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194-169
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: 12/05/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241217 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 8/17/2024 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 9/26/2024 YELLOWJACKET PERF-GPT BCU 24 50133206390000 214112 8/19/2024 YELLOWJACKET PERF BCU 25 50133206440000 214132 9/27/2024 YELLOWJACKET PLUG-PERF BLOSSOM 1 50133206480000 215015 9/30/2024 YELLOWJACKET GPT-PLUG-PERF HV B-17 50231200490000 215189 9/23/2024 YELLOWJACKET GPT KU 24-7 50133203520100 205099 10/3/2024 YELLOWJACKET PERF KU 13-06A 50133207160000 223112 12/5/2024 AK E-LINE Plug Setting KU 22-6X 50133205800000 208135 12/8/2024 AK E-LINE Perf KU 23-07A 50133207300000 224126 12/7/2024 AK E-LINE CBL MPU L-17 50029225390000 194169 10/5/2024 YELLOWJACKET PERF MPU R-103 50029237990000 224114 10/14/2024 YELLOWJACKET CBL MPU C-23 50029226430000 196016 11/29/2024 AK E-LINE Plug/cement MPU D-01 50029206640000 181144 11/26/2024 AK E-LINE Perf PBU 13-24B 50029207390200 224087 9/26/2024 YELLOWJACKET CBL PBU 06-07A 50029202990100 224043 9/29/2024 BAKER MRPM PBU 06-18B 50029207670200 223071 10/1/2024 BAKER MRPM PBU 07-32B 50029225250200 204128 10/28/2024 BAKER SPN PBU 14-32B 50029209990200 224073 10/12/2024 BAKER MRPM PBU H-13A 50029205590100 209044 10/23/2024 BAKER SPN PBU L2-20 50029213760000 185134 10/7/2024 BAKER SPN PBU L3-22A 50029216630100 219051 10/9/2024 BAKER PEARL 10 50133207110000 223028 9/25/2024 YELLOWJACKET GPT-PERF PEARL 11 50133207120000 223032 8/29/2024 YELLOWJACKET GPT-PLUG-PERF SRU 241-33 50133206630000 217047 8/23/2024 YELLOWJACKET PERF Please include current contact information if different from above. T39863 T39864 T39865 T39868 T39869 T39870 T39871 T39872 T39873 T39875 T39874 T39867 T39866 T39876 T39877 T39880 T39878 T39879 T39881 T39882 T39883 T39884 T39885 T39886 T39887 MPU L-17 50029225390000 194169 10/5/2024 YELLOWJACKET PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.18 08:35:44 -09'00' 1. 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 8,788 feet N/A feet true vertical 7,366 feet N/A feet Effective Depth measured 8,695 feet 1,744' & 8,375 feet true vertical 7,283 feet 1,744 & 7,000 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 8,078' 6,742' Viking ESP Retr Packers and SSSV (type, measured and true vertical depth)7” x 4” Baker FB-1 N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: 324-300 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 112' 560 Size 112' 3,603' 000 0 00 339 measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 194-169 50-029-22539-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025509 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT L-17 Plugs Junk measured LengthCasing Conductor 8,780' 3,632'Surface Production 20" 9-5/8" 7" 112' 3,632'5,750psi 7,240psi8,780' 7,359' Burst N/A Collapse N/A 3,090psi 5,410psi 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 2:00 pm, Nov 08, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.11.08 11:01:22 - 09'00' Taylor Wellman (2143) WCB 2-10-2025 DSR-11/20/24 RBDMS JSB 111824 _____________________________________________________________________________________ Revised By: TDF 11/8/2024 SCHEMATIC Milne Point Unit Well: MP L-17 Last Completed: 10/18/2024 PTD: 194-169 TD =8,780’(MD) / TD = 7,366’(TVD) Orig. KB Elev.: 50.00’MSL 7” 3 6 8& 9 14 & 15 9-5/8” 1 PBTD =8,695’ (MD) / PBTD = 7,283’(TVD) 4 2 17 18 20” 10 & 11 16 12 & 13 7 5 19 + 20 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / NT80LHE N/A Surface 112' N/A 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 3,632’ 0.0758 7" Production 26 / NT-80S / NSCC 6.276 Surface 8,780’ 0.0371 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 8,078’ 0.0058 3-1/2” Tubing 9.2 / L-80 / EUE 8rd 2.992 8,375’ 8,392’ 0.0087 JEWELRY DETAIL No Depth Item 1 219’STA #4: 2-7/8" x 1" Patco GLM W/ BK-DGLV 2 1,685’STA #3: 2-7/8" x 1" Patco GLM W/ BK-DGLV 3 1,744’ Packer, Viking ESP Retr. Dual Vent 4 1,798’STA #2: 2-7/8" x 1" Patco GLM W/ BK-DGLV 5 1,855’ 2-7/8” X-Nipple with RHC –Min ID 2.20 6 7,860 STA #1: 2-7/8" x 1" Patco GLM W/ BK-DGLV 7 7,946’ 2-7/8” XN-nipple 2.313" /2.205" No-Go 8 7,996..6’ Discharge Head: B/O PMP 400 9 7,997’ Zenith Head: S/A B/O 400PX PRESS PORT 10 7,998’ Pump #2: 400PMSSD 126 FLEX7ER HS 12CRC 11 8,020’ Pump #1: 400PMSSD 126 FLEX7ER HS 12CRC 12 8,042’ Gas Separator: 38GM2T HV E V X MT HS FER 13 8,047’ Intake: GPXARCINT FER H6 14 8,048’ Upper Tandem Seal: GS3 B/B/L SB H6 PFSA HL FER 12CRC 15 8,055’ Lower Tandem Seal: GS3 B/B/L SB H6 PFSA HL FER 12CRC 16 8,062’ Motor: 562XP 150/2430/38_125/2020 06R 17 8,073’ Guage- E7 MW 456 400 BAR 150C AFL w/ Centralizer:Btm @ 8,078’ 18 8,375’ CTM 7” x 4” Baker FB-1 Packer 19 8,385’ CTM HES 2.813” XN-Nipple w/ 2.75” No-Go. 20 8,390’ WLEG: Btm @ 8,392’ OPEN HOLE / CEMENT DETAIL 20” 260 sx of Arcticset in 30” Hole 9-5/8" 710 sx PF ‘E’ / 250 sx Class “G” in 12-1/4” Hole 7” 244 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = 58 deg. @ 7,800’ MD Hole Angle through perforations = 53 deg. Max Dog Leg 4.65 deg. @1,407’ MD TREE & WELLHEAD Tree 3-1/8”- 5M WKM Wellhead 13-3/8” FMC Actuator Baker CAC Model “M” Tbg. Hng. 12” x 3.5” NSCT GENERAL WELL INFO API: 50-029-22539-00-00 Drilled, Cased & Completed by Nabors 4ES – 8/16/1995 ESP Swap by ASR#1 – 10/18/2024 FRAC DETAIL Frac’d ‘B’ Sands w/ 65,000 # 16/20 Carbolite Behind Pipe PERFORATION DETAIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status B Silt 8,426’ 8,458’ 7,050’ 7,077’ 32 1995 Open 8,430’ 8,462’ 7,048’ 7,075’ 27 1995 Open Ref. Log: AWS GR/CCL 4/2/1995. 3-3/8” Dia. Guns @ 6spf, 22gm. Jumbo Jet, EHD=0.76”, TTP=6.4”, 60 Deg. Phasing Well Name Rig API Number Well Permit Number Start Date End Date MP L-17 ASR#1 50-029-22539-00-00 194-169 10/7/2024 10/21/2024 Testing complete - 2 F/P due to air in the system, retests - good. Blow down system. Hang ESP sheave and trunk. Remove fresh water from pits. Spot in tiger tank and RU. Fill gas buster w/ 9.9ppg and lock out. IA static - pull CTS/BPV. Pull HNGR off seat at 62k, dragging 61k - 70k. Cut ESP cable and tie into spooler. Fill hole w/ 11.1bbls. BO/LD hanger, Kelly, and TIW. POOH W/ 2-7/8" EUE and ESP F/ 8,160'. Maintaining 1x displacement. Scale on pipe from ~2,000' remaining in hole. (6,000' - 8,080' MD). OOH. Missing all components below Discharge Head Flange - ESP assembly = 42' OAL, 4.00" O.D. Pump looking up. BO Discharge Head / JT. Threads corroded, discharge head covered w/ heavy scale. Clamps/bands - Recovered: 131/131 Lasal Clamps. Missing: 25/52 Flat Bands. 5.5/9 flat guards. 4/4 "preform". Swap handling equipment to 3-1/2" WS. No operations to report. 10/5/2024 - Saturday RU ASR-1 and ancillary equipment. Function test BOPE. Rig accepted 16:00 10/07/2024. Begin testing BOPE 250/3000psi. AOGCC witness waived. 10/8/2024 - Tuesday 10/6/2024 - Sunday No operations to report. 10/7/2024 - Monday 10/4/2024 - Friday No operations to report. 10/2/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 10/3/2024 - Thursday No operations to report. POOH W/ 2-7/8" EUE and ESP F/ 8,160'. Well Name Rig API Number Well Permit Number Start Date End Date MP L-17 ASR#1 50-029-22539-00-00 194-169 10/7/2024 10/21/2024 10/11/2024 - Friday Cont. RIH w/ Burn shoe BHA on 3-1/2" G-105 NC31 workstring F/ 227' T/ 8,032' S/O wt = 49K P/U wt = 87K Static lose rate = 1.8 BPH. P/U & M/U 2x 10' 3.5" G-105 NC31 pups for space out of fish top. Cont RIH to tag fish at 8,193' Kelly up & line up to pump. Wash dw to top of fish at 5BPM w/ 1,170 psi. Observed pressure change at fish top to 1,300 psi. Cont. to wash & ream to reach full locate 8,206.5', Shut dw pumps. Swallow over fish dry to full locate at 8,206'. Begin POOH W/ 3-1/2" workstring F/ 8,193' T/ 227' pumping 1X displacement. L/D BHA. P/U M/U over shot W/ 4" Grapple, 6 X 4-3/4" collars, jars, bumper sub. Begin RIH W/ 3-1/2" workstring. RIH w/ Overshot BHA on 3-1/2" G-105 NC31 workstring T/ 7,356' S/O wt = 43K P/U wt = 66K Static lose rate = 2 BPH. 10/9/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Install wear bushing. M/U RCJB BHA; RCJB, 2 boot baskets, bumper sub, jars, 6 - 4-3/4 drill collars. RIH W/ 3-1/2 workstring and RCJB BHA T/ 8,223' SOW 50K, PUW 90K. Tag top of fish. Line up to circulate. Obtain parameters. ROT wt = 65K P/U = 91K S/O = 45K. 5 BPM w/ 1575 psi. ROT RPM 36 & 3.5k TQ. Pump a total of 300 bbls. NO change in parameters. Shut down pumps & monitor well. B/D fluid lines. Well losing fluid at 2 BPH. POOH W/ 3-1/2 workstring and RCJB F/ 8,223' T/ 4,994' SOW 46K, PUW 53K. 10/10/2024 - Thursday Cont. POOH W/ 3-1/2" workstring and RCJB F/ 4,994' T/ 230' SOW 11K, PUW 11K. Losing 2 BPH. L/D RCJB BHA. No ss bands in RCJB or boot baskets. Decision made to run 4-3/4" Burn shoe. Mobilize Burn shoe to location. P/U & M/U Burn shoe, 3x washpipe ext, bumper sub, jars. 6 X 4-3/4" drill collars and pump out sub. RIH w/ Burn shoe BHA on 3-1/2" G-105 NC31 workstring F/ 227' - T/ 7,833' S/O wt = 48K P/U wt = 84K Static lose rate = 1.8 BP Cont. RIH w/ Overshot BHA on 3-1/2" G-105 NC31 workstring F/ 7,356' T/ 8,100' S/O wt = 50K P/U wt = 87K Static lose rate = 2 BPH. Kelly up. Obtain parameters. Wash over fish. Swallow over to 4.5' Set dw 10K. Pick to 92 K for 5K overpull. Work incrementally until 20k overpull reached. Begin jarring. Cont jarring operations, increasing overpull until 30K overpull reached while jarring. After jarring with 30K overpull. Pipe moving freely down. Still having overpull picking up. RIH to 8,208'. P/U seeing up to 20K overpull ( fish dragging ) POOH to 8,178' Pump a lube pill. At 3 BPM w/ 1,000 psi. Spot pill above fish. Begin POOH. POOH w/ Overshot BHA on 3-1/2" G-105 NC31 workstring F/ 8,178' S/O wt = 50K P/U wt = 87K Static lose rate = 1 BPH. Seeing 2-5K drag, POOH T/ 111'. Carriage having mechanical / hydraulic issues. Stop to trouble shoot. 10/12/2024 - Saturday Rig functional at lower hyd. pressure. L/D 2x spiral 4-3/4" DC & overshot. Fish on. L/D overshot w/ pump assy. swallowed. With ESP rep. Disassemble ESP 1 pump, seal & motor. Fish complete. Possible ESP cable pieces missing. Esp cable compressed together in sections, unable to discern lengths. Flat guard cut in half some small bolts missing. Clean & clear rig floor of ESP tools. Swap equipment to P/U & M/U BHA P/U and torque up RCJB,7" CSG scraper, boot baskets and XO. Mechanic adjust new hyd pumps. 4 hrs down time. P/U & M/U remaining BHA. bumper sub and jars, 6 X 4-3/4" DC. Begin RIH W/ 3-1/2" workstring. Rig power loss. Operational error. NPT. Rig not fueled. Fuel & continue RIH W/ 3-1/2" G-105 NC31 workstring and RCJB clean out BHA T/8,375' . S/O wt = 58K P/U wt = 80K. Loss rate = Tag Sump PKR at 8375'. P/U & kelly up. 10/13/2024 - Sunday Troubleshooting mechanical/ hydraulic issues. 10/14/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP L-17 ASR#1 50-029-22539-00-00 194-169 10/7/2024 10/21/2024 Hilcorp Alaska, LLC Weekly Operations Summary Scrape 4 X at 8,100' to 8,000'. Tag Sump PKR at 8,375'. P/U & kelly. Pump at 5.5 BPM w/ 1,500 psi. Re-tag sump PKR. Depth = 8,375'. Set on PKR & pump with RCJB for 15 mins. Begin Reciprocating. P/U & S/O wt consistent. 80K & 57K. Pump a total of 340 bbls for 1.5X BUS. L/D Jt #204. B/D lines. POOH w/ clean out BHA. F/ 8,353' T/ 228' L/D 6 X 4-3/4 DC, bumper sub, jars, scraper, 2 boot baskets and RCJB. No debris recovered. Clean & clear rig floor. Set test plug. Test BOPE as per approved sundry. AOGCC waived witness to testing. Test F/ 250 psi low T/ 3000 psi high f/ 5/5 charted mins. 10/15/2024 - Tuesday Test BOPE as per approved sundry. AOGCC waived witness to testing. Well Name Rig API Number Well Permit Number Start Date End Date MP L-17 ASR#1 & WH 50-029-22539-00-00 194-169 10/7/2024 10/21/2024 No operations to report. Line up to Pump dw IA to test ESP PKR. B/D TBG pump line. Bleed off cap line ensuring vent valve shut. Pressure up on IA, 7' x 2-7/8" at 50 psi per min as per sundry to 1,500 psi. MIT ESP PKR. Passing. Open vent valve. Pump dw vent valve with test pump .2 BPM. Ensuring function (good). BPV installed. Flush BOP stack with johnny wacker. Flush lines, manifold and bop stack with fresh water. Release from L-17 at 12:00 on 10-19-2024. 10/19/2024 - Saturday WELL S/I ON ARRIVAL. PULL 1" DMY GLV @ 218' MD. SET 1" DPSOV @ 218' MD. MAKE SEVERAL RUN'S TO 1,854' MD TO PULL BALL & ROD. RUN 2.25" LIB GET IMPRESSION OF G-FISH NECK. PULL RHC BODY FROM 1,854' MD. WELL S/I ON DEPATURE 10/22/2024 - Tuesday 10/20/2024 - Sunday N/U Tree/Adapter test void 500 low 5000 high 5/10 mins (good test), Pulled BPV with T-bar and secured well. 10/21/2024 - Monday 10/18/2024 - Friday RIH w/ ESP assy. on 6.5# 2-7/8" L-80 EUE pipe f/ 3,142' - t/ 6,321' Testing ESP cable every 1,000' Loss rate= .8 BPH. Run speed 60 FPM. P/U & M/U EDP PKR. Splice ESP cable through PKR & Test (good) Install vent valve cap line. Test to 5000 psi. Cont. RIH w/ ESP assy. on 6.5# 2-7/8" L-80 EUE pipe f/ 6,321' t/ 8,055'. M/U hanger & perform hanger splice. Test cable & Splice cap line to hanger. Pressure cap line to 5000 psi for test (good) Land hanger on correct RKB. RILDS Final P/U = 62K S/O wt = 46K Final depth = 8,077' Drop ball & rod. Line up to pump down TBG for PKR set & test. 10/16/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Completed BOPE testing with no failures. Completed accumulator drawdown. Pull test plug. Fill well with 8 bbls. P/U & M/U ASX-1 7" test PKR. Begin RIH. RIH w/ AS1-X 7" test PKR on 3--1/2" G105 NC31 pipe F/ 16'. T/ 8,050' P/U wt = 68K S/O wt = 52K. Loss rate = .8 BPH. Pump 20 bbls of 9.9 ppg fluid dw workstring. Clear annulus around PKR. Place PKR on depth for setting. Rig carriage showing signs of HYD problems. NPT. Change out solenoid on carriage A hyd. loop. Test carriage. No issues. One hour down time. Set 7" test PKR at 8,052' COE.. Set 23k on PKR. Test CSG to 1,900 psi for 30 charted mins. Good test. Release PKR. Monitor well. Tbg flowing. Fluid weight under 9.9 ppg. Tubing out of balance due to operational error in pits. All pits weighted up to 9.9 ppg. Pump TBG volume. Shut dw. TBG static. POOH w/ AS1-X 7" test PKR lay dw singles of 3-- 1/2" G105 NC31 pipe F/ 8,050' T/ 7,420' P/U wt = 64K S/O wt = 48K. Loss rate = .8 BPH 10/17/2024 - Thursday POOH w/ AS1-X 7" test PKR lay dw singles of 3--1/2" G105 NC31 pipe F/ 7,420' T/ BHA . L/D Test PKR. No damage & functioning. Change handling equip. Hang sheave for ESP cable. Preform derrick inspection. P/U & M/U motor, lower & upper tandem seal. Service as needed. Tie in MLE. M/U intake, gas sep., Pump #1 / 2. Zenith, & discharge head. Test & RIH w/ ESP assy. on 6.5# 2-7/8" L-80 EUE pipe f/ 91' - t/ 3,142'. Testing ESP cable every 1,000' Loss rate= .8 BPH. Run speed 60 FPM. RIH w/ ESP assy. on 6.5# 2-7/8" L-80 EUE pipe f/ 3,142' - t/ 6,321' Testing ESP cable every 1,000' Loss rate= .8 BPH. Run speed 60 FPM. P/U & M/U EDP PKR. Splice ESP cable through PKR & Test (good) Install vent valve cap line. Test to 5000 psi. Cont. RIH w/ ESP assy. on 6.5# 2-7/8" L-80 EUE pipe f/ 6,321' t/ 8,055'. M/U hanger & perform hanger splice. Test cable & Splice cap line to hanger. Pressure cap line to 5000 psi for test (good) Land hanger on correct RKB. RILDS Pressure up on IA, 7' x 2-7/8" at 50 psi per min as per sundry to 1,500 psi. MIT ESP PKR. 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: Swap Vent Packer 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): 8,788'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG 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 MPSP (psi): MILNE PT UNIT L-17 MILNE POINT KUPARUK RIVER OIL N/A Will perfs require a spacing exception due to property boundaries? Current Pools: N/A Subsequent Form Required: Suspension Expiration Date: Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 2-7/8" 6.5 / L-80 / EUE 8rd 8,078' 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 AOGCC USE ONLY 7,366' 11/18/2024 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 194-169 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22539-00-00 Hilcorp Alaska LLC C.O. 432E Length Size Proposed Pools: 112' 112' Plugs (MD): 8,695' 7,283' 2,618 TVD Burst 8,392' MD N/A 5,750psi 7,240psi 3,603' 7,359' 3,632' 8,780' 112' 20" 9-5/8" 7" 3,632' 8,780' Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Perforation Depth MD (ft): See Schematic See Schematic 3-1/2" Viking ESP Ret. &7” x 4” Baker FB-1 Packer and N/A 1,744 MD/ 1,744 TVD & 8,375 MD/ 7,000 TVD and N/A 9.2 / L-80 / EUE 8rd 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 2:50 pm, Nov 08, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.11.08 14:39:01 - 09'00' Taylor Wellman (2143) 324-641 10-404 DSR-11/20/24SFD 11/12/2024MGR27NOV24 X BOP Test to 3000 psi. Annular to 2500 psi. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.12.05 14:28:48 -09'00'12/05/24 RBDMS JSB 121324 Well: MPL-17 PTD: 194-169 API: 50-029-22539-00-00 Well Name:MPL-17 API Number:50-029-22539-00-00 Current Status:Shut-in Producer Rig:ASR #1 Estimated Start Date:11/18/2024 Estimated Duration:2 days Regulatory Contact:Tom Fouts Permit to Drill Number:194-169 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 3,292 psi @ 6,739’ TVD BH gauge 11/7/2024 | 9.4 PPGE 9.9 KWF Max Potential Surface Pressure: 2,618 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 53° Sail Angle from 7,083’ MD Brief Well Summary: MPU L-17 is a Kuparuk producer drilled in 1995. It received a frac of 65K lbs of 16/20 Carbolite. There was 1 ESP installed from ’96-’99 and it has been shutin since. This well exists in an unsupported fault block on primary depletion. We ran the ESP completion Oct 2024 and could never get a passing MIT-IA. Objectives: Pull failed vent packer, replace it, RIH set and test packer. Notes Regarding Wellbore Condition: - 7” casing test to 1,900 psi. 10/16/2024 Pre-Rig Procedure (Non Sundried Work) 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 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 9.9# brine water down tubing, taking returns up casing to 500 barrel returns tank. Bullhead down tbg and IA taking returns to formation as needed to establish and maintain a full column of 9.9# brine. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure (Begin Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with 9.9# brine prior to setting CTS. 3. Test BOPE to 250 psi low/ 3,000 psi high. Test 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. Well: MPL-17 PTD: 194-169 API: 50-029-22539-00-00 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” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with 9.9# brine water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out Centrilift for ESP pull. 6. RU spoolers to handle ESP cable. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an 13-5/8” x 3-1/2” Gen 5, 3-1/2” NSCT Top & Btm. b. 2024 tubing PU weight on ASR recorded as 62 kip. Slack off weight recorded as 46 kip. c. 2-7/8” L-80 EUE yield is 144 kip. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8” tubing to the x-nipple at 1,855’ MD, kick out the vent packer. a. Re-use all the tubing, nipple and GLM. 10. Load the x-nipple with an RHC. 11. RIH with GLM. a. If needed, drop a longer +-30’ joint out below the vent packer for the ESP cable and replace it with a shorter 26-27’ jt. You might have to dig around on D-pad to find one. 12. PU a new Viking packer with Dual vent Viking valves Gen 1. a. The previous packer was a single vent valve, you will need the cap tube and parts to connect to the dual vent valves. 13. RIH with new 2-7/8” 6.5# L-80 ESP completion to +/- 8,080’MD (due to DLS above and below) and obtain string weights. a. Check electrical continuity every 1000’. b. Note PU and SO weights on tally. c. Install ESP clamps per Baker, and cross coupling clamps every other joint d. Photograph vent packer prior to running in hole. Nom. (OD)Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 ~8,080’ MD 4.5 2 Intake Sensor 30 5.62 34 Motor 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 8 Gas Separator 52 5.38 10 GINPSH 45 5.38 ~57 Pump 45 POOH and lay down the 2-7/8” tubing to the x-nipple at 1,855’ MD, kick out the vent packer. a. Re-use all the tubing, nipple and GLM. Well: MPL-17 PTD: 194-169 API: 50-029-22539-00-00 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 2-7/8” XN-nipple 2.313" / 2.205" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" ~6,085 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 2-7/8” X-nipple with RHC profile 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 31 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 31 2-7/8" EUE 8rd Jt 6.5 L-80 30 Packer, Viking ESP Retr. Dual Vent ~1,750 MD 2-7/8" 30 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" ~1,550 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 14. Terminate the ESP cable and make up the ESP penetrator to the ESP cable. Ensure the 3/8” NPT control line feed thru port is dummied off. a. Same as below the vent packer, if needed, drop a longer +-30’ joint out to accommodate the ESP cable length and replace it with a shorter 26-27’ jt. You might have to dig around on D-pad to find one. 15. Make up the control line to the dual vent valves. Pressure up on the control line to 5,000 psi and hold for 5 minutes checking for leaks (note the opening pressure in the daily report). Bleed the pressure to 500 psi and maintain 500 psi while running in hole. a. Periodically confirm control line is maintaining 500 psi. 16. Continue running ESP completion per plan. Well: MPL-17 PTD: 194-169 API: 50-029-22539-00-00 17. PU and MU the 3-1/2” tubing hanger. Make final splice of the ESP cable to the penetrator. MU the control line to the tubing hanger and dummy off any additional control line ports if present. 18. Land tubing hanger, avoiding any damage to ESP cable or control line. RILDS. Lay down landing joint. Note PU and SO weights on tally and in daily report. 19. Drop ball and rod. 20. Pressure up on tubing to 4,000 psi and hold for 15 minutes to set the ESP packer. 21. Bleed tubing to 0 psi. 22. Pressure up on tubing to 4,000 psi and hold for 5 more minutes and then bleed to 0 psi. 23. Bleed packer control line to 0 psi, closing packer vent valves. 24. Slowly pressure up IA at 50 psi/min to 1,500 psi and hold for 30 minutes. Chart test. 25. Lay down landing joint. 26. Set BPV. 27. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Slickline: 1. RU slickline, pressure test PCE to 250psi low / 3,000psi high. 2. Pull ball and rod. 3. Pull RHC profile. 4. Pull DGLV and set GLSOV in upper GLM at ~200’ MD. 5. RDMO. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Double 13-5/8” BOPE Schematic Freeze protect? GLSOV Chart test. _____________________________________________________________________________________ Revised By: TDF 11/8/2024 SCHEMATIC Milne Point Unit Well: MP L-17 Last Completed: 10/18/2024 PTD: 194-169 TD =8,780’(MD) / TD = 7,366’(TVD) Orig. KB Elev.: 50.00’MSL 7” 3 6 8& 9 14 & 15 9-5/8” 1 PBTD =8,695’ (MD) / PBTD = 7,283’(TVD) 4 2 17 18 20” 10 & 11 16 12 & 13 7 5 19 + 20 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / NT80LHE N/A Surface 112' N/A 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 3,632’ 0.0758 7" Production 26 / NT-80S / NSCC 6.276 Surface 8,780’ 0.0371 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 8,078’ 0.0058 3-1/2” Tubing 9.2 / L-80 / EUE 8rd 2.992 8,375’ 8,392’ 0.0087 JEWELRY DETAIL No Depth Item 1 219’STA #4: 2-7/8" x 1" Patco GLM W/ BK-DGLV 2 1,685’STA #3: 2-7/8" x 1" Patco GLM W/ BK-DGLV 3 1,744’ Packer, Viking ESP Retr. Dual Vent 4 1,798’STA #2: 2-7/8" x 1" Patco GLM W/ BK-DGLV 5 1,855’ 2-7/8” X-Nipple with RHC –Min ID 2.20 6 7,860 STA #1: 2-7/8" x 1" Patco GLM W/ BK-DGLV 7 7,946’ 2-7/8” XN-nipple 2.313" /2.205" No-Go 8 7,996..6’ Discharge Head: B/O PMP 400 9 7,997’ Zenith Head: S/A B/O 400PX PRESS PORT 10 7,998’ Pump #2: 400PMSSD 126 FLEX7ER HS 12CRC 11 8,020’ Pump #1: 400PMSSD 126 FLEX7ER HS 12CRC 12 8,042’ Gas Separator: 38GM2T HV E V X MT HS FER 13 8,047’ Intake: GPXARCINT FER H6 14 8,048’ Upper Tandem Seal: GS3 B/B/L SB H6 PFSA HL FER 12CRC 15 8,055’ Lower Tandem Seal: GS3 B/B/L SB H6 PFSA HL FER 12CRC 16 8,062’ Motor: 562XP 150/2430/38_125/2020 06R 17 8,073’ Guage- E7 MW 456 400 BAR 150C AFL w/ Centralizer:Btm @ 8,078’ 18 8,375’ CTM 7” x 4” Baker FB-1 Packer 19 8,385’ CTM HES 2.813” XN-Nipple w/ 2.75” No-Go. 20 8,390’ WLEG: Btm @ 8,392’ OPEN HOLE / CEMENT DETAIL 20” 260 sx of Arcticset in 30” Hole 9-5/8" 710 sx PF ‘E’ / 250 sx Class “G” in 12-1/4” Hole 7” 244 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = 58 deg. @ 7,800’ MD Hole Angle through perforations = 53 deg. Max Dog Leg 4.65 deg. @1,407’ MD TREE & WELLHEAD Tree 3-1/8”- 5M WKM Wellhead 13-3/8” FMC Actuator Baker CAC Model “M” Tbg. Hng. 13.625” x 3.5” NSCT GENERAL WELL INFO API: 50-029-22539-00-00 Drilled, Cased & Completed by Nabors 4ES – 8/16/1995 ESP Swap by ASR#1 – 10/18/2024 FRAC DETAIL Frac’d ‘B’ Sands w/ 65,000 # 16/20 Carbolite Behind Pipe PERFORATION DETAIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status B Silt 8,426’ 8,458’ 7,050’ 7,077’ 32 1995 Open 8,430’ 8,462’ 7,048’ 7,075’ 27 1995 Open Ref. Log: AWS GR/CCL 4/2/1995. 3-3/8” Dia. Guns @ 6spf, 22gm. Jumbo Jet, EHD=0.76”, TTP=6.4”, 60 Deg. Phasing _____________________________________________________________________________________ Revised By: TDF 11/8/2024 PROPOSED Milne Point Unit Well: MP L-17 Last Completed: 10/18/2024 PTD: 194-169 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / NT80LHE N/A Surface 112' N/A 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 3,632’ 0.0758 7" Production 26 / NT-80S / NSCC 6.276 Surface 8,780’ 0.0371 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±8,078’ 0.0058 3-1/2” Tubing 9.2 / L-80 / EUE 8rd 2.992 8,375’ 8,392’ 0.0087 JEWELRY DETAIL No Depth Item 1 ±XXX’STA #4: 2-7/8" x 1" Patco GLM W/ BK-DGLV 2 ±X,XXX’STA #3: 2-7/8" x 1" Patco GLM W/ BK-DGLV 3 ±X,XXX’ Packer: Dual Vent Viking ESP Retr. Dual Vent 4 ±X,XXX’STA #2: 2-7/8" x 1" Patco GLM W/ BK-DGLV 5 ±X,XXX’ 2-7/8” X-Nipple with RHC – Min ID 2.20 6 ±X,XXX’STA #1: 2-7/8" x 1" Patco GLM W/ BK-DGLV 7 ±X,XXX’ 2-7/8” XN-nipple 2.313" / 2.205" No-Go 8 ±X,XXX’ Discharge Head: 9 ±X,XXX’ Zenith Head: 10 ±X,XXX’ Pump #2: 11 ±X,XXX’ Pump #1: 12 ±X,XXX’ Gas Separator: 13 ±X,XXX’ Intake: 14 ±X,XXX’ Upper Tandem Seal: 15 ±X,XXX’ Lower Tandem Seal: 16 ±X,XXX’ Motor: 17 ±X,XXX’ Guage- w/ Centralizer: Btm @ ±8,078’ 18 8,375’ CTM 7” x 4” Baker FB-1 Packer 19 8,385’ CTM HES 2.813” XN-Nipple w/ 2.75” No-Go. 20 8,390’ WLEG: Btm @ 8,392’ WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = 58 deg. @ 7,800’ MD Hole Angle through perforations = 53 deg. Max Dog Leg 4.65 deg. @1,407’ MD TREE & WELLHEAD Tree 3-1/8”- 5M WKM Wellhead 13-3/8” FMC Actuator Baker CAC Model “M” Tbg. Hng. 13.625” x 3.5” NSCT GENERAL WELL INFO API: 50-029-22539-00-00 Drilled, Cased & Completed by Nabors 4ES – 8/16/1995 ESP Swap by ASR#1 – 10/18/2024 FRAC DETAIL Frac’d ‘B’ Sands w/ 65,000 # 16/20 Carbolite Behind Pipe PERFORATION DETAIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status B Silt 8,426’ 8,458’ 7,050’ 7,077’ 32 1995 Open 8,430’ 8,462’ 7,048’ 7,075’ 27 1995 Open Ref. Log: AWS GR/CCL 4/2/1995. 3-3/8” Dia. Guns @ 6spf, 22gm. Jumbo Jet, EHD=0.76”, TTP=6.4”, 60 Deg. Phasing TD =8,780’(MD) / TD = 7,366’(TVD) Orig. KB Elev.: 50.00’MSL 7” 3 6 8& 9 14 & 15 9-5/8” 1 PBTD =8,695’ (MD) / PBTD = 7,283’(TVD) 4 2 17 18 20” 10 & 11 16 12 & 13 7 5 19 + 20 OPEN HOLE / CEMENT DETAIL 20” 260 sx of Arcticset in 30” Hole 9-5/8" 710 sx PF ‘E’ / 250 sx Class “G” in 12-1/4” Hole 7” 244 sx Class “G” in 8-1/2” Hole Milne Point ASR 13-5/8” BOP 11/8/2024 13 5/8" 5M Hydril or Shaffer CIW or Sh affer 13 5/8" 5M 2 1/16" 5M Kill Valves Manual and M anual 2 1/16" 5M Choke Valves Manual and HCR 3 1/2" x 5 1/2" VBR Rams Blinds Spacer Spool 13 5/8" 5M x 13 5/8" 5M CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] MPU L-17 Sundry 324-641 PTD194-169 Freeze protection Date:Friday, December 6, 2024 3:06:31 PM From: Ryan Lewis <ryan.lewis@hilcorp.com> Sent: Friday, December 6, 2024 10:20 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] MPU L-17 Sundry 324-641 PTD194-169 Freeze protection Jack- In the case of the well getting shut in, the vent valves get closed. The Vent Valves are tied into the SSV panel and when we dump the pressure to close the XV, the vent valves also close. Thanks, RL From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Wednesday, December 4, 2024 2:15 PM To: Ryan Lewis <ryan.lewis@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] MPU L-17 Sundry 324-641 PTD194-169 Freeze protection Thanks Ryan, Can gas be ejected into the IA when the ESP is off? Jack From: Ryan Lewis <ryan.lewis@hilcorp.com> Sent: Wednesday, December 4, 2024 11:09 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] MPU L-17 Sundry 324-641 PTD194-169 Freeze protection Jack- CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 1. My error, I meant FP Freeze Protect, not FR. Station #3 is to allow you to FP in case of a long-term shut-in. 2. OV to take free gas that is ejected to the IA at the gas separator of the ESP just before the first ESP pump. It travels up the IA through the open vent valve to surface. Then the gas flows through the Differential Pressure Screened Oriface Valve (DPSOV). I anticipate gas production to be 25 MCFD (GOR = 250 SCF/bbl x 100 BOPD = 25,000 SCFD). 3. We do not FR above the packer on install because the well is coming on as soon as the rig is gone. It is probably appropriate to run through the purpose of each of the 4 GLM from bottom to top. STA #4 – OV to take free gas that is ejected to the IA at the gas separator of the ESP just before the first ESP pump. It travels up the IA through the open vent valve to surface. Then the gas flows through the Differential Pressure Screened Oriface Valve (DPSOV). I anticipate gas production to be 25 MCFD (GOR = 250 SCF/bbl x 100 BOPD = 25,000 SCFD). STA #3 In the case of a long term shut-in would need to pump a Freeze Protect FP. We do not FP when we land the well because it will be coming on directly after the rig is gone and we can get it re-connected. STA #2 If the vent valve fails in the closed position, we can still take IA gas from under the packer back into the production stream. STA #1 Circulate kill fluid around tubing and IA. If things aren’t 100% clear please keep asking questions. When you look at our tubing string and jewelry it looks busy and it is with the ESP packers but every GLM has its purpose. Thanks, RL From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Wednesday, December 4, 2024 9:54 AM To: Ryan Lewis <ryan.lewis@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] MPU L-17 Sundry 324-641 PTD194-169 Freeze protection Ryan – Please provide clarification on what you mean with your response to Mel’s questions. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 1. Station #3 is to FR if the packer is blocked/plugged. – What is meant by FR? Please provide clarification on what is meant and the purpose. 2. Station #4 the OV is to jump the gas back into the liquid stream and out of the well. The same as jumping the gas back into the line on surface. – Explain the source of this gas and the purpose? Gas vented from the ESP? How much gas in expected? 3. Do you need to freeze protect above the packer? I didn’t see a response to this question and there is not a freeze protect step in your program. Thanks Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 Office (907) 227-2760 Cell From: Ryan Lewis <Ryan.Lewis@hilcorp.com> Sent: Tuesday, December 3, 2024 10:34 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] MPU L-17 Sundry 324-641 PTD194-169 Freeze protection Station #3 is to FR if the packer is blocked/plugged. Station #4 the OV is to jump the gas back into the liquid stream and out of the well. The same as jumping the gas back into the line on surface. Thanks, RL From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, November 27, 2024 4:32 PM CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. To: Ryan Lewis <Ryan.Lewis@hilcorp.com> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: [EXTERNAL] MPU L-17 Sundry 324-641 PTD194-169 Freeze protection Ryan, Do you need to freeze protect above the packer? I don’t understand why set an OV at the GLM at ~200’ MD. Can you explain? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Jack Lau The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Gluyas, Gavin R (OGC) From:Rixse, Melvin G (OGC) Sent:Friday, October 25, 2024 3:28 PM To:AOGCC Records (CED sponsored) Subject:APPROVAL MPU L-17 PTD: 194-169 Sundry:324-300 Ryan, Approved to POP under Evaluation for 5 days. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Lewis <Ryan.Lewis@hilcorp.com> Sent: Friday, October 25, 2024 8:42 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MPU L-17 PTD: 194-169 Sundry:324-300 Mel- MPL-17 is an over-pressured (10.0# EMW) well and we ran an ESP Vent Packer. When we set the packer and dropped the ball and rod it got stuck in the landing joint. After the rig was gone, we went and set a pronged X plug in the x-nipple and performed a proper packer set sequence. We changed the GLVs and they do not seem to be leaking and we have cycled the vent valve several times. Hilcorp would like to Start the ESP run it Under Evaluation for 5 days, give the well the opportunity to clear out any junk in the vent valve. After 5 days, we will shut down the ESP to obtain a passing MIT-IA. We will also perform a 30 min negative test on the vent packer since that is the real-life application of testing a vent valve. Hilcorp will 24/7 Man watch the well for the duration of the 5 day producing period. Since this has happened a few times now, I am actively looking for a new vent valve vendor going forward. Thanks, Ryan Lewis Hilcorp Alaska – Operations Engineer CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 (303) 906-5178 Ryan.lewis@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: 5/21/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240521 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 3-07A 50029219110100 198147 5/11/2024 HALLIBURTON Coilflag MPU E-19 50029227460000 197037 3/25/2024 READ CaliperSurvey MPU F-66A 50029226970100 196162 5/8/2024 READ CaliperSurvey MPI 1-27 50029216930000 187009 5/7/2024 READ PPROF MPU L-17 50029225390000 194169 5/8/2024 READ CaliperSurvey NCI A-12B 50883200320200 223053 5/2/2024 READ MAPP NCI A-17 50883201880000 223031 5/3/2024 READ MAPP PBU 11-41 50029237820000 224017 5/11/2024 HALLIBURTON RBT/Coilflag PBU D-31B 50029226720200 212168 5/12/2024 HALLIBURTON RBT PBU F-31A 50029216470100 212002 5/8/2024 READ CaliperSurvey PBU J-19 50029216290000 186135 5/2/2024 HALLIBURTON RBT PBU L-292 50029237510000 223025 5/6/2024 HALLIBURTON PPROF Please include current contact information if different from above. T38831 T38832 T38833 T38834 T38835 T38836 T38837 T38838 T38839 T38840 T38841 T38842 MPU L-17 50029225390000 194169 5/8/2024 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.22 09:57:50 -08'00' 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): 8,788'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG 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 2-7/8" 6.5 / L-80 / EUE 8rd 8,081' MILNE PT UNIT L-17 MILNE POINT KUPARUK RIVER OIL N/A 7,366' 8,695' 7,283' 2,770 N/A 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 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 7/15/2024 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 194-169 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22539-00-00 Hilcorp Alaska LLC C.O. 432E Length Size Proposed Pools: 112' 112' 9.2 / L-80 / EUE 8rd TVD Burst 8,392' MD N/A 5,750psi 7,240psi 3,603' 7,359' 3,632' 8,780' 112' 20" 9-5/8" 7" 3,632' 8,780' Perforation Depth MD (ft): See Schematic See Schematic 3-1/2" 7” x 4” Baker FB-1 Packer and N/A 8,375 MD/ 7,000 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 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 7:45 am, May 20, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.05.20 07:31:58 - 08'00' Taylor Wellman (2143) 324-300 SFD 5/20/2024 DSR-5/20/24 * BOPE test to 3000 psi. Annular to 2500 psi. * Charted and recorded inner casing pressure test to 1900 psi. No AOGCC witness required. 10-404 MGR21MAY24*&:&':IRU-/& Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.05.21 17:32:39 -05'00'05/21/24 RBDMS JSB 052824 Well: MPL-17 PTD: 194-169 API: 50-029-22539-00-00 Well Name:MPL-17 API Number:50-029-22539-00-00 Current Status:Shut-in Producer Rig:ASR #1 Estimated Start Date:7/15/2024 Estimated Duration:5 days Regulatory Contact:Tom Fouts Permit to Drill Number:194-169 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 3,435 psi @ 6,650’ TVD 5/8/2024 | 10.0 PPGE 10.2 KWF Max Potential Surface Pressure: 2,770 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 53° Sail Angle from 7,083’ MD Brief Well Summary: MPU L-17 is a Kuparuk producer drilled in 1995. It received a frac of 65K lbs of 16/20 Carbolite. There was 1 ESP installed from ’96-’99 and it has been shutin since. This well exists in an unsupported fault block on primary depletion. The BHPS indicates the well has returned to original formation pressure and we expect similar results to the original completion. Objectives: Pull failed ESP completion, run test packer then run new ESP completion. Notes Regarding Wellbore Condition: - 7” casing test to 3,500 psi. 2/27/1995 Pre-Rig Procedure (Non Sundried Work) 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 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 10.0# brine water down tubing, taking returns up casing to 500 barrel returns tank. Bullhead down tbg and IA taking returns to formation as needed to establish and maintain a full column of 10.0# brine. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure (Begin Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 10.2 KWF 10.2 - mgr 10.2 - mgr 10.2 ppg brine. - mgr Well: MPL-17 PTD: 194-169 API: 50-029-22539-00-00 3. Test BOPE to 250 psi low/ 3,000 psi high. Test 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. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with 10.0# brine water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out Centrilift for ESP pull. 6. RU spoolers to handle ESP cable. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an 12” x 3-1/2”NSCT. b. 1995 tubing PU weight on Nabors 4ES recorded as 62 kip. Slack off weight recorded as 48 kip. c. 2-7/8” L-80 EUE yield is 144 kip. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8” tubing. a. Send all tubing to be rattled, drifted, and inspected. b. Keep ported discharge head and centralizer for future use. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Recorded Clamp Totals: i. Lasal Clamps: 131 ii. Flatguards clamps = 9 iii. Flat Bands = 52 iv. Preform = 4 10. Lay Down ESP. With 52 bands in the well we will most likely need to make junk basket runs to retrieve the bands. 11. Contingency: RU slickline, pressure test PCE to 250psi low / 3,000psi high. 12. Make Junk Basket runs to the Baker FB-1 Pkr. at 8,375’ CTM. 13. POOH. Repeat until the hole is clean. RD SL. 14. Contingency: If needed, PU 3-1/2” workstring, 7” casing scraper, and muleshoe. RIH to 8,375’ CTM. 15. Circulate well clean. 16. Scrape casing interval from 8,100’ to 8,000’ MD. 17. POOH while filling hole with 2x displacement. 18. PU and RIH with 7” test packer to 8,050’ MD. 19. Test 7” casing to 1,900 psi for 30 minutes. 20. POOH with test packer. 21. RIH with new 2-7/8” 6.5# L-80 ESP completion to +/- 8,080’MD (due to DLS above and below) and obtain string weights. Charted and recorded. - mgr 10.2 - mgr Well: MPL-17 PTD: 194-169 API: 50-029-22539-00-00 a. Check electrical continuity every 1000’. b. Note PU and SO weights on tally. c. Install ESP clamps per Baker, and cross coupling clamps every other joint d. Photograph vent packer prior to running in hole. 22. PU and MU Viking packer with Gen 2 -1.31” Vent Valves. Verify that there are six (6) setting shear pins and confirm with OE number of release shear pins. Target release pins to shear at 18,900 pounds overpull. Nom. (OD)Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 ~8,080’ MD 4.5 2 Intake Sensor 30 5.62 34 Motor 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 8 Gas Separator 52 5.38 10 GINPSH 45 5.38 ~57 Pump 45 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 2-7/8” XN-nipple 2.313" / 2.205" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" ~6,085 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 2-7/8” X-nipple with RHC profile 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 31 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 31 2-7/8" EUE 8rd Jt 6.5 L-80 30 Packer, Viking ESP Retr. Dual Vent ~1,750 MD 2-7/8" 30 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 Well: MPL-17 PTD: 194-169 API: 50-029-22539-00-00 2-7/8" ~1,550 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 23. Terminate the ESP cable and make up the ESP penetrator to the ESP cable. Ensure the 3/8” NPT control line feed thru port is dummied off. 24. Make up the control line to the dual vent valves. Pressure up on the control line to 5,000 psi and hold for 5 minutes checking for leaks (note the opening pressure in the daily report). Bleed the pressure to 500 psi and maintain 500 psi while running in hole. a. Periodically confirm control line is maintaining 500 psi. 25. Continue running ESP completion per plan. 26. PU and MU the 2-7/8” tubing hanger. Make final splice of the ESP cable to the penetrator. MU the control line to the tubing hanger and dummy off any additional control line ports if present. 27. Land tubing hanger, avoiding any damage to ESP cable or control line. RILDS. Lay down landing joint. Note PU and SO weights on tally and in daily report. 28. Drop ball and rod. 29. Pressure up on tubing to 4,000 psi and hold for 15 minutes to set the ESP packer. 30. Bleed tubing to 0 psi. 31. Pressure up on tubing to 4,000 psi and hold for 5 more minutes and then bleed to 0 psi. 32. Bleed packer control line to 0 psi, closing packer vent valves. 33. Slowly pressure up IA at 50 psi/min to 1,500 psi and hold for 30 minutes. Chart test. 34. Lay down landing joint. 35. Set BPV. 36. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Slickline: 1. RU slickline, pressure test PCE to 250psi low / 3,000psi high. 2. Pull ball and rod. 3. Pull RHC profile. 4. Pull DGLV and set GLSOV in upper GLM at ~200’ MD. 5. RDMO. Well: MPL-17 PTD: 194-169 API: 50-029-22539-00-00 Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Double BOPE Schematic Hilcorp Alaska LLC 0 _____________________________________________________________________________________ Revised By: TDF 5/14/2024 PROPOSED Milne Point Unit Well: MP L-17 Last Completed: 8/17/1995 PTD: 194-169 TD = 8,780’(MD) / TD = 7,366’(TVD) Orig. KB Elev.: 50.00’MSL 7” 3 6 8 11 & 12 9-5/8” 1 PBTD =8,695’ (MD) / PBTD = 7,283’(TVD) 4 2 14 15 20” 9 13 10 7 5 16 + 17 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / NT80LHE N/A Surface 112' N/A 9-5/8" Surface 40 / L-80 / BTC 8.679 Surface 3,632’ 0.0758 7" Production 26 / NT-80S / NSCC 6.276 Surface 8,780’ 0.0371 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 8,081’ 0.0058 3-1/2” Tubing 9.2 / L-80 / EUE 8rd 2.992 8,375’ 8,392’ 0.0087 JEWELRY DETAIL No Depth Item 1 ±XXX’STA #4: 2-7/8 X 1'' G, DV Installed 2 ±X,XXX’STA #3: 2-7/8 X 1'' G, DV Installed 3 ±X,XXX’ Packer, Viking ESP Retr. Dual Vent 4 ±X,XXX’STA #2: 2-7/8 X 1'' G, DV Installed 5 ±X,XXX’ 2-7/8” X-Nipple with RHC profile 6 ±X,XXX’STA #1: 2-7/8 X 1'' G, DV Installed 7 ±X,XXX’ 2-7/8” XN-nipple 2.313" / 2.205" No-Go 8 ±X,XXX’ Ported Discharge Head 9 ±X,XXX’ Pump 10 ±X,XXX’ GINPSH 11 ±X,XXX’ Gas Separator 12 ±X,XXX’ Upper Tandem Seal 13 ±X,XXX’ Lower Tandem Seal 14 ±X,XXX’ Motor 15 ±X,XXX’ Intake Sensor w/ Centralizer: Bottom @ ±X,XXX’ 16 8,375’ CTM 7” x 4” Baker FB-1 Packer 17 8,385’ CTM HES 2.813” XN-Nipple w/ 2.75” No-Go. 18 8,390’ WLEG: Btm @ 8,392’ OPEN HOLE / CEMENT DETAIL 20” 260 sx of Arcticset in 30” Hole 9-5/8" 710 sx PF ‘E’ / 250 sx Class “G” in 12-1/4” Hole 7” 244 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ Max Hole Angle = 58 deg. @ 7,800’ MD Hole Angle through perforations = 53 deg. Max Dog Leg 4.65 deg. @1,407’ MD TREE & WELLHEAD Tree 3-1/8”- 5M WKM Wellhead 13-3/8” FMC Actuator Baker CAC Model “M” Tbg. Hng. 12” x 3.5” NSCT GENERAL WELL INFO API: 50-029-22539-00-00 Drilled, Cased & Completed by Nabors 4ES – 8/16/1995 FRAC DETAIL Frac’d ‘B’ Sands w/ 65,000 # 16/20 Carbolite Behind Pipe PERFORATION DETAIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status B Silt 8,426’ 8,458’ 7,050’ 7,077’ 32 1995 Open 8,430’ 8,462’ 7,048’ 7,075’ 27 1995 Open Ref. Log: AWS GR/CCL 4/2/1995. 3-3/8” Dia. Guns @ 6spf, 22gm. Jumbo Jet, EHD=0.76”, TTP=6.4”, 60 Deg. Phasing Milne Point ASR Rig 1 BOPE 2023 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR 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. 17~"/~ 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:~ Dianna TO RE-SCAN Notes: Vincent Nathan Lowell Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si . • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 " "� �' 1 Mr. Tom Maunder vo9 Alaska Oil and Gas Conservation Commission \ I — 1 333 West 7 Avenue V Anchorage, Alaska 99501 �� Subject: Corrosion Inhibitor Treatments of MPL -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPL -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPL -Pad Date: 10/08/11 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 MPL -01A 2030640 50029210680100 Sealed conductor N/A N/A WA N/A NA MPL -02A 2091470 50029219980100 Sealed conductor N/A WA N/A N/A NA MPL -03 1900070 50029219990000 Tanko conductor N/A N/A N/A N/A NA MPL-04 1900380 50029220290000 Sealed conductor N/A N/A N/A N/A NA MPL -05 1900390 50029220300000 Sealed conductor N/A N/A WA N/A NA MPL -06 1900100 50029220030000 Sealed conductor N/A N/A N/A WA NA MPL -07 1900370 50029220280000 Sealed conductor N/A WA N/A WA NA MPL -08 1901000 50029220740000 Sealed conductor N/A WA N/A WA NA MPL -09 1901010 50029220750000 Sealed conductor N/A WA N/A WA NA MPL -10 1901020 50029220760000 Sealed conductor WA WA WA WA NA MPL -11 1930130 50029223360000 Sealed conductor N/A N/A WA N/A NA MPL -12 1930110 50029223340000 Sealed conductor N/A WA N/A N/A NA MPL -13 1930120 50029223350000 Sealed conductor N/A WA N/A WA NA MPL -14 1940680 50029224790000 Sealed conductor N/A N/A WA N/A NA MPL -15 1940620 50029224730000 3.3 N/A 3.3 N/A 15.3 8/9/2011 MPL -16A 1990900 50029225660100 23 Needs top job ---,IN. MPL -17 1941690 50029225390000 0.2 N/A 0.2 N/A 5.1 9/1/2011 MPL -20 1971360 50029227900000 0.4 N/A 0.4 WA 3.4 8/10/2011 MPL -21 1951910 50029226290000 1.7 N/A 1.7 WA 8.5 8/10/2011 MPL -24 1950700 50029225600000 0.2 N/A 0.2 WA 8.5 10/8/2011 MPL -25 1951800 50029226210000 1.7 N/A 1.7 N/A 15.3 8/10/2011 MPL -28A 1982470 50029228590100 0.3 WA 0.3 N/A 8.5 10/8/2011 MPL -29 1950090 50029225430000 0.5 WA 0.5 N/A 3.4 8/7/2011 MPL -32 1970650 50029227580000 0.5 WA 0.5 N/A 5.1 8/10/2011 MPL -33 1971050 50029227740000 0.2 WA 0.2 WA 8.5 10/8/2011 MPL -34 1970800 50029227660000 1.7 N/A 1.7 N/A 8.5 8/9/2011 MPL -35A 2011090 50029227680100 0.2 N/A 0.2 WA 8.5 10/8/2011 MPL -36 1971480 50029227940000 0.1 N/A 0.1 N/A 7.6 9/1/2011 MPL -37A 1980560 50029228640100 6 N/A 6 N/A 47.6 8/13/2011 MPL-39 1971280 50029227860000 1.7 N/A 1.7 WA 6.8 8/8/2011 MPL-40 1980100 50029228550000 1 N/A 1 N/A 6.8 8/8/2011 MPL -42 1980180 50029228620000 5.3 N/A 5.3 WA 30.6 8/14/2011 MPL -43 2032240 50029231900000 17.5 Needs top job MPL-45 1981690 50029229130000 10 N/A 10 N/A 8.5 8/10/2011 ANNULAR INJECTION DATA ENTRY SCREEN Cumulative Data Asset Milo.e. .......................................... Rig Name ~,ZJ~ .......................................... Inj Well Name M..P..~:.IZ ..................................... Sur Csg Dep ~.5.0.~. ................ Legal Desc ;~.6..4.8.'.bI~.L~.I.Q0.'.W.F,,I,...~;.e.~;,.Q;~,.T..I.~{~.~..1.[ ..................................... Research Permit Start Permit End · ........ .4.-..1.~:~Z. ....... Rig CompletionFormation IntermittantFinal Well Total Mud/Ctg Wash Fluids Fluids FreeZe Freeze ........ .t~.,~.o.~ ................ .t~,.~.~.~. ................... ~.~. .................................................................................. ~.~-~ ...................... .to.~ ........... Daily Data Mud, Ctgs, e, rr~ I i ~~ Fr~ - MPK-25 03/15/96 MPK-25 03/20/96 175 225 400 MPK-25 03/21/96 1,273 1,273 MPK-25 03/22/96 .... 300 --- 300 MPK-25 03/23/96 80 80 MPK-25 03/24/96 70 70 M P K-38 03/25/96 150 150 M P K-38 03/29/96 198 198 MPK.3~.. . 03/30/96 155 ...... 155 - MPK-38 03/31/96 250 10 260 MPK-38 04/01/96 320 320 MPK-38 04/02/96 185 185 MPK-38 04/03/96 335 10 345 ............................................................................................................. MPK-38 04/04/96 400 400 MPK-38 04/06/96 0 0 MPK-38 04/07/96 0 0 MPK-38 04/08/96 150 150 M P K-38 04/09/96 1,373 1,373 MPK-38 04/11/96 260 20 280 MP K-38 04/12/96 49~J ~ ,-,u / MPK-38 04/13/96 20 20 MPK-38 04/14/96 135 10 145 MPK-38 04/15/96 140 20 160 "MPK-38 04/16/96 50 70 120 60 10 100 MPK-37 04/23/96 30 'MPK-37 !04/24/96 MPK-37 04/25/96 MPK-37 04/26/96 MPK-37 04/27/96 MPK-37 104/28/96 50 MPK-37 1,240 10 · 300 10 200 10 700 10 20 MPK-37 04/29/96 350 04/30/96 1,000 60 1,250 310 210 710 70 ................. 350 1,060 MPK-02 05/04/96 350 350 · ~rl~i~:~ .................. I'~6~ .......... 1~-~'~ ...................... 1 ............................... l ................. ] .................... l"~'b- ................. 1 ....................... I'~ .................... MPK-02 05/07/96 280 10 290 M~K-02 05/08/96 520 10 530 ~K-02 05/09/96 522 20 542 221 1.5 BPM @ 700 PSI ~.- 1.5 BPM @ 700 PSI ~- 1.5 BPM @ 700 PSI 1.5 bpm @ 700 PSI 3 BPM @ 800 PSI ;~ 3 BPM @ 800 PSI 70 bbls of the 950 was returned ce~ 1.5 BPM @ 700 PSI 1.5 BPM @ 700 PSI 10 231 MPK-02 05/10/96 VIPK-02 05/11/96 '335 MPK-02 05/12/96 925 MPK-02 05/13/96 625 335 925 100 725 Open ,3 BPM @ 750 PSI d rvloes rilling December 14, 1998 900 East Benson Boulevard, MB 8-1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 RECEIVED Re: Annular Disposal Information Request Dear Ms. Mahan: DEC 14 1998 Alaska 0il & Gas Cons. Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular Disposal Records from July 25, 1995 through present time. We compared your list with our records and are able to provide you with the following data: · Individual Annular Disposal Logs from the SSD database which coincide with the approved wells on your attached AOGCC Annular Log. TheSSD records are provided to you in the same order as listed on your log. · There were some wells on your list which were not injected into. These wells are identified aS follows: · Endicott wells 1-03/P-16, 1-65/N-25, 1-59/0-24 · :Exploration well Pete's Wicked #1 · Milne Point wells E-22, E-23, F-O1, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & K-05, K-02, H-07, K-25, K-37, E-17, F-21, K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F-49i, K-18 · PBU Wells E-38, 18-34, 15-42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because the waste materials generated from these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarifY this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disposal. · The wells listed above in BOLD were not permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSDprocedure to be permitted with a Sundry Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. We also provide ~you with a cumulative report from our database of records from July 25, 1995 through the present. FrOm those records, we show the following wells not listed on your report were used for annular disposal: NOV ! g 2002 ,..-Annular Disposal Letter -', 12/14/98 * Endicott wells i-23/o-15, 1-61/Q-20, 2-40/S-22 · Exploration well Sourdough #3 - 3~, -o o ~ " · ~vnme ~'oint wells F-06 H- , - · , rr~u wells 18-30, 18-31, mmvmum ~ogs are provided to yi3u t'~1~ the~ ~ogs~ ~e~l S-33- · Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these recordS. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace _ HSE Manager (w/out attachments) ~CANNED NOV ! ~ 20D2 RECEIVED ]4 1998 ~aska Oil & ~as Cons. Commission Anchorage l, ~ar(~d SerVice Drilling Indl'ar Injection Volumes ~ly 25, 199~ until December 1998 Imulative Report Surface ,. Casing ' ' 'lnj Well Depth Legal Desc Cum Mud Cum Rig Cum Total & Ctgs Wash Jicott 'on 15 Sec. 36, T12N, R16E ., 'on 15 2020'FNL, 2087'FEW, SEC.36,T 12N, R 16E 'on 15 1-19/I-18 5000 1-23/O-15 4246 1-33/M-23 5013 3217'NSL, 2114'WEL, Sec 36,T12N, R16E 'on 15 1-61/Q-20 4236 3075'NSL, 2207'WEL, Sec 13,T12N, R16E 25,228 , 8,960 7,848 992 32,084 30,604 1,160 9,879 9,729 150 2!.~379 . Cum Compl Cum Form Cumlnterm Cum Final Disposal Period Annulus Fluids Fluids ..Frgeze Freeze Start E~nd Slatus 120 12/5/95 12/5/96 Open 200 120 9/30/95 12/31/95 Open 8/31/95 12/31/95 Broached on 15 2-40/S-22 4531 2020'FNL 2289'FEL Sec 36 T12N R16E 31 195 29 952 1 063 120 60 7/25/95 12/31/95 Open ............ . '. .......................... '. ............. ! ........ ~ ', ....................... ~ ........................... '. on 14 15-47 3515 3648'NSL, 4956'WEL, Sec22,T11N, R14E 3,002 903 2,009 90 11/7/95 12/31/95 . Open on 14 DS 15-45 3829 4749' NSL, 5180' WEL, Sec. 22, T11N, 1,882 1,697 134 51 4/4/96 4/4/97 Broached on 14 DS 15-48 3548 Sec. 22, T11N, R14E 3,385 216 820 2,283 66 12/21/95 12/21/96 Open on 14 DS 15-49 3667 4676' NSL, 5165' WEL, Sec. 22, T11N, 4,669 1,559 1,141 1,904 65 2/21/96 2/21/97 Open on 9 18-30 3930 1499'SNL, 26'WEL, Sec 24,T11N, R14E 2,266 936 380 800 150 7/25/95 12/31/95 Open ~..,..? .................................. !..~.-..3...! ................................... 3? ................................. ~3~7.?~N~.s~.~.~4.~w..~.E~L.~.~s~t%~T.~!~1.N.~.R..~!~..4..~ ........................................ ~.,,.~ .................................. .2.?.0 ........................... !d.o.._o.. ............................. ~¢??.. ...................................................................................................................... !..7,..! ................ ~!~E~ ......................... !.~?./.9.~. ..................... ~P...tn. ................. 3n 9 18-32 3830 3632'NSL, 41'WEL, Sec 24,T11N, R14E 3,311 1,861 200 1,100 150 8/24/95 12/31/95 Open 3n 9 18-33 4140 3690'NSL, 56'WEL, Sec.24,T11N, R14E 5,215 2,050 3,035 10 120 9/28/95 12/31/95 Open ors 18E 12-35 3543 348'NSL, 705'WEL, Sec 18,T10N, R14E 3,723 3,436 137 150 9/1/95 12/31/95 Open 3rs 18E 12-36 3452 63'FSL, 899'FEL, Sec 18,T10N, R15E 4,002 1,961 50 1,871 120 10/13/95 12/31/95 Open ?,.,r..s,..?..8..~ ...................... !..3.,-,.3...6., ........................................ ~.3,,.! ................................. 1_5..8_5_ '_N...S.L..,_5_ 1 .~ 7_i~.E_. ,L,.,_ .S,,?_.1_3.,. _T.1..0N.**R14..E- .......................... .4..1,,_3,.7._ ................... _.3.,._5..23__ .......... __4__6.4__ ............................................. .150 10/26/95 12/31/95 Open ~rs 18E 14-44 3288 2829'NSL, 1617'WEL, Sec 9,T10N, R14E 3,974 2,319 1,535 120 8/17/95 12/31/95 Open Ioration 4 Sourdough ¢¢3 4236 2245'FSL, 5067' FEL, Sec. 29, T9N, R24E 5,786 4,630 1,156 1/26/96 1/26/97 Closed e -- MPK-17 3508 3648'NSL,2100'WEL, Sec.03,T12NR11E 19,608 18,538 285 685 100 4/18/96 4/18/97 . Open )rs 22E MPC-23 4941 1038 NSL, 2404 WEL, Sec 10,T13N, 2,060 1,800 130 130 1/25/96 1/25/97 Open )rs 22E MPC-25 8595 1143'FNL, 2436'FWL, Sec 10,T13N, R10E 1,905 1,465 300 140 1/5/96 1/5/97 Open )rs 22E MPC-26 4704 1086 NSL, 2419 WEL, Sec 10,T13N, 5,228 4,483 555 190 12/19/95 12/19/96 Open )rs 22E MPC-28 5405 Sec 10,T13N, R10E 425 350 75 2/15/96 2/15/97 Open Page 1 NOV _'! 'g 200 =ha..r,,~d oervice Drilling ~.nn~l'ar Injection Volumes luly 25, 199'$ until December 1998 ;umulative Report Sudace Casing lig Inj Well Depth labors 22E MPF-06 8766 'abors 22E MPF-14 6690 ..... , abors 22E MPF-70 7919 abors 22E MPH-05 5335 Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Lega! Desc Cum Total & Ctgs Wash Fluids Fluids Freeze .... Ereeze Start End. Status Sec 06,T13N, R10E 1,927 1,731. 196 1/25/96 1/25/97 Open Sec 06,T13N, R10E UM 18,717 17,107 1,270 340' 6/3/96 6/3/97 Open 21,89'NSL, 2591'WEL, Sec 6,T13N, R10E 19,775 18,794 735 , 190 56 6/17/96 6/17/97 Open 2882'NSL, 4028'WEL, Sec 34,T13N, R10E 8,283 7,711 382 190 8/19/95 12/31/95 Open abors 22E MPH-06 7304 2824'NSL, 4044'WEL, Sec 34,T13N, R10E 8,515 8,335 180 8/5/95 12/31/95 Open abors 22E MPI-07 2680 2339'NSL, 3906'WEL, Sec 33,T13N, R10E 1,680 1,280 250 80 70 9/21/95 . 12/31/95 ,Open abors 22E MPJ-13 2835 2319'NSL, 3179'WEL, Sec 28,T13N, R10E 14,127 13,292 645 60 130 10/17/95 12/31/95 Open abors 22E MPJ-16 3112 2317'NSL, 3336'WEL, Sec 28,T13N, R10E 985 915 70 11/12/95 12/31/95 Open abors 27E B-24 4080 Sec 18,T13N, R11E UM 1,468 1,396 72 , 1/25/96 1/25/97 Open abors 27E MPF-22 8841 Sec 06,T13N, R10E UM 6,536 6,466 70 12/12/95 12/12/96 Open abors 27E MPF-25 3405 1857'NSL 2696'WEL, Sec 6,T13N, R10E ' 9,897 9,357 250 , 225 65 12/26/95 12/26/96 Open ~bors 27E MPF-37 6621 1931'NSL 2643'WEL, Sec 6,T13N, R10E 7,032 6,887 70 75 7/25/95 12/31/95 Open ~bors 27E MPF-38 8561 1994'NSL 2731'WEL, Sec 6,T13N, R10E 9,232 9,157 75 12/6/95 12/31/95 Open ~bors 27E MPF-45 6678 1979'NSL, 2608'WEL, Sec 6,T13N, R10E 17,562 17,381 181 7/31/95' 12/31/95 ' Open ~bors 27E MPF'53 6750 2028'NSL 2572'WEL, Sec 6,T13N, R10E 6,051 5,671 165 75 60 80 8/19/95 12/31/95 Open ~bors 2~E MPF.61 6585 2077'NSL 526'WEL Sec 31,T14N, R10E 5,732 5,657 75' 8/31/95 12/31/95 Open ~bors 27E MPF-62 6059 2141'NSL 2627'WEL, Sec 6,T13N, R10E 386 316 70 10/13/95 12/31/95 Open ~bors 27E MPF-69 5772 2125'NSL, 2502'WEL, Sec 6,T13N, R10E 9,740 91665 . 75 8/31/95 12/31/95 Open ~bors 27E MPF-78 7085 2237'NSL 2555'WEL, Sec 6,T13N, R10E 8,476 7,456 40 775 65 140 9/12/95 12/31/95 Open lbors 27E MPL-24 6515 3654'NSL 5180'WEL, Sec 8,T13N, R10E 6 790 4 900 1,320 165 335 70 11/27/95 12/31/95 Open OA ,E F-33 3570 3332'NSL, 2174'WEL, Sec 2,T11N, R13E 1,468 183 660 465 160 2/21/96 2/21/97 Open E F-36 3691 2642'NSL, 2878'WEL, Sec 2,T11N, R13E 6,963 ' 1,998 1,359 3,471 135 12/18/95 12/18/96 Open )yon 9 D-30 3456' 3625' NSL, 1066' WEL, SEC. 23, T11 N, 5,261 2,811 1,275 1,035 140 1/31/96 1/31/97 Open ~yon 9 D-31 3215 SEC. 26, T11N, R13E 150 150 4/20/96 4/10/97 Open ~yon 9 D-33 3222 2965' NSL, 1067' WEL, SEC. 23, T11N, 4,661 2,425 2,106 130 2/21/96 2/21/97 Open ~bors 18E S-43 3121' 4211 'NSL,4503'WEL,SEC35,T12N,R12E 5,943 2,636 1,716 1,511 80 5/7/97 5/7/98 OPEN SCANNED NOV Page 2 Shared Se'i;~ice Dr, illing ~,nn~ii~'r injection Volumes July 25, 1995. until December 1998 ;umulative Report surface casing lig Inj Well . Depth labors 28E B-33 3504' · labors 28E E-34 3664 · labors 28E E-36 3648 Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Legal Desc .. CU.m Tot~! & Ctgs Wash Fluids. Fluids Fregze Freeze Start End Sta!us 969'SNL 1898'EWL, Sec 31, T11N, R14E 3,974 2,842 857 195 80 5/1/96 12/31/96 Broached : 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 7,228 1,420 858 40 110 8/23/95 12/31/95 Open 1706'SNL 822'WEL, Sec6,TllN, R14E 9,271 4,417 1,293 3,096 365 100 7/25/95 12/31/95 Open labors 28E E-37 3810 3391'NSL, 881'WEL, Sec 6,T11N, R14E 4,695 4,241 374 . 80 9/16/95 12/31/95 Open 'abors 28E E~39 . 3638 3358'NSL, 501'WEL, Sec 6,3'11N, R14E 2,250 928 220 1,022 80 8/28/95 12/31/95 Open ab0rs 28E G-O4A 3509 2917'NSL, 1974'WEL, Sec 12,T11N, R13E 5,937 1,798 1,824 2,315 10/20/95 12/31/95 Open a..b(~r.s .28..~ ............. ?..~.! ............................. .3...5.(~.9 ...................... ~ 9.1.. !..'.~...S...L,....2..3.6....8.1...W...E. I~,.....S.e..c,....!?.~..T.1....! ~.t.R.!...4..E. .......................... !_!..,...4.3.? ................................. .3..,..9....5...6. .......................... ~.Q.~ ............................. ~,.~.7.0. .7....0. ....................................... '_6.?. ............... ~!8! .9..~... .................. !.~!.3]?.5' ......................... ..0..p....e? ................. abors 28E S-24 2750 1633'SNL 4228'WEL Sec 35 T12N R12E 20 261 11 773 2 i77 5 751 275 285 12/9/95 12/9/96 Open :....... ,. ............................ ! ................... ,. ........................................................... .'. ................................................ ,. .............................. , .......................................... ~ : .................................................. abors 28E S-33 2958 1639'SNL, 1487'WEL, Sec 35,T12N, R12E 18,014 6,613 2,431 8,392 270 308 12/1/95 12/1/96 Open abors 28E S-41 3331 4152' NSL 4504' WEL Sec 35 T12N 8 062 4 159 2 034 1 754 115 2/8/96 2/8/97 Open ........................... ; , ............................................. ,. ............................... ~ ................. ~ ...................................................... .'. ................................................... ,. .......................................... .'. ................................................... ~ ................................................................................................................................................................................................................................................................... abors ........................ 28E S-42 30.77 ................ .S. ~c..35, T. 12N.,. R_.!..2...E' ................................................................................................ !...6..8_ .................................... 1.....0...0.. ............................................................................................................................................................................................................................................................................................................................................................................................... 88 3/13/96 3/13i97 Open abors 2ES H-35 3157 4535'NSL 1266'WEL Sec 21 T11N R13E 4 860 3 725 555 480 20 80 10/26/95 12/31/95 Open abors 2ES H-36 3550 4478'NSL 1265'WEL, Sec 21,TllN, R13E 1,452 857 100 410 85 10/26/95 12/31/95 Open Page 3 o w-.. leos r:J!JJng TO: FROM: DATE: SUBJECT: APl # Blair Wondzell Chris West October 27, 1995 MPB-24 Well Suspension 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose setting three plugs in this well as detailed in the attaChed form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8" x 7" annulus available for the injection of liquid 'wastes. There are no other well annulii on this pad for injection. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call me if I may be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 NOV Milne Point 2001 Shut in Wells Date Reason for Future Utility Plans & Sw Name Shut-in Well Shut-in ~ Current Mechanical Condition of Well2 Possibilities3 Comments M'~B-07 ' Jul-97 A No known problems ' I High GOR well, Facilities can not handle gas. Possible production after gas expansi, on project. MPB-08 May-94 E No known problems 3 Futher use as an injector n. ot required MPB-13 Jan-86 B GL well that was shut in due to high 3 We#house and towlines removed water cut. Possible channel into water zone. MPB-17 Jan-96 E No mechanical problems. Quick 3 ' We#house and towlines removed communication with producer .. . MPB-19 Jul-91 B GL well. High water cut producer. 3 Wellhouse and towlines removed Possible frac into water zone MPC-11 Feb-96 E No known problems 3 Further use as an injector not required while associated producer shut-in MPC-12/ Jan-O0 E Fish in h°le, drilling problems 3 SuSpended due to drilling problems. 12a MPC-16 Aug-93 A ~High GOR well, p'erfs and completion 3 We#house and towlines ~emoved abandoned MPC-17 May-O0 D Leak in 9 5/8" CaSing to surface I Evaluating possible plans for solution'to iproblem. MPC-20 Apr-O0 B High water cut well, no mechanical I Evaluating possible plans for solution t° problems . problem. ~Mpc-21 Feb-02 D Problems with Jet pUmp Completion I Evaluating possible plans for solute'on to problem.. MPD-01 Dec.90 C Dead ESP completion, no support to I Evaluating pos~lbl'e plans for solution to block problem. Possible alternative uses for we#bore MPD-02/ Aug-99 B Dead ESP completion, very high water I Evaluating possible p'lans. 02a cut well MPE-02 Jun-OS. C i No known problems 2 ReComplete to upper Kup zone MPE-19 Aug-99 C ,Failed ESP on tubing string 2 Well brought on line in 2002 MPL-01 Feb.O0 B High water cut well, no mechanical I Evaluating possible plans iproblems dead ESP in hole ..... MPL-IO Feb-99 E No proof that is supports other wells I Evaluating side track posSibilities . MPL~tX i~-i-~ Apr-O0 B No menchanical problems, dead ESP I Evaluating side track possibilities MPL-21 "0ct,98 :E ' -High-pressurebiock - ~$O00psi, no I Possible use fo'r inJe~tion when pressure support needed for producers ,lowers MPL-37a Nov-99 C Dead ESP, no other mechanical I i Evaluating possible side track plans or issuses recompletions MPL-39 Jan-99 E Could not inject gas into Well, no use I Evaluating possible side track ~lans or for it. recompletions . .. , , , *Note - Wells were shut in 100% during 2001 SCANhlE Milne Pt Shut in Wells 2001.xls MEMORANDUM TO: THRU' State of Alaska Alaska Oil and Gas Conservation Commission .'v' Julie Heusser, ~'X~ DATE: March 27, 2001 Commissioner ~' Tom Maunder, ~-~~ P. I. Supervisor /~ o~lcr~-~ FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit BPX / F-Pad March 27,, 20...01' i traveled to BPX's F-Pad in the Prudhoe Bay Field to witness Safety Valve System tests. Merv Liddelow, BPX representative in charge of testing, performed the tests in a safe and proficient manner. Of the 24 wells tested, 13 failures were witnessed. Wells F-01 and F-15 were shut in pending repairs. Mr. Liddelow indicated to me that all other failures had been corrected and successfully re-tested within 24 hours. The AOGCC test report is attached for reference. I conducted 24 well house inspections concurrent with the SVS tests, with no exceptions noted. .SUMMARY; I witnessed SVS tests and conducted well house inspections on BPX's F-Pad in the Prudh°e Bay Field. 24 wells, 48 components tested. 13 failures. 27.08% failure rate. 24 well house inspections conducted. Attac. hments' SVS PBU F Pad 3-27-01 JJ .0C: NON-CONFIDENTIAL · . . SVS PBU F Pad 3-27-01 JJ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Unit/Pad: PBF/PBU/F-Pad Separator psi: LPS 153 Date: 3/27/01 HPS 650 Weft Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE F-01 1700460 650 550 490 P 5 OIL I 1 F-02 1700560 650 550 530 P P OIL F-03 1700580 , F-04 1710020 F-05 17i06bO 650 550" 530 'i ~ 0IL F'06 '17i0120 ~' ' F-07 1720230 F208 1740110" ' F-°9 'i790760 650" 550' 540~ P 4 ' ' ' OIL F-10A 2000670 F-11A' 2000620, 6~0 55'0 5'i0 e 4 '' OIL F'12 '17910~6 650 ' "550 ~30 P P " Oi~ F-13A 1961520 650 550 530 P 4 OIL . F-14 1800120: F-15 1811300 650 550 480 3 P OIL F-i'6A i9~1'600 " 650: 550 410 P P OIL F~17A '.'. Y 1941630 153 125 130 P P ..... OiL F-19 1811060 F-21 "' 1890560 153" 125 i15' P 'P OIL F-22 '18~0620 "'650 550 0 2 P OIL F-23A 19~0~40 153 125'' 0! 2 P ..... OIL F-24 1831540 F_56A' -' 1981'890 ..... F-27 i8616~0 ' " F-28 1861590 _ F-29 1861330 F-30 1891100 F'31 18~1570 650 550 '0 2 " P ' " OIL F-32 '1890330 650 550 550 P ~ P "' OIL F-33 196003'0 ..... F-34A 1961090 F-35 1880810 650 550 480 P "P ' OiL F-36 ,I 195 i 9~) 153 125 0 2 P OIL F-37 189099.0 650 550 530' P P ' OIL , RJF 1/16/01 Page 1 of 2 SVS PBU F Pad 3-27-01 JJ1 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI, PSI ,Trip Code ., .Code Code Pass, ed GASorC¥C,L.E F-38 1901350 F'-39 1901410 153 125 115 P P OIL F-40 1911170 650 550 550 P P OIL F-41 1911040' 650 550 490 P P OIL F-42 1901580 650 550 530i ' P P OIL i~'-43 1'9i0750 " 153 125 0 1 P ...... OIL F-44 1910080 .... F-45 19102~'0 ..... F-46 1901780 650 550 440 3 P " OIL F-47A ' 20'00~50 F-48 1910860 , , , , ,, ,, , ,, Wells: 24 Components: 48 Failures: 13 Failure Rate: 27.08°/I~! 90 Day Remarks: F-1, F-15 shut-in, operator reports that all other failures repaired and passed retest. RJF 1/16/01 Page 2 0£2 SVS PBU F Pad 3-27-01 JJ1 01' OR BEFORE W MEMORANDUM State of Alaska TO: THRU: Alaska Oil and Gas Conservation Commission. Julia Heusser, ~ DATE: December 22, 2000 Commissioner Tom Maunder, P. I. Supervisor FROM: John Crisp, Petroleum Inspector SUBJECT: Safety Valve Tests Milne Point Field L Pad December 22, 2000: I traveled to BPX's Milne Point Field L Pad to witness Safety Valve System tests. I conducted wellhouse inspections during SVS tests. Larry Niles was BP rep. in charge of SVS testing. As usual, Larry was ready to begin testing as soon as I arrived on location. Wellhouses on L Pad are heated & have lights, this makes for safe working conditions & minimal SVS failures. Wellhouses are clean'& in good condition. The AOGCC test report is attached for SVS failure reference. ~ SUMMARY: I traveled to BPX MPU L Pad for SVS tests. 20 wells, 40 components tested. 1 Failure witnessed. 2.5% failure rate. 20 wellhouses inspected. No failures to report. Attachments: SVS MPU L pad 12-22-00jc cc; NON-CONFIDENTIAL i SVS MPU L Pad 12-22-OOjc.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: John Crisp Submitted By: John Crisp Field/Unit/Pad: PBU MPU L Pad Separator psi: LPS 140 Date: 12/22/00 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE II I L-01 1840050 L-02 1900060 140 100 90 P P OIL ,, L-03 1900070 L-04 1900380 140~ 100 105 P P OIL L-05 1900390 140 100. 100 P P OIL L-06 1900100 140 100 100 P P OIL L-07 1900370 140 100 100 P P OIL L-08 1901000 4000 2000 1950 e e WAG. L-09 1901010 L-11 1930130 140 100 115 P P OIL L-12 1930110 140 100 100 P P OIL L-13 1930120 140 100 100 P P OIL L-14 1940680 140 100 95 P P OIL L-15 1940~20 L-16A 1990900 L-17 1941690 L-20 1971360 140 100 100 P P OIL L-25 1951800 140 100 105 P P OIL L-28A 1982d70 140 100 110 P P OIL L-29 1950090 140 100 95 P P OIL L-32 1970650 140 100 100 P P OIL L-33 1971050 L-35 1970920 140 100 105 P P OIL L-36 1971480 140 100~ 105 P P OIL L-37A 1980560 L-40 1980100 140 100 106 P P V-~\~-~¥~\'~ OIL L-45 1981690 140 100 105 P P ~ OIL L-34 1970800 4000 2000 1900 P 4 WAG Wells: 20 Components: 40 Failures: 1 Failure Rate: 2.5% [390 Day Remarks: 12/26/00 Page 1 of 2 SVS MPU L Pad 12-22-00jc.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 12/26/00 Page 2 of 2 SVS MPU L Pad 12-22-00jc.xls D A "i'-A "1" D A T/'-., ..... P L U S 9q.-~ 'J 69 6768 9L~- ..... i69 DGR/CNO/SL.D 9~-'169 DGR/CNO/SLD 9~.-'-~ 'i 69 DGR/EWRq. 94 .... 16©~, DGRi:E~?R4 9Li.--'. 'J 69 -',.:~ k / L,L.. l.../ F."£NAL 9/~ "' I 69 '3 R/' C '::.: L / P E R F 94--" 'i 69 PFC,/F'E RF ~bJ?/3650"- 8788 H D 2-,- 3 .-~'~7 ~.~ 00 ...... 8893 1 ~8350~--8540 'i i I)A I" i::.-'. I.;: E C VD ri 8 / 3 [) / .q "'~ I)" 0 8/'., /' 08/30/95 n,, 8/'"~, 0/" 9. b "i? "9!:5 (') *"B. ,,' / 0 !,,_ f" / '//9 ".Cj r.:: () (!; i/ 'l [.; / ..... Ape di"y d 'i t c h s ,F:~ m p i e ,.~ ~,Vas; 1:he we1 i cc.;r"ed? Ar"e wel 1 C C H I'4 E N T S 'in c o rn p i ')' a n c ~s: .......... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION , /ELL COMPLETION OR RECOMP LETION 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. 94-169 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 5o-029-22539 !4. Location of well at surface 9. Unit or Lease Name 3660' NSL, 5055' WEL, SEC. 8, T13N, RIOE ~ ~'"'~;'~ TM ::'~""' .... Mi/ne Point Unit At Top Producing Interval r ,-,~-~- i~~~ ' ~" !i 10. Well Number · !i ~,~.~~i MPL-17 299' NSL, 291' WEL, SEC. 7, T13N, RIOE i ' :¢~'-'/i-*-]r~ i ~ · 11. Field and Pool At Total Depth i,:: ~ ¢~ .~I Milne Point-Kuparuk Sands 164' NSL, 389' WEL, SEC. 7, T13N, RIOE 5. Elevation in feet (indicate KB, DF, etc.) 6. LeaSe Designation and Serial No. KBE = 50' ADL 025509 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 01/17/95 01/29/95 08/17/95[ N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDI 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 8788' MD/7366' TVD 8695' MD/7283' TVD YES [] NO []I N/A feet MD 1800' (Approx.) 22. Type Electric or Other Logs Run GR/CCL, GR/CDR/CDN 23. CASING, LINER AND CEMENTING RECORD SE'I-RNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'Ff'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1¢ NTSOLHE 32' 112' 30" 260 sx Arcticset (Approx.) 9-5/8" 40# L-80 35' 3632' 12-1/4" 710 sx PF "E"/250 sx "G" 7" 26# L-80 35' 8778' 8-1/2" 244 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE .. DEPTH SET (MD) PACKER SET(MD) 3-3/8" Gun Diameter, 6 spf 2-7/8", L-80 8081' N/A MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8426;8458' 7045'-7073' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8430;8462' 7048'-7076' Freeze protect w/82 bbls dieSel Frac 'B' Sand 65000# 16/20 Carbolite behind pipe ~27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 05/15/96 ESP Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water, submit core chips. ORIGINAL Form 10-407 ~'¥ in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. (Subsea) Top Kuparuk D 8242' 6833' Top Kuparuk B 8425' 6993' Top Miluveach 8640' 7183' .. 31. LIST OF A'Ff'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed // .... Title Senior Drilling Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Form 10-407 Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ~LAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MP L-17 BOROUGH: NORTH SLOPE UNIT .' UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 01/17/95 09:00 SPUD: RELEASE: 02/28/95 06:00 OPERATION: DRLG RIG: NABORS 27E WO/C RIG: NABORS 27E 01/17/95 ( 1) TD: 0'( 0) 01/18/95 (2) TD: 1079' (1079) 01/19/95 ( 3) TD: 3040' (1961) 01/20/95 (4) TD: 3650'( 610) RIGGING UP MW: 0.0 VIS: 0 WELD ON FLOW NIPPLE TO RISER. WELD ON PAD EYES FOR ALL LINES ON BRIDGE CRANE INB CELLAR. REPAIR DRAG CHAIN IN PITS. RIG UP TURN BUCKLES ON RISER. REMOVE BROKEN STEAM HEATER F/ CELLAR AREA. INSTALL FLARE LINE F/ CHOKE TO PITS. INSTALL FLL LINES ON STABBING BOARD AND DERRICK BOARD. CHANGE OIL IN ROTARY TABLE. WORK ON IRON ROUGHNECK. WORK ON AIR PURGE DRAWORKS MOTORS AND MUD PUMP MOTORS. PUT 3" BALL VALVES ON WELL HEAD IN CELLAR. RU MOUSE HOLE. CLEAN AND READY COLLAR SLIPS. CLEAN RIG FLOOR AND CELLAR. DRILLING MW: 0.0 VIS: 0 CONTINUE RIGGING UP. ACCEPT RIG @ 0900 HRS ON 17 JAN 1995. FUNCTION TEST DIVERTER SYSTEM. FUNCTION TEST OK. STRAP BHA. RE-INSTALL CUTTINGS TANK AND BERM SAME. PU/MU BHA. ESTABLISH CIRCULATION. WALK THROUGH ON RIG F/ LEAKS. DRILL FROM 228 - 1048' CBU. MAKE WIPER TRIP TO JARS. -- RIH. BREAK CIRC @ 1000'. WASH TO 1048' NO FILL. DRILLING F/ 1048 - 1079' DRILLING MW: 0.0 VIS: 0 DRILL F/ 1079 - 1999'. SURVEY, CBU. TRIP TO 817' RIH TO 1957', WASH TO 1999'. NO PROBLEMS, NO FILL. DRILL TO 2661' ORIENT, SLIDE AND DRILL T0 3040' RUN 9 5/8" CSG MW: 0.0 VIS: 0 DRILLING F/ 3040 - 3072'. CBU. SHORT TRIP TO 1900'. NO PROBLEMS, NO FILL. DRILL F/ 3072 - 3650' CBU. POH TO 817' SLM, NO CORRECTION. RIH TO 3620' WASH TO 3650' -- NO PROBLEMS. CIRC, RECIPROCATE, CONDITION HOLE. PULL CSG TOOLS TO RIG FLOOR. POH. LAY DOWN BHA. DOWN LOAD MWD AND LAY DOWN. RIG UP CSG TOOLS. RUN SHOE JTS. CHECK FLOATS. RUN CSG. : MP L-17 ~PERATION: RIG : NABORS 27E PAGE: 2 01/21/95 ( 5) TD: 3650 PB: 3561 01/22/95 ( 6) TD: 3650 PB: 3561 01/23/95 ( 7) TD: 3865'( 215) 01/24/95 (8) TD: 5428'(1563) 01/25/95 (9) TD: 6099'( 671) NIPPLE UP BOPE MW: 0.0 RUN 9 5/8" CSG. MU HGR AND LANDING JT. BREAK CIRCULATION. ESTABLISH GOOD CIRCULATION RATE. CIRCULATE AND CONDITION. TEST LINES. RELEASE BTM PLUG. RELEASE TOP PLUG. BUMP PLUG. BLEED OFF. CHECK FLOATS. NO CMT TO SURFACE. RIG DOWN CMT HEAD. BLOW DOWN LINES. RIG UP FOR TOP JOB. CIRCULATE HOLE CLEAN. PUMP 100 SACK TOP JOB. LAY DOWN MOUSE HOLE, TURN BUCKLES, LDG JT. CLEAR FLOOR, LAY DOWN CSG TOOLS. ND FLOW LINE RISER, DIVERTER SYSTEM, DRLG NIPPLE AND 20; ANNULAR. NIPPLE UP 10 3/4" SPEED HEAD AND TEST. NIPPLE UP BOPE. PIPE RAMS TOP AND BOTTOM. BLIND/SHEAR MIDDLE. TEST BOPE MW: 0.0 ARRANGE RAMS IN BOP STACK. TIGHTEN RAM DOORS. LINE UP STACK WITH CHOKE LINE. TIGHTEN ALL FLANGES AND CLAMPS. NIPPLE UP RISER HOOK UP FLOW LINE. SET MOUSE HOLE. HOOK UP HYDRAULIC LINES. HOOK UP BLEED OFF & DRAIN LINES. MODIFY TEST JT & RISER. PICK UP STABILIZERS, BIT, SUBS, TEST PLUGS, WEAR RING AND RUNNING TOOL. MODIFY TEST JT. SET TEST PLUG. ATTEMPT TO TEST. DISCOVERED PADDLE MISSING FROM INSIDE MANUAL VALVE ON KILL LINE SIDE. REPAIRED VALVE. WOULD NOT TEST. REPLACED VALVE W/ REBUILTS VALVE. RETEST, THE VALVE THAT WAS REPLACED WOULD NOT TEST. TEST CHOKE MANIFOLD. DRILLING MW: 0.0 VIS: 0 TEST CHOKE MANIFOLD. 1 VALVE FAILED. REPAIR, RETEST. OK. TEST TOP PIPE RAMS. NO TEST. PICK UP KELLY. TEST KELLY VALVES AND SAFETY VALVES. TIW FAILED. REPAIRED AND RETESTED. OK. REPLACED SEALS PISTON SEAL ON TOP RAMS. RETESTED, OK. BLOW DOWN LINES. INSTALL WB. MU BHA #2. CHANGE OUT DC MODULE IN SCR. MU BHA #2. RIH TO 1610'. RIH TO FLOAT COLLAR @3548'. CIRC AND CONDITION MUD. TEST CSG. DRILL FC, 80' CMT, FS, 10' NEW HOLE. CIRCULATE FOR LOT. DRILLING MW: 0.0 VIS: 0 DRLG F/ 3865 - 4558'. CHANGE SHAKER SCREENS TO LARGER MESH. DRILL F/ 4558 - 4653'. CBU. BLOW OUT LINES. SHORT TRIP TO 3540' NO PROBLEMS, NO FILL. DRILL F/ 4653 - 5428' WAIT IN WEATHER MW: 0.0 VIS: 0 DRILL F/ 5428 - 5632'. BLOW DOWN LINE. TRIP AND FILL TANK. BLOWDOWN LINES, MONITOR WELL. POH 15 STANDS. RIH 10 STANDS. MONITOR WELL. BIT @ SHOE. RIH, NO PROBLEMS. NO FILL. DRILL F/ 5632 - 5841'. SHAKERS BLINDING OVER. CHANGE SHAKER SCREENS. DRILL F/ 5979 - 6099' CIRC BOTTOMS UP. MONITOR WELL. POH TO SHOE. : PIP L-17 ~PERATION: RIG : NABORS 27E PAGE: 3 01/26/95 (10) TD: 6730' ( 631) 01/27/95 (11) TD: 8130'(1400) 01/28/95 (12) TD: 8235'( 105) 01/29/95 (13) TD: 8693' ( 458) 01/30/95 (14) TD: 8788' ( 95) DRILLING MW: 0.0 VIS: 0 WAIT ON WEATHER. RIH. FILL PIPE AND BREAK CIRCULATION. DRILL F/ 6099 - 6730'. DRILLING MW: 0.0 VIS: 0 DRILLING F/ 6730 - 7592' DRILLING F/ 7592 - 7686' CIRCULATE F/ SHORT TRIP. SET BACK KELLY. FLOW CHE~K WELL. OK. 11 STAND SHORT TRIP. HOLE VERY CLEAN. DRILLING F/ 7686 - 8130'. DRILLING MW: 0.0 VIS: 0 CBU. PREPARE POH. FLOW CHECK WELL, OK. SET BACK KELLY. POH. FLOW CHECK AT SHOE, OK. POH. FLOW CHECK BEFORE BHA ENTERS STACK, OK. POH TO MWD. DOWNLOAD MWD. GRADE PDC BIT. DECIDE NOT TO ATTEMPT RE-RUN. LD NEYRFOR TURBINE. SERVICE WEAR RING. FUNCTION TEST BOPE. PU BHA #3. CHANGE BATTERIES IN MWD TOOLS. ORIENT MWD/MOTOR. LOAD SOURCES. RIH'TO 849'. INSTALL SAFETY VALVE. SLIP AND CUT DRILLING LINE. RIH. BENCHMARK SURVEY @ 3763', OK. CONTINUE RIH. BREAK CIRC. REAM F/ 8053 - 8130'. DRILLING F/ 8130 - 8235'. SHORT TRIP @ 8693' MW: 0.0 VIS: 0 DRILLING F/ 8235 - 8378'. FLOW CHECK WELL, OK. SHORT TRIP TO 7862'. SMOOTH TRIP. NO PROBLEMS. PRECAUTIONARY WASH 42' TO BOTTOM. CONTINUE DRILL F/ 8378 - 8418'. DRILLING F/ 8408 - 8693' TEST BOPE MW: 0.0 VIS: 0 FLOWCHECK WELL. SHORT TRIP TO 8148' HOLE IN GOOD SHAPE. NO PROBLEMS NO FILL. DRILLING F/ 86~3 - 8788' FLOWCHECK WELL. SHORT TRIP TO 8366'. NO PROBLEMS NO FILL. CIRCULATE HOLE CLEAN. PREPARE POH TO LOG. FLOWCHECK WELL, OK. POH. STRAP OUT OF HOLE. NO CORRECTION. FLOWCHECK WELL AT SHOE AND AT BHA. ATTEMPT DOWNLOAD MWD. NO GO. LD SAME. LD BIT AND MOTOR. CLEAR FLOOR. RU ATLAS WL TO RUN RFT. PU NO PROBLEM. ATTEMPT TO WORK THROUGH AT 5590'. NO GO. PU SMALLER TOOL. WLIH W/ SAME. SET DOWN AGAIN AT 5590'. ATTEMPT TO WORK THROUGH. NO GO. WLOH. RD ATLAS WL. PREPARE TO TEST BOPE. ~L · MP L-17 OPERATION: RIG : NABORS 27E PAGE: 4 01/31/95 (15) TD: 8788' ( 0) 02/01/95 (16) TD: 8788 PB: 7368 02/02/95 (17) TD: 8788'( 02/03/95 (18) TD: 8788'( o) o) LD DP MW: 0.0 VIS: 0 REPAIR BOPE TEST JOINT. COMPLETE TEST BOPE. TEST GOOD. REMOVE TEST PLUG. INSTALL WEAR RING. LD NON MAG BHA. PU STEEL BHA. RIH W/ BHA /34. BREAK CIRC. CONTINUE RIH TO 5554'. MU KELLY. BREAK CIRC AND WORK ACROSS HOLE FROM 5554 - 6097' NOTHING UNUSAUAL WNCOUNTERED IN THIS -- INTERVAL. SET BACK KELLY. CONTINUE RIH SLOWLY. HOLE SMOOTH AND CLEAN. PU KELLY. BREAK CIRC. WASH TO BOTTOM AT 8788'. CIRCULATE AND CONDITION MUD TO RUN 7" CASING. PUMP LO/HI VIS SWEEP. HOLE IN VERY GOOD CONDITION. SPOT 100 BBL SLUG ON BOTTOM TREATED WITH THERMATHIN AND DESCO. SET BACK KELLY. FLOW CHECK WELL, OK. POH 10 STANDS. HOLE SLICK. PIPE PULLS SMOOTH. POH. LD DP. RIH W/ 7" 26# NT-80S NSCC CSG MW: 0.0 POH LD DP/ CHECK F/ FLOW @ 9 5/8" SHOE AND AT BHA. LD HWDP. LD BHA. LD STAB'S, CLEAR FLOOR. PULL WEAR RING, INSTALL TEST PLUG, CHANGE TOP RAMS TO 7" AND TEST FOOR SEALS, OK. RU TO TUN 7" 26# NT-80S NSCC CASING. RIH W/ RBP MW: 0.0 VIS: 0 RUN 7", 28#, NT-80 CSG. BREAK CIRCULATION @ 7708. CONTINUE TO RUN CSG. TOTAL 212 JTS. MU HGR AND LDJ JT. LAND CASING. MAKE UP CMT HEAD. BREAK CIRCULATION. CIRCULATE. SWITCH OVER TO HOWCO. PUMPED 10 BBL H20, TEST LINES. RELEASED BOTTOM PLUG, PUMP 50 BBL CLASS "G" CMT, RELEASE TOP PLUG. SWITCH TO RIG PUMP, DISPLACE W/ 8.3 SOURCE WATER. CLCULATED STROKES TO BUMP 3304' SHUT DOWN PUMP, BLED OFF. CHECKED FLOATS, OK. MONITOR WELL, STATIC. SLIGHT PRESSURE ON CSG FROM EXPANSION. BLEED OFF CSG THROUGH CHOKE. CONTINUE TO FLOW SLOW. SHUT IN TO BUILD UP. CONTINUE TO LET BLEED OFF. LAY DOWN CEMENT HEAD AND LANDING JT. CLEAR FLOOR OF CSG TOOLS. BLOW DOWN LINES. INSTALL CSG PACK OFF. RILDS. TEST PACKOFF. CHANGE TOP RAMS TO 3 1/2". RIG UP TO INJECT DOWN ANNULUS. BODY TEST RAMS. INSTALL WEAR RING. MAKE UP RB? ON 3 1/2" DRILL PIPE AND RIH. CLEAN CELLAR MW: 0.0 VIS: 0 PICK UP 3 1/2" DP, RIH TO 3025' W RBP. TEST 7" CSG. DROP BALL. SET RBP @ 3025'. PULL 25K OVER TO SHEAR. LAY DOWN 3 1/2" TO 2010'. BLOW OUT MUDLINES. FREEZE PROTECT WELL @ 2010'. LAY DOWN 3 1/2" DP. WASH EACH JT IN MOUSE HOLE. CHANGE TOP RAMS TO 5 1/2". ND BOPE AND SET BACK. TOP OFF WELL W/ DIESEL. NU ADAPTOR, VALVE AND CAP. BLOW DOWN AND SECURE ALL LINES. CLEAN UP CELLAR. RELEASE RIG @ 0600 HRS ON 02/03/95. : NiP L-17 ~PERATION: RIG : NABORS 27E PAGE: 5 02/26/95 (19) TD: 8788 PB: 8695 02/27/95 (20) TD: 8788 PB: 8695 02/28/95 (21) TD: 8788 PB: 8695 M/U FTA #1 & PICKING UP 4-3/4 MW: 0.0 MOVE RIG FROM L-13 TO L-17 AND SPOT OVER WELL & TRIM HERC & BERM. ET. NIPPLE DOWN 7-1/16" VALVE & FLG. O-PSI ON WELL. NIPPLE UP BOP'S & INSTALL 3-1/2" RAMS & NEW KILL LINE HOSE. TEST BOP'S TO 250 LOW & 3500 HIGH. PULL TEST PLUG & INSTALL WEAR RING. M/U FTA #1 & PICK UP DRILL COLLARS. TRIP FOR SCRAPER MW: 0.0 CONT PICK UP DP TO 2600' REV CIRC DIESEL CAP TO TANK. P/U DP TO 3003' & RIG TO REV CIRC OVER PLUG. REV CIRC 40 BBL XANVIS PILL AS WASHING DN TO LATCH PLUG. @ 3048' LATCH & PULL PLUG LOOSE. RIG UP MUD BUCKET & POOH W/PLUG & LD FTA #1. RIH W/BHA #2 CONT TO P/U DP FROM SHED & DRIFT TO 8676'_ DRLG CMT F/8676-8684' 4-ES KB. CIRC. XANVIS SWEEP @ 6-BPM. TEST CSG TO 3500 PSI. OK. POOH FOR SCRAPER RUN. RIG RELEASED MW: 0.0 CONT POH & CHG BHA. RIH W/SCRAPER & BIT. TAG PBTD @ 8684' CIRC 5-BPM. 700 PSI. PUMP 40 BBL. XANVIS SWEEP & DISPLACE WELL WITH CLEAN SOURCE WATER. L/D 3-1/2" DP. FREEZE PROTECT 2000' TO SURF. W/DIESEL. CONT TO ;/D DP. NIPPLE DOWN BOP'S & NIPPLE UP 7-1/16" TREE VALVE & TREE CAP. FILL WITH DIESEL TO TOP. SECURE WELL AND CLEAN UP CELLAR ETC. RIG RELEASED @ 1600 HRS. 2/2/8/95. SIGNATURE: (drilling superintendent) DATE: SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX/ARCO Well Name: M P L- 1 7 Rig Name: 4 E S AFE: 3 3 0 0 9 6 Accept Date: 08/14/95 Spud Date: Release Date: 08/1 8/95 Aug 14 1995 MIRU, spot 4ES over well & RU. Test bridge plug t/500 psi. ND tree & repair RILDS & NU BOPS, install 3-1/2" rams. Install test plug & install WR. Load pipeshed w/3-1/2" DP. Rig accepted 08/14/95 @ 2100 hrs. Aug 15 1995 Cont to strap & PU BHA #1 & 3-1/2" DP t/8310' tag. Release plug & CBU. POOH with Baker plug. MU BHA #2, RIH with same t/8375'. Break circ & latch LLC & rotate in attempt to release anchor inidications are it did release. Monitor well. POOH w/BHA #2. Aug 16 1995 POOH. Recovered LLCV retrieving tool, LLCV & anchor. LD fishing tools. PU bit, 7" csg scraper. TIH, tag pkr @ 8385'. Circ. POOH, LD 3-1/2" DP. Pull WR bushing, install test plug. Change rams f/3-1/2" t/2-7/8". Test 2-7/8" rams, pull test plug. RU to run 2-7/8" ESP completion. MU ESP & test. OK. Run ESP completion string. Aug 17 1995 Finish running completion string, MU hanger. Install penetrator & make hanger cable splice. Land hanger, run in lock down screws & test. OK. ND BOP, NU tree & test. OK. Pull 2-way check. Freeze protect w/82 bbls diesel. Install 2-way check, prepare to move. Rig release 08/18/95 @ 0600 hrs. Page ] " SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MP L-17 500292253900 NORTH SLOPE COMPUTATION DATE: 2/ 9/95 DATE OF SURVEY: 012995 MWD SURVEY JOB AKIMBER: AK-MM-950103 KELLY BUSHING ELEV. = 51.00 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -51.00 153 153.00 102.00 252 251.99 200.99 341 340.98 289.98 430 429.98 378.98 0 0 N .00 E .00 .00N .00E 0 39 N 48.42 W .42 .58N .65W 0 45 N 47.14 W .10 1.39N 1.54W 0 28 S 48.67 W .95 1.54N 2.25W 0 44 S 18.61 W .45 .75N 2.71W .00 - .45 -1.08 -1.10 - .24 520 519.96 468.96 609 608.90 557.90 699 698.82 647.82 789 788.74 737.74 883 882.70 831.70 1 34 S 22.58 E 1.25 .94S 2.43W 2 22 S 25.92 E .92 3.73S 1.15W 2 35 S 25.31 E .23 7.25S .54E 1 57 S 18.56 E .77 10.54S 1.89E 1 39 S 10.94 E .40 13.39S 2.66E 1.37 3 .88 7.03 10.01 12.68 977 976.67 925.67 1073 1072.65 1021.65 1168 1167.64 1116.64 1264 1263.63 1212.63 1361 1361.49 1310.49 1 15 S 6.88 E .44 15.75S 3.04E 0 51 S 7.38 E .42 17.52S 3.26E 0 53 S 9.05 E .04 18.95S 3.47E 0 36 S 1.24 W .32 20.20S 3.57E 0 31 S 12.29 W .14 21.15S 3.47E 14.93 16.62 17.99 19.20 20.16 1456 1456.34 1405.34 1551 1551.15 1500.15 1646 1646.39 1595.39 1741 1741.16 1690.16 1839 ko~38.68 1787.68 0 33 S 19.76 W .08 22.00S 3.22E 0 35 S 18.03 W .04 22,89S 2.92E 0 45 S 19.94 W .18 23.95S 2.55E 0 33 S 33.81 W .27 24.93S 2.08E 0 30 S 38.14 W .07 25.67S 1.55E 21.04 21.97 23 .08 24.13 24.95 1931 1930.61 1879.61 2027 2027.07 1976.07 2121 2121.09 2070.09 2218 2218.22 2167.22 2312 2311.95 2260.95 0 39 S 49.76 W .21 26.33S .89E 0 41 S 53.56 W .06 27.04S .00W 0 42 S 42.07 W .15 27.80S .84W 0 38 S 51.99 W .14 28.57S 1.67W 0 43 S 39.36 W .18 29.35S 2.45W 25.72 26.58 27.48 28.39 29.30 2403 2403.22 2352.22 2502 2502.30 2451.30 2593 2593.42 2542.42 2689 2688.52 2637.52 2784 2783.36 2732.36 0 45 S 41.42 W .04 30.24S 3.21W 0 42 S 43.04 W .05 31.17S 4.05W 0 45 S 41.30 W .07 32.03S 4.83W 2 11 S 7.61 E 1.88 34.31S 5.01W 4 4 S 14.50 E 2.01 39.37S 3.92W 30 .32 31.39 32.37 34 .64 39.42 2877 2876,62 2825.62 2969 2967.29 2916.29 3069 3065.66 3014.66 3165 3160.10 3109.10 3260 3252.56 3201.56 6 22 S 18.49 E 2.49 8 55 S 18.34 E 2.79 10 31 S 12.11 E 1.91 12 11 S 10.39 E 1.77 14 19 S 9.72 E 2.25 47.52S 1.44W 46.98 59.09S 2.41E 57.64 75.35S 6.75E 72.83 93.95S 10.43E 90.44 115.40S 14.23E 110.83 C OFILMED SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING MILNE POINT / MP L-17 500292253900 NORTH SLOPE COMPUTATION DATE: 2/ 9/9 DATE OF SURVEY: 012995 MWD SURVEY JOB NUMBER: AK-MM-950103 KELLY BUSHING ELEV. = 51.00 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORD DEGREES DG/100 NORTH/SOUTH EAST INATES /WEST VERT. SECT· 3353 3342.62 3291.62 3447 3431.43 3380.43 3544 3522.15 3471.15 3586 3560.90 3509.90 3668 3636.48 3585.48 16 53 S 9.45 E 2·76 140.21S 18 19 28 S 10.71 E 2.78 168.93S 23 21 55 S 11.29 E 2.54 202.58S 30 22 20 S 10.05 E 1.49 218.07S 33 23 9 S 9.16 E 1.09 249.31S 38 .41E .54E · 09E · 01E .29E 134.45 161.74 193.62 208.31 238.06 3763 3724.65 3673.65 3859 3812.44 3761.44 3954 3897.93 3846.93 4049 3983.57 3932.57 4144 4069·09 4018.09 22 28 S 10·27 E .85 285 25 10 S 9.24 E 2.86 324 25 42 S 9.74 E .59 364 25 17 S 9.95 E .43 404 26 58 S 9.82 E 1.76 445 .87S 44 .08S 51 .19S 57 .44S 64 .78S 71 · 54E · 09E .80E · 78E · 99E 272.85 309·21 347·41 385.69 425.01 4240 4153.20 4102.20 4332 4232.41 4181.41 4427 4309.94 4258.94 4523 4385.05 4334.05 4617 4455.20 4404.20 29 38 S 8·49 E 2.87 490 32 53 S 7.61 E 3.53 538 36 55 S 4.94 E 4.56 591 40 43 S 3.45 E 4.07 652 41 47 S 3.44 E 1.14 713 .52S 79 .15S 85 .92S 91 .20S 96 .63S 99 · 17E · 89E · 74E .13E · 83E 467.68 513.26 565.04 623·50 683.20 4712 4525·40 4474.40 4806 4591.64 4540.64 4900 4655.83 4604.83 4995 4718.30 4667.30 5091 4780.02 4729.02 43 45 S .83 E 2.76 778 46 13 S .82 W 2.93 844 47 54 S 3·62 W 2.81 913 49 20 S 4.28 W 1.62 984 50 27 S 6.68 W 2.24 1057 .50S 102.22E .72S 102.20E .63S 99.51E .38S 94.62E .34S 87.61E 746.54 811.64 879.87 950.32 1023.33 5185 4840.06 4789.06 5279 4900.06 4849.06 5374 4959.83 4908.83 5469 5018.26 4967.26 5563 5075.40 5024.40 50 25 S 8.60 W 1.57 1129 50 36 S 8.85 W .29 1201 51 16 S 11.63 W 2.38 1273 52 32 S 12.22 W 1.43 1346 52 35 S 12.31 W .09 1419 .36S 77 .35S 66 .81S 53 .76S 38 .71S 22 · 95E .90E .80E .39E .53E 1095.90 1168.69 1242.32 1316.87 1391.49 5658 5133.25 5082·25 5753 5190·88 5139.88 5848 5248.78 5197.78 5944 5307.45 5256.45 6039 5365.49 5314.49 52 43 S 12.00 W .29 1493 52 31 S 11·05 W .82 1567 52 7 S 13.51 W 2.10 1640 52 19 S 13.64 W .24 1714 52 27 S 12.76 W .75 1787 .82S .74S · 97S .56S .92S 6.57E 8.50W 24.44W 42.21W 59.41W 1467.27 1542.70 1617.61 1693.21 1768.48 6134 5423·04 5372.04 6229 5480.35 5429.35 6323 5537·08 5486.08 6418 5595.18 5544.18 6513 5652.68 5601.68 52 52 S 12.79 W .44 1861 53 2 S 11.59 W 1.02 1935 52 34 S 13.82 W 1.96 2008 52 28 S 14.37 W .47 2082 52 32 S 13.56 W .69 2154 .51S .76S .70S .20S .94S 76.10W 92.14W 108.58W 127.03W 145.12W 1843.88 1919.81 1994.53 2070·17 2144·99 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING MILNE POINT / MP L-17 500292253900 NORTH SLOPE COMPUTATION DATE: 2/ 9/95 DATE OF SURVEY: 012995 MWD SURVEY JOB NUMBER: AK-MM-950103 KELLY BUSHING ELEV. = 51.00 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DG/100 TOTAL RECTANGULAR COORD NORTH/SOUTH EAST INATES VERT. /WEST SECT. 6609 5711.20 5660.20 52 34 S 13.16 W .33 2229.32S 162 6703 5768.24 5717.24 52 43 S 12.57 W .52 2302.18S 179 6798 5825.92 5774.92 52 50 S 13.28 W .61 2376.20S 196 6893 5883.10 5832.10 53 0 S 12.57 W .62 2449.95S 213 6988 5940.00 5889.00 53 11 S 13.06 W .45 2523.84S 230 .79W 2221.35 .43W 2296.03' .41W 2371.91 .34W 2447.51 .15W 2523.23 7083 5997.00 5946.00 53 13 S 12.29 W .65 2598.21S 246 7178 6054.94 6003.94 51 46 S 12.85 W 1.60 2671.90S 263 7273 6115.15 6064.15 49 4 S 13.63 W 2.93 2742.80S 279 7367 6178.14 6127.14 46 59 S 12.13 W 2.51 2811.06S 295 7462 6244.40 6193.40 44 55 S 13.40 W 2.36 2877.88S 310 .87W 2599.41 .30W 2674.86 .97W 2747.61 .59W 2817.58 .72W 2886.04 7558 6313.98 6262.98 42 18 S 13.92 W 2.75 2942.32S 326 7653 6385.61 6334.61 38 49 S 15.44 W 3.84 3001.64S 341 7745 6458.98 6407.98 35 19 S 19.07 W 4.49 3054.59S 358 7841 6538.92 6487.92 32 39 S 21.36 W 3.07 3105.18S 376 7936 6619.48 6568.48 30 51 S 22.91 W 2.10 3151.37S 395 .37W 2952.26 .88W 3013.42 .26W 3068.47 .85W 3121.62 .62W 3170.47 8031 6700.90 6649.90 30 39 S 23.54 W .40 3195.90S 414 8119 6777.68 6726.68 29 55 S 29.37 W 3.41 3236.01S 434 8215 6860.79 6809.79 29 20 S 33.10 W 2.02 3276.43S 459 8308 6941.74 6890.74 29 7 S 33.95 W .51 3314.19S 484 8404 7025.50 6974.50 29 2 S 34.88 W .48 3352.61S 510 .72W 3217.74 .66W 3260.84 .15W 3305.06 .16W 3346.76 .49W 3389.37 8499 7108.83 7057.83 28 16 S 34.85 W .81 3389.98S 536 8593 7192.64 7141.64 27 17 S 35.77 W 1.13 3426.01S 562 8688 7277.18 7226.18 26 15 S 36.81 W 1.20 3460.39S 587 8788 7366.37 7315.37 26 15 S 36.81 W .00 3495.60S 613 THE CALCULATION PROCEDURES ARE BASED THREE-DIMENSION MINIMUM CURVATURE ON THE USE OF METHOD. .52W 3430.88 .04W 3470.97 .27W 3509.40 .63W 3548.85 HORIZONTAL DISPLACEMENT = 3549.05 FEET AT SOUTH 9 DEG. 57 MIN. WEST AT MD = 8788 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 190.57 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MP L-17 500292253900 NORTH SLOPE COMPUTATION DATE: 2/ 9/95 DATE OF SURVEY: 012995 JOB NUMBER: AK-MM-950103 KELLY BUSHING ELEV. = 51.00 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEA~D VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -51.00 .00 N .00 E 1000 999.66 948.66 16.26 S 3.10 E 2000 1999.59 1948.59 26.84 S .26 E 3000 2997.73 2946.73 63.63 S 3.91 E 4000 3938.98 3887.98 383.66 S 61.14 E .00 .34 .34 .41 .07 2.27 1.86 61.02 58.75 5000 4721.45 4670.45 988.04 S 94.35 E 6000 5341.63 5290.63 1757.64 S 52.56 W 7000 5947.01 5896.01 2532.96 S 232.26 W 8000 6674.20 6623.20 3181.38 S 408.40 W 8788 7366.37 7315.37 3495.60 S 613.63 W 278.55 217.53 658.37 379.81 1052.99 394.63 1325.80 272.80 1421.63 95.83 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MP L-17 500292253900 NORTH SLOPE COMPUTATION DATE: 2/ 9/95 DATE OF SURVEY: 012995 JOB NUMBER: AK-MM-950103 KELLY BUSHING ELEV. = 51.00 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEA~D VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 51 51.00 151 151.00 251 251.00 351 351.00 -51.00 .00 100.00 200.00 300.00 1 1 .00 N .00 E .00 .00 N .00 E .00 .00 .56 N .63 W .00 .00 .38 N 1.53 W .01 .01 .48 N 2.31 W .02 .01 451 451.00 400.00 551 551.00 500.00 651 651.00 600.00 751 751.00 700.00 851 851.00 800.00 .49 N 2.80 W 1.73 S 2.10 W 5.31 S .38 W 9.30 S 1.47 E 12~49 S 2.49 E .03 .01 .06 .03 .14 .08 .23 .10 .29 .06 951 951.00 900.00 1051 1051.00 1000.00 1151 1151.00 1100.00 1251 1251.00 1200.00 1351 1351.00 1300.00 15.19 S 2.97 E 17.19 S 3.22 E 18.70 S 3.43 E 20.06 S 3.58 E 21.06 S 3.49 E .33 .04 .35 .02 .36 .01 .37 .01 .37 .01 1451 1451.00 1400.00 1551 1551.00 1500.00 1651 1651.00 1600.00 1751 1751.00 1700.00 1851 1851.00 1800.00 21.95 S 3.24 E 22.89 S 2.92 E 24.01 S 2.53 E 25.01 S 2.03 E 25.75 S 1.48 E .38 .00 .38 .01 .39 .01 .40 .01 .40 .00 1951 1951.00 1900.00 2051 2051.00 2000.00 2151 2151.00 2100.00 2251 2251.00 2200.00 2351 2351.00 2300.00 26.48 S .71 E .41 .01 27.21 S .23 W .41 .01 28.07 S 1.09 W .42 .01 28.80 S 1.96 W .43 .01 29.73 S 2.77 W .44 .01 2451 2451.00 2400.00 2551 2551.00 2500.00 2651 2651.00 2600.00 2751 2751.00 2700.00 2851 2851.00 2800.00 30.71 S 3.62 W .44 .01 31.61 S 4.46 W .45 .01 32.90 S 5.19 W .47 .02 37.14 S 4.50 W .57 .10 44.81 S 2.35 W .90 .33 2952 2951.00 2900.00 3054 3051.00 3000.00 3156 3151.00 3100.00 3258 3251.00 3200.00 3362 3351.00 3300.00 56.66 S 1.60 E 72.69 S 6.18 E 92.02 S 10.08 E 115.01 S 14.16 E 142.75 S 18.84 E 1.70 .80 3.09 1.39 5.03 1.94 7.73 2.71 11.63 3.89 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MP L-17 500292253900 NORTH SLOPE COMPUTATION DATE: 2/ 9/95 DATE OF SURVEY: 012995 JOB NUMBER: AK-MM-950103 KELLY BUSHING ELEV. = 51.00 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEAgD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION 3468 3451.00 3400.00 3575 3551.00 3500.00 3683 3651.00 3600.00 3792 3751.00 3700.00 3902 3851.00 3800.00 175.73 S 24.82 E 17.10 5.48 214.07 S 32.29 E 24.48 7.38 255.45 S 39.28 E 32.93 8.45 296.84 S 46.49 E 41.40 8.47 341.99 S 54.01 E 51.39 9.98 4013 3951.00 3900.00 4124 4051.00 4000.00 4237 4151.00 4100.00 4355 4251.00 4200.00 4479 4351.00 4300.00 389.27 S 62.12 E 62 436.71 S 70.42 E 73 489.30 S 78.99 E 86 550.33 S 87.43 E 104 623.84 S 94.26 E 128 .30 .30 .62 .11 .46 10 11 13 17 24 .91 .00 .32 .48 .35 4611 4451.00 4400.00 4748 4551.00 4500.00 4893 4651.00 4600.00 5045 4751.00 4700.00 5202 4851.00 4800.00 709.88 S 99.60 E 160 803.45 S 102.43 E 197 908.33 S 99.82 E 242 1022.48 S 91.62 E 294 1142.45 S 75.97 E 351 .5O .50 .47 .47 .45 32.04 37.00 44.97 52.00 56.97 5360 4951.00 4900.00 5523 5051.00 5000.00 5687 5151.00 5100.00 5851 5251.00 5200.00 6015 5351.00 5300.00 1263.03 S 56.02 E 409 1388.54 S 29.33 E 472 1516.63 S 1.72 E 536 1643.75 S 25.11 W 600 1769.53 S 55.25 W 664 .38 .08 .91 .88 .37 57 62 64 63 63 .94 .70 .83 .96 .50 6180 5451.00 5400.00 6345 5551.00 5500.00 6510 5651.00 5600.00 6674 5751.00 5700.00 6840 5851.00 5800.00 1897.55 S 84.27 W 729 2026.36 S 112.92 W 794 2152.81 S 144.61 W 859 2280.08 S 174.50 W 923 2408.40 S 204.01 W 989 .39 .98 .28 .87 .21 65.02 65.59 64.30 64.59 65.34 7006 5951.00 5900.'00 7172 6051.00 6000.00 7327 6151.00 6100.00 7471 6251.00 6200.00 7608 6351.00 6300.00 2538.16 S 233.47 W 1055.67 2667.02 S 262.19 W 1121.30 2782.61 S 289.48 W 1176.59 2884.23 S 312.24 W 1220.99 2973.90 S 334.43 W 1257.16 66 65 55 44 36 .45 .63 .29 .41 .17 7735 6451.00 6400.00 7855 6551.00 6500.00 7973 6651.00 6600.00 8089 6751.00 6700.00 8204 6851.00 6800.00 3049.17 S 356.42 W 3112.39 S 379.67 W 3168.71 S 402.94 W 3222.42 S 427.35 W 3271.82 S 456.14 W 1284.29 1304.89 1322.01 1338.12 1353.33 27.13 20.59 17.12 16.11 15.21 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MP L-17 500292253900' NORTH SLOPE COMPUTATION DATE: 2/ 9/95 DATE OF SURVEY: 012995 JOB NUMBER: AK-MM-950103 KELLY BUSHING ELEV. = 51.00 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEA~D VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8318 6951.00 6900.00 3318.47 S 487.04 W 1367.92 14.59 8433 7051.00 7000.00 3364.23 S 518.59 W 1382.33 14.41 8546 7151.00 7100.00 3408.49 S 549.46 W 1395.97 13.64 8659 7251.00 7200.00 3450.05 S 579.54 W 1408.36 12.39 8770 7351.00 7300.00 3489.53 S 609.08 W 1419.86 11.50 8788 7366.37 7315.37 3495.60 S 613.63 W 1421.63 1.77 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS WELL LOG TRANSMITTAL k~ To: State of Alaska August 1, 1995 Alaska Oil and Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 I RE: MWD Formation Evaluation Logs - MP L-17 AK-MM-950103 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs: 2"x 5" TVD Resistivity and Gamma Ray Logs: 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 2" x 5" MD Neutron and Density Logs: 1 Blueline 1 Folded Sepia 2" x 5" TVD Neutron and Density Logs' 1 Magnetic Tape w/LDWG Listings 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3m---'~ · Fax (907) 563-7252 A Dresser Industries, Inc. Company LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE A~NCHORAGE AK, 99501. Dear Sir/Madam, Reference: MPL-17 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PFC/PERF FINAL BL+RF Date: RE: 13 June 1995 Transmittal of Data ECC #: 6401.01 Sent by: PRIORITY MAIL Data: PFC/PERF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please-stgn and ~.eturn Petrotechntcal Dat~ Cen2~ BP Exploration (Alaska) In~ ~0 E~st Benson Boulev~d ......................... 1995 ~~ · .... ~laska Oil & Bas C~s. mmission Anchora~ BP EXPLORATION To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: David Johston, Chairman COMM ' L~ RES ENG ~ SR ENG I~ SR ENG ENG ASST ENG ASST SR GEOL/¢¢~C Date: April 28, 199! iGEOL ASST GEOL ASST '~ STAT TECH Subject: Milne Point Unit Drilling Operations- Clarification Per our conversation with Blair Wondzell on April 26, we would like to clarify our drilling operations at Milne Point unit F and L pads. MPL-17 (Permit # 94-169). Drilled surface hole and set 9-5/8" surface casing at 3650'. Drilled to 8788' MD and set 7" casing across the Kuparuk sands. The well was suspended with source water in the casing and a 7" retrievable bridge plug set at 3025'. The well will be perforated, hydraulically sand frac'd and cleaned out with coiled tubing without a rig on the well. The well will be completed by a rig as an ESP completion with 2-7/8" tubing at a later date. MPL-29 (Permit # 95-009). Drilled surface hole and set 9-5/8" surface casing at 7676' in January, 1995. The well was suspended with a dry hole tree in order to move N27E to the newly set MPF-pad and drill several development wells before break-up and pad compacting operations commenced. N27E will be moving back to MPL-29 in early May to complete drilling operations on this well. The well will be completed with 3-1/2" tubing by N27E as a Kuparuk water injection well. MPF-25 (Permit # 95-16). Drilled surface hole and set 9-5/8" surface casing at 3425'MD. Drilled to 11502'MD and set 7" casing across the Kuparuk sands. The well was perforated and hydraulically sand frac'd without a rig and will be cleaned out with coiled tubing. The well will be completed by a rig as an ESP completion with 2-7/8" tubing this fall. MPF-13 (Permit # 95-27). Drilled surface hole and set 9-5/8" surface casing at 3968'MD. Drilled to 10975'MD and set 7" casing across the Kuparuk sands. The well was perforated and hydraulically sand frac'd without a rig and will be cleaned out with coiled tubing. The well will be completed by a rig as an ESP completion with 2-7/8" tubing this fall. RECEIVED MAY-2 1995 Alaska Oil & Gas Cons. Commission ~nchorage MPF-37 (Permit # 95-25). Drilled surface hole and set 9-5/8" surface casing at 6621'MD. Drilled to 12915'MD and set 7" casing across the Kuparuk sands. The well was perforated and hydraulically sand frac'd without a rig and will be cleaned out with coiled tubing. The well will be completed by a rig as an ESP completion with 2-7/8" tubing this fall. MPF-01 (Permit #95-45). Drilled surface hole and set 9-5/8" surface casing at 7124'MD. Drilled to 12941'MD and set 7" casing across the Kuparuk sands. The well will be perforated and hydraulically sand frac'd without a rig and then cleaned out with coiled tubing. The well will be completed by a rig as an ESP completion with 2-7/8" tubing this fall. Yours Sincerely, /....,:?.? i Drilling Engineer Supervisor cc. Well file RECEIVED mAY '-2 1995 Alaska Oil & Gas CODS. Commission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP MPL-17 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Date: RE: 6 April 1995 Transmittal of Data ECC #: 6401.00 Sent by: PRIORITY MAIL Data: GR/CCL Prints/Films: 1 1 GR/~CL FINAL BL+RF GR/CCL/PERF FNLBL+RF Run # 1 Run ~ 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: RECEIVED APR i / 199,5 "~-~: ~ ~3~; & ~"-~ eo~,s. Commission PZease sign and Petrotec~ical Data Cent~ BP Exploration (~aska) ~0 ~st Bensom ~uleva~ MEMORANDUM TO: David Joh_.~ Chairmah~'"- State of Alaska. Alaska Oil and Gas Conservation Co~hmission DATE: January 21, 1995 FROM: Blair Wondzeil, P. i. Supervisor John Spaulding,~7~/~¢ Petroleum lnspebtor FILE NO: SUBJECT: AW9LAUCD.doc BOP Test Nabors 27E BPX / MPU / MPL-17 Milne Point Unit PTD 94-169 SatUrdaY JanuarY 21, 1994: I witnessed the MPU well MPL-17. BOP Test on Nabors 27E at BPX As noted in the attached AOGCC BOP Tests report several failures were observed. upper pipe rams leaked, repaired and re-tested · 1 manual kill valve failure, repaired and re-tested · ball type floor valve failure, repaired and re-tested · choke manifold valve failure, repaired and re-tested · all 3 methane gas detectors failed, repaired, m-calibrated and re-tested Nabors 27E has been stacked for the past three years. I was assured by Rod Kiepsig Nabors toolpusher that the problems encountered on this test would be addressed and not happen in the future. Nabors Drilling is planning to institute a very intensive PM program in the very near future. This PM program should help alleviate many of the problems associated with BOP Tests on all Nabors rigs. Summary: I witnessed the BOP test on Nabors 27E, 7 failures, 20 hours. Attachment: aw91aucd STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: X Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8" Test: Initial X Workover: Nabors Rig No. 27E PTD # BP Exploration Rep.: MPL-17 Rig Rep.: Set @ 3632' Location: Sec. Weekly Other DATE: 1/21/95 94-169 Rig Ph.# 659-4373 Jim Gaffney Rod Klepsig 8 T. 13N R. 10E Meridian Umiat MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Dri. Rig OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F 1 250/3000 P I 250/4000 F 1 25015000 P 1 250/5000 P I 250/5000 P 2 250/5000 P I 250/3000 F N/A N/A N/A FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly/IBOP Ball Type Inside BOP CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes ACCUMULATOR SYSTEM: System Pressure Pressure After Closure Test Quan. Pressure P/F 1 250/5000 P 1 250/5000 P 1 250/4000 F 1 250/5000 P 15 Test Pressure P/F 250 / 5000 P 39 250/5000 P 2 Functioned Functioned 3050 I P 1500 MUD SYSTEM: Visual Alarm Trip Tank OK Pit Level Indicators OK OK Flow Indicator OK OK Methane Gas Det. OK OK H2S Detectors~' NA NA 200 psi Attained After Closure System Pressure Attained 1 Blind Switch Covers: Master: Nitgn. Btl's: 7@ 2400 1@0 minutes 20 sec. minutes 42 sec. X Remote: X Psig. Number of Failures 7 Test Time ll Hours Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within t 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: II II Top pipe rams leaked at mud seal (repaired), Floor valve leak (replaced), Choke valve leak (repaired) Ail methane gas detectors (3) failed and were re-calibrated Distribution: orig-Well File c - Oper./Rig c- Database ~ - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: W~nessed By: John H. Spaulding FI-021L (Rev. 2/93) AW9LAUCD.XLS "" ....... i!t 1 .,..,. / ALASKA OIL AND GAS / CONSERVATION CO/ SSION / 'i ONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 4, 1995 Adrian Clark Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point MPL-17 BP Exploration (Alaska), Inc. Permit No: 94-169 Sur. Loc. 1618'SNL, 5055'WEL, Sec. 8, T13N, R10E, UM Btmhole Loc. 249'NSL, 361'WEL, Sec. 7, T13N, R10E, UM Dear Mr. Clark: 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 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 Chairman~ BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] RedrillF'lllb. Type of well. ExploratoryF'l Stratigraphic TestF1 Developme'nt Oil[] Re-Entry [] Deepenl'-II 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 = 32.5 feet Milne Point Unit - Kuparuk 3. Address 6. Property Designation Sands I P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 25509 ~. Location of well at surface 7. Unit or property Name 11. TYpe Bond(m,, 20 ^AC 25.025 1618' SNL, 5055' WEL, SEC. 8, T13N, RIOE Milne Point , At top of productive interval 8. Well number Number 294' NSL, 330' WEL, SEC. 7, T13N, RIOE MPL-17 2S100302630-277 At total depth ;9. Approximate 'spud date Amount 249' NSL, 361' WEL, SEC. 7, T13N, RIOE 1/12/95 $200,000. O0 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. proposed depth (Ma and TVDI property line ADL 25515-249' feet No close approach feet 2560 8376' MD/7165' TVD feet 1'6'. To' be completed for deviated wells 17. Anticipated pressure (s,,e 20 AAC 25.035 (e)(2)) Kickoff depth 300 feet Maximum hole ancjle 4s o Maximum sun'ace 3700 psig At total depth (TVD) 7165 74400 psi~ 18. Casing program Setting Depth s~ze Specifications Top Bottom Quan!ity Of. cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.1tt Nr~u~ Weld 80' 32' 32' 112' 112' 260 sx Arct/cset I (Approx,) 12-1/4" 9-5/8" 40# L-80 BTRC 2969' 31' 31' 3000' 2980' 597 sx PF "E"/250 sx "G"/250 sx PI"C" 8-1/2" 7" 26# L-80 BTRc 8646 30' ,30' 8676' 7165' 167 sx "G"/181 sx PF"E" 19. To be completed for Redrill, Re-entry, and Deepen Operations~ Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing ,Length Size Cemented Measured depth True Vertical depth Structural Conductor SurfaceRECEIVED Intermediate ProductionD[C 2 7 1994 Liner PeRoration depth: measured ¢~8_'L~.¢Jl & Gas Cons. Commission true vertical --"~'~"'".~-L, ~'lCJ'10ra ','~ , 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch L-'I Drilling program[21 Drilling fluid AAG 25.050 ce~if~l'~,t t.h¢ f. qregoi~.~s true and correct to the best of my'knowledge prograrrff [] Time vs depth plot [] Refraction analysis [] Seabed report l-I 20 requirements[] 21. I hereby / -- Si~)ned ./ )' ~--~'~"-'~-"""~ //~ Title Dr#ling Engineer Supervisor Daie/~/2.-~-/~ ~/ . . Commission Use Only -- P'e~-mit Number }APl number IAppr0val date ISee cover letter ?~4'-,//~'~ 15 0-0 2---¢- .Z_ ~....4-,? ~' J /--~ -/7~.- ¢ 5~' Jfor other requirements Conditions of approval Samples required [] Yes 'J~'~ Mud log required []Yes [] No Hydrogen sulfide measures [] Yes ~ No Directional survey required J~ Yes [] No BOP 11-I · · ~5M' [-I10M; F']15M; Required working pressure foruJ ~,o ~,uu ~:~~E"JglrlL2cM~Jg'l~]"3~M~y ' Other: by order ofI"/, Approved by David W. Johnston Commissioner [ne commission Date Form 10-401 Rev. 12-1-85 Submit ~plicate Name: I MPL-17 Well Plan Summary [Type of Well (producer or injector)' I Producer iSurface Location' Target Location: Bottom Hole Location' 1618' FNL 5055' FEL Sec 08 T13N R10E UM., AK. 0294' FSL 0330' FEL Sec 07 T13N R10E UM., AK. 0249' FSL 0361' FEL Sec 07 T13N R10E UM., AK. [AFE Number: [330096 [Rig: [Nabors 27E Estimated Start Date: I January 12, 1995 IOperating days to complete: 12 etc.)' Well Design (conventional, slimhole, Ultra Slimhole Formation Markers: Formation' ToPs MD TVD (ss') Formation Pressure/EMW , base permafrost 1750' 1700' n/a MA n/a n/a n/a NA (Top Schrader) 4147' 4009' 1728 psig / 8.0 ppg OA 433~2' 4149' 1791 psig/.8.0 ppg 'Base Schrader Bluff 4767" 4449' '1868 psig / 8.0 ppg Top HRZ 7590' 6494' n/a Base HRZ 7789~' " 6659 ' n/a Kupark D Shale 8161' 6944' n/a Top Kuparuk B 8121' 6895' 3478 pslg / 9.7 ppg Target 8266' 7020' 354'1 psig / 9.7 ppg Total Depth 8676' 7165' n/a Casin: /Tubin Pro ram' Hole Csg/ Wt/Ft Grade Con Length' Top Btm Size Tbg n MD/TVD MD/TVD O.D. 30" 20" 91.1# NT80LHE weld 80 32/32 112/112 12 1/4" 9 5/8" 40~ L-80 brrc 2969 31/31 3000/2980 8 1/2'~ 7" 26# L-80 btrc 86~6 30/30 8676/7165 Internal yield pressure of the 7" 26g casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 6860' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3600 psi is 2898 psi, well below the internal yield pressure rating of the 7" casing. Logging Prol I Open Hole Logs: Surface Intermediate Final ICased Hole Logs: ;ram: None LWD GR/Resistivity/Neutron/Density & RFT (Schrader Bluff sands) GR/CCL/Cement Bond Log only if necessary based on results of cement ob. A gamma ray log will be obtained from surface to TD. Mud Logging is not required. RECEIVED DEC 2 ? i994 JJi1.8, Gas Cons. Commission ........ '- gnchora.'~ Mud Program: Special design considerations INone- LSND freshwater mud Surface Mud Properties' l Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity. Point gel gel Loss 8 6 5O 15 8 10 9 8 tO tO tO tO tO tO tO 9.6 90 35 15 30 10 15 Intermediate Mud Properties: N/A I .. Density Marsh Yield 10 sec 10 min pH Fluid ... (PPG) Viscosity Point gel gel Loss , Production Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscos!tY Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.2 50 15 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: [KOP: [300' ]Maximum Hole Angle: 145 degrees I Close Approach Well'I None It will be necessary to shut in the MPL-1 for a close approach (11' at 3400' MD) while drilling MPL-17. There are no other drilling close approach wells for drilling MPL-17. Disposal: Cuttings Handling: CC2A Fluid Handling: MPU wells L-13, L-14 and L-15 are permitted and available for annular injection. These wells are located on the original pad and quite some distance (+- 1000') from the new pad extension where these wells will be drilled. If possible truck liquid drilling waste to these wells for injection, otherwise all drilling and completion fluids will be trucked to CC2 for processing. Annular Injection: L-17 is the first well drilled from the L-pad extension. It may not be feasible to fie Nabors 27E into the other wells with open annulii on the original L-pad (L- 13, L-14i and L-15i) due to the distance of the pad extension to the original pad. All cuttings/fluids from this well (L-17) that cannot be injected at L-pad will be hauled to CC2@ for processing and injection. ! AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED VOL (BBLS) (BBLS) Milne Point L 13 5390 35,000 1/1/95 -'1/31/95 Milne Point L-14i 0 35,000 1'/1/95 -1/31/95 Milne F;oint L-15i 0 35,000 1/1/95 -1/31/95 i i i 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. MPL-17 Proposed Summary of Operations , . 3. 4. 5. . 10. 11. 12. 13 14. 15. Drill and Set 20" Conductor. Weld an FMC landing ring for the FMC Universal Slimhole Wellhead on conductor. Prepare location for rig move. MIRU Nabors 27E drilling rig. NU and function test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole to 3000' md (2980' tvd). Run and cement 9-5/8" casing. ND 20" Diverter, NU and Test 13-5/8" BOPE. Run Wear Bushing. RIH w/drilling assembly with insert bit. Test the 9-5/8" casing to 3500 psig, Drill' out float equipment and 10 feet of new formation, Perform a LOT. Drill 8-1/2" hole through the Schrader Bluff sands (base estimated @ 4600' MD/4449'TVD) and dull the bit (previous runs have averaged +- 2500' MD). Control drill through the Schrader Bluff to facilitate LWD logs. If hydrocarbons are indicated in Schrader Bluff, POH and R/U E-line. Run RFF's in the Schrader Bluff sands. Obtain pressure settings and fluid samples per onsite Geologists. Continue to drill 8.5" hole with turbine and PDC to 8676' md (7424' tvd), POOH, LD DP. Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing (2 stage cement job). Note: This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). Run and Test 7" Pack-Off to 5000 psig. P/U 3-1/2" DP, 6" bit and casing scraper. RIH and drill out DV collar and plugs in 7" casing. Continue to PBTD and displace mud in casing to brine. Test casing to 3500 psi. ND BOPE. R/U CTU tubing head false b0wl, BPV and 7-1/16" frac tree. RDMO Nabors 27E drilling rig to drill MPL-29. 'CEIVE E D MPL-17 WELL %5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" TVDSS. CIRC. TEMP 70 deg F at 3000' SPACER' 75 bbls fresh water. 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' 597 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: 15.6 ppg APPROX NO SACKS: 250 YIELD: 0.96 cu ft/sk. MIX WATER: 3.7 gal/sk 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. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 618' md above 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", 40g capacity for float joints. 5. Top Job Cement Volume is 250 sacks. MPL-17 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE,I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140© F 7000' TVDSS. BHST 170 deg F at 7040' SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 167 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 rain @ 140° F FREE WATER: 0cc @ 45 degree angle. .~TAGE II CEMENT JOB ACROSS .THE ~CHRADER BLUFF SANDS; CIRC. TEMP: 60© F BHST 80 deg F at 7040' TVDSS. SPACER: 75 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight.~,'C~"~": ~f- E]V D LEAD, CEMENT TYPE; ADDITIVES: Retarder WEIGHT: 12.0 ppg gal/sk Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 APPROX #SACKS: NONE THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADD/TIVES: 0.2% CFR-3, 0.2% Halad 344, 2.0% CaC12 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 181 THICKENING TIME: 4 hours @ 50 FLUID LOSS: 100-150 cc FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7-1/8 .... x 8-1/4" Straight Blade Turbulators -- two per joint on the bottom 16 joints of 7" Casing (32 total). This will cover 300' above the LK1. 2. Run one 7-1/8" x 8-1/4" Straight Blade Turbulators inside the 9-5/8" casing shoe. 3. Total 7-1/8"" x 8-1/4" RH Turbulators needed is 33. 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. The cement volume is calculated to cover 750' md with 30% excess above guage hole. 2. Stage 2 cement volume is calculated to cover from the OG base to the to 500' above the NA Top with 30% excess. DRILLING HAZARD~; AND RI~;K~;; See the Milne Point L-Pad Data Sheet prepared by Pete Van Dusen for a general recap of the originall3 wells drilled by Conoco on L-Pad plus the L- 14 and L-15 wells recently drilled by BPX. There will be one close approach while drilling this well. MPL-1 will need to be shut-in due to a crossing of 11' as MPL-17 is drilled @ 3400' MD. There will be intensive road construction on the west side (opposite side of the pad from MPL-17) of L-pad as a road is laid from L-pad to F-pad and F-pad ~s constructed. Ensure personnel and vehicles use caution while approaching and on L-pad. Consruction is due to start in mid-January and will continue through the end of Febuary. Surface casing Will be set high on this well above the UGNU/Schrader Bluff Sands. This was done on L-12 and L-03 with success; however, lost circulation while running production casing were experienced. It is important that we drill the hole with minimum doglegs, concentrating on maintaining a low solids mud, and practicing good hole cleaning procedures. Lost Circulation: Lost circulation while drilling the production interval has been a problem in on 4 different L-pad wells. The Kuparuk sands and a number of shallower intervals are highly fractured. Wells L-07, L-08, L-09 and L- 11 lost varying amounts of mud (from 70 to 220 bbls) drilling through or near the top of the Kuparuk sands. Be prepared to treat these losses with LCM treatments. Have the LCM materials outlined in the Drilling Fluid Program on location and recommended pills ready to address the Lost Circulation Problem when drilling into the Kuparuk Sand. Stuck Pipe Potential: Stuck pipe has occurred on 3 wells on this pad at the interface between the Kalubik and D-shale (called the Kuparuk cap rock). These wells and the corresponding depths at which they were stuck were: L-06 @ 6871' ss, L-07 @ 6859' ss, L-11 @ 6835' ss. Kick Tolerance: The surface casing setting depth for this well allows a kick tolerance of 32.4 bbl influx (Gas) based on a 12.5 ppg LOT at the 9- 5/8" casing shoe and a estimated reservoir pressure of 3541 psig (9.7 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: This will be this first well drilled into this particular block and formation pressures are inticipated to be at virgin reservoir pressure (9.7 ppg EMW). The producer, L-01, approximately 3000' to the north across one fault and has a flowing BHP of 1760 psi and an estimated reservoir pressure of 2800 psi (7.7 ppg EMW). 3500' directly to the north of L-01 (and in the same fault block as L01) L-10i is injecting water at 2532 psi and 638 BWPD. g~ch0r,,. MPL MPL-~ ? - TV9 t-,/S 2~il 130 O N - 74E,~357.~ ~ WELL PERMIT CHECKLIST UNIT# PROGRAM: exp [] dev~ redrll [] aery [] ON/OFF S~O~ C~h~ ADMINISTRATION ENGINEERING 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............ 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. 10. Operator has appropriate bond in force ........ Il. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... · N N Y N 14. Conductor string provided ............... Y~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. -O N 17. CMT vol adequate to tie-in long string to surf csg . . .-~ ~ 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· .~Y ~:~ 22. Adequate wellbore separation proposed ......... ~N 23. If diverter required, is it adequate .......... ~N 7 ~ ~ ~ [- ' ~ ~ /~ , /. F ~ ~? ~ ~ ~~~~ 24. Drilling fluid progr~ schema~ic ~ equip lis~ adequate .~N ~ ~~ ~~rr~~~ T~ /u~ ~ ~ ~.. 25. BOPEs adequate ..................... ~N . ~9~fP~~ 27. Choke manifold complies w/~I ~-53 ~ . · ~- N 29. Is presence of H2S gas probable ............. Y ~ , --~--' GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y/~ 32. Seismic analysis 9f shallow gas zones .......... Y/ N 33. Seabed condition survey (if off-shore) ......... f N 34. Contact name/phone for weekly progress reports .... / Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: Z · '"~MS'~cheklist rev 03/g4 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. ~ubfile 2 is type: LIS TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: 6465.00 LOGGING ENGINEER: MARK HANIK M. WORDEN OPERATOR WITNESS: J. ROBERTSON J. ROBERTSON SURFACE LOCATION SECTION: 8 TOWNSHIP: 13N RANGE: 10 E ~ FNL: 1618 '~ FSL: ~ FEL: 5055 ~ ~ FWL: ELEVATION (FT FROM MSL 0) 'mo_% KELLY BUSHING: 51.00 %~ DERRICK FLOOR: 49.50 ~'~ GROUND~ LEVEL: 16.70 ~ ~. WELL CASING RECORD u~. OPEN HOLE CASING DRILLERS 500292253900 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES MWD RUN 3 MWD RUN 3 BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 20.000 112.0 3RD STRING 12.250 9.625 3633.0 PRODUCTION STRING 8.500 8788.0 REMARKS: MWD - DGR/EWR4/CNP/SLD. ALL DEPTHS ARE DRILLER'S DEPTHS. ANNULAR & CRITICAL VELOCITIES ARE CALCULATED USING THE POWER LAW MODEL. NO DEPTH SHIFTS APPLIED AS THIS IS THE DEPTH REFERENCE FOR THIS WELL. MIC OFILMET) ~LE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP NPHI RHOB $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 3600.0 8738.0 3600.0 8710.0 3600.0 8717.0 3632.0 8725.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: - EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 3650.0 8131.0 3 8131.0 8788.0 MERGED MAIN PASS. CN : BP EXPLORATION WN : MPL-17 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: 1 2 3 4 5 6 7 8 9 10 Name Tool Code Samples Units GR MWD 68 1 AAPI RPX MWD 68 1 OHMM RPS MWD 68 1 OHMM RPM MWD 68 1 OHMM RPD MWD 68 1 OHMM NPHI MWD 68 1 PU-S RHOB MWD 68 1 G/C3 DRHO MWD 68 1 G/C3 PEF MWD 68 1 BN/E ROP MWD 68 1 FPHR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 810 01 1 xl FET MWD 68 1 HR 4 4 90 180 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 496 44 Tape File Start Depth = 8800.000000 Tape File End Depth = 3600.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 124813 datums Tape Subfile: 2 578 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes ~'ape SUbfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE S~RY VENDOR TOOL CODE START DEPTH DGR 3600.0 EWR4 3600.0 CNP 3600.0 SLD 3632.0 $ 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 8077.0 8049.0 8056.0 8066.0 27-JAN-95 2.19a 3.93 MEMORY 8131.0 3650.0 8131.0 0 22.5 52.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD DENSITY DGR DUAL GAMMA RAY $ TOOL NUMBER P0317CRNSLDG6 P0317CRNSLDG6 P0317CRNSLDG6 P0317CRNSLDG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 8.500 3633.0 LSND 10.20 47.0 10.0 90O 5.6 .000 .000 .000 .000 .0 130.0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: SANDSTONE 2.65 HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MWD RUN 2. $ CN : BP EXPLORATION WN : MPL-17 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA .000 .0 0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 RHOB MWD 68 1 G/C3 4 8 DRHO MWD _ 68 1 G/C3 4 9 PE MWD 68 1 BN/E 4 10 ROP MWD 68 1 FPHR 4 11 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 810 01 1 4 90 180 01 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 434 Tape File Start Depth = 8150.000000 Tape File End Depth = 3600.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 109213 datums Tape Subfile: 3 503 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes -£ape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 8076.0 EWR4 8049.0 CNP 8056.0 SLD 8066.0 $ 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 8738.0 8710.0 8717.0 8725.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD DENSITY DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 30-JAN-95 2.19a 3.93 MEMORY 8788.0 8131.0 8788.0 0 26.3 29.9 TOOL NUMBER P0317CRNSLDG6 P0317CRNSLDG6 P0317CRNSLDG6 P0317CRNSLDG6 8.500 3633.0 LSND 10.20 49.0 9.0 900 5.0 .000 .000 .000 .000 .0 142.0 .0 .0 SANDSTONE 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MWD RUN 3 o $ CN : BP EXPLORATION WN : MPL-17 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA .000 .0 0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 RHOB MWD 68 1 G/C3 4 8 DRHO MWD 68 1 G/C3 4 9 PE MWD 68 1 BN/E 4 10 ROP MWD 68 1 FPHR 4 11 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 810 01 1 4 90 180 01 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 77 Tape File Start Depth = 8800.000000 Tape File End Depth = 8000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 144026 datums Tape Subfile: 4 146 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS 95/ 7/26 01 **** REEL TRAILER **** 95/ 7/27 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 27 JLY 95 8:39a Elapsed execution time = 15.11 seconds. SYSTEM RETURN CODE = 0
