~IN~t~ SEP 7 2008 Perforation Depth MD (ft): 18064' - 18127' - Perforation Depth TVD (ft): 7233' - 7286' - 2-7/8", 6.5# L-80 17953' 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 includ+ng 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: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®"Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 N/A Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number S ature Phone 564-4750 Date ~" L(-d .Sondra Stewman, 564-4750 Form 10-404 Revised 0412006 Submit Original Only w Tree: 2-9/16" 5M Wellhead 11" x 7" FMC Ge . 5A Tubing Hanger:TC-B-EC-HT. 7-1/16" x 2-7/8" w/ 8rd bot. 3" ACME LH top. CIW-H BPVT. 20" 91.1 ppf, H-40 112' KOP @ 500' Max. hole angle = 74 to 78 deg. f/ 3780' to 16,000' Hole angle thru' perfs = 32 deg. 9 5/8", 40 ppf, L-80 Btrc. 7" 26 ppf, L-80, Btrc.prod. casing, ( drift ID = 6.151", cap. = 0.0383 bpf ) M P U F -54 2 7/8" 6.5 ppf, L-80, 8rd EUE tbg. ( drift ID = 2.347", cap. = 0.00592 bpf ) Stimulation Summary DS Frac 3 / 31 / 97 #16/20 carb. 164.# M Behind pipe. Perforation Summary Ref log: GR/CCL Marked line 1/31/97 Size SP Interval TVD 4.5" 6 18,117'-18,127 (7243'-7268') 3-3/8" 6 18,097'-18,117 (7260'-7277') 3-3/8" 6 18,084`-18,072' (7233`-7240') 3-3/8" 6 18,078`-18,090' (7445`-7255') DATE IREV. BY I COMMENTS 1 /15/00 GMH ESP RWO 4ES 3/6/2005 JRC ESP RWO with Add Perfs 7/21/08 REH ESP RWO by Nabors 3S Orig.~lev. = 41.2 (N 22E) Orig. Elev. = 12.10' DF To Csg. spool= 29.7 ' (N 22E) Camco 2 7/8" x 1" 140' sidepocket KBMM GLM ~ HES 9 5/8" ES" Cementer 1,299' AVA Ported sleeve (1.875 id) 17,883' Centrilift Pump 17,898' 160 P11 - PMSSD 1:1 Centrilift Gas Separator 17,916' GRSFTXAR (400 internals) Centrilift Tandem Seal Section GSB3DBUT/LT AB/AB PFSA/CL6 17,921' Centrilift KMH 190 HP 17,933' 2415v / 48 amp Motor Pumpmate XTO 17,949' Centrilift 6-Fin Centralizer 17,951' Bottom Markerjoints 17,828' -17,870' 7345' tvd 7" float collar (PBTD) 18,319' 7" float shoe 18,402' MILNE POINT UIT WELL F-54 API NO: 50-029-22726 BP EXPLORATION (AK) MPF-54 Well History Date Summary 7/2/2008 T/I/0=450/580/0 (Freeze Protect for RWO) Pumped 15 bbls Diesel down tubing. Pumped 2 bbls 60/40 methanol, 3 bbls Diesel, and 2 bbls 60/40 down Production and Test flowlines. FWHP=500/580/0 Swab, Wing ,SSV, and Laterals Closed. Master, IA, and OA Open. 7/3/2008 RIH W/ 2.1"CENT, SOFT SET, SPARTEK GAUGES AT REPORT TIME. 7/4/2008 T/I/0=575/600/40 Assist S-line (RWO-Prep) -Pump as directed down tbg w/8 bbls 60/40 methanol, 30 bbls diesel/crude (50/50 mix) & 87 bbls produced water to assist s-line getting down hole. Verify valve positions: wing & choke closed. Casing, master, ssv & swab open s-line on well & in hole. Notify operator upon departure. Final WHP's=650/680/160 RIH W/ 2.1 CENT SOFT SET SPARTEK GAUGES MADE 3 HOUR ~ 10,600' PULLED 2.31" BPI FROM 17,903' SLM.PULLED 1" BEK-DPSOV FROM 130' MD, SET 1" BK-DGLV 7/14/2008 RAN SS, DUAL SPARTEK GAUGES W/GAUGE CARRIER, UNABLE TO GET DEEPER THAN 12150' SLM, (78 DEGREE DEVEATION). 3 HOUR STOP ~ 12150' SLM, 30 MIN STOP (~ 11650' SLM. 7/15/2008 MPU Well Support Techs. Set BPV, Demobe well house,and both, test and production lats and to header valves also the foundation. it is now ready for rig to look at, to shoot grade of the ground. 7/20/2008 SET DPSOV IN IN GLM #1 IN PIPE SHED 7/21/2008 (Freeze Protect TBG & IA) T/I/0= 0/0/0 Pump 15 bbls dead crude down TBG followed by 65 bbls dead crude down IA to freeze protect well. FWHP=O/0/0 swab closed/ wing closed/ ssv closed/ master closed/ IA and OA open to gauges. 7/25/2008 The Well Support Techs rigged up and set the foundation, installed the flowlines and set the wellhouse. They then removed the back pressure valve and leak tested the flowlines to 1150 psi. NOTE: The leak test was GOOD and the BPV was left OUT... BP EXPLORATION Page 1 of 2 Operations Summary Report Legal Well Name: MPF-54 Common Well Name: MPF-54 Spud Date: 12/24/1996 Event Name: WORKOVER Start: 7/16/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/21/2008 Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/17/2008 09:30 - 12:00 2.50 RIGD P PRE Rig released for MPF-18 ~ 9:30. Scope down and lower Derrick. Disconnect rig modules. Prep for move. 12:00 - 17:00 5.00 MOB P PRE Stand by for Crane Rescue. (AES crane off of road between L and F Pads). Crib in cellar on MPF-54. Call for Peak trucks ~ 15:00 17:00 - 20:00 3.00 MOB P PRE PJSM with Truck crew. Move off MPF-18 and spot Carrier over MPF-54 with BP/WSL, Nabors toolpusher and MPU Pad operator present. 20:00 - 22:00 2.00 MOB P PRE Spot Pits and Pipe shed, build Hand-I burms. 22:00 - 23:00 1.00 RIGU P PRE Scope up and raise Derrick. Rig accepted at 23:00 hours. 23:00 - 00:00 1.00 WHSUR P DECOMP Rig up hard line and valves to Tree for Well kill. 7/18/2008 00:00 - 01:00 1.00 WHSUR P DECOMP RU second annulas valve to Tree, pressure test hard lines to Tree to 3,500 psi., test hard line to Tiger tank to 500 psi. 01:00 - 02:00 1.00 WHSUR P DECOMP PU/MU and test lubricator to 500 psi, well support techs pulled TWC. Well head pressures,Tubing = 660 psi, IA = 680 psi, OA = 50 psi. 02:00 - 07:30 5.50 WHSUR P DECOMP PJSM Well kill. Notify Pad operator and MPU Radio of gas venting operation. Bleed gas to Tiger tank, tubing = 470 psi, IA = 0 psi, OA = 50 psi. Pumped 105 bbls of heated seawater down the tubing at 4 BPM (recovered 86 bbls). Close in returns and Bullhead 30 bbls into formation at 2 BPM. Pumps off, tubing = 0 psi, IA = 370 psi. Circulate 625 bbls the long way at 3-1/2 BPM taking returns to the Tiger tank. (lost 80 '~ Bbls 07:30 - 09:30 2.00 WHSUR P DECOMP Flow check well. Tbg on 10 psi, IA ~ 0 psi, but flowing from IA. Circulate 200 Bbls ~ 3 1/2 BPM, 1120 psi. Lost 27 Bbls. Flowcheck well. Tbg and IA on vaccum. Blow down hardlines. Check after 20 minutes, well still on vacuum. 09:30 - 11:30 2.00 WHSUR P DECOMP Dry rod TWC, test to 3500 psi from above. Chart for 10 minutes. ND Tree. Inspect hanger threads w/ 3-1/2" LH Acme XO - 9 turns. 11:30 - 16:00 4.50 BOPSU P DECOMP NU DSA. PU BOPE from cradle, MU to DSA. NU BOPE. Well takin 10 Bbls / Hr durin ND-NU rocedure. 16:00 - 20:00 4.00 BOPSU P DECOMP State's right to witness BOPE testing waived by Chuck Scheve ~ 06:00. Test BOPE 250 / 3500 psi with 2-7/8" test joint against TWCV. 20:00 - 20:30 0.50 BOPSU P DECOMP Blow down lines. 20:30 - 21:30 1.00 WHSUR P DECOMP PU/MU and test Opso Lopso lubricator to 500 psi with diesel, Well techs pulled TWC, tubing and IA on a vac. 21:30 - 22:00 0.50 WHSUR P DECOMP MU landing joint, screw into Hanger, FMC Wellhead tech BOLDS, pull free at 95 K. Flow check Well. Tbg and IA on a vac. 22:00 - 23:00 1.00 WHSUR P DECOMP Pumped 21 bbls to fill the IA. Circulate 110 bbls down the tubing at 3 BPM / 860 psi with returns going to pits. 23:00 - 23:30 0.50 WHSUR P DECOMP LD landing joint and tubing hanger. 23:30 - 00:00 0.50 PULL P DECOMP POH 1 stand 2-7/8" tubing, L/D GLM, pup and 1 joint 2-7/8" tubing, pull ESP cable over sheave in Derrick. Fill Well bore at 15 BPH with no returns. 7/19/2008 00:00 - 06:00 6.00 PULL P DECOMP Continue to POH with ESP Assembly and stand 2-7/8" tubing in Derrick, using 15 BPH continuous hole fill with out returns. 78 stands out at 05:30. Change out ESP cable spool. 06:00 - 10:00 4.00 PULL P DECOMP Crew change, service rig. Continue POH standing back tubing Printed: 8/14/2008 3:38:53 PM r~ ~~ BP EXPLORATION Operations Summary Report Page 2 of 2 Legal Well Name: MPF-54 Common Well Name: MPF-54 Spud Date: 12/24/1996 Event Name: WORKOVER Start: 7/16/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/21/2008 Rig Name: NABOBS 3S Rig Number: Date From - To ~ Hours Task Code NPT Phase Description of Operations 7/19/2008 06:00 - 10:00 4.00 PULL P DECOMP in Derick. 10:00 - 11:30 1.50 PULL P DECOMP 145 Stands OOH, change out power tongs. Change spools in spooling unit. Losses ~ 15 Bbls / Hr. 11:30 - 19:30 8.00 PULL P DECOMP Continue to POH w/ hole fill regulated to 15 Bls / Hr. 19:30 - 22:00 2.50 PULL P DECOMP L/D ESP pump and motor assembly. Found ESP flat cable to have -3" of armor worn away. Last ESP spool recovered from well failed conductivity test. Recovered 294 La Salle clamps, 4 Protectolizers, 3 flatguards, 571 jts, AVA sleeve. 22:00 - 22:30 0.50 PULL P DECOMP Clean and clear rig floor. 22:30 - 00:00 1.50 PULL P DECOMP Remove ESP cable and trunk from Derrick, remove ESP pump and motor components from pipe shed and load with new, change out spools in spooling unit. 7/20/2008 00:00 - 03:00 3.00 BUNCO RUNCMP PU/MU ESP pump and motor assenbly, pull ESP cable over sheave in Derrick and make up to motor, Centrilift tech perform couductivity check. Make up AVA sleeve and pup joint. 03:00 - 06:00 3.00 BUNCO RUNCMP Run ESP completion on 2-7/8" 8rd, EUE, 6.5#, L-80 Tubing from Derrick. Check conductivity of ESP cable every 2,000' and flush pump with 10 bbls of seawater. Best-O-Life 2000 pipe dope. Torque to 2,300 ft-Ib. Eeed wellbore continually , with seawater with loss rate of -5 BPH with return .Flushed pump at 3/4 BPM / 1150 psi. Ran 70 joints at 05:30 hrs. 06:00 - 10:30 4.50 BUNCO RUNCMP Continue RIH to 124 Stands in hole, losses ~ 8 Bls / Hr. 10:30 - 13:30 3.00 BUNCO RUNCMP Flush pump ~ 3/4 BPM, 1100 psi w/ 10 Bbls of SW. Make cable to cable splice w/ 124 Stands in the hole. 13:30 - 20:00 6.50 BUNCO RUNCMP Cable splice complete. Continue RIH w/ ESP completion on 2-7/8 tubing from Derrick. Hole fill ~ 10 Bbls / Hr. 175 Stds in hole ~ 15:55 hrs. and 244 stds in hole ~ 20:00 hrs. 20:00 - 00:00 4.00 BUNCO RUNCMP Flush pump ~ 1/2 BPM, 1250 psi w/ 10 Bbls of SW. Make cable to cable splice w/ 244 Stands in the hole. Fill hole ~ 10 BPH loss. 7/21/2008 00:00 - 02:30 2.50 BUNCO RUNCMP Continue to RIH with 2-7/8" tubing ESP completion assembly, from 244 stds to 285 stds and 1 jt, GLM and pup. Ran 292 LaSalle cable protectors, 4 Protectolizers, 3 Flatguards. Flush pump 1/2 BPM ~ 1150 psi with 10 bbls seawater. Tubing hanger threads = 3" LH Acme. Hole fill ~ 10 BPH loss. 02:30 - 03:00 0.50 BUNCO RUNCMP PU/MU landing joint and tubing hanger with FMC Wellhead tech. 03:00 - 05:00 2.00 BUNCO RUNCMP Centrilift tech made tubing hanger penetrator splice and installed shipping cap. 05:00 - 06:00 1.00 BUNCO RUNCMP Land tubin han er and RILDS with FMC Wellhead teck ~ 17,954', PUW = 100 K, SOW = 30 K. LD landing joint. 06:00 - 09:00 3.00 BUNCO RUNCMP D rod TWC with FMC Wellhead tech and tested from above to 3,500 psi for 10 charted minutes. Good test. Blown down lines and drain BOP. ND BOPE. LD BOPE in cradle. ND DSA 09:00 - 13:00 4.00 BUNCO RUNCMP NU 2-9/16" Tree.. Test tubing head adapator to 5000 psi for 20 minutes. Test tree to 5000 psi for 10 minutes with diesel, and chart.. At 10:00, noticed 8 gal leak of Koomey fluid under carrier near cellar. Leak result of leaking end fitting on Koomey hose. All notices were made. Material was cleaned up and disposed of properly. IR # 2720098. Rig released ~ 13:00 for move to MPG-14 Printed: 8/14/2008 3:38:53 PM STATE OF ALASKA ~v~a~o' OIL AND GAS CONSERVATION COAAMI$SION BODE Test Report Submit to: Contractor; Nabors Rig No.; 3S DATE: 7/18/2008 Rig Rep.: G.Sweatt/R.Bjorhus Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: Bp Op.. Phone: 659-4485 Op. Fax: 659-462$ Rep.: J. Menke /D.R Field/Unit 8~ Well No.: MP F,54 PTD # '11920 ~+ Operation: Drag: Workover: x Explor.: Test: Initial: x Weekly: BialVeekly Test Pressure: Rams: 250/3500 Annular: 250/3500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: Test ResuR Test Result Location Gen.: P WeN Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 7/8 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind P Choke Ln. Valves 1 31/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 1 2 1/16" 5000 F Check Valve 0 NA FLOOR SAFETY VALVES: Quantity Test Re Upper Kelly 0 NA Lower Keay 0 NA Batt Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes Hydraulic Chokes ACCUMULATOR SYSTEM: Time/Pressure System Pressure 3100 Pressure After Closure 1725 P_ P Test Result P P P P P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 30sec Trip Tank P P Full Pressure Attained 2 min 40 sec Pit Level Indicators P P BI"ind Switch Covers: All stations Flow Indicator P P Nitgn. Bottles (avg): 2075 Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 0 Test Tune: 4 Hours Repair or replacement of equipment wiN be made within Inspector 659-3607, follow with written confirmation to Supervises at: Remarks: tested w/ Z 7/8 test joint 24 HOUR NOTICE GIVEN YES X NO Date est start 07!16/08 Time 17:00 Finish BOP Test (for rigs) p~~ BFL 11/14/07 ~~c,~~~~ ~UL L; ~ 2~~8 Components tested ALL days. Notify the North Slope By Chuck Sheave Witrress R.Biorhus/D.Rhodes Nabors 3s BOP Test MP F-54 7-18-08 (2).xls 1. Operations Performed: o Aba ndon o Alter Casing o Change Approved Program STATE OF ALASKA '\ ALASKA 1 AND GAS CONSERVATION COh..MISSION REPORT OF SUNDRY WELL OPERATIONSECEIVED APR - 5 Z005 Change out ESP Alaska OillieMeÇons. CöïïlffiÎssion D~sion 181 Repair Well 0 Plug Perforations 0 Stimulate 181 Pull Tubing 0 Perforate New Pool 0 Waiver o Operation Shutdown 181 Perforate 0 Re-Enter Suspended Well 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: III Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 196-192 6. API Number: 50-029-22726-00-00 99519-6612 41.60' 9. Well Name and Number: MPF·54 8. Property Designation: ADL 355021 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands 11. Present well condition summary Total depth: measured 18430 feet true vertical 7543 feet Plugs (measured) N/A Effective depth: measured 18319 feet Junk (measured) N/A true vertical 7448 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1490 470 Surface 9872' 9-5/8" 9904' 4489' 5750 3090 Intermediate Production 18372' 7" 18402' 7519' 7240 5410 Liner "·~I('iJ.N··í\U::r\ )D F)!) .'! I' 20D~~ ~"Ib'~ ~,¡ç;""". . It J 4: . _ J Perforation Depth MD (ft): Perforation Depth TVD (ft): 18064' - 18127' 7233' - 7286' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 2-7/8",6.5# L-80 17954' None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8Ft APR 0 6 2005 13. Oil-Bbl Prior to well operation: 474 Subsequent to operation: 499 14. Attachments: 0 Copies of Logs and Surveys run III Daily Report of Well Operations III Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure 99 318 240 88 401 210 Tubinq Pressure 328 350 15. Well Class after proposed work: o Exploratory III Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if c.o. Exempt: Contact David Reem, 564-5743 Printed NamZjondra Stewman 8!P~~~_ Form 10-404 Revised 04/2004 Title Technical Assistant Phone 564-4750 C4' ..¡....ç. ~repared By Name/Number: Date) . \.......LfC.--Uidra Stewman, 564-4750 Submit Original Only Tree: 2-9/16" 5M ) Wellhead 11" x 7" FMC c., 5A Tubing Hanger:TC-B-EC-HT. 7-1/16" x 2-7/8" wI 8rd bot. 3" ACME LH top. CIW-H BPVT. 20" 91.1 ppf, H-40 I 112' I· KOP @ 500' Max. hole angle = 74 to 78 deg. fl 3780' to 16,000' Hole angle thru' perfs = 32 deg. 9 5/8", 40 ppf, L-80 Btrc. I 9903' Ij 7" 26 ppf, L-80, Btrc.prod. casing, (drift 10 = 6.151", cap. = 0.0383 bpf) 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift 10 = 2.347", cap. = 0.00592 bpf ) Stimulation Summary os Frac 3/31 /97 #16/20 carbo 164.# M Behind pipe. Perforation Summary Ref log: GR/CCL Marked line 1131/97 Size SPF Interval (TVO) 18,117'-18,127' (7243'-7268') 18,097' -18, 117' (7260'-7277') 18,064'-18,072' (7233'-7240') 18,078'-18,090' (7245'-7255') 4.5" 6 3-3/8" 6 3-3/8" 6 3-3/8" 6 MPU F-54 í ~ ~ ~ / ' ~ ~ ~ ~ ' "/ ~ ~ ~ ~ ~ ~ ~ ~ ~ /, ~ ~ I ~, ~ ~ ~ ~' ~ ~ ~ ~ ~ / ..~IIIW~!II~IIIWIIIIIIIIIIIIIIII~ Or¡-)F Elev. = 41.2 (N 22E) Orig. \.:JL Elev. = 12.10' OF To Csg. spool= 29.7 ' (N 22E) Cameo 2 7/8" x 1" sidepocket KBMM GLM I 130' I ) HES 9 5/8" ES" Cementer I 1,299' I ~ AVA Ported sleeve ( 1.875 id)1 17,882' I WI 3000 psi. Shear Sleeve Centrilift GC 2200 ESP, Serie¡ 513, GPMTAR 1:1,122 Stg. 17,900' Intake TVO Centrilift Tandem Gas Separator Intake Centrilift GST34B ILPFSH6 seal section 7,109' 17,918' 17,918' Centrilift KME1 562 series, 190 hp motor, 2415 v. I 48 amps. Phoenix Multisensor Bottom 17,931 ' 17,952' Centrilift 6-Fin Centralizer Bottom X Marker joints 17,828' -17,870' 17,954' 7" float collar (PBTO) 7" float shoe 7345' tvd 118,319' I 18,402' DATE REV. BY COMMENTS MILNE POINT UIT 04/08/97 MOO ESP Completion 4ES WELL F-54 1 0/22/98 MOO ESP RWO wI scalecaps 4ES API NO: 50-029-22726 1/15/00 GMH ESP RWO 4ES 3/6/2005 JRC ESP RWO with Add Perfs BP EXPLORATION (AK) . " ) ') BPEXPLORATI.ON ()þetEltionsSummary . Report . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-54 MPF-54 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/2/2005 Rig Release: 3/6/2005 Rig Number: Spud Date: 12/24/1996 End: 3/6/2005 From- Tö Hours TaSk Code NPT . Phase De~cri ptionofOperations 3/2/2005 20:00 - 22:00 2.00 RIGD P PRE PJSM. Scope down & lower derrick. Rig down. 22:00 - 00:00 2.00 MOB P PRE PJSM. Move rig & rig components from MPF-65 to MPF-54. 3/3/2005 00:00 - 02:00 2.00 RIGU P PRE Move from MPF-65 to MPF-54. Spot rig over well & R/U. Spot in pits & pipe shed. Raise & scope up derrick. 02:00 - 03:30 1.50 RIGU P DECaMP Con't to R/U. R/U lines to tree & tiger tank. Begin taking on seawater. Test lines to 3500 psi. ACCEPTED RIG @ 0200 Hrs. 03:30 - 04:00 0.50 KILL P DECaMP Hold PJSM & Pre-Spud meeting wI all hands. 04:00 - 06:00 2.00 KILL P DECaMP Kill well. SITP 760 psi. SICP 500 psi. Open well & bleed off tbg & csg pressure to 50 psi. Begin pumping & kill well. 4 BPM @ 1300 psi. 06:00 - 08:00 2.00 KILL P DECaMP Continue killing well, pumping heated seawater down tubing @ 4112 bpm I 2000 psi, taking mildly gassy oil returns thru choke & out to tiger tank. See returns clean up to seawater wI 675 bbls pumped. Pump 750 bbls total, clean seawater returns. 08:00 - 08:30 0.50 KILL P DECaMP Monitor well. Tubing & fA on vacuum. Set two way check valve. 08:30 - 10:00 1.50 WHSUR P DECaMP PJSM. Bleed void & NID tree. 10:00 - 12:00 2.00 BOPSUR P DECaMP PJSM. N/U 13 5/8" x 5M BOPE. 12:00 - 15:30 3.50 BOPSUR P DECaMP PJSM. Conduct full BOPE test as per AOGCC & BP requirements. Witnessing of test waived by AOGCC rep John Crisp. Test witnessed by Nabors Tool Pusher & BP Company Man. (1) internal failure of valve #13. This is a non critical valve. Nabors given (7) days to procure parts & repair. State notified. 15:30 - 16:00 0.50 BOPSUR P DECaMP P/U lubricator, pull two way check valve. 16:00 - 17:00 1.00 PULL P DECaMP PJSM. BOLDs. P/U landing joint. Pull hanger to floor, saw 100K max up wt, hnager pulled free. Up wt = 85K. Well stable. Fill hole wI 25 bbls. UD hanger & landing jt. 17:00 - 17:30 0.50 PULL P DECaMP Pull ESP cable over sheave, attach to spool & prep to POOH. 17:30 - 23:00 5.50 PULL P DECaMP POOH & stand back 2 7/8" tubing. Pulled 118 stands. 23:00 - 00:00 1.00 PULL P DECaMP Cut cable & change out reels in spooling unit. 3/4/2005 00:00 - 00:30 0.50 PULL P DECaMP Finish changing reels in spooling unit. Connect cable to new reel. 00:30 - 04:00 3.50 PULL P DECaMP Con't to POOH & stand back 2 7/8" tubing. Pulled 190 stands. 04:00 - 06:00 2.00 PULL P DECaMP Inspect, break out & UD ESP. 06:00 - 07:30 1.50 PULL P DECaMP Clear I Clean rig floor. Service rig. 07:30 - 15:00 7.50 CLEAN P DECOMP PJSM. M/U 3 1/2" mule shoe & RIH on 2 7/8" EUE 8 rnd tbg. 15:00 - 16:00 1.00 CLEAN P DECaMP Tag fill @ 18,266' on jt #585. Rig up headpin & circulating hose. Bring on pump @ 4 bpm I 1700 psi & wash down to 18,295'. 65K upwt, 43K down wt. 16:00 - 17:00 1.00 CLEAN P DECaMP PJSM. Pick up (25') & line up to reverse circulate. Close bag & reverse circulate down to 18,295'. Reverse circulate @ 4 bpm I 850 psi to clean returns. Frac sand & formation sand in returns. 17:00 - 19:00 2.00 CLEAN P DECaMP PJSM. Make connection & reverse circulate down, tag hard @ 18,322'. Reverse circulate @ 4 bpm I 800 psi to clean returns Chase wi 40 bbl EP mud lube pill.. 19:00 - 19:30 0.50 CLEAN P DECaMP POOH & UD 17 singles of 2 7/8" tubing. 19:30 - 00:00 4.50 CLEAN P DECaMP POOH & stand back 2 7/8" tubing. 3/5/2005 00:00 - 01 :30 1.50 CLEAN P DECaMP Con't to POOH & stand back 2 7/8" tubing. Pulled 190 stands. 01 :30 - 03:00 1.50 PERFOB P OTHCMP Clear & clean rig floor. N/D flow nipple. Install shooting flange. 03:00 - 05:30 2.50 PERFOB P OTHCMP R/U E-line equip. Hold PJSM. Test lubricator to 1000 psi, Ok. Assemble & arm perf guns. Printed: 3m2005 9:46: 13 AM ) ') BPEXPLORATION O:per~tiollS$Um.l11äry . Report Page2of2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-54 MPF-54 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/2/2005 Rig Release: 3/6/2005 Rig Number: Spud Date: 12/24/1996 End: 3/6/2005 Date Frorn-To· Hours -Task Code NPT Phase Description of Operations 3/5/2005 05:30 - 07:00 1.50 PERFOB P OTHCMP RIH wI perf guns. 07:00 - 09:00 2.00 PERFOB P OTHCMP PJSM. Tie in. Top shot @ 18064'. Shoot perfs w/3 3/8" 6 spf Powerjet. Perf from 18,064' - 18,072' & 18,,078' - 18,090'. Monitor well, well on vacuum. POOH wI E-Line. ASF. 09:00 - 10:30 1.50 PERFOB P OTHCMP PJSM. Rig down Schlumberger E-Line. 10:30 - 11 :30 1.00 RUNCOMP RUNCMP PJSM. Rig up to run ESP completion. 11 :30 - 14:00 2.50 RUNCOMP RUNCMP PJSM. Pick up ESP pump assembly. Plug in MLE & test, No Good, MLE damaged. 14:00 - 17:00 3.00 RUNCOMP RUNCMP Pull Cable over sheave & back on reel. Cut off MLE & splice on new one. 17:00 - 19:00 2.00 RUNCOMP RUNCMP Pull cable back over sheave & plug into pump. Ran pup & A V A sleeve. Tested cable, good. Install protectolizers & flat guards. 19:00 - 23:30 4.50 RUNCOMP RUNCMP RIH wI new ESP on 2 7/8" tubing. Pump thru tubing 10 bbls & check cable every 2000'. Ran 82 stands. 23:30 - 00:00 0.50 RUNCOMP RUNCMP Change out reels. Make reel to reel splice. 3/6/2005 00:00 - 03:00 3.00 RUNCOMP RUNCMP Con't to make reel to reel splice. Test same. 03:00 - 08:30 5.50 RUNCOMP RUNCMP Con't to RIH wI ESP completion. Pump thru ESP 10 bbls & check cable every 2000'. 1 bpm I 900 psi. 08:30 - 11 :30 3.00 RUNCOMP RUNCMP PJSM. WI 168 stands in the hole @ 15,725', make reel to reel splice & test, OK. 11 :30 - 13:00 1.50 RUNCOMP RUNCMP Continue in hole, testing cable & flushing tubing wi 10 bbls @ 1 bpm I 900 psi every 2000'. 13:00 - 15:00 2.00 RUNCOMP RUNCMP PJSM. P/U landing joint & hanger. Install penetrator & attach field connection & test, OK. 15:00 - 15:30 0.50 BOPSURP RUNCMP PJSM. Land hanger, LID landing jt. RILDs. Set 2 way check & test @ 3500 psi, OK. 15:30 - 16:30 1.00 BOPSUP P RUNCMP N/D BOPE. 16:30 - 18:00 1.50 WHSUR P RUNCMP N/U tree. Test tree & hanger void to 5000 psi, OJ. 18:00 - 19:00 1.00 WHSUR P RUNCMP P/U lubricator & pull TWC. Install BPV & LID lubricator. 19:00 - 20:00 1.00 WHSUR P RUNCMP Secure well. Clean cellar. RELEASE RIG @ 2000 hrs. Printed: 3/7/2005 9:46: 13 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Pedorate _ ACIDIZE ESP Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora[je, AK 99519-6612 4. Location of well at surface 3188' FNL, 2662' FEL, Sec. 06, T13N, R10E, LIM At top of productive interval 4508' FNL, 1745' FEL, Sec. 24, T14N, R09E, LIM At effective depth 4370' FNL, 1794' FEL, Sec. 24, T14N, R09E, UM At total depth 4313' FNL, 1809' FEL, Sec. 24, T14N, R09E, UM 5. Type of Well: Development __X Explorato~__ Strat~graphic_ Service__ (asp's 541900, 6035544) (asp's 537582, 6050039) (asp's 537532, 6050177) (asp's 537517, 6050234) 6. Datum elevation (DF or KB feet) RKB 42 feet 7. Unit or Property name Milne Point Unit 8. Well number MPF-54 9. Permit number / approval number 196-192 10. APl number 50-029-22726-00 11. Field / Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical 18430 feet 7543 feet Effective depth: measured 18319 feet true vertical 7448 feet Plugs (measured) Casing Length Conductor 78' Surface 9871' Production 18372' Junk (measured) Size Cemented 20" 250 sx Arcticset I 2052 s× PF 'E', 860 sx 9-5/8" Class 'G' 7" 300 sx Class 'G' Measured Depth True Ve~icalDepth 112' 112' 9903' 4488' 18402' 7519' Perforation depth: Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) measured Open Perfs 18097'-18127' true vertical Open Perfs 7260'-7268' 2-7/8", 6.5#, N-80 Tubing to 17888'. ESP Pump Bottom @ 17946' No Packer. Camco 2-7/8" x 1" sidepocket KBMM GLM @ 130'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation SHUT-IN Subsequent to operation SHUT-IN OiI-Bbl Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report ot Well Operations __ 6. Status of well classification as: Oil _x Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Technical Assistant DeWayne R. Schn 5GANNED ORiGiNAL Cr~.t~ec)J'~3oarv 31, 2003 elSared by DeWayne R Schnorr 564-5174 SUBMIT iN DUPLICATE I BDM$ BFL Form .10-404 Rev 06/'15/88 · MPF-54 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 12/18/2002 12/23/2OO2 01/O5/2OO3 01/O6/2OO3 ESP MAINTENANCE: ESP ACID WASH SLICKLINE: DRIFT &TEST TUBING SLICKLINE: SET BPI TURBINE SHUTDOWN: FREEZE PROTECT EVENT SUMMARY 12/18/02 PUMPED 15 BBLS 7.5% DAD ACID FOLLOWED BY 102 BBLS DEAD CRUDE. DID NOT OBSERVE ANY KIND OF PRESSURE DROP ONCE ACID HIT ESP. STARTED ESP AT 35 HZ AND PUT BACK ON PRODUCTION. RAMPED UP TO NORMAL OPERATING PARAMETERS. STILL TROUBLE SHOOTING PRODUCTION LOSS. LAST WELL TEST 277 BOPD, 544 TOTAL FLUID. 12/23/02 TGSM, MIRU HES & FESCO. PRESSURE TESTED SURFACE EQUIPMENT TO 3500 PSI. PRESSURE TESTED TUBING TO 1500 PSI @ 17069' WLM, 17099' MD. COULD NOT GET D&D HOLE FINDER PASSED 17069' WLM. RAN 2.25' LIB AND WENT THROUGH 17069' WLM. SAT DOWN ON SOMETHING IN TUBING BUT WAS ABLE TO PUSH IT DOWN HOLE AND TAGGED AVA SLEEVE @ 17843' WLM, 17873' MD. 01/05/03 TGSM. RIGGED HES UP. DROPPED BPI. CHASED TO NIPPLE WITH SHEARED CS. BEAT ON BPI FOR ABOUT THRITY MINUTES. PULLED OUT OF BPI. BROUGHT PUMP ON. HIGHER PRESSURE AND CLIMBING. BPI SET. LAY HES DOWN FOR NIGHT. 01/06/03 ARRIVED ON LOCATION. HELD PRE-JOB SAFETY MEETING. PRESSURE TESTED TO 3500 PSI. STARTED DOWN THE TUBING WITH 15 BBLS DEAD CRUDE @ 1.0 BPM WITH 1200 PSI MAX. WELL FREEZE PROTECTED WITH DEAD CRUDE FOR SHUT-IN. FLUIDS PUMPED BBLS METHANOL 137 DIESEL 117 CRUDE 15 7.5% DAD ACID 269 TOTAL Page 1 W~llhea~: 11" x 7" FMC Gen. 5A ' Orig. GL Elev. = 12.10' Double actuated ,wi 8rd bdt 3"LH : ii DF To Csg, spool= 29,7 ' (N 22E) top BPV H-profile 2-9/16" ; Camco 2 7/8" x 1" KOP @ 500' i sidepocket KBMM GLM Max. hole angle = 74 to 78 deg. f/ 3780' to 16,000' Hole angle thru' peals = 32 deg ;3 9 5/8% 40 ppf. L-80 Btrc. 9903' ~ , Note: Do Not £×¢ood 2600 psi. while Pumping on th~ tubing. ^ ( dri~ ID = ~151". cap = 0.0383 bpi ) i 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg, , W/3000 psi. Shear Sleeve ( drift ID = 2.347", cap, = 0.00592 bpf ~ Centrilift GC 2200 ESP, series I I 513, GPMTAR 1:1, 122 Stg.I 17,988' I ~ . CentriliR Tandem Gas Stimulation Summar~ ~ ~ DS Frae 3 / 31 / 97 #16120 carb. ~: !!~ Centrilift KME1 562 series, 17,927' 164# M Behind pipe * ,~= 190 hp motor, 2415 w Perforatiorl Summar~ ~ D Centrili~Cent01ift 6-FinPHD BottOmcentralizer Ref Ida: GR/CCL Marked line 1131/97 ~ J J 17,946' 02/02/97 , ; 7" float collar (PBTD) MILNE POINT UIT 02/08/97 MDO ~il~al cOmplelion 27E WELL F-54 04/08/97 MDO SPComp~ebon 4ES APl NO: 50-029-22726 1/15/00 GMH ES~VO4~S BP EXPLORATION (AK) .... STATE OF ALASKA -- ALASKA ,.,,L AND GAS CONSERVATION CO,,,,,/IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator BP Exploration (Alaska) Inc. [--I Operation Shutdown i-] Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well []Other Change Out ESP 6. Datum Elevation (DF or KB) RTE - 41.6' 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: iX] Development [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 2092' NSL, 2662' WEL, SEC. 6, T13N, R10E, UM At top of productive interval 795' NSL, 1761' WEL, SEC. 24, T14N, R9E, UM At effective depth 910' NSL, 1794' WEL, SEC. 24, T14N, R9E, UM At total depth 943' NSL, 1914' WEL, SEC. 24, T14N, R9E, UM 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-54 9. Permit Number / Approval No. 196-192 10. APl Number 50- 029-22726-01 1. 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 18430 feet 7554 feet 18319 feet 7460 feet Length Size Structural Conductor 78' 20" Surface Intermediate 9872' 9-5/8" Production 18372' 7" Liner Plugs (measured) Junk (measured) Cemented MD TVD 250 sx Arcticset I 112' 112' 2052 sx PF 'E', 860 sx Class 'G' 9904' 4489' 300 sx Class 'G' 18402' 7519' Perforation depth: measured 18097' - 18127' true vertical 7261' - 7286' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 17946' Packers and SSSV (type and measured depth) None ORIGINAL 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED Alaska 0il & Gas Cons. O0rnmissioD Anchorage 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] 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 ¢-i, ?/~/~ 0 Terrie Hubble ~i,':! ' ~ , .. Title Technical Assistant III Prepared By Name/Number: Date 0['-'/~0' O0 ~,. Terrie Hubble, 564-4628 ~ ~ Form 10-404 Rev. 06/15/88 Facility Date/Time 11 Jan 00 12 Jan 00 13 Jan 00 14 Jan 00 M Pt F Pad Progress Report Well MPF-54 Page 1 Rig Nabors 4ES Date 17 January 00 12:00-01:00 12:00-01:00 O1:00 O1:00-06:00 O1:00-06:00 06:00 06:00-16:00 06:00-16:00 16:00 16:00-18:00 16:00-16:30 16:30 16:30-18:00 18:00 18:00-21:00 18:00-21:00 21:00 21:00-00:00 21:00-00:00 00:00 00:00-01:00 00:00-01:00 01:00 01:00-06:00 01:00-06:00 06:00 06:00-06:00 06:00-10:00 10:00 10:00-11:00 11:00 11:00-14:30 14:30 14:30-06:00 06:00 Duration 13hr 13hr 5hr 5hr 10hr 10hr 2hr 1/2 hr 1-1/2 hr 3hr 3hr 3hr 3hr lhr lhr 5hr 5hr 24 hr 4hr lhr 3-1/2 hr 15-1/2 hr Activity Move rig Rig moved 100.00 % Rig Down from L-pad & move to F- pad & rig up over MPF-54 and safe out equipment, level derrick. At well location - Slot Fluid system Fill pits with Seawater Rig Tiger tank & fill pits with sea h20 & rig lines to tree for well kill. & test same. Completed operations Well control Circulated closed in well at 15998.0 ft Test lines to 3500 psi. & hold well kill pjsm. & sitp=1200 sicp=1900 psi. & circ. influx from well bore through sava nipple @ 15998' loosing approximatly 1000' oftvd, well bore & bull head 80 bbl. to clear influx from sump. & monitor well bore. Hole displaced with Seawater - 150.00 % displaced Wellhead work Installed Hanger plug Equipment work completed Removed Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack 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 17960.0 ft bolds & install landing it. & attempt to pull tbg. @ 80 % of tensile unable work tbg. & pump EP lube wet csg. to enable to get more direct pull at pump. Stopped: To hold safety meeting Pull Single completion, 2-7/8in O.D. (cont...) Circulated at 17960.0 ft Circ. & work tbg. string to 80 % of tensile while adding EP lube to get lubricity to move completion string due to well bore geomentry (worked out successfully, after 4-bbl. cp lube added to fluids.) Obtained req. fluid properties - 1.00 %, hole vol. Removed Tubing hanger lay dn hanger & landing joint. Equipment work completed Circulated at 17960.0 ft circ. & raise brine wt. to 8.8 ppg. Obtained req. fluid properties - 100.00 %, hole vol. Pulled Tubing in stands to 90.0 ft pooh with tbg. to esp assy. Retrieved 90.0 ft from ESP RECEIVED JAN 21 DO0 Alaska Oil & Gas Cons. Comm Anchorage ~lon Facility M Pt F Pad Progress Report Well MPF-54 Page 2 Rig Nabors 4ES Date 17 January 00 Date/Time 15 Jan 00 06:00-09:30 06:00-09:30 09:30 09:30-06:00 09:30-06:00 06:00 06:00-13:30 06:00-11:00 11:00 11:00-13:30 13:30 13:30-15:00 13:30-15:00 15:00 15:00-16:30 15:00-16:30 16:30 16:30-18:30 16:30-18:00 18:00 18:00-18:30 18:30 18:30-06:00 18:30-21:00 21:00 Duration 3-1/2 hr 3-1/2 hr 20-1/2 hr 20-1/2 hr 7-1/2 hr 5hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 2hr 1-1/2 hr 1/2 hr 11-1/2 hr 2-1/2 hr Activity Pull Single completion, 2-7/8in O.D. (cont...) Rigged down sub-surface equipment - ESP finish pooh & lay dn esp assy Equipment work completed Run Single completion, 2-7/8in O.D. Ran Tubing in stands to 12960.0 ft clean floor & mu esp assy. & rih with same flushing pump & make 2-mid-line splices in cable. Stopped: To hold safety meeting Run Single completion, 2-7/8in O.D. (cont...) Ran Tubing in stands to 17945.0 ft cont. rih to setting depth & install hanger. Hanger landed Serviced ESP install esp cable connector to hanger. Equipment work completed Wellhead work Installed Tubing hanger install hanger & rilds & set twc & test same to 2500 psi. Equipment work completed Nipple down BOP stack Rigged down BOP stack Equipment work completed Wellhead work Installed Xmas tree install tree & test same to 5000 psi. Equipment work completed Removed Hanger plug Equipment work completed Fluid system Freeze protect well - 60.000 bbl of Diesel Completed operations Gas Co~$. ~misslo~ A~ChOra~e AOGCC Individual Well ~ /~ ~0 Geological Materials Inventory PERMIT DATA T DATA PLUS 96-192 GR/CCL DEPTH ~00-18302 96-192 ADN-MD ~9918-1843 96-192 CDR-MD ~'~212-18430 96-192 CDR-TVD ~"~12-7477 96-192 ADN-TVD ~5'~4500-7477 96-192 7628 ~>~CHLUM GR/CDR/ADN '96-192 STAT PRESS .~'~985-18112 96-192 GR/CCL ~'~7850-18197 96-192 MULTI SHOT ~SPERRY 9844.4-18278.36 96-192 MWD SRVY ~-~CHLUM 0-18439.4 96-192 MULTI SHOT ~/GYRODATA 0-18273. Page: 1 Date: 04/07/99 T / RUN RECVD D .............. FINAL 02/21/97 FINAL 03/27/97 FINAL 03/27/97 FINAL 03/27/97 FINAL 03/27/97 1 03/27/97 FINAL 04/06/97 FINAL 04/06/97 08/06/97 08/06/97 08/06/97 10-407 ~OMPLETION DATE @ ~ / f~ DAILY WELL OPS R @ / / ! /~7/ TO 4//P / ~ Are dry ditch samples required? yes ~And received? Was the well cored? yes ~.Analysis & description received? Are well tests required? yes ~_Received? r e ,! Well is in compliance ~-~ I~i~tia 1 COMMENTS @ @ ~'i / ~ / ~'?/ ye s ~-nc~ ye s---mrO~ BOX STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COrv~viiSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other ESP Changeout 6. Datum Elevation (DF or KB) RTE = 41.6' 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2092' NSL, 2662' WEL, SEC. 6, T13N, R10E, UM At top of productive interval 772' NSL, 1745' WEL, SEC. 24, T14N, R9E, UM At effective depth 886' NSL, 1777' WEL, SEC.24, T14N, R9E, UM At total depth 943' NSL, 1792' WEL, SEC. 24, T14N, R9E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 7. Unit or Property Name Milne Point Unit 12. Present well condition summary Total depth: measured 18430 feet true vertical 7554 feet Effective depth: measured 18319 feet true vertical 7460 feet Plugs (measured) Junk (measured) 8. Well Number MPF-54 9. Permit Number / Approval No. 96-192 10. APl Number 50- 029-22726 11. Field and Pool Milne Point Unit/Kuparuk River Sands Casing Length Size Structural Conductor 78' 20" Surface Intermediate 9872' 9 5/8" Production Liner 18372' 7" Cemented MD TVD 250 sx Arcticset 1 112' 112' 2052 sx PF 'E', 860 sx Class 'G' 9904' 4489' 300 sx Class 'G' 18402' 7519' Perforation depth: measured true vertical 18097' -18127' (Subsea) 7219' - 7244' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 17960' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure JAN 08 1999 ~,unorage ......... ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] 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 ¢Jea~e~.~/--taa, '~'"-~-~ ' ~' ~:~"EU~:/ Title Staff Technical Assistant Prepared By Name/Numbec " // Date Jeanne L. Haas, 564-5225 Facility Date/Time 20 Oct 98 21 Oct 98 22 Oct 98 23 Oct 98 24 Oct 98 M Pt F Pad Progress Report Well MPF-54 Rig (null) Page Date Duration Activity 22:00-23:30 23:30-05:00 05:00-06:00 06:00-06:15 06:15-07:00 07:00-08:00 08:00-10:00 10:00-10:30 10:30-10:45 10:45-11:30 11:30-12:00 12:00-15:30 15:30-17:30 17:30-17:45 17:45-18:00 18:00-18:15 18:15-19:00 19:00-20:00 20:00-20:30 20:30-22:30 22:30-23:00 23:00-23:30 23:30-02:15 02:15-02:30 02:30-06:00 06:00-06:15 06:15-06:30 06:30-15:00 15:00-17:00 17:00-17:30 17:30-18:00 18:00-18:15 18:15-00:30 00:30-01:30 01:30-03:00 03:00-05:00 05:00-05:45 05:45-06:00 06:00-06:15 06:15-06:45 06:45-07:00 07:00-08:30 08:30-09:00 09:00-14:45 14:45-15:00 15:00-16:00 16:00-17:00 17:00-18:00 18:00-18:15 18:15-19:00 19:00-21:30 21:30-04:00 04:00-06:00 06:00-06:30 1-1/2 hr 5-1/2 hr lhr 1/4 hr 3/4 hr lhr 2hr 1/2 hr 1/4 hr 3/4 hr 1/2 hr 3-1/2 hr 2hr 1/4 hr 1/4 hr 1/4 hr 3/4 hr lhr 1/2 hr 2hr 1/2 hr 1/2 hr 2-3/4 hr 1/4 hr 3-1/2 hr 1/4 hr 1/4 hr 8-1/2 hr 2hr 1/2 hr 1/2 hr 1/4 hr 6-1/4 hr lhr 1-1/2 hr 2hr 3/4 hr 1/4 hr 1/4 hr 1/2 hr 1/4 hr 1-1/2 hr 1/2 hr 5-3/4 hr 1/4 hr lhr lhr lhr 1/4 hr 3/4 hr 2-1/2 hr 6-1/2 hr 2hr 1/2 hr Rigged down Drillfloor / Derrick Rig moved 100.00 % Rigged up Service lines Held safety meeting Rigged up Drillfloor / Derrick Installed High pressure lines Fill pits with Seawater Retrieved Hanger plug Bleed down well Circulated closed in well at 16879.0 ft Bullhead well Circulated closed in well at 16879.0 ft Circulated at 16879.0 ft Flow check Installed Hanger plug Held safety meeting Removed Xmas tree Installed BOP stack Serviced Variable ram Tested All functions Retrieved Hanger plug Retrieved Tubing hanger Circulated at 16773.0 ft Flow check Pulled Tubing in stands to 14947.0 ft Held safety meeting Serviced Drillfloor / Derrick Pulled Tubing in stands to 50.0 ft Retrieved Electrical submersible pumps Rigged up Tubing handling equipment Made up BHA no. 1 Held safety meeting R.I.H. to 17793.0 ft Singled in drill pipe to 18231.0 ft Reverse circulated at 18319.0 ft Reverse circulated at 18315.0 ft Circulated at 18315.0 ft Laid down 31.5 ft of 3-1/2in OD drill pipe Held safety meeting Laid down 283.0 ft of 3-1/2in OD drill pipe Singled in drill pipe to 18137.0 ft Reverse circulated at 18137.0 ft Laid down 346.0 ft of 3-1/2in OD drill pipe Pulled out of hole to 3.0 fl Pulled BHA Serviced Block line Rigged up Completion string handling equipment Serviced Electrical submersible pumps Held safety meeting Rig waited: Equipment Serviced Electrical submersible pumps Ran Tubing in stands to 8050.0 ft Serviced Electric cable Serviced Electric cable (cont...) 1 05 January 99 Progress Report Facility M Pt F Pad Well MPF-54 Rig (null) Page 2 Date 05 January 99 Date/Time 25 Oct 98 06:30-15:00 15:00-18:30 18:30-19:15 19:15-19:30 19:30-21:30 21:30-22:15 22:15-22:30 22:30-23:30 23:30-00:30 00:30-01:00 01:00-01:15 01:15-01:30 01:30-02:00 02:00-02:30 02:30-03:30 Duration 8-1/2 hr 3-1/2 hr 3/4 hr 1/4 hr 2hr 3/4 hr 1/4 hr lhr lhr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr lhr Activity Ran Tubing in stands to 16350.0 ft Serviced Electric cable Ran Tubing in stands to 17939.0 ft Rigged up Tubing hanger Serviced Electric cable Ran Tubing on landing string to 17960.0 ft Installed Hanger plug Removed BOP stack Installed Xmas tree Tested Xmas tree Retrieved Hanger plug Installed Hanger plug Installed High pressure lines Freeze protect well - 17.000 bbl of Diesel Removed High pressure lines 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 [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 96-192 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 .~..-~..:_... ....... ,- 50-029-22726 4. Location of well at surface ,~ ........ ,..,It ~ 9. Unit or Lease Name 2092' NSL, 2662' WEL, SEC. 6, T13N, R10E, UM~:~./~.~_i" .0A',,; .~ i ~ ' Milne Point Unit At top of productive interval ~ Vt,&IFIl0 10. Well Number 772' NSL, 1925' WEL, SEC. 24, T14N, RDE, UM ;' ,¢,.~./ ~ MPF-54 At total depth~:-''~'-'~.~j i ¢.. · 11 Field and Pool 943' NSL, 1972' WEL, SEC. 24, T14N, RDE, UM ;'"'"- ' Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands Plan RTE = 41.6'I ADL 355021 12. Date Spudded 113. Date T.D. Reached I 14. Date Comp., Susp., orAband.llE. Water depth, if offshore 16. No. of Completions 1/4/97I 1/18/97! 4/6/97I N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 18430 7554 FTl 18319 7460 FTI [~Yes I--INoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run Gyro, MWD, LWD, CDR, ESS 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 34' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 32' 9904' 12-1/4" 2052 sx PF 'E', 860 sx Class 'G' 7" 26# L-80 30' 18402' 8-1/2" 300 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 4-1/2" Gun Diameter, 6 spf 2-7/8", 6.5#, L-80 17903' N/A MD TVD MD TVD 18097'-18117' 7272'-7289' 18117'-18127' 7289'-7297' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 170 bbls diesel Frac 18097'-18117', 165000# 16/20 Carbolite behind pipe 18117'-18127' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) April 18, 1997I Electric Submersible Pump [:)ate 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 GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas . t_eL. Submit core chips. ORIGINAL ~a~a ~0it & ~as O0ns, C, ommis~ .... '-~, gnch0rago Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Kuparuk 'A' 18056' 7237' Top Kuparuk A3 18059' 7240' Top Kuparuk A2 18075' 7253' Top Kuparuk A1 18095' 7270' 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 /~_.v../---,- L/ ~:-'~ Title Senior Drilling] Engineer Date ~ IS"/~) 7 Chip Alvord . MPF-54 96-192 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Progress Report Facility M Pt F Pad Well MPF-54 Rig Nabors 22E Page 1 Date 30 July 97 Date/Time 01 Jan 97 13:01-15:00 15:00-15:30 15:30-18:00 18:00-18:30 18:30-01:00 02 Jan 97 01:00-05:15 05:15-06:00 06:00-07:30 07:30-02:00 03 Jan 97 02:00-06:00 06:00-08:15 08:15-08:45 08:45-09:00 09:00-16:00 16:00-19:00 19:00-00:00 04 Jan 97 00:00-01:00 01:00-01:30 01:30-06:00 06:00-16:30 16:30-17:45 17:45-18:30 18:30-18:45 18:45-19:30 19:30-20:30 20:30-06:00 05 Jan 97 06:00-06:30 06:30-18:00 18:00-18:30 18:30-18:45 18:45-20:00 20:00-21:15 21:15-23:30 23:30-01:00 06 Jan 97 01:00-03:00 03:00-03:30 03:30-06:00 06:00-06:30 06:30-16:00 16:00-16:30 16:30-18:00 18:00-18:30 18:30-18:45 18:45-21:00 21:00-22:00 22:00-00:00 07 Jan 97 00:00-01:00 01:00-03:00 03:00-03:30 03:30-06:00 06:00-18:00 18:00-19:30 19:30-23:30 23:30-01:00 Duration 1-3/4 hr 1/2 hr 2-1/2 hr 1/2 hr 6-1/2 hr 4-1/4 hr 3/4 hr 1-1/2 hr 18-1/2 hr 4hr 2-1/4 hr 1/2 hr 1/4 hr 7hr 3hr 5hr lhr 1/2 hr 4-1/2 hr 10-1/2 hr 1-1/4 hr 3/4 hr 1/4 hn' 3/4 hr lhr 9-1/2 hr l/2hr 11-1/2 hr 1/2 hr 1/4 hr 1-1/4 hr 1-1/4 hr 2-1/4 hr 1-1/2 hr 2hr 1/2 hr 2-1/2 hr 1/2 hr 9-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/4 hr 2-1/4 hr lhr 2hr lhr 2hr 1/2 hr 2-1/2 hr 12hr 1-1/2 hr 4hr 1-1/2 hr Activity Rigged down Drillfloor / Derrick Held safety meeting Rig moved 10.00 % Held safety meeting Rig moved 60.00 % Rig moved 80.00 % Rig waited · Equipment Rig waited' Equipment (cont...) Rig moved 100.00 % Rigged up Drillfloor / Derrick Rigged up Drillfloor / Derrick (cont...) Held safety meeting Held drill (Spill) Rigged up Divertor Fill pits with Water based mud Rigged up Divertor Made up BHA no. 1 Tested Divertor Racked back drill pipe Racked back drill pipe (cont...) Made up BHA no. 1 Held safety meeting Held drill (Abandonment) Drilled cement to 112.0 ft Made up BHA no. 1 Drilled to 854.0 ft Held safety meeting Drilled to 2139.0 ft Held safety meeting Held drill (Fire) Drilled to 2525.0 ft Circulated at 2525.0 ft Pulled BHA Serviced Top drive R.I.H. to 2430.0 ft Washed to 2525.0 ft Drilled to 2716.0 ft Held safety meeting Drilled to 3575.0 ft Repaired Top drive Drilled to 3670.0 ft Held safety meeting Held drill (Kick while drilling) Drilled to 4053.0 ft Circulated at 4053.0 ft Pulled out of hole to 1500.0 ft Serviced Top drive R.I.H. to 3861.0 ft Reamed to 4053.0 ft Drilled to 4530.0 ft Drilled to 6054.0 ft Circulated at 6054.0 ft Pulled BHA Made up BHA no. 2 Facility M Pt F Pad Progress Report Well MPF-54 Page 2 Rig Nabors 22E Date 30 July 97 Date/Time 08 Jan 97 09 Jan 97 10 Jan 97 11 Jan 97 12 Jan 97 13 Jan 97 01:00-02:00 02:00-03:00 03:00-04:30 04:30-06:00 06:00-06:30 06:30-21:00 21:00-23:30 23:30-01:00 01:00-02:00 02:00-03:00 03:00-06:00 06:00-00:30 00:30-03:00 03:00-06:00 06:00-09:00 09:00-10:00 10:00-10:30 10:30-16:00 16:00-20:30 20:30-00:00 00:00-03:30 03:30-05:00 05:00-05:15 05:15-06:00 06:00-06:15 06:15-07:00 07:00-19:30 19:30-23:00 23:00-23:30 23:30-01:00 01:00-01:30 01:30-03:00 03:00-05:00 05:00-05:30 05:30-06:00 06:00-06:15 06:15-06:30 06:30-08:00 08:00-11:00 11:00-12:00 12:00-15:30 15:30-19:30 19:30-20:00 20:00-00:00 00:00-01:30 01:30-03:00 03:00-06:00 06:00-09:00 09:00-10:00 10:00-12:00 12:00-13:00 13:00-13:30 13:30-14:30 14:30-06:00 Duration lhr lhr 1-1/2 hr 1-1/2 hr 1/2 hr 14-1/2 hr 2-1/2 hr 1-1/2 hr lhr lhr 3hr 18-1/2 hr 2-1/2 hr 3hr 3hr lhr 1/2 hr 5-1/2 hr 4-1/2 hr 3-1/2 hr 3-1/2 hr 1-1/2 hr 1/4 hr 3/4 hr 1/4 hr 3/4 hr 12-1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 2hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1-1/2 hr 3hr lhr 3-1/2 hr 4hr 1/2 hr 4hr 1-1/2 hr 1-1/2 hr 3hr 3hr lhr 2hr lhr 1/2hr lhr 15-1/2 hr Activity Serviced Top drive R.I.H. to 1952.0 ft Reamed to 2720.0 ft R.I.H. to 5850.0 ft Reamed to 6054.0 ft Drilled to 8062.0 ft Circulated at 8062.0 ft Pulled out of hole to 5485.0 ft Serviced Top drive R.I.H. to 8062.0 ft Drilled to 8349.0 ft Drilled to 9918.0 ft (cont...) Circulated at 9918.0 ft Pulled out of hole to 3400.0 ft Pulled out of hole to 340.0 ft (cont...) Serviced Block line Serviced Top drive R.I.H. to 9918.0 ft Circulated at 9918.0 ft Pulled out of hole to 1000.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 9-5/8in (400.0 ft OD) Ran Casing to 500.0 ft (9-5/8in OD) (cont...) Rigged down Circulating head Ran Casing to 9903.0 ft (9-5/8in OD) Circulated at 9903.0 ft Pmnped 70.000 bbl spacers - volume (null) Mixed and pumped slurry - 483.000 bbl Mixed and pumped slurry - 176.000 bbl Displaced slurry - 714.000 bbl Circulated at 1302.0 ft Pumped 70.000 bbl spacers - volume (null) Mixed and pumped slurry - 250.000 bbl Mixed and pumped slurry - 310.000 bbl (cont...) Displaced slurry - 68.000 bbl Cleared Flowline Rigged down Divertor Installed Casing spool Rigged up BOP stack Tested BOP stack Installed Wear bushing Made up BHA no. 3 Singled in drill pipe to 1298.0 ft Drilled cement to 1302.0 ft Singled in drill pipe to 5000.0 ft Singled in drill pipe to 9800.0 ft (cont...) Tested Casing - Via annulus and string Drilled installed equipment - Landing collar Circulated at 9938.0 ft Performed formation integrity test~ il, q~[.~ ~Pqb[ Circulated at 9938.0 ft Drilled to 11725.0 ft Facility ii M Pt F Pad Progress Report Well MPF-54 Rig Nabors 22E Page 3 Date 30 July 97 Date/Time 14 Jan 97 15 Jan 97 16 Jan 97 17 Jan 97 18 Jan 97 19 Jan 97 20 Jan 97 21 Jan 97 06:00-16:00 16:00-17:00 17:00-19:00 19:00-20:00 20:00-21:00 21:00-22:30 22:30-06:00 06:00-20:30 20:30-22:00 22:00-00:30 00:30-01:30 01:30-03:30 03:30-06:00 06:00-06:00 06:00-11:00 11:00-16:00 16:00-17:30 17:30-18:30 18:30-20:00 20:00-21:00 21:00-02:00 02:00-04:00 04:00-06:00 06:00-08:00 08:00-09:00 09:00-10:00 10:00-13:00 13:00-14:00 14:00-16:30 16:30-23:30 23:30-02:00 02:00-03:30 03:30-04:15 04:15-04:30 04:30-06:00 06:00-14:00 14:00-15:00 15:00-22:30 22:30-23:00 23:00-06:00 06:00-06:45 06:45-07:00 07:00-09:00 09:00-10:00 10:00-11:30 11:30-12:30 12:30-14:30 14:30-15:30 15:30-18:00 18:00-19:00 19:00-20:00 20:00-06:00 06:00-07:00 07:00-10:00 Duration 10hr lhr 2hr lhr lhr 1-1/2 hr 7-1/2 hr 14-1/2 hr 1-1/2 hr 2-1/2 hr lhr 2hr 2-1/2 hr 24 hr 5hr 5hr 1-1/2 hr lhr 1-1/2 hr lhr 5hr 2hr 2hr 2hr lhr lhr 3hr lhr 2-1/2 hr 7hr 2-1/2 hr 1-1/2 hr 3/4 hr 1/4 hr 1-1/2 hr 8hr lhr 7-1/2 hr 1/2 hr 7hr 3/4 hr 1/4 hr 2hr lhr 1-1/2 hr lhr 2hr lhr 2-1/2 hr lhr lhr 10hr lhr 3hr Activity Drilled to 13061.0 ft (cont...) Circulated at 13061.0 ft Pulled out of hole to 9900.0 ft Serviced Block line Serviced Top drive R.I.H. to 13061.0 ft Drilled to 14016.0 ft Drilled to 16117.0 ft (cont...) Circulated at 16117.0 ft Pulled out of hole to 9819.0 ft Serviced Top drive R.I.H. to 16308.0 ft Drilled to 16308.0 ft Drilled to 17547.0 ft (cont...) Drilled to 17892.0 ft (cont...) Circulated at 17892.0 ft Pulled out of hole to 16000.0 ft R.I.H. to 17892.0 ft Drilled to 18045.0 ft Circulated at 18045.0 ft Drilled to 18430.0 ft Circulated at 18430.0 ft Pulled out of hole to 14500.0 ft Pulled out of hole to 9900.0 ft (cont...) Serviced Block line Serviced Top drive R.I.H. to 18150.0 ft Reamed to 18430.0 ft Circulated at 18430.0 ft Pulled out of hole to 450.0 ft Pulled BHA Tested Top ram Rigged up Casing handling equipment Held safety meeting Ran Casing to 7in (1600.0 ft OD) Ran Casing to 9800.0 ft (7in OD) (cont...) Circulated at 9800.0 ft Ran Casing to 18402.0 ft (7in OD) Rigged up Circulating head Circulated at 18402.0 ft Pumped 70.000 bbl spacers - volume (null) Mixed and pumped slurry - 60.000 bbl Displaced slurry - 701.000 bbl Rigged down Casing handling equipment Installed Seal assembly Rigged down Top ram Rigged down BOP stack Freeze protect well - 60.000 bbl of Diesel Installed Casing spool Installed All tree valves Tested All tree valves Laid out 5in drill pipe from derrick Serviced Block line Installed Flowline valve MILNE POINT, ALASKA TO: Rossberg 'FROM:. L.M. Hinkel 'Operation -Date:* MPF-~4 . ~Completion E'Line i 1/31197 ,, Well Name:' Main Category: Sub Category:. . objective: Date: 12/2/97 Run-GR/CCL/Gyro on "marked line"for depth control. Perforate the Kupamk ;A" sands, Operations: 10:00 12:00 12:15 12:25 13:35 15:45 15:55_ 20:00 21:30 23:45 23:50 MIRU Schlumberger Wimline Unit # 8345. Pick up 7" lubricator, pack-off head,, and.GFFCCL/Gyro tools, Hold safety and pre-job meeting, Openwell (25 ~ turns). Start RIH with.logging to°Is using a ~narked line".. Make 'station stops" as directed by the Gyro Data service hand. Tools at-3800 ft. Start into maximum wellbore angle (74° - 78°). At 18,325 ft. MD. (not corrected), Start logging up. End log at 9800 ft. (100 ff above the 9 5/8" oasing shoe). Continue out of hole, Finished out of hole, Lay down logging tools. Lay down 7" lubricator. Start to re-head to small line for perforating operations. Request radio silence on the Pad. Pick-up 7' lubricator, BOP, grease head., and Gun #1 (10 ff gun). Open well and start RIH. 2/1197 02:15 03:4o 04:00 04:08 04:08 Gun now at 15,200 ft. Start to have some problems getting deeper. Log short joints at 17,828 ff. and 17,870 fi. Make a (+) 40 ff correction. RIH. Log repeat pass. Made no further correotions. RIH. Log Gun #1 into place with top shot at 18,117 ft. and the bottom shot at 18,127 ft. Fire gun. Log off. Start to POOH. 06:10 06:50 08:25 08:45. 09:30 10:30 14:00 14:35 14:55 16:50 19:30 20:30 22:50 23:30 2/2/97 01:00 03:00 .04:30 05:30 09:20 09:25 09:35 10:00 13:30 Finished CCH. Well on a slight vac, Lay down gun. All shots fired. Pick-up Gun #2 (20 ft gun) and start to RIH. Unable to get passed 4,200 ff. Try several~times. No suCCess. POOH. Lay down gun and change, roller-configuration, Start RIH again;~ ~ Gun stopped at 6,420 ff. Unable to continue deeper again. Order out two 10 ft'guns. POOH. Lay down gun. (No other roller configuration options for the 20 ft .gun due to lubricator length and gun Weight/safety factor of cable 'head). 10 ft guns ardve on location. Pick-up.Gun #2 (10 ft). Open well and start RIH. Gun at 1400 ft. Wireline Unit diesel making funny noise and blowing excessive black smoke. Shut down and have mechanic check out. Not good! Diesel engine has a broken intake valve and a possible hole in the piston, Start engine and limp out of hole. Finished CCH, Secure well. Rig down and prepare to swap out logging units. MIRU Schlumberger Wireline Unit Cf 8317, Pick up grease head, 7" lubricator, BOP, and Gun #2 (with same roller configuration that the first 10 ft gun had). Gun stopping between 11,300 ff and 11,700 ft. Pull back above 4-,000 ff and start again. RIH again. Working gun down hole, Now trying to get gun passed 14,500 ft area. Losing ground, now at 12,100 ft. Decide to try and pump gun down. Call out HB&R. RU HB&R. Puli gun up to 10,000 ft, Unable to drop back down hole. Pull up hole to 9,800 ff. Saw increase in line tension. Stopped and tried to go back down. Unable to come up or go down. Work line.. Bring HB&R on line to attempt to pump gun down hole. Had an "O" ring leak at the top of SWS lubricator. SD pump. (report spill). Continue to work line and attempt to free gun. Discuss options with BP/SWS supervisors. Close BOP rams. Attempt to again pump gun down hole, but ram are not holding (fluid leaking again from bad "O" ring at top of lubricator). SD pump. (no other options left to be able to pump down hole). 14:30 16:00 20:00 2,1:00 Made decision to work line up to maximum safe surface limits to free gun or puli out of cable head. Order out Kinley line cutter. Start to work line. Unable to pull out of cable head. -Discuss "other" line cutting operations with MPU PE group. Cancel -Kinley line cutter. Start to gather up wireline fishing tools and discUss plans to make a "Surface cut". Well. ~emains dead. RU Halliburton picker truck and GS fishing stdng. Hold safety and pre-job meeting. Check well again (dead). Slack off E-line and stack line in hole. Raise SWS lubricator. Clamp off line. Cut line and install fishing neck. Latch GS and hold with Halliburton picker. Remove line clamp and lower fishing neck down to bottom master valve. Close bottom valve on fishing neck. Shear GS and lay down,tool. Close top master and install tree cap. Well secured. . SWS RDMO. Tie in Iog/date SchlUmberger GR/CCL dated 1/31/97 II ,. .... ii 4 TD at 18,307 ft MD (Corrected E-Line) CCL to TS 4.4 ft.. Gun #1 .... ----Interval Measured Depth ...... Top Shot - ' Bottom Shot Gun Dia. Shot Density Orientation Phasing 'I18,117 ff. 11i , 2-7 t. II4 ~/=,..lis'' ' IIRan;:l°m' ils0° 1 : Note: Only the bottom 10 feet of. the Proposed 30 foot interval were shot. SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPF-54 Rig Name: N-4ES AFE: 347026 Accept Date: 03/26/97 Spud Date: - Release Date: 04/06/97 Mar 27 1997 MIRU. RU, level derrick. Raise & safe out equipment & berm same. Test psi on well & well on vacuum. ND tree & NU BOP's. Install 3-1/2" rams & pull BPV. Install test plug & test BOP's. Test waived by John Spaulding with AOGCC. Install wear ring. Strap & MU FTA #1. Pull wear ring. Shoe would not go because of ID gauge. Re-dress shoe to 6- 1/6". RIH with FTA #1 on 3-1/2" DP from shed. Rig accepted 03/26/97 @ 1500 hrs. Mar 28 1997 Cont RIH with FTA #1 & tag wire at 4393' & work to 4564'. Displace diesel cap from well got oil & gas on bottoms up. POOH, no rec. Had good wire marks on shoe OD gauge. MU FTA #2. TIH with FTA #2 to 4599'. TOH with FTA #2. TIH with FTA #2 to 4720'. TOH with FTA #2. Clear FTA #2 of wire pulled 426' from well leaving top of wire at approx 5246'. RIH with FTA #2. Mar 29 1997 Cont RIH with spear to 5828'. POOH with run #3 & remove wire approx. 400' wire. RIH with spear, run #4 to 5986' & rotate 6 turns. POOH with spear, run #4 & rec kinley cutter & 200' wire. RIH with spear run #5 to 6265' & turn 6 turns. TOH with spear run #5 & rec 200' wire. TIH with spear run #6 to 6579' & turn 8 times. TOH with spear run #6 & pulling to 50K over at Jmes rotate free. Mar 30 1997 Cont POOH with spear run #6 & rec 200'. 125 line on spear with line hanging heavy. Wait on HES slickline truck. Rig HES truck & POOH with HES tools & SWS gun. MU BHA #3 & load pipe shed & RIH with same to 18354' & pull to top of perfs. RU & displace well bore with sea water. Page Mar 31 1997 Cont displace well with clean sea water. Monitor well. TOH with 3-1/2" DP stand back. Cut 84' drlg line, slip 42'. TOH with 3-1/2" DP, LD BHA #3, TOH. ND flowline, NU shooting flange, RU e-line lub, test same. RIH with 3-3/8" guns, 6 spf & perf 18097- 18117'. POOH, LD guns. MU high press temp tool, RIH to 18116', perf test, POOH, LD e-line tools. RD Western e-line, ND shooting flange, NU flowline, prep to run 4-1/2" work string. Apr 1 1997 ND perf flange, NU flow nipple, set test plug, ND 3-1/2" rams, NU 4-1/2" rams, PU test it. Test 4-1/2" rams. RD test jt, pill test plug, RU for 4-1/2" work string run. MU mule shoe BHA. RIH with 4-1/2" work string. Load pipe shed with 4-1/2" tubing. TIH with 4- 1/2" tubing to 17184'. RU Dowell for frac. Press test lines to 7000#. Analize frac data. Frac per well plan. 169357# 16/20 total, 164983# 16/20 behind pipe, 4375# 16/20 in csg, ISIP 1750# @ 5:40am. Monitor well pressure. Apr 2 1997 Monitor well, wait for pressure from frac to decrease. Bleed down tbg & annulus f/40# to no flow, rec'd 1 bbl back. Monitor, well static. Rev CBU, gel water returns. Total gel water, small amount of frac sand. Cont circ, monitor well static. POOH, LD work string. Slip drlg line. Cont POOH, LD work string. Apr 3 1997 TOH, LD work string & mule shoe. Clear floor, set test plug, ND 4-1/2" rams, NU 3-1/2" rams. Test 3-1/2" rams. Pull test plug, set wear ring. Strap mule shoe, RIH with 3-1/2" DP, tag sand @ 17798'. TOH, LD 18 its DP, TIH with 6 stds from derrick. Rev circ, add Xanvis to system. Rev circ, wash frac sand to 18144'. Apr 4 1997 Rev wash sand f/18144' to 18315', mixing LCM & washing 30-60 BPH losses. Rev circ, mix pump Xanvis sweep, space out clean sea water to spot across perfs. Monitor well. TOH, LD 3-1/2" DP, taking torque checks. Cut drlg line. Cont TOH, LD 3-1/2" DP. Apr 5 1997 TOH, LD 3-1/2" DP, LD BHA #5. Pull wear ring, set test plug, ND 3-1/2" rams, NU 2- 7/8" rams. Test pipe rams, pull test plug. Load 2-7/8" pipe in shed, SLM drift, RU floor to run ESP. MU ESP, RIH on 2-7/8". Load new spool, MU ESP splice. Page 2_. Apr 6 1997 MU splice reel to reel. Cont RIH with ESP on 2-7/8" tbg. MU reel to reel splice. Cont RIH with ESP to 17903', MU hanger landing jt. MU ESP pigtail splice. LD hanger, RILDS, LD landing jt, set TWC. ND BOP. NU adapter flange & tree. Check ESP, ok. Test hanger adapter flange, tree, pull TWC. RU test hard lines. AOGCC waive 7 day BOP test due to running completion. Apr 7 1997 Freeze protect, bullhead 104 bbls diesel down tbg, 66 bbls annulus. Blow down lines, install BPV, secure well. Rig released 04/06/97 @ 1200 hrs. Page 3 SPEF~--~-SUN DRILLING SERVICES ANC~{ORAGE ALASKA BP EXPLORATION (ALASKA) MILNE POINT / MPF-54 500292272600 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 4/97 DATE OF SURVEY: 011897 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70014 KELLY BUSHING ELEV. = 41.60 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS DIRECTION DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 9844.40 4504.86 4463.26 10070.64 4561.69 4520.09 10165.34 4587.52 4545.92 10260.85 4612.43 4570.83 10356.40 4636.13 4594.53 76 12 74 41 73 39 76 6 75 9 N 16.40 W N 15.03 W N 18.56 W N 17.20 W N 17.48 W .00 7304.23N 2165.72W 7618.46 .89 7514.99N 2225.03W 7837.37 3.75 7602.20N 2251.35W 7928.46 2.91 7689.94N 2279.65W 8020.64 1.03 7778.30N 2307.24W 8113.20 10451.85 4660.85 4619.25 10547.48 4683.56 4641.96 10643.22 4704.18 4662.58 10737.61 4725.57 4683.97 10833.00 4748.16 4706.56 74 49 77 42 77 24 76 24 76 11 N 18.08 W N 17.69 W N 18.15 W N 18.40 W N 19.44 W .70 7866.09N 2335.39W 8205.37 3.05 7954.49N 2363.91W 8298.24 .56 8043.44N 2392.68W 8391.71 1.10 8130.74N 2421.50W 8483.61 1.08 8218.40N 2451.55W 8576.22 10929.00 4770.38 4728.78 11024.76 4791.99 4750.39 11120.59 4814.54 4772.94 11216.21 483J.86 4796.26 11311.90 4861.40 4819.80 77 1 N 18.13 W 76 53 N 18.26 W 75 52 N 18.90 W 75 53 N 18.36 W 75 37 N 17.57 W 1.58 8306.81N 2481.62W 8669.55 .20 8395.44N 2510.75W 8762.81 1.24 8483.72N 2540.42W 8855.90 .55 8571.59N 2570.05W 8948.58 .85 8659.81N 2598.66W 9041.31 11407.43 4884.13 4842.53 11502.90 4906.37 4864.77 11598.44 4929.41 4887.81 11693.93 4951.90 4910.30 11789.30 4973.75 4932.15 76 50 76 13 75 52 76 53 76 37 N 15.74 W N 16.51 W N 17.47 W N 15.03 W N 15.70 W 2.25 8748.69N 2625.24W 9134.08 1.02 8837.88N 2651.02W 9226.91 1.04 8926.55N 2678.12W 9319.63 2.70 9015.64N 2704.08W 9412.42 .74 9105.15N 2728.68W 9505.22 11884.99 4996.11 4954.51 11980.50 5019.13 4977.53 12075.20 5040.23 4998.63 12171.05 5059.71 5018.11 12266.55 5079.80 5038.20 76 20 N 15.93 W 75 45 N 15.29 W 78 29 N 13.93 W 78 3 N 13.60 W 77 40 N 14.15 W .37 9194.67N 2754.03W 9598.25 .90 9283.95N 2778.98W 9690.92 3.20 9373.27N 2802.25W 9783.16 .57 9464.42N 2824.58W 9876.88 .69 9555.06N 2846.97W 9970.12 12361.20 5100.23 5058.63 12456.93 5121.43 5079.83 12552.65 5143.12 5101.52 12648.08 5165.13 5123.52 12743.80 5187.75 5146.15 77 77 76 76 76 24 0 47 33 6 N 14.37 W N 14.80 W N 14.70 W N 15.17 W N 14.60 W .37 9644.63N .60 9734.97N .25 9825.13N .54 9914.85N .74 10004.74N 2869.74W 10062.45 2893.24W 10155.74 2916.98W 10248.91 2940.91W 10341.72 2964.80W 10434.67 12839.50 5211.12 5169.52 12934.78 5234.86 5193.26 13030.46 5259.09 5217.49 13126.22 5284.08 5242.48 13220.74 5308.37 5266.77 75 36 75 32 75 7 74 37 75 34 N 15.65 W N 15.46 W N 15.95 W N 15.99 W N 16.06 W 1.19 10094.32N .21 10183.22N .66 10272.32N .51 10361.19N 1.01 10448.99N 2989.02W 10527.43 3013.76W 10619.68 3038.81W 10712.23 3064.25W 10804.66 3089.46W 10895.99 ORIGINAL SPEP='v-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLOILATION (ALASKA) MILNE POINT / MPF-54 500292272600 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 4/97 DATE OF SURVEY: 011897 MAGNETIC MULTI-SHOT sURVEy JOB NUMBER: AK-EI-70014 KELLY BUSHING ELEV. = 41.60 FT. OPERATOR: BP EXPLORATION TRUE SD~-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. 13316.29 5332.01 5290.41 13411.83 5355.64 5314.04 13507.27 5379.66 5338.06 13602.78 5403.08 5361.48 13698.31 5425.81 5384.21 75 46 75 35 75 14 76 22 76 5 N 16.30 W .31 10537.90N 3115.26W N 16.70 W .44 10626.66N 3141.55W N 17.54 W .93 10714.93N 3168.74W N 15.87 W 2.07 10803.60N 3195.35W N 16.29 W .51 10892.76N 3221.05W 10988.57 11081.14 11173.50 11266.08 11358.86 13793.92 5448.46 5406.85 13889.32 5470.49 5428.89 13984.80 5491.91 5450.31 14080.51 5512.94 5471.34 14174.60 5533.73 5492.13 76 30 76 47 77 16 77 20 77 7 N 14.92 W 1.45 10982.22N 3246.03W N 14.86 W .31 11071.92N 3269.89W N 15.35 W .72 11161.75N 3294.13W N 15.57 W .23 11251.74N 3319.02W N 15.31 W .35 11340.19N 3343.45W 11451.72 11544.49 11637.49 11730.84 11822.58 14270.22 5554.68 5513.08 14365.83 5576.03 5534.43 14461.50 5598.20 5556.60 14557.11 5620.94 5579.34 14652.62 5644.28 5602.68 77 33 76 39 76 33 75 55 75 47 N 15.59 W .52 11430.12N 3368.31W N 14.54 W 1.43 11520.10N 3392.53W N 14.79 W .27 11610.14N 3416.09W N 14.80 W .65 11699.93N 3439.80W N 14.45 W .38 11789.54N 3463.17W 11915.85 12009.00 12102.00 12194.81 12287.36 14748.17 5667.58 5625.98 14843.87 5690.67 5649.07 14939.12 5713.83 5672.23 15034.80 5737.26 5695.66 15130.52 5760.59 5718.99 75 59 76 4 75 46 75 52 75 54 N 14.62 W .28 11879.24N 3486.43W N 14.86 W .27 11969.06N 3510.06W N 15.46 W .69 12058.23N 3534.22W N 15.59 W .17 12147.61N 3559.05W N 15.34 W .25 12237.09N 3583.80W 12379.95 12472.76 12565.12 12657.86 12750.67 15226.16 5783.66 5742.06 15321.64 5806.80 5765.20 15417.38 5831.46 5789.86 15512.90 5857.43 5815.83 15608.30 5883.25 5841.65 76 10 75 46 74 21 74 5 74 30 N 15.71 W .46 12326.52N 3608.64W N 16.30 W .73 12415.56N 3634.18W N 15.35 W 1.77 12504.55N 3659.41W N 15.90 W .62 12593.07N 3684.17W N 15.64 W .51 12681.46N 3709.13W 12843.46 12936.09 13028.57 13120.47 13212.30 15703.90 5909.10 5867.50 15799.55 5935.47 5893.87 15895.09 5961.77 5920.17 15990.67 5988.07 5946.47 '16085.82 6014.39 5972.79 74 6 73 52 74 9 73 54 73 59 N 16.26 W .76 12769.95N 3734.42W N 16.47 W .32 12858.16N 3760.33W N 16.41 W .30 12946.26N 3786.33W N 16.99 W .64 13034.27N 3812.73W N 17.37 W .40 13121.63N 3839.73W 13304.33 13396.26 13488.11 13580.00 13671.44 16181.67 6042.18 6000.58 16276.55 6072.54 6030.94 16372.26 6106.32 6064.72 16468.03 6143.73 6102.13 16563.58 6183.92 6142.32 72 17 70 22 68 16 65 43 64 31 N 17.43 W 1.77 13209.15N 3867.16W N 17.30 W 2.02 13294.93N 3893.98W N 17.67 W 2.22 13380.33N 3920.88W N 17.71 W 2.67 13464.30N 3947.67W N 17.51 W 1.26 13546.92N 3973.89W 13763.15 13853.02 13942.55 14030.68 14117.35 SPER .SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) MILNE POINT / MPF-54 500292272600 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 4/97 DATE OF SURVEY: 011897 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70014 KELLY BUSHING ELEV, = 41,60 OPERATOR: BP EXPLORATION FT, TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT, SECT, 16657,72 6225,99 6184,39 62 22 N 17,05 W 2,34 13627,32N 16753,37 6272.39 6230,79 59 35 N 18,03 W 3,04 13707,06N 16848,82 6322,67 6281,07 56 49 N 18,12 W 2,89 13784,18N 16943,50 6376,56 6334,96 53 46 N 17,98 W 3,22 13858,19N 17039,08 6434,92 6393,32 50 56 N 17,24 W 3,03 13930,31N 17134,72 6496,83 6455,23 48 22 N 16,19 W 2,81 14000,12N 17230,27 6562,11 6520,51 45 26 N 15,92 W 3,07 14067,16N 17324,78 6630,61 6589,01 41 37 N 15,10 W 4,08 14129,87N 17420,56 6703,96 6662,36 38 23 N 16,11 W 3,45 14189,17N 17515,32 6779.91 6738,31 35 2 N 17,18 W 3,59 14243,45N 3998,90W 14201,54 4024,09W 14285,17 4049,26W 14366,27 4073,38W 14444,08 4096,29W 14519,75 4117,27W 14592,64 4136,56W 14662,40 4153,98W 14727,47 4170,52W 14789,03 4186,73W 14845,67 17610,27 6858,77 6817,17 32 35 N 17,27 W 2,59 14293,92N 17706,32 6939,80 6898,20 32 22 N 17,40 W ,24 14343,16N 17736,00 6964,86 6923,26 32 24 N 17,04 W ,67 14358,34N 17802,00 7020,71 6979,11 32 0 N 16,78 W ,64 14391,99N 17898,12 7102,14 7060,54 32 12 N 16,36 W ,31 14440,95N 4202,38W 14898,51 4217,75W 14950,08 4222,45W 14965,98 4232,68W 15001,15 4247,25W 15052,23 17993,48 7182,83 7141,23 32 11 N 16,18 W ,10 14489,72N 18087,48 7262,21 7220,61 32 34 N 16,02 W ,42 14538,09N 18117,00 7287,09 7245,49 32 35 N 16,49 W ,86 14553,36N 18182,78 7342,66 7301,06 32 5 N 15,51 W 1,11 14587,18N 18278,36 7423,81 7382,21 31 41 N 15,43 W ,42 14635,85N 4261,48W 15103,03 4275,44W 15153,38 4279,89W 15169,27 4289,59W 15204,46 4303,06W 15254,94 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD, HORIZONTAL DISPLACEMENT = 15255,31 FEET AT NORTH 16 DEG, 23 MIN, WEST AT MD = 18278 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 343,22 DEG, TIE-IN SURVEY AT 9844,40' MD LAST SURVEY AT 18278,36' MD SPE}- .... -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) MILNE POINT / MPF-54 500292272600 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 4/97 DATE OF SURVEY: 011897 JOB NUMBER: AK-EI-70014 KELLY BUSHING ELEV. = 41.60 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 9844.40 4504.86 4463.26 7304.23 N 2165.72 W 5339.54 10844.40 4750.88 4709.28 8228.84 N 2455.24 W 6093.52 11844.40 4986.53 4944.93 9156.74 N 2743.21 W 6857.87 12844.40 5212.34 5170.74 10098.89 N 2990.30 W 7632.06 13844.40 5460.23 5418.63 11029.65 N 3258.67 W 8384.17 753.98 764.34 774.19 752.12 14844.40 5690.80 5649.20 11969.55 N 3510.19 W 9153.60 15844.40 5947.92 5906.32 12899.48 N 3772.55 W 9896.48 16844.40 6320.26 6278.66 13780.66 N 4048.11 W 10524.14 17844.40 7056.67 7015.07' 14413.50 N 4239.17 W 10787.73 18278.36 7423.81 7382.21 14635.85 N 4303.06 W 10854.55 769.43 742.87 627.67 263.59 66.82 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPEt~-~-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) MILNE POINT / MPF-54 500292272600 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 4/97 DATE OF SURVEY: 011897 JOB NUMBER: AK-EI-70014 KELLY BUSHING ELEV. = 41.60 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 9844.40 4504.86 4463.26 7304.23 N 2165.72 W 5339.54 9994.55 4541.60 4500.00 7444.11 N 2206.00 W 5452.95 113.41 10377.74 4641.60 4600.00 7797.98 N 2313.44 W 5736.14 283.20 10805.51 4741.60 4700.00 8193.23 N 2442.66 W 6063.91 327.76 11231.54 4841.60 4800.00 8585.70 N 2574.73 W 6389.94 326.03 11649.36 4941.60 4900.00 8973.88 N 2692.40 W 6707.76 317.82 12082.09 5041.60 5000.00 9379.83 N 2803.88 W 7040.49 332.73 12545.99 5141.60 5100.00 9818.86 N 2915.33 W 7404.39 363.89 12961.77 5241.60 5200.00 10208.41 N 3020.73 W 7720.17 315.79 13355.29 5341.60 5300.00 10574.18 N 3125.87 W 8013.69 293.52 13764.55 5441.60 5400.00 10954.63 N 3238.68 W 8322.96 309.27 14209.96 5541.60 5500.00 11373.45 N 3352.56 W 8668.36 345.41 14641.72 5641.60 5600.00 11779.31 N 3460.54 W 9000.12 331.76 15052.58 5741.60 5700.00 12164.22 N 3563.68 W 9310.98 310.87 15454.97 5841.60 5800.00 12539.46 N 3669.00 W 9613.37 302.39 15821.62 5941.60 5900.00 12878.50 N 3766.34 W 9880.02 266.65 16179.75 6041.60 6000.00 13207.41 N 3866.61 W 10138.15 258.13 16462.84 6141.60 6100.00 13459.80 N 3946.23 W 10321.24 183.09 16690.80 6241.60 6200.00 13655.18 N 4007.54 W 10449.20 127.96 16882.91 6341.60 6300.00 13811.13 N 4058.07 W 10541.31 92.11 17049.63 6441.60 6400.00 13938.11 N 4098.69 W 10608.03 66.71 17200.79 6541.60 6500.00 14046.80 N 4130.74 W 10659.19 51.17 17339.41 6641.60 6600.00 14139.19 N 4156.51 W 10697.81 38.62 17468.02 6741.60 6700.00 14216.91 N 4178.67 W 10726.42 28.62 17589.89 6841.60 6800.00 14.283.43 N 4199.12 W 10748.29 21.86 17708.45 6941.60 6900.00 14344.25 N 4218.09 W 10766.85 18.56 17826.63 7041.60 7000.00 14404.49 N 4236.45 W 10785.03 18.18 17944.76 7141.60 7100.00 14464.79 N 4254.25 W 10803.16 18.13 18063.02 7241.60 7200.00 14525.43 N 4271.81 W 10821.42 18.26 18181.53 7341.60 7300.00 14586.54 N 4289.42 W 10839.93 18.51 18278.36 7423.81 7382.21 14635.85 N 4303.06 W 10854.55 14.62 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS TIE-IN SURVEY AT 9844.40' MD LAST SURVEY DEPTH AT 18278.36' MD Schlumberger ANADRILL Survey Report Client: BP Exploration Field: Milne Point Well Name: MPF-54 API No: 50-029-22726-00 Job No: 39095 Depth measured from KB Elevation of kelly bushing Elevation of drill floor Elevation of ground level Magnetic Declination Grid Convergence Total Correction TIE IN POINT Measured depth True vertical depth N/S disp (-ye for S) E/W disp (-ye for W) 0.00 FT 0.00 FT 0.00 FT 0.00 FT MEASURED INTERVAL VERTICAL DEPTH DEPTH FT FT FT 0.0 0.00 0.00 112.0 112.00 112.00 207.9 95.90 207.90 232.4 24.50 232.40 323.0 90.60 323.00 415.1 92.10 415.08 505.7 90.60 505.64 594.8 89.10 594.66 682.1 87.30 681.71 777.4 95.30 776.39 868.1 90.70 866.23 957.6 89.50 954.58 1025.8 68.20 1021.60 1112.1 86.30 1106.00 1208.3 96.20 1199.53 1303.7 95.40 1291.73 1399.0 95.30 1382.99 1494.8 95.80 1473.72 1588.9 94.10 1562.29 1685.4 96.50 1652.79 1781.1 95.70 1741.87 18-JAN-97 MWD Survey Survey Date: Computation Date: 41.60 FT 41.60 FT 12.10 FT 28.13 DEG 0.0 DEG 28.13 DEG 18-Jan-97 18-Jan-97 Inclination 0.00 DEG Azimuth 0.00 DEG Azimuth from rotary table to the target 343.22 DEG Minimum Curvature Method TARGET SECTION FT 0.00 STATION INCLN. DEG 0.00 AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS N/-S E/-W CEMENT DEG FT FT FT DEG D/HF 0.0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.0 0.00 0.00 0.00 0.00 0.00 -0.19 0.23 158.9 -0.18 0.07 0.19 158.90 0.24 -0.30 0.26 171.9 -0.28 0.09 0.30 161.32 0.26 0.04 0.68 342.1 0.03 -0.04 0.05 303.66 1.03 1.71 1.40 340.9 1.61 -0.58 1.71 340.27 0.78 4.32 8.08 14.58 25.42 37.82 52.12 64.74 82.67 105.09 129.53 1.90 2.96 5.62 7.47 8.24 10.16 11.19 12.89 14.17 15.57 17.90 19.54 19.92 20.71 22.15 22.68 25.35 28.57 31.62 34.34 156.97 187.71 219.48 252.96 287.89 346.0 4.11 -1.30 4.32 342.42 0.57 348.6 7.80 -2.12 8.08 344.83 1.20 348.3 14.20 -3.43 14.61 346.43 3.05 345.1 24.76 -5.97 25.46 346.45 1.98 342.6 36.66 -9.43 37.85 345.58 0.93 343.8 50.36 -13.55 52.15 344.94 2.16 347.8 62.60 -16.62 64.77 345.13 1.86 348.6 80.22 -20.30 82.75 345.80 1.98 347.8 102.25 -24.91 105.24 346.31 1.34 344.3 125.99 -30.84 129.71 346.25 1.74 343.0 152.32 -38.58 157.13 345.79 2.48 342.4 181.67 -47.73 187.83 345.28 1.72 342.8 211.98 -57.23 219.57 344.89 0.43 340.1 243.73 -67.90 253.01 344.43 1.27 342.0 276.80 -79.24 287.92 344.03 1.67 340.7 311.27 -90.87 324.26 343.73 0.76 341.2 348.00 -103.55 363.08 343.43 2.80 341.7 388.88 -117.25 406.17 343.22 3.39 343.1 434.76 -131.78 454.29 343.14 3.26 343.0 484.17 -146.84 505.95 343.13 2.87 37.71 41.92 44.71 47.13 50.14 345.0 538.10 -162.26 562.03 343.22 3.74 345.1 598.34 -178.35 624.36 343.40 4.32 345.3 660.82 -194.85 688.94 343.57 2.97 345.2 725.97 -212.01 756.30 343.72 2.58 344.7 796.19 -230.89 829.00 343.83 3.13 Page 1 1876.5 95.40 1830.07 324.25 1972.0 95.50 1917.29 363.08 2067.1 95.10 2002.05 406.17 2163.1 96.00 2085.10 454.29 2258.0 94.90 2164.70 505.95 2353.4 95.40 2241.84 562.03 2450.8 97.40 2316.64 624.35 2545.0 94.20 2385.17 688.93 2638.8 93.80 2450.42 756.27 2735.7 96.90 2514.45 828.95 ORIGINAL [] Schlumberger ANADRILL Survey Report 18-JAN-97 Page 002 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 2832.1 96.40 2574.38 904.42 52.98 345.0 869.07 -250.62 904.48 343.91 2.96 2925.5 93.40 2629.17 980.01 55.17 344.9 942.10 -270.26 980.10 343.99 2.35 3021.6 96.10 2682.56 1059.84 57.34 346.4 1019.51 -290.05 1059.97 344.12 2.60 3117.0 95.40 2732.89 1140.78 58.97 345.7 1098.16 -309.59 1140.96 344.26 1.82 3212.1 95.10 2780.34 1223.14 61.17 344.9 1177.87 -330.51 1223.36 344.33 2.43 3308.7 96.60 2825.13 1308.69 63.57 344.3 1260.37 -353.24 1308.94 344.34 2.54 3403.8 95.10 2866.06 1394.52 65.45 343.6 1342.87 -376.98 1394.78 344.32 2.09 3500.9 97.10 2904.61 1483.63 67.77 341.8 1427.94 -403.49 1483.85 344.22 2.93 3595.6 94.70 2938.55 1572.01 70.22 342.2 1512.02 -430.80 1572.19 344.10 2.62 3690.4 94.80 2969.01 1661.71 72.29 340.3 1597.01 -459.66 1661.85 343.94 2.89 3784.1 93.70 2996.02 1751.33 74.21 340.7 1681.58 -489.61 1751.41 343.77 2.09 3881.6 97.50 3021.36 1845.40 75.66 341.1 1770.55 -520.42 1845.45 343.62 1.54 3977.8 96.20 3045.70 1938.39 75.03 340.5 1858.44 -551.02 1938.41 343.49 0.89 4071.8 94.00 3069.18 2029.29 76.03 340.3 1944.18 -581.55 2029.30 343.35 1.08 4167.7 95.90 3092.18 2122.24 76.22 339.5 2031.61 -613.55 2122.24 343.20 0.83 4262.6 94.90 3113.90 2214.53 77.33 342.0 2118.83 -644.00 2214.53 343.09 2.82 4357.0 94.40 3134.64 2306.61 77.28 344.2 2206.93 -670.77 2306.62 343.09 2.27 4452.8 95.80 3156.20 2399.95 76.71 343.4 2296.57 -696.81 2399.95 343.12 1.01 4549.2 96.40 3179.23 2493.55 75.65 344.5 2386.53 -722.69 2493.55 343.15 1.56 4640.3 91.10 3202.14 2581.64 75.22 346.7 2471.92 -744.62 2581.64 343.24 2.38 4741.2 100.90 3227.43 2679.12 75.75 347.1 2567.06 -766.76 2679.13 343.37 0.65 4833.8 92.60 3249.71 2768.84 76.41 346.1 2654.49 -787.59 2768.87 343.47 1.27 4929.4 95.60 3272.19 2861.64 76.39 346.1 2744.69 -809.91 2861.69 343.56 0.02 5023.9 94.50 3294.87 2953.26 75.83 346.1 2833.74 -831.95 2953.34 343.64 0.59 5120.2 96.30 3318.78 3046.47 75.42 345.0 2924.07 -855.23 3046.57 343.70 1.19 5214.3 94.10 3341.86 3137.64 76.19 345.2 3012.23 -878.68 3137.77 343.74 0.84 5311.4 97.10 3365.05 3231.91 76.17 343.7 3103.07 -903.96 3232.05 343.76 1.50 5407.9 96.50 3388.75 3325.45 75.40 343,3 3192.76 -930.53 3325.60 343.75 0.89 5502.8 94.90 3413.30 3417.11 74.62 341.6 3280.16 -958.16 3417.24 343.72 1.92 5599.4 96.60 3439.19 3510.15 74.29 341.9 3368.54 -987.31 3510.25 343.66 0.45 5694.5 95.10 3464.67 3601.72 74.62 341.1 3455.43 -1016.38 3601.81 343.61 0.88 5790.4 95.90 3489.30 3694.35 75.62 341.4 3543.19 -1046.17 3694.41 343.55 1.09 5886.2 95.80 3512.74 3787.21 76.05 342.0 3631.38 -1075.34 3787.25 343.50 0.76 5983.6 97.40 3536.48 3881.65 75.74 342.0 3721.22 -1104.53 3881.68 343.47 0.32 6076.7 93.10 3559.39 3971.86 75.77 341.7 3806.97 -1132.64 3971.89 343.43 0.31 6172.5 95.80 3582.41 4064.82 76.42 341.6 3895.23 -1161.91 4064.84 343.39 0.69 ~6267.2 94.70 3605.00 4156.76 75.98 342.2 3982.65 -1190.49 4156.77 343.36 0.77 6363.4 96.20 3627.87 4250.19 76.51 342.3 4071.64 -1218.97 4250.19 343.33 0.56 6459.1 95.70 3650.85 4343.08 75.71 343.4 4160.41 -1246.37 4343.09 343.32 1.39 6555.7 96.60 3674.35 4436.78 76.13 342.9 4250.08 -1273.53 4436.79 343.32 0.66 6650.0 94.30 3697.50 4528.19 75.45 343.6 4337.62 -1299.87 4528.20 343.32 1.02 6743.5 93.50 3721.08 4618.67 75.33 343.1 4424.30 -1325.80 4618.68 343.32 0.53 6840.9 97.40 3745.60 4712.93 75.51 342.9 4514.45 -1353.36 4712.94 343.31 0.27 6936.8 95.90 3769.09 4805.91 76.13 342.8 4603.29 -1380.77 4805.91 343.30 0.65 7029.1 92.30 3792.21 4895.26 74.86 343.4 4688.79 -1406.75 4895.27 343.30 1.51 Page 2 [] Schlumberger ANADRILL Survey Report 18-JAN-97 Page 003 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 7126.2 97.10 3817.81 4988.93 74.56 342.8 4778.40 -1433.98 4988.93 343.30 0.67 7219.4 93.20 3842.49 5078.80 74.74 344.0 4864.53 -1459.65 5078.80 343.30 1.26 7314.7 95.30 3867.47 5170.76 74.86 343.8 4952.89 -1485.16 5170.77 343.31 0.24 7412.2 97.50 3892.58 5264.96 75.30 344.2 5043.45 -1511.13 5264.97 343.32 0.60 7507.4 95.20 3916.71 5357.04 75.33 343.9 5132.00 -1536.43 5357.05 343.33 0.31 7603.9 96.50 3941.48 5450.29 74.92 344.6 5221.76 -1561.75 5450.31 343.35 0.82 7699.1 95.20 3965.38 5542.42 76.00 344.2 5310.52 -1586.53 5542.44 343.37 1.21 7794.7 95.60 3988.79 5635.09 75.66 344.9 5399.86 -1611.22 5635.11 343.39 0.79 7889.9 95.20 4012.37 5727.30 75.66 344.0 5488.71 -1635.95 5727.33 343.40 0.92 7984.0 94.10 4035.40 5818.52 76.00 344.4 5576.50 -1660.79 5818.56 343.42 0.55 8079.9 95.90 4058.10 5911.68 76.62 344.3 5666.22 -1685.93 5911.72 343.43 0.65 8177.5 97.60 4082.04 6006.28 74.98 343.9 5757.22 -1711.85 6006.33 343.44 1.73 8271.2 93.70 4106.70 6096.67 74.50 344.0 5844.09 -1736.84 6096.72 343.45 0.52 8367.3 96.10 4132.93 6189.12 73.82 343.7 5932.89 -1762.55 6189.17 343.45 0.77 8462.1 94.80 4158.71 6280.34 74.62 343.5 6020.41 -1788.31 6280.39 343.46 0.87 8559.2 97.10 4182.82 6374.40 76.63 343.5 6110.59 -1815.02 6374.45 343.46 2.07 8653.8 94.60 4204.84 6466.40 76.45 343.7 6198.85 -1841.00 6466.45 343.46 0.28 8748.5 94.70 4227.47 6558.34 75.89 344.2 6287.22 -1866.42 6558.40 343.47 0.78 8844.6 96.10 4251.41 6651.39 75.27 344.5 6376.84 -1891.53 6651.46 343.48 0.71 8940.7 96.10 4276.43 6744.17 74.54 343.9 6466.12 -1916.79 6744.24 343.49 0.97 9034.8 94.10 4301.19 6834.94 74.95 343.6 6553.27 -1942.20 6835.02 343.49 0.53 9130.5 95.70 4326.43 6927.26 74.47 343.0 6641.69 -1968.72 6927.33 343.49 0.79 9226.9 96.40 4351.78 7020.26 75.04 342.5 6730.52 -1996.30 7020.33 343.48 0.77 9321.1 94.20 4375.39 7111.45 75.92 343.6 6817.74 -2022.89 7111.52 343.47 1.47 9416.3 95.20 4399.22 7203.62 75.09 343.5 6906.14 -2048.99 7203.69 343.47 0.88 9512.6 96.30 4423.18 7296.89 76.10 343.4 6995.55 -2075.56 7296.96 343.47 1.05 9609.8 97.20 4446.97 7391.13 75.56 343.7 7085.93 -2102.24 7391.20 343.48 0.63 9710.1 100.30 4472.33 7488.16 75.15 344.3 7179.21 -2128.99 7488.24 343.48 0.71 9797.8 87.70 4493.85 7573.17 76.45 343.2 7260.83 -2152.78 7573.25 343.49 1.92 9844.4 46.60 4504.86 7618.45 76.21 343.6 7304.23 -2165.72 7618.53 343.48 0.98 10010.2 165.80 4545.94 7779.07 75.10 343.8 7458.40 -2210.80 7779.16 343.49 0.68 10104.2 94.00 4570.86 7869.71 74.15 343.0 7545.25 -2236.70 7869,79 343.49 1.30 10196.3 92.10 4595.76 7958.37 74.48 342.4 7629.91 -2263.06 7958.46 343.48 0.72 10294.8 98.50 4621.21 8053.51 75.57 341.7 7720.43 -2292.39 8053.58 343.46 1.30 10394.4 99.60 4646.60 8149.76 74.89 340.9 7811.66 -2323.27 8149.82 343.44 1.03 10485.0 90.60 4669.61 8237.32 75.69 341.1 7894.51 -2351.80 8237.37 343.41 0.91 10582.0 97.00 4692.14 8331.60 77.45 341.1 7983.77 -2382.35 8331.64 343.38 1.81 10679.0 97.00 4713.59 8426.11 77.00 340.4 8073.08 -2413.54 8426.14 343.36 0.84 10771.9 92.90 4735.15 8516.35 76.16 340.1 8158.13 -2444.08 8516.37 343.32 0.96 10866.9 95.00 4757.75 8608.50 76.31 340.4 8244.97 -2475.26 8608.51 343.29 0.34 10962.9 96.00 4779.91 8701.81 77.00 340.8 8333.07 -2506.28 8701.81 343.26 0.83 11059.1 96.20 4801.93 8795.37 76.54 340.6 8421.46 -2537.23 8795.37 343.23 0.52 11154.1 95.00 4824.42 8887.60 76.07 341.7 8508.80 -2567.06 8887.60 343.21 1.23 11249.9 95.80 4847.41 8980.57 76.16 341.8 8597.13 -2596.18 8980.58 343.20 0.14 11346.3 96.40 4870.49 9074.15 76.13 342.1 8686.11 -2625.18 9074.15 343.18 0.30 Page 3 [] Schlumberger ANADRILL Survey Report 18-JAN-97 Page 004 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET DEPTH DEPTH SECT I ON FT FT FT FT 11441.3 95.00 4892.86 9166.47 11537.1 95.80 4915.42 9259.57 11632.0 94,90 4938.15 9351.70 11728 . 9 96.90 4960.75 9445 . 93 11825.4 96.50 4982.90 9539.85 S TAT I ON INCLN. DEG 76.63 76.13 76.16 76.86 76.60 AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS N/-S E/-W CEMENT DEG FT FT FT DEG D/HF 343.4 8774.29 -2652.56 9166.47 343.18 1.43 342.4 8863.28 -2679.93 9259.57 343.18 1.14 342.7 8951.17 -2707.56 9351.71 343.17 0.31 343.7 9041.38 -2734.80 9445.93 343.17 1.24 343.4 9131.46 -2761.39 9539.85 343.17 0.41 11919.5 94.10 5005.11 9631.29 12014.4 94.90 5027.60 9723.49 12112.4 98.00 5048.96 9819.10 12206.6 94.20 5068.41 9911.19 12302.7 96.10 5089.05 10004.97 76.10 76.48 78.35 77.82 77.37 343.1 9219.02 -2787.75 9631.29 343.18 0.62 343.5 9307.33 -2814.24 9723.49 343.18 0.57 345.6 9399.51 -2839.71 9819.10 343.19 2.83 345.6 9488.78 -2862.63 9911.19 343.21 0.56 345.3 9579.63 -2886.21 10004.97 343.23 0.56 12395.3 92.60 5109.37 10095.27 12491.5 96.20 5130.87 10189.00 12587.2 95.70 5152.72 10282.14 12683.2 96.00 5175.04 10375.50 12780.2 97.00 5198.25 10469.67 77.28 76.89 76.71 76.40 75.92 344.8 9666.91 -2909.52 10095.27 343.25 0.54 344.8 9757.40 -2934.10 10189.00 343.26 0.41 344.4 9847.23 -2958.84 10282.15 343.28 0.45 344.3 9937.13 -2984.03 10375.50 343.29 0.34 343.7 10027.67 -3009.99 10469.68 343.29 0.78 12873.5 93.30 12968.9 95.40 13063.4 94.50 13160.4 97.00 13256.1 95.70 5221.26 10560.08 5245.26 10652.42 5269.50 10743.76 5294.45 10837.49 5318.57 10930.10 75.52 75.34 74.94 75.25 75.55 343.6 10114.43 -3035 343.4 10202.96 -3061 343.2 10290.45 -3087 343.3 10380.21 -3114 343.3 10468.91 -3141 .44 10560.09 343.30 0.44 .67 10652.43 343.30 0.28 .91 10743.77 343.30 0.47 .93 10837.50 343.30 0.33 .54 10930.11 343.30 0.31 13350.3 94.20 13446.3 96.00 13542.2 95.90 13636.3 94.10 13731.8 95.50 5341.96 11021.35 5365.85 11114.32 5389.73 11207.19 5412.49 11298.49 5435.28 11391.24 75.69 75.50 75.66 76.34 76.05 342.7 10556.17 -3168 342.2 10644.82 -3196 342.8 10733.40 -3224 342.8 10820.62 -3251 343.4 10909.36 -3278 .22 11021.36 343.29 0.63 .26 11114.33 343.29 0.54 .19 11207.20 343.28 0.63 .18 11298.50 343.28 0.72 .14 11391.24 343.28 0.68 13828.4 96.60 13925.6 97.20 14020.9 95.30 14115.5 94.60 14211.3 95.80 5458.27 11485.06 5480.73 11579.61 5502.03 11672.50 5522.95 11764.75 5544.36 11858.12 76.42 76.86 77.31 77.13 77.05 344.2 10999.46 -3304 344.0 11090.41 -3330 343.7 11179.63 -3356 344.0 11268.25 -3381 343.4 11357.87 -3407 .32 11485.06 343.28 0.89 .23 11579.62 343.29 0.49 .07 11672.50 343.29 0.56 .73 11764.76 343.29 0.36 .94 11858.13 343.30 0.62 14306.1 94.80 14400.1 94.00 14496.4 96.30 14591.6 95.20 14687.3 95.70 5565.68 11950.48 5587.11 12041.98 5609.63 12135.58 5632.58 12227.94 5655.91 12320.74 76.95 76.70 76.25 75.85 75.93 344.4 11446.62 -3433.55 11950.50 344.8 11534.86 -3457.86 12042.00 344.8 11625.21 -3482.41 12135.60 344.4 11714.29 -3506.94 12227.96 344.1 11803.61 -3532.13 12320.77 343.30 1.03 343.31 0.49 343.32 0.47 343.33 0.59 343.34 0.32 14779.0 91.70 14873.9 94.90 14969.1 95.20 15065.7 96.60 15162.0 96.30 5678.13 12409.69 5701.14 12501.75 5724.46 12594.04 5748.20 12687.68 5771.77 12781.04 76.02 75.92 75.72 75.83 75.83 344.3 11889.22 -3556.36 12409.72 344.1 11977.81 -3581.43 12501.78 343.7 12066.49 -3607.02 12594.08 343.6 12156.34 -3633.38 12687.71 343.6 12245.91 -3659.74 12781.08 343.35 0.23 343.35 0.23 343.36 0.46 343.36 0.15 343.36 0.00 15258.9 96.90 15354.5 95.60 15450.7 96.20 15545.6 94.90 15642.4 96.80 5795.29 12875.05 5819.24 12967.59 5844.88 13060.31 5870.84 13151.59 5897.22 13244.72 76.08 74.90 74.18 74.07 74.30 343.5 12336.07 -3686.36 12875.09 343.7 12424.85 -3712.49 12967.63 343.5 12513.80 -3738.67 13060.35 343.3 12601.27 -3764.75 13151.63 343.5 12690.53 -3791.36 13244.77 343.36 0.28 343.36 1.25 343.37 0.77 343.37 0.23 343.37 0.31 Page 4 [] Schlumberger ANADRILL Survey Report 18-JAN-97 Page 005 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET DEPTH DEPTH SECTION FT FT FT FT 15737.1 94.70 5923.02 13335.84 15833.8 96.70 5949.70 13428.79 15929.7 95.90 5976.10 13520.98 16026.9 97.20 6002.83 13614.42 16120.2 93.30 6029.43 13703.84 STATION INCLN. DEG 74.09 73.87 74.17 73.91 72.96 AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS N/-S E/-W CEMENT DEG FT FT FT DEG D/HF 343.2 12777.83 -3817.46 13335.89 343.37 0.38 342.7 12866.69 -3844.72 13428.83 343.36 0.55 342.7 12954.71 -3872.13 13521.02 343.36 0.31 342.3 13043.84 -3900.23 13614.46 343.35 0.48 342.5 13129.08 -3927.27 13703.87 343.35 1.04 16215.9 95.70 6058.72 13794.94 16308.6 92.70 6089.60 13882.32 16404.8 96.20 6124.76 13971.85 16501.2 96.40 6163.44 14060.12 16597.1 95.90 6204.70 14146.68 71.40 69.68 67.44 65.24 63.80 342.3 13215.92 -3954.82 13794.97 343.34 1.64 342.1 13299.14 -3981.54 13882.35 343.33 1.87 342,2 13384.36 -4008.99 13971.87 343.33 2.33 342.2 13468.43 -4035.97 14060.14 343.32 2.28 342.4 13550.90 -4062.30 14146.70 343.31 1.51 16691.8 94.70 6248.06 14230.86 16787.0 95.20 6295.21 14313.53 16882.5 95.50 6346.67 14393.93 16978.3 95.80 6402.35 14471.84 17075.7 97.40 6462.65 14548.31 61.70 58.92 55.86 53.05 50.45 342.4 13631.14 -4087 341.6 13709.79 -4113 341.4 13786.07 -4138 341.8 13860.03 -4163 342.9 13932.90 -4186 .75 14230.88 343.31 2.22 .30 14313.55 343.30 3.01 .82 14393.94 343.29 3.21 .42 14471.85 343.28 2.95 .63 14548.32 343.28 2.81 17167.3 91.60 6522.62 14617.54 17264.3 97.00 6589.67 14687.62 17359.3 95.00 6659.30 14752.20 17455.3 96.00 6733.59 14812.98 17549.0 93.70 6809.46 14867.94 47.74 44.80 40.91 37.67 34.17 343.4 13999.15 -4206.70 14617.54 344.4 14066.48 -4226.15 14687.62 344.6 14128.73 -4243.42 14752.21 342.9 14187.09 -4260.39 14812.99 343.0 14239.64 -4276.51 14867.95 343.27 2.99 343.28 3.12 343.28 4.10 343.29 3.56 343.28 3.74 17645.0 96.00 6889.65 14920.70 17741.3 96.30 6970.92 14972.35 17835.6 94.30 7050.75 15022.55 17933.1 97.50 7133.38 15074.30 18027.1 94.00 7212.92 15124.39 32.52 32.37 31.96 32.16 32.24 342.1 14289.98 -4292 342.2 14339.14 -4308 343.1 14387.04 -4323 343.6 14436.63 -4338 343.4 14484.65 -4352 .32 14920.71 .20 14972.36 .22 15022.56 .05 15074.31 .27 15124.40 343.28 1.79 343.28 0.16 343.27 0.71 343.28 0.34 343.28 0.14 18122.4 95.30 7293.34 15175.53 18217.8 95.40 7373.92 15226.59 18312.8 95.00 7454.55 15276.80 18340.1 27.30 7477.75 15291.19 32.67 32.06 31.78 31.89 343.7 14533.70 -4366.75 15175.54 343.28 0.48 344.7 14582.84 -4380.66 15226.60 343.28 0.85 345.0 14631.32 -4393.79 15276.81 343.29 0.34 345.2 14645.24 -4397.49 15291.21 343.29 0.56 Projection To "TD" 18430.4 90.30 7554.42 15338.87 31.89 345.2 14691.36 -4409.68 15338.88 343.29 0.00 Page 5 ~.~. ~x~=o~,,o, F PAD, WELL NO: MPF-54 MILNE POINT FIELD, ALASKA Gyro Multishot Survey Inside Drillpipe Survey date' 30- JAN, 1997 Job number :A0197GCE380 ORIGINAL CONTENTS JOB NUMBER :A0197GCE380 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 · A0197GCE380 Tool 749 was run in WELL# MPF-54 on SCHLUMBERGER 15/32" Wireline inside 7" casin! survey was run without problems. SURVEY CERTIFICATION SHEET JOB NUMBER: A0197GCE380 The data for this survey and the calculations for this survey were obtained and perforrr according to standards and procedures as set forth by Gyrodata Limited, true and correct to my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the star procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtai~ wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: A01975CE380 CLIENT: B.P. EXPLORATION RIG: SCHLUMBERGER LOCATION: F PAD, MILNE POINT FIELD, ALASKA WELL: MPF-54 LATITUDE: 70.505 N LONGITUDE: 149.2 W SURVEY DATE: SURVEY TYPE : 31,JAN 1997 GYRO MULTISHOT IN 7" CASING DEPTH REFERENCE: ROTARY TABLE ELEVATION 41.6' MAX. SURVEY DEPTH: 18273' SURVEY TIED ONTO: NA SURVEYINTERVAL: 0-18273' APl NUMBER: 050-029- 22726 TARGET DIRECTION: 343.22 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. OUTRUN SURVEY LISTING A Gyr od'a t a D i re c t i ona i Survey for B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: A0197GCE380 Run'Date: 31-Jan-97 12:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 41.6 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 343.220 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: A0197GCE380 A Gy r o d a t a Direct i o n a 1 Survey Page MEASURED 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. HORIZONTAL C O O R D I N A T E.S feet 0.0 0.00 0.00 0.0 100.0 .09 129.13 100.0 200.0 .19 207.06 200.0 299.0 .08 253.57 299.0 400.0 1.30 338.33 400.0 500.0 1.83 341.89 500.0 600.0 2.78 346.67 599.9 700.0 5.69 348.26 699.6 800.0 7.31 344.17 798.9 900.0 8.40 343.02 898.0 0.0 0.00 0.0 0.0 -.1 .09 .1 129.1 - .3 .19 .3 168.1 - .4 .14 .4 192.4 .8 1.28 .9 317.1 3.5 7.5 14.9 26.2 39.9 .55 3.5 334.9 .97 7.5 340.2 2.91 14.9 343.9 1.68 26.2 344.8 1.11 39.9 344.4 0.00 N 0.00 E .05 S .06 E .25 S .05 E .41 S .09 W .63 N .58 W 3.20 N 1.50 W 7.08 N 2.56 W 14.30 N 4.12 W 25.28 N 6.87 W 38.39 N 10.74 W 999.0 10.68 344.89 995.6 1099.0 12.56 345.97 1093.6 1198.0 13.78 344.62 1190.0 1298.0 15.14 343.90 1286.8 1400.0 17.27 343.72 1384.7 56.3 76.4 98.9 123.9 152.3 2.32 56.3 344.3 1.90 76.4 344.6 1.27 99.0 344.7 1.37 123.9 344.6 2.09 152.4 344.5 54.16 N 15.25 W 73.66 N 20.30 W 95.47 N 26.03 W 119.50 N 32.81 W 146.83 N 40.75 W 1450.0 18.32 343.46 1432.3 1500.0 18.97 343.32 1479.7 1550.0 19.43 342.84 1526.9 1600.0 19.77 342.98 1574.0 1650.0 20.16 342.54 1621.0 167.6 183.6 200.0 216.8 233.9 .11 167.7 344.4 .31 183.6 344.3 .97 200.1 344.2 .70 216.8 344.1 .82 233.9 344.0 161.48 N 45.07 W 176.80 N 49.64 W 192.52 N 54.42 W 208.56 N 59.35 W 224.86 N 64.41 W 1700.0 20.79 341.92 1667.9 1750.0 21.52 341.79 1714.5 1800.0 22.07 341.90 1760.9 1850.0 22.60 341.73 1807.2 1900.0 23.11 341.68 1853.3 251.4 269.4 288.0 307.0 326.4 .35 251.4 343.9 .46 269.4 343.8 .11 288.0 343.6 .06 307.0 343.5 .03 326.4 343.4 241.51 N 69.75 W 258.66 N 75.37 W 276.31 N 81.16 W 294.36 N 87.09 W 312.80 N 93.19 W 1950.0 24.11 341.79 1899.1 2000.0 26.14 342.09 1944.3 2050.0 27.73 342.76 1988.9 346.4 367.6 390.3 .00 346.4 343.3 .06 367.6 343.2 .23 390.3 343.2 331.82 N 99.47 W 352.00 N 106.05 W 373.59 N 112.88 W B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: A0197GCE380 A Gy r o d a t a Directional Survey Page MEASURED 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. HORIZONTAL C 00 R D I N A T E,S feet 2100.0 29.53 343.29 2032.8 2150.0 30.66 343.30 2076.1 414.2 439.3 3.64 414.2 343.2 2.25 439.3 343.2 396.51 N 119.87 W 420.52 N 127.08 W 2200.0 32.35 343.70 2118.7 2250.0 33.96 344.37 2160.5 2300.0 35.45 344.63 2201.6 2350.0 37.51 345.47 2241.8 2400.0 39.52 346.46 2281.0 465.4 492.8 521.2 550.9 582.0 3.42 465.4 343.2 3.29 492.8 343.3 3.00 521.2 343.3 4.23 550.9 343.4 4.22 582.0 343.5 445.57 N 134.50 W 471.86 N 142.01 W 499.30 N 149.62 W 528.02 N 157.28 W 558.22 N 164.83 W 2450.0 41.33 346.78 2319.0 2500.0 43.14 346.76 2356.0 2550.0 44.76 346.81 2392.0 2600.0 45.57 346.74 2427.3 2650.0 47.28 346.85 2461.8 614.4 648.0 682.6 718.0 754.1 3.65 614.4 343.7 3.62 648.0 343.9 3.23 682.7 344.0 1.61 718.1 344.2 3.44 754.3 344.3 589.76 N 172.33 W 622.48 N 180.03 W 656.27 N 187.96 W 690.78 N 196.07 W 726.04 N 204.35 W 2700.0 48.68 346.68 2495.2 2750.0 50.46 346.56 2527.6 2800.0 51.64 346.62 2559.1 2850.0 53.32 346.79 2589.5 2900.0 54.28 346.82 2619.1 791.2 829.2 868.0 907.6 947.9 2.81 791.4 344.4 3.55 829.4 344.5 2.36 868.3 344.6 3.37 907.9 344.7 1.93 948.2 344.8 762.20 N 212.85 W 799.23 N 221.66 W 837.05 N 230.68 W 875.64 N 239.80 W 914.92 N 249.01 W 2950.0 55.65 346.99 2647.8 3000.0 56.67 347.28 2675.6 3050.0 57.87 347.22 2702.6 3100.0 58.42 347.40 2729.0 3150.0 59.49 347.19 2754.8 988.7 1030.1 1072.1 1114.5 1157.2 2.76 989.1 344.9 2.08 1030.6 345.0 2.40 1072.6 345.0 1.15 1115.1 345.1 2.17 1157.9 345.2 954.80 N 995.29 N 1036.31 N 1077.74 N 1119.53 N 258.29 W 267.54 W 276.82 W 286.15 W 295.57 W 3200.0 60.72 346.77 2779.7 3250.0 62.02 346.34 803.7 3300.0 63.23 345.98 2826.7 3350.0 64.41 345.63 2848.7 3400.0 65.45 344.78 2869.9 1200.4 1244.3 1288.6 1333.4 1378.7 2.56 1201.2 345.3 2.70 1245.1 345.3 2.52 1289.5 345.3 2.43 1334.4 345.4 2.59 1379.6 345.4 1161.76 N 1204.44 N 1247.55 N 1291.05 N 1334.84 N 305.34 W 315.54 W 326.16 W 337.17 W 348.74 W A Gyroda t a D i re c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: A0197GCE380 Page MEASURED 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. HORIZONTAL C 0 0 R D I N A T E.S feet 3450.0 66.51 344.13 2890.3 3500.0 67.87 343.63 2909.7 3550.0 68.91 343.37 2928.1 3600.0 70.50 343.35 2945.4 3650.0 71.18 343.16 2961.8 1424.3 1470.4 1516.9 1563.8 1611.0 2.43 1425.3 345.3 2.88 1471.4 345.3 2.14 1517.8 345.2 3.17 1564.7 345.2 1.42 1611.9 345.1 1378.84 N 1423.11 N 1467.68 N 1512.61 N 1557.84 N 360.98 W 373.78 W 386.98 W 400.41 W 414.01 W 3700.0 72.61 342.55 2977.4 3750.0 73.50 342.09 2991.9 3800.0 74.43 342.02 3005.8 3850.0 75.21 342.13 3018.9 3900.0 75.98 342.12 3031.3 1658.6 1706.4 1754.4 1802.7 1851.1 3.08 1659.4 345.1 1.98 1707.2 345.0 1.87 1755.2 344.9 1.57 1803.4 344.8 1.55 1851.7 344.8 1603.25 N 1648.82 N 1694.54 N 1740.45 N 1786.54 N 428.02 W 442.55 W 457.35 W 472.20 W 487.06 W 3950.0 75.50 342.15 3043.6 4000.0 75.63 342.06 3056.1 4050.0 76.16 342.26 3068.3 4100.0 76.61 342.28 3080.0 4150.0 76.71 342.19 3091.6 1899.5 1947.9 1996.4 2045.0 2093.7 .97 1900.2 344.7 .32 1948.5 344.6 .14 1997.0 344.6 .88 2045.5 344.5 .28 2094.2 344.5 1832.67 N 1878.75 N 1924.91 N 1971.19 N 2017.52 N 501.93 W 516.80 W 531.66 W 546.46 W 561.30 W 4200.0 77.19 342.19 3102.8 4250.0 77.77 342.66 3113.7 4300.0 77.95 342.70 3124.2 4350.0 77.88 344.06 3134.7 4400.0 77.92 344.94 3145.2 2142.4 2191.2 2240.1 2288.9 2337.8 .96 2142.8 344.4 .48 2191.6 344.4 .37 2240.5 344.3 .66 2289.3 344.3 .73 2338.2 344.3 2063.90 N 2110.43 N 2157.09 N 2203.94 N 2251.05 N 576.20 W 590.94 W 605.50 W 619.49 W 632.55 W 4450.0 77.39 344.'95 3155.8 4500.0 76.98 345.17 3166.9 4550.0 76.41 345.84 3178.4 4600.0 76.08 346.36 3190.3 4650.0 75.76 347.21 3202.5 2386.6 2435.4 2484.0 2532.5 2580.9 .06 2387.1 344.3 .92 2435.8 344.3 .74 2484.5 344.4 .21 2533.0 344.4 .77 2581.5 344.4 2298.22 N 2345.33 N 2392.44 N 2439.58 N 2486.79 N 645.24 W 657.81 W 669.98 W 681.65 W 692.73 W 4700.0 75.92 347.51 3214.7 4750.0 76.26 347.85 3226.7 4800.0 76.54 347.98 3238.5 2629.3 2677.6 2726.1 .66 2629.9 344.5 .94 2678.4 344.5 .62 2726.9 344.6 2534.10 N 2581.52 N 2629.04 N 703.34 W 713.69 W 723.87 W A Gyro data D i re c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: A0197GCE380 Page · 4 MEASURED 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. HORIZONTAL C 0 0 R D I N A T E.S feet 4850.0 77.02 347.97 3249.9 4900.0 77.10 348.02 3261.1 2774.6 2823.1 .96 2775.5 344.7 .18 2824.1 344.7 2676.64 N 2724.31 N 734.01 W 744.15 W 4950.0 76.73 347.80 3272.4 5000.0 76.71 347.68 3283.9 5050.0 76.19 347.56 3295.6 5100.0 76.10 346.95 3307.6 5150.0 76.16 346.09 3319.6 2871.7 2920.2 2968.7 3017.1 3065.5 .85 2872.7 344.8 .24 2921.3 344.8 1.06 2969.9 344.9 1.19 3018.4 344.9 1.67 3066.9 344.9 2771.93 N 2819.48 N 2866.96 N 2914.31 N 2961.51 N 754.35 W 764.68 W 775.11 W 785.82 W 797.13 W 5200.0 76.52 346.00 3331.4 5250.0 76.78 345.96 3343.0 5300.0 76.73 345.09 3354.4 5350.0 76.65 344.36 3365.9 5400.0 75.97 344.45 3377.8 3114.1 3162.7 3211.3 3259.9 3308.5 .73 3115.5 345.0 .54 3164.1 345.0 1.69 3212.8 345.0 1.43 3261.5 345.0 1.39 3310.0 345.0 3008.66 N 3055.86 N 3102.99 N 3149.93 N 3196.72 N 808.85 W 820.63 W 832.80 W 845.61 W 858.67 W 5450.0 76.04 344.45 3389.9 5500.0 75.39 343.39 3402.2 5550.0 75.05 342.83 3414.9 5600.0 74.84 342.47 3427.9 5650.0 74.55 342.44 3441.1 3357.0 3405.5 3453.8 3502.1 3550.3 .15 3358.5 345.0 2.43 3407.0 344.9 1.28 3455.3 344.9 .82 3503.6 344.9 .57 3551.7 344.9 3243.46 N 3290.01 N 3336.28 N 3382.36 N 3428.35 N 871.68 W 885.10 W 899.15 W 913.55 W 928.08 W 5700.0 75.11 342.52 3454.2 5750.0 75.28 342.58 3467.0 5800.0 76.18 342.87 3479.3' 5850.0 76.41 343.00 3491.2 5900.0 76.49 343.09 3502.9 3598.6 3646.9 3695.3 3743.9 3792.5 1.12 3600.0 344.8 .36 3648.3 344.8 1.90 3696.7 344.8 .52 3745.2 344.7 .23 3793.8 344.7 3474.37 N 3520.48 N 3566.75 N 3613.19 N 3659.68 N 942.61 W 957.10 W 971.50 W 985.75 W 999.93 W 5950.0 76.66 343.04 3514.5 6000.0 76.19 343.25 3526.2 6050.0 76.16 343.14 3538.2 6100.0 76.37 343.13 3550.0 6150.0 76.82 343.08 3561.6 3841.2 3889.8 3938.3 3986.9 4035.5 .35 3842.4 344.7 1.01 3891.0 344.7 .22 3939.6 344.7 .43 3988.1 344.6 .91 4036.7 344.6 3706.21 N 3752.72 N 3799.20 N 3845.68 N 3892.22 N 1014.09 W 1028.19 W 1042.22 W 1056.32 W 1070.45 W A G y r o d'a t a D i r e c t i o n' a i S u r v e y B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: A0197GCE380 Page MEASURED 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 C O 0 R D I N A T E,S feet 6200.0 6250.0 6300.0 6350.0 6400.0 6450.0 6500.0 6550.0 6600.0 6650.0 77.16 343.00 3572.9 76.94 343.33 3584.1 76.67 343.72 3595.5 76.96 343.74 3606.9 77.23 343.75 3618.1 76.53 343.98 3629.4 76.32 344.27 3641.2 76.60 344.31 3652.9 76.94 344.32 3664.3 76.16 344.31 3675.9 4084.2 .69 4085.4 344.6 4133.0 .79 4134.1 344.6 4181.7 .93 4182.8 344.6 4230.3 .58 4231.5 344.6 4279.1 .53 4280.2 344.6 4327.8 1.47 4328.9 344.5 4376.4 .70 4377.5 344.5 4425.0 .56 4426.1 344.5 4473.6 .68 4474.8 344.5 4522.2 1.57 4523.4 344.5 3938.82 N 3985.46 N 4032.14 N 4078.87 N 4125.66 N 4172.44 N 4219.19 N 4265.98 N 4312.84 N 4359.66 N 1084.66 W 1098.78 W 1112.58 W 1126.22 W 1139.86 W 1153.40 W 1166.69 W 1179.85 W 1193.01 W 1206.15 W 6700.0 6750.0 6800.0 6850.0 6900.0 75.74 344.34 3688.1 75.94 344.45 3700.3 76.10 344.47 3712.4 76.01 344.10 3724.4 76.12 343.97 3736.5 4570.7 .83 4571.9 344.5 4619.2 .46 4620.4 344.5 4667.7 .31 4668.9 344.5 4716.2 .74 4717.5 344.5 4764.8 .33 4766.0 344.5 4406.36 N 4453.05 N 4499.80 N 4546.51 N 4593.17 N 1219.26 W 1232.31 W 1245.30 W 1258.45 W 1271.79 W 6950.0 7000.0 7O50.0 7100.0 7150.0 76.52 344.00 3748.3 76.70 344.05 3759.9 75.15 344.07 3772.0 75.01 344.15 3784.9 75.03 344.05 3797.8 4813.3 .79 4814.6 344.5 4862.0 .37 4863.2 344.5 4910.5 3.10 4911.7 344.5 4958.8 .32 4960.0 344.5 5007.1 .20 5008.3 344.5 4639.86 N 4686.63 N 4733.26 N 4779.73 N 4826.18 N 1285.19 W 1298.58 W 1311.90 W 1325.13 W 1338.36 W 7200.0 7250.0 7300.0 7350.0 7400.0 74.89 344.56 3810.8 75.14 345.17 3823.7 75.20 345.07 3836.5 75.30 345.09 3849.3 75.40 345.12 3861.9 5055.3 1.03 5056.6 344.5 5103.6 1.28 5104.9 344.5 5151.9 .22 5153.2 344.5 5200.3 .21 5201.6 344.5 5248.6 .20 5250.0 344.5 4872.66 N 4919.29 N 4966.00 N 5012.72 N 5059.47 N 1351.43 W 1364.04 W 1376.45 W 1388.90 W 1401.33 W 7450.0 75.60 345.06 3874.4 7500.0 75.68 345.08 3886.8 7550.0 75.43 345.11 3899.3 5297.0 .43 5298.4 344.5 5345.4 .16 5346.8 344.5 5393.8 .52 5395.2 344.5 5106.25 N 5153.05 N 5199.84 N 1413.78 W 1426.26 W 1438.72 W B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: A0197GCE380 A Gy r o d a t a Direct i o n a 1 Survey Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL C O O R D I N A T E,S feet 7600.0 7650.0 75 . 30 345 . 25 3912 . 0 5442 . 1 75 . 02 345 . 19 3924 . 8 5490 . 4 .37 5443.6 344.5 .58 5491.9 344.5 5246.61 N 5293.34 N 1451.09 W 1463.42 W 7700.0 7750.0 7800.0 7850.0 7900.0 76.17 345.22 3937.2 5538.8 75.79 345.18 3949.3 5587.3 75.88 345.13 3961.6 5635.8 75.83 344.99 3973.8 5684.2 75.97 344.95 3985.9 5732.7 2.31 5540.3 344.6 .76 5588.8 344.6 .21 5637.3 344.6 .29 5685.8 344.6 .29 5734.3 344.6 5340.16 N 5387.07 N 5433.93 N 5480.77 N 5527.61 N 1475.79 W 1488.18 W 1500.60 W 1513.10 W 1525.67 W 7950.0 8000.0 8050.0 8100.0 8150.0 76.12 345.08 3998.0 76.04 345.28 4010.0 76.52 345.40 4021.9 76.78 345.60 4033.4 76.19 345.52 4045.1 5781.2 5829.7 5878.2 5926.9 5975.4 .38 5782.8 344.6 .43 5831.3 344.6 .99 5879.9 344.6 .66 5928.6 344.6 1.19 5977.2 344.6 5574.48 N 5621.40 N 5668.39 N 5715.49 N 5762.57 N 1538.22 W 1550.64 W 1562.93 W 1575.11 W 1587.23 W 8200.0 8250.0 8300.0 8350.0 8400.0 75.09 345.08 4057.5 74.88 344.97 4070.5 74.57 344.89 4083.7 74.08 344.61 4097.2 73.89 344.78 4111.0 6023.8 6072.1 6120.3 6168.4 6216.5 2.37 6025.6 344.6 .46 6073.9 344.6 .64 6122.1 344.6 1.10 6170.3 344.6 .51 6218.3 344.6 5809.42 N 5856.07 N 5902.65 N 5949.09 N 5995.45 N 1599.53 W 1612.01 W 1624.55 W 1637.21 W 1649.89 W 8450.0 8500.0 8550.0 8600.0 8650.0 74.28 344.79 4124.7 75.23 344.97 4137.8 76.50 345.25 4150.0 77.06 345.31 4161.5 76.77 345.21 4172.8 6264.5 6312.8 6361.2 6409.9 6458.5 .80 6266.4 344.6 1.92 6314.6 344.6 2.59 6363.1 344.6 1.13 6411.8 344.6 .62 6460.5 344.6 6041.85 N 6088.42 N 6135.27 N 6182.35 N 6229.45 N 1662.51 W 1675.09 W 1687.55 W 1699.92 W 1712.32 W 8700.0 8750.0 8800.0 8850.0 8900.0 76.36 345.06 4184.4 76.10 345.02 4196.3 75.79 345.15 4208.4 75.41 345.23 4220.9 75.13 345.17 4233.6 6507.1 6555.7 6604.2 6652.6 6700.9 .86 6509.1 344.6 .51 6557.7 344.6 .67 6606.2 344.6 .79 6654.6 344.6 .56 6703.0 344.6 6276.45 N 6323.37 N 6370.24 N 6417.06 N 6463.81 N 1724.79 W 1737.33 W 1749.81 W 1762.19 W 1774.54 W . A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: A0197GCE380 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet 8950.0 74.75 345.20 4246.6 9000.0 74.63 345.18 4259.8 9050.0 75.06 344.90 4272.8 9100.0 74.47 344.60 4286.0 9150.0 74.58 344.31 4299.3 9200.0 74.53 344.53 4312.6 9250.0 75.03 344.29 4325.8 9300.0 75.04 344.23 4338.7 9350.0 75.78 344.23 4351.3 9400.0 75.27 344.17 4363.8 VERTICAL SECTION feet 6749.1 6797.3 6845.6 6893.8 6942.0 6990.2 7038.4 7086.7 7135.1 7183.5 DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. .76 6751.3 344.7 .24 6799.5 344.7 .00 6847.7 344.7 .32 6896.0 344.7 .60 6944.2 344.7 .44 6992.4 344.7 .12 7040.6 344.7 .11 7088.9 344.7 .48 7137.3 344.6 .03 7185.7 344.6 HORIZONTAL C 00 R D I N A T E.S feet 6510.49 N 1786.89 W 6557.11 N 1799.22 W 6603.74 N 1811.68 W N 1824.36 W 6696.71 N 1837.28 W 6743.13 N 6789.60 N 6836.09 N 6882.66 N 6929.25 N 1850.22 W 1863.19 W 1876.29 W 1889.44 W 1902.62 W 9450.0 75.20 344.15 4376.5 9500.0 75.67 344.21 4389.1 9550.0 75.92 343.97 4401.4 9600.0 75.76 344.08 4413.6 9650.0 75.44 344.15 4426.0 7231.8 7280.2 7328.7 7377.2 7425.6 .14 7234.1 344.6 .94 7282.4 344.6 .69 7330.9 344.6 .39 7379.4 344.6 .64 7427.8 344.6 6975.76 N 7022.32 N 7068.93 N 7115.54 N 7162.12 N 1915.82 W 1929.01 W 1942.30 W 1955.64 W 1968.89 W 9700.0 75.32 344.07 4438.6 9750.0 75.24 343.90 4451.3 9800.0 75.86 343.78 4463.8 9850.0 76.14 343.92 4475.9 9900.0 76.18 343.75 4487.9 7474.0 7522.3 7570.7 7619.2 7667.8 .29 7476.2 344.6 .36 7524.6 344.6 .26 7573.0 344.6 .62 7621.5 344.6 .35 7670.0 344.6 7208.65 N 7255.14 N 7301.64 N 7348.24 N 7394.87 N 1982.14 W 1995.48 W 2008.95 W 2022.44 W 2035.96 W 9950.0 75.94 343.71 4499.9 10000.0 75.31 343.44 4512.3 10050.0 74.79 343.08 4525.2 10100.0 74.30 342.77 4538.6 10150.0 74.07 342.49 4552.2 7716.3 7764.7 7813.0 7861.2 7909.3 .50 7718.5 344.6 .37 7767.0 344.6 .25 7815.3 344.6 .14 7863.4 344.6 .72 7911.5 344.6 7441.46 N 7487.91 N 7534.17 N 7580.24 N 7626.15 N 2049.55 W 2063.25 W 2077.16 W 2091.31 W 2105.67 W 10200.0 74.35 342.10 4565.8 10250.0 76.05 341.45 4578.6 10300.0 75.45 341.33 4590.9 7957.4 8005.8 8054.2 .94 7959.6 344.6 3.62 8007.9 344.5 1.22 8056.3 344.5 7671.99 N 7717.90 N 7763.83 N 2120.30 W 2135.42 W 2150.88 W B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: A0197GCE380 A Gy r o d a t a Direct i o n a 1 Survey Page MEASURED 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. HORIZONTAL C O O R D I N A T E,S feet 10350.0 75.16 341.01 4603.6 10400.0 74.82 340.77 4616.5 8102.5 8150.8 · 86 8104.5 344.5 · 82 8152.7 344.5 7809.61 N 7855.24 N 2166.49 W 2182.31 W 10450.0 74.89 340.56 4629.6 10500.0 76.06 340.83 4642.1 10550.0 77.57 341.02 4653.5 10600.0 77.46 340.63 4664.3 10650.0 77.32 340.39 4675.3 8199.0 8247.4 8296.0 8344.8 8393.5 .43 8200.9 344.5 .41 8249.2 344.4 .04 8297.8 344.4 .80 8346.5 344.4 .54 8395.2 344.4 7900.78 N 7946.46 N 7992.47 N 8038.57 N 8084.57 N 2198.28 W 2214.28 W 2230.19 W 2246.23 W 2262.51 W 10700.0 76.85 340.12 4686.4 10750.0 76.24 339.83 4698.1 10800.0 76.12 339.59 4710.0 10850.0 76.20 339.54 4722.0 10900.0 76.54 340.63 4733.8 8442.2 8490.7 8539.2 8587.6 8636.2 1.07 8443.8 344.3 1.34 8492.3 344.3 .53 8540.7 344.3 .18 8589.1 344.3 2.21 8637.5 344.2 8130.44 N 8176.13 N 8221.67 N 8267.16 N 8312.85 N 2278.97 W 2295.62 W 2312.46 W 2329.41 W 2345.96 W 109576.92 340.43 474 11000.0 77.12 340.34 11050.0 76.60 340.11 11100.0 76.22 339.99 11150.0 75.89 340.18 5.2 8684.8 4756.5 4767.8 4779.6 4791.6 .85 8733.4 8782.1 8830.6 8879.0 8686.1 344.2 .45 8734.7 1.15 8783.3 .79 8831.8 .75 8880.2 8358.73 N 2362.18 W 344.2 8404.62 N 2378.54 W 344.2 8450.44 N 2395.01 W 344.2 8496.13 N 2411.60 W 344.1 8541.75 N 2428.13 W 11200.0 76.28 341.46 11250.0 76.11 341.29 11300.0 75.73 340.97 11350.0 75.94 341.44 11400.0 76.79 342.79 4803.7 4815.6 4827.8 4840.0 4851.8 8927.5 8976.1 9024.5 9073.0 9121.6 2.61 8928.6 .47 8977.1 .99 9025.5 1.00 9074.0 3.13 9122.5 344.1 8587.59 N 2444.07 W 344.1 8633.60 N 2459.58 W 344.1 8679.49 N 2475.26 W 344.1 8725.38 N 2490.88 W 344.1 8771.62 N 2505.80 W 11450.0 76.59 342.63 11500.0 76.40 342.33 11550.0 75.96 342.12 11600.0 75.72 341.74 11650.0 76.32 342.78 4863.3 4875.0 4886.9 4899.2 4911.2 9170.2 9218.8 9267.4 9315.8 9364.3 .51 9171.2 .69 9219.8 .98 9268.3 .88 9316.7 2.36 9365.2 344.0 8818.08 N 2520.27 W 344.0 8864.44 N 2534.90 W 344.0 8910.68 N 2549.72 W 344.0 8956.77 N 2564.76 W 344.0 9002.98 N 2579.55 W B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: A0197GCE380 A Gy r o d a t a D i r e c t i ona i Survey Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL C O O R D I N A T E.S feet 11700 11750 11800 11850 11900 .0 .0 .0 .0 .0 76.59 343.39 4922.9 76.73 343.25 4934.5 76.38 343.05 4946.1 76.12 342.87 4958.0 76.04 342.75 4970.0 9413.0 9461.6 9510.2 9558.8 9607.3 · 29 9413.8 344.0 .39 9462.5 344.0 · 81 9511.1 344.0 .62 9559.7 344.0 .28 9608.2 344.0 9049.48 N 2593.69 W 9096.09 N 2607.65 W 9142.63 N 2621.75 W 9189.06 N 2635.98 W 9235.43 N 2650.32 W 11950 12000 12050 12100 12150 .0 .0 .0 .0 .0 76.02 342.73 4982.1 75.60 342.75 4994.3 77.33 344.34 5006.1 78.00 345.25 5016.7 78.00 345.14 5027.1 9655.8 9704.3 9752.9 9801.8 9850.6 .07 9656.7 344.0 .85 9705.2 344.0 .63 9753.8 344.0 .24 9802.6 344.0 .23 9851.5 344.0 9281.77 N 9328.06 N 9374.67 N 9421.81 N 9469.09 N 2664.72 W 2679.10 W 2692.87 W 2705.68 W 2718.18 W 12200 12250 12300 12350 12400 .0 .0 .0 .0 .0 77.61 345.03 5037.7 77.38 344.90 5048.5 77.29 344.75 5059.5 77.08 344.77 5070.6 77.02 344.60 5081.8 9899.5 9948.3 9997.0 10045.8 10094.5 .83 9900.4 344.0 .51 9949.2 344.0 .35 9998.0 344.0 .41 10046.7 344.0 .35 10095.4 344.0 9516.32 N 9563.46 N 9610.54 N 9657.58 N 9704.58 N 2730.76 W 2743.42 W 2756.19 W 2769.01 W 2781.88 W 12450 12500 12550 12600 12650 12700 12750 12800 12850 12900 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 76.71 344.60 5093~1 76.70 344.46 5104.6 76.58 344.26 5116.2 76.39 344.13 5127.9 76.16 344.08 5139.7 76.19 343.98 75.74 343.69 75.49 343.46 75.34 343.39 75.26 343.33 10143.2 10191.8 10240.4 10289.1 10337.6 5151.7 10386.2 5163.8 4.7 1.06 5176.2 10483.1 5188.8 10531.5 5201.5 10579.9 .63 10144.1 344.0 .27 10192.8 344.0 .46 10241.4 344.0 .46 10290.0 344.0 .47 10338.6 344.0 .20 10387.2 10435.7 344.0 .68 10484.1 .32 10532.5 .18 10580.8 9751.52 N 9798.42 N 9845.27 N 9892.05 N 9938.76 N 2794.81 W 2807.79 W 2820.90 W 2834.14 W 2847.45 W 344.0 9985.44 N 2860.81 W 10032.03 N 2874.31 W 344.0 10078.48 N 2888.01 W 344.0 10124.86 N 2901.82 W 344.0 10171.20 N 2915.66 W 12950 13000 13050 .0 .0 .0 75.10 343.10 75.06 343.08 74.66 342.98 5214.3 10628.2 5227.2 10676.5 5240.2 10724.8 .56 10629.2 .09 10677.5 .82 10725.7 344.0 10217.48 N 2929.62 W 344.0 10263.70 N 2943.68 W 344.0 10309.86 N 2957.76 W A Gyrod'a t a D i re c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: A0197GCE380 Page ,10 MEASURED 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. HORIZONTAL C 0 0 R D I N A T E.S feet 13100.0 74.55 343.03 5253.5 13150.0 74.37 342.94 5266.9 10773.0 10821.2 .24 10773.9 344.0 .39 10822.1 344.0 10355.96 N 2971.86 W 10402.03 N 2985.95 W 13200.0 75.20 342.84 5280.0 13250.0 75.05 342.62 5292.8 13300.0 75.22 342.63 5305.7 13350.0 75.30 342.48 5318.4 13400.0 75.32 342.32 5331.1 10869.4 10917.7 10966.0 11014.4 11062.8 .67 10870.4 344.0 .54 10918.7 344.0 .35 10967.0 344.0 .32 11015.3 344.0 .31 11063.7 344.0 10448.14 N 10494.29 N 10540.41 N 10586.54 N 10632.64 N 3000.15 W 3014.49 W 3028.93 W 3043.42 W 3058.05 W 13450.0 75.08 342.04 5343.8 13500.0. 75.05 341.73 5356.7 13550.0 75.28 342.19 5369.5 13600.0 75.97 342.87 5381.9 13650.0 75.98 342.60 5394.1 11111.1 111 11207.7 11256.1 11304.6 .60 .73 11112.0 343 11160.3 343.9 .98 11208.6 343 .93 11257.0 343 .54 11305.5 343 .9 10678.66 N 3072.84 W 10724.58 N 3087.86 W .9 10770.53 N 3102.83 W .9 10816.73 N 3117.37 W .9 10863.06 N 3131.77 W 13700.0 75.79 342.50 5406.2 13750.0' 75.83 343.27 5418.5 13800.0 76.19 344.21 5430.6 13850.0 76.24 344.06 5442.5 13900.0 76.29 344.00 5454.4 11353.1 11401.6 11450.1 11498.7 11547.2 .42 11354.0 343 .48 11402.4 343 .98 11450.9 343 .32 11499.5 343 .15 11548.1 343 .9 10909.32 N 3146.31 W .9 10955.64 N 3160.58 W .9 11002.22 N 3174.16 W .9 11048.93 N 3187.44 W .9 11095.63 N 3200.81 W 13950.0 76.56 343.87 5466.1 14000.0 76.86 343.74 5477.6 14050.0 77.03 343.57 5488.9 14100.0 76.92 343.42 5500.2 14150.0 76.84 343.66 5511.5 11595.8 11644.5 11693.2 11741.9 11790.6 .59 11596.7 343 .66 11645.3 343 .46 11694.0 343 .37 11742.8 343 .50 11791.5 343 .9 11142.33 N 3214.26 W .9 11189.06 N 3227.83 W .9 11235.80 N 3241.53 W .9 11282.51 N 3255.37 W .9 11329.21 N 3269.17 W 14200.0 76.77 343.63 5522.9 14250.0 76.83 343.52 5534.3 14300.0 76.76 343.63 5545.8 14350.0 76.36 344.64 5557.4 14400.0 76.34 344.71 5569.2 11839.3 11888.0 11936.7 11985.3 12033.8 .15 11840.1 343.9 .24 11888.8 343.9 .24 11937.5 343.9 .12 11986.1 343.9 .14 12034.7 343.9 11375.92 N 11422.62 N 11469.31 N 11516.08 N 11562.94 N 3282.87 W 3296.63 W 3310.39 W 3323.69 W 3336.53 W A Gyroda t a D i re c t i on.a i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: A0197GCE380 Page 11 MEASURED 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. HORIZONTAL C 00 R D INA T E.S feet 14450.0 76.25 344.65 5581.0 14500.0 76.04 344.47 5593.0 14550.0 75.82 344.42 5605.1 14600.0 75.55 344.34 5617.5 14650.0 75.52 344.41 5630.'0 14700.0 75.61 344.18 5642.5 14750.0 75.68 344.13 5654.9 14800.0 75.71 344.08 5667.2 14850.0 75.67 343.95 5679.6 14900.0 75.73 343.95 5691.9 14950.0 75.43 343.88 5704.4 15000.0 75.37 343.78 5717.0 15050.0 75.39 343.72 5729.6 15100.0 75.67 343.56 5742.1 15150.0 75.64 343.52 5754.5 12082.4 12130.9 12179.4 12227.9 12276.3 12324.7 12373.1 12421.6 12470.0 12518.5 12566.9 12615.3 12663.6 12712.0 12760.5 .21 12083.3 343.9 .55 12131.8 343.9 .44 12180.3 343.9 .57 12228.8 343.9 .14 12277.2 343.9 .49 12325.6 343.9 .16 12374.0 343.9 .11 12422.5 343.9 .27 12470.9 343.9 .12 12519.4 343.9 .61 12567.8 343.9 .23 12616.2 343.9 .13 12664.6 343.9 .65 12713.0 343.9 .11 12761.4 343.9 11609.79 N 11656.59 N 11703.31 N 11749.97 N 11796.60 N 11843.21 N 11889.81 N 11936.41 N 11982.98 N 12029.54 N 12076.07 N 12122.54 N 12168.99 N 12215.45 N 12261.90 N 3349.37 W 3362.29 W 3375.29 W 3388.34 W 3401.37 W 3414.4'8 W 3427.71 W 3440.98 W 3454.32 W 3467.72 W 3481.13 W 3494.61 W 3508.15 W 3521.78 W 3535.51 W 15200.0 75.71 343.42 5766.8 15250.0 75.76 343.25 5779.2 15300.0 75.72 343.26 5791.5 15350.0 75.27 343.19 5804.0 15400.0 74.26 343.28 5817.2 15450.0 73.96 343.25 5830.8 15500.0 73.81 343.27 5844.7 15550.0 73.80 343.22 5858.7 15600.0 73.99 343.18 5872.5 15650.0 74.10 343.16 5886.3 12808.9 12857.4 12905.8 12954.3 13002.5 13050.6 13098.6 13146.6 13194.7 13242.7 .24 12809.9 .34 12858.3 .07 12906.8 .92 12955.2 2.02 13003.4 .61 13051.5 .29 13099.5 .09 13147.6 .39 13195.6 .23 13243.7 343.9 12308.35 N 3549.29 W 343.9 12354.77 N 3563.19 W 343.2401.17 N 3577.15 W 343.9 12447.52 N 3591.12 W 343.9 12493.71 N 3605.03 W 343.9 12539.76 N 3618.88 W 343.9 12585.76 N 3632.71 W 343.9 12631.74 N 3646.55 W 343.9 12677.73 N 3660.44 W 343.9 12723.74 N 3674.35 W 15700.0 73.89 343.04 5900.1 15750.0 73.82 342.91 5914.0 15800.0 73.72 342.74 5928.0 13290.8 13338.8 13386.8 .48 13291.7 .28 13339.7 .39 13387.7 343.9 12769.73 N 3688.32 W 343.9 12815.65 N 3702.38 W 343.9 12861.52 N 3716.56 W A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: A0197GCE380 Page 12 MEASURED 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. HORIZONTAL C O O R D I N A T E.S feet 15850.0 73.68 342.58 5942.0 15900.0 73.84 342.57 5956.0 13434.8 13482.8 .33 13435.7 343.9 .32 13483.7 343.9 12907.33 N 12953.13 N 3730.86 W 3745.23 W 15950.0 73.97 342.59 5969.8 16000.0 73.80 342.27 5983.7 16050.0 73.75 342.14 5997.7 16100.0 73.79 342.12 6011.7 16150.0 72.14 341.92 6026.3 13530.9 13578.9 13626.9 13674.9 13722.7 .26 13531.7 343.9 .69 13579.8 343.9 .26 13627.7 343.9 .10 13675.7 343.9 3.32 13723.5 343.8 12998.96 N 3759.62 W 13044.76 N 3774.12 W .47 N 3788.79 W 13136.16 N 3803.52 W 13181.63 N 3818.28 W 16200.0 71.99 341.84 6041.7 16250.0 70.40 341.91 6057.8 16300.0 70.16 341.71 6074.7 16350.0 68.28 341.70 6092.4 16400.0 67.95 341.62 6111.1 13770.2 13817.6 13864.6 13911.3 13957.7 .34 13771.1 343.8 3.18 13818.4 343.8 .61 13865.4 343.8 3.77 13912.1 343.8 .68 13958.5 343.8 13226.84 N 13271.82 N 13316.54 N 13360.92 N 13404.96 N 3833.08 W 3847.80 W 3862.50 W 3877.17 W 3891.77 W 16450.0 66.01 341.70 6130.6 16500.0 65.32 341.71 6151.2 16550.0 64.17 341.86 6172.6 16600.0 64.13 341.74 6194.4 16650.0 61.85 342.33 6217.1 14003.7 14049.3 14094.5 14139.5 14184.0 3.88 14004.5 343.8 1.38 14050.0 343.8 2.31 14095.2 343.8 .22 14140.1 343.8 4.69 14184.7 343.8 13448.64 N 13491.89 N 13534.84 N 13577.59 N 13619.96 N 3906.25 W 3920.56 W 3934.69 W 3948.75 W 3962.49 W 16700.0 61.86 342.17 6240.6 16750.0 59.24 341.57 6265.2 16800.0 58.94 341.06 6290.9 16850.0 56.63 340.93 6317.6 16900.0 55.63 341.26 6345.4 14228.1 14271.6 14314.5 14356.7 14398.2 .28 14228.7 343.8 5.34 14272.2 343.8 1.06 14315.1 343.8 4.62 14357.4 343.8 2.08 14398.8 343.7 13661.95 N 13703.33 N 13743.97 N 13783.96 N 13823.24 N 3975.93 W 3989.47 W 4003.21 W 4016.99 W 4030.44 W 16950.0 53.61 341.41 6374.4 17000.0 52.41 340.98 6404.5 17050.0 50.73 341.88 6435.5 17100.0 49.76 342.89 6467.5 17150.0 48.21 343.12 6500.3 14439.0 14478.9 14518.0 14556.5 14594.2 4.03 14439.6 343.7 2.50 14479.5 343.7 3.64 14518.6 343.7 2.48 14557.0 343.7 3.12 14594.7 343.7 13861.86 N 13899.66 N 13936.79 N 13973.42 N 14009.50 N 4043.49 W 4056.36 W 4068.83 W 4080.47 W 4091.49 W A Gyroda t a D i re c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: A0197GCE380 MEASURED 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 C O O R D I N A T E.S feet Page 13 17200.0 46.61 343.06 6534.2 17250.0 45.36 343.62 6568.9 17300.0 43.31 344.69 6604.7 17350.0 41.59 344.87 6641.6 17400.0 39.29 343.83 6679.6 14631 . 0 3 . 19 14631 . 5 343 . 7 14666 . 9 2 . 64 14667 . 5 343 . 7 14701.9 4.36 14702.4 343.7 14735.6 3.46 14736.2 343.7 14768.0 4.79 14768.6 343.7 14044.72 N 14079.16 N 14112.77 N 14145.34 N 14176.56 N 4102.20 W 4112.51 W 4122.05 W 4130.91 W 4139.65 W 17450.0 38.13 343.05 6718.6 17500.0 35.77 342.51 6758.6 17550.0 34.72 342.92 6799.4 17600.0 32.76 341.97 6841.0 17650.0 32.64 342.12 6883.1 14799.3 2.52 14799.9 343.7 14829.4 4.75 14829.9 343.7 14858.2 2.16 14858.8 343.7 14886.0 4.06 14886.5 343.7 14913.0 .29 14913.5 343.7 14206.53 N 14235.24 N 14262.79 N 14289.27 N 14314.96 N 4148.56 W 4157.45 W 4166.03 W 4174.40 W 4182.72 W 17700.0 32.49 342.25 17750.0 32.40 342.46 17800.0 32.65 342.57 17850.0 32.37 342.70 179 32.06 343.27 7094.0 6925.2 14939.9 .32 14940.4 6967.4 14966.7 .29 14967.3 7009 . 6 14993 . 6 . 51 14994 . 1 7051 . 7 15020 . 5 . 57 15021 . 0 15047 . 1 . 87 15047 . 7 343 . 7 343.7 14340.58 N 4190.96 W 343.7 14366.15 N 4199.09 W 343.7 14391.79 N 4207.17 W 343.7 14417.44 N 4215.19 W 14442.93 N 4222.99 W 17950.0 32.24 343.61 18000.0 32.22 343.47 18050.0 32.36 343.55 18100.0 32.66 343.07 18150.0 32.58 343.62 18200.0 32.31 343.87 18250.0 32.05 344.30 18273.0 32.01 344.44 7136.4 15073.7 .50 15074.3 7178.7 15100.4 .16 15100.9 7220.9 15127.1 .28 15127.6 7263.1 15154.0 .80 15154.5 7305.2 15180.9 .61 15181.5 7347.4 15207.7 .60 15208.3 7389.7 15234.4 .69 15234.9 7409.2 15246.6 .36 15247.1 343.7 14468.43 N 4230.57 W 343.7 14494.01 N 4238.12 W 343.7 14519.62 N 4245.71 W 343.7 14545.36 N 4253.42 W 343.7 14571.18 N 4261.15 W 343.7 14596.93 N 4268.65 W 343.7 14622.54 N 4275.96 W 343.7 14634.28 N 4279.24 W Final Station Closure: Distance: 15247.10 ft Az: 343.70 deg. A Gyroda t a D i re c t i ona i Survey for B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: SUB380 Run Date: 31-Jan-97 12:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 41.6 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 343.220 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: SUB380 A Gy r o d a t a D i r e c t iona i Survey Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet -4 10 20 30 40 1.6 0.0 0.0 0.0 0.0 0.00 0.00 0.0 .13 161.55 141.6 .14 226.60 241.6 .60 289.32 341.6 1.52 339.81 441.6 0.0 .1 1.9 0.00 0.0 0.0 .13 .3 145.3 .17 .4 178.3 .62 .9 245.0 .97 3.5 324.5 0.0 N 0.0 E .1 S .1 E .3 S .1 W .5 N .3 W 1.7 N 1.0 W 50 60 70 80 90 0.0 0.0 0.0 0.0 0.0 2.23 343.88 541.6 4.00 347.34 641.6 6.38 346.53 741.6 7.78 343.67 841.6 9.42 343.85 941.6 5.2 10.6 19.7 32.1 47.2 .72 7.5 337.1 1.78 14.9 341.7 2.39 26.2 344.3 1.43 39.9 344.6 1.65 56.3 344.3 4.8 N 1.9 W 10.1 N 3.2 W 18.9 N 5.3 W 30.9 N 8.5 W 45.4 N 12.8 W 100 110 120 130 140 0.0 0.0 0.0 0.0 0.0 11.56 345.40 1041.6 13.17 345.30 1141.6 14.50 344.23 1241.6 16.33 343.80 1341.6 18.44 343.44 1441.6 65.7 87.6 112.2 139.8 170.7 2.12 76.4 344.4 1.58 99.0 344.7 1.32 123.9 344.7 1.77 152.4 344.6 1.95 183.6 344.4 63.3 N 17.6 W 84.5 N 23.2 W 108.3 N 29.6 W 134.8 N 37.3 W 164.5 N 46.0 W 150 160 170 180 190 0.0 0.0 0.0 0.0 0.0 19.53 342.88 1541~6 20.44 342.27 1641.6 21.84 341.85 1741.6 22.98 341.69 1841.6 26.02 342.07 1941.6 205.3 241.6 280.2 321.5 366.3 .89 216.8 344.2 1.05 251.4 344.0 1.25 288.0 343.7 1.04 326.4 343.4 3.94 367.6 343.2 197.5 N 56.0 W 232.2 N 66.8 W 269.0 N 78.7 W 308.1 N 91.6 W 350.8 N 105.6 W 200 210 220 230 240 0.0 0.0 0.0 0.0 0.0 29.76 343.29 2041.6 33.23 344.07 2141.6 37.49 345.46 2241.6 42.44 346.77 2341.6 46.28 346.78 2441.6 419.3 480.4 550.8 634.9 733.0 3.36 439.3 343.2 3.35 492.8 343.2 4.22 550.9 343.4 3.63 648.0 343.8 2.37 754.3 344.2 401.4 N 121.3 W 460.0 N 138.6 W 527.8 N 157.2 W 609.7 N 177.0 W 705.4 N 199.5 W 250 260 270 0.0 0.0 0.0 50.98 346.59 2541.6 55 . 36 346 . 95 2641 . 6 58 . 94 347 . 29 2741 . 6 846.4 979.9 1135.3 3.02 868.3 344.5 2.58 989.1 344.8 1.65 1157.9 345.2 816.0 N 225.7 W 946.2 N 256.3 W 1098.1 N 290.7 W B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: SUB380 A Gy r o d a t a Directional Survey Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2800.0 64.03 345.74 2841.6 2900.0 70.15 343.36 2941.6 1318.9 1553.5 2.46 1334.4 345.4 2.95 1564.7 345.2 1277.0 N 333.6 W 1502.7 N 397.4 W 3000.0 75.58 342.15 3041.6 3100.0 77.91 344.64 3141.6 3200.0 76.67 347.97 3241.6 3300.0 76.75 345.97 3341.6 3400.0 74.57 342.45 3441.6 1891.7 2321.2 2739.2 3156.9 3552.1 .06 1900.2 344.7 .05 2338.2 344.3 .71 2775.5 344.6 .56 3164.1 345.0 .59 3600.0 344.9 1825.2 N 499.5 W 2235.1 N 628.1 W 2642.0 N 726.6 W 3050.3 N 819.2 W 3430.0 N 928.6 W 3500.0 76.22 343.14 3541.6 3600.0 76.33 344.28 3641.6 3700.0 76.29 343.99 3741.6 3800.0 75.24 345.08 3841.6 3900.0 76.03 345.21 3941.6 3952.3 4378.2 4785.8 5171.1 5556.4 .28 3988.1 344.7 .70 4426.1 344.5 .53 4814.6 344.5 .21 5201.6 344.5 .75 5588.8 344.6 3812.6 N 1046.3 W 4221.0 N 1167.2 W 4613.4 N 1277.6 W 4984.6 N 1381.4 W 5357.2 N 1480.3 W 4000.0 76.37 345.54 4041.6 4100.0' 75.62 345.05 4141.6 4200.0 74.90 345.19 4241.6 4300.0 75.21 344.23 4341.6 4400.0 75.30 344.03 4441.6 5960.8 6327.8 6730.7 7097.9 7485.2 .03 5977.2 344.6 .13 6363.1 344.6 .68 6751.3 344.7 .43 7137.3 344.7 .31 7524.6 344.6 5748.4 N 1583.6 W 6103.0 N 1679.0 W 6492.6 N 1782.2 W 6846.9 N 1879.3 W 7219.5 N 1985.2 W 4500.0 74.25 342.71 4541.6 4600.0 76.01 340.82 4641.6 4700.0 76.80 340.49 4741.6 4800.0 76.05 341.62 4841.6 4900.0 76.52 343.13 4941.6 7871.9 8245.3 8669.4 9079.6 9491.4 1.04 7911.5 344.6 2.33 8249.2 344.4 1.28 8686.1 344.2 1.29 9122.5 344.1 .65 9511.1 344.0 7590.4 N 2094.5 W 7944.5 N 2213.6 W 8344.2 N 2357.0 W 8731.7 N 2492.9 W 9124.6 N 2616.3 W 5000.0 77.52 344.98 5041.6 5100.0 76.16 344.06 5141.6 5200.0 74.65 342.98 5241.6 5300.0 75.13 342.09 5341.6 5400.0 76.24 344.07 5441.6 9917.1 10345.2 10729.8 11102.6 11495.0 .71 9949.2 344.0 .43 10387.2 344.0 .76 10773.9 344.0 .65 11112.0 343.9 .45 11499.5 343.9 9533.4 N 2735.3 W 9946.1 N 2849.5 W 10314.7 N 2959.2 W 10670.6 N 3070.2 W 11045.4 N 3186.4 W B.P. EXPLORATION F PAD, WELL NO. MPF-54 MILNE POINT FIELD, ALASKA Job Number: SUB380 A Gy r o d a t a D i re c t i ona i Survey- Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 5500.0 76.78 343.59 5541.6 5600.0 75.61 344.19 5641.6 5700.0 75.66 343.57 5741.6 5800.0 73.85 343.26 5841.6 5900.0 73.68 342.58 5941.6 6000.0 71.99 341.84 6041.6 6100.0 65.64 341.70 6141.6 6200.0 61.76 342.15 6241.6 6300.0 55.77 341.21 6341.6 6400.0 50.54 342.07 6441.6 11919.0 12321.3 12710.2 13087.8 13433.5 13769.9 14028.0 14229.8 14392.5 14525.3 .24 11937.5 343.9 .47 12325.6 343.9 .63 12713.0 343.9 .36 13099.5 343.9 .33 13435.7 343.9 .36 13771.1 343.8 2.55 14050.0 343.8 .47 14272.2 343.8 2.43 14398.8 343.7 3,42 14557.0 343.7 11452.3 N 3305.4 W 11840.0 N 3413.6 W 12213.6 N' 3521.2 W 12575.4 N 3629.6 W 12906.1 N 3730.5 W 13226.5 N 13471.7 N 13663.6 N 13817.8 N 13943.7 N 3833.0 W 3913.9 W 3976.5 W 4028.6 W 4071.0 W 6500.0 46.34 343.18 6541.6 6600.0 41.58 344.87 6641.6 6700.0 36.77 342.74 6741.6 6800.0 32.75 341.97 6841.6 6900.0 32.46 342.33 6941.6 14638.7 14735.7 14816.6 14886.4 14950.3 3 . 07 14667 . 5 343 . 7 3.46 14768.6 343.7 3.81 14829.9 343.7 4.01 14913.5 343.7 .31 14967.3 343.7 14052.1 N 14145.4 N 14223.0 N 14289.6 N 14350.5 N 4104.4 W 4130.9 W 4153.7 W 4174.5 W 4194.1 W 7000.0 32.44 342.67 7041.6 7100.0 32.23 343.60 7141.6 7200.0 32.51 343.32 7241.6 7367.6 32.01 344.44 7409.2 15014.0 15077.0 15140.3 15246.6 .56 15021.0 343.7 .46 15100.9 343.7 .53 15154.5 343.7 .36 15247.1 343.7 14411.3 N 14471.6 N 14532.2 N 14634.3 N 4213.3 W 4231.5 W 4249.5 W 4279.2 W Final Station Closure: Distance: 15247.10 ft Az: 343.70 deg. 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: A0197GCE380 TOOL NUMBER: 749 MAXIMUM GYRO TEMPERATURE: MAXIMUM' AMBIENT TEMPERATURE: 81C 82.0 C MAXIMUM INCLINATION: 77.8 AVERAGE AZIMUTH: 343.7 WIRELINE REZERO VALUE: N/A REZERO ERROR / K: N/A CALIBRATION USED FOR FIELD SURVEY: 1723 CALIBRATION USED FOR FINAL SURVEY: 1723 PRE JOB MASS BALANCE OFFSET CHECK: -.45 POST JOB MASS BALANCE OFFSET CHECK~: USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES UPON ARRIVAL AT RIG: OK -.35 UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH FIELD SURVEY 18273 32.01 344.44 FINAL SURVEY 18273 32.01 344.44 TVD NORTHING EASTING 7409.2 14634.3 7409.2 14634.3 -4279.2 -4279.2 FUNCTION TEST JOB NUMBER ' A0197GCE380 5 Survey stations were collected at the measured depth shown below. The tables repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 1398 17.23 17.23 17.23 17.23 17.23 AZIMUTH M.D. ff 1 2 3 4 5 1398 343.79343.91 343.73343.81 343.88 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: A0197GCE380 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 749 GYRO SECTION DATA SECTION POWER SECTION BACKUP TOOL No. 758 GYRO SECTION DATA SECTION POWER SECTION A0124 C0089 C0040 A0222 C0084 C0080 COMPUTER A0222 POWER SUPPLY PRINTER A0079 INTERFACE A0087 COMPUTER A0349 POWER SUPPLY PRINTER A0029 INTERFACE A0055 A0085 A0107 WIRELINE COMPANY: CABLE SIZE: 15/32" SCHLUMBERGER WIRELINE RUNNING GEAR IN SCHLUMBERGER HOUSING W/GR CCL AND ROLLERS TOTAL LENGTH OF TOOL :8 FEET MAXIMUM O.D.: 3.375 INCHES TOTAL WEIGHT OF TOOL: 400 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: A0197GCE380 01/30/97 10:00 14:30 18:00 23:00 ALERTED FLY CHARTER TO SLOPE ARRIVE ATLAS, CHECK TOOLS, O.K. CHECK TOOL IN COMBO W/CCL/GR-O.K. 01/31/97 08:15 09:15 11:15 12:00 12:30 16:00 19:45 21:45 22:30 TO LOCATION ARRIVE AT LOCATION RU SCHLUMBERGER, MU TOOL, SAFETY MEETING RIH 100' STATIONS TO 1400' RIH SURVEY CONTINUOUS TO 18273' START OUTRUN W/GR 40FPM SURVEY CONTINUOUS OUT FROM 9000' LD TOOL. LEAVE LOCATION 02/01/97 07:00 12:00 14:00 CHECK TOOL, O.K., PROCESS SURVEY RETURN MILNE POINT WITH RESULTS STAND BY FOR JOB ON K PAD. Transmittal ¢ ~ of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 01-Apr-97 Well Name Services Bluelines R/F Sepia IFilm MPF-54 GR/CCL PERF 1 1I 0 MPF-54 PRESSURE SURVEY 1 1. 0.; -- 'Received byO r", ~_ !../~ _-. V~ APR O 6 !997 Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) March 25, 1997 TO: BP Exploration (Alaska) Inc. Petrotectnicai Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the MWD Depth Corrected CDR/ADN, CDR/ADN TVD°S for well MPF-54, Job # 97066 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 1 OH LIS Tape 3 Bluelines each 1 Film each 1 Depth Shift Display State of Alaska Alaska Oil & Gas Conservation Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1 OH LIS Tape 1 Blueline each 1 RF Sepia each OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 I OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail: Z 777 937 547 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, Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by:'~~~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO, 10814 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 2/21/97 Well Job # Log Description Date BL RF Sepia LIS Tape MPF-21 ULTRASONIC IMAGER 9701 04 I 1 M P F-21 GR-CCL CORRELATION 9701 05 I 1 MPF-21 CEMENT BOND LOG 9701 04 I 1 MPF-21 TDT GRAVEL PACK LOG 9701 08 I 1 MPF-21 9 5/8" PACKER RECORD 9701 05 I 1 MPU K-33 STATIC TEMPERATURE PRESSURE 9701 29 I 1 MPU K-33 BRIDGE PLUG SET 970207 I 1 MPU K-33 GR/CCL DEPTH LOG 9701 29 I 1 MPU F-54 GR/CCL DEPTH LOG 9701 31 I 1 M PH-07 GR/CCL CORRELATION LOG 9701 21 I 1 MPK-06 PERFORATION RECORD 9701 1 2 I 1 MPK-06 GR-CCL PRIMARY DEPTH LOG 9701 1 2 I 1 MPE-17 CEMENT BOND LOG 9701 07 I 1 M P E-17 COMPLETION RECORD 9701 27 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 MEMORANDUM TO: David John~~, Chairma~~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 12, 1997 THRU: Blair Wondzell, ~~ FILE NO: awokalee.doc P. !. Supervisor Chuck Scheve, ~'" Petroleum Inspector FROM: SUBJECT: BOPE Test Nabors 22E ~/vt p, r~ '~'~PTD # 96-192 Sunday January, 12, 1997: I traveled to BPX's MPU F-54 Well being drilled by Nabors Rig 22E and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE test report show%.the test iasted'2.5-hours with no failures. The test went well with good test procedures being employed by the Nabors crews. The rig was clean and all related equipment appeared to be in good working order. The location though crowded was well organized. Summary: i witnessed the initial BOPE on Nabors rig 22E test time 2.5 hours no failures. Attachment: awokalee.xls X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drig Contractor: Operator: Well Name: Casing Size: 9 5/8 Test: Initial X Workover: Nabors Rig No. 22E PTD # BPX Rep.: MPF-54 Rig Rep.: Set @ 9,403 Location: Sec. Weekly Other DATE: 1/12/97 g6-192 Rig Ph.# 659-4446 Charlie Dixon Rod Klepzig 6 T. 13N R. IOE Meridian UM Test MISC. INSPECTIONS: Location Gen.: OK Well Sign OK Housekeeping: OK (Gen) Dri. Rig OK P'ID On Location Yes / Hazard Sec. Yes ~'' Standing Order Posted Yes / FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 1 250/5,000 P = . I 250/5, O00 P 1 P 1 250/5,000 250/5,000 P BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves 1 HCR Valves 2 Kill Line Valves Check Valve N/A , .. Test Press. 25O/25O0 1 250/5,000 I 250/5,000 250/5,000 250/5,000 N/A PtF P P P P ~ N/A . MUD SYSTEM: ~r~ual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK ,, H2S Gas Detector OK OK , , CHOKE MANIFOLD: No. Valves 18 No. Flanges 36 Manual Chokes 2 Hydraulic Chokes 1 , Test Pressure P/F 250/5,000 P P 250/5,000 Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure 3000 Pressure After Closure 1400 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 8 Bottles 1900 Psig. ,, minutes 25 sec. ,, 3 minutes '45 sec. Yes Remote: YES Number of Failures: 0 ,Test Time: ,3.5 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I REMARKS: Good Test Distribution: orig-Weil File c - Oper./Rig c- Database c - Tdp Rpt File c- Inspector STATE VVITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: VV'rtnessed By: Chuck Scheve FI-021L (Rev. 12/94) AWOKALEE.XLS MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 4, 1997 THRU: Blair Wondzeil, ~ FILE NO: P. I. Supervisor ~/'~ FROM: Doug Amos, ~.,.~:~ ¢¢,.,~.,,,_ SUBJECT: Petroleum Inspector ewohaded.doc Confidential: Yes _, Attachment Only ; Diverter Inspection Nabors 22E BP× MPU F-54 PTD No. 96-0192 NoX, · Saturday, January 4, 1997: I traveled to BPX MPU F-54 well to inspect the Diverter System on Nabors Rig 22E. Due to weather conditions, I was unable to witness the function test at midnight on 1/3/97. As the attached AOGCC Diverter System Inspection Report indicates I found the system in compliance. Despite the presence of Nabors Rig 4ES on location the site was crowded but well organized. The warning signs were in clear view and the area surrounding the terminus of the vent lines was clear. SUMMARY: I inspected the Diverter System on BPX MPU F-54 well at Nabors Rig 22E. Attachment: EWOHADED.XLS Drlg Contractor: Operator: Well Name: Location: Sec. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Date: Nabors Alaska Drilling Inc. BP Exploration MPU F-54 6 T. 13N. R. 1/4/97 Operation: Development X Exploratory: Rig No. 22E PTD # 96-192 Rig Ph. # Oper. Rep.: Tom Anglen Rig Rep.: Rod Klepzig 10 E. Merdian Umiat 659-4446 MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: OK Well Sign: OK Systems Pressure: Not Tested psig Housekeeping: OK (Gen.) Drig. Rig: OK Pressure After Closure: psig Reserve Pit: N/A Flare Pit: N/A 200 psi Attained After Closure: ~ min. ~ sec. Systems Pressure Attained: ~ min. ~ sec. Nitrogen Bottles: Not Tested DIVERTER SYSTEM INSPECTION: Diverter Size: 20 Divert Valve(s) Full Opening: Yes Valve(s) Auto & Simultaneous: Yes Vent Line(s) Size: 10 Vent Line(s) Length: Line(s) Bifurcated: Yes Line(s) Down Wind: Yes Line(s) Anchored: Yes Turns Targeted / Long Radius: N/A 121/15 ft. in. psig MUD SYSTEM INSPECTION: Light Alarm in. Trip Tank: NFF NfT Mud Pits: N/T N/T Flow Monitor: N/T N/T GAS DETECTORS: Light Alarm Methane N/T N/T Hydrogen Sulfide: N/T N/T Pad Access Active Wells 10" Diver[er Vent Lines Pipe Shed Existing Flow Lines Mud Pits I -- NORTH -~ -- Camp 20" Annular W/J0"~¢:..:~Hydraulic. Knife:__.__=:..¢~ Valve Shop Non Compliance Items 0 Repair Items Within Day (s) And contact the Inspector @ 659-3607 Remarks: I was unable to witness the diverter function test on 1/3/97. Distribution odg. - Well File c - Oper/Rep c - Database c - Trip Rpt File c- Inspector AOGCC REP.: Doug Amos OPERATOR REP.: EWOHADED.XLS Tom Anglen DVTRINSP.XLT (REV, 1/94) TONY KNOWLE$, GOVERNOR ALAS~ OIL A~NII GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 12, 1996 Tim Schoficld Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Well Name: tV[PF-54 BP Exploration (Alaska), Inc. Permit No. 96-192 Sur. Loc.' 2092' NSL, 2662' WEL. SEC. 06, T13N, R10E Btmhole Loc: 940' NSL. 1937' WEL. SEC. 24, T14N. R09E Dear Mr. Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Approval for annular injection is contingent on the operator's submittal of an Application for Sundr)' Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and an.',' diagnostic logs that were run. The documentation submitted should include a CQL or a valid LOT to assure the Comnfission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may ~vitness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Cha~ ) BY ORDER OMMISSION slh~.'enclosurcs cc: Department oFFish & Game. Habitat Section w/o encl. Department of Enviromncnt Conservation xw;o cncl. STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION · PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen~ [] 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 - 41.6' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 355021 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2092' NSL, 2662' WEL, SEC. 6, T13N, R10E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 757' NSL, 1882' WEL, SEC. 24, T14N, RDE MPF-54 At total depth 9. Approximate spud date Amount $200,000.00 940' NSL, 1937' WEL, SEC. 24, T14N, RDE 12/17/96 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 355018, 940'I No Close Approach 2560 18498' MD / 7641' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 300' Maximum Hole Angle 75.79 o Maximum surface 3284 psig, At total depth (TVD) 7270' / 3649 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 9692' 31' 31' 9723' 4478' 18o9 sx PF'E', 860 sx'G', 150 sx PF'E' 8-1/2" 7" 26# L-80 Btrc-Mod 18468' 30' 30' 18498' 7641' 213 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 MD TVD Structural Conductor Surface Intermediate ProductionRECEIVED Liner DEC 0 2 1996 Perforation depth: measured Alaska Oil & Gas Cons. Commission true vertical Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] 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 21.1Signedhereby certify~re,~nd....~.. -~ tz,,,~,'k~ (~,._.,_ r ~, ~/]c°rrect, to the best of my knowledge¢~::'/~//~_.f, TimSohof,e,d ' ~-,~-~,~¢~,_,fJ~ Title Senior Drilling Engineer Date / Commission Use Only Permit Number I APl Number _ I A,,pproval Date I See cover letter ~.~ _ ~ ~ 50- ~ ~ '~ -~ ~-~- ~-- /' ~ ~ ( ~ _ j.~_o)/~, for other requirements Yes No Conditions of Approval: Samples Required [] /~i~'~'''~s Mud Log Required [] Yes _~ No. Hydrogen Sulfide Measures [] No Directional Survey Required /~"Yes [] No Required Working Pressure for DOPE [] 2M; [] 3M; ~ 5M; [] 10M; [] 15M Other: Original SJgnuo ~.~ by order of Approved By 0avid W .Inhr~e~'r,,~ Commissioner the commission Date r-~' Form 10-401 Rev. 12-01-85 Submit In Triplicate , ~;hared Services Drilling Contact: James E. Robertson I Well Name: IMP F-54 Well Plan Summary 564-5159 IType of Well (producer or injector)' KUPARUK PRODUCER Surface Location: 2092 NSL 2662 WEL Sec 06 T13N R10E UM., AK 757 NSL 1882 WEL Sec 24 T14N R09E UM., AK Target Location: Bottom Hole Location- 940 NSL 1937 WEL Sec 24 T14N R09E UM., AK I AFE Number: 1337026 I I Rig: I Nabors 22-E I IEstimated Start 117DEC96 Date' IOperating days t°comPlete' 121 I Well Design' I Milne Point Ultra Slimhole Longstring Horizontal 9-5/8", 1 40# Surface X 7", 26# Longstring Formation Markers' /P~~/~~ Formation Tops MD TVD (bkb) ,~' base permafrost 1,8 3 7 1,7 91 "~/~--.,~,,~,.~ _ NA 7,700 3,982 Top of Schrader Bluff Sands (8.3p;~j~,~ Seabee Shale 9,573 4,442 Base of Schrader Bluff Sands (8.3 ppg) HRZ 17,713 6,961 High Resistivity Zone MK-19 17,887 7,111 Top Kuparuk 17,967 7,181 Kuparuk Cap Rock Target Sand -Target 18,117 7,311 Target Sand (9.6 ppg) Total Depth 18,498 7,641 t.;aslng/luDing Fro,( ram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btrc 9692 31/31 9723/4478 8- 1/2" 7" 2 6 # L-80 btrc- 18468 30/30 18498/7641 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 _+7270 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3649 psi is 3284 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface MWD Directional surface to TD. Intermediate N/A Final Cased Hole Logs: MWD Directional and LWD (GR/RES). Downhole WOB and Torque N/A Mudloggers are NOT required for this well. Mud Program' I Special design I None-SPUD MUD considerations 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 9.0 150 35 1 5 30 1 0 1 5 Intermediate Mud Pro3erties' N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~]el ~lel Loss Production Mud Properties: I LSND freshwater mud to horizontal section Density Marsh .,Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.0 50 1 5 1 0 20 9.5 4-6 Well Control' Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional' J KOP: J3oo' Close Approach Well' Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. 1. The base of the Permafrost for all wells located in the Milne Point Unit is _+1,800' TVD. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 2. There are _+26 wells on Milne Pt. 'F' Pad. There may be additional unidentified wells within one quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 3. The wastes to be disposed of during drilling operations can be defined as "DRILLING WASTES". 4. The cement design for this well ensures that annular pumping into hydrocarbon zones will not OCCUr. RECEIVED DEC 02 1996 Alaska 0il & 8as Cons. c0mmis¢0~ Anchore. ge ! , . . , . . , . 10. 11. 12. 13. 14. 15. MP F-54 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head on conductor as well as a nipple to aid in performing potential wellhead stability cement job. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD 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) as well as Downhole Weight on Bit and Downhole Torque. RIH, Drill out Float Equipment and 20' of new formation. Perform FIT to 12.5 ppg. Drill 8.5" hole to TD as per directional plan. Run and Cement 7", 26#, L-80, Buttress-Modified casing. Displace cement with seawater and enough diesel to cover from the base of permafrost to surface. Test casing to 3000 psig. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. MIRU completion. NU & Test BOPE to 5000 psig. Complete well with 2-7/8" tubing. Install Surface Lines and Wellhouse and put the well on production. bRILLING HAZARDS AND RISKS: Seethe 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: MP F-30 will be separated from MP F-54 by 378 feet when MP F-54 is at 10,423' md and 41 0 feet when MP F-54 at 12,781' md. MP F-22 will be separated from MP F-54 by 915 feet when MP F-54 is at 12,781' md. Lost Circulation: There has not been any appreciable amount of lost circulation on any of the F Pad wellls to date. Stuck Pipe Potential: Well MPF-53 was stuck coming out on the shod trip at surface casing point. Proir to this incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed. If significant gravels are encountered stop and raise funnel viscosity to 150 cp viscosity immediately. Formation Pressure: The maximum expected pore pressure for this well is 9.6 ppg EMW (3,649 psi @ 7,311' TVD). There has been no injection in this region, therefore the reservoir pressure should not exceed this estimate. RECEIVED DEC 02. 1996 CASING SPACER: MP F-54 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON SIZE' 9-5/8" CIRC. TEMP 60 deg F at 2840' TVDSS. 75 bbls spacer weighted to mudweight in the hole. 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 1246 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANUULAR VOLUME FROM 100 FEET TVD ABOVE SCHRADER BLUFF TO BASE OF PERMAFROST AT 1800' MD +30% EXCESS +ANNULAR VOLUME FROM 1800' MD TO STAGE COLLAR AT 1300' MD +200% EXCESS. STAGE1 TAIL CEMENT TYPE: PREMIUM 'G' ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: 0.2% CFR-3 + 0.20% HALAD-344 + CELLO-FLAKES 15.8 ppg YIELD'1.15 ft3/sx MIX WATER: 5.0 gal/sk 860 THICKENING TIME: Greater than 4 hrs at 50° F. 100-150 cc FREE WATER: 0 TAIL CEMENT FROM TD TO 100 FEET TVD ABOVE SCHRADER BLUFF + 30% EXCESS + 80'md 9-5/8", 40# capacity for float joints. STAGE2 LEAD: TYPE 'E' PERMAFROST ADDITIVES: Reta rd e r WEIGHT: 12.0 ppg APPROX #SACKS: YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 563 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANUULAR VOLUME FROM STAGE COLLAR AT 1300' MD TO SURFACE+ 200% EXCESS. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED 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/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly - -batch mixing is not necessary. MP F-54 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140° F SPACER: 20 bbls fresh water BHST 170° F at 7040' TVDSS. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE' Premium G ADDITIVES: WEIGHT: 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 213 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 18 joints of 7" casing (36). 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/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: , Single stage cement job is calculated to cover 1000 FT MD above the Kuparuk 'C' Sand with 30% excess. ; ANADRILL ,o. ! · ! . AKA-DPC 'APPROVED · FOR PERMITTING · ONLY ' PLAN C? blPF-54. (P6) 'VERTICAL'SEC TION VIEW Section at: 3431.22 . TVD Sca]e.' I inch = 2000 'feet · , Oep Scale · I ,inch = 2000 feet Drawn ' 26 Nov t996 Harker 'Ident i f 1cation HD BKB SECTN INCLN A ........................ A) KB ' ~ ' ........... 0 0 0:~0 B-- , B) KOP/BUILD ~/~00 300 ' 300 0 0.00 C .... C) BUILD 1.5/103 600 600 8 3.00 .... D ' ~' ' '- ~' D) BUILD 2/100. 900 899 35 7.50 E) END 2/100 BUILD 1810 1767 294 25.6~, t · -4 I .................. iA~E_~d~l,:.tl~ F) BUILD 2.5/100 1860 1B12 316 25 6~ .... ' ........... G) END 2.5/~0D BUILD 3B63 3040 . IBIS 75.7~ F~ ~ ' H) 9-5/8' CASING POINT 9724 4478 7499 ,75.7~ I) DROP 3~00 ~6187 6065 J3765 75.7~ " J) END 3/I00 DROP t77t3 6962 .~4950 30.0( -- - ' "' :- K) TARGET , ' ~8t~8 73~2 ~5~52 30.0( L) l" CASING POINT ~8498' 7641 ~5343 30.0( H} TO ' 18498 7641 15343 30.0( -~ - ~ .... ~s~ ~ ~- ~41~ . · . . -~~:~-~:': ~~~'~.~'~~ ....... ,:.:~ :: ............. ~.~:: ........ :: ====================== ~: ~: .... ::::::::::::: :::::::::::::::::::::::::::::::::::: I I .! o looo 2ooo 3000 4ooo 5000 6oo0 7ooo BO00 9000 tO000 Section Departure (Anadrll] (c)96 NPF54P6 3.0~.08 1~:09 AN P) 200 eet ) Z 0 I I .1~ J, 'Nov-26'-96 11=21A Anad~ll DPC 907_344 2160 P.21 Marker Identification A) END 3/100 DROP B) TARGET C) 7' CASING POINT D} TD "o """ ~" '""~" MPF-54 (P6) 177t3 6962 14950 30.00 ,~,~ ~ ,~,~ ~o.oo VERTICAL SECTION VIEW ~B~g8 764~ ~5343 3o.oo ,, , ~8498 7641 ~5343 30.00 Section at: 343.~2 TVD Sca]e.: ~ inch : 200 feet Dep Scale.: ~ inch = 200 feet i4200 1,~300 34400 -34500 14600 14700 i,4800' J4900 i5000 J§JO0 J§200 i5300 J5400 {5500 t5600 ' ' Section Departure · [Ana~ri]] {cig6 ~F54P6 3.Ob. OB Ii: tO AN PJ RECEIVED ,-.,-.. 0 2 199~ Alaska 011 & (~s Corm. Commissior, AHchorage 907 3J4 2160 P.22 Nov-26-96 11:22A Anadri~-q DPC c) · D) -E) F) G) H) I) J) K) L) H) "SHARED' SEt, VICES ii · Hanker I~nt~f~catlon Al KB B) KOP/BUILD 1/100 BUILD 1.5/100 BUILD 2/~00 END 2/~00 BUILD BUILD 2.5/~00 END 2.§/I00 BUILD 9-5/8" CASING POINT DROP 3/~00 END 3/100 DROP TARGET 7' CASING POIN! TD mm m I mm MD N/S E/W o o. 300 0 N 600 8 N 1860 302 N 91 3863 174t N 525 9724 7180 N 2~65 16~87 13~79 N 3973 177~3 143~4 N 4316 18118 14507 N 4374 ~8498 t4689 N 4429 18498 ~4689 N 4429 ii DRILLING i ~ m! · ! · · MPF-54 (P.6) PLAN VIEW CLOSURE ' ~53~ feet at Azimut~ 3q3.22 DECLINATION.' +28.122 (E) SCALE · I ~nch : 2500 feet DRAWN · 26 Nov 1996 im Anadri ]1 Schlumberger m m Il . · . .. . -. .-- ~-. .. 8750 "7500 . . ::6250 -" 5000.- ' 3750. 2500 J250 0 t250 2500 3750 ' . 5000 6250 7500 8750 · <- WEST' EAST -> . N lOBO0. O0 -i- + .4- N 9800.00 LEGEND AS-BUILT CONDUCTOR · EXISTING CONDUCTOR .I.D, ' F PAD ' · 78 · 77 · 70 · 69 · 62 · 61 54 + · 53 · 48 · 45 · 38 · 57 · 30 m 22 ·14 · 25 · 1 J.q*;)/ r, lu ·L,lUq I'",UZ ! I SIMPSON !LACOONj + VICINITY MAP ------ -,-_SURVEYOR'S C_..T .... ~ ..... I HEREBY CERTIFY T.' PROPERLY REGISTERE;...'..:,..'. "; ........ TO PRACTICE LAND E;URVEY, N~ i'.' THE STATE OIr ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIREC3 SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF'APRIL 7, 1996 NOTES 1. DATE OF SURVEY; APRIL ?, l gg6. 2. REFERENCE FIELD BOOK: MPg6-o~ (pgs, 32-36). 3. ALASKA STATE PLANE COOEDINAT£S ARE ZONE 4., NAD 2'/. 4. GEODETIC'-COORDINATES ARE NAD 1927. 5. PAD SCALE FACTOR IS 0.ggggoIgg. 6. HORIZONTAL/VERTICAL CONTROL IS BASED ON MONUMENTS L-1 NORTH AND L-2 SOUTH. LOCATED WITHIN PROTRACTEO SEC. 061 T. 13 N.I, ~. 10 E.r UMIAT MERIDIAN ALASKA WI~LL A.S.P. PLANT G'EOOETIC ' GEOD~'TIC CELLAR ' SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D. DD) BOX ELEV. OFFSETS xY: 6,035,275.21 N=10,060.05 70'30'26.250" 70'5072917° 12.5' 1,824' FSL F-lC 541~709.47 E= 4~999.95 14.9'39'31.505" 149.6587514' 2~855' FEL Y=6,035,324.04 N:10,119.96 70'50'26.728' 70.5074244.' 1,872' FSL F'IB X- 54..1,7.4.4..20 E 5,000.06 149'3cJ'30.474" 149.6584650' 12.4' 2,820' FEL F-54 Y-6,035,544..26 N,,I0,389.90 70'30'28.886' 70.5080239' 2,092' FSL X- 541fgDO.22 E- 5,000.03 149'39'25.843" 149.6,571786' 12.1' 2~662' FEL ~:I'I~AL AS BUg,.T ISSUE R[VI~OW DRAIn: JACOBS ,. BP EXPLORATION [3A~t.:: 4/10/91~ ..... ~'~'~ MILNE POINT UNIT F-PAD ,~.~, CONDUCTOR AS-BUILT ~"-2oo' WELL NO. 10, 18 & 54 WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION INIT CLASS .~:_~,/ /- ,,'~?/ GEOL AREA C~ g",) UNIT# -- //:.~ .~__~' ON/OFF SHORE ! A,~R DATE -ENGiNEERi~G . . 1. Permit fee attached ....................... N 2_ Lea.se number appropriate .................... Y' N ,3. Unique we~ name and number ................. N 4. Well Ioc~t~ in a dot, ned pool .................. N 5. Well located proper distance from ddg unit boundary ..... Y N 6. Well located proper distance from other we~s ......... Y N 7. Sufficient acreage available in driBng unit. ........... N 8. if deviated, is wellbore plat included .............. N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. .IYt N 11. Permit ca~ be issued wil~out conservation order ...... ~yyY N 12_ Permit can be issued with~ administmth/e approval .... N 13. Can permit be approved before 15-day walt. ........ N REMARKS 'GEOLOGY ....... APPR 14. 1.5. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 2_~. 29. Conductor string provided .................. ~)N Surface casing protects all known USDWs ......... ~ N CMT vol adequate to circuS, to on conductor & surf csg . . . ~ N jt./~ -- CMT vol adequate to l~e-in long s~ing to surf csg ...... CMT will cover all known productive horizons. ........ (.:~N Casing designs adequste for C, T, B & ~ ..... ~ N , Adequate t~nk~ge or reserve pit. ............... /r~ N If a re<frill, has a 10-403 for abndnmnt been approved .... Adequate wellbore separation proposed ............ if diverter required, is it adequate ................ Drilling fluid program scherr~c & equip list adequate .... BOPEs adequate ........................ BOPE press ralJng ~lequate; test to ,~'-C~ psig. Choke ma.~old complies w/APl RP-53 (May 84) ....... Work will occur without operation shutdown .......... ( Is presence of H2S gas probable ............... ~ N 30. Permit can be issued w/o hydrogen sulfide measles ..... Y N 31. DAt~ presented on poten~al overpressure zones ....... Y N 32_ Seismic Analysis of shallow gas zones ............. Y N 33. Seabed condilJon survey (if off-shore) ............. Y N 34. Comact name/phone for weekJv~ progress repoT ,. ...... Y N lex~/orat~ry on/y/ "- Y'7 z--7 GEOLOGY: ENGINEERING: COMMISSION: JDH ~ JDN '" TAB '~ Comments/Instructions: HOW4jb- A.~r-ORM,5"ct-,e~ my 4,'96 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. ECE VED MAR 2 7 1997 ......................... .g,~. Oii& Gas Cons~ . . * ~S~ COMP~ING CENTER * . ****************************** . ............................ . * ....... SCHL~BERGER ....... * . ............................ . ****************************** COMPANY NAME : B.P. EXPLORATION WELL NAME : MPF- 54 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUlViBER : 50-029-22726-00 REFERENCE NO : 97066 Date. * ALASKA COMPUTING CENTER * * ****************************** * ............................ * ....... SCHLUMBERGER * ............................ * ****************************** COMPANY NAME : B.P. EXPLORATION WELL NAME : MPF-54 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NLrMBER : 50-029-22726-00 REFERENCE NO : 97066 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-MAR-1997 15:13 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/03/19 ORIGIN : FLIC REEL NAblE : 97066 CONTINUATION # : PREVIOUS REEL : COb~_2VT : B.P. EXPLORATION, MILNE POINT MPF-54, API #50-029-22726-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/03/19 ORIGIN · FLIC TAPE NAM~ : 97066 CONTINUATION # : 1 PREVIOUS TAPE : COb~VlENT · B.P. EXPLORATION, MILNE POINT MPF-54, API #50-029-22726-00 TAPE HEADER MILNE POINT MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL : FEL : FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MPF-54 500292272600 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES 19-MAR-97 BIT RUN1 97066 COOPER DIXON BIT RUN2 ......... 97066 BOSSE/ST. AM DIXON BIT RUN 3 ......... 6 13N 10E 2092 2662 41.22 41.22 12.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 9903.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-MAR-1997 15:13 3RDSTRING PRODUCTION STRING Well drilled 12-JAN through 19-JAN-97 with MWD GR AND CDR/ADN. Data was collected in two bit runs (MWD GR data combined as one bit run). $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 97/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUAE4ARY LDWG TOOL CODE .............. $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 213.0 18466.0 BASELINE DEPTH .............. 88888.0 18249.0 18244.0 18239.5 18143.5 18120.5 18113.0 18103.5 18074.5 18066.0 18008.5 17984.0 17967.0 17952.0 17944.0 17927.5 17895.0 17891.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... MWD ....... 88924.0 18285.0 18276.5 18272.5 18176.0 18156.5 18148.5 18138.0 18109.5 18100.5 18043.0 18018.5 18000.0 17986.0 17977.5 17962.0 17929.5 17925.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17861.0 17896.0 17824.0 17855.5 17774.5 17805.5 17753.0 17785.0 17743.5 17774.5 17716.0 17748.0 17704.0 17735.5 17689.5 17722.0 17634.0 17665.0 17628.5 17660.5 17614.5 17644.5 17609.0 17641.5 17599.0 17630.0 17564.5 17594.0 17553.0 17583.0 17479.0 17507.5 17450.0 17478.0 17443.5 17472.0 17420.0 17450.0 17365.0 17398.5 17344.0 17376.5 17260.0 17292.5 17250.5 17283.5 17241.5 17274.0 17184.5 17216.5 17159.5 17192.5 17155.5 17190.0 17141.5 17174.0 17103.5 17134.0 17087.5 17118.5 17081.5 17112.0 17073.5 17105.5 17003.5 17036.0 16988.5 17019.5 16972.5 17005.0 16954.0 16987.0 16885.0 16922.0 16801.5 16835.5 16788.0 16820.0 16781.0 16813.5 16778.5 16812.0 16768.0 16799.5 16745.0 16776.5 16732.0 16763.0 16702.5 16734.5 16689.5 16723.0 16675.5 16707.0 16669.0 16700.5 16665.0 16698.0 16603.5 16637.5 16596.5 16629.5 16594.0 16626.0 16534.5 16566.5 16511.0 16544.0 16491.0 16522.0 19-MAR-1997 15:13 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 16480 5 16473 0 16392 5 16381 5 16371 5 16351 5 16322 5 16302 5 16129 0 15915 5 15887 0 15870 0 15866.5 15864.0 15849.0 15840.5 15836.5 15824.0 15799.5 15739.0 15726.0 15688 5 15652 5 15648 5 15641 0 15624 0 15598 0 15584 0 15568.5 15548.0 15519.0 15489.0 15480.5 15470.0 15400.0 15364.0 15338.0 15281.0 15150.5 15134.5 15105.0 15065.5 15047.5 15025.0 14987.0 14931.0 14836.5 14829.5 14824.5 14764.5 14742.0 14712.0 14703.5 14699.5 14624.5 16513.0 16506.5 16427.0 16414.5 16406.5 16386.5 16358.0 16336.0 16158.5 15946.5 15918.5 15901.0 15895.5 15894.0 15877.0 15866.0 15863.0 15849.5 15825.5 15768.0 15757.0 15721.5 15684.5 15680.0 15673.0 15661.5 15630.0 15615.5 15602.0 15578.0 15554.5 15523.0 15512.0 15501.5 15433.0 15396.0 15371.5 15312.5 15184.0 15169.0 15137.5 15095.5 15080.0 15059.0 15020.5 14966.5 14869.5 14860.0 14854.5 14794.5 14769.0 14742.5 14735.0 14729.5 14655.0 19-MAR-1997 15:13 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 14563 0 14556 5 14506 0 14384 5 14335 5 14290 5 14287 0 14266 0 14148 0 14140.5 14106.0 14044.0 13987.5 13913.0 13879.5 13859.5 13840.0 13792.0 13755.0 13737.0 13708.5 13577.5 13537.0 13527.5 13512.0 13491.0 13342.5 13310.0 13260.5 13237.5 13224.5 13212.0 13118.5 13104.5 12995.0 12989.5 12984.5 12952.0 12916.0 12842.5 12787.0 12728.0 12574.0 12538.5 12463.5 12448.0 12332.0 12249.5 12114.5 12096.5 12058.0 12024.0 11988.0 11962.0 11951.5 14593.5 14588.5 14537.0 14417.0 14367.0 14325.0 14322.0 14302.0 14178.0 14170.0 14135.5 14071.0 14011.5 13935.5 13904.5 13885.0 13869.0 13824.5 13786.5 13767.5 13738.0 13606.0 13565.5 13554.5 13538.0 13516.5 13370.0 13339.5 13287.5 13265.5 13252.0 13240.5 13148.5 13134.5 13023 5 13021 0 13014 5 12982 5 12949 0 12872 5 12817 0 12756 0 12605 0 12569.0 12493.5 12478.5 12358.5 12277.0 12143.5 12129.0 12091.0 12054.0 12018.0 11990.5 11979.0 19-MAR-1997 15:13 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-MAR-1997 15:13 PAGE: 11846.5 11723.5 11581.0 11533.5 11491.0 11478.0 11451.0 11398.0 11343.5 11167.0 11072.0 11034.5 10986.5 10902.0 10866.5 10849.0 10818.0 10665.5 10616.5 10476.0 10448.5 10362.5 10346.5 10307.0 10274.5 10208.5 10088.5 10026.0 9963.5 9936.0 9902.0 9777.0 213.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ 11877.5 11751.5 11607.5 11560.5 11519.0 11507.5 11480.0 11432. 0 11375. 0 11193.5 11099.5 11060.0 11014.0 10927.0 10888.5 10875.5 10846.5 10690.5 10641.5 10504.5 10479.5 10393.0 10375.5 10337.5 10304.5 10239.5 10114.0 10052.0 9996.5 9968.0 9930.0 9800. 0 213.0 BIT RUN NO. MERGE TOP MERGE BASE 1 213.0 9918.0 2 9831.0 18466.0 The depth adjustments shown above reflect the MWD GR to the PDC GRCH logged by SWS. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. The ADN quadrant outputs are as follows: ROBB/ROBU/ROBL/ROBR are bottom, upper, left, and right quadrant density; and are also listed as RHO1, RH02, RH03, RH04 in the LDWG listing. The other outputs (Delta Rho, PEF, Max. Density) are listed with their quadrants as DRHB/DRHU/DRHL/DRHR, PEB/PEU/ PEL/PER, and ROMB/ROMU/ROML/ROPIR. The LDWG outputs of CALA and CALS are HDIA and VDIA respectively. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-MAR-1997 15:13 PAGE: 7 LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN B.P. EXPLORATION Company Name FN MILNE POINT Field Name WN MPF-54 Well Name APIN 50-029-22726-00 API Serial Number FL 2092' FSL & 2662' FEL .Field Location SECT 6 Section TOWN 13N Township RANG iOE Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on LATI 70. 50802 Lati rude LONG 149.65718 Longitude WITN DIXON Witness Name SON 039095 Service Order Number PDAT MEAN SEA LEVEL Permanent datum EPD FT O. Elevation of Permanent Datum LMF DRILL FLOOR Log Measured From APD FT 41.22 Above Permanent Datum EKB FT 41.22 Elevation of Kelly Bushing EDF FT 41.22 Elevation of Derrick Floor EGL FT 12.1 Elevation of Ground Level TDD FT 18430. Total Depth - Driller TDL FT 18430. Total Depth - Logger BLI FT 18430. Bottom Log Interval TLI FT 213. Top Log Interval DFT LSArD Drilling Fluid Type DFD G/C3 9.800001 Drilling Fluid Density DFV S 45. Drilling Fluid Viscosity RMS OH~q 1.85 Resistivity of Mud Sample MST DEGF 70. Mud Sample Temperature RMFS OH~4PI 1.63 Resistivity of Mud Filtrate S MFST DEGF 70. Mud Filtrate Sample Temperatu TCS 1700 18-JAN-97 Time Circulation Stopped TLAB 0145 18-JAN-97 Time Logger at Bottom BHT DEGF 155. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth FET TIME AFTER BIT RESISTIVITY RA CDR ATTN RESISTIVITY RP CDR PHSF RESISTIVITY LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-MAR-1997 15:13 PAGE: DEFI QRO VERY ENHANCED AMPLITUDE RESISTIVITY QRO VERY ENHANCED PHASE RESISITIVTY DIELECTRIC RESISITIVTY RATE OF PENETRATION Gamma Ray VRA VRP DER ROP GR RHOB RHO1 RH02 RH03 RH04 DRHO PEF DCAL CALS CALA NPHI RHOB LOWER QUAD RHOB UPPER QUAD RHOB LEFT QUAD RHOB RIGHT QUAD Differential Caliper Thermal Neutron Porosity ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME 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 039095 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 039095 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD O H~ff~039095 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-MAR-1997 15:13 PAGE: 9 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) RP MWD 0H~4~039095 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD 0HI~1039095 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~4 039095 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD 0HT~1039095 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 039095 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 039095 O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 039095 O0 000 O0 0 1 1 1 4 68 0000000000 RHO1 MWD G/C3 039095 O0 000 O0 0 1 1 1 4 68 0000000000 RH02 MWD G/C3 039095 O0 000 O0 0 1 1 1 4 68 0000000000 RH03 MWD G/C3 039095 O0 000 O0 0 1 1 1 4 68 0000000000 RH04 MWD G/C3 039095 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOI4WD G/C3 039095 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 039095 O0 000 O0 0 1 1 1 4 68 0000000000 DCALMWD IN 039095 O0 000 O0 0 1 1 1 4 68 0000000000 CALSMWD IN 039095 O0 000 O0 0 1 1 1 4 68 0000000000 CALAMWD IN 039095 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 039095 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 18466.000 FET.MWD -999.250 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 130.446 GR.MWD -999.250 RHOB.MWD -999.250 RHO1.MWD -999.250 RHO2.MWD -999.250 RHO3.MWD -999.250 RHO4.MWD -999.250 DRHO.MWD -999.250 PEF.MWD -999.250 DCAL.MWD -999.250 CALS.MWD -999.250 CALA.MWD -999.250 NPHI.MWD -999.250 DEPT. 18000.000 FET.MWD VRA.MWD 3.396 VRP.MWD GR.MWD 102.777 RHOB.MWD RHO3.MWD 2.464 RHO4.MWD DCAL.MWD 0.712 CALS.MWD 0.723 RA.MWD 2.588 RP.MWD 2.973 3.250 DER.MWD 2.809 ROP.MWD 127.690 2.543 RHO1.MWD 2.549 RHO2.MWD 2.441 2.518 DRHO.MWD 0.043 PEF.MWD 3.377 11.136 CALA.MWD 11.136 NPHI.MWD 34.900 DEPT. 15000.000 FET.MWD VRA.MWD 2.906 VRP.MWD GR.MWD 105.033 RHOB.MWD RHO3.MWD 2.446 RHO4.MWD DCAL.MWD 0.456 CALS.MWD 0.496 RA.MWD 3.021 RP.MWD 3.306 3.209 DER.MWD 3.194 ROP.MWD 219.494 2.452 RHO1.MWD 2.484 RHO2.MWD 2.331 2.421 DRHO.MWD 0.079 PEF.MWD 3.315 11.203 CALA.MWD 12.003 NPHI.MWD 34.700 DEPT. 12000. 000 FET.MWD VRA . MWD 5. 509 VRP . MWD GR.MWD 100.550 RHOB.MWD RH03 .MWD 2. 408 RH04 .MWD DCAL.MWD O. 323 CALS.MWD 0.486 RA.MWD 4.999 RP.MWD 5.861 5.961 DER.MWD 5.633 ROP.MWD 224.986 2.403 RHO1.MWD 2.402 RHO2.MWD 2.393 2.426 DRHO.MWD 0.020 PEF.MWD 3.185 9.735 CALA.MWD 10.136 NPHI.MWD 34.800 DEPT. 9000.000 FET.MWD -999.250 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 92.730 GR.MWD 105.920 RHOB.MWD -999.250 RHO1.MWD -999.250 RHO2.MWD -999.250 RHO3.MWD -999.250 RHO4.MWD -999.250 DRHO.MWD -999.250 PEF.MWD -999.250 DCAL.MWD -999.250 CALS.MWD -999.250 CALA.MWD -999.250 NPHI.MWD -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-MAR-1997 15:13 PAGE: 10 DEPT. 6000.000 FET.MWD VRA.MWD -999.250 VRP.MWD GR.MWD 45.080 RHOB.MWD RHO3.MWD -999.250 RHO4.MWD DCAL.MWD -999.250 CALS.M~fD DEPT. 3000.000 FET.MWD VRA.MWD -999.250 VRP.MWD GR.MWD 33.760 RHOB.MWD RHO3.MWD -999.250 RHO4.MWD DCAL.MWD -999.250 CALS.MWD DEPT. 213.000 FET.MWD V~A.MWD -999.250 VRP.MWD GR.MWD 30.980 RHOB.MWD RHO3.MWD -999.250 RHO4.MWD DCAL.MWD -999.250 CALS.MWD -999.250 RA.f4WD -999.250 DER.~TWD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 CALA.MWD -999.250 RA.MWD -999.250 DER.MWD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 CALA.MWD -999.250 RA.MWD -999.250 DER.MWD -999.250 RHOi.~WD -999.250 DRHO.MWD -999.250 CALA.~4WD -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 .250 RP.~fWD .250 ROP.I~WD .250 RHO2.MWD .250 PEF.MWD .250 NPHI.~fWD .250 RP.MWD .250 ROP.MWD .250 RHO2.MWD .250 PEF.MWD .250 NPHI.MWD .250 RP.~gWD .250 ROP.MWD .250 RHO2.MWD .250 PEF.MWD .250 NPHI.MWD -999.250 218.390 -999.250 -999.250 -999.250 -999.250 453.540 -999.250 -999.250 -999.250 -999.250 136.960 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME '. EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 97/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NU~ER: 1 DEPTH INC~: 0.5000 FILE SOI~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-MAR-1997 15:13 PAGE 11 MWD 213.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (~ORY 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 GR GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 9900.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: *********MWDGR RUN1 ************* DRILLED INTERVAL 212' - 9900' GR AND ROP INTERPOLATED AT AK ICS $ LIS FORMAT DATA 19-JAN-97 FAST 4.0 4. OC REAL- TIME 18430.0 213.0 18430.0 70 0.2 76.2 TOOL NUMBER ........... DSS 8.500 9903.0 LSND 9.80 45.0 1. 850 70.0 1.630 70.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-MAR-1997 15:13 PAGE: 12 TABLE TYPE : CONS TUNI VALU DEFI CN B.P. EXPLORATION Company Name FN MILNE POINT Field Name WN MPF-54 Well Name APIN 50-029-22726-00 API Serial Number FL 2092' FSL & 2662' FEL Field Location SECT 6 Secti on TOWN 13N Township RANG 10E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on LATI 70. 50802 Lati rude LONG 149. 65718 Longi rude WITN DIXON Wi tness Name SON 039095 Service Order Number PDAT MEAN SEA LEVEL Permanent datum EPD FT O. Elevation of Permanent Datum LMF DRILL FLOOR Log Measured From APD FT 41.22 Above Permanent Datum EKB FT 41.22 Elevation of Kelly Bushing EDF FT 41.22 Elevation of Derrick Floor EGL FT 12.1 Elevation of Ground Level TDD FT 18430. Total Depth - Driller TDL FT 18430. Total Depth - Logger BLI FT 18430. Bottom Log Interval TLI FT 213. Top Log Interval DFT LSND Drilling Fluid Type DFD G/C3 9. 800001 Drilling Fluid Density DFV S 45. Drilling Fluid Viscosity RMS O~ 1.85 Resistivity of Mud Sample MST DEGF 70. Mud Sample Temperature RMFS OHI4M 1.63 Resistivity of Mud Filtrate S MFST DEGF 70. Mud Filtrate Sample Temperatu TCS 1700 18-JAN-97 Time Circulation Stopped TLAB 0145 18-JAN-97 Time Logger at Bottom BHT DEGF 155. Bottom Hole Temperature TABLE TYPE : CURV DEFI ........................................................... DEPT Dep th ROPE RATE OF PENETRATION ROP5 GRIN Gamma Ray GRRW None Identified Channel Name to assure the Compatibility with LOS LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-MAR-1997 15:13 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E 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 039095 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW1 F/HR 039095 O0 000 O0 0 2 1 1 4 68 0000000000 ROP5 LW1 F/HR 039095 O0 000 O0 0 2 1 1 4 68 0000000000 GRIN LW1 GAPI 039095 O0 000 O0 0 2 1 1 4 68 0000000000 GRRW LW1 039095 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9900.000 GRRW. LW1 -999.250 DEPT. 9000.000 GRRW. LW1 -999.250 DEPT. 6000.000 GRRW. LW1 -999.250 DEPT. 3000.000 GRRW. LW1 -999.250 ROPE. LW1 88.830 ROP5. LW1 88.830 GRIN. LW1 ROPE. LW1 121. 550 ROPS. LW1 121. 550 GRIN. LW1 ROPE. LW1 283. 290 ROPS. LW1 283. 290 GRIN. LW1 ROPE.LW1 245.110 ROPS.LW1 245.110 GRIN. LW1 -999.250 102. 865 57.018 35.310 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-MAR-1997 15:13 PAGE: 14 DEPT. 212. 000 ROPE. LW1 GRRW. LW1 30. 980 171.710 ROPS.LW1 171.710 GRIN. LW1 30. 980 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE · 97/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE · 97/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SOW2~ARY VENDOR TOOL CODE START DEPTH MWD 9805.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: STOP DEPTH 18430.0 19-JAN-97 FAST 4.0 4.0 MEMORY 18430.0 213.0 18430.0 70 31.9 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-MAR-1997 15:13 PAGE: 15 MAXIMUM ANGLE: 76.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR ADN NEUT./AZIM. DENS. $ TOOL NUMBER RGS059 ADN059 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) 8.500 9903.0 BOREHOLE COArDITIONS MUD TYPE '. LSArD MUD DENSITY (LB/G): 9.80 MUD VISCOSITY (S) : 45.0 MUD PH: MUD CHLORIDES (PPM) : 2000 FLUID LOSS (C3): RESISTIVITY (Otff4~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 1. 850 MUD AT MAX CIRCULATIONG TEDIPERATURE : MUD FILTRATE AT (MT): 1. 630 MUD CAKE AT (MT): 70.0 70.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 0.3 EWR FREQUENCY (HZ): 20000 REMARKS: *********LWD - RUN 2 ************* DRILLED INTERVAL 9918' - 18430' HOLE ANGLE AT TD = 31.89 DEG @ 18430' RES TO BIT: 56.90'; GR TO BIT: 67.32' NEUT TO BIT: 114.73'; DENS TO BIT: 110.60' TD WELL @ 0145 18-JAN-97 GR CORRECTED FOR HOLE SIZE AND MUD WEIGHT TNPH CORRECTED FOR HOLE SIZE, HI, AND MUD SALINITY $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN FN WN APIN B.P. EXPLORATION MILNE POINT MPF-54 50-029-22726-00 Company Name Field Name Well Name API Serial Number LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-MAR-1997 15:13 PAGE: 16 TUNI VALU DEFI FL 2092' FSL & 2662' FEL Field Location SECT 6 Sec tion TOWN 13N Town ship RANG 10E Range COON NORTH SLOPE County STAT ALASKA State or Province NA TI USA Nat i on LATI 70. 50802 Lati rude LONG 149. 65718 Longi rude WITN DIXON Wi tness Name SON 039095 Service Order Number PDAT MEAN SEA LEVEL Permanent datum EPD FT O. Elevation of Permanent Datum LMF DRILL FLOOR Log Measured From APD FT 41.22 Above Permanent Datum EKB FT 41.22 Elevation of Kelly Bushing EDF FT 41.22 Elevation of Derrick Floor EGL FT 12.1 Elevation of Ground Level TDD FT 18430. Total Depth - Driller TDL FT 18430. Total Depth - Logger BLI FT 18430. Bottom Log Interval TLI FT 213. Top Log Interval DFT LSND Drilling Fluid Type DFD G/C3 9. 800001 Drilling Fluid Density DFV S 45. Drilling Fluid Viscosity RMS OHT4~I 1.85 Resistivity of Mud Sample MST DEGF 70. Mud Sample Temperature RMFS OFff4~I 1.63 Resistivity of Mud Filtrate S MFST DEGF 70. Mud Filtrate Sample Temperatu TCS 1700 18-JAN-97 Time Circulation Stopped TLAB 0145 18-JAN-97 Time Logger at Bottom BHT DEGF 155. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT ATR PSR ATVR PSVR DER ROPE GR TABR ROFiB ROBB ROBU ROBL ROBR Depth CDR ATTN RESISTIVITY CDR PHSF RESISTIVITY QRO VERY ENHANCED AMPLITUDE RESISTIVITY QRO VERY ENHANCED PHASE RESISITIVTY DIELECTRIC RESISITIVTY RATE OF PENETRATION Gamma Ray TIME AFTER BIT RESISTIVITY RHOB LOWER QUAD RHOB UPPER QUAD RHOB LEFT QUAD RHOB RIGHT QUAD LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-MAR-1997 15:13 PAGE: 17 DEFI DRHB DRHU DRHL DRHR PEB PEU PEL PER TNPH Thermal Neutron Porosit}~ TNRA Thermal Neutron Ratio Calibrated DCAL Differential Caliper PiD I A VDIA RPM ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 112 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** 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 039095 O0 000 O0 0 3 1 1 4 68 0000000000 ATR LW2 OHMM 039095 O0 000 O0 0 3 1 1 4 68 0000000000 PSR LW2 0t~4M039095 O0 000 O0 0 3 1 1 4 68 0000000000 ATVRLW2 OHI4M039095 O0 000 O0 0 3 1 1 4 68 0000000000 PSVR LW2 OH~ff4 039095 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-MAR-1997 15:13 PAGE: 18 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) O0 000 O0 0 3 1 1 4 68 0000000000 DER LW2 0H~I039095 ROPE LW2 F/HR 039095 O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI 039095 O0 000 O0 0 3 1 1 4 68 0000000000 TABR LW2 039095 O0 000 O0 0 3 1 1 4 68 0000000000 RO~IBLW2 G/C3 039095 O0 000 O0 0 3 1 1 4 68 0000000000 ROBB LW2 G/C3 039095 O0 000 O0 0 3 1 1 4 68 0000000000 ROBU LW2 G/C3 039095 O0 000 O0 0 3 1 1 4 68 0000000000 ROBL LW2 G/C3 039095 O0 000 O0 0 3 1 1 4 68 0000000000 ROBR LW2 G/C3 039095 O0 000 O0 0 3 1 1 4 68 0000000000 DRHB LW2 G/C3 039095 O0 000 O0 0 3 1 1 4 68 0000000000 DRHULW2 G/C3 039095 O0 000 O0 0 3 1 1 4 68 0000000000 DRHL LW2 G/C3 039095 O0 000 O0 0 3 1 1 4 68 0000000000 DPJ4RLW2 G/C3 039095 O0 000 O0 0 3 1 1 4 68 0000000000 PEB LW2 039095 O0 000 O0 0 3 1 1 4 68 0000000000 PEU LW2 039095 O0 000 O0 0 3 1 1 4 68 0000000000 PEL LW2 039095 O0 000 O0 0 3 1 1 4 68 0000000000 PER LW2 039095 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH LW2 PU 039095 O0 000 O0 0 3 1 1 4 68 0000000000 TNRALW2 039095 O0 000 O0 0 3 1 1 4 68 0000000000 DCALLW2 IN 039095 O0 000 O0 0 3 1 1 4 68 0000000000 HDIA LW2 IN 039095 O0 000 O0 0 3 1 1 4 68 0000000000 VDIA LW2 IN 039095 O0 000 O0 0 3 1 1 4 68 0000000000 RPM LW2 RPM 039095 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 18430.000 ATR.LW2 -999.250 PSR.LW2 -999.250 ATVR.LW2 PSVR.LW2 -999.250 DER.LW2 -999.250 ROPE.LW2 130.446 GR.LW2 TABR.LW2 -999.250 ROMB.LW2 -999.250 ROBB.LW2 -999.250 ROBU. LW2 ROBL.LW2 -999.250 ROBR.LW2 -999.250 DRHB.LW2 -999.250 DRHU. LW2 DRHL.LW2 -999.250 DRHR.LW2 -999.250 PEB.LW2 -999.250 PEU. LW2 PEL.LW2 -999.250 PER.LW2 -999.250 TNPH.LW2 -999.250 TNRA.LW2 DCAL.LW2 -999.250 ttDIA.LW2 -999.250 VDIA.LW2 -999.250 RPM. LW2 DEPT. PSVR . LW2 TABR . LW2 ROBL. LW2 DRHL. LW2 PEL. LW2 DCAL. LW2 DEPT. PSVR . LW2 TABR. LW2 ROBL. LW2 DRHL . LW2 PEL . LW2 DCAL. LW2 18000 000 2 298 1 744 2 457 0 134 4 509 0.734 15000. 000 2. 830 0.328 2. 431 O. 060 3.170 0.190 ATR. LW2 2.384 PSR. LW2 2. 296 ATVR. LW2 DER.LW2 2.328 ROPE.LW2 146.344 GR.LW2 ROMB. LW2 2. 543 ROBB . LW2 2. 561 ROBU. LW2 ROBR. LW2 2. 503 DRHB. LW2 O. 035 DRHU. LW2 DRHR. LW2 O. 093 PEB. LW2 2. 856 PEU. LW2 PER.LW2 3. 738 TNPH. LW2 35.800 TNRA.LW2 HDIA. LW2 11. 069 VDIA. LW2 11. 870 RPM. LW2 ATR . LW2 DER. LW2 ROMB. LW2 ROBR. LW2 DRHR. LW2 PER. LW2 HDIA. LW2 2 742 2 802 2 427 2 427 0 048 3 071 11 815 PSR. LW2 2.839 ATVR. LW2 ROPE. LW2 160.202 GR.LW2 ROBB. LW2 2. 443 ROBU. LW2 DRHB . LW2 0.016 DRHU. LW2 PEB.LW2 2.870 PEU. LW2 TNPH.LW2 37. 700 TNRA.LW2 VD IA . LW2 11. 656 RPM. LW2 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 2.374 117.995 2.384 0.231 5.891 22.041 80.333 2.657 105.213 2.370 0.068 3.100 22.714 90.577 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-MAR-1997 15:13 PAGE: 19 DEPT. 12000. 000 ATR.LW2 PSVR . LW2 - 999.250 DER. LW2 TABR . LW2 O . 592 ROMB . LW2 ROBL . LW2 2. 396 ROBR . LW2 DRHL . LW2 O . 102 DRHR . LW2 PEL . LW2 3.210 PER. LW2 DCAL . LW2 O . 528 HDIA . LW2 DEPT. PSVR LW2 TABR LW2 ROBL LW2 DRHL LW2 PEL LW2 DCAL LW2 9804. 000 ATR. LW2 -999. 250 DER. LW2 -999. 250 ROMB. LW2 -999. 250 ROBR. LW2 -999. 250 DRHR. LW2 -999. 250 PER. LW2 -999. 250 PiDIA. LW2 3.286 PSR . LW2 3.369 ROPE. LW2 2. 404 ROBB.LW2 2.375 DRHB . LW2 O. 046 PEB. LW2 2.912 TNPH . LW2 10. 803 VDIA. LW2 -999.250 PSR.LW2 -999.250 ROPE.LW2 -999.250 ROBB.LW2 -999.250 DRHB.LW2 -999.250 PEB.LW2 -999.250 TNPH.LW2 -999.250 VDIA.LW2 3 417 ATVR. 269 083 GR. 2 421 ROBU. 0 O17 DRHU. 3 029 PEU. 36 700 TNRA. 10 469 RPM. -999 250 ATVR. -999 250 GR. -999 250 ROBU. -999 250 DRHU. -999 250 PEU. -999 250 TNRA. -999 250 RPM. LW2 LW2 LW2 LW2 LW2 LW2 LW2 LW2 LW2 LW2 LW2 LW2 LW2 LW2 3.363 93.996 2.344 0.146 3.156 22.370 97.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/03/19 ORIGIN : FLIC TAPE NAME : 97066 CONTINUATION # : 1 PREVIOUS TAPE : COI~_aVT : B.P. EXPLORATION, MILNE POINT MPF-54, API #50-029-22726-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/03/19 ORIGIN : FLIC REEL NA~E : 97066 CONTINUATION # : PREVIOUS REEL : CO~4ENT : B.P. EXPLORATION, MILNE POINT MPF-54, API #50-029-22726-00
