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Home My WebLink About196-0401. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP Swap Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7,875 feet N/A feet true vertical 7,360 feet N/A feet Effective Depth measured 7,780 feet 7,531 feet true vertical 7,274 feet 7,054 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 7,280' 6,827' Packers and SSSV (type, measured and true vertical depth)7" BWD Sump N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:MP K-13 AOGCC 10 40415. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: N/A 3,090psi 5,410psi 5,750psi 7,240psi7,861' 7,352' Burst N/A 3,723'Surface Production 20" 9-5/8" 7" 78' 3,691' MILNE PT UNIT K-13 Plugs Junk measured Length Collapse measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-040 50-029-22655-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0375133 MILNE POINT / KUPARUK RIVER OIL measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 112' Size 112' 3,576' Casing Conductor 7,833' N/A Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 289 560 2271 22029 0 1280 234 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 323-379 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:46 am, Jan 22, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.01.19 09:44:59 - 09'00' Taylor Wellman (2143) RBDMS JSB 012524 DSR-1/26/24WCB 2024-07-03 _____________________________________________________________________________________ Revised By: TDF 1/19/2024 SCHEMATIC Milne Point Unit Well: MPU K-13 Last Completed: 10/7/2023 PTD: 196-040 TD =7,875’ (MD) / TD = 7,360’(TVD) 20” KB Elev.: 56.95’/ GL Elev.: 27.5’ (N27E) RT to Tubing Spool = 29.54’(N 27E) 7” 12 3 6 & 7 8 & 9 10 & 11 13 9-5/8” 1 2 PBTD=7,780’(MD) / PBTD = 7,274’(TVD) 4 & 5 14 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 / BTC-M 8.835 Surface 3,723’ 7" Production 26 / L-80 / BTC-M 6.276 Surface 7,861’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 7,280’ JEWELRY DETAIL No Depth Item 1 132’ STA 2: GLM 2-7/8" x 1" KBMM w/ DPSOV 2 7,103’ STA 1: GLM 2-7/8" x 1" KBMM w/ Dummy Valve 3 7,158’ 2-7/8” XN-Nipple (2.205” No-go ID) 4 7,210’ Discharge Head: B/O PMP 513 5 7,211’ Zenith Ported Sub: HEAD S/A B/O PRESS PORT 513/538P PMP 6 7,212’ Pump 2: 538PMSXD 20 GINPSHH H6 STD_PN 7 7,229’ Pump 1: 538PMSXD 20 GINPSHH H6 STD_PN 8 7,239’ Gas Sep.: 538GM2T HV E V X MT HS FER STD 9 7,244’ Intake: GPXARCINT FER H6 10 7,245’ Upper Tandem Seal: GS3 B/B/L SB H6 PFSA HL FER 12CRC 11 7,252’ Lower Tandem Seal: GS3 B/B/L SB H6 PFSA HL FER 12CRC 12 7,259’ Motor: 562XP 250 Hp/2,505 V / 61 A / 10R 12CRC 13 7,279’ Sensor and Centralizer: Bottom @ 7,280’ 14 7,627’ Fish: 7” BWD Sump Packer/ XN Nipple/ WLEG – ±21’ long PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk C 7,474’ 7,526’ 7,002’ 7,049’ 52’ 10/5/2023 Open Kuparuk C 7,474’ 7,526 7,002’ 7,049’ 52’ 12/9/1996 Open Kuparuk B7 7,547’ 7,557’ 7,068’ 7,077’ 10’ 10/5/2023 Open Ref Log: GR / CCL / 12/8/1996. 4-1/2” 24 gm. Big Hole Charges @ 12 spf. (EHD=&). TTP= 7.88” (135/45 Degree Phase) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sx of Arcticset I in 24” Hole 9-5/8" Cmt w/ 938 sx PF “E”, 700 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 235 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 700’ Max Hole Angle = 26 deg. @ 3,430’ Max Hole Angle through perforations = 25 deg. TREE & WELLHEAD Tree Cameron 2-9/16” – 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hng. Top lift Thread=3” LH Acme, Btm= 2-7/8” 8rd EUE &2.5” CIW H BPV Profile GENERAL WELL INFO 50-029-22655-00-00 Drilled, Cased & Completed by Nabors 22E - 10/17/1996 Completed with ESP by Nabors 4ES – 1/14/1997 ESP Changeout by Nabors 4ES - 1/19/1999 ESP Changeout by Nabors 4ES – 8/22/1999 ESP Changeout by Nabors 4ES – 8/30/2000 ESP Changeout by Nabors 4ES – 4/2/2003 ESP Changeout by Doyon 14 – 5/7/2004 ESP Changeout by ASR#1 – 10/7/2023 STIMULATION DETAIL 12/9/1996 – Frac Packed ‘C’ Sands w/ 1,500 lbs. 20/40 Cabolite Prop. Behind pipe. Screened out to formation. Well Name Rig API Number Well Permit Number Start Date End Date MP K-13 ASR#1 50-029-22655-00-00 196-040 9/28/2023 1/11/2024 9/29/2023 - Friday POOH LD w/ 2-7/8" 6.5# L-80 ESP completion. F/ 7,000' T/ 4,163'. POOH LD w/ 2-7/8" 6.5# L-80 ESP completion. F/ 4,163' T/ 57'. POOH LD ESP PUMP ASSY. After pulling the protectilizer off the tandem seal noticed that 6 of the allen bolts were broke off at the head. Recovered all of the bolt heads and lock washers. RD ESP running equip, clear off rig floor and cat walk. Bring in 3.5'' work string to get strapped and tallied in pipe shed. PU MU 7'' scrapper and 7'' test packer run as per Yellow Jacket Rep. RIH w/ 7'' scrapper and 7'' test packer run on 3.5'' work string T/ 3,156 PUW=29K SOW=25K 9/27/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/28/2023 - Thursday Rig accepted at 19:00 9/29/23. P/U 2-7/8" Test joint & lock in pipe rams for BOP test. Fill stack w/ fresh water. Test BOPE as per approved sundry, test t/ 250 psi low & 2,500 psi high f/ 5/5 charted mins. AOGCC inspector, Austin Mcleod witnessed testing. Preform accumulator drawdown. L/D testing tools & B/D all fluid line. Line up gas buster & fill. Pull CTS & BPV. P/U landing joint. M/U TIW & head pin. Install kelly hose. Torque hanger lift thread XO to landing joint. Engage landing joint into hanger. BOLDS. IA on a vacuum. Pull hanger. Hanger off seat at 57K. P/U wt = 60K. S/O wt = 39 K. Cut ESP cable & tie on to pull over sheave. L/D hanger. POOH w/ 2-7/8" 6.5# L-80 ESP completion. F/ 7,293' T/ 7,000' RIH 3.5'' work string w/ tandem 7'' scraper and test packer assy. F/3,156' T/ 7443'. Wash pipe down F/7,443' T/7,523' @ 2.5bpm 100psi tagged up at 7,523' pumped 82bbls total. POOH LD 3.5'' work string F/ 7,523' T/ 7,010', Set packer as per YJ Rep. Filled the hole with 27bbls of 8.4ppg source water. Pressure tested 7'' casing to 2000psi for 30mins charted. POOH LD 3.5'' work string w/ tandem 7'' scraper and test packer assy. LD tandem 7'' scraper and test packer assy as per YJ rep. RU Slick line and begin Slick line operations. 1st run bailer stopped @ 7,565' pooh and noticed that the bailer was damaged. 2nd run bull nose stopped @ 7,565' pooh didnt notice any damage 3rd run LIB soft nose 3.8'' OD stopped @ 7,565'. 4th run bow spring centralizer and was able to get to 7,572'. 5th run bow spring centralizer and sample bailer was able to get full bailer of sand and debris. 6th run bow spring centralizer and sample bailer. 9/30/2023 - Saturday 10/1/2023 - Sunday Continue slick line operations using sample bailer and 2' extension to try and clear out sump packer for gun run. Service rig and check fluids. Load shed with 3.5'' work string and YJ milling tools. CO all pipe handling equip to 3.5''. Fix the cat walk due to chain failure. PU MU milling and junk basket BHA for milling out sump packer. RIH with 3.5'' work string F/ 392' T/ 7,478' PUW= 87K SOW=55K. Wash down F/ 7500' T/7,526' @ 4.8bpm psi=600 Started milling up sump packer @ T/7,526' as per YJ rep RPM=90 Flow= 3bpm PSI= 150 TQ=2-3K WOB=4k PUW= 87K SOW=55K RTW=70K. While pumping not getting any returns. Test BOPE as per approved sundry, test t/ 250 psi low & 2,500 psi high f/ 5/5 charted mins. AOGCC inspector, Austin Mcleod witnessed testing. Well Name Rig API Number Well Permit Number Start Date End Date MP K-13 ASR#1 50-029-22655-00-00 196-040 9/28/2023 1/11/2024 Hilcorp Alaska, LLC Weekly Operations Summary POOH LD 3.5'' workstring F/1,600' T/392'. POOH LD 4.25'' DC and Milling assy as per YJ rep. Cleaning out Junk baskets 30lbs of metal. PU MU Fishing spear assy and 4.25'' DC as per YJ rep. RIH with Fishing spear assy on 3.5'' workstring F/299' T/7465' PUW= 80K SOW=59K. Washed down F/7465' T/ 7538' TOF. Pumping 2bpm @ 800psi washing down and working spear into the sump packer as per YJ rep. Jarring on fish over pulling 30-40K. pumping 1-2 bpm working pipe up and down with 10' pup got free. Worked back down to 7,555' LD JT and 10' pup. Worked pipe. Kellyed up and pumping 1bpm and pulled free. BD Kelly hose and surface lines. POOH LD 3.5'' work string F/7538' T/ 2719' PUW=31K SOW=27K. Cont'd milling up sump packer @ 7,526' as per YJ rep RPM=90 Flow= 3bpm PSI= 150 TQ=2-3K WOB=4k PUW= 87K SOW=55K RTW=70K. While pumping not getting any returns. Cont'd milling up sump packer T/ 7,529' where it was able to get pushed down to 7,536' and stopped. Cont'd milling at 7,536' as per YJ rep RPM=90 Flow= 3-5bpm PSI= 150 TQ=2-3K WOB=4-13k PUW= 87K SOW=55K RTW=70K. While pumping not getting any returns. Cont'd milling at 7,536' as per YJ rep RPM=90 Flow= 3- 5bpm PSI= 150 TQ=2-5K WOB=4-13k PUW= 87K SOW=55K RTW=70K. Reverse circ the well @ 7.8bpm psi=650 getting returns to the shaker. working the pipe without rotating setting 20K down on the sump packer trying to get it to wash down to depth with not success. While getting returns saw little sand and some metal shavings on the magnet. Monitor well and checked fluids on the rig. POOH LD 3.5'' work string F/ 7,536' T/ 1,600' PUW=24K SOW=21K 10/3/2023 - Tuesday 10/2/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP K-13 ASR#1 50-029-22655-00-00 196-040 9/28/2023 1/11/2024 No operations to report. Baker rep fished hanger splice and installed into postion. Land Hanger S/O 43K P/U 62K. RILDS. Install BPV. Clamp count, Cross collar clamps - 122, Protectilizer - 6, Flat guards - 2. Begin RDMO. Pull rack pins. Blow lines dry. Empty pits. Rig released at 12:00 10-7-2023. PSI tested tree void to 500psi low and 5000psi high good test. Baker came out and tested ESP connection on K-13 all tested good. 10/7/2023 - Saturday No operations to report. 10/10/2023 - Tuesday 10/8/2023 - Sunday No operations to report. 10/9/2023 - Monday 10/6/2023 - Friday Connect flow line and hole fill. install bird bath. spot in spooler. Hang sheave. P/U M/U and service ESP equipment. RIH with 2 7/8'' ESP completion Testing ESP cable every 1000' F/80' T/2,680'. Fire Drill and Drill review. RIH with 2 7/8'' ESP completion Testing ESP cable every 1000' F/2,680' T/ 5,154'. RIH with 2 7/8'' ESP completion Testing ESP cable every 1000' F/5,154' T/ 7280'. PU MU landing jt to hanger, terminate ESP cable at hanger start hanger splice. 10/4/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continue to POOH W/ work string F/2,719' T/ 300'. L/D BHA and fish. 9 collars, bumper sub, jars, spear and fish. P/U M/U Clean out BHA including reverse junk mill, 2 boot baskets bumper sub and jars, and 9 Drill collars. RIH W/ work string F/ 305' T/7,510'. Hook up kelly hose to power swivel and kellyed up to the jt to get parameters for washing down. SOW= 57K PUW=81K. Wash down F/7,510' T/ 7,625' pumping 2bpm with 150psi no rotation. First took 5k weight @ 7,570' washed off quickly. Took 10K down @ 7,578' washed off after working pipe. Lined up to reverse circ well bring on the pumps @ 5bpm and 500psi staging them up to 8bpm @ 700psi. Circ till the well cleaned up and no more sand was coming across the shaker. Monitor well prior to opening up the annular from reverse circ. Short trip F/7,625' T/7390' and back to bottom @ 7,627' where it took 2k down weight with no pumps on. No fill was found on bottom. PUW= 85K SOW=55K. POOH LD 3.5'' workstring F/7,627' T/4,875'. 10/5/2023 - Thursday POOH W/ work string F 4,875' T/333'. Pumping double displacement. L/D clean out BHA. 9 drill collars jars, bumper sub 2 boot baskets, and reverse mill. Rig down flow spool and spacer spools. N/U shooting flange. PJSM W/ E-line. R/U E-line PCE, set 7'' test plug as per wellhead tech. Pressure test shooting flange and wire line equip to 250psi low 2500psi high for 5 min each. RD testing equip pull 7'' test plug out of stack. MU the guns for running in the hole. RIH with AK E-line guns tagged bottom @ 7,627' pulled up to perf on depth @ 7,557'-7547' corelating shooting depth with Hilcorp GEO as per Gamma Ray / Casing Collar Correlation log from 12-8-1996. Second run of gun perfs from 7,526'-7,500'. Third run of gun perfs from 7,500'-7,474'. All of the shoots loaded fired on all runs. RD AK E-line ND shooting flange. NU spacer spools, flow nipple and bird bath. MU the guns for running in the hole. RIH with AK E-line guns tagged bottom @ 7,627' pulled up to perf on depth @ 7,557'-7547' Baker rep fished hanger splice and installed into postion. Land Hanger S/O 43K P/U 62K. RILDS RIH with 2 7/8'' ESP completion Testing ESP cable every 1000' F/80' T/2,680'.RIH with 2 7/8'' ESP completion Testing ESP cable every 1000' F/2,680' T/ 5,154'. RIH with 2 7/8'' ESP completion Testing ESP cable every 1000' F/5,154' T/ 7280'. PU MU landing jt to hanger, terminate ESP cable at hanger start hanger splice Second run of gun perfs from 7,526'-7,500'. Third run of gun perfs from 7,500'-7,474' Well Name Rig API Number Well Permit Number Start Date End Date MP K-13 ASR#1 50-029-22655-00-00 196-040 9/28/2023 1/11/2024 1/12/2024 - Friday No operations to report. 1/10/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/11/2024 - Thursday Met with Reservoir Engineer and decided that due to steadily increasing production rates we will continue to produce the Kuparuk C and B3 zones. We will not isolate the B3 or C and allow the well to flow comingled. No operations to report. No operations to report. 1/13/2024 - Saturday No operations to report. 1/16/2024 - Tuesday 1/14/2024 - Sunday No operations to report. 1/15/2024 - Monday Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/25/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231025 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 241-23 50283201910000 223061 9/27/2023 AK E-LINE CBL BRU 241-23 50283201910000 223061 10/4/2023 AK E-LINE GPT/Plug/Perf GP ST 18742 37 50733203940000 187109 9/30/2023 AK E-LINE Plug IRU 41-01 50283200880000 192109 9/22/2023 AK E-LINE Perf/GPT LRU C-02 50283201900000 223057 9/28/2023 AK E-LINE Perf LRU C-02 50283201900000 223057 9/25/2023 AK E-LINE Perf/GPT MPU K-13 50029226550000 196040 10/1/2023 AK E-LINE GPT/Plug/Perf NCI A-05 50883200250000 169032 9/27/2023 AK E-LINE Perf Please include current contact information if different from above. T38097 T38097 T38098 T38099 T38100 T38100 T38101 T38102 10/25/2023 MPU K-13 50029226550000 196040 10/1/2023 AK E-LINE GPT/Plug/Perf Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.25 11:33:48 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/29/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230929 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU B-28 50029235660000 216027 9/22/2023 READ Caliper Survey MPU G-02 50029219260000 189028 9/18/2023 READ Caliper Survey MPU K-13 50029226550000 196040 9/18/2023 READ Caliper Survey MPU L-29 50029225430000 195009 9/17/2023 READ Caliper Survey Please include current contact information if different from above. T38019 T38020 T38021 T38022 9/29/2023 MPU K-13 50029226550000 196040 9/18/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.09.29 12:48:41 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT K-13 JBR 10/17/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 2-7/8" & 3-1/2" joints Test Results TEST DATA Rig Rep:Pace/DooredOperator:Hilcorp Alaska, LLC Operator Rep:Heim/Gallen Rig Owner/Rig No.:Hilcorp ASR 1 PTD#:1960400 DATE:9/29/2023 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopSAM230930094845 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4.5 MASP: 1619 Sundry No: 323-379 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 11"P #1 Rams 1 2-7/8"x5"P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2-1/16"P HCR Valves 1 2-1/16"P Kill Line Valves 3 2-1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1900 200 PSI Attained P17 Full Pressure Attained P51 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2412 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P12 #1 Rams P5 #2 Rams P5 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0      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 Swap 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? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7,875' 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7,531 MD/ 7,054 TVD and N/A Todd Sidoti todd.sidoti@hilcorp.com 777-8443 Perforation Depth MD (ft): See Schematic See Schematic 2-7/8" 6.5 / L-80 / EUE 8rd 20" 9-5/8" 7" 3,691' 7,833' 7" BWD Sump Packer and N/A 5,750psi 7,240psi 3,576' 7,352' 3,723' 7,861' Length Size Proposed Pools: 112' 112' TVD BurstMD N/A78' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0375133 196-040 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22655-00-00 Hilcorp Alaska LLC C.O.432E AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 7/30/2023 7,293' Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT K-13 MILNE POINT KUPARUK RIVER OIL N/A 7,360' 7,780' 7,274' 1,619 No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:30 am, Sep 11, 2023 323-379 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.07.07 15:14:58 - 08'00' Taylor Wellman (2143) 7/30/2023 1,619 DSR-9/11/23 Sep 11, 2023 BOPE test to 2500 psi. 10-404 SFD 9/11/2023MGR11SEP23&': 09/11/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.09.11 17:14:49 -05'00' RBDMS JBS 091223 RWO – Perf ESP Swap Well: MPU K-13 Date: 5 July 2023 Well Name: MPU K-13 API Number: 50-029-22655-00-00 Current Status: Producer [ESP Failed] Pad: K-Pad Estimated Start Date: July 30th, 2023 Rig: ASR 1 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-040 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) Second Call Engineer: Scott Pessetto (907) 564-4373 (O) (801) 222-2203 (M) Current Bottom Hole Pressure: 2,319 psi @ 7,000’ TVD (SBHP measured 2/13/2013) 6.4 PPGE Max. Proposed Surf Pressure: 1,619 psi (Using 0.1 psi/ft gas gradient) Max Inclination: 25° @ 2765’ MD Brief Well Summary: MPK-13 is a Kuparuk producer producing from the C sands only. The current ESP in MPK-05 failed in 2010 and is need of replacement. Notes Regarding Wellbore Condition x Well requires an 8 year MIT. x Caliper ran in 2011 indicates that tubing is in good condition. Objective: Perforate B7 sands, re-perforate C sand, replace failed ESP with new assembly and return well to production. Pre-Rig Procedure (No sundry required): Slickline Pumping & Well Support 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. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. 5. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH or diesel. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 6. RD Little Red Services and reverse out skid. 7. RU crane. Set BPV. ND tree and NU BOPE. RD Crane. 8. NU BOPE house. Spot mud boat. Brief RWO Procedure: 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 bbl returns tank. RWO – Perf ESP Swap Well: MPU K-13 Date: 5 July 2023 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well with ppg produced water prior to setting CTS. 3. 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 rams on 2-7/8” and 3-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. 5. Call out vendor for ESP pull. 6. RU Spooler to pull #1 ESP cable. 7. MU landing joint or spear and PU on the tubing hanger. a. P/U weight was 67,000# and S/O was 55,000# during last RWO. 8. Recover the tubing hanger. 9. POOH and lay down the 2-7/8” tubing. Number all joints a. Keep all tubulars for re-use. b. Tubing caliper indicates that all joints are good. c. Keep XN nipple and GLMs for future use. d. Keep ported discharge head and centralizer for future use. e. Note any sand or scale inside or on the outside of the ESP on the morning report. f. Look for over-torqued connections from previous tubing runs. g. Recover the following amount of clamps/guards from the completion: i. 121 LaSalle Clamps ii. 4 pump protector clamps iii. 1 motor protector clamp 10. Lay Down ESP. 11. RIH with 7” test packer assembly on 3-1/2” WS to 7,000’. a. Calculated TOC behind 7” casing is 4092’. 12. Test casing to 2,000 psi for 30 minutes charted. POOH with test packer. 13. MIRU Eline unit and pressure test lubricator to 250 psi low / 2500 psi high. 14. MU and RIH with JB and ~2.25”GR and tag PBTD. POOH. 15. MU and RIH with 2-1/8” spiral strip gun and perforate form 7547-7557’. a. Correlate to GR-CCL log dated 8-DEC-1996 MAIN PASS. 16. MU and RIH with 2-7/8” HSC guns and perforate from 7474-7526’. a. Correlate to GR-CCL log dated 8-DEC-1996 MAIN PASS. 17. PU new ESP and RIH on 2-7/8” tubing, making electrical checks every 2,000 feet. a. Set base of ESP assembly at ± 7,400’ MD. b. 1 joint of 2-7/8” Tubing A If risk of pressure under BPV, utilize lubricator assy to pull. - mgr RWO – Perf ESP Swap Well: MPU K-13 Date: 5 July 2023 c. 2-7/8” XN d. 1 joint of 2-7/8” Tubing e. 2-7/8” GLM w/ DV installed. f. 2-7/8” Tubing g. 2-7/8” GLM w/ OV installed at ± 125’ MD. h. 2-7/8” Tubing 18. Land tubing hanger and space out. RILDS. Lay down landing joint. Note PU and SO weights on tally. 19. Set BPV. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE and NU tree. 3. 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. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 7/6/2023 SCHEMATIC Milne Point Unit Well: MPU K-13 Last Completed: 5/7/2004 PTD: 196-040 TD =7,875’ (MD) / TD = 7,360’(TVD) 20” KB Elev.: 56.95’/ GL Elev.: 27.5’ (N27E) RT to Tubing Spool = 29.54’(N 27E) 7” 9 3 5 6 7 & 8 10 12 9-5/8” 1 2 PBTD =7,780’(MD) / PBTD = 7,274’(TVD) 4 11 13 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 / BTC-M 8.835 Surface 3,723’ 7" Production 26 / L-80 / BTC-M 6.276 Surface 7,861’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 7,293’ JEWELRY DETAIL No Depth Item 1 141’ STA 2: 2-7/8" x 1" CAMCO GLM w/ DPSOV 2 7,077’ STA 1: 2-7/8" x 1" CAMCO GLM w/ DGLV 3 7,220’ 2-7/8” XN-Nipple (2.205” No-go ID) 4 7,235.6’ Discharge Head: GPDIS 5 7,236’ Pump: GPMTAR 1:1, 151 stg GC1700 6 7,254’ Gas Sep.: GRSXTBAR (w/ 400 internals) 7 7,259’ Upper Tandem Seal: GSB3DBUTILH6PFS 8 7,266 Lower Tandem Seal: GSB3DBLTH6AFLASHSN 9 7,272’ Motor: KMH 562, Re-rated 152 HP/ 2,325V / 40 A 10 7,288’ Pumpmate Sensor and Centralizer:Bottom @ 7,293’ 11 7,531 7” BWD Sump Packer 12 7,543 Halliburton 3-1/2” XN Nipple – 2.635” ID 13 7,544’ WLEG:Bottom @ 7,545’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk 7,474’ 7,526 7,002’ 7,049’ 52’ 12/9/1996 Open Ref Log: GR / CCL / 12/8/1996. 4-1/2” 24 gm. Big Hole Charges @ 12 spf. (EHD=&). TTP= 7.88” (135/45 Degree Phase) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sx of Arcticset I in 24” Hole 9-5/8" Cmt w/ 938 sx PF “E”, 700 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 235 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 700’ Max Hole Angle = 26 deg. @ 3,430’ Max Hole Angle through perforations = 25 deg. TREE & WELLHEAD Tree Cameron 2-9/16” – 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hng. Top lift Thread=3” LH Acme, Btm= 2-7/8” 8rd EUE &2.5” CIW H BPV Profile GENERAL WELL INFO 50-029-22655-00-00 Drilled, Cased & Completed by Nabors 22E - 10/17/1996 Completed with ESP by Nabors 4ES – 1/14/1997 ESP Changeout by Nabors 4ES - 1/19/1999 ESP Changeout by Nabors 4ES – 8/22/1999 ESP Changeout by Nabors 4ES – 8/30/2000 ESP Changeout by Nabors 4ES – 4/2/2003 ESP Changeout by Doyon 14 – 5/7/2004 STIMULATION DETAIL 12/9/1996 – Frac Packed ‘C’ Sands w/ 1,500 lbs. 20/40 Cabolite Prop. Behind pipe. Screened out to formation. _____________________________________________________________________________________ Revised By: TDF 7/7/2023 PROPOSED Milne Point Unit Well: MPU K-13 Last Completed: 5/7/2004 PTD: 196-040 TD =7,875’ (MD) / TD = 7,360’(TVD) 20” KB Elev.: 56.95’/ GL Elev.: 27.5’ (N27E) RT to Tubing Spool = 29.54’(N 27E) 7” 9 3 5 6 7 & 8 10 12 9-5/8” 1 2 PBTD =7,780’(MD) / PBTD = 7,274’(TVD) 4 11 13 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 / BTC-M 8.835 Surface 3,723’ 7" Production 26 / L-80 / BTC-M 6.276 Surface 7,861’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±7,293’ JEWELRY DETAIL No Depth Item 1 ±125’ STA 2: 2-7/8" x 1" GLM w/ DPSOV 2 ±X,XXX’ STA 1: 2-7/8" x 1" GLM w/ DGLV 3 ±X,XXX’ 2-7/8” XN-Nipple (2.205” No-go ID) 4 ±X,XXX’ Discharge Head: 5 ±X,XXX’ Pump: 6 ±X,XXX’ Gas Sep.: 7 ±X,XXX’ Upper Tandem Seal: 8 ±X,XXX’ Lower Tandem Seal: 9 ±X,XXX’ Motor: 10 ±X,XXX’ Sensor and Centralizer: Bottom @ ±7,400’ 11 7,531 7” BWD Sump Packer 12 7,543 Halliburton 3-1/2” XN Nipple – 2.635” ID 13 7,544’ WLEG:Bottom @ 7,545’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk C 7,474’ 7,526 7,002’ 7,049’ 52’ 12/9/1996 Open Kuparuk B7 ±7,547’ ±7,557’ ±7,068’ ±7,077’ ±10 Future Future Ref Log: GR / CCL / 12/8/1996. 4-1/2” 24 gm. Big Hole Charges @ 12 spf. (EHD=&). TTP= 7.88” (135/45 Degree Phase) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sx of Arcticset I in 24” Hole 9-5/8" Cmt w/ 938 sx PF “E”, 700 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 235 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 700’ Max Hole Angle = 26 deg. @ 3,430’ Max Hole Angle through perforations = 25 deg. TREE & WELLHEAD Tree Cameron 2-9/16” – 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hng. Top lift Thread=3” LH Acme, Btm= 2-7/8” 8rd EUE &2.5” CIW H BPV Profile GENERAL WELL INFO 50-029-22655-00-00 Drilled, Cased & Completed by Nabors 22E - 10/17/1996 Completed with ESP by Nabors 4ES – 1/14/1997 ESP Changeout by Nabors 4ES - 1/19/1999 ESP Changeout by Nabors 4ES – 8/22/1999 ESP Changeout by Nabors 4ES – 8/30/2000 ESP Changeout by Nabors 4ES – 4/2/2003 ESP Changeout by Doyon 14 – 5/7/2004 STIMULATION DETAIL 12/9/1996 – Frac Packed ‘C’ Sands w/ 1,500 lbs. 20/40 Cabolite Prop. Behind pipe. Screened out to formation. Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 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 Blind Ram 2-7/8" x 5" VBRs 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. I~~ _©~ O File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy i~ Vincent Nathan Lowell Date: [] TO RE-SCAN Notes' Is~ Re-Scanned by: Be~,edy Dianna Vincent Nathan Lowell Date: • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 -MINED FEB 17 2012 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission LJ `5 333 West 7 Avenue 1V Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPK -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPK -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 0 l BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPK 10/29/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPK -02 1960810 50029226750000 0.2 NA 0.2 NA 5.1 9/5/2011 MPK -05 1960680 50029226700000 1.9 NA 1.9 NA 17.9 8/24/2011 MPK-06 1961910 50029227250000 1.5 NA 1.5 NA 8.5 8/27/2011 MPK-09 2050140 50029232470000 1.9 NA 1.9 NA 12.8 8/24/2011 �7 MPK -13 1960400 50029226550000 1.7 NA 1.7 NA 14.5 8/24/2011 MPK -17 1960280 50029226470000 1 NA 1 NA 2.6 8/24/2011 MPK -18A 1970270 50029227330100 4.6 NA 4.6 NA 23.8 8/27/2011 MPK -21A 2031620 50029227180100 0.4 NA 0.4 NA 6.9 10/29/2011 MPK -22 2050220 50029232490000 2 NA 2 NA 5.1 8/27/2011 MPK -25 1960320 50029226500000 4.2 NA 4.2 NA 30.6 8/24/2011 MPK -30 1961680 50029227110000 1.5 NA 1.5 NA 17.0 8/25/2011 MPK-33 1962020 50029227290000 1.7 NA 1.7 NA 15.3 8/24/2011 MPK-34 1961690 50029227120000 2.5 NA 2.5 NA 25.5 8/25/2011 MPK-37 1960760 50029226740000 2 NA 2 NA 17.0 8/24/2011 MPK -38 1960300 50029226490000 3.2 NA 3.2 NA 15.3 8/25/2011 MPK -43A 1970410 50029227380100 1.7 NA 1.7 NA 13.6 9/16/2011 { STATE OF ALASKA " ALAS~ - .L AND GAS CONSERVATION Cd",.,.J1ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 56.95' 0 Suspend 181 Repair Well 181 Pull Tubing 8. Property Designation: ADL 375133 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 7875 7364 7780 7278 Casing Structural Conductor Surface Intermediate Production Liner Length 78' 3691' 7833' Perforation Depth MD (ft): Perforation Depth TVD (ft): 0 Waiver 181 Other 0 Time Extension Ch_ange Out ESP 0 Annular Disposal 5. Permit To Drill Number 196-040 6. API Number: 50-029-22655-00-00 0 Operation Shutdown 0 Perforate 0 Plug Perforations 0 Stimulate 0 Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: B Development 0 Exploratory 0 Stratigraphic Test 0 Service 9. Well Name and Number: MPK-13 10. Field I Pool(s): Milne Point Unit I Kuparuk River Sands feet feet Plugs (measured) NIA feet Junk (measured) NIA feet Size MD TVD Burst Collapse 20" 112' 112' 9-5/8" 3723' 3576' 5750 3090 7" 7861' 7352' 7240 5410 RECE.iVE 7002' - 7049' 7474' - 7526' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): MAY 2 8 ?OO4 2-7/8" ,6.5# AIaID on & Gft8 ConS. CommMia 7" HES BWD Sump packer at 7531' with a 3-1/2" taiIPi~~1' 7543' SCANNl:.U JUN 1 0 2004 JU N 0 ,~'>\ " II, ,,'/~ 1'< ' U Treatment description including volumes used and final pressure: ,.IBFl 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casinq Pressure TubinQ Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run a Daily Report of Well Operations a Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory B Development 0 Service 16. Well Status after proposed work: BOil 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 Name Sondra Stewman --- ,,""~l -, Si9';~~~:~)~'--~ (~;.~~~~_.- Form 10-404 Revised 12/2003 Title Technical Assistant , Prepared By Name/Number: Phoneç~ILI-L~,-15Ð DateS'Zf;-ÖL\ ~ondra SteW'mnô6t471~)'\"'~ i ( \, I, 1: )~' ,~ ~---~I'1Ii€l! ðC:~ ~u" ~ l.~J ~ j \J""\ :1 !QWI 1!_~' WJm tÞ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-13 MPK-13 WORKOVER f ( ( BP EXPLORATION Operations Summary Report Page 1 of 2 Start: Rig Release: Rig Number: Spud Date: 8/25/2000 End: 2/7/2004 5/5/2004 Date From - To H 0 U rs Task Code NPT Phase Description of Operations -- 5/5/2004 01 :00 - 06:00 5.00 MOB P PRE PJSM. Scope down & layover derrick. Move rig & rig components from MP K-30 to MP K-13. Rig up on well. 06:00 - 07:00 1.00 RIGU P PRE PJSM. Rig up lines, take on sea water. Rig accepted @ 07:00 hrs. 07:00 - OS:OO 1.00 KILL P DECOMP Rig up lines to tiger tank & circulating lines on tree. OS:OO - 09:00 1.00 KILL P DECOMP PJSM. Rig up lubricator, pull BPV. SITP = 200 psi, II A = 190 psi, OIA = 50 psi. Pressure test surface equipment to 3500 psi, OK. 09:00 - 13:00 4.00 KILL P DECOMP PJSM. Line up & circulate @ 3-4 bpm I 700 psi. Crude returns to tiger tank. Circulate 350 bbls, returns cleaning up. Monitor well, well dead. OIA increased to 550 psi due to thermal expansion, line up & bleed off to tiger tank. 13:00 - 13:30 0.50 WHSUR P DECOMP PJSM. Rig down surface lines. Install 2 way check valve. 13:30 - 14:30 1.00 WHSUR P DECOMP PJSM. Bleed void & NID tree. 14:30 - 17:00 2.50 BOPSUP P DECOMP PJSM. N/U 13 5/S" x 5M BOPE. AOGCC State Rep Chuck Sheve waived witnessing BOPE test. 17:00 - 20:30 3.50 BOPSUPP DECOMP Test BOP equip as per AOGCC/BP requirements, LP 250 psi, HP 3500 psi. 20:30 - 21 :00 0.50 WHSUR P DECOMP P/U lubricator, Pull TWC. LID plug & lubricator. 21 :00 - 21 :30 0.50 PULL P DECOMP BOLDS. P/U wI 63K & pull hanger up 2'. 21 :30 - 22:00 0.50 PULL P DECOMP Circulate bottoms up. Monitor well. Well Dead. Had very small amt of gas to surface while circulating. 22:00 - 22:30 0.50 PULL P DECOMP Pull hanger to floor. LID hanger & test ESP cable. 22:30 - 23:00 0.50 PULL P DECOMP Pull ESP cable over sheave & connect to spooler. 23:00 - 00:00 1.00 PULL P DECOMP POOH w/2 7/S" ESP completion. Stand tubing back in derrick. 5/6/2004 00:00 - 02:00 2.00 PULL P DECOMP Con't to POOH w/2 7/8" ESP completion & standback in derrick. Pulled 75 stands, + 2 GLMs assys, + "XN nipple assy. Recovered 121 LaSalle Clamps, 2 Flat Guards, 4 Protectolizers. 02:00 - 04:00 2.00 PULL P DECOMP Pull & LID pump & motor. 04:00 - 05:00 1.00 PULL P DECOMP Clear & clean rig floor. Prep to RIH to clean out well bore. 05:00 - 09:00 4.00 CLEAN P DECOMP M/U muleshoe on 2 7/8" tubing & RIH. Tag 15 1/2' in on Jt # 237 @ 7431'. 52K up wt, 45K down wt. 09:30 - 10:30 1.00 CLEAN P DECOMP PJSM. Line up & attempt to wash down, no good. Spud on top of fill @ 7431' while circulating @ 5112 bpm I 1100 psi a few times with no effect. Set 5-7K down, throw in rotary slips & rotate while pumping 5 bpm. Max torque = 2000 ft/lbs. Pull slips, able to wash down now. 10:30 - 13:00 2.50 CLEAN P DECOMP Reverse circulate out fill @ 5 112 bpm I 1100 psi to 7509' where we experienced total loss of returns. Line up to circulate long way & wash down to 7541', hard tag on packer. Pick up l' & reverse circulate 50 bbls, no returns. 13:00 - 16:30 3.50 CLEAN P DECOMP PJSM. Break off circ head & POOH w/2 7/8" tbg, laying down 1st 14 jts. 16:30 - 17:30 1.00 RUNCOMP COMP Clear & clean rig floor. PJSM. Rig up to run 2 7/S" ESP completion string. 17:30 - 19:00 1.50 RUNCOMP COMP P/U & M/U ESP. Service & test same. 19:00 - 20:00 1.00 RUNCOMP COMP Pull MLE over sheave. Plug in & test connection. 20:00 - 00:00 4.00 RUNCOMP COMP RIH wI ESP on 2 7/S" tubing. Test & pump thru pump every 2000'. 5fi 12004 00:00 - 00:30 0.50 RUNCOMP COMP P/U landing jt. M/U into hanger. Install penetrator. 00:30 - 02:00 1.50 RUNCOMP COMP Make fiield connection. Plug into penetrator & test same. 02:00 - 02:30 0.50 RUNCOMP COMP Land completion. RILDs. Ran 227 jts of 2 7/S" tbg. Bottom of Printed: 5/10/2004 9:21 :43 AM SCANNED JUN .1 0 2004 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ~: ~' (' Page 2 of 2 BP EXPLORATION Operations Summary Report MPK-13 MPK-13 WORKOVER Start: Rig Release: Rig Number: Spud Date: 8/25/2000 End: 2/7/2004 5/5/2004 5/7/2004 02:00 - 02:30 From - To Hours Task Code NPT Phase COMP centralizer @ 7293'. Top of ESP @ 7236'. "XN" @ 7220'. GLM wI dummy @ 7077'. GLM wI DSOV @ 141'. Install TWC. test to 3500 psi. NID BOPE. N/U & test tree. Make final ESP electrical check. Install BPV & test. Clean cellar & secure well. RELEASE RIG @ 0600 Hrs. Date 02:30 - 04:00 04:00 - 05:30 05:30 - 06:00 0.50 RUNCDrv1P 1.50 BOPSUP P 1.50 WHSUR P 0.50 WHSUR P Description of Operations COMP COMP COMP SCANNED ~JUN 1 0 2004 Printed: 5/10/2004 9:21:43 AM Tree: Cameron 2 9/16" - 5M~ Wellhead: 11" x 7 1 116" 5~< AC Gen 5A, wI 2 7/8" FMC Tbg. Hng., top lift thread = 3" LH Acme, btm = 2 7/8" 8rd EUE & 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 KOP @ 700' Max. hole angle = 26° @ 3430' Hole angle thru' perfs = 25 deg. I 112' II 9 5/8", 40 ppf, L-80 Btrc. I 3723' I j 2-7/8",6.5 ppf, L-80, EUE 8rd tubing drift ID = 2.347", cap = .00579 bpf 7", L-80, Mod. Btrc. 26 ppf prod. csg. ( drift 10 = 6.151 ", cap. = 0.0383 bpf ) Stimulation Summary 12/09/96 Frac packed 'c' sands w/ 1500 Ibs. 20/40 carbolite prop. behind pipe. Screened out to formation. Two 7" Marker jts.from 7,306' to 7,348' md Perforation Summary Ref. Log: GR/CCL 12/08/96 Size SPF Interval 4.5" 12 7474'-7526' (TVD) 7005'-7036' 24 gm. bighole charges (EHD=.7) TTP= 7.88" (135/45 degree phase) ..,1 DATE REV. BY 10 121 196 MDO 01/21/98 M.linder 10/19/98 MDO 01/20/99 JBF 8/21/99 MH 08/30/00 M.Linder 4/2/03 Hulme 05/07/04 J. Cubbon MPU K-13 . I l 't :f f -t ~ " ,. " ,. " " ,.. ,. " ,.. " ~ ~ =jLF ...-" Ori~ 'Elev. = 56.95' (N 27E) Orig. ,-"L Elev. = 275' RT To Tbg. Spool = 29.45' (N 27E) .. Camco 2 7/8" x 1" sidepocket KBMM GLM ~ Cameo 2 7/8" x 1" sidepocket KBMM GLM 2-7/8" HES XN-Nipple ( 2.205" id ) 141 ' I 7077' I 7220' Centrìlift Pump 151 Stages I 7236' I GC 170 GPMTAR -1:1 Tandem Gas Seperator GRSXTBAR I 7254' I Tandem seal sections I 7259' I GSB3DBUT /LTI LH6PFS AFLAS/HSN Centrilift KMH 562 series, I 7272' I 171 hp motor, 2390 v./44 a. PumpMate wI 6 fin centralizer I 7288' I 7" HES BWO sump. 3.5" XN nipple (2.75" x 2.63") 7" float collar (PBTD) 7" float shoe COMMENTS Drilled and Cased by Nabors 27E Rebuild lost drawing. ESP RWO & Scale pellets 4ES ESP Replacement by Nabors 4ES ESP ReDlacement by Nabors 4ES RWO - Pulled screens RWO - ESP Replacement by 4ES I 7531' I 7543' I 7780' I 7861' MILNE POINT UNIT WELL K -13 API NO: 50-029-22655 BP EXPLORATION (AK) RWO ,. ESP Replacement~by 4ES SCANNED JUN 1 {) 2004 .. H STATE OF ALASKA ,/' ALASKA..L AND GAS CONSERVATION CO...,II1ISSION REPORT OF SUNDRY WELL OPERATIONS <. . r' 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 56.95' 0 Suspend 1m Repair Well 1m Pull Tubing 8. Property Designation: ADL 375133 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 78' Surface 3691' Intermediate Production 7833' Liner 7875 7364 7780 7278 Perforation Depth MD (ft): Perforation Depth TVD (ft): 0 Waiver 1m Other 0 Time Extension Change Out ESP 0 Annular Disposal 5. Permit To Drill Number 196-040 6. API Number: 50-029-22655-00-00 0 Operation Shutdown 0 Perforate 0 Plug Perforations 0 Stimulate 0 Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: a Development D Exploratory D Stratigraphic Test D Service 9. Well Name and Number: MPK.13 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands feet feet Plugs (measured) N/A feet Junk (measured) N/A feet Size MD TVD Burst Collapse 20" 112' 112' 9-5/8" 3723' 3576' 5750 3090 7" 7861' 7352' 7240 5410 RECEIVED 7474' - 7526' MAY 2 ~ 2004 2-7/8" ,6.5# Af8Ika Oil & Ges ConS. CornIJi'Mr¡ 7" HES BWD Sump packer at 7531' with a 3-1/2" tailP~~1' 7543' 7002' - 7049' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: IBIIS BF L ..,N 0 3 'If}fì4 13. Prior to well operation: Subsequent to operation: 14. Attachments: D Copies of Logs and Surveys run a Daily Report of Well Operations iii Well Schematic Diagram Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casino Pressure Tubina Pressure 15. Well Class after proposed work: D Exploratory a Development D Service 16. Well Status after proposed work: a Oil D Gas D WAG D GINJ D WINJ D WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman .--, Si9~ ~~$i~> Form 10-404 Revised 12/2003 Title Technical Assistant Phone~,y- y¡ Sù 0 RIG ¡ I\JA, Prepared By Name/Numbe~ Date_~"LdM "D"'1f'$7~," r', ~ r-, .' . . , EX P to RA;r.lÖNj;.;~ ¿r " 'CoP,,'.. """',éopy.,%Y'" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-13 MPK-13 WORKOVER Start: 5/5/2004 Rig Release: Rig Number: Spud Date: 8/25/2000 End: 2/7/2004 FrQm~...t.!¡), HQu..~~';Æit1lçi'$I<' 5/5/2004 01 :00 - 06:00 5.00 MOB P PRE 06:00 - 07:00 1.00 RIGU P PRE 07:00 - 08:00 08:00 - 09:00 P P DECOMP DECOMP 1.00 KILL 1.00 KILL 09:00 - 13:00 P DECOMP 4.00 KILL 13:00 - 13:30 0.50 WHSUR P DECOMP 13:30 - 14:30 1.00 WHSUR P DECOMP 14:30 - 17:00 2.50 BOPSUP P DECOMP 17:00 - 20:30 3.50 BOPSUP P DECOMP 20:30 - 21 :00 0.50 WHSUR P DECOMP 21 :00 - 21 :30 0.50 PULL P DECOMP 21 :30 - 22:00 0.50 PULL P DECOMP 22:00 - 22:30 0.50 PULL P DECOMP 22:30 - 23:00 0.50 PULL P DECOMP 23:00 - 00:00 1.00 PULL P DECOMP 5/6/2004 00:00 - 02:00 2.00 PULL P DECOMP 02:00 - 04:00 2.00 PULL P DECOMP 04:00 - 05:00 1.00 PULL P DECOMP 05:00 - 09:00 4.00 CLEAN P DECOMP 09:30 - 10:30 1.00 CLEAN P DECOMP 10:30 - 13:00 2.50 CLEAN P DECOMP 13:00 - 16:30 3.50 CLEAN P DECOMP 16:30 - 17:30 1.00 RUNCOMP COMP 17:30 - 19:00 1.50 RUNCOMP COMP 19:00 - 20:00 1.00 RUNCOMP COMP 20:00 - 00:00 4.00 RUNCOMP CaMP 5/7/2004 00:00 - 00:30 0.50 RUNCOMP COMP 00:30 - 02:00 1.50 RUNCOMP COMP 02:00 - 02:30 0.50 RUNCOMP COMP PJSM. Scope down & layover derrick. Move rig & rig components from MP K-30 to MP K-13. Rig up on well. PJSM. Rig up lines, take on sea water. Rig accepted @ 07:00 hrs. Rig up lines to tiger tank & circulating lines on tree. PJSM. Rig up lubricator, pull BPV. SITP = 200 psi, II A = 190 psi, CIA = 50 psi. Pressure test surface equipment to 3500 psi, OK. PJSM. Line up & circulate @ 3-4 bpm 1700 psi. Crude returns to tiger tank. Circulate 350 bbls, returns cleaning up. Monitor well, well dead. O/A increased to 550 psi due to thermal expansion, line up & bleed off to tiger tank. PJSM. Rig down surface lines. Install 2 way check valve. PJSM. Bleed void & N/D tree. PJSM. N/U 135/8" x 5M BOPE. AOGCC State Rep Chuck Sheve waived witnessing BOPE test. Test BOP equip as per AOGCC/BP requirements, LP 250 psi, HP 3500 psi. P/U lubricator, Pull TWC. UD plug & lubricator. BOLDS. P/U w/63K & pull hanger up 2'. Circulate bottoms up. Monitor well. Well Dead. Had very small amt of gas to surface while circulating. Pull hanger to floor. UD hanger & test ESP cable. Pull ESP cable over sheave & connect to spooler. POOH w/2 7/8" ESP completion. Stand tubing back in derrick. Con't to POOH w/2 7/8" ESP completion & standback in derrick. Pulled 75 stands, + 2 GLMs assys, + "XN nipple assy. Recovered 121 LaSalle Clamps, 2 Flat Guards, 4 Protectolizers. Pull & UD pump & motor. Clear & clean rig floor. Prep to RIH to clean out well bore. M/U muleshoe on 2 7/8" tubing & RIH. Tag 15 1/2' in on Jt # 237 @ 7431'. 52K up wt, 45K down wi. PJSM. Line up & attempt to wash down, no good. Spud on top of fill @ 7431' while circulating @ 5112 bpm 11100 psi a few times with no effect. Set 5-7K down, throw in rotary slips & rotate while pumping 5 bpm. Max torque = 2000 ftllbs. Pull slips. able to wash down now. Reverse circulate out fill @ 5 1/2 bpm 11100 psi to 7509' where we experienced total loss of returns. Line up to circulate long way & wash down to 7541', hard tag on packer. Pick up l' & reverse circulate 50 bbls, no returns. PJSM. Break off circ head & POOH w/2 7/8" tbg, laying down 1st 14jts. Clear & clean rig floor. PJSM. Rig up to run 2 7/8" ESP completion string. P/U & M/U ESP. Service & test same. Pull MLE over sheave. Plug In & test connection. RIH wI ESP on 27/8" tubing. Test & pump thru pump every 2000'. P/U landing it. M/U into hanger. Install penetrator. Make fiield connection. Plug into penetrator & test same. Land completion RILDs, Ran 227 its of 2 7/8" tbg. Bottom of Printed' 5/10/2004 9:21'43 AM -------- ---------- ---------------- ------------- r". , /\ ,B~",~?<~L , '::.T,..:./".'t""'i.o... ?~.':."o':X-;",...','.'...S.....o .,'.' a;~..'Qn$~' 0 ,"Co.", ""','~ .,",'.WH" 0 - ..", ... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-13 MPK-13 WORKOVER Start: 5/5/2004 Rig Release: Rig Number: Spud Date: 8/25/2000 End: 2/7/2004 'LOCa:tß1; From - ,.I;'.>,~!?¡iRt!Qrì 0 , :,..,:1. .' 5/7/2004 02:00 - 02:30 0.50 RUNCOMP CaMP centralizer @ 7293'. Top of ESP @ 7236'. "XN" @ 7220'. GLM wI dummy @ 7077'. GLM wI DSOV @ 141'. Install TWC. test to 3500 psi. N/D BOPE. N/U & test tree. Make final ESP electrical check. Install BPV & test. Clean cellar & secure well. RELEASE RIG @ 0600 Hrs. 02:30 - 04:00 04:00 - 05:30 05:30 - 06:00 1.50 BOPSUP P 1.50 WHSUR P 0.50 WHSUR P CaMP CaMP CaMP Printed: 5/10/2004 9:21.43 AM , .. ., Tree: Cameron 2 9/16" - 5M-" Wellhead: 11" x 7 1/16" S\¡, JlC Gen 5A, wI 27/8" FMC Tbg. Hng., top fift thread = 3" LH Acme, btm = 2 7/8" 8rd EUE & 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 I 112' KOP @ 700' Max. hole angle = 26° @ 3430' Hole angle thru' perfs = 25 deg. 95/8",40 ppf, L-80 Btrc. I 3723' I ~ 2-7/8",6.5 ppf, L-80, EUE 8rd tubing drift 10 = 2.347", cap = .00579 bpf 7", L-80, Mod. Btrc. 26 ppf prod. csg. (drift 10 = 6.151", cap. = 0.0383 bpf) Stimulation Summary 12/09/96 Frac packed 'C' sands w/ 1500 Ibs. 20/40 carbolite prop. behind pipe. Screened out to formation. Two 7" Marker its.from 7,306' to 7,348' md Peñoration Summary Ref. Log: GR/CCL 12/08/96 Size SPF Interval (TVD) 7005'-7036' 4.5" 7474'-7526' 12 24 gm. bighole charges (EHD=.7) TTP= 7.88" (135/45 degree phase) ~ DATE REV, BY 10 /21 / 96 MDO 01/21/98 M,linder 10/19/98 MDO 01/20/99 JBF 8121199 MH 08/30100 M.Linder 412/03 Hulme 05107104 J Cubbon Drilled and Cased by Nabors 27E Rebuild lost drawing, ESP RWO & Scale pellets 4ES ESP Replacement by Nabors 4ES ESP Reclacement bv Nabors 4ES RWO - Pulled screens RWO - ESP Replacement by 4ES RWO - ESP Replacement"by 4ES II MPU K-13 tl fi ~ 7 , , ~ ~ ~ JII8~ COMMENTS - Ori~ Elev. = 56.95' (N 27E) Orig. '-AL Elev. = 27.5' AT To Tbg. Spool = 29.45' (N 27E) Camco 2 7/8" x 1" sidepocket KBMM GLM 141' . Camco 2 7/8" x 1" sidepocket KBMM GLM 2-7/8" HES XN-Nipple ( 2.205" id ) I 7077' I 7220' Centrilift Pump 151 Stages I 7236' I GC 170 GPMTAR 1:1 Tandem Gas Separator GRSXTBAR I 7254' I Tandem seal sections I 7259' I GSB3DBUT/LTILH6PFS AFLAS/HSN Centrilift KMH 562 series, I 7272' I 171 hp motor, 2390 v.l44 a. PumpMate wI 6 fin centralizer I 7288' I ,. Old- screen 'assembly pulled 8/30/00. . . . . 7" HES BWD sump. 3.S" XN nipple (2.7S"x 2.63") 7" float collar (PBTO) 7" float shoe I 7531' I 7543' I 7780' I 7861' MilNE POINT UNIT WELL K -13 API NO: 50..Q29-22655 _.- BP EXPLORATION (AK) . ""'" · · ~..~ STATE OF ALASKA -,_~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 56.95' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3676' NSL, 2111' WEL, SEC. 3, T12N, R11 E, UM X = 584445, Y = 60058.1,,1 MPK-13 ', 9. Permit Number/ Approval No. At top of productive interval ~ 196-040 5000' NSL, 165' WEL, SEC. 3, T12N, R11E, UM X = 586374, Y = 6007157 10. APl Number At effective depth 50-029-22655-00 5078' NSL, 54' WEL, SEC. 3, T12N, R11E, UM X = 586483, Y = 6007237 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 5102' NSL, 21' WEL, SEC. 3, T12N, R11E, UM X = 586516, Y = 6007261 Sands 12. Present well condition summary Total depth: measured 7875 feet Plugs (measured) true vertical 7364 feet Effective depth: measured 7780 feet Junk (measured) true vertical 7278 feet Casing Length Size Cemented MD TVD Structural Conductor 78' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 3691' 9-5/8" 938 sx PF 'E', 700 sx Class 'G' 3723' 3576' Intermediate Production 7833' 7" 235 sx Class 'G' 7861' 7352' Liner Perforation depth: measured 7474'- 7526' RECEIVED APR ] 6 2O03 true vertical 7002' - 7049' Alaska Oil & Gas Cons. Con~n-S-nl$ io Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, EUE 8rd tubing to 7292' Anchorage Packers and SSSV (type and measured depth) 7" HES BWD Sump packer at 7531' with a 3-1/2" tailpipe to 7543' (The gravel pack assembly was pulled, leaving the sump packer in place.) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: i5. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service '"'~'~. [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Son~~(.~,.~.....~) Title Technical Assistant Date .-, ~ t /'~ I k ! ~pa/~. ~B~y. N__arn~_ _umber: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 ;~~[-~ ~A7 Ci 5 ~.~.~ mit In Duplicate BP EXPLORATION ' ~'.'.. 'page.1 of"1 . Operations .$umm:a .Report ..' :. .... .. . .. ... . . : ..... . . .' . . . .. . . .... :. . Legal Well Name: MPK-13 Common Well Name: MPK-13 Spud Date: 8/25/2000 Event Name: WORKOVER Start: 3/31/2003 End: 4/2/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From-To Hours Task COde Up~: : DescriptiOn..ofOpe.ratic~ns: 3/31/2003 16:00 o 19:30 3.50 MOB P PRE RDMO MPK-34 & Move to MPK-13. Spot in rig & equip. 19:30 - 21:00 1.50 RIGU P PRE Rig up. raise & scope derdck. 21:00 - 23:30 2.50 RIGU P DECOMP ACCEPT RIG @ 2100 HRS, 3/31/2003... Take on seawater. P/U lubricator & pull BPV. L/D lubricator. R/U kill lines. Test lines to 2500 Psi, OK. 23:30 - 00:00 0.50 KILL P DECOMP Performed Well Kill Risk Assessment. PJSM. Begin kill operations. SITP 130 Psi. SICP 100 Psi. Open wel & begin killing well. Pump in & 6 BPM. No returns to surface. Caught pressure w/21 Bbls down tbg. --/- 3600'. 4/1/2003 00:00 - 01:00 1.00 KILL DECOMP Finish killing well. Circulated 280 bbls 120 degree heated seawater. Had no returns thru out job. 6 BPM, Final circ pressure 900 Psi. Pumped total of 280 Bbls. Monitor well, well on vacuum, then dead. 01:00 - 01:30 0.50 WHSUR DECOMP Set TWC & test to 2500Psi, OK. 01:30 - 02:30 1.00 WHSUR DECOMP N/D & load out x-mas tree. 02:30 - 04:30 2.00 BOPSURt DECOMP I N/U DOPE. Install 2 7~8" pipe rams. 04:30 - 06:00 1.50 BOPSUR DECOMP R/U test equip. Pressure test body of DOPE. LP 250 Psi, HP 3500 Psi. Function test koomey. BOP test witnessing waived by Jeff Jones w/AOGCC. 06:00 - 07:00 1.00 WHSUR DECOMP P/U lubricator. Pull TWC. L/D lubricator. 07:00 - 07:30 0.50 WHSUR DECOMP P/U landing Jt & M/U into tbg hanger. BOLDS. 07:30 - 08:00 0.50 WHSUR DECOMP Pull hanger w/76K to floor.. Test ESP. 08:00 - 08:30 0.50 PULL DECOMP Pull 2 7~8" tbg & attach ESP cable to spooler. 08:30 - 12:30 4.00 PULL DECOMP POOH w/ESP completion & stand back in derrick. 12:30 - 14:00 1.50 PULL DECOMP L/D pump & motor. Retrieved (118) La Salle Clamps & (4) i Protectralizers. 14:00 - 15:00 1.00 PULL DECOMP Clear & clean floor. Load out old ESP. Unload new pump & motor. 15:00 - 17:00 2.00 RUNCOI~ COMP P/U new pump & motor. Assemble, test & service same. 17:00 - 18:30 1.50 RUNCOr~ COMP , Pull MLE over sheave, plug in & test ESP 18:30 - 21:00 2.50 RUNCOI~ COMP RIH to 4000' w/new ESP on 2 7~8" tubing. Test & flush pump every 2000'. 21:00 - 22:00 1.00 RUNCOI~ COMP Cut & slip 100' of drilling line. 22:00 - 00:00 2.00 RUNCOI~I COMP Con't to RIH w/ESP completion. Ran 227 jts 2 7/8" 6.5#, L-80, EUE, 8 RD tbg to 7292' MD. P/U 68K, S/O 56K. Used 121 LaSalle Clamps, 2 Flat Guards, 4 Protectolizers. 4/2/2003 00:00 - 00:30 0.50 RUNCOr~ COMP Make up hanger & landing Jr. Install new penetrator. 00:30 - 02:00 1.50 RUNCOr~ I COMP Splice EFT connector. Plug in & test same. 02:00 - 02:30 0.50 RUNCOI~ COMP Land hanger & set TWC. 02:30 - 04:00 1.50 BOPSUR COMP N/D DOPE. 04:00 - 05:30 1.50 WHSUR COMP N/U X-mas tree & test to 5000 Psi, ok. Perform final ESP test, Ok. 05:30 - 06:00 0.50 WHSUR COMP P/U lubricator & pull TWC. Install BPV. Secure well. Release Rig @ 0600 HRS, 4/2/2003. _.,- ~ 0 200:3 Printed: 4/8/2003 9:04:04 AM .... STATE OF ALASKA ' - ALASKA ,L AND GAS CONSERVATION COMN,. ,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 56.95' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3676' NSL, 2111' WEL, SEC. 3, T12N, R11E MPK-13 At top of productive interval 9. Permit Number/ Approval No. 196-040 5000' NSL, 165' WEL, SEC. 3, T12N, R11E 10. APl Number At effective depth 50-029-22655-00 5078' NSL, 54' WEL, SEC. 3, T12N, R11E 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 5102' NSL, 21' WEL, SEC. 3, T12N, R11E Sands 12. Present well condition summary Total depth: measured 7875 feet Plugs (measured) true vertical 7364 feet Effective depth: measured 7780 feet Junk (measured) true vertical 7278 feet Casing Length Size Cemented MD TVD Structural Conductor 78' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 3691' 9-5/8" 938 sx PF 'E', 700 sx Class 'G' 3723' 3576' Intermediate Production 7833' 7" 235 sx Class 'G' 7861' 7352' Liner Perforation depth: measured 7474'- 7526' SEP 2 2 ?000 true vertical 7002' - 7049' AiaSk~ 0;i & Gas~,_,,.:.;'.~,',:' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, EUE 8rd tubing to 7269' Packers and SSSV (type and measured depth) 7" HES BWD Sump packer at 7531' with a 3-1/2" tailpipe to 7543' (The gravel pack assembly was pulled, leaving the sump packer in place.) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data Oil-abl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~/~~ ~ Title TechnicalAssistantlll Date Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate. :: : : : : ::BP AMOc° SEP 2 2 2000 Page 1 of 2 : °pera iOn Summary & ( as Cor, . commission ,qn orage Legal Well Name: MPK-13 Common Well Name: MPK-13 Spud Date: 8/25/2000 Event Name: WORKOVER Sta~: 8/25/2000 End: 8/30/2000 Contractor Name: NABORS Rig Release: 8/30/2000 Group: Rig Name: NABORS 4ES Rig Number: 4ES ::~r°~ ~ ~° ;~ :H~rs:1 : ~ Description of Operations 8/25/2000 06:00 - 15:00 9.00 RIGU DECOMP Moved Rig from MP E-22 to MP K-13 Location and rig up. Rig accepted at 15:00 hrs. 08-25-2000. 15:00 - 16:30 1.50 RIGU DECOMP Rig up HCR valve, hook up lines in the cellar, Rig up Lubricator and pull BPV and lay down same. 16:30 - 20:30 4.00 KILL DECOMP Tested lines to 3,000 psi. SlTP 300 psi and Annular 350 psi. Rigged up to circulate annulus to Tiger tank through choke. Pumped 390 bbls of 8.4 PPG water at 4.9 bbl/min rate at 700 to 1300 psi. Pumped 135 bbls over calculated displacement volume. Recovered 197 bbls of fluid to frac tank. 20:30 - 21:00 0.50 WHSUR DECOMP Install and Test ~C. Test to 3500 psi from above. 21:00 - 22:00 1.00 WHSUR DECOMP Nipple down Tree. 22:00 - 00:00 2.00 WHSUR DECOMP Install Double Studded Adapter and NU BOP 8/26/2000 00:00- 00:30 0.50 WHSUR DECOMP Nipple Up BOP 00:30 - 02:00 1.50 BOPSUR DECOMP Do Full Body test on BOP test 7 1/16"x 13 5/8" flange to 3500 psi 02:00 - 04:00 2.00 BOPSUF DECOMP PU Lubricator and Pull ~C/LD Lubricator MU Landing JT. Back Off Lock Down Screws 04:00 - 04:30 0.50 PULL DECOMP Pull Hanger to floor and lay down landing Joint. 04:30 - 06:00 1.50 PULL DECOMP Flush Injection chemicals in in Capilaw line. 06:00 - 15:30 9.50 PULL DECOMP Shoot fluid level prior to pulling production assembly. POOH with 2 7/8" production assembly. Shot fluid levels eve~ 2,000' while POH. Pumped actual pipe displacement evew 5 stands. Echometer indicated fluid level maintaining at 1,990' +-. Bolt from slips broke off and fell in hole. Production Assembly pulled tight at 757'. Pulled free with 55K over string weight. POH and laid down ESP assembly. 15:30 - 17:30 2.00 PULL DECOMP Clear rig floor and rig up tubing punch. Punched holes in in 3 1/2" ;tubing on tail pipe to relieve pressure. REcovered 1' of sand in tail pipe. Rigged down tubing punch. 17:30 - 00:00 6.50 CLaN DECOMP Rigged Up Hallibu~on HallibuKon Wireline UNit. Ran tools on 3/16" braded line. Run ¢ 1- Junk basket and 6.00" gauge ring to top of 7" Hallibu~on Versatrieve packer at 7,368' WLM. poh with Junk basket with no recovew. Run ¢ 2- RIH with 5 1/2" ski~ed magnet to 7,368'. POH with magnet recovering small amont of metal slivers. Run ¢ 3- RIH w/2 1/4" bailer with 3.70" tapered swedge to 7,411' WLM. Correlate 3.70" tapered swedge tagged up in safety sub at 7,399'. POOH with bailer. 8/27/2000 00:00 - 00:30 0.50 CLaN DECOMP Rigged down Hallibu~on Slick line unit. 00:30 - 01:30 1.00 PULL DECOMP Picked up Howco retreiving tool and BHA 01:30 - 04:00 2.50 PULL DECOMP PU 3 1/2" DP while running in the hole 04:00 - 05:00 1.00 PULL DECOMP Cut & slip 84' drlg line ;05:00 - 09:00 4.00 PULL DECOMP PU 3 1/2" DP while running in the hole to 7,378' 09:00 - 10:00 1.00 PULL DECOMP Picked up Kelly and washed down at 1.5 bbl/min and tagged top of packer at 7,403'. Attempted to latch packer with retrieving tool. Worked and sheard pins in 7" Hallibu~on Versatrieve Packer. Pick up weight 126 K and 103 K down weight. Pulled free. 10:00 - 14:30 4.50 PULL DECOMP Pulled out of the hole with 3 1/2" drillpipe, BHA and Hallibu~on retieving tool. J slot indicated that packer never J-ed up. Laid down retrieving tool and Picked up Jars. 14:30 - 15:00 0.50 WHSUR DECOMP ~lnstall wear ring 15:00 - 18:30 3.50 PULL DECOMP Picked up Spear and MU on BHA. RIH with BHA on 3 1/2" drill pipe to 7,389'. t8:30 - 19:30 1.00 PULL DECOMP Picked up Kelly and tag top offish at 7,404'. Speared packed and 3ulled 50 K over Pickup weight and jars hit. Pulled packer free. 19:30 - 00:00 4.50 PULL DECOMP Pulled out of the hole with 3 1/2" DP. Recovered Hallibu~on 7" Printed: 9/19/2000 4:11:13 PM :: :i : ?i:: : i ::ii ii : ::: ii : i :::: ii: : :: : : i i: o erati0nslSUmmary Report Legal Well Name: MPK-13 Common Well Name: MPK-13 Spud Date: 8/:25/2000 Event Name: WORKOVER Start: 8/25/2000 End: 8/30/2000 Contractor Name: NABORS Rig Release: 8/30/2000 Group: Rig Name: NABORS 4ES Rig Number: 4ES ::: ~ate 1~,o~ !:~I ~i~ !Aci(i!~!~ ~haSelt: Description of Operations 8/27/2000 19:30 - 00:00 4.50 PULL DECOMP Versatrieve packer. Fish length 32.50'. 8/28/2000 00:00 - 03:00 3.00 CLEAN DECOMP Picked up 5 1/2" wash pipe and RIH with Washover BHA on 3 1/2" DP to 7,415' 03:00 - 07:30 4.50 CLEAN DECOMP Picked up Kelly and tagged top of fish at 7,433'. Wash over fish at 3 bpm at 350 psi. 07:30 - 11:30 4.00 PULL DECOMP Pulled out of the hole with 5 1/2" Wash Over assembly and laid down wash pipe. 11:30 - 15:00 3.50 FISH DECOMP Make up 5 3/4 overshot w/3 1/2" grapple. TIH with overshot assenmbly on 3 1/2" drill pipe to top of screens at 7433'. 15:00 - 20:00 5.00 FISH DECOMP Picked up kelly,washed over fish and engaged grapple, pulled 20K over pick up weight. Packed off, dropped ball and rod to open pump out sub. Pressured up to 1,800 psi and sheared to shear pump out sub. Stand Kelly back and pull out of the hole with fish. 20:00 - 21:00 1.00 FISH DECOMP Laid down BHA and cleaned rig floor 21:00 - 00:00 3.00 CLEAN DECOMP Make up mule shoe and TIH with 3 1/2" drill pipe 6,823' 8/29/2000 00:00 - 00:30 0.50 CLEAN DECOMP TIH with mule shoe and BHA to top of sump packer at 7,527' hard bottom. Picked up 2' off bottom 00:30 - 04:00 3.50 CLEAN DECOMP Reverse circulated well with 325 bbls of clean sea water at 4 bpm @ 540 psi. Well clean 04:00 - 10:00 6.00 CLEAN DECOMP Pulle out of the hole and lay down 3 1/2" driil pipe 10:00 - 10:30 0.50 CLEAN DECOMP Laid down 6 -4 3/4" drill collars and mule shoe 10:30 - 11:00 0.50 WHSUR DECOMP Pull wear bushing 11:00 - 12:30 1.50 RUNCOI~ COMP Clean rig floor and rig up to run 2 7/8" ESP completion 12:30- 14:30 2.00 RUNCOr ,COMP Picked up up, make up and serviced ESP, Plug in and check ESP cable 14:30 - 00:00 9.50 RUNCOr :COMP RIH with 2 7/8" ESP completion assembly and ESP cable. Do reel to reel splice on ESP cable at 5485'. TIH to 7,267'. 8/30/2000 00:00 - 02:30 2.50 RUNCO~I COMP MU Hanger and Landing Jt. Attach field connector kit, connector and penetrator and test. Land Hanger Test TWC. 02:30 - 04:00 1.50 WHSUR COMP ND BOP 04:00 - 06:00 2.00 WHSUR COMP NU Tree and test to 5,000 psi. Pull TWC and install BPV. Rig released at 06:00 hrs 08-30-00 SEP £?- . ~,... , . , . ,. Printed: 9/19/2000 4:11:13 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown []Stimulate I--I Plugging [] Perforate [] Pull Tubing I~AIter Casing [] Repair Well [~ Other Change Out ESP 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3676' NSL, 2111' WEL, SEC. 3, T12N, R11E At top of productive interval 4999' NSL, 153' WEL, SEC. 3, T12N, R11E At effective depth 5078' NSL, 54' WEL, SEC. 3, T12N, R11E At total depth 5103' NSL, 10' WEL, SEC. 3, T12N, R11E 5. Type of well' [~ Development I--I Exploratory [] Stratigraphic [--I Service 6. Datum Elevation (DF or KB) KBE - 57' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-13 9. Permit Number / Approval No. 96-40 10. APl Number 50-029-22655 ~ 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 7875 feet true vertical 7360 feet Effective depth: measured 7780 feet true vertical 7274 feet Casing Plugs (measured) Junk (measured) Length Size Cemented M D TVD Structural Conductor 78' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 3691' 9-5/8" 938 sx PF 'E', 700 sx Class 'G' 3723' 3576' Intermediate Production 7833' 7" 235 sx Class 'G' 7861' 7352' Liner Perforation depth: measured 7474' - 7526' true vertical 7002' - 7049' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, EUE 8rd tubing to 7367' Packers and SSSV (type and measured depth) 7" Cavins Desander at 7235'; Gravel Pack Assembly at 7403' - 7531' with a 3-1/2" tailpipe to 7543' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 7. I hereby certify that the foregoing is true and correct to the best of my knowledge Terde Hubble ~, Title Technical Assistant III Prepared By Name/Number: 6. Status of well classifications as: [~ Oil [--I Gas I~ Suspended Service 5. Attachments [--I Copies of Logs and Surveys run [] Daily Report of Well Operations Tubing Pressure Terrie Hubble, 564-4628 ~ ~n ~u plicat~ ~--..~.._~ Form 10-404 Rev. 06/15/88 Facility M Pt K Pad Date/Time 17 Aug 99 12:15-06:00 12:15-06:00 Duration 17-3/4 hr 17-3/4 hr 18 Aug 99 06:00 06:00-06:00 06:00-11:00 24 hr 5hr 11:00 11:00-21:00 21:00 21:00-22:00 lOhr lhr 19 Aug 99 22:00 22:00-23:30 23:30 23:30-04:00 04:00 04:00-06:00 06:00 06:00-09:00 06:00-09:00 1-1/2 hr 4-1/2 hr 2hr 3hr 3hr 09:00 09:00-12:30 09:00-12:30 3-1/2 hr 3-1/2 hr 12:30 12:30-15:30 12:30-15:30 15:30 15:30-16:30 15:30-16:30 16:30 16:30-18:00 16:30-18:00 18:00 18:00-21:30 18:00-21:30 21:30 3hr 3hr lhr lhr 1-1/2 hr 1-1/2 hr 3-1/2 hr 3-1/2 hr Progress Report Well MPK- 13 Page Rig Nabors 4ES Date 1 08 September 99 Activity Move rig Rig moved 50.00 % Lower derrick -& Move pits & pipe shed too K-pad & while moving sub & camp to K-Pad sub sank on K-Pad access road & block rig up with plywood & 3x12's timbers. Began precautionary measures building road bed up to hold rig. Move rig (cont...) Rig moved 5.00 % crib up & fill in hole with lumber & pull rig from stuck spot. & make decison to matt road in spots with plywood. Began precautionary measures Rig moved 5.00 % ferry plywood around rig & lay same dn road. Began precautionary measures Rig moved 5.00 % Move rig dn road approximately 1-mile & stuck rig in soft spot. Began precautionary measures Rig moved 5.00 % crib rig up & pull out of stuck spot. Began precautionary measures Rig moved 5.00 % lay plywood on road from soft spot to K-pad. Began precautionary measures Rigged up Drillfloor / Derrick move rig onto K-pad & set sub & pits. Stopped: To hold safety meeting crew change Move rig (cont...) Rig moved 100.00 % rig spotted & bermed rig accepted @ 0600 hrs. 8/19/99 At well location - Slot Fluid system Fill pits with Seawater fill pits with sea h20 & pull bpv & rig lines to tiger tanks. Completed operations Well control Circulated closed in well at 7800.00 ft Hole displaced with Seawater - 150.00 % displaced Wellhead work Installed Hanger plug Equipment work completed test twc to 2500 psi. Wellhead work Removed Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Facility Date/Time 20 Aug 99 21 Aug 99 M Pt K Pad Progress Report Well MPK- 13 Page 2 Rig Nabors 4ES Date 08 September 99 21:30-01:00 21:30-01:00 01:00 01:00-05:30 01:00-05:30 05:30 05:30-06:00 05:30-06:00 06:00 06:00-07:30 06:00-07:30 07:30 07:30-19:00 07:30-19:00 19:00 19:00-23:00 19:00-23:00 23:00 23:00-06:00 23:00-06:00 06:00 06:00-17:00 06:00-11:00 11:00 11:00-14:30 14:30 14:30-15:30 15:30 15:30-17:00 17:00 17:00-18:00 17:00-18:00 18:00 18:00-19:00 18:00-19:00 19:00 19:00-21:00 19:00-21:00 21:00 21:00-23:00 21:00-23:00 Duration 3-1/2 hr 3-1/2 hr 4-1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 11-1/2 hr 11-1/2 hr 4 hr 4hr 7hr 7hr llhr 5hr 3-1/2 hr lhr 1-1/2 hr lhr lhr lhr lhr 2hr 2hr 2hr 2hr Activity Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi test witnessed by John Spaulding (aogc) Derrick management Serviced Choke manifold change manul valve on kill line next to bop's Work completed, Failsafe valves changed out Wellhead work Removed Hanger plug Stopped: To hold safety meeting Wellhead work (cont...) Retrieved Hanger plug Equipment work completed Pull Single completion, 2-7/8in O.D. Pulled Tubing in stands to 7358.00 ft pull esp completion and lay dn pump & accessories. Completed operations Slickline wireline work Conducted slickline operations on Slickline equipment - Tool run run # 1 5.95" gr/jb to 7395' rec. rubber & band. run #2 2.49" swedge to 7775' td check run #2 Completed run with Junk basket/gauge ring from 0.00 ft to 7775.00 f~ Run Single completion, 2-7/8in O.D. Ran Tubing in stands to 2500.00 ft mu cavins desander & esp assy & rih with same Stopped: To hold safety meeting crew change Run Single completion, 2-7/8in O.D. (cont...) Pulled Tubing in stands to 7367.00 ft Completed operations Serviced ESP splice esp cable & attempt to land hanger Equipment work completed Laid down 31.25 ft of Tubing lay dn l-it. tbg. Completed operations Serviced ESP splice esp cable & land hanger Equipment work completed Wellhead work Installed Tubing hanger install tbg. hanger & rilds Equipment work completed, seal energised Wellhead work Installed Hanger plug set twc & test to 2500 psi. Equipment work completed Nipple down BOP stack Removed BOP stack Equipment work completed Wellhead work Installed Xmas tree install tree & test to 5000 psi. Facility Date/Time M Pt K Pad 23:00 23:00-06:00 23:00-01:00 Progress Report Well MPK- 13 Page Rig Nabors 4ES Date 3 08 September 99 22 Aug 99 01:00 Duration 7hr 2hr Activity Equipment work completed Fluid system Freeze protect well - 13.000 bbl of Diesel mu lub & pull twc & set bpv & pump diesel dn tbg. & remove ines & secure tree. Completed operations rig released @ 0100 hrs. 8/22/99 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert C h riste nso n,(V/~JU[[4/ DATE: Chairman THRU: Blair Wondzeil, ~ FILE NO: P. I. Supervisor FROM: John H Spauldin¢/~,~ SUBJECT: Petroleum InspectOr August 19, 1999 awqlhsgf.doc BOPE Test Nabors 4ES MPU K-13 PTD 96-040 August 19, 1999: I traveled to BPX's Milne Point Unit to witness the BOP test on Nabors 4ES. The AOGCC BOPE test report is attached for reference. As noted on the test report form 1 manual valve located on the choke line failed to test. Gene Sweatt the rig rep. had a new one on location and was installing it when I departed. He will call and fax a copy of the chart in the morning. The rig was in very good condition. The surrounding area was well kept with good access to the rig. SUMMARY: I witnessed the BOP test on; Nabors 4ES, 21 components, 1 failure, 5 hours Attachment: awqlhsgf.xls Not Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: Nabors Rig No. 4ES PTD # Operator: BPX Rep.: Well Name: K-13 Rig Rep.: Casing Size: 7" Set @ 7,861 Location: Sec. Test: Initial X Weekly Other 96-040 DATE: 8/19/99 Rig Ph.# 659-4154 Larry Myers Gene Sweatt T. R. Meridian TEST DATA MISC. INSPECTIONS: Location Gen.: ok Well Sign ok Housekeeping: ok (Gert) Drl. Rig ok PTD On Location Hazard Sec. ok Standing Order Posted ok -~- BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln, Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 1 250/3,500 P 250/3,500 P 250/3,500 P 250/3,500 P 250/3,500 F* 250/3,500 P 250/3,500 P 250/3,500 MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Quan. Test Pressure 250/3,500 P/F 250/3,500 25O/3,5OO P 250/3,500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 11 250/3,500 P 22 250/3,500 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4@ '1900 3,000 1, 700 P minutes 30 sec. minutes 20 sec. x Remote: Psig. : : TEST RESULTS Number of Failures: 1 ,Test Time: 5.0 'Hours, Number of valves tested 21 Repair or Replacement of Failed Equipment will be made within I days. Notify the Inspector and follow with Written or Faxed verification to the AOOCC Commission Office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: Grig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X' NO Waived By: Witnessed By: John H. Spaulding FI-021L (Rev. 12/94) awqlhsgf, xls STATE OF ALASKA ALASKA 0,,_ AND GAS CONSERVATION COMIv,,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown I--]Stimulate [] Plugging [] Perforate [] Pull Tubing [--]Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface t5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 57' 7. Unit or Property Name Milne Point Unit 8. Well Number 3676' NSL, 2111' WEL, SEC. 3, T12N, R11E At top of productive interval 4999' NSL, 153' WEL, SEC. 3, T12N, R11E At effective depth 5078' NSL, 54' WEL, SEC. 3, T12N, R11E At total depth 5103' NSL, 10' WEL, SEC. 3, T12N, R11E 12. Present well condition summary Total depth: measured 7875 feet true vertical 7360 feet Effective depth: measured 7780 feet true vertical 7274 feet Plugs (measured) Junk (measured) MPK-13 9. Permit Number / Approval No. 96-40 10. APl Number 50-029-22655 11. Field and Pool Milne Point Unit / Kuparuk River Sands ORIGINAL Casing Length Size Cemented M D TVD Structural Conductor 78' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 3691' 9-5/8" 938 sx PF 'E', 700 sx Class 'G' 3723' 3576' Intermediate Production 7833' 7" 235 sx Class 'G' 7861' 7352' Liner Perforation depth: measured 7474' - 7526' true vertical 6998' - 7045' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, EUE 8rd tubing to 7388' Packers and SSSV (type and measured depth) 7" Cavins Desander at 7255'; Gravel Pack Assembly at 7403' - 7531 with a 3-1/2" tailpipe to 7543' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 5. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 7. I hereby certify that the,foregoing is true and correct to the best of my knowledge Signed cdeV, ' ~ Terrie Hubble"/~,/~/~. Title Technical Assistant III Prepared By Name/Number: Date Terrie Nubble, 564-462__8_ Submit In Duplicate-~ Form 10-404 Rev. 06/15/88 Progress Report Facility M Pt K Pad Well MPK-13 Page 1 Rig Nabors 4ES Date 08 March 99 Date/Time 17 Jan 99 18 Jan 99 19 Jan 99 00:00-06:00 06:00-09:00 09:00-10:00 10:00-11:00 11:00-13:00 13:00-14:30 14:30-17:30 17:30-21:00 21:00-22:00 22:00-06:00 06:00-09:00 09:00-10:00 10:00-13:00 13:00-13:30 13:30-14:30 14:30-15:30 15:30-16:00 16:00-18:00 18:00-20:00 20:00-23:30 23:30-05:30 05:30-06:00 06:00-06:30 06:30-12:00 12:00-16:00 16:00-16:30 16:30-18:00 18:00-19:30 19:30-21:30 21:30-22:00 22:00-00:00 Duration 6hr 3hr lhr lhr 2hr 1-1/2 hr 3hr 3-1/2 hr lhr 8hr 3hr lhr 3hr 1/2 hr lhr lhr 1/2 hr 2hr 2hr 3-1/2 hr 6hr 1/2 hr 1/2 hr 5-1/2 hr 4hr 1/2 hr 1-1/2 hr 1-1/2 hr 2hr 1/2 hr 2hr Activity Rig moved 75.00 % Rig moved 100.00 % Rigged up High pressure lines Installed Hanger plug Circulated closed in well at 7356.0 ft Removed Xmas tree Rigged up BOP stack Tested BOP stack Removed Hanger plug Pulled Tubing in stands to 0.0 ft Rigged down sub-surface equipment - ESP Made up BHA no. 1 R.I.H. to 7375.0 ft Reverse circulated at 7375.0 ft R.I.H. to 7775.0 ft Reverse circulated at 7775.0 ft Pulled out of hole to 7522.0 ft Acid job - 12.000 bbl acid pumped at 575.0 psi, conc. = 12.00 %, press Mixed and pumped 24.000 bbl of treatment Pulled Tubing in stands to 0.0 ft Functioned ESP Ran Tubing in stands to 300.0 ft Held safety meeting Ran Tubing in stands to 7387.0 ft Installed Tubing hanger Installed Tubing hanger Rigged down BOP stack Installed Xmas tree Tested Xmas tree Freeze protect well - 65.000 bbl of Diesel Rigged down High pressure lines STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: E~] Operation Shutdown F'] Stimulate I--I Plugging I-] Perforate [] Pull Tubing I-3AIter Casing [-I Repair Well [~Other ESP Changeout 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3676' NSL, 2111' WEL, SEC. 3, T12N, R11E At top of productive interval 4999' NSL, 153' WEL, SEC. 3, T12N, R11E At effective depth 5079' NSL, 43' WEL, SEC. 3, T12N, R11E At total depth 5103' NSL, 10' WEL, SEC. 3, T12N, R11E 5. Type of well: [~ Development [] Exploratory [--I Stratigraphic ['-1 Service 6. Datum Elevation (DF or KB) Plan RTE = 57' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-13 9. Permit Number / Approval No. 96-40 10. APl Number 50-029-22655 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 7875 feet true vertical 7360 feet Effective depth: measured 7780 feet true vertical 7274 feet Casing Length Size Structural Conductor 78' 20" Surface Intermediate 3691' 9 5/8" Production - Liner 7833' 7" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset 1 (Approx) 938 sx PF 'E', 700 sx Class 'G' 235 sx Class 'G' MD TVD 112' 112' 3723' 3576' 7861' 7352' Perforation depth: measured 7474'- 7526' true vertical (Subsea) 6945' - 6992' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 set at 7387' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure I15. Attachments [] Copies of Logs and Surveys run ,J~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 Jea - Title Staff Technical Assistant /'/ Prepared By Name/Number: Date ~.~////¢ c"'/ Jeanne L. I/-la,~s, 564-5225 Facility M Pt K Pad Progress Report Well MPK-13 Page 1 Rig Nabors 4ES Date 28 January 99 Date/Time 17 Jan 99 18 Jan 99 19 Jan 99 00:00-06:00 06:00-09:00 09:00-10:00 10:00-11:00 11:00-13:00 13:00-14:30 14:30-17:30 17:30-21:00 21:00-22:00 22:00-06:00 06:00-09:00 09:00-10:00 10:00-13:00 13:00-13:30 13:30-14:30 14:30-15:30 15:30-16:00 16:00-18:00 18:00-20:00 20:00-23:30 23:30-05:30 05:30-06:00 06:00-06:30 06:30-12:00 12:00-16:00 16:00-16:30 16:30-18:00 18:00-19:30 19:30-21:30 21:30-22:00 22:00-00:00 Duration 6hr 3hr lhr lhr 2hr 1-1/2 hr 3hr 3-1/2 hr lhr 8hr 3hr lhr 3hr 1/2 hr lhr lhr 1/2 hr 2hr 2hr 3-1/2 hr 6hr 1/2hr 1/2 hr 5-1/2 hr 4hr 1/2hr 1-1/2 hr 1-1/2 hr 2hr 1/2 hr 2hr Activity Rig moved 75.00 % Rig moved 100.00 % Rigged up High pressure lines Installed Hanger plug Circulated closed in well at 7356.0 ft Removed Xmas tree Rigged up BOP stack Tested BOP stack Removed Hanger plug Pulled Tubing in stands to 0.0 ft Rigged down sub-surface equipment - ESP Made up BHA no. 1 R.I.H. to 7375.0 ft Reverse circulated at 7375.0 ft R.I.H. to 7775.0 ft Reverse circulated at 7775.0 ft Pulled out of hole to 7522.0 ft Acid job - 12.000 bbl acid pumped at 575.0 psi, conc. = 12.00 %, press Mixed and pumped 24.000 bbl of treatment Pulled Tubing in stands to 0.0 ft Functioned ESP Ran Tubing in stands to 300.0 ft Held safety meeting Ran Tubing in stands to 7387.0 ft Installed Tubing hanger Installed Tubing hanger Rigged down BOP stack Installed Xmas tree Tested Xmas tree Freeze protect well - 65.000 bbl of Diesel Rigged down High pressure lines MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' Robert Christenson~/" DATE' Chairman January 17,1999 THRU' FILE NO: Blair Wondzell, P. I. Supervisor FROM' Lawrence M Wade .~., SUBJECT: Petroleum Inspectdr .DOC BOP Test Nabor s 4ES MPU K-13 PTD 96-040 January 17,1996: I traveled to Milne Pt to witness a BOP test on Nabors 4ES. They have ex-toolpushers on the brake and the testing came off very smoothly and efficiently. Except for a little trouble with the test pump~ everything went well. SUMMARY: BOP test on Nabors 4ES, 3 hours, 0 failures. Attachments: akpgaqge.xIs cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: X Nabors Rig No. 4ES PTD # BPX Rep.: K-13 Rig Rep.: 7" Set @ 7,861 Location: Sec. X Weekly Other DATE: 1/17/99 Rig Ph.# 659-4454 Larry Myers Gene Sweatt To Test Pressures R, Meridian 250/5000 MISC. INSPECTIONS: Location Gen.: Housekeeping: PTD On Location Standing Order Posted (Gen) Well Sign Drl. Rig Hazard Sec. BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. 1 Test Press. P/F 250/3000 P 250/5000 250/5000 P 250/5000 P 250/5000 P 250/5000 P 250/5000 P 250/5000 MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X X H2S Gas Detector X X FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Quan. 1 Test Pressure P/F 250/5000 P I 250/5000 P 1 250/5000 P 1 250/5000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 11 250/5000 P 35 250/5000 P 1 Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 4 @ 1650 3,000 1,700 minutes 34 sec. minutes 30 sec. x Remote: x Psig. Number of Failures: ,Test Time: 3.0 Hours. Numberof valves tested 17 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 REMARKS: Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade FI-021L (Rev.12/94) akpgaqge.xls PERMIT AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS Page: 1 Date: 11/25/98 RUN RECVD 96-040 ADN- MD L~'~ 3743-7875 / 96-040 CDR-MD ~ 3743-7875 96-040 CDR- TVD ~1, 35S0-7320 / 96-040 g.DN- TVD L 3SOD-7310 96-040 7S62 '(~ C~I',I.j-M CDR/_~XDlq' 96-040 GR/CCL ~L~616-7761 96-040 96-040 96-040 STAT PRESS/TEMP ~L~7504-7600 PACKER SET RCD ~7250-7559 PERF ~ 7180-7565 · 10-407 OMp ,ET o DATE Are dry ditch samples required? yes ~d received? the well cored? yes ~~alysis & description received? Was Are well tests required? yes n~Received? Well is in compliance ~ I~itial CO~ENTS FINAL 01/10/97 FINAL 01/10/97 FINAL 01/10/97 FINAL 01/10/97 i 01/10/97 FINAL 01/24/97 FINAL 01/24/97 FINAL 01/24/97 FINAL 01/24/97 ..... STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION CUMMISSION 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. 96-40 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22655 4. Location of well at surface ?~:7i?;;':::~ :~ "i' 9. Unit or Lease Name 3676' NSL, 2111'WEL, SEC. 3, T12N, R11E ~ ...... ,,..,. ; ~, Milne Point Unit At top of productive interval i "~-~-/'~'/~'~" i~l)~~ 10. WellNumber 4999' NSL, 153' WEL, SEC. 3, T12N, R11E / , / M PK-13 At total depth ~ '.'~:~-;~-;~i~ ., 11. Field and Pool 5103' NSL, 10'WEL, SEC. 3, T12N, R11E:_- _/~.~2¢.-_~ .~.i Milne Point Unit/Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and s-e~i'~i'RTd.- .... Sands KBE = 57'I ADL 375133 12. Date Spudded10/09/96 I13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °fish°re 16' N°' °f C°mpleti°nsl 0/15/96 12/10/96 N/A MSL One 17. Total 'Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set~l. Thickness of Permafrost 7875 7360 FT~ 7780 7274 F~ []Yes E3No I N/A MD/ 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, EMS, GR/RES/CDR/CDN, GR/CCL, GR/JB 23. CASING, LINER AND CEMENTING RECORD CASING t SE-FI-lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-I-I'OM 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' 3723' 12-1/4" 938 sx PF 'E', 700 sx Class 'G' 7" 26# L-80 28' 7861' 8-1/2" 235 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 12 spf 2-7/8", 6.5#, L-80 7364' N/A MD TVD MD TVD 7474'-7526' 6998'-7045' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ORIGINAL Freeze protect w/70 bbl diesel Gravel pac assy, 7403'-7531' 1 500# 20/40 Carbolite behind pipe 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) December 17, 1996 I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD · I Flow Tubing Casing Pressure CALCULATED . OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED FEB 7 1997 - _. Alaska 011 & Gas Cons. Commission ,bnnhnr~n~ Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Marks. 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. (Subsea) KC1 7465' 6937' Top Kuparuk 'B' 7523' 6990' Top Kuparuk B7 7543' 7008' ORIGINAL 31. List of Attachments Summary of Daily Drilling Reports, Surveys i32. I hereby certify that the foregoing is true and p~.rrect to the best of my knowledge Signed ~ ~'~~//~~~ /$/~ Tim Schofield ' Title Senior Drilling Engineer Date 2. 7. Prepared By Name/Number: Kathy Campoamor, 564-5122 INSTRUCTIONS GENERA,: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEI~I 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. ITEI~,I 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. ITEI~I 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 SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPK-1 3 Rig Name: N-22E AFE: 337051 Accept Date: 1 0/08/96 Spud Date: 1 0/09/96 Release Date: 1 0/1 7/96 Oct 7 1996 (1) RD drillfloor/derrick. Rig waited: Equipment. Held safety meeting. Rig moved 25 %. Oct 8 1996 (2) Held safety meeting. Rig moved 95 %. Held safety meeting. RU drillfloor/derrick. Held safety meeting. Oct 9 1996 (3) Held safety meeting. Held safety meeting. Held drill (H2S). RU drillfloor/derrick. RU divertor. Rig accepted 10/08/96 @ 1100 hrs. RU additional services. Held safety meeting. RU divertor. Racked back drill pipe. Tested divertor. MU BHA #1. Drilled to 160 ft. Pulled BHA. RD flowline. Oct 10 1996 (4) Held safety meeting. Held drill (fire). Repaired bell nipple. RU bell nipple. RIH to 160 ft. Drilled to 261 ft. Pulled BHA. MU BHA #1. RIH to 261 ft. Drilled to 506 ft. Held safety meeting. Drilled to 1720 ft. Oct 11 1996 (5) Held safety meeting. Held drill (kick while drilling). Circulated at 1720 ft. Drilled to 2196 ft. Circulated at 2196 ft. POOH to 112 ft. Serviced top drive. RIH to 2100 ft. Reamed to 2196 ft. Drilled to 2482 ft. Held safety meeting. Drilled to 3743 ft. Circulated at 3743 ft. Oct 12 1996 (6) Held safety meeting. Held drill (kick while drilling). Circulated at 3743 ft. POOH to 900 ft. Serviced top drive. RIH to 3650 ft. Reamed to 3743 ft. Circulated at 3743 ft. Took EMS survey at 3621 ft. Pulled BHA. Held safety meeting. RU casing handling equipment. Ran casing to 3692 ft (9.625 in OD). Washed to 3723 ft. Circulated at 3723 ft. Mixed and pumped slurry- 230 bbl. Displaced slurry - 267 bbl. Circulated at 1299 ft. Mixed and pumped slurry- 275 bbl. Page Oct 13 1996 (7) Displaced slurry - 88 bbl. Held safety meeting. Cleared flowline. RD divertor. Installed wellhead integral components. Tested casing spool. RU BOP stack. Tested BOP stack. Held safety meeting. Held drill (spill). Tested BOP stack. MU BHA #2. Singled in drill pipe to 1297 ft. Drilled installed equipment - DV collar. Singled in drill pipe to 3636 ft. Tested casing. Drilled installed equipment - Landing collar. Circulated at 3763 ft. Performed formation integrity test, 14.7 ppg EMW. Oct 14 1996 (8) Held safety meeting. Held drill (fire). Drilled to 4821 ft. Circulated at 4824 ft. POOH to 3723 ft. Serviced top drive. RIH to 4821 ft. Drilled to 5107 ft. Held safety meeting. Held drill (H2S). Drilled to 5975 ft. Circulated at 5975 ft. POOH to 4821 ft. RIH to 8975 ft. Drilled to 6061 ft. Oct 15 1996 (9) Held safety meeting. Held drill (kick while drilling). Drilled to 6978 ft. Held safety meeting. Held drill (kick while tripping). Drilled to 7204 ft. Circulated at 7204 ft. POOH to 5965 ft. RIH to 7204 ft. Drilled to 7490 ft. Oct 16 1996 (10) Held safety meeting. Held drill (spill). Drilled to 7875 ft. Circulated at 7875 ft. POOH to 250 ft. Pulled BHA. Held safety meeting. Held drill (abandonment). Conducted electric cable operations. Conducted electric cable operations. Conducted electric cable operations. MU BHA #3. RIH to 3723 ft. Serviced block line. Oct 17 1996 (11) Held safety meeting. Held drill (kick while tripping). RIH to 7875 ft. Circulated at 7875 ft. POOH to 250 ft. Pulled BHA. Serviced top ram. Held safety meeting. RU casing handling equipment. Ran casing to 7861 ft (7 in OD). Circulated at 7861 ft. Oct 18 1996 (12) Held safety meeting. Mixed and pumped slurry - 85 bbl. Tested casing. RD casing handling equipment. Serviced top ram. RD BOP stack. Installed wellhead integral components. Serviced fluid system. Freeze protect w/60 bbls diesel. Rig released 10/17/96 @ 1900 hrs. Page 2 SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPK-1 3 Rig Name: N-4ES AFE: 347051 Accept Date: 1 2/07/96 Spud Date: -- Release Date: 1 2/1 0/96 Dec 7 1996 MIRU. Move to MPK-13. Spot sub over well & level & berm same. Dec 8 1996 Rig accepted 12/07/96 @ 0600 hrs. Rig lines to tree. Test casing. ND tree & NU BOP's & install 3-1/2" rams. Pull hanger & install test plug. Test BOP's per policy & replaced kill line. Test witnessed by Bobby Foster w/AOGCC. MU BHA & RIH with same on 3-1/2" tubing. Displace diesel out of well bore. Cont RIH t/7775'. Mix & pump casing wash & follow with filtered brine. Rev circ. Dec 9 1996 Cont to displace well to 10.2 ppg brine. POOH. ND flow nipple & NU shooting flange. WO SWS. Rig SWS & test lub. RIH with GR/CCL & run from PBTD to surface pipe. Run 3 gun runs with SWS & perf 7474'-7526' with 4-1/2" gun @ 12 spf. Make 2 runs to 7600' with GR/JB. MU & RIH with CTLF tool. Tool failed. POOH & repair. Re-run SWS CTLF tool t/7620' & POOH. MU & RIH with HES "BWD" sump packer. Dec 10 1996 Cont to RIH with HES "BWD" packer & set @ 7531'. POOH & RD SWS. ND flange & NU flow nipple. MU gravel pac assy. TIH with gravel pac assy & engage into sump packer. Drop 2" ball & test lines. Set packer @ 7403' & test annulus, shear @ 2400 psi. Test tubing & shear off. Packer over PU weight & rev setting ball out. Rig Dowell & test lines. Perform data frac. Wait on frac design. Pump frac as design. Got 1500# 20/40 behind pipe & screened out & rev excess SD from tubing & re-stress pac. RD Dowell. POOH & laying down 3-1/2" tubing &frac pac tools. Cut drlg line. Change rams & test same. MU & service ESP assy. Dec 11 1996 MU & service ESP assy. RIH w/ESP assy. Circ through pump for friction psi. RIH w/ESP assy. MU splice at hanger. Land tubing. RILDS, LD landing jt. Set TWC. ND BOP's & NU tree & test. Freeze protect well with 70 bbl diesel & secure well. BPV set & lines blown down. Rig released 12/10/96 @ 2400 hrs. Page ! FEB 7 1997 . ,.., '-- ' - l .... PAGE 1 SD IY-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION (ALASKA) INC MILNE POINT/MPK-13 500292265500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN .00 .00 -56.95 0 134.45 134.45 77.50 0 224.52 224.52 167.57 0 315.57 315.56 258.61 0 406.67 406.66 349.71 0 0 13 22 34 38 COURSE DIRECTION DEGREES N .00 S 11.65 S 25.76 S 13 . 15 S 19.00 DATE OF SURVEY: 101196 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60146/7 KELLY BUSHING ELEV. = 56.95 FT. OPERATOR: BP EXPLORATION DLS TOTAL RECTANGULAR COORDINATE DG/100 NORTH/SOUTH EAST/WEST S VERT. SECT. E .00 .00N .00E W .16 .25S .05W E .27 .69S .04E E .24 1.41S .28E E .09 2.33S .55E .00 -.18 -.35 -.56 -.86 497.67 497.65 440.70 0 588.53 588.51 531.56 0 678.46 678.43 621.48 1 769.57 769.49 712.54 2 861.33 861.13 804.18 3 37 38 0 19 28 S 24.76 S 36.77 S 76.49 N 73.25 N 70.81 E .07 3.26S .92E E .15 4.12S 1.43E E .73 4.71S 2.51E E 1.70 4.36S 5.06E E 1.25 2.91S 9.47E -1.07 -1.13 -.57 1.73 6.19 952.46 951.96 895.01 5 1047.44 1046.43 989.48 5 1143.22 1141.65 1084.70 6 1238.82 1236.50 1179.55 7 1334.68 1331.20 1274.25 9 52 55 27 51 53 N 53.82 N 53.37 N 53.94 N 53 . 42 N 54.40 E 3.02 .75N 15.84E E .07 6.55N 23.70E E .56 12.67N 32.03E E 1.48 19.73N 41.62E E 2.12 28.43N 53.59E 13 .52 23 .28 33.61 45.52 60.30 1430.17 1425.19 1368.24 1525.57 1519.05 1462.10 1621.12 1613.10 1556.15 1716.47 1706.95 1650.00 1812.05 1800.91 1743.96 10 10 10 10 10 25 9 8 15 50 N 55.79 N 55.81 N 56.19 N 55.72 N 56.22 E .62 38.07N 67.40E E .28 47.66N 81.51E E .08 57.08N 95.47E E .15 66.53N 109.46E E .61 76.32N 123.97E 77.15 94.20 111.04 127.93 145.43 1906.53 1893.67 1836.72 11 2001.60 1986.91 1929.96 11 2097.56 2080.82 2023.87 12 2192.64 2173.17 2116.22 15 2288.31 2265.12 2208.17 16 4 25 19 6 54 N 56.39 N 56.47 N 56.60 N 56.98 N 56.57 E .24 86.28N 138.91E E .37 96.53N 154.35E E .95 107.42N 170.82E E 2.93 119.76N 189.70E E 1.88 134.23N 211.77E 163.38 181.92 201.66 224.21 250.60 2382.95 2355.15 2298.20 18 2478.55 2444.66 2387.71 22 2574.01 2532.73 2475.78 23 2669.60 2620.28 2563.33 24 2765.10 2707.06 2650.11 25 56 9 12 7 12 N 56.50 N 54.76 N 54.51 N 55.06 N 55.90 E 2.14 150.29N 236.07E E 3.41 169.26N 263.74E E 1.11 190.56N 293.76E E .99 212.68N 325.11E E 1.19 235.27N 357.96E 279.72 313.27 350.07 388.44 428.30 2859.26 2792.32 2735.37 25 2954.90 2879.04 2822.09 24 3049.16 2964.96 2908.01 23 3144.97 3052.41 2995.46 24 3240.67 3139.27 3082.32 25 0 51 43 29 7 N 56.10 N 55.79 N 53.53 N 54.13 N 54.50 E .24 257.61N 391.08E E .20 280.19N 424.48E E 1.56 302.60N 456.11E E .85 325.70N 487.71E E .69 349.12N 520.33E 468.25 508.57 547.33 586.44 626.59 RECEIVED FEB 7 Alaska Oil & Gas Cons. Commissior, Anchorag~ STf--"RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE POINT/MPK-13 500292265500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 101196 MAGNETIC MULTI-SHOT SURVEY JOB AKIMBER: AK-EI-60146/7 KELLY BUSHING ELEV. = 56.95 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3267.20 3163.28 3106.33 3335.20 3224.75 3167.80 3430.14 3310.44 3253.49 3525.46 3396.53 3339.58 3552.19 3420.70 3363.75 25 11 N 54.44 E .22 355.67N 529.51E 25 26 N 55.10 E .57 372.45N 553.26E 25 33 N 54.96 E .13 395.87N 586.75E 25 17 N 53.67 E .65 419.74N 619.99E 25 18 N 53.60 E .13 426.51N 629.19E 637.86 666.93 707.81 748.71 760.12 3621.19 3483.06 3426.11 3780.86 3627.76 3570.81 3876.16 3714.43 3657.48 3971.46 3801.31 3744.36 4066.60 3888.36 3831.41 25 21 N 53.79 E .14 444.00N 652.98E 24 38 N 54.05 E .46 483.74N 707.53E 24 29 N 55.04 E .46 506.73N 739.81E 24 1 N 56.22 E .71 528.84N 772.13E 23 34 N 56.29 E .49 550.17N 804.05E 789.63 857.09 896.70 935.86 974.26 4162.06 3975.94 3918.99 4257.36 4063.45 4006.50 4352.66 4151.09 4094.14 4447.96 4238.68 4181.73 4543.26 4326.07 4269.12 23 18 N 55.87 E .33 571.35N 835.56E 23 21 N 56.74 E .37 592.29N 866.97E 22 54 N 56.49 E .48 612.89N 898.23E 23 29 N 56.65 E .62 633.57N 929.56E 23 31 N 56.96 E .13 654.38N 961.37E 1012.23 1049.97 1087.40 1124.95 1162.95 4638.56 4413.46 4356.51 4733.86 4500.92 4443.97 4829.16 4588.47 4531.52 4924.46 4676.15 4619.20 5019.76 4763.76 4706.81 23 30 N 56.40 E .23 675.27N 993.14E 23 17 N 58.56 E .93 695.62N 1025.05E 23 14 N 58.71 E .09 715.21N 1057.t9E 22 54 N 57.90 E .48 734.83N 1088.97E 23 26 N 57.63 E .57 754.83N 1120.69E 1200.97 1238.80 1276.39 1313.70 1351.18 5115.06 4851.24 4794.29 5210.36 4938.58 4881.63 5305.66 5025.78 4968.83 5400.96 5112.85 5055.90 5496.26 5199.76 5142.81 23 17 N 56.99 E .30 775.25N 1152.51E 23 52 N 57.26 E .61 795.94N 1184.53E 23 42 N 57.24 E .17 816.74N 1216.87E 24 14 N 57.43 E .56 837.65N 1249.47E 24 12 N 57.38 E .05 858.71N 1282.42E 1388.97 1427.09 1465.52 1504.24 1543.33 5591.56 5286.76 5229.81 5688.86 5375.52 5318.57 5782.16 5460.47 5403.52 5877.46 5547.35 5490.40 5972.76 5634.44 5577.49 23 58 N 56.66 E .39 879.88N 1315.05E 24 22 N 57.07 E .44 901.66N 1348.42E 24 28 N 57.09 E .10 922.63N 1380.80E 24 4 N 57.19 E .42 943.88N 1413.71E 23 50 N 56.57 E .35 965.02N 1446.12E 1582.22 1622.06 1660.63 1699.79 1738.48 6068.06 5721.21 5664.25 6163.36 5807.51 5750.56 6258.66 5893.89 5836.94 6353.96 5980.51 5923.56 6449.26 6067.42 6010.47 25 0 N 56.38 E 1.23 986.79N 1478.97E 25 10 N 56.48 E .18 1009.14N 1512.64E 24 48 N 55.96 E .45 1031.52N 1546.11E 24 28 N 55.87 E .35 1053.79N 1579.01E 23 58 N 55.45 E .56 1075.84N 1611.29E 1777.88 1818.29 1858.55 1898.28 1937.38 RECEIVED FEB 7 Oil & ~m ¢on~. Oommiss~u,~ AllOhOr~g~ S! RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE POINT/MPK-13 500292265500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 101196 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60146/7 KELLY BUSHING ELEV. = 56.95 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6544.56 6154.46 6097.51 24 5 N 54.58 E .39 1098.10N 1643.09E 6639.86 6241.61 6184.66 23 37 N 53.77 E .60 1120.66N 1674.35E 6735.16 6328.68 6271.73 24 20 N 55.09 E .93 1143.19N 1705.86E 6830.46 6415.25 6358.30 25 5 N 55.50 E .81 1165.88N 1738.62E 6925.76 6501.55 6444.60 25 6 N 54.67 E .37 1189.02N 1771.77E 1976.18 2014.72 2053.45 2093.30 2133.72 7021.06 6587.90 6530.95 24 57 N 54.53 E .16 1212.38N 1804.64E 7116.36 6674.24 6617.29 25 7 N 53.91 E .32 1235.96N 1837.36E 7211.66 6760.49 6703.54 25 13 N 54.12 E .14 1259.78N 1870.16E 7306.96 6846.67 6789.72 25 18 N 54.14 E .09 1283.61N 1903.11E 7402.26 6932.87 6875.92 25 11 N 53.86 E .18 1307.50N 1936.00E 2174. 04 2214. 36 2254. 87 2295.52 2336.15 7497.56 7019.01 6962.06 25 28 N 54.20 E .34 1331.45N 1968.99E 7592.86 7105.01 7048.06 25 34 N 54.16 E .11 1355.48N 2002.29E 7688.60 7191.40 7134.45 25 29 N 54.20 E .09 1379.63N 2035.76E 7783.46 7276.98 7220.03 25 36 N 54.18 E .11 1403.57N 2068.94E 2376.90 2417.95 2459.20 2500.10 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2500.10 FEET AT NORTH 55 DEG. 50 MIN. EAST AT MD = 7783 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 55.79 DEG. TIE-IN SURVEY AT SURFACE 0.0' MD LAST SURVEY STATION AT 7,783.46' MD S: IRY-SUN DRILLING SERVICES ikNCHOR3kGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE POINT/MPK-13 500292265500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 101196 JOB NUMBER: AK-EI-60146/7 KELLY BUSHING ELEV. = 56.95 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -56.95 .00 N .00 E 1000.00 999.25 942.30 3.63 N 19.77 E 2000.00 1985.34 1928.40 96.36 N 154.09 E 3000.00 2919.97 2863.02 290.85 N 440.16 E 4000.00 3827.38 3770.43 535.30 N 781.79 E .00 .75 .75 14.66 13.90 80.03 65.38 172.62 92.59 5000.00 4745.63 4688.68 750.62 N 1114.05 E 6000.00 5659.35 5602.40 971.09 N 1455.31 E 7000.00 6568.80 6511.85 1207.22 N 1797.40 E 7783.46 7276.98 7220.03 1403.57 N 2068.94 E 254.37 81.75 340.65 86.27 431.20 90.55 506.48 75.28 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. RECEIVED FEB Alaska Oil & Gas Cons. Commission Anchorage St RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE POINT/MPK-13 500292265500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 101196 JOB NUMBER: AK-EI-60146/7 KELLY BUSHING ELEV. = 56.95 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 .00 .00 -56.95 56.95 56.95 .00 156.95 156.95 100.00 256.95 256.95 200.00 356.96 356.95 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .33 S .07 W .00 .00 .88 S .14 E .00 .00 1.81 S .38 E .01 .00 456.96 456.95 400.00 556.97 556.95 500.00 656.98 656.95 600.00 757.02 756.95 700.00 857.14 856.95 800.00 2.85 S .74 E .01 .01 3.83 S 1.22 E .02 .01 4.62 S 2.14 E .03 .01 4.51 S 4.57 E .07 .04 2.99 S 9.23 E .19 .12 957.48 956.95 900.00 1058.01 1056.95 1000.00 1158.62 1156.95 1100.00 1259.46 1256.95 1200.00 1360.82 1356.95 1300.00 1.06 N 16.26 7.20 N 24.58 13.69 N 33.43 21.42 N 43.89 31.05 N 57.24 E .53 .34 E 1.06 .53 E 1.67 .60 E 2.51 .85 E 3.87 1.36 1462.47 1456.95 1400.00 1564.07 1556.95 1500.00 1665.66 1656.95 1600.00 1767.30 1756.95 1700.00 1869.12 1856.95 1800.00 41.36 N 72.24 51.48 N 87.13 61.45 N 101.99 71.66 N 117.00 82.31 N 132.92 5.52 1.64 7.12 1.61 8.71 1.59 10.35 1.63 12.17 1.82 1971.03 1956.95 1900.00 2073.13 2056.95 2000.00 2175.86 2156.95 2100.00 2279.77 2256.95 2200.00 2384.86 2356.95 2300.00 93.19 N 149.31 104.54 N 166.47 117.42 N 186.10 132.86 N 209.70 150.64 N 236.60 14.08 1.91 16.18 2.10 18.91 2.73 22.82 3.91 27.91 5.09 2491.82 2456.95 2400.00 2600.36 2556.95 2500.00 2709.80 2656.95 2600.00 2820.23 2756.95 2700.00 2930.55 2856.95 2800.00 172.14 N 267.83 196.59 N 302.21 222.10 N 338.60 248.41 N 377.39 274.44 N 416.02 34.87 6.96 43.41 8.54 52.85 9.43 63.28 10.44 73.60 10.32 3040.42 2956.95 2900.00 3149.96 3056.95 3000.00 3260.20 3156.95 3100.00 3370.86 3256.95 3200.00 3481.68 3356.95 3300.00 300.51 N 453.28 326.91 N 489.38 353.94 N 527.08 381.21 N 565.82 408.66 N 604.92 83.47 9.87 93.01 9.55 103.25 10.24 113.91 10.65 124.73 10.83 IRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE POINT/MPK-13 500292265500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 101196 JOB NUMBER: AK-EI-60146/7 KELLY BUSHING ELEV. = 56.95 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3592.29 3456.95 3400.00 3702.95 3556.95 3500.00 3812.97 3656.95 3600.00 3922.87 3756.95 3700.00 4032.33 3856.95 3800.00 436.68 N 643.00 464.66 N 681.22 491.60 N 718.37 517.80 N 755.68 542.56 N 792.65 E 135.34 10.61 E 146.00 10.65 E 156.02 10.03 E 165.92 9.90 E 175.38 9.45 4141.38 3956.95 3900.00 4250.28 4056.95 4000.00 4359.02 4156.95 4100.00 4467.88 4256.95 4200.00 4576.94 4356.95 4300.00 566.76 N 828.79 590.75 N 864.62 614.26 N 900.29 637.94 N 936.20 661.71 N 972.64 E 184.43 9.05 E 193.33 8.90 E 202.07 8.74 E 210.93 8.86 E 219.99 9.06 4685.98 4456.95 4400.00 4794.86 4556.95 4500.00 4903.62 4656.95 4600.00 5012.34 4756.95 4700.00 5121.28 4856.95 4800.00 685.68 N 1008.92 708.18 N 1045.63 730.52 N 1082.10 753.25 N 1118.20 776.59 N 1154.57 E 229.03 9.05 E 237.91 8.88 E 246.67 8.76 E 255.39 8.72 E 264.33 8.94 5230.45 4956.95 4900.00 5339.71 5056.95 5000.00 5449.32 5156.95 5100.00 5558.94 5256.95 5200.00 5668.47 5356.95 5300.00 800.34 N 1191.37 824.15 N 1228.38 848.34 N 1266.21 872.59 N 1303.97 897.09 N 1341.36 E 273.50 9.17 E 282.76 9.26 E 292.37 9.62 E 301.99 9.61 E 311.52 9.53 5778.29 5456.95 5400.00 5887.97 5556.95 5500.00 5997.37 5656.95 5600.00 6107.51 5756.95 5700.00 6217.96 5856.95 5800.00 921.75 N 1379.46 946.20 N 1417.31 970.50 N 1454.42 996.02 N 1492.86 1021.96 N 1531.95 321.34 9.82 331.02 9.69 340.42 9.40 350.56 10.13 361.02 10.46 6328.07 5956.95 5900.00 6437.80 6056.95 6000.00 6547.29 6156.95 6100.00 6656.60 6256.95 6200.00 6766.19 6356.95 6300.00 1047.77 N 1570.13 1073.20 N 1607.46 1098.74 N 1643.99 1124.63 N 1679.76 1150.51 N 1716.35 E 371.12 10.11 E 380.85 9.73 E 390.34 9.49 E 399.65 9.31 E 409.24 9.59 6876.51 6456.95 6400.00 6986.93 6556.95 6500.00 7097.27 6656.95 6600.00 7207.75 6756.95 6700.00 7318.33 6856.95 6800.00 1176.95 N 1754.71 1204.02 N 1792.90 1231.19 N 1830.81 1258.80 N 1868.81 1286.46 N 1907.05 E E E E E 419.56 10.32 429.98 10.42 440.32 10.34 450.80 10.48 461.38 10.58 CEIVED FEB 7 Aim~ka Oil 6. {';as Cons Co[~lmissiol-~ S tRY-SUN DRILLING SERVICES ANCHOR3tGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE POINT/MPK-13 500292265500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 101196 JOB NUMBER: AK-EI-60146/7 KELLY BUSHING ELEV. = 56.95 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7428.87 6956.95 6900.00 1314.18 N 1945.14 E 471.92 10.54 7539.58 7056.95 7000.00 1342.02 N 1983.65 E 482.63 10.72 7650.44 7156.95 7100.00 1370.02 N 2022.43 E 493.49 10.85 7761.25 7256.95 7200.00 1397.95 N 2061.15 E 504.30 10.81 7783.46 7276.98 7220.03 1403.57 N 2068.94 E 506.48 2.18 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS RECEIVED FEB 7 199'/ Alaska Oil & ~a~ Oon~. C, Omrlfi~ttim', Anol]ora9~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10728 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 1/23/97 Well Job # Log Description Date BL RF Sepia LIS Tape MPC-25A JEWELRY LOG-GR/CCL 961 22 2 1 1 MPC-25A INJECTION PROFILE 961 22 2 I 1 : MPC-25A WATER FLOW LOG-TDTP-GR/CCL 961 22 3 1 1 MPE-16 PERFORATING RECORD 9 61 22 9 I 1 MPE-16 PACKER DEPTH DETERMINATION 9 61 23 0 I 1 MPE-16 DEPTH CONTROL LOG-GR/CCI. 9 61 22 2 I 1 MPE-16 CEMENT BOND LOG 9 61 22 2 I 1 MPU F-77 TUBING PUNCHING RECORD 9 61 21 0 1 1 MPU F-77 GRAVEL PACK LOG 9 61 21 7 1 1 MPU K-13 GPJCCL CORRELATION LOG 9 61 20 8 I 1 MPU K-13 PERFORATING RECORD 9 61 20 8 1 1 MPU K-13 STATIC PRESSURE/TEMP LOG 961 20 9 I 1 MPU K-13 PACKER SE'I-rING RECORD 961 209 I 1 MPU K-17 SUMP PACKER SE'I-rING RECORD 961 21 3 1 1 MPU K-17 PERFORATION RECORD 9 61 21 3 I 1 MPK-38 PERFORATION RECORD 9 61 201 I 1 MPK-38 PACKER SET RECORD 961 201 I 1 MPK-38 PERF RECORD 9 61 204 I 1 oho, ~b, 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 Received by~~~~ Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) Januaw 9, 1997 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the MWD Depth Corrected CDR/ADN, CDRJADN TVD'S for well MPK-13, Job # 96369 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 State of Alaska Alaska'Oil & Gas Conservation At-tn: Lori Taylor 3001 Porcupine Drive Ar~chora_.g..e, 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 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail: Z 777 937 516 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 ~-9.,9.5,~19~6 ~6-~2':~. Date Delivered: JA :I ! 0 1997 Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received b~ © · -MEMORANDbM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 7, 1996 Blair Wondzell, ~ P. I. Supervisor FROM: Bobby Fost SUBJECT: Petroleum Inspector FILE NO: AWPILGDD.doc BOPE Test - Nabors 4ES BPX-MPU-K-13 PTD # 96-0040 Saturday, December 7, 1996: I traveled this~late to BPX's MPU well K-13 being worked over by Nabors rig 4ES and witnessed the initial BOPE test. As the attached AOGCC BOPE test report shows there was 1 failure. The air driven pump on the accumulator system was not operational. This will be repaired ASAP and the AOGCC inspector will be notified. Summary: ! witnessed the initial BOPE test on Nabors rig 4ES working over BPX's MPU well K-13 - test time 2 hours - 1 failure. Attachment: AWPILGDD.XLS __X__ Unclassified Confidential (Unclassified if doc. removed ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: X DATE: 12./7~6 Nabors Rig No. 4ES PTD # 96-0040 Rig Ph.# 65g-4154 BPX Rep.: LARRY MYERS MPK- 13 Rig Rep.: GENE SWEA TT Set @ Location: Sec. l0 T. 13N R. IOE Meddian Umiat X Weekly Other Test MISC. INSPECTIONS: Quan. Pressure Location Gen.: P Well Sign P * 250/5,000 Housekeeping: P (Gen) Drl. Rig P * 250/5,000 Hazard Sec. P r 2 250/5,000 PTD On Location P - Standing Order Posted P" FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP 250/5,000 P/F BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. I 250/2500 1 250/5,000 250/5,000 1 250/5,000 I 250/5,000 1 250/5,000 2 250/5,000 N/A 250/5,000 P/F Test P Pressure P/F P 250/5,000 P N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P p CHOKE MANIFOLD: No. Valves 12 No. Flanges Manual Chokes 1 Hydraulic Chokes I 28 250/5,000 P Functioned Func§oned P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 3 Blind Switch Covers: Master: Nitgn. Btl's: Four Bottles 2000 A V~l. 2,950 I P 1,850 P minutes 32 sec. minutes 0 sec. P Remote: P Psig. Number of Failures: '/ ,Test Time: 2.0 'Hours. Number of valves tested '/7 Repair or Replacement of Failed Equipment will be made within ASAP 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 I [ I REMARKS: The air powered pump on the accumulator was not opera~fonal ~- this is to be repaired ASAP and the A OGCC inspector not/fled. ,~ Distribution: odg-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Wrtnessed By: BOBBY D. FOSTER FI-021L (Rev. 12/94) AWPILGDD.XLS TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3.001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 4, 1996 Tim Schofield Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPK-13 (formerly MPK-18) BP Exploration (Alaska), Inc. Permit No: 96-040 Sur. Loc. 36762qSL, 2Ill,VEL, Sec. 3, T12N, RllE, UM Btmhole Loc. 50663ISL, 63WqEL, Sec. 3, T12N, R11E, UM Dear Mr. Schofield: Enclosed is the approved amended application for permit to drill the above referenced well. The Commission notes the original permit, dated March 7, 1996, was for MPK-18 and we have no objections to the name change proposed by the operator. The Commission also notes the bottomhole has been moved and therefore, looks changed. As MPK-18 was granted a spacing exception in Conservation Order No. 375, there is no requirment to seek an additional spacing exception for MPK- 13. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. dlf/Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. BP EXPLORATION David W. Johnston, Chairman Anchorage, Alaska 99501-3192 . ~ Subject; Before Spud Changes to Approved Application for Permit to Drill #96-40 The below listed changes are requested with respect to Approved Application for Permit to Drill # 9 6 - 40. This.correspondence is submitted In order to be in compliance with AOSCC Regulation 20 APC 25.01.5, CHANGES TO DRILLING PERMIT, (a) For a proposed change in a drilling permit ........ before the start of actual drilling operations. e 2. 3, 4. $. The well number be changed from MP K-18 to MP K-13 The Location of well at surface be changed to 3§76' NSL, 2111' WEL, SEC3,T12N, R11E. The loc~tion At total depth be changed to 5066' NSL, 63' WEL, SEC ,3, T12N, Rl lE. The surface easing cement job will be a two stage cement job instea, d of a single stage cement job. Electric wireline logs MAY be run in open hole, MP K-18 was originally permitted in March 1996 however prudence has dictated that the well not be drilled until October 1996. It has since been determined that a more optimal wellbore trajectory will be obtained by drilling the well out of the MP K-13 surface slot location, Coming out of MP K-13 may also minimize potential close approach problems in the future, Therefore the request to change the Well number on Permit Number 96-40 from MP K-18 to MP K-13. Since March 1996 our ~ufface ~sing cementing program has been modified due to annular injection issues and the modifications are reflected in the attached permit. Since March 1996 our logging companies have changed ~nd therefore an E-line open hole Icg may be requested in order'.to calibrate it against LWD. E~entlaily it is being requested that the Well Number on Permit Number 96-40 be changed from MP K-~18 to MP K-13. A well will be drilled from surface slot MP K-18 in the future with a new Permit to Drill being submitted. I sincerely apologize for the confusion and inconvenience caused by this request, questions or if further information is requested contact J, E, Robertson at 564.5159, Re,~l~ectfu~ ~' / Drilllng Op's Engineer Shared Services Drilling If there are any RECEIVED OCT 0 2 199 Alaska 0il & (3as Cans. Cammisslon Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMIvlISSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork I~Drill I-IRedrill Ilb. Typeofwell I-IExploratory r-IStratigraphic Test I~Development Oil [] 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 = 57' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 375133 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3676' NSL, 2111' WEL, SEC. 3, T12N, R11E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 4995' NSL, 168' WEL, SEC. 3, T12N, R11E MPK-13 At total depth 9. Approximate spud date Amount $200,000.00 5066' NSL, 63' WEL, SEC. 3, T12N, R11E : 10/06/96 12. Distance to nearest prop,e, rty line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL375132, 63 No Close Approach 2560 7778' MD / 7277' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 600' Maximum Hole Angle 24.3° Maximum surface 3287 psig, At total depth (TVD) 7024' / 3652 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 153' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 3665' 31' 31' 3696' 3557' 786 sx PF'E', 697 sx'G', 150 sx PF'E' 8-1/2" 7" 26# L-80 Btm 7748' 30' 30' 7778' 7277' 210 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 Production RECEIVED Liner 0CT 0 1 1996 Perforation depth: measured Alaska 011 & Gas Cons. Commission . Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling 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. I hereby certify that the foregoing is trup and co/[ect to the best of my knowledge Signed ~:~-~;'"~ ~'""~' ' ,~' /J . ~..//~/ Tim Schofield /~,f3,? ~C-~~'{~'"~ Title Senior Drilling Eng,neer Date / Commission Use Only Permit Number I APl Numbe~" Approval Date I See cover letter I for other requirements I Conditions of Approval: Samples Required [] Yes I~ No Mud Log Required [] Yes I:~ No Hydrogen Sulfide Measures I-lYes I~ No Directional Survey Required I~Yes [] No Required Working Pre~urefor DOPE [] 2M; ©3M; ,1~ 5M; [] 10M; [] 15M Other: urlginal SJgr~e(] d~ by order of Approved By David W. Johnstor; Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate 4995 NSL 168 WEL Sec 03 T12N R11E UM., AK Target Location: Bottom Hole Location: 5066 NSL 63 WEL Sec 03 T12N R11E UM., AK IAFE Number: 1337051 I IEstimated Start 16 OCT 96 IDate: I Rig: I Nabors 22-E IOperating days to complete' IWell Design (conventional, slimhole, etc.)' KBE: 57' IMilne Point Ultra Slimhole Longstring 9- 5/8", 40# Surface X 7", 26# Longstring Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1,81 6 1,807 Top Schrader Bluff 4,799 4,562 Top of Schrader Bluff Sands (8.3 ppg) SeabeeShale 5,029 4,772 Base of Schrader Bluff Sands (8.3 ppg) HRZ 6,904 6,481 High Resistivity Zone Top Kuparuk 7,239 6,786 Kuparuk Cap Rock Target (Kuparuk 7,404 6,936 Kuparuk 'C' Sand (10.0 ppg) 'C1' Sand) Base of Kuparuk 7,563 7,081 Kuparuk B6 (10.0 ppg) Total Depth 7,778 7,277 215' below base of Kuparuk (8.6 ppg) cas~ng/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 32/32 112/1 53 12 1/4" 9-5/8" 40# L-80 btrc 3665 31/31 3696/3557 8- 1/2" 7" 2 6 # L-80 btrc 7748 30/30 7778/7277 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 +_7024 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3652 psi is 3287 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface MAY run E-line triple combo package dependent on cost MWD Directional surface to TD. Intermediate N/A Final Cased Hole Logs: MWD Directional and LWD (GR/CDR/CDN). N/A Mudloggers are NOT required for this well. U~IIISJ[.y Ma~ all[ ~ I~lu IU ~t~ IU ]lllll I,./~ ~ lUlM (PPG) Viscosity Point gel gel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel ~lel Loss 9.0 40 1 0 3 7 8.5 6 - 8 to to to to to to to 11.0 50 15 10 20 9.5 4-5 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: IKOP: 1600' Maximum Hole An~lle: Close Approach Well: Disposal: 124'3o (No Shut Ins) Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. 1. The base of the Permafrost for all wells located in the Milne Point Unit is _+1,850' TVD. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 2. There are _+5 wells on Milne Pt. 'K' 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. , , , , 10. 11. 12. 13. 14. 15. 16. Urill a 1:.'-1/4" surtace hole as per directional pla,~. Hu,~ L~iruc;do,~dl MVVIJ ~om,m uU,~uu ~u 12-1/4" TD. Run and cement 9-5/8" casing. ND 20" Diverter, NU and Test 13-5/8" BOP MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 20' of new formation. Perform LOT. Drill 8.5" hole to TD as per directional plan. NOTE: A potential E-line triple combo log MAY be run in order to compare with LWD Run and Cement 7" 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. Perforate and Stimulate in absence of rig. Displace well with appropriate weight brine and set a wireline retrievable bridge plug. MIRU a completion rig. NU & Test BOPE to 5000 psig. Complete well with 2-7/8" tubing. Install Surface Lines and Wellhouse and put the well on production. Minimize circulation times. The addition of lecithin to the mud system in surface is expected to minimize destabilization of the hydrates. Close Approach: There are no close approaches associated with the drilling of MP K-13. Shallow Set Casing: The wells at K Pad will typically use shallow set casing which can provide cost savings if the wells are trouble free. There are increased risk for stuck pipe, lost circulation, especially while running casing. The casing program will include running centralizers over both the Kuparuk and Schrader Bluff, and cemented in a single stage. The rig team will need to be more careful on these wells to fully realize the cost benefits. Lost Circulation: The Kuparuk sands and a number of shallower intervals typically are highly fractured. Be prepared to treat these losses while drilling initially with LCM treatments. This will become even more prevalent in the production hole when we shallow set surface casing. Weighting up before entering the reservoir will be the most likely time we would lose circulation Stuck Pipe Potential: There have been no cases of stuck pipe at 'K' pad to date IN SURFACE HOLE. However, well M P F- 53 was stuck coming out on the short trip at surface casing point. Subsequent fishing operations were not successful and a very expensive BHA was lost in the hole. If significant gravels are encountered stop and raise funnel viscosity to 150 cp viscosity immediately. In the 8-1/2" hole section here have been several cases of stuck pipe occuring at the top of the Kuparuk - with both the intervals above and below the Schrader Bluff open. The stuck pipe intervals and short trip guidelines on the Pad Data Sheet should be followed to avoid stuck pipe incidents. Running casing should be as smooth and quickly as possible to avoid stopping casing and possibly getting stuck. Formation Pressure: Schrader Bluff SAND Kuparuk SAND 45O5' TVD SS 7O24' TVD SS 1967 PSI 3652 PSI 8.4 PPG EMW 10.0 PPG EMW The maximum expected pore pressure for this well is 10.0 ppg EMW (3652 psi @ 7024' TVD SS). Reservoir pressure is not expected to exceed this estimate. WEIGHT: 12.0 ppg APPROX NO SACKS: 786 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. LEAD CEMENT: ANUULAR VOLUME FROM BASE OF PERMAFROST TO STAGE COLLAR AT 1300' MD + 200% EXCESS AND FROM STAGE COLLAR AT 1300' MD TO SURFACE + 200% EXCESS TAIL CEMENT TYPE: Premium G ADDITIVES: WEIGHT: APPROX #SACKS: 0.2% CFR-3,0.2% HALAD-344, 2.0% CaCI2 + CELLO-FLAKES 15.8 ppg YIELD:l.15 ft3/sx MIX WATER: 5.0 gal/sk 697 THICKENING TIME: Greater than 4 hrs at 50° F. FLUID LOSS: 100-150 cc FREE WATER: 0 TAIL CEMENT FROM TD TO BASE OF PERMAFROST + 30% EXCESS WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: 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. ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX NO SACKS: 150 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on 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. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover from TD to base of permafrost + 30% excess. 2. The Lead Slurry volume is anuular volume from top of tail cement to the stage collar at 1300' md + 200% excess, and annular volume from the stage collar at 1300' md to surface + 200% excess. 3. 80'md 9-5/8", 40# capacity for float joints. 4. Wellhead stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the wellhead. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 12.25ppg APPROX # SACKS: FLUID LOSS: 0.2% CFR-3, 30 lb/sack silicate, 1.25% Halad 344 YIELD: 2.81 cu ft/sk MIX WATER: 16.0 gal/sk 210 SACKS THICKENING TIME: 4 1/2 hrs @ 140° F < 45cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: , . 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint from TD to 300' above the top of the Kuparuk (32), Two per joint from 120' below the Schrader Bluff to 120' above the top of the Schrader Bluff (22). 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: . Stage 1 cement volume is calculated to cover from TD to 500' md above the top of the Schrader Bluff sands. I Harken Identification MD BKB'" SECTN INCLN ) ' ] A) KB 0 0 0 O. O0 BI KOP/BUILD t/~00 600 600. 0 0 O0 } C) ENO 1/t00 BUILD t666 1659:. 99 10.66 ) __~ { ............................ O} BUILD 2.5/100 2016 2004, 164 i0.66 C, E) END 2.5/t00 BUILD 2562 2523': 327 24,30 3aZ~l~Rl~ niisr' ~ F) g-5/8' CASING POINT 369G 3557 794 24.30 Gl TARGET 7469 6996 2347 24.30 ) ~ H) 7' CASING POINT 7778 7277" 2474 24,30 i I1 TO 7778 7277 2474 24.30 . } , - . .----. .. . I . i I I · 'T~'~/t])- '~ ~ .... -Tm,m ~ m,,,~ ............ ar~d~,P~- Hum.~,~ -l~{Y ~tpl~' ..... ~.-_-e,_. .'."-""-... ,._._.._.. _....,..__. _._._.~..., _. ., ,. . ,..._._.~11~,.~ el~.- 0 500 iO00 t500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 Section Departure Mnad~'ili [c)96 {4~Ki3P6 3.0~.0i I~ 36 AN P) ' ' ~ [,, , Anadr ~ 11 Sch lumDer~er · B~'-~') ............. Marker IUent~f~cation MD BKB SECTN INCLN I , ' . A) TARGET ' 7469 6996' 2347 24.30 B) 7' CASING POINT 7778 7~77 ~474 ~4.30 C) TD 7778 7277 2474 24.30 I ~ ~. ~ ..... ~ ....... 2000 ~n~n O4AA ~,~A ~A~ 2250 2300 g350 2400 g450 ~500 2550 ~fi00 2650 2700 Sect ion 0eparture ~'ri ll Schlumberger MPK- 13 (P6) PLAN VIEW CLOSURE.... · 2474 feet at Azimuth 55.79 DECL SCALE DRAWN SHARED SERVICES DRI Marker A) KB C) END D) BUILD E) END F) 9-5/8' 7' :NATION.: +28.062 (E) I :, ...... : I inch : 300 feet ~ i TARGET (RadiUs Identification MD N/S E/W .... /"?~_' 0 ON OE /BUILD 1/~ 600 0 N 0 E l/lO0 BUILD 1666 '~ N 82 E LO 2.5/t00 2016 9Z N 135 E 2.5/i00 BUILD 2562 184 N 270 E /8' CASING POINT 3696 446 N 657 E GET 7469 i3~ N 1941 E CASING POINT 7778 1391 N 2046 E .... 7778 I39! N 2046 E f ' j ~[4AD~ LL i I I I I 150 0 150 300 450 600 750 900 1050 i200 1350 i500 1650 1800 1950 2: <- WEST' EAST -> (Ana~a!! (c)96 I~RI3P6 3.0~.0! 8:44 m P) , ID: SEP ll '96 8:25 No.O0$ P.02 1'~l~ ...... r.__.~..~ !~'LE' £.~ ~ ' ....... ~:'~'~'~l', ~ ..... --~-'%~ I , I I I ~_. ~ ~ ' .~. .,,,~.~ . · · I ' '~ I ~'~ ~ ~ t~ ~ "'~" ' ' K-PAD " ~ N ~ ~';~ , : '-,' ~ ~ ~ '"1~-~ktL~~-, 1' '.L.~: I I ~INITY I I ~'~'~' 1 I I I I ~ ~ · x I ~0TES I : .'~ I1 Ii 4. I 1. DA'I~ OF ~U~FY: 5EPTEMDER 8. 1~96. I ~, m ri 6 I 2. ~EFERFNdF FIELD BOOK; MP96--O6 (43. 4~). I / [I [11 , I 3. A~ 51ATF PIANF COORDINATE5 j g ~ ~ ~o j ZONL 4, ALASKA, NAD 27, I K-13~ II 14 I ~. HORIZONTAl CONTROl. BA~¢[[) I ~, I'1 '~ 1[; I MONUMkN1 "FO~' AND MDU MONUM~N'I C. 1. m i/~ ~ 18 j 6. LLLVA'IIONS ARE RP MPH DATUM (M.~.L.). j i~ II [.J ~o J 7. VLIJ'II~L CON1ROl IR RASED ON BRAIDCN CAP A3 W~I I C-l, ELEVATION = 16.~6'. j j ~ l~ [J ~ I ~I'ABLISHED DY DOMI~OFF · A'.~C)CIA1FF;. I Z':' ~ ~ LJ ~ I ,' ,'," - '· I '~ ~ ~K-~o I ~.~ :~ , , 4," '.~. I ~ N~ ,"' "" '",¢ ~_ F~ ~, .... ,% ~..~, ~~ ~,,, EN-S LL I :~ ~ g ~o I p .. ......,..,,.u:, , ' , ,, I I :~'.,, ,.,"" I I I I I SURVEYOR'S CERTIFICATE J J I IIERC~Y CLRIIFY 'IHA1 I AM PROPLRLY RgGI~;1FRFI) AND LICENSED J J TO PNACII(:F I AN[) g[JR~YING IN J J 1HF S1AI'E OF ALASKA AND TI IA'I j . j THIS PLAT REPRESENTS A [;LJNv~ Y ................ MADE DY ME OR UNDER MY SUPER~SION AND TI IAT All DIMENSIONS AND OTIILR D~IAI[~; ANF LOCAIkD ~'IHIN PRO,ACTED ~C. 3, '1. 17 N., R, 11 E,, UMIAT.~F~IDIAN, AK. CORRECT AS or ~I.P'rtMHFR B, 19~6. ~LL ..... A.~.P. PLANT ~ODE'J'Ib GFOD[~C ~ CELLAR. SLdl'ION NO. COORQ~N~'~I.s CO0~INAT[S r, osmoN(~s) .osnmN(~,D~)j~.OX .CLEV. j offsets ~EGEND Y=6,005,a10.73 N. 9,909.82 70'25'32.~g'/" '/O,4258047' 27.5' 3,6?6' FSI. ~ AS-HUll [ WELL CONDUCI~R K-13 ~X= 584.445.49' L. ~0~0~.65 1~9'1~'42.6U4" 14~.~11B567' 2,111' FEL ....... , .... . , Y=6,005,741.~g ~N, g78g.'/O 70'25'52.19~" 7Q,425610B' 3,605' FSi B EXISTING Wl.l.I tONI)liCTOR Y= 6.005,713.85 N. 9,'/GO. Q1 70'2~'31,926" 7U. 425635D' 5,577' FSL (-34 X.. '5~4,e03,~2 E, ~ 109.9B 14g'1B'38,O77"j 14g.3105'/Bg' 27.8' ~1~9~' .............. . . ... .............. " , ............ p, ~t~org~. ~'~' ............... · .... ,~,. ~1/~ ........ ......... ~""""~PU[~O Mil NI' Iff)IN] tJNIT ................ ............... ~ ~- ~ ~ I oF 1 ........................ ~ w~1 ~, I~ STATE OF'ALASKA AI~SKA OIL ~ GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: TH~ APPLICATION OF BP ) ~XPLORATION (ALASKA) ) INC. for an order granting an ) exception to spacing requirements ) of Conservation Order 173 to ) provide for the drilling of the ) BP MPK-18 development oil well. ) Conservation Order No. 3 75 BP Exploration (Alaska), Inc. MPK-18 March 7, 1996 IT APPEARING THAT: BP Exploration (Alaska), Inc. submitted an application dated February 16, 1996 requesting exception to the well spacing provisions of Conservation Order 173 to allow drilling the BP MPK-38 development oil well to a producing location within 500 feet of a property boundary in Section 03 T12N R11E Umiat Meridian (UM). . Notice of opportunity for public hearing was published in the Anchorage Daily News on February 21, 1996 pursuant to 20 AAC 25.540. . No protests to the application were received. FINDINGS: . The BP MPK-18 well as proposed will be a deviated hole drilled from a surface location 3688' from the south line (FSL) and 1998' from the east line (FEL) of Section 3, T12N, R11E, UM to a proposed producing location 4995' FSL and 167' FEL of Section 3 T12N, R11E, UM. 2. Offset owners Oxy USA, Inc. and ARCO. Alaska, Inc. have been duly notified. o An exception to the well spacing provisions of Conservation Order 173 is required for the BP MPK- 18 development oil well. Conservation Order No. ~- ~ March 7, 1996 CONCLUSION: Granting a spacing exception to allow drilling of the BP MPK-18 well as proposed will not result in waste nor jeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED: BP Exploration (Alaska), Inc.'s application for exception to the well spacing provisions of Conservation Order 173 for the purpose of drilling the MPK- 18 well is approved. DONE at Anchorage, Alaska and dated March 7, 1996. David W. Johnston, Alaska Oil Gas Con Commission kerman Babcock, Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an oder, a person affected by it my file with the Commission an application for reheating. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day afl. er the application for rehearin~ was filed). ALASKA OIL ~ GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVEF~NOF~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 7, 1996 Tim Schofield, Senior Drilling Enghaeer BP Exploration (Alaska) ~c. P 0 Box 196612 Anchorage, AK 99519-6612 Well # Company Permit # Surf Loc Btmhole Loc lVfilne Point Unit/vfPK-18 BP Exploration (Alaska) Inc 9640 3688'NSL, 1998'WEL, Sec 03, T12N, K11E, UM 5144'NSL, 5238'WEL, Sec 02, T12N, KllE, LrM Dear Mr Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevent/on 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 ~ representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspec~r on the Noah Slope pager at 659-3607. Dasd W J~lmston \ - ~ Chairman ~ BY ORDER OF THE COM/VIISSION lib/end c: Dept of Fish & Game, Habitat Section - w/o end Dept of Environmental Conservation- w/o end OXY OXY USA INC. Box 50250, ~'ld'land, TX February 22, 1996 Via. Facsimile 90.7:276-7542 Mr. Bob Crandall Alaska Oil and Gas Conservation Commission Reference: ApplicaCion for Spacing Exception ~i'lne pQint K-18 We~! Dear Mr. Crandall: .. OXY USA Inc., an affected party, has no objection to the drilling of the Milne Point K-18 well as proposed by BP Exploration. Should you have any questions, please give me a call at 915-685- 5673. Respectfully, Edward J. Behm, Jr. Asset Team Leader Heavy Oil Team xc: Chris. West, BPX - Anchorage EJB/j ap Alaska Oil & Gas Cons. Commi,~ion Anchorage An Occidental Oil and (ias ~ompany BP EXPLORATION (ALAS..A) PRUDHOE BAY, ALASKA FAX # (907) 564-5193 P. 1/? TO-' Bob Crandail II COMPANY. AOGCC LOCATION: Anchorage .- FAX #: 276-7542 ! I FROM: Kathy Campoamor SHARED SERVICES DRILLING LOCATION: ANCHORAGE, ALASKA PHONE #: 564-5122 _ PAGES TO FOLLOW: I COMMENTS: Postal receipts for MPK-18 DATE: 2-20-96 --- IF YOU DO NOT RECEIVE ALL PAGES, OR HAVE ANY PROBLEMS, PLEASE CALL THE FOLLOWING NUMBER- (907) 564-5122 Receipt for Certified Mail No Insurance Coverage Provided Do not use for I~ternationa! Mail Z 14E 7~ 132 ,~ Receipt for fll?Y.-I~' Certified Mail No Insurance Coverage Provided Do not use for Inte?nation~l Mail P.%, Sla~, and ZIP / ~peo,el Oehv~y Fee '~oso{¢~d Del;very Retu~ Rnffmpl 8hq'~ln~. ~ '1 ~.., ..... .. P.2/2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill I-Illb. Type of well. Exploratoryf-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 61 feet Milne Point Unit / Kuparuk River 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 375132 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 3688' NSL, 1998' WEL, SEC. 3, T12N, R11E Milne Point Unit At top of productive interval 8. Well number Number 4995' NSL, 167' WEL, SEC. 3, T12N, R11E MPK-18 2S100302630-277 At total depth 9. Approximate spud date Amount 5144' NSL, 5238' WEL, SEC. 2, T12N, R11E 03/12/96 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD andTVD) property line ADL375133 42 feet MPK-10,61'@2150'TVD feet 2560 8171'MD/7281'TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 4500 feet Maximum hole angle2¢.o8 o Maximum surface 3005 psig At total depth (TVD) 7529'/3758 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.1# NT8OLHE Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 3469' 31' 31' 3561' 3561' 703 sx PF 'E', 250 sx 'G', 250 sx PF 'E' 8-1/2" 7" 26# L-80 Btrc & Mod B 7629' 30' 30' 7659' 7510' 245 SX Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface ~_~ ~,~.~ ~ ~ V Intermediate Production FEE~ 20 t996 Liner Perforation depth: measured true vertical A,¢~,,~, ;,.,-. ' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch'Fl':";"b¢iiing"" '"'-'~' program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed reportl-I 20 AAC 25.050 requirements[] 21.1 hereby certify that the foregoing/_ i~ t~uel)~ and correct to the best of my knowledge.z./~--/q Signed ¢ '~'"~ ' ~/~;r¢ '~' ¢--~/q-~'-~''[c;~,- Title Senior Drillin~l En~tineer Date · Use , ~ Commission Only Permit Number APl number Approval date See cover letter ~ .~..~-¢z'~' ]50-0~,,~---' ~"~" ~'"'¢'"-k~"'--~/ r~e~ ~7 for other requirements L;onditi6ns df approval Samples required [] Yes ~rNo Mud Icg requ d 'l-lYes [] No Hydrogen sulfide measures [] Yes ~ No Directional survey required ,~ Yes [] No Required working pressure for BOPE 1-12M; f-13M; ,,~5M; I-IIOM; 1-115M; Other: Original $19P,~u o~ by order of Approved by David W. Johnston Commissioner me commission Date~,~,,--- Form 10-401 Rev. 12-1-85 Submit in triplicate Target Location: 4993' FSL IO'/' blzL Sec 5 TI2N RI Ih UM., AK. Bottom Hole 5144' FSL 5238' FEL Sec 2 T12N R11E UM., AK. Location: Note: Target & BHL footages are based on assumed true and square sections and are not surveyed legal locations. I AFE Number: ]337020 I [Rig: I Nabors 27E I IEstimated Start Date: IMarch 12, 1996 1 IOperating days to drill and case: 113 I IMD: 18~7~' I ITVD: 1728~'BKB I IKBE: 16~'1 IWell Design (conventional, slimhole, I UltraSlimhole, 7" Longstring etc.): Formation Markers: Formation Tops MD TVD Formation Pressure/EMW Base permafrost 1811 1811 n/a NA (Top Schrader) 4592 4566 1905 psig / 8.0 ppg OA 1955 psig / 8.0 ppg Base Schrader Bluff 4827 4776 1995 psig / 8.0 ppg Top HRZ 7092 6485 n/a Base HRZ n/a Kupark D Shale 7506 6790 n/a Kuparuk C 7790 7000 3650 psig / 10 ppg TKB 3669 psig / 10 ppg Total Depth 8171 7281 n/a Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MD/TVD MD/TVD O.D. 30" 20" 91.1# NT80LHE weld 80 32' 112/112 12 1/4" 9 5/8" 40# L-80 btrc 3469' 3 1' 3561/3561 8 1/2" 7" 26# L-80 Btrc & 5129 30' 7659/7510 Mod B 2500 N/A (tbg) 2-7/8" 6.5# L-80 EUE 6771' 2 9' 6800/7021 8rd 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 7529' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3758 psi is 3005 psi, well below the internal yield pressure rating of the 7" casing. The Modified Buttress 7" 26# will be run on bottom. Logging Program: ]Open Hole Logs: Surface Schrader Bluff Final ]Mud Logs: MWD ONLY MWD / CDR LWD GR/Resistivity/SFC CSG to TD Neutron/Density over Kupamk intervals Mud logs and samples are not required AP1 # 50-029-22XXX February 16, 1996 [ present to keep mud temperatures to a minim6m. Surface Mud Properties: [ Spud Mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 80 15 8 10 9 8 to to to to to to to 10.5 100 35 -15 30 10 15 Production Mud Properties: I LSND Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 15 3 7 8.5 6-10 to to to to to to to 10.5 50 20 10 20 9.5 4 - 6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 14500' Maximum Hole Angle: Maximum Dog Leg: Inclination in target: Close Approach Well: 21.08 degrees < 4 degrees 21 Degrees MPK 10 Well Plan is 61 feet @ 2150 feet TVD Cascade IA is the only close approach well, and was drilled and abandoned. This well has cement plugs over the Kuparuk , and from 5100 to 4712, and a cement retainer at 2820. This will be treated as a plugged well This will allow MPK-18 wellpath to be drilled as per BP's close approach guidelines. The well path should be followed as close as possible to ensure we do not compromise the proximity tolerances. 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. Fluid Handling: All drilling and completion fluids can be annular injected after allowing the cement on the 7" casing cement job to cure 6 hours following CIP. AP1 # 50-029-22XXX February 16, 1996 I he receiving zone to which the fluids will migrate is idend,ieu u:~ t]~l~ ~'r[nc~ t.,,eeK gr~olugJlG~l formation at 2500 - 3300' TVD. The confining layer is the Sagavanirktok Shale defined by logs between 2500 'TVD. Additional data which demonstrates the confining layers, porosity, and permeability of the injection zone was submitted to the AOGCC on 7-24-95. 4. There are no wells on Milne Point K Pad. There may be additional unidentified wells within a quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 5. The drilling wastes to be disposed of during this operations can be defined as drilling mud, cement contaminated drilling mud, and drill cuttings; rig wash fluid (inclusive of rig boiler blow down, and mud and cement rinse water of associated rig equipment, completion fluids (seawater and brine), formation fluids, reserve pit fluids, and drill rig domestic waste water. (Note: if you plan to dispose of fluids OTHER than those outlined above you must list them on the request) The maximum volume to be disposed of in the annulus is 35,000 bbls. Fluid densities will range from 8.3 to 13.0 ppg. Any deviation from this program must be detailed separately. 6. The 9.625" surface casing shoe will set at 3561'md 3561 ('tvd) and cemented with 703 "E" and 250 "G" sacks cement. This depth is below the base of the permafrost (1750' TVD) and into the top of the Prince Creek formation which has a long established history of annular pumping at Milne Point. The break down pressure of the Prince Creek formation is 13 to13.5 ppg equivalent mud weight. 7. The burst rating (80%) for the 9.625" 40# 'surface casing is4600 psi. The collapse rating (80%) for the7" 26# 'intermediate/production casing is 4325 psi. 8. The Maximum Allowable Surface Pressure while annular pumping is the lesser of 2000 psi or the calculated pressure according to the following equation: MASP (psi) = (Max Breakdown ppg-8.3 ppg) X 0.052 X Surf Csg Shoe TVD MASP (psi) = 962 psi 9. The maximum pressure imposed at the surface casing shoe is calculated according to the following equation: Max Press @ Surf Csg Shoe (psi) = .052 x Max Breakdown ppg x Surf Csg Shoe TVD Max Prss at Surf Csg Shoe =2499 psi This pressure is less than the 80% burst and collapse casing pressures calculated i 1 0. Additional data supplied as needed. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREVVOL iPERMITTED PERMITTED DATES INJECTED (BBL) VOL (aBE) Milne Point M P K- 17 0 35,000 Requested Milne Point M P K- 25 0 35,000 Requested Milne Point M P K- 38 0 35,000 Requested Milne Point M PK- 18 0 35,000 Requested FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annunlus was injected into to avoid freezing. AP1 # 50-029-22XXX February 16, 1996 80 once you penetrate the permafrost. If we encounter a large gravel section in the top of the Schrader Bluff, and flowing coal problems Immediately increase viscosity to 150 sec/qt. 2. Mud Weight - It is necessary to weight up the spud mud to 10 ppg by the base of the Permafrost to protect against any shallow gas or hydrates from 2000 - 2500. Allow the mud weight to increase as required while drilling the 12-1/4" hole up to 10.5 ppg maximum. 3. Filtrate Control - Plan to decrease the APl Filtrate level to 8cc by casing point. 4. Misc. Issues - There tends to be large amounts of clay below the Permafrost. Use ConDet (drilling Detergent) as required. Utilize mud from a previous well or from Nabors 22E to reduce spud mud costs. 8-1/2" Production Hole: 1. Rheology - Run Xanvis and/or Biozan as required to provide effective LSRV for good hole cleaning. Target the YP in the 20 range with a LSR-YP in the 5-8 range. (Do Not allow flow rates to get below 550 gpm in order to ensure adequate hole cleaning.' pUmp Iow vis/high vis weighted sweeps in combination with short trips to remove/prevent cuttings bed development). 2. Mud Weight - Drill out surface casing with a 9.0 ppg watered back spud mud. Hold the weight as Iow as possible down to 400' MD above the Kuparuk Cap (Kuparuk D shale). Weight up to the recommended final mud weight, 10.5 ppg on this well, prior to drilling the cap. ; 3. Filtrate Control - Run APl filtrate in the 6 - 10 cc range from the surface casing shoe to the top of the HRZ (use PAC's and bentonite). At the HRZ top , drop the APl filtrate to the 4 - 6 cc range and reduce the HTHP filtrate to the 12 - 14 cc range (200° F) with PAC's and Baranex and hold to TD. 4. Other Issues - This well will have a short departure (990'), the mud engineer and rig supervisor should evaluate the necessity of 2 ppb Boreplate and 2 ppb Barotrol treatment at the HRZ top for additional wellbore stabilization and/or lubricity based on actual downhole conditions. Maximize solids control efforts via mechanical seperation and dilution so as not to let the MBTs exceed 20 ppb at the weight-up point for the Kuparuk Sands. Short Trip and Mud Treatment Recommendations: Short trip guidelines will be left to the discretion of the rig supervisor but as a rule thumb these recommendations are offered. Short trip to the last short trip interval or a minimum of 1500 feet whichever is the greater distance when drilling below the top of the HRZ. Wipe thru any tight spots and record the results of all trips on the IADC and morning report -- note depths of intervals wiped or reamed. Even if there are no problems on short trips, record no problems on trip. Surface to Seabee Formation(4700' tvd): Short trips are recommended in this hole interval through the kick-off section. Short Trip every 2000 feet. These clays have a tendency to ball up the bit and the BHA -- Condet in the Pits and 2 cups of SAPP on connections or SAPP pills have helped to combat bailing on past wells. (PHPA has been used without noticable improvement.) Seabee Formation to the HRZ: Historically, this section of the hole from the base of the Schrader Bluff sands to the HRZ has been pretty forgiving and has been drilled without a wiper trip with little or no problems. However, it is recommended to perform a wiper trip to the 9-5/8" shoe once the HRZ is topped -- short trip more frequently if hole conditions dictate or at Rig Supervisor's discretion. H RZ to TD It is important that short trips be made every 1000 feet or 24 hours in this hole section. To date the 15 wells drilled of MPF-pad have had no stuck pipe incidents and only one tight hole section. AP1 # 50-029-22XXX February 16, 1996 control flow rates to below 600 GPM when hydrates are present to keep mud temperatures to a minimum. The MPU PE group will be perforating, 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. Lost Circulation: The Kuparuk sands and a number of shallower intervals typically are highly fractured. Wells on F Pad have lost varying amounts of mud (from 70 to 1000 bbls) drilling through or near the top of the Kuparuk sands, especially while running casing and cementing. Be prepared to treat these losses while drilling initially with LCM treatments. There has not been any appreciable amount of lost circulation in surface hole on any of the F Pad wellls to date. This is due to setting surface pipe deeper to cover the Schrader Bluff interval which might break down at the mud weights required to TD the well. Stuck Pipe Potential: Well MPF-53 was stuck coming out on the short trip at surface casing point. Proir to this incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed. Subsequent fishing operations were not successful and a very expensive BHA was lost in the hole from 2516 - 3342. Kick Tolerance: The surface casing setting depth for this well allows a kick tolerance of 97.5 bbl influx (Gas) based on a 12.5 ppg LOT at the 9-5/8" casing shoe and a estimated reservoir pressure of 3594 psig (9.6 ppg equivalent MW). Trip Schedules are required for all trips. All trips will be performed with a trip tank or one pit isolated for use as a trip tank. Formation Pressure: The maximum expected pore pressure for this well is 9.6 ppg EMW (3594 psi @ 7200' ssTVD). There has been no injection in this region since then, therefore the reservoir pressure should not exceed this estimate. Several wells from F pad have exhibited "breathing" of mud, alternating loss and flow back of uncontaminated muds volume. No oil, gas, or other formation fluid influx have been confirmed even when large fluid influx have been measured. In spite of this we will continue to take the conservative approach to circulate the well until stable before tripping or before running casing. When this occurs, the drilling superintendent should always be quickly notified and kept appraised. WATER USAGE Have the water truck drivers track the water usage on a daily log. Send a copy of this log to Dennise Casey in the Anchorage Office on a monthly basis. AP1 # 50-029-22XXX February 16, 1996 3. MIRU Nabors 27E drilling rig. , NU and function test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by AOGCC supervisor. Build Spud Mud. . Drill 12-1/4" surface hole to 3561' md (3561' tvd). Use extreme care when drilling through the known hydrate interval down to _+ 3100 feet TVD. Run and cement 9-5/8" casing. 8. ND 20" Diverter, NU and Test 13-5/8" BOPE. Run Wear Bushing. . RIH w/PDC bit and Double Power Section PDM (motor). Test the 9-5/8" casing to 3000 psig and plot pressure vs volume for LOT baseline. Drill out float equipment and 10 feet of new formation, Perform a LOT to a maximum of 12.5 ppg as per Recommended Practices Manual. Record pressure vs. cumulatrive volume for LOT test for well file. Follow Pad Data Sheet short trip guidelines. 10. Drill 8-1/2" hole to end of the build past the Base of Schrader Bluff at 5347' MD (5196' TVD). POOH to run MRIL wireline logs. 11. Drill 8-1/2" hole to TD at 8171' MD (7281' TVD). (Note: This hole section will be logged with LWD Triple Combo (GR/Res/Neu/Dens). 12. Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing with 1 stage cement program. Test casing to 3500 psi and freeze protect wellbore to 2000' TVD with diesel. Closely monitor casing running loads for drag. Make sure there is a circulating head for the topdrive before starting to run casing. 13. ND BOPE and NU dry hole tree. Release rig to MPK-37i. Note: This well will be perforated, and cleaned out with a completion rig and prior to running the ESP completion. 14. MIRU workover completion unit. ND dry hole tree. NU BOPs and test. 15. PU and RIH with 3.5" DP and 6" bit, clean out to PBTD. TOOH. 16. PU and RIH with perforating string (procedure to be distributed later with perforation intervals). 17. PU and RIH with 2-7/8" EUE 8rd tubing with Electric Submersible Pump (ESP) completion. 18. 17. Set 2 way check. ND BOPE and NU tree and test. Pull two way check, freeze protect, set BPV, close valves. Test tree. RDMO with workover/completion rig. F F]B 20 1~S6 POST RIG WORK ~.i~.s',.:.a Oii& q~,~ Cons. Cemmi~3~ioF~ Gomplote tho handover form and turn it and the w~ll files over to production. Turn over th~ well files alon9 with the handovor form. , A SBT/GR/CCL is not required on this well and will only be run if there are problems on the production cement job. , An adequate volume to cover 2000' of diesel needs to be injected down the 7" X 9-5/8" annulus before moving the rig off the well. Please note type and volume of freeze protection pumped down the outer annulus on the morning report. , The rig will not complete this well. PEs will perforate and clean out this well with a pulling unit. AP1 # 50-029-22XXX February 16, 1996 LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: 703 THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad-344, 2.0% CaC12 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc YIELD:i.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0ppg YIELD: 2.17cuft/sk. MIXWATER: 11.63 gal/sk APPROX NO SACKS: 250 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on the bottom 10 joints above the FS. 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Do not overdisplace by more than 1/2 the shoe joint. Mix slurry on the fly -- batch mixing is not necessary. Make sure to fill the casing every joint to avoid having to shut down to fill the casing. Casing has been stuck while we were shut down filling only 5 joints. CEMENT VOLUME: 1. The Tail Slurry volume is a standard 250 sacks is calculated to cover the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. AP1 # 50-029-22XXX February 16, 1996 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.3% CFR-3, 30#/SK Silicalite, 1.7% Halad 344 WEIGHT: 12.25 ppg YIELD: 2.81 cu ft/sk APPROX # SACKS: 245 FLUID LOSS: < 45cc/30 min @ 140° F MIX WATER: 16 gal/sk THICKENING TIME: 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 17 joints of 7" Casing (34 total). This will cover 200' above the C Sand. 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 6900' - 6100' to cover the Schrader Bluffs Sands (20Total). 3. Run one 7" x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7" x 8-1/4" Straight Blade Rigid Centralizers needed is 55. OTHER' 'CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 500' md above the NA Top with 30% excess. AP1 # 50-029-22XXX February 16, 1996 BPF+100% I 0.1116 Depth I BBLS ! Cu. Ft. Sacks Top of Ceme~ Shoe Depth ~i~i Calculated G Tail Volume 51.2 288 250 2938 E Lead Volum~ 1500 167.3 940 433 1438 E Tail Volume I 1438 , 104.3 585 270 0 I I _ Total E 7 0 3! Total G ! 2 5 0, 9-5/8" Bows ! I 0, [ I I Production 1-Stage Cement Job Cement Yield Hole Size 8.51 Silicalite Slurry 2.81 Casing Size 7 BPF ! 0.0226 BPF + 30% i 0.0294 ! Top of Cemen! Stage 1 i i I BBLS I Cu. Ft. Sacks Calculated __ Formation Top!i~iiiii!~i~iiii ! 1 23 t 689 245 4092 Centralizers 1 85 Turbulators ! i ! Total G ST1 245 ! · Total ST Bladet 1 86 Page 2 1811 3500I 4776 51% 6790 7000 7281 0.00 @ 0 ND TIE IN 191 296 0.00 ~ 1811 MD Bose PemmoFrost 80O 0 800 10DO IE:~]O 1403 1600 1800 8000 8800 1800 VERTICAL SECTION PLANE: 54.45 CASING POINT DATA OD MD lnG Azi TVD N/S E/W c) 5/8 in 3561 0,00 0,00 3561 0 N 0 E 7 in 8171 42.48 54,45 7881 14~ N 8038 E ,I L9 5/8 ;n OD, e 3561 MD, 3561 TVD CRITIC/N_ POINT DATA 0.00 8 3650 MD KEP / START ElF BUILD 8 8.50/1CX) Pt MD Inc Azi. TVD N/S E/W 2.50 ~ 3750 MD TIE IN 0 0.00 54.45 0 0 N 0 E Bose 1811 0.00 54.45 1811 0 N 0 E 5.00 ~ 3850 MD Pe~xifros± ~ 7 50 8 3950 MD KEP / START 3650 0.00 54.45 3650 0 N 0 E · DF BUILD @ ~ 10.00 ~ 4050 MD Ft N ]2.50 8 4150 MD NA Sonds 4592 Er3.56 54.45 45E~ 111 N 155 E ~_ ~r~ ~ A~ Mn Bose Scl~ode~ 4~7 Ex9.43 54.45 4776 172 N 241 E ~ ........... END DF BUILD 5347 42.42 54.45 5196 349 N 488 E N 17.50 ~ 4350 HD TFRZ 7093 42.42 54.45 64E~ 1034 N 1446 E ~ o~r~ ~ AA~n ~,~ TKUD 75D6 42.42 54.45 6790 11% N 1673 E -N cu.L~J ~ ,~,~J .-.u K-L / TKLI~I 7791 42.42 54.45 70(]0 138;]7 N 1820 E 23.[:Fo ~ 4592 HD NA S~nds TD 8171 4~42 54.45 7EqB1 1457 N 2038 E ~ 29.43 @ 4EN~7 MD Bose Sct~cde~ '~ 3e.50~ e 4950 MD ~SED BI-L '~, 35.00 e 5050 MD . TVD 7281.00 '% 37.50 e 5150 MD MD 8~71.15 '~, 40.00 @ 525D HD VS L:505.12 N/S 14~).54 N @ 5347 MD END DF BUILD E/W 8038.16 E 600 - @ 7093 MD TFRZ 1778 NW~.42 e ~ MD TKUD 42 ~ 7791 MD K-L / TKUC1 2248 ,~7, 7, M 281 '; ~.~eO~ 81~ ~D DrD7 rVD I I I I I I ~ I 0 5OO 1C~O 1.500 80OO ~ 300O ,-,. II ;, Halliburton Energy Services - Drilling Systems PSL Proposal Report Survey Reference: WELLHEAD Reference World Coordinates: Lat. 70.25.33 N - Long. 149.18.39 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (fi): 6005824.00 N 584557.00 E North Aligned To: TRUE NORTH Vertical Section Reference: WELLHEAD Closure Reference: WELLHEAD TVD Reference: WELLltEAD Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2. I.B Vertical Section Plane: 54.45 deg. BPX - Shared Services Drilling Alaska State Plane: Zone4 Milnc Pt: MPK MPK- 18 Est MPK-18 Wpl Measured lncl Drift Subsea TVD Course TOTAL Depth Dir. Depth Length Rectangular Offsets (fi) (deg.) (deg.) (ft) (fi) (fi) (ft) (fi) TIE IN 0.00 0.00 0.00 o6 ! .00 0.00 0.00 0.00N 0.00 E Base Permafrost 1811.00 0.00 0.00 1750.00 1811.00 1811.00 0.00N 0.00E CASING POINT OD = 9 5/8 in, ID = 8.84 in, Weight = 40.00 lb/fi. 3561.00 0.00 0.00 3500.00 3561.00 1750.00 0.00N 0.00E KOP / START OF BUILD ~ 2.50 deg/100 fi 3650.00 0.00 0.00 3589.00 3650.00 89.00 0.00N 0.00E 3750.00 2.50 54.45 3688.97 3749.97 100.00 1.27N 1.77E 3850.00 5.00 54.45 3788.75 3849.75 100.00 5.07N 7.10E 3950.00 7.50 54.45 3888.14 3949.14 100.00 11.40N 15.95 E 4050.00 10.00 54.45 3986.97 4047.97 100.00 20.24N 28.33 E 4150.00 12.50 54.45 4085.04 4146.04 100.00 31.59N 44.20E 4250.00 15.00 54.45 4182.17 4243.17 100.00 45.40N 63.54E 4350.00 17.50 54.45 4278.17 4339.17 100.00 61.67N 86.30E 4450.00 20.00 54.45 4372.85 4433.85 100.00 80.36N 112.45 E 4550.00 22.50 54.45 4466.05 4527.05 100.00 101.43N 141.94E NA Sands 4592.33 23.56 54.45 4505.00 4566.00 42.33 III.06N 155.41E 4650.00 25.00 54.45 4557.57 4618.57 57.67 124.85N 174.70E 4750.00 27.50 54.45 4647.25 4708.25 100.00 150.56N 210.68E Base Schrader 4827.07 29.43 54.45 4715.00 4776.00 77.07 171.92N 240.57E 4850.00 30.00 54.45 4734.92 4795.92 22.93 178.53N 249.81E 4950.00 32.50 54.45 4820.40 4881.40 100.00 208.69N 292.02E GRID Coordinates Northing Easting (ft) Closure Vertical Dist. Dir. Section (fi) (deg.) (fi) 6005824.00 584557.00 0.00(~ 0.00 0.00 6005824.00 584557.00 0.00~ 0.00 0.00 6005824.00 584557.00 0.00~ 0.00 0.00 6005824.00 584557.00 6005825.29 584558.76 6005829.15 584564.04 6005835.58 584572.82 6005844.57 584585.10 6005856.09 584600.84 6005870.12 584620.01 6005886.65 584642.59 6005905.63 584668.52 6005927.03 584697.77 6005936.81 584711.13 6005950.81 584730.26 6005976.93 584765.94 6005998.62 584795.58 6006005.34 584804.75 6006035.97 584846.60 o.o0~ o.oo o.oo 2.18~ 54.45 2.18 8.72~ 54.45 8.72 19.61~ 54.45 19.61 34.82~ 54.45 34.82 54.33~ 54.45 54.33 78.09~ 54.45 78.09 106.07~ 54.45 106.07 138.21~ 54.45 138.21 174.46~ 54.45 174.46 191.01~ 54.45 191.01 214.73~ 54.45 214.73 258.95~ 54.45 258.95 295.68~ 54.45 295.68 307.05~ 54.45 307.05 358.92~ 54.45 358.92 Build Walk DLS Cum. Rate Rate Dogleg (dg/lOOfi) (dg/lOOfi) (dg/lOOfi) (deg) Expected Total Rectangular Coords (ft) Max Hor Min i Error Er (fi) ( 0.00 0.00 0.00 0.0 0.00N 0.00 E 0.00 0.00 0.00 0.00 0.0 0.00N 0.00 E 5.00 0.00 0.00 0.00 0.0 0.00N 0.00 E 0.00 0.00 0.00 0.00 0.0 0.00N 0.00 E 9.61 2.50 0.00 2.50 2.5 1.26N 1.78 E 9.86 2.50 0.00 2.50 5.0 5.03N 7.12 E 10.13 11.29N 16.03 E 20.0IN 28.49 E 31.17N 44.50 E 44.72N 64.03 E 60.62N 87.05 E 78.83N 113.54 E 99.31N 143.45 E 108.67N 157.12 E 122.04N 176.71E 146.89N 213.31E 167.49N 243.73 E 173.87N 253.14 E 202.86N 296.18 E 2.50 0.00 2.50 7.5 2.50 0.00 2.50 10.0 2.50 0.00 2.50 12.5 2.50 0.00 2.50 15.0 2.50 0.00 2.50 17.5 2.50 0.00 2.50 20.0 2.50 0.00 2.50 22.5 2.50 -0.00 2.50 23.6 2.50 0.00 2.50 25.0 2.50 0.00 2.50 27.5 2.50 -0.00 2.50 29.4 2.50 0.00 2.50 30.0 2.50 0.00 2.50 32.5 10.42 10.74 11.14 11.62 12.23 13.00 13.95 14.40 15.08 16.47 17.70 18.08 19.97 1. I. 1. 1 11 1 11 1' I 11 I1 11 Halliburton Energy Services - Drilling Systems PSL Proposal Report Measured lncl Drift Subsca TVD Course T O T A L ~'/~ GRID Coordinates Closure Vertical Build Walk DLS Cum. Expected Total Max Hot Min Depth Dir. Depth Length Rectangular Offsets Northing Easting Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error (fl) (deg.) (deg.) (ft) (fi) (ft) (fi) (ft) (R) (f~) (fi) (deg.) (ft) (dg/lOOft) (dg/lOOff) (dg/lOOR) (deg) (fl) (fl) (fl) 5050.00 35.00 54.45 4903.54 4964.54 100.00 240.99N 337.21E 6006068.78 584891.43 414.47~ 54.45 414.47 2.50 0.00 2.50 35.0 233.83N 342.33E 22.12 5150.00 37.50 54.45 4984.18 5005.18 100.00 275.36N 385.32E 6006103.70 584939.13 473.60(~ 54.45 473.60 2.50 0.00 2.50 37.5 266.71N 391.50E 24.54 5250.00 40.00 54.45 5062.16 5123.16 100.00 311.75N 436.24E 6006140.66 584989.63 536.19~ 54.45 536.19 2.50 0.00 2.50 ,40.0 301.43N 443.62E 27.22 END OF BUILD 5346.76 42.42 54.45 5134.95 5195.95 96.76 348.82N 488.10E 6006178.31 585041.06 599.93~ 54.45 599.93 2.50 0.00 THRZ ~092.90 42.42 54.45 6424.00 6485.00 1746.13 1033.65N 1446.40E 6006874.02 585991.36 1777.78~ 54.45 1777.78 0.00 0.00 TKUD 7506.05 42.42 54.45 6729.00 6790.00 413.15 1195.69N 1673.14E 6007038.65 586216.20 2056.47~ 54.45 2056.47 0.00 0.00 K-L / TKUC 1 7790.51 42.42 54.45 6939.00 7000.00 284.46 1307.26N 1829.26E 6007152.00 586371.00 2248.36~ 54.45 2248.36 0.00 0.00 CASING POINT OD = 7 in, ID = 6.28 in, Weight = 26.00 lb/ft. 8170.88 42.42 54.45 7219.80 7280.80 380.37 1456.44N 2038.01E 6007303.58 586577.99 2504.93~ 54.45 2500.93 0.00 0.00 TD - 8171.15 42.42 54.45 7220.00 7281.00 0.27 1456.54N 2038.16E 6007303.69 586578.14 2505.12~ 54.45 2505.12 0.00 0.00 2.50 42.4 336.71N 496.75 E 30.05 0.00 42.4 989.42N 1478.01 E 85.38 0.00 42.4 1143.86N 1710.18E 98.78 0.00 42.4 1250.19N 1870.04 E 108.02 0.00 42.4 1456.44N 2038.01 E 0.00 0.00 42.4 1392.47N 2083.94 E 120.4 150 CLDSEST POINTS Slot D~stonce D~r~ection ReF MD ReF TVD Sep.Foc-tor, I~K-37 Est 1~.~ 194.38 0.00 0.00 185.30 I~K-~5 Est 1~4.48 P19.45 O.CE) 0.00 1~4.~ I~--d(- 17 As-Stoked 100.3~ ~48.07 0.00 0.00 1 (Y~.40 CASCADE-iA c)9.4~ 174.3~ 5050.00 4%4.54 1,30 CASCADE-O1 991.51 140.41 5350,00 5198,34 16.40 ~1~K-38 Est 14g.?l 157.85 0.00 0.00 14g.70 NPK- 10 Est 60.17 33g. E)CI 0.00 0.00 60.;?El FEB E O 1996 TVD is measured from the WELLHEAD Interval Step Depth 50.00 ~.(MD) From 0.00 To 8171.15 ~(MD) All Directions using BP Highside Method in Dee. Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Close Approach Status Offset Flowing Zone Flowing Shut-in Enter Enter Exit Exit Well Safety Min. Safety Safety Shut-in Danger Danger Shut-in Clear Spread MD TVD Dist Dist Zone Zone Zone Zone MD MD MD MD MPK-37 Wpl 144.4 169.4 2000 2000 30.0 5.0 MPK-25 Wpl 83.6 108.6 2000 2000 30.0 5.0 MPK-17 Wp2 43.6 81.0 3650 3650 46.5 9.1 CASCADE-lA -40.3 7.3 5050 4965 60.2 12.6 CASCADE-01 869.2 917.6 5350 5198 61.7 13.4 MPK-38 Wpl 83.6 121.3 3700 3700 47.0 9.3 MPK-10 Wpl 17.9 43.6 2100 2100 31.0 5.2 5050 5100 Close Approach Status OK OK OK SHUT-IN OK OK OK N/S and E/W are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 ft.(MD) From 0.00 To 8171.15 ft.(MD) All Directions using BP Highside Method in Dee. Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Closest Points Slot Wellpath Distance Direction RefMD MPK-37 Est MPK-37 Wpl 185.32 194.38 0.00 193.80 193.74 2200.00 MPK-25 Est MPK-25 Wpl 124.48 219.45 0.00 129.04 218.63 2150.00 MPK-17 As-StakdVIPK-17 Wp2 109.39 248.07 0.00 109.95 248.00 3700.00 CASCADE-IA CASCADE-lA 99.42 174.36 5050.00 CASCADE-01 CASCADE-01 991.51 140.41 5350.00 1162.09 165.75 5800.00 MPK-38 Est MPK-38 Wpl 149.71 157.85 0.00 151.53 158.25 3750.00 MPK-10 Est MPK-10 Wpl 60.17 339.20 0.00 61.26 339.98 2150.00 Ref TVD 0.00 2200.00 0.00 2150.00 0.00 3700.00 4964.54 5198.34 5530.54 0.00 3749.97 0.00 2150.00 Sep Factor 185.3 16.2 124.5 ! 1.0 109.4 5.6 1.3 16.4 14.4 149.7 7.7 60.2 5.2 EXHIBIT 2 VERIFICATION OF APPLICATION FOR SPACING EXCEPTION MILNE POINT K-18 C. West, Drilling Operations Engineer BP Exploration (Alaska) Inc., does hereby verify the following' 1. I am acquainted with the application submitted for the drilling of the Milne Point K-18 Well. 2. I have reviewed the application submitted for the exception to 20 AAC 25.055, Conservation Order 173 Rule #3 and all facts therein are true. 3. I have reviewed the plat attached as Exhibit 1 and it correctly portrays pertinent and required data. DATED at Anchorage, Alaska this / ~ day of ,~/..¢ ,1996. STATE OF ALASKA Drilling Operations Engineer THIRD JUDICIAL DISTRICT /---~t..,~SUBSCRIBEDr~ AND, SWORN1996. TO before me this / day of NOTAI:~ PUBLIC IN AND FOR ALASKA My commission expires: BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 16, 1996 ARCO Alaska Inc. Attn: James R. Weingarner, Senior Landman P. O. Box 100360 Anchorage, AK 99510--360 RE' Request for Exception to the Provisions of 20 AAC 25.055 - and C. O. 173 Rule 3 for MPK-18 Well Genletmen: Pursuant to the requirements of 20AAC 25.055(b) BP Exploration (Alaska) Inc hereby gives notice of a request to the Alaska Oil and Gas Conservation Commission for an exception to the provisions of 20 AAC 25.055(a)(1). Specifically, the exception location applied for will be as followed: 1) 'Surface Location: 3688 FSL, 1998 FEL Section 03, Township 12 North, Range 11 East Unimat Meridian 2) Kuparuk Entry · 4995 FSL, 167 FEL Section 3, Township 12 North, Range 11 East Unimat Meridian 2) Bottomhole Location: 5144 FSL, 5238 FEL Section 2, Township 12 North, Range 11 East Unimat Meridian A copy of the request is attached. Very t ru~..yo u rs, enc. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: From: Date: Subject: Bob Crandall, AOGCC Chris West, BPX (Shared Services Drilling) February 16, 1996 Application for Spacing Exception for the Milne Point Well K-18 (20 AAC 25.050 and 20 AAC 25.055) and Conservation Order 173 Rule #3. The MPK-18 well is planned to drill into the Kuparuk River formation is the northeast quarter of section 3 T12N R11E. This section is located within ADL lease 375133 The MPK-18 well is planned as a high angle producer to be completed with an electric submersible pump. The ownership of both these leases is identical. The location of key points for this wellpath are: 1) Surface Location: 3688 FSL, 1998 FEL Section 03, Township 12 North, Range 11 East Unimat Meridian 2) Kuparuk Entry · 4995 FSL, 167 FEL Section 3, Township 12 North, Range 11 East Unimat Meridian 2) Bottomhole Location: 5144 FSL, 5238 FEL Section 2, Township 12 North, Range 11 East Unimat Meridian This proposed location is within the NF_/4 of section 3 T12N, R11E and in close proximity to the eastern boundary of that 1/4 section. The Spacing requirements of 20 AAC 25.055 and Conservation Order 173 Rule #3 do not allow without exception the drilling of a well closer than 500 feet to a property line. This spacing exception is being sought to allow optimum placement of well MPK-18 within a fault block for the Kuparuk River Formation within the NE/4 of section 3. Based upon this information, we verify these facts to be true and that the plat portrays the pertinent and required data. We also feel this addresses the requirements both ACC 25.050 and ACC 25.O55. Thank you for your assistance in this matter. Please direct any questions to Tom Niswander at 564-5472. Respectfully, Chris West CC: ARCO Alaska Inc BPX OXY Ev 9 o ,' ~ , 75(') K-F K~9 AI:) K-1 O~ K~Ni K-10 K-5 B.H. t<-B +1 ..... .~,, / K-'t7 B,H, . ~ 24~ F K~E K~Ji K-25 B.H. K-37 B.H. 4- !,,. K~Oi K-6 B.H. F K-'14 B,H, K-Gi + K-26 K-34 B.H. + K-I K-41 B.H. A,o L.. ~ K-22 B,H, K-Qi K~30 B.H, K-C K-42 B,H. + K-B K-17 B,H, '-'F K-18 B.H. 168 89°15'16" 249 89°15'16" K-A K-38 B,H, K-25 B.H. +. + K-37 B.H, + K-I ~ K-4' '~' N COR SEC 4 & 3 X=581255.73 Y=6007379.07 T12N R11E "SEC 4, 3, 9, 10" X=581324.45 Y=6002099.77 T12N R11E MILNE POINT "F" PAD Well MPK-18 (K-L) Grid Distances & Azimuths ASP Zone 4, NAD 27 Mean SF=0.99990812 February 12, '1996 Shown Well K-18 Proposed Surface Loc. X=584557.95 Y=6005824.81 N COR SEC 3 &2 X=586534.93 Y=6007438.44 = ~ T12N R11E / K-18 K-L / TKUC1 X=586371.00 Y=6007152,00 "SEC 3, 2, 10, 11" X=586603.64 Y=6002159.14 T12N R11E K-18 K-L / TKUC1 X=586371.00 Y=6007152.00 168 N COR SEC 3 & 2 X=586534.93 Y=6007438.44 T12N R11E K-18 Downhole TD X=586578.14 Y=6007303.69 MPU K-PAD WELL K-18 (K-L) & Well K-38 (K-A) SECTION LINE TIES (2/12/96) NAME COMMENTS ALASKA STATE PLANE ZONE 4 (NAD 27) S & E SEC LINE OFFSETS SECTION, TOWN., Y X FSL FEL RANGE, UMIAT, AK Well K-18 Well Surface (K-L) 6,005,824.81' 584,557.95' 3,688' 1,998' SEC 03 T12N R11E Well K-18 K-L/TKUC1 6,007,152.00' 586,371.00' 4,995' 168' SEC03 T12N R11E Well K-18 K-L TD 6,007,303.69' 586,578.14' 5,144' 5,238' SEC02 T12N R11E Well K-38 Well Surface (K-A) 6,005,686.12' 584,615.06' 3,549' 1,943' SEC 03 T12N R11E Well K-38 K-A/TKUC1 6,004,798.00' 586,320.00' 2,642' 249' SEC 03 T12N R11E Well K-38 K-ATD 6,004,705.07' 586,498.49' 2,547' 72' SEC 03 T12N R11E Notes: Coordinates shown are North American Datum 1927 (NAD 27). File Name: K-A & K-L Sec Ties 2/12/96 · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~ ~ ~- l 013 INIT CLASS ~,DMINISTRATION ........... WELL NAME //~ J~ K "' / ~ ,.~R DATE . ~ENGiNEERiNG .~) ~ ,~ / - 0; [ GEOL AREA ~, c~ 13 1. Permit fee attached ....................... ~ N Lease number appropriate ................... (~ N PROGRAM: exp [] dev~ redrll [] serv [] wellbore seg [] ann. disposal UNIT# ! I 3~ ON/OFF SHORE ~ ~'- REMARKS . 3. Unique well name and number ................. (~ N 4. Well located in a defined pool ................. 5. Well located proper distance from ddg unit boundary ..... ._Y(~ 6. Well located proper distance from other wells ......... 7. Sufflcient acreage available in drimng unit. .......... (~N ,~tL__.£~ ,J9 CC ~/?~ ~'~'?-- 8. If deviated, is wellbore plat included .............. N .... 9. Operator only affected party ................... Y Operator has appropriate bond in fome ............ (~:)_N , lO. 11. Permit can be issued without conservation order ....... Y ~ "" ' , ~(~J~ 12. Permit can be issued without administrative approvai ..... 13. Can permit be approved before 15-day wait. ......... 14. Conductor string provided ................... (~ N 15. Surface casing protects ail known USDWs ......... .~ N 16. CMT vol adequate to circulate on conductor & surf csg . . . ~ N 17. CMT vol adequate to fie-in long string to surf csg ...... .~ N 18. CMT will cover ail known productive horizons ......... .Y~/N 19. Casing designs adequate for C, T, B & permaJrost. ..... ~Y.~N 20. Adequate tankage or reserve pit. ............... L.Y./N 21. If a re-drill, has a 10-403 for abndnmnt been approved .... ~ 22. Adequate wellbore separation proposed ............ ~ N /~- 23. If diverter required, is it adequate ................ ~ N ~ 24. Ddlling fluid program schematic & equip list adequate .... ~ N 25. BOPEs adequate .............. ~ '~0 ..... ~Y) N 26. BOPE press rating adequate; test to [0 {~ psig. _~ N 27. Choke manifold complies w/APl RP-53 (May 84) ....... ~ N .[~ 28. Work will occur wi~out operation shutdown .......... ~ N 29. Is presence of H2S gas probable ............... Y~/N 'GEoLOGy A~R DATE 30. Permit can be issued w/o hydrogen sulfide measu~ 31. Data presented on potential overp~_.~.~.. ..... Y N 32. Seismic anaJysis of s~nes ............ Y N 33. ~hore) ............ Y N 34. name/phone for weekly progres.~, repo~.. ...... Y N le, xp~aratory on~yj GEOLOGY: RPC ENGINEERING: COMMISSION: JDH ,.~ JDN~ TAB ~'~ Comments/instructions: HOW/lib - A.N:ORMS"chekI~ rev 4/96 WELL PERMIT CHECKLIST PROGRAM:,. exp [] dev~ redrll [] serv [] ~ ADMINISTRATION 5. 6. 7. 8. 9. 10. 11. 13. Permit fee attached .............. Lease number approprilt2.., i .... i ~ ..... Unique well name and n~ber ............... Well located in a defined pool ............. Well located proper distance from drlg unit boundary Well located proper distance from other ells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party ............... Operator has appropriate bond in force ......... Permit can be issued without conservation order ..... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ........ ENGINEERING 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ .~ N 16. CMT vol adequate to circulate on conductor & surf csg. N 17. CMT vol adequate to tie-in long string to surf csg . . N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved..~----4~--- 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~_~ N 26. BOPE press rating adequate; test to psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... Y ~/%3/~-- 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... Y//N 33. Seabed condition survey (if off-shore) ......... 34. Contact name/phone for weekly progress reports .... /6 Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOWlljb - A:~FORMS~cheklist rev 11/95 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. * ALASKA COMPUTING CENTER . ****************************** * ............................ ....... SCHLUMBERGER * ............................ ****************************** COMPANY NAME : B.P. EXPLORATION WELL NAME : MPK-13 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22655-00 REFERENCE NO : 96369 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-JAN-1997 14:18 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/01/ 7 ORIGIN ' FLIC REEL NAME : 96369 CONTINUATION # : PREVIOUS REEL : COGENT : B.P. EXPLORATION, MILNE POINT MPK-13, API #50-029-22655-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE . 97/01/ 7 ORIGIN · FLIC TAPE NAME : 96369 CONTINUATION # : 1 PREVIOUS TAPE : COGENT · B.P. EXPLORATION, MILNE POINT MPK-13, API #50-029-22655-00 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 BIT RUN 1 ......... 96369 R UMINER ANGLEN i ST STRING 2ND STRING MPK-13 500292265500 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES 7-JAN-97 BIT RUN 2 BIT RUN 3 .................. 3 12N lie 3676 2111 56.95 56.95 27.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.875 3723.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-JAN-1997 14:18 3RD STRING PRODUCTION STRING REMARKS: Well drilled 12-OCT through 15-0CT-96 with CDR/ADN. Ail data was collected in a single bit run. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION ' O01CO1 DATE ' 97/01/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMPLa~Y LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 3631,5 7881.0 BASELINE DEPTH 88888.0 7778.5 7767.5 7759.0 7750.0 7739.0 7728.0 7723.5 7682.5 7675.0 7625.0 7620.5 7613.0 7609.0 7603.5 7601.5 7586.5 7580.5 7575.0 .......... EQUIVALENT UNSHIFTED DEPTH 88894.0 7784.5 7774.5 7766 0 7755 0 7744 0 7733 0 7728 0 7686 5 7679 0 7629 5 7626 0 7616 0 7613.5 7608.0 7606.0 7590.5 7584.0 7578.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7562.0 7551.0 7542.5 7531.5 7524.5 7517.0 7514.0 7502.5 7490.0 7483.0 7476.0 7470.0 7467.0 7451.0 7445.0 7422.0 7413.5 7405.5 7397.0 7389.0 7355.5 7347.0 7340.0 7326.5 7324.5 7309.5 7305.0 7281.0 7262.0 7257.5 7241.0 7234.0 7226.0 7216.0 7195.5 7191.0 7175.5 7164.0 7152.5 7141.0 7135.0 7104.5 7096.0 7086.5 7084.0 7077.5 7070.5 7046.0 7044.0 7040.5 7037.5 7017.0 7008.0 7006.5 6993.0 7565 0 7554 5 7545 0 7534 0 7528 0 7519 5 7516.5 7506.0 7493.5 7487.5 7480.0 7475.0 7470.5 7454.0 7448.5 7424.0 7416.5 7408.0 7399.5 7392.0 7357.5 7349.0 7341 0 7329 0 7326 0 7312 0 7306 5 7282 0 7264 0 7259 5 7242.5 7235.0 7226.5 7218.5 7199.0 7192.5 7177.0 7167.0 7155.0 7143.5 7136.0 7107.0 7098.5 7087 0 7085 5 708O 0 7073 5 7047 0 7044 0 7042 0 7039.0 7018.5 7009.5 7007.5 6994.5 7-JAN-1997 14:18 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 6989.0 6969.0 6933.0 6929.0 6922.0 6909.0 6905.5 6879.5 6858.5 6852.0 6850.0 6841.0 6831.5 6826.0 6800.5 6797.0 6792.0 6763.5 6748.0 6735.0 6728.5 6721.0 6707.5 6699.5 6666.5 6655.0 6653.0 6646.5 6641.5 6615.5 6587.5 6583 5 6573 0 65 65 0 6559 0 6544 5 6527 5 6510 5 6484 0 6448 5 6430 5 6411, 0 6389.0 6343.0 6301.0 6260.0 6238.0 6180.0 6143.0 6140.0 6100.0 6083.5 6068.0 6034.0 6015.5 6990.0 6970.0 6935.5 6931.5 6924.5 6909.0 6906.5 6880.0 6859.5 6853.0 6850.0 6843.0 6832.0 6827.0 6803.0 6799.5 6793.5 6765.5 6749.0 673 6.0 6730.0 6722.5 6709.0 6700.5 6667.0 6656.5 6653.5 6648.0 6643.5 6616.5 6588.0 6585.0 6575.5 6566.5 6559.5 6545.5 6530.0 6512.5 6486.0 6448.5 6429.5 6411.0 6389.5 6345.5 6303.5 62 62.5 6240.5 6182.0 6145.0 6142.5 6102.0 6085.0 6070.0 6039.0 6019.0 7-JAN-1997 14:18 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 5992.0 5986.5 5974.5 5960 0 5951 0 5911 5 5864 5 5855 5 5831 0 5822 0 5816.5 5783.0 5740.0 5703.0 5679.0 5661.5 5646.0 5631.0 5611.5 5542.0 5520.0 5513.0 5490 0 5437 0 5427 5 5388 5 5354 0 5344 5 5326 0 5317 0 5292.0 5287.0 5275.5 5251.5 5229.0 5200.0 5185.0 5179.5 5151.0 5135.0 5115.5 5104.0 5097.5 5087.0 5068.5 5047.0 5041.0 5035.0 5024.5 5O07.0 4997.0 4975.5 4965.0 4943.0 4933.5 5999.0 5990.5 5977 5 5961 0 5955 0 5915 0 5868 5 5861 0 5835 0 5827 0 5819.5 5783.0 5739.0 5702.0 5680.5 5663.0 5647.0 5631.5 5611.5 5542.0 5520.5 5512.5 5489 5 5437 0 5427 5 5388 5 5355 5 5344 0 5326.5 5318.0 5290.0 5285.0 5274.5 5249.5 5227.0 5199.5 5184.5 5179.0 5154.5 5139 5 5118 5 5106 0 5100 0 5088 5 5069 0 5049.0 5044.5 5038.5 5026.0 5008.0 4997.5 4977.5 4965.5 4945.0 4935.0 7-JAN-1997 14:18 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 4909.5 4896.5 4887.5 4879 5 4861 5 4855 0 4847 5 4845 5 4837 5 4831 5 4822 0 4819 5 4817 5 4802.0 4798.5 4791.5 4784.5 4776.5 4773.0 4767.5 4764.5 4763.0 4757.0 4746.5 4741.5 4725.5 4715.0 4706.5 4695.0 4693.0 4680.0 4670.5 4647.0 4637.0 4634.5 4611.0 4605.5 4594.0 4558.0 4551.0 4537 5 4533 0 4530 0 4519 0 4506 0 4488 5 4468 5 4453 5 4447 5 4425 5 4399 5 4389.0 4379.0 4373.0 4365.5 4910.5 4899.5 4889.0 4881.5 4862.5 4856.0 4846.0 4844.5 4838.5 4833.0 4825.0 4821.0 4817.5 4805.0 4800.5 4793.0 4785.5 4778.0 4775.5 4768.5 4766.0 4763.5 4758.0 4746.5 4743.0 4727.0 4717.0 4708.0 4698.5 4696.5 4683.0 4673.5 4649.0 4637.0 4636.0 4615.5 4609.5 4599.0 4559.5 4552.5 4539 0 4535 0 4531 5 4523 0 4508 5 4492 5 4471 0 4457 5 4453.5 4429.5 4404.0 4393.5 4383.5 4373.5 4367.5 7-JAN-1997 14:18 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 4363.0 4348 5 4327 0 4312 5 4304 0 4298 5 4293 5 4285 5 4278 0 4276 0 4267.0 4246.0 4233.5 4228.0 4219.0 4203.0 4195.5 4171.5 4163.5 4160.0 4155.0 4145.0 4140.0 4134.0 4130.0 4127.0 4117.5 4108.0 4096.0 4093.0 4088.0 4081.5 4072.5 4069.5 4065.0 4056.0 4050.0 4043.5 4033.5 4031.0 4025.5 4010.0 4008.0 4001.5 3996.5 3993.5 3965 0 3945 5 3943 0 3925 5 3919 5 3910 5 3900.5 3889.5 3883.5 43 64.5 4349.5 4328.5 4312.0 4306.5 4302.0 4296.0 4287 5 4276 5 4274 0 4265 5 4244 5 4233 0 4229 0 4220.0 4201.5 4194.0 4171.5 4166.0 4162.0 4157.0 4148.0 4141 . 5 4135.5 4133.0 4128.0 4119.0 4109.5 4100.5 4097.0 4094.5 4083.0 4075.5 4073.0 4069.0 4059.0 4053.5 4047.5 4037.5 4034.0 4026.0 4010.5 4008.5 4003.0 3996.5 3994.5 3965.5 3946.5 3943.5 3926.0 3922.5 3913.0 3902.0 3890.5 3884.0 7-JAN-1997 14:18 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-JAN-1997 14:18 PAGE: 3871.0 3867.0 3861.0 3845.0 3839.5 3837.5 3817.5 3800.0 3790.5 3785.0 3769.5 3767.0 3753.0 3743 5 3737 0 3727 5 3721 5 3718 0 3708 5 3698 5 3695.5 3688.0 3684.0 3682.0 3678.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE .............. $ RE~JA~KS: 3873.0 3869.5 3862.0 3847.5 3841.0 3839.5 3818.5 3801.5 3790.5 3785 5 3771 0 3768 5 3755 0 3745 5 3736 5 3729 0 3725 5 3720 0 3714 0 3704 5 3697.5 3688.0 3685.0 3682.5 3678.0 100.0 BiT RUN NO. ~fl~RGE TOP MERGE BASE The depth adjustments shown above reflect the MWD GR to the PDC GRCH logged by SWS. All 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/RO~. The LDWG outputs of CALA and CALS are HDIA and VDIA respectively. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-JAN-1997 14:18 PAGE: ** 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 5482246 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 5482246 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0H~45482246 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD 0H~45482246 O0 000 O0 0 1 1 1 4 68 0000000000 ~ MWD 0H~4~5482246 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD 0H~I5482246 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 5482246 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 5482246 O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 5482246 O0 000 O0 0 1 1 1 4 68 0000000000 RHO1 MWD G/C3 5482246 O0 000 O0 0 1 1 1 4 68 0000000000 RH02 MWD G/C3 5482246 O0 000 O0 0 1 1 1 4 68 0000000000 RH03 MWD G/C3 5482246 O0 000 O0 0 1 1 1 4 68 0000000000 RH04 MWD G/C3 5482246 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 5482246 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 5482246 O0 000 O0 0 1 1 1 4 68 0000000000 DCALMWD IN 5482246 O0 000 O0 0 1 1 1 4 68 0000000000 CALAMWD IN 5482246 O0 000 O0 0 1 1 1 4 68 0000000000 CALSMWD IN 5482246 O0 000 O0 0 1 1 1 4 68 0000000000 TNRAMWD. 5482246 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD. PU-S 5482246 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-JAN-1997 14:18 PAGE: 10 DEPT. 7881.000 FET.MWD VRA.MWD -999.250 VRP.MWD RHOB.MWD -999.250 RHO1.MWD RHO4.MWD -999.250 DRHO.MWD CALA.MWD -999.250 CALS.SfWD DEPT. 6000. 000 FET.MWD VRA.MWD 2. 998 VRP.MWD RHOB.MWD 2. 457 RHO1 .MWD RHO4.MWD 2. 471 DPJ40.fVfWD CALA. MWD 8. 602 CALS. MWD DEPT. 4000. 000 FET. MWD VRA . f~WD 4. 394 VRP . MWD RHOB. MWD 2.300 RHO! . MWD RHO4.MWD 2.291 DRHO.MWD CALA. M~FD 8. 335 CALS. MWD -999.250 RA.MWD -999.250 ROP.MWD -999.250 RHO2.MWD -999.250 PEF.MWD -999.250 TNRA.MWD. 0.411 RA.MWD 2.806 ROP.MWD 2.495 RHO2.MWD 0.079 PEF.MWD 8.535 TNRA.MWD. O. 223 RA. MWD 4. 099 ROP. MWD 2. 301 RH02 . MWD O. 019 PEF.MWD 8.335 TNRA . MWD . DEPT. 3631.500 FET.MWD -999.250 RA.MWD VRA.MWD -999.250 VRP.MWD -999.250 ROP.MWD RHOB.MWD -999.250 RHO1.MWD -999.250 RHO2.MWD RHO4.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALA.MhrD -999.250 CAI~S.SfWD -999.250 T1V-RA.MRrD. -999.250 RP.MWD 131.376 GR.MWD -999.250 RHO3.MWD -999.250 DCAL.MWD -999.250 NPHI.MWD. 2.985 RP.MWD 178.216 GR.MWD 2.504 RHO3.MWD 3.711 DCAL.MWD 22.682 NPHI.MWD. 3. 656 RP.MWD 230. 761 GR .MWD 2.218 RH03. MWD 3. 038 DCAL . MWD 26.190 NPHI. MWD. -999.250 RP.MWD -999.250 GR.MW-D -999.250 RHO3.MWD -999.250 DCAL.MWD 27.989 NPHI.MWD. -999.250 -999.250 -999.250 -999.250 -999.250 2.808 97.496 2.466 0.026 37.600 4.216 88.072 2.281 0.520 48.800 -999.250 -999.250 -999.250 -999.250 53.400 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE · 97/01/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ADER FILE NU~4BER RAW MP~D LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-JAN-1997 14:18 PAGE: 11 Curves and log header data for each bit run in separate files. BIT RUN NUFi~ER: 1 DEPTH INCREMENT: 0.5000 FILE SU~9~ARY VENDOR TOOL CODE START DEPTH MWD 3630.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 7875.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR ADN DENS./NEUT. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (0B2~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MA TRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 15-0CT-96 FAST 4.0 4.0 MEMORY 7875.0 3631.0 7875.0 30 24.4 25.5 TOOL NUMBER RGS751 ADN044 8.500 3723.0 LSND 10.50 46.0 9.5 1000 5.2 2.380 73.0 2. 042 73.0 2. 540 73.0 SANDSTONE 2.65 1.0 20000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-JAN-1997 14:18 PAGE: 12 ~KS: ************ RUN 1 ************* DRILLED INTERVAL 3743 ' - 7875 ' MAX HOLE ANGLE = 25.6 DEG @ 7684 ' RES TO BIT: 56.39'; GR TO BIT: 67.39' NEUT TO BIT: 115.03'; DENS TO BIT: 110.90' TD WELL @ 11:00 15~0CT-96 CHLORIDES = 1000 PPM DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 120 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 8 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 5482246 O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 OH~ffff 5482246 O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW1 OP~4~ 5482246 O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 OH~M 5482246 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW1 F/HR 5482246 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 5482246 O0 000 O0 0 2 1 1 4 68 0000000000 TABR LW1 5482246 O0 000 O0 0 2 1 1 4 68 0000000000 TABD LW1 5482246 O0 000 O0 0 2 1 1 4 68 0000000000 ROSB LW1 G/C3 5482246 O0 000 O0 0 2 1 1 4 68 0000000000 ROMB LW1 G/C3 5482246 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-JAN-1997 14:18 PAGE: 13 NA24~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ROBB LW1 G/C3 5482246 O0 000 O0 0 2 1 1 4 ROBU LW1 G/C3 5482246 O0 000 O0 0 2 1 1 4 ROBL LW1 G/C3 5482246 O0 000 O0 0 2 1 1 4 ROBR LW1 G/C3 5482246 O0 000 O0 0 2 1 1 4 DRHB LWl G/C3 5482246 O0 000 O0 0 2 1 1 4 DRHU LW1 G/C3 5482246 O0 000 O0 0 2 1 1 4 DRHL LW1 G/C3 5482246 O0 000 O0 0 2 1 1 4 DRHR LW1 G/C3 5482246 O0 000 O0 0 2 1 1 4 PEB LW1 5482246 O0 000 O0 0 2 1 1 4 PEU LW1 5482246 O0 000 O0 0 2 1 1 4 PEL LW1 5482246 O0 000 O0 0 2 1 1 4 PER LW1 5482246 O0 000 O0 0 2 1 1 4 CALN LW1 IN 5482246 O0 000 O0 0 2 1 1 4 TNPH LW1 PU 5482246 O0 000 O0 0 2 1 1 4 TNRA LW1 5482246 O0 000 O0 0 2 1 1 4 DPHB LW1 PU 5482246 O0 000 O0 0 2 1 1 4 DCAL LW1 IN 5482246 O0 000 O0 0 2 1 1 4 HDIA LW1 IN 5482246 O0 000 O0 0 2 1 1 4 VDIA LWl IN 5482246 O0 000 O0 0 2 1 1 4 RPM LW1 RPM 5482246 O0 000 O0 0 2 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 7875. 000 ATR. LW1 ROPE. LW1 131 . 376 GR. LW1 ROSB. LW1 -999. 250 ROMB. LW1 ROBL. LW1 -999. 250 ROBR. LW1 DRHL.LW1 -999.250 DRHR.LW1 PEL . LW1 - 999.250 PER. LWi TNRA. LW1 - 999. 250 DPHB. LW1 VD IA . LW1 - 999.250 RPM. LW1 DEPT. 6000. 000 ATR. LW1 ROPE. LW1 123. 291 GR. LW1 ROSB. LW1 2. 302 ROMB. LW1 ROBL . LW1 2.479 ROBR . LW1 DRHL . LW1 O . 078 DRHR . LW1 PEL. LW1 3. 411 PER. LW1 TNRA. LW1 22.505 DPHB. LW1 VDIA . LW1 8. 535 RPM. LW1 DEPT. ROPE. LW1 ROSB. LW1 ROBL. LW1 DRHL. LW1 PEI.. LW1 TNRA . LW1 VDIA. LW1 4000. 000 ATR. LW1 227 837 GR.LW1 2 248 ROMB. LW1 2 289 ROBR. LW1 0 079 DRHR. LW1 3 178 PER. LWl 26 099 DPHB. LW1 8. 335 RPM. LWi -999.250 PSR.LW1 -999 250 TABR.LW1 -999 250 ROBB.LW1 -999 250 DRHB.LW1 -999 250 PEB.LW1 -999 250 CALN. LW1 -999 250 DCAL.LW1 -999 250 2. 982 PSR. LW1 105. 087 TABR.LW1 2. 455 ROBB. LW1 2. 453 DRHB. LW1 O . 069 PEB . LW1 3. 448 CALN.LW1 9. 000 DCAL. LW1 79.244 4.102 PSR.LW1 89. 071 TABR. LW1 2. 299 ROBB. LW1 2.322 DRHB.bW1 O . 076 PEB . LW1 2.806 CALN. LW1 20. 600 DCAL. LW1 68.918 -999. 250 DER. LW1 -999. 250 TABD. LW1 - 999. 250 ROBU. LW1 -999. 250 DRHU. LW1 -999. 250 PEU. LW1 -999. 250 TNPH. LW1 -999. 250 HDIA. LW1 2 749 DER. LW1 0 436 TABD. LW1 2 502 ROBU. LW1 0 077 DRHU. LW1 3 566 PEU. LW1 8 643 TNPH. LW1 0.143 HDIA.LW1 3. 909 DER. LW1 O. 223 TABD. LW1 2.310 ROBU. LW1 0. 024 DRIqU. LW1 2. 971 PEU. LW1 9. 007 TNPH. LW1 O. 507 HDIA. LW1 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2 824 0 921 2 474 0 114 4 009 37 100 8 535 3.969 0.663 2.222 0.114 2.913 48.500 8.335 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-JAN-1997 14:18 PAGE: 14 DEPT. 3630. 000 ATR. LW1 ROPE. LW1 -999. 250 GR. LW1 ROSB. LW1 -999. 250 RO~IB. LW1 ROBL. LWl -999. 250 ROBR. LW1 DRHL. LW1 -999. 250 DRHR. LW1 PEL. LW1 -999. 250 PER. LW1 TNRA. LW1 - 999. 250 DPHB. LW1 VD IA . LW1 -999. 250 RPM. LW1 -999. 250 PSR. LW1 -999. 250 TABR. LW1 -999. 250 ROBB. LW1 -999. 250 DRHB. LW1 -999. 250 PEB. LW1 -999. 250 CALN. LW1 -999. 250 DCAL . LW1 -999. 250 -999. 250 DER. LW1 - 999. 250 TABD. LW1 - 999. 250 ROBU. LW1 - 999. 250 DRHU. LW1 -999. 250 PEU. LW1 - 999. 250 TNPH. LW1 -999. 250 HDIA. LW1 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE ' 97/01/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE · 97/01/ 7 ORIGIN : FLIC TAPE NAME : 96369 CONTINUATION # : 1 PREVIOUS TAPE : COR~4~NT : B.P. EXPLORATION, MILNE POINT MPK-13, API #50-029-22655-00 **** REEL TRAILER **** SERVICE NAiViE : EDIT DATE : 97/01/ 7 ORIGIN : FLIC REEL NAME : 96369 CONTINUATION # : PREVIOUS REEL : CO~4ENT : B.P. EXPLORATION, MILNE POINT MPK-13, API #50-029-22655-00