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190-007
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: Install ESP 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 8,900 feet 8,780 feet true vertical 7,316 feet N/A feet Effective Depth measured 8,780 feet 8,394 feet true vertical 7,225 feet 6,930 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 8,318' 6,863' Packers and SSSV (type, measured and true vertical depth)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: Casing Conductor 8,836' 2,758'Surface Production 13-3/8" 9-5/8" 7" 80' 2,726' 8,868' MILNE PT UNIT L-03 Plugs Junk measured Length Burst Collapse measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-007 50-029-21999-00-00 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 N/A 0 00 336 80' 2,495' 1,474 320 3,520psi 7,240psi7,267' N/A N/A 2,020psi 5,410psi 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) 226 Gas-Mcf MD 80' 0 Size DLH Hydraulic Packer 7" x 3.5" 324-547 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 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 12:03 pm, Nov 27, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.11.26 12:57:52 - 09'00' Taylor Wellman (2143) WCB 2-11-2025 DSR-12/16/24 RBDMS JSB 120424 _____________________________________________________________________________________ Revised By: TDF 11/26/2024 SCHEMATIC Milne Point Unit Well: MPU L-03 Last Completed: 10/27/2024 PTD: 190-007 TD =8,900’ (MD) / TD = 7,316’(TVD) 13-3/8” Orig. KB Elev.: 32’(Nabors 33E) 7” 8&9 5, 6 & 7 10 & 11 12 19 14 Est. TOC @ 8,000’ 9-5/8” 4 13 PBTD =8,780’(MD) / PBTD = 7,225’(TVD) KUP B Silts KUP A Sands Arctic Pack 15 20 RA Tag @ 8,305’ 16, 17 & 18 TOF @ 8,763’ 1 2 3 ` CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / Weld 12.715 Surface 80' 0.157 9-5/8" Surface 36 / J-55 / Btc. 8.921 Surface 2,758’ 0.0773 7" Production 26 / L-80 / Hydril 563 6.276 Surface 8,868’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 3.958 Surface 8,318’ 0.0152 JEWELRY DETAIL No Depth Item 1 219’ Sta #2: 2-7/8" x 1" Patco GLM W/ BK-DPSOV 2 8,088’ Sta #1: 2-7/8" x 1" Patco GLM W/ BK-DGLV 3 8,178’ XN-Nipple 2.313” w/ 2.205” No-Go 4 8,230’ Discharge Head w/ Ported Sub : 513 Pmp & 513/538PX 5 8,232’ Pump #3: 538 PMSXD FLEX27 82 FER H6 6 8,249’ Pump #2: 538 PMSXD FLEX27 82 FER H6 7 8,267’ Pump #1: 538PMSXD 20 GINPSHH H6 STD 8 8,277’ Gas Separator: 538GM2T HV E V X MT HS FER 9 8,282’ Gas Intake: GPXARCINT FER H6 10 8,283’ Upper Tandem Seal: GS3 B/B/L SB H6 PFSA HL FER 12CRC 11 8,290’ Lower Tandem Seal: GS3 B/B/L SB H6 PFSA HL FER 12CRC 12 8,297’ Motor: 562XP 250/2505/61, 125/2020 10R 12CRC 13 8,314’ Sensor & Centralizer: Bottom @ 8,318 14 8,391’ On/ Off Overshot w/ 5.88” Gauge Ring / Scoop Guide 15 8,394’ 7” DLH Hydraulic Packer 3-1/*2” EUE 8rd BxP 16 8,410’ 3-1/2” Halliburton Auto Fill 17 8,413’ 3-1/2” Halliburton Mirage Plug 18 8,432’ 3-1/2” HES Shear Sub 50k Pull BxP EUE 8rd 19 8,436’ 4-1/8” 250 Micron Screen 3-1/2” NU 9.2# L-80 20 8,499.5’ 3-1/2” NU Bull Plug - Bottom @ 8,500’MD / 7,011’ TVD PERFORATION DETAIL KUP Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status B silts 8,508’ 8,552’ 7,017’ 7,051’ 44 10/2/1990 Open A3 8,601’ 8,627’ 7,089’ 7,108’ 26 10/2/1990 Open A2 8,634’ 8,662’ 7,114’ 7,135’ 28 10/2/1990 Open A1 8,674’ 8,704’ 7,144’ 7,167’ 30 10/2/1990 Open OPEN HOLE / CEMENT DETAIL 13-3/8" ±500 sks Permafrost “C”in 30” Hole 9-5/8" 377bbl class ‘E’, 84bbl Class ‘G’ in 12-1/4” Hole 7” 48bbl Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 41.35 deg. @ 4,000’ Max Hole Angle through perforations = 40 deg. Max DLS =5.68 deg. @ 3,256’ MD TREE & WELLHEAD Tree 2-9/16” 5M FMC Wellhead 11” 5M FMC w/ 11” 2-7/8” WKM Tubing Hanger w/ 2-7/8” EUE 8rd , 2-1/2” CIW “H” BPV profile GENERAL WELL INFO API: 50-029-21999-00-00 Drilled, Cased and Comp. by Nabors 33E - 10/14/1990 ESP RWO – 4/18/1994 ESP RWO by Polar #1– 7/96 ESP RWO by Nabors 4ES – 2/17/99, 12/30/00 & 5/9/04 ESP RWO by Nabors 3S – 5/2/07, 2/1/08 & 10/25/08 ESP RWO by Nabors 4ES – 3/18/2010 ESP RWO w/ Packer and Screens by Doyon 16 – 12/22/2011 ESP RWO by Nordic – 1/10/2016 ESP RWO by Doyon 14 – 2/11/17 TTESP Replacement – 8/26/2024 ESP Install – 10/27/2024 STIMULATION SUMMARY Well Frac’d @ 40bpm w/ 1,521bbls gel w/ 147,022 lbs 16-20 carbolite proppant. NOTE 7” Casing tested to 3,500psi above 8,460’ on 1/5/2012 Well Name Rig API Number Well Permit Number Start Date End Date MP L-03 ASR#1 50-029-21999-00-00 190-007 10/21/2024 10/28/2024 10/18/2024 - Friday No operations to report. 10/16/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 10/17/2024 - Thursday No operations to report. Cont. testing as per approved sundry. Complete failed test # 1 & 2 with 2-7/8" test mandrel. Test t/ 250 psi low & 2,500 psi high f/ 5/5 charted mins. Completed testing with 3 F/P tests.P/U tee bar. Pull CTS & BPV. TBG on a vacuum. BOLDS. P/U on hanger t/ 140K. Set hanger back down on profile. Lock in. Remove landing joint & shut blinds. RU CSG jacks. Pull hanger w/ 70k, 150k travelling weight. Disconnect ESP and 3/8" Control line. LD hanger. POOH F/ 8,275' - T/ 7,550'. No operations to report. 10/19/2024 - Saturday Accepted Rig at 02:00 on 10-21-2024. Begin testing BOPE as per approved sundry. AOGCC waived witness to testing. Test t/ 250 psi low & 2500 psi high f/ 5/5 charted mins. Testing & working through failures. (K5) leaking C/O. K2 valve leaking, change out. Retorque bolts. Attempted to test. Leak persist. Tightened lock down screws. Determined CTS plug & BPV. Installed landing JT isolating BPV profile. Achieved good test w/ landing jt in. Pull CTS & BPV. Install new with wellhead Rep. Shell test BOPE. Good test. Cont. Test BOPE as per approved sundry. Completed testing with 4- 1/2" test mandrel for six tests with two F/P tests. Switch over to 2-7/8" Test mandrel. Cont. testing. 10/22/2024 - Tuesday 10/20/2024 - Sunday No operations to report. 10/21/2024 - Monday Begin testing BOPE as per approved sundry. AOGCC waived witness to testing. Test t/ 250 psi low & 2500 psi high f/ 5/5 charted mins. Testing & working through failures. (K5) leaking C/O. K2 valve leaking, change out. Retorque bolts. Attempted to test. Leak persist. Tightened lock down screws. Determined CTS plug & BPV. Installed landing JT isolating BPV profile. Achieved good test w/ landing jt in. Pull hanger w/ 70k, 150k travelling weight. Disconnect ESP and 3/8" Control line. LD hanger. POOH Well Name Rig API Number Well Permit Number Start Date End Date MP L-03 ASR#1 & WH 50-029-21999-00-00 190-007 10/21/2024 10/28/2024 10/25/2024 - Friday Continue RIH w/ BHA: 6.125" Junk Mill, 2 boot baskets, 7" scraper, 7" AS1X test packer. 3-1/2",10.37#, G-105, NC31 workstring F/ 4,235'. Work scraper to 8,316'. No issues. Reverse circ. 2x BU - 3bpm at 400psi, 157bbls total. Obtained trace amounts of sand at 104bbls. Circulate until clean. Park packer at 8,290' COE and set w/ 3 RH turns, stack 30k to confirm set. Fill IA and test CSG to 1,900psi for 30 charted min - Good. POOH and LD BHA maintaining 1x displacement. PU and service ESP motor. PU/MU seals. 10/23/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continue POOH on elevators F/ 7,550' - T/ 7,493'. PUW remained 124k 5-8k drag. Cut and secure ESP cable and C/L. Install landing joint. Land Hanger 52k SOW. RILDS. RD CSG jacks. POOH F/ 7,493' - T/ 7,112' Lost 12k PUW vs 4.8k calculated. POOH T/ 4,009' maintaining 1x displacement. 10/24/2024 - Thursday Continue POOH on elevators F/ 4,009' maintaining 1x displacement. Encounter light scale from 4,787' becoming heavy 5,028' MD. BO/LD ESP assembly. Recovered: 203 CC clamps - 3 Protectolizers - 2 Flat guards - 2 carbon bands. Scale from bottom of upper seal to bottom of motor. PU/MU YJOS BHA: 6.125" Junk Mill, 2 boot baskets, 7" scraper, 7" AS1X test packer. RIH w/ 3- 1/2",10.37#, G-105, NC31 workstring T/ 4,235'. No operations to report. Continue assembling ESP components and test - good. RIH w/ 2-7/8", 6.5#,L, EUE R2 ESP Completion. Install clamps first 10 connections, every other after. Test ESP systems every 1,000'. Cable Splice at 1,115' - 1,118' MD. Final tests on ESP systems - Good. Land hanger while monitoring. RILDS. FINAL PUW = 67k, SOW = 45k. 10/26/2024 - Saturday N/U tree/adaptor after N/D BOP, torqued adaptor and test void 500 low 5000 high 5/10 mins (good test) Pulled BPV with T- bar and secure tree. 10/29/2024 - Tuesday 10/27/2024 - Sunday Rig Down ASR-1. Rig released 12:00 10/27/2024. Continue RDMO on MPL-60 WSR. M/U tubing hanger to LJ then to string pre- set BPV, S/B for ESP splice to penetrator, land hanger to RKB of 15.94 and RILDS 10/28/2024 - Monday 1900 psi csg test is a COA of Sundry 324-547. -WCB RILDS Continue assembling ESP components and test - good. RIH w/ 2-7/8", 6.5#,L, EUE R2 ESP Completion Continue POOH on elevators F/ 7,550' - T/ 7,493'. Fill IA and test CSG to 1,900psi for 30 charted min - Good. POOH Continue POOH on elevators F/ 4,009 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: 9/27/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240927 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14B 50133205390200 222057 8/14/2024 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 8/18/2024 YELLOWJACKET PERF BRU 214-13 50283201870000 222117 9/13/2024 AK E-LINE Perf BRU 221-26 50283202010000 224098 9/9/2024 AK E-LINE CBL BRU 222-26 50283201950000 224035 8/20/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 9/14/2024 AK E-LINE CBL END 1-61 50029225200000 194142 9/11/2024 READ CaliperSurvey KBU 32-06 50133206580000 216137 8/6/2024 YELLOWJACKET PERF MPU B-24 50029226420000 196009 9/9/2024 READ CaliperSurvey MPU L-03 50029219990000 190007 9/18/2024 READ CaliperSurvey MPU R-103 50029237990000 224114 9/16/2024 AK E-LINE TubingCut MPU R-103 50029237990000 224114 9/19/2024 AK E-LINE TubingCut MRU M-02 50733203890000 187061 9/17/2024 AK E-LINE Plug NCIU A-19 50883201940000 224026 9/20/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 9/13/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 9/15/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 8/18/2024 AK E-LINE CBL NCIU A-20 50883201960000 224065 9/11/2024 AK E-LINE PPROF NCIU A-20 50883201960000 224065 8/26/2024 READ MemoryRadialCementBondLog PBU 09-27A 50029212910100 215206 9/13/2024 AK E-LINE CBL/TubingPunch PBU 09-34A 50029213290100 193201 12/31/2023 YELLOWJACKET PL PBU 13-24B 50029207390200 224087 8/21/2024 YELLOWJACKET CBL-PERF PBU 13-24B 50029207390200 224087 8/23/2024 YELLOWJACKET CBL PBU 13-26 50029207460000 182074 8/13/2024 YELLOWJACKET CCL PBU NK-26A 50029224400100 218009 7/20/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T39593 T39594 T39595 T39596 T39597 T39598 T39599 T39600 T39601 T39602 T39603 T39603 T39604 T39605 T39605 T39605 T39605 T39606 T39606 T39607 T39608 T39609 T39609 T39610 T39611 MPU L-03 50029219990000 190007 9/18/2024 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.27 14:47:28 -08'00' 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: Install TTCESP 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 8,900 feet 8,780 feet true vertical 7,316 feet N/A feet Effective Depth measured 8,780 feet 8,394 feet true vertical 7,225 feet 6,930 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 / Hydril 8,275' 6,830' Packers and SSSV (type, measured and true vertical depth)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: DLH Hydraulic Packer 7" x 3.5" 324-178 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 9 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 80' 320 Size 80' 2,495' 0800 51 3361,022 334 measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-007 50-029-21999-00-00 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-03 Plugs Junk measured LengthCasing Conductor 8,836' 2,758'Surface Production 13-3/8" 9-5/8" 7" 80' 2,726'3,520psi 7,240psi8,868' 7,267' Burst N/A Collapse N/A 2,020psi 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 1:37 pm, Sep 23, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.09.23 08:12:32 - 08'00' Taylor Wellman (2143) RBDMS JSB 100124 WCB 12-2-2024 DSR-9/27/24 _____________________________________________________________________________________ Revised By: TDF 9/20/2024 SCHEMATIC Milne Point Unit Well: MPU L-03 Last Completed: 8/26/2024 PTD: 190-007 TD =8,900’ (MD) / TD = 7,316’(TVD) 13-3/8” Orig. KB Elev.: 32’(Nabors 33E) 7” 6 3, 4 & 5 7 &8 9 11 17 12 Est. TOC @ 8,000’ 9-5/8” 1 10 PBTD =8,780’(MD) / PBTD = 7,225’(TVD) KUPBSilts 2 KUP A Sands Arctic Pack 13 14 18 RA Tag @ 8,305’ 15 & 16 TOF @ 8,763’ ` CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / Weld 12.715 Surface 80' 0.157 9-5/8" Surface 36 / J-55 / Btc. 8.921 Surface 2,758’ 0.0773 7" Production 26 / L-80 / Hydril 563 6.276 Surface 8,868’ 0.0383 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / Hydril 521 3.958 Surface 8,275’ 0.0152 JEWELRY DETAIL No Depth Item 1 8,162’ D&D Packoff & Stinger assembly 2 8,163’ Pump, Discharge head, Hanger receptacle 3 8,164’ Pump 380 SXD 116-P18UT 4 8,186’ P2P Pump 380 SXD 116-Flex 17.5 5 8,207’ P2P Pump 380 SXD 116-Flex 17.5 6 8,233’ TTC Drilled Tubing Crossover 7 8,243’ Upper Tandem Seal - GSB3 DB HL H6 PFS 8 8,250’ Lower Tandem Seal - GSB3 DB HL H6 PFS 9 8,257’ Motor – CL-5 XP-200 10 8271’ Sensor – Phoenix XT150 Type O 11 8,273’ 6 Fin Centralizer –Bottom @ 8,275’ 12 8,391’ On/ Off Overshot w/ 5.88” Gauge Ring / Scoop Guide 13 8,394’ 7” DLH Hydraulic Packer 3-1/*2” EUE 8rd BxP 14 8,410’ 3-1/2” Halliburton Auto Fill 15 8,413’ 3-1/2” Halliburton Mirage Plug 16 8,432’ 3-1/2” HES Shear Sub 50k Pull BxP EUE 8rd 17 8,436’ 4-1/8” 250 Micron Screen 3-1/2” NU 9.2# L-80 18 8,499.5’ 3-1/2” NU Bull Plug - Bottom @ 8,500’MD / 7,011’ TVD PERFORATION DETAIL KUP Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status B silts 8,508’ 8,552’ 7,017’ 7,051’ 44 10/2/1990 Open A3 8,601’ 8,627’ 7,089’ 7,108’ 26 10/2/1990 Open A2 8,634’ 8,662’ 7,114’ 7,135’ 28 10/2/1990 Open A1 8,674’ 8,704’ 7,144’ 7,167’ 30 10/2/1990 Open OPEN HOLE / CEMENT DETAIL 13-3/8" ±500 sks Permafrost “C”in 30” Hole 9-5/8" 377bbl class ‘E’, 84bbl Class ‘G’ in 12-1/4” Hole 7” 48bbl Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 41.35 deg. @ 4,000’ Max Hole Angle through perforations = 40 deg. Max DLS =5.68 deg. @ 3,256’ MD TREE & WELLHEAD Tree 2-9/16” 5M FMC Wellhead 11” 5M FMC w/ 11” 2-7/8” WKM Tubing Hanger w/ 2-7/8” EUE 8rd , 2-1/2” CIW “H” BPV profile GENERAL WELL INFO API: 50-029-21999-00-00 Drilled, Cased and Comp. by Nabors 33E - 10/14/1990 ESP RWO – 4/18/1994 ESP RWO by Polar #1– 7/96 ESP RWO by Nabors 4ES – 2/17/99, 12/30/00 & 5/9/04 ESP RWO by Nabors 3S – 5/2/07, 2/1/08 & 10/25/08 ESP RWO by Nabors 4ES – 3/18/2010 ESP RWO w/ Packer and Screens by Doyon 16 – 12/22/2011 ESP RWO by Nordic – 1/10/2016 ESP RWO by Doyon 14 – 2/11/17 TTESP Replacement - 8/26/2024 STIMULATION SUMMARY Well Frac’d @ 40bpm w/ 1,521bbls gel w/ 147,022 lbs 16-20 carbolite proppant. NOTE 7” Casing tested to 3,500psi above 8,460’ on 1/5/2012 Well Name Rig API Number Well Permit Number Start Date End Date MP L-03 SL & CTU 50-029-21999-00-00 190-007 8/15/2024 8/26/2024 8/16/2024 - Friday MIRU. Perform weekly BOP test - 250/4000psi. Passing test. Perfrom Slip test. Passing test. MU BOT fishing BHA (Jars+4" GS only). 8/14/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 8/15/2024 - Thursday WELL S/I UPON ARRIVAL. SPOT IN UNIT. INSPECT LOC. PJSM. TS=.125" WIRE, 5',KJ,5',KJ,5' x 1 7/8" R.STEM (2.6" wheels), OJ, KJLSS. PT PCE 300psi LOW / 3700psi HIGH **PASS**. RIH W/ 2' x 1 7/8" STEM, 3.80" GAUGE RING. SD @ 8,152' SLM. RIH W/ 4 1/2" GR (steel). LATCH TUBING STOP @ 8,153' SLM, PULL STOP. MAKE 2 RUNS W/ 4-1/2 GR TO PACKOFF AT 8,153' SLM TOTAL JAR TIME 65 MIN. No operations to report. RIH w/4" GS, latch into packoffs/spacer pipe at 8156'. Retrieved packoff/spacer pipe. RIH to latch upper ESP section.POOH. Recover top pump. RBIH w/ 4" GS. Not able to latch. POOH. RIH w/ 3" GS. Tag 8196' CTM. Latch and pull the pump. Rig pump down , Rig up new pump w/ 3" GS. Load the well 318bbl of 1% KCL. RIH with pump #1. Land pump #1 at 8222 CTMD. Pump off and POOH pumping pipe displacement + MCHF. Pressure test safety joint, bump test H2S/LEL monitors, and hold well control drill - kick while deploying. Flow check well at surface - no flow. Swap to 4" GS and deploy both sections of the upper pump assembly. 8/17/2024 - Saturday No operations to report. 8/20/2024 - Tuesday 8/18/2024 - Sunday RIH w/4" GS and both sections of the upper pump assembly. Tagged at 8152 CTM consistently. Pump off of final pump sections. POOH and freeze protect tubing with 42.5 bbl of diesel and IA with 52 bbl diesel. POOH. RDMO. 8/19/2024 - Monday Rig up new pump w/ 3" GS. Load the well 318bbl of 1% KCL. RIH with pump #1. Land pump #1 at 8222 CTMD. Pump off and POOH pumping pipe displacement RIH w/4" GS, latch into packoffs/spacer pipe at 8156'. Retrieved packoff/spacer pipe. RIH to latch upper ESP section.POOH. Recover top pump. RBIH w/ 4" GS. Not able to latch. POOH. RIH w/ 3" GS. Tag 8196' CTM. Latch and pull the pump RIH w/4" GS and both sections of the upper pump assembly. Tagged at 8152 CTM consistently. Pump off of final pump sections. POOH and freeze protect tubing with 42.5 bbl of diesel and IA with 52 bbl diesel. POOH. RDMO. Well Name Rig API Number Well Permit Number Start Date End Date MP L-03 SL & CTU 50-029-21999-00-00 190-007 8/15/2024 8/26/2024 8/23/2024 - Friday WELL SHUT-IN ON ARRIVAL. MADE 2 RUNS TO 8,140' SLM W/ 2.94" X MAGNET (recovered ~5 cups of metal shavings) 8/21/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 8/22/2024 - Thursday No operations to report. No operations to report. RAN 4-1/2" DOGLESS GS TO ESP @ 8,177' MD. RIG-DOWN SLICKLINE AND RIG-UP 3/16" BRAIDED LINE. RECOVER 2 x 20' UPPER ESP PUMP SECTIONS FROM 8,012' BLM. (Missing shipping sleeve). RAN 3.7 LIB TO TOP OF LOWER ESP SECTION @ 8,049' BLM. MADE 2 ATTEMPTS TO FISH SHIPPING SLEEVE FROM TOP OF LOWER SECTION OF ESP @ 8,049' BLM. 8/24/2024 - Saturday RAN ESP TEST TOOL TO LOWER PUMP SECTION @ 8,174' BLM. SET LOWER PUMP ASSEMBLY IN ESP AT 8,174' BLM. SET UPPER 2 SECTIONS OF PUMP ASSEMBLY @ 8,102' BLM. SET 4-1/2" D&D PACKOFF W/ STINGER ASSEMBLY (oal - 90"). AT 8,095' BLM. SET 4-1/2" TUBING STOP (oal - 23"). AT 8,093' BLM. WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED. 8/27/2024 - Tuesday 8/25/2024 - Sunday MAKE 3 ATTEMPTS TO FISH SHIPPING SLEEVE AT 8,147' BLM (See log). PULL LOWER SECTION OF ESP FROM 8,147' BLM. 8/26/2024 - Monday 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: Install ESP 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): 8,900'N/A Casing Collapse Conductor N/A Surface 2,020psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: 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 KUPARUK RIVER OIL N/A 7,316' 8,780' 7,225' 1,980 8,780' Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT L-03 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/15/2024 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 190-007 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21999-00-00 Hilcorp Alaska LLC C.O. 816 Length Size Proposed Pools: 80' 80' 12.6# / L-80 / Hydril TVD Burst 8,275' MILNE POINT MD N/A 3,520psi 7,240psi 2,495' 7,267' 2,758' 8,868' 80' 13-3/8" 9-5/8" 7" 2,726' 8,836' DLH Hydraulic Packer 7" x 3.5" and N/A 8,394' MD / 6,930' TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Perforation Depth MD (ft): See Schematic See Schematic 4-1/2" No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:16 pm, Sep 23, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.09.23 11:23:36 - 08'00' Taylor Wellman (2143) 324-547 * BOPE test to 2500 psi. * IC casing test to 1900 psi to be charted and recorded (not witnesses by AOGCC). MGR03OCT2024 10-404 DSR-9/27/24SFD 10/4/2024JLC 10/4/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.10.07 13:42:59 -08'00' 10/7/24 RBDMS JSB 100824 Well: MPL-03 PTD: 190-007 API: 50-029-21999-00-00 Well Name:MPL-03 API Number:50-029-21999-00-00 Current Status:Shut-in ESP Rig:ASR #1 Estimated Start Date:10/15/2024 Estimated Duration:7 days Regulatory Contact:Tom Fouts Permit to Drill Number:190-007 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: 2663 psi @ 6,834’ TVD 8/27/2024 | 7.6 EMW, 7.8 KWF Max Potential Surface Pressure: 1,980 psi Gas Column Gradient (0.1 psi/ft) Max Angle:42° at 4,200’ MD Brief Well Summary: MPL-03 was drilled in January 1990, fracture stimulated and completed in October of 1990 as a Kuparuk River producer. ESP installation history: October 1990 (initial), May 1994, July 1996, February 1999, December 2000, May 2004, May 2007, January 2008, October 2008, March 2010, January 2012, and January 2016. The ESP has slowly lost efficiency over the previous year. We replaced the thru tubing pumps went to start it up and shorted electrically downhole. We plan to pull the assembly and run a conventional ESP. Objectives: Pull failed ESP completion, run test packer, MIT-IA and run new ESP completion. Notes Regarding Wellbore Condition: - 7” casing test to 3,500 psi on 1/5/2012 at 8,460’ MD. 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 produced 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 produced water. 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. a. Rig up casing jacks in case we need them since the last up weight recorded was 150Kip when you account for the Doyon 14 block weight. Well: MPL-03 PTD: 190-007 API: 50-029-21999-00-00 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. 3. Test BOPE to 250 psi low/ 2,500 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 4-1/2” 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 produced water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out Centrilift for TTCESP 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 BPV profile is 4” H-type, 4-1/2” NSTC x 4-1/2” Hyd 521 bottom. b. 2017 tubing PU weight on Doyon 14 recorded as 190kip. Slack off weight recorded as 90 kip. Block weight of 40 kip. c. 4-1/2” L-80 EUE yield is 208 kip. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 4-1/2” tubing. a. Wash and toss all the 4-1/2” tubing b. Keep TTCESP parts 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. Canon Clamps: 203 ii. Flat guards: 2 iii. Protectolizers: 3 iv. Carbon steel bands: 2 v. 4” Flat Clamps: 2 10. Lay Down ESP. If the ESP comes out clean, then go straight to the test packer run step 15. 11.Contingency: a. PU 3-1/2” workstring, 7” casing scraper, and muleshoe. RIH to 8,300’ MD. b. Circulate well clean. c. Scrape casing interval from 8,200’ to 8,300’ MD. d. POOH while filling hole with 2x displacement. 12. RU SL 13. RIH 7” Evotrieve and set at 8,250’ MD. 14. Test 7” casing to 1,900 psi for 30 minutes. Well: MPL-03 PTD: 190-007 API: 50-029-21999-00-00 15. RIH with Braided line to retrieve Evotrieve. 16. After you release the plug and confirm it is moving, stop and let the rubbers relax for 30 min, then POOH. 17. RIH with new 2-7/8” 6.5# L-80 ESP completion to +/- 8,300’ 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 Nom. Size Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 4.5 2 Intake Sensor 30 5.62 34 Motor - 250HP 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 8 Gas Separator 52 5.38 25 Pumps – GINPSHH 24 stg 45 5.38 57 Pumps – Flex-27 82 stg 45 5.38 57 Pumps – Flex-27 82 stg 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 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" 7,725 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, 1/4" OV 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 18. Land tubing hanger. Use extra caution to not damage cable. 19. Lay down landing joint. 20. Set BPV. 21. RDMO ASR. Well: MPL-03 PTD: 190-007 API: 50-029-21999-00-00 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. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Double BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 9/20/2024 SCHEMATIC Milne Point Unit Well: MPU L-03 Last Completed: 8/26/2024 PTD: 190-007 TD =8,900’ (MD) / TD = 7,316’(TVD) 13-3/8” Orig. KB Elev.: 32’(Nabors 33E) 7” 6 3, 4 & 5 7 &8 9 11 17 12 Est. TOC @ 8,000’ 9-5/8” 1 10 PBTD =8,780’(MD) / PBTD = 7,225’(TVD) KUPBSilts 2 KUP A Sands Arctic Pack 13 14 18 RA Tag @ 8,305’ 15 & 16 TOF @ 8,763’ ` CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / Weld 12.715 Surface 80' 0.157 9-5/8" Surface 36 / J-55 / Btc. 8.921 Surface 2,758’ 0.0773 7" Production 26 / L-80 / Hydril 563 6.276 Surface 8,868’ 0.0383 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / Hydril 521 3.958 Surface 8,275’ 0.0152 JEWELRY DETAIL No Depth Item 1 8,162’ D&D Packoff & Stinger assembly 2 8,163’ Pump, Discharge head, Hanger receptacle 3 8,164’ Pump 380 SXD 116-P18UT 4 8,186’ P2P Pump 380 SXD 116-Flex 17.5 5 8,207’ P2P Pump 380 SXD 116-Flex 17.5 6 8,233’ TTC Drilled Tubing Crossover 7 8,243’ Upper Tandem Seal - GSB3 DB HL H6 PFS 8 8,250’ Lower Tandem Seal - GSB3 DB HL H6 PFS 9 8,257’ Motor – CL-5 XP-200 10 8271’ Sensor – Phoenix XT150 Type O 11 8,273’ 6 Fin Centralizer –Bottom @ 8,275’ 12 8,391’ On/ Off Overshot w/ 5.88” Gauge Ring / Scoop Guide 13 8,394’ 7” DLH Hydraulic Packer 3-1/*2” EUE 8rd BxP 14 8,410’ 3-1/2” Halliburton Auto Fill 15 8,413’ 3-1/2” Halliburton Mirage Plug 16 8,432’ 3-1/2” HES Shear Sub 50k Pull BxP EUE 8rd 17 8,436’ 4-1/8” 250 Micron Screen 3-1/2” NU 9.2# L-80 18 8,499.5’ 3-1/2” NU Bull Plug - Bottom @ 8,500’MD / 7,011’ TVD PERFORATION DETAIL KUP Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status B silts 8,508’ 8,552’ 7,017’ 7,051’ 44 10/2/1990 Open A3 8,601’ 8,627’ 7,089’ 7,108’ 26 10/2/1990 Open A2 8,634’ 8,662’ 7,114’ 7,135’ 28 10/2/1990 Open A1 8,674’ 8,704’ 7,144’ 7,167’ 30 10/2/1990 Open OPEN HOLE / CEMENT DETAIL 13-3/8" ±500 sks Permafrost “C”in 30” Hole 9-5/8" 377bbl class ‘E’, 84bbl Class ‘G’ in 12-1/4” Hole 7” 48bbl Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 41.35 deg. @ 4,000’ Max Hole Angle through perforations = 40 deg. Max DLS =5.68 deg. @ 3,256’ MD TREE & WELLHEAD Tree 2-9/16” 5M FMC Wellhead 11” 5M FMC w/ 11” 2-7/8” WKM Tubing Hanger w/ 2-7/8” EUE 8rd , 2-1/2” CIW “H” BPV profile GENERAL WELL INFO API: 50-029-21999-00-00 Drilled, Cased and Comp. by Nabors 33E - 10/14/1990 ESP RWO – 4/18/1994 ESP RWO by Polar #1– 7/96 ESP RWO by Nabors 4ES – 2/17/99, 12/30/00 & 5/9/04 ESP RWO by Nabors 3S – 5/2/07, 2/1/08 & 10/25/08 ESP RWO by Nabors 4ES – 3/18/2010 ESP RWO w/ Packer and Screens by Doyon 16 – 12/22/2011 ESP RWO by Nordic – 1/10/2016 ESP RWO by Doyon 14 – 2/11/17 TTESP Replacement - 8/26/2024 STIMULATION SUMMARY Well Frac’d @ 40bpm w/ 1,521bbls gel w/ 147,022 lbs 16-20 carbolite proppant. NOTE 7” Casing tested to 3,500psi above 8,460’ on 1/5/2012 _____________________________________________________________________________________ Revised By: TDF 9/20/2024 PROPOSED Milne Point Unit Well: MPU L-03 Last Completed: 8/26/2024 PTD: 190-007 TD =8,900’ (MD) / TD = 7,316’(TVD) 13-3/8” Orig. KB Elev.: 32’(Nabors 33E) 7” 5 2,3&4 6 & 7 8 16 11 Est. TOC @ 8,000’ 9-5/8” 1 9 & 10 PBTD =8,780’(MD) / PBTD = 7,225’(TVD) KUP B Silts KUP A Sands Arctic Pack 12 17 RA Tag @ 8,305’ 13, 14 & 15 TOF @ 8,763’ ` CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / Weld 12.715 Surface 80' 0.157 9-5/8" Surface 36 / J-55 / Btc. 8.921 Surface 2,758’ 0.0773 7" Production 26 / L-80 / Hydril 563 6.276 Surface 8,868’ 0.0383 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / Hydril 521 3.958 Surface 8,275’ 0.0152 JEWELRY DETAIL No Depth Item 1 ±X,XXX’ Discharge Head : Ported 2 ±X,XXX’ Pump #3: 3 ±X,XXX’ Pump #2: 4 ±X,XXX’ Pump #1: 5 ±X,XXX’ Gas Separator: 6 ±X,XXX’ Upper Tandem Seal: 7 ±X,XXX’ Lower Tandem Seal: 8 ±X,XXX’ Motor: 9 ±X,XXX’ Sensor: 10 ±X,XXX’ 6 Fin Centralizer – Bottom @ ±X,XXX’ 11 8,391’ On/ Off Overshot w/ 5.88” Gauge Ring / Scoop Guide 12 8,394’ 7” DLH Hydraulic Packer 3-1/*2” EUE 8rd BxP 13 8,410’ 3-1/2” Halliburton Auto Fill 14 8,413’ 3-1/2” Halliburton Mirage Plug 15 8,432’ 3-1/2” HES Shear Sub 50k Pull BxP EUE 8rd 16 8,436’ 4-1/8” 250 Micron Screen 3-1/2” NU 9.2# L-80 17 8,499.5’ 3-1/2” NU Bull Plug - Bottom @ 8,500’MD / 7,011’ TVD PERFORATION DETAIL KUP Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status B silts 8,508’ 8,552’ 7,017’ 7,051’ 44 10/2/1990 Open A3 8,601’ 8,627’ 7,089’ 7,108’ 26 10/2/1990 Open A2 8,634’ 8,662’ 7,114’ 7,135’ 28 10/2/1990 Open A1 8,674’ 8,704’ 7,144’ 7,167’ 30 10/2/1990 Open OPEN HOLE / CEMENT DETAIL 13-3/8" ±500 sks Permafrost “C”in 30” Hole 9-5/8" 377bbl class ‘E’, 84bbl Class ‘G’ in 12-1/4” Hole 7” 48bbl Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 41.35 deg. @ 4,000’ Max Hole Angle through perforations = 40 deg. Max DLS =5.68 deg. @ 3,256’ MD TREE & WELLHEAD Tree 2-9/16” 5M FMC Wellhead 11” 5M FMC w/ 11” 2-7/8” WKM Tubing Hanger w/ 2-7/8” EUE 8rd , 2-1/2” CIW “H” BPV profile GENERAL WELL INFO API: 50-029-21999-00-00 Drilled, Cased and Comp. by Nabors 33E - 10/14/1990 ESP RWO – 4/18/1994 ESP RWO by Polar #1– 7/96 ESP RWO by Nabors 4ES – 2/17/99, 12/30/00 & 5/9/04 ESP RWO by Nabors 3S – 5/2/07, 2/1/08 & 10/25/08 ESP RWO by Nabors 4ES – 3/18/2010 ESP RWO w/ Packer and Screens by Doyon 16 – 12/22/2011 ESP RWO by Nordic – 1/10/2016 ESP RWO by Doyon 14 – 2/11/17 TTESP Replacement –8/26/2024 STIMULATION SUMMARY Well Frac’d @ 40bpm w/ 1,521bbls gel w/ 147,022 lbs 16-20 carbolite proppant. NOTE 7” Casing tested to 3,500psi above 8,460’ on 1/5/2012 Updated 9/20/2024 11” BOPE INTEGRATED 11'͛-5000 INTEGRATED 4.30'INTEGRATED 11" - 5000 2-7/8" x 5" VBR Blind 11'͛- 5000 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManual Stripping Head ManualManual 5-1/2" Pipe Ram Milne Point ASR 11” BOP w/ Jacks 05/17/2017 Milne Point ASR 11” BOP (Triple) 9/20/2024 Superceded Milne Point ASR Rig 1 BOPE 2024 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Rams Blin d11'’- 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 HCRManualManual Stripping Head Manual 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: Install TTCESP 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): 8,900'N/A Casing Collapse Conductor N/A Surface 2,020psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: 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 DLH Hydraulic Packer 7" x 3.5" and N/A 8,394' MD / 6,930' TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Perforation Depth MD (ft): See Schematic See Schematic 4-1/2" 80' 13-3/8" 9-5/8" 7" 2,726' 8,836' MD N/A 3,520psi 7,240psi 2,495' 7,267' 2,758' 8,868' Length Size Proposed Pools: 80' 80' 12.6# / L-80 / Hydril TVD Burst 8,275' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 190-007 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21999-00-00 Hilcorp Alaska LLC C.O. 432E AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 4/1/2024 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT L-03 MILNE POINT KUPARUK RIVER OIL N/A 7,316' 8,780' 7,225' 1,038 8,780' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Coldiron at 7:52 am, Mar 26, 2024 324-178 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.03.22 15:28:55 - 08'00' Taylor Wellman (2143) 10-404 A.Dewhurst 26MAR24 * Approved for open hole deployment/undeployment with well fully displaced (T and IA) to KWF. MGR04APR21 DSR-4/12/24JLC 4/12/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.12 15:34:59 -08'00'04/12/24 RBDMS JSB 041624 TTCͲESPPumpSectionSwap Well:MPULͲ03 PTD:190Ͳ007 API:50Ͳ029Ͳ21999Ͳ00Ͳ00 WellName:MPULͲ03APINumber:50Ͳ029Ͳ21999Ͳ00Ͳ00 CurrentStatus:ProducerPad:LͲPad EstimatedStartDate:4/1/24Rig:CT Reg.ApprovalReq’d?YesDateReg.ApprovalRec’vd: RegulatoryContact:TomFoutsPermittoDrillNumber:190Ͳ007 FirstCallEngineer:RyanLewis(303)906Ͳ5178(M) SecondCallEngineer:TaylorWellman(907)777Ͳ8449(O)(907)947Ͳ9533(M) AFENumber:JobType:TTCͲESPPumpSwap CurrentBottomHolePressure:1,964psi@6,834’TVDDownholeGauge42hrSI|5.6PPG5.8KWF Max.AnticipatedSurfacePressure:1,038psi(Basedon0.1psi/ft.gasgradient) MaxAngle:41.3°@4,000’MD MaxDogleg: 5.68°/100ft@3,256’MD BriefWellSummary: MPLͲ03wasdrilledinJanuary1990,fracturestimulatedandcompletedinOctoberof1990asaKuparukRiver producer.ESPinstallationhistory:October1990(initial),May1994,July1996,February1999,December2000, May2004,May2007,January2008,October2008,March2010,January2012,andJanuary2016.TheESPhas slowlylostefficiencyoverthepreviousyear.BHPincreased125psi(825psito950psi).Wewillproactively replace. Objectives: CTtopullTTCESP,4runs.Openholedeploytandemmotorsonrun#2.InstallnewTTCESP,4runs. NotesRegardingtheWell&Design x 1/5/20123,500psigoodpressuretest.CasingtestrequiredatnextRWO. Procedure: Slickline: 1. MIRUSL.PTlubricatorto200psiglow,2,500psighigh. 2. Driftandtagthetubingstopwithsamplebailer. 3. RIHwithGSretrievingheadtoretrievetubingstop. 4. RIHwithGSretrievingheadtoretrievepackoff. 5. RDMO. CoiledTubing Notes: x DuetothenecessaryopenholedeploymentofanExtendedBHA,24ͲhourcrewandWSScoverageis required. x ThewellwillbekilledandmonitoredbeforerecoveryoftheTTCͲESPpumpsections.Thiswillbedone priortoPOOHfromtherecoveryofthepackoff.Thiswillprovideguidanceastowhetherthewellwill bekilledbybullheadingorcirculatingbottomsupthroughoutthejob–ForMPULͲ03thewellwillbe circulatedbottomsuptoavoidpossibilityofchargingtheKuparukFormationwhilebullheadingan entirewellvolume. TTCͲESPPumpSectionSwap Well:MPULͲ03 PTD:190Ͳ007 API:50Ͳ029Ͳ21999Ͳ00Ͳ00 1. MIRUCoiledTubingUnitwith1.75”coiledtubingandspotancillaryequipment. 2. PressuretestBOPEto3,500psiHi250Low,10mineachtest. a. Eachsubsequenttestofthelubricatorwillbeto3,500psiHi250Lowtoconfirmnoleaks. b. NoAOGCCnotificationrequired. c. RecordBOPEtestresultson10Ͳ424form. d. Ifwithinthestandard7ͲdaytestBOPEtestperiod,afullbodytestandfunctiontestoftherams issufficienttomeetweeklyBOPEtestrequirement. 3. AfterMUMHAandpulltestingtheCTC,tagͲupontheCTstrippertoensureBHAcannotpullthrough thebrassuponPOOHwiththeBHA. 4. RIHandlatchintopumpsection.Jarfreeandpulltosurface.Onceatsurface,confirmwellisdead.Kill welldownbacksideasneededandbleedoffanyresidualpressure. 5. RIHandlatchintopumpsection.Jarfreeandpulltosurface.Onceatsurface,confirmwellisdead.Kill welldownbacksideasneededandbleedoffanyresidualpressure. 6. Bakerneedstoverifycontinuityinthecable. 7. CirculateKWFdownthetubingandtakingreturnsuptheIA.Pumpatleast1wellborevolume(279 bbls). 8. MUnewTTCͲESPRun#1aspersectionsintheattachment. 9. RIHw/TTCͲESPPumpsectionsandland.PumpoffofGSandleaveinplace. a. NoteanytubingpressurechangeinWSR. 10. Aftersetting,PUHandensurethatthepumpsectionsareinplacedownhole.POOH. 11. Confirmwellisdead.Bleedanypressureofftoreturntank.Killwellw/KWF,8.33ppgsourcewater or8.5ppgasneeded.MaintainholefilltakingreturnstotankuntillubricatorconnectionisreͲ established.FluidsmanͲwatchmustbeperformedwhilerecovering/deployingESPpumpsectionto ensurethewellremainskilledandthereisnoexcessflow. 12. *PerformdrillbypickingupsafetyjointwithTIWvalveandspaceoutbeforeMUESPPumpsection. Reviewwellcontrolstepswithcrewpriortobreakinglubricatorconnectionandcommencing breakdown/makeupof71’ESPpumpsection.OncethesafetyjointandTIWvalvehavebeenspaced out,keepthesafetyjoint/TIWvalvereadilyaccessibleneartheworkingplatformforquickdeploymentif necessary. b. Atthebeginningofeachjob,thecrossover/safetyjointmustbephysicallyMUtothetopofthe ESPpumpsectiononetimetoconfirmthe4”GSiscompatible. 13. MUnewTTCͲESPRun#2aspersectionsintheattachmentswhilemaintainingholefill. Make up PCE. mgr Continue to secure well with PCE. mgr Make up PCE. - mgr TTCͲESPPumpSectionSwap Well:MPULͲ03 PTD:190Ͳ007 API:50Ͳ029Ͳ21999Ͳ00Ͳ00 14. RIHw/TTCͲESPPumpsectionsandland.PumpoffofGSandleaveinplace. c. NoteanytubingpressurechangeinWSR. 15. Aftersetting,PUHandensurethatthepumpsectionsareinplacedownhole. a. Ifpumpsareleftinhole,POOHasnormalandfreezeprotectwellonwayOOH(willnotneed openholeoperationstobreakͲoffofwell). b. IfanyindicationthattheESPPumpSectionsarestillattachedtocoil: i. ConfirmwellisdeadandreͲkillifnecessarybeforepullingtosurface.Pumppipe displacementwhilePOOH. ii. Stopatsurfacetoreconfirmwellisdead.Killwellifnecessary.Reviewwellcontrolsteps andStandingOrderswithcrewpriortobreakinglubricatorconnectionandcommencing breakdownofESPPumpSection. iii. EnsuresafetyjointandTIWvalveassemblyareonͲhandbeforebreakingofflubricator tocheckESPPumpSection. 16. RDMOCTU. 17. FPwell. Slickline 1. RUSLUnitandpressuretestPCEto250psilow/2,500psihigh. 2. RIHandsetpackoff(Run#3). 3. RIHandsettesttoolintopackoffandpressuretesttubingto1,000psi.POOHw/testtool. 4. RIHandsettubingstop(Run#4). 5. RDMOSLunit. Attachments: 1. CurrentWellboreSchematic 2. ProposedSchematic 3. TTCͲESPDiagram 4. CoilTubingBOPESchematic 5. StandingOrdersforOpenHoleWellControlduringPerfGunDeployment 6. EquipmentLayoutDiagram Make up PCE. mgr TTCͲESPPumpSectionSwap Well:MPULͲ03 PTD:190Ͳ007 API:50Ͳ029Ͳ21999Ͳ00Ͳ00 TTCͲESPDiagram TTCͲESPPumpSectionSwap Well:MPULͲ03 PTD:190Ͳ007 API:50Ͳ029Ͳ21999Ͳ00Ͳ00 CoiledTubingBOPs StandingOrdersforOpenHoleWellControlduringPerfGunDeployment TTCͲESPPumpSectionSwap Well:MPULͲ03 PTD:190Ͳ007 API:50Ͳ029Ͳ21999Ͳ00Ͳ00 TTCͲESPPumpSectionSwap Well:MPULͲ03 PTD:190Ͳ007 API:50Ͳ029Ͳ21999Ͳ00Ͳ00 EquipmentLayoutDiagram TTC-ESP Pump Section Swap Well: MPU L-03 PTD: 190-007 API: 50-029-21999-00-00 Well Name:MPU L-03 API Number:50-029-21999-00-00 Current Status:Producer Pad:L-Pad Estimated Start Date:4/1/24 Rig:CT Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:190-007 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) AFE Number:Job Type:TTC-ESP Pump Swap Current Bottom Hole Pressure:1,964 psi @ 6,834’ TVD Downhole Gauge 42 hr SI | 5.6 PPG 5.8 KWF Max. Anticipated Surface Pressure:1,038psi (Based on 0.1 psi/ft. gas gradient) Max Angle:41.3° @ 4,000’ MD Max Dogleg:5.68°/100ft @ 3,256’ MD Brief Well Summary: MPL-03 was drilled in January 1990, fracture stimulated and completed in October of 1990 as a Kuparuk River producer. ESP installation history: October 1990 (initial), May 1994, July 1996, February 1999, December 2000, May 2004, May 2007, January 2008, October 2008, March 2010, January 2012, and January 2016. The ESP has slowly lost efficiency over the previous year. BHP increased 125 psi (825 psi to 950 psi). We will proactively replace. Objectives: CT to pull TTCESP, 4 runs. Open hole deploy tandem motors on run #2. Install new TTCESP, 4 runs. Notes Regarding the Well & Design x 1/5/2012 3,500 psi good pressure test. Casing test required at next RWO. Procedure: Slickline: 1. MIRU SL. PT lubricator to 200 psig low, 2,500 psig high. 2. Drift and tag the tubing stop with sample bailer. 3. RIH with GS retrieving head to retrieve tubing stop. 4. RIH with GS retrieving head to retrieve packoff. 5. RDMO. Coiled Tubing Notes: x Due to the necessary open hole deployment of an Extended BHA, 24-hour crew and WSS coverage is required. x The well will be killed and monitored before recovery of the TTC-ESP pump sections. This will be done prior to POOH from the recovery of the packoff. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job – For MPU L-03 the well will be circulated bottoms up to avoid possibility of charging the Kuparuk Formation while bullheading an entire well volume. Superceded TTC-ESP Pump Section Swap Well: MPU L-03 PTD: 190-007 API: 50-029-21999-00-00 1. MIRU Coiled Tubing Unit with 1.75” coiled tubing and spot ancillary equipment. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. d. If within the standard 7-day test BOPE test period, a full body test and function test of the rams is sufficient to meet weekly BOPE test requirement. 3. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with the BHA. 4. RIH to just above the Receptacle, Discharge head, Top pump. Circulate the well over to source water (8.33 ppg) to load and kill the tubing. e. Current estimates indicate the well can be killed with source water. f. Wellbore volume to top perf = 136 bbls g. 4-1/2” Tubing – 8,233’ X 0.0152 = 125 bbl h. 7” Liner (counting ESP motor section volume) – 275’ X .0383bpf = 11 bbl 5. Bleed off all WHP and confirm well is dead. 6.RIH and latch into pump section. Jar free and pull to surface. Once at surface, confirm well is dead. Kill well down backside as needed and bleed off any residual pressure. 7. RIH and latch into pump section. Jar free and pull to surface. Once at surface, confirm well is dead. Kill well down backside as needed and bleed off any residual pressure. 8. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF, 8.33 ppg source water or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re- established. Fluids man-watch must be performed while recovering/deploying ESP pump section to ensure the well remains killed and there is no excess flow. 9.*Perform drill by picking up safety joint with TIW valve and space out before MU ESP Pump section. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown/makeup of 71’ ESP pump section. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. a.At the beginning of each job, the crossover/safety joint must be physically MU to the top of the ESP pump section one time to confirm the 4” GS is compatible. 10. Baker needs to verify continuity in the cable. 11. MU new TTC-ESP Triple Pump Sections as per sections in the attachments (Run #1 and #2) while maintaining hole fill. IA to remain shut in. - mgr?? - mgr tubing and coil - mgr MAKE UP PCE. - mgr Shut in well. Break lubricator. Lay dow TTESP assy. - mgr MAKE UP PCE. - mgr Shut in well. Break lubricator. Lay down TTESP. - mgr Superceded TTC-ESP Pump Section Swap Well: MPU L-03 PTD: 190-007 API: 50-029-21999-00-00 12. RIH w/ TTC-ESP Pump sections and land. Pump off of GS and leave in place. b. Note any tubing pressure change in WSR. 13. After setting, PUH and ensure that the pump sections are in place downhole. a. If pumps are left in hole, POOH as normal and freeze protect well on way OOH (will not need open hole operations to break-off of well). b. If any indication that the ESP Pump Sections are still attached to coil: i. Confirm well is dead and re-kill if necessary before pulling to surface. Pump pipe displacement while POOH. ii. Stop at surface to reconfirm well is dead. Kill well if necessary. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of ESP Pump Section. iii. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to check ESP Pump Section. 14. RDMO CTU. 15. FP well. Slickline 1. RU SL Unit and pressure test PCE to 250psi low / 2,500psi high. 2. RIH and set packoff (Run #3). 3. RIH and set test tool into packoff and pressure test tubing to 1,000psi. POOH w/ test tool. 4. RIH and set tubing stop (Run #4). 5. RDMO SL unit. Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. TTC-ESP Diagram 4. Coil Tubing BOPE Schematic 5. Standing Orders for Open Hole Well Control during Perf Gun Deployment 6. Equipment Layout Diagram MAKE UP PCE. - mgr Superceded _____________________________________________________________________________________ Revised By: TDF 9/26/2022 SCHEMATIC Milne Point Unit Well: MPU L-03 Last Completed: 2/11/2017 PTD: 190-007 TD =8,900’ (MD) / TD = 7,316’(TVD) 13-3/8” Orig. KB Elev.: 32’(Nabors 33E) 7” 5 3 & 4 6&7 8 10 16 11 Est. TOC @ 8,000’ 9-5/8” 1 9 PBTD =8,780’(MD) / PBTD = 7,225’(TVD) KUPBSilts 2 KUP A Sands Arctic Pack 12 13 17 RA Tag @ 8,305’ 14 & 15 TOF @ 8,763’ ` CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / Weld 12.715 Surface 80' 0.157 9-5/8" Surface 36 / J-55 / Btc. 8.921 Surface 2,758’ 0.0773 7" Production 26 / L-80 / Hydril 563 6.276 Surface 8,868’ 0.0383 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / Hydril 521 3.958 Surface 8,275’ 0.0152 JEWELRY DETAIL No Depth Item 1 8,177’ D&D Packoff & Stinger assembly (Set on 2/17/17) 2 8,186’ Pump, Discharge head, Hanger receptacle (Set on 2/17/17) 3 8,204’ P2P Pump 380 SXD 116-Flex 17.5 (Set on 2/17/17) 4 8,224’ P2P Pump 380 SXD 116-Flex 17.5 (Set on 2/17/17) 5 8,233’ TTC Drilled Tubing Crossover 6 8,243’ Upper Tandem Seal - GSB3 DB HL H6 PFS 7 8,250’ Lower Tandem Seal - GSB3 DB HL H6 PFS 8 8,257’ Motor – CL-5 XP-200 9 8271’ Sensor – Phoenix XT150 Type O 10 8,273’ 6 Fin Centralizer –Bottom @ 8,275’ 11 8,391’ On/ Off Overshot w/ 5.88” Gauge Ring / Scoop Guide 12 8,394’ 7” DLH Hydraulic Packer 3-1/*2” EUE 8rd BxP 13 8,410’ 3-1/2” Halliburton Auto Fill 14 8,413’ 3-1/2” Halliburton Mirage Plug 15 8,432’ 3-1/2” HES Shear Sub 50k Pull BxP EUE 8rd 16 8,436’ 4-1/8” 250 Micron Screen 3-1/2” NU 9.2# L-80 17 8,499.5’ 3-1/2” NU Bull Plug - Bottom @ 8,500’MD / 7,011’ TVD PERFORATION DETAIL KUP Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status B silts 8,508’ 8,552’ 7,017’ 7,051’ 44 10/2/1990 Open A3 8,601’ 8,627’ 7,089’ 7,108’ 26 10/2/1990 Open A2 8,634’ 8,662’ 7,114’ 7,135’ 28 10/2/1990 Open A1 8,674’ 8,704’ 7,144’ 7,167’ 30 10/2/1990 Open OPEN HOLE / CEMENT DETAIL 13-3/8" ±500 sks Permafrost “C”in 30” Hole 9-5/8" 377bbl class ‘E’, 84bbl Class ‘G’ in 12-1/4” Hole 7” 48bbl Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 41.35 deg. @ 4,000’ Max Hole Angle through perforations = 40 deg. Max DLS =5.68 deg. @ 3,256’ MD TREE & WELLHEAD Tree 2-9/16” 5M FMC Wellhead 11” 5M FMC w/ 11” 2-7/8” WKM Tubing Hanger w/ 2-7/8” EUE 8rd , 2-1/2” CIW “H” BPV profile GENERAL WELL INFO API: 50-029-21999-00-00 Drilled, Cased and Comp. by Nabors 33E - 10/14/1990 ESP RWO – 4/18/1994 ESP RWO by Polar #1– 7/96 ESP RWO by Nabors 4ES – 2/17/99, 12/30/00 & 5/9/04 ESP RWO by Nabors 3S – 5/2/07, 2/1/08 & 10/25/08 ESP RWO by Nabors 4ES – 3/18/2010 ESP RWO w/ Packer and Screens by Doyon 16 – 12/22/2011 ESP RWO by Nordic – 1/10/2016 ESP RWO by Doyon 14 – 2/11/17 STIMULATION SUMMARY Well Frac’d @ 40bpm w/ 1,521bbls gel w/ 147,022 lbs 16-20 carbolite proppant. NOTE 7” Casing tested to 3,500psi above 8,460’ on 1/5/2012 _____________________________________________________________________________________ Revised By: TDF 3/11/2024 PROPOSED Milne Point Unit Well: MPU L-03 Last Completed: 2/11/2017 PTD: 190-007 TD =8,900’ (MD) / TD = 7,316’(TVD) 13-3/8” Orig. KB Elev.: 32’(Nabors 33E) 7” 6 3, 4 & 5 7 &8 9 11 17 12 Est. TOC @ 8,000’ 9-5/8” 1 10 PBTD =8,780’(MD) / PBTD = 7,225’(TVD) KUP B Silts 2 KUP A Sands Arctic Pack 13 14 18 RA Tag @ 8,305’ 15 & 16 TOF @ 8,763’ ` CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / Weld 12.715 Surface 80' 0.157 9-5/8" Surface 36 / J-55 / Btc. 8.921 Surface 2,758’ 0.0773 7" Production 26 / L-80 / Hydril 563 6.276 Surface 8,868’ 0.0383 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / Hydril 521 3.958 Surface 8,275’ 0.0152 JEWELRY DETAIL No Depth Item 1 X,XXX’ D&D Packoff & Stinger assembly 2 X,XXX’ Pump, Discharge head, Hanger receptacle 3 X,XXX’ Pump 380 SXD 116-P18UT 4 X,XXX’ P2P Pump 380 SXD 116-Flex 17.5 5 X,XXX’ P2P Pump 380 SXD 116-Flex 17.5 6 8,233’ TTC Drilled Tubing Crossover 7 8,243’ Upper Tandem Seal - GSB3 DB HL H6 PFS 8 8,250’ Lower Tandem Seal - GSB3 DB HL H6 PFS 9 8,257’ Motor – CL-5 XP-200 10 8271’ Sensor – Phoenix XT150 Type O 11 8,273’ 6 Fin Centralizer –Bottom @ 8,275’ 12 8,391’ On/ Off Overshot w/ 5.88” Gauge Ring / Scoop Guide 13 8,394’ 7” DLH Hydraulic Packer 3-1/*2” EUE 8rd BxP 14 8,410’ 3-1/2” Halliburton Auto Fill 15 8,413’ 3-1/2” Halliburton Mirage Plug 16 8,432’ 3-1/2” HES Shear Sub 50k Pull BxP EUE 8rd 17 8,436’ 4-1/8” 250 Micron Screen 3-1/2” NU 9.2# L-80 18 8,499.5’ 3-1/2” NU Bull Plug - Bottom @ 8,500’MD / 7,011’ TVD PERFORATION DETAIL KUP Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status B silts 8,508’ 8,552’ 7,017’ 7,051’ 44 10/2/1990 Open A3 8,601’ 8,627’ 7,089’ 7,108’ 26 10/2/1990 Open A2 8,634’ 8,662’ 7,114’ 7,135’ 28 10/2/1990 Open A1 8,674’ 8,704’ 7,144’ 7,167’ 30 10/2/1990 Open OPEN HOLE / CEMENT DETAIL 13-3/8" ±500 sks Permafrost “C”in 30” Hole 9-5/8" 377bbl class ‘E’, 84bbl Class ‘G’ in 12-1/4” Hole 7” 48bbl Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 41.35 deg. @ 4,000’ Max Hole Angle through perforations = 40 deg. Max DLS =5.68 deg. @ 3,256’ MD TREE & WELLHEAD Tree 2-9/16” 5M FMC Wellhead 11” 5M FMC w/ 11” 2-7/8” WKM Tubing Hanger w/ 2-7/8” EUE 8rd , 2-1/2” CIW “H” BPV profile GENERAL WELL INFO API: 50-029-21999-00-00 Drilled, Cased and Comp. by Nabors 33E - 10/14/1990 ESP RWO – 4/18/1994 ESP RWO by Polar #1– 7/96 ESP RWO by Nabors 4ES – 2/17/99, 12/30/00 & 5/9/04 ESP RWO by Nabors 3S – 5/2/07, 2/1/08 & 10/25/08 ESP RWO by Nabors 4ES – 3/18/2010 ESP RWO w/ Packer and Screens by Doyon 16 – 12/22/2011 ESP RWO by Nordic – 1/10/2016 ESP RWO by Doyon 14 – 2/11/17 STIMULATION SUMMARY Well Frac’d @ 40bpm w/ 1,521bbls gel w/ 147,022 lbs 16-20 carbolite proppant. NOTE 7” Casing tested to 3,500psi above 8,460’ on 1/5/2012 TTC-ESP Pump Section Swap Well: MPU L-03 PTD: 190-007 API: 50-029-21999-00-00 TTC-ESP Diagram TTC-ESP Pump Section Swap Well: MPU L-03 PTD: 190-007 API: 50-029-21999-00-00 Coiled Tubing BOPs Standing Orders for Open Hole Well Control during Perf Gun Deployment TTC-ESP Pump Section Swap Well: MPU L-03 PTD: 190-007 API: 50-029-21999-00-00 TTC-ESP Pump Section Swap Well: MPU L-03 PTD: 190-007 API: 50-029-21999-00-00 Equipment Layout Diagram STATE OF ALASKA • ALIIIA OIL AND GAS CONSERVATION COMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations Li Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ Other: ESP Completion 0 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development 0 Exploratory ❑ 190-007 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-21999-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025509 MILNE PT UNIT L-03 ft EC a VED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL MAR 1 0 2017 11.Present Well Condition Summary: AOGCCTotal Depth measured 8,900 feet Plugs measured 8,780 feet true vertical 7,316 feet Junk measured N/A feet Effective Depth measured 8,780 feet Packer measured 8,394 feet true vertical 7,228 feet true vertical 6,930 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 13-3/8" 80' 80' N/A N/A Surface 2,726' 9-5/8" 2,758' 2,495' 3,520psi 2,020psi Production 8,836' 7" 8,868' 7,267' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCANNED APP #2r' 7 Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/Hydril 8,275' 6,838' Packers and SSSV(type,measured and true vertical depth) DLH Hyd Pkr N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1,000 0 Subsequent to operation: 264 114 632 280 249 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development 0 Service ❑ Stratigraphic El Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas ❑ WDSPL 9 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-008 '` Contact Paul Chan Email pchanahilcorp.com Printed Name Bo York t Title Operations Manager Signature �'� he 15', Y e c-k Phone 777-8345 Date 3/9/2016 3 av-l-7 RBDMS Lti MAR 2 2 2017 Form 10-404 Revised 5/2015 ? � Submit Original Only • • Milne Point Unit Well: MPU L-03 SCHEMATIC Last Completed: 2/11/2017 PTD: 190-007 Iiileorp Alaska,LIC L� TREE&WELLHEAD Orig.KB Elev.:32'(Nabors 33E) Tree 2-9/16"5M F4 MC '1 �\ Wellhead 11"5M FMC w/11"2-7/8"WKM Tubing Hanger w/2-7/8"C iii {� EUE 8rd,2-1/2"CIW"H"BPV profile 13-3/8" t' �� OPEN HOLE/CEMENT DETAIL 13-3/8" ±500 sks Permafrost"C"in 30"Hole Arctic Pack 9-5/8" 377bb1 class'E',84bb1 Class'G'in 12-1/4"Hole 4 ‘,./• 7" 48bb1 Class"G"in 8-1/2"Hole s CASING DETAIL 5t� # li Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/Weld 12.715 Surface 80' 0.157 9-5/8" Surface 36/1-55/Btc. 8.921 Surface 2,758' 0.0773 �� �t; 7" Production 26/L-80/Hydril 563 6.276 Surface 8,868' 0.0383 9-5/8" " 1 ' ..et TUBING DETAIL 4-1/2" Tubing 12.6/L-80/Hydril 521 3.958 Surface 8,275' 0.0152 WELL INCLINATION DETAIL NOTE KOP @ 600' 7"Casing tested Max Hole Angle=41.35 deg.@ 4,000' to 3,500psi Max Hole Angle through perforations=40 deg. above 8,460'on Max DLS=5.68 deg.@ 3,256'MD 1/5/2012 JEWELRY DETAIL No Depth Item 1 8,177' D&D Packoff&Stinger assembly (Set on 2/17/17) Est.TOC @ 8,000 2 8,186' Pump,Discharge head,Hanger receptacle (Set on 2/17/17) \n 3 8,204' Pump eye,intake,pump (Set on 2/17/17) '% 4 8,233' TIC Drilled Tubing Crossover (tot F 5 8,243' Upper Tandem Seal-GSB3 DB HL H6 PFS ss 6 8,250' Lower Tandem Seal-GSB3 DB HL H6 PFS 7 8,257' Motor-CL-5 XP-200 4° 8 8271' Sensor-Phoenix XT150 Type O > i'' 9 8,273' 6 Fin Centralizer-Bottom @ 8,275' i, 10 8,391' On/Off Overshot w/5.88"Gauge Ring/Scoop Guide & 1 11 8,394' 7"DLH Hydraulic Packer 3-1/*2"EUE 8rd BxP 44 e2 12 8,410' 3-1/2"Halliburton Auto Fill � 3 13 8,413' 3-1/2"Halliburton Mirage Plug 1Illi 4 14 8,432' 3-1/2"HES Shear Sub 50k Pull BxP EUE 8rd 15 8,436' 4-1/8"250 Micron Screen 3-1/2"NU 9.2#L-80 i 6&5 16 8,499.5' 3-1/2"NU Bull Plug-Bottom @ 8,500'MD/7,011'ND PERFORATION DETAIL iA7 r ty KUP Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status 8 B silts 8,508' 8,552' 7,017' 7,051' 44 10/2/1990 Open RA Tag©8,305' 9 A3 8,601' 8,627' 7,089' 7,108' 26 10/2/1990 Open `4; A2 8,634' 8,662' 7,114' 7,135' 28 10/2/1990 Open rr Al 8,674' 8,704' 7,144' 7,167' 30 10/2/1990 Open ,;, ., to 11 STIMULATION SUMMARY 12 .+i Well Frac'd @ 40bpm w/1,521bb1s gel w/ 114&13 147,022 lbs 16-20 carbolite proppant. ", Ktli 15 $, 16 GENERAL WELL INFO il KUP B Sins API:50-029-21999-00-00 4N Drilled,Cased and Comp.by Nabors 33E 10/14/1990 TOF@8,763' KUP ASaids ESP RWO-4/18/1994 ESP RWO by Polar#1-7/96 ., ESP RWO by Nabors 4ES-2/17/99,12/30/00&5/9/04 ESP RWO by Nabors 3S-5/2/07,2/1/08&10/25/08 TD=8,900'(MD)/TD=7,316'(ND) ESP RWO by Nabors4ES-3/18/2010 PBTD=8,780'(MD)/PBTD=7,225'(ND) ESP RWO w/Packer and Screens by Doyon 16-12/22/2011 ESP RWO by Nordic-1/10/2016 ESP RWO by Doyon 14-2/11/17 Revised By:TDF 3/9/2016 • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-03 Doyon 14 50-029-21999-00-00 190-007 2/8/17 2/11/17 Daily pe atrio is t ,� r 44P.:114::1°.44 ; -, -1 #. z 2/8/2017-Wednesday Accept rig at 06:00. Shim rig. Skid Rig Floor to drilling position. RU rig Floor. Prep pits to take on fluid.Spot cuttings box in place. Prep cellar. Roads& Pads move & spot flowback tank.Well Support lubricate out BPV. RU on tree to circulate/kill well.Take on 266 bbls of 8.5 ppg seawater in pits. Load Baraklean in pits. Load additional 290 bbls 1400 seawater in pits. RU lines to Flowback tank. Test same to 1,500 psi. PJSM w/crew. Open tubing to flowback tank and bleed off gas (900 psi to 0 psi). Line up to pump down tubing taking returns out IA to flowback tank. Initially 1,000 psi on IA. Bleed through choke.Begin pumping down tubing w/3 bpm, 160 psi. Pump 40 bbls w/ 1 drum of Baraklean. Chase with 8.5 ppg seawater. Increase rate to 5 bpm. Observed returns w/75 bbls away(diesel & crude). Pumped total of 410 bbls,got 233 back to flowback tank. Final returns were 110'8.4+ ppg seawater. Approximately 70% returns after seeing initial returns to surface.Shut in tubing and IA(0 psi on both). Blow down lines. Wellhead Rep install TWC.Wellhead Rep Greg Ruge bleed down hanger void, N/D tree and secure in cellar. Verify threads on TBG hanger.N/U 11" x 13-5/8" adapter flange w/24" 13- 5/8" spacer spool, and BOP stack. M/U kill and choke lines/Install riser and mouse hole,then measure rig RKB.WelI Head rep Greg Ruge remove BPV and install TWC.Perform BOPE shell test and tighten flanges as necessary.Test BOPE w/2-7/8" and 4-1/2"test joints to 250psi low and 3,500psi high f/5 charted mins each.AOGCC rep Brian Bixby waived witness of test at 16:50 hrs on 2/8/17. 2/9/2017-Thursday Continue to test BOPE w/2-7/8" &4-1/2"test joints.AOGCC Rep. Brian Bixby waived witness of test at 1650 hrs on 2/8/17.RD test equipment. Blow down lines. Check pressures (0 psi). Wellhead Rep. pull TWC (well on vac). Mobilize GBR and Centrilift equipment to rig floor. Spot Spooling unit and GBR hydraulic unit.PU 2-7/8" landing joint and engage hanger. BOLDS. Pull hanger free w/112k. Pull hanger to rig floor w/ 110k PUW.FiII hole using hole fill pump (47 bbls). Fill tubing w/ 15 bbls. Break circulation and pump tubing volume (50 bbls) w/5 bpm, 1,800 psi. LD landing joint/hanger.Test ESP connections at penetrator. Cut ESP cable. Blow down Top Drive. RU Centrilift.PJSM & POH LD ESP completion f/8,269'to ±3,158'. M U Halliburton storm PKR as per Halliburton hand and RIH on 1 stand of 2-7/8" pipe out of the derrick, set PKR, ;v' back out PKR running tool and L/D. Fill hole up to blind shear rams, close rams and test storm PKR to 3,500psi f/5 charted 4,e,/- mins(good test)Drain stack and wellhead, power down accumulator, remove mousehole/rotary table bushing/riserN/D BOP stack, riser spool, and adapter flange, stand back BOP's onto stump. Wellhead rep_Greg Ruge on location to install new TBG spool. N/U BOP stack, adapter flange, install mousehole/riser/rotary table bushing, power up accumulator system. R/U and body test new TBG spool, adapter flange, BOP stack, f/250psi low4 3/500psihf./5 charted mins each (good test)NPT:Trouble shoot GBR power unit for running CSG tongs, pull unit into welding shop to thaw out and swap startersM/U Halliburton storm packer retrival tool on the bottom of a stand of 2-7/8" tubing, M/U to PKR, check for pressure below PKR (no pressure) and release storm PKR. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-03 Doyon 14 50-029-21999-00-00 190-007 2/8/17 2/11/17 Daily Opera ions'7T` lu i° H uiE ; ; IWul of ' 2/10/2017- Friday RU ESP cable to spooling unit. Fill backside w/44 bbls 8.5 ppg seawater.POH LD remainder of 2-7/8"tubing f/3,158' to ESP motor assembly at±75'.LD ESP motor assembly. Feed cable out to spooling unit. Recovered 259 joints, 2 GLM's, 1 XN- Nipple, 138 Cannon Clamps, 5 Protectolizers & 3 flat clamps. RIH w/2-7/8" EUE pipe on stands out of the derrick from L-39 (779'md).Come out of the hole sideways w/2-7/8' EUE pipe from 779'md to surface.L/D all ESP completion tools and 2- 7/8" handling equipment, mobilize 4-1/2" handling equipment. Unspool ESP cable and capillary line f/spooling unit to the //�� rig floor, running both through Centrilift dual sheave. P/U 4.5" ESP motor assemb y as per Centrilift rep and RIH to 89'md, Co"' perform pre-run preparation procedure. (Fill seal assemblies w/CL-5 oil, install MLE cable, connect capillary line to 6 fin ('' centralizer,test ESP for conductivity). RIH w/4.5" 12.6# L-80 Hydril 521 tubing f/89'md to 484'md making up to 4,610ft-lbs torque, utilizing lift nubbins on all joints, dog collars in the slips on all joints, and cannon clamps on all connections. Centrilift test ESP cable conductivity(good test). Continue to RIH w/4.51112.6# L-80Hydril 521 tubing_fL484'md_to. ^3,500'md making up to 4610ft-lbs torque, utilizing lift nubbins on all joints, dog collars in the slips on all joints, and cannon clamps on all connections,testing ESP cable conductivity every 1,000'md. 2/11/2017-Saturday Continue to RIH w/4.5" 12.6# L-80 Hydril 521 tubing f/3,500'to 7,274' making up to 4610ft-lbs torque, utilizing lift nubbins on all joints, dog collars in the slips on all joints, and cannon clamps on all connections,testing ESP cable conductivity every 1,000'md. Make ESP cable splice at 7,274'. Continue to RIH w/ ESP completion to 8,242'md making up to 4,610ft-lbs torque, utilizing lift nubbins on all joints, dog collars in the slips on all joints,and cannon clamps on all connections, testing ESP cable conductivity every 1000'md. PUW= 190klbs, SOW= 90klbs. M/U tubing hanger,tie in capillary line to hanger, splice ESP cable to penetrator, and insert through hanger. Land hanger, Hilcorp wellhead hands Greg and Johnny on location to RILDS. R/U to circulate down TBG,taking returns up the IA. Pump 30bbl baraklean pill @ 3BPM = 130psi and chase surface to surface w/8.6ppg seawater @ 6BPM = 600psi taking returns back to the pits. Pump 320bbl equivalent w/ 90bbl losses. R/D and blow down all circulation lines, R/D landing joint, R/D GBR tongs from the floor. Hilcorp wellhead hands Greg and Johnny, M/U 3 piece T-bar, install BPV, and break down 3 piece T-bar. N/D BOPE and set back on stump. M/U tree adapter flange and production tree.Test void on tubing spool and adapter flange to 5,600psi, leak noted on LDS on tubing spool, re-torque LDS and re-test to 5,600psi, (good test). Fill tree w/diesel and shell test to 5,000psi f/5mins (good test). Pull BPV and close master, swab and wing valves on the tree. NOTE: Released rig at 06:00 hrs on 2/12/17. 2/12/2017 -Sunday I No activity to report. 2/13/2017-Monday No activity to report. 2/14/2017-Tuesday No activity to report. •VOF Tlr�' • • "��\�y/y',v THE STATE Alaska Oil and Gas N�.; � of® TTAsKA Conservation Commission "111'1"2-9711•*- — =�_ 333 West Seventh Avenue * GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 o Main: 907.279.1433 ALAS'' Fax: 907.276.7542 www.aogcc.alaska.gov Bo York • Operations Manager Hilcorp Alaska, LLC SCANNED ti t 2 1.'1 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR L-03 Permit to Drill Number: 190-007 Sundry Number: 317-008 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 14:40..0 Cathy '. Foerster Chair DATED this�day of January, 2017. RBDE S U— 6 2017 . • i RECEIVED STATE OF ALASKA JAN I1 � ALASKA OIL AND GAS CONSERVATION COMMISSION ii 1 7 APPLICATION FOR SUNDRY APPROVALS A,, 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well Q , Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 . Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Completion Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑, 190-007 ^ 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage AK 99503 50-029-21999-00-00 7.If perforating: 433,Ad 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.4,3'2-C Will planned perforations require a spacing exception? Yes ❑ No ❑ / MILNE PT UNIT KR L-03 , 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025509 " MILNE POINT/KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,900' ' 7,316' . 8,780' s 7,225' 1,786 8,780' N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 13-3/8" 80' 80' N/A N/A Surface 2,726' 9-5/8" 2,758' 2,495' 3,520psi 2,020psi Production 8,836' 7" 8,868' 7,267' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic I See Attached Schematic 2-7/8" L-80/6.5#/EUE 8rd 8,296' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): DLH Hydraulic Packer 7"x 3.5"and N/A 8,394'MD/6,930'TVD and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic [] 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch a Exploratory ❑ Stratigraphic❑ Development Q. Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1/18/2017 OIL Q. WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: N/A GAS 0 WAG ❑ GSTOR 0 SPLUG 0 Commission Representative: N/A GINJ 0 Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Paul Chan Email pchan(a hilcorp.com Printed Name Bo York Title Operations Manager i Signature / Ale Phone 777-8345 Date 1036.e. 11)16 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 311 - oaf Plug Integrity 0 BOP Test [ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4- 36-OO ipS; &' ' he S" Post Initial Injection MIT Req'd? Yes ❑ No 0 Spacing Exception Required? Yes ❑ No 12/ Subsequent Form Required: /u"-'jet( RBDiy1S i.L .r`.N 2 6 2617 , d APPROVED BY 1)944........,4_____Approved by: too COMMISSIONER THE COMMISSION Date: f'—20- /7 ?Ka ifi tri— (/°) 1 �a1a �''Suitrm and of rm 10-403 Revised 11/2015 J � 1p'i�tiAs valid for 12 months from the date of approval. Attachments in Duplicate 1E4 • S Well Prognosis Well: MPU L-03 leorp Alaska,LL Date:01/09/2017 Well Name: MPU L-03 API Number: 50-029-21999-00-00 Current Status: Oil Well [Failed ESP] Pad: L-Pad Estimated Start Date: January 18th, 2017 Rig: Doyon 14 Reg.Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190-007 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Ai=l:Number: r labiy4 et _ aiESP Repair' -'VA Current Bottom Hole Pressure: 2471 psi @ 6,851' TVD (ESP gauge 1/3/2017/6.94 ppg EMW) Maximum Expected BHP: 2471 psi @ 6,851' TVD (No new perfs being added) / MPSP: 1786 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPL-03 was drilled in January 1990, fracture stimulated and completed in October of 1990 as a Kuparuk River producer. ESP installation history: October 1990 (initial), May 1994,July 1996, February 1999, December 2000, May 2004, May 2007,January 2008, October 2008, March 2010,January 2012, and January 2016. The ESP has failed. Notes Regarding Wellbore Condition • 7" Casing was tested to 3500 psi for 30 minutes on January 5th 2012 • CO 390A: Hilcorp Alaska respectfully requests that a packer not be required on this ESP completion as the reservoir pressure is less than 8.55 ppg EMW. CK ,.°7_° 1 Objective: c" `y Replace failed ESP with TTC-ESP (thru tubing conveyed). v Y,f� �, mak'4 F' 4 L�, ��c � , f ,/ Brief RWO Procedure: 1. MIRU Doyon 14 and 500 bbl returns tank. 2. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/±8.45 ppg seawater. 3. Set BPV. ND tree/ NU BOPE. Set TWC. 4. Test BOPE to 250 psi Low/3,500 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min . Record accumulator pre-charge pressures and chart tests. a. Perform Test per Doyon 14 BOP Test Procedure. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" and 4-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 5. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) • s Well Prognosis Well: MPU L-03 Hilcorp Alaska,ISI) Date:01/09/2017 a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) (o�` +/ d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 6. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.45 ppg seawater as needed. p2rs./a4.sy C. 14 pp Fa14v 7. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2016 ESP swap was 100K lbs when unseating the hanger and 97k lbs prior to landing the new completion. (block weight 40k lbs) b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 8. Recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 9. POOH and lay down the 2-7/8" tubing. Number all joints. Tubing will not be re-used on this well. Lay down failed ESP. a. Mark all bad joints of tubing for disposal. b. Note any sand or scale inside or on the outside of the ESP on the morning report. 10. MU new TTC-ESP as follows: a. Centralizer �•-"'►� b. Gauge c. Motor—CL5 d. Lower Tandem Seal e. Upper Tandem Seal 1. TTC Drilled Tubing Crossover g. 10' Crossover,4-1/2" Hydril 521 box x NSTC pin h. 1 joint new 4-1/2" Hydril 521 L-80 tubing i. Joint(s) of condition B 4-1/2" Hydril 521 L-80 tubing as needed j. Dummy tubing hanger k. Landing joint / 11. Land tubing hanger and RILDS. LD landing joint. 4'"/� � ,' 12. MU pump assembly#1 and land in TTC assembly: 1/c /" ! ! Well Prognosis Well: MPU L-03 Itilrorp Ala Aka,It) Date:01/09/2017 a. Model 450 Pump Eye b. Model 380 Pump Intake c. Model 380 Pump _,,m13. MU pump assembly#2 and land on pump assembly#1: \ ` �"' a. Model 380 Pump tA)1 5 b. Model 380 Discharge Head c. Hanger receptacle 14. MU pack off assembly#1 and land on pump assembly#2 a. D&D Stinger b. 4' Spacer Pup c. D&D Kobe Knockout d. D&D Packoff 15. Run test tool and test packoff assembly. LD test tool. 16. Run tubing stop assembly. LD dummy landing joint. 17. PU 4-1/2" landing joint and screw into tubing hanger. BOLDS. 18. LD dummy tubing hanger. 19. MU ESP power cable to MLE. Run 3/8" external capillary string w/clamps down to base of ESP. 20. RIH on 4-1/2" Hydril 521 tubing. Set base of ESP centralizer at±8,300' MD. 21. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off)weights on tally. 22. Set BPV. ND BOPE and NU 4-1 ree. Pull BPV and set TWC. Test tree to 500 psi low/5000 psi high. Freeze protect well (may be done post-rig) Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Blank RWO MOC Form H . • MniU Well:ile PoMPUnt L-03nit , •H SCHEMATIC Last Completed: 1/10/2016 Mem)Alaska,LLC PTD: 190-007 Orig.KB Elev.:32'(Nabors 33E) TREE&WELLHEAD Tree 2-9/16"5M FMC 4 ) 11"5M FMC w/11"2-7/8"WKM Tubing Hanger w/2-7/8" Wellhead EUE 8rd,2-1/2"CIW"H"BPV profile 13-3/8" OPEN HOLE/CEMENT DETAIL 1 Arctic Pack 13-3/8" ±500 sks Permafrost"C"in 30"Hole 49-5/r 377bb1 class'E',84bb1 Class'G'in 12-1/4"Hole z 1, r 7" 48bb1 Class"G"in 8-1/2"Hole yf CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/Weld 12.715 Surface 80' 0.157 9-5/8" Surface 36/1-55/Btc. 8.921 Surface 2,758' 0.0773 In I , t"4 7" Production 26/L-80/Hydril 563 6.276 Surface 8,868' 0.0383 x 9-5/8"'`r`« 3 1 ', It TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf 8,296' 0.00579 WELL INCLINATION DETAIL 9 NOTE KOP @ 600' 7"Casing tested Max Hole Angle=41.35 deg.@ 4,000' to 3,50opsi / Max Hole Angle through perforations=40 deg. above 8,460'on Max DLS=5.68 deg.@ 3,256'MD €, „ 1/5/2012 JEWELRY DETAIL No Depth Item Est.TOC©8,00a ' r 1 135' GLM Camco 2-7/8"x 1"KBMM w/Dummy-ID=2.371" 2 8,059' GLM Camco 2-7/8"x 1"KBMM Open-ID=2.371" 3 8,202' 2-7/8"XN-Nipple(2.250 No-go ID) ki 2 4 8,217' Discharge Head:GPHVDIS 5 _ 8,218' Pump:SXD 119-P23 MIN ID=2.250" 1 t ., I , 6 8,235' Pump:SXD 68-G31 MVP @8,202' ,,a l ) 3 P, )(tj 7 8,251' Gas Separator:GRSFTXAR H6 ." kof, 8 8,256' Upper Tandem Seal:GSB3DBUT SB/SB PFSA 't ( `' 9 8,263' Lower Tandem Seal:GSB3DBUT SB/SB PFSA , ', 10 8,270' Motor:KMH 266HP,2,345 Volt,69 amp 11 8,292' Sensor:Pumpmate XTO s 5&6 12 8,294' Centralizer:Bottom @ 8,296'MD/6,854'TVD -0tt- 13 8,407' HES 7"x 3.5"VTA Packer III 7 14 8,425' HES 3.5"Shear Sub(50k) 8&9 15 8,436' Poromax 250 Micron Sand Screen �Y 16 8,500' Bull Nose Plug PERFORATION DETAIL '' z''~10 KUP Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status ;i,' RA Tag @ 8,305 :� J B silts 8,508' 8,552' 7,017' 7,051' 44 10/2/1990 Open e ; 12 11 A3 8,601' 8,627 7,089' 7,108' 26 10/2/1990 Open A2 8,634' 8,662' 7,114' 7,135' 28 10/2/1990 Open t, X13 Al 8,674' 8,704' 7,144' 7,167' 30 10/2/1990 Open .' 14 STIMULATION SUMMARY °+ ;,� 15 I Well Frac'd @ 4obpm w/1,521bbls gel w/ `s 9 147,022 lbs 16-20 carbolite propant. GENERAL WELL INFO 16 KUP B Silts API:50-029-21999-00-00 Drilled,Cased and Comp.by Nabors 33E -10/14/1990 KUP ASands ESP RWO-4/18/1994 ESP RWO by Polar#1-7/96 to - « ESP RWO by Nabors 4ES-2/17/1999,12/30/2000,5/9/2004 7"r& i ESP RWO by Nabors 3S-5/2/2007,2/1/2008,10/25/2008 TD=8,900'(MD)/TD=7,316'(TVD) ESP RWO by Nabors 4ES-3/18/2010 PBTD=8,78(Y(MD)/PBTD=7,225'(TVD) ESP RWO w/Packer and Screens by Doyon 16-12/22/2011 ESP RWO by Nordic 3-1/10/2015 Revised By:PC 1/9/2017 • Milne Point Unit Well: MPU L-03 PROPOSED Last Completed: 1/10/2016 Hilcora Alaska,LLC PTD: 190-007 • Orig.KBEIev.:32'(Nabors33E) TREE&WELLHEAD _ Tree 2-9/16"5M FMC 11"5M FMC w/11"2-7/8"WKM Tubing Hanger w/2-7/8" # k., Wellhead EUE 8rd,2-1/2"CIW"H"BPV profile Is 1 13-3/8' ,. � OPEN HOLE/CEMENT DETAIL nAraicPaGc 13-3/8" ±500 sks Permafrost"C"in 30"Hole ,-,:e. 9-5/8" 377bb1 class'E',84bbl Class'G'in 12-1/4"Hole to. 7" 48bbl Class"G"in 8-1/2"Hole °s CASING DETAIL f+ Size Type Wt/Grade/Conn ID Top Btm BPF 4 I 13-3/8" Conductor 48/H-40/Weld 12.715 Surface 80' 0.157 9-5/8" Surface 36/J-55/Btc. 8.921 Surface 2,758' 0.0773 ,, �7 7" Production 26/L-80/Hydril 563 6.276 Surface 8,868' 0.0383 9-5/8". , I i TUBING DETAIL 4-1/2" Tubing 12.6/L-80/Hydril 521 3.958 Surf ±8,300' 0.0152 WELL INCLINATION DETAIL NOTE KOP @ 600' 7"Casing tested Max Hole Angle=41.35 deg.@ 4,000' to 3,500psi Max Hole Angle through perforations=40 deg. above 8,460'on 1/5/2012 Max DLS=5.68 deg.@ 3,256'MD JEWELRY DETAIL No Depth Item Est.TOC @8,000' 1 D&D Packoff 2 D&D Stinger r*f 3 Discharge Head 0 4 Pump `( 5 Pump '.47 / 6 TTC Drilled Tubing Crossover ( ,fI C/ e 7 Upper Tandem Seal "4 i vi �r` 8 Lower Tandem Seal ` 9 Motor 10 ESP Gauge / 11 ±8,300' Centralizer 12 8,391' On/Off Overshot w/5.88"Gauge Ring/Scoop Guide / 13 8,394' 7"DLH Hydraulic Packer 3-1/*2"EUE 8rd BxP 14 8,410' 3-1/2"Halliburton Auto Fill 15 8,413' 3-1/2"Halliburton Mirage Plug 16 8,432' 3-1/2"HES Shear Sub 50k Pull BxP EUE 8rd 17 8,436' 4-1/8"250 Micron Screen 3-1/2"NU 9.2#L-80 18 8,499.5' 3-1/2"NU Bull Plug-Bottom @ 8,500'MD/7,011'TVD RA Tag©8,305 11 PERFORATION DETAIL KUP Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 12 B silts 8,508' 8,552' 7,017' 7,051' 44 10/2/1990 Open 13 A3 8,601' 8,627' 7,089' 7,108' 26 10/2/1990 Open t; II 14 A2 8,634' 8,662' 7,114' 7,135' 28 10/2/1990 Open 015&16 Al 8,674' 8,704' 7,144' 7,167' 30 10/2/1990 Open 4; rrill 17 ! STIMULATION SUMMARY GENERAL WELL INFO a~= 18 `' Well Frac'd @ 40bpm w/1,521bbls gel w/ API:50-029-21999-00-00 1 KUP B Silts 147,022 lbs 16-20 carbolite proppant. Drilled,Cased and Comp.by Nabors 33E -10/14/1990 ESP RWO-4/18/1994 KUP ASands ESP RWO by Polar#1-7/96 a ESP RWO by Nabors 4ES-2/17/99,12/30/00&5/9/04 7"A ** ESP RWO by Nabors 3S-5/2/07,2/1/08&10/25/08 ESP RWO by Nabors 4ES-3/18/2010 TD=8,900'(MD)/TD=7,316'(TVD) ESP RWO w/Packer and Screens by Doyon 16-12/22/2011 PBTD=8,780'(MD)/PBTD=7,225'(TVD) ESP RWO by Nordic-1/10/2016 Revised By:TDF 2/10/2016 1/04/16 • DOYON 14 BOP'S . DRILLING 13-5/8 5000 PSI RIG FLOOR --_ _ ,_ n n n n n 0 , e ) 1 HYDRIL 13-5/8" ANNULAR 'GE" z00F A0 NGE •HYDIRDL / iiuuniuu&um.unii i EIYDRIL MPL DOUBLE GATE I i a � o o L3-5/8" 5000 PSI •°•). 1..;:;'', o 411,-..i..7.••°• i` 3TUD z STUD BR-160 Cr E^]M ,.,m i xl to 10" OPERATORS i CO —/ _ i PIPE RAMS ` � / t0 ill nt •-44" 10" OPERATORS • �■ • •1. BLIND RAMS I �_ ii I: V_/ -/Gmr �I j 3-1/8" 5000 PSI MANUAL VALVE • E IIIM o. G ii 3-1/8" 5000 PSI HCR VALVE --� —_— i�in�uouiuiuunun --(l_p_i_koiL — „, LUD CROSS / 13-5/8" 5000 PSI FLANGE a FLANGE BX-180 nu.-uurn trove inn ��. WITH lEA. 3-1/8" & 4-1 16 OUTLETS u �...ate■ .:-,••�_ I HYDRIL MPL SINGLE GATE iG Willa — f i.i p 13-5/8" 5000 PSI �� FLANGE z FLANGE BX-160 � ! -�� �• •- POIP"E OPERATORS , li -L� "' IIuunmuin Immure FI • CUBING SPOOL -1 I- 1ui;venni utungiii' i(1------- .__D 1 . , GROUND LEVEL I I • . . EXISTING TREE/WELLHEAD MPU L-03 Wellhead/Tree llilrnrp Alnakn,13.0 Milne Point Unit Tree Cap rl r1 II�1 {. w 1'. c p 1 Tree Valve 2-9/16" 5M ,. �� pQo �:,........,. 0 e Tree Cross 2-9/16" 5M 111 lie(o o�i `moo Tree Valve 2-9/16" 5M SSV 2-9/16" 5M 0 t4.1i, .YfY Qe � Tree Valve 2-9/16" 5M ?� or'am�� (Ifl `` 000 `5} 4 (-1 C b ESP Cable �� �, �� '--.. , Control Line ..-------- ` z . Tubing Adapter ' A_ . , cr/ „ i Tubing Head _H .pi, , A-4'� 11" 5M Top x 11" 5M Btn i 4 1-I / , we le* ®iii 611A �m ik■et 'M-i: twirl"-, titirit III .,.. 1 to a id tan Ii ,.0110,1"4.,..il Casing Head III fithicir,,,,,a.roo 11"5M Top x 11" 5M Btm a i 0 _ 0.) a) > m o v0 oai 0To , o 0 °a ... M �as O . -a co 0 c > To a) 1 0-- 3 a C. >.E am -o a) c L w V > -0Y r a CI E Q oo a L COas C as al a ) o Q O M -a Q a) o > ca = LL. J 2 _ al Q L 0 �� • 3 O a a)U 'aa (n o O G L w 0 Q a m a) -°p 'a, 2 a a iic c O L a)0 aO E cs ^' 0 C _ C 'C a7 d �+ CO CO CL, Q,,, anN i 0 >, a It 0 o ' w -oU W m Z EU as o as aV ino °Q ¢ STATE OF ALASKA ALItA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well Q Re-enter Susp Well❑ Other: ESP Completion ❑✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: '*i+0 Hilcorp Alaska LLC Development ❑✓ Exploratory ❑ 190-007 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-21999-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVE0 ADL0025509 MILNE PT UNIT KR L-03 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): FEB 10 2016 N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: AOGCC Total Depth measured 8,900 feet Plugs measured 8,780 feet true vertical 7,316 feet Junk measured 8,763(Fill) feet Effective Depth measured 8,763 feet Packer measured 8,394 feet true vertical 7,212 feet true vertical 6,930 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 13-3/8" 80' 11,280' 1,730psi 740psi Surface 2,726' 9-5/8" 2,758' 2,495' 3,520psi 2,020psi Production 8,836' 7" 8,868' 7,267' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic CY ;( True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 8,303' 6,859' 8,394'MD Packers and SSSV(type,measured and true vertical depth) DLH Hyd Pkr N/A 6,930'ND N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 181 73 816 270 220 Subsequent to operation: 216 228 991 240 224 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations [2.] Exploratory Li Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 3I5- 750 Contact P ul Chan Email pchan@hilcorp.com Printed N Bo York Title OperationsManager Signature ..,e.,......_ T - cep yt Phone 777-8345 Date 2/10/2016 i 3'-z' lt.' Form 10-404 Revised 5/2015RBDMS LL Fig 1 1 2016 Submit Original Only 14 • • Milne Point Unit Well: MPU L-03 SCHEMATIC Last Completed: 1/10/2016 Bacon,Alaska,LLC PTD: 190-007 Orig.KB Elev.:321Nabors 33E) TREE&WELLHEAD Tree 2-9/16"5M FMC ' 11"5M FMC w/11"2-7/8"WKM Tubing Hanger w/2-7/8" 0 t4 ) i, 4. ti Wellhead EUE 8rd,2-1/2"ow"H"BPV profile 13-3/8 FZ OPEN HOLE/CEMENT DETAIL i' 1 ‘.4Arctic Pack 13-3/8" ±500 sks Permafrost"C"in 30"Hole ‘., 9-5/8" 377bb1 class'E',84bb1 Class'G'in 12-1/4"Hole or r 7" 48bbl Class"G"in 8-1/2"Hole I~' CASING DETAIL aa, ar it Size Type Wt/Grade/Conn ID Top Btm BPF i.' 13-3/8" Conductor 48/H-40/Weld 12.715 Surface 80' 0.157 # < 9-5/8" Surface 36/1-55/Btc. 8.921 Surface 2,758' 0.0773 f` , w* ,, 7" Production 26/L-80/Hydril 563 6.276 Surface 8,868' 0.0383 9-5/8 '�,, "At TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf 8,296' 0.00579 WELL INCLINATION DETAIL NOTE KOP @ 600' 7"Casing tested Max Hole Angle=41.35 deg.@ 4,000' to 3,500psi Max Hole Angle through perforations=40 deg. above 8,460'on Max DLS=5.68 deg.@ 3,256'MD 1/5/2012 JEWELRY DETAIL No Depth Item Est.TOC @8,00a 1 135' _STA 2:GLM Camco 2-7/8"x 1"KBMM Dbl Screen Orifice-ID=2.441" 2 8,085' STA 1:GLM Camco 2-7/8"x 1"KBMM Dummy-ID=2.441" :.;, 3 8,227' 2-7/8"XN-Nipple(2.250 No-go ID) 2 11. 4 8,238' Discharge Head:GPDIS f 5 8,238.4' Pump:SXD 137P17 MIN ID=2.250" w 6 8,257 Gas Separator:GRSFTXAR H6 @8,20Z 7 4,,1 3 K 7 8,262' Upper Tandem Seal:GSB3DBUTSB/SB PFSA " 8 8,269' Lower Tandem Seal:GSB3DBLT SB/SB PFSA CL5 9 8,276' Motor:MSP1-325- 210HP,2,145 Volt,59 amp • 4 10 8,299' Sensor:Phoenix XT150 11 8,300' Centralizer:Bottom @ 8,303'MD/6,859'ND 5 12 8,391' On/Off Overshot w/5.88"Gauge Ring/Scoop Guide 4' 13 8,394' 7"DLH Hydraulic Packer 3-1/*2"EUE 8rd BxP k III 6 14 8,410' 3-1/2"Halliburton Auto Fill 15 8,413' 3-1/2"Halliburton Mirage Plug ;i 16 8,432' 3-1/2"HES Shear Sub 50k Pull BxP EUE 8rd 17 8,436' 4-1/8"250 Micron Screen 3-1/2"NU 9.2#1-80 V' 9 18 8,499.5' 3-1/2"NU Bull Plug-Bottom @ 8,500'MD/7,011'ND RATag @8,305' Ea10811 PERFORATION DETAIL R KUP Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status , 12 1 B silts 8,508' 8,552' 7,017' 7,051' 44 10/2/1990 Open A3 8,601' 8,627' 7,089' 7,108' 26 10/2/1990 Open 414 A2 8,634' 8,662' 7,114' 7,135' 28 10/2/1990 Open to 015&16 Al 8,674' 8,704' 7,144' 7,167' 30 10/2/1990 Open 0140 17 STIMULATION SUMMARY GENERAL WELL INFO 18 Well Frac'd @ 40bpm w/1,521bbls gel w/ API:50-029-21999-00-00 KUPBSiIts 147,022 lbs 16-20 carbolite propant. Drilled,Cased and Comp.by Nabors 33E -10/14/1990 ESP RWO-4/18/1994 KUP ASands ESP RWO by Polar#1-7/96 Ir ESP RWO by Nabors 4ES-2/17/99,12/30/00&5/9/04 7 * ESP RWO by Nabors 3S-5/2/07,2/1/08&10/25/08 ESP RWO by Nabors 4ES-3/18/2010 TD=8,900'(MD)/TD=7,316'(TVD) ESP RWO w/Packer and Screens by Doyon 16-12/22/2011 PBTD=8,780'(MD)/PBTD=7,225'(TVD) ESP RWO by Nordic-1/10/2016 Revised By:TDF 2/10/2016 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-03 Nordic 50-029-21999-00-00 190-007 1/1/16 1/10/16 Daily Operations: 12/30/2015 -Wednesday No activity to report. 12/31/2015-Thursday No activity to report. 1/1/2015 - Friday 6 hrs to arrive L-Pad. Receive approval from Pad Operator to pull over Well L-03. Spot Rig over L-03. Berm up rig. Spot secondary equipment. Rig up to kill well. Service TD. Pull BPV with Lubricator. Rig up hoses to Kill Manifold and Tree. Rig up and test hard line to Kill tank to 2,500psi. Open up Well to Choke Manifold with 420psi on the IA and 320psi on the Tbg. Bleed well down to kill tank. Bring on pump @ 3 BPM with 760psi down tubing taking returns to Kill Tank. FCP 670psi 310bb1. Pumped 18bbls lost. Monitor well (well on vac.) Install BPV. N/D tree. Inspect hanger and threads (Good no spear needed). N/U BOP's, install bell nipple, choke and kill line. Pull BPV. Install TWC. Rig up &Test BOPE to 250psi low/3,000psi high, f/5 charted minutes each test using 2-7/8" and 3-1/2" test jt.Test annular to 250psi low/3000 psi high. BOP test was waived to witness by State Rep. Bob Noble. Perform Accumulator draw down test: System press. = 3,000 psi -After closure = 1,950 psi - 200 psi attained in 19 sec. - Full pressure attained in 96 seconds. Rig down test equipment. 1/2/2015-Saturday Finish BOP Test. Rig down test equipment. Pull TWC. MU Landing Joint. B.O.L.D.S. Unseat Tbg Hanger with 130K Up Wt, PUH 4'. Close Bag. Line up to CBU to Kill Tank. Circulate 1 hole volume to kill tank. 4 BPM/1,010psi ICP. Pump 127 bbls and increase pump rate to 5 BPM/1,488psi tbg and 250psi on choke. Circulate total of 295 bbls, with 305 to Kill tank. Load and tally 3-1/2" drill pipe in pipe shed. Open Annular with well on vac. Pull Tubing Hanger to floor w/120K Up Wt. Test Cable. Undress and lay down Tubing Hanger. POOH with 2-7/8" ESP completion from 8,200'to 2,000' standing back 2-7/8" tubing in derrick. Lay down 13 bad joints so far. Hole fill taking 1 bbl over calculated each fill. Continue to POOH with ESP.from 6,923'to surface.Total of 21 bad jnts. L/D motor assembly & Pumps. Set test plug. Change out the lower BOP pipe rams from 2-7/8" to 3-1/2".Test lower pipe rams 250psi/3,000psi, hold for 5 each test (Good) rig down test equipment. Pull test plug. Install wear ring. Pick up packer retrieving tool. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-03 Nordic 50-029-21999-00-00 190-007 1/1/16 1/10/16 Daily Operations: 1/3/2015 - Sunday Continue to TIN with packer retrieving tool picking up 3-1/2" drill pipe out of the pipe shed from 1,685'. Tag fill @ 8,388'(Top of PKR Estimated @ 8,407'). 162K Pu, 110K So. MU TD wash down from 8,388' to 8,402' @ PM/630psi. Did see slight increase in pump pressure. Pump hi vis sweep to surface from 8,402' @ 6 bpm/1,042psi. Lots of fine sands during circulation. 670 units max gas. Continue to wash down from 8,402' @ 2 bpm, engage seals in top of PKR @ 8,415'.Attempt several times to Latch PKR as per halliburton Rep, washing down and seeing seals engage, but could not get a good latch due to possible fill inside the PKR. Set down 30K at one point attempting to latch. Park directly above top of PKR with Retrieving tool. Reverse circulate bottoms up. Recovered sand and scale @ bottoms up. Circulate down drill pipe to clear WS. Attempt to latch PKR again with no success. Consult with Project engineer. POOH from 8,415' with PKR Retrieval tool for stinger/scraper run to C/O inside of PKR. Park @ 3,000'. Slip and cut drill line. Continue POOH f/3,022'to Surface. L/D packer retrieval tool. Make up BHA#2 Clean out Assembly. Mule shoe 10.26-xo .63 -xo 1.78- DPS 1.86-xo - 1.93 - boot basket- boot basket-7" scrapper- bit sub 3.10-Total = 31.24'. RIH with BHA 44 @ to 4,300+/-. Rig up an rev. circ. 64bb1 @ 5bpm 603 psi. R/D and blow down top drive. Continue RIH from 4,300' to 8,414'. Broke circ. @ 8,400' @ 2bpm 270psi. Washing down to 8,414' were we took weight setting down 5 to 10k (no pressure increase) pull up and attempted several times (No go). Pick up to 8,410' and reverse circ. 63bbls. Easing rate up to 5bpm 955psi at B/U we saw 10.5 gal. Of 90%sand 10%scale. Open up annular and attempt wash down @ 2bpm 240psi. Past 8,414' (No Go). Picked up to 8,413' and closed annular rev. circ. 221 @ 5bpm 975psi. . • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-03 Nordic 50-029-21999-00-00 190-007 1/1/16 1/10/16 Daily Operations: 1/4/2015- Monday Continue to reverse circulate well clean.Shut down pump. Park @ 8,414'Just inside PKR Profile. Rig up circulating lines for acid job. PT same to 2,500psi. While waiting on Acid transport, Reverse circulate bottoms up through rig up to ensure proper alignment of flow paths. Circulate drill string volume for same. Acid on location @ 08:00 hrs. Monitor well on trip tank while implementing procedure and plan forward. Spot LRS and Acid 1 Load 50 bbls Sea Water on to LRS. Riup LRS/SLB circulating lines. PJSM with all parties envolved. LRS PT lines to 3,000psi. LRS pump 10 bbls 15% HCL and follow with 50 bbls SW followed by 2 bbls 60/40 methanol down drill pipe. Placing acid @ end of Pipe 8,414'. Isolate, blow down and rig down LRS and acid transport. Line up to pump down drill string with Rig Pump. Pump .50 bbls and let soak for 15 minutes. Repeat this process for 10 bbls. Monitor well on trip tank between stages and watching for increase in losses. Line up to reverse circulate to the kill tank. Reverse circulate 15 bbls soda ash pill and follow with 300 bbls Sea Water from pits @ 5 BPM/1,460psi, dropping to 1,320psi after bottoms up strokes. Expel acid and soda ash to Kill tank (STS Volume is 284 bbls). Flush dead legs on flow paths to Kill Tank. Rig down circulating equipment. Blow down Surface line to Kill Tank. Total volume pumped 311 bbls/w 304 bbls back. MU top drive. Bring on pump @ 3 bpm. PUH and slack back off setting down @ 8,414' 5K, PU off tag and rotate pipe 1/2 turn and work torque down hole. Slack off and pass through top of PKR @ 8,414' no go out on BHA @ 8,426' mule shoe depth with 5K and 40 psi pump pressure increase. PUH and park @ 8,415'. Reverse circulate bottoms up from 8,415'. 310bbl @ 5bpm 1,000psi 10gal of 98% sand 2%scale. Open annular. Monitor well. Pull one stand and blow down equipment. POOH F/8,346' to surface. Lay down BHA: Note boot baskets were empty. Clean off rig floor and pick up retrieval tool. Make up BHA#3: 6' 3-1/2" IF pup jnt. Running tool 7.26.Total =13.26. RIH to 8,414'. M/U top drive, washed down through the packer pumping @ lbph 50psi, after seeing pressure build up, pumps were stopped and pressure was bled off.That was a good indication that the seals were engaged into the packer, sat down 10k to latch up, picked up to 15k over to verify latch (No-go). Attempt engage packer with retrieval tool several time with tool rep. (no go). Rev. circ. @ 5bpm 930psi to see if there still some debris around the packer and profile. Note: we tagged up @ 8,412' and got in to 8,418'. Attempt engage packer with retrieval tool (no go). Blow down TD and POOH call town and discuss next option. • • 1111 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-03 Nordic 50-029-21999-00-00 190-007 1/1/16 1/10/16 Daily Operations: 1/5/2015 -Tuesday POOH with Packer retrieving tool. Inspect tool. Showing signs of seals engaging. Remove seals off of tools. Dress tool for rerun. RIH with retrieving tool T/8,409'. UP/DN 162/108K. Break circ @ 1 bpm & bring pumps up to 5 bpm to condition fluid (Slight Gas Break out). Circ 70 bbl. Circ @ 1 bpm 60 psi. Set down & string pressured up @ 8,415'. Shut down pumps. Set down 7K. P/U with no over pull. Set down with 10 K. No over pull. Slight bobble.Try working set down weight up to 20K along with various parameters. No change. Circ btm up while discussing with town. POOH with retrieving tool. Mob out tools from baker to Mill packer.LID Halliburton retrieving tool. P/U Bakers Milling Assembly. BHA: 6-1/8" X 3-2/8" PACKER MILL 2.24-4-3/4" BOOTBASKET 3.99 -4-3/4" BOOTBASKET 4.40-4-3/4" BOOTBASKET 3.95 - BIT SUB BFF 3.01 -4-3/4" BOWEN LBS 7.55 -4-3/4" BOWEN OIL JAR 11.13 - PUMP OUT SUB 1.54- 12---4-3/4" DRILL COLLARS 362.61 Total =400.42. RIH with Bakers Milling Assembly on 3-1/2" drill pipe out of the derrick. Mill Packer F/8,413'T/8,416'. WOB 2-5K, 213 gpm. 1,051psi. TD RPM 80, 5-8k ft/lbs tq, P/U 165K, S/O 120K, ROT 140K. Sea water 8.5+ ppg, 22-25% Return flow. Hi vis sweep brought back 70%fine metal shaving 30%oil sand mixture. Vis of sweep 130. Continue Milling Packer @ 8,416'. WOB 5- 10K, 209 gpm. 790psi. TD RPM 80, 5-6k ft/lbs tq, P/U 165K, S/0 120K, ROT 140K. Sea water 8.5+ ppg, 20-22% return flow. Slip released from packer @ 8,416' pushed to 8,423'. P/U and circ. Pump 20 bbl Hi-Vis sweep, pumping @ 417gpm 2,830psi. 80 rpm. 2,700 unit of gas seen at B/U. Stop Rotation and push packer down 8,4311, set 5K down. Pick up and circ. • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-03 Nordic 50-029-21999-00-00 190-007 1/1/16 1/10/16 Daily Operations: 1/6/2015-Wednesday Circ 20 bbl sweep around with no cuttings in returns. Monitor well. Static. Blow down TD. Recovered 17#of metal from milling. POOH F/8,431'T/7,925'. Hole not taking corect fill. Circ Btms up. No gas. Continue to POOH F/7,925'T/6,355' 3.5 bbl under calculated hole fill. RIH T/8,405'. Kelly up. Weight up pits to 8.7 ppg. Circ @ 275 gpm 1,250psi 8.7 in and out. Shut down & monitor well. Losing 1 bph. Slip & cut drilling line. POOH F/8,405' To BHA. Stand back 4-3/4" collars.Well 3 bbl over hole fill. Clean out boot baskets approximately 25 pounds of metal was recovered. Make up BHA#7: 2-13/16" Spear 2.62 -Spear Ext. 3.09-Spear Ext. 3.02-XO 1.53 -4-3/4" BOWEN LBS 7.55 -4-3/4" BOWEN OIL JAR 11.13 - PUMP OUT SUB 1.54- (12) 4 3/4" DRILL COLLARS 362.61 Total = 393.09'. RIH with spear t/8,406, P/U 175k-S/O 110 pumping @ 2bpm 350psi located the top of the fish @ 8,450'. S/O to the no go shoulder @ 8,558'. Pump pressure increased to 550psi. Turned pumps off and set 5k on fish. P/U to 8,425' P/U weight increased 180k(5k over). Rolled pumps @ 2bpm -550psi, ensure fish was still engaged. Monitor well-static loss rate @ 1.5 bpm. POOH to 8,009'fish periodically hanging. Pull 20k over attempt to circ. (no go) spear plugged off. Dropped the ball & rod. Circ sub opened @ 2,185 si. Circ, B/U @ 412 gpm 2,410psi. (14 units @ B/U). Continue POOH f/8,009'to 5,690' periodically hanging up on junk while pulling out. 1/7/2015 -Thursday Continue POOH F/5,690'T/4,774'. Periodically hanging up while pulling up. Having to work through spots by going back down. Over pulling not working. Can't fire jars. Continue to work through hang ups with up & downs. T/ BHA. Stand back drill collars, Recover packer&screens.,Packer slips intact with upper mandrel. Rubber in pieces stuck in jars. See 0 Drive for pics. L/D spear,Jars, Bumper. Screens full of frac sand. Did not see holes in screens.They looked good other than silt/scale build up on low side of screen. M/U Clean out BHA: Mule shoe 10.26-xo .63 -xo 1.78- DPS 1.86-xo -4-3/4 BOOTBASKET 3.99 -4-3/4 BOOTBASKET 4.40-4-3/4 BOOTBASKET 3.95 - 7" scrapper- bit sub 3.10- (12) 4-3/4 DRILL COLLARS 362.61 Total = 362.61. RIH to 8,507', established parameters, P/U 178k S/O 110k pumping @ 3bpm 300 psi. Wash from 8,507' to 8,763'. Set down 5k over pump pressure increased 600psi.Attempt to wash through with no success. Pull up to 8,758'. Circ hole clean. Pumped a series of Hi-vis sweeps @ 9bpm 2,950psi. Sweep brought back approximately 20 gal of 80%sand 20%scale mixture. 800 units of gas @ B/U. Blow down top drive. Pull up to 8,507' (top of the perfs.) Monitor well static loss rate 2bph. POOH F/8,505' -T/4,415'. Circ. B/U @ 500gpm 2,500psi 5gal of sand and scale mixture (no units gas at B/U). Monitor well -continue POOH from 4,415'. • I raj Hilcorp Alaska, LLC gig Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-03 Nordic 50-029-21999-00-00 190-007 1/1/16 1/10/16 Daily Operations: 1/8/2015- Friday POOH F/4,415'T/ BHA. L/D (12)4-3/4 DC. L/D scraper& boot baskets. 2 cups of frac sand in boot baskets. M/U stack wash tool. Wash stack with swizzle stick. R/D wash tool. BDTD. Change handling equipment. P/U screens, Shear sub, Mirage plug with auto fill,Tri Point 7" DLH Hydraulic packer, On Off tool. Crew change, Clear floor of old packer. Halliburton inspecting shear sub & Mirage plug. Bring in 2-7/8 new joints to replace bad ones laid down during decomplete. RIH,:wit Lp eker& screens. F/ 158' T/8,393' on 3.5 Drill pipe. P/U weight 170k S/O 107k. Rig up test equipment. Pump down the drill pipe @ 2bpm to ensure that the auto fill is closed (Good). Pressure up to 3,500psi to set DLH Hydraulic Packer& hold for 30 min(Good). Line up and test the IA 1,500psi, hold for 30min. (first 10min 5psi. bled off, total though out pressure test 10psi) Good. Bled pressure to 0, line up & pump down the drill pipe to 4,500psi and bust the Mirage plug (Good). Rig down test equipment, make up the top drive, rotate in reverse 2 raps and release off DLH packer(Good). P/U 8,361' CBU "TOP OF DLH PAKER @ 8,393'. CBU @ 6bpm @ 885psi 166 unit of gas @ bottoms up- Monitor well. (No Flow). POOH L/D 3-1/2" drill pipe T/7,340'. Monitor well due to hole fill being off 1.6-CBU 5bpm 850psi (No gas at bottoms up). Continue POOH 7,340' -to 3,904'. 1/9/2015-Saturday POOH to surface - Laydown BHA. Slip and cut off 66' of drilling line. Pull wear ring- Install test plug. Rig up and Test BOP's. Test ROPE to 250psi low/3,000psi high f/. 5 charted minutes each test using 2-7/8" and 3-1/2" test jts. Test annular to 250psi low/3,000psi high. Draw down test: System press. = 3,000psi-After closure = 1,950psi - 200psi attained in 21 sec. - Full pressure attained in 96 seconds. BOP test was witnessed by AOGCC Rep. Guy Cook. Pull test plug& rig up to run 2-7/8" ESP completion. Make up ESP motor-service-test (Good). Run in the hole with 2 7/8" ESP_completion. Test cable every 2,000'for continuity.Test cable @ 2,060' for continuity(Good). Continue Run in the hole with 2-7/8" ESP completion. F/2,060' -T/3,975'.Test cable @ 3,975'for continuity (Good). Continue Run in the hole with 2-7/8" ESP completion. F/3,975' -T/6, 048. Test cable @ 6,048' for continuity (Good). Continue Run in the hole with 2-7/8" ESP completion. F/6, 048 -T/6,528'.Test cable, change spools and make cable splice on 2nd spool. Monitor well on Trip Tank while making splice with 1 BPH static loss rate. 1/10/2015-Sunday Continue splice on ESP cable at 6,528'. Continue to RIH w/ ESP completion f/6,528' to 8,260' changing out bad joints as needed. PUW 112k-SOW 80k. MU landing jt w/floor valve & hanger. Splice ESP cable to lower connector. Continue to splice ESP cable to lower connector. Land hanger in well head. Verify alignment and RILDS per Well Head Rep. Final depth at bottom of pump assembly= 8,302.51'. PUW 112k-SOW 80k. Set BPV per Well Head Rep. ND BOPE. N/A tree -test hanger void 500psi low/5,000psi high, hold for 10 min. Pull BPV-final test on ESP (good) Nordic 3 Rig Released @ 20:00 hrs. 1-10-2016. 1/11/2015- Monday No activity to report. 1/12/2015 -Tuesday No activity to report. of Tit . • 4,4. �//y%SA THE STATE Alaska Oil and Gas �w 7 of® T Conservation Commission 1 1L � 333 West Seventh Avenue g e, Alaska 99501-3572 ,�.T,,, GOVERNOR BILL WALKER Anchorage,Main: 907.279.1433 *h.' ®F LAS*P Fax: 907.276.7542 www.aogcc.alaska.gov Bo York tJ � Operations Manager Hilcorp Alaska, LLC j q© 00 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Milne Point Field,Kuparuk River Oil Pool,MPU KR L-03 Sundry Number: 315-750 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this //`0 day of December, 2015 Encl. RBDMSLADEC 211015 • • RECEIVED STATE OF ALASKA DEC 15 2015 _ ALASKA OIL AND GAS CONSERVATION COMMISSION /zip6'/Xs APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing E Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ESP Completion 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development O. 190-007 3.Address. Stratigraphic [1Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-21999-00-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432C • Will planned perforations require a spacing exception? Yes ❑ No 0 MILNE PT UNIT KR L-03 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025509 , MILNE POINT/KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,900' 7,316' . 8,780' 7,225' 1,823 8,780' N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 13-3/8" 80' 112' 1,730psi 740psi Surface 2,726' 9-5/8" 2,758' 2,495' 3,520psi 2,020psi Production 8,836' 7" 8,868' 7,267' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic / See Attached Schematic 2-7/8" L-80/6.5#/EUE 8rd 8,296' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): HES 7"x 3.5"VTA and N/A • 8,407(MD)/6,940(TVD)and N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 . Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 12/24/2015 Commencing Operations: OIL E. WINJ E WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Paul Chan Email pchan@.hilcorp.com Printed Name Bo York Title Operations Manager Signature ` Phone 777-8345 Date 12/15/2015 i'lr--- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: * 300 O /DS— j3oP /.25 fr & f',,kms► w,,«.i,J co 3 'o '4 ( .BN1 < S. 5-.1-Pr j__.. ) Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: I Q— `10' 1 /D APPROVED BY Approved by:r0,y�J COMMISSIONER THE COMMISSION Date: 12 -/3_1 5 yyy 111 QrRd1c1tNsALr a2015 7/,_ oar0 h a e of approval. Attachments in Duplicate • • Well Prognosis Well: MPU L-03 iiil(orp Alaska,LL) Date: 12/10/2015 Well Name: MPU L-03 API Number: 50-029-21999-00 Current Status: Oil Well [Failed ESP] Pad: L-Pad Estimated Start Date: December 24th, 2015 Rig: Nordic 3 Reg. Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190-007 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 2,523 psi @ 7,000' TVD (BHP 12/11/2015 /6.93_p_pg EMW) Maximum Expected BHP: 2,523 psi @ 7,000' TVD (No new perfs being added)/ MPSP: 1,823 psi (0.1 psi/ft gas gradient) S 5 1 Li PPS. Brief Well Summary: MPU L-03 was drilled in February 1990 and completed in October 1990 as a Kuparuk River formation producer. The well has had multiple ESPs installed: May 1994,June 1996, February 1999, December 2000, May 2004, May 2007, February 2008, October 2008, March 2010, and January 2012. A FCO and casing pressure test were performed during the January 2012 workover. The ESP has failed phase to phase and phase to ground. Notes Regarding Wellbore Condition • Casing tested to 3,500 psi for 30 minutes down to 8,460' MD on 1/5/2012. •' Objective: Replace failed ESP and run a new ESP. Brief RWO Procedure: 1. MIRU Nordic#3 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 2. Pull BPV. Circulate well clean with R.5 ppg sea water. 3. Set BPV. ND Tree. NU 11" BOPE. Pull BPV and set TWC. 4. Test BOPE to 250 psi low/3,000 i jgh, 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 Nordic 3 BOP Test Procedure. /s� b. Notify AOGCC 24 hrs in advance of BOP test. c. Submit completed 10-424 BOPE test results within 5 days of completed test. d. Confirm test pressures per the Sundry Conditions of approval. e. Test VBR rams and annular with 2-7/8" and 3-1/2" test joint. 5. Contingency: (If the tubing hanger won't pressure test due to eroded and/or corroded BPV profile and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path, test choke manifold per standard procedure • • Well Prognosis Well: MPU L-03 I ikor!)Alit, LI Date: 12/10/2015 c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 6. Bleed any pressure off tubing and casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg seawate as needed. 7. MU landing joint or spear and recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 8. POOH and stand back the 2-7/8" tubing. Tubing will be re-used. Lay down failed ESP. a. Replace bad joints of tubing as necessary. b. Look for over-torqued connections from previous Doyon#16 tubing runs. 9. RIH with cleanout assembly to top of Halliburton packer at 8407' MD. Circulate the well clean. If needed, spot sized salt pill to control losses. POOH. F?_O w/ (L .J cra-4-7 10. Contingency: The screens on the Halliburton VTA packer may have failed. Depending upon the results from the FCO,the screens/packer may be fished. a. PU spear/Halliburton retrieving tool and recover packer and screens. POOH. b. RIH with cleanout assembly and tag fill. Circulate the well clean. If needed, spot sized salt pill to control losses. POOH. Depending upon the condition of the screens, a new packer/screens may be set. c. RIH with packer/screens and set at-8400'. POOH. 11. PU new ESP and RIH with existing 2-7/8" 8RD EUE L-80 tubing a. Run Upper GLM @ ± 140' w/valve b. Run lower GLM @ ±8,060'w/valve c. Run 2-7/8" XN profile @ ±8,200' MD d. Set base of ESP at±8,300' MD 12. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 13. Set BPV. ND BOPE. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 14. RU hot oil and freeze protect well to 2100' MD if needed. 15. RD Nordic#3 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 16. Turn well over to production. 17. RU well house and flowlines. • Well Prognosis Well: MPU L-03 Hikcora Alaska,LLI Date: 12/10/2015 Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic 5. Existing Tree/Wellhead 6. Nordic#3 Flow Diagram 7. Blank RWO Changes Form H . • Milnll:e PointU Unit WeMP SCHEMATIC Last Completed: 1/11/2012 Hilcorp Alaska,LLC PTD: 190-007 Orig.KB Elev.:32'(Nabors 33E) TREE&WELLHEAD Tree 2-9/16"5M FMC i 11"SM FMC w/11"2-7/8"WKM Tubing Hanger w/2-7/8" 4 Wellhead EUE 8rd,2-1/2"CIW"H"BPV profile 13-3/8" OPEN HOLE/CEMENT DETAIL 1 AraicPaGc 13-3/8" ±500 sks Permafrost"C"in 30"Hole 4: 9-5/8" 377bb1 class'E',84bb1 Class'G'in 12-1/4"Hole � 7" 48bb1 Class"G"in 8-1/2"Hole 1,4 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 0 113-3/8" Conductor 48/H-40/Weld 12.715 Surface 80' 0.157 "r '+`" ) 9-5/8" Surface 36/1-55/Btc. 8.921 Surface 2,758' 0.0773 1 7" Production 26/L-80/Hydril 563 6.276 Surface 8,868' 0.0383 9-5/8" � 4 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf 8,296' 0.00579 WELL INCLINATION DETAIL NOTE KOP @ 600' 7"Casing tested Max Hole Angle=41.35 deg.@ 4,000' to 3,500psi Max Hole Angle through perforations=40 deg. I above 8,460'on Max DLS=5.68 deg.@ 3,256'MD ) j 1/5/2012 1 JEWELRY DETAIL No Depth Item Est.TOC @8,000/ 1 135' GLM Camco 2-7/8"x 1"KBMM w/Dummy-ID=2.371" 2 8,059' GLM Camco 2-7/8"x 1"KBMM Open-ID=2.371" .s . ",1',.''' 3 8,202' 2-7/8"XN-Nipple(2.250 No-go ID) k2 4 8,217' Discharge Head:GPHVDIS '+ 5 8,218' Pump:SXD 119-P23 MIN ID=2.250" '4 t " 6 8,235' Pump:SXD 68-G31 MVP @8,202' ,, Iiiii 3 62,1 7 8,251' Gas Separator:GRSFTXAR H6 `: ! ." 8 8,256' Upper Tandem Seal:GSB3DBUT SB/SB PFSA k'_' 9 8,263' Lower Tandem Seal:GSB3DBUTSB/SB PFSA 1 i': al l,4. 10 8,270' Motor:KMH 266HP,2,345 Volt,69 amp 1 11 8,292' Sensor:Pumpmate XTO s 5&6 12 8,294' Centralizer:Bottom @ 8,296'MD/6,854'TVD e 13 8,407' HES 7"x 3.5"VTA Packer IIII t 7 14 8,425' HES 3.5"Shear Sub(50k) i.8&9 15 8,436' Poromax 250 Micron Sand Screen ' 16 8,500' Bull Nose Plug PERFORATION DETAIL jag `fit 10 KUP Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status RATag@8305' B silts 8,508' 8,552' 7,017' 7,051' 44 10/2/1990 Open 11 A3 8,601' 8,627' 7,089' 7,108' 26 10/2/1990 Open 12 '0 A2 8,634' 8,662' 7,114' 7,135' 28 10/2/1990 Open , ' • X13 Al 8,674' 8,704' 7,144' 7,167' 30 10/2/1990 Open r. 14 STIMULATION SUMMARY 15Well Frac'd @ 40bpm w/1,52lbbls gel w/ 4 147,022 lbs 16-20 carbolite propant. *R } GENERAL WELL INFO >' 16 KUP B Silts API:50-029-21999-00-00 it 14 Drilled,Cased and Comp.by Nabors 33E -10/14/1990 KUP A Sands ESP RWO-4/18/1994 ESP RWO by Polar#1-7/96 ESP RWO by Nabors 4ES-2/17/1999 7"/A. ESP RWO by Nabors 4ES-12/30/2000 TD=8,900'(MD)/TD=7,316'(TVD) ESP RWO by Nabors4ES-5/9/2004 PBTD=8,780'(MD)/PBTD=7,225'(TVD) ESP RWO by Nabors 3S-5/2/2007 ESP RWO by Nabors 3S-2/1/2008 ESP RWO by Nabors 3S-10/25/2008 ESP RWO by Nabors 4ES-3/18/2010 ESP RWO w/Packer and Screens by Doyon 16-12/22/2011 Revised By:TDF 12/14/2015(V) • Milne n . ii • Well: Poi MPU t L-03Unit PROPOSED Last Completed: 1/11/2012 !neon)Alaska,LLC PTD: 190-007 Orig.KB Elev.:32'(Nabors 33E) TREE&WELLHEAD Tree 2-9/16"5M FMC 11"5M FMC w/11"2-7/8"WKM Tubing Hanger w/2-7/8" ,,' Wellhead EUE 8rd,2-1/2"CIW"H"BPV profile 13-3/8" � � 1 OPEN HOLE/CEMENT DETAIL I 13-3/8" ±500 sks Permafrost"C"in 30"Hole {" Ardic Pack ' 9-5/8" 377bb1 class'E',84bb1 Class'G'in 12-1/4"Hole �/ 7" 48bbl Class"G"in 8-1/2"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/Weld 12.715 Surface 80' 0.157 9-5/8" Surface 36/1-55/Btc. 8.921 Surface 2,758' 0.0773 7" Production 26/L-80/Hydril 563 6.276 Surface 8,868' 0.0383 9-5/8 4 '� TUBING DETAIL 2-7/8" Tubin 6.5/L-80/EUE 8rd 2.347 Surf ±8,296' 0.00579 WELL INCLINATION DETAIL NOTA KOP @ 600' 7"Casing tested Max Hole Angle=41.35 deg.@ 4,000' to 3,500psi above 8,460'on Max Hole Angle through perforations=40 deg. 1/5/2012 Max DLS=5.68 deg.@ 3,256'MD JEWELRY DETAIL No Depth Item Est.TOC@8,000' 1 ±135' GLM Camco 2-7/8"x 1"KBMM w/Dummy-ID=2.371" 2 ±8,059' GLM Camco 2-7/8"x 1"KBMM Open-ID=2.371" 3 ±8,202' 2-7/8"XN-Nipple(2.250 No-go ID) 2 .`'„ 4 ±8,217' Discharge Head:GPHVDIS 5 ±8,218' Pump:SXD 119-P23 6 ±8,235' Pump:SXD 68-G31 MVP 3 7 ±8,251' Gas Separator:GRSFTXAR H6 8 ±8,256' Upper Tandem Seal:GSB3DBUT SB/SB PFSA 9 ±8,263' Lower Tandem Seal:GSB3DBUT SB/SB PFSA rE `.4 10 ±8,270' Motor:KMH 266HP,2,345 Volt,69 amp 11 ±8,292' Sensor:Pumpmate XTO .,5&6 12 ±8,294' Centralizer:Bottom @ 8,296'MD/6,854'TVD , 13 ±8,407' HES 7"x 3.5"VTA Packer !111E1 7 14 ±8,425' HES 3.5"Shear Sub(50k) it !'88,9 15 ±8,436' Poromax 250 Micron Sand Screen 16 ±8,500' Bull Nose Plug PERFORATION DETAIL k*„10 KUP Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status RA Tag @8,305 ,''11 B silts 8,508' 8,552' 7,017' 7,051' 44 10/2/1990 Open -------‘p, liii 12 A3 8,601' 8,627' 7,089' 7,108' 26 10/2/1990 Open �►ta A2 8,634' 8,662' 7,114' 7,135' 28 10/2/1990 Open IffliEpiiM3 Al 8,674' 8,704' 7,144' 7,167' 30 10/2/1990 Open *14 STIMULATION SUMMARY 15 Well Frac'd @ 40bpm w/1,521bbls gel w/ 147,022 lbs 16-20 carbolite propant. 01110 16GENERAL WELL INFO KUP B Silts API:50-029-21999-00-00 Drilled,Cased and Comp.by Nabors 33E -10/14/1990 KUP ASands ESP RWO-4/18/1994 -4-- ESp RWO by Polar#1-7/96 ESP RWO by Nabors 4ES-2/17/1999 7 I ESP RWO by Nabors 4ES-12/30/2000 TD=8,900'(MD)/TD=7,316'(TVD) ESP RWO by Nabors 4ES-5/9/2004 PBTD=8,780'(MD)/PBTD=7,225'(TVD) ESP RWO by Nabors 3S-5/2/2007 ESP RWO by Nabors 3S-2/1/2008 ESP RWO by Nabors 3S-10/25/2008 ESP RWO by Nabors 4ES-3/18/2010 Revised By:TDF 12/14/2015(V) ESP RWO w/Packer and Screens by Doyon 16-1/11/2012 Mit Point • H Nordic#3 BOP 1Tiirer1 l*4 a,LI ( 1 Irti Ili irri inti \ ,...Hydril Hydril 11" 5M Ili do di 1 1 di i < Shaffer r,00 Pipe or VBR Rams a 11" 5M Blinds 3 1/8 5M Kill Valves iim••.° ,,,`" 3 1/8 5M Choke Valves Manual and HCR Manual and HCR I1 1111 _1'1rul L'o:l :i4Ih,;,Jl1 , ,p1 , 'ii �• C C J � OI 1 _ Hydril — cot 9- 11" 5M 1=u Pipe Rams ao r; c • r, Plilij1 „.,,„..„„,„V ( n .-,-,-„-,'...---„-„'„-.".",',".^.-„^„".-.- .., ;; .v r . x vA„-,','.'," m IYI 1.l 1.1 I.I 0 -„%"*" xYk, j ' ,,,,....,,,,,.,%. 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F F F x F M F V A F # O v v v F F ' N r n s m ill0; I h h O �O n n �f ° . 11 • • MPU L-03 EXISTING TREE/WELLHEAD Wellhead/Tree xi!corp Alaska,LLC Point Unit Tree Cap ' o n/o 0 Tree Valve 2-9/16 5M O I.,h,.l c sr Tree Cross 2-9/16" 5M pl®(o)o Tree Valve 2-9/16" 5M o SSV 2-9/16" 5M 0 5I^ISP 0 0 Tree Valve 2-9/16" 5M4-A.(off ' b-0. 0- 711- 11;: n—I ESP Cable "' "' Control Line Tubing AdapterII r a ' 1- Tubing Head 'UI iii 11" 5MTop x11" 5MBtm _■ � otilila I( )i ii.. no �, Iii III mai l swrz s!' _ �t Casing Head . 9 11" 5M Top x 11" 5M Btm ��l�l. °1°(..0c>f) '�' � i"' iii t ie... ■ "" • • O I x m 2 F u o .+ U X a 15 i 0i4HI T � -N* n zn m 'a x L E a W -_ h0 3 dY Z N _ O 2 Q e W ! ;. .4.ic' -:I _ l1 I n1 i z oy r1 O W u " U 11 y x aY 11 o m m , 'I`— U E � N I f 1 Y f •U l ldlsn0 see Y f E • f • . E g E -- " I 1:4 s IU O E E • • E gi. A.. G s� { ~ •{ u El f u f p C u f E E y = U U 0 .- ..— �•. Uwe P._ < �p U . I li .i • _ ,1,, U o — , :Y' U 1 * U C 1 611101 Y mg F kM{il C O C O ,13 V c.ry H a. D L1Ak_ 04 a� LLtt gg ott a U ` . • c CD CD - 0 / = J2 - as as w c > 7 / o2 . .o 7 2 12.2 § m « -...- E £ • c o f -0U) \ § Ytd / % f k . f ? < ® ,_ .— 7 \ \ / 22 I \ ag / ma/ - RI / m % .§ ■ a)2 \ k k § % 03 Co / Q % I / 5 / § ® 7 / I fd k \ � 2 E §c 2 0 2/ '\ � / H lc § co 4 lei � 0. _ Q / \ 2 tL. 0, (a c , § o ° 3 = _� Q = 0 R E Co X \ f 0 CO U / _� / u .. _ • e C) E E � \ Co 0 e 0 Co $ CO < 2 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. t q{~" ~/-/' File Number of Well History File PAGES TO DELETE 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 Complete COMMENTS: Scanned by: ~Bren [] TO RE-SCAN Notes: Vincent Nathan Lowell Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd STATE OF ALASKA ALASIWIL AND GAS CONSERVATION COMMI ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon IN Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Replace Failed ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 190 - 007 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 a 50 029 - 21999 - 00 - 00 7. Property Designation: 8. Well Name and Number: ADL 025509 — MPL -03 9. Field / Pool(s): .. Milne Point Unit / Kuparuk River Oil Pool 10. Present well condition summary Total depth: measured 8900' feet Plugs (measured) None feet true vertical 7316' feet Junk (measured) None feet Effective depth: measured 8780' feet Packer: (measured) 8407' feet true vertical 7225' feet Packer: (true vertical) 6940' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13 -3/8" 115' 115' Surface 2725' 9 -5/8" 2758' 2494' 3520 2020 Intermediate Production 8837' 7" 8868' 7291' 7240 5410 Liner , I PA N 5 t 2012 Perforation Depth: Measured Depth: 8508' - 8704' True Vertical Depth: 7017' - 7167' Tubing (size, grade, measured and true vertical depth): 2 -7/8', 6.5# & L -80 8296' & 6854' & 3 -1/2 ", 9.3# 8407' - 8500' 6940' - 7011' Packers and SSSV (type, measured and true vertical depth): HES 7" x 3 -1/2" VTA Packer Sand Screen 8407' 6940' 11. Stimulation or cement squeeze summary: RECEIVED Intervals treated (measured): hh Treatment description including volumes used and final pressure: .3A &u12 Aige4 Oil & ¶aE CL"-.'a4. C n is inn 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ❑Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory ., ® Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ❑ GINJ ® Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Jesse Rosenbaum, 564 -5155 N/A Printed Name Terrie Hubble Title Drilling Technologist • of oi1 r Prepared By Name /Number: Signature � / 4i Phone 564 -4628 Date IZ_Terrie Hubble, 564 -4628 Form 10-404 Revise 10/2010 JAN 26 201 7 e... 1.2(€.(z. ,d07 /Snit Original Only • • North America - ALASKA-BP Page 1 of 17 Operation Summary,Report, Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- 00VON -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 @36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/27/2011 12:00 - 13:30 1.50 WHSUR P WHDTRE SECURE WELL CELLAR. 13:30 - 18:30 5.00 RIGD P PRE PJSM - BRIDLE UP DERRICK AND PREPARE TO LAY DOWN - SET TOP DRIVE LOWER IN ROTARY TABLE. - LAY DOWN DERRICK AND SECURE 18:30 - 20:30 2.00 RIGD N RREP - PRE PJSM -AIR UP DAMAGED TIRE - RAISE CELLAR DOORS 20:30 - 23:00 2.50 MOB P PRE PJSM - PREP RIG AND MOVE OFF WELL - STAGE RIG ON RIG MATS FOR TIRE REMOVAL -PJSM - REMOVE BOP'S FROM CELLAR - SECURE BOPS TO MOVING STAND - UNABLE TO SOURCE CH2MHILL TRUCK TO MOVE BOP SKID - SET BOP STACK DOWN, AND THEN MOVED THE RIG AWAY FROM STACK 23:00 - 00:00 1.00 MOB N RREP PRE STAGE RIG FOR SPREADER BEAM AND TIRE REMOVAL -SHIM RIG TO SUPPORT RIG WITHOUT REAR SPREADER BAR TOUCHING THE GROUND 12/28/2011 00:00 - 06:00 6.00 MOB N RREP PRE CREW CHANGE AND PJSM -RIG DOWN EQUIPMENT FROM REAR BULKHEAD -RIG DOWN CELLAR EQUIPMENT TO ACCOMMODATE TIRE CHANGE -PULL REAR SPREADER BAR OUT OF CELLAR - CONTINUE TO REBUILD THE LOWER HALF OF CHOKE MANIFOLD - CONTINUE TO SERVICE THE KOOMEY UNIT 06:00 09:00 3.00 MOB N RREP - PRE REMOVE OLD TIRE -OFF DRILLER SIDE / OUTBOARD REAR. -MOUNT AND AIR UP. 09:00 - 12:00 3.00 MOB N RREP PRE PSJM, REINSTALL REAR BULKHEAD IN CELLAR. -R/U CELLAR WHEEL AREA - INSTALL NEW CHOKE VALVES, SPOOL SPACERS AND 4 -WAY BLOCKS. 12:00 - 15:00 3.00 MOB N ■- PRE PJSM - CONT. RIG UP CELLAR - CONTINUE RIG UP CHOKE MANIFOLD 15:00 - 16:00 1.00 MOB N PRE CLEAN UP TOOLS - PREP FOR RIG MOVE - DELAYED INSTALLING AUXILIARY BOOSTERS DUE TO DOYON 14 INCIDENT 16:00 18:00 2.00 MOB P ■- PRE PJSM - INSTALL BOOSTER WHEELS - FUNCTION TEST 18:00 21:00 3.00 MOB P -_ PRE PJSM - MOVE RIG TO EDGE OF PAD Printed 1/23/2012 7:54:20AM dikNorib Page20117 Operation Summary Report Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- 00VON -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 @36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 00:00 3.00 MOB P PRE PJSM WITH SECURITY - START RIG MOVE FROM NGI-10 TO WEST DOCK ROAD - TRAVEL 4 MILES DOWN WEST DOCK ROAD 12/29/2011 00:00 - 06:00 6.00 MOB P PRE PJSM WITH CREW COMING ON TOUR - CONTINUE TO MOVE RIG DOWN WEST DOCK ROAD TO K PAD ACCESS ROAD - TURN DOWN K PAD ROAD TRAVELING TOWARDS SPINE ROAD - ABOUT AT SPINE ROAD INTERSECTION BY 06:00 06:00 - 09:00 3.00 MOB P PRE PULL OVER AT SANTAFE PAD -LET TRAFFIC PASS - PRUDHOE BAY FIELD MAKE CREW CHANGE OUT. 09:00 - 12:00 3.00 MOB P ■- PRE TRAVEL J PAD AND PULL OVER -LET TRAFFIC PASS -TAKE ON BOILER WATER. 12:00 - 16:30 4.50 MOB P -_ PRE TRAVEL TO AND CROSS THE KUPARUK RIVER BRIDGES. 16:30 - 00:00 7.50 MOB P PRE CONTINUE WEST ON THE SPINE ROAD - STOP AT Z PAD FOR TRAFFIC - AT SAND HILL / KUPARUK SIGN FOR CREW CHANGE 12/30/2011 00:00 - 01:00 1.00 MOB P PRE CONTINUE WEST ON SPINE ROAD - STOP AT MPU ACCESS ROAD AND ALLOW TRAFFIC TO PASS 01:00 06:00 5.00 MOB P ■- PRE TRAVEL COP AD ROAD - PULL LL OFF FF A AT TEXACO FOR PAD FOR FUEL AND TRAFFIC 06:00 - 09:00 3.00 MOB P PRE LET TRAFFIC PASS -TAKE ON FUEL -LET MILNE POINT BUSSES BY FOR AIRPORT CHANGE OUT. -MI MUD PLANT START MIXING 11.7 PPG KWF. 09:00 - 13:00 4.00 MOB P PRE TRAVEL NORTH TO MILNE POINT 'Y' INTERSECTION. -CREW HAD HOT LUNCH AT MILNE POINT BASE CAMP. - INSPECT MOVING SYSTEM - TOOLPUSHER AND ROADS / PAD FORMAN INSPECT L &F PAD INTERSECTION -AND DISCUSS PAD PREP AND TEXACO PAD AREA. MOVE RIG LOADER TO TEXACO PAD. 13:00 - 19:00 6.00 MOB P PRE TRAVEL NORTH WEST TO L & F PAD ROAD -MADE WEEKLY CREW CHANGE FROM ANCHORAGE, DELAYED BY NABORS CAMP MOVING ON THE SPINE ROAD. -MAKE 90 DEG LEFT TURN, STEP BY STEP ON TO L & F PAD ROAD. * * *24 HRS NOTICE OF UP COMMING BOPE TEST GIVEN TO AOGCC STATE INSPECTOR JEFF JONES @17:45 HRS. DUE TO RIG MOVE WE AGREED TO GIVE UPDATE —06:30 HRS 12 -31- 2011 * ** Printed 1/23/2012 7:54:20AM a :ALASKA America ALASKA - BP ° Page 3 of 17 Operation Summary Report Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- 00VON -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 @36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 - 22:45 3.75 MOB P PRE INSPECT MOVING SYSTEM AND GREASE JACKING CYLINDERS EAT DINNER AT RIG TRAVEL WEST ON L PAD ACCESS ROAD TO L PAD 22:45 - 00:00 1.25 MOB P PRE PULL ONTO L PAD AND SPOT TO DERRICK UP - PJSM / DERRICK UP - RIG UP RIG FLOOR LINES AND HOSES - CONTINUE TO MU CHOKE MANIFOLD - PULL REAR BOOSTER WHEELS - SPOT NEW TREE AND FLANGE BEHIND WELL -SPOT IN BOP CROSS OVER AND SQUEEZE MANIFOLD - SPOT WSL OFFICE 12/31/2011 00:00 - 02:00 2.00 MOB P PRE CONTINUE TO RU TO SPOT RIG - RIG UP RIG FLOOR LINES AND HOSES - CONTINUE TO MU CHOKE MANIFOLD - LOAD BOP INTO CELLAR - WORK ON WSL OFFICE GENERATOR 02:00 04:00 2.00 MOB P ■- PRE -OT NTE AROUND LEAD S - SET MATTIATTING G BOARDD TO DOUBLE TO DOUBLE STACK FOR BOP / WELL HEAD CLEARENCE 04:00 - 07:00 3.00 MOB P PRE PJSM/ SPOT RIG OVER MPU L -03 - PAD OPERATOR NOTIFIED AND WAIVED WITNESS - WSL AND TP PRESENT - SPOT RIG OVER WELL HEAD - SHIM UP RIG * **TALKED TO AOGCC STATE INSPECTOR JEFF JONES @06:45 HRS. WE AGREED THE RIG WOULD GIVE UPDATE -06:30 HRS 1 -1- 2012 * ** 07:00 - 12:00 5.00 MOB P PRE AT 07:45 HRS -1 GAL GRAY WATER LEAK WAS REPORTED, FROM A UNCAPED VACUUM HOSE AT THE CAMP LIFT STATION. -ALL LEVEL '0' NOTIFICATION WERE MADE. - BRIDLE DOWN DERRICK. -TAKE ON 11.7 PPG KWF AT 07:30 HRS. (RIG ACCEPTANCE) -R/U CELLAR. -SPOT CUTTING BOX -HARD LINE CREW SPOT FLOW BACK TANK AND -HOOK UP HARD LINE FROM TANK TO RIG. -HARD LINE TESTED WITH DIESEL TO 4000 PSI. - REMOVE 6 OLD CHOKE VALVES FROM RIG FLOOR. -MAIN CAMP START MOVE TO MILNE POINT AT 0930 HRS. 12:00 - 14:30 2.50 RIGU P PRE CONTINUE TO R/U CIRCULATING MANIFOLD AND LINE IN CELLAR. - FINISH PREP THE CHOKE MANIFOLD WITH THE 6 NEW VALVES FOR TESTING. Printed 1/23/2012 7:54:20AM North'AmericLASKA - BP . _ Page 4 of 17 O peration Summary Report . Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- OOVON -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 @36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 - 19:30 5.00 RIGU N RREP PRE TEST 13 VALVES AND 35 FLANGES -250 / 5000 PSI HI FOR 5 CHARTED MINUTES. - UPDATED AOGCC WITH TEST TIME AT 18:45 - JEFF JONES WAIVED WITNESS OF BOPE TEST 19:30 - 20:30 1.00 RIGU P PRE HOLD RIG EVAC DRILL HOLD AAR - NO NEW FINDINGS 20:30 - 23:00 2.50 WHSUR P DECOMP PJSM RU WELL SUPPORT LUBRICATOR TO TREE AND TEST -TEST 250 PSI LOW / 3500 PSI HIGH FOR 5 CHARTED MIN -PULL BPV -WHP = 1480 PSI AND IA = 1500 PSI -RD LUBRICATOR 23:00 - 00:00 1.00 KILLW P DECOMP PJSM TO BLEED OFF AND KILL WELL 1500 IA AND 1490 TUBING BLEED IA THROUGH MANUAL CHOKE TO FLOW BACK TANK W/ 150 PSI DWN STREAM IA =925 PSI AT 00:00 1/1/2012 00:00 - 02:30 2.50 KILLW P DECOMP CONTINUE TO BLEED DOWN IA THROUGH HAND CHOKE - MAX 150 PSI DOWN STREAM PRESSURE - HANDS REPORT 50/50 GAS AND FLUID AT —300 PSI - WELL HEAD PRESSURE TRACKING IA 02:30 - 04:30 2.00 KILLW P DECOMP HANDS REPORT FLOW BACK TANK IS HALF FULL - HAVE VAC TRUCK SUCK OUT 170 BBLS CRUDE - MOVE OUT VAC TRUCK - 30 BBLS SLUDGE REMAINING IN TANK - WHP AND IA SLOWLY INCREASING 04:30 - 09:00 4.50 KILLW P DECOMP BLEED OFF SMALL GAS CAP AGAIN WITH b VAC TRUCK OFF FLOW BACK TANK - PUMP 50 BBLS DOWN TUBING AT 3 BPM AND 150 PSI CHOKE PRESSURE - SHUT IN IA AND BULL HEAD 50 BBLS 11.7 BRINE DOWN TUBING AT- 3BPMAND2000PSI - OPEN UP AND CIRCULATE OUT IA WITH 320 BBLS 11.7 BRINE - HOLDING 150 PSI DOWN STREAM PRESSURE ON CHOKE - ALL RETURNS TO FLOW BACK TANK - SHUT DOWN AT 11.6 HEAVY AND MONITOR WELL, LESS THEN 10 PSI ON TBG AND IA. - BLOWN DOWN LINES TO TIGER TANK. 09:00 - 10:30 1.50 KILLW P DECOMP CIRCULATE 20 BBLS THROUHG THE CHOKE TO THE FLOW BACK TANK. -5.5 BPM/ 1970 PSI. 11.7 PPG KWF. -LOST 8 BBLS. -TOTAL FLUID LOSS = 46 BBLS. - SHUT -IN TBG AND IA FOR 15 MINUTES -OPEN TBG AND IA WITH A VERY SLIGHT VACUMM DETECTED. Printed 1/23/2012 7:54:20AM forth America - ALASKA BP . Page 5 of 17 Operation Suijmmary Report.. Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- 00VON -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 ©36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 11:00 0.50 KILLW P DECOMP HELD RIG EVAC. DRILL WITH NIGHT CREW -TEMP = -45 DEG F. -PAD OPS AND MPU BASE OPERATIONS NOTIFIED OF DRILL. - DISCUSSED ROLLS OF THE PAD OPERATOR AND MILNE POINT BASE OPERATIONS CENTER DURING ANY INCIDENT AT MILNE POINT. 11:00 - 13:30 2.50 WHSUR P DECOMP PJSM W/WELL HEAD REP -SET 2.5" TYPE 'H' TWC. - PERFORM ROOLING TEST FROM BELOW TO 500 PSI AT 1.10 BPM / 10 CHARTED MINUTES. GOOD. -TWC FAILED TO TEST FROM ABOVE. 13:30 - 16:30 3.00 WHSUR P DECOMP R/U AND TEST WELL SUPPORT LUBRICATOR - PRESSURE TEST TO TEST LUBRICATOR TO THE TREE. -250 LOW / 3500 PSI HI F/5 CHARTED MINUTES. -PULL TWC AND RECOVERED SMALL PIECE OF PLASTIC IN POPET -PULL LUBRICATOR 16:30 - 19:00 2.50 WHSUR P DECOMP R/U AND TEST WELL SUPPORT LUBRICATOR - REPEAT PRESSURE TEST TO TEST LUBRICATOR TO THE TREE. -250 LOW / 3500 PSI HI F/5 CHARTED MINUTES. -SET NEW TWC -TEST FROM BELOW WITH ROLLING TEST AT 500 PSI - GOOD TEST - TEST FROM ABOVE TO 4,000 PSI - GOOD TEST - RD LUBRICATOR AND TEST EQUIPMENT 19:00 - 22:00 3.00 WHSUR P DECOMP BLOW DOWN ALL CIRCULATING LINES PJSM - RD CIRCULATING LINES IN CELLAR - CAMERON BLEED OF TUBING VOID - N TREE AND ADAPT F LA NG E - CLEAN/CLEAR OUT CELLAR 22:00 - 02:33 BOPSUR P DECOMP PJSM/ NU BOP ADAPTOR SPOOL - NU BOP STATIC LOSS RATE OF 1 BPH LOSSES FOR THE DAY = 87 BBLS OF 11.7PPG BRINE 1/2/2012 00:00 - 03:00 3.00 BOPSUR P DECOMP CREW CHANGE AND PJSM - CONTINUE TO NU BOP'S TO ADAPTOR SPOOL 03:00 - 05:00 2.00 BOPSUR P DECOMP PJSM / CHANGE BOP RAMS - INSTALL 2 -7/8" X 5" VARIABLE PIPE RAMS INTO LOWER PREVENTER - INSTALL 2 -7/8" SOLID RAMS INTO UPPER ACTUATOR 05:00 - 08:30 3.50 BOPSUR P DECOMP PJSM / RU TO TEST BOPE - GAS BUSTER WITH 7.4 BBLS - WORK AIR OUT OF KOOMEY LINES - KOOMEY HYDRAULIC FLUID WAS CHANGED OUT DURRING RIG MOVE Printed 1/23/2012 7:54:20AM W orth America - ALASKA..- BP Page 6 of 17 Operation Summary Report Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- 00VON -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 @36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 14:00 5.50 BOPSUR P DECOMP SHFI L TEST BOPE TO 250 LOW AND 4,000 HIGH - ATTEMPT TO TEST ANNULAR TO 3,500 PSI - MECHANIC TROUBLE SHOOTING KOOMEY LINES - MOBALIZE ANNULAR ELEMENT FROM SHOP TO RIG - WAIT ON ANNULAR TO BE DELIVERED (DELAYED BY 7 ES CAMP MOVE FROM I PAD) 14:00 - 20:30 6.50 BOPSUR N RREP DECOMP PJSM FOR CHANGE OUT OF ANNULAR ELEMENT - CHANGE OUT ANNULAR ELEMENT - FUNCTION ANNULAR SEVERAL TIMES 20:30 - 22:00 1.50 BOPSUR P DECOMP PJSM FOR UPPER RAM CHANGE OUT - NOW THAT SECOND SET OF 2 -7/8 X 5" VRB'S HAVE ARRIVED - CHANGE O T TOP PIP AMS TO 2 -7 /R X 5" VRB'S -BOP'S ARE NOW DRESSED WITH 2 -7/8" X 5" ,./ VRB PIPE RAMS IN TOP AND BOTTOM 22:00 - 23:00 1.00 BOPSUR P DECOMP RU TO TEST BOPE - RU TEST LINES - FILL STACK WITH WATER - FUNCTION BOP'S TO WORK WATER OUT 23:00 - 00:00 1.00 BOPSUR P DECOMP START TESTING 13 -5/8" BOPE -TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS. -TEST WITNESS WAIVED BY JEFF JONES OF AOGCC -TEST VARRIABLE RAMS TO 250 PSI LOW �V AND4,000 PSI HIGH �" - HYDRILL TESTED TO 250 PSI LOW AND 3,500 PSI HIGH -TEST USING 2 -7/8" AND 4" TEST JOINTS. - PRESSURE TEST FOR 5 CHARTED MIN EACH. -ALL TEST WITNESSED BY BP WSL / DDI TP. -ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT - AK -10 -45 16 BBLS OF 11.7 PPG BRINE LOST TODAY Printed 1/23/2012 7:54:20AM orth America - ALASKA - BP _ Page 7 of 17 Operation Summary Report Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- 00V0N -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 @36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/3/2012 00:00 - 06:00 6.00 BOPSUR P DECOMP CONTINUE TESTING 13 -5/8" BOPE : -TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS. -TEST WITNESS WAIVED BY JEFF JONES OF AOGCC -TEST VARIABLE RAMS TO 250 PSI LOW AND 4,000 PSI HIGH - HYDRILL TESTED TO 250 PSI LOW AND 3,500 PSI HIGH -TEST USING 2 -7/8" AND 4" TEST JOINTS. - PRESSURE TEST FOR 5 CHARTED MIN EACH. -ALL TEST WITNESSED BY BP WSL / DDI TP. -ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT - AK -10 -45 -13 3/8" ANNULAR FAILED AND A NEW ELEMENT WAS INSTALLED. -HCR VALVE FAIL AND PASSED AFTER GREASE AND FUNCTIONED. KOOMEY TEST: 2800 PSI SYSTEM PRESSURE 1700 PSI AFTER CLOSURE 200 PSI INCREASE IN 17 SEC FULL PRESSURE ATTAINED IN 85 SEC 6 N2 BOTTLES AT 2,000 PSI 06:00 - 07:30 1.50 BOPSUR P -_ DECOMP R/D BOPE TEST EQUIPMENT -BLOW DOWN LINES 07:30 - 08:30 1.00 BOPSUR P -_ DECOMP RIG U DUTCH RISER -CLEAN TWC PROFILE 08:30 - 09:00 0.50 BOPSUR P -_ DECOMP RIG UP DSM LUBRICATOR -M /U TOOLS TO PULL TWC 09:00 - 09:30 0.50 BOPSUR P ■- DECOMP TEST LUBRICATOR PSI LOW -250 PS 3500 I LOW, 3500 PSI HIGH, 5 MIN CHARTED 09:30 - 10:30 1.00 BOPSUR P -_ DECOMP DSM ATTEMPT TO PULL TWC, UNSUCCESSFUL 10:30 - 11:00 0.50 BOPSUR N SFAL _ DECOMP LAY DOWN DSM RISER -SUCK OUT STACK 11:00 - 12:00 1.00 BOPSUR N SFAL DECOMP PICK UP OSPSO -LOPSO -M /U CROSSOVERS - FUNCTION TEST ESD = GOOD 12:00 - 16:30 4.50 BOPSUR N SFAL DECOMP RIG DOWN OSPSO - LOPSO -M /U DUTCH RISER -M /U LUBRICATOR AND TEST TO 250 PSI LOW AND 3500 PSI HIGH, CHARTED -STAB INTO TWC AND PULL SAME 16:30 - 17:00 0.50 BOPSUR P -_ DECOMP R/D LUBRICATOR AND DUTCH RISER -BLOW DOWN LINES 17:00 - 18:30 1.50 BOPSUR P DECOMP M/U LANDING JOINT - CAMERON BACK OUT LDS -PULL HANGER FREEAT 100K, PUWT =95K - MONITOR WELL 10 MINUTES = STATIC Printed 1/23/2012 7:54:20AM orth Americ tu= ALASKA - BP . Page 8 Of 17 Operation Summary Report Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- 00VON -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 @36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 23:30 5.00 BOPSUR P DECOMP CLOSE BAG AND CIRCULATE THROUGH THE CHOKE -CBU 1X, 5.5 BPM = 1850 PSI -SLOW PUMP RATE DOWN TO 3.2 BPM = 660 PSI, DUE TO LOSS RATE -5.5 BPM = 10% LOSS RATE, 3.2 BPM = MINIMAL LOSS RATE -SHUT DOWN AND MONITOR FOR 10 MINUTES - OBSERVED MINIMAL GAS BUBBLES BREAKING OUT IN STACK WITH STABLE FLUID COLUMN - ELECTED TO CIRCULATE A SECOND BOTTOMS UP, 3BPM = 440 PSI 23:30 - 00:00 0.50 PULL P DECOMP MONITOR WELL FOR 10 MINUTES -NO FLOW = STATIC - PULLED HANGER TO RIG FLOOR -LAY DOWN LANDING JOINT AND HANGER -BLOW DOWN LINES - CIRCULATE ACROSS TOP OF HOLE WHILE CREW CHANGE 1/4/2012 00:00 - 03:30 3.50 PULL P DECOMP PULL OUT OF HOLE WITH 2 7/8" ESP COMPLETION STRING FROM 8290' TO 7330' -STAND BACK 2 7/8" 8RD EUE -LAY DOWN GLMS AND PUPS - MAINTAIN CONTINUOUS HOLE FILL WITH 11.7 PPG BRINE - LOSING ABOUT 2 BPH TO THE HOLE 03:30 - 04:00 0.50 PULL P DECOMP HELD KICK WHILE TRIPPING DRILL ON STAND #10 - HAD NEW HANDS ON RIG FLOOR AND MOTOR MAN ON THE BRAKE - GOOD DRILL WITH GOOD RESPONSES AND LESSONS LEARNED FOR NEW HANDS - AAR WITH ALL INVOLVED TO CAPTURE INDIVIDUAL LEARNING'S FOR HANDS 04:00 - 06:00 2.00 PULL P DECOMP CONTINUE TO PULL ESP COMPLETION FROM 7330' TO 5912' - STAND BACK 2 -7/8" TUBING - LAY DOWN PUPS AND GLM'S - MAINTAIN CONTINUOUS HOLE FILL WITH 11.7 PPG BRINE - LOSING ABOUT 2 BPH TO THE HOLE 06:00 - 09:30 3.50 PULL P DECOMP -START TO GET BACK 11.2 PPG RETURNS OUT OF THE WELL -RIG UP AND CIRCULATE, 3 BPM = 520 PSI -FLUID IN TRIP TANK STEADILY LIGHTENING UP FROM 11.2 TO 11.5+ PPG AFTER 92 BBLS PUMPED IN OF 11.7 PPG - MONITORED WELL FOR 10 MIN AND SLIGHT LOSSES OBSERVED - CONTINUE TO CIRCULATE CLEAN BRINE FROM ISOLATED PIT - MONITOR WELL AND DISCUSS OPTIONS WITH TOWN -AGREE TO CONTINUE WITH 11.5 HEAVY RETURNS AND MONITOR WELL CLOSELY 09:30 - 12:00 2.50 PULL P DECOMP CONTINUE TO PULL ESP COMPLETION F/5912' T/4831' - MONITORING EVERY HOUR FOR 10 MIN -STILL GETTING 11.5 TO 11.6 PPG RETURNS WITH — 1 BPH LOSES Printed 1/23/2012 7:54:20AM •orthAmericaALASKABP Page 9 of 17 C?peratwori Summary Report Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- 00VON -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 @36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 19:00 7.00 PULL P ■- DECOMP CREW CHANGE -PULL -PULL ESP COMPLETION F/4831' TO DISCHARGE HEAD, PUMP, MOTOR 19:00 - 21:00 2.00 PULL P DECOMP LAY DOWN CENTRILIFT PUMP AND MOTOR ASSY -NOTE: 2 WASHOUTS IN PUMP - RECOVERED 138 TOTAL LASSALE CLAMPS 21:00 - 23:00 2.00 PULL P DECOMP RIG DOWN TUBING HANDLING EQUIPMENT -PJSM/ RIG DOWN ESP CABLE SHEAVE -PJSM/ INSTALL 6 1/4" WEAR BUSHING -CLEAN AND CLEAR RIG FLOOR 23:00 - 00:00 1.00 PULL P DECOMP -PJSM TO PU AND RUN RTTS - MOBILIZE RTTS TO RIG FLOOR -M /U RTTS AND PREP TO P/U DRILL PIPE -TOTAL 24 HOUR FLUID LOSS TO HOLE = 99 BBLS - MAINTAINING HOLE FILL WITH 11.6 PPG BRINE 1/5/2012 00:00 - 00:30 0.50 PULL P DECOMP PJSM - SERVICE RIG FLOOR -SPCC CHECKS -BLOW DOWN CHOKE AND KILL LINES, AND CHOKE MANIFOLD TO FLOW BACK TANK 00:30 - 06:00 5.50 EVAL P DECOMP RIH WITH RTTS -PICK UP 4" HT 38 DRILL PIPE 1X1 FROM PIPE SHED -NO RETURNS DURING THE FIRST 20 JOINTS - STARTED TO GET A LITTLE LESS THAN HALF RETURNS AROUND JOINT # 20 - MAINTAINING HOLE FILL WITH 11.6 PPG BRINE -ON JOINT #115 (3520'MD) OF 266. 06:00 - 07:00 1.00 EVAL P DECOMP CBU AT 3520' MD -PUW / 85K, SOW / 83K -3 BPM / 210 PSI -11.5 PPG OUT, 11.6PPG IN - MONITOR WELL FOR 10 MIN. AT —1 BPH LOSS RATE. 07:00 12:00 5.00 EVAL P ■- DECOMP CONTINUE TO PICK UP 4" HT 38 DRILL PIPE 1X1 FROM PIPE SHED -FROM 3520' TO 7469' MD. 12:00 - 12:30 0.50 EVAL P -_ DECOMP PJSM AND PERFORM PRE TOUR CHECK - SERVICE TOP DRIVE. 12:30 - 14:30 2.00 EVAL P DECOMP CONTINUE TO PICK UP 4" HT 38 DRILL PIPE 1X1 FROM PIPE SHED -FROM 7469' TO 8417' MD. - PUW /158K,SOW /120K. - WEIGHT UP SURFACE VOLUME TO 11.8 PPG. 14:30 - 15:00 0.50 EVAL P DECOMP PJSM, SPACE OUT WITH 5 FT PUP -RIH AND TAG TOP OF PACKER AT 8468' MD -SET 7" RTTS WITH HES REP -SET AT 8460' MD. 15:00 - 16:00 1.00 EVAL P DECOMP -RU TO TEST 7" CSG. - TESTED 3500 PSI FOR 30 CHARTED MIN. - REPORTED RESULTS TO ADW WTL AND RECEIVED INSTRUCTIONS TO PROCEED. -R/D TEST EQUIPMENT. Printed 1/23/2012 7:54:20AM •orth Page lO of 17 4peration.Summary .Report Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- 00VON -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 @36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 16:30 0.50 EVAL P ■- DECOMP RELEASE RTTS -LET ELEMENT RELAX - POSITION RTTS AT 8465' MD 16:30 - 18:30 2.00 EVAL P DECOMP CIRCULATE IN 11.8 PPG KWF IN. - CIRCULATE OUT 11.6 PPG FLUID - 11.7 PPG ALL AROUND - FLOW CHECK WELL - NO FLOW 18:30 19:00 0.50 EVAL P ■- DECOMP F/ T/ M. - LAY DOWN 4 JNTS NTS DRILL PIPE AND 2 PUP JOINTS 19:00 20:30 1.50 EVAL P ■- DECOMP PJSM FOR S AND S DRILL LINE A - CUT AND SLIP 68 8 OF FT OF 1 -1/4" DRILL LINE - INSPECT DRAW WORKS AND CLEAN UP 20:30 - 22:30 2.00 EVAL P DECOMP POH WITH RTTS FROM 8354 FT - MAINTAIN CONTINUOUS HOLE FILL WITH 11.7 PPG BRINE - STAND BACK 4" DRILL PIPE IN DERRICK 22:30 - 23:00 0.50 EVAL P -_ DECOMP CREW CHANGE AND PJSM -CREW WALKAROUND'S 23:00 - 00:00 1.00 EVAL P DECOMP CONTINUE TO TRIP OUT OF HOLE WITH RTTS F/ 8354 T/4088' MD. - MAINTAIN CONTINUOUS HOLE FILL WITH 11.7 PPG BRINE - STAND BACK 4" DRILL PIPE IN DERRICK -24 HRS LOSS, 130 BBLS -1 -2 BPH LOSS RATE 1/6/2012 00:00 - 03:30 3.50 EVAL P DECOMP PJSM, POOH F/4088' TO SURFACE -UD 7" RTTS BHA -CLEAN / CLEAR RIG FLOOR - STATIC LOSS RATE = —1 TO 2 BPH 03:30 - 05:30 2.00 FISH P DECOMP PJSM. M/U FISHING BHA - PACKER 6" MILL, JUNK BASKETS, BUMPER SUB, JARS, PUMP - OUT -SUB. -P /U (9 4 3/4 COLLARS 05:30 - 10:30 5.00 FISH P DECOMP RIH W/ 4" DP FROM DERRICK F/347' T/8476' MD - PUWT =167K, SOWT =122K, ROTW =138K, 100 RPM =8K FREE TQ -SPR #1 @ 2 BPM =120 PSI, 3 BPM =340 PSI -5 BPM =750 PSI 10:30 12:00 1.50 FISH P ■- DECOMP TAG PACKER AT 8476' MD -BEGIN MILLING PACKER F/8476 T/8477' MD -5 -10K WOB, 8 -9K MILLING TQ 12:00 - 12:30 0.50 FISH P DECOMP PJSM, CHANGE OUT CREW - CONTINUE MILLING OPERATIONS AT 8477' MD - EXPERIENCE LOSS RATE OF 18 BPH 12:30 - 18:00 5.50 FISH P DECOMP PICK UP OFF PACKER - REDUCE PUMP RATE TO 2 BPM= 110PSI DUE TO HIGH LOSS RATE AND AMOUNT OF FLUID ON LOCATION - CIRCULATE AT LOWER RATE UNTIL FLUID ARIVES ON LOCATION - CONDUCT "EFFICIENT DRIVE TEAM MEETING" WITH CREW - CONDUCT D2 KICK WHILE TRIPPING DRILL Printed 1/23/2012 7:54:20AM W orth America - ALASKA ;SP Page 11 of 17 Operation Summary Report Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- 00VON -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 @36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 19:30 1.50 FISH P DECOMP CONTINUE MILL PACKER F/8477' T/8478' MD -5 BPM=820 PSI -12K WOB, 80 RPM =8K TQ - PACKER FELL FREE - FOLLOW /PUSH DOWN HOLE 20' TO 8498' MD 19:30 - 21:00 1.50 FISH P DECOMP CLOSE ANNULAR PREVENTER AND LINE UP TO CHOKE -CBU 1X THRU GAS BUSTER -3 BPM =250 PSI -LOSS OF 9 BBLS ON CIRCULATION 21:00 - 22:00 1.00 FISH P DECOMP RIH - TAGGED PACKER DOWN HOLEAT 8614' MD - MILLED AND / OR PUSHED PACKER F/8614' T/8616' MD -3 BPM =310 PSI -60 RPM -6K TQ 22:00 - 00:00 2.00 FISH P DECOMP PJSM, BLOW DOWN TOP DRIVE AND CHOKE LINES -POH F/8616' T/4486' MD -24 HOUR LOSSES = 154 BBLS - —1 TO 2 BPH STATIC LOSS RATE 1/7/2012 00:00 - 01:30 1.50 FISH P DECOMP PJSM, CHANGE OUT CREWS - INSPECT / SERVICE RIG CHECKS -SPCC CHECK - CONTINUE POOH F/4486' T/347' MD 01:30 - 02:30 1.00 FISH P DECOMP OUT OF HOLE WITH FISHING BHA #1 -UD BHA -BOOT BASKETS FULL = 3 GALLONS METAL SHAVINGS -MILL HAD MINIMAL WEAR 02:30 - 03:00 0.50 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR - MOBILIZE BHA'S 03:00 - 03:30 0.50 FISH P DECOMP PJSM, M/U FISHING BHA #2 -SPEAR W/3.198 NOM. CATCH GRAPPLE, BUMPER SUB, OIL JAR, PUMP OUT SUB, COLLARS T/304' MD 03:30 - 04:00 0.50 FISH N RREP DECOMP TROUBLE SHOOT IRON ROUGHNECK - HYDRAULIC CYLINDER ON SPINNERS - DRILLER SIDE. 04:00 - 07:30 3.50 FISH P DECOMP RIH ON HT38 DRILL PIPE F/305' T/8550' MD - MAINTAIN HOLE FILL W/11.7 BRINE -LOSS RATE —8 BPH WHILE TRIPPING IN HOLE 07:30 - 08:00 0.50 FISH P DECOMP SPEAR PACKER - PUWT =165K, SOWT =125K -2 BPM =430 PSI -TAG AT 8616' MD -SPEAR PACKER AND ENGAGE GRAPPLE TO 8618' MD WITH 10K DOWN WT. -P /U WITH NO OVERPULL -SET BACK DOWN 3' HIGHER WITH 15K DOWN WT - MONITOR WELL 08:00 - 08:30 0.50 FISH P DECOMP POH F/8618' T/7624' MD - VISUALLY MONITOR WELL FOR SWABBING -FIRST 5 STANDS TAKING PROPER FILL Printed 1/23/2012 7:54:20AM •ohAmerca-ALAS= Page 12 of 17 Operation Summary Report - . Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- 00VON -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 @36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 09:00 0.50 FISH N RREP DECOMP PJSM - CHANGE OUT RADIUS SPINNER (HYDRAULIC CYLINDER) ON IRON ROUGHNECK 09:00 - 10:00 1.00 FISH P DECOMP CONTINUE POH WITH FISH F/ 7624' T/ 4700' MD -NO DRAG -PIPE COMMING WET. 10:00 - 10:30 0.50 FISH P DECOMP DROP DART AND PUMP TO OPEN CIRC SUB -3 BPM / 340 PSI 10:30 - 12:00 1.50 FISH P DECOMP CONTINUE TO POH F/ 4700' BHA AT — 400'MD. 12:00 - 12:30 0.50 FISH P DECOMP PJSM CREW CHANGE - MONITOR WELL AT —1 -2 BPH STATIC LOSS RATE. - SERVICE TOP DRIVE - PERFORM PRETOUR CHECKS. 12:30 - 13:30 1.00 FISH P DECOMP POH F/ —400' AND STAND BACK 43/4" DRILL COLLARS. 13:30 - 15:00 1.50 FISH P DECOMP PJSM RELEASE SPEAR FROM FISH -PUNCH 4 HOLES IN 3 1/2" SCREEN ASSEMBLY TO RELEASE TRAPPED PRESSURE -NO ADDENORMAL PRESSURE WAS RELEASED. - ASSEMBLY PLUGGED FROM THE LAST 2 FT OF SCREENS DOWN TO THE PLUG INSIDE THE 'XN'. NO SAND NOTED, JUST PARAFFIN. 15:00 - 16:00 1.00 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR -CLEAN SODIUM BROMIDE OFF TOOLS -UD FISHING TOOLS FROM FLOOR. 16:00 - 17:30 1.50 FISH P DECOMP PU AND MU BAKER CLEAN OUT BHA - 6" MILL - 6" SMOOTH BOAR STING MILL - MAGNETS AND JUNK BASKET -9 4-3/4" DRILL COLLARS 17:30 - 20:00 2.50 FISH P DECOMP TIH ON 4" HT 38 DRILL PIPE - MAINTAIN HOLE FILL WITH 11.7 PPG BRINE - TIH TO 8388 FT AND GET PARAMETERS: - 165KUPWT,118KDWT -SPR'S PUMP 1 = 2 BPM =130 PSI AND 3 BPM = 300 PSI 20:00 - 22:00 2.00 FISH P DECOMP MU TO TOP DRIVE AND CLEAN 7" FROM 8302 FT TO 8500 FT - 4 BPM 380 PSI AND 60 RPM - PUMPS OFF RIH AND TAG TOP OF FILL AT 8638 FT WITH 15 K WOB - WASH DOWN TO 8681 FT -4 BPM AT 540 PSI -60 RPM 22:00 - 00:00 2.00 FISH N RREP DECOMP COULD NOT MU TOP DRIVE TO CONTINUE WASHING IN HOLE - INSPECT TOP DRIVE AND THREADS ON SAVER SUB ARE WORN OUT - CHANGE OUT SAVER SUB 1/8/2012 00:00 - 01:00 1.00 FISH P DECOMP CONTINUE TO WASH DOWN THROUGH FILL TO PBTD OF 8740 FT - WASHED DOWN TO 8752 FT DRILLERS DEPTH. - 4 BPM AT 460 PSI AT 60 RPM Printed 1/23/2012 7:54:20AM [orth America - ALASKA - BP Page 13 of 17 ,Operation Summary Report Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- 00V0N -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 ©36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 04:00 3.00 FISH P DECOMP CIRCULATE 2 20 BBL HIGH VIS SWEEPS - BOTH SWEEPS ARE BRINGING BACK LOTS OF FRAC SAND. - PUMP 5 BPM AT 740 PSI WITH MINIMAL LOSSES - CIRCULATE TO TRY AND GET 11.7 PPG IN AND OUT 04:00 - 05:00 1.00 FISH P DECOMP PU TO 8491 FT MONITOR WELL - WELL IS STATIC - LAST BRINE WEIGHTS WERE 11.72 PPG IN AND 11.68 PPG OUT - PU TO 8302 FT 05:00 - 08:30 3.50 FISH P DECOMP CIRCULATE 11.8 PPG NABR IN TILL 11.79 PPG OUT - MONITOR WELL STATIC FOR 15 MINUTES. -BLOW DOWN TOP DRIVE. -24 HOUR NOTICE FOR WEEKLY BOP TEST TO AOGCC STATE INSPECTOR CHUCK SCHEVE 08:30 - 12:00 3.50 FISH P DECOMP POH F/8302' MD WITH BHA #3, CLEAN -OUT BHA. -L/D (9) 4 3/4" DRILL COLLARS. 12:00 - 14:30 2.50 FISH P DECOMP LD CLEAN OUT TOOLS -CLEAN AND CLEAR RIG FLOOR - MOBALIZE BAKER TOOLS 14:30 - 16:00 1.50 RUNCOM P RUNCMP RU TO RUN PACKER AND SCREEN - ASSEMBLY - PU OLD SCREEN AND TAKE OUT D NIPPLE - LD OLD SCREENS - PU NEW 4 -1/8" 250 MICRON SCREENS - MU SCREENS TO SHEAR SUB AND 7" VTA HALLIBURTON PACKER - MU ONE STAND TO PACKER AND SECURE IN WELL 16:00 - 22:30 6.50 RUNCOM N RREP RUNCMP RIGSENSE MONITORING AND RECORDING SYSTEM. - NO DISPLAY ON MONITOR SCREEN. - QUADCO REP CAM OUT AND REPAIRED COMPUTER IN DOG HOUSE -TOTCO SCREENS IN DOG HOUSE, RIG FLOOR, AND PITS ARE RETURNED TO SERVICE 22:30 - 00:00 1.50 RUNCOM P RUNCMP PJSM -RIH WITH PACKER AND SCREEN ASSY T/3135' MD - 1 MINUTE PER STAND - MONITOR RETURNS CLOSELY, AVOID PUSHING FLUID AWAY -24 HR LOSSES TOTAL = 104 BBLS 1/9/2012 00:00 - 02:00 2.00 RUNCOM P RUNCMP PJSM, CHANGE OUT CREW -SPCC AND RIG CHECKS -CONT RIH F/3135' T/8407' MD = TOP OF PACKER DEPTH - MAINTAIN HOLE FILL WITH 11.8 PPG BRINE - UP WEIGHT = 170 K - DWN WEIGHT = 113 K Printed 1/23/2012 7:54:20AM •1 orth America - ALASKA - BP Page 14 of 17 Operation Summary Report Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- 00V0N -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 @36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 04:30 2.50 RUNCOM P RUNCMP POSITION PACKER TOP AT 8407' MD - BOTTOM OF SCREENS AT 8500' MD -DROP 1 1/2" BRASS PACKER SETTING BALL TO SEAT -RU HEAD PIN -PUMP AT 1/2 BPM AND PRESSURE UP TO 500 PSI - PRESSURE UP TO 2800 PSI FOR 5 MIN TO START SETTING -BLEED OFF PRESSURE -PU 10 K OVER TO 180 K -SET DOWN 10 K TO 103 K - PRESSURE UP TO 2900 FOR 5 MIN - PRESSURE UP TO 3300 PSI 5 MIN -PU TO 165 K AND SHEAR OUT OF PACKER - PRESSURE BLED OF TO ZERO\ -RIG DOWN HEAD PIN 04:30 - 12:00 7.50 RUNCOM P RUNCMP PJSM -LAY DOWN DRILL PIPE 1X1 -POOH F/8407 T /BHA -LAY DOWN PACKER RUNNING TOOL - MAINTAIN HOLE FILL WITH 11.8 PPG BRINE - 07:00, NOTIFIED AOGCC OF BOPE TEST TIMES -CHUCK SCHEVE WAIVED STATES RIGHT TO WITNESS 12:00 - 14:30 2.50 BOPSUR P RUNCMP PJSM, CHANGE OUT CREWS -PULL WEAR BUSHING - INSTALL 2 7/8 TEST JOINT, TIW -CLOSE RAMS -FLUSH ALL LINES, CHOKE MANIFOLD, GAS BUSTER, ETC WITH FRESH WATER TO CLEAN OUT BROMIDE AND SALTS 14:30 - 18:30 4.00 BOPSUR N RREP RUNCMP PJSM - CHANGE OUT 3 1/8 HCR CHOKE VALVE DUE TO PRIOR FAIL PASS RECORD 18:30 - 20:00 1.50 BOPSUR P RUNCMP R/D 2 7/8 TEST JOINT -R/D AND R/U WELL CONTROL FLOOR VALVES 20:00 - 21:00 1.00 BOPSUR P RUNCMP M/U STACK WASHER -FLUSH BROMIDE FROM STACK WITH FRESH WATER -R/D AND L/D STACK WASHER 21:00 - 22:30 1.50 BOPSUR P RUNCMP R/U TEST EQUIPMENT -M /U 2 7/8 TEST JOINT AND TEST PLUG - INSTALL TEST PLUG -FILL AND PREP SUFACE EQUIPMENT FOR BOP TEST Printed 1/23/2012 7:54:20AM 'North America - ALASKA BP Page 1 is of 17 Operation Summary Report Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- 00VON -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 @36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:30 - 00:00 1.50 BOPSUR P RUNCMP BEGIN TESTING 13 -5/8" BOPE -TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS. -TEST WITNESS WAIVED BY CHUCK SCHEVE OF AOGCC -TEST VARIABLE RAMS TO 250 PSI LOW AND 4,000 PSI HIGH - HYDRILL TESTED TO 250 PSI LOW AND 3,500 PSI HIGH -TEST USING 2 -7/8" TEST JOINT - PRESSURE TEST FOR 5 CHARTED MIN EACH. -ALL TEST WITNESSED BY BP WSL / DDI TP. -ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT - AK -10 -4 -24 HOUR LOSS TOTAL = 23 BBLS 1/10/2012 00:00 - 03:30 3.50 BOPSUR P RUNCMP PJSM, CREW CHANGE OUT - PERFORM SPCC AND RIG CHECKS CONTINUE TEST BOPE: -TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS. - TEST WITNESS WAIVED BY CHUCK SCHEVE ^ L ‘( OF AOGCC -TEST VARIABLE RAMS TO 250 PSI LOW AND ,\/,' 4,000 PSI HIGH - HYDRILL TESTED TO 250 PSI LOW AND 3,500 PSI HIGH -TEST USING 2 -7/8" TEST JOINT - PRESSURE TEST FOR 5 CHARTED MIN EACH. -ALL TEST WITNESSED BY BP WSL / DDI TP. -ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT -AK -10-4 - REPLACED HCR CHOKE VALVE FAIL AND PASSED AFTER GREASE AND FUNCTIONED. KOOMEY TEST: -2850 PSI SYSTEM PRESSURE -1550 PSI AFTER CLOSURE -200 PSI INCREASE IN 20 SEC - FULL PRESSURE ATTAINED IN 96 SEC -6 N2 BOTTLES AT 2,000 PSI CLOSING TIMES: - ANNULAR = 26 SEC -UPPER RAMS = 6 SEC - BLIND /SHEAR RAMS = 14 SEC - LOWER RAMS = 6 SEC 03:30 - 04:30 1.00 BOPSUR P RUNCMP R/D TEST EQUIPMENT -BLOW DOWN CHOKE MANIFOLD -VAC PUT FRESH WATER FROM STACK -L /D TEST PLUG AND JOINT Printed 1/23/2012 7:54:20AM EbNorth America - ALASKA - BP Page 16 of 17 Operation Summary Report Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- 00V0N -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 @36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 05:00 0.50 RUNCOM P RUNCMP PJSM -R/U TO RUN COMPLETION -MAKE HANGER DUMMY RUN W /CAMERON REP. TO ENSURE LANDING POSITION OF ALIGNMENT PIN AND HANGER IN THE WELL HEAD 05:00 - 06:00 1.00 RUNCOM P RUNCMP STAGE CENTRI -LIFT EQUIP. AND CANNON CLAMPS ON RIG FLOOR 06:00 - 10:30 4.50 RUNCOM P RUNCMP PJSM -P /U ESP MOTOR ASSEMBLY & FILL WITH OIL. - PERFORM CONDUCTIVITY TEST ON ESP CABLE 10:30 - 12:00 1.50 RUNCOM P RUNCMP PJSM -RIH WITH 2 7/8 EUE 8 RD TUBING TEST CONDUCTIVITY TO 1600' -LD 1 BAD JT. - REPLACE WITH ONE FROM PIPE SHED 31.32' 12:00 - 22:00 10.00 RUNCOM P RUNCMP PJSM, CREW CHANGE OUT - PERFORM SPCC AND RIG CHECKS -RIH WITH 2 7/8 EUE 8 RD TUBING -TEST CONDUCTIVITY EVERY 1000' -L/D 10 BAD JTS (PREVIOUS TONG DAMAGE, FAILED TO DRIFT) - REPLACE WITH JTS FROM PIPE SHED 22:00 - 00:00 2.00 RUNCOM P RUNCMP CHANGE OUT SPOOL AND SPLICE CENTRILIFT ESP CABLE -R/U, FILL PIPE AND BREAK CIRCULATION, 1/2 TO 1 BPM = 110 PSI, 5 BBL TOTAL PUMPED - PUWT =73K, SOWT =65K -24 HOUR LOSS TOTAL = 30 BBLS 1/11/2012 00:00 - 01:30 1.50 RUNCOM P RUNCMP PJSM, CREW CHANGE OUT - PERFORM SPCC AND RIG CHECKS - CONTINUE CHANGE OUT SPOOL AND SPLICE CENTRILIFT ESP CABLE - PERFORM CONDUCTIVITY TEST, TESTED GOOD 01:30 - 06:00 4.50 RUNCOM P RUNCMP RIH WITH 2 7/8 EUE 8 RD TUBING F /6000' T/8295' MD, UPPER GLM AT 140' -PUT CLAMPS ON EVERY JOINT FROM 2100' -900' BECAUSE OF DOGLEGS GREATER THAN 4 DEG -UPPER GLM WOULDN'T DRIFT, REPLACE WITH SPARE ON LOCATION -MPU PE ON LOCATION TO VERIFY DUMMY IS LOADED IN GLM -M /U GLM, FINAL 3 JOINTS, AND 4.07 PUP JOINT -TOTAL RAN = 258 JTS 06:00 - 08:00 2.00 RUNCOM P RUNCMP R/U TIW AND HEAD PIN - CIRCULATE TUBING VOLUME, 3 BPM = 610 PSI - PUMP10 BBLS OF 11.9 PPG TO BALANCE OUT WELL - PERFORM CONDUCTIVITY TEST 08:00 - 10:00 2.00 RUNCOM P RUNCMP M/U HANGER - PUWT =97K, SOWT =76K - TERMINATE ESP CABLE - CENTRILIFT REP, PERFORM CONDUCTIVITY TEST Printed 1/23/2012 7:54:20AM //North America - ALASKA - BP Page 17 of 17 Operation Summary Report Common Well Name: MPL -03 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2011 End Date: X4- 00VON -E (1,825,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/1/1990 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292199900 Active Datum: 4 : 03 2/15/1999 22:00 @36.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 10:30 0.50 RUNCOM P RUNCMP LAND TBG HANGER - CAMERON REP RILDS -L/D LANDING JOINT AND TIW VALVE. 10:30 - 12:30 2.00 RUNCOM P RUNCMP SET AND TEST TWC - PERFORM ROLLING TEST FROM BELOW -2.5 BPM / 500 PSI F/ 10 CHARTED MIN. -FROM ABOVE TO 250 LOW AND 3500 PSI HI -FOR 5 CHARTED MIN. PASSED. - NOTIFIED AOGCC OF 24 HOUR BOPE TEST VIA PAGER 659 -3607 12:30 - 15:30 3.00 RUNCOM P RUNCMP WASH AND FLUSH WORKOVER FLUID (SODIUM BROMIDE) FROM RIG FLOOR AND LINES. - CLEAN SAND OUT OF MUD PIT #1. -FLUSH AND RINSE PIT #2 - 4. - FLUSH MUD PUMP / CIRCULATING LINE AND TOP DRIVE. - RECOVER 11.7 PPG NACL / NABR FROM PITS AND OFF LOAD TO STORAGE TANK ON MPL -PAD. 15:30 - 17:30 2.00 RUNCOM P RUNCMP PJSM, N/D 13 5/8 "BOPE - - VACUUM OUT BOP STACK. - DISCONNECT KOOMEY HOSES AND TURN BUCKLES. -N /D BOP STACK 17:30 - 21:30 4.00 RUNCOM P RUNCMP CLEAN AND INSPECT TUBING HANGER AND PENETRATOR - INSTALL TUBING HEAD ADAPTOR AND TREE -TEST ADAPTOR VOID TO LOW OF 250 PSI FOR 5 MIN, HIGH OF 5000 PSI FOR 30 MIN WITH DIGITAL RECORDER -FINAL CONDUCTIVITY CHECK OF ESP CABLE -AT 8064' BHP = 4125 PSI, MOTOR TEMP = 164 F, INTAKE TEMP = 162 F 21:30 - 23:30 2.00 RUNCOM P RUNCMP R/U AND TEST LUBRICATOR - 250 PSI LOW, 3500 PSI HIGH, 5 MIN CHARTED -PULL TWC -M /U BPV -RE -TEST 250 PSI LOW, 3500 PSI HIGH, 5 MIN CHARTED - INSTALL BPV -R/D LUBRICATOR 23:30 - 00:00 0.50 RUNCOM P RUNCMP PERFORM ROLLING TEST BELOW BPV -1 BPM = 560 PSI, 5 MIN - SECURE TREE AND WELL HEAD -24 HOUR LOSS TOTAL = 26 BBLS, INCLUDING 14 BBLS LOST DURING ROLLING TEST * *RIG RELEASED AT 24:00 ** Printed 1/23/2012 7:54:20AM Tree: 2- 9/16" - 5M FMC ID M P U L -03 Orig "Elev. = 55.0' (N33E) Wellhead: 11" 5M FMC Orig. Ong" Elev. = 22.85' w/ 2 -7/8" WKM Tubing Hanger w/ i 1 RT to Csg Spool = 32.15' (N33E) 2 7/8" EU 8rd, 2.5" CIW H BPV profile T a Casing tested to 3500 bove8460" on 1/5/12 20" 91.1 ppf, H -40 I 115' Camco 2-7/8" x 1" 135' KBMM GLM 9 -5/8" 40 # /ft., L -80 BTC. 2758' KOP @ 600' Max Hole Angle = 41.35 deg. Camco 2-7/8" x 1" KBMM @ 4000' GLM 8059' Hole angle through perfs. = 40 deg. Max DLS = 5.68 deg. @ 3256' MD IIIII mil HES 2.313" "XN" Nipple (No -Go ID 2.25 "). 8202' Pump 119 -P23 SXD 8218' 2-7/8" 6.5 # /ft., L-80, 8 rd. EUE tbg. Pump 68 -G31 MVP /SXD (Drift ID = 2.347 ", cap. = 0.00587 bpf) 0 0:1 0, 2 .. 7" 26 # /ft., L -80, BTC, p roduction � ° ' 5x0 Tandem Gas Separator 8251' . Model - GRSFTXAR H6 csg., (drift ID = 6.151 ", cap. = 0.0383 bpf) _ OEM Tandem Seal Section 8256' 1111- GSB3DB UT /LT SB /SB PFSA ® Motor, 266 HP, 2345 volt, 8270' 69 amp, Model KMH lipj PumpMate XTO w/ 8292' Stimulation Summary % i 6 fin Centralizer Frac all zones w/147,022# 16/20 CL PumpMate TVD = 6851' HES 7" x 3.5" VTA Packer 8407' (/ L / / 444yi Perforation Summary HES 3.5" Shear Sub (50k) 8425' Ref. Log L -03 OH DIL -SFL 2/13/90 Poromax 250 micron Size SPF Interval (TVD) Sand Screen 8436' 4.5" 5 8508` -8552' 7016' -7050' 4.5" 5 8601`-8627' 7087' -7107' Bull Nose Plug 8500' 4.5" 5 8634' -8662' 7121' -7133' — 4.5" 5 8674' -8704' 7143' -7166' _ _ = = FCO w/ Doyon 16 to PBTD on 1/7/12 n _ 7" float collar (PBTD) 1 8740' I "Pert. w/4.5 ", 5 spf @ 72 deg. phasing" 7" float shoe 8868 I I DATE REV. BY COMMENTS MILNE POINT UNIT 5/94 D D. Linder RWO WELL L -03 7/96 Hildreth ESP SP RWO Polar #1 2/21/99 12/30/00 GM ESP RWO Nabors 4ESNabors 4ES API NO. 50-029 -21999 05/10/04 JRC ESP RWO Nabors 4ES 5/2/07 Lee Hulme ESP RWO Nabors 3S 2/1/08 Lee Hulme ESP RWO Nabors 3S 10/25/08 REH ESP RWO Nabors 3S 03/18/10 REH ESP RWO- Nabors 4ES BP EXPLORATION (AK) 1/11/12 Hulme ESP RWO & new Pkr & screens -Doyon 16 STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMM N REPO~OF SUNDRY WELL OPERA IONS FtECEIVE~ APR 0 5 ~ 201D 1. Operations Performed: ~t~~glS•s3SI0f1 ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspende~Q ^ Atter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension Ch nge Out ESP 2. Operator Name: 4. Well Class Before Work: .Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 190-007 3. Address: ^ Service ^ Stratigraphic .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21999-00-00 7. Property Designation: 8. Well Name and Number: ADL 025509 MPL-03 9. Field /Pool(s): Milne Point Unit / Kuparuk River Oil Pool 10. Present well condition summary Total depth: measured $900' feet true vertical 7316' feet Plugs (measured) None Effective depth: measured $7$0' feet Junk (measured) None true vertical 7225' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 115' 115' Surface 2725' 9-5l8" 2758' 2494' 3520 2020 Intermediate Production 8837' 7" 8868' 7291' 7240 5410 Liner Perforation Depth: Measured Depth: 8508' - 8704' True Vertical Depth: 7017' - 7167' Tubing (size, grade, measured and true vertical depth): 2-7/8", 6.5# & L_80 8291' & 6850' & 3-1/2" Tailpipe 8468' - 8503' 6987' - 7013' Packers and SSSV (type, measured and true vertical depth): Baker Model'D' Packer Sand Screen 8468' 6987 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 12, Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 248 79 532 260 266 Subsequent to operation: 44,5 108 1,005 320 282 13. Attachments: ^ Copies of Logs and Surveys run 1 Well Class after work: ^ Exploratory ®Development ^ Service erations ® Dail Re ort of Well O y p p ® Well Schematic Diagram .Well Status after work: ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mehrdad Nadem, 564-5941 N/A Printed Name Terrie Hubble Title Drilling Technologist ~ ~ ffiG' Prepared By Name/Number {~J Signature Phone 564-4628 Date 1 Terrie Hubble, 564-4628 Form 10-404 Revised 07/2009 L7 Submit Original Only ABDMS aPR o~s 20~ q,~ y.~ ~ ~ • • BP EXPLORATION Page 1 of 5 Operations Summary Report Legal Well Name: MPL-03 Common Well Name: MPL-03 Spud Date: 2/1/1990 Event Name: WORKOVER Start: 3/4/2010 End: 4/30/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 3/13/2010 09:00 - 14:30 5.50 MOB P PRE RDMO -MPF-29 -R/D FLOOR, BLOW DOWN WATER AND STEAM -RAISE BEAVER SLIDE -SCOPE DOWN AND LOWER DERRICK -MOVE OFF OF MPF-29 AND MOVE TO MPL- PAD 14:30 - 18:00 3.50 MOB N WAIT PRE STAGE RIG ON MPL-PAD TO ALLOW NORDIC 2 TO MOVE THROUGH MPL-PAD -THERE WOULD NOT BE ENOUGH CLEARANCE TO MOVE NORDIC 2 THROUGH IF NABOBS 4ES WAS SPOTTED OVER MPL-03. -GENERAL RIG MAINTENANCE WHILE WAITING FOR NORDIC 2 TO MOVE BY. 18:00 - 00:00 6.00 MOB N WAIT PRE CONTINUE GENERAL RIG MAINTENANCE WHILE WAITING FOR NORDIC 2 TO MOVE BY. 3/14/2010 00:00 - 01:30 1.50 MOB N WAIT PRE CONTINUE GENERAL RIG MAINTENANCE WHILE WAITING FOR NORDIC 2 TO MOVE BY. -NORDIC 2 PASSED THROUGH MPL-PAD AT 01:30 HOURS 01:30 - 06:00 4.50 MOB P PRE SPOT NABOBS 4ES OVER MPL-03. -NOTIFIED PAD OPERATOR BEFOR SPOTTING OVER WELL BP WSL AND NABOBS TOOLPUSHER WERE IN CELLAR WHILE SPOTTING OVER WELL. -SPOT PITS, #3 GENERATOR AND PIPESHED. -SPOT CUTTINGS TANK, TIGER TANK AND FUEL TANK. 06:00 - 12:00 6.00 MOB N WAIT PRE WAIT ON WEATHER. - (-44) DEG F ~ 08:00. -CAN NOT RAISE DERRICK UNTIL TEMPERATURES ARE ABOVE (-40) DEG F. -GENERAL MAINTENANCE WHILE WAITING ON WEATHER. 12:00 - 14:00 2.00 MOB P PRE RAISE AND SCOPE DERRICK -TEMPERATURE (-32) DEG F. 14:00 - 15:00 1.00 KILL P DECOMP TAKE ON 120 DEGREE SEAWATER INTO PITS. -R/U CIRCULATING LINES TO WELL AND TEST TO 3,500 PSI -R/U RETURN LINES TO TIGER TANK AND TEST TO 120 PSI WITH AIR. "RIG ACCEPTANCE 14:00 " 15:00 - 17:00 2.00 KILL P DECOMP R/U WELL SUPPORT LUBRICATOR -TEST TO 500 PSI WITH DIESEL FOR 5 MINUTES -PULL 2-1/2" CAMERON TYPE "H" BPV_ -TBG PRESSURE 900 PSI, IA PRESSURE 810 PSI 17:00 - 18:00 1.00 KILL P DECOMP BLEED OFF GAS TO TIGER TANK. 18:00 - 20:30 2.50 KILL P DECOMP PUMP 60 BBLS OF 120 DEGREE SEAWATER DOWN T BU LNG TAKING RETURNS OUT THE IA THROUGH THE CHOKE TO THE TIGER TANK. -2-1/2 BPM AT 450 PSI TBG, 330 PSI ON CSG. -BULLHEAD 40 BBLS DOWN THE TBG AT 3 BPM BUILDING TO 1,200 PSI. -PUMP DOWN TUBING TAKING RETURNS OUT THE IA THROUGH THE CHOKE TO THE TIGER TANK, 4 BPM AT 540 PSI AND 330 PSI IA Printed: 4/5/2010 10:59:25 AM • • BP EXPLORATION Page 2 of 5 Operations Summary Report Legal Well Name: MPL-03 Common Well Name: MPL-03 Spud Date: 2/1/1990 Event Name: WORKOVER Start: 3/4/2010 End: 4/30/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours ..Task Code NPT Phase Description of Operations 3/14/2010 118:00 - 20:30 I 2.50) KILL I P 20:30 - 21:30 I 1.001 KILL I P 21:30 - 00:00 2.50 KILL P 3/15/2010 00:00 - 02:00 2.00 KILL P 02:00 - 03:00 I 1.001 KILL I P 03:00 - 04:00 1.00 KILL P 04:00 - 08:00 I 4.001 KILL I P DECOMP -320 BBLS SEAWATER PUMPED STARTED GETTING SEAWATER RETURNS. -439 BBLS PUMPED CLEAN 8.5 PPG SEAWATER BACK. -NO FLUID LOSSES TO WELL DECOMP MONITOR WELL, PRESURE BUILDING TO 220 PSI ON TBG AND 230 PSI ON IA -BLEED DOWN PRESSURE AND SHUT BACK IN. PRESSURE BUILDING BACK TO THE SAME LEVELS. -BLEED DOWN PRESSURE AND LINE UP TO OBSERVE WELL FOR FLOW. -WELL STILL FLOWING. SHUT IN. PRESSURE BUILDING TO SAME LEVEL DECOMP ORDER OUT 9.4 PPG BRINE FROM MI/SWACO. DECOMP WAITING ON 9.4 PPG BRINE AND TRUCKS. -EMPTY SEAWATER FROM PITS -EMPTY TIGER TANK. DECOMP HOLD WEEKLY SAFETY MEETING WITH CREW. -DISCUSS BP AND NABOBS INCIDENTS. -DISCUSS PERSONAL SAFETY COMMITMENT DECOMP TAKE ON HEATED 9.4PPG BRINE INTO THE PITS. -VERIFY WEIGHT OF FLUID DECOMP PUMP 60 BBLS OF 9.4PPG BRINE DOWN TUBING TAKING RETURNS OUT THE IA THROUGH THE CHOKE TO THE TIGER TANK. -3 BPM AT 250 PSI TBG, 290 PSI ON CSG. BULLHEAD 40 BBLS DOWN THE TBG -3 BPM BUILDING TO 1,050 PSI. PUMP DOWN TUBING TAKING RETURNS OUT THE IA -THROUGH THE CHOKE TO THE TIGER TANK -4 BPM AT 340 PSI AND 300 PSI IA -PUMPED 446 BBLS STOP PUMPS AND SHUT-IN CHOKE. -120 PSI ON BOTH IA AND TBG. -BLEED DOWN BOTH IA AND TUBING THROUGH CHOKE IN STEPS. -PRESSURES STEPPED DOWN TO 50 PSI ON BOTH IA AND TBG. 08:00 - 09:45 I 1.751 KILL I P 09:45 - 15:15 I 5.501 KILL I P DECOMP LINE UP AND CIRCULATE THROUGH PITS. - AT 2 BPM EXPERIENCED LOSSES OF - 2 BBLS / 5 MIN. REDUCED PUMP RATE. - AT 1 BPM AND EXPERIENCED A GAIN OF - 5 BBLS / 5 MIN. SHUT DOWN PUMPS - EXPERIENCED A PIT GAIN OF 3 BBLS / 5 MIN. CLOSED CHOKE AND SHUT-IN WELL. -PRESSURE ON TUBING SLOWLY CLIMBED TO 80 PSI OVER 1.5 HRS. DECOMP CONSULTED RWO ENGINEER Printed: 4/5/2010 10:59:25 AM • BP EXPLORATION Page 3 of 5 Operations Surnrnary Report Legal Well Name: MPL-03 ', Common Well Name: MPL-03 Spud Date: 2/1/1990 ~' Event Name: WORKOVER Start: 3/4/2010 End: 4/30/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 3/15/2010 09:45 - 15:15 5.50 KILL P DECOMP -DECISION WAS MADE TO WEIGHT UP TO 9.9 PPG NACL BRINE. -ORDERED TWO 290 BBL VAC TRUCKS OF 9.9 PPG BRINE. -SENT ONE 290 BBL VAC TRUCK OF 9.4 BRINE TO MUD PLANT TO WEIGHT UP TO 9.9 PPG. WAIT ON FLUIDS. -SPOT SPOOLING UNIT. 15:15 - 00:00 8.75 KILL P DECOMP LOAD PITS WITH 290 BBLS OF 9.9 PPG NACL BRINE. -TURN FIRST TRUCK DIRTY AND DISPOSE OF 260 BBLS OF 9.4 AND CRUDE FROM TIGER TANK. -WEIGHT LIGHT ON FIRST TRUCK WEIGHT UP TO 9.9 PPG. -WAIT ON ADDITIONAL 9.9 PPG BRINE 3/16/2010 00:00 - 02:30 2.50 KILL P DECOMP PUMP 60 BBLS OF 9.9 PPG BRINE DOWN TUBING TAKING RETURNS OUT THE IA THROUGH THE CHOKE TO THE TIGER TANK. -3 BPM AT 590 PSI TBG, 90 PSI ON CSG. BULLHEAD 40 BBLS DOWN THE TBG -3 BPM BUILDING TO 1,500 PSI. PUMP DOWN TUBING TAKING RETURNS OUT THE IA -THROUGH THE CHOKE TO THE TIGER TANK -3.5 BPM AT 690 PSI AND 90 PSI IA -PUMPED 402 BBLS. CLEAN 9.9 PPG RETURNS TO SURFACE 02:30 - 03:30 1.00 KILL P DECOMP 0 PSI ON TUBING 0 PSI ON IA -VISUALLY CHECK FOR FLOW, NO FLOW -TUBING AND IA ARE BOTH ON A SLIGHT VAC 03:30 - 05:00 1.50 WHSUR P DECOMP INSTALL 2-1/2" CAMERON TYPE 'H' TWC WITH CAMERON WELLHEAD TECH -TEST FROM ABOVE TO 3,500 PSI FOR 10 CHARTED MINUTES -TEST FROM BELOW TO 500 PSI FOR 10 CHARTED MINUTES BY ROLLING TEST AT 2 BPM. 05:00 - 06:00 1.00 WHSUR P DECOMP N/D 2-9/16" TREE AND 11"ADAPTOR FLANGE -INSPECT HANGER AND WELLHEAD. 06:00 - 06:30 0.50 BOPSU P DECOMP RIG SERVICE -PERFORM PRE-TOUR CHECKS. 06:30 - 08:30 2.00 BOPSU P DECOMP N/U 13-5/8" x 5K HYDRIL BOPE. -RIG UP BOPE TEST EQUIPMENT. -FILL STACK ~ 08:30 - 13:00 4.50 BOPSU P DECOMP TEST BOPE PER BP/AOGCC REQUIREMENTS: ~ -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. -TESTED 2-7/8" X 5" VBR'S WITH 2-7/8" TEST JOINT. -TESTED ANNULAR WITH 2 7/8" TEST JOINT. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESSED BY TP. -TESTED FLOOR VALVES. -PERFORM KOOMEY TEST Printed: 4/5/2010 10:59:25 AM C~ BP EXPLORATION Page 4 of 5 Operations Summary Report Legal Well Name: MPL-03 Common Well Name: MPL-03 Spud Date: 2/1/1990 Event Name: WORKOVER Start: 3/4/2010 End: 4/30/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations ~ 3/16/2010 08:30 - 13:00 4.50 BOPSUFI P 13:00 - 13:30 0.50 BOPSU P 13:30 - 14:30 1.00 WHSUR P 14:30 - 15:30 1.00 BOPSU P 15:30 - 18:30 3.OO BOPSUFIP 18:30 - 00:00 5.501 PULL P 3/17/2010 00:00 - 02:30 2.50 PULL P 02:30 - 03:00 0.50 PULL P 03:00 - 04:00 1.00 PULL ~P 04:00 - 06:00 2.00 BUNCO P 06:00 - 06:30 0.50 06:30 - 07:30 1.00 07:30 - 18:00 10.50 DECOMP -200 PSI BUILD UP TO 3000 PSI FROM 1700 PSI = 30 SECONDS. -FULL BUILD UP TO 3000 PSI = 163 SECONDS. -4 BOTTLES x 1850 PSI. -WITNESSING TEST WAIVED BY LOU GRIMALDI OF AOGCC. ON 3/13/2010 DECOMP RU DUTCH RISER SYSTEM. -CROSSOVER/LUBRICATOR DECOMP RU LUBRICATOR AND TEST SAME TO 500 PSI WITH DIESEL. -PULL TWC. -TUBING AND IA ARE ON A SLIGHT VAC. -LD LUBRICATOR AND RD DUTCH SYSTEM. DECOMP MU LANDING JOINT W/TIW VALVE SCREW INTO HANGER. -"CAMERON" BOLDS -PULL TBG HANGER OFF SEAT ~ 55 K -LD HANGER -CUT ESP CABLE. -MU LANDING JOINT W/TIW VALVE. DECOMP CBU WITH 300 BBLS 9.9 PPG BRINE -OIL STILL BREAKING OUT -CONTINUE TO CIRCULATE 4 BPM/ 930 PSI -SPR = 1 BPM / 50 PSI DECOMP .EQf~„r -F/ -8,368' MD W/ ESP ASSEMBLY f -STAND BACK 2 7/8" TBG IN DERRICK. -FEED WELL @ -20 BPH - -7 BPH LOSS RATE DURING TRIP - 139 LASALLE CLAMPS RETRIEVED - 3 FLAT GUARDS - 5 PROTECTOLIZERS DECOMP BREAK OUT AND LAY DOWN ESP ASSEMBLY TO THE PIPE SHED DECOMP DUMMY RUN WITH WKM TUBING MANGER -CAMERON HAND ON SITE FOR DUMMY RUN TO ENSURE HANGER ORIENTATION USING ALIGMENT PIN. DECOMP CLEAN AND CLEAR RIG FLOOR -SWAP OUT ESP CABLE SPOOL RUNCMP PU/MU CENTRILIFT ESP MOTOR AND ASSEMBLY. CENTRILIFT FIELD TECH. ASSEMBLED AND PREPARED REMAINING ESP BHA COMPONENTS. -FEED WELL AT -20 BPH W/ SEAWATER. --6 BPH LOSS RATE. RUNCMP RIG SERVICE -PERFORM PRE-TOUR CHECKS. RUNCMP COMPLETE M/U OF ESP ASSEMBLY RUNCMP CONTINUE TO RUN IN HOLE WITH ESP COMPLETION ON 2-7/8" EUE 8RD TUBING FROM THE DERRICK -CHECK ESP CABLE CONDUCTIVITY EVERY 2000'. -FILL TUBING AND FLUSH W/ 5 BBLS AT EVERY CABLE CHECK AND SPLICE..5 BPM C~ 1800 PSI. Printed: 4/5/2010 10:59:25 AM • BP EXPLORATION Page 5 of 5 Operations Summary Report Legal Well Name: MPL-03 Common Well Name: MPL-03 Spud Date: 2/1/1990 Event Name: WORKOVER Start: 3/4/2010 End: 4/30/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 3/17/2010 18:00 - 19:00 1.00 RUN 19:00 - 21:00 2.00 RUN 21:00 - 21:30 0.50 RUN RUNCMP MU HANGER & LANDING JOINT - INSTALL PENETRATOR RUNCMP CENTRILIFT MU HANGER SPLICE RUNCMP LAND TUBING HANGER AND 2-7/8" ESP COMPLETION. RUN IN LOCK DOWN SCREWS. -256 JOINTS OF 2-7/8" TUBING TO 8290.84', MU TORQUE _ 2,300 FT-LBS. -PU WT = 55K LBS, SO WT = 37K LBS. -139 LASALLE CLAMPS, 3 FLAT GUARDS, AND 6 PROTECTOLIZERS RUNCMP INSTALL TWC AND TEST. -1000 PSI FROM ABOVE FOR 10 CHARTED MINUTES. -500 PSI ROLLING TEST FROM BELOW FOR 10 CHARTED MINUTES -2 SPM, 2.6 BBLS TOTAL. RUNCMP NIPPLE DOWN BOP STACK AND ADAPTER, STAND BACK IN CELLAR WHDTRE N ADAPTER FLANGE AND TREE. WHDTRE TEST HANGER VOID TO 5000 PSI FOR 30 MINUTES - GOOD TEST. TEST TREE TO 5000 PSI FOR 5 MINUTES -GOOD TEST. WHDTRE PU MPU WELL SUPPORT LUBRICATOR AND MAKE UP TO TREE. -FILL WITH DIESEL AND TEST TO 500 PSI FOR 5 MINUTES -GOOD TEST. -PULL TWC AND INSTALL BPV. -TEST BPV TO 500 PSI FOR 5 MINUTES -GOOD TEST. -CHANGE OUT FLANGE ON IA. WHDTRE CLEAN AND CLEAR RIG FLOOR -SECURE TREE AND CELLAR. WHDTRE AAR ON MPL-03 WITH ERIC GREGORY CREW. -RELEASE RIG AT 06:00 HRS. -FREEZE PROTECT WILL BE DONE BY LITTLE RED AFTER NABOBS 4ES MOVES OFF THE WELL. 21:30 - 23:00 I 1.501 RU 3/18/2010 23:00 - 00:00 00:00 - 00:30 00:30 - 01:30 1.00 RUNCOI 0.50 WHSUR 1.00 WHSUR 01:30 - 03:30 I 2.001 WHSUR 03:30 - 04:30 1.00 WHSUR 04:30 - 06:00 1.50 WHSUR Printed: 4/5/2010 10:59:25 AM Tree: 2-9/16" - 5M FMC Wellhead: 11" 5M FMC w/ 2-7l8" WKM Tubing Hanger w/ 2 7/8" EU 8rd, 2.5" CIW H BPV profile MPU L-03 Orig~Elev. = 55.0` (N33E) Orig. GL Elev. = 22.85' RT to Csg Spool = 32.15` (N33E) 20" 91.1 ppf, H-40 115' 9-5/8" 40#/ft., L-80 BTC. 2758' KOP @ 600` Max Hole Angle = 41.35 deg. @ 4000' Hole angle through perfs. = 40 deg. Max DLS = 5.68 deg. @ 3256` MD 2-7/8" 6.5#/ft., L-80, 8rd. EUE tbg. (Drift ID = 2.347", cap. = 0.00587 bpf) 7" 26#/ft., L-80, BTC, production csg., (drift ID = 6.151", cap. = 0.0383 bpf) Camco 2-7/8" x 1" KBMM GLM 151' Camco 2-7/8" x 1" KBMM GLM 430' Camco 2-7/8" x 1" ` KBMM GLM 8139 HES 2-7/8" "XN" Profile 8197' Nipple (ID 2.25"). Pump 119-P23 Modei - sxD 8212` Pump 68-G31 MVP/SXD Tandem Gas Separator 8246` Model - GRSFTX ARH6 Tandem Seal Section 8251' GS83DBUT/LT 56/SB PFSA Motor, 266 HP, 2345 volt, 8264' 69 amp, Modei KMH Stimulation Summary Frac all zones w/147,022# 16/20 CL Perforation SummarX Ref. Loa L-03 OH DIL-SFL 2/13/90 Size SPF Interval TVD 4.5" 5 8508`-8552' 7016`-7050' 4.5" 5 8601 `-8627' 7087'-7107' 4.5" 5 8634'-8662' 7121'-7133' 4.5" 5 8674`-8704' 7143`-7166' "Pert. w/4.5", 5 spf @ 72 deg. phasing" DATE REV. BY COMMENTS 5/94 M. Linder RWO 7/96 D. Hildreth ESP RWO Polar #1 5/2/07 10/25/08 REH 03/18/10 REH ESP RWO Nabors 3S ESP RWO Nabors 3S ESP RWO-Nabors 3S ESP RWO-Nabors 4ES (1 ~lh I PumpMate XTO 8287' u UU w/6 fin Centralizer Baker Model "D" Packer 8468' w/22.14" Sand Screen 3.5" Camco "D" Nipple 8501 ` w/a 2 Plug Min ID = 2.313" WLEG 8503` 7" float collar (PBTD) 8740` 7" float shoe 886g~ MILNE POINT UNIT W~~ L-03 API NO. 50-029-21999 BP EXPLORATION (AK) STATE OF ALASKA - ALA OIL AND GAS CONSERVAT#~FJ CC~310N `} REPORT OF SUNDRY WELL OPERATIQ;NS ~~ 1~ 8ot3- 1. Operations Performed: ^ Abandon ^ Repair Well ^ Plug Per~Orations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ' ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP - ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development- ^ Exploratory 190-007 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21999-00-00' 7. KB Elevation (ft): KBE = 55.0' - 9. Well Name and Number: MPL-03 ' 8. Property Designation: 10. Field /Pool(s): ADL 025509 ~ Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 8900 , feet true vertical 7316 - feet Plugs (measured) 8501' Effective depth: measured 8780 feet Junk (measured) N/A true vertical 7225 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 115' 115' Surface 2725' 9-5/8" 2758' 2494' 3520 2020 Intermediate Production 8837' 7" 8868' 7291' 7240 5410 Liner s~+'e:. Perforation Depth MD (ft): 8508' - 8704' Perforation Depth TVD (ft): 7017' - 7167' 2-7/8", 6.5# L-80 8368' Tubing Size (size, grade, and measured depth): 3-1/2" tail pipe 8468' - 8503' Packers and SSSV (type and measured depth): Baker Model 'D' Packer Sand Screen 8468' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 590 0 Subsequent to operation: 436 133 766 200 220 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: _ ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ' ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 N/q Printed Name Sondra Stew Title Drilling Technologist t Prepared By NamelNumber. nature Phone 564-4750 Date Sondra Stewman 56a-4750 Form 10-404 Revised E~4/290Q ,~,, ~ ~S Submit Original Only .,~,~ . ~~e~~ z ~~~~~ ~~ Tree: 2-9/16" - 5M FMC ~ Wellhead: 11" 5M FMC w/ 2-7/8" WKM Tubing Hanger w/ 2 7/8" EU 8rd, 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 115` 9-5/8" 40#/ft., L-80 BTC. 2758' KOP @ 600' Max Hole Angle = 41.35 deg. @ 4000' Hole angle through perfs. = 40 deg. Max DLS = 5.68 deg. @ 3256` MD 2-7/8" 6.5#/ft., L-80, 8rd. EUE tbg. (Drift ID = 2.347", cap. = 0.00587 bpf) 7" 26#/ft., L-80, BTC, production csg., (drift ID = 6.151", cap. = 0.0383 bpf) simulation Summary Frac all zones w/147,022# 16/20 CL Perforation Summary Ref. Loa L-03 OH DIL-SFL 2/13/90 Size SPF Interval TVD 4.5" 5 8508`-8552' 7016`-7050' 4.5" 5 8601 `-8627' 7087`-7107' 4.5" 5 8634'-8662' 7121'-7133' 4.5" 5 8674'-8704' 7143'-7166' "Pert. w/4.5", 5 spf @ 72 deg. phasing" DATE I REV. BY I COMMENTS RT Elev. = 55.0' (N33E) Orig. GL Elev. = 22.85' RT to Csg Spool = 32.15' (N33 Camco 2-7/8" x 1" KBMM GLM 154' Camco 2-7/8" x 1" 431 ` KBMM GLM Camco 2-7/8" x 1" KBMM GLM HES 2-7/8" "XN" Profile Nipple (ID 2.25"). 8140' 8283` Pump 119P23 Modei - sxD 8298 Pump 18P75 Model-sxD Tandem Gas Separator 8322' Model - GRSFTX BARH6 Tandem Seal Section 8328' GSB3DBUT SB/SB PFSA/FSA CL5 Motor, 266 HP, 2345 volt, 8342` 69 amp, Model KMH Re-rated to 195 KMH-A 2177v/ 53A PumpMate XTO w/6 fin Centralizer 8363' Baker Model "D" Packer 8468' w/22.14" Sand Screen 3.5" Camco "D" Nipple 8501' w/a 2 Plug Min ID = 2.313" WLEG 8503' 7" float collar (PBTD) 7" float shoe 870' 8868` MILNE POINT UNIT WELL L-03 API NO. 50-029-21999 5/94 7/96 M. Linder D. Hildreth RWO ESP RWO Polar #1 2/21/99 MDO ESP RWO Scalecaps Nabors 4ES 12/30/00 GMH ESP RWO Nabors 4ES 05/10/04 JRC ESP RWO Nabors 4ES 5/2/07 Lee Hulme ESP RWO Nabors 3S BP EXPLORATION (AKl 10/25/08 I REH I ESP RWO-Nabors 3S MPU L-03 • • BP EXPLORATION Page 1 of 6 Operations Summary Report Legal Well Name: MPL-03 Common Well Name: MPL-03 Spud Date: 2/1/1990 Event Name: WORKOVER Start: 10/16/2008 End: 10/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/25/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task ~ Code' NPT Phase Description of Operations 10/17/2008 18:00 - 21:00 3.00 RIGD P PRE RD /Blow down steam and water lines. Scope derrick down and lay over on carrier. 21:00 - 00:00 3.00 RIGD P PRE Prep units for move to MPL-03. Pull Carrier off Well with MPU pad operator, BP WSL and Nabors toolpusher present. 10/18/2008 00:00 - 00:30 0.50 RIGD P PRE Prep units for move. 00:30 - 03:30 3.00 MOB P PRE Move Rig and Camp from MPI-Pad to MPL-Pad. 03:30 - 10:00 6.50 RIGU P PRE Spot Camp, lay mats and Rig components. At 07:00 hrs, back the Carrier over well with MPU Pad operator, BP WSL and Nabors Toolpusher present. At 0800 hrs, back the Pipe Shed and mate up with the Carrier. Spot the Tiger Tank. Back the Pits and mate up with the Carrier. 10:00 - 14:00 4.00 RIGU P PRE PJSM. Raise and scope the Derrick. Hook up air, steam lines and power to all components. Spot and RU Little Red and Upright Tank. Rig accepted at 13:00 hours 10/18/2008. 14:00 - 17:00 3.00 KILL P DECOMP Take on heated seawater to the Upright and the Pits. RU hardline to the Tiger Tank. Pressure test all surface lines to 3,500 psi against the Choke and the hardline to the Tiger Tank to 500 psi - OK. 17:00 - 18:00 1.00 WHSUR P DECOMP RU Lubricator and ull 2-1/2" T e "H" BPV with Well rt Techs. Note wellhead pressures: Tbg = 500 psi , IA = 700 psi , OA = 50 psi. LD Lubricator. 18:00 - 18:30 0.50 WHSUR P DECOMP Crew change, perform pre tour checks. 18:30 - 23:00 4.50 WHSUR P DECOMP Bleed gas from IA through choke to Tiger tank from 700 psi to 0 psi. Stop, close choke. Pump 66 bbls 140 Deg F 8.45 ppg seawater down the tubing, taking returns up the IA through the choke to the Tiger tank at 3 BPM. Stop, close choke. Recovered 35 bbls in Tiger tank. Bullhead 40 bbls down the tubing with the choke closed at 3 BPM / -450 psi. Monitor SITP for 15 minutes, TBG = 10 psi, IA = 300 psi. Pump 338 bbls heated 8.45 ppg seawater down tubing at 3 BPM / -400 psi through a open choke to the Tiger tank until clean returns observed on surface. Recovered 194 bbls from Tiger tank. 23:00 - 23:30 0.50 WHSUR DECOMP Monitor well for 30 minutes. Tubing and IA on a vacuum, OA = 0 psi. 23:30 - 00:00 0.50 WHSUR P DECOMP Blow down lines and RD kill manifold. 10/19/2008 00:00 - 00:30 0.50 WHSUR P DECOMP RU and test LRS line to well head IA valve to 500 psi. 00:30 - 01:30 1.00 WHSUR P DECOMP Dry rod TWC and test from above to 3,500 psi for 10 charted_ minutes with Cameron well head tech. 01:30 - 03:00 1.50 WHSUR P DECOMP ND Tree and Adapter Flange. Check Hanger threads with Cameron rep - OK. Top Hanger threads are 2-7/8" EUE 8rd. Fill the IA with -20 bbls per hour of 8.45 ppg seawater with LRS while ND / NU. 03:00 - 07:00 4.00 BOPSU P DECOMP NU 11" X 13-3/8" DSA, PU BOPE from shipping cradle and NU to DSA. 07:00 - 08:00 1.00 BOPSU P DECOMP Function test BOPE and prepare 2-7/8" Test Joint. Pressures test BOPE er BP / AOGCC Regulations to 250 psi low and 3,500 psi high. The test was witnessed by the BP WSL, Nabors Toolpusher and state representative Bob Noble. 08:00 - 14:00 6.00 BOPSU N RREP DECOMP The motor that runs the hydraulic unit for the test pump locked up and will not work. Confirmed it was the motor by isolating it and trying to get it to run. Continue to feed the IA with 20 bbls of seawater per hour with Little Red. RU Elephant Trunk and containment in front of Spooling Unit. Electrician from 7ES Printetl: 11/10/2008 10:25:29 AM • • BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: MPL-03 Common Well Name: MPL-03 Spud Date: 2/1/1990 Event Name: WORKOVER Start: 10/16/2008 End: 10/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/25/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/19/2008 08:00 - 14:00 6.00 BOPSU N RREP DECOMP troubleshoots the motor and problem found to be the pins on the plug that connects to the plug board were damaged - Electrician made repairs and the motor was put back in service. 14:00 - 14:30 0.50 BOPSU P DECOMP Fill the Stack and pressure up to 3,500 psi to continue the BOPE test. Find a drip coming out of the test port fitting that tests the two hanger seals. Call out Cameron wellhead tech to change out the fitting. 14:30 - 16:00 1.50 BOPSU N WAIT DECOMP Wait on Cameron wellhead tech to arrive on location. 16:00 - 16:30 0.50 WHSUR N SFAL DECOMP Change out the check valve on the test fitting on the upper flange of the Tubing Spool due to a bad check valve -the ball was missing. Install new one with Cameron wellhead tech. 16:30 - 19:30 3.00 BOPSU P DECOMP Resume testing BOPE per BP / AOGCC Regulations to 250 psi low and 3,500 psi high. The test was witnessed by the BP WSL, Nabors Toolpusher and State Representative Bob Noble. Tested the Annular to 3,500 psi with 2-7/8" Test Joint. All tests were held for 5 minutes with no failures. 19:30 - 20:00 0.50 BOPSU P DECOMP LD test joint and pump out BOP stack. 20:00 - 21:00 1.00 WHSUR P DECOMP RU Opso Lopso and Lubricator and test with diPSPI to 50o nsi Pull TWC with MPU well su ort tech. 21:00 - 21:30 0.50 PULL P DECOMP MU 2-7/8" landing joint with TIW valve. Cameron rep BOLDS. Pull tubing hanger off seat at 73 K. PUW = 62 K. 21:30 - 22:00 0.50 PULL P DECOMP Circulate 50 bbls of 8.45 ppg heated seawater at 3 BPM/ 450 psi. Returns at surface after pumping 20 bbls. Estimated fluid level at -500 ft md. Monitor well for 15 minutes. Tubing and IA on a vacuum, OA = 75 psi. 22:00 - 23:00 1.00 PULL P DECOMP BO/LD tubing hanger and landing joint. 23:00 - 00:00 1.00 PULL P DECOMP PJSM with Centrilift. POH with ESP completion assembly and stand back 2-7/8" tubin in Derri k. Snake ESP cable over sheave in Derrick. Maintain continuous fill rate at -20 BPH, with no returns. POH 2 stands and L/D GLM (DPSOV). 10/20/2008 00:00 - 08:00 8.00 PULL P DECOMP POH with ESP completion assembly and stand back 2-7/8" tubing in Derrick. Maintain continuous fill rate at -20 BPH. 106 stand out at 05:30 hours. 08:00 - 12:00 4.00 PULL P DECOMP On surface with the existing ESP Assembly. Drain, break out and lay down all the components with Centrilift rep. 12:00 - 13:30 1.50 PULL P DECOMP RD Elephant Trunk. Clear and clean Rig Floor. 13:30 - 18:00 4.50 BUNCO RUNCMP PJSM. P_U new ESP Assembly components with Centrilift re s. 18:00 - 00:00 6.00 BUNCO RUNCMP Run ESP com letion on 2-7/8" L-80 6.5# EUE 8rd tubin from Derrick. Utilizing Best-O-Life 2000 pipe dope and MU Torque = 2,300 ft-Ibs. Maintain continuous fill rate at -20 BPH, with no returns. Every 2,000' RIH stop and check conductivity of cable. Fill the Tubing and flush ESP pump with 10 bbls seawater. -2,000' = 1/2 BPM / 310 psi. ESP splice observed on stand #85 RIH. 240 joints, XN, KBMM GLM dummy ran at 00:00 hours. 10/21/2008 00:00 - 00:30 0.50 BUNCO RUNCMP Run ESP completion on 2-7/8" L-80 6.5# EUE 8rd tubing from Derrick. Utilizing Best-O-Life 2000 pipe dope and MU Torque = 2,300 ft-Ibs. Maintain continuous fill rate at -20 BPH, with no returns. Every 2,000' RIH stop and check conductivity of cable. Fill the Tubing and flush ESP pump with 10 bbls seawater. -4,000 = 1/2 BPM / 310 psi. and -6,000 = 1/2 BPM Printed: 11/10/2008 10:25:29 AM • BP EXPLORATION Operations Summary Report Page 3 of 6 ~ Legal Well Name: MPL-03 Common Well Name: MPL-03 Spud Date: 2/1/1990 Event Name: WORKOVER Start: 10/16/2008 End: 10/25/2008 Contractor Name: NABOBS ALASKA DRI LLING I Rig Release: 10/25/2008 Rig Name: NABOBS 3S Rig Number: i ..Date From - To Hours Task Code NPT Phase Description of Operations -_ 10/21/2008 00:00 - 00:30 0.50 BUNCO RUNCMP / 320 psi. Stop on joint #248, MU TIW valve. 00:30 - 02:30 2.00 BUNCO RUNCMP Centrilift rep made reel to reel ESP cable splice in spooling unit. Splice is on joint #252 RIH. 02:30 - 03:30 1.00 BUNCO RUNCMP Continue RIH with ESP assembly, two KBMM GLM with DPSOV's to joint #260. 03:30 - 04:00 0.50 BUNCO RUNCMP Fill the Tubing and flush ESP pump with 10 bbls seawater at 1/2 BPM / 350 psi. 04:00 - 04:30 0.50 BUNCO RUNCMP PU / MU landing joint to tubing hanger and orient alignment with Cameron rep. 04:30 - 06:30 2.00 BUNCO RUNCMP Centrilift rep make tubing hanger penetrator splice to ESP Cable. 06:30 - 08:00 1.50 BUNCO RUNCMP Establish final PUW = 72K ,SOW = 49K. Have trouble landing the Hanger with Cameron wellhead rep due to bent/bad alignment pin. The pin will not completely run in nor back up. Discuss with wellhead rep and Anchorage wellhead supervisor. 08:00 - 10:30 2.50 BUNCO RUNCMP Discuss options and plan forward with Anchorage Engineering. 10:30 - 12:30 2.00 PULL C 12:30 - 13:00 0.50 PULL C 13:00 - 18:00 5.00 PULL C 18:00 - 21:00 3.00 PULL C 21:00 - 22:00 1.00 PULL C 22:00 - 23:00 1.00 WHSUR C 23:00 - 00:00 1.00 WHSUR C 10/22/2008 00:00 - 06:30 6.50 WHSUR C 06:30 - 07:30 1.00 WHSUR C 07:30 - 09:00 1.50 W HSUR ~ C 09:00 - 11:00 I 2.00 I W HSUR I C 11:00-12:00 ~ 1.OO~WHSUR~C acker ull the lu circulate the well and re-run the ESP com letion. DECOMP RU to pull out of the hole with the ESP Completion. RU Elephant Trunk and containment in front of Spooler. DECOMP Pull the Hanger to the floor and lay down with Cameron wellhead rep. Check the Hanger and it is good. LD Landing Joint. DECOMP POOH with 2-7/8" ESP Completion standing back in the Derrick. Maintain 20 bbls per hour fill rate with seawater while POOH. 85 stands (170 Jts) out of the hole at 1700 hrs. DECOMP BD / LD ESP pump assembly. Leave handling pups on discharge head. DECOMP RD elephant trunk. Transfer 180 bbls from upright tank to pits. Clean and clear rig floor. INTERN PJSM. RU floor to RIH with RBP. INTERN RIH with 7" RBP and running tool with 2-7/8" tubing out of derrick. Maintain hole fill at 20 BPH. INTERN Continue RIH with 7" RBP out of derrick. INTERN In with 254 Joints of 2-7/8" Tubing. Establish PUW = 55K , SOW = 40K. Set 7" RBP with center of element at 8,002' with.. Halliburton rep. Slack off to 25K to ensure that the lower slips are set - OK. Pick up to 70K to confirm that upper slips are set - OK. POOH three stands and fill the well with 21 bbls of seawater. INTERN Attem t to t st 7" RBP - no Jo . Pum in awa at 1.5 bpm with 250 psi. Check alignment of everything and re-attempt, still pumping away. RIH and set more weight on the RBP per Halliburton rep. Set another 5K down on the RBP. Pressure up the wellbore against the RBP to 1,000 psi and chart for 10 mins -good test. This proves up our first mechanical barrier. INTERN POH 3 stands of Tubing standing back in the Derrick. PUMU 7" RTTS with SSCV with Halliburton reps. RIH on 1 stand of Tubing from the Derrick. Establish PUW = 55K ,SOW = 40K. Set the 7" RTTS with SSCV at 68' center of element. INTERN Pressure test the 7" RTTS with SSCV from above against Printed: 11/10/2008 10:25:29 AM • C~ BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: MPL-03 Common Well Name: MPL-03 Spud Date: 2/1/1990 Event Name: WORKOVER Start: 10/16/2008 End: 10/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/25/2008 Rig Name: NABOBS 3S Rig Number: Date. From - To Hours Task Code NPT Phase Description of Operations 10/22/2008 11:00 - 12:00 1.00 WHSUR C INTERN closed blind rams to 3 500 psi for 10 charted mins -good test This proves up our second mechanical barrier. 12:00 - 13:00 1.00 WHSUR C INTERN Drain the Stack and RD 2-7/8" Handling Equipment. Clear and clean Rig Floor. 13:00 - 14:00 1.00 WHSUR C INTERN RU 3-1/2" Handling Equipment. PU 3-1/2" Joint of Drill Pipe and make up the Packoff Pulling Tool to it. Run in and "J" into the Packoff. BOLDS with Cameron wellhead rep. Check the IA and OA for any pressure -both are on a vac. 14:00 - 14:30 0.50 WHSUR C INTERN Pull the Packoff with PUW = 30K. Pull to the floor with 10K (block weight). Inspect Packoff and notice that the junk ring broke off, will retrieve with the Tubing Spool. LD Pulling Tool and Joint of 3-1/2" Drill Pipe. 14:30 - 17:00 2.50 BOPSU C INTERN Lockout / tagout the Accumulator Unit. ND 13-5/8" 5M BOPE with tubing spool attached. Hold rig evacuation drill with the well secure -all personnel responded accordingly. At 1600 hrs pick the Stack up off the wellhead. 17:00 - 18:00 1.00 WHSUR C INTERN Cameron tech attempted to pull packoff lower seal and junk ring from casing bow . nable to pull, discuss different options with WSL on packoff removal. Discuss with Anchorage engineering on plan forward. 18:00 - 18:30 0.50 WHSUR C INTERN Pre-tour checks. Derrick inspection, check PVT and cellar. Call for welder from GBR. 18:30 - 20:30 2.00 WHSUR C INTERN Wait on GBR to travel from Deadhorse. Preform general housekeeping in cellar to prep for welding operations. Place fire blankets and extinguishers in cellar. Plug Casing hole with fire blanket to keep debris from falling in hole. Meet with pad-op to perform hot work permit. 20:30 - 23:30 3.00 WHSUR C INTERN PJSM with the crew, Cameron wellhead rep and GBR welder. Fill out hot work permits and task hazard analysis of welding in cellar. Weld 1/2" steel stock down to funk ring and to 1" x 4" x 12" plate. Place 1 " plate under porter power jack. Use jack to dislod a 'unk rin .Clean out void and remove lower seal. Make second weld on lower ring in same fashion as previous. Use jack to remove lower ring. Clean out void for new packoff,. 23:30 - 00:00 0.50 WHSUR C INTERN MU landing joint with packoff running tool. Set new 7" packoff. RILDS. LD landing joint and running tool. 10/23/2008 00:00 - 04:00 4.00 BOPSU C INTERN PJSM. NU BOPE with new tubing spool attached. 04:00 - 05:30 1.50 BOPSU C INTERN Bod test BOPE and tubing spool to 3500 psi. 2 grease zirts and LDS packing glands leaking. Replace zirts and tighten packing glands. Unable to hold 3500 psi. Isolate kill and choke lines, re-test with visual checks -unable to test. 05:30 - 06:00 0.50 WHSUR C INTERN PUMU test plug on landing joint. 06:00 - 08:00 2.00 WHSUR C INTERN Attempt to pressure test from above on the test plug. Change out seals on Test Plug due to not holding initially. Use pressure to fully seat the Plug and obtain a bottom to test against. Unable to get pressure test to 3,500 psi due to a leak in our surface system. Troubleshoot and isolate the problem to be in our kill line valve on the mud manifold. 08:00 - 12:30 4.50 WHSUR X SFAL INTERN Rebuild the inside of the kill line valve on the mud manifold. The valve internals were washed out and needing replaced. 12:30 - 13:30 1.00 WHSUR C INTERN Pressure test the BOPE body breaks to 250 psi low and 3,500 psi high or 5 charted mins - aood test Blow down and rig down test equipment. Drain the BOP Stack. rnnceo: iviviwva ivco:car.m BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 10/23/2008 13:30 - 14:00 14:00 - 15:30 15:30 - 16:30 MPL-03 MPL-03 WORKOVER NABOBS ALASKA DRILLING I NABOBS 3S Hours ~ Task Code NPT 0.50 WHSUR C 1.50 WHSUR C 1.00 WHSUR C 16:30 - 17:30 1.00 WHSUR C 17:30 - 00:00 6.50 WHSUR C 10/24/2008 100:00 - 01:00 01:00 - 02:00 02:00 - 04:30 1.00 WHSUR C 1.00 BUNCO 2.50 BUNCO 04:30 - 14:30 10.00 RU 14:30 - 15:30 1.00 RU 15:30 - 16:00 0.50 RU 16:00 - 17:30 17:30 - 18:00 18:00 - 18:30 1.50 RUNCOA~'P 0.50 RUNCO.1p 0.50 WHSUR P 18:30 - 22:30 4.001 WHSUR I P Start: 10/16/2008 Rig Release: 10/25/2008 Rig Number: Phase INTERN INTERN INTERN INTERN INTERN INTERN RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP Page 5 of 6 Spud Date: 2/1 /1990 End: 10/25/2008 Description of Operations PU Landing Joint and pull Test Plug. LD same. Change out Elevators. PU RTTS Pulling Tool and RIH on one stand of 2-7/8" Tubing. Sting into the RTTS and screw in with 21 turns to the right to open the SSCV. Pull the RTTS to the rig floor with a PUW = 55K. Stand back the stand of Tubing. Break out and lay down the RTTS with Halliburton rep. RIH with three stands of Tubing from the Derrick. Establish parameters of PUW = 55K and SOW = 40K. Latch onto 7" RBP at 8,002' and release per Halliburton rep. U circulating hose to headpin and line up to pump down t e Tubing with Rig Pump. RU Little Red to pump down IA. Allow elements on RBP to relax. Close the Annular and bullhead 35 bbls of seawater down the IA with Little Red at 2 bpm / 1,000 psi and 30 bbls of seawater down the Tubing at 2 bpm / 1,000 psi. Total of 65 bbls bullheaded to sweep the rathole below the RBP (rathole vol = 30 bbls). Shut down the pumps and blow down all lines. RD circulating hose and headpin. RD Little Red off the IA. Monitor the well - both the Tubing and IA on a vac. Observe fluid level in the IA falling. Fill up with seawater to confirm and observe it falling. Calculate static loss rate of 25 bbls per hour. POOH with 7" RBP standing back Tubing in the Derrick. Maintain 20 bbls per hour fill rate with seawater while POOH. LD top single to accomodate BHA length. LD RBP and running tool. PU single and make stand up. Clear and clean rig floor. PJSM with crew and Centrilift tech. RU equipment to run completion. Bring tools and equipment to shed and floor for running pump assembly. MU centralizer, ESP pump, motor and seals as per Centrilift hand. String ESP cable from spooler over sheave to rig floor. MU motor leads and check conductivity (new motor lead extension per Centrilift). Flow check well and obtain static loss rate of 27 bbls per hour with seawater. PJSM. RIH with 2-7/8" ESP completion as per tally. Maintain 20 BPH hole fill. Check conductivity and flush pump with 10 bbls every 2000' at a rate of 1 bpm / 850 psi. Use La Salle clamps on first 9 joints then every second joint. MU torque on tubing - 2,300 ft-Ibs. Using Best-O-Life 2000 Pipe Dope on all connections. In with 130 stands of 2-7/8" Tubing. Break out Joint #260 and remove from the string replacing it with a 10' Pup Joint and an 8' Pup Joint. Ran a total of 259 Joints of Tubing. PUMU Headpin and circulating hose and perform final flush through the ESP Pump at 1 bpm / 975 psi. Blow down lines. Ran a total of 139 LaSalle Clamps, 6 Protectolizer and 3 Flat Guards. PUMU Landing Joint and Tubing Hanger and align with Cameron rep. Establish final PUW = 72K and SOW = 48K. Perform lower field connector splice with Centrilift reps. Land Tubing Hanger and RILDS with Cameron rep. Dry rod 2-1/2" Type "H" TWC with Cameron rep. Pressure test Set on cradle, pull BOP out of cellar. Printed: 11/10/2008 10:25:29 AM i ~ ! BP EXPLORATION Page 6 of 6 Operations Summary Report Legal Well Name: MPL-03 Common Well Name: MPL-03 Spud Date: 2/1/1990 Event Name: WORKOVER Start: 10/16/2008 End: 10/25/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/25/2008 Rig Name: NABORS 3S Rig Number: Date From - To Hours ' Task Code NPT Phase ' Description of Operations 10/24/2008 22:30 - 00:00 1.50 WHSUR P RUNCMP NU tree and adapter flange. Make final ESP conductivity checks with Centrilift. Phase to phase ESP Cable = 2.8 Ohms Phase to ground ESP Cable = 1.14 GigaOhms ,Pressure at intake = 2,946 psi ,Temperature at intake = 159.7 degF , Temperature at motor = 161.6 degF. Suck out pits and upright tank. Suck out crude from drip pan in ESP spooling unit. 10/25/2008 00:00 - 01:30 1.50 WHSUR P RUNCMP Finish NU tree. Test tubing hanger void to 5,000 psi for 30 min. Test tree to 5,000 psi with diesel for 10 min -charted. 01:30 - 03:00 1.50 WHSUR P RUNCMP RU lubricator, test to 500 si with diesel. Pull TWC. Set 2-1/2" Type "H" BPV. RD and LD lubricator. Normal up cellar, wellhead valves and wipe down tree. PU tools and equipment. "`Rig Released at 0300 hrs on 10/25/2008"' Pfintetl: 7 7 /1 U/20U8 1 U:LS:"L`J AM Well History Well Date Summary MPL-03 10/6/2008 (Acid Treatm/v nt) T/V0= 200/280/20 Pump 5 bbl 60/40 meth spear followed by 10 bbls dead crude dow n TBG for infectivity test, then 15 bbls of 7.5% DAD Acid followed by 3 bbls 60/40 meth to flush Acid from lines then 21 bbls dead crude overflush for Acid. Acid fell out to ESP, cut displacement 16 bbls early. IA/OA, master &ssv open. Swab & w ing closed. Turn w ell over to operator for soak/ESP run & flow back. FWHP=200/280/0 MPL-03 10/9/2008 ***WELL S/I ON ARRIVAL*** (LIB ESP) RUN 1.70" LIB TO 8311' MD CLEAN IMPRESSION O ESP PUMP PULL BEK- STA @ 166' MD, SET BEK-DPSOV ***WELL S/I ON DEPART*** MPL-03 10/10/2008 (Tbg Infectivity test) T/V0=300/340/40 Ramp 24 bbls diesel dow n TBG @ around 1 bpm to verify TBG to be clear. FWHP= 200/340/40 (swab-shut /wing-shut /ssv-shut /master-open / IA and OA open to gauges.) MPL-03 10/12/2008 (Assist Slickline) T/V0= 300/400/40 PT TBG to 2000 Psi. Aw gers continued on 10-13-08 MPL-03 10/12/2008 ***WELL S/I ON ARRVAL*** TROUBLE GEEING CAT STANDING VALVE DOWN HOLE RUN BRUSH AND 2.29 GAUGE RING TO XN-NIPPLE @ 8295' MD RUN CAT SV, WORK THRU 2 TIGHT SPOTS ***CONT ON WSR 10-13-08** MPL-03 10/13/2008 (Assist Slickline) T/V0=300/400/40 PT TBG to 2000 Psi w ith 8 bbls diesel. FWHP= 350/400/40 ( Slickline on well @ time of departure. Va and OA open to gauges) MPL-03 10/13/2008 ***CONT FROM WSR 10-12-08*** (rw o prep) SET CAT SV IN XN-NIPPLE @ 8295' MD, LRS FT TUBING TO 2000# GOOD TEST, PULL CAT SV PULL~BI -~i~C~FF~Z51~ST1~~~:~1~'Z`R~ PULL BEK-DPSOV FROM STA #2, &STA #3, SET BK-DGLV IN SAME ***WELL S/I ON DEPART`** MPL-03 10/14/2008 (sbhps) *"* WELL S/I ON ARRNAL *** CURRENTLY RIH W/ SBHPS GAUGES *** CONT ON 10/15/08 *** MPL-03 10/14/2008 MPU Well Support Techs demobe wellhouse flow-lines and foundation, also installed BPV all blinds TO to spec. Note :ST removed BPV for slick-Line and then re-installed the next dav. SO YES BPV IN HOLE MPL-03 10/15/2008 *** CONT FROM 10/14/08 *** (sbhps) RAN SBHPS PER PROGRAM, 1st STOP @ 7826' MD, 2nd STOP @ 8296' MD. *** WELL S/I ON DEPARTURE, BP./ INSTALLED *** MPL-03 10/20/2008 PULLED 2 DGLV'S. SET 2 DPSOV'S AND SET 1 DGLV IN MANDRELS ON RIG 3S MPL-03 10/25/2008 T/V0=0/0/0 (Freeze R-otect Post RWO) PUrrped 65 bbls Dead Crude down IA. Continued on 10-26- 08 WSR MPL-03 10/26/2008 (Freeze Rotect Post RWO) Continued from 10-25-08 WSR Pumped 15 bbls Dead G7ude down tubing. FWHP= 0/0/0 Master, Wing, Swab, SSV, IA, and OA closed. MPL-03 10/26/2008 MPU Well support Tech re-hooked w ell, Foundation flow-lines and well house. TO flanges to spec. and PT flow-lines to 1150 PSI both Test and Roduction. Note: BPV removed fromwell profile Also replaced IA and OA jewlery with new. Print Date: 11/20/2008 Page 1 of 1 STATE OF ALASKA /O o~0-D~ ALA OIL AND GAS CONSERVATION COMI'~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate 0, Other ~ ACID TREATMENT Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 190-0070. 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-21999-00-00 7. KB Elevation (ft): 9. Well Name and Number: 55 KB ~ MPL-03 - 8. Property Designation: 10. Field/Pool(s): ,, ADLO-025509 ~ MILNE POINT Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: Total Depth measured 8900 - feet Plugs (measured) None true vertical 7316 - feet Junk (measured) None Effective Depth measured 8741 feet true vertical 7194.95 feet Casing Length Size MD TVD Burst Collapse Conductor 83 20" 91# H-40 32 - 115 32 - 115 1740 750 Surface 2725 9-5/8" 40# L-80 33 - 2758 33 - 2494 5750 3090 7420 5410 Production 8837 7" 26# L-80 34 - 8503 34 - 7013 r a~.~kd~i~«D'~~ R+~11~ s ~ LUUU Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 32 - 8315 0 0 - Packers and SSSV (type and measured depth) 3 1/2" BAKER MODEL D PACKER 8468 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 358 103 651 261 Subsequent to operation: 370 103 647 255 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ' Development ~' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil +~' - Gas WAG GINJ ! WINJ ' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 10/8/2008 Form 10-404 Revi d 04/2006 ~ ~e ~ Submit Original Only /~.- ` ~~.~'~ ,:_, ~ MPL-03 190-007 PERF ~TT~(_HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPL-03 4/14/90 PER 8,674. 8,704. 7,144.01 7,166.83 MPL-03 10/14/90 PER 8,508. 8,552. 7,017.21 7,050.91 MPL-03 10/14/90 PER 8,601. 8,627. 7,088.37 7,108.21 MPL-03 10/14/90 PER 8,634. 8,662. 7,113.55 7,134.88 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK,. OPEN OH OPEN HOLE • L~ A MPL-03 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 10/6/2008', (Acid Treatmwnt) T/I/0= 200/280/20 Pump 5 bbl 60/40 meth spear followed ', ' by 10 bbls dead crude down TBG for infectivity test, then 15 bbls of 7.5% ', DAD Acid followed by 3 bbls 60/40 meth to flush Acid from lines then 21 bbls ', ', 'dead crude overflush for Acid. Acid fell out to ESP, cut displacement 16 bbls ', 'early. IA/OA, master & ssv open. Swab & wing closed. Turn well over to ', 'operator for soak/ESP run & flow back. FWHP=200/280/0 ', FLUIDS PUMPED BBLS 8 60/40 METH 15 7.5% DAD ACID 21 CRUDE 44 TOTAL I-tClrC~ v ~~ STATE OF ALASKA ~~ ~~~ ~ `~ L~~C~ ALASKA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIOp~ka Qil & Gas Cons. Cammissiol Anchorage 1. Operations Performed: ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 190-007' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21999-00-00 ' 7. KB Elevation (ft): KBE = 55.0' 9• Well Name and Number: MPL-03 - 8. Property Designation: 10. Field /Pool(s): - ADL 025509 - Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 8900 ~ feet true vertical 7316 ' feet Plugs (measured) 8501' Effective depth: measured 8780 feet Junk (measured) N/A true vertical 7225 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 115' 115' Surface 2725' 9-5/8" 2758' 2494' --- ~^-3520 2020 Intermediate Production 8837' 7" 8868' 7291' 7240 5410 Liner ~1~. ~ FF~ ~ ~ zap Perforation Depth MD (ft): 8508' - 8704' Perforation Depth TVD (ft): 7017' - 7167' 2-718", 6.5# L-80 8387' Tubing Size (size, grade, and measured depth): 3-1/2" tail pipe 8468' - 8503' Packers and SSSV (type and measured depth): Baker Model 'D' Packer Sand Screen _. __ . _. _ _:. 8468' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ .. 100 Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 300 0 Subsequent to operation: 357 138 880 350 268 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 N/A Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Sign ture Phone 564-4750 Date(-Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 Submit Original Only !~ ~r~~ Tree: 2-9/16" - 5M FMC 7 M P U L-03 ~~ RT Elev. = 55.0` (N33E) Wellhead: 11" 5M FMC Orig. GL Elev. = 22.85' w/ 2-7/8" WKM Tubing Hanger w/ I I I IJ RT to Csg Spool = 32.15' (N3 2 7/8" EU 8rd, 2.5" CIW H BPV profile ' ' ' 20" 91.1 ppf, H-40 115' 9-5/8" 40#/ft., L-80 BTC. 2758` KOP @ 600` Max Hole Angle = 41.35 deg. @ 4000' Hole angle through pen`s. = 40 deg. Max DLS = 5.68 deg. @ 3256` MD 2-7/8" 6.5#/ft,, L-80, 8rd. EUE tbg. (Drift ID = 2.347", cap. = 0.00587 bpf) 7" 26#/ft., L-80, BTC, production csg., (drift ID = 6.151", cap. = 0.0383 bpf) Stimulation Summarv Frac all zones w/147,022# 16/20 CL Perforation Summary Ref. Loa L-03 OH DIL-SFL 2/13/90 Size SPF Interval TVD 4.5" 5 8508'-8552' 7016'-7050' 4.5" 5 8601'-8627' 7087'-7107' 4.5" 5 8634`-8662' 7121 `-7133' 4.5" 5 8674`-8704' 7143`-7166' "Perf. w/4.5", 5 spf @ 72 deg. phasing" HES 2-7/8" 8rd. XN "XN" Profile 8295` Nipple (ID 2.205"). DATE REV. BY COMMENTS 5/94 7/96 M. Linder D. Hildreth RWO ESP RWO Polar #1 2/21/99 MDO ESP RWO Scalecaps Nabors 4ES 12/30/00 GMH ESP RWO Nabors 4ES 05/10/04 JRC ESP RWO Nabors 4ES 5/2/07 Lee Hulme ESP RWO Nabors 3S 2/1/08 Lee Hulme ESP RWO Nabors 3S Pump 142P23 Modei-sxD $311` Pump 18P75 Modei-sxD Tandem Gas Separator ' Model - GRSFTX BARH6 8338 Intake (TVD) 6886` Tandem Seal Section 8343` GSB3DBUT SB/SB PFSA/FSA CL5 Motor, 225 HP, 2190 volt, 8357` 59 amp, Model KME-1 <<~~~~ PumpMate XTO 8382' w/6 fin Centralizer PumpMate TVD = 6920' TVD Baker Model "D" Packer w/22.14" Sand Screen 8468' 3.5" Camco "D" Nipple 8501' w/a 2 Plug Min ID = 2.313" WLEG 8503` 7" float collar (PBTD) 8740` 7" float shoe gggg° MILNE POINT UNIT WELL L-03 API NO. 50-029-21999 BP EXPLORATION (AK) Camco 2-7/8" x 1" KBMM GLM 166' Camco 2-7/8" x 1" KBMM GLM 444` Camco 2-7/8" x 1" 8089, KBMM GLM • • BP EXPLORATION Operations Summary Report Page 1 of 3 ~ Legal Well Name: MPL-03 Common Well Name: MPL-03 Spud Date: 2/1/1990 Event Name: WORKOVER Start: 1/24/2008 End: 2/1/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/1/2008 Rig Name: NABORS 3S Rig Number: Date From - To ~ Hours Task 'Code NPT Phase ~ Description of Operations 1/27/2008 18:30 - 22:30 4.001 MOB P PRE Blow down steam and water lines. Scope derrick down and lay 22:30 - 00:00 1.50 MOB P 1/28/2008 00:00 - 06:00 6.00 MOB P 06:00 - 13:30 I 7.501 RIGU I P 13:30 - 18:00 I 4.501 RIGU I P 18:00 - 00:00 6.001 KILL ~ P 1/29/2008 100:00 - 01:30 I 1.501 KILL I P 01:30 - 03:30 I 2.001 KILL I P over on carrier. PRE Unhook lines and prep units to move. R/D handi-berm. PRE Move pits and pipeshed off of MPL-13, Move carrier off of MPL-13 to MPL-03. At 5:00 give AOGCC notice of upcoming BOPE testing. PRE Position Carrier, Pit, and Pipe Shed modules for spotting over the well. Lay out Herculite and matting boards. PJSM. Spott carrier over wellhead. John Crisp w/ AOGCC to come witness BOPE testin . PRE Raise and scope derrick. Continue hooking up Rig components. Build up around wellhead working area. DECOMP IA valves on wellhead froze. Thaw IA valves and hook up secondary annulus valve. Hook up lines to well. Hook up lines to slop tank. Lines were packed off with snow. Take on heated seawater. Rig accepted at 18:00 hours on 1/28/2008 DECOMP Warm up and test pump lines to 3,500 psi. Test lines to tiger tank to 500 psi. DECOMP R/U well support lubricator and test to 500 psi. Pull BPV. 270 03:30 - 06:00 2.50 KILL P DECOMP Pump 60 bbls of heated seawater down tubing taking returns out the IA tthrough the choke 3 bpm 03720 psi. Line up and bullhead 60 bbls of heated seawater down tubing 2-1/2 bpm at 980 psi. Line up and pump heated seawater down the tubing taking returns through the choke 4 bpm C~3 1020 psi 06:00 - 07:30 1.50 KILL P DECOMP Continue circulate 130 deg SW to kill well. 595 Bbls pumped, 220 Bbls lost (includes 60 Bbls bullheaded). 07:30 - 10:00 2.50 KILL P DECOMP Tb and IA on Vac. Flowcheck for 30 minutes while Blowing down circulation, kill, and tiger tank lines. Dry rod TWC. Pump 105 Bbls SW in IA (~ 3.5 BPM, catch fluid in 15 Bbls, inject in to formation Ca3 1100 psi and chart to test TWC from below for 30 min. Test TWC to 3500 si from above and chart for 3 minutes. Total losses to well during kill and testing = 325 10:00 - 12:00 2.00 WHSUR P DECOMP Gravity feed SW in IA every 2 hours during ND / NU _ operations. C~ 11:00 (2 hours since bullhead) IA took 18 Bbls. ND tree. Inspect hanger threads. 8 1/2 turns to MU to 2 7/8" hanger threads. Cameron service lock down screws and packing. 12:00 - 18:30 6.50 WHSUR P DECOMP MU DSA to wellhead. PUMU ROPE. (stack upright on cradle ~ 13:30), ~ 14:30 talked to John Crisp w/ AOGCC to be here ~ 6:00 p.m. for witnessing of BOPE testing. 17:30 John Crisp called to waive AOGCC's rights to witness BOPE testing. 18:30 - 19:30 1.00 WHSUR P DECOMP Function test BOPE com onents. Had to heat u annular to function test. 19:30 - 22:30 3.00 WHSUR P DECOMP Well head gland nuts and hanger port leaked. Retighten same. 22:30 - 00:00 1.50 WHSUR P DECOMP Test BOPE with 2 7/8" test jt. 250 psi low ,3500 psi . Test annuular to 3500 psi. 1/30/2008 00:00 - 02:00 2.00 BOPSU P DECOMP Con't BOPE test. 02:00 - 03:00 1.00 BOPSU P DECOMP UD test jt. and blow down lines. 03:00 - 06:00 3.00 PULL P DECOMP PJSM with DSM and Cameron, PU and MU Opso Lopso & lubricator, pull TWC. MU 2 7/8" landing joint, screw into Printed: 2/13/2008 2:24:36 PM • • BP EXPLORATION Page 2 of 3 Operations Summary Report Legal Well Name: MPL-03 Common Well Name: MPL-03 Spud Date: 2/1/1990 Event Name: WORKOVER Start: 1/24/2008 End: 2/1/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/1/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/30/2008 03:00 - 06:00 3.00 PULL P DECOMP hanger w/ 8 1/2 turns. 06:00 - 09:00 3.00 PULL P DECOMP Pull han er to ri floor w/ 75K PU wt (includes blocks). Load hole w/ 32 Bbls SW. Flowcheck well. Necessary to use a tugger to pull pipe over to be able to pass through rotary table (w/ bushings removed). Re-land hanger. Adjust tensioner lines from carrier to derrick to change position of blocks. Pull hanger to rotary table and still out of alignment. Land tbg hanger, back out landing joint, close blind rams and secure well. 09:00 - 11:00 2.00 PULL P DECOMP PJSM and Change of scope plan forward discussion. Rig down elephant trunk, BOPE tensioner chains, riser, and equipment prior to lowering Derrick to re-jack the sub structure. 11:00 - 19:00 8.00 PULL P DECOMP Scope derrick to down position. Lower Derrick. Jack and level sub structure. IA on Vac. At 16:00 load IA w/ 18 Bbls SW. Raise and scope Derrick, re-connect flowline, etc. 19:00 - 20:30 1.50 PULL P DECOMP PJSM. PU and MU landing jt. screw into hanger with 8 1/2 turns, pull tbg. hanger to rig floor (PUWT 75K includes blocks) Load hole w/ 32 bbls SW. LD landing jt., 2 pups and tbg hanger. 20:30 - 00:00 3.50 PULL P DECOMP PJSM with Centrilift, POH stand back 2-7/8", 6.5# L-80 EUE 8rb tb . in derrick. Run ESP cable over shieve to spooler. Fill well with SW, by pumping double steel displacement. 30 stands out (-6430') ~ 2400 hrs. 1/31/2008 00:00 - 06:00 6.00 PULL P DECOMP Con't POH f/ -6430' and stand back in derrick, 2-7/8" 6.5# L-80 EUE 8rd tbg. and ESP cable to the spooling unit. Tubing connection starting to break-out hard - 50 stands out (5200') no scale or bad i e noted. Fill well with SW by pumping double steel displacement, and fill well with 27 bbls SW C~3 0330 hrs. 06:00 - 11:30 5.50 PULL P DECOMP Crew change, PJSM w/ Centrilift re: BOLD ESP assembly. BOLD pump. No scale or fill in pump. No visible sign of mechanism for failure. However, shaft on u er um ass (main pump) is broken internally. Shaft will rotate from the top, but not from the bottom. Rig down elephant trunk. Losses C~3 -25 Bbls /hour. Recovered 138 ec. LaBelle clamps, 6 ec. Protectolizers, 3 ec. Flat Guards. 11:30 - 15:30 4.00 BUNCO RUNCMP PUMU new ESP BHA. Losses ~ - 25 Bbls /hour. 15:30 - 00:00 8.50 BUNCO RUNCMP Run ESP on 2 7/8" tbg, torqued to 2300 ft-Ibs, Lasalle cable protectors on first nine joints then every second joint on the round cable, also on all GLM pups but not on the tubing hanger pup. RIH 97 stands (-6250')Continue to RIH with ESP on 2 7/8" 6.5#, L-80, EUE 8 Rd tubing. Check cable conductivity and pump through motor every 2,000' (~ 1 bpm / 930 psi, pumping a total of 10 bbls SW each time. 2/1/2008 00:00 - 04:30 4.50 BUNCO RUNCMP Make reel to reel splice at -6250, flush pump with 10 bbls SW, 1 BPM C~ 930 psi 04:30 - 06:00 1.50 BUNCO RUNCMP Continue to RIH w/ ESP on 2-7/8" tbg. 06:00 - 08:00 2.00 BUNCO RUNCMP PUMU top GLM's w/ DPSOV installed. ESP RIH w/ 6 protectolators, 3 flat guards, 138 LaSalle cable clamps. PUMU hanger to proper orientation 08:00 - 10:00 2.00 BUNCO RUNCMP Centrilift make penetrator splice for connector to the hanger. 10:00 - 12:00 2.00 WHSUR P OTHCMP Land Tbg hanger. RILDS. Break out landing joint. Dry rod Printed: 2/73/2008 2:24:36 PM • • BP EXPLORATION Page 3 of 3 Operations Summary Report Legal Well Name: MPL-03 Common Well Name: MPL-03 Spud Date: 2/1/1990 Event Name: WORKOVER Start: 1/24/2008 End: 2/1/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/1/2008 Rig Name: NABOBS 3S Rig Number: I Date From - To Hours Task Code Description of Operations NPT Phase 2/1/2008 10:00 - 12:00 2.00 WHSUR P OTHCMP TWC. Pump SW in IA ~ 3 BPM, 800 psi for 30 minutes to test TWC from below. Test TWC from above to 3500 psi for 30 minutes. Both tests charted. 12:00 - 14:30 2.50 WHSUR P OTHCMP ND BOPE 14:30 - 18:00 3.50 WHSUR P OTHCMP NU Tree. Final checks by Centrilift: 1.0 gig phase to ground / 3.0 gig phase to phase / 149 deg F intake temp / 2959 psi at intake. CIW test hanger void to 5000 psi for 20 minutes. Test tree and valves to 5000 psi and chart. 18:00 - 19:00 0.00 WHSUR P OTHCMP Shoot fluid level on IA C~3 400' down. 19:00 - 21:00 2.00 WHSUR P OTHCMP Pull TWC with lubricator, Shoot fluid level in tbg. C«~ 350' down. Install BPV and secure tree and annular valves. Release Rig for move to MPL-28A C? 2100 hrs. 2/1/2008 Printed: 2/13/2008 2:24:36 PM ALA A OIL AND GAS CONSERVATION COM SION Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage ~! Cn 1 in JAN 1~ ~~~ STATE OF ALASKA 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate0 Other ~ ACID ' Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well [~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' ' Exploratory ~ 1so-oo70 3. Address: P.O. Box 196612 Stratigraphic Service ~' 6. API Number: Anchorage, AK 99519-6612 50-029-21999-00-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 55 KB _ MPL-03 ' 8. Property Designation: 10. Field/Pool(s): ADLO-025509 ~ MILNE P04NT-- Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: ` /S; ~.e~ BYGe Total Depth measured87'86 feet ,n Plugs (measured) None as true vertical 7 feet ~/•~ Junk (measured) None ~ ~' Effective Depth measured 8741 feet ~;' -, ~'+ ~ •~~ ,~~~ ~ U~~ true vertical 7194.95 feet Casing Length Size MD TVD Burst Collapse Conductor 83 20" 91.1# H-40 32 - 115 32 - 115 1740 750 Surface 2725 9-5/8" 40# L-80 33 - 2758 33 - 2494 5750 3090 Production 8837 7" 26# L-80 34 - 8503 34 - 7013 7240 5410 Perforation depth: Measured depth: 8508 - 8552 8601 - 8627 8634 - 8662 8674 - 8704 _ True Vertical depth: 7017.21 - 7050.91 7088.37 - 7108.21 7113.55 - 7134.88 7144.01 - 7166.83 _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 32 - 8315 0 0 - Packers and SSSV (type and measured depth) 3 1/2" BAKER MODEL D PACKER 8468 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 144 39 291 289 Subsequent to operation: 0 ~ 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory Development ~" Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~ GINJ 1~. WINJ ~' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 1/15/2008 Form 10-404 Revised 04/2006 - ~' L. ~~ Submit Original Only fff ~°~ /sd r•zZ.~~ • ~ MPL-03 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ::ACT{Vt"FY[7Ai'E•° SUMMARY- .,.. , . ,....._. 1/10/2008'CTU #9 w/ 1.5" OD CT. Spot unit and begin rigging up. Perform weekly BOP i ~test...Job in progress... ; 1/10/2008'CTU #9 w/ 1.5" OD CT. Spot unit and begin rigging up. Perform weekly BOP test. MU BHA #1. ***Continued on 1 /11108 W SR""" 1/10/2008 Heat uprights 1% KCL XS for coil job. Temperature is -42 degrees F. Unstab, night cap BOPS and test, and go to weather standby Ticket to be continued for rigging down after weather standby. FLUIDS PUMPED BBLS 83 60/40 METH 84 1 % XS KCL 12.3 10% DAD ACID 179.3 TOTAL 1/11/2008 Attempt to get ESP started. CTU #9 with 1.5" OD CT. "**Continued from 1/10/08 WSR"** RIH with BHA #1 (1.75" OD JSN). Dry tag ESP at 8232' ctmd. Circulate two bottoms up at high pump rate to circulate out any fill -tag depth remained unchanged at 8232' ctmd. Lay-in 12.3 bbls 10% DAD acid on top of ESP. Work acid through ESP in stages, letting each stage of acid soak in the ESP. Total acid soak time is 3 hours 15 minutes. Coordinate with DSO and centralift representative to bring ESP online. ESP starts immediately, but will not support flow. Well returned ~5 bbls liquid, then returns ceased. Shut-in return line and try to build WHP with no success. Conclude that ESP will not support flow to surface. Overdisplace acid into formation and freeze protect well with 25 bbls 60/40 methanol. Post-acid injectivity through ESP is the same as pre-acid injectivity through ESP, ~0.2 bpm at 2400 psi. ***Job Complete""'" V~A~~ STATE OF ALASKA ALA~A OIL AND GAS CONSERVATION COM S{ON Gov r ~ 200 REPORT OF SUNDRY WELL OPERATIQ~~ Iai1 & Gas Gorls. Cammissinn 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate 0 ,~ Oth~ U D Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well[] 2. Operator BP Exploration (Alaska}, Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ~ 1so-oo70 3. Address: P.O. Box 196612 Stratigraphic '~ Service 6. API Number: Anchorage, AK 99519-6612 50-029-21999-00-00 7. KB Elevation (ft): 9. Well Name and Number: 55. KB MPL-03 8. Property Designation: 10. Field/Pool(s): , ADLO-025509 - MILNE POINT Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: Total Depth measured 8780 feet Plugs (measured) None true vertical 7224.59 feet Junk (measured) None Effective Depth measured 8741 ~ feet true vertical 7194.95 feet Casing Length Size MD TVD Burst Collapse Conductor 83 20" 91.1# H-40 32 - 115 32 - 115 1740 750 Surface 2725 9-5/8" 40# L-80 33 - 2758 33 - 2494.01 5750 3090 Production 8837 7" 26# L-80 34 - 8503 6986.51 - 7013.38 7240 5410 Perforation depth: Measured depth: 8508 - 8552 8601 - 8627 8634 - 8662 8674 - 8704 True Vertical depth: 7017.21 - 7050.91 7088.37 - 7108.21 7113.55 - 7134.88 7144.01 - 7166.83 _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 SURFACE - 9324' 0 0 - Packers and SSSV (type and measured depth) 3 1/2" BAKER MODEL D PACKER ~. --r. 8468 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): h ~~~~~~ ~~~ ~ G~~7 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 232 61 _.-_,~3$...~:.._ ---•-•-------- 277 Subsequent to operation: 230 62 314 288 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 1~" Development ~' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas '' WAG GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pr I,e Title Data Management Engineer Signature Phone 564-4944 Date 11/9/2007 Form 10-404 Revi d 04/2006 ~' ~k i' ;~ 1~4% ~~,`y Submit Original Only • • MPL-03 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY'' 7'T/I/0=300/340/0. (Acid treatment) Spear into tbg w/ 13 bbls crude followed by 10 `' bbls 5% DAD acid. Spot acid on ESP w/ 3 bbls 60/40 meth & 36 bbls crude. Let ,soak for 20 minutes. Run ESP forward & backward. Turn well over to DSO. FW H P=900/340/0. FLUIDS PUMPED BBLS 49 CRUDE 10 5% DAD ACID 3 60/40 METH 62 TOTAL as a nil R. r" 1. Operations Performed: '''0} t..Ons. Comm' o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter ~aEèR" Well I o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver 181 Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 190-007 / 3. Address: o Service o Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21999-00-00/ 7. KB Elevation (ft): KBE = 55.0' / 9. Well Name and Number: MPL-03 v 8. Property Designation: 10. Field 1 Pool(s): ADL 025509 ( Milne Point Unit 1 Kuparuk River Sands 11. Present well condition summary Total depth: measured 8900 / feet true vertical 7316 / feet Plugs (measured) NIA Effective depth: measured 8780 feet Junk (measured) NIA true vertical 7225 feet Casing Length Size MD TVD ~.. - ..' Burst Collapse Structural Conductor 80' 13-3/8", 48# 115' 115' Surface 2725' 9-5/8",36# 2758' 2494' 3520 2020 Intermediate Production 8837' 7",26# 8868' 7291' 7240 5410 Liner sCANNED JUN 1 4 2007 Perforation Depth MD (ft): 8508' - 8704' Perforation Depth TVD (ft): 7017' - 7067' 2-7/8",6.5# L-80 8324' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Baker Model '0' Packer Sand Screen with 8468' 31/2" tubing from 8468' - 8503' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. ReDresentative Daily Averaae Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl CasinQ Pressure Tubina Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 285 150 608 390 271 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Frank Roach, 564-4373 Printed Name Sondra Stewman Title Technical Assistant -;;:rv~ DateS'hO!Ò7 Prepared By Name/Number: Sigr(;iÍur; ~ / Phone 564-4750 Sondra Stewman, 564-4750 - Form 10-404 Revised 04/2006 . STATE OF ALASKA ~ RECE/" ALAYA Oil AND GAS CONSERVATION CO.ION ~ vED REPORT OF SUNDRY WELL OPERATIONS MAY 3 0 2007 41 k sian ORIGINAl RBDMS BFL JUN 11 Z007 Submit Original Only ~ 2-9/16" - 5M FMC Wellhead: 11" 5M FMC wI 2-7/8" WKM Tubing Hanger wI 3" Acme, 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 æÐ 9-5/8" 40#/ft., L-80 BTC. \2758' I KOP @ 600' Max Hole Angle = 41.35 deg. @ 4000' Hole angle through perfs. = 40 deg. Max DLS = 5.68 deg. @ 3256' MD 2-7/8" 6.5#/ft., L-80, 8 rd. EUE tbg. (Drift ID = 2.347", cap. = 0.00587 bpf) 7" 26#/ft., L-80, BTC, production csg., (drift 10 = 6.151", cap. = 0.0383 bpf) Stimulation Summary Frac all zones w/147,022# 16/20 CL Perforation Summary Ref. LOQ L-03 OH DIL-SFL 2/13/90 Size SPF Interval TVD 4.5" 5 8508'-8552' 7016'-7050' 4.5" 5 8601'-8627' 7087'-7107' 4.5" 5 8634'-8662' 7121'-7133' 4.5" 5 8674'-8704' 7143'-7166' "Perf. w/4.5", 5 spf @ 72 deg. phasing" MPU L-03 DATE REV. BY COMMENTS 5/94 M. Linder RWO 7/96 D. Hildreth ESP RWO Polar #1 2/21/99 MOO ESP RWO Scalecaps Nabors 4ES 12/30100 GMH ESP RWO Nabors 4ES 05/10104 JRC ESP RWO Nabors 4ES 5/2/07 Lee Hulme ESP RWO Nabors 3S . RT Elev. : 55.0' ~N33E) . GL Elev. - 22.85 RT to Csg Spool = 32.15' (N33E) Cameo 2-7/8" x 1" I KBMM GLM . 167' Cameo 2-7/8" x 1" KBMM GLM 445' Cameo 2-7/8" x 1" 8090' I KBMM GLM HES 2-7/8" 8rd. I "XN" Profile 8232' Nipple (ID 2.205"). Pump 145P11 Model- SSD 1:1 I 8248' I Pump 47P62 Model-SXD Tandem Gas Separator 8279' I Model - GRSFTX BARH6 Intake (TVD) 6841' I Tandem Seal Section 8284' I GSB3DBUT SB/SB PFSNFSA CL5 Motor, 225 HP, 2190 volt, I 8297' I 59 amp, Model KME-1 (rerated) PumpMate XTO I 8320' w/6 fin Centralizer Baker Model "0" Packer 8468' w/22.14" Sand Screen 3.5" Cameo "0" Nipple I 8501' wla 2 Plug Min 10 = 2.313" WLEG 8503' 7" float collar (PBTD) 8740' 7" float shoe 8868' MILNE POINT UNIT WELL L-03 API NO. 50-029-21999 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-03 MPL-03 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/27/2007 Rig Release: 5/2/2007 Rig Number: Spud Date: 2/1/1990 End: 5/2/2007 4/27/2007 00:00 - 12:00 12.00 RIGD N WAIT PRE Waiting on weather. Winds @ 40 mph. Limit for raising and lowering derrick of 25 mph. 12:00 - 00:00 12.00 RIGD N WAIT PRE Continue to wait on winds to abate. Wind @ 12:00 - 36 mph / wind @ 17:00 - 34 mph. Perform maintenance on clutch for Drawworks. Clean and maintain Rig. 4/28/2007 00:00 - 03:30 3.50 RIGD N WAIT PRE Continue to wait on windy conditions in order to proceed with RD operations off of MPL-28A. At 00:00 hrs, the wind reading is 29 mph. The limit for raising or lowering the Derrick is 25 mph. At 02:00 hrs, reading is 30 mph. 03:30 - 06:00 2.50 RIGD P PRE The wind reading @ 24 mph. Hold PJSM with WSL, Tourpusher and Crew. Lower the off-driller's side wind wall. Scope down the upper section of the Derrick. Prepare to lower the Derrick. Check the wind speed again, it is at 25 mph. Lower the Derrick down onto the Carrier. RD off of well slot MPL-28A. 06:00 - 09:30 3.50 RIGD N WAIT PRE Wait on Peak Trucks to move the rig. 09:30 - 14:00 4.50 MOB P PRE Begin to move rig from MPL-28 to MPL-03. 14:00 - 22:30 8.50 RIGU P PRE Spot BOPE behind wellhead. Place matting boards and herculite. Spot carrier. Spot and RU pit module, and pipe shed module. Raise and scope derrick. Continue rigging up. Finish RU of Handy Berm. Spot and RU Tiger Tank and hardline. Thaw out frozen steam lines. 22:30 - 00:00 1.50 RIGU P PRE Prepare the Cellar. RU lines to Tree. Accepted the Rig at 22:30 hrs on 4/28/2007. 4/29/2007 00:00 - 02:00 2.00 RIGU P PRE Continue RU lines to the Tree. Take on 140 degree F seawater into the Pits. Called AOGCC w/ notification of upcoming BOPE test. Left message. 02:00 - 03:00 1.00 WHSUR P DECOMP PU and MU Lubricator to the Tree with Well Support Techs. Pull the BPV. Tubing pressure = 800 psi. OA = 0 psi. 03:00 - 04:00 1.00 KILL P DECOMP PJSM. Pressure test hard line to the Tiger Tank to 500 psi - OK. Pressure test surface lines to 3,000 psi. The flange on the Wing Valve leaked. Re-tighten and re-pressure to 3,000 psi. Uni-bolt on Kill Line leaking. Re-tighten and re-pressure to 3,000 psi - OK. 04:00 - 08:00 4.00 KILL P DECOMP Pre-kill meeting with WSL, Tourpusher, Nabors Crew and Veco Truck Drivers. Open the well to a closed Choke. The Tubing pressure = 810 psi, the IA pressure = 770 psi. Bleed the IA to 40 psi in 15 mins. Break circulation with seawater at a rate of 4 bpm /310 psi. Got returns after 50 bbls away. Pumped a total of 70 bbls and shut in to bullhead. Tubing pressure = 10 psi, IA pressure = 110 psi. Bullhead 25 bbls of seawater at a rate of 4 bpm / 600 psi. Open up the IA and continue circulating the well with seawater taking returns to the Tiger Tank. Took 10 bbls to catch fluid. Circulating at a rate of 4 bpm / 650 psi. Pumped a total of 575 bbls. 08:00 - 09:30 1.50 WHSUR P DECOMP Check WHP's. Tbg /IA / OA /- 0 / 0 / 0 psi. Well on vacuum. Dry rod TWC and test from below pumping SW @ 4 BPM pressure to 500 psi, total of 35 Bbls bullheaded. Test from above to 3500 psi and chart both. Total SW pumped during kill of 610 Bbls with losses to formation of 240 Bbls. (includes 60 Bls bullheaded) 09:30 - 11 :00 1.50 WHSUR P DECOMP Nipple down tree. 278" Hanger lifting threads ok w/ 7 1/2 turns to MU. Notify AOGCC of upcoming BOPE test with Printed: 5/7/2007 11: 15:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-03 MPL-03 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/27/2007 Rig Release: 5/2/2007 Rig Number: Spud Date: 2/1/1990 End: 5/2/2007 message and no response. Gravity feed IA wI SW @ 15 Bls I Hr. DECOMP NU 135/8" x 11" DSA. NU 135/8" BOPE. ,/ DECOMP Jeff Jones wI AOGCC waived State witness of upcoming BOPE test. Continue to NU BOPE. DECOMP Function test BOPE. Pressure test BOPE @ 250 I 3500 psi. 3500 psi on annular. The Annular is leaking and not testing. Function it and change annular pressure several times with no improvement. Try to achieve a test with a second 2 7/8" Test Joint - No Joy. Drain the fluid out of the Stack and function the Annular to inspect it - the Annular is in pretty bad shape. Call NOC for another Element. Wait on arrival of new GK Annular Element. Finish blowing down and draining of Stack. Lay down Test Joint and RD Test Equipment. New Element arrives on location. Prepare for changing out of Annular. PJSM with WSL and Tourpusher. ND Riser and Air Boot. PU Potato Masher. PU 5" HWDP and MU to Potato Masher for removing Bonnet on the Hydril. Lay down Bonnet. Remove damaged GK Element and lay down. PU and replace with a new GK Element. RU Bonnet with the 5" HWDP and Potato Masher. NU Riser and Air Boot. DECOMP Cycle annular preventer to condition. PU test joint and install. Pressure test annular to 250 psi I 3500 psi. DECOMP MU 0 so-Lo so and screw into tubing hanger. MU 2" plug valve to OL. PU lubricator, polish rod, and pulling tool for TWC. Slight problem screwing into TWC. Engage TWC and pull. Tbg and IA on vacuum. Break out lubricator and TWC. 1 small piece of rubber from Hydril (- 3/4") wedged in threads of TWC with pulling tool. LD lubricator, BOLD OL. DECOMP PUMU 2 7/8" landing joint with TIW valve. Engage hanger with 8 turns. BOLDS. Pull hanger to floor with 65K #'s PU wt. Pump 15 Bbls SW into IA. Tbg IIA on vacuum. Cut cable. BOLD tubing hanger for Cameron to re-dress. DECOMP POH standing back 2 7/8" tubing in Derrick. Run ESP cable over shieve and connect to spooling unit. Continue POH double displacing with SW every 5 stands. 65 Stands OOH @ 16:00 hrs. Find 3 bent jts and 2 galled connections. 90 stands out of the hole at 20:00 hrs. 110 stands out of the hole at 22:00 hrs. Laid down a total of 8 bad Joints, 2 GLM Assemblies, and 1 XN Nipple Assembly. Stood back 130 stands of 2 7/8" Tubing in the Derrick. Recovered a total of 137 LaSalle Clamps. DECOMP On surface with the existing ESP Assembly. Begin breaking down and laying down existing ESP Assembly with Centrilift rep. Pump 20 bbls of seawater into the well every hour while breaking down the ESP. RUNCMP PU and MU new ESP Assembly with Centrilift rep. Load new Spool into Spooling Unit with Milne Loader. Continue pumping 20 bbls of seawater into the well each hour. RUNCMP Run ESP cable over Shieve and RIH wI new completion on tubing from Derrick. 100-stands in at 1600-hrs. 118-stands at 11 :00 - 12:00 12:00 - 15:00 15:00 - 22:00 22:00 - 23:30 1.50 BOPSU N RREP DECOMP 23:30 - 00:00 0.50 BOPSU N RREP DECOMP 4/30/2007 00:00 - 05:00 5.00 BOPSU N RREP DECOMP 05:00 - 06:30 1.50 BOPSU P 06:30 - 08:00 1.50 WHSUR P 08:00 - 09:30 1.50 PULL P 09:30 - 00:00 14.50 PULL P 5/1/2007 00:00 - 04:00 4.00 PULL P 04:00 - 09:00 5.00 RUNCO 09:00 - 17:00 8.00 RUNCO Printed: 5/7/2007 11:15:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-03 MPL-03 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/27/2007 Rig Release: 5/2/2007 Rig Number: Spud Date: 2/1/1990 End: 5/2/2007 10:30 - 12:30 2.00 DHB P POST 1730-hrs. Make ESP cable splice. Continue RIH with new ESP Assembly on 2 7/8" Tubing from the Derrick. MU TIW and Head Ppin, fill tubing and flush Pump with 10 bbls of seawater at a rate of 1 bpm I 410 psi. Ran a total of 139 LaSalle Clamps, 6 Protectolizers and 3 Flat Guards. PU and MU Tubing Hanger with Cameron rep. Verify orientation and alignment of Hanger with Cameron rep. Install shipping cap on Penetrator. Make Penetrator splice on ESP Cable with Centrilift rep. UW = 61 K , DW = 45K. Perform checks on ESP Cable with Centrilift rep. Phase to phase = 3.2 ohms and phase to ground = 1.26 Gigaohms. Land Tubing Hanger with Cameron rep. Hanger appeared to not be properly aligned since did not see it slide into the slot. Cameron rep instructs to turn to the left a couple of inches while slacking off. Did not see it slide into the slot again. Cameron rep functions a LDS to try and determine if we are down completely. Cameron rep instructs to PU on Hanger to see if it will slide out of slot and the Hanger jumped while PU. Decision made to bring the Hanger to the Floor to visually inspect. The two rubber seals on the Hanger have damage to them along with the Compression Ring. The Compression Ring has a LDS profile gouge and found the tip of 1 LDS on top of the Hanger. Need to re-dress the Hanger and repair the LDS. Perform a check on the ESP Cable and everything is okay with it. Break out and lay down Tubing Hanger. Load it onto the Cameron rep's truck. Wait on Cameron rep to re-dress the Hanger and PU another LDS at Tool Service. P/U MIU re-dressed Hanger to Landing Joint, RIH and orient hanger over guide pin with chain tongs. P/U weight, 65,OOO-lbs; SIO weight, 45,000-lbs. Set down, Cameron Tech screws in orientation screw and it seats at correct depth. Back it out a turn, then P/U slowly on Landing Joint and see Hanger slightly turn, indicating hanger is properly set. RI four LDS. Pull damaged LDS and gland nut. Look inside with flashlight and see that the Hanger is, indeed, set correctly. Install new LDS and Gland Nut. POH Landing Joint. RILDS. Cameron Rep P/U TWC with dry rod and install it in Hanger. Fill BOP Stack with seawater, close Blind Rams, and test topside to 1,OOO-psi for recorded 10-minutes; good test. RIU to test from below. Change out seal in Unibolt connection. Start pumping down IA at 2-1/2-BPM and 30-psi. Increase rate to 3-BPM and pressure climbs to 300-psi after 26-Bbls pumped; 350-psi at 30-Bbls away; 400-psi at 33-Bbls; 450-psi at 37-Bbls; 500-psi at 44-Bbls. Decide to stop pumping with 10-Bbls remaining in Pits. Check IA and well is on vacuum. N/D BOPE. N/U Adaptor Flange and Tree and make final ESP tests: Phase-to-Phase 3.2-0hms, balanced. Phase-to-Ground 5/2/2007 00:00 - 01 :00 TUBHGR 01 :00 - 03:30 RUNCMP 03:30 - 04:00 TUBHGR 04:00 - 05:00 1.00 RNTBH P TUBHGR 05:00 - 08:30 3.50 RNTBH SFAL TUBHGR 08:30 - 10:30 2.00 RNTBH P TUBHGR 12:30 - 14:00 14:00 - 18:00 1.50 BOPSU P 4.00 WHSUR P POST POST Printed: 51712007 11:15:59AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-03 MPL-03 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/27/2007 Rig Release: 5/2/2007 Rig Number: Spud Date: 2/1/1990 End: 5/2/2007 51212007 14:00 - 18:00 4.00 WHSUR P POST 1.09-Giga-Ohms. Motor Temp, 150.4-F. Intake Temp, 152.7-F. test to 5,000-psi. PT Tree to 5,OOO-psi and record. PU Lubricator with Well Support Techs and pull TWC. Set BPV with Lubricator. Rig released at 180Q-hrs on 51212007. Printed: 5m2007 11: 15:59 AM ¡r' STATE OF ALASKA { ALASKA .- IL AND GAS CONSERVATION COlvlN1ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 0 Suspend a Repair Well a Pull Tubing 0 Waiver a Other 0 Time Extension Change Out ESP 0 Annular Disposal 5. Permit To Drill Number 190-007 6. API Number: 50-029-21999-00-00 0 Operation Shutdown 0 Perforate 0 Plug Perforations 0 Stimulate 0 Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: a Development 0 Exploratory 0 Stratigraphic Test 0 Service 99519-6612 KBE = 55.0' 8. Property Designation: ADL 025509 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8900 7316 8780 7225 Casing Structural Conductor Surface Intermediate Production Liner Length 80' 2725' 8837' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size (size, grade, and measured depth): 9. Well Name and Number: MPL-03 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands feet feet Plugs (measured) NIA feet Junk (measured) NIA feet Size MD TVD 13-3/8", 48# 115' 115' 9-5/8", 36# 2758' 2494' 7",26# 8837' 7291' Burst Collapse 3520 2020 7240 5410 8508' - 8704' 7017' - 7067' RECE.\\!E.o jU~ () 9 ?S~\)tIç Pt~~a Oil & comrnissi\l\1 8374' 2-7/8",6.5# Packers and SSSV (type and measured depth): Baker Model '0' Packer Sand Screen with 31/2" tubing from 8468' - 8503' 8468' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casinq Pressure TubinQ Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run a Daily Report of Well Operations a Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory a Development 0 Service 16. Well Status after proposed work: a Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Ream, 564-5743 Printed Name Sondra Stewman Title Technical Assistant Fonn~~=~~~V~~~~._._~ ÓhR FGrÑÃr .' Prepared By Name/Number: Date ()((Ï" 08-v~.sondra Stewman, 564-4750 ( ( ( BP EXPLORATION Operations Summary Report Page 1 of 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-03 MPL-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/7/2004 Rig Release: 5/9/2004 Rig Number: 4ES Spud Date: 2/1/1990 End: 5/9/2004 Date From - To Hours Task Code NPT Phase Description of Operations 5/7/2004 06:00 - 19:30 13.50 MOB P PRE PJSM. Rig down off of MP K-13. Scope down & layover derrick. Move rig components to MP L-03. 10 mile move. 19:30 - 20:30 1.00 RIGU P PRE Spot in rig sub over MPL-03 wellhead. Spot in pits & pipe shed. Spot camp. & rig equip. 20:30 - 22:00 1.50 RIGU P PRE Con't to R/U equip. Raise & scope derrick. 22:00 - 23:30 1.50 RIGU P DECOMP Accepted rig @ 2200 hrs. Spot in tiger tank & lay lines to tank. R/U lines to tree & install HCR valve on annulus. Take on heated seawater. 23:30 - 00:00 0.50 WHSUR P DECOMP P/U lubricator & pull BPV. UD lubricator & plug. 5/8/2004 00:00 - 00:30 0.50 KILL P DECOMP Pressure test lines to 3500 psi. Ok. 00:30 - 01 :00 0.50 KILL P DECOMP Hold PJSM & Pre-Spud meeting. 01 :00 - 04:30 3.50 KILL P DECOMP Open well. SITP 770 psi. SlAP 860 psi. Circulate & kill well. Pump 4.5 BPM @ 530 psi. Had oil to surface after 60 Bbls. Pumped 90 bbls, SI & bullheaded 18 bbls in to well. 4 .5 BPM @ 430 psi. Open choke & con't to circulate. After 325 bbls still had oil. After 380 bbls had diesel to surface. After 470 bbls had seawater to surface. SID & circulate thru gas buster & into pits. Lost 18 bbls in 10 min while circulating @ 3 BPM. SID & monitor well. Well on vacuum. 04:30 - 05:00 0.50 KILL P DECOMP Blow down & RID kill lines. Install TWC. 05:00 - 07:30 2.50 WHSUR P DECOMP Bleed off hanger void. NID X-mas tree. Inspect threads on hanger, starting threads damaged. Order out Spear. 07:30 - 09:30 2.00 BOPSUP P DECOMP PJSM. N/U 13 5/8" x 5M BOPE. AOGCC State Rep Chuck Sheve waived wintessing BOPE test. 09:30 - 13:00 3.50 BOPSUR P DECOMP PJSM. Perform full test on BOPE, no failures. Pull two way check. 13:00 - 14:30 1.50 PULL P DECOMP PJSM. M/U spear assembly wI 2.443" grapple. Engage tubing below hanger. Verify IIA on vacuum. BOLDs. Pull hanger to floor. Broke over @ 92K, steady up weight = 83K. Lay down hanger. 14:30 - 16:00 1.50 PULL P DECOMP PJSM. Line up & circulate @ 3 bpm 1500 psi, pump 88 bbls before seeing returns. Pump 130 bbls till clean returns. Monitor well & rig up to pull ESP completion. 16:00 - 20:30 4.50 PULL P DECOMP PJSM. POOH w/2 7/8" ESP completion, double displacing on hole fill. Recovered 261 jts 2 7/8' tbg, "XN" Nipple assy, 2 GLM assys, 5 protectolizers, 3 Flat Clamps, 136 LaSalle Clamps & ESP. 20:30 - 21 :00 0.50 PULL P DECOMP Disconnect cable from ESP. Pull cable over sheave & spool up. Change out spools. 21 :00 - 22:00 1.00 PULL P DECOMP Break out & UD ESP. Inspect & test pump & motor. 22:00 - 22:30 0.50 PULL P DECOMP UD elephant hose & drain same. Unload ESP. Clear & clean rig floor. 22:30 - 00:00 1.50 PULL P DECOMP P/U assemble, service & test new ESP. 5/9/2004 00:00 - 00:30 0.50 RUNCOMP COMP Con't to P/U assemble, service & test ESP. 00:30 - 01 :00 0.50 RUNCOMP COMP Pull cable over sheave. Plug into ESP & test. 01 :00 - 05:30 4.50 RUNCOMP COMP RIH wI wI ESP on 2 7/8" tubing. Replaced 1 - 10' tbg pup & 10 LaSalle clamps. Ran 80 stands. Test ESP & pump thru pump every 2000'.1 BPM @ 1900 psi. 05:30 - 09:00 3.50 RUNCOMP COMP Change reels. Make reel to reel splice & test same, OK. Fill hole, 57 bbls. 09:00 - 09:30 0.50 RUNCOMP COMP Continue to RIH w/2 7/8" ESP completion. 77K up wt, 45K down wt. 09:30 - 12:00 2.50 RUNCOMP COMP PJSM. Make up tubing hanger & make field connection splice, Printed: 5/10/2004 9:21 :57 AM (' ( BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 5/9/2004 MPL-03 MPL-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To Hours Task Code NPT Phase 09:30 - 12:00 2.50 RUNCOMP COMP 12:00 - 13:00 1.00 RUNCOMP COMP 13:00 - 15:00 2.00 BOPSUP P COMP 15:00 - 19:00 4.00 WHSUR P COMP Page 2 of 2 Start: 5/7/2004 Rig Release: 5/9/2004 Rig Number: 4ES Spud Date: 2/1/1990 End: 5/9/2004 Description of Operations test same, OK. PJSM. Land tubing hanger, RILDs. Set two way check & test, OK. PJSM. N/D BOPE. PJSM. N/U adapter flange & tree. Test void & tree to 5000 psi, OK. Secure well. Rig released @ 19:00 hrs, 05/09/2004. Printed: 5/10/2004 9:21:57 AM Iœe.;. 2-9/16" - 5M FMC { Wellhead: 11" 5M FMC wI 2-7/8" WKM Tubing Hanger wI 3" Acme, 2.5" CIW H BPV profile MPU L-03 .. ~j,/ I,j Q..fL /3 '--1~ TL'H'F' 20" ~t1'ppf, H-40 1115' I ~ f7 ~ ~ ~ ~ ~ ~ ----, ;-) ~ ~ ~ ~ ~ ~ ~ I ~ 9-5/8" 40#/ft., L-80 BTRC. 12758' I ~ KOP @ 600' Max Hole Angle = 41 .35 deg, @ 4000' Hole angle through perfs. = 40 deg Max OLS = 5.68 deg @ 3256' MO 2-7/8" 6.5#/ft., L-80, 8 rd. EUE tbg. (Drift 10 = 2.347", cap. = 0.00587 bpf) 7" 26#/ft., L-80, BTRC, production csg., (drift ID = 6.151", cap. = 0.0383 bpf) Stimulation Summary Frac all zones w/147,022# 16/20 CL Perforation Summary Ref. Log L-03 OH Dll-SFL 2/13/90 Size SPF Interval (TVD) 4.5" 5 8508'-8552' 7016'-7050' 4.5" 5 8601 '-8627' 7087'-7107' 4.5" 5 8634'-8662' 7121'-7133' 4.5" 5 8674'-8704' 7143'-7166' "Perf. w/4.5", 5spf @ 72 deg. phasing" ~I~[)- '" DATE REV. BY COMMENTS 5/94 M. Linder RWO 7/96 D. Hildreth ESP RWO Polar #1 . 2/21/99 MOO ESP RWO Scalecapr.~ Nabors 4ES 12/30/00 GMH ESP RWO Nabors 4ES 05/10104 JRC ESP RWO Nabors 4ES ..- t~ , ~':~I~ '~"¡I~ f ,g. RT Elev. = 55.0' (N##E) Orig. Gl Elev. = 22.85' RT to Csg Spool = 32.15' (N##E) ~ Cameo 2-7/8" x 1" l KBMM GlM 165' ~ Cameo 2-7/8" x 1" I 8157' I KBMM GlM HES 2-7/8" 8rd. I 8296' I "XN" Profile Nipple (10 2.205"). Pump, 151 stg. GC1700, I 8315' I Model- GPMTAR 1:1 Tandem Gas Separator 18332' I Model - GRSTXARH6 Intake (TVD) I 6886' I Tandem Seal Section I 8338' I Motor, 190 HP, 2415 volt, I 8351' I 48 amp, Model KMH Pheonix MS-01 Sensor I 8368' I PHO w/6 fin Centralizer I 8372 I Baker Model "0" Packer I 8468' w/22.14" Sand Screen 3.5" Cameo liD" Nipple I ' w/a 2 Plug Min 10 = 2.313" 8501 WLEG I 8503' 7" float collar (PBTO) 1- 874°t31&'/ I I 8868' I 7" float shoe MILNE POINT UNIT WELL L-03 API NO. 50-029-21999 BP EXPLORATION (AK) 'I ~ .~~"' STATE OF ALASKA ALASKA ~lL AND GAS CONSERVATION COMM, ..ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. TyPe of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE - 55' AMSL [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service "~. Location of well at surface 8. Well Number 3259' NSL, 5090' WEL, SEC. 08, T13N, R10E, UM ~ {%~ ~, ~ .... ~i",:~ ~'~ ...... ~'~;~ MPL-03 At top of productive interval i~, ~'~' ~¢ ~ ! '~/~ i~..~ 9. Permit Number / Approval No. 190-007 453' SNL, 3867' WEL, SEC. 07, T13N, R10E, UM 10. APl Number At effective depth ~' L~ ~ 0 9 ~ 0 0 1 50-029-21999 359' SNL, 4135' WEL, SEC. 07, T13N, R10E, UM 11. Field and Pool At total depth Alaska ()il & Gas Cons. Commis,:ior'; Milne Point Unit / Kuparuk River 333' SNL, 4208' WEL, SEC. 07, T13N, R10E, UM Anchorace Sands i'2. 'Pre'sent well condition summary .... Total depth: measured 8900 feet Plugs (measured) true vertical 7316 feet Effective depth: measured 8780 feet Junk (measured) true vertical 7225 feet Casing Length Size Cemented MD TVD Structural Conductor 80 20" 500 sx Permafrost 'C' to Surface 80' 80' Surface 2725' 9-5/8" 277 Bbls PF 'E', 84 Bbls Class 'G' 2758' 2494' Intermediate Production 8837' 7" 138 Bbls Class 'G' 8868' 7291' Liner Perforation depth: measured 8508' - 8552', 8601' - 8627', 8634' - 8662', 8674' - 8704' truevertical 7017'-7066', 7088'-7108', 7114',-7135', 7144'-7167' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE to 8367'; 3-1/2" tubing 8468' - 8503' Packers and SSSV (type and measured depth) Baker Model 'D' packer at 8468' with Sand Screen 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ":14. Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~r~~¢) ~~ Title Technical Assistant Date Prepared By Name/Number: Terrie Hubble, 564-4628 r" -- -~ .4 ,,~ ,~ ,.~ ,~ r"~ _ _ _ ,.., f~ ~ .= ~ ,.., ~, ........ Form 10-404 Rev. 06/15/88 Submit In Duplicate Legal Well Name: MPL-03 Common Well Name: MPL-03 Spud Date: 2/1/1990 Event Name: WORKOVER Start: 12/23/2000 End: 12/30/2000 Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 4ES Rig Number: 4ES Date From~ Hours ~ask ~:: '.~,~ ~hase : ~ ~ DeScription of Operations 12/28/2000 02:30 - 06:00 3.50 MOB PRE MOVE FROM E-10 TO L-3. 06:00 - 07:30 1.50 MOB PRE SPOT & BERM RIG. 07:30 - 09:00 1.50 MOB PRE ~ISE & SCOPE DERRICK. RIG UP TIGER TANK & HARD LINES.ACCEPTED RIG ~ 0900 HRS. 12-28-00. 09:00 - 10:00 1.00 WHSUR DECOMP R/U & PULL BPV. TAKE ON SEAWATER FOR KILLING OPS. 10:00 - 11:30 1.50 WHSUR DECOMP ~U HARD LINES & HCR VALVE TO X-MAS TREE. 11:30 - 12:30 1.00 KILL DECOMP PRESSURE TEST LINES TO 2500 PSI, 12:30 - 15:30 3.00 KILL DECOMP OPEN WELL, SlTP 160 PSI, SlCP 350 PSI. KILL WELL ~ 3 BPM 800 PSI. WELL DEAD & ON VACUM. 15:30 - 16:00 0.50 WHSUR DECOMP INSTALL ~C VALVE & TEST TO 3500 PSI, OK. 16:00 - 17:30 1.50 WHSUR DECOMP N/D X-MAS TREE. 17:30 - 21:30 4.00 BOPSUF DECOMP N/U BOPE. 21:30 - 22:00 0.50 BOPSUF DECOMP ~U TEST EQUIP. HOLD PRE JOB MTG W/AOGCC REP. 22:00 - 00:00 2.00 BOPSUF DECOMP PRESSURE TEST BOPE, LP 250 PSI, HP 3500 PSI. TEST WITNESSED BY JEFF JONES W/AOGCC. 12/29/2000 00:00 - 02:00 2.00 BOPSUF DECOMP FINISH TESTING BOPE. LP 250 PSI, HP 3500 PSI. 02:00 - 04:00 2.00 PULL DECOMP PULL ~C. MAKE UP ~NDING JT. PUMP 75 BBLS SEA WATER & SHOOT FLUID LEVEL (+/- 1950') MONITOR WELL. 04:00 - 04:30 0.50 WHSUR DECOMP BOLDS & PULL TBG HANGER (73K) 04:30 - 05:00 0.50 PULL DECOMP MD TBG HANGER & TEST ESP CABLE. 05:00 - 14:00 9.00 PULL DECOMP POOH W/2 7/8" COMPLETION. 14:00 - 15:30 1.50 PULL DECOMP MD ESP. 15:30 - 16:30 1.00 PULL DECOMP MD TP & SCREEN ASSY. 16:30 - 17:30 1.00 CLEAN DECOMP CLEAR FLOOR & PREPARE TO P/U ESP. 17:30 - 19:30 2.00 RUNCO~ COMP M/U & SERVICE ESP. ~U CABLE ON SHEAVE. 19:30 - 20:30 1.00 RUNCO~ COMP CHANGE OUT ~ VALVE ON CHOKE MANIFOLD. 20:30 - 00:00 3.50 RUNCO~ COMP RIH W/2 7/8" COMPLETION STRING. 12/30/2000 00:00 - 03:30 3.50 RUNCO~ COMP CHANGE SPOOL & MAKE CABLE SPLICE ~ 7150'. 03:30 - 04:00 0.50 RUNCO~ COMP FINISH RUNNING 2 7/8" COMPLETION STRING. 04:00 - 04:30 0.50 RUNCO~ COMP M/U ~NDING JT & SPACE OUT. 04:30 - 06:30 2.00 RUNCO~ COMP MAKE EFT SPLICE & TEST SAME. 06:30 - 07:00 0.50 RUNCO~ COMP ~ND COMPLETION ~ 8367'. RILDS. 07:00 - 08:00 1.00 WHSUR COMP SET ~C VALVE & D~IN UP STACK. 08:00 - 10:00 2.00 BOPSUF COMP N/D BOPE. 10:00 - 12:00 2.00 WHSUR COMP CHANGE OUT ADAPTER F~NGE & N/U X-MAS TREE. 12:00 - 13:00 1.00 WHSUR COMP PRESSURE TEST X-MAS TREE & HANGER TO 5000 PSI, OK. 13:00 - 13:30 0.50 WHSUR COMP PULL ~C & INSTALL BPV. 13:30 - 14:00 0.50 WHSUR COMP FINAL CHECK ON ESP, OK. SECURE WELL & CLEAN CEL~R. RELEASE RIG ~ 1400 HRS, 12-30-00. Alaska Oil & O3s Anchorage Printed: 1/26/2001 4:24:27PM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED I ON OR BEFORE OCTOBER 27, 20.00 E P M C:LORIhMFILM.~ L E W ATERIAL U N D E THIS M ARK ER R STATE OF ALASKA ALASKA C._ AND GAS CONSERVATION COM,v, iSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [--] Operation Shutdown [~ Pull Tubing 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2021' SNL, 190' EWL, SEC. 08, T13N, R10E, UM At top of productive interval 450' SNL, 3991' WEL, SEC. 07, T13N, R10E, UM At effective depth 359' SNL, 4135' WEL, SEC. 07, T13N, R10E, UM At total depth 361' SNL, 4224' WEL, SEC. 07, T13N, R10E, UM [~ Stratigraphic [] Service Stimulate [--] Plugging [-] Perforate Alter Casing [] Repair Well [] Other Change Out ESP I 5. Type of well: 6. Datum Elevation (DF or KB) [~ Development KBE = 55' AMSL [--] Exploratory 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-03 9. Permit Number / Approval No. 90-07 10. APl Number 50-029-21999 1. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 8900 feet true vertical 7321 feet Effective depth: measured 8780 feet true vertical 7225 feet Casing Plugs (measured) Junk (measured) Length Size Cemented M D Structural Conductor 115' 20" Cement to surface 115' Surface 2758' 9-5/8" 227 Bbls Class 'E', 84 Bbls Class 'G' 2758' Intermediate Production 8868' 7" 138 Bbls Class 'G' 8868' Liner TVD 115' 2494' 7291' Perforation depth: measured 8508' - 8572', 8601' - 8627', 8634' - 8662', 8674' - 8704' true vertical 7017'-7066', 7088'-7108', 7114',-7135', 7144'-7167' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE tubing to 8423'; 3-1/2" tubing from 8468' - 8503' Packers and SSSV (type and measured depth) Baker Model 'D' packer at 8468' with Sand Screen 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 5. Attachments r-~ copies of Logs and Surveys run [~ Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 7. I hereby certify that the f. gregoing is true and correct to the best of my knowledge Signed TerrieHubble ¢~/1¢/(J~'"¢/~' ~ Title Technical Assistant III Date 0~2-0¢~¢¢ ~ Submit In Duplicate~'~..~ Form 10-404 Rev. 06/15/88 Progress Report Facility M Pt L Pad Well MPL-03 Page 1 Rig Nabors 4ES Date 08 March 99 Date/Time 15 Feb 99 16 Feb 99 17 Feb 99 22:00-05:00 05:00-06:00 06:00-08:00 08:00-11:00 11:00-12:30 12:30-14:00 14:00-17:00 17:00-19:00 19:00-02:00 02:00-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-09:00 09:00-15:30 15:30-19:00 19:00-20:30 20:30-22:30 22:30-00:00 Duration 7hr 1 hr 2 hr 3 hr 1-1/2 hr 1-1/2 hr 3hr 2hr 7hr lhr 2 hr 1 hr 1/2 hr 2-1/2 hr 6-1/2 hr 3-1/2 hr 1-1/2 hr 2 hr 1-1/2 hr Activity Rig moved 100.00 % Retrieved Hanger plug Rigged up High pressure lines Circulated closed in well at 8371.0 ft Removed Xmas tree Installed BOP stack Tested BOP stack Removed Tubing hanger Pulled Tubing in stands to 8430.0 ft Retrieved ESP Rigged up sub-surface equipment - Other sub-surface equipment Installed ESP Held safety meeting Installed ESP Ran Tubing in stands to 8423.0 ft Installed Tubing hanger Removed BOP stack Installed Xmas tree Freeze protect well - 12.000 bbl of Diesel STATE OF ALASKA AL~,.,, ;A OIL AND GAS CONSERVATION COMMIS$,~i~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing x Alter casing Repair well Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2021'SNL, 190' EWL, SEC. 8, T13N, RIOE At top of productive interval 450' SNL, 3991' WEL, SEC. 7, T13N, RIOE At effective depth 450' SNL, 3991' WEL, SEC. 7, T13N, RIOE At total depth 361' SNL, 4224' WEL, SEC. 7, T13N, RIOE 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55' feet 7. Unit or Property name Mi/ne Point Unit 8. Well number MPL -3 9. Permit number/approval number 90-07/94-058 10. APl number 50- 029-21999 11. Field/Pool kuparuk River Pool 8900 feet Plugs (measured) 7321 feet Effective depth: measured true vertical 8780 feet Junk (measured) 7222 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth True vertical depth true vertical Tubing (size, grade, and measured depth) 2-7/8", 6.5t/, L-80 tubing to 8422' MD Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Model D packer @ 8468' MD; Otis "DHR" packer @ 589' MD; Otis "FMX" TRSV SSS V @ 569' K/:LI:I V i'U MAY 2 4 1994 /~,isska 0il & Gas Cons. Commission Reoresentative Daily Average Production or Injection Da, t~ '""~"'u~l~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report/of Well Operations x Oil x Gas Suspended 17. I hereby ce/~i~/-tha~t ~e,/oregoi~ is true and correct to the best of my knowledge. Signed ,~/~;~~~'~M/7' / .~f/_ ." ~/~5" Title Drilling EngineerSupervisor Form 10-404 Rev 06/15/88 Service Date ~'~'.~/'~" SUBMIT IN DUPLICATe_ ~ MPU L-3 W/O #1 04/09/94 WAIT ON TRUCKS AND HEAVY EQUIPMENT TO FINISH 18E RIG MOVE. REBUILD BOP STACK WITH 2 NEW RAMS W/14" OPERATORS FOR BLIND///SHEAR RAMS AND VBR'S. COMPLETE INSTALLATION OF DRY HOLE TREE ON NO POINT #1. TEST PACKOFF SEALS ON 7" HANGER - OK. FUNCTION TEST AND CHECK HYDRAULIC MOVING SYSTEM FOR LEAKS PRIOR TO RIG MOVE. 04/10/94 8,868' CONT. WAITING FOR HEAVY EQUIPMENT FOR RIG MOVE FROM 18E. PREP FOR MOVE - CLEAR CELLAR OF EXCESS EQUIPMENT LAY HERCULITE. GENERAL PAD CLEANUP. PLUMB FIREWATER LINES IN PITS AND PUMP ROOM. BLOW DOWN LINES. UNHOOK POWER CABLES BETWEEN MODULES. MOVE PIPE SHED, MOTOR COMPLEX AND PITS TO L-PAD. PULL SUB AND MAST AWAY FROM HOLE. 04/11/94 8,868' ACCEPTED RIG @ 1800 HR'S ON 04/10/94. MOVE SUB AND DERRICK TO L- PAD. SPOT COMPLEXES. HOOK UP AIR, STEAM, WATER. TAKE ON SOURCE WATER. HOOK UP FILTER UNIT. FILTER SOURCE WATER. R/U LUBRICATOR. PULL BPV. R/U TO PUMP DOWN TBG. BULLHEAD 60 BBL WATER 2.5 BPM 1550 PSI FOLLOWED BY 12 BBL DIESEL. MONITOR WELL. NO PRESSURE, NO FLOW. INSTALL BPV. N/D XMAS TREE. 04/12/94 8,868' N/U X/O FLANGE AND CAP CONTROL LINE. N/U BOPE. INSTALL LANDING JOINT. TEST BOP'S AND CHOKE MANIFOLD. P/U T-BAR AND PULL TWC AFTER ALLOWING PRESSURE TO BLEED OFF. N/U RISER AND FLOW LINE. CENTER RIG OVER HOLE. CLOSE BLINDS AND BULLHEAD 60 BBL WATER + 12 BBL DIESEL DOWN TUBING TO STOP GAS MIG'N. INSTALL L/JT HOOK UP, KILL LINE TO ANNULUS AND SHEAR ANNULAR VENT VALVE. THAW OUT FROZEN CHOKE LINE. UNSEAT HGR WITH 200K AND P/U 3'. CIR AND KILL WELL AT 2 BPM. RETURNS through GAS BUSTER. CIRC OUT DIESEL, THEN CRUDE - VERY LITTLE GAS. 04/13/94 8,868' CONT. CIRC THROUGH CHOKE. KILL FLUID TO SURFACE. SHUT IN AND OBSERVE WELL. CIR ON CIR'N THROUGH CHOKE. OPEN WELL UP. GAS BREAKOUT AT FLOW LINE. CIRC WELL @ 5 BPM - NO PIT GAIN BUT SOME GAS BREAKING OUT@ SURFACE. CONT. ClRO@5BPM. MIXAND_P.U. IVJP_ RECE IVEL) MAY 2 4 1994 Ai~,ska Oil & Gas Cons. Commission Anchorage 25 BBL HEC SWEEP AROUND TO CLEAR OIL AND GAS FROM WELL. INCR. IN GAS BREAKOUT + OIL BUT NO PIT GAIN. RESEARCH BHP DATA FOR WELL. RECENT BHP SURVEY DATA ARE SUSPECT. ALSO, NEARBY W/I WELL IS STILL ON LINE. ClRC 8.5 PPG KILL FLUID TO TBG. SOME OIL AND GAS @ SURFACE. KILL FLUID NOW HEAVILY CONTAMINATED WITH CRUDE. CIRC THROUGH CHOKE. SHUT WELL IN WITH 200 PSI ON CSG. WAIT ON ADDITIONAL NACL, VAC TRUCKS TO CLEAN PITS OF CONTAMINATED FLUIDS AND BRING IN FRESH SOURCE WATER. WEIGHT UP NEW SOURCE WATER TO 8.8 PPG. OPEN CHOKE AND ClRC 8.8 PPG BRINE TO KILL WELL. 04/14/94 8,868' CONT. CIRC WELL TO 8.8 PPG BRINE @ 2 BPM TO KILL WELL. CLOSE IN WEIGHT 8.8 AROUND. PUMP ONE FULL CIRC THROUGH CHOKE - NO GAS. SI WELL AND MONITOR CSG PRESSURE. CIRC 9.3 PPG BRINE TO WELLBORE @ 3 BPM. CLOSE CHOKE. OPEN ANNULAR, FLOW CHECK - NO LOSS/GAIN. CIRC WELL AT 3 BPM AND RAISE BRINE WT TO 9.5+ PPG. MONITOR WELLBORE - FLUID LEVEL DROPPING. TRIP MARGIN. R/U TO PULL TUBING. PULL HANGER TO FLOOR. L/D LANDING JOINT, ESP CABLE WAS PARTED JUST BELOW HANGER. CHECK CABLE WITH METER - FURTHER DAMAGE INDICATED DOWNHOLE. L/D HANGER. POH TO SSSV LAYING OUT CABLE ON GROUND. L/D SSSV. CONT. POH SPOOLING ESP CABLE ONTO EWS SPOOLING UNIT. 74 STANDS OUT. 04/15/94 8,868' CONT. POH WITH TBG AND RACK BACK IN DERRICK. INSPECT AND LAY DOWN PUMP AND MOTOR ASSEMBLY. CHG. TOP RAMS TO 7". TEST DOOR SEALS. TEST LPR'S. INSTALL WEAR RING. R/U ATLAS W! SHOOTING NIPPLE INTO RAMS. RUN #1 GR/CCL - STOPPED AT 8684' WLM OKB. RUN #2 - GAUGE RING/JB TO 20' ABOVE TOP PERF. R/D ATLAS. CHG. TOP RAMS TO 2 7/8" TBG OPEN ENDED. REV. CIRC AND WASH DOWN 8688-8725'. TAG FILL- WASH DOWN TO 8735'. REV CIRC. S/D CIRC - ONLY 250 BBL FLUID LEFT AND MILNE PROD CANNOT SUPPLY SOURCE WATER. MONITOR WELL. FM CHARGED UP. POH W/TBG - PREP FOR WIRELINE. 04/16/94 8,868' POH WITH 2 7/8" WORK STRING. PULL WEAR RING. RUN TEST PLUG. CHG. TOP RAMS TO 7" AND TEST. PULL TEST PLUG. INSTALL WEAR RING. R/U ATLAS. PUT SHOOTING NIPPLE IN TOP RAM. RUN GAUGE RING/JUNK BASKET TO 20' ABOVE PERFS - OK. POH. NO JUNK OR SAND. P/U 3 1/2" TAILPIPE, GRAVEL PACK SCREEN AND MOD D PACKER. RIH, TIE IN AND SET PKR AT 8468' WLM. POH. R/D ATLAS. CHG. TOP RAMS TO 2 7/8" PULL WEAR RING, RUN TEST PLUG AND TEST DOORS. OK. PULL TEST PLUG. R/U FLOOR FOR COMPLETION. P/U MOTOR, SEAL SECTION AND PUMP. PERFORM PRE INSTALLATION CHECKS, A'I-I-ACH POWER RECEIVED MAY 2 4 ]994 Aiaska 0il & Gas Cons. Commission Anchorage CABLE AND STRAP TO SIDE OF HOUSING. RIH WITH 2 STEEL BANDS PER JOINT. 110 JTS IN HOLE. 04/17/94 8,868' CONT. RUNNING 2 7/8" TUBING AND ESP POWER CABLE. L/D 3 JTS TBG ON STDS 51 & 52. WOULD NOT DRIFT. ELECTRICAL CHECK FOR CABLE INTEGRITY EVERY 1000' WHILE RIH. L/D 2 BAD JTS ON STDS 71 & 78. P/U GLM AND PACKER. SPLICE ESP CABLE BELOW PACKER AND ATTACH PIGTAIL. P/U TRSV. HOOK UP CONTROL LINE AND TEST. CONT. RIH WITH TUBING ESP CABLE AND CONTROL LINE. SPACE OUT WITH PUP JOINTS TO MAKE TUBING STRING FIT PRE CUT CABLE LENGTH ABOVE PACKER. M/U TBG HANGER AND TIE IN CABLE THROUGH PENETRATOR. LAND TUBING. RUN IN LOCK DOWN SCREWS AND TEST HANGER SEAL. CLEAR FLOOR. R/U TO REV CIRC. HOOK UP HOT OIL TRUCK TO ANNULUS. BULLHEAD 12 BBL DIESEL DOWN TUBING. BLEED OFF CTRL LINE PRESSURE AND CHK TRSV - OK. RE-PRESSURE CONTROL LINE, DROP SETTING BALL AND ALLOW TO FALL TO RHC PLUG IN X NIPPLE BELOW PACKER. 04/18/94 8,868' PRESSURE TBG AND SET PACKER. TEST ANNULUS. BACK OUT LANDING JOINT. INSTALL TWC. N/D BOPE. HOOK UP CONTROL LINE. N/U TREE AND TEST ADAPTER. RE-TIGHTEN LOCK DOWN SCREW AND TEST TREE. R/U LUBRICATOR AND PULL TWC. INSTALL BPV. RELEASE RIG @1600 HR'S ON 04/17/94. RECEIVED MAY 2 4 1994 AJ~ska Oil & Gas Cons. Commission Anchorage BP EXPLORATION DATE: 04/28/94 T# 85649 BP/MILNE POINT CASED HOLE LOGS BP/MILNE POINT OPEN HOLE LOGS .EnClosed'~s the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4424. .. OPEN :~OLE LOGS: NOPoINT-i~/MWD:DPR/GR 3/18-04/03/94 1-5 104-14465 BAKER 2/5"MD NOPOINT-1/MWD:DEN-NEU PORO/GR 3/18-04/03/94 1-5 104-14465 BAKER 2/5"MD ~I-NOPOINT~I/MWD:DEN-NEU PORO/DpR/GR 3/18-04/03/94 1-5 104-14465 BAKER 2/5"MD .NOpOiNT_-i~MWD :BULK DENSITY/GR 3/18-04/03/94 1-5 104-14465 BAKER 5 "MD N6'~OIN~-i~MWD:DPR/GR 3/18-04/03/94 1-5. 120- 7150 BAKER 2/5"TVD NOPOINT'I~MWD:DEN-NEU PORO/GR 3/18-04/03/94 1-5 120- 7150 BAKER 2/5"TVD NOPOINT-i~MWD:DEN-NEU PORO/DPR/GR 3/18-04/03/94 1-5 120- 7150 BAKER 2/5"TVD CASED HOLE LOGS' E-03 ~PFC 04/19/94 #1 10600-11206 ATLAS 5 " L-03 ~'GR 04/14/94 #1 8250- 8683 ATLAS 5 " ?0°U~MPL-03 04/14/94 #1 8270- 8477 ATLAS 5 ~/PFC MPL-03 ~PFC 04/15/94 #1 8258- 8492 ATLAS 5 " ~"---------N---OPOINT-1 ~SBL 04/07/94 #1 12553-14354 ATLAS 5 " NOPOINT-1 ~, 04/07/94 #1 -- 0- 358 ATLAS Please sign and return one c6py~f this transmittal. Thank-you, SonYa Wallace Petrotechnical Data Center OH/CH LOGS MAGTAPE S Milne Point Milne Point Milne Point OXY OXY OXY AOGCC AOGCC ' ~'1~,A STATE REPORTS D ~aE CT IONi~, Milne Point OXY Greatland MEMORANDU v TO: THRU: FROM: P. I. Supervisor"~ Bobby Fost~~ Petroleum Ins[3ector State or-Alaska Alaska Oil and Gas Conservation Commission DATE: April 11, 1994 FILE NO: SUBJECT: AWOIDKBD.doc BOPE Test - Nabors 22E BPX - MPU - L-3 Milne Point Field qO Monday, April 10, 1994: I traveled to BPX's Milne Point Unit well L-3 this date to witness the upcoming BOPE test on Nabors Rig 22E.. As the attached AOGCC BOPE Test Report shows there were no failures. The lower pipe rams could not be tested due to a offset tubing hanger. There was a danger of closing the lower rams because of the short distance between the hanger and the variable bore rams which could cause the landing joint to be bent or the tubing hanger threads to be damaged. I requested Kick Maskell, BPX rep., to have the rams tested when the tubing was out of the hole. The location was clean and the extra drilling tools were stored as to give access to all areas of the rig. The rig was clean and seemed to be in good working order. Summa,ry: I witnessed the BOPE test on BPX's MPU well L-3 - test time 3.5 hours - no failures. Attachment: AWOIDKBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg:-:- .. Workover: Drlg Contractor:·: ,Nabors Drillin~ Rig No, , .... Operator:-~ ...... . .BP Exploration,, .... Well Name: MPU L-3 Casing Size: 7" Set ~;~ , 8, 868 Test: Initial X Weekly ........ 22E PTD # 90-07 Rep.: DATE: 4/11/94 Rig Ph.# 659-6475 / 6476 Dick Meskell Rig Rep.: Location: Sec. 8 T. ,, Brien Busby 13N R. 10E Meridian ~ , , Umiat Test ~llSC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F Location Gen.: OK Well Sign OK Upper Kelly / IBOP I ~ 300/5,000 I P Housekeeping: ~ (Gen) DH. Rig '~K~'~ Lower Kelly / tBOP Reserve Pit N/_.A~ ' Ball Type Inside BOP ,. Test Pressure 300/5,000 P/F P P P CHOKE MANIFOLD: No. Valves 17 ,,! No. Flanges 42 ! Manual Chokes 2' Hydraulic Chokes Test Pressure P/F ~10 T TES TED 3oo/ o , ,oo/5,ooo ,! ' ' 3oo ,,ooo !, ' I "' BOP STACK: Quan. Annular Preventer 1 Pipe Rams - 1" Pipe Rams 1 ' Blind Rams 1 Choke Ln. Valves -"1 ' HCR Valves "2' Kill Line Valves 1 Check Valve MUD SYSTEM: Visual Alarm Trip Tank OK None ~it Level Indicators OK OK Flow Indicator '~K ' OK' Gas Detectors '" OK" OK Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 3,100 ~ P Pressure After Closure 'J ,','i" ','1450', ',I, P' 200 psi Attained After Closure minutes 20 sec. System Pressure Attained ' "~" minutes ' 4- sec. Blind Switch Covers: Master. 'Yes Rem0{e:'" Yes Nitgn. Btl's: 4 ~ 2, 000 ...... 4~ 1~50 ..... Psig. Number of Failures: .. 0_ ,Test Time:, 3.,50' Hours. Number of valves tested 2,,5, Repair or Replacement of Failed Equipment will be made within N la days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I I III ill I IIII II I J I IJ I I III I I I . I I . II I I. . I II REMARKS: The lower pipe rams,co,,uld not ,be teste, d d,u, .e.to a offs.et tubin, 9 .h,an~ler- will be tested with tubing out,of hole Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector il i . I I.II I rll III I ! YES .... ,X,, . NO . '! i 24HOUR NOTICE GtVENji YES X NO Waived By: Witnessed By: BOBBY D. FOSTER FI-O21L (Rev, 2/93) AWOIDKBD.XLS BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 25, 1994 David W. Johnston AOGCC 3001 Porcupine Dr. Anchorage, Alaska 99501-3192 Dear Mr. Johnston: BP Exploration requests approval (Form 403 attached) to pull the failed ESP and rerun new ESP equipment in Milne Point Unit well L-3 to restore production of approximately 1,300 BOPD. The replacement ESP will be run on 2-7/8" coiled tubing. This will be the first coiled tubing ESP completion performed at MPU. If successful, it is planned to deploy all ESPs on coiled tubing in the future, with the intent being to reduce down-time and operating costs; thus, extending the economic life of the wells. Based on the current rig schedule, this work will commence on April 27, 1994 and finish on May 15, 1994. If you have questions regarding this proposal, please contact Steve Rossberg, Lead Production Engineer, at 564-7637. Bruce J. Policky Exploitation Manager cc: RSR, DW, FWG, L-7 Well File RECEIVED MAR -2 1994 Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS~JN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate Change approved program __ Pull tubing x Variance __ Perforate __ Other __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service 4. Location of well at surface 190' FWL, 2021' FNL, SECTION 8, T13N, RIOE, UM At top of productive interval 3991' FEL, 450' FNL, SECTION 7, T13N, RIOE, UM At effective depth 3991'FEL, 450'FNL, SECTION7, T13N, RIOE, UM At total depth 4224' FEL, 361' FNL, SECTION 7, T13N, RIOE, UM RECEIVED MAR -2 1994 Alaska 0ii & Gas Cons. Commission Anchorage 6. Datum elevation (DF or KB) 55' KB feet 7. Unit or Property name Milne Point Unit 8. Well number L-3 9. Permit number 90-07 10. APl number 50- 029-21999 11. Field/Pool Kuparuk River Pool 12. Present well condition summary Total depth: measured 8900 feet Plugs (measured) true vertical 7321 feet Effective depth: measured 8780 feet Junk (measured) true vertical 7222 feet Casing Length Size Cemented Measured cl~D~ Structural Conductor 80' 13-3/8" To Surface 80' Surface 2758 9-5/8" 227bbl. E &84 bbl G 2758' Intermediate Production 8868' 7" 138 bbL Class G 8868' Liner Perforation depth: measured 8508-8572', 8601-8627', 8634-8662', 8674-8704' True vertical depth BKB 80' 2500' true vertical 7020'-7070', 7092'-7112', 7117'-7139', 7148'-7171' Tubing (size, grade, and measured depth) 2-7/8", L-80, at 8,438', Bottom of ESP at 8481' Packers and SSSV (type and measured depth) Otis ,RDH ,ESP Packer at 568'. Otis, Series 10, FMX TRSV at547' 13. Attachments Description summary of proposal × Detailed operations program __ Pull failed ESPand rerun new pumping equipment to restore production. BOP sketch 14. Estimated date for commencing operation April27, 1994 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .//~ ..~~~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so rep/resentative may witness Plug integrity BOP Test / Location clearance__ Mechanical Integrity Test __ Subsequent form required 10- HO ~ Date 2/24/94 I Approval No- ~,¢.._{~)~ Approved by order of the Commission Original Signed By David W. Johnston Form 10-403 Rev 06/15/88 Commissioner ~pprovea L;opy Returned Date SUBMIT IN TRIPLICATE MILNE POINT UNIT WELL L-3 ESP REPLACEMENT PROCEDURE February 24, 1993 1. Install BPV. MIRU drilling rig. 2. Shear open annular vent valve by pressuring up on the 2-7/8" tubing by 7" casing annulus to 3500 psig with the valve closed. 3. Kill well by circulating hole full with 10.2 ppg NaBr/NaCI brine. Spot salt-based LCM pills, if necessary. 4. ND tree. NU BOPs. Pull BPV. Install two-way check. Pressure test BOP equipment. 5. MU landing joint to tubing hanger. PU 20,000 to 30,000 lbs. above pipe weight to release Otis RDH packer located at 533'. 6. POOH with 2-7/8" tubing and ESP. Lay down ESP." 7. TIH with bit and casing scraper to PBTD to confirm perf interval is clear of fill. POOH. 8. Install 11", false bowl assembly in tubing spool. Install 6-13/16" tubing hanger with BPV in the false bowl. Install packing and BPV. Install lock - down flange and 5,000 psig valve. RD and move off drilling rig. 9. Move in and rig up coiled tubing unit. NU BOPs. Pull BPV and install two-way check. Pressure test BOPs and pull two-way check. 10. MU ESP assembly and TIH on 2-7/8" coiled tubing. 11. MU Otis DHR packer with a mandrel and valve located below the packer to allow gas back into the tubing. Install an Otis X nipple between the packer and mandrel. Install a 2-7/8" tubing retrievable SCSSV in the production tubing above the packer and space out to place the SCSSV at least 500' below ground level. 12. Cut and land coiled tubing in tubing hanger. Freeze protect annulus. 13. RU wireline and set a plug in the X nipple located below the production packer. Pressure up against the plug to approximately 3,000 psig to set the packer. POOH with plug and rig down wireline. 14. Pressure test packer by pressuring up on the annulus to 500 psig. 15. Freeze protect tubing. Install BPV. Close SCSSV. ND BOPs. NU tree. Pull BPV. Install two-way check and test tree. Pull two-way check. Install BPV. 16. RDMO workover rig. RU and test flow line. Pull BPV. Return to production. RECEIVED MAR -2 1994.. Ai~.sk~ 0il & Gas Cons. Commission Anchorage August 19, 1983 Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 Mr. Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive - Anchorage, Alaska 99501-3192 Dear Mr. Grant: The enclosed verification listings were to be included in the package sent over yesterday. A duplicate copy of the transmittal is enclosed for your reference. I apologize for any inconvenience this may have caused and I hope this doesn't present any problems or confusion. Please contact me at 564-7611 if you have any questions. Thank you. Sincerely, Dorothy B0brbeau Exploration Secretary DRB/drb Encl. ~Jonoco Inc. Anchorage Division To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 [] Under Separate Cover Enclosed r~ecord of Shipment of Confidential Information Date From Steve Davies Conoco Inc. August 17, 1993 3201 C Street, Suite 200 Anchorage, Alaska 99503 (907) 564-7640 Via Petroleum Couriers Subject Milne Point Quantity Contents PTD WELL NAME REQUIRED DATA I each 90-007 MPU L-:~'7 ~'7 Digital Data ~ L-3 Magnetic Tape. (LIS Format) APl #50-029-21999. LogDate: 13-Feb-90, Ref. #73695, Run No. 1. 1 each 90-102 MPU L-10:[:~ '~ ~c~, Digital Data & LIS L-10 Magnetic Tape. (LIS Format) APl #50-029-22076. Log Date: 12-Mar-91, Ref. #74436, Run No. 1 & 2. 1 each 91-024 MPU G-6 Daily Drilling History Core Analysis Report RECEIVED AUG 1 ~ 199~ Alaska 0il & Gas Cons. Commission Anchorage Reference your request of August 9, 1993, The E-6 Well Sidewall Core Analysis and description for intervals 4840'-5093' were never made. The core samples were sent directly from the well site to a laboratory for oil gravity analysis. The process used to produce that analysis destroyed the samples. For Well G-6, the Daily Drilling History and Core Analysis Report (which includes SWC description and analysis) are enclosed. The CCL/GR curves are on the Depth Determination log dated 8/6/91. As discussed with Linda Starr 8/17/93, you already have a copy of that log on file. Signed By --(~/z_.~.z~~ ~ ~ Transmittal Approved By ,S,LeTve Davies,/. Z Date August 17, 1993 Instructions: Please ack~oceipt pro~tly by~ing and ret urnine/.=,.,-c.-.-j cc_ r.-; .... Remarks fJ / // J ~ Transmittal Copy Only To -" 0RIGIN_ L STATE OF, ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION W i,,,L COMPLETION OR RECOMRLK. TION REPORT AND LOG 1. Status of Well OIL~ GAS ~ SUSPENDED 2. Name of Operator CONOCO INC. 3. Address - - ~ - --- - 4. Location of well at surface ~90~ E~, 202~ E~, ~C~O~ 8, L;iassificat~on of Serv,ce Well 7. Permit Number 90-07 8 APl Number ¢129-21999 9. Unit or Lease Name MILNE POINT UNIT 10. Well Number At Top Producing Interval 3991" FEL, 450" FNL, SECTION 7, T13N, R10E, UM At Total Depth 4224" FEL, 361" FNL, 5. Elevation in feet (indicate KB, DF, etc.) KB 55" MSL ~ 2. Date Spudded 02/01/90 L-3 11. Field and Pool SECTION 7, T13N, R10E, OM KUPARUK RIVER FIELD 6. Lease Designation and Serial No. ~DL25509 [ --I Aband. 15. Wa,er Depth, if offshore '16 No of Coml3leti°nsj 13. Date T.D. Reached 14. Date Comp., Susp. or COMP N/AreaL MS L 1 02/13/90 10/14/90 · I18.Plug Back Depth {MD+TVD) 1D. Directional Survey 20. Depth whereSSSV se! 8,780/7229 YES~ NO ~ 546~ feet MD J +18001 __ ______ 17. Total Depth (MD+TVD) 8,900/7321 22. Type Electric or Other Logs Run GR, CCL, GYRO, PERF, 23. CL, CNL, LDT CASING, LINER AND CEMENTING RECORD CASING SIZE 9-5/8"" 71, NT. PER FT. 36# HOLE SIZE T SETTING DEPTH MD GRADE ~ LBOTTOM H-40 :[-~" ---J_~-~--~ 31 8r 68~RKB 24. Perfo~-ations open to Production (MD+TVD of Top and Bottom and interval, size and number) 8,508- 8,572" (7020) 8,601- 8,627" (7092) 8,634- 8,662" (7117) 8,674- 8,704~ (7148) - 7070" ) - 7112" ) - 7139") - 7171" ) _30" 12.25 80511 ISIZE CEMENTING RECORD J AMOUNT PULLED TO SURFACE ! NONE 227 BBL CLASS ""E"' NONE 84 BBL CL~%SS ""G""' NONE 138 BBLS CLRSS"G": NONE TUBING RECORD I DEPTHSET (MD) [PACKER SET (MDI i 7/8"* 567 ~ 567 ' "~ , 8397" 7/8" 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED RLL PERFOI~ATE~ 63;882 GALLONS GEL W/. j4 5 OD CARRIER W/HYPERJET CHARGES ZONES 147_. 022# 16/20 CARBOLITE 5JSPF & 72 DEGREE P~SIN~ J; = : :,~ =:: ~ -: _ _ · _-: _- __.__- -:~ 27. PRODUCTION TEST Date First Production ~ Method of Operation (Flowing, gas lift, etc.) /, WATER-BBL jOIk GRAVITY-APl {co, r) I 11-3 t l! ~ '"" Hours Tested UCTION FOR OIL-BBL GAS-MCF TEST I ~. l~;.7 ~Flow-Tubin9 Casing Pressu;;- [CALCULATED ~ OIL'BBL GAS'MCF Press. 3~ ~ ~24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ch~ps. NONE SubmJ! Jn clupJ,cat¢- U Form 10407 ........................... 29. GEOLOGIC MARKERS NAME MEAS. DEPTH RKB TRUE VERT. DEPTH RKB 30. FORMATION TESTS Include interval tested, pressure c~ata, all fluids recovered and gravity, GOR, and time of each phase. N/A Not Tested Kuparuk Fun Lower Kuparuk Base Kuparuk 8342 8611 8742 6882 7095.5 7203.5 31. LIST OF ATTACHMENTS Daily Activity Reports and Gyro ~urv~y 32. I hereby certify that the foregoing ~s true and correct to the best of my knowledge 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 iniection, 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 loroducing 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 eievation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' tf no cores taken, indicate "none". Fo~m 10-40- DRILLING HISTORY Kuparuk River Field - North Slope Borough, Alaska Milne Pt. L No. 3 (P) CONFIDENTIAL Location: 2,021' FNL, 190' FWL, Sec 8, T13N, R10E, Objective: 9,040' - Kuparuk River W.I. 100% AFE 10-61-1191 Umiat Meridian 02-01-90: Accept rig @ 2100 hrs. & test diverter 1/31/90. Mix spud mud & P/U BHA. Orient MWD. RIH to 107'. Drlg F/107' to 567'. Repair MWD sensor. Drlg F/567' to 991'. Survey @ 909'. Short trip. Drlg F/991' to 1080'. Service rig. Drlg F/1080' to 1111'. Mud wt. 9.1 Viscosity: 48 Cum. mud cost: $ 3,832 Nabors 27E (0-1-0) Drilling Foreman: Polya 02-02-90: Drlg F/ 1111' to 2164'. Short trip. Drlg F/ 2164/ to 2769'. Circulate bottoms up & make short trip. 10' fill. Circulate bottoms up. Prep. to run surf. csg. Mud wt. 9.3 Viscosity: 48 Cum. mud cost: $ 9,046 Nabors 27E (0-2-0) Drilling Foreman: Polya 02-03-90: Drlg F/ 2769' to 2779'. POOH & LD BHA. RU to run csg. Run 65 jts 9 5/8", 36# J-55, Btrs csg. Circ. 1.5 hole volume at 10 BPM. PT cmt. line. Pump 50 bbls 10.5 ppg sepiolite & water tail, 277 bbls 12.3 ppg Permafrost E cement, 84 bbls 15.8 ppg class G Premium cmt. Displace cement at 10 BPM w/ 206 bbls 9.2# gelled mud. Bumped plug w/ 2000 psig, float held. Full cmt. returns. B/O & LD landing joint & RD csg crew. Install 9 5/8" junk ring & cap & P/U speed head. Mud wt. 9.2 Viscosity: 41 Cum. mud cost: $ 10,439 Nabors 27E (0-3-0) Drilling Foreman: Polya 02-04-90: Make up speed head. Make up adapter flange & orient stack. NU & test BOP. Run wear bushing. Make up BHA & orient MWD. TIH & tag Float collar @ 2676'. RU to test csg. Mud wt. 9.2 Viscosity: 41 Cum. mud cost: $ 11,110 Nabors 27E (0-4-0) Drilling Foreman: Polya 02-05-90: PT 9 5/8" csg. OK. Drill out float collar @ 2676' and PT above shoe OK. Drill out float shoe @ 2758' and new formation to 2789'. Perform LOT-ERW 10.9ppg. Drlg F/2789' to 4063'. Short trip. Drlg F/4063' to 4628', MWD failed. Mix and pump Dry slug. POOH for MWD. Mud wt. 9.3 Viscosity: 34 Cum. mud cost: $ 16,212 Nabors 27E (0-5-0) Drilling Foreman: Polya 02-06-90: Finish POOH, change bit and MWD. RIH test MWD and motor and orient MWD. Drlg. f/4628' to 5164'. Short trip. Drlg. f/5164' to 5420'. POOH to PU turbine and Sec MX22 PDC bit.. DRILLING HISTORY Kuparuk River Field - North Slope Borough, Alaska Milne Pt. L No. 3 (P) CONFIDENTIAL Location: 2,021' FNL, 190' FWL, Sec 8, T13N, R10E, Objective: 9,040' - Kuparuk River W.I. 100% AFE 10-61-1191 Umiat Meridian Directional Survey MD Angle Direction 4716 36.50 N64.1W 4972 36.90 N65.2W 5030 36.80 N68.9W 5157 38.30 N69.0W 5315 37.40 N67.1W Mud wt. 9.1 Viscosity: 41 Cum. mud cost: $ 20,833 Nabors 27E (0-6-0) Drilling Foreman: Polya 02-07-90: Continue POOH. MU bit, turbine, new jars. RIH to shoe, test MWD - OK. Drlg. f/5395' to 5924'. Experienced 600 psi pressure drop on standpipe. POOH, found washout in drill pipe. TIH. Drlg. f/5924' to 6129'. Mud wt. 9.4 Viscosity: 38 Cum. mud cost: $ 24,250 Nabors 27E (0-7-0) Drilling Foreman: Polya 02-08-90: Drlg. f/6129' to 6490'. Short trip. Drlg. f/6490' to 6819'. Detected washout. POOH wet, found washout in drill pipe. TIH. Drlg. f/6819' to 7204'. Mud wt. 9.5 Viscosity: 46 Cum. mud cost: $ 28,433 Nabors 27E (0-8-0) Drilling Foreman: Polya 02-09-90: Drlg f/ 7204'-7300', short trip, drld f/ 7300'-7614', short trip, drld f/ 7677'-8059', well started taking fluid at 10.2 ppg while circ. and giving back fluid with pumps shutdown, monitored well until static, start short trip. Mud wt. 10.2 Viscosity: 44 Cum. mud cost: $ 40,115 Nabors 27E (0-9-0) Drilling Foreman: Polya 02-10-90: Complete wiper trip. Estab. circ, lost 50 BB1, pumped fine Mica pill. Lost additional 100 BBL and lost complete returns. Reduced mud wt. to 10.1 PPG. Attempts to circ. failed. POOH wet (35 stands). Established circ. RIH circ. and conditioning mud. Drlg. f/8059' to 8129'. Mud wt. 10.1 Viscosity: 42 Cum. mud cost: $ 52,434 Nabors 27E (0-10-0) Drilling Foreman: Polya 02-11-90: Drlg. f/8129' to 8344'. Short trip. Drlg. f/8344' to 8517'. Mud wt. 10.1 Viscosity: 39 Cum. mud cost: $ 56,621 Nabors 27E (0-11-0) Drilling Foreman: Polya DRILLING HISTORY Kuparuk River Field - North Slope Borough, Alaska Milne Pt. L No. 3 (P) CONFIDENTIAL Location: 2,021' FNL, 190' FWL, Sec 8, T13N, R10E, Objective: 9,040' - Kuparuk River W.I. 100% AFE 10-61-1191 Umiat Meridian 02-12-90: Drlg. f/8516' to 8780'(TD). Short trip. Drlg. f/8780' to 8900'. Circ bottoms up. POOH, worked thru one tight spot. Mud wt. 10.1 Viscosity: 37 Cum. mud cost: $ 61,344 Nabors 27E (0-12-0) Drilling Foreman: Polya 02-13-90: Complete wiper trip to shoe & POOH. RIH & circ. to stabilize hole. Wash & ream fill F/8850' to 8900'. Circ. & condition hole. POOH & L/D MWD & turbine. R/U Schlumberger & log well. Mud wt. 10.1 Viscosity: 40 Cum. mud cost: $ 66,390 Nabors 27E (0-13-0) Drilling Foreman: Polya 02-14-90: R/D Schlumberger. Make up BHA & RIH to csg. shoe. Circ. hole & RIH to 8882'. Ream F/ 8882' to 8900', circ. & condition mud. POOH laying down drillpipe & BHA. R/U to run csg. Start in hole w/ 7", 26#/ft, L-80, BTRS, csg. Mud wt. 10.1 Viscosity: 42 Cum. mud cost: $68,024 Nabors 27E (0-14-0) Drilling Foreman: Fox 02-15-90: Continue to RIH w/ 7" csg. to 4900'. Lost displacement returns & could not establish circ. POOH w/ csg & R/D csg. equip. Install wear bushing and P/U BHA & SIH w/ drillstring. Mud wt. 9.9 Viscosity: 38 Cum. mud cost: $69,153 Nabors 27E (0-15-0) Drilling Foreman: Fox 02-16-90: Continue to RIH w/ drillstring to 8900' circ. and condition hole. Wash & ream tight spots F/ 8626' to 8900'. Circ. & condition hole. POOH L/D drillpipe. Mud wt. 10.1 Viscosity: 35 Cum. mud cost: $73,318 Nabors 27E (0-16-0) Drilling Foreman: Fox 02-17-90: Continue POOH. L/D HWDP & BHA. R/U to run csg. RIH w/ 7", 26#/FT., L-80, Btrs. csg. While reciprocating & circ. @ 7120' csg. stuck. Worked free & continue to RIH to 8868'. Circ. the last two joints in. Reciprocate, circ. & condition mud. Mud wt. 10.2 Viscosity: 38 Cum. mud cost: $75,912 Nabors 27E (0-17-0) Drilling Foreman: Fox 02-18-90: Continue to recip. & circ. csg. RU Haliburton and pressure test lines. Pump 45 BBL, 11.0 ppg sepolite spacer. Pump 48 BBL Premium cement, drop top plug, pump 5 BBL water followed by 140 BBL 10.2 ppg NaCl & 190 BBL mud. Drop top plug & PT csg. to 3000 psi for 10 min - OK. Release pressure - floats held. Drop stage collar opening bomb, wait 30 min. & open collar. Circ. & cond. hole. Pump 50 BBL water preflush, 90 BBL 15.8 ppg Premium cmt., drop closing plug, pump 5 BBL water followed by 182 BBL 10.2 DRILLING HISTORY Kuparuk River Field - North Slope Borough, Alaska W.I. 100% Milne Pt. L No. 3 (P) CONFIDENTIAL AFE 10-61-1191 Location: 2,021' FNL, 190' FWL, Sec 8, T13N, R10E, Umiat Meridian Objective: 9,040' - Kuparuk River ppg NaCl brine & 15 BBL diesel. Bump plug w/ 3000 psi & held for 10 min. Release pressure - collar not leaking. RD Halliburton. ND BOP. Install hanger packoff, tbg. spool and pressure test to 5000 psi. NOTE: Total of 203 jts. of 7" csg. run. PBTD @ 8868' RKB. Baker stage collar @ 5293' RKB. Mud wt. 10.2 Viscosity: 38 Cum. mud cost: $76,374 Nabors 27E (0-18-0) Drilling Foreman: Fox 02-19-90: Released rig at 2400 hrs. 02-18-90. Milne Point L No. 3 COMPLETION HISTORY Kuparuk River Field - North Slope Borough, Alaska W.I. 100% Milne Pt. L No. 3 (P) CONFIDENTIAL AFE 10-61-1191 Location: 2,021' FNL, 190' FWL, Sec 8, T13N, R10E, Umiat Meridian Objective: 9,040' - Kuparuk River 9-29-90: MIRU. NDWH & NUBOP. Pressure test BOPE to 4000 psig. · 7" OK. Test annular preventer to 3500 psig OK. P/U 6 1/8" bit, csg. scraper, 6 4 3/4" DC's & XO. RIH picking up 2 7/8" tubing. Brine wt. 10.2 Viscosity: NA Brine cost: $ 106,219 Cum. cost: $1,846,646 EWS 4 (0-18-1) Drillinq Foreman: Fox 9-30-90: Continue to RIH w/ tbg. Tag TOC @ 5158'. R/U power swivel and establish circ. Start drilling cmt. SD to bypass filters and change hydraulic power supply configuration. Continue drlg. cmt. @ 6'/hr. Drop through cmt. and rotate and reciprocate across depths drilled out to clean csg. Tag DV tool 8' below bottom of cmt. Brine wt. 9.8 Viscosity: NA Brine cost: $ 106,219 Cum. cost: $1,865,646 EWS 4 (0-18-2) Drilling Foreman: Fox 10-01-90: Drill out DV tool and reciprocate through tool to clean out. Press. test csg to 3000 psig. OK. RIH w/ tbg. & TFF @ 8741'. Circ. hole & mix up and reverse 25 bbl. of 3.5# HEC, & one hole vol. filtering fluid to 10 mic. Circ 2nd volume filtering to 3 mic. & PT csg to 3000 psig for 30 min. OK. Pump 2nd HEC pill of 20 bbl and circ hole clean. POOH w/ tbg. Brine wt. 9.8 Viscosity: NA Brine cost: $ 106,219 Cum. cost: $1,975,258 EWS 4 (0-18-3) Drilling Foreman: Fox 10-02-90: Continue to POOH w/ tbg., DC's, bit & scraper. R/U perforators. Waiting on Gyro tool. RIH w/ Perf. gun/GR/CCL. Run correlation w/ DIL. Perforate csg. POOH. Run 2nd gun & perf. P/U Gyro logging tool & orient. RIH & run Gyro Survey. POOH & L/D Gyro. Made 3 more perf. runs. OK. Made final perf. run and switch failed. Reran final gun & perf csg. Brine wt. 9.8 Viscosity: NA Brine cost: $ 106,219 Cum. cost: $2,063,970 EWS 4 (0-18-4) Drilling Foreman: Fox 10-03-90: R/D perf. C/O pipe rams. Spot Frac equip. & R/U Dowell. Hold pre-job safety meeting. PT lines to 6,000 psig. Frac well @ 40 bpm w/ 63,882 gals gel w/ 147,022 lbs 16-20 carbolite propant. Flushed w/ 320 bbls 11.0 ppg brine. R/D Dowell. R/U slick line & RIH w/ 1.75" LIB TFF @ 8509' WLM. R/D slick line. Brine wt. 11.0 Viscosity: NA Brine cost: $ 106,219 Cum. cost: $2,282,919 EWS 4 (0-18-5) Drillinq Foreman: Fox Milne Point L No. 3 COMPLETION HISTORY Page 2 10-04-90: Continue R/D slick line. M/U bulldog bailer. RIH w/ 6 1/8" bit, 4 5/8" bailer, & 40 jts drillpipe, bailer pump assembly, and continue in hole w/ drill pipe. Tagged fill @ 8544' RKB. CO to 8704' and dropped through to 8725' and tool stuck. Work w/ tool to free, no success. R/U to circ. Brine wt. 11.0 Viscosity: NA Brine cost: $ 106,219 Cum. cost: $2,307,360 EWS 4 (0-18-6) Drilling Foreman: Stevens 10-5-90: Mu power swivel - Could not rotate pipe but still have jar action w/ bailer. Blend source water to weight 11.0 brine to 9.8 ppg brine. Circulated down tbg - work pipe reciprocating / bumping up w/bailer. Pujped 54 bbls bullhjeaded down csg 20 bbls @ a time & worked pipe continue to work bailer. Ru tongs to turn and hold left hand torque. Brine wt. 9.8 Viscosity: NA Brine cost: $ 174,340 Cum cost: $2,307,360 EWS 4 (0-19-70 Drilling Foreman: Stevens 10-06-90: Attempted Mechanical blind back-off of Dp below bailer - DP backed off high above bailer - Change tongs & MU pipe Ru HLS e- line Rih w/ccl & tag top of bailer locate tool Jt on perforated Jt abo0ve bailer @ 7474 WLM POOH & MU string shot Rih W/String shot & ccl Locate in tool jt @ 7474' Fire shot - 4 1/4 turns left hand torque Pooh & Rd HLS E-Line. Pu & work pipe - Pipe backed off 104K pull wt. w/7474' 14# DP Pooh 122 stds & 1 Dt. Cut and slip drillinbg line. Pu Dc's mu screw-in sub, bumper sub, oiljars, 6 dc's & accelerator - Rih - Ld 1 STD w/Jt that string shot fired LD 1 single. Rih w/4" DP check/ tighten each connection. Tag top of fish, Mu screw-w sub, Torque up string. Begin Jarring w/85K up over up wt. Brine wt 9.8-11.0 ppg Viscosity: N/A Brine Cost: $ 179,476 Cum cost: $2,448,275 Drilling Foreman: Stevens 10-07-90: Continued Jarring - No Movement Turn pipe to right to torque up connections. Attempt mechanical backoff but pipe backed off high. Torque up pipe & call HLS to Run string shot. Wait on Logging truck, Mu string shot Ru HLS, Ru tongs to hold left-hand torque Rih w/ ccl& string shot, Locate in screw in sub, fire shot - pipe backed off, Pooh & RD HLS. Pooh w /4" DP. LD screw-in sub, Jars, Bumper Sub. Pu Mill Shoe 6" X 4 3/4", 2JTS 5" x 5 3/4 "wash pipe drive sub, bumper sub, jars, 6 dc's. Rib w/4" DP, tighten/check each connection while RIH. Brine wt 9.8-11.0 ppg Viscosity: N/A Brine Cost: $ 179,476 Cum cost: $2,493,195 Drilling Foreman: Stevens Milne Point L No. 3 COMPLETION HISTORY Page 3 10-08-90: Continue Rih w/4" DP, MU power swivel and wash over fish from 7467' - 7528'. RD swivel Pooh & LD oil jars. Mu 6"x 4 3/4" Mill, 6" outside cutter, 2 Jts 5 3/4" x 5" wash pipe, bumper sub, 6 DC's on 4" DP Rih to fish. RU Power swivel, wash over fish, PU to make cut/activate cutter @ 7510' - engage cutter swivel, stalled out, drop down 2' PU & begin cutting - Rotate @ aprox. 60 RPM 15 min. to complete cut. PU 20' l15K & set down RD power swivel. *** Safety Meeting*** Pooh - Fill w/displacement. Vol. (35 bbl.) Work on power tongs. Continue Pooh - LD wash pipe, recover bailer, LD cut Jt, Perf Jt, Top of fish @ 7510'. MU BHA as follows: 5 3/4" overshot w/4 1/2" grapple & pack-off, 5 3/4" overshot extension, Bumper sub, Jars, 6 DC's on 4" DP. Test Bope. RiH w/BHA. Brine wt 9.8-11.0 ppg Viscosity: N/A Brine Cost: $ 179,476 Cum cost: $2,544,391 Drilling Foreman: Stevens ORIGINAL SUB - S URFA CE DIRECTIONAL SURVEY r~ UIDANCE ~ ONTINUOUS !-~ OOL Company conoco INC. Well Name MILN~ POINT UNIT L-3(2021' FNL, 190' FWL,SEC 3,T13N, R10E) Field/Location MILNE POINT, NORTH SLOPE, ALASKA Job Reference No. 74096 Loc~qed By- FRITZKE Date ~ I C R 0 FI L N E nm2p~ -;V0'' SCHLUMBERGER G'CT DIRECTIONAL SURVEY CUSTOMER LISTING FOR CONOCO INC. MILNE POINT UNIT L-] MILNE POINT NORTH SLOPE, ALASKA SURVEY DATE: 02-~CT-1990 ENGINEER: ~RITZKE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTEO ONTO A TARGET AZIMUTH OF NORTH 6~ 3EG 59 MIN WeST NOTE ~** THE ~IELD CALCULATED CHANNEL VOEP WAS CORRECTED ~Y SUBTRACTING 0.2' PRIOR TO THIS PROCESSING 96 '0 99'0 IS '0 SE'O 08'0 £E 09 50'ZEEE SO'LSEE O0'O06E I5 6E 59'SSZE 59'OIEE O0'OOBE 99 6E 56'Bite 58'E£ZE O0'OOIE Z9 6E 06'IOI£ 06'95IE 00'009£ 5g 6E OI*SZOE OI*O$OE 00'005£ 9I 6E 50'8962 SO'EOOE O0'O09E ET LE ZZ'69BZ ZZ'gZ6Z O0'OOEE II SE 58'8BIZ S8'EgBZ O0'OOZE E gE 5~'£OlZ 55 'ZgLZ O0'OOIE 69 £E 55'ZZ9Z 55'ZB9Z O0'O00E M L5 Oi N 68'010t M ES'g56 N 56'6ZE M 0 IL N ZI'BD6 M 99'96B N 9L'BOE M 95 0i N 0I'~6~ M 55'9E$ N ZI'6BZ M B ]£ N 0E'95/ M 69'5IZ N 69'99Z M BZ Il N B6'I69 M Z0'959 N IO'OZZ M 59 IZ N Z£'B29 M ZI'Z65 N Z6'96I M 9! ~Z N Ii'E05 M ZZ'6£9 h 99'E~t M 0£ ~i N ~g'9~ M 96'EZ~ N OZ'EEI ZE'Z 99 '0 /.9'0 80'I 59'0 IE'O Z9'I OI 'B 6Z'OIO] M S 69 N E~'£96 M ~I IL N 65'988 M 9I Zi N 9Z'OZ~ M 99 6~ N EE']69 M 0I B9 N 90'BZ9 M G 6g N 61'S95 M 05 69 N 96'~05 M 6 0£ N Ti'E99 M ~Z 0£ N BE BE B6'B95Z B6'EO9Z O0'O06Z ~ 55 BE SI'IlgZ 5I'925Z O0'O08Z IZ 6E 05'E6EZ 05'8992 O0'O0£Z 9I 09 B~'gIEZ BS'IAEZ O0'O09Z 5E 6E 5I'99IZ 5I'6IZZ O0'O09Z 99 BE 56'$00Z ~6'Egoz O0'OOZZ O BE B9'OE6I $9'5B6] 00'0012 99 EE LI'O~I £t'506! O0'O00Z M ~9 ZZ N OI'E6E M Eg'SIE N 25'9t! M 9 EZ N i.g'~9£ M zg'6z£ N 09'00I M ~ EL N 6Z'96Z M ~6'£BZ N Z9'9~ M E9 EL N ZE'BgZ M gE'BEZ N 19'69 M I5 EZ N O0'EOZ M 66'96I N 99'95 M Z~ E~ N EO'65I M ZZ'~SI N M S 9Z N ~5'611 M 96'9I~ N M 9I SL N 6I'B$ M ~Z'SB N Eg'ZZ M 9I lA N GE'I9 M Z8'6~ h E~'E~ M e~ OG N EE'6E M 6G'SE N 6~'9 OL '0 95 '0 99'0 IE'9 69'~ OZ'ZZ N 50'0 O5'Z B8'OI S 99'E Z5'I 9E'O S 6E'9 ~B'I 90'0 S 68'£ lZ'O IO'O S 9E'E 9t'O EO'O S 99'~ 60'0 90'0 S 09'I 00'0 SO'O S 9E'O 8, Z'O 00'0 N 00'0 00'0 6~ 6 SB'EgB gB'B6B 00'006 li 5 99'99£ 99' 66/. 00'005 E~ E ]6'999 16'669 00'00/ $9 0 B6'9)~ B6'665 00'00~ Z] 0 {)6' 999 ~,6'66 t 00'005 £Z 0 B6'99E B6'66E 00'009 9[ 0 66'99Z 66'66Z O0'OOE /E 0 66'99~ 66'66~ O0'OOZ 9£ 0 00'59 O0'OOI O0'OOI 0 0 00'S5- 00'0 00'0 HI~WIZV 'ISIO IS]M/IS~ HInDS/HI~ON Xl.I~^~S NOII3~S HI.~WIZV NOII~IA]O lqgI£~]A IV3II~BA O]UASV]W 3S~AOD V~S-BAS ~R~l Hld~O Q~BAS~]W ~0 1=]~ OOI N]AB ~0~ SgfllVA O]lVlOd~)lNI 1~ O0'SS :NOIIVA39~. ONIHSng All~) 066l-iJO-ZO :A3AU~S ~0 ~1~0 INIOd aNIIW £-9 iINR £NIOd 3NIIW ']NI 06-130-0I :~1~0 NCIIVlfldWO3 COMPUTATION DATE: 10-0CT-90 PAGE 2 CONOCO INC. MILNE POINT UNIT L-3 MILNE POINT NORTH SLOPE, ALASKA DATE OF SURVEY: 02-0:CT-1990 KELLY BUSHING ELEVATION: 55.00 FT ENGINSER: FR[TZKE · INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH BEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE ' SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/J00 mEET FEET FEET DEG MIN 4100.00 3537.16 3482' 16 4! 34 4200.00 3611.64 3556.64 42 11 4300.00 3686.80 3631.80 40 1 4500.00 3841.26 3786.26 39 28 4700.00 3996.46 3941.46 37 13 SO0.O0 OZ .?S VO0.O0 5000.00 4236.92 4181.92 36 56 5100.00 4316.53 4261.53 37 38 5200.00 4395.18 4340.18 38 34 5300.00 4473.84 4418.84 37 36 5400.00 4552.97 4497.97 37 47 5500.00 4632.19 4577.19 37 21 5600.00 4712.09 4657.09 36 '25 5700.00 4792.88 4737.88 36 1 5800.00 4873.45 4818.45 36 40 5900.00 4953.61 489~.61 36 40 6000.00 5033.94 4978.94 36 24 6100.00 5114.61 5059.61 36 6 6200.00 5195.36 5140.36 36 12 6300.00 5276.15 5221.15 36 5 6400.00 5356.50 5301.50 37 12 6500.00 5435.73 5380.73 37 52 6600.00 5514.50 5459.50 38 8 6700.00 5593.09 5538.09 38 17 6800.00 5671.45 5616.45 38 25 6900,00 5749.69 5694.69 38 42 7000.00 5827.84 5772.84 38 10 7100.00 5907.48 5852.48 36 29 7200.00 59~8.05 5933.05 36 24 7300.00 5068.31 6013.31 36 49 7400.00 6148.11 6093.11 37 20 7500.00 6227.33 6172.33 37 51 7600.00 6305.96 6250.96 38 18 7700.00 6384.97 6329.97 37 3! 7800.00 6464.17 6409.17 37 51 7900.00 6542.89 6487.89 38 3 N 64 58 W 1696.37 N 64 59 W 1762.64 N 64 50 W 1829.20 N 63 22 W 1894.92 N 63 4B W 1958.28 N 64 54 W 2021.46 N 64 59 W 2084.97 N 64 2 W 2147.24 N 64 27 W 2206.59 N 65 44 W 2266.21 N 67 59 W 2326.22 N 68 41 W 2386.73 N 68 47 W 2448.48 N 68 14 W 2510.22 N 67 43 W 2571.36 N 67 30 W 2632.36 N 68 3 W 2692.49 N 68 41 W 2751.41 N 69 7 W 2810.65 N 69 59 W 2870.43 N 70 43 W 2929.97 N 71 33 W 2989.02 N 72 22 W 3047.92 N 73 2 W 3106.73 N 72 11 W 3166.13 N 71 25 W 3227.07 N 71 41 W 328B.62 N 72 7 W 3350.38 N 72 30 W 3412.40 N 73 11 W 3474.54 N 71 30 W 3536.78 N 66 35 W 3597.21 N 66 52 W 3656.40 N 67 2 W 3716.02 N 67 I W 3776.25 N 57 9 W 3837.24 N 67 24 W 3895.99 N 69 17 W 3960.29 N 69 26 W 4021.34 N 70 20 W 4083.00 0.70 0.62 0.89 1.95 1.11 0.79 0.72 3.3q I .29 I .19 0.81 0.92 0.57 1.06 0.31 0.57 1.24 0.62 0.74 0.57 0.62 0.54 0 0.24 1.76 0.61 0.28 0.38 0.82 0.51 4.61 0.82 0.70 0.53 0.84 0.66 0.70 0.53 0.67 2.60 606.59 N 1584.21 W 1696.37 N 69 3 W 634.70 N 1644.41 W 1762.64 N 6)3 54 W 662.95 N 1704.86 W 1829.22 N 6;;3 45 W 691.70 N 1764.21 'W 1894.96 N 68 35 W 720.26 N 1821.11 W 1958.37 N 6)3 25 W 747.67 N 1878.26 W 2021.60 N 68 18 W 774.48 N 1936.00 W 2085.17 N 68 12 W 801.27 N 1992.42 W 2147.50 N 68 6 W 827.39 N Z045.96 W 2206.93 N 67 59 W 852.49 N 2100.18 W 2266.60 N 67 54 W 876.08 N 2155.41 W 2326.65 N 67 53 W :398.36 N 2211.67 W 2387.16 N 67 54 W 920.75 N 2269.22 W 2448.90 N 67 55 W 943.31 N 2326.69 W 2510.64 N 67, 56 W 966.28 N 2383.36 W 2571.79 N 6)' 56 W 989.56 N 2439.77 W 2632.81 N 67 55 W 1012.34 N 2495.42 W 2692.95 N 67 55 W 1034.07 N 2550.20 W 2751.87 N 67 56 W 1055.39 N 2505.46 W 2811.10 N 67 57 W 1076.30 N 2661.48 W 2870.87 N 67 59 W 1096.31 N 2717.57 W 2930.37 N 68 2 W 1115.45 N 27?3.48 W 2989.38 N 63 5 W 1133.71 N 2829.56 W 3048.23 N 68 I0 W 1151.22 N 2885.83 W 3106.98 N 68 15 W 1168.86 N 2942.68 W 3166.33 N 68 20 W 1188.07 N 3090.59 W 3227.24 N 68 24 W 1207.60 N 3059.02 W 3288.76 N 68 27 W 1226.83 N 3117.80 W 3350.49 N 68 31 W 1245.74 N 3176.97 W 3412.48 N 68 35 W 1264.09 N 3236.49 W 3474.5~ N 68 40 W 1282.49 N 3296.10 W 3536.81 N 63 44 W 1304.74 N 3352.29 w 3597.25 N 68 44 W 1328.14 N 3406.71 W 3656.45 N 68 42 W 1351.48 N 3461.60 W 3716.07 N 63 40 W 1375.03 N 3517.08 W 3776.32 N 68 39 W 1398.77 N 3573.29 W 3837.31 N 63 37 W 1422.67 N 3630.26 W 3899.08 N 68 36 W 1445.24 N 3687.25 W 3960.38 N 68 36 W 1456.74 N 3744.40 W 4021.43 N 6)3 37 W 1488.23 N 3802.20 W 4083.08 N 68 37 W COMPUTATION DATE: lO-OCT-gO PAGE 3 CONOCO INC. MILNE POINT UNIT L-3 MILNE POINT NORTH SLOPE, ALASKA DATE OF SURVEY: 02-0CT-1990 KELLY BUSHING ELEVATION: 55.00 FT ENGINEER: FRITZKE ' INTERPOLATED VALUES FOR EVEN 10,0 :EET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IOO FEET ~EET FEET DEG MIN 8000.00 66Z1.89 6566.89 37 44 8100.00 6700.71 6645.71 38 19 8200.00 6778.87 6723.87 38 54 8300.00 6856.5Z 6801.52 39 8 8400.00 6933.85 6878.85 39 32 8500.00 7010.83 6955.83 39 55 8600.00 7087.27 7032.27 ¢0 13 8700.00 7163.48 7108.48 40 32 8780.00 7224.29 7169o29 40 32 N 73 20 W 4144.20 N 73 28 W 4205.56 N 73 32 W 4267.74 N 72 38 W 4330.59 N 70 58 W 4393.91 N 70 1~ W 4457.72 N 70 31 W ¢52Z.17 N 70 30 W 4586.83 N 70 30 W 4638.80 0.15 O.2:J 0.78 0.98 1.01 1.07 0.43 0.00 0.00 1506.99 N 3860.55 W 4144.26 N 68 41 W 1524.56 N 3919.$4 W 4205.60 N 6,~ 45 W 1542.24 N 3979.36 W 4267.76 N 68 ~9 W 1560.51 N 4039.66 W 4330.59 N 68 53 W 1580.33 N 4099.88 W 4393.91 N 68 55 W 1601.67 N 4160.04 W 4457.72 N 68 57 W 1623.26 N 4220.79 W 4522.t7 N 68 58 W 1644.62 N 4281.85 W 4586.83 N 68 59 W 1661.98 N 43.30.8'5 W 6638.80 N 69 0 W COMPUTATION DATE: lO-OCT-g0 PAGE 4 CONOCO INC. MILNE POINT UNIT L-3 MILNE POINT NORTH SLOPE~ ALASKA DATE OF SURVEY: 02-0CT-1990 KELLY BUSHING ELEVATION: 55.00 FT ENGINEER: FRITZKE INTERPOLATED VALUES FOR EVEN 1000 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE, MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH E~ST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -55.00 0 0 1000.00 997.34 942.34 [0 50 2000.00 1905.17 1850.17 33 44 3000.00 Z682.55 2627.55 37 49 4000.00 3462.42 3407.42 4! 35 5000.00 4236.92 4181.92 36 56 6000.00 5033.94 4978.94 36 24 7000.00 5827.84 5772.84 38 10 8000.00 6621.89 6566.89 37 44 8780.00 7224.29 7169.29 40 32 N 0 0 E 0.00 N 70 13 W 38.52 N 70 24 W 443.71 N 67 26 W 1072.14 N 64 5~ W 1695.37 N 67 59 W 2:32-6.2.2 N 70 43 W 292g.97 N 7! 30 W 3536.?8 N 7~ 20 W N 70 30 W 0.00 3.6Z 8.10 1.32 0.70 0.81 0.62 4.61 0.15 0. O0 0.00 N 0.00 E 0.00 N 0 0 E 6.19 N 38.89 W 39.38 N 80 58 W 133.70 N 4Z3.96 W 444.55 N 72 30 W 353.03 N 1012.92 W 1072.68 N 70 47 W 606.59 N 1594.21 W 1696.37 N 69 3 W 876.08 N 2155.41 W 2326.65 N 67 53 W 1096.31 N 2717.57 W 2930.37 N 68 2 W 1282.49 N 3296.10 W 3536.81 N 68 44 W 1506.99 N 3860.55 W 4144.26 N 6~ 41 W 166.1.98 N 4330.85 W 4638.80 N 69 0 W COMPUTATION D~TE: lO-OCT-g0 PAGE 5 CONOCO INC. MILNE POINT UNIT L-3 MILNE POINT NORTH SLOPE~, AL6SKA D,&TE OF SURVEY: 02-0CT-199~ KELLY BUSHING ELEVATION: 55.00 FT ENGINEER' FRITZKE ' INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SE~ COURSE MEASURED VERTICAL VERTIC&L DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG M.IN VERTiCaL DOGLEG RECTANGULAR COORDINATES HgRIZ. DEPARTURE SECTION SEVERITY NORTH/SOU'TH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN O. O0 0.00 -55.00 0 0 N 0 0 E 55°00 55.00 0.00 0 25 S Z7 33 W 155.00 155.00 100.00 0 37 S 0 39 E 255.01 255.00 ZO0.O0 0 37 S 2 16 E 355°02 355.00 300.00 0 30 S 0 54 E 455.02 455.00 400.00 0 19 S 5 50 E 555.02 555.00 500.00 0 2.3 S 31 46 W 655°04 655.00 600.00 2 0 S 86 19 W 755.20 755.00 700.00 4 17 N BO 50 W 855.68 855.00 800.00 7 14 N 73 34 W 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E -0.26 0.00 0.92 S 0.07 W -0.68 0.00 2.00 S 0.0~ W -1.04 0.00 2.96 S 0.03 W -1.138 0.23 3.70 S 0,06 E -1.43 0.32 4.11 S 0.05 W -0.22 3.80 4.71 S 1.58 W 5.23 2.49 4.11 S 7.18 W 14.76 6.02 2.06 S 16.60 W 0.00 N 0 0 E 0.00 Iq 0 0 E O. 92 S 4 26 w 2.00 S I 9 w 2.96 S 0 30 W 3.70 S 0 56 E 4.11 S 0 43 W 4.97 S 18 32 W 8.28 S 60 14 'W 16.73 S 82 56 W 956.97 955.00 900.00 9 59 1058.97 1055.00 1000.00 13 17 1162.41 1155.00 1100.00 15 50 1267.04 1255.00 1200.00 18 58 1374.75 1355.00 1300.00 24 35 1485.86 1455.00 1400.00 26 25 1597.97 1555.00 1500.00 27 42 1712.01 1655.00 1600.00 29 19 1826.11 1755.00 1700.00 28 44 1940.91 1855.00 1800.00 30 4 N 69 11 W 30.80 1.34 N 70 50 W 50.81 3.75 N '7'0 42 W 77.23 1.04 N 70 48 W 107.95 4.08 N 7.3 52 W 147.75 4.16 N 73 37 W 195.99 0.43 N 72 38 W 246.54 2.35 N 71 3 W 301.28 0.95 N 70 41 W 356.19 1.87 N 70 34 W 412.55 3.42 3.50 N 31.65 W 31.84 N 83 41 W 10.26 N 50.49 W 51.53 N 78 31 W 18.97 N 75.45 W 77.80 N 75 53 W 29.20 N 104.42 W 108.43 N 74 13 W 41.23 N 142.44 W 148.29 N 73 51 W 54.67 N 188.95 W 196.70 N 73 52 W 69.33 N 237.47 W 247.38 N 73 43 W 86.52 N 289.51 W 302.16 N 73 22 W 104.52 N 341.42 W 357.06 N 72 59 W 123.28 N 394.59 W 413.40 N 72 39 W 2061.25 1955.00 1900.00 37 16 2188.53 2055.00 ZO00.O0 38 44 2317.10 2155.00 2100.00 39 7 2446.72 2255.00 2200.00 40 7 2579.25 2355.00 2300.00 40 31 2708.~+0 2455.00 2400.00 39 18 2837.10 2555.00 2500.00 39 0 2965.06 2655.00 2600.00 38 4 3090.67 2755.00 2700.00 36 9 3213.67 2855.00 2800.00 35 17 N 70 21 W 479.29 N 69 52 W 558.01 N 68 58 W 638.82 N 67 43 W 721.28 N 68 39 W B06.70 N 72 16 W 889.90 N 70 35 W 970.84 N 67 42 W 1050.65 N 66 16 W 1126.61 N 64 40 W 1198.10 2.18 0.34 0.62 1.35 3.96 0.67 1.06 0.58 1.36 0.57 145.66 N 457.49 W 480.12 N 72 ZO W 172.51 N 531.50 W 558.79 N 72 1 W 200.82 N 607.19 W 639.5~ N 71 42 W 231.28 N 683.83 W 721.88 N 71 19 W 263.87 N 762.81 W 807.15 N 70 55 W 290.75 N 8~1.62 W 890.42 N 70 57 W 316.36 N 918.48 ~ 971.44 N 71 0 W 344.83 N 993.05 W 1051.21 N 70 51 W 374.50 N 1063.02 W 1127.06 N 70 36 W 404.18 N 1128.19 W 1198.41 N ?0 17 W 3338.25 2955.00 2900.00 38 26 3467.32 3055.00 3000.00 39 45 3597.52 3155.00 3100.00 39 42 3727.52 3255.00 3200.00 39 48 3857.90 3355.00 3300.00 40 13 3990.09 3455.00 3400.00 41 31 4123.87 3555.00 3500.00 41 37 4258.11 3655.00 3600.00 41 7 4388.48 3755.00 3700.00 39 20 4517.80 3855.00 3800.00 39 29 N 66 39 W 1272.22 N 67 26 W 1353.76 N 66 41 W 1437.11 N 65 50 W 1520.07 N 65 6 W 1603.57 N 64 53 W 1689.82 N 65 0 W 1778.46 N 64 3 W 1867.?8 N 63 37 W 1951.01 N 65 6 W 2032.75 2.93 0.65 0.59 0.40 1.10 0.85 0.66 3.49 1.17 0.79 435.06 N 1195.73 W 1272.42 N 70 0 W 466.65 N 1270.95 W 1353.91 N 69 50 W 499.01 N 13~7.81 W 1437.22 N 69 41 W 532.49 N 1423.82 W 1520.14 N 69 30 W 567.33 N 1499.88 W 1603.59 N 6) 17 W 603.81 N 1578.26 W 1689.82 N 69 4 W 641.41 N 1658.77 W 1778.46 N 68 52 W 679.63 N 1739.77 W 1867.80 N 63 40 W 717.03 N 1814.57 W 1951.10 N 63 26 W 752.46 N 1888.51 W 2032.90 N 68 17 W COMPUTATION DATE: 10-0CT-90 PAGE ,6 CONOCO INC. DATE OF SURVEY: 02-0CT-1990 MILNE POINT UNIT L-3 KELLY BUSHING ELEVATION: 55.00 FT MILNE POINT NORTH SLOPE, ALASKA ENGINEER: FRI'TZKE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH , TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINAT£S HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH OEG MIN 4647.31 3955.00 3900.00 38 52 4772.95 4055.00 4000.00 36 21 4897.54 4155.00 4100.00 36 58 5022.64 ¢255.00 4200.00 37 Z 5148.75 ¢355.00 4300.00 38 8 5276.19 4455.00 4400.00 37 44 5402.56 4555.00 4500.00 37 47 5528.67 4655.00 4600.00 37 5653.17 4755.00 4700.00 36 2 5777. O! 4855.00 4~00.00 36 31 5901.74 4955.00 4900.00 36 40 6026.16 5055.00 5000.00 36 17 6150.00 5155.00 5100.00 36 8 6273.83 5255.00 5200.00 36 4 6398.12 5355.00 5300.00 137 10 6524.42. 5455.00 5400.00 37 59 6651.51 5555.00 5500.00 38 1Z 6779.00 5655.00 5600.00 38 27 6906.8! 5755.00 5700.00 38 43 7034.37 5855.00 5800.00 37 26 7158.99 5955.00 5900.00 36 15 7283.39 6055.00 6000.00 36 45 7408.68 6155.00 6100.00 37 23 7535.10 6255.00 6200.00 38 7 7662.19 6355.00 6300.00 37 38 7788.40 6455.00 6400.00 37 46 7915.37 5555.00 6500.00 37 57 8041.99 $655.00 6600.00 37 53 8169.37 6755.00 6700.00 38 42 8298.04 6855.00 6900.00 39 8 8427.43 6955.00 6900.00 39 35 8557.75 7055.00 7000.00 40 12 8688.84 7155.00 7100.00 40 32 8780.00 7224.29 7169.29 40 32 DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN N 64 41 W 2114.84 N 63 59 W 2190.60 N 65 42 W 2264.73 N 68 12 W 2339.85 N 68 45 W 2416.67 N 68 25 W 2495.67 N 67 4~ W 2572.93 N 67 35 W 2549.73 N 68 23 W 2723.87 N 69 0 W 2796.93 N 70 0 W 2871.,4.7 N 70 55 W 2945.47 N 71 59 W 3018.46 N 72 54 W 3091.136 N 72 13 W 3165.00 N 71 26 W 3242.07 N 71 53 W 3320.41 N 72 22 W 3399.36 N 73 13 W 3478.79 N 68 55 W 3557.83 N 66 47 W 3632.14 N 67 Z w 3706.09 N 67 Z W 3'781.53 N 67 11 W 3858.83 N 68 44 W )937.24 N 69 2.5 W 4014.24 N 70 56 W 409Z.46 N 73 25 W 416:).80 N 73 37 W 4248.60 N 72 40 W 4329.35 N 70 35 W 4411.38 N 70 29 W 4494.91 N 70 30 W 4579.58 N 70 30 W 453~.B0 3.00 0.88 1.11 0.73 1.07 1.54 0 0.66 0.58 0.93 0 0.70 0.53 0.44 1.77 0.53 0.33 0.78 0.43 5.61 0.24 0.39 0.74 0.85 1.62 0.64 3.12 0.84 0.58 0.96 0.85 0.40 0.00 0.00 787.22 N 1963.11 W Z115.07 N 68 9 W 820.43 N 2031.50 W Z190.91 N 68 1 W 851.88 N 2098.83 W 2265.17 N 6? 55 W 881.16 N Z168.05 W 2340.28 N 67 53 W 909.23 N 2239.57 W 2417.10 N 67 54 W 937.93 N 2313.17 W 2496.09 N 6'7 56 W 966.87 N 2384.81 W' 2573.36 N 67 56 W 996.20 N 2455.82 W 2650.18 N 67 55 W 1023.99 N 2524.57 W 2724.34 N 67 55 W 1050.49 N 2572.65 W 2797.39 N 67 57 W 1076.65 N 2662.45 W 2871.91 N 67 59 W 1101.42 N 2732.21 W 2945.86 N 68 3 W 1124.67 N 2801.47 W 3018.80 N 68 8 W 1146.70 N 2871.10 W 3091.62 N 68 14 W 1168.52 N 2941.61 W 3165.20 N 68 20 W 1192.85 N 3014.82 W 3242.22 N 68 25 W 1217.56 N 3089.25 W 332.0.53 N 68 29 W 1241.80 N 3164.52 W 3399.45 N 68 34 W 1265.32 N 3240.57 W 347B.84 N 63 40 W 1289.62 N 3315.91 W 3557.86 N 68 45 W 1318.58 N 33"34.38 W )632.17 N 6Fi 43 W 1347.60 N 3452.45 W 3706.14 N 68 41 W 13T7.09 N 3521.94 W 37<31.59 N 68 39 W 1407.15 N 3593.20 W 3858.91 N 68 37 W 1436.98 N 3655.74 W 3937.33 N 63 36 W 1464.24 N 3737.75 W 4014.32 N 68 36 W 1491.36 N 3~11.13 W 4092.54 N 68 38 W 1514.34 N 38~15.15 W 4169.85 N 68 4.2 W 1536.80 N 3960.94 W 4248.63 N 68 48 W 1560.14 N 4038.48 W 4329.36 N 68 53 W 1586.09 N 4116.3) W ~411.38 N 68 56 W 1614.15 N 4195.08 W 4494.91 N 68 57 W 1642.20 N 4275.01 W ~579.58 N 6~ 59 W 1661.98 N 4330.85 W 4638.80 N 69 0 W CONOCO INC. MILNE POINT UNIT L-3 MILNE POINT NORTH SLDPE~ ALASKA MARKER BOTTOM 9 5/8" C&SING GCT LAST READING PBT9 BOTTOM 7" CASING TO COMPUTATION DATE: 10-OCT-gO PAGE 7 DATE OF SURVEY: 02-0CT-1990 KELLY BUSHING ELEVATION: 55.00 FT ENGINEER: FRITZK~ INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 2021~ FNL & 190'm FWL, SEC3 T13N RIOE MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST Z758.00 2~93.~8 Z438.~8 300.38 N 871.40 W 8663.90 7136.05 7081.05 1636.79 N 4259.74 W B741.00 7194.65 7139.65 1653.52 N 4306.96 W 8'7B0.00 7124.29 7169.29 1661.98 N ,330.$5 W 8780.00 7224.Z9 7169.29 1661.98 N 4330.85 W COMPUTATI3N DATE: 10-0CT-90 PAGE CONOCO INC. MILNE POINT UNIT L-3 MILNE POINT NORTH SLOPEr ALASKA MARKER PBTO TO DATE DF SURVEY: 02-0CT-1990 KELLY 5USHING ELEVATION: 55.00 PT ENGINEER: FRITZKE Xc~~~ STRATIGRAPHIC SUMMARY SURFACE LOCATION MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW K~ FROM KB SU~-SEA NORTH/SOUTH EAST/WEST 8741.00 7194.65 7139.65 1S53.52 N 4306.96 W 8780.00 7224.29 7169.29 1661.98 N 4330.35 W FINAL WELL LOCATION AT TO: TR~ SUB-SEA MEASURED VERT AL VERTICAL OEPTH DEPTH DEPTH ~'780.00 7224.29 7169.29 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 4638.80 N 69 0 W SCHLUMBERGER B I REC T 1' ONIqL SURV E Y COMPANY CONOCO INC. 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DEPTHS HORIZ SCRLE = 1/1000 IN/FT PEFliviiT # /'~'~ - COi~DLETiON DATE AOGCC GEOLOGICAL MATERIALS iNVENTORY LIST / ~ /~/ / ,,,9 o CO. CONTACT ~.~ ~ o ¢ check off or list data as it is received,*list received date for 407, if not drilline history well tests cored intervals core analysis ditch intervals uired list as NR core descri lital data 5-7'~'-1 i .... , n,~ TYPF I RUN -,~,~ INTERVALS SCALE ...... NO. {to thc nearest foot~ [inchl100' ~1] ' ' ' ._ ~s) I I .I IIII II I III II i II I I I II I ~ ....... ~ I ..... TO: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Receipt of the following terial which was transmitted via QUANT I TY DESCRIPTION Copy sent to sender YES NO SCHLUMBERGER WELL SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COMPANY LOCATION ATTENTION ~ COM PUTI NG CENTER PRINT CENTER WELL NAME · SERVICES · ADD'L TAPES · .... NO. OF BOXES: JOB NO. · ADD'L TAPES · WELL NAME · SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES · JOB NO. · ADD'L TAPES · WELL NAME · SERVICES · WELL NAME · SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER: DATE DELIVERED: NO. OF BOXES: JOB NO. · ADD'L TAPES · SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 I~L~ REPLY TO OCT 0 5 1990 SCHLUIdBERGERWELL ~I~'IGES Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 AHention: .Marc Shannon Gentlemen: Enclosed ore2_BL_prints o{ the GCT, Perf Depth Control, Run 1, .10/02/90 .... on: Company CONOCO, Inc. , Well Milne Point Unit L-3 Field. Milne Point .. Additional prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 A~tn: George Lamb - OF 2016 PER . County Nnrth Slope State_ Alaska _i_]tL__~rints, 1RF Sepia CONOCO~ 1000 South Pine Ponca City, OK 74603 Attn: Log Library 1 BL prints, 1 RF Sepia OXY U.S.A., Inc. 6 P~_ta_.P_mt~c Midland., TX 79710 At,n: John Carrol _*(915/685-5600) ~rints, 1RF Sepia Chevron U.S.A. .6001Bollinger Canyon Road San Ramon, GA 94583-0943 Attn: Priscilla HacLeroy *{415/842-1OOO) 1BL nrintS; I"RF Sepia ~. Alask, a~0~l & Gas ConserVation ~,.?C'~mmis si on ,~ (.73001 Porcupine Drive ./ f?¥~ Anchorage, AK '99501 ~ ~./~ ~ttn: John Box1e ....... ?' ~" The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. Sws-- 1327-F prints prints , prints OCT 0 9 1990 Very truly yours, SCH LUMJI~{i~I~~~ David M, Saalwaechter DISTRICT MANAGER ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program ~ 2. Name of Operator CONOCO INC. 3. Address P.O. BOX 340045. PRUDHOE BAY. AK - 4. Location of well at surface 190' FWL, 2021' FML,SEC 8, At top of productive interval At effective depth GYRO SURVEY At total depth NOT AVAILABLE Operation shutdown __ Re-enter suspended well Plugging __ Time extension Stim ula--~'j~ Pull tubing __ Variance __ P'~'~'orate ~il~,._ Other I 5. Type of Well: Development Exploratory Stratigraphic 9973 Service T13M,R10E,UM. 6. Datum elevation (DF or KB) 55' KB MSL 7. Unit or Property name MILNE POINT UNIT 8. Well number L-3 feet ,i 9. Permit number 90-7 10. APl number 5o- 029-21999 11. Field/Pool KUPARUK FIELD 12. Present well condition summary Total depth: measured: true vertical Effective depth: measured true vertical 8900' 8780' Casing Length Size Structural Conductor 80' 13 3/8" Sudace 2725' 9 5/8" Intermediate Production 8837' 7" Liner Perforation depth: measured true vertical feet feet -, feet feet Plugs (measured) Junk (measured) Cemented STAGE COLLAR PLUG O 5293' RKB NOT APPLICABLE NOT APPLICABLE Measured depth TO SURFACE 277 BBL CLASS E 84 BBL CLASS G 138 BBL CLASS G 110' RKB 2758' RKB 8868' RKB True vertical depth 110' RKB 2492' RKB 2492' RKB 7297' RKB RECEIVED Tubing (size, grade, and measured depth) NOT Packers and SSSV (type and measured depth)NOT APPLICABLE APPLICABLE OC'F 0 8 1990 Gas Cons.Go_m~i s,~),'"-~.~ 13. Attachments Description summary of proposal Detailed operations program )(__ BOP sketch 14. Estimated date for commencing operation SEPT. 28. lggo 16. If proposal was verbally approved LONNIE SMITH Name of approver 09/2.1/90 uate approved 15. Status of well classification as: Oil X_ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~')'~.~3Z~, q l'~q I'~0 Title SENIOR PRODUCTION FOREMAN I, FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10-, Approved Copy Returned . ,. Jc;>/(O_/_qo 0m, A,_ Approved by oroerort-,,e,..,or,;c,~,ss,'on LONNIE C. SMITH ~-c7 Commissioner I Approva, .o. ? t2- 7 7 ~' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ~'- MPU L-3 WELL Milne Point Unit PROPOSED COMPLETION PROCEDURE AFE No. 10-61-1191 9/28/90 - CVL O_.b. ject i ye' Mill out DV tool @ 5293'; perforate the LK-3, LK-2, LK-], and /Z sands; fracture stimulate; run an ESP and postpone start-up until surface equipment hook-up is completed. Surface Lo~]on; 2021' FNL & 190' FWL of' Sec. 8, Ti3N, RiOE All depths are measured from original RKB (49.0') and open hole logs dated 2/]3/90. Surface: 9-5/8", 36 #/ft, J-55, btrs. set ~ 2758' Production: 7", 26 #/ft, L-80, btrs. set Ca 8868'. Capacity = 0.0382 bbl/ft Drift ID = 6.276" Burst Pressure = 7240 psi TubingZworkstr: 2-7/8", 6.5 #/ft, L-80, EUE 8rd (approx, 8400' required). Capacity -- 0.00579 bbl/ft tubing; 0.0302 bbl/ft annulus ID ~ 2.441"; Drift ID- 2.347" Burst Pressure = 10,570 psi Torque (ft-lb): Min = 1730; Optimum- 2300; Max = 2880 PBTD: 8780' RA Tag @ 8503' Pore pressure = 9.6 ppg equivalent (3550 psi) Fluid in well = 10.2 ppg NaBr/C1 Proposed completion fluid -- 11.0 ppg NaBr/C1 (10 deg F TCT) Max Angle : 40 deg; Angle through pay -- 40 deg RECEIVED P_roposed RU, Drilling of DV Tool, and Wellbore Cle_anup..Procedur~e.' NOTE: Hold frequent on site safety meetings prior to all potentially hazardous tasks. Skid rig to the L-3 well and RU on well. ND tree and tubing hanger. NU BOP's. Install pipe rams for 2-7/8" tubing. Test rams to 250/4000 psi and test Xydril to 350/3500 psi. Record tests on AOGCC and Conoco daily reports. 2, MU bit w/o jets, drill collars, and full gauge nominal rotatable casing scrapers on tubing. PU tubing and GIH to Baker Model "J" stage collar @ 5293'. Drill out cement and tool. . GIH below proposed bottom perfs @ 8704'. Reverse circulate the following cleansing pill at maximum pump rates. a, c~ Lead pad - 25 bbls of 3.5 #'s HEC/bbl of brine Chemical pad - 50 bbls of brine + 1 drum of surfactant/dispersant(Safe-Kleen, Dirt Magnet, etc..) Tail pad - 25 bbls of 3.5 #'s HEC/bbl of brine Post flush - circulate with filtered brine (10 microns) at maximum rates until less than 50 NTU NOTE: 1. Safety and environmental precautions must be taken when handling brine and chemicals. Review MSDS sheets prior to handling. 2. Chemicals must be mixed and maintained above 70 deg F. 3, Monitor brine clarity every 50 bbls during post flush with a Turbidity Meter. Submit results to engineering. 4, POOH and L/D bit and drill collars. Pr__Kg_posed LK-3, LK-2~_ LK-!, and LZ Perforating Proceduce_: · RU Schlumberger electric line. Hook up down-joint w/ pack-off and place in Hydril for pressure control. Run Gyro survey. · Hold safety meeting and discuss hazards and required precautions associated with wireline perforating. Pressure test lubricator. NOTE: All Conoco and Schlumberger (see attached) perforating safety procedures must be strictly adhered to. These procedures and safety meetings shall be repeated with each subsequent gun run. MU 20' x 4.5" OD gun assembly (5 SPF, 37gm, 51B deep penetrating charges) with GR/CCL for depth control. GIH and correlate w/ open hole logs. Place guns on depth to shoot LZ @ 8552'-72'. POOH and monitor hole. L/D spent guns. NOTE: Measure OD and length of all tools to be run in the hole. Measure and record distance from top shot on gun assembly to GR/CCL. 4, Repeat step 3. five additional times as follows w/ CCL as depth control, if first run proves CCL correlation feasible. Run No. __Length Interva! ...... Sand 2 30' 8674'-8704' LK-3 3 28' 8634'-8662' LK-2 4 26' 8601' -8627' LK- 1 ........ 5 20' 8532'-8552' LZ 6 24' 8508'-8532' LZ o RD electric line. Monitor fluid level. Do not attempt to keep the hole full to surface, This may result in large volumes of fluid lost to the formation. _Propos~.d Hydraulic l:ra¢~uni,9 P~ Spot seven 500 bbl frac tanks on location. Elevate the rear of the tanks approximately 8". Visually inspect the interior of the tanks for cleanliness. DO NOT ENTER THE TANKS. Fill five tanks with 500 bbls clean injection water. Fill the sixth and seventh with filtered 11.0 ppg NaBr/C1 completion fluid w/ 4 gal/lO0 bbl Unitreat 3900 biocide/inhibitor for flush. The water/brine should be heated and filtered to 10 microns absolute with a hot oil truck and maintained at 75 to 80 degrees F to insure proper hydration of the gelling agent. Water from the central facility, carried in clean transports is acceptable. 2. Rig up Dowell Schlumberger to perform the mini-frac and frac treatments. NOTE: a. Use of threaded connections, crossovers, swedges, etc. in the treating line is not acceptable. b. Use two in-line densitometers. c. Use two shut-off valves on the wellhead. d. Set the backup pumps for the crosslinker and diesel. ee Standby pumps (50%) are required. These pumps must be manned and primed to come on line immediately if needed. A standby blender should be hooked up and ready to come on line in case of primary blender failure. fe BOP saver selection and installation shall be coordinated by Conoco and DS personnel on-site prior to frac RU. ge Tank bottoms are included in the volumes listed. Plan for 50 bbl tank bottoms. he Use the in-line densitometer during the treatment. rate, pressure, and density on a chart. Record i . Take samples of the crosslinked gel during the treatment. Place these samples in a bath at 150 deg F. Note the actual break time. Note the pre-pad is not crosslinked and does contain diesel. j. DO NOT OVERDISPLACE I'HE TREATMENT UNDER ANY CIRCUMSTANCES. Batch mix 2500 bbl gelling agent at 40 lb/lO00 gal and additives as prescribed in the attached material/equipment detail. The pre-pad consist of non-crosslinked gel. Particulate fluid loss additive should be added in the pre-pad and pad fluids only. Diesel (5%) and crosslinker activator are the only additives that should be mixed on the fly. Sand (Carbo-Lite) will be added in the prescribed stages through the blender. 4. Hold on-site safety meeting with rig personnel and frac crew to Page 4 communicate hazards of the operation. 5. Pump the frac job as follows at 40 BPM' Stage Name Stage Barrels Cumulative Treat Pump Proppant Gel Pumped Barrels Press Time ......... _]_L~ ..... [Ea. stage) Slurry Pumped (psi) (Min) Pre-Pad 0 200 200 2600 5.0 PAD 0 1081 1280 3700 27.0 PPG Slurry ....... 695~_0 ........... ~... 1370.......... 36~0_ _2.3.. PPG Slurry 15700 94 1480 3350 2.8 PPG Sl urr~ .... 21900, 127 1640. 3050 4.0 p.PG ~J. urry 42200 126 1810 2900 4.3 10 PPG Slurry 52500 I25 1990 2700 4.5 im 6, ~ Shut down. Allow the pressure to bleed off into the formation, Record the ISIP, and pressure for 30 minutes. Close all surface valves and leave the well shut in. Insure well is dead. Monitor the break time of the last sample collected. Rig down pumping equipment. After the frac treatment there is a possibility of proppant in the wellbore. Rig up slickline and RIH with a sinker bar to insure the perforations are clear. Tag bottom to identify the amount of proppant in the casing. Rathole should be sufficient to prevent proppant from covering the perforations. If the bar tags proppant in the perforation interval then GIH with bailer to remove proppant from the well to clear the perforation interval, Use the tubing bailer with sufficient barrel length. Rig down slickline unit when complete. Page 5 i b.L r'.-IU: 4-L,._'i'_-qU N','4X P..roposed ~SP and Tubinq Runninq Procedure: 1 MU ESP assembly as illustrated on the attached Otis completion guide. Strap and record the length of each component. Run a standard Centrilift motor centralizer for 562 Series motors and 7", 26 #/ft casing on the bottom of the motor. , RIH w/ ESP no faster than 30' per minute. RIH w/ sliding sleeve in open position. Maintain sufficient hydraulic pressure on the control line while RIH to maintain valves in the open position. Attach two cable bands per joint. Attach additional bands above and below each cable splice. Set the bottom of the motor at 8480'. 3, Locate packer and safety valves such that the tubing retrievable SCSSV is at a depth of 500' or greater. Packers should be pinned to begin setting at approximately 1100 psi. , Pump 55 bbl of diesel down annulus for 1800' of freeze protection prior to setting packer. 5, RU slickline and RIH w/ plug and set in "X" nipple located below packer. Pressure up to 1000 psi. Set packer by gradually increasing pressure from 1000 psi to 2500 psi in 500 psi increments. Retrieve plug and POOH. RD slickline. 0 Pump 11 bbl of diesel down tubing for 1800' of freeze protection prior to closing SSSV's. Bleed off control line pressure to close the annular vent valve and SCSSV. Pressure test the packer and vent valve system w/ 500 psi of annular pressure for 10 minutes. Bleed off pressure. connection for production. C. Van LinebeYger Sr. Prod. Engineer Reviewed by' ND BOP's. NU tree. RD and move to next well. Await surface facilities Approved by: Marc Shannon Supervising Prod. Engr. D. E. Howell Production Supt. cc: DEH, PMS, MPU Sr. Fm. (2), CVL, Original to File: L-3 Well File Page 6 LO.O ~ lO0.O0 I h__..L l'.ll_l: 4-~_,.X;'~U ~'~4',.-' I-?_1;-; ';~-o'SF~' ................ ~ooo.o .~oooo ~ooE.'~ CENTRILIFT EQUIPMENT QUOTATION A ~8Ke~ IHu,ghe$ r.,o~D~ny I C, Ai~ACITY TOTAL HEAD :,..L.'-~)oo ." t . ~, '.'. ..... SP. aR. .97' PERFS ]~e B.H.T. LT~ PRIMAI~.Y G.D.R, 1. CASING O.D. WEIGH? NET ~1~ SURFACE VAndAmmE ~n~OU~NC~ MOTOR H,P. [00 VOLTAGE 230 SEmES ~00 PUMP INTAKE SER~E$ PUMI~ Ci..ACHII~G. SERIES FLAT GUARDS BANDS CABLE BANDS CHECK VALVE VALVE __ MOTOR CONTROLLER ACCESSORIES INCLUDE[; VARIABL.E FREQUENCY CONTI~OLLER: TRANSFORMER~, ' SIZE VARIABLE FREQUENCY TRANSFORMER JUNCTION BOX (VENTED-SAFETY) TUBING HEAD CONOCO, INC. 3~o~ "c'" 's~-~.-t ..... '-A~h0-~e,' ~- 60 HERTZ AMPERAGE MOD~L ~.~I~ LENGTH ].2.0 ~SG, NO. NO. PCS. MODEL X~P~ LENGTH 1. 9,2 MOOEL L~NGTH MODEL LENGT~ CONN, MODEL LENGTH MODEL LENGT~ 6. TY~ LEN~T~ ARMO~ TY~E XT'3 LENGT. 3~'i ARMOR LENG'I'N ii i . _ _ i ...... . , il--- _. ~., W~LL NAME L-3 FIE~D NAME.' X ~-a~U k ........... -- - __ .... -~CA~,'6N:--D~adh0r~e-; AK ..... ' ..... SE~ING D~PTH REO. SURFACE VOLTAG~ 2~0 REQU1R~D KVA TU~ING SIZE THREAD FRICTION LOSS T.D.H, B ~ 50 HERTZ 27 NO. POS. i MOD EL SIZE VOLTAGE OVERLOAD ~ UNDERCURRENT S.D. ~ RECORDING AMMETER AUTO t;E$¥'ART 2 LII~tHYING ARRESTI~R 'L~ OTHER )0 KVA ZCS TYPE KVA Galv. 842 582 263 · CABLE REEL. NO. RE~;L, SL.IP POI~IT BHIPPIN~I CASE QTY. ,~ CADE QTY. BI,tIPPiNG CASE QTY. ~HIPPING CASE QTY. IIitZE SIZE SIZE ,NOTE: SERVICING EQUIPMENT MAY BE RETURN,.E,q FOR ~.oo% CREDIT WJ,ININ 6 MO..~jL~B.J. ECT TO A REPAIR EQUAL TO 25~ OF THE LiST PRICE. 64~6 i4~ CONOCO MILNE POINT System p~rf:~.nan-~e I ! F vsc ~) PUMP :230 .statUe FC6~O MOTOR (60 Hz r~tt~j) 562 series 1230 ~ 3~ ~mP T ~T T L..J I¢0 2O0 30O en, cjin,~d by: [ ~0 500 6OO 700 800 gOO lO00 1 I00 ESP SIZING FOR !'~. VAN Lb'qESERGER 1200 1300 BPI) FIF~D NAME: Mil~ Point NAME: h Pad ~~ 2-7/8" 6.4 ~ ~ 8~ x 2-3/8" 4.6 ~ ~ 8~ ~: 432/1001/01/90 ~ 17, 1990 - (907) 2~1-7780 6.4 lb ~JE T~bir~ 2. Electric Cable - Size #2 2.44" 3 · 668" 3. 1/4" Stainless Steel Cuntrol .25" Line. 0.049" Wall ~hickness x 600' I~ 316 Material (WN 2~ sxx 31o~0) 4. 2-7/8" 2.313" Ot/S "FMC' 2.313" 4.76" Serie~ 10 Tubir~ Retrievable FI~ ~~. ~S ~i~. ~ ~ ~1-75, 2-7/8" 6.4 ~ 8~. ~. (P~ 778 ~ 23~1-E) 5. 2-7/8" 6.4 L~ ~3 8Rd 2.44" 3.668" Pup Joint W/Ooupl~ 4-80 6. O~b/natio~ Oouplir~ 2.44" 3.668" 2-7/8" ~3 8 Rd x 2-3/8" ~J 8 ~%~ BXB P-105 7. BIW Power Cable Feed Thru 2.25" For No. 2 Round Cable. 100 AMP, 2400 Volts, 4 KV Rated. Field Attachable Male Co~r an~ Power Feed Thru with a 20' Electric Cable Pig-Tail. (P/N ~ oo 1225) 2-7/32"-14 L%L~-2 X 2-3/8" EU 8~ BxP (?/N ~ O 672Z) 9. Otis Annular Vent Valve 3,000 pi W.P. Setting _De~th 540', 2-3/8" ~J 8Rd a~P (P/N 78 a%~ 2001) I0. 2-3/8" 4.6 lb ~J 8 Rd PU~ Joint P-105 600' 7.0' 6.0' .6' 23' 1.97" 2.62" 1.8' 3.09" EOC. 3.69" 3.06'1 i. 83" 1.99" 2.61' !b..L NFl: 4--b,..:;;'dU ..----... ll%TE: Sapte~,~r 17, 1990 7" 26-32 lb 2-3/B" El3 8i~ (p,~ ~ Ac~ ?oo~) 1.94'4 1.94" SeC. 12. 2-3/8" 4.6 lb Ell 8Rd pup Join~ w/~l~ p-10s 13. Otis "X"' Selective Nifo].. W/Ooupltn~ ~,-n.O (Nipple P/N 11 X 1870~A for 2-3/8" a. 2-3/8" 4.6 ~ ~ 8~ 5.95" 7.1 ' 14. 2-3/8" 4.6 lb ~3 8 ~ pup Joint w/c~pl~ P-lOS 1 .. 99" 3 · 06" 15. __~!~__._r~.or 2-3/8" ~ x 2-7/8" ~: ~ P-105 ** 3.06" ' 1.0' 16. 2-7/8" 6.4 lb ~ Tubing 3.06" 17. ot/s C~mlatin~ ~11 at 1,000 Hi Diff. "Blank" Thread f~ 2-7/8" ~ ~)* 1.875" 17A. 2-3/8" Otis '~t' Sliclir~ side Door (opens up/ct__~s~s_ Down) Not Shown on Drawing 1.99" 3.06" 4 · 0 ' 18. o~-(1) 2-7/8- 6.4 lb ~z Joint of Tubing or Pup Joint~kxDOO Supplt~ 1.97 2 · 44" 3.76" .6' 3. 668" 3.668" .80' 1.29" 875" 3 · 093" 3.0 ' 3.668" 2.44" 17 18 19 Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, Al< 99734 (907) 659-6300 March 9, 1990 Mr. Mike Minder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Letter of Application Dear Mr. Minder, As per your request, I am submitting the Form 10-40~'s to be added to the end of Well Form 10-40~'s, Operation Summaries and logs that Jim Fox submitted at the conclusion'- of the E-4 and L-3 Wells. We are requesting to shut down well operations on these wells until we can move the drilling rig far enough ahead of the workover rig to conduct completion operations. The cement plug was bumped, casing pressure tested, the tree was flanged up and tested and the well was shut in. Sincerely, J.D. Polya ~" Drilling Foreman JDP/djw RECEIVED ~IAR 1 6 1990 :'~i;'~.sl¢a .Oil .& Gas Cons, CommissJo[~ , ~,nchorag~ ' STATE OF ALASKA ALASKA OIL AN D GAS CONSERVATION COM MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casinG __ Repair well __ Change approved program __ 2. Name of Operator CONOCO INC. 3. Address Operation shutdown -X- Re.enter suspended well __ Plugging ~ Time extension __ Stimulate __ Pull tubing ~ Variance __ Perforate ~ Other __ 5. Type of Well: 6. Datum elevation (DF or KB) Development._~ 55' KB MSL Exploratory __ Stratigraphic ~ Service · 7. Unit or Property name M!LNE PO!NT UN!T 4. Location of well at surface 190' FWL, 2021' FNL, At top of productive interval SEC 8, T13N, RIOE, UM At effective depth Gyro Survey Not At total depth Presently Available 12. Present well condition summary Total depth: measured true ve~icat Effective depth: measured true vertical Casing Length Structural Conductor 80 ' Surface 2725' Intermediate Production 8837 ' Liner 8900' *7322' 8780' *7229' Size feet feet feet feet Plugs (n-leasured) Junk (measured) Cemented 8. Well number i-3 9. Permit number 90-7 10. APl number 50-- 132q-21 qqq 11. Field/Pool Kuparuk Stage Collar Plug/5293'RKB N/A Measured depth True vertical depth 13-3/8" To Surface 110' 110' 9-5/8" 277 BBL Class E 2758' 2492' 84 BBL Class G 7" 138 BBL Class G 8868' 7297' Perforation depth: measured N/A feet truevertical*Note: Survey depths Tubing (size, grade, and measured depth) N/A based on MWD directional data not froB.a Gyro Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal X--- Detailed operations program 14. Estimated date for commencing operation 16. If was verbally approved Name of approver Date approved 15. Status of well classification as: Oil__ Gas__ Suspended --X" Service 17. I hereb,y,,lce~ that ,t'h'~rpregoing is true and correct to the best of my knowledge. Signed Title _~¢n'i nY' P~n~ll~f.~ nn FOR COM M[SSION USE O ~ LY ............. Conditions of approval: Notify Commission so representative may witness I Approval No. Plug integrity ~ BOP Test __ Location clearance ~ I Mechanical Integrity Test __ Subsequent form required 10-,,,,//-o4- ORIGINAL ,SIGNED BY ~.~~.~ Approved by order of the Commission ~ S~TH ~sioner Form 10-403 Rev 06/15/88 Date~ .-~..~;~ SUBMIT IN TRIPLICATE SCHLUMBERGER WELL SER¥1CES A DIVISION ~ SCHLUMBEII~G,E:R TECHNOL~Y CO, RPO4qATION HOUSTON. TEXAS 77251-2175 FEB 1 6 1990 CONOCO Anchorage 3201 "C" Street, Suite 200 Anchorage, Alaska 99503 A~ention: Marc Shannon ~ I~PLY TO tCHLUMeEReERWELL ~RVI~$ Pouch 340069 Prudhoe Bay, AK 99734-0069 ATTN: Bernie/Shelley Gentlemen: DI~ NGT, CNL (Raw), CNL (Porosity), Enclosed ore_ 2 BLprintsof the Cyberlook, Run 1, Company CONOCO Inc Well Milne Point Unit L-3 Field M~lne_~oint Additional prints ore being sent to: 1BL prints CONOCO Inc 600 North Dair Ashford Houston, Texas 77079 ATTN: George Lamb - OF 2018 PER County North Slope State Alaska _l~rints & 1RF Sepia & Film CONOCO Inn !OOO Sn,,rh Pine P_oncm C~ry; OK 7&6~ A~TTN: Log Library 1BL prints & 1RF Sepia OXY USA Inc P O Box Midland, Texas 79710 ATTN: John Carrol prints 1BL prints & 1RF Sepia Chevron U.S.A. _P 0 Box 5043 $a~ Ramon, CA 94583-Oqq43 ATTN: Pricilla Macl.eroy * B/L prints& 1 RF Sepia /Alask~ Oil & Gas Conservatinn I: ,, 3001Porcuoine Dr ~Anchora~e. A]aRka qqSOl The film is R~nt to the Log Library ,. prints prints , Rmcoived by: Date: We appreciote the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES SWS -- 13 2 7 -F David M. Saalwaechter l~l~ector ..... . ............ · .... Vt sual Audio TH p tank L/ I .... ,1- - _~.-: r ........ Pft gauge ~ .=! ........ F!~m~n~oc ... .... :.. .. ~ ,, Ge~ de~o~o¢~ ..... ~ ~, .. Annulee preventer. , ~'~ Pipe Bltnd rams Choke line valves HCR valve Full charge preal attained j ,mtn~dl~* 6ac -- iii ii __ : ._. Re~ete I.-- Bltnd iwttOh cover Upper Kelly I Te;t pretaure .:~6~::~ ...... Lc~er Kell~ ~ Te~ pressure .... !t411 type ~ Te~t preaeure .... ~.~ ~ ~ In~de ~ I _.. Te~t prel~ur. ._~0~ .... ~oke mahtfold~ Tel~ peealure~:_._~Ooo_ .. Adjustable cheke~ . _ .a~,._:;,._, . Hydreultoally a;ereted Ohoke . . .... TEST,REeULT$~ Fet lue., ,___ J .... Telt time Repair or replacement of failed aquila, nC ~o be mede wltMn eno tnapector/¢~aHon offl(l~ ~ottfled. OH~I * AOGCC; o - Opera,or ~LASK~ OIL ~!~ K~11 1the valve~ ~ . .... __~.~0._~._. . ..... Cheek verye ......... - Number velve~ /7' Number flaflgal .... ~i· ........ ' ..... · -- _~. .. Hydraul toe1 ly ~ra~d choke i1'- ' end I nspect~Dr/CC~t ,1~ ( ~n of f t ce flor1 f ~ ed. Remerk$ J L/ u:_: :.. ' ' or~g - AC)GCC c ' Superv~,or C.O0~ {rev 05/~?/~9) tntpector~ ~ January 4, 1990 Telecopy No. (907) 276-7542 D F Rainwater Sr Production Foreman Conoco In¢ Pouch 340045 Prudhoe Bay, ~ 99734 Re: Milne Pt Unit L-3 Conoco'Iht Permit # 90-7 Surf Loc 2021'FNL, 190'FWL, Sec 8, T13N, R10E, UM Btmhole Loc 421'FNL, 930'FWL, Sec 7, T13N, R10E, UM Dear Mr Rainwater: 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. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment $othat a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24'hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very truly y. ours, / ~ ~.~..· t /' ~ :- i / ,~z ~ V ~hatterton ~hai~an Alaska Oil a~d Gas Conservation Co~ission BY O~ER OF THE COMMISSION jo Enclosure C: Department of Fish & Game, Habitat Section - w/o enei Department of Environmental Conservation - w/o encl STATE OF ALASKA ALASY--'OIL AND GAS CONSERVATION ~"')MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill I~ Redrill lb. Type of well. Exploratory [] Stratigraphic Test [] .Development Oil Re-Entry [] Deepen Service [] Developement Gas [] Single Zone,,J~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool CONOCO INC. KB 35 feet Kuparuk River Field '3. Address 6. prOPerty Designation Pouch 340045, Prudhoe Bay, AK 99734 ADL 25509 4. LOcation of well at surface ' ' 7. Unit or property Name '11. TyP'~' Bond(see 20 AAC 25.025) 2021'FNL,190'FWL,SEC 8,T13N,R10E,U.M. Milne Point Unit Blanket At top of p. roductive interval 8. Well nurpber Number 500'FNL, ]150'FWL,SEC 7,T13N,R10E,U.M. L-3 8086-]5-54 At total depth 9. APproximate spud date Amount 421'FNL, 930'FWL,SEC 7,T]3N,R]OE,U.M. January 5, 1990 $200,000 12. Distance to nearest ' ' 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MO and TVO) )rop/erty line '~' 2] FNL at, TD feet 104'e]245 TO L-] feet 2533 7335',l'VD/8895'Hgeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (eX2)) Kickoff depth 500 feet Maximum hole angle 38° Maximum surface 3200 psig At total depth (TVD) 3800 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling I'ength MD TVD MD TVD (include stage data) 30" i3 3/8" 48 H-40 Weld .... 80 35 35 ]'15 115 '~_485 sks Permafrost C i2 i/4:; 9 5/8" 36 d-bb BIK5 Z/3Z 3b 35 Z/b/ 2500 _+865 sks Permafrost E - +326 ~ks Class G 8 I/2" 7" 26 L-SO BTRS 8860 35 35 6695 7335 +265 sks Class G/N2 · _3i8 sks Class G r~ .... t''~_ 19. To be completed for Redrill, Re-entry, and Deepen Operations. u~w~ oq i~¢,,~ +lou Present well condition summary -!-60 bbls Dead Crude 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 ConductorRECEIVED Surface IntermediateDEC o t989 Production Liner ½~j~SJ(a Oil & GaS Cons. Perforation depth: measured Anchorage true vertical Pit Sketch X 20. Attachments Filin_~q fee 1~( 'Property pla.t ~X 'Bop Sketch L~( Diverter SketCh [~( Drilling program EX Drilling fluid program .'~ Time vs depth plot ~ Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements EX 21. I hereby certify that, j,t~e foregoing is true and'correct to the best of my knowledge " Signed/./ ~//'~'.'~.2'.c.',~ Title Senior Production Foreman Date 12/15/'8 Commission Use Only Permit Number ! APl number " i Approval date' ' ' I See cover 'etter : _~"?~ff~'_~_,~ ' 50-- O"~ 9- 2-----//~;;~¢? 01 / 04 / 90 for other requirements Conditions of approval Samples req'uired E} Yes ~ No Mud log required Ei Yes '..~No Hydrogen sulfide measures [] Yes /~_No Directional survey required ~¢'Yes ~ No Required working p/r,e'~re for~ BOP.,~.;~2/M4) Fq.,3M;// ~ 5M; [] 10M; [] 15M Other: ' -" by order of Approved by ~._ ~/. "7. /.,,. ~,_ ~,/,.¢ ~/¢~~~) Commissioner. the commission Date, ..,. ..... .. Form 10-401 Rev. Sub(q n triplicate N 0 IR VICINITY MAP 8 PAD L SECTION 8, TI3N, RIOE, UMIAT MERIDIAN LOCATION IN SECTION WELL i FROM NORTH LINE : FROM WEST LINE , i { 1970' : 158' · · / STATE PLANE COORDINATES WELL ~ NORTHINGS :' LASTINGS I ~ 6,031,499.2 : 544, 758.7 · .: · ; ° : ZONE 4 ·O~C,~r' .' 0~~Bg- ..,,,~s~;ODET lC,' ......... ; ........................... POSITIONS "i .............. ~$,~0~'~ ....... :: ..... , ............................. i'~,~, ~6~c0 WELL ," LATITUDE ~ LONGITUDE AS- BUILT .~:,,,,~,,.,._ . .... ,,,, ............ , ................................ , ................ ~I~BU~"' ~ ! 7o° 29' 4¢ : ~49° ~8' oz" ; · · ! .: · CERTIFICATE OF SURVEYOR: I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND ~-~ THIS PLAT REPRESENTS A LOCATION SURVEY ~,.~.t~'~.~ SURV~YEO FOR, CONOCO [. I [~[-I'q '.~- DATE 7-24-84 ~,~. ~ ,~, 3340 A/cdc Boulevard, Suite 201, Anchorage, Alaska 99503 S~LE I" : 200' UNIT 35,744 AC,'~ T 13 N R 9 E T 13N R 10 E T 13 N R 11 E MILNE POIN~ -- co.oc ET,L 7. O 11 7 ADL-47434 2560 AC ADL-47433 ~60 AC '~D~743~8 A~ ~ ~-255~ 2533 ~C ..... ~ , ,- ._.~ / . 18 17 . 16 15 23 24 ~1 ADL2~S516 2 21 22 ADL-47439 ADL-315846 AO~-~tSe4e ' AOL-47437 2560 AC ~-25514 2560 AC ADL-25515 2~4 AC t2eO AC 1280 AC , ADL-47438 25 ~C, 1280 AC ,,.1280 Acj , 30 2~ 2~ 2~ 2~ · 25 30 29 EXI~IBIT A ~ ~ ~ 31 3 ~3 34 B.eed on Uml~ ~ ~ Mllee 0 ~ ~ ~ ~ 2235AC 20 sADL725~ 256OAC ADL-25518 2560 AC ADL-28231 2555 AC --. i i ii iii ii i i I II I II I o ~ CH(Y. ~ A.CO ' IOHlO 6/84 UNIT AREA Meridlan.Alalkt I 2 ~ I Scale MUO CLEANER PUM~$ MUO TROUGH w~T~RPUt4P CH'-~GE 14 · I ,, CHANGE AGITATO~ -""~'/1"'"- BUTTERFLY V/., L VC ~ GATE: VALV£ .~.~ MuD GU~ ~ PSv ~ SUCI~N V~VE ;.uG 27E FLOW SHEET iOJ ~vanoS l~ellixn~ pu~ ~tun aloa~s~a pu~ jol~Inmn~oe uoIIe~ 091 (;) ~pnI~ul IO~lUO* ~IlnsJplH · li~aaa palsal aanssa~d ~ dlll q~ea uo paleaado aq ol 3dO~ 'palelado qnq 9 d~,[a q~la R~ SSela V9 aads 9 £~ IdY s~aam 8uIlez (;) (~) (~) (~) dOI nVll · oool Idv . e/~ e~ ~ dog I~V¥ , ~000~ IdV ,, II/SCl (~) IN I"{ 9NISVD 3OVRMfi$ ,,~/~-6 MOR ]3V15 JOR .._.. AINI'I AHlOd ~ FROM MUD KILL MANIFOLD FRO)~ REi, IOTE HIGH ¢----('Tf'~. m--.2 k._.(..~ REMOTE PRr~SURF GAGE SENSOI~ PRESSURE PU~IP --" '- LLi '~ NOTE: ~ HYDRAULIC CONTROLLED '"' REMOTE OPERATED H11}RAULIC CONTROL S¥STEu FOR BOP STACK 8 CHOKE k~,~,qIFOLD TO INCLUDE (5~ STATIOti CCNIROL MANIFOLD LOCATED REI/OTEL¥ VIITH 3000 PSI ACCUqULATOR 8 160 GAl.. RESERYOIR 8 AUX. ENERGY SOURCE. STA. 60NTROL MAN/FOLD PLUS ~RIABLE CHOKE C..,ONTROL TO 8E lOCATED ON RIG FLOOR. KILL 8~ CHGKE MANIFOLDS TO MEET APl RP53 CL. 5M Sl"D$. $. KILL ~/ANIFOLD SIZE- RATING Z'- 5000 4. CHOKE MANIFOLD SIZE - RATING $"- 5000 ADJUSTABLE ~OKE /\ (5) ~ DRILLING cl. ~ SPOOL ~ HYDRAULIC CONTROLLED A R EMOTE OPERATED ~ ~ SHAKER 1 TO ATMOSPHERIC MUD/GAS SEPARATOR DE g ~ 0 t?J9 Anchorage CHOKE (t KILL UANIFOLDS FOR ClS/8'~ ~ 7" OD CASING BOP STACK BOP I~ANIFOLD LAYOUT- CONOCO, INC. : CONOCO, INC, MILNE POINT UNIT DIVERTER STACK FOR 13 318' -CONDUCTOR FILL kip LIN[ FL{:) LINI STARTi~O H[AD 13 3IS' C,I$1NG 1. The hydraulic control syste~ will be in accordance with AP1 specifications and AOGCC requirements. 2. The HCR valve will open when the preventer closes. A single 10" relief line will run off of the drilling spool HCR valve and will have a targeted downstream tee for downwind diversion. Valves on both sides of the tee will be full opening and linked together to enable one to always be open and the other to be closed. SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT L-3 Conoco Inc. 3201.C Street, Suite 200 Anchorage, AK 99503 I · Be Ce II. A. Be Ce De III. Casing and Cementing Program The 13-3/8" conductor will be set at 80' below the surface then cemented to the surface with +_480 sacks Permafrost type "C". The 9-5/8" surface casing will be cemented in I stage using +_865 sacks of Permafrost "E" cement followed by +_326 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. The 7" production casing will be cemented in two stages. The first stage will be cemented as the attached program shows. The secondary cement job will consist of +180 sacks of permafrost type "C" cement followed by +_60 barrels of Arctic Pack pumped down the 7" x 9-5/8" annulus. Drilling Fluid Program 0-500' 9.0 ppg freshwater spud mud. 500'-5000' 9.0 ppg-9.8 ppg freshwater spud mud.~~~~y 5000'-8000' 9.0 ppg-9.5 ppg dispersed. 8000'-TD 10.4 ppg dispersed. Dri 11 lng Program Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River Field. The mud system will be low solids, non- dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at TD will be 10.4 ppg. A 20", 2000 psi diverter will be installed on the 13-3/8" conductor for drilling surface hole. A 13-3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure test will be performed as per State Regulations. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is E-1 with 15' of closure at a depth of 761'. Dead crude will be placed in the 7"x 9-5/8" annulus after disposing of excess drilling fluids. The well will be perforated and completed after releasing the drilling rig. A~ B, Drill a 30" conductor hole to +_80' and set 13-3/8" conductor. Drill a ]2-1/4" surface hole to -+4563' TVD (5730' MD) and set 9- 5/8" casing. C. Drill an 8-1/2" production hole to 9908' MD and set 7" casing. TVD MD FORMATION BIT MUD WT YP PV YIS FL O' O' Gravel 1-1-4 9.0 32 20 90 ]5 500' 500' Sand/Clay 1-1-4 9.0 25 20 65 15 2500' 2767' Surface Casing 3607' 4275' "K" Sands 1-1-4 9.2 25 15 65 14 3696' 4275' "M" Sands 1-1-4 9.4 25 15 65 13 3952' 4612' "N" Sands 1-1-4 9.4 25 15 65 12 4124' 4821' "0" Sands 1-1-4 9.4 25 ]5 65 6811' ' Kup Top 1-1-6 10.2 8 ]2 35 5 7035' 8514' L K (1) 1-1-6 10.2 8 12 35 5 7054' 8540' L K (2) 1-1-6 10.2 8 12 35 5 7235' 8750' B L K 1-1-6 10.4 6 12 35 5 7335' 8895' TD 1-1-6 10.4 6 12 35 5 * The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300' TVD a Sundry Notice will be submitted. * L-1 is presently shutin and will be continue to be shutin while drilling L-3. Page 2 Conco Inc. November 30, 1989 WELL DATA Hole Size: Casing Size: Excess: BHCT: Depths: Mud Weight: Est. Frac Grad.: 8.5 Inch 7 Inch 50% 130 Degrees TVD MD 9 5/8 Inch Surface 2500 Feet 3000 Feet 7 Inch T.D. 7335 Feet 9040 Feet T.O.C. 3600 Feet + 4100 Feet 10.4 PPG .65 psi/ft DISCUSSION To follow, is a Static Foam Cement Design Program which calculates both foamed cement and nitrogen volumes. This data is then input into the Cement Job Simulator Program which models the job dynamic- ally. A major point that needs to be brought out when analyzing both programs is that we need to add 25 barrels of slurry in order to bring the top of cement up to approximately 4400 feet. In order for this job to be successful, an accurate caliper log needs to be run to determine the hole size. In both of these computer designs I assumed a 50% excess factor for all cement volumes. As you can see, the height or our foamed cement is directly dependant on the hydrostatic head. CEMENT DESCRIPTION Foamed Cement will contain: Premium Cement with .4% HALAD-344, .2% CFR-3, .08% LWL, 1.5% Howco-Suds and .75%,HC-2 both based on the volume of mixing water required. ' Slurry Weight: Foamed Slurry Weight: Slurry Volume: Water Required: Volume Needed: 15.5 PPG 10.5 PPG 1.8 Cu. Ft. 5.2 Gal/Sk 85 Bbl's RECEIVED Page 3 Conoco Inc. November 30, 1989 Tail Slurry will contain: Premium Cement with .4% HALAD-344, .2% CFR-3, .08% LWL Slurry Weight: Slurry Volume: Water Required: Volume Needed: 15.5 PPG 1.18 PPG 5.2 Gal/Sk 33 Bbl's Spacer Used: Type: Sepiolite Weight: 10 PPG It should be noted that only one slurry will be needed for the job. The surfactant and stabilizer (Howco-Suds and HC-2) will be metered into the mixing water. RECEIVED · .C.L ~2 ;~,' , , FOAM CEMENT DE$I,~-- PROGRAM W/JOB CALCULAT I OI.F--~ O P T IONS - - VERf ION 5-16-83 CONOCO,INC. WELL NO. :L-3 CO. REP. :DAVE MOUNTJOY JOB TYPE :? IN. PRODUCTION CASING INTERVAL NO. FLUID DENSITY - LB/GAl. SURFACE DOWN-HOLE LENGTH UN- FT FOAMED AVG. TOP BOTTOM 3600. 10.0 10.0 10.0 10.0 500. !5.5 I0.$ 10.3 10.7 500. 15.5 10.5 10.3 !0.7 500. 15.5 10.$ 10.3 10.7 500, 15.5 I0.$ 10.3 10.7 760. i$.$ !0.5 10.3 10.7 975. !5.S 15.5 15.5 15.5 PRESSURE AVG. PSI TEMP DEG TOP BOTTOM F 0. 1870. 47. 1870. £143. 78. 2143. 2416. 85. 2416. 2688. 93. 26BB. 2961. 100. 2961. 3376. 110. 3376. 4161. 123. AVG. EXP. GAS FACTOR SCF BBLS FOAM PER PER BBL BBL SLURRY , 405. 454. 502. 547. 600. 0. 1.000 1.544 1.552 1.559 1.567 1.576 1.000 RECEIVED ~ i~-'.~ t.~.,.:~' CUSTOMER: CONOCO,INC. WELL DE$CRIPTIC~-'' L-3 PROVIDED BY: HA_~IBURTON SERVICES FLUIDS FLUID FLUID DENSITY PV YP VOLUME 1-IF NUMBER DESCRIPTION LB ...... GAL CP LB/100 SQ FT BBLS FOAMED MUD I0.00 1~.0 6.0 ~39.6 0 SEPOLITE I0.00 2.5 2.0 ~0.0 0 FOAMED CEMENT 15.50 58.0 ~8.0 85.0 1 TAIL CEMENT 15.50 58.0 18.0 33.0 0 MUD DISPLACMENT 10.00 12.0 6.0 3~5.0 0 TRACER FLUID NZ TABLE VOL. CMT. BBL$ N2 PER STAGE STARTING ENDING SCF/'BBL 0.0 11.0 $05.0 I1.0 21.9 ~54.0 21.9 32.8 SO2.O 32.8 $3.6 557.0 43.6 59.9 600.0 GEOMETRIES TABLE MEASURED ANGLE OF GEOMETRY DEPTH DEVIATION NUMBER START END START END 1 INNER CASING-ID-- 5.276 O. 90~0. 35.4 35.~ ~ 9 158 ¥ 7 nnn ANN-INC ~0 % ~v 90~0 ~000 ~ ~' '3 8.92! BY 7.000 ANNULUS 3000. 0. 36.0 O.0 RECEIVED - CUSTOMER: CO,NUCO,if,~u. WELL DESCRIPTION: L-3 ** PROVIDED BY: HA~ ~URTON' SERVICES ** PUMP RATES TABLE THE PUMP RATE FOR THE .... MUD -- WILL BE 4.0 BPM. THE PUMP RATE FOR THE .... SEPOLITE -- WILL BE 4.0 BPM. THE PUMP RATE FOR THE .... FOAMED CEMENT ~- WILL BE 4.0 BPM. THE PUMP RATE FOR THE .... TAIL CEMENT -- WILL BE 4.0 BPM. THE PUMP RATE FOR THE .... MUD DISPLACMENT -- WILL BE 8.0 BPM. WELL PARAMETERS SURFACE TEMPERATURE (F) CIRCULATING TEMPERATURE (F) .... BACK-PRESSURE (PSI) FRAC ZONE DEPTH (FT) FRAC ZONE GRADIENT (LB/GAL) .... ,.0.0 130.0 14.7 9040.0 1£.$ ** CUSTOMER: CONOCO,INC. ~ ~* WELL DE$CRIPTI~.: L-3 ~-~ *~ ** PROVIDED BY: H, ~IBURTON SERVICES *~ **************************************************************** TURBULENCE TABLE THIS TABLE LISTS THE RATES REQUIRED TO ACHIEVE TURBULENCE IN THE NUMBER 2 GEOMETRY. FLUID DESCRIPTION RATE FOR TURBULENCE (BPM) MUD 8. ! SEPOLITE FOAMED CEMENT 16.1 TAIL CEMENT 16.1 MUD DISPLACMENT 8.1 ..... PRESSURE TO BREAK CIRCULATION TABLE ..... SURFACE GEL STRENGTH PRESSURE LB/100 SQ-FT PSI PRESSURE PRESSURE AT TD AT 9040. FT PSI PSI 10 193. 4185. 4185. ZS ~83. 4~03. ~03. $0 967. 4767. 4767. i00 !934. 5493. $493. ~50 2900. 62Z0. 6220. 200 3867. 69~7. 6947. HYDROSTATIC PRESSURE: AT AT TD 9040. FT = ~0~,0. PSI = 40~0. PSI RECEIVED CUSTOMER: CONOCO,INC. WELL DESCRIPTI~,: L-3 PROVIDED BY: h. ~LIBURTON SERVICES ..... VOLUME & RATE CALCULATIONS ..... TIME (MIN) 0.0 0.'3 2.0 3.8 5.5 7.3 9.0 10.0 10.3 12.0 13.8 15.5 17.3 19,0 20.8 Z£.5 24.3 Z6.0 27.8 29.5 31.3 31.5 33.3 35.0 36.8 38.5 39.5 SURFACE UNFOAMED LIQUID TOTAL FLUID LEADING EDGE FLUID VOLUME RATE OUT OF TRACER IN OUT IN OUT IN OUT VOLUME RATE FLUID (BBLS) (BPM) (~BLS) (BPM) 0.0 0.0 4.0 4.0 0.0 4.0 O. 1.0 1.0 4.0 4.0 1.0 4.0 O. 8.0 8.0 4.0 4.0 8.0 4.0 O. 15.0 15.0 4.0 4.0 15.0 4.0 O. 22.0 22.0 4.0 4'.0 22.0 4.0 O. 2.9.0 2.9.0 4.0 4.0 2.9.0 4.0 O. 36.0 36.0 4.0 4.0 36.0 4.0 O. 40,0 40.0 4.0 4.0 40.0 4.0 O. 41.0 42.2 4.0 9.0 42.2 9.0 -59. 48.0 57.7 4.0 8. 9 57.7 8.9 -464. 55.0 '72,5 4.0 8.4 72.5 8.4 -850. 62.0 86.7 4.0 8.1 86.7 8.1 -1ZZ1, 69,0 100,6 4.0 8.0 100.6 8.0 -1585. 76.0 115.0 4,0 8.2 115.0 8.2 -1961. 83.0 128.4 4.0 7.6 1ZB.4 7.6 -2310. 90.0 141.7 4.0 7.6 141.7 7.6 -2659. 97.0 I55.0 4.0 7.6 155.0 7.6 -3004. 104.0 167.3 4.0 7.1 1~7.3 7.1 -3328. Ii1.0 179.6 4.0 7.0 179.6 7.0 -3649. 118.0 191.5 4.0 6.8 191.5 6.8 -3961. 125.0 Z03.4 4.0 6.7 203.4 6.7 -4Z70. IZ6,0 204.8 4.0 5.6 204.8 5.6 -4306. 133.0 209.7 4.0 2.8 209.7 Z.8 -4435. 140.0 214.6 4.0 2.8 214.6 2.8 -4563. 147.0 219.4 4.0 2.8 219.4 Z.B -4690. 154.0 224.4 4.0 2.8 224.4 2.8 -4818. 158.0 227.4 4.0 3.0 227.4 3.0 -4897. 40.5 5 ! 43.I 5 1 44.0 5 1 44.9 5 1 45.8 5 ! 47.5 5 1 48.4 5 1 49. '3 5 1 50.! 5 1 ********** DISPLACEMENT IS STARTING *********************** 166.0 232.7 8 · 0 5.3 Z3Z. 7 5 · 3 - 5036. 187.0 249.Z 8,0 6, 3 249.Z 6.3 -5467, 194.0 Z54,2 8.0 5.7 254.2 5.7 -5598. 201.0 259.6 8.0 6.2 259.6 6,Z -$740. ZO8.O 265 222.0 277.0 8.0 6.7 277.0 6.7 -6193. 2Za n 287 8 ~ 0 6 6 ~82 8 6 6 -6~4c . ~ ~ 8 0 6 ~ ~°4 f g ~ -E.~.c~' CUSTOMER: CONOCO,INC. ~ WELL DESCRIPTIQ-~I: L-3 ._~ ** PROVIDED BY: }. LIBURTON SERVICES *~ ..... VOLUME & RATE CALCULATIONS ..... SURFACE UNFOAMED LIQUID TOTAL FLUID TIME FLUID VOLUME RATE OUT IN OUT IN OUT IN OUT VOLUME RATE (MIN) (BBL$) (BPM) (BBLS) (BPM) 51.9 5 1 257.0 306.8 8.0 7.0 306.8 7.0 52.8 $ 1 264.0 312.9 8.0 6.9 312.9 6.9 53.6 $ 1 271.0 318.9 8.0 6.8 318.9 6.8 54.5 $ I 278.0 325.0 8.0 7.0 3Z$.0 7.0 55.4 5 1 285.0 331.3 8.0 7.2 331.3 7.2 57.1 5 1 299.0 344.0 8.0 7.3 344.0 7.3 LEADING EDGE OF TRACER FLUID (FT) -6973. -7132. -7289. -7449. -7613. -7947. ************** SEPOLITE IS ENTERING THE ANNULUS 58.0 $ I 306.0 350.1 8.0 6.9 350.1 6.9 -8105. 59.8 $ 1 320.0 363.0 8.0 7.4 363.0 60.6 $ 1 327.0 369.3 8.0 7.2 369.3 7.Z -8606. 61.5 5 I 334.0 375.8 8.0 7.4 375.8 7.4 -8775. FOAMED CEMENT IS ENTERING THE ANNULUS 63.3 5 1 348.0 388.8 8.0 7.4 388.8 7.4 8955. 64.1 5 1 356.0 394.6 8.0 6.7 394.6 6.7 878£. 65.0 5 1 36Z.0 400.9 8.0 7.2 400.9 7.Z 8596. 66.8 5 1 376.0 413.7 8.0 7.3 413.7 7.3 8219. 67.6 S 1 383.0 420.1 8.0 7.3 420.1 7.3 8029. 68.5 5 1 390.0 426.7 8.0 7.5 426.7 7.5 7835. 69.4 5 I 397.0 433.3 8.0 7.6 433.3 7.6 7639. 71.1 5 1 411.0 446.9 8.0 7.8 446.9 7.8 7Z38. 72.0 $ ! 418.0 453.8 8.0 7.9 453.8 7.9 7035. 7Z.9 5 i 425.0 460.8 8.0 8.0 460.8 8.0 6829. 73.8 5 ! 432.0 467.8 8.0 8.0 467.8 8.0 6621. 74.6 $ ! 439.0 ~74.9 8.0 8.1 ~74.9 8.1 6412. 75.5 5 ! 446.0 482.1 8.0 8.2 4'82.1 8.2 6200. 76.4 $ 1 453.0 489.4 8.0 8.3 489.4 8.3 5985. 77.3 5 1 460.0 496.8 8.0 8.5 496.8 8.5 5766. 78.1 $ 1 467.0 504.2 8.0 8.5 50~.£ 8.5 5548. TAIL CEMENT IS ENTERING THE ANNULUS 79.0 5 i 474.0 ~11.5 8.0 8.4 5!!.5 8.4 5331. 79.9 5 1 481.0 519.2 8.0 8.8 519.2 8.8 5103. ~0 ~ ~ I -~ ~] S26 ~ ~ 0 8 7 c~6 9 8 7 ~878 81.6 5 ! 495.0 53~.6 8.0 ~.9 534.6 ~.9 46~9. 82.6 5 1 503.0 543.0 a.0 8.4 5+3.0 8.& &~01. CUSTOMER: CONOCO,INC. ~ WELL DESCRIPT~3n%!: L-3 ~-~, PROVIDED BY: ~ ,LIBfJRTON SERVICES ** FREE FALL CALCULATIONS TIME (MIN) 0.0 0.3 £.0 3.8 5,5 7.3 9.0 10.0 10.3 12,0 13.8 15.5 17.3 19,0 20.8 ZZ.5 24.3 26,0 27.8 29.5 31.3 31.5 33.3 35.0 36.8 38.5 39.5 40.5 43,! 44,0 44.9 ~5,8 47.5 48,4 49,3 50.i EQUIVALENT URFACE FLUID SURFACE CIRCULATING FREE FLUID VOLUME PRESSURE DENSITY FALL N OUT IN IN OUT TD ZONE HEIGHT (BBLS) (PSI) (LBS/GAL) (FT) 1 1 0.0 194.6 15. 10.4 10.~ 0. Z 1 1.0 406.3 15. 10.4 10.4 0. £ 1 8,0 406,3 15. 10.4 10.4 O. £ 1 15.0 405.0 15. 10.4 10.4 O. Z 1 2Z,O 405.0 15. 10.4 10.4 O. £ 1 Zg,0 403,7 15. 10.4 10,4 O. £ 1 36.0 403,7 15. 10.4 10,4 0. 2 I 40.0 402.7 15, 10.4 10.4 0. 3 1 41.0 697.7 15. 11.0 11.0 O. 3 1 46,0 667.6 15. 10.8 10.6 0. 3 1 55,0 684.1 15, 10.7 10.7 O. 3 I 62,0 702.0 15. 10.7 10.7 0. 3 ! 69.0 728.1 '14. 10.6 10.6 O. 3 1 76.0 731.4 15. i0.5 10.5 O. 3 1 83.0 754.1 15. 10.S 10.S 0. 3 I 90.0 784.7 14. 10.5 10.5 0. 3 1 97.0 802.9 15. 10.5 10.5 0. 3 1 104.0 822.5 15. 10.4 10.4 0. 3 I 111.0 839.4 15. 10.4 10.4 0. 3 1 118.0 853.3 15, 10,4 10.4 0. 3 1 125.0 864,7 15. 10.4 10.4 O. 4 I 1Z6.0 835.4 15. 10.4 10.4 0. 4 ! !33,0 757,7 15. 10.4 10.4 0. 4 1 140.0 688.0 15. 10.4 10.4 0. 4 1 147.0 619,5 15. 10.4 10.4 0, 4 I !54.0 552.7 15. 10.4 10.4 O. 4 1 158.0 513.8 15. 10.4 10.4 0. DISPLACEMENT IS LEADING EDGE OF TRACER FLUID (FT) 0. 0. 0. 0. 0. 0. 0. O. -59. -464. -850. -1585. -1961. -2310. -Z659. -3004. -3328. -3649. -3961. -4270. -4306. -4435. -4563, -4690. -4818, -4897. STARTING *********************** 5 ! 168.0 505.4 14. 10.4 10.4 5 I i87.0 422.6 15. 10.4 10.4 5 1 194,0 423.4 14. 10.4 10.4 5 ! 201,0 412.2 15. 10,4 i0,4 5 I 2'38,0 394.4 I$, 10.4 !0,4 5 ! 2Z2,0 353.0 15, !0.~ 10.4 5 1 229.0 339.8 15, 10.4 !0.4 5 i 236.0 333.8 15. 10.4 10.4' 5 I 243.0 323.0 !S. '!0.5 1'3.5 -5036. -5467, -5598. -5740. -5886. -6!93. -6345. -6496, -6654, CUSTOMER: CONOCO,INC, WELL DESCRIPTIOAIj L-3 PROVIDED BY: H. IBURTON ..... FREE FALL CALCULATIONS EQUIVALENT SURFACE FLUID SURFACE CIRCULATING FREE TIME FLUID VOLUME PRESSURE DENSITY FALL IN OUT IN IN OUT TD ZONE HEIGHT (MIN) (BBLS) (PSI) (LBS/GAL) (FT) S1.9 S I 257.0 Z88.Z 15. 10.4 10.4 0. 52.8 5 1 264,0 277.5 15. 10.4 10.4 O. 53.6 5 1 271.0 274.0 15. 10.4 10.4 O. 54.5 5 1 278.0 263.9 15. 10.5 10.5 O. 55.4 $ 1 285.0 255.4 15. 10.S 10.S 0. 57.1 5 1 299,0 224.3 14. 10.4 10.4 O. ***55.***-****** SEPOLITE IS ENTERING THE ANNULUS 58.0 5 1 306,0 £Z&.3 15. 10.4 10.4 59.8 $ 1 320.0 207.2 15. 10.4 10.4 60.6 5 1 3Z7,0 213.2 14. 10.5 10.5 61.5 5 1 334.0 209.0 15. 10.5 10.5 FOAMED CEMENT IS ENTERING THE ANNULUS 63.3 5 1 348.0 188.5 15. 10.4 10.4 64.1 5 1 355.0 gZ6.0 15. 10.5 10.5 65.0 5 I 36Z,0 265.4 15. 10.6 10.6 66.8 5 1 376.0 333,1 IS. 10.8 10,8 67.6 5 1 383.0 385.7 14. 10.9 10.9 68.5 5 1 390.0 425.3 14. 11.0 11.0 69.4 S 1 397.0 461.0 1S. 11.1 11.1 71.I 5 I 411.0 529.1 15. 11.3 11.3 72.0 S 1 418.0 570.1 1S. 11.4 11.4 7Z.9 5 1 425.0 607.4 15. 11.4 11.4 73.8 5 1 432.0 645.1 15. !1.5 11.5 74,6 5 1 439.0 683.5 15. 11.6 11.6 75.5 5 1 446.0 722.6 iS. 11.7 11.7 76.4 5 1 453.0 773.5 15. 11.8 11.8 77.3 S 1 ~60.0 814.3 1S. 11.9 11.9 78.1 5 1 467.0 852.4 14. 12.0 I2.0 **5,5*****5*5* TAIL CEMENT IS ENTERING THE ANNUL US 79,0 ~ 1 474.0 9~4,9 15. 1Z.1 1Z.1 79.9 $ 1 481.0 1020.9 lS, 12.2 12.2 S0,8 5 I 488,0 1114. I !$. 12.4 12.4 81.5 S ! 495.0 1210.9 '1.5. 12.5 12.5 8-~....6 $ 1 ~cO'~.0 135~...4 15. I~,.. 7 12.7 LEADING EDGE OF TRACER FLUID (FT) -6973. -7132. -7289. -7449, -7613. -7947. 0. -8105. 0. -8441. 0. -8606, 0. -8775. . O. O. O. O. O, O. O. O. O, O. O. O. O. O. O. 8955. 8782. 8596. 8219. 8029. 7835. 7639. 7238. 7035. 6829. 6621. 641Z. 6£00. 5985. 5766. 5548. O. 5331, O. $103. O. 4878. O. 4649. O. 4401. IF THE ANNULUS IS SHUT IN WITH AFTER THE PLUG !S BUMPED THE EQUIVALENT GRADIENT ON FRAC ~ONE ( ~n4a FT~ ~OiLL BE 11 n ~S,'"C~L THE ;.::asl 0il & C's Co!':$. ** CUSTOMER: CONOCO,INC *~ WELL DESCRIPTLa~: ** PROVTDED. ..... HOOK LOAD SIMULATION ..... CASING WEIGHT 2350~0. LBF STATIC HOOK LOAD 199123. LBF MAXIMUM HOOK LOAD 233477. L~F MINIMUM HOOK LOAD 863~3. LBF VOLUME PUMPED, PRIOR TO MAXIMUM HOOK LOAD 187. BBLS VOLUME PUMPED, PRIOR TO MINIMUM HOOK LOAD 503. 8HL$ STAGE NO. LENGTH (FT) ! SOO. $00. 3 SO0. SOO. 760. 6 97S. S V W/ ( LURRi OLUME EXCESS B~LS) 11.0 10.9 10.9 10.8 16.3 33.0 EXCESS (%) 50. $0. 50. $0. SO. SO. CUM. SLURRY VOLUME (BBLS) 11.0 21.9 32.7 43.6 59.9 9Z.9 PUMP RATE (BPM) 4.0 4.0 4.0 4.0 4.0 4.0 WATER VOLUME (BBLS) 6.5 6.4 6.4 6.4 9.6 19.5 CUM MIX WATER VOLUME (BBLS) 6. 13. 19. Z6. 35. TOTAL ELAPSED TIME (MIN) 2.7 8.2 10.9 15.0 Z3.Z STAGE NO. LENGTH (FT) 1 2 SO0. 3 SO0, 4 SO0. 5 7GO, 6 975. CUM. SLURRY VOLUME (BBLS) 11.0 Zl.9 32.7 43.6 59.9 92.9 FOAMER RATE (GPM) 2.2 2.2 0.0 FOAMER VOLUME (GAL) 6.1 6.1 6.0 6.0 9.1 0.0 CUM. FOAMER VOLUME (GAL) 6. 18. 24. 33. 33. N2 CONC. ( S CF/EIB L 405 454 507. 547 600 0. N£ RATE (SCFM) 1618 1817 Z006 2188 Z401 0. .CUM. NZ VOLUME (SCF) 4439. 9396. 14845. 20758. 30566. 30566. TOTAL ELAPSED TIME (MIN) 2.7 8.2 10,9 15.0 23.2 DRY MIX TO BLEND (SKS) UNFOAMED SLURRY VOL (BBLS) WATER REQUIREMENT (GAL/SK) YIELD (CUFT/SK) ZSS. 157, 60. 33. 5.£0 S .ZO 1.18 1.18 R CEIVEO Ae B. C. D. E. F. G. H. I. J. TIME ESTIMATE Rig Up Drill Surface Hole Run Surface Casing and Cement Drill Out and Test Drill Production Hole Log Open Hole Condition, POOH, L.D. Run Producti on Casing Cement Production CaSing Move Rig Hours Days Cum. Day~ 10 0.42 0.42 36 1.50 1.92 36 1.50 3.42 8 0.33 3.75 200 8.33 12.08 36 1.50 13.88 20 0.83 14.41 10 0.42 14.83 10 0.42 15.25 10 0.42 15.67 TOTALS 376 15.67 15.67 WP/PERMSUPP MILNE POINI INIT WELL -/_ -~ -1 -2 -3 -4 -5 -6 -7 -8 -9 10 11 Rate vs. Depth 0.00 2.00 4.00 6.00 8.00 10.00 12.00 14.00 16.00 18.00 RIG DAYS HORIZONTAL PROJECTION / SCALE 1 IN. - .000 FEET CONOCO, ;.ne, Pad L. We I I No ~ ;3 Rev teed Pr'oposa I HI Ine Point: Unit:, Nor. i:h Si ope. Alaska 5000 3000 WEST-EAST 4000 3000 2000 1000 0 I I , i' I I 1000 i TD LOCAT'[ON t 4.21 ' FNL, 93;0' Ft4L SEC. 7', T!3;#, R!OE z TARGET LOC^T!ON~ $00' FHL. 1150' FWL SEC. 7. T1,3N. RIOE 20OO . 1000 _ ~ 1000 _ TAR / THO- ~EST 4210 ~'~ ~; ~ .... N 70 DEG 8 MI N 14 4476' (TO TARGET) SURFACE LOCATION~ 2021' FNL. 190' FWL SEC. 8. T13N. R1CE CONOCO, ! no. ~- Ped L, Well Not MI Ine Point Unit, Revised Proposal North Slope, Aleske 0 - RKB ELEVATION,~' 1 000 _ 2000 _ 3000 _ 4000. 5000 _ 6000 _ 7000 _ 8000 _ : 0 KOP 5 IO TVD=500 TMD=500 DEP=O BUILD 2.5 DEG PER lO0 FT 25 3O EOB TVD=1908 TMD=2016 DEP=484 9 5/8" CSO PT TVD=2500 THD=2767 DEP=945 AVERAGE ANGLE 37 DEG 55 HI N TAROET/ TOP KUP SNDS TVD:7035 THD=8515 DEP=4476 TD / 7" LINER TVD=7335 THD=8895 DEP--4710 i i i 1000 2000 3000 VI=RT T I~.AI .qFP. T T RI,,! I 4000 I 5OOO 1850 - 1900 - 0 50 100 I I 1950 250 I , , '-.- .., -,,.,,., i ~ tSO0 ~ N~O0 ~ .~ _ i ~$00 2000 - ! ""I 1.00 i ~.. ' '-~oo --- '~°° 2050 - . ~, "~?,o~o t .,~, ~ r'.. , 5700 .._ J' 5900 21 O0 ~: J ~ (.'~ J2150 _ ', / 65o° ~ ~ ~ , i . 0 50 1 O0 1 50 200 250 300 350 /°"~ 1 O0 "'/900 · 500 I 300 I 350 40" _ ~8So _ 1 900 _ 1 950. _ 2000 I~2050 _ 2100 _ 2150 I 40O CORPORATION ":'"*~'; PIJEIILO, COLO, .... ~ONoco, INC, · ?ATTN: LUCy FEL! · *~*'"* ~' ap 0 BOX 44~:$'" . CONOCO HPU D;=$ CT, _ L u~'.,%ii. L~ ,WUUL~ t L:f~''707 659-6390 002 ~ t mil, CI~&I STEEL COBPORATION P.O. Bo~ 316 Pueblos Colorsdo 81002 Customer order~ 907-1£0789 CF&I Order; Number s lC ~ P $ $1 Cu N~ er Mu ~u.~ ~ B Ti C~ 1 ,------ . _ '--' ,i~ _ - ..... i,liii. · Il~II"*'Im$II~ ......Iill.4IIIlldIl'i · 33899 33900 47330 47331 L 0.24 0.93 .009 .006 .19 .19 .07 0.05 .013 .015 .000 ,0o04..004 .0014 L 0.23 0.99 .014 .004 ,22 .24 .07 0.09 .012 .0L$ .000 .00(,$ .004 .00I¢ r., 0.26 0.97 .03.3 ,003 .23 ,2¢ .o? o.08 ,o31 .o15 .ooo .00(.,4 .oo¢ L 0.25 ,),~4 .011 .004 .20 .13 .07 0.08 .010 .0~8 .000 .0004 .004 .0015 Hea~ Lo~ iSample Number Number INum~er 33899 33900 1 ¢?33O 4733~ Original Dimensions 1. ¢s2 x .'.~z- 1.493 X .3'7~ 1.490 X .386 PSI PSI In./In. Pct. BHNI 5'S-;~OO '-~, 76'0 2 ~4. o o 55,700 82,400 2 32,0 0 55,800 81,600 2 34.0 0 1.493 ~ .~65 ~ 56,000 80,600 2 ~8.0 0 ALL MELTING AND ~u%NUFACTURING PROCESSES OF THIS TEST ~RTIFICAT~J OCCURRED IN THE UNITED STATF.$ OF AMERICA, This is to certify that the material subject to this certifi¢~ of inspection and Notice of Limited W~rranty was m.~nufactured in accordance with and conforms to the specifications designated hereon. N0 ~RANTY IS ~PRE$$ED 0R IMPLIED otheT than those set forth above. In ~rticular, CF&I Steel Corporation specifically disclaims any implied warranty of meuchantabilit}* o~' fitneSS for intende~purpo~e, ~uali~y Cont'rol Depart~ CONOCO MPU OPS CTR~?-659-6190 00? · .CF&I STEEL CORPORATION P 0 BOX 3~6 CONOCO, NC. $ .& ..,., I~L~]I3PT'~Z~t & T~X EXEMP? TAG FOR:COHOCQ INC. $&T WHSE-~LASKA P.O. CONOCO XTEN NO, $£AHLE$$ STEEL CASING (D~C.T.G.) H & g GRADE J-55 FOR ARCTIC SERVICE ?-5/8 IN ?'.352 WALL ~a.~e LB/FY R-3 BUTYR£$~ T/C ' · 2~ ~ -0723-2- ~ ' HEAT QTY UOM THRD LENGTH 3-3899 16 JNT 3-39e0 26 JNT 20.7 4-7~3e 2~ JNT 2~o7 4-733! ~2 JNT 2e,7 BRL, TO SHIP TOTAL TOTAL NET WT. 679,i 1t12,9 ,? 24449 40~64 47909 PA F_ do ~ 12/28/89 16:40 CONOCO MPU OPS CTR 90?-659-6390 003 ~ERTIFICATE OF INSPECTION ' co NOCO, XNC. 4 0 · TAG FOR:CONOCO !NC. $8~T WHSE.-RLASKR P,O,. CONOCO SEAMLESS STE£L PIPE CAEING (O,C:,T,.G,) H & K GRADE J-$5 FOR RRCI'ZC SERVICE R-3 ~BUTTRE$$ -T/C 62t 1 HEAT QTY UOIt THED LENGTH 3-~89~ t G JNT 20.7 3-3eeo t4 JNT 2G.7 4-7]~ 12 JNT 2~,7 4-7331 1~ JNT 20,7 BnL. TO SHIP TOTRL FEET .~76,~7 20761 18576 26876 03~64 ~.AT NCr 12/J0/89 CONOCO MPU OPSCTR 90?-659-6390 001 Conoco Inc. Request For Facsimile Tramminion En~Oq~ Ex~. 5' I-~catie~ (Clt~} Room No, To Name ' ' 1~ No. Loc~°n INo. of Cover + SI)I~ll [r~'tructiofla Fax Keply Number: (907) 659-63'90 ETN &81-6390 notify (907) 659-6340 if ¢omplata Cran~m£ss{o~ is noC received. CONOCO MPU OPS CT" ]0?-659-6390 001 , ~ P. DATE; Oecember 29, IgBg PAG[ 1 of I TO: Dave Mount Joy Conoco A1 aska FAX NO: 007.65g-6390 FROM' J. E. O~o'ntsto Manager-Tubular Products Please flncl ~elow the Impact values for the ?lye heats conducted on 3/4 ~4ze specimens at -~O°F. Meat 3-38gg Heat 3-SOO0 Heat 4-7330 Heat 4-733I Heat 8-9110 Indty..Ld_4pl Tests (~.~/Lbs) 3 Tes% Arq, 10, lZ, 17 13.0 20, 14, 9 14.3 33, 42, 32 3S.7 22, 21. 28 23.7 16, 21, 24 ~0.0 Mlnlmum allowable average ?or 3/4 stze speclmen - 12 ?t/lbs Minimum Individual test ?o? $/a stze speclmen - 0 ?t/lbs If you require Further Information, don't hesitate to call, .~. E. Otontsto ~anager-Tubulae Peoducts ~EO/$p cc: J. O, Hotttn~e~ 01/0~/~0 ~: 17 CONOCO MPU OPS CTR 907-659-6~90 · 1. 2.t~90 14~40 00~ ~i~,~)~ CF&I ~'FEI~ CORPORATION mme;m,~ Pueblo, Colorado 81002 TEL NO, 800.-gg~-!)g00 FAX NO: 71g-951-72~6 {)ATE: ~]&nuary 2, 1990 PAGE ._~ of' _.L TO; Dave HountJoy Conoco Alaska FAX HO: 901-65~-6390 FROM: J. E. O{on~sto Hanager-Tubular Products Below are listed some impact values for APX K-B$ product as requested, All were c~nducted at room temperature, Heat~ Im0acl~ Value (&yg_). Ft/Lb.s 3-7337 35,8 4-0607 31,0 4-0608 35,0 3-7336 34.5 3-7328 35,5 4-0581 30,3 3-7313 27,0 3-7314 27.5 4-O580 36.8 'These impacts are above most, manufacturers K-SS product as CF&I designs their steel for tou.~hnes~, As previously stated, the Arctic service d-55 meet API J-SS in every sense but is designed for better impmct p~oper'ties at low temperatures. If ~'urther information is required, let me know, j. F, Otonis{o Manager-Tubul ar Products JEO/sp .~4~-.t AlichOl,..u., CHECK LIST FOR NEW kq~LL PERMITS ITEM APPROVE DATE (2 thru 8) (8) (3) Admin.//(~_ ~ 9. ' '(9 thru 10. (10 and 13) 12. 13. (4) Casg (14 thru 22) (23 thru 28) Company ~--~nJ cD e"J-) YES Is the permit fee attached .......................................... 2. Is well to' be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... (6) OTHER ~2~ th~ 3~~1)~ (6) Add: For 29. 30. 31. 32. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate.~w Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~'~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. :,,fiX4. ,,; . ~z ~ CD Geolo g~y~ Engigeering: --- n1/3o/89 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE :2:/oo /-o,'1 /, o ,3 Additional Remarks: I Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX.. No special 'effort has been made to chronologically organize this category of information. ALASKA COmPUTiNG ~m~mwm~mmmmmmm~mmmmm~mm~mmmm~ COMPANY NAME ~ CONOCO ~NC, WILL NAME ~ MILNE POINT UNIT FIELD NAN~ : MIbNE POINT BOROUGH ~ NORTH SbOPE STATE : AI, ASKA APl NUMBER : 50-029-21999 EEFE~ENCE NO : 73695 MICROFILMED 0,,, ~ l o / .~ .7 / ..~ ~ ._ ! -- ~S.~Tgpe Verification [,lstlno )~hlummerger AlasKa Computing ~;j:.. *$*~ REEL HEADER ORIGIN : FLIC iEEL NAME { 73695 ~'~r<CONTINUATION # { PREVIOU~ REEL COMMENT Center 26-~R-1990 15:28 : CONOCO INC,, ~ILNE POINT UNIT L-3, API ~50-029-21999 SERVICE NAME ~ EDIT " DATE : 90/03/26 ~'~.'.ORIGIN { FLIC TAPE NAME ~_ : 73695 ~ .CONTINUATION # : 1 ?:i PREVIOUS TAPE : · !gii-.COMMENT : CONOCO INC., MILNE POINT U~IT L-3, API ~§0-029-21999 FILE NAME { EDIT ,001 ~' SERVICE : FLIC '.VERSION : 001A04 DATE : 90/03/26 MAX REC SIZE : 1024 FILE TYPE : LO bAST FILE : ?:' COMPANY NAME: CONOCO INC. ~:~ WELL: MILNE POINT UNIT ~ FIELD{ MILNE POINT ~.'~. BOROUGH: NORTH SLOPE ;., STATE{ ALASKA ~f~ API NUMBER: 50-029-21999 LOCATION: 2021' FNL & 190' FWL SECTION: 3 TOWNSHIP: 13N PERMANENT DATUM: EI, EVATION: 0 RANGE: IOE PAGE: ,'~S Ta'pe Verification Listing ;¢hlt~mmerger AlasKa Computing Center 26-NAR-lq90 15:28 LOG MEASURED FROM RKB 34 ELEVATIONS KB: 34 DATE LOGGED: 13-FEB-90 RUN NUMBER: ONE ".TD DRI~ER: 8900 -'tTP LOGGER~ 8882 ..CASING I ?.9-5/8" ~ DRILLER DEPTH OF 2758 BIT'SIZE t -8 1/2" . ~TYPE F~UID IN HOLE: DISPERSED .. DENSITY: 10,1 ..... PH{ 9,5 MUD RESISTIVITY~ 2,33 ~ 60 FILTRATE RESISTIVITY: 2 30 ~ 60 MUD CAKE RESISTIVIT¥: 2~12 ~ 60 ABOV~ P~RNANENT DATU~ DF: 33 VISCOSITY: 40 FLUID LOSS~ 5 TIME CIRCULATION ENDED: 11:00 13-FEB TTO~ 20 30 13 FEB TIME LOGGER ON BO, .. MAXIMUM TEMP RECORDED: 151 PRUDHOE BAY SARBER POI,,YA/DIL[,ON ':' bOGGING DISTRICT: "' bOGGING ENGINEER: WITNESS: < "TOOL NUMBERS: ~i,' AMIV-.AA-7 '~; NGT-D-739 :' NSC,,E-775 ~!'"" DIC,,EB-27 i:' TCM-509 TCC-B-320 CNC-HA-398 DR$-C-4950 DIS-HC-276 "' FIELD REMARKS: T005 STRING (EOT-TOP) = 'ITE LDT-CNb-NGT-TCC-AMS FOUR 1,5" RUBBER FINNED STANDOFFS AND A 2~ HO~E FINDER USED, NEutRoN MATRIX =_ SAND HOLE CORRECTION = CALIPE~ DENSITY ~ATRIX = 2,65 G/CC.. F~UI~IDENS~Y. i,O G/CC, NOT FILTERING ~ODE - bEAST $OUARE$ TO CORRESPOND TH bOG THE TOOL STRING WAS STICKING AT SEVERAL DEPTHS ON THE MAIN bOGGING PAS THIS CAUSE[) A SPIKE ON THE IbM CURVE THAT IS SUSPECT.. THE SPIKE LABELED ON THE bOG. AN EXTRA ~OGGING PASS WAS MADE OVER THE ZONE OF INTEREST TO AOUIRE HIGH RESOLUTION bDT DATA (~1,2" SAMP~f RATE) THIS,EXTRA PASS DATA I$ NOT PRESENTED ON THIS PRINT BUT IS ON LIS TAPE IN FILE 17. THE ELEVATION GROUND bEVEL I~ NOT KNOWN AT THE TIME THI~ LOG WAS GENERATED THE ELEVATION~ FOR THE KELLY BUSHING AND DRILL FLOOR ARE GIVEN ~ F£ET OVER THEGROUND. PAGE: DATE ,JOB STARTED: 22-MAR-90 .JOB REFERENCE NO: 73695 bDP/ANA: KOHRING Tape Verlttcatlon Listing Iummerger AlasKa Computinq Center 26-MAR-lq90 15~2B PAGEr , ,, , ,: FILE - EDIT,O01 CONOCO INC, MILNE POINT MILNE POINT [INIT 50-02772i999 DATA-~AMPbED EVERY -,5000 FEET DATA INCLUDED TOOL EXTENSION TOOL TYPE [.)SgD NAME ~ DIT-E ,DTE PHASOR DUAl.., INDUCTION SFL 8874' TO 2753' LDT ,LDT LITHO DENSITY 8803' TO 7394' ~ CNT-A/D/H ,CNI, COMPENSATE[) {~EUTHON 8839' TO 7394' $ NGT 'NGT NATURAL GAMMA SPECTROSCOPY 8811' TO 7394' ,TABLE TYPE ~ CONS ,-, TUNI VAbU DEFX ~ii.~CN CONOCO Com Name ~>! FN Fie~n~ame ~,~WN ,SECT ,:~': TOWN .COUN '~ STAT N~T! SON ~ PDAT ' APD .'EKB EDF E~[., TDD FT FT FT FT FT FT MILNg p~NC ~ILNE POINT UNIT 50-029-21999 2021' FNL & ~.90' FW5 ~3N NORTH SLOPE ALASKA USA POLYA/DIbLON 548444 ~4, 999,25 8900, Well Name APX Serial Number Field Location SeCtion Township Range ounty tare or Province Nation Witness' Name Service Order Number Permanent datum bog Measured From ~S T~pe Verification [,istina chlumperger Alaska Computln.q Center 26-MAR-1990 15:28 TUNI VALU DEFI Bbl FT 8874, Bottom bOg Interval T-~X FT 2753 Top ~og Interval TCS ]1:0~ 13-FEB Time Circulation Stopped -TEAB 20:30 13-FE8 ~me [,ogger At Bottom T~BbE TYPE ~ CURV DEFI ..., · IbM Medium Induction Standard Pr e isttvitY ~ 'ILL Deep Induction Standard Processed Resistivity '$P S~ontaneous Potential I DUCTION DEEP PHASER RESISTIVITY IDPH INPH IFRE IDQF 'I~QF CDP CIMP 'IIRD IIXD ~TEN$ ~MTE~ ~MRES DPH! RHOB DRHO ~bU ~ITH i~;'~SS1 ~SS2 bSHV ,SSHV S1RH ~SRH LUR~ .SGR TENS MRES INDUCTION ~EDIUM PHASER RESISTIVITY Induction Calibrated Fre~uen~ IDOF DEEP INDUCTION OUADITY CTO~ IMOF MED INDUCTION O[IAI, ITY FACTOR INDUCTION DEEP PHASER CONDUCTIVITY INDUCTION MEDIUM PHASER CONDUCTIVITY Deep Induction Real Intermediate Conductivity Dee~ Induction Ouad Interme.iate Conductivl~ ~ed um Induction Real Intermediate Conductl tY $ roscopy Gamma-Ray ~ud Tem ture Head Tension Density Porosity Bul~ Density Delta EH Photoelectric Factor ~ual$ty control of long spacing for LD?, 9ua~ty control on short spacing bong S~acJng Computed Count Rate- h~bL+bU/2) 5on~ Upper [-2 Window Count ~ate (LUt+bU2) 50rig bower window Count ~ate ~ltho[qg W~ndow Count Rate Short Spacing ! Window Count ~ate Short Spacin~ 2 Window Count Rate bong'Spacing Htqh Voltage Output Short SPac~.ng High Voltage Loop Output Short $~acln~ ! Density" ' 5onq SpacinQ~EHOR (Uncorrected) Long Upper RHOB Caliper Spectroscopy Gamma~Rav Tension M~d ?em~erature MUD Resistivity Verification bisting *¢hlum~erger AlasKa Computing Center 26-MAR-1990 15:28 PAGE~ ~; .. DEFI i:;.' HTEN Head Tenslon NPH! Neutron Porosity · TNPH The~ma! Neutron Porosity TNRA Calibrated Thermal Neutron Ratio NPOR Neutron Porosity Output Front an Application Program "RCNT RCNT R'CFT RCFT CNTC CNTC .-~. -., CFTC CFTC .$GR Spectroscopy Gamma-Ray TENS Tension MRES MUD Resistivity .' NTE~ Mud Te~pe[ature HTEN Head Tension 8GR Spectroscopy Gamma-Ra~ ..' CGR Computed GR from Thor urn, Uranium, Potassium THOR T~o. rlum POTA Potassium U. RAN Uranium ~ W3NG ~lndow 3~I I - t 6 ~EV) ~??:~'W4NG Window 4 ~,6~ 2 MEV) .,: WBNG Window 5~ - ~ r~EV') .:.' -TEN8 Tension :.' ~TE~ MUd Temperature ;~ MRE8 MUD ReSistivity ;~.: ~C8 Cable Speed ~ :HTEN Head Tension ** DATA FORMAT 8PECIFICATIO~ R~CC)RD ** SET TYPE /. TYPE REPR CODE 0 0 284 1 1 66 2 66 3 73 4 66 5 66 6 73 ? 65 $ 68 9 65 11 66 12 6B l) 66 14 65 0 FT Verification Llstingg erger AlasKa Computin Center 26-MAR-1990 15:28 PAGEI Y ~EPR YALU~ 16 66 0 66 0 {~m~mmmm~mmm~m~mm~mmMmmmmmm ':$* SET TYPE - CHAN ** NAME 8ERV UNIT- SERVICE AP1 APl APl API FIbE NUM~ NUMB SIZE REPR PROCE$S ID ORDER # LOG TYPE 'CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 548444 O0 000 O0''~ 0 ~ 1 1 4 68 0000000000 SFbU DTE OHM~ 548444 07 220 01 0 1 1 1 4 68 0000000000 iSH DTE OHM~ 548444 07 120 44 0 1 1 1 4 68 0000000000 'ILD SP IDOF 'IMQF CIDP CI MP II~D IIXD I'IRM MRE8 '.HTEN DPHI RHOB ~ITH 882 bSHV SSHV S~RM bURH CAbI TENS MTEM MRES DTE OHMM 548444 07 120 46 0 1 1 1 4 68 0000000000 DTE MY 548444 07 010 O1 0 1 1 1 4 68 0000000000 DTE OHMM 548444 07 120 46 O 1 1 1 4 68 0000000000 DTE OHMM 548444 07 120 44 0 1 1 1 4 68 0000000000 DTE HZ 548444 07 000 O0 0 1 ! 1 4 68 0000000000 DTE 548444 07 000 O0 0 1 1 1 4 68 0000000000 DTE 548444 07 000 O0 0 1. 1 1 4 68 0000000000 DTE MMHO 548444 07 110 46 0 1 1 1 4 68 0000000000 DTE MMHO 548444 07 110 44 0 1 1 1 4 68 0000000000 DTE MMHO 548444 07 000 O0 0 1 1 1 4 68 0000000000 DTE MMHO 548444 07 000 O0 0 I 1 1 4 68 0000000000 DTE M~HO 548444 07 000 O0 0 I 1 i 4 68 0000000000 DTE GAPI 548444 07 310 O1 0 1 I 1 4 68 O000OO0000 DTE LB 548444 07 635 21 0 I 1 I 4 68 0000000000 DTE DEGF 548444 07 000 O0 O 1 1 1 4 68 0000000000 DTE OHMM 548444 07 000 O0 0 1 1 I 4 68 0000000000 DTE LB 548444 07 000 O0 0 I 1 1 4 68 0000000000 LDT PU 548444 07 890 O1 0 1 1 1 4 68 0000000000 LDT G/C3 548444 07 350 02 0 I 1 1 4 68 0000000000 EDT G/C3 548444 07 356 O1 0 I 1 1 4 68 0000000000 LDT 548444 07 358 01 0 I 1 1 4 68 0000000000 LDT 548444 07 354 O1 0 1 1 1 4 68 0000000000 LDT 548444 07 354 O1 0 I 1 1 4 68 0000000000 LDT CPS 548444 07 354 01 0 1 1 1 4 68' 0000000000 LDT CPS 548444 07 354 Ol 0 I 1 1 4 68 0000000000 LDT CPS 548444 07 35q 01 0 1 I 1 4 68 0000000000 LDT CPS 548444 07 354 O! 0 i i 1 4 68 0000000000 LDT CPS 548444 07 354 02 0 1 ! 1 4 68 0000000000 LDT CPS 548444 07 354 02 0 1 1 1 4 68 0000000000 LDT V 548444 07 354 O0 0 I 1 1 4 68 0000000000 LDT V 548444 07 354 O0 0 1 I 1 4 68 0000000000 LDT GiC3 548444 07 350 02 0 1 1 1 4 68 0000000000 bDT G/C3 548444 07 350 02 0 I 1 1 4 68 0000000000 LDT G/CS 548444 07 350 02 0 I 1 I 4 68 0000000000 bDT IN 548444 07 280 O1 0 1 1 I 4 68 0000000000 LDT GAP! 548444 07 310 O1 0 1 I 1 4 68 0000000000 bDT LB 548444 07 635 21 0 ~ 1 1 4 68 0000000000 LDT DEGF 548444 07 000 00 0 1 1 1 4 68 0000000000 bDT OH~M 548444 07 000 O0 0 1 I 1 4 68 0000000000 ,Z$.TEpeYerification Listing 26-MAR-lq90 15:28 ~chfumDerger AlasKa Computin~ Center : ,: ~:,~ ID ORDER # LOG TYPg CbASS HOD NUMB SAMP ELE~ CODE CHEX) ::::'HTEN LDT LB 548444 07 %{,- NPH! CNL PU 548444 07 'TN 07 TNPHR~ CNL PU 548444 CN~ 548444 07 NPOR CN~ PU 548444 07 RCNT CN, CPSc. ~548444 07 RCFT CN5 CPS * 548444 07' CNTC CNL CPS 548444 07 CFTC CN5 CPS 548444 07 ~:~ .'SGR CNL GAPI 548444 07 TENS CNL LB ..- 548444 07 ,MRE$ CNb OHMM 548444 07 MTEM CNL DEGF 548444 07 .HTEN CNL LB '548444 07 i SGR NGT GAPI 548444 07 ~ ~CGR NGT GAPI 548444 07 ~" THOR NGT PP~ 548444 07 POTA NGT .PU 548444 07 !~:,..'~URAN NGT PP~ 548444 07 WING NGT CPS 548444 07 W2NG NGT CPS 548~44 07 W~NG NGT CPS 548444 07 L W4NG NGT CPS 548444 07 WSNG NGT CPS 548444 07 ~TENS NGT ~B 548444 07 ~'!MTE~ NGT DEGF 548444 07 ~i'MRES NGT OHM~ 548444 07 ';!: .CS NGT F/HR 548444 07 ' *HTEN NGT LB 548444 07 000 O0 0 i 1 I 4 68. 0000000000 890 O0 0 1 I I 4 68 0000000000 890 00 0 I 1 1 4 68 0000000000 420 O1 0 1 1 1 4 68 0000000000 890 O0 0 1 1 1 4 68 0000000000 420 Ol 0 ! I 1 4 68 0000000000 420 Ol 0 1 1 1 4 68 0000000000 420 'O1 0 ! 1 1 4 68 0000000000 420 O1 0 1 1 1 4 68 0000000000 310 01" 0 1 I 1 4 68 0000000000 635 21 0 1 I I 4 68 0000000000 000 00 0 1 1 1 4 68 0000000000 000 00 0 I 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 1 0 O1 O I 1 1 4 68 0000000000 10 O1 0 1 1 I 4 68 0000000000 790 50 0 1 I 1 4 68 0000000000 719 50 0 1 1 1 4 68 0000000000 792 50 0 1 1 1 4 68 0000000000 310 01 0 i 1 I 4 68 0000000000 310 01 0 1 1 1 4 68 0000000000 310 O1 0 1 1 1 4 68 0000000000 310 01 0 1 1 1 4 68 0000000000 310 01 0 1 1 I 4 68 0000000000 635 21 0 1 1 I 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 1 I I 4 68 0000000000 636 21 0 1 1 1 4 68 0000000000 000 00 0 1 1 1 4 68 0000000000 DATA ** DEPT SP TENS DPHI · ObS LL ~SHV LURH DTE DTE DTE DTE LDT LDT LDT LDT LDT MTE~ LDT TNPH CNL RCFT CNL TENS CNL '$GR NGT URAN NGT W4NG NGT 8948 000 -5 3 000 205 250 ~970 000 10 993 0 012 136 625 1159 000 2 461 149,625 35'425 697,917 1970,000 1~5'885 0,491 20,525 SFLU,DTE 4,887 IOPH,DTE 4,191 IMQF,DTE ~,000 IIXD,DTE 3 ,203 ~TEM DTE 149,625 RHOB~bDT 2,469 OSS,LDT -0,009 LITH,LDT 59.156 SSHV,LDT 1214,000 CALl,bDT 2,668 ~RE$,LDT 0,733 TNRA,CNL 3,082 CNTC CNL 2179,320 MRES~CNL 0,733 'G CGR N,T 56,495 WlNG:NGT 394,527 WSNG N~T 13,683 ILM DTE IMPH ClDP DTE IIR~ DTE MRES DTE DRHO,~DT LS,LDT SSI,LDT S1RH,SDT SGR,LOT HTEN bDT ~POR CNL CFTC MTE~ CNb THOR NOT ~2NG NGT TENS,NGT 3 861 3 238 242 0 0 259 2O7 2 125 -68 35 ~25 RCNT 717 55 149 625 H?EN 1,897 POTA 194,983 W3NG ~970,000 MTE~ ILD DTE 889 IFRE 500 CIMP 500 SGR 733 HTEN 023 PEF 000 LO 875 SS2 37! LSRH 885 TENS 313 NPHI DTE DTE DTE DTE LDT LOT bDT bDT LDT ,CNL ,CNL ,CNL ,CNL ,NGT ,NGT PAGE: 4 168 20 000, ooo, 885 24 125 30~ 750 2 445 1970 000 2278 125 885 -68 313 3 222 ichl erger 'AlasKa Computing Center NRE$.NGT 0,733 C$.NGT SP,DTE XDQF,DTE IIRD,DTE TENS,DTE DPHZ,bDT OhS,bDT bL,LDT bDT MTEN ,TNPH RCFT ',TENS :!SGR URAN DEPT '": SP IOOF II DP, HI LsDL HV LURH MTEM TNpH i RCFT TENS bDT CNL CNb CNL NGT NGT NGT NGT DTE DTE DTE DTE bDT bDT bDT bDT bDT bDT CNL CNL CNL NGT NG NGT MRES NGT XDOF,DTE 'XZRD,DTE TENS,DTE DPHZ,bDT OLS,LDT. .LL,LDT LOT MTEM bDT TNPH CNL ReFT CNL TENS CNL SGR NGT 89~0,000 6,000 3 205 250 5892 000 10 993 0 012 :.:136 625 1159 000 2 461 149:125 35 25 :.~97 9t7 9'2 000' 125 885 · 3 408 20 525 0 733 8800,000 -26,422 0,000 363,§00 §$8~,000 17,340 0,001 160 750 1159 000 2 365 150 000 47 798 456 406 5584 000 log 715 2 750 17 22 0 %44 8:00,000 45,313 0 000 108 313 5192 000 17 522 0 001 164 500 1159 000 2 354 149 750 29 818 956 381 5192 000 81 725 SFLU,DTE IDPii. DTE IMQF.DTE IIXD,DTE MTEM,DTE RHOB.LDT QSSLDT LITH LOT SSHV bDT CALl LDT-- ~RE$ bDT TNRA CNL CNTCCNL ~RES CNL CGR NGT WING NGT W5NG,NGT CS,NGT SFLU,DT£ IDPH DTE I~QF DTE IIXD DTE MTEM DTE RHOB bDT QSS,LDT LITH,LDT SSHV,LDT CALI bDT MRES bDT TNRA CNL C~TC C~b MRE$ CNL CGR NGT WiNG,NGT ~LNG.NGT CS,NGT SFLU,DTE IDPH,DTE I~OF OTE IIXDiDTE ~TEM DTE RHOB bDT OSS bDT LITH DDT SSHV bDT CALl bDT ~RES LDT TNRA CNL CNTC.CN5 CG NGT 26-~AR-1990 15:28 235,375 HTEN,NGT 4 887 ,000 3 ,203 149,625 2,469 ~0,009 9,156 1215 000 2 668 o 3 2 2179 320 0 733 101 253 394 527 13 683 854 500 ILM,DTE IMPH,OTE CIDP,DTE IIRM,DTE MRES OTE DRHO LOT LS bDT SS1 bDT SIRH bDT SGR bDT HTEN bDT NPOR CNb CFTC CNL NTEM CNL THOR NGT W2NG NGT TENS NGT HTEN NGT 2,508 IL~,OTE 2 268 IMPH,DTE 0:000 CIDP,OTE 64,438 IlR~,DTE 150,000 MRES,DTE 2,364 DRHO'LDT 0,030 DS,bDT 74,000 SSI,LOT 1214,000 S1RH,DDT 10,813 SGR,LDT 0,744 . HTEN,~DT .890 NPOR CNL 185 ,~07 CFTC CNL O. 44 MTEM CND . . 8 TENS NGT 891,500 HTEN NGT 8,508 8,516 0,000 11,914 149 750 0 89 438 1214 000 9 lb4 0 5 0 5 Ib~ DTE IMPH DTE ClDP DTE IIRM OTE ~RES DTE DRHO bDT DS,bDT SSi,bDT SIRH'LDT SGR,~DT HTEN,LDT NPOR,CNL CFTC,CNL MTEM,CNb T}{OR,NGT -68,3i3 3 861 IbP OTE 3 887 IFRE DTE 237 875 CI~P DTE 242 0 0 259 207 2 ~25 1033 35 717 149 13 194 '589] 103 500 SGR DTE 733 HTEN DTE 023 PEF LDT 000 LU LOT 875 8S2 bDT 371 LSRH bDT 885 TENS bDT 000 NPH! CNL 425 RCNT~CNL 255 $GR,CNL 62~ HTEN,CNL POTA,NGT ~3 W3NG,NG? 000 MTEM.NGT 000 2 270 ILD,DTE 2 271 IFRE,DTE 440 500 CIHP,DTE 407 0 0 303 20~ 109 904 46 475 150 13 174 5584 904 500 SGR DTE 744 HTEN DTE ~10 PEF 5O LU 25 SS2 LSRH 000 NPH! 968 RCNT 778 SGR POTA .456 W3NG 000 MTEM 000 bDT LD.T LOT bDT LOT CNL CNL CNL CNL NGT NGT NGT 8 359 8 0 0 3O9 81 761 30 998 149 9 ILD DTE 500 IFREiDTE 313 CI~P DTE 000 SGR DTE 7~5 HTEN DTE 0.13 PEF bDT 750 bU bDT 875 SS2 295 LSRH :725 TENS 000 NPHI 331 RCNT 217 $GR 750 HTEN 756 POTA bDT LOT bDT CNL CNb CNL CNL NGT PAGE{ 4 168 20 000 257 250 125 885 245 125 301, 750 2 445 5892 000 42 251 2278 688 125 885 1033 000 3 332 77 537 149 625 2,227 20,000 440,000 109 715 904 000 3 285 000 292 500 2 354 5584 000 47 001 1 904 000 2 614 150 0 8 250 20 000 1.17 563 81. 725 76[ 000 2 775 · 290 750 292 750 5191 348 000 30 489 2789 81',725 761,000 2,003 'IS chlu~e Verification btstlnO erger Alaska Computing Center URAN,NGT 1,876 ~ING,t~GT W4NG,NGT 8,871 ~SNG,NGT MRE$,NGT 0,735 C$,NGT <. DEPT 'IDQF IIRD ,TENS :~:.,' I,,SHV !/:;: ~' T N P H ~'-.:~:TENS ?' URAN DTE DTE DTE DTE bDT bDT bDT [.,PT bDT bDT tnb tNb (::Nb NGT NOT NGT OLS i: bURH ,,{' RCFT !SGR DTE DTE OTE DTE DT bDT LDT DDT bDT CNL NOT ( URAN NGT W4NG NGT MRES,NGT DE:pT IDODF TENS DPHI ,OLS DTE DTE DT£ bDT LOT bDT bDT bDT MTEM.LDT TNPH,CNL RCFT,CNL 8600 000 -37 813 0 000 242 625 5372 000 ..,-11 134 0 027 '144 250 1159 000 2 441 .... 151 250 40 640 587 408 5372 000 105 042 2 066 13 827 0 733 8500 000 -59 500 0 000 334 500 5652 000 9 876 -0 006 132 i25 1160 000 2 467 150 75O 34 821 707 989 5652 000 114 235 2 023 9 886 0 739 8400,000 '56,313 0.000 325.250 5192 000 13 606 -0 006 153 250 1159 000 2 385 118,875 5,784 679,983 SFt. U,DTE IDPH,DTE IMOF,DTE IIXD,DTE MTEM,DTE RHOB.LDT OSS,LDT LITIt,LDT~ SSHV.LDT CALl LDT MRES bDT TNRA CNL CNTC CNb MRES CNL CGR NGT ~ING NGT WLNG,NGT CS,NGT SFbU,DTE IDPH,DTE I~OF,DTE IIXD,DTE ~TEM,DTE OS bDT 5ITH,5DT SSHV,LDT CALl,DDT MRES:~DT TNRA NL CNTC,CNL CG NGT ~ING,NGT W5NG,NGT C$,NGT 26-MAR-1990 15:28 253 327 W2NG,NGT 7:886 TENS,NGT 887,500 HTEN,NGT 4 500 3 0 3 4~9 151 250 2,466 O, ~7 76 ~ 5 1214: 3, 5 2032,615 O'l 3 B~,370 33 ,852 11,358 89t,000 2,393 2,4701 0 0 0 5 313 15O4 750 0 0 65 250 1215 000 l0 5 097 22436 645 100 6 381 17 17 lO1 8~2.000 ILM DTE I~PH DTE CIDP DTE IIRM DTE MRES DTE DRHO,LDT SS1 DT SGR PT HTEN,LDT NPOR,CNh CFTC,¢Nb MTEM,CNL THOR,NGT W2NG,NGT TENS,NGT MTEN,NGT IL~,DTE IMPH,DTE ClDP,DTE IIRM,DTE 2RES,DTE DRHO,LDT LS,LDT S8~,LDT S!~ ,bDT SGR,DDT HTEN,LDT NPOR,CN~ CFTC,CNL MTEM CNL THOR:NGT W2NG,NGT TENS,NGT HT£N,N~T 125,678 W3NG,NGT 5192.000 290 242 0 0 270 213 2 105 897 43 596 151 13 162 5372 897 3 867 ILD,DTE 3 664 IFRE,DTE SGR DTE 733 HTEN DIE 039 PEF 500 LU bDT 000 SS2 LDT bSRH bDT 000 NPHI CNL 506 .RCNT 971 SGR ~50 H~EN WSNG 000 2TE~,NGT 000 2 44i 2 404 379 0 0 253 207 2 114 1023 34 727 150 14 167 5652 i023 SFLU D3~E 2 ~12 ILN,OTE 2 IDPH:D S 2: 3 IMPH,OTE 2 IMO[IDTE 01000 CIDP,DTE 394 IiX DTE 56 406 IIRM,DTE 384 gTEa,DTE 148 875 MRE$,DTE 0 ~HOB,LDT 2 425 DRHO.~DT 0 DIT~,DDT 78,625 SSI,DDT 217 SSHV,LDT 1215,000 SIRH,DDT 2 CALI,LDT 10,414 SGR,LDT 128 8RES,hDT 0.753 HTEN LDT 852 TNRA.C~L 3.1~8 NPOR:CNL 37 CNTC,CND 2158,659 CFTC,CND 685 441 IFRE 500 ¢I~P 500 SGR HTEN 875 LU 8S2 235 TENS 000 NPHI 375 RCNT 625 SGR 75~ HTEN 65 POTA 079 W3NG 000 MTEM 000 DTE DTE DTE DTE LDT LDT LDT C:NL CNL NGT NGT 414 ILD.DTE .~61 IFRE.DTE 500 CI~P,DTE 000 GR,DTE 753 HTEN,DTE 044 PEF,LDT 250 LU LDT 125 SS2:LDT 271 LSRH.LDT 038 TENS,LDT 000 NPHI,CNb 507 RCNT,CNL 923 SGR,CNL PAGE~ 46.821 149,750 3 439 20 000 272 750 105 042 897 000 2 738 252 625 290 500 2 426 5372 000 43 687 200! 335 ~05 O42 897 000 2 512 '55 309 151 250 2 451 20 000 409 500 114 235 1021 000 ' 033 243 375 281 500 463 5652 000 32. 968 2374 429 114 235 102~ 000 · 981 858 2 506 20 000 406 000 128 038 852 000 2 863 275 750 304 500 5192 889 3~ 840 128 038 ~$ T~pe Verification bistlng chLumberger Alaska Computing Center TENS CNL 5192,000 ~RE&,CNL SGR:NGT 128,038 CGR,NGT URAN,NGT 1,499 WlNG.NGT W4NG,NGT' 9,346 WLNG,NGT MRES,NGT 0,753 CS,NGT DEPT XDQF DTE XXRD'DTE TENS DTE .DPHI ~DT O~SLDT :,LLLDT bSHV bURH NTEM ~TNPH RCrT TENS !SGR .URAN W4NG DEpT ~IDQF '~IXRD TENS bDT bDT bDT .tNb CNb CNL NOT NGT NGT NGT DTE DTE DTE DTE LDT bDT · Lb,bDT bSH¥ bDT bURH bDT <i'~ MT E ~ · i~ ~TNPH ~: RCFT ~ ~TENS ,URAN W4NG :i:,ii, DEPT :' XD~F 'IIRD ~!':~'TEN$ DPH! , LL LSHV bDT CNb tnb CNL NGT NGT NGT NGT DTE DTE DTE DTE bDT bDT bDT bDT LURH bDT MTEM,LDT 8300 000 -54 719 0 000 >.434 750 5-340 000 16 863 0 003 162 125 -1159 000 2 363 146 875 42 357 485 524 5340 000 129,056 4,426 5,799 10,759 8200 000 -21 375 0 000 487 000 5200 000 21 1'06 -0 010 178 375 ~159 000 2 30i 145 250 46 44~ 410 534 5200 000 126 811 5 325 13 941 0 771 8100 000 -18 313 0 000 327 000 5192 000 I1 453 -0 036 132 625 1159 000 2 441 144 375 SFLU,DTE IOPH,DTE iMQF,)TE IIXD DTE MTE~ DTE RHOB bDT- QSS GDT LITH DDT SSHV bDT CALX LDT MRES LDT TNRA CNL CNTC CNL ~RESCh5 CGR NGT wiNG NGT W5NG NGT CS NGT SFbU,DTE IDPH,DTE I~OF,DTE IIXD,DTE ~TEM,DTE RHOB,LDT OSS,LDT LITH bDT $SHViLDT CALl LOT MRES LDT TNRA CHh CNTC CNb ~RES CNL CGR NGT ~ING NGT ~5NG NGT CS NGT 2b-bAR-1990 15:28 0 753 MTE~,CNL 118i320 THOiiNGT 405 312 W2N NGT 13 281 TEN NGT 1688,000 HTEN,NGT 1,447 1,882 0,000 86,688 0,028 82,125 1214 0,759 , 674 188 ,464 0 759 97 416 357 17 8 1,578 1,609 0 0 109 ~05 145 210 2 ~02 0 19 O, 0 ! 1773 ~00 ILM,DTE IMPH,DTE ClDP DTE IIRM DTE MRE$ DT£ DRHO bDT bM bDT SSi bDT S1RH bDT SGR bDT HTEN bDT NPOR CNL CFTC CNL ~TEM CNL THOR NGT W2NG NGT TENS NGT HTEN NGT ILM,DTE IMPH,DTE CIDP,DTE ~RESDTE DRHO, LDT LS LDT SS £,DT SlR~ CDT SGR bDT HTEN bDT NPOR CNb CFTC CNb MTE:~ CNL THOR W2NG NGT TENS NGT HTEN NGT , OTA,NGT . TEM.NGT 852,000 2 i00 ILD,DTE 1 978 IFRE,DTE 531 000 CIMP,DTE 439 250 SGR,DTE 759 HTEN,DTE 018 PEr,bDT 305 250 212 927 43 529 146 206 LU 250 $$2 289 LSRH 056 TENS 500 NPHI 066 RCNT 305 8GR 875 HTEN 606 POTA 320 W3NG 000 MTE~ 500 1 595 1 621 573 0 0 336 210 2 46 451 907 LDT LDT bDT LDT CNL CNL CNL CNL NGT SFLU,DTE 2.887 XLM,DTE .2 IDPH DTE 2,543 IMPH,DTE 2 I~OF!DTE ~,000 ClDP,DTE 393 I,.~XD DTE 5~,844 IIRM,DTE 364 M g~ DTE 144,375 MRES,DTE 0 RHOSihDT 2.4~1 DRHO.LDT 0 O$S bDT 0 0 2 LS,LDT 258 LITH,LDT 65:750 SSI,bDT 203 SSHV,LDT I214,000 SIRH,LDT 2 CALI.LDT 10 ~4 SGR,LDT 114 MRES,LDT O:7/5 HTEN,~DT 897 ILD DTE 601 IFRE DTE 000 CIMP DTE 000 SGR DTE ~ HTEN DTE PEF bDT 250 LU LD~ 500 SS2 LDT 2'6? LSRH bDT 81 EN 500 I ~ bDT PH L CN 257 RCNT CNL i SGR CNL ~ HTEN CNL 0 POTA NGT W3NG,NGT ~ ~TEM.NGT 50O IFRE'DTE 000 CI~P,DTE 000 SGR,DTE 775 HTEN,DTE 0 PEr,LoT ~I0 LO;LOT ,125 S$2,LDT 408 LSRH,LDT 95 TENS,LOT 00 NPHI,CNL PAGE= 10 85],000 ,825 73,783 148,875 2~ 833 000 505 500 129 056 927 500 2 914 -286 250 298 000 · 2 354 5340 000 43,165 1944,687 129,056 927,,500 ? ,6ot ,208 146,875 1. 597 20 000 624 500 1.26 811 907 500 2 955 316 000 303 250 2 293 5200 000 47 351 119526 387 3 392 68 773 145 250 · 2 506 20 000 385 750 114 495 897 000 3 322 25 500 28~ 500 449, 519~ 000 32 401 ,~$ Tape Verification EistLnq ;chLummeTger AlasK~ Computing Cente~ TNPH CNL RCFT TENS URAN W4NG D-EPT *~SIP 'XDQF ~IIRD DPH I LURH RCFT T~N8 MRE$ DEFT DPHI ~HV ~URH ~TNPH LSGR .j~: ~:URAN W4NG MRE8 DEFT ;TENS DPHI OLS LL ~ $ H V 33,044 CNL 825,089 CNL 5192,000 NGT 114,495 NOT 2,113 NGT 12,910 NGT 0,775 DTE DTE DTE DTE bDT bDT bDT bDT bDT bDT CNL CNL NGT NGT NGT NGT DTE DTE DTE DTE ]bDT bDT bDT bDT bDT bDT CNL, CNL CNL, NGT NGT NGT NGT DTE DTE DTE DTE bDT bDT bDT DDT 8000 000 =-21 25O - 0 000 321 750 5224 000 10 751 .... -0 041 128 375 1159 000 2 455 142 250 32 596 880 394 5224 000 94 661 4 706 8 929 0 782 7900 000 -18 750 0 000 304 250 5052 000 B 005 -0 024 129 875 1159 000 2 ~63 141 50 31 590 791 686 5052 000 113 973 4 004 8 372 0,792 7800 000 -14 039 0 000 270 750 5120 000 10 011 0 021 129 625 1158 000 TNRA CNL CNTC:CNL MR£S CNL CGR NGT WING NGT ~5NG NGT CS NGT SFLU,DTE IDPH,DTE IMOF,DTE IIXD,DTE* MTEM,DTE RHOB bDT QMS bDT LITH DDT SSHV bDT CALl,bDT MRES bDT TNRAiCNL CNTC CNL MRES,CNb CGR NOT WbNG,MGT C$,NGT SFLU,DTE IDPH,DTE IMOF.DTE IIXD DTE MTEM DTE RHOB bDT QSS bDT bITH bDT SSHV bDT CALl bDT MRES bDT TNRA CNL CNTC CNL MRES CNL CGRiNGT wING NGT W5NG NGT CS,NGT SFLU DTE IDPH DTE IMOF DTE IIXD DTE MTEM DTE RHOB bDT OSS,bDT LITH,LDT SSHV,LDT 26-MAR-1990 15:28 3.056 2536,0~5 0 7 5 100 228 381 33i 12 910 1781 000 0,000 49.563 12. 3 1214,000 10.$13 3, 2 2654.428 0,782 6~,736 30 .532 7.937 ~7~8,000 2 748 2 708 0 000 48 ~ 141 1508 2.518 0 42 121~ 000 0 2 3 04~ 2339 865 0,7~2 86,2 3 414,884 1774 O0 3,250 3.152 0,000 140, 0 2.4 5 60, 8 1214,000 NPOR,CNL CFTC,CNL MTEM,CN~ THOR,NG~ W2NG,NGT TENS,NGT HTEN,NGT IbM OTb CIDP OTb IIRM DTE NRES DTE DRHObDT LS bDT SS1 bDT S1RH bDT SGRLDT HTEN bDT NPOR CNb CFTC CNL MTEM CNL THOR NGT W2NG,NGT TENS,NGT HTEN,NGT IbM DTE iMPH DTE CIDP DTE IIRM DTE MRE$ DTE DRHO bS bDT SS! bDT S1RH bDT SGR bDT HTEN bDT NPOR CNL CFTC CNb MTEM,CNb THOR,NGT W2NG',NGT TENS,NGT HTEN,NGT IbM DTE IMPH DTE CIDP DTE IIRM OTb ~RES DTE DRHO bDT bM bDT SSl bDT. S1RH,bDT 32.218 RCNT,CNL .375 ~i'065 ~TEN,CNL OTA.NG~ ,784 3NG,NGT 8~ ,000 TEM, .000 2 551 363 0 0 252 200 2 94 907 32 896 142 7 145 5224 907 ILD,DTE 547 XFRE,DTE 750 CIMP,DTE 750 SGR,DTE 782 HTEN DTE 007 PEF bDT 125 LU 375 SS2 436 bS.RH 661 TENS 500 NPH! 305 RCNT 544 SGR 250 HTEN 1 6 POTA 33 W3NG 000 MTEM 5OO bDT bDT bDT bDT CNL CNL CNL CNL NGT NOT NGT 2 768 ILL,OTb 2 760 IFRE,DTE 361 250 CINP,DTE 000 SGR,DTE HTEN,DTE 336 0 0 252 213 2 113 837 3O 798 141 tO 178 5052 837 792 051 PEr bDT 250 LU 500 S82 bDT 344 973 TENS bDT 000 NPHI CN5 928 RCNT CNL 536 SGR CNL 50 HTEN,CNL 40 POTA,NGT · 605 W3NG NGT 000 MTEMiNGT 000 3 195 I. LD DTE 3 188 IFRE DTE 317 000 CI~P DTE 291 750 SGR DTE 0 797 HTEN DTE 0 004 PEF bDT 246 000 LU LDT 197 875 SS2.LDT 2 463 bSRH,bDT PAGEI 11 2707 070 114 495 897 000 2 616 5~ 639 144 375 2~ 535 000 392 500 94 661 907 500 24~ 205 2 465 5224 000 31 503 2795 802 94 661 907 500 2 315 49 603 142 250 2 717 20 000 362 000 837 0 3 359 244 750 95 2488 655 .113 73 298 53 02 3 141, 250 3 115 20 000 313 500 111 134 938 000 ~3 039 232 750 274 250 2 480 ~IS ,Tape Yerification Listing ~chXumberger AlasKa Computing Center bURHoEDT MTEM :TNPH ~:: RCFT :~ TENS ; ~SGR URAN W4NG · MRES CALI LOT ,bDT MI{ES,LOT ,tNb TNRA,CNL ,CNL CNTC,CNL CNL MRE$,CNL NGT CGR,NGT NGT WlNG,NGT NGT WSNG,NGT NGT CS,~GT ::~ DEPT IDOF 'IIRD TENS : DPHI OLS LL ~ bSHV 'i LURH MTEM TNPH ReFT TENS " W4NG MRES DTE DTE DTE DTE bDT LDT bDT LDT LDT LDT CNb CNL CNL NGT NGT NGT NGT DEPT iDsP · QF IIRD TENS DPH! OhS LURH MIEN i!:'TNPH RCFT i..TENS URAN N4NG NRE$ DTE DTE DTE DTE LDT LDT LDT LDT DT CNL CNL CNL NGT NGT NGT NGT DF. PT IOOF IIRD TENS DPH! SFLU,DTE IDPH OTE' I~OF DTE IIXD DTE ~TEM DTE RHOB LOT OSS LOT 5ITH LOT $SHV LOT CALf bDT ~RES LOT TNRA CNL CNTC CNL ~RES CNb CGR NGT wlNG NGT W5NG NGT C$.NGT 2,496 140,500 33,943 839,214 5120,000 111,134 3,101 11,905 0.797 7-700 000 -15 250 0 000 ]10 5OO --5132 000 10 742 -0 013 131 125 1157 000 2 465 139 750 33 249 847 272 5132 000 100 062 0 259 13 875 0 804 7600,000 -21 734 0 000 286 750 5020 000 8 139 -0 013 118 813 1157 000 2,520 138,625 30,868 894,749 5020 000 99 862 2 803 6 931 0 8~0 7500,000 '16,438 0,000 340,250 4960,000 12,857 '0,014 SFLU.DTE IDPH DTE IMOF DIE IIXD DIE ~TEM DIE RHOB DDT QSS LDT blTH LDT $SHV LDT CALI bDT MRES LDT TNRA CNL CNTC CNL ~RES CNL CGR NGT ~ING NGT W5NG NGT CS NGT 26-~;AR-1990 15:28 10,867 0,797 252~ '094 ,414 0 797 89 809 351 190 8 929 1775 000 2. 8 0 000 5 13~ 000 0 037 64 000 1214 O0 10 1~ 0 804 262~ 018 228 0 804 97 595 290 87 18 131. 1776 000 2,998 2,949 0,000 46,469 138,625 53 594 1213 000 11 719 0 810 264~ 954 120 0 810 77 240 318 1777 000 SGR bDT HTEN bDT NPOR CNL CFTC CNL MTEM CN5 THOR NGT W2NG NGT TENS NGT HTEN NGT ILM DIE IMPH DIE CIDP DIE IIR~ DIE MRES DIE DRHO bDT LS,LDT SSi LDT S1RH LDT SGR LDT HTEN LOT NPOR CNL CFTC CNL MTEM CNL THOR NGT W2NG NGT TENS NGT HTEN NGT ILM,DTE IMPH DIE C!DP DIE IIRM DIE MRES DIE DRHO bDT L$ bDT 851 LDT 51RH LDT SGR bDT HTEN ~DT NPOR CNL CFTC CNL ~TEM CNL THOR NGT W2NG,NGT TENS,NGT HTEN,NGT 111 134 TENS LDT 938 33 826 140 11 191 5120 938 000 NPHI CNL 664 RCNT CNL 920 SGR CNL 500 HTEN CNL 789 POTA NGT 468 W3NG,NGT 000 NTEM,NGT 000 2 711 ILD DTE 2 715 IFRE DTE 7 371 0 253 201 I00 882 139 50 CIMP 750 SGR 80~ HTEN 008 PEF 000 000 SS TENS 500 NPHX SGR 750 HTEN 989 POTA 537 W3NG 000 MIEN 500 DTE DTE DTE bDT bDT LDT LDT LDT CNL CNL CNL CNL NGT NGT NGT 2 317 0 -0 231 .2 99 895 29 914 138 11 128 5020 895 IFRE DTE 0 CIMP DIE 0.00 SGR 810 HTEN 002 PEF 000 LU 5 LSRH 862 TENS 500 NPHX RCNT 625 HTEN 333 POTA MIEN 50O DTE DTE bDT LDT LDT bDT bDT CNb CNL CNL CNL NOT NGT NGT SFLU,DTE 2 086 IbM.DIE 2,301 ILO,DIE DIE IOPH,DTE 2':430 IMPH.OTE 2.344 IFRE.DTE DIE I~OF,DTE 0,000 CIDP,DTE 411,500 ClMP.PTE DIE IIXD.DTE 49.719 IIRM,DTE 402'000 SGR,DTE DIE ~TE~.DTE 137,625 MRES,DTE 0.817 HTEN'DTE LDT RHOB.LDT 2.438 DRHO,LDT 0,001 PEF,LDT bDT OSS.LDT 0,021 LS,bDT 264.500 LU.bDT PAGE~ 12 5110,000 2,552 2654,483 111,134 938,000 2,981 51,587 140,500 2 662 20 000 368 000 100 O62 933 500 25O 2751 165 203 46 81 139 ~50 2'~ 916 000 27~ 000 5020 000 30 119 · 2~26 230 ~99 862 895 50O 13~ 625 5 2,359 2 0 '5O0 1 9,777 88~,500 ,074 254,000 ,chlum erger Alaska Computln Center LSHV RCFT .TENS URAN W4NG MRES DEPT IDQF lIED TENS DPHZ LSHV LURH Lb bDT bDT bDT bDT NGT NGT NGT NGT DTE DTE DTE DTE bDT bDT bDT LDT bDT MTE~ LOT .TNPH CNL. RCFT CNL .TENS CNL URAN W4NG WIRES DEPT 'IIRD DPHI LSH¥ NTE~, ~TNPH RCFT TENS URAN W4NG MRE$ NGT NGT NGT NGT DTE DTE DTE DTE bDT bDT bDT bDT bDT CNt, CNL CNb NGT NGT NGT NGT DEPT SP UTE IDQF OTB IIRD DTE TENS DTE 137 625 1157 000 2 438 137 625 33 610 838 377 4960 000 109 777 1 541 "'-'-10 880 0 817 7400 000 -24 594 0 000 299 000 5084 000 13 862 -0 006 141 875 1157 000 2,428 136,750 36,716 765.988 5084'000 109,827 7300 000 -26 688 0 000 296 500 5328 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 250 -999 250 -999 250 -999 250 7200 000 -22 750 0 000 364 000 5188 000 LITH.bDT SSHV.LDT CALl,LOT MRES.LDT TNRA.CML CNTC.CNL MRES.CNL CGR.NGT wlNG,NGT. W5NG.NGT CS.NGT · SFbU DTE IDPH DTE IMOF DTE IIXD DTE MTEM DTE RH00 LOT OSS.LDT LITH,L, DT SSHV.[.DT CALl,bDT ~RES,bDT TNRA.CNL CNTC.CNL ~RES CNb CGR NGT WlNG NGT W5NG NGT CS NGT SFbU DTE IDPH DTE IMOF DTE IIXD DIE ~TEM DTE RHOB I,,DT QSS bDT 5ITH bDT SSHV,LDT ALI.LOT ~RES,LDT '~NRA,CNL NTC,CNb MRES,CNL CGR.NGT ~ING'NGT W5NG.NGT CS,NGT SFLU DTE IDPH DTE IMOF DTE IIXD DTE ~TE~{ DTE 26-~AR-1990 15:28 b7.000 1213,000 10,516 0,817 3.076 2479.369 0,817 98,352 363,007 8,902 1812,000 2,570 2,836 0 136' 3 0 72~125 1213,000 10,938 0 2470 344 0 822 105 3 10 2 1810 ~0 2.926 2 879 0 000 50 3 -999 ~50 -999 50 -999 ~50 '999 50 '999 0 -Egg 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 2, 8 0,000 65,813 135,250 SSI bDT S1RH bDT SGR bDT HTEN bDT NPOR CHh CFTC.CNb MTEH,CNb THOR,NGT W2NG,NGT TENS,NGT HTEN,N~T ILM,DTE IMPH,DTE CIDP,DTE IIRM,DTE MRES.DTE DRHG.bDT LS.LDT SS1,LDT S1RH,~DT SGR,bDT HTEN,bDT NPOR,CNL CFTC.CNL ~TEM;CNL THOR,NGT W2NG,NGT TENS,NGT HTEN,NGT IbM DTE IMPH DTE ClDP DTE IIRM DTE MRE$ DTE DRHO bDT bS bDT SSI:LOT S{RH bDT SGR bDT HTEN bDT NPOR ~NL CFTC CNL ~TEM CNL THOR NGT W2NG NGT TENS NOT HTEN NGT Ib~ DTE I~PH:DTE CIDP,DTE IIRM,DTE MRES,DTE 2 347 324 0 "999 '999 '999 '999 "999 '999 '999 '999 '999 "999 '999 '999 '999 198 625 SS2 LOT 2 434 109 777 TENS,bDT 886 500 NPHI,CNL 33 892 RCNTi!NL 822 818 &GR 137 625 HTEN Nb 12 937 POTA GT 194 857 W3NG.NGT 4960 000 MTEM.NGT 886 500 2 XFRE 352 500 CI~P 341 250 SGR -0 PEF 271 0 LU 197 ~5 SS2 TENS 100~ 000 NPHI 3 235 RCNT 765 496 SGR 5084 1008 2 873 ILD DTE 881 IFR~ DTE 000 CI~ DTE 000 SGR DTE 824 HTEN DTE 250 PEr bDT 2~0 bU LDT 0 $$2 LDT ~50 LSRH bDT 0 TENS LOT ~0 NPHI CNL 250 RCNT CNL 250 SGR CNL 950 HTEN CNL 250 POTA NGT 250 W3NG 250 NTEM.NGT 250 !. IFRE,DTE 44 ,750 CIMP,DTE 41 .750 SGR.DTE ,826 HTEN.DTE DTE DTE DTE DTE bDT LDT LDT LDT bDT CNL CNL CNL 750 HTEN CNL 193 POTA,NGT 457 W3NG,NGT 000 MTEM,NGT 000 PAGEI 13 277 250 2 436 4960 000 32 576 2574 582 109 777 886 500 3 258 6 13~ 325 625 2,768 20,000 367,500 1-09,827 1008 000 3 035 258 25O 282 500 2 424 5084 000 35 52 2552 143 I0 100~ 827 000 { 98 77 3~4 t36 750 2 826 20 000 346 750 110 299 !105 000 -999 2,50 -999 250 -999 250 '999250 "999 250 '999 250 '999 250 '999 250 "999 250 '999 250 -999 250 -999 250 2,230 20,000 7,750 4~3,853 1068,000 ~S~Ta~e..¥eriflcation Listing .chl.um erger Alaska Computing Center , DPHI bDT LDRH · ~TE~ · - TNPH : RCFT TEUS URAN W4NG '~ DEPT ~ ~$p ~, IIRD D~HI bURH ~! >L U R A N ? N4NG ?.MRE8 "IIRD DPHI NTEM , TNPH ReFT TBNS bDT bDT bDT bDT bDT CUb NGT NGT NGT NGT DTE DTE DTE DTE bDT bDT bDT bDT bDT. bDT CNb CUb UGT NGT NGT NGT DTE DTE DTE DTE bDT bDT bDT bDT bDT bDT CUb CUb CNb ~SGR NGT URAN.NGT W4NG.NGT MRES~NGT -999 250 -999 250 -999 250 -999 250 -999 250 -999 25O ~999 250 -999 250 -999 250 ~999 250 -999 25O -999 250 -999 250 7100 000 -24 531 0 000 338 250 4992 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 25O -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 7000 000 0, O0 325,500 4880 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 RHOB,LDT O$S.LDT blTH.LDT SSHV,LDT CALI,LDT ~RES,LDT TNRA,CNL CNTC.CNL MRES.CNL CGR.NGT ~ING,NGT ~SNG.NGT CS,NGT SFLU,DTE IDPH.DTM IMOF.DTE IIXD DTE STEM DTE R}IOB bDT 088 bDT LITH bDT SSHV bDT CAL! bDT MRES bDT TNRA CNL CNTC CNG MRES CNb CGR NGT WING NGT w5NG NGT CS NGT SFLU,DTE DTE IDPH,0 ~ IMQF,.TE, IIXD DTE MTEMiDTE RH08 hOT 055 bDT biTH bDT $SHV bDT CALI bDT MRES bDT TNRA,CNL CNTC,CNb MRES,CS~L CGR,NGT WlNG,NGT wSNG,NGT CS,NGT 26-MAR-1990 15:28 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -9~9 -999 250 -999 250 -999 250 '999 250 '999 250 "999 250 2 492 2!445 0 000 59 063 134 250 -999 250 -999 250 -999 250 -999 2~0 -999 250 '999 250 '999 250 "999 250 "999 250 "999 50 "999 ~50 '999 250 '999 250 2.578 2 557 5~ 000 4O6 132 875 -999 250 -999 -999 250 -999 25'0 -999 250 -999 250 -999 25,0 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 DPHO,bDT DS,bDT SSl-.bDT SIRH,bDT SGR,bDT HTEN,bDT NPOR,CNb CFTC,CNb ~TEM,CNb THOR,NGT W2NG,NGT TEN$,NGT HTEN,NGT ILM,DTE I~PH,DTE CIDP,DTE IIRM,DTE MRES,OTE DRHO,LDT DS,bDT SS1,LDT S1RH.bDT SGR,bDT HTEN.bDT NPOR,CNb CFTC,CNh MTEM,CNE THOR.NGT W2NG,NGT TEN$,NGT HTEM,NGT ILM,DTE IMPH DTE CIDP DTE IIRM DTE ~RE$ DTE DRHO bDT DS LOT SSI,bDT $1RH,bDT SGR,bDT HTEN,LDT NPOR,CNb CFTC,CNL MTE~,CNL THOR,NGT W2NG,NGT TEN$,NGT HTEN,NGT -999 250 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 250 250 SS2 250 bSRH 250 TENS 250 NPHI 250 RCNT 250 SGR 50 HTEN 50 POTA 0 W3NG 25O PEF.LDT bU bDT bDT bDT bDT CNb CNb CNb NGT NGT NGT 2 2 408 380 o -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 38 ILD ~43 IFRE 500 CIMP 250 SGR 825 HTEN 250 PEF 250 50 SS TENS 250 NPH! 25O RCNT 250 SGR 25O 250 POTA DTE DTE DTE ,DTE DTE bDT bDT bDT bDT bDT CNL CNb NGT 250 W3NG NGT ~100 ~TE~,NGT 2 539 ILD.DTE 2 5]? IFRE,DTE 390 750 CI~P.DTE 365 0 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 500 SGR DTE 809 HTEN DTE 250 PEF bDT 250 LU LDT 250 $S2 bDT 250 LSRH ~DT 250 TENS 250 NPHI 250 RCNT 250 SGR POTA 250 W3NG 250 ~TE~ 25O bDT CNL CNL NGT NGT NGT PAGEI -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 · 20 0 409 000 101 349 1025 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 0 -999 250 393 750 87 358 1052 000 -999 250 -999 250 -99 $0 -999 250 ,-999 250 -999 0 -999 250 '-999 250 -999 250 -999 250 14 IS Tam'~e Yerltlcatlon Llstln~ cbiu erger Alaska Computin Center DEPT IIRD TENS DPHI bsbb MT EM RCFT TENS URAN W 4 N G MRES DEPT 'IOOF XXRD TENS DPHI MTEM ~TNPH TENS SGR DEPT SP '~DOF DPH I Ob8 h'SHV bURH DTE DTE DTE DTE gDT bDT gDT bDT bDT gDT CNb NGT NGT NGT NGT DTE DTE DTE DTE bDT bDT bDT bDT bDT bDT CNb CNL, NGT NGT NGT NGT DTE DTE DTE DTE LDT gDT bDT bDT bDT MTEI~ gDT TNPB CNL 'RCFT CNL TENS CNL URAN NGT W4NG NGT 6900 000 -26 953 0 000 324 250 4828 000 -999 250 -999 250 -999 25O -999 250 ~99 250 ~99~ 25O -999 250 -999 250 -999 250 .... ~999 250 -999 250 -999 250 -999 250 680O 000 -23 781 0 000 369 500 4744 000 -999 250 -999 250 -999 250 -999 250 -999 25O -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 '999 250 6700 000 -22 594 0 000 347 250 4908 000 -999 250 -999 250 -999 25O -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 SFLU DTE IDPH,DTE IMOF,DTE IIXD,DTE MTEM,DTE RHOB,LDT QSS,LDT gITH,LDT SSHV,bDT CALI,LDT ~RES,LDT TNRA.CNb CNTC CNL MRES CNL CGR NGT WING NGT W5NG NGT CS,NGT BFgU,DTE IDPH,DTE IMOF,DTE IIXD DTE MTEm:DTE RHOB gDT OSS gDT gITH bDT SSHV LDT ¢~4I ~DT MRES bDT T~RA CN~ C~TC CNb MRES C~R WING NGT W5NG NGT CS NGT SFgU DTE IDPH:D~E IMOF,DTE IIXD.DTE ~TEM DTE RHOB bDT OSS bDT LIT[{ bDT SSH¥ bDT CALI bDT MRES LDT TNRA CNL CNTC CNL MRES CN~ CGR NGT wING NGT ~bNG,NGT 26-MAR-1990 15:28 2 59O 2:570 0.000 53 719 131:750 -999,250 -999.250 -999,250 -999,250 -999 250 -999 250 -999 ~50 -999 250 · -999 250 -999 250 -999 250 -999 250 -999 250 2 307 2 217 0 000 68 750 130 750 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -99~ 250 -99 250 -999 250 -999 250 -999 250 -999 250 -999 250 2,344 2,373 0 000 62 625 129 875 -999 250 -999 ' -999 250 -999 250 -999,~50 -999, 50 -999,250 -999,250 -999,~50 -999,~50 -999, 50 ILM,DTE IMPH,DTE ClDP,DTE IIRM,DTE MRES,DTE DRHO,LDT LS,LDT SSI,bDT S1RH,gDT SGR,bD? HTEN,bDT NPOR,CNb Cf'TC CNg MTE~ CNL THOR NGT W2NG NGT TENS NGT HTEN NGT IgM,DTE IMPH,DTE CIDP,D?E IIRM,DTE MRES,DTE DRHO,gDT gS gDT SSI gDT SIRH gDT SGR bDT HTEN gDT NPOR CNb CFTC CNg MTEM CNb THOR NGT W2NG NGT TENS NGT HTEN,NGT ILM,DTE IMPM,DTE CIDP,DTE IIRM,DTE MRE$,DTE DRHO,LDT LS,gDT SSI,gDT SlRH,LDT SGR,gDT HTEN,LDT NPON,CNb CFTC,CNg MTEM,CNL THOR,NGT W2NG,NGT TENS,NGT 2 549 2 388 364 0 '999 '999 '999 '999 '999 '999 '999 -999 -999 -999 -999 -999 -999 ILD,DTE 545 IFRE,DTE 750 CIM~,DTE 000 SGR DTE 801 HTEN DTE 250 PEFbDT 250 LU bDT 250 SS2 gD~ 250 LSRH bDT 250 TENS gDT 250 NPHI CNL 250 RCN? CNL ~50 SGR CNg 250 HTEN CNg 250 POTA,NGT 250 W3NG,NGT 250 NTEM,NGT 250 2 205 2 450 500 CXMP 419 250 SGR 0 820 HTEN -999 250 PEr -999 250 gU -999250 S$2 -999 250 5SRH -999 250 TENS -999 250 NPH~ -999 250 RCNT -999 250 SGR -999 250 HTEN -999 250 POTA -999 250 W3NG -999 250 ~TEM -999 250 ILD DTE 219 IFRE DTE DTE DTE DTE LDT bDT gDT bDT LDT CNg NGT NG~ NGT 42 SGR,DTE 0 840 HT£N,DTE '999 250 PEF,gDT -999 250 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 gU,LDT 250 SS2,LDT 250 bSRH,bDT 250 TENS.bDT 250 NPHI,CNg 250 RCN? CNL 250 SGR CNL 250 HTEN CNL 250 POTA NGT 250 W3NG NG? 250 NTEM,NGT PAGE~ 2,525 20,000 392,500 94,005 1055,000 "999,250 "999,250 "9990250 '999,250 '999,250 '999,250 '999,250 999,250 999,250 999,250 "999'250 '999,250 189 ooo 450 250 lO 020 1031 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 "999 250 -999 250 344 2~ 000 1036 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ~999 250 -999 250 .-999 250 -999 250 -999 ~50 -999 250 15 Tape Verification Listing ,¢hlumberger AlasKa Computing Center '999,250 CS,NGT .: DEPT · IDOF IIRD TENS DPHI · bSHV bURH '. HTEM i".:TNPH RCFT TENS :URAN !> :,>,, W4NG ' HRE~ ~ . · ' ~:~ IDGF ?? '. D P H I ' ~UR.H :~NPH RCFt TENS ' URAN MRES ~. DEPT SP ~ IIRD ~TENS DPHI :, OLS ~URH : :TNPH RCFT TENS DTE DTE DTE DTE bDT bDT bDT bDT bDT bDT CNg NGT NGT- NGT NGT DTE DTE DTE DTE bDT bDT bDT' bDT bDT CNg NGT NGT NGT NGT DTE DTE DTE DTE bDT LDT {~DT bDT bDT bDT CNb' CNb 'SGR,NGT 6600.000 -24 750 0 000 334 000 4724 000 -999 250 -999 25O ~9-99 250 -999 250 -999 250 -999 250 -999 250 -.-999 250 -999 250 -999 250 -999 250 -999,250 -999,250 6500 000 -27 375 0 000 366 500 4440 .000 -999 250 -999 250 '999 250 '999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 6400 000 -23 781 0 000 378 750 4360 000 -999 250 -999 25O -999 250 -999 250 -999 250 ;999 250 999 250 -999 250 '999 250 -999 250 SFLU,DTE IDPH,DTE IMQF,DTE IIXD,DTE MTE~,DTE RHOB.LDT QMS,bDT LITH,LDT SSHV,LDT CALl,bDT' MRES,LDT TNRA.CNL CNTC,CNL MRES,CNL CGR,NGT WlNG,NGT W5NG,NGT CS,NGT SFLU DTE IDPH DTE IMOF DTE IIXO DTE ~TEM DTE [{HOB bDT QMS bDT LITH bDT SSHV bDT CALI LDT MRES bDT TNRA CNb CNTC CNb ~RES CNL CGR NGT W1NG,NGT WSNG,NGT C$,NGT SFLU DTE IDPH DTE IMOF DTE IIXD DTE STEM DTE RHOB bDT QSS LDT 5ITH LDT SSHV LDT CALI LDT MRES bDT TNRA CNL CNTC CNb MRES CNL CGR NGT 26-~AR-1990 15:28 -999.250 HTEN.NGT 2,369 2.492 0 000 5 813 12~ 000 -999 250 -999 -999 -999 -999 '999 " -999 -999 -999 -999 -999 '999 -999 25O 25O 250 25o 250 25O 25O 25O 25O 25O ,250 .250 2 107 0 0 64 O0 -999 ~50 -99 50 -999 -999 50 '999 250 -999 250 -999 250 2,018 2,156 0 000 72 750 127 000 -999 250 -999 250 -999 250 '999 250 '999 250 '999 250 -999 250 -999 250 -999 250 '999,250 ILM,DTE IMPH DTE CIDP DTE IIRM DTE MRES DTE DRHO gDT bM,bDT S$i,LDT S1RH,LDT SGR,LDT HTEN gDT NPOR:CNL CFTC,CN5 MTEM,CNL THOR,NGT WING,NGT TENS,NGT HTEN,NGT IbM DTE INPH OTE ClDP DTE NRES DTE -999.250 t , S , '999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,]50 -~99, 50 ' 99,250 '999,250 -999,.250 -~ 164 445 426 0 2 434 IbD,DTE 2 424 IFRE,DTE 401 000 CIMP.DTE 380 750 SGR,DTE 0 853 HTEN,DTE '999 250 PEF.bDT gU bDT 882 bD~ bSRH gDT TENS bDT NPHX CNg RCNT CNg SGR POTA NGT W3NG NOT MTEM,NGT lbD DTE 174 IFRE DTE 750 CIMP DTE 750 SGR DTE 35 HTEN DTE DRHO SS SlR~ HTEN NPOR CFTC STEM THOR WING TENS HTEN bDT -999 bDT , -999 bDT -999 bDT -999 bDT .999 bDT -999 CNg -999 CNb .999 CNb -999 NGT -999 NOT -999 NGT -999 NOT -999 ~50 ~U 50 PEF 50 8S2 50 bSRH TENS 250 RCNT 250 PO?A 250 W3NG 250 ~TEM 25O gDT bDT gDT' bDT bDT CNb CNb NGT NGT NGT ILM,DTE IMPH,DTE CIDP DTE lira DTE ~RES OTE DRHO bDT LS bDT SS1 LDT S1RH bDT SGR bDT HT£N bDT NPOR CNL CFTC CNL STEM CNL THOR,NGT 2 102 ILD,DTE 2 og6 IFRE,DTE 463 500 439 0 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 CIMP.DTE 000 SGR,DTE PEF,LDT 50 LU,LDT 50 ESl,bDT 250 bSRH gDT 25O TENS LD~ 250 NPHI 250 RCNT HYEN CN~ 250 POT4,NGT PAGE: 412 250 -9~ 903 ! ii ooo 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 2 199 20000 459 750 il 93~ 175 · 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 *-999 250 -999 250 -99~,250 -99 250 -999 250 -999 250 2 20 g}o 476 500 92 642 926 500 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 16 ;IS Ta'pe Verification Listlng ,¢hfumberger Alaska Computing Center URAN,NGT '999,250 .lNG NGT W4NG,NGT -999,250 W5NG:NGT MRE$,NGT -999,250 CS,NGT DEPT. SP'DTE IDQF,DTE IIRD.DTE TENS DTE DPH! bDT OhS TNPH ..,RCFT ?~! TENS 7. SGR URAN N4NG .j, DEPT SP j<~ IDQF 'XI~D ".TENS bSHV "bURH MTEM 'R~FT ~!~: TENS :$GR U~AN W NC ,,:, bDT bDT bDT bDT bDT CNb (:Nb tnb NGT ' NGT NGT NGT DTE DTE DTE DTE bDT bDT LOT bDT bDT bDT CNb CNb CNL NGT DTE DTE D?E DTE bDT bDT LDT bDT LDT MTEM bDT TNPHiCNL RCFT CNL 6300,000 -27 484 0 000 318 000 4400 000 ~999 250 ,999 250 -999'250 -999 250 -999 250 .~999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 6200 000 -25 750 0 000 340 500 4272 000 -999 250 -999 25O -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 6100 000 -27 484 4~84 000 -999. 250 -999 250 -999 250 -999 250 -999 250 -999,250 ~999,250 999,250 SFLU.DTE 1DPH,DTE IMOF,DTE IIXD,DTE ~TE~,DTE RHOB,LDT Q$S.bDT LITH LOT' $SHV bDT CAL! bDT PRES bDT TNRA CNL CNTC CNL ~RE$ CNL CGR NGT W1NG NGT W5NG NGT CS NGT SFLU DTE IDPH DTE IMQF DTE IIXD DTE ~TEM DTE RHOB bDT QSS LDT LITH LOT SSHV:LDT C^L~,LDT ~RES,LDT TNRA,CNL C~TC,CNL MRE$ CN5 CGR NGT WING NGT w5NG NGT CS NGT SFLU,DTE IDPH,DTE I~QF,DTE IIXD,~TE MTE~ DTE RHOB bDT (}SS LDT LITH LDT SSHV bDT CALI LDT ~RES bDT TNRA CNL CNTC CNL 26-MAR-1990 15:28 ~999,250 W2N¢;.NG~ 999,250 TEN$,NGT -999,250 HTEN,NGT 2,492 2,6~! 0,0 0 57.5b$ 125 688 -999 -999 -999 -999 · -' -999 -999 -999 -999 -99~ -999 -999 -999 250 250 250 250 250 250 250 5O 0 2 279 2 426 0 000 6 -999 0 -999 ~50 -999 50 -999 250 - ~ 250 -99 250 -999 250 -999 250 -999 250 ~999 250 -999 250 2 100 2 256 6~ 000 75O 123 875 -999 250 -999 250 -999 250 -999 ~50 ~999 50 -999 250 -999 250 -999 25O ILM,DTE IMPH,DTE CIDP,DTE IXRM,DTE MRE$,DTE DRHO,bDT LS,LDT SSI,bDT S1RH bDT SGR bDT HTEN LOT NPOR CNL CFTC CNb MTEM CN5 THOR NGT WgNG NGT TENS NGT HTEN NGT IbM DTE IMPH DTE CIDPDTE IIRM DTE ~RE$ DTE DRHO bDT LS bDT SS1 bDT S1RH bDT SGR LOT HTEN LOT NPOR CN5 CFTC CNL MTEM,CNb THOR,NGT W2NG.NGT TENS,NGT HTEN,NGT Ib~ DTE IMPH DTE CIDP DTE IIRM DTE MRE$ DTE DRHO bDT LS GDT SSi bDT S1RH,bDT SGR,GDT HTEN,LDT NPOR,CNL CFTC,CNL 999.250 W3NG,NGT 99,250 MTEM,NG~ ~99,250 2 656 2 378 349 0 -999 -999 .-999 -999 --999 =999 -999 -999 -999 -999 -999 -999 -999 IbD,DTE 551 IFRE DTE 250 CIMP 750 SGR 780 HTEN 250 PEF 0 250 bSRH 250 TENS 0 NPH! 0 ~GR W3NG MTEM DTE DTE DTE bDT bDT bDT ,bDT NGT NGT 2 352 2 412 393 0 -999 -999 -999 -999 -999 -999 =999 -999 -999 .-999 -999 -999 -999 ILD DTE 348 IFRE DTE 000 CIMP DTE 0 SGR DTE ~5 HTEN DTE 250 PEF bDT 250 LU bDT LSRH LDT 5 NPHI, CNL 5~ RCNT CNb 25 SGR CNL 250 HTEN CNL 250 POTA,NGT 250 W3NG,N~T 250 ~TEM,N T 250 2 178 I. bD,DTE 2 178 IFRE,DTg 43 000 4~4 CIMP,.DTE 250 SGR,D~E HTEN,DTE .PEF.bDT .0 -999 -999 -999 -999 -999 -999 -999 -999 823 250 250 LU LDT 250 $S2 LDT 250 bSEH bDT 250 TENS LDT 250 NPHZ CNE 250 RCNT CNb 250 SGR CNL PAGE~ ,,,999.,250 -99~,250 2 625 20 000 391 750 85 336 956 500 99~:250 :99 250 -999 250 -999,250 -999250 -999.~50 -99~ 50 -99 250 -999250 -999 250 2 398 ,20 000 425 0 ] Ooo -999 250 -999 250 -999 ~50 -999 250 -999 250 =999 250 -99~ 250 -99 250 -999 ~50 -999 50 -999 ~0 -999 50 2~ 221 000 459 000 96 675 1011 500 -999 250 -999 250 -999 250 -999 250 '999 250 -999 250 -999 250 -999 250 17 0~ 666- Of~ 666- Of 666- Oil: 666- Oil 666-. 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DTE DTE DTE DTE bDT bDT bDT ~SHV,LDT -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 5700,000 ..,.731,594 0 000 461 250 4050 000 -999 250 ..~999 250 -999 250 -9gg 250 -999 250 -999 250 -999 250 -999 ~50 ~999 250 -999 250 -999 250 -99~ 250 -99 250 5600,000 -27 125 0 000 4 000 ooo -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 "999 250 -999 250 -999 250 -999 250 5~00.000 29.344 0.000 34~,000 ~86 ,000 999,250 999,250 :999.250 -999.250 TNRA.CNL CNTC.CNL MRES.CNL CGR.NGT WlNG.NGT W5NG.NGT C$.NGT SFLU.DTE IDPH.DTE IMOF,DTE IIXD,DTE- ~TEM,DTE RI'lOB,bDT QSS.LDT LITH bDT SSHV LDT CAL! LDT MRES LDT TNRA CNb CNTCCNL ~RES CNL CGR NGT W1NG NGT WSNG NGT CS NGT SFbU DTE IDPH DTE IMQF DTE IIXD DTE MTEM DTE RHOB.bDT QSS,LDT LITH,bDT SSHV.bDT CALl LOT MRES:LDT TNRA CNb CNTC CNL MRES CNL CGR NGT WiNG NGT WSNG NGT CS NGT SFbU DTE IDPH DTE I~QF DTE IIXD DTE MTEM DTE RHOB.LDT (DSS,bDT LITH.LDT SSHV.~DT 26-~AR-1990 15:28 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 1,602 1.705 0 000 117 119 '- -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 *999 -999 563 625 250 250 250 250 250 250 250 250 25O 250 50 2,172 1,B56 0 000 72 500 119 000 -999 ~50 -999 50 -999 250 -999 0 "999 250 -999 250 -999 250 '99 50 -999 -999 250 2. 1 0 O0 57 ~94 -9 0 -999 ~50 -999 50 -999 250 NPOR,CNL CFTC,CN5 MTEM,CNL THOR.NG'£ W2NG,NGT TENS,NGT HTEN,NGT ILM DTE IMPH DTE CIDP DTE IIRM DTE MRES OTE DRHO bDT LS bDT $S1 bDT S1RH SGR bDT HTEN bDT NPOR CNb CFTC CNL MTEM CNL THOR NGT W2NG NGT TENS NGT HTEN NGT IbM DTE IMPH DTE ClDP DTE IIRM DTE MRES DTE DRHO bDT LS bDT S8~ bDT S1RH bDT SGR 5DT HTEN bDT NPOR CND CFTC CNb MTEM CNb THOR NGT W2N GT TEN~ N NGT HTEN NGT ILM DTE !MPH DTE CIDP OTE IIRM DTE MRES DTE DRHO bDT L$ bDT SS1 bDT $1RH LDT '999 250 RCNT.CN~ -999 250 SGR.CNb -999 250 HTEN,CNL -999 250 POTA,NG~ -999 250 w3NG,NG~ -999 250 MTEM.NGT -999 250 1 694 1 586 54O 0 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 ILO DTE 678 IFRE DTE 000 CIMP DTE 500 SGR DTE 955 HTEN DTE 250 PEF bDT 250 bU LOT 250 .8S2 LOT 250 GSRH bDT 250 TENS bDT 250 NPH! CNL 250 RCNT CNL 250 SGR CNL 250 HTEN CNb 250 POTA NGT 250 W3NG NOT 1 88b 1 538 487 0 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 IbD DTE 838 IFRE DTE 500 CIMP DTE 750 SGR DTE 963 HTEN DTE 250 PEF bDT 250 bU bDT 250 8S2 LOT 250 LSRH bDT 250 TENS bDT 250 NPHI CNL 250 RCNT CNb 250 SGR CNL 250 HTEN CNb 250 POTA NGT 250 W3NG NGT 250 NTE~ NGT 25O IFRE 4 0 -999 -999 -999 -999 250 LO 250 SS2 250 LSRH DTE DTE DTE DTE DTE bDT LDT LDT bDT PAGE: -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 I 723 -20 000 595 500 83 114 913 500 -999 250 -999 250 -999 250 -999 250 -999 0 -999 ~50 '999 50 -999 250 '999 '999 250 -807 88°o 85 11 861 ~00 -999 250 -999 250 -999 250 -999 250 .-999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 2 383 20 000 .909 500 -999 250 · -999 250 -999 250 -999 250 19 ,~S.T~pe Verification £,lstlnq ;¢hlumberger Alaska Computing Center bURH LDT MTEM RCFT TENG URAN WbNG MRE$ DEPT IDOl;' ~RD TEN~ LL LURH bDT CNb CNb CNb NGT NGT NGT NGT DTE DTE DTE DTE bDT bDT bDT bDT bDT MTEM bDT TNPH CNb RCFT CNL NOT URAN,NGT W4NG,NGT MRES,NGT ~! 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L bURH MTEM : URA MRES DTE DTE DTE bDT bDT bDT bDT bDT bDT CNb CNL NOT NOT NOT NGT -999 25O -999 250 -999 250 -999 25O -999 250 -999 250 999,250 999,250 999,250 5-400 000 -30 406 0 000 287 75O -3744 000 '999 250 -999 250 -999 250 -999 250 -999 250 :999,25o 999,250 :999,250 999,250 999,250 :999,250 '999~250 '999,~50 5300 000 -33 25O 0 000' 37~ 250 38! 000 -999 0 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 CALI,LDT MRES.LDT TNRA CNb CNTC,CNL ~RES,CNL COR,NGT WlNG.NGT WSNG.NGT CS.NOT FLU,DTE DPH,DTE IMOF,DTE IIXO,DTE MTEM,DTE RHOB,LDT QSS,LDT LITH,LDT SSHV,LDT CALI,LDT ~RES,bDT TNRA,CNb CNTC,C~L NRES.CNL CGR,NGT W1NG,NGT W5NG,NGT C$,NGT SFLU.DTE IOPH,DTE IMOF,DTE IIXD,DTE MTEM,DTE RHO~]LDT 05 LDT LITH bDT -S8HV bDT CAbI LDT MRE$ LDT TNRA CNL CNTC CNL M~E$ CN5 CGR,~GT W!NG,NGT W5NG,~GT CS,NGT DEPT, SP,DTE IDOF.DTE IRD,DTE IENS.DTE ~PHI,LDT OLS,LDT 52O0 000 -39 063 0 00o 3 25O -999 250 -999 250 26-MAR-1990 15128 -999,2b0 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 2,543 2,984 0 000 116 8 -999 250 '999 250 '999 250 '999 250 "999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 ~50 '999 50 '999 250 1,838 2 0 o 59 719 lJ5 625 '999 250 -999 250 '999 ~$0 -999 50 -999 250 -999 250 -999 ~50 -999 250 ~999 0 -999 250 -999,250 -999,250 SGR.bDT HTEN,bDT NPOR,CN4 CFTC,CN4 MTEH,CNL THOR,NOT W2NG,NGT TENS,NOT HTEN,NGT IbM DTE IMPH DTE CIDP DTE IIRM DTE MRES DTE DRHO bDT bM bDT SS1 bDT G1RH LOT SGR bDT HTEN bDT NPOR CNb CFTC CNb MTEM CNL THOR NOT W2NG NOT TENS:NOT HTEN,NGT ILM,DTE IMPH,OTE CIDP.DTE IIRM DTE MRES DTE DRHO bDT LS LOT SS{ bDT $1RH bDT SGR 5DT HTEN bDT NPOR,CNL CFTC,CNb MTEM,CNL THOR,NOT W2NG,NGT TENS.NOT HTEN,NGT SFLU,OTE 2 217 ILM,DTE IDPH,DT~ 2:693 IMPH,OTE. OTE 0 ~ CIDP DTE I~OF, E IIXD,DT 51.: I~RM:DT~ ~TE~4.DTE 114 500 "R""Eo. DTE RHOB,LDT '999:250 DRHO,GDT OSS,LDT '999,250 LS,LDT -999 250 TENS.I~DT -999 250 -999 -999 -999 -999 -999 -999 -999 250 RCN? Nb 50 SGR,CNb i 50 HTEN,CNb 50 POTA,NGT 250 W3NG,NGT 250 MTEN,NGT 25O 2 746 2 334 338 0 -999 -999 -999 -999 -999 -999 -999 -999 '-999 -999 -999 -999 -999 ILD OTE 19 IFRE DTE 50 CIMP DTE 500 $GR DTE 986 HTEN DTE 250 PEF bDT 250 bU bDT 250 250 LSRH bDT 250 TENS LDT 250 NPHI CNL 250 RCNT CNL 250 SGR CNL 250 HTEN,CNL 250 POTA,NGT 250 W3NG.NGT 250 MTEM.NGT 25O 2,'078 2 446 444 0 '-999 -999 -999 -999 -999 -999 -999 -999 '-999 -999 -999 -999 -999 ILD DTE 063 IFRE DTE 000 CINP DTE 000 SGR DTE 994 HTEN DTE 250 .PEF bDT 250 LU [,DT 250 S82 bDT 250 LSRH bDT 250 TENS bDT 250 NPH! 250 RCNT CNL 250 SGR,CNL 250 HTEN,CNL 250 POTA 50 MTEM.NGT 25O 2,459 ILD,DTE 2,465 IFRE.DTE ~7~,000 CI~P,DTE 7 ,000 SGR,DT~ 999 PEF:LDT 2999 250 LU,I, DT PAGE{ -999 250 -999 250 -999 250 -999 290 -999 250 -999 250 -999 250 -999;250 898 2~ 000 367 500 93 244 000 -999 250 -999 250 -999 250 -999 250 -999 )50 -999 50 -999 250 -999 250 -999 250 '999 250 '999 250 2 178 .20 000 484 250 5O0 -999 250 -999 250 · -999 250 -999 250 999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 22,613 :ooo 40 250 95,973 -9 250 -99 250 2O .'XS .T~e Verification blstino ;ChlUm erger AlasKa Computin~ Center LiURH :MTEM :TNpH RCFT 'SGR URAN 'W4NG MRE$ DEPT XDOF IIRD 'DPH! OT.,S MTEM .TNPH RCFT TENS URAN W4NG :DEPT DPH~ ~TE~ .TNPH TENS '~SGR MRES DEPT 8P IDOF IIRD T~N8 bL LDT LDT bDT bDT CNL CNL CNL NGT NGT DTE DTE DTE DTE bDT bDT bDT BDT bDT bDT CHI, CNL CNL NGT NGT NGT NGT DTE DTE DTE DTE bDT LOT LDT bDT bDT bDT CNL CNL NGT NGT NGT NGT DTE DTE DTE DTE -999,250 m999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 ~999,250 -999,250 5100 000 -44 688 0 000 .... 267 000 3714 000 -999 250 -999 ~50 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 5000 000 -5i 625 0 000 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 4900,000 -58,844 0,000 162 375 3490:00O LITM bDT SSHV:bDT CALI,LDT MRES,LDT TNRA,CNb CNTC'CNL MRES,CNL CGR,NGT WlNG,NGT W5NG,NGT CS,NGT . SFbU DTE IDPH DTE IMQF DTE IIXD DTE MTEM DTE RHOB LOT QSS [,DT LXTH LDT $SHV bDT CAbI,LDT MRES,GDT TNRA CNb MRES CNb CGR NGT WING NGT W5NG NGT CS NGT SFbU,DTE IDP}I,DTE IMQF,DTE IIXD,DTE MTEM,OTE RHOB.bDT QSS,LDT bITH,bDT SSHV,LDT CAbI,LDT MRES,I, DT TNRA CNb CNTC:CNL MRES,CNb CGR,NGT WlNG,NGT W5NG,~GT CS'~GT SFLU.DTE IDPH,DYE IhtQF.DTE I1XD,DTE ~TE~.DTE 26-NAR-1990 15~28 -999 250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 50 -999 250 -999 250 -999 ~50 -999 250 3.i52 3.318 3~ 000 250 ti3 ~50 -999 ~50 '99~ 50 '99 250 '999 250 '999 250 '999 250 '999 250 '999 ~50 '999 250 '999 250 - 9 50 '999 250 2.55~ 2,977 0 000 44 - 9 250 -999 250 m999 250 -99~ 250 "99 250 -999 ~50 -999 50 ~999 250 -999 250 -999 250 -999 250 -999 250 4 30 0,000 21,547 111.188 SSI,bDT $1NH,bOT SGR,LDT HTEN,LDT NPOR CNb CFTC CNL MTEM CNb THOR NGT W2NG NGT TENS NGT HTEN NGT IbM DTE IMPH DTE CIDP DTE IIRM DTE MRE~ DTE DRHO bDT DS bDT SSI bDT 8~RH bDT SGR LOT HTEN LOT NPOR CNL CFTC CNL STEM CNL THOR,NGT W2NG,NGT TENS,NGT HTEN,NGT .~,DTE CIDP,DTE IIRM,DTE MRE$,DTE DRHO,LOT [,8,LDT S81,bDT $IRH bDT SGR bDT HTEN bDT NPOR CNb CFTC CNb MTEM CNb THOR NGT W~NG NGT TENS NGT HTEN MGT IbM DTE IMPH OTE CIDP DTE IIRM DTE MREG DTE ~999,250 SS2,LOT .999,250 LSRH,LDT 999,250 TEN$,LD~ ~999,250 NPHI,CNL 999,250 RCNT,CNL -999,250 8GR,CNL -999,250 HTEN,CNL -999,250 POTA,NGT -999,250 W3NG,NGT -999,250 MTEM.NGT -999,~50 3,068 IbD,DTE 3.092 IFRE,DTE 301,000 CIMP,DTE 303,750 SGR,DTE ~ ~25 HTEN,DTE -99 50 PEF,LDT LU, .LOT -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 250 bDT 250 882 250 LSRH,LDT 250 TENS,LD~ 250 NPHI CNL 250 RCNT:CNL )~0 SGR CNL 0 HTEN:CNL 50 POTA,NGT 50 W3NG,NGT 250 MTEM,NGT 25O 2 760 2 335 336 ! -999 -999 -999 -999 -999 -999 '-999 -999 -999 .-999 -999 -999 -999 ILO DTE 766 IFRE DTE 750 CIMP DTE 750 SGR OTB 031 HTEN DTE 250 PEF,LDT 250 [,U,LDT 250 SS2,.LDT 250 LSRH,bDT 0 TENS,bDT 250 RCNT,CNL 250 SGR,CNL 250 HTEN CNL 250 POTA:NGT 250 W3NG NGT 250 MTEM:NGT 250 4 770 ILO DTE 4 672 IFRE DTE 187 500 ClNP DTE 196 875 SGR DTE 1. 034 HTEN DTE PAGE~ 21 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 176 2~ 000 32 50 960 500 -999 ~$0 -999 25O -999 250 -999 250 -999 250 -999 250 -999 250 -9 50 -999 250 -999 -999 50 2. 902 20 000 361. 500 88 285 821 000 -999 2.50 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 5 215 20 000 6O6 9O $ 50O ;IS..T~m~e Yerification blstinq ~chlU erger AlasKa Computing Center .. DPHI,bDT bSHV.bDT bURH bDT <. TMPH ~ RCFT -TENS ,..: "$GR ~' URAN DEPT SP IDOF ,TEN~ "DPHI ~L ~/ ~URH ~', RCFT · , TENS URAN 'L.' W~NG , '~XRD DPHI ~' ~SHV = ~URH , MTEM ~NPH bDT CNb CNb NGT NGT NGT NGT DTE DTE DTE DTE bDT bDT bDT bDT bDT bDT CN~ NGT NGT NGT NGT DTE DTE DTE DTE bDT bDT bDT bDT LDT LDT CNL · TENS CNL 'SGR NGT URAN.NGT W4NG NGT MRES:NGT 2999,250 999,250 -999.250 -999 25O -999 250 =999 250 -999 250 -999 250 -999 250 ~999 250 -999 250 -999 250 -999 250 4800 000 '61 406 000 24~ 500 3420 000 '999 250 "999 250 '999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 4700 000 -72 750 0 000 318 250 - 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999,250 -999,250 RHOB.LI3T OSS.LDT BITH,LDT SSHV,hDT CALI.LDT ~RES,LDT TNRA,CNL CNTC,CNL NRES,CN£, CGR,NGT WlNG'NGT W5NG,NGT CS.NGT SFLU,DTE IDPH.DTE IMQF.DTg IIXD,DTE MTEM,DTE RHOB.LDT QSS,LDT 5ITH.LD? SSHV.LDT CAL[ bDT ~RESiLDT TNRA CNL CSTC.CNb ~RES.CNL CGR NGT WlNGiNGT W5NG NGT CS,NGT SFLU.DTE IOPH,DTE I~OF,DTE I.[XD,DTE MTEM,DTE RHOB,bDT Q$S,bDT LITH,bDT SSHV.LDT CAL! LDT MRES:~DT TNRA,CNB CMTC,CNL MRES,CNL CGR,NGT WiNG W5NG:NGT CS,NGT 26-~AR-1990 15~28 '999.250 -999 250 '999 250 "999 250 -999 250 -999 250 '99~250 -99 250 99 250 -999 250 -999 250 -999 250 3 0 00~ 30 '999,25~ '999 ~50 -999 50 -999 -999 ~50 -999 ~0 -999 i 0 -999 -999 0 .99: o 4 145 0 0 0 47 9~9 250 -999 0 -999 250 '999 250 '99~ 250 '99 250 '999,250 '999.250 -999,2b0 -999,250 -999,250 DRHO,bDT LS,hDT SSI,bDT $1RH,hDT SGR,LDT HTEN bDT ~POR CNh CFTC CNb MTEH CN~ TMOR NGT W2NGNGT TENS NGT HTEN NGT IbM,DTE IMPH,DTE DP,DTE MRES,DTE DRHO.bDT LS.LDT SSI,bDT $1RH,LDT SGR,bDT HTEN,bDT NPOR.CNL CFTC,CNL MTEM,CNb THOR N~T W2NG NGT TENS NGT HTEN NOT IbM DTE IMPH DTE CiDP DTE IIRM DTg MRES DTE DRHO bDT LS bDT SSi bDT S1RH bDT SGR bDT HTEN LDT NPOR CNb CFtC C~b MTEN.CNL THOR,NGT W2NG,NGT TEN$,NGT HTEN.NGT -999.250 PEF LOT -999,250 LU bDT -999.~50 882 bDT -999. 50 [.$RH bDT -999,250 TENS bDT -999,250 NPH] CNb -999.250 RCNT CNb -999,250 SGR CNL -999,250 HTEN,C~L "999,250 POTA,NGT "999,250 ~3NG,NG~ -999.250 MTE~.NGT -999.250 ' 3,301 ILD,DTE 3,334 IFRE,DTE 288 000 CI~P DTE 282 750' MGR DTE ! -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 ! HTEN DTE ~0 PEF 250 bU bDT 250 8S2 LOT 50 LSRH,LDT ~50 TEN bDT 50 SG CNL 50 HTEN,CNh ~0 POTA.NGT 0 W3NG,NGT 250 ~TEM,NGT 25O 2 2 376 330 ! -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 1 It, D,DTE ~7 IFRE.DTE 500 CIMP.DTE 750 $GR.DTE 062 HTEN.DTE 0 PEF,LDT ~0 LU,LDT 50 $S2.LDT 50 bSRH.bDT NPRI,CNL 50 RCNT,CNL 50 SGR,CNL 50 HTEN.CNL 250 POTA,NGT 250 W3NG,NGT 250 MTEM,NGT 25O PAGE;; 22 -999 250 -999 250 -999 250 -999 250 -999 250 .-999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 3 381 20 000 299 750 60 834 913 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999;250 -999..250 '99 250 ~9 250 -9g 250 20 0 358 500 70 194 85~ 000 -99 250 -999 250 - 99 50 -999 250 -999 250 -99~ 250 "99 250 "999 250 '999 250 '999 250 '999 250 ~S Ta' e Verification Listing ,chlum~erger AlasKa, Computing Center DEPT, SP,DTE IDQF,DTE IIRD,DTE TENS,DTE DPHI,bDT LSHV bDT LURH bDT HTEM bDT TNPH CNL RCFT CNL TENS CNL SGR NGT URANNGT. W4NG NOT MRE$ NGT DEPT SP DTE !~. 'IDOF DTE IIRD DTE' ~,~:TENS~ DTE ~i!i:'.DPH! bDT ~:J~-,Ob$ bDT ~:'::,,bURH bDT '!? .TNPH CNL i!.i ~:TENS CNL '$GR NGT · URAN NGT :ili-'W4NG NGT MRES NGT 'IIRD DTE :~i ~TENS DTE DPHI bDT OhS bDT USHV bDT bURH bDT MTEM bDT ~'..TNPH CNL ~.~RCFT ~; :'~SGR NGT ~; 'URAN NGT ~!i~i'W4NG NGT 4600 000 -71 188 0 000 279 500 3324 000 -999 250 -999 250 -999 250 -999 250 -.999 250 -999 250 -999 250 -999 250 -999 250 =999 250 -999 250 -999 250 -999 250 ~500,000 111'375 0,000 646 500 3164 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -99~ 250 -99 250 -999 950 -999 ~50 -999 50 -999 250 4400,000 '53,125 0 000 294 750 33 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 SFLU,DTE IDPH.DTE INOF,DTE IIXD,DTE ~TEM,DTE RHOB,LDT OSS,I. DT LITH.LDT SSHV,bDT CAbI,LDT MRES,LDT TNRA.CNL- CNTC,CNL MRES.CNL CGR,NGT ~iNG,NGT W5NG.NGT CS.NGT SFLU,DTE IDPH.DTE IMOF.DTE IIXD DTE ~TEM DTE RHOB bDT QSS bDT LITH bDT SSHV bDT CALl bDT ~RES bDT TNRA CNb CNTC CNL ~RES CN5 CGR NGT W1NG,NGT WLNG,NGT CS,NGT SFLU,DTE IDPH DTE IHOF DTE IIXD DTE ~TEM DTE RHOB bDT OSS,LDT LITH,LDT SSHV,LDT CALl,bDT MRE$,LDT TNRA,CNL CMTC,CNL MRES,CNL CGR,NGT WlNG,hGT ~bNG,~GT 26-~AR-1990 15:28 5.430 3,027 0 000 42 156 108 875 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999,250 -999,250 -999.250 -999.250 -999,250 -999,250 -999,250 IL~ DTE IMPH DTE CIDP DTE IIRM DTE MRES DTE DRHO bDT b~ bDT SS! bDT S1RH bDT SGR bDT H?EN bDT NPOR,CNb CFTC,CNL MTEM CNL THOR NOT W2NG NGT TENS NGT HTEN NGT 2 .953 ! 0 150 107 -999 -999 -999 -999 '999 '999 -999 -999 -999 -999 999 -999 151 000 625 688 250 250 250 250 250 250 250 NPOR 250 CFTC 250 MTEM 250 THOR 250 W2NG 250' TENS 250 HTEN IbM DTE IMPH:DTE CIDP,DTE IIRM,DTE MRE$ DTE DRHO bDT LS bDT SS1 bDT 'S1RH bDT SGR bDT HTEN bDT CNL NGT N~T NOT 2 262 2 918 106 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 0 -99~ 250 -99 250 ILM,DTE IMPH,DTE ClDP,DTE IIR~,DTE ~RES,DTE DRHOeLDT LS,LDT SSI,bDT $1RH,bDT SGR,LDT HTEN,bDT NPOR,CNL CFTC,CNb MTEM,CNb THOR,N~T W~NG,N T TENS,NOT 3 33O 303 1 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 3 076 139 IFRE 000 CIMP 000 SGR 073 HTEN 250 PEF 250 t,~ 250 SS 250 bSRH 250 TENS 250 NPHI 250 RCNT 250 SGR,CNL 250 HTEN,CNb - 250 POTA,NGT 250 W3NG,NGT 250 MTE~,NGT 250 1 868 741 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2 2 342 315 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 ILL DTE DTE DTE DTE DTE bDT LOT bDT ,bDT ,bDT ,CNL .tNb 2 000 ClMP 50O 084 HTEN 250 PEF 250 bU 250 250 bSRH 250 TENS 250 NPHX 250 RC~T 250 50 50HTEN POTA .250 w3NO 250 ~TEM 25O ILD DTE IFRE DTE DTE DTE DTE bDT bDT bDT bDT CNb NGT 953 ILD DTE 928 IFRE DTE 500 CINP DTE 250 SGR 095 HTEN 250 PEF 250 250 250 bSRH 250 TENS 250 NPHI 250 RCNT 0 HTEN 250 POTA 250 w3NG 250 MTE~ DTE DTE BDT bDT bDT bDT bDT CNL C~b PAGE: 2 992 20 000 318 250 83 113 875 000 -999 250 -999 250 -999 250 -999 250 -999 25O -999 0 -999 250 -999 250 -999 250 -999 250 · -999 250 2O 825 000 28 5 -99 250 -99~ 250 -999 250 -999 250 -999 250 -999 250 -999 0 -999'2 0 '999 0 2 867 · 20 000 341 250 971. 0 -999 250 -999 250 -999 250 "999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 23 ,'IS Tap Yerlfication Listing ~¢hlumbeerger Alaska Computing Center 26-MAR-1990 15;28 PAGE: 24 MRES,NGT II DTE D~H Oh ,LDT ~SHV bURH ::,TNPH RCFT -TENS .URAN W4NG · ,' DEpT ~' IIRD ~ TEN8 ~ DPHI bL J' i:i LURH : TNPH :' ~CFT :TENS URAN : W4NG ~ MRE$ bDT LDT bDT LDT CNL NGT NGT N T DTE DTE DTE DTE bDT bDT bDT bDT LDT bDT CNL NGT NGT NGT NGT DEPT i /'XDQF 'XIRD TENS DPHI bSHV LURH ~TE~ TNPH RCFT .TENS 'SGR DTE DTE DTE DTE bDT bDT bDT bDT bDT bDT NGT '999,250 CS,NGT 4300 000 -62 750 0 000 344 750 3164 000 -999,250 -999,250 ~999,250 --999,250 -999,250 -999,250 -999,250 .m999,250 -999,250 -999,)50 -999, 50 -999,250 '999,250 4200,000 '103 625 0 000 582 000 3020 000 '999 250 '999 250 '"999 25O '999 250 '999 250 '999 250 -999 250 -999 250 -999 250 -999 ~50 -999 50 -999 250 -999 950 4100 000 -104 500 0 000 533 000 3100 000 -999 250 -999 25O -999 250 -999 250 -999 250 -999,250 -999,250 .-999,250 -999 250 -999:250 SFLU,DTE IDPH DTE IMQF DT£ IIXD DTE MTE~ DTE RHOB LDT QSS,bDT LiTH,LDT $SHV,LDT CALI,LDT. ~RES,LDT TNRA,CNL CNTC,CNL NRES,CNL CGR,NGT WING,NGT W5NG,NGT CS,NGT SFLU,DTE IDPH,DTE INOF,DTE IIXD,DTE ~TEM,DTE RHOB,LDT QSS,LDT LITH,LDT SSHV,SDT CALl bDT ~RES LDT TNRA CNL CNTC CN[, ~RES CNb CGR NGT ~ING NGT W5NG NGT CS NGT SFLU,DTE iDPH,DTE IMQF,DTE IIXD,DTE ~TEM DTE RHOB!LDT QSS LDT ~ITH,LDT SSHV,LDT CALX,LDT ~RES,LDT TNRA,CN5 CNTC CNL CGS,NGT -g99,250 HTEN,NGT 2 939 2~416 0 000 65 688 105 563 -999 25O -999 25O -999 250 -999 25O -999 25O -999 25O -999 25O "99 50 '999 250 '999 250 '999 250 '999 250 0 000 117 000 -999 0 -999 250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 50 -999 250 "999 250 99 0 -999 250 2.408 1,465 0 000 10 10] 063 5 -99~ 250 -999 250 -999 0 -999 250 -999 250 -999 250 -999 250 -999 250 Ib~ DTE INPH DTE CIDP DTE IIR~ DTE MRES DTE DRHO 5DT LS,LDT SSI,bDT SIRH,LDT SGR,~DT HTEN,bDT NPOR,CN5 CFtC CNb ~TE~ CN~ THOR NGT W2NG NGT TENS NGT HTEN NGT ILS DTE IMPH DTE CIDP DTE IIRM DTE MRESDTE DRHO bDT bS bDT SS1 bDT $1RH bDT SO~ I, OT HTEN bDT NPOR CNb CFTC CNL ~TE~ CNL THOR NGT W2NG NGT TENS NGT HTEN NGT Ib~ DTE IMPH DTE CIDP DTE IIRM DTE MRE$ DTE DRHO LDT bS LOT S$1 bDT $1RH 4DT SGR 4DT HTEN bDT NPOR CND CFTC CNb MTEM CNL THOR N~T '999.250 2 553 2 413 363 1 -999 -999 -999 -999 -999 -999 -999 '999 -999 -999 -999 -999 -999 ILD,DTE 527 IFRE DTE 750 CI~P DTE 500 SGR DTE 098 HTEN DTE 250 PEF LDT 250 b~ LDT 250 SS bDT 250 bSRH bDT 250 TENS bDT 250 NPHI CNb 250 RCNT CNE 250 SGR CNL 250 HTEN CNL 25~ POTA NGT 25 W3NG NOT 250 STEM NGT 250 380 ILD,DTE 376 IFRE,DTE 749 500 CXMP,DTE 658 1 -999 -999 -999 '999 -999 -999 -999 -999 -999 -999 '999 -999 '-999 000 SGR DTE 112 HTEN DTE 250 PEF bDT 250 bU bDT 250 SS2 LDT 250 LSRH LOT 250 TENS bDT 250 NPH! CNL 250 RCNT,CNL 250 SGR,CNb 250 HTEN,CNL ~0 POTA.NGT 0 ~50 250 1 476 1 682 617 1 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 ILD DTE 4~! IFREiDTE 000 CIMPDTE 500 SGR DTE ~ HTEN PEF bDT 250 LDT bU 250 250 LSRH 250 TENS NPHI 250 SGR 250 HTEN 250 POTA LOT bDT LDT CNL CNL CNL NGT 2 387 395 0 4 -999 250 -999 ) -999 250 -999 250 · -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 2~ 279 000 726 500 51 010 83O 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 1 406 20 000 693.000 48 310 90O 500 -999 250 -999 ~50 '999 50 "999 250 -999 250 -999 ~50 -999 50 -999 250 '999 250 '999 250 .IS T~pe Verification Listing .¢hlumberger AlasKa Computing Center URAN,NGT . H4NG,NGT NRE$,NGT DEPT, 'SP,DTE 'IDOF,DTE IIRD.DTE TENS,DTE DPHI,LDT QGS,LDT LL,~DT ~SHV,~DT bURH,EDT TNPH,CNL RCFT C~ TENS "SGR URAN W4NG DEPT, IDQF ,.DPHI '.'LURH CNL ' NGT NGT NGT NGT DTE DTE DTE DTE bDT LDT LDT LDT LDT :TNPH,CNb RCFT,CNb TEN~,CNb SG NGT ~ ,NGT W4 ,NGT MRE$,NGT !ii' DEPT · SP DTE "IDOF DTE =i 'IIRD DTE TENS DTE DPH! bDT ':'' OL$ bDT .: ~' LUR H i, RCFT bDT bDT bDT bDT CNL CNb -999 250 WlNG hGf -999;250 W5NG,NGT -999,250 C$,NGT 4000,000 -73,438 0,000 272,750 3240,000 '999,250 ~999,250 '999.250 '999,250 '999.250 -~999 250 '999 250 '999 250 '999 250 '999 250 '999 250 -999 250 -999 250 3900,000 -58,750 0,000 261.000 3060 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 25O -999 250 -999 250 3800,000 '53,625 0 000 29 000 -999 250 -999 2§0 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 SFLU,DTE IDPH.DTE I~QF DTE IIXO,DTE ~TEM,DTE RHUB,LDT OSS,LDT LITH,bDT- SSHV.LDT CALl bDT ~RE$ bDT TNRA CNL CNTC CNL MRES CNL CGR,NGT ~ING,NGT W5NG,NGT CS,NGT SFLU,DTE IDPH DTE IMOF DTE IIXD DTE MTEM DTE RHOB [,DT QS$ LDT bITH [,DT SSHV bDT CALl LDT MRE$ I.,DT TNRA CNb CNTC CNL MRE$ CNL CGR WING NGT W5NG NGT C$,NGT SFLU,DTE IDPH,DTE IMOF,DTE IiXD,DTE ~TEM,DTE RHOB,bDT OSS.LDT ~ITH,LDT SSHV,LDT CALI,LDT MRES,LDT TNRA,CNL CNTC,CNL 2b-MAR-1990 15:2~ -999.250 W2NG,NGT -999,250 TENS,MGT -999,250 HTEN,NOT 2.990 3.170 0.000 40.938 103 -999 250 -999 -999 -999 -'--999 -999 -999 -999 -999 -999 -999 -999 -999 2 0 25O 25O 25O 25O 25O 250 250 25O 25O 25O 3.271 3.281 0 000 35 969 .102 5OO · ,999 250 -999 250 -999 250 -999 250 -999 250 -999 250 '999 250 -999 250 -999 250 -999 -999 250 -999 250 -999 250 5,207 5,785 0 000 102'18 '999,250 '999,250 '999,~50 '999, 50 '999,250 ~999,~50 '999. 50 '999,250 IbM OTE IMPH DTE CIDP DTE IIRM DTE MRES DTE DRHO bDT LS bDT SSI bDT S1RH bDT SGR bDT HTEN bDT NPOR CNb CFTC CNL ~TE~ CNb THOR NGT W2NG NOT TENS NGT' HTEN NOT ILM,DTE IMPH,DTE CIDP,DTE IIRM,DTE MRES,DTE DRHO LDT LS bDT SS1 bDT S1RH bDT SGR bDT HTEN bDT NPOR CNL CFTC CN6 MTE~ CN~ THOR W2NG NGT TENS NOT HTEN NGT ILM,DTE !MPH'DTE DP,DTE ~IR~,DTE MRES,DTE DRHO,LDT SSI,LDT S1RH,LOT SGR,I, OT HTEN,bDT NPOR.,CNL CFTC,CNb ~99,250 W3NG,NGT 99,250 ~TEM,NGT '999.250 3 IFRE,DTE 298 500 SGR TE I 131 HTEN -999 250 -999. 0 -999 $0 -999 -999 250 -999 250 -999 250 -999 250 -999 $0 -999 ~50 -999 '-999 PEF bSRH TENS NPH! RCNT HTEN POTA W3NG ,LDT ,bDT bDT CNL, CNL CNL CNL NGT NGT NGT 3 098 3 304 301 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 ILD DTE 088 IFRE DTE 0 CIMP DTE ~0 SGR DT£ 146 HTEN DTE 250 PEF bD~ 250 LU bDT 258 S82 25 bSRH NPH! 250 RCNT 250 SGR 250 .T£N 250 POTA 25O W3NG 250 ~TZ~ ~50 bDT bDT bDT CNL CNL NGT 5 5 172 187 -999 -999 -999 -999 -999 -999 ~999 -999 012 ILD,DTE 055 I'FRE,DTE 750 CIMP,DTE 500 8GR,DTE ~87 HTEN DTE 250 PEF bDT 25O L~ ~$O NPHI ~$O RCN? 250 $GR bDT bDT LDT bDT CNL CNb CNb PAGE: 25 999.250 :999'250 3 O0 2O ~00 322 000 56 849 996 500 -999 250 -99 -999 ~50 -99~ -999 -999 250 -999 250 '"' 118 '999 -999 250 3 213 20 000 323 !0 9~ 0 0 -999 250 -:999 250 .999'i50 '999 50 · -999 50 1999 250 -999 2~0 '999 250 -999 250 -999 250 -999 250 -999~250 O0 i 97 625 90 049 858 5O0 -999 250 -999 250 -999 250 -9 250 '999 -999 250 Verification LlstJ. n~ ~¢hlUmberger AlasKa Computing Center 26-MAR-1990 15:28 TENS CNb -999,250 ~%RE6.CNL -999,250 'SGR:NGT -999,250 CGR.NGT -999,250 URAN,NGT -999,250 W!NG NGT -999.250 W4NG,NGT -999,250 {~bNG:NGT :999.250 MRES,NGT -999,250 CS,NGT 999.250 DEPT, SP,DTE ~. IDQF,DTE IIRD,DTE TENS,DTE DPHI,LDT OLS LOT ~ Lb LDT ~$HV ~DT bURH bDT bDT CNb NGT NGT NGT DTE DIE DTE DTE LOT bDT LOT bDT ~DT bDT CNL CNL CNL NOT NGT NOT NGT DTE DTE DTE DIE bDT bDT bDT LOT LOT bDT 3700.000 '62,625 0 000 ~'~'I-13 563 2910 000 '999 250 -999 250 -999 250 -,999 250 -999 250 -999,250 -999,250 -999,250 -999.250 -999,250 '999,250 '999,250 '999,250 3600 000 '57 313 0 000 59 875 3010 000 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 ~500 000 '56 625 0 000 154 375 2900 000 "999 250 '999 250 '999 250 ~999,250 99,250 ' 99,250 SFI, U.DTE IOPH,DTE I~OF,DTE IIXO,DTE MTEM,DTE RHOB,LDT' 085 bDT ~ITH~LDT $$HV,LDT CALI,LDT ~RES bDT TNRA CNL CNTC CNL MRES CNL CGR NGT WING NGT W5NG NGT CS NGT SFLU DIE IOPH:DTE IMQF DTE IIXO DTE MTEM DTE RH00 LOT QSS LDT LITH bDT SSHV LDT CALI LDT ~RES LDT TNRA CNL C~TC:CNL MRE$ Chh CGR:NGT ~ING,NGT WbNG,NGT CS,NGT SFbU,OTE DTE IDPH,) IMOF,iTE IIXD,DTE ~TEM,DTE RHOB,LDT OSS,LOT LITH,LDT $SHV,LDT CALl,bDT MRES.LOT MT EM TNPH RCFT TENS URAN W4NG MRE$ DEPT St:' IOOF ~TENS DPHI EURH MTEM TNPH RCFT TENS SGR UR MR ES DEPT IIRD DPHI OL$ LL 5URH MTE~ 6 2 0.000 10 219 101 -999 -999 -999 -999 -999 -999 -99 -999 -999 -999 -999 -999 5 250 250 250 250 250 0 50 0 18 0 000 5 '999 0 '999 ~50 '999 50 '999 250 -999 250 '999 250 '999 250 '999 250 '999 250 999 250 -999,2§0 5:727 0.000 12.7{9 99,375 999 250 999 250 -99~,250 -99 , 250 w999.250 MTEM CNb THOR NGT W2NG NGT TENS NGT HTEN NGT IbM DTE IMPH DTE CIDP DIE IIR~ DTE ~RES DTE DRHO bDT LS bDT SS1 bDT S1RH bDT SGR bDT HTEN bDT NPOR CNL CFTC CNL ~TEM CNb THOR NGT W2NG NGT TENS NGT HTEN NGT Ib~ DIE IMPH DTE ClDP DTE IIRM DTE MRE$ DTE DRHO bDT LS bDT SS1 bDT SIRH bDT SGR bDT HTEN bDT NPOR CNL CFTC CNL MTEM CNL THOR NGT W2NG NGT TENS NGT HTEN,NGT IbM DTE IMPH DTE ClDP DTE IIRM DTE ~RE$ DTE DRHO bDT bS LOT SS! LOT $1RH bDT SGR'LOT HTEN,bDT '999 250 HTEN.CNL '999 250 POTA,NGT '999 250 W3NG,NGT '999 250 MTE~.NGT '999 250 125 130 1 -999 -999 -999 -999 -999 7 242 ILO,DIE 7 332 IFRE,DTE 063 CI~P,DTE 250 SGR,DTE 166 HTEN,DTE 250 PEF,LD~ 250 LU,bD~ 50 SS2,bDT 50 LSRH,bDT 50 TENS,bD~ -999 250 NPHI,CNL =999 6GR NL '999 250 HTEN Nb '999 250 POTA GT '999 250 W3NG GT '999 250 NTEM,NGT -999 250 18 422 lbO,DIE 18 141 IFRE,DTE 59 531 CI~P,DTE HTEN,DTE 51 -999 -999 -999 -999 -999 -999 -999 -999 999 -999 -999 -999 531 160 :~§ PEF.LDT LO,bDT 50 SS2,LDT 50 LSR~.LDT 250 TENS,bDT 250 250 RCNT,CN~ 250 SGR,CNL 250 HTEN,CNL 250 POTA,NOT 250 W3NG'NGT 250 NTEM'NGT 25O 4 4 174 191 1 -999 -999 -999 -999 -999 -999 IFRE DTE 500 CIMP DTE 375 SGR DTE .175 HTEN DTE 250 PEF bDT 250 LU bDT 250 SS2 bDT 250 250 TENS,bDT 250 NPHI'.CNL PAGE: 26 999,250 999,250 99 250 7 770 20 000 136 250 53 527 886 ~00 -99~ 50 -99 250 -999 250 -999 250 -99~250 -99 250 -999250 -999 250 -999 250 -999 250 '-999 250 -999 250 15 211 .20 000 55 094 3 30 -999 250 -999 2~0 -999 ~ 0 ,-999 50 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 21 205 875 ,75 394 962 500 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 IS Ta~e Yerltication blstin~ chlumberger Alas.~a Computin~ Center TNPM CNL RCFT CNL .TENS ~SOR · DEPT IDQF 'TENS DPH! OhS LURH RTB~ TNPH RCFT 'SGR URAN ~4NG : DEPT - .$p >,' IDQF :' I'IRD .TENS DPHI :MTEM ~ RCFT .~:~ URAN CNL NGT NGT NGT DTE DTE DTE DTE bDT EDT bDT bDT EDT (:Nh CNL CNh NGT NGT NGT NGT DTE DTE DTE ~DT EDT bDT EDT EDT bDT CNh CNL, CNL, NGT -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999,250 3400 000 ~.,.-57 438 * 0 000 171 875 2810 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 25O -999 25O -999 250 -999 25O 3300 000 -71 625 0 000 75 250 2770 000 -999 25O -999 25O -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 TNRA,CNL CNTC,C~& MRES,CNL CGR,NGT WING,NGT WhNG,NGT CS,NGT SFLU,DTE IDPH,DTE IMOF,DTE IIXD,DTE-. MTEM,DTE RHOB,LDT QSS,LDT LITH,LDT SSHV,LOT CALI,LDT ~RES,LDT TNRA,C~L CNTC,CNL MRES,CNL CGR,NGT WING,NGT ~5NG.I.~GT C$,NGT SFLU OTE IDPHiDTE IMQF DTE IIXD,DTE MTEM,DTE RHOB,LDT QSS EDT LITH EDT SSHV bDT CAb! EDT ~RES LDT TNRA CND CNTC CNL MRES CNL CGR!NGT WING NGT WhNG NGT CS,NGT W4NG NGT · MRES,NGT DEPT, 3200 000 SF[,tI,DTE SP,DTE -66:688 .IDPH,DTE 'IDQF,DTE 0,000 I~QF,DTE I'IRD,DTE 109,500 !IXD,DTE TENS,DTE 2724,000 MTEM,DTE : DPHI,bDT '999,250 RHOB,LDT .QLS,LDT -999,250 QSS,bDT L[.,LDT -999,250 LITH,LDT LSHV,LDT -999,250 $SHV,LDT 26-MAR-~990 15128 -999.2b0 -999.250 -999 250 '999:250 '999,250 -999,250 -999,~50 4,207 5,090 0.000 15,367 98 688 · " -999 250 ' 9 250 -999 250 -999 ~50 99 .2 0 -999,250 '999.250 -999 250 -999!250 -999 ~50 -999. 50 10,594 12,820 0,000 6 414 98 125 -999 250 -999 250 -999 250 -999 250 -999250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 6,754 8.188 0 000 7 688 97 125 -999 250 -999 250 -999 250 -999 250 NPOR,CNb CFTC,CNb NTEM CNL THOR NGT W2NG NGT TENS NGT HTEN NGT IhM,DTE IMPH,DTE ClDP,DTE IlRM DTE MRES DTE DRHO bDT LS bDT SSI EDT SIRH LDT SGR LDT HTEN bDT NPOR CNL CFTC CNL NTEN CNL THOR NGT ,2NG NGT TENS ~{GT HTEN NGT Ib~ IMPH DTE CIDP DTE IIAM DTE NRES DTE DRHO bDT b$ bDT SSl bDT S1RH EDT SGR bDT HTEN EDT NPOR CNL CFTC CNL MTEM CNL THOR NGT W2NG NGT TENS NGT HTEN NGT I~,M,DTE I~4PH,DTE CIDP,OTE IIR~,DTE MRES,DTE DRHO,bDT LS,LDT SSI,EDT S1RH,LDT -999 250 RCNT.CN5 -999 250 SGR,CNL -999 ~50 HTEN,CNh -999 50 POTA,NGT -999 250 ~SNG.NGT -999 250 ~TE~,NGT -999,2~0 4 4 196 214 ! -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 83 ILO,DTE 18 IFR!!DTE 250 CI~ DTE 000 SG DTE 195 HTEN,DTE 250 PEF,LD~ 250 LU,LD~ 250 SS2,LDT 50 LSRH,LDT 250 NPH~ NL 250 RCN ,CNL 250 SGR,CNL 250 HTEN.CNL 50 POTA,NGT 50 WSNG,NGT 250 MTE~,NGT 25O 1! 266 1! 78 84 1 -999 -999 -999 -999 '999 -999 .-999 -999 -999 -999 .-999 -999 ILD DTE 633 iFR~ DIE 000 CIM DTE 063 SGR DTE ~99 HTEN DTE 250 PEF bDT 250 h~ LDT 250 SS bDT 250 LSRH LDT 250 TENS 250 NPHI CNL 250 RCNT CNb 250 SGR C~b 250 HTEN CNG 250 POTA NGT 250 W3NG,NGT 250 MTg,,NOT 250 7 7 122 {.32 1 -999 ,~999 -999 -999 ILD.DTE 125 CIMPiDTE 500 SGR DTE 207 HTEN DTE 250 PEF,bDT 250 LO,bDT 250 S$2,LOT 250 LSRH,LDT PAGE: 27 '999,250 '999~250 '999,250 '999,250 '999,250 '999,250 5 020 20 000 226 250 77 266 944 500 --999 250 -999 250 -999 250 -999 250 -999 250 -999 250 '999 25O '999,250 '999,250 '999,250 "999,250 '999,250 12 117 20 ~00 85 38 58 978 926 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 "999 250 "999 250 '999 250 '999250 -g99 250 8 031 20 000 ooo 324 908 000 -999 250 -999 250 -999 250 -999 250 OGE 666- OGE 666- OOG 906 88t ~0~~ O0 O~ Og~ 666- OGE 666 OGE 666. 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': 3/,0 dS £DN &DN £DN qN3 qN3 qND ,I, Oq 3.1'.0 ,tDN &DN DNtM " AH~q qq~ &d3O NVan aDS" qND:HdN&': £oq'N3&N :aluao 6ulAndmoD e~seT¥ Ja61aqmnTqOi but%sTq uotleoT~TJaA ~S.T~pe Verification LlstfDq chlumberger AlasKa Computing Center b[,.LDT -999,250 b[TM,LDT ~$HV.LDT '999 250 SSHV,bDT LURH,LDT -999 250 CALf,bDT MTEN,LDT --999 250 ~RES.LDT TNPH CNL -999 250 TNRA CNL RCFT CNL -999 250 CNTC',CNb :<.i~-:TENS CNb -999 250 MRE$,CNL *$GR NGT -999 250 CGR,MGT URAN NGT 1-999 250 W!NG,NGT ,~!i'W4NG NGT ~999,250 W5NG.NGT ~,NRES NGT "999,250 CS,NGT DEPT, 2800,000 SFLU DTE SP,DTE -85,625 IDPH DTE ID~F,DTE .... 0.000 I~F DTE IIRD,D?E 83,43@ IIXD DTE TENS DTE 2634 000 ~TE~ DTE DPHI bDT -999 250 RHOB,LDT OhS bDT -999 250 ~SS,bDT LL ~DT -999 250 b[TH,LDT 5SHY bDT -999 250 SSH¥,bDT ~URH ~DT -999 250 CALI,LDT MTEM ~DT -999 250 ~RE$,bDT TNPH CNb -999 250 TNRA CNL ,iii~ RCFT CNL -999 250 CNTC C~L TENS CNL -999 250 MRES '$GR NGT -999,250 CGR NGT !i ~URAN NGT. -999,250 H~NG NGT W4NG,NGT -999,250 ~bNG NGT MRES.NGT -999,~50 CS NGT </: .DEPT 2700 000 SFGU DTE .SP DTE -74 000 DPH DTE 0 000 I~QF DTE :iiIIRD DTE 54 656 I IXD DTE ~:hTEN$ DTE 2574 000 M'rE~ DTE ~i~<DPHI,~DT -999 250 RHOB bDT ,OhS,bDT' '999 250 QSS ~l)T Lb,bDT -999 250 LITH bDT , 250 LSHV bDT -999 SSHV ~DT bURH bDT -999 250 CAbI MTEM bDT -999 250 MRES bDT TNPH CNL -999 250 TNRA CNL ReFT CN5 -999 250 CNTC CNL CS. U.A..G 25o W4NG NGT -999 250 WbNG"NGT NRE8 NGT -999 250 C$,NG~ DEPT 269~,500 SFLU ET~ 9696 000 SP:DTE '75,750 XDPF~:~TE 1V:7~9 IIRD:DTE 52,500 IIXD,DTE 0,000 ~:~ TENS,DTE 2604,000 MYE~q. DTE 93.3~3 26-MAR-1990 15:28 -999.2b0 SSX,LDI' -999 250 $1RH,GDT -999:250 SGR,bDT '999,250 HTEN,bDT :~9.250 NPOR CNb 999, 50 THOR,NGT '999,250 W2NG,NGT :999,250 999,250 HTEN,NGT 8 539 o 7 367 94 500 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 "999 ~50 '999 50 '999 250 '999 ~50 '99~ 50 '99 250 9696 000 16 797 0 000 000 9~ 625 '999 25O "999 250 99 250 -99~ 250 -99 250 -999 250 -999 250 -999 250 -999 ~50 -99~ 250 -99 250 -999,250 IbM DTE IMPH DTE CIDP DTE IIRM DTE MRES DTE DRHO bDT BS bDT SSI bDT SGR DT HTEN bDT NPOR CNb CFTC CNb THOR NGT W2NG NGT ENS NGT TEN NGT Ib~ OTE IMPH DTg CIDP DTE IIRM DTE MRE$ PTg DRHO bDT S$! bDT $XRH bDT SGR bDT HTEN bDT NPOR CNb CFTC CNb MTEN CNI, THOR NGT W2NG,NGT TEN$,NGT HTENeNGT II, M,DTE IMPH, DTE CI DP, OTE IIRM,DT£ MRES,DTE -999 250 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 $82,bOT 250 bSRH bDT 250 TENS bDT 250 NPMI CNb 250 RCNT CNL 250 SGR CNL 250 HTEN CNL 250 POl'a NG~ 250 W3NG NGT 250 MTEM NGT 250 9 922 ILD,DTE 9 648 IFRE,DTE CINP,DTE SGR,DTE HTEN.DTE 90 95 1 -999 -999 -999 -999 -999 -999 -999 .-999 -999 -999 -999 -999 -999 688 375 250 250 PEr,bDT 250 bU.GDT 250 S$2.bDT 250 LSRH,bDT 250 TENS.~DT 250 NPHI.CNb 250 RCNT,CNL 250 SGR,CNL 250 HTEN,CNL ~8 POTA.NGT W3NG,NGT 250 MTEM'~GT ~50 1950 000 1950 59 -410 -999 -999 *-999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 ILD,DTE 000 IFRE,DTE i O0 CI~P.DTE ~ SGR,DTE HTEN,DTE 250 PEF bDT 250 LU:LDT 250 SS2,LDT 250 LSRH,LDT 50 TENS.bDT ~50 NPHI,CNL 250 RCNT,CNL 250 $GR,CNL 250 HTEN.CNL 250 POTA,NGT 250 W3NG NGT 250 ~TE~:NGT 25O 1950 000 1950~000 56 406 -319i500 { 267 ILD DTE IFRE:DTE CIMP,DTE SGR.DTE HTEN.DTE PAGE: 29 -999 250 -999 250 -999-250 -999 250 -999 250 · -999 250 -999 25O -999 250 -999 250 -999 250 10 789 20 000 103 563 46 146 982 500 -999 250 -999 250 -999 250 -999 250 -999 250 9 2so 250 -999 250 -999 250 -999 0 -999 250 16,2 1 20 ~0 994 O0 '-999 250 -999 250 -999 250 -999 250 -999250 -999 250 -999 250 -999 ~50 -999 250 -999 250 -999 250 -999 250 16 969 20 000 '322 75O 47 667 1015 000 666'~'6~0~06 ['q £IN~ £NIOd 3N~IW iNIOd 3N~IW 'DNI ODONOD 9~/£0/06 : ~0 ~0¥t00 : NOIg~3A :~: ~OVIO0 DIQ'3 TOO' ,riO3 OG~ 666- OG~ 666. 0~ 666- 0~ 666- Og~ 666- Og~ 666- OG~ 666- OGZ 666- 0~ 666- OG~ 666- 0~ 666- 0~ 666- O~ :39~d qND'N3&H qND*aDg Og~ qND'IHdN ~'H~gq 0~ ~Qq'Nq Og~ 666- 666- 666- 666- 666- 666- 666' 666- 666- 666' 666' 666- OgE 666' £DN N3IH &DN MOHI qND'BO~N 0§~;' Ogi~ O~Z 0~;~ 0~: 0~ O.q~: O~Z Oq~ 0~ 666' 666' 666- 666- 666' 666' 666- 666~ 666- 666- 666- 666' 666' 8g:~I 066t-~VW-9~ &Oq'AHgD $O'i'H£Ifl iOq'gOH8 Og~ 666- og~ 666- Og~ 666- Og~ 666~ Og$ 666- 0gZ°666- 0g~666- 0g~:666~ 0~ 666- 0~666- 0~'666- 0gg'666' 0gg°666' ,T. DN &DN qN3 HdN& &Oq'IHdG .~a:luaD buTlndu~O3 eNseIV JaB.~qmnlq~i! ,SS T~pe Verification Listing lChlUmberger Alaska Computlno Center 26-~AR-1990 15:2H PAGE: DATA SAMPLED EYER¥ -,1000 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NA~E bDT ,LDH LITHO DENSITY 8800' TO 8500' CNT-A/D/H ,CNH COMPENSATED NEI!TRON 8800' TO 8500' TABLE TYPE : CONS TUNI VALb DEFI CN CONOCO INC. Compan~ Name FN ~ILNE POINT Field Name WN ~ILNE POINT UNIT 5-3 ~ell Name APIN 50-029-21999 API Serial_ Number F5 2021' ~NL & 190' FW5 Field Location 'SECT 3 Section TOWN 13~'~ Township RANG ~ OE Range COUN NORTH ~LOPE County STAT ALASKA State or Province ..NATI USA Nation 'WITN POL~/DII~LON Witness' Name .SDN 548 4 Service Order Number :.PDAT ~Sb Permanent datum /~'~, EPD FT 0 :b~r ~B bog ~easured From APD FT 34, )~ "::'EK B FT 34, ED F F T 33 FT '9~9,25 ~:TDD FT B900, _ ' 'T B E TYPE . CURV ~: ' DEFI ;~ ~:.: RHO~ Bulk Density DRHO Delta RHO PER Photoelectric Factor ObS Quality control of lon~ spacing for LDT ~.'~ bS Long S acln? o~ uted Court Rate (LL+6U/2) · LU Long Upper ' ndow Count Rate (LUI+LU2) : :~DVd uolsua£ peaH N~&H ' A]TA'[~T~B aAH ~ ...:, mnT~se~oa ,~unTue~n ,,~u~zoq£ ~uo~.~g pa~n~moD eH-emme9 AdOOSO~O~d~ D£JD. D&&D oI~eH uo~naN Te~aq& pa~e~q~TeD ~SNi X~TSO~Od uo~lnaN Tem~aq& HdN& A~solod uo1~naN XHdN uo~sua& peaH N3~H ? uo~ua& gN3~' ,. · n~sse~od ,~nTu.e:~ 'mnT~oq& ~oz~ 89 pe~ndwqD ~e~-em~e9 AdoogoI~eag 8gg' ~adyTeD IqVD · ~OFIB JaddA buoq H~ (pe~oa~q~uA) QOH~ bUTO-eag 6uoq ^~;sue~ ~ Ou;ae~g ~oqg H~g lnd~r,o dOOq abe~Ton HbTH byTDe~ ~Oqg AHgg :nd~nO eb~TOn qbTH bUTO~g ouoq AHgq · a~ ~unoD ~OpU~M ~ bUTDed~ ~oqg ~unoD ~opu~ :a~oq buoq q~ ........ ...... .... .....----.. ........... ................._ I~3O 8g:~T 066T-~VN-9~ · ,'iS T~pe Verification [.,istln,: ~chlumberger AlasKa ComDutlnO Center 26-MA~-1990 15:28 PAGE~ 33 1.4 65 FT 15 66 60 lb 66 1 0 66 1 DEPT FT ..... 548444 O0 DPHI LDH PU 548444 07 RHOB LDH G/C3 548444 07 DRHO ~DH G/C3 548444 07 .PEF 5DH 548444 07 :.'~:-QL$ GDH 548444 07 08S bDH 548444 07 L$ 5DH CPS 548444 07 LU 5DH CPS 548444 07 5L ~DH CPS 548444 07 ~ITH LDH CPS 548444 07 SS! 5DH CPS 548444 07 $82 5DH CPS 548444 07 LSHV LDH V 548444 07 $SHV LDH V 548444 07 .SlRB LDH G/C3 548444 07 5$RH 5DH G/C3 548444 07 LUR~ LDH G/C3 548444 07 CAb'I 5DH IN 548444 07 'SGR 5DH GA~I 548444 07 .CGR 5DM GASI 548444 07 TENS 5DH LB 548444 07 ~TE~ LDH DEGF 548444 07 FRE5 LDH OH~M 548444 07 HTEN ~DH LB 548444 07 NPH! CNH PU 548444 07 TNPH CNH PU 548444 07 TNR~ CNH 548444 07 NPOR CNH PU 548444 07 :~ .RCNT CNH CPS 548444 07 RCFT CNH CPS 548444 07 ~i~i.,.:.CNTC CNH CPS 548444 07 :~: ~CFTC CNH CPS 548444 07 SGR CNH GAPI 548444 07 CGR CNH GAPI 548444 07 ~'(:. TENS CNH 58 548444 07 MR~$ CNH OH~ 548444 07 MTE~ CNH DEGF 548444 07 ' .HTEN CNH 58 548444 07 ooo oo o 2 1 1 4 68 0000000000 ~90 O, 0 ~ 1 ' 4 68 0000000000 3~0 02 o ~ 1 1 4 6~ 0000000000 ~s~ ol o ~ 1 , 4 6~ 0000000000 358 O1 0 2 1 I 4 68 0000000000 354 Ol 0 2 1 1 4 68 0000000000 354 O1 0 2 1 i 4 68 0000000000 ]s~ ol o ~ , 1 4 68 oooooooooo ~54 ol o ~ 1 1 4 68 oooooooooo 354 Ol o 2 1 1 4 68 0000000000 3~4 O1 0 2 I , 4 6~ 0000000000 354 02 o 2 ! 1 4 68 0000000000 35~ 02 0 2 I I 4 68 0000000000 354 O0 0 2 1 ). 4 68 0000000000 354 oo 0 2 I ! 4 68 0000000000 350 02 0 2 1 1 4 68 0000000000 350 02 o 2 I , 4 6~ 0000000000 350 o~ o 2 I t 4 68 oooooooooo 2~0 O1 o 2 1 1 4 68 oooooooooo 3~,0 O1 0 2 1 I 4 6~ oooooooooo 31o ol o 2 ~ 1 4 6~ oooooooooo 635 21 o 2 1 , 4 68 oooooooooo ooo oo o 2 1 ,. 4 68 0000000000 ooo .oo o 2 1 ~ 4 68 0000000000 ooo oo o 2 1 l, 4 68 0000000000 890 O0 0 2 1 1 4 68 oooooooooo 890 oo o ~ 1 i 4 68 0000000000 420 Ol o 2 I 1 4 6B 0000000000 890 oo o ~ 1 ~. 4 68 0000000000 4~0 ol o 2 1 ! 4 6~ oooooooooo 4~0 ol o 2 1 1 4 6~ 0000000000 4~0 O1 0 ~ 1 1 4 6~ oooooooooo 420 O1 0 2 1 1 4 68 0000000000 a,o ol o 2 1 1 4 6~ oooooooooo 31o o1 o 2 ! I 4 68 oooooooooo 635 21 o 2 I 1 4 68 oooooooooo ooo oo o ~ i 1 4 6~ 0000000000 ooo oo o 2 ~ 1 4 68 0000000000 ooo oo o ~ 1 1 4 68 oooooooooo ,~I& T&Pe verification [,istinq ~¢hlumberger Alaska Con, putJ. ng Center DATA PEF,LDH bU.bDH SS2,LDH ~CGR.bDH H~EN,LDH NPOR,CNH CF?C,CNH MRE$,CNH '~EF, LB,bDH bSRH,~DH CGR,LDH 'HTEN,~DH CNH CFTC~CNH MRE$.CNH DFPT PEF ~U 882 L$RH 'CGR <i!HTEN N~O~ CFTC I~DH DDH DDH .bDH LDH LDH CNH CNH CNH DEPT PEF LDH LU LDH '582 LDH bSRH LDH CGR LDH HTEN LDH NPOR,CNH MRE$ NH 400 DPHI 758 OLS:LDH 000 LL,LDH 000 LSHV,LDH 389 LIJRH,LDH 340 TEHS,LDH 500 NPHI,CNH 886 RCNT.CNH 41~ SGR,CNH 751 MTEM'CNH- 8795. 4, 278. 290 2 82 744 O, 8700, "278, 294, 2 66 844 3 0 8600, 4, 24{, 26 , 2, 1041 44, 583, 0, 8500 247 281 2 88O 34 735 0 8488, 2. 244 278: 105' 825, 35, 686, 000 DPHI,bDH 256 (]5S,LDH 000 LL,bDH 750 LSHV.LDH 377 LIJRH.LDH 322 TE~S,bDH 500 ~PHI.CNH 256 RCNT.CNH 296 SGR CHH 751 MTEM:CNH 000 DPHI,I,DH 172 QLS,LDP 375 Lb. LDH 500 bSHV. LDH 453 LIIRH LDH 262 TENS.~DH 000 NPHI. NH 206 RCNT,CNH 826 SGR,CNH 749 HTEM,CNH 15:28 5 17~ RHOB,LDH ~0i03 O$$,bDH 148 000 LITH.LDH llb7 000 2,]81 CALI,bDH 5732,000 MT£M,~DH 17,~ I TNPH,CNH 2949, ~7 ~CFT,C~H 93 856 CGR,CNH 148:125 HTEN,CNH 15,800 0,003 156,750 11.57,000 2 381 5252 000 30 354 2758 855 77 148 ~21 O0 12,216 0 133 750 1159 000 2 469 58O4 000 43 538 1947 329 103,~40 149, O0 RHOB.LDH LITH:LDH 8SHV,bDH CALI,bDH MTEM,LDH TNPH,CNH RCFT CNH CGR:CNH HTEN,CNH RHOB,LDH Q$$,LDM DITH,bDH SSHV,LDH CALI.LDH MTEM'LDH TNPH,CNH RCFT,CNH CGR,CNH HTEN,CNB 000 DPHI,LDH 10,766 RHOO,LDH 725 QLS LDH -0,014 OSS,LDH 750 LL:LDH 133'500 LITH,LDH 750 LSHV,LDH 1159,000 SSHV,LDH 457 LURH,LDH 2.455 CALI,LDH 063 TEN~:LDH 539~,000 ~TEM.LDH 000 NPH CNH 3 .675 TNPH,CNH 457 RCNT,CNH 2357 978 RCFT,CNH 442 SGR,CNH 117:495 CGR,CNH 753 ~TEM.CNH I48,750 HTEN,CNH DEPT, 000 I)PHI.LDH il,04'7 RHOB,DDH PEF,LDH 504 oLS.LOH 0,oi6 O$S,LDH LU LDH 750 LD,LDH 1~1,375 LITH,bDH 'SS2~LDH 750 DSHV,LDH 1159,000 SSHV,LDH LSRH,LDH 467 I, URtt,LDH 2,463 CALI,bDH CGR,LDH 776 TENS,bDH 5284.0()0 ~TEM,LDH HTEN.LDH 500 NPHI,CNH 32,735 TNPH.CNH N:POR,CNH 692 RCNT,CNH 2210,738 RCF'r,CNH CFTC.CNH 714- SGR.CNH 123,5~9 CGR,CNH O, 73, i213, 10, 148, 18, 1341, 82, 744, , O, 93. 1213 9 148 30 994 66 844 0 56 1214 9 149 41 545 8O 1041 2 0 71 1214 10 148 34 733 111 880 2, 74, 1214 10 148 35 699 105 400 026 813 000 656 125 886 251 340 500 389 018 625 000 180 500 007 544 322 500 448 037 156 000 9 000 472 030 625 000 359 750 215 949 063 000 468 OO4 625 000 516 875 422 582 776 DRHO LDH S$1,LDH &IRH,LDH $GR,bDH MRE$,LDH TNRA,CNH CNTC,CNH TENS,CNH DRHO,LDH L$,LDH SS1,LDH SIRH.LDH SGR,bDH TNRA NH CNTC,CNH TENS,CNH DRHO,bDH I,S,hDH SSi LDH $1RH:bDH SGR,LDH MRES.LDH TNRA,CNH CNTC,CNH TENS.C~H DRH0,LOH L$,LDH SSI,LDH 81RH,LDH SGR.LOH MRES,hDH TNRA.CNH CNTC.CNH TENS,CNH DRHO,LDH LS,LDH SSI,LOH SI~H,LDH SGN LDH gRE$!bDH TNRA CNH CNTC,CNH TENS.CNH PAGE: 0 011 287 000 207 125 2 344 93 856 0 751 2 077 2821 058 5732 000 0,011 295,750 207,750 2,334 77,821 0,751 2,819 2673,735 5252.000 -0 006 255 000 193 875 2 479 103 140 0 749 5804 000 0 015 257 250 205 250 2 396 117 495 0 753 3 186 2239 836' 5392 000 0 000 253 750 196 125 2 469 123 589 0 59 3 ~87 2148 315 5284 000 34 IS T&pe Yerification Llst J. nq chlumberger AlasKa Computir~q Center MRES,CNH 0.759 !qT~H,CNH END OF DATA 2b-~AR-19gO 15:28 148,875 HTF, N,CNM 825,500 PAGE: 35 ~ FILE TRAILER FILE NAME : EDIT ,002 SERVICE i....: FLIC VERSION : O0]A04 DATE : 90/03/26 ~ MAX REC SIZE : ~024 :: FILE TYPE : LO **** TAPE TRAILER SERVICE NAME : EDIT DATE : 90/03/~6 ORIGIN ~ FLIC ,TAPE NAME : 73695 CONTINUATION # = ! PREVIOUS TAPE : COMMENT CONOCO INC,, MI[~NE POINT UNIT L-3, AP1 #50-,029-21999 ***~ REEL TRAILER 'SERVICE NAME : EDIT DATE : 90/03/26 ~ ORIGIN : FbIC REEL NAME : 73695 CONTINUATION # : PREVIOUS REEL : COM~ENT : C[I~JOCO I~C,, ~ILNE POINT UNiT L-3, AP1 ~50-029-21999
