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Home My WebLink About196-135MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, September 23, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC F-21 MILNE PT UNIT F-21 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/23/2025 F-21 50-029-22694-00-00 196-135-0 N SPT 2545 1961350 1500 0 0 0 0 4YRTST P Guy Cook 8/14/2025 Water source well workover on Hilcorp's ASR 1. Required 4 year casing test. Mono-bore well with no OA. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT F-21 Inspection Date: Tubing OA Packer Depth 0 1791 1741 1737IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250814102912 BBL Pumped:1.4 BBL Returned:1.4 Tuesday, September 23, 2025 Page 1 of 1           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: 08/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250807 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 6/26/2025 AK E-LINE PPROF T40741 BCU 25 50133206440000 214132 7/16/2025 AK E-LINE Plug/Cement T40742 BRU 211-35 50283201890000 223050 6/11/2025 AK E-LINE Perf T40743 BRU 211-35 50283201890000 223050 6/20/2025 AK E-LINE PPROF T40743 BRU 213-26 50283201920000 223069 7/7/2025 AK E-LINE Perf T40744 BRU 213-26T 50283202040000 225038 7/2/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 7/4/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 6/28/2025 AK E-LINE Perf T40745 BRU 241-23 50283201910000 223061 7/18/2025 AK E-LINE Perf T40746 GP 11-13RD 50733200260100 191133 6/2/2025 AK E-LINE PPFROF T40747 KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF T40748 MPU E-28 50029232590000 202055 5/8/2025 AK E-LINE Caliper T40749 MPU F-21 50029226940000 196135 7/10/2025 AK E-LINE Caliper T40750 MPU G-02 50029219260000 189028 7/6/2025 AK E-LINE Puncher T40751 MPU I-01 50029220650000 190090 7/7/2025 AK E-LINE TubingPunch T40752 NS-19 50029231220000 202207 6/27/2025 AK E-LINE Perf T40753 PBU J-07C 50029202410300 225026 5/29/2025 BAKER MRPM T40754 PBU N-07B 50029201370200 223122 6/7/2025 BAKER MRPM T40755 PCU-05 50283202030000 225037 7/10/2024 AK E-LINE Perf T40756 TBU D-07RD2 50733201170200 192155 7/19/2025 AK E-LINE Perf T40757 TBU M-09 50733204760000 196127 7/18/2025 AK E-LINE Perf T40758 Please include current contact information if different from above. T40750MPU F-21 50029226940000 196135 7/10/2025 AK E-LINE Caliper Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.08 11:16:55 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Change-out 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 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): 4,995'N/A Casing Collapse Conductor N/A Surface 3,090psi 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 WTRSP 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 ryan.lewis@hilcorp.com 303-906-5178 See Schematic See Schematic 5-1/2" (2) 9-5/8" Versatrieve & 9-5/8" HES Sump Packer and N/A 3,912 MD/ 2,545 TVD, 4,144 MD/ 2,642 TVD & 4,604 MD/ 2,872 TVD and N/A Ryan Lewis N/A 5,750psi2,976'4,970' 113' 20" 9-5/8"4,941' Length Size Proposed Pools: 113' 113' 17# / L-80 / IBT TVD Burst 3,866' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 196-135 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22694-00-00 Hilcorp Alaska LLC N/A AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 7/14/2025 Perforation Depth MD (ft): 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 F-21 MILNE POINT TERTIARY UNDEF WTRSP N/A 2,986' 4,868' 2,933' 825 N/A 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 3:54 pm, Jul 01, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.07.01 13:50:02 - 08'00' Taylor Wellman (2143) 325-396 SFD 7/12/2025 * BOPE pressure test to 1500 psi. 24 hour notice. MGR14JULY25 DSR-7/1/25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.07.15 08:56:58 -08'00'07/15/25 RBDMS JSB 071525 ESP Change Out Well: MPU F-21 Date: 06/26/2025 Well Name:MPU F-21 API Number:50-029-22694-00-00 Current Status:Water Source Well [Failed ESP] Pad:F-Pad Estimated Start Date:7/11/25 Rig:ASR Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:205-870 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: 1,070 psi @ 2,449’ TVD (FL at surface / 8.4 ppg EMW) Maximum Expected BHP:1,070 psi @ 2,449’ TVD (Consistent w/ other WSW wells / 8.4 ppg EMW) Max Potential Surface Pressure: 825 psi Gas Column Gradient (0.1 psi/ft) Brief Well Summary: MPU F-21 was drilled and completed with a gravel pack in January 1997 as a Tertiary water source well. The well has had multiple ESPs installed: May 1997 (initial), February 1998 (penetrator only), September 2009, June 2018 and March 2022. The ESP failed electrically on 6/20/25. Notes Regarding Wellbore Condition x Last CSG Test (3,850’ – surface) 2,000 psi – 06/25/2018 Objective: Pull failed ESP run a new ESP. Slickline: 1. RU slickline, pressure test PCE to 250psi low / 2,500psi high. 2. Drift and tag with sample bailer. 3. Caliper from 3,767’ to surface. 4. RDMO. Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 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 brine. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. ESP Change Out Well: MPU F-21 Date: 06/26/2025 Brief RWO Procedure (Begin Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 3. Test BOPE to 250 psi low/ 1,500 psi high. Test annular to 250 psi low/ 1,500 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 ram on 5-1/2” 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 ESP pull. 6. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an FMC 11” x 4-1/2”, with 4-1/2” NSCT thread top and btm, w/ 4”CIW-H. b. 2022 tubing PU weight on Doyon-14 recorded as 102k kip including 40K block weight. Slack off weight recorded as 75 kip including 40k block weight. c. 5-1/2”” L-80 IBT yield is 397kip. 7. Confirm hanger free, lay down tubing hanger. 8. POOH and lay down the 5-1/2” tubing. a. Plan to re-use all the tubing unless otherwise indicated by the caliper. b. Keep ported discharge head and centralizer for future use. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Recorded Clamp Totals: i. Canon Clamps: 93 ii. Protectolizers: 2 iii. Crestolizers: 2 9. Lay Down ESP. 10. RIH with used 5-1/2” 17# L-80 ESP completion to +/- 3,767’ 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 re-use cross coupling clamps every joint Nom. Size Length Item Lb/ft Material Notes 7.5 2 Centralizer 4 2 Intake Sensor 30 ESP Change Out Well: MPU F-21 Date: 06/26/2025 7.25 34 Motor - 500HP 80 7.25 34 Motor - 500HP 80 6.75 7 Lower Tandem Seal 38 6.75 7 Upper Tandem Seal 38 Intake 7.25 57 Pumps – HC12500 32 stg 45 7.25 57 Pumps – HC12500 32 stg 45 7.25 57 Pumps – HC12500 16 stg 45 1 Ported Discharge Head 13 L-80 5-1/2” 10 X-Over 5.5" 8RD LTC x 5.5" IBT 17 L-80 5-1/2” 3,733 Tubing jts IBT 17 L-80 5-1/2” 2 5.5" IBT L-80 Tubing 17# PUP 17 L-80 4-1/2” 2 X-Over 5-1/2” x 4-1/2" NSCT 6.5 L-80 4-1/2” 1 Tubing Hanger 6.5 L-80 11. Land tubing hanger. Use extra caution to not damage cable. 12. Lay down landing joint. 13. Set BPV. 14. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 4/18/2022 SCHEMATIC Milne Point Unit Well: MPU F-21 WSW Last Completed: 3/25/2022 PTD: 196-135 TD =4,995’(MD) / TD =2,986’(TVD) Orig. DFElev.:40.9’/Orig. GL Elev.:11.8’ RKB Elev = 19.95’ (Nabors 4ES) 9-5/8” 1 9 2 &3 7 & 8 13 10 11 12 15 20” 4 4-1/2” x 5-1/2” Crossover @ 23.01’ Min ID= 3.958” PBTD = 4,868’ (MD) / PBTD =2,933’(TVD) 5&6 14 1617 18 19 20 D Sands C Sands CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 113' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 1,932’ 47 / L-80 / BTC-MOD 8.681 1,932’ 4,970’ TUBING DETAIL 5-1/2” Tubing 17 / L-80 / IBT 4.892 Surface 3,866’ JEWELRY DETAIL No Depth Item 1 3,767’ Discharge head: B/O PMP 675 5.5X8 RND LONG CSG 2 3,768’ Pump #1: HPHVMARC 035 HC20000ARC 316SS HD/BAS 3 3,785’ Pump #2: HPHVMARC 035 HC20000ARC 316SS HD/BAS 4 3,803’ Bolt on Intake: HPINTARC HS 23T 5 3,804’ Upper Tandem Seal: HSB3 UT FER EHL INV CUW AB PFSA DS 6 3,811’ Lower Tandem Seal: HSB3 LT FER EHL SSCV INV INC CUW 7 3,818’ Motor: HMI, U CS 500/1965/153 10R 8 3,840’ Motor: HMI, L CS 500/1,965/153 10R 9 3,864’ Centralizer w/ XO -Bottom @ 3,866’ 10 3,912’ 9-5/8” HES Versatrieve Packer 11 3,932’ Safety Shear Sub,Min ID = 3.88” 12 3,935’ 5-1/2”, 20 ppf, N-80, LTC Blank Pipe; ID=4.778” 13 3,960’ 5-1/2” 0.12 Ga. Pre-Pack Screen, ID=4.778” 14 4,082’ 5-1/2” 0.12 Ga. Screen, ID=4.778” 15 4,144’ 9-5/8” HES Versatrieve Packer 16 4,164’ Safety Shear Sub,Min ID = 3.88” 17 4,167’ 5-1/2”, 20 ppf, N-80, LTC Blank Pipe; ID=4.778” 18 4,329’ 5-1/2” 0.12 Ga. Pre-Pack Screen, ID=4.778” 19 4,571’ 5-1/2” 0.12 Ga. Screen, ID=4.778” 20 4,604’ 9-5/8” HES Sump Packer set on e-Line 1/05/1997 PERFORATION DETAIL – Ref Log: Open hole MWD 8/10/96 Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Upper Prince Creek ‘C’ Sand 3,979’ 4,139’ 2,572’ 2,639’ 160 1/09/1997 Open Lower Prince Creek ‘D’ Sand 4,339’ 4,599’ 2,721’ 2,826’ 260 1/06/1997 Open 24gm SWS 4.5” 12 spf 43C big hole charges @ 135/45 deg. phasing (w/ 0.7” EHD and 7.9” TTP) WELL INCLINATION DETAIL KOP @ 300’ Max Hole Angle = 68.1 ° f/ 3,731’ Hole angle thru perfs= 67° TREE & WELLHEAD Tree CIW 4-1/16” 5M ‘FLS’ Wellhead 11”x 12” 5M FMC Gen 6 Unibore w/ two 2” 5M valves on side ports 11” x 4-1/8” 5M adapter and 11” x 4.5” tbg hng 4.5” NSCT threads top and bottom and 4” CIW-H GENERAL WELL INFO API: 50-029-22694-00-00 Drilled and Cased by Nabors 22E – 8/13/1996 Install Gravel Pack by Nabors 4ES – 1/11/1997 Initial ESP by Nabors 4ES – 5/18/1997 Replace Penetrator by Nabors 5S – 2/05/1998 Change out ESP by Nabors 4ES – 9/20/2009 ESP Swap 6/24/2018 ESP Swap by Doyon 14 – 3/22022 OPEN HOLE / CEMENT DETAIL 20” Cmt w/250 sx Arcticset 1 (Approx.) in a 24” Hole 9-5/8” 980 sx PF ‘E’, 1,000 sx Class ‘G’ in a 12-1/4” Hole GRAVEL PACK DETAIL C Sand: 9,500lbs of 20-40 Carbolite 1/09/1997 D Sand: 8,000lbs of 20-40 Carbolite 1/08/1997 Min. Gravel Pack Restriction ID = 2.97” _____________________________________________________________________________________ Revised By: TDF 6/27/2021 PROPOSED Milne Point Unit Well: MPU F-21 WSW Last Completed: 3/25/2022 PTD: 196-135 TD = 4,995’(MD) / TD =2,986’(TVD) Orig. DF Elev.: 40.9’/ Orig. GL Elev.: 11.8’ RKB Elev = 19.95’ (Nabors 4ES) 9-5/8” 1 9 2 & 3 7 & 8 13 10 11 12 15 20” 4 4-1/2” x 5-1/2” Crossover @ 23.01’ Min ID= 3.958” PBTD = 4,868’ (MD) / PBTD =2,933’(TVD) 5 & 6 14 16 17 18 19 20 D Sands C Sands CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 113' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 1,932’ 47 / L-80 / BTC-MOD 8.681 1,932’ 4,970’ TUBING DETAIL 5-1/2” Tubing 17 / L-80 / IBT 4.892 Surface ±X,XXX’ JEWELRY DETAIL No Depth Item 1 ±X,XXX’ Discharge head: 2 ±X,XXX’ Pump #1: 3 ±X,XXX’ Pump #2: 4 ±X,XXX’ Bolt on Intake: 5 ±X,XXX’ Upper Tandem Seal: 6 ±X,XXX’ Lower Tandem Seal: 7 ±X,XXX’ Motor: 8 ±X,XXX’ Motor: 9 ±X,XXX’ Centralizer w/ XO - Bottom @ ±X,XXX’ 10 3,912’ 9-5/8” HES Versatrieve Packer 11 3,932’ Safety Shear Sub,Min ID = 3.88” 12 3,935’ 5-1/2”, 20 ppf, N-80, LTC Blank Pipe; ID=4.778” 13 3,960’ 5-1/2” 0.12 Ga. Pre-Pack Screen, ID=4.778” 14 4,082’ 5-1/2” 0.12 Ga. Screen, ID=4.778” 15 4,144’ 9-5/8” HES Versatrieve Packer 16 4,164’ Safety Shear Sub,Min ID = 3.88” 17 4,167’ 5-1/2”, 20 ppf, N-80, LTC Blank Pipe; ID=4.778” 18 4,329’ 5-1/2” 0.12 Ga. Pre-Pack Screen, ID=4.778” 19 4,571’ 5-1/2” 0.12 Ga. Screen, ID=4.778” 20 4,604’ 9-5/8” HES Sump Packer set on e-Line 1/05/1997 PERFORATION DETAIL – Ref Log: Open hole MWD 8/10/96 Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Upper Prince Creek ‘C’ Sand 3,979’ 4,139’ 2,572’ 2,639’ 160 1/09/1997 Open Lower Prince Creek ‘D’ Sand 4,339’ 4,599’ 2,721’ 2,826’ 260 1/06/1997 Open 24gm SWS 4.5” 12 spf 43C big hole charges @ 135/45 deg. phasing (w/ 0.7” EHD and 7.9” TTP) WELL INCLINATION DETAIL KOP @ 300’ Max Hole Angle = 68.1 ° f/ 3,731’ Hole angle thru perfs= 67° TREE & WELLHEAD Tree CIW 4-1/16” 5M ‘FLS’ Wellhead 11”x 12” 5M FMC Gen 6 Unibore w/ two 2” 5M valves on side ports 11” x 4-1/8” 5M adapter and 11” x 4.5” tbg hng 4.5” NSCT threads top and bottom and 4” CIW-H GENERAL WELL INFO API: 50-029-22694-00-00 Drilled and Cased by Nabors 22E –8/13/1996 Install Gravel Pack by Nabors 4ES –1/11/1997 Initial ESP by Nabors 4ES –5/18/1997 Replace Penetrator by Nabors 5S –2/05/1998 Change out ESP by Nabors 4ES –9/20/2009 ESP Swap 6/24/2018 ESP Swap by Doyon 14 –3/22022 OPEN HOLE / CEMENT DETAIL 20” Cmt w/250 sx Arcticset 1 (Approx.) in a 24” Hole 9-5/8” 980 sx PF ‘E’, 1,000 sx Class ‘G’ in a 12-1/4” Hole GRAVEL PACK DETAIL C Sand: 9,500lbs of 20-40 Carbolite 1/09/1997 D Sand: 8,000lbs of 20-40 Carbolite 1/08/1997 Min. 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ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬ,ͲϰϬͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϯΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬd ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ ϭ͕ϵϯϮ͛ ϰϳͬ>ͲϴϬͬdͲDK ϴ͘ϲϴϭ ϭ͕ϵϯϮ͛ ϰ͕ϵϳϬ͛ dh/E'd/> ϱͲϭͬϮ͟ dƵďŝŶŐ ϭϳͬ>ͲϴϬͬ/d ϰ͘ϴϵϮ ^ƵƌĨĂĐĞ ϯ͕ϴϱϯ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ ϯ͕ϳϲϵ͛ WƵŵƉ͗ϭϮ,ϭϮϱϬϬ,W,shZ Ϯ ϯ͕ϳϳϲ͛ WƵŵƉ͗Ϯϵ,ϭϮϱϬϬ,W,s>Z ϯ ϯ͕ϳϵϭ͛ WƵŵƉǁͬ/ŶƚĞŐƌĂů/ŶƚĂŬĞ͗Ϯϵ,ϭϮϱϬϬ,W,s>Z ϰ ϯ͕ϴϬϲ͛ hƉƉĞƌdĂŶĚĞŵ^ĞĂů͗,^ϯhdD&Z ϱ ϯ͕ϴϭϰ͛ >ŽǁĞƌdĂŶĚĞŵ^ĞĂů͗,^ϯ>dD&Z ϲ ϯ͕ϴϮϭ͛ DŽƚŽƌ͗>ϱ͕,D/ϴϬϬ,W ϳ ϯ͕ϴϱϲ͛ ĞŶƚƌĂůŝǌĞƌʹ ŽƚƚŽŵΛϯ͕ϴϱϴ͛ ϴ ϯ͕ϵϭϮ͛ ϵͲϱͬϴ͟,^sĞƌƐĂƚƌŝĞǀĞWĂĐŬĞƌ ϵ ϯ͕ϵϯϮ͛ ^ĂĨĞƚǇ^ŚĞĂƌ^Ƶď͕DŝŶ/сϯ͘ϴϴ͟ ϭϬ ϯ͕ϵϯϱ͛ ϱͲϭͬϮ͕͟ϮϬƉƉĨ͕EͲϴϬ͕>důĂŶŬWŝƉĞ͖/сϰ͘ϳϳϴ͟ ϭϭ ϯ͕ϵϲϬ͛ ϱͲϭͬϮ͟Ϭ͘ϭϮ'Ă͘WƌĞͲWĂĐŬ^ĐƌĞĞŶ͕/сϰ͘ϳϳϴ͟ ϭϮ ϰ͕ϬϴϮ͛ ϱͲϭͬϮ͟Ϭ͘ϭϮ'Ă͘^ĐƌĞĞŶ͕/сϰ͘ϳϳϴ͟ ϭϯ ϰ͕ϭϰϰ͛ ϵͲϱͬϴ͟,^sĞƌƐĂƚƌŝĞǀĞWĂĐŬĞƌ ϭϰ ϰ͕ϭϲϰ͛ ^ĂĨĞƚǇ^ŚĞĂƌ^Ƶď͕DŝŶ/сϯ͘ϴϴ͟ ϭϱ ϰ͕ϭϲϳ͛ ϱͲϭͬϮ͕͟ϮϬƉƉĨ͕EͲϴϬ͕>důĂŶŬWŝƉĞ͖/сϰ͘ϳϳϴ͟ ϭϲ ϰ͕ϯϮϵ͛ ϱͲϭͬϮ͟Ϭ͘ϭϮ'Ă͘WƌĞͲWĂĐŬ^ĐƌĞĞŶ͕/сϰ͘ϳϳϴ͟ ϭϳ ϰ͕ϱϳϭ͛ ϱͲϭͬϮ͟Ϭ͘ϭϮ'Ă͘^ĐƌĞĞŶ͕/сϰ͘ϳϳϴ͟ ϭϴ ϰ͕ϲϬϰ͛ ϵͲϱͬϴ͟,^^ƵŵƉWĂĐŬĞƌƐĞƚŽŶĞͲ>ŝŶĞϭͬϬϱͬϭϵϵϳ WZ&KZd/KEd/>ʹZĞĨ>ŽŐ͗KƉĞŶŚŽůĞDtϴͬϭϬͬϵϲ ^ĂŶĚ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ hƉƉĞƌWƌŝŶĐĞ ƌĞĞŬ͚͛^ĂŶĚ ϯ͕ϵϳϵ͛ 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tĞůů͗DWh&ͲϮϭt^t >ĂƐƚŽŵƉůĞƚĞĚ͗ϲͬϮϰͬϮϬϭϴ Wd͗ϭϵϲͲϭϯϱ dсϰ͕ϵϵϱ͛;DͿͬdсϮ͕ϵϴϲ͛;dsͿ KƌŝŐ͘&ůĞǀ͗͘ϰϬ͘ϵ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϭϭ͘ϴ͛ Z<ůĞǀсϭϵ͘ϵϱ͛;EĂďŽƌƐϰ^Ϳ ϵͲϱͬϴ͟ ϮϬ͟ ϰͲϭͬϮ͟ǆϱͲϭͬϮ͟ ƌŽƐƐŽǀĞƌΛϮϯ͘Ϭϭ͛ DŝŶ/сϯ͘ϵϱϴ͟ Wdс ϰ͕ϴϲϴ͛;DͿͬWdсϮ͕ϵϯϯ͛;dsͿ '6DQGV &6DQGV ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬ,ͲϰϬͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϯΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬd ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ ϭ͕ϵϯϮ͛ ϰϳͬ>ͲϴϬͬdͲDK ϴ͘ϲϴϭ ϭ͕ϵϯϮ͛ ϰ͕ϵϳϬ͛ dh/E'd/> ϱͲϭͬϮ͟ dƵďŝŶŐ ϭϳͬ>ͲϴϬͬ/d ϰ͘ϴϵϮ ^ƵƌĨĂĐĞ ϯ͕ϴϱϯ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ цϯ͕ϳϲϵ͛ WƵŵƉηϭ͗ Ϯ цϯ͕ϳϳϲ͛ WƵŵƉηϮ͗ ϯ цϯ͕ϳϵϭ͛ WƵŵƉǁͬ/ŶƚĞŐƌĂů/ŶƚĂŬĞ͗ ϰ цϯ͕ϴϬϲ͛ hƉƉĞƌdĂŶĚĞŵ^ĞĂů͗ ϱ цϯ͕ϴϭϰ͛ >ŽǁĞƌdĂŶĚĞŵ^ĞĂů͗ ϲ цϯ͕ϴϮϭ͛ DŽƚŽƌ͗ ϳ цϯ͕ϴϱϲ͛ ĞŶƚƌĂůŝǌĞƌʹŽƚƚŽŵΛϯ͕ϴϱϴ͛ ϴ ϯ͕ϵϭϮ͛ ϵͲϱͬϴ͟,^sĞƌƐĂƚƌŝĞǀĞWĂĐŬĞƌ ϵ ϯ͕ϵϯϮ͛ ^ĂĨĞƚǇ^ŚĞĂƌ^Ƶď͕DŝŶ/сϯ͘ϴϴ͟ ϭϬ ϯ͕ϵϯϱ͛ ϱͲϭͬϮ͕͟ϮϬƉƉĨ͕EͲϴϬ͕>důĂŶŬWŝƉĞ͖/сϰ͘ϳϳϴ͟ ϭϭ ϯ͕ϵϲϬ͛ ϱͲϭͬϮ͟Ϭ͘ϭϮ'Ă͘WƌĞͲWĂĐŬ^ĐƌĞĞŶ͕/сϰ͘ϳϳϴ͟ ϭϮ ϰ͕ϬϴϮ͛ ϱͲϭͬϮ͟Ϭ͘ϭϮ'Ă͘^ĐƌĞĞŶ͕/сϰ͘ϳϳϴ͟ ϭϯ ϰ͕ϭϰϰ͛ ϵͲϱͬϴ͟,^sĞƌƐĂƚƌŝĞǀĞWĂĐŬĞƌ ϭϰ ϰ͕ϭϲϰ͛ ^ĂĨĞƚǇ^ŚĞĂƌ^Ƶď͕DŝŶ/сϯ͘ϴϴ͟ ϭϱ ϰ͕ϭϲϳ͛ ϱͲϭͬϮ͕͟ϮϬƉƉĨ͕EͲϴϬ͕>důĂŶŬWŝƉĞ͖/сϰ͘ϳϳϴ͟ ϭϲ ϰ͕ϯϮϵ͛ ϱͲϭͬϮ͟Ϭ͘ϭϮ'Ă͘WƌĞͲWĂĐŬ^ĐƌĞĞŶ͕/сϰ͘ϳϳϴ͟ ϭϳ ϰ͕ϱϳϭ͛ ϱͲϭͬϮ͟Ϭ͘ϭϮ'Ă͘^ĐƌĞĞŶ͕/сϰ͘ϳϳϴ͟ ϭϴ ϰ͕ϲϬϰ͛ ϵͲϱͬϴ͟,^^ƵŵƉWĂĐŬĞƌƐĞƚŽŶĞͲ>ŝŶĞϭͬϬϱͬϭϵϵϳ WZ&KZd/KEd/>ʹZĞĨ>ŽŐ͗KƉĞŶŚŽůĞDtϴͬϭϬͬϵϲ ^ĂŶĚ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ hƉƉĞƌWƌŝŶĐĞ ƌĞĞŬ͚͛^ĂŶĚ ϯ͕ϵϳϵ͛ ϰ͕ϭϯϵ͛ Ϯ͕ϱϳϮ͛ Ϯ͕ϲϯϵ͛ ϭϲϬ ϭͬϬϵͬϭϵϵϳ KƉĞŶ >ŽǁĞƌWƌŝŶĐĞ ƌĞĞŬ͚͛^ĂŶĚ ϰ͕ϯϯϵ͛ ϰ͕ϱϵϵ͛ Ϯ͕ϳϮϭ͛ Ϯ͕ϴϮϲ͛ ϮϲϬ ϭͬϬϲͬϭϵϵϳ KƉĞŶ ϮϰŐŵ^t^ϰ͘ϱ͟ϭϮƐƉĨϰϯďŝŐŚŽůĞĐŚĂƌŐĞƐΛϭϯϱͬϰϱĚĞŐ͘ƉŚĂƐŝŶŐ;ǁͬϬ͘ϳ͟,ĂŶĚϳ͘ϵ͟ddWͿ t>>/E>/Ed/KEd/> <KWΛϯϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϲϴ͘ϭΣĨͬϯ͕ϳϯϭ͛ ,ŽůĞĂŶŐůĞƚŚƌƵƉĞƌĨƐсϲϳΣ dZΘt>>, dƌĞĞ /tϰͲϭͬϭϲ͟ϱD͚&>^͛ tĞůůŚĞĂĚ ϭϭ͟ǆϭϮ͟ϱD&D'ĞŶϲhŶŝďŽƌĞǁͬƚǁŽϮ͟ϱDǀĂůǀĞƐŽŶ ƐŝĚĞƉŽƌƚƐϭϭ͟ǆϰͲϭͬϴ͟ϱDĂĚĂƉƚĞƌĂŶĚϭϭ͟ǆϰ͘ϱ͟ƚďŐŚŶŐ ϰ͘ϱ͟E^dƚŚƌĞĂĚƐƚŽƉĂŶĚďŽƚƚŽŵĂŶĚϰ͟/tͲ, 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϲϵϰͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϮϮʹϴͬϭϯͬϭϵϵϲ /ŶƐƚĂůů'ƌĂǀĞůWĂĐŬďǇEĂďŽƌƐϰ^ʹϭͬϭϭͬϭϵϵϳ /ŶŝƚŝĂů^WďǇEĂďŽƌƐϰ^ʹϱͬϭϴͬϭϵϵϳ ZĞƉůĂĐĞWĞŶĞƚƌĂƚŽƌďǇEĂďŽƌƐϱ^ʹϮͬϬϱͬϭϵϵϴ ŚĂŶŐĞŽƵƚ^WďǇEĂďŽƌƐϰ^ʹϵͬϮϬͬϮϬϬϵ ^W^ǁĂƉϲͬϮϰͬϮϬϭϴ KWE,K>ͬDEdd/> ϮϬ͟ ŵƚǁͬϮϱϬƐǆƌĐƚŝĐƐĞƚϭ;ƉƉƌŽǆ͘ͿŝŶĂϮϰ͟,ŽůĞ ϵͲϱͬϴ͟ ϵϴϬƐǆW&͚͕͛ϭ͕ϬϬϬƐǆůĂƐƐ͚'͛ŝŶĂϭϮͲϭͬϰ͟,ŽůĞ 'Zs>W<d/> ^ĂŶĚ͗ϵ͕ϱϬϬůďƐŽĨϮϬͲϰϬĂƌďŽůŝƚĞϭͬϬϵͬϭϵϵϳ ^ĂŶĚ͗ϴ͕ϬϬϬůďƐŽĨϮϬͲϰϬĂƌďŽůŝƚĞϭͬϬϴͬϭϵϵϳ DŝŶ͘'ƌĂǀĞůWĂĐŬZĞƐƚƌŝĐƚŝŽŶ /сϮ͘ϵϳ͟ ,,OF Tk • �P �\I%,-�s THE STA Alaska Oil and Gas ®f LASKA Conservation Co missiOn Witt = == 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 LASS Fax: 907.276.7542 www.aogcc.alaska.pov Bo York SC JUN 2 0 LU Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Tertiary Undefined WTRSP, MPU F-21 Permit to Drill Number: 196-135 Sundry Number: 318-239 Dear Mr. York: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, e:467 C.c.s Cathy P. oerster Commissioner DATED this day of June, 2018. RBDMS JUN 1 a 201e • 0 CIECEIVD JUN O2 i8 STATE OF ALASKA S �� j s/ ALASKA OIL AND GAS CONSERVATION COMMISSION /� g APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 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 El Other: ESP Change-out 0 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 196-135 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ . 6.API Number: Anchorage Alaska 99503 50-029-22694-00-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑J MILNE PT UNIT F-21 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL-025509 ' MILNE POINT/TERTIARY UNDEF WTRSP • 1 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): I 4,995' • 2,986' • 4,868' 2,933' 148 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 113' 20" 113' 113' N/A N/A' Surface 4,941' 9-5/8" 4,970' 2,976' 5,750psi 3,090psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 5-1/2" 17#/L-80/IBT 3,853' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): (2)9-5/8"Versatrieve&9-5/8"HES Sump Packer and N/A 3,912 MD/2,545 TVD,4,144 MD/2,642 TVD&4,604 MD/2,872 ND and NI/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 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: 6/19/2018 Commencing Operations: OIL ❑ WTRSP ❑., • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Stan Porhola SW r_____ AuthorizedTitle: Operations Manager Contact Email: spOrhOla tl hiICOrp.COm Contact Phone: 777-8412 Authorized Signature: - Date: 6/4/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,b 111 - i l Plug Integrity ❑ BOP Test 2- CI d✓�-,[' ©Mechanical Integrity Test ❑ Location Clearance Other: /Ck ,SQP re-yr 7c Z$ Ca L, Post Initial Injection MIT Req'd? Yes ❑ No 2 Spacing Exception Required? Yes El No Subsequent Form Required: 0.1 APPROVED BY Approved by: ,67 COMMISSIONER THE COMMISSION Date: 6 _, _ / O RBDMS JUN 181018 ORIGINAL Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments io Duplicate • • Well Prognosis Well: MPU F-21 Ililcoro Alaska,LLi Date:6/04/2018 Well Name: MPU F-21 API Number: 50-029-22694-00 Current Status: SI Water Source [ESP] Pad: F-Pad Estimated Start Date: June 19th, 2018 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-135 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Job Type: ESP Repair Current Bottom Hole Pressure: 1,318 psi @ 2,700'TVDss (SBHPS 6/01/2018/9.39 ppg EMW) Maximum Expected BHP: 1,318 psi @ 2,700'TVDss (No new perfs being added) MPSP: 148 psi (SITP. Prince Creek water supply well with 0.433 psi/ft gradient) Brief Well Summary: MPU F-21 was drilled and completed with a gravel pack in January 1997 as a Tertiary water source well. The well has had multiple ESPs installed: May 1997 (initial), February 1998 (penetrator only), and September 2009. The ESP recently failed in May 2018. Notes Regarding Wellbore Condition • The 9-5/8" production casing was tested to 4,000 psi at 4,868' MD on January 5, 1997. Objective: The purpose of this work is to pull the failed ESP, pressure test the casing and run a new ESP. Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 9.5 ppg NaCI brine down tubing, taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house.Spot mud boat. . Well Prognosis Well: MPU F-21 Hileoru Alaska,lit Date:6/04/2018 Vf6. Brief RWO Procedure: de roe- 10. MIRU Hilcorp ASR#1 WO Rig, ancilla equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pul BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/9.5 ppg NaCl brine prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/1,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test.V c. Confirm test pressures per the Sundry Conditions of approval. d. Test pipe ram on 5-1/2"test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/9.5 ppg NaCl brine as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2009 ESP swap was 56K lbs. (not including block weight) b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 16. Recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. a. Contingency(If ESP failure is found to only be a failure of the penetrator on the ESP cable below the tubing hanger) b. Repair failed penetrator splice. c. Move to Step#27 (Land Hanger). 17. POOH and lay down the 5-1/2" tubing. Number all joints. Tubing will be re-used as noted. Lay down ESP. a. Replace bad joints of tubing as necessary and note on tally new tubing run. • Well Prognosis Well: MPU F-21 tlilcorn AJa..ka,LU Date:6/04/2018 b. Note any sand or scale inside or on the outside of the ESP on the morning report. c. Look for over-torqued connections from previous tubing runs. 18. Change out 5-1/2" pipe rams and install 2-7/8" x 5" VBRs. 19. Test 2-7/8" x 5"VBRs to 250 psi Low/2,500 psi High, (hold test for 5-min). Record accumulator pre- charge pressures and chart tests. f. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. g. Notify AOGCC 24 hours in advance of BOP test. h. Confirm test pressures per the Sundry Conditions of approval. i. Test VBR ram on 3-1/2" test joint. j. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 20. PU 9-5/8" test packer. 21. RIH to+/-3,800' MD on 3-1/2" workstring. 22. Set test packer.Test casing to 2,000 psi for 30 min and chart. Bleed down pressure. 23. POOH and LD 3-1/2" workstring and 9-5/8"test packer. 24. Change out 2-7/8" x 5"VBRs and install 5-1/2" pipe rams. 25. Test 5-1/2" pipe rames to 250 psi Low/2,500 psi High, (hold test for 5-min). Record accumulator pre-charge pressures and chart tests. k. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. I. Notify AOGCC 24 hours in advance of BOP test. m. Confirm test pressures per the Sundry Conditions of approval. n. Test pipe ram on 5-1/2" test joint. o. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 26. PU new ESP and RIH on 5-1/2" tubing. Set base of ESP assembly at±3,850' MD. a. 4-1/2" x 5-1/2" XO @ 23' MD. b. ESP Pump @ ±3,770' MD. c. Base of ESP motor @ ±3,850' MD d. Test ESP cable at least every 1,000'. Utilize cross collar and mid-joint clamps as needed. 27. Land tubing hanger. RILDS. Note PU (Pick Up) and SO (Slack Off) weights on tally./ .i4iJr 28. Freeze protect inner annulus taking returns out the tubing (+/- 120 bbl). SI inner annulus. pm 29. Freeze protect tubing (+/-60 bbl). 30. Lay down landing joint.Set BPV. Post-Rig Procedure: 31. RD mud boat. RD BOPE house. Move to next well location. 32. RU crane. ND BOPE. 33. NU existing 4-1/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 34. RD crane. Move 500 bbl returns tank and rig mats to next well location. 35. Replace gauge(s) if removed. 36. Turn well over to production. RU well house and flowlines. • • Well Prognosis Well: MPU F-21 llitcora Alaska,LL Date:6/04/2018 Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Blank RWO Sundry Change Form 14 • Milne Point Unit • • Well: MPU F-21 WSW SCHEMATIC Last Completed: 9/20/2009 fiilcorp Alaska,iaPTD: 196-135 .c Orig.DF Elev.:40.9'/Orig.GL Elev.:11.8' TREE&WELLHEAD RKB Elev=19.95'(Nabors 4ES) Tree CIW 4-1/16"5M'FLS' E 11"x 12"5M FMC Gen 6 Unibore w/two 2"5M valves on 2A Wellhead side ports 11"x 4-1/8"5M adapter and 11"x 4.5"tbg hng 4.5"NSCT threads top and bottom and 4"CIW-H 41/2'x 5-1/2" Crossover@23.01' OPEN HOLE/CEMENT DETAIL Min Io-3.833 20" Cmt w/250 sx Arcticset 1(Approx.)in a 24"Hole 9-5/8" 980 sx PF'E',1,000 sx Class'G'in a 12-1/4"Hole WELL INCLINATION DETAIL KOP @ 300' Max Hole Angle=68°f/3,636' Hole angle thru perfs=67° ': CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surface 113' 9-5/8" Surface 40/L-80/BTC 8.835 Surface 1,932' 47/L-80/BTCMOD 8.681 1,932' 4,970' TUBING DETAIL 5-1/2" Tubing 17/L-80/IBT 4.892 Surface 3,853' JEWELRY DETAIL No Depth Item 1 3,770' Discharge Head HPDIS(Integral to UT Pump) 2 3,772' Pump:30HC12500 3 3,784' Pump:5HC12500 4 3,788' Pump:w/Integral Intake 35HC12500 5 3,804' Upper Tandem Seal:HST3 4B HL INV PFSA UT 6 3,811' Lower Tandem Seal:HST3 4B HL INV PFSA LT 7 3,818' Motor:CL5 HMI 800 HP r J 1 8 3,912' 9-5/8"HES Versatrieve Packer 9 3,932' Safety Shear Sub,Min ID=3.88" 2,3&4 10 3,935' 5-1/2",20 ppf, N-80,LTC Blank Pipe;ID=4.778" 11 3,960' 5-1/2"0.12 Ga.Pre-Pack Screen,ID=4.778" 12 4,082' 5-1/2"0.12 Ga.Screen,10=4.778" ' 5&6 13 4,144' 9-5/8"HES Versatrieve Packer 14 4,164' Safety Shear Sub,Min ID=3.88" If 15 4,167' 5-1/2",20 ppf, N-80,LTC Blank Pipe;ID=4.778" 7 16 4,329' 5-1/2"0.12 Ga.Pre-Pack Screen,ID=4.778" 17 4,571' 5-1/2"0.12 Ga.Screen,10=4.778" it '` 18 4,604' 9-5/8"HES Sump Packer set on e-Line 1/05/1997 8 _ PERFORATION DETAIL-Ref Log: Open hole MWD 8/10/96 io4°` Sand Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status 11$ C Sands Upper Prince 3,979' 4,139' 2,572' 2,639' 160 1/09/1997 Open 12. Creek'C'Sand 13.4.1mo_ _ 4 Lower Prince 4,339' 4,599' 2,721' 2,826' 260 1/06/1997 Open 14{*, Creek'D'Sand 24gm SWS 4.5"12 spf 43C big hole charges @ 135/45 deg.phasing(w/0.7"EHD and 7.9"TTP) iii dI DSaids 17 18 GRAVEL PACK DETAIL GENERAL WELL INFO C Sand:9,500Ibs of 20-40 Carbolite 1/09/1997 API:50-029-22694-00-00 D Sand:8,000lbs of 20-40 Carbolite 1/08/1997 Drilled and Cased by Nabors 22E-8/13/1996 9 5/8" a'., _,,,11Min.Gravel Pack Restriction ID=2.97" Install Gravel Pack by Nabors 4ES -1/11/1997 TD=4,995'(MD)/TD=2,997'(1VD) Initial ESP by Nabors 4ES -5/18/1997 PBTD 4,868'(MD)/PBTD=2,933'(TVD) Replace Penetrator by Nabors 5S -2/05/1998 Change out ESP by Nabors 4ES -9/20/2009 Revised By:STP 6/04/2018 • • Milne Point Unit Well: MPU F-21 WSW PROPOSED Last Completed: 9/20/2009 Ilr7awrp Alaska,LLC PTD: 196 135 Orig.RKB Elev.:40.97 GL Elev.:11.8 TREE&WELLHEAD '! RKB Elev=19.95'(Nabors 4ES) Tree CIW 4-1/16"5M'FLS' 20' /MP i 11"x 12"5M FMC Gen 6 Unibore w/two 2"5M valves on Wellhead side ports 11"x 4-1/8"5M adapter and 11"x 4.5"tbg hng 4.5"NSCT threads top and bottom and 4"CIW-H 41/2"x5-1/2" Crossover@23.01' OPEN HOLE/CEMENT DETAIL Mn ID 3.833 1~ 20" Cmt w/250 sx Arcticset 1(Approx.)in a 24"Hole 9-5/8" 980 sx PF'E',1,000 sx Class`G'in a 12-1/4"Hole WELL INCLINATION DETAIL l KOP @ 300' ° Max Hole Angle=68°f/3,636' I Hole angle thru perfs=67° CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surface _ 113' 9-5/8" Surface 40/L-80/BTC 8.835 Surface 1,932' 47/L-80/BTC-MOD 8.681 1,932' 4,970' TUBING DETAIL 5-1/2" Tubing 17/L-80/IBT 4.892 Surface 3,853' JEWELRY DETAIL No Depth Item 1 ±3,770' Discharge Head HPDIS 2 ±3,772' Pump: 3 ±3,784' Pump: 4 ±3,788' Pump:w/Integral Intake 5 ±3,804' Upper Tandem Seal: 6 ±3,811' Lower Tandem Seal: 7 ±3,818' Motor: 1 1 8 3,912' 9-5/8"HES Versatrieve Packer 9 3,932' Safety Shear Sub,Min ID=3.88" 2.3&4 10 3,935' 5-1/2",20 ppf, N-80,LTC Blank Pipe;ID=4.778" 11 3,960' 5-1/2"0.12 Ga.Pre-Pack Screen,ID=4.778" I:FI:I! 12 4,082' 5-1/2"0.12 Ga.Screen,ID=4.778" I 5&6 13 4,144' 9-5/8"HES Versatrieve Packer i i 14 4,164' Safety Shear Sub,Min ID=3.88" 15 4,167' 5-1/2",20 ppf, N-80,LTC Blank Pipe;ID=4.778" 16 4,329' 5-1/2"0.12 Ga.Pre-Pack Screen,ID=4.778" 7 17 4,571' 5-1/2"0.12 Ga.Screen,ID=4.778" Li 18 4,604' 9-5/8"HES Sump Packer set on e-Line 1/05/1997 PERFORATION DETAIL—Ref Log: Open hole MWD 8/10/96 8 9 � Sand Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status _ 1a Upper Prince CSaids Creek'C'Sand 3,979' 4,139' 2,572' 2,639' 160 1/09/1997 Open Lower Prince Creek'D'Sand 12 4,339' 4,599' 2,721' 2,826' 260 1/06/1997 Open 14 13 .4 24gm SWS 4.5"12 spf 43C big hole charges @ 135/45 deg.phasing(w/0.7"EHD and 7.9"TTP) 15 r 16-_ GRAVEL PACK DETAIL C sands C Sand:9,500Ibs of 20-40 Carbolite 1/09/1997 17"" D Sand:8,000lbs of 20-40 Carbolite 1/08/1997 18y. Min.Gravel Pack Restriction ID=2.97" GENERAL WELL INFO 9.5/8" A.y�' ._, 11 API:50-029-22694-00-00 Drilled and Cased by Nabors 22E—8/13/1996 TD=4,995'(MD)/TD=2,997'(TVD) Install Gravel Pack by Nabors 4ES —1/11/1997 PBTD=4,868'(MD)/PBTD=2,933'(TVD) Initial ESP by Nabors 4ES —5/18/1997 Replace Penetrator by Nabors 5S —2/05/1998 Change out ESP by Nabors 4ES —9/20/2009 Revised By:TDF 6/04/2018 0 Sine Point . .11 ASR Rig 1 BOPE 2018 Ildoo p Alsx.l.a.IAA: 11" BOPE Stripping Head ( 1 4.48' Plbydril G4 nil" - 5000 ter- IIIIIIIiiiiil'iiiiii aiii In III lit III Iii bo CI ®-U lIIII _:4.54' '— VBR or Pipe Rams ' ��) 11 '- 5000 II ' :.=. � - Blind IIIIli iii Iiia iii 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves I!r9lrlirIU Ili'' 2.00' : ; I-.1[:(0) t .L• : I.I. 0A.NIIOl i I i ' „ki in lit MAI flit i HCR 'Manual Manual HCR Updated 5/14/2018 . 13 • MPU F-21 EXISTING TREE/WELLHEAD Wellhead/Tree Milne Point Unit Hilcorp Alaska.LLC Tree Cap 9.) .61 I.1 AM AIME ; 1P ) ) Tree Valve 4-1/16 5M od 1l.1i 1—111 Tree Cross 4-1/16" 5M 10 r )l o Tree Valve 4-1/16" 5M J ----' 4' SSV 4-1/16" 5M 0 ti Tree Valve 4-1/16" 5M r'I Opo' .., . . ESP Cable "' '" Tubing Adapter 117 ,n 1111111= — .F: Tubing Head in wn 11" 5M Top x11" 5MBtmair— t4gor-V r.° firlii% ‘V 011 ■ k IVAgiv MMI 0 • d N d _> N -cL d 'p ACL = Oca o VTo _ V o5 Qac = �E a) Qa E E c" E < O = a) 2 Q G 3 Q Q 73 = o m � Y m +v > m w ._ - 2 ami _. CLo L CU m CS a m L as .Y2 a) O O) 0 0 CO C N (0 CD C (0 N L L 0 - C o L. o o ago L Q 0 r j f6 tea'! L n1 OL N = U. LL o.,— R D. O .0 @ V = d N (6 U = 73 0 a O 41 C V 0 O Q O G) cp E 4--; a` = a) U 0 -0 a) N L Oy _a CI- 0 �ro m• .. a O L L d CD 2 O NC 0-4 a 0 O 0. a 0 L Q (B O e0 W Q. O �O+ C D N N Ce ,-- Q N (0 p C C C/1 N 0 3 O O CI O 0) N .0) CD CU OCUCD a O N a) Q. Q. ,: U = m E U o al++ SI" C a 0. n N 0 o v� c'n Q � Q a XHVZE Pages NOT Scanned in this Well History File 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. ,/~O ',L¢~'~ile Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy~Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by; Beverly Dianna' .... ,,~.,~owell Date: Isl • .x, bp BP Exploration (Alaska) Inc. - Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 Str-ANNED FEE, 17 2012 December 30, 2011 Mr. Tom Maunder / 3 S Alaska Oil and Gas Conservation Commission CJ 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator . • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date j ft bbls ft gal MPF -01 1950450 50029225520000 10.2 WA 10.2 N/A 122.4 8/7/2011 MPF -02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/62011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 --.-3 . MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10292011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/12011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/92011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/12011 MPF -33 2010620 50029226890000 23 Need top job , MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF-37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF -42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF-45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF -49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/312011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/12011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/112011 MPF -66A 1961820 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF-69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/112011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF -81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF -83 2000930 50029229630000 1.2 N/A 1.2 N/A 13.6 8/3/2011 MPF -84B 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 NIA 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/132011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/12011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 _ 8/112011 STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 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 ^ Perforate ^ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Euploratory ``.. 196-135 3. Address: ~ Service ^ Stratigraphic . API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22694-00-00 7. Property Designation: 8. Well Name and Number: ADL 025509 L MPF-21 9. Field / Pool(s): Milne Point Unit / Prince Creek 10. Present well condition summary Total depth: measured ~~ 4g95' feet true vertical • 2986' feet Plugs (measured) None Effective depth: measured 4889' feet Junk (measured) None true vertical 2gq2' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 113' 20" 113' t 13' ' "" "~ 1490 470 Surface Interrnediate Production 4939' 9-5/8" 4968' 2975' 6870 4760 Liner ~~b`3J~f1l~~ ~~ ~J ~~ i? ~U~~ Perforation Depth: Measured Depth: 3979' - 4599' True Vertical Depth: 2572' - 2826' Tubing (size, grade, measured and true vertical depth): 5-1/2", 17# L-80 3853' 2522' Packers and SSSV (type, measured and true vertical depth): Gravel Pack Assembly w/ (2) 9-5/8" HES 3912 ; 2545'; Versatrieve Packers &(1) 9-5/8" HES 4144'; 2642'; 'BWD' Sump Packer 4604' 2828' 11. Stimulation or cement squeeze summary: Intervals treated (measured): ~~~ ~; ~~ ~ ~ 2009 Treatment description including volumes used and final pressure: ~~~s~~ ~i~ ~ ~as ~on3. Commission Anchorag~ ~2. Representative DailyAve~age 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 ~ Dail ort of Well O erations Re y p p ~ Well Schematic Diagram 15. Well Status after work: ^ Oil ^ Gas ^ W~SPL ^ GSTOR ~ w"r'~S ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number esr N/A if C.O. Exempt: Contact Mackie Derrick, 564-5891 N/A Printed Name Terrie Hubble Title Drilling Technologist • ~ O / Prepared By N~nNNumber D t P ~ Si nature 9 a e hone 564-462$ Terrie Hubble, 564-4628 Form 10-404 Revised 07/2009 U A~/y'~ < ~~ I~~~f s;~,., Submit Original Only T~~rsl "-~-' ~ I Cv ~l~° v 7 ~ • BP EXPLORATION Page 1 af 4' Operations Summary Report Legal Well Name: MPF-21 Common Well Name: MPF-21 Spud Date: Event Name: WORKOVER Start: 9/1/2009 End: 9/22/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/22/2009 Rig Name: NABORS 4ES Rig Number: 4ES : Date From - To Hours Task Cod~ NPT Phase Description of Operations 9/18/2009 06:00 - 08:00 2.00 MOB P PRE SCOPE DERRICK DOWN AND LAY OVER. -PREPARE MODULES TO MOVE TO MPF-21 FROM MPF-65. -MOVE OFF MPF-65. 08:00 - 11:30 3.50 MOB P PRE MOVE IN AND RIG UP ON MPF-21. -SPOT SUB BASE, PITS AND PIPE SHED. ' 11:30 - 13:00 1.50 MOB P PRE RIG UP. RAISE & SCOPE DERRICK. ACCEPT RIG @ 13:00 HRS 9/18/09 13:00 - 16:00 3.00 MOB P PRE RIG UP TREE & TIGER TANK TO CIRCULATE. -RU & TEST LUBRICATOR. TEST TO 500 PSI - PASS. -PULL BPV. LD SAME. TAKE ON 8.5 PPG SEAWATER. 16:00 - 18:00 2.00 KILL P DECOMP TEST SURFACE LINES TO 3500 PSI. -OPEN W ELL T/I/O = 120/120/0 -PUMP 120 DEGREE SEAWATER Q 3-5 BPM / 400 - 650 PSI. -PUMP 262 BBLS DOWN TBG. RECIEVED 145 BBLS TO TIGER TANK. -MONITOR WELL 5 MINUTES. - VACUUM. 18:00 - 20:30 2.50 KILL P DECOMP CONTINUE TO CIRCULATE OUT FREEZE PROTECTION. -CIRCULATE DOWN TBG 3-5 BPM / 300 - 920 PSI. -PUMPED 277 BBLS. RECIEVED 80 BBLS TO TIGER TANK. -TOTAL PUMPED 539 BBLS. TOTAL RECIEVED 225 BBLS.. 20:30 - 21:30 1.00 KILL P DECOMP BULLHEAD 200 BBLS DOWN IS. -PUMP 5 BPM / 300 PSI. -MONITOR WELL - VACUUM. 21:30 - 22:30 1.00 WHSUR P DECOMP SET & TEST TWC. , -TEST TO 3500 PSI FROM ABOVE FOR 10 CHARTED MINUTES. -TEST TWC FROM BELOW 1 BPM / 0 PSI 10 CHARTED MINUTES. 22:30 - 00:00 1.50 BOPSU P DECOMP ND TREE. 9/19/2009 00:00 - 02:30 2.50 BOPSU P DECOMP NU BOPS. 02:30 - 05:00 2.50 BOPSU P DECOMP CHANGE RAMS FROM 2 7/8" x 5" TO 3 1/2" x 6" VBR's. 05:00 - 06:00 1.00 BOPSU P DECOMP RU TO TEST BOP's. 06:00 - 06:30 0.50 BOPSU P DECOMP TEST BOPE AND RELATED EQUIPMENT. TEST TO BP & AOGCC PROCEDURES & REGULATIONS. -BOP CONFIGURATION: -13-5/8" HYDRIL GK 5000. -BLIND SHEAR RAMS. -SPACER SPOOL. -3-1/2" X 6" VARIABLE BORE RAMS. TEST CHOKE MANIFOLD, BLINDS, 3-1/2" X 6" VBR'S, -MANUAL CHOKE, HCR CHOKE, MANUAL KILL, HCR KILL, -FLOOR VALVES. -TEST TO 250 PSI LOW AND 3 500 PSI HIGH PRESSURE. -USED 5-1/2" TEST JOINT ON RAMS & ANNULAR. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -JEFF JONES AOGCC WAIVED W ITNESS OF TEST. -TEST WAS WITNESSED BY WSL & TP. Printed: 9/29/2009 11:37:43 AM • • BP EXPLORATION Page 2'of 4' Operations Summary Repart Legal Well Name: MPF-21 Common Well Name: MPF-21 Spud Date: Event Name: WORKOVER Start: 9/1/2009 End: 9/22/2009 Contractor Name: NABORS ALASKA DRI LLING I Rig Release: 9/22/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date' From - To Hours Task Code NPT Phase f Deseription of Operations 9/19/2009 06:00 - 06:30 0.50 BOPSU P DECOMP NOTED: CHOKE HOSE FAILURE. 06:30 - 07:00 0.50 BOPSU N RREP DECOMP DRAIN STACK. BLOW DOWN CHOKE MANIFOLD. 07:00 - 08:00 1.00 BOPSU P DECOMP SAFETY MEETING, AFTER ACTION REVIEW OF F-65 08:00 - 11:30 3.50 BOPSU N RREP DECOMP CHANGE OUT CHOKE HOSE. 11:30 - 15:30 4.00 BOPSU P DECOMP CONTINUE TO TEST BOP'S. VARIABLE PIPE RAM FAILURE. 15:30 - 20:00 4.50 BOPSU N RREP DECOMP CHANGE OUT PIPE RAMS TO 5-1/2" FIXED RAMS. -CLEAN & INSPECT CHOKE MANIFOLD. -INSTALL SAFETY CLAMPS ON CHOKE HOSE. 20:00 - 22:00 2.00 BOPSU P DECOMP CONTINUE TO TEST BOP'S. -ALL TESTS PASS. PERFORM DRAW-DOWN TEST ON KOOMEY.. -200 PSI BUILD UP = 45 SECONDS. -FULL PRESSURE = 182 SECONDS TO 3000 PSI -4 BOTTLES 1700PS1. RD BOP TEST EQUIPMENT. 22:00 - 22:30 0.50 BOPSU P DECOMP RU DUTCH SYSTEM. -SHOOT FLUID LEVEL 120' MD. 22:30 - 23:00 0.50 BOPSU P DECOMP RU & TEST LUBRICATOR TO 500 PSI. -PULL TWC. 23:00 - 00:00 1.00 BOPSU P DECOMP MU LANDING JT. BOLDS. 9/20/2009 00:00 - 00:30 0.50 PULL P DECOMP PULL TBG HANGER TO FLOOR. FREE @ 55K. -PULL TO FLOOR 55K. LD HANGER. 00:30 - 01:30 1.00 PULL P DECOMP CIRCULATE ONE TBG VOLUME (88 BBLS). RU SPOOLER. 01:30 - 06:00 4.50 PULL P DECOMP PULL 5 1/2" TBG - ESP COMPLETION ASSEMBLY. -PTSM W/DAY CREW. 06:00 - 06:30 0.50 PULL P DECOMP CREW CHANGE -SERVICE RIG: GREASE DRAWWORKS AND BLOCKS, DAILY DERRICK INSPECTION, ENVIRO WALKAROUND AND CHECK PVT'S. 06:30 - 07:30 1.00 PULL P DECOMP CONTINUE POH WITH 5-1/2" TBG AND ESP COMPLETION LAYING SINGLES DOWN INTO PIPE SHED 1 X 1. -LOST 23 1-1/4" CARBON STEEL BANDS DOWNHOLE. -WHEN ESP ASSEMBLY PULLED FROM HOLE, A LARGE NEST OF CARBON STEE~ BANDS WERE SETTING ON TOP OF WELLHEAD. ORDERED 4-1/2" WIRELINE MAGNET FROM WIRELINE TOOL ROOM TO FISH BANDS WITH. 07:30 - 10:30 3.00 PULL C DECOMP WAIT ON WIRELINE MAGNET TO ARRIVE. 10:30 - 11:00 0.50 FISH C DECOMP FISH 9 EA. OF 1-1/4" CARBON STEEL BANDS FROM WELLBORE WITH WIRELINE MAGNET ON HYDRAULIC TUGGER LINE. (14) 1-1/4" CARBON STEEL CABLE BANDS REMAIN LOST DOWNHOLE. 11:00 - 12:00 1.00 PULL P DECOMP BREAK OUT AND LAY DOWN ESP BHA. 12:00 - 13:00 1.00 PULL P DECOMP NABORS PERSONNEL (ONLY) CONFERENCE CALL WITH RIG LEADERSHIP. WEELY HSE MEETING WITH FULL CREW. 13:00 - 14:30 1.50 PULL P DECOMP CONTINUE BREAKING OUT AND LAYING DOWN ESP BHA. 14:30 - 17:30 3.00 FISH C DECOMP MIRU SLICKLINE UNIT WITH FULL PRESSURE CONTROL. -TEST TO 500 PSI. Printed: 9/29/2009 11:37:43 AM • • BP EXPLORATION' Page 3 of 4 ' Operations Summary Report Legal Well Name: MPF-21 Common Well Name: MPF-21 Spud Date: Event Name: WORKOVER Start: 9/1/2009 End: 9/22/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/22/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date' From - To Hours Task Code NPT Phase Deseriptio,n of Operations 9/20/2009 17:30 - 20:00 2.50 FISH C DECOMP RIH W/ 8.45 GAUGE RING & JUNK BASKET TO 600' MD. -WORK DOWN . -POH RECOVERED 2 BANDS & 1 RUBBER PIECE 1" X 1". -FAILED TO RECOVER BANDS FROM STACK. 20:00 - 21:30 1.50 FISH C DECOMP RIH W/ SAME ASSEMBLY, WORK @ 3,716' MD. POH. -RECOVERED 4.5 BANDS. 7.5 BANDS REMAIN. 21:30 - 23:30 2.00 FISH C DECOMP RIH W/ SAME ASSEMBLY TO 3,919' MD. POH. -RECOVERED 2 BANDS. -5.5 BANDS LEFT ON TOP OF PACKER ASSEMBLY. 23:30 - 00:00 0.50 FISH C DECOMP RD SLICKLINE. 9/21/2009 00:00 - 02:00 2.00 FISH C DECOMP CONTINUE TO RD SLICKLINE. -RD DUTCH SYSTEM. 02:00 - 03:30 1.50 RUNCO P RUNCMP WEEKLY SAFETY MEETING. 03:30 - 06:00 2.50 RUNCO P RUNCMP PU & SERVICE ESP PUMP. , -RU TO RUN ESP PUMP ASSEMBLY. ' 06:00 - 06:30 0.50 RUNCO P RUNCMP CREW CHANGE -SERVICE RIG; GREASE DRAWWORKS, BLOCKS AND CROWN. DAILY DERRICK INSPECTION AND CHECK PVT'S. ENVIROMENTAL WALKAROUND RIG. 06:30 - 08:30 2.00 RUNCO P RUNCMP COMPLETE ASSEMBLY OF ESP BHA AND PREP TO RIH. 08:30 - 16:00 7.50 RUNCO P RUNCMP RIH WITH ESP BHA PICKING UP SINGLE JOINTS OF 5-1/2" 17#, L-80 IBT TUBING FROM PIPE SHED. RIH WITH 93 JTS. TUBlNG AND ESP BHA. -INSTALLED CANNON CROSS COUPLING CABLE CLAMPS ON EVERY TUBING COUPLING. -TORQUED TUBING CONNECTIONS TO THE MARK - AVERAGE TORQUE = 4,000 FT-LBS. -USED BEST-O-LIFE 2000 THREAD COMPOUND. 16:00 - 16:30 0.50 RUNCO P RUNCMP PUMU TUBING HANGER ON LANDING JOINT WITH CLOSED TIW VALVE AND TWC PRE-LOADED IN HANGE . 16:30 - 18:00 1.50 RUNCO P RUNCMP CENTRILIFT SERVICE TECHNICIAN MAKE LOWER WELLHEAD PENETRATOR CONNECTOR SPLICE. -SIM-OPs = CONFERENCE CALL W/ NBRS TOWN & CREWS. 18:00 - 19:00 1.00 RUNCO P RUNCMP INSTALL FIELD CONNETOR ON ESP CABLE. -SIM-OP's = CONFERENCE CALL W/ NBRS TOWN & CREWS. 19:00 - 20:00 1.00 RUNCO P RUNCMP LAND TBG HANGER W/ TWC INSTALLED. -PUW 56K, SOW 39K. RILDS. 20:00 - 21:00 1.00 RUNCO P RUNCMP TEST TWC FROM BELOW. -INJECT @ 3 BPM / 100 PSI FOR 10 CHARTED MINUTES. 21:00 - 22:00 1.00 RUNCO P RUNCMP CHANGE RAMS FROM 5-1/2" FIXED TO 2-7/8" x 5" VARIABLES. 22:00 - 23:00 1.00 RUNCO P RUNCMP SAFETY MEETING, DISCUSS: NABORS TENETS. -CONDUCT AFTER ACTION REVIEW FOR MPF-21. 23:00 - 00:00 1.00 RUNCO P RUNCMP ND BOP's. 9/22/2009 00:00 - 01:00 1.00 RUNCO P RUNCMP ND BOPE. 01:00 - 02:30 1.50 RUNCO P RUNCMP NU TREE. 02:30 - 03:00 0.50 RUNCO RUNCMP -TE VTS OID TO 5000 PSI F/ 10 CHARTED MINUTES. 03:00 - 04:30 1.50 RUNCO P RUNCMP PU & TEST LUBRICATOR. -PULL TWC. INSTALL BPV. -TEST FROM BELOW 3 BPM / 100 PSI / 10 CHARTED MINUTES. Printed: 9/29/2009 11:37:43 AM ~ • BP ExPLOR,4TION Page 4 of 4; Operations Summary Report Legal Well Name: MPF-21 Common Well Name: MPF-21 Spud Date: Event Name: WORKOVER Start: 9/1/2009 End: 9/22/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/22/2009 Rig Name: NABORS 4ES Rig Number: 4ES ' Date, From - To Hours Task Code NPT Phase Description of Operations 9/22/2009 04:30 - 06:00 1.50 RUNCO P RUNCMP RD LINES. SECURE WELL. -T/I/O = 0/0/0 RELEASE RIG 06:00 HRS 9/22/09 Printed: 9/29/2009 11:37:43 AM ~ . Tree: CIW 4 1/16" 5M 'FL~ MPU F~21 Welihead: 11 " x 12" 5M FM en 6 Unibore w/ two 2" 5M valves on side ports 11 " 5M x 4'!/8" 5M adapter and 11" x 4.5" tbg. hng. 4.5" NSCT threads top and bottom and 4" CIW-H BPV profile. ~ . 20" 91.1 ppf, H-40 ~ ~ 3 KOP C~ 300' Max. hole angle = 63° to 68 f/ 2800' to PBTD' Hole angle through perfs = 66°. DLS > 4deg./100' C~ 700' - 2150' / 5.5", 17 ppf, L-80 IBT tubing (cap. = 0.0232 bpf, drift = 4.767' Centrilift No. 1, CL-81 Cable 9 5/8", 47 ppf, L-80 Btrc. mod. prod. csg. from TD to 1930' 40 ppf, L-80 Btrc. prod. csg. f/ 1930' -surt (cap. = 0.0758 bpf, 13.2 fpb.) Gravef Pack Summary: `C' Sand - 9.5 to 12.6 M# of 20-40 mesh Carbolite behind pipe prior to screen out 'D' Sand - 8 M# of 20-40 mesh Carbolite behind pipe before screen out Perforation Summary: Ref loa: Open hole MWD - 09/14/95 Size SP Interval (TVD) Prin e C eR'C" Sand 4.5" 12 3979' - 4139' (2572' - 2639') "D" Sand 4.5" 12 4339' - 4599' (2721' - 2826') 24 gm. SWS 43C big hole charges @ 135° / 45° deg. phasing (w/ 0.7" EHD and 7.9" TTP),w/ 135 / 45 deg. phasing WS'W Orig. D~v. = 40.90' (N 22E) ~ Orig. GL v. = 11.8' RDF To 9 5/8" hng. - 29.1' Note: the minimum restriction in the tbg. string is located in the 4.5" hanger and the two 4.5", 12.6 ppf pup jts. w/ 4.5" x 5.5" crossover. The minimum ID is 3.833" E~~' ~~~~-~' '.~ci n~e C' c'e e-k l~?c~,~-~-e..c' ~~c ~ ~`1 3853' ' 9 5/8" HES Versatrieve pkr. 3,912' md 5 1/2", 20 ppf, N-80, LTC " 934' md 3 blank pipe (ID = 4.778 , 5 1/2", 0.012" Ga.pre-pack 3,960' md screen (ID = 4.778" 5 1/2", 0.012" Ga. screen " 4,081' md (ID = 4.778 : " 4 143' md ID) Honed Seal unit (3.00 , Collet Muleshoe Guide 4,149' md 9 5/8" HES Versatrieve pkr. 4,144' md Closing sleeve ass'bly 4,153' md 5 1/2", 20 ppf, N-80, LTC blank pipe (ID = 4.778" q ~67' md 5 1/2", 0.012" Ga.pre-pack screen (ID = 4.778") 4,329' md 5 1/2", 0.012" Ga. screen 4,571' md ( I D = 4.778"; HES 9 5/8" 'BWD' sump pkr. 4 604' wlm 9 5/8" Float collar (PBTD) 4,889' md 9 5/8" csg. shoe 4,968' md DATE REV. BY COMMENTS OS/24/96 01/06/97 MDO / JSF JBF/ MDO Drilled and Cased by Nabors 22E Lower ravel ack 05/18/97 JBE Initial ESP Completion by Nabors 4 ES 02/05/98 MDO Replace penetrator at hanger 5-S 9/20/09 L. Hulme Replace ESP 4ES MILNE POINT UNIT WELL F-21 WSW API NO: 50-029-22694 BP EXPLORATION RE: MPU Water Supply Wells • • Subject: RE: MPU Water Supply Wells From: "MPU, Well Operations Supervisor" < welloperationssupervisor @BP.com> Date: Fri, 02 Mar 2007 13:49:38 -0900 To: Thomas Maunder <tom maunder admin.state.ak.us> Tom, I from what I know, they have always been ESPs. If you would like, I can dig back through the well files. Please let me know. Thanks, c t, i John R. Cubbon v �` i APR �. 2 2.01 MPU Well Operations Supervisor 1- 907 - 670 -3330 Original Message From: Thomas Maunder [mailto:toT maunder admix_ slat .ak.us] Sent: Friday, March 02, 2007 1:28 PM To: MPU, Well Operations Supervisor Subject: Re: MPU Water Supply Wells Thanks John. For the ESP wells, they have always been ESPs correct? Tom MPU, Well Operations Supervisor wrote, On 3/2/2007 1:17 PM: 1/ Hi Tom, C{\S O �X V �m L ` \ `O \ (o The information for these wells is as follows: F -02 ESP Completion Active Water Supply Well + (A(o- (j`A O A2A ESP Completion Active Water Supply Well kc6 S _ k B -01 ESP Completion Non- Active Water Supply Well (has not been utilized since at least 2004, and likely much longer) ESP Completion Active Water Supply Well tS( - \ " S- F-58 ESP Completion Active Water Supply Well \C:O ` c F -77 ESP Completion Active Water Supply Well Co S -22 Jet Pump Completion in the UGNU. Has been SI since 2005 due to a o's _ i l., \ ., \ excessiv an production. S 90 nr;lled as a hot Ivishak water supply well in 2006. We are evaluating completion options and trying to overcome potential a ©S - \ ' corrosion challenges due to the high CO2 content of the water. Tentative plan to put into service later in 2007. I hope this helps Tom. If you have any questions, or need any further details, please don't hesisitate to let me know. Thanks John R. Cubbon MPU Well Operations Supervisor 1- 907 - 670 -3330 1 of 2 3/2/2007 1:58 PM RE: MPU Wa ter Supp W ells • Original Message From: Thomas Maunder [mailto:t.om m: :ndergadmi.ri.state.ak.i.s] Sent: Monday, February 26, 2007 3:13 PM To: Cubbon, John R Subject: MPU Water Supply Wells John, I see that MPF -02 was just worked over. In the course of checking a few things, I noticed in our production report that this well was reported to be a flowing completion and it appears to have been since completion in August 1996. I have checked our reports on your other wells and found the following: MPA -02A -- submersible, SI or no information to August 1995, then flowing or no information since. MPB- 01---- submersible, SI or no information to January 1998, then flowing to September 2001 and SI since MPF- 21 - - -- flowing since completion June 1997 MPF- 58 - - -- flowing since completion November 1996 MPF- 77 - - -- flowing since completion April 1996 MPK- 34 - - -- flowing since completion December 1997 MPS- 22 - - -- hydraulic pump or flowing since completion in October 2003, SI mostly MPS- 90 - - - -no water production reported I think the production method for all the wells is ESP. Am I correct? I am not sure where the error might be coming from. When you confirm the production method, I will get with our stat techs here and see how we are receiving the information. Then I will get back to you and we can see what changes may be needed. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC f 2 of 2 3/2/2007 1:58 PM RE: Milne Point K-pad water supply well MPK-34 (PTD #1961690)... e e Subject: RE:Milne Point K-padwater supply well MPK-34 (PTD #1961690}and F-Pad water'k~pply wells_F;io2,~58,atld 77 (PTD #1960700,:._~:~,~;,f1961560, and #1951360) ,,' From: "MPU, Well'Operations Supervisor" <welloperati~nssupervisor@BP.com> Datë: Thu, 29 Dee 200507:05:21 -0900 Tci:.omas Maundef<toni.iìtaunder@admin.s\te.ak.us> .y. ""):;{"::":;." Thanks Tom! JRC 5{;J\NNE.L é1 !: From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, December 29, 2005 6:50 AM To: MPU, Well Operations Supervisor Cc: MPU, Operations Manager; Jim Regg Subject: Re: Milne Point K-pad water supply well MPK-34 (PTD #1961690) and f-Pad water supply wells MPf-02, 21, 58, and 77 (PTD #1960700, #1961350, #1961560, and #1951360) Hi John, I did some checking as well. Your understanding regarding a regulatory requirement for SSV s on water supply wells is correct. There is no requirement to employ SSV s on such wells. Thanks for checking. Tom Maunder, PE AOGCC MPU, Well Operations Supervisor wrote, On 12/2812005 6:12 PM: Hi Tom, As per our conversation yesterday, I am curious if we are required to have a functioning SSV on our water supply wells here at Milne Point. These wells produce from the Prince Creek and Ugnu formations and are not hydrocarbon producing. From what I can gather reading through the regulations, I can't see where we are required to have a functioning SSV on these wells, but wanted to check with you to make sure. The wells were equipped with SSVs when they were drilled, but we would like to remove the panels and use them elsewhere if they are not required on our source water wells. Our source water wells are not capable of unassisted flow and are produced with Electrical Submersible Pumps. These wells are equipped with pilots that will shut down the ESP if the flowline pressure drops below 500 psi (Le. we develop a leak). Thanks for your help on this Tom and please don't hesisitate to let me know if you need any further information. Best Regards, John R. Cubbon MPU Well Operations Supervisor 1-907-670-3330 1 of! 12/29/20057:10 AM PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 05/24/99 RUN RECVD 96-135 TEMP ~-3600 96-135 SBT ~2080-3571 96-135 SBT/GR/CCL u~'~9-3579 96-135 GR-CCL CORRELATE~'~r00-4863 96-135 PACK RCD J~00-4863 96-135 GRAVEL PACK ~4030-4624 96-135 USIT ~0-3500 96-135 CBL ~/0-3470 96-135 DGR/RES-MD ~/104-4995 96-135 MWO SRVY :~R'-SPERRY 0-4995 96-135 MMS SRVY --R SPERRY 0-5048 1 08/30/96 1 08/30/96 FINAL 09/11/96 FINAL 02/21/97 FINAL 02/21/97 FINAL 02/21/97 FINAL 02/21/97 FINAL 02/21/97 FINAL 02/26/97 FINAL 02/26/97 1-3 04/02/97 08/29/97 08/29/97 lO-4O7 ~ COMP~,ETION DAT~, ~ .?~;? /q 7/ Are dry ditch samples required? yes n~ ~d received? Was the well cored? yes n~.~alysis & description received? Are well tests required? yes ~:~Received? Well is in compliance Initial CO~ENTS yes T D BOX -- ~ALASKA~ .eared r-vices rilling BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: February 26, 1999 From: Subject: Terrie Hubble Technical Assistant Miscellaneous Surveys Enclosed, in duplicate, are a number of directional surveys that l have come across while clearing out Ms. Campoamor's desk. I have verified that these surveys do not affect the previously calculated TVD's and below surface locations of these wells, so it was not necessary to correct the 10-407's. They are simply being submitted for your records. If they are duplicates, please discard them. Thank you. /tlh Endicott MPI 1-09A/L-21 Milne Point MPC-09 Milne Point MPF-21 Milne Point MPF-37 Milne Point MPF-45 Milne Point MPF-69 Milne Point MPF-79 Permit #97-29 Permit #85-36 Permit #96-135 Permit #96-25 Permit #95-58 Permit #95-125 Permit #97-180 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION (ALASKA), INC. MPU / MPF-21PB1 500292269470 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 5/98 DATE OF SURVEY: 081196 MWD SURVEY JOB NUMBER: AK-PIM-60103 KELLY BUSHING ELEV. = 40.90 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -40.90 0 0 N .00 E .00 .00N .00E .00 149.18 149.18 108.28 0 12 S 68.74 E .13 .09S .24E .20 201.95 201.95 161.05 0 27 S 51.99 E .50 .26S .49E .46 262.61 262.60 221.70 0 45 S 33.97 E .59 .74S .90E 1.08 324.07 324.05 283.15 1 51 S 26.36 E 1.79 1.96S 1.57E 2.47 354.03 353.99 313.09 2 24 S 26.24 E 1.87 420.64 420.48 379.58 4 0 S 22.16 E 2.41 444.00 443.78 402.88 4 19 S 23.15 E 1.44 534.62 534.06 493.16 5 34 S 22.47 E 1.37 565.69 564.98 524.08 5 50 S 21.80 E .92 2.96S 2.07E 3.59 6.37S 3.56E 7.30 7.93S 4.22E 8.98 15.14S 7.24E 16.77 18.01S 8.41E 19.84 578.82 578.04 537.14 5 53 S 20.84 E .80 624.08 623.04 582.14 6 25 S 22.22 E 1.22 656.40 655.12 614.22 7 26 S 24.22 E 3.27 686.42. 684.81 643.91 9 18 S 26.92 E 6.30 715.75 713.67 672.77 11 16 S 27.18 E 6.75 19.26S 8.89E 21.17 23.77S 10.68E 25.99 27.35S 12.22E 29.88 31.29S 14.12E 34.25 35.96S 16.50E 39.48 748.60 745.78 704.88 13 0 S 27.12 E 5.24 807.31 802.69 761.79 15 19 S 27.44 E 3.97 897.92 889.43 848.53 18 16 S 32.00 E 3.56 986.40 971.60 930.70 25 5 S 32.29 E 7.70 1083.98 1056.97 1016.07 32 41 S 32.01 E 7.79 42.10S 19.65E 46.39 54.87S 26.24E 60.75 77.56S 39.29E 86.92 105.22S 56.69E 119.51 145.11S 81.74E 166.51 1178.05 1134.89 1093.99 35 26 S 31.00 E 2.98 .1271.87 1210.28 1169.38 37 35 S 29.18 E 2.58 1366.70 1283.91 1243.01 40 30 S 28.47 E 3.09 1460.01 1353.14 1312.24 43 41 S 27.77 E 3.46 1555.46 1419.14 1378.24 48 47 S 26.77 E 5.40 190.04S 109.26E 219.11 238.34S 137.23E 274.90 290.68S 166.02E 334.63 345.85S 195.48E 397.18 407.11S 227.04E 466.08 1649.71 1480.02 1439.12 50 43 S 28.49 E 2.48 1744.46 1541.08 1500.18 49 1 S 27.16 E 2.08 1839.69 1603.26 1562.36 49 26 S 25.30 E 1.54 1934.27 1663.66 1622.76 51 10 S 24.10 E 2.07 2030.29 1722.38 1681.48 53 24 S 25.03 E 2.46 470.82S 260.40E 538.00 534.88S 294.22E 610.43 599.57S 326.09E 682.50 665.68S 356.49E 755.13 734.75S 388.07E 830.92 2125.07 1776.93 1736.03 56 18 S 25.80 E 3.13 804.74S 421.34E 908.32 2220.54 1829.32 1788.42 57 7 S 26.23 E .93 876.46S 456.34E 988.07 2313.51 1878.02 1837.12 59 42 S 25.38 E 2.88 947.76S 490.81E 1067.18 2408.78 1922.41 1881.51 64 44 S 23.95 E 5.45 1024.34S 525.95E 1151.28 2500.00 1961.34 1920.44 64 44 S 23.95 E .00 1099.73S 559.44E 1233.55 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF([~' ~,, I!' i~'il ,il~,~:~ ,,,i['~i', THREE-DIMENSION MINIMUM CURVATURE METHOD. ' ..... ~ ......... HORIZONTAL DISPLACEMENT = 1233,85 FEET i:?"¥?~,i"ii~"~:'~!~~'~'"' i.~i~..~...~. AT SOUTH 26 DEG. 57 MIN. EAST AT MD = 2500 ,~ ~, ,~, VERTICAL SECTION RELATIVE TO WELL HEAD ,q~Ci~?.~v.i~. VERTICAL SECTION COMPUTED ALONG 151.77 DEG. TIE-IN AT SURFACE 0.00' MD PROJECTED SURVEY AT 2,500.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 BP EXPLORATION (ALASKA), INC. MPU / MPF-21PB1 500292269470 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 5/98 DATE OF SURVEY: 081196 JOB NUMBER: AK-MM-60103 KELLY BUSHING ELEV. = 40.90 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -40.90 1000.00 983.86 942.96 2000.00 1704.33 1663.43 2500.00 1961.34 1920.44 .00 N .00 E .00 110.19 S 59.83 E 16.14 16.14 712.71 S 377.78 E 295.67 279.53 1099.73 S 559.44 E 538.66 242.99 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 BP EXPLORATION (ALASKA), INC. MPU / MPF-21PB1 500292269470 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 5/98 DATE OF SURVEY: 081196 JOB NUMBER: AK-MM-60103 KELLY BUSHING ELEV. = 40.90 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -40.90 40.90 40.90 .00 140.90 140.90 100.00 240.90 240.90 200.00 340.93 340.90 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .08 S .22 E .00 .00 .50 S .74 E .00 .00 2.47 S 1.82 E .03 .03 441.11 440.90 400.00 541.49 540.90 500.00 642.06 640.90 600.00 743.59 740.90 700.00 847.06 840.90 800.00 7.73 S 4.13 E .21 .18 15.76 S 7.50 E .59 .38 25.66 S 11.46 E 1.16 .57 41.10 S 19.14 E 2.69 1.53 64.49 S 31.49 E 6.16 3.47 952.87 940.90 900.00 1065.07 1040.90 1000.00 1185.43 1140.90 1100.00 1310.86 1240.90 1200.00 1443.17 1340.90 1300.00 93.82 S 49.50 E 11.97 5.81 136.66 S 76.46 E 24.17 12.20 193.70 S 111.46 E 44.53 20.35 259.44 S 148.93 E 69.96 25.43 335.63 S 190.09 E 102.27 32.31 1588.49 1440.90 1400.00 1744.19 1540.90 1500.00 1898.00 1640.90 1600.00 2061.73 1740.90 1700.00 2242.06 1840.90 1800.00 429.30 S 238.23 E 147.59 45.32 534.70 S 294.13 E 203.29 55.70 639.91 S 344.95 E 257.10 53.81 757.74 S 398.87 E 320.83 63.73 892.75 S 464.33 E 401.16 80.33 '2452.11 1940.90 1900.00 2480.00 1952.80 1911.90 1060.15 S 541.86 E 511.21 110.05 1083.20 S 552.09 E 527.20 15.99 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [--I Operation Shutdown I--] Stimulate I--~ Plugging L--I Perforate [--I Pull Tubing []Alter Casing [~ Repair Well [--] Other Replace penetrator at hanger 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Type of well: i--I Development [--I Exploratory [--] Stratigraphic [~Service 4. Location of well at surface 1833' NSL, 2714' WEL, SEC. 6, T13N, R10E At top of productive interval 426' SNL, 1526' WEL, Sec. 7, T13N, R10E At effective depth 1152' SNL, 1117' WEL, Sec. 7, T13N, R10E At total depth 1232' SNL, 1070' WEL, SEC. 7, T13N, R10E 6. Datum Elevation (DF or KB) RTE = 41' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-21 9. Permit Number / ApprovalNo. 96-135 10. API Number 50-029-22694 11. Field and Pool Milne Point/Prince Creek 12. Present well condition summary Total depth: measured 4995 feet true vertical 2978 feet Effective depth: measured 4889 feet true vertical 2931 feet Casing Length Structural Conductor Surface Intermediate Production Liner Size 82' 20" 4938' 9-5/8" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx.) 830 sx PF 'E', 1000 sx Class 'G' MD TVD 112' 112' 4968' 2964' Perforation depth: measured true vertical 3979' - 4139', 4339' - 4599' (Subsea) 2538' - 2599', 2680' - 2785' Tubing (size, grade, and measured depth) 5.5" 17 ppf, L-80 tubing to 3762' Packers and SSSV (type and measured depth) 9 5/8" HES Versatrieve pkr at 3912', 9 5/8" HES Versatrieve pkr at 4144' and 9 5/8" HES 'BWD' sump pkr at 4604' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [--I Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: I--I Oil I-'1 Gas I--I Suspended Service Prince Creek Water Source 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ Jeae-~,e~.''~s'/~/~¢~ '*~ //~/'~""~J~J' Title Staff Technical Assistant Date Prepared By Name/Number: Jeanne L. Haas, 564-5225 Facility Date/Time 02 Feb 98 03 Feb 98 04 Feb 98 05 Feb 98 M Pt F Pad Progress Report Well MPF-21 Rig Nabors 5S Page Date Duration Activity 06:00-17:00 17:00-06:00 06:00-06:30 06:30-08:00 08:00-10:00 10:00-11:30 11:30-13:00 13:00-17:00 17:00-17:30 17:30-19:00 19:00-22:00 22:00-02:00 02:00-06:00 06:00-07:00 07:00-07:30 07:30-16:00 16:00-18:00 18:00-18:15 18:15-22:00 22:00-23:00 23:00-03:00 03:00-06:00 06:00-11:30 llhr 13hr 1/2 hr 1-1/2 hr 2hr 1-1/2 hr 1-1/2 hr 4hr 1/2 hr 1-1/2 hr 3hr 4hr 4hr lhr 1/2 hr 8-1/2 hr 2hr 1/4 hr 3-3/4 hr 1 hr 4 hr 3 hr 5-1/2 hr Rig moved 100.00 % Skid rig Held safety meeting Rig moved 100.00 % Filter Seawater Removed Hanger plug Cleared Chicksan lines Circulated at 3810.0 ft Flow check Circulated at 3810.0 ft Installed Hanger plug Rigged up All rams Tested BOP stack Cleared Flowline Held safety meeting Removed Tubing hanger Repaired Electric cable Held safety meeting Repaired ESP Installed Tubing hanger Removed BOP stack Installed Xmas tree Freeze protect well - 160.000 bbl of Diesel 1 26 February 98 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well i--1Oil [--I Gas E~]Suspended l--iAbandoned ~[,Service Prince Creek Water Source 2. Name of Operator 7. Permit Number BP Explorat,ion (Alaska)Inc. 96-135 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22694 i4. Location of well at surface ~ I 9. Unit or Lease Name 1833' NSL, 2714' WEL, SEC. 6, T13N, R10E~ Milne Point Unit At top of productive interval 10. Well Number 443' SNL, 1535' WEL, SEC. 7, T13N, R10E MPF-21 At total depth 11. Field and Pool 1256' SNL, 1089' WEL, SEC. 7, T13N, R10E Milne Point/Prince Creek 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RTE = 52'I ADL 025509 12. Date Spudded 113. Date T.D. Reached I 14. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 8/7/96 I 8/11/96 t 5/17/97 I MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of PermafroSt 4995 2997 STI N/A N/A FTI [~Yes []No I MD I 1800' (Approx.) 22. Type Electric or Other Logs Run GR/LWD 23. CASlNG~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1 # H-40 Surface 113' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 29' 4968' 12-1/4" ~30 sx PF 'E', 1000 sx 'G', 150 sx PF 'E' .... .... 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SiZE DEPTH SET (MD) PACKER SET (MD) ....... 4.5" at 12 spf 5.5" 17# L-80 3762' 4144' MD TVD MD TVD 3979'-4139' 2583'-2651' 4339'-4599' 2732'-2837' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ................. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED , 3979'-4139' 9.5 to 12.6M# 20/40 carbolite behind pipe 4339'-4699' 8M# of 20-40 mesh carbolite behind pipe 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 6/2/97 I Other - Water Source Well Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I FieTM TL~'l~'ing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-Hour RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ....... bid. o , - - Form 10-407 Rev. 07-01-80 Submit In Duplicate -~' Geologic Markers 30. Formation Tests _-. Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GQR, and time of each phase. No markers picked · 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAIvord .,~/~ ~. (~-~ Title Senior Drilling Engineer .. Date ~--2(2,~[~)7 MPF-21 96-135 Prepared By Name/Number: Jeanne Haas 564-5225 Well Number Permit No. / Approval No. ~NSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut~In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 06 Aug 96 07 Aug 96 08 Aug 96 09 Aug 96 10 Aug 96 11 Aug 96 M Pt F Pad Progress Report Well MPF-21 Rig Nabors 22E Page Date Duration Activity 12:00-15:00 15:00-15:30 15:30-06:00 06:00-06:30 06:30-16:00 16:00-18:00 18:00-18:30 18:30-18:45 18:45-19:45 19:45-22:00 22:00-23:00 23:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-06:45 06:45-08:00 08:00-08:30 08:30-18:00 18:00-18:30 18:30-03:15 03:15-03:30 03:30-04:00 04:00-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-09:00 09:00-12:30 12:30-13:00 13:00-13:30 13:30-14:30 14:30-15:15 15:15-16:00 16:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-06:45 06:45-07:00 07:00-07:30 07:30-08:00 08:00-08:30 08:30-18:00 18:00-18:30 18:30-18:45 18:45-19:00 19:00-19:30 19:30-20:00 20:00-06:00 06:00-06:30 06:30-06:45 3hr 1/2 hr 14-1/2 hr 1/2 hr 9-1/2 hr 2hr 1/2 hr 1/4 hr lhr 2-1/4 hr lhr 5hr lhr lhr 1/2hr 1/4 hr 1-1/4 hr 1/2 hr 9-1/2 hr 1/2 hr 8-3/4 hr 1/4hr 1/2hr lhr 1/2 hr 1/2 hr 1/2 hr lhr lhr 1/2 hr 3-1/2 hr 1/2 hr 1/2hr lhr 3/4 hr 3/4 hr 2hr 1/2 hr 11-1/2 hr 1/2hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 1/2hr 9-1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/2hr 1/2 hr 10hr 1/2 hr 1/4 hr Rigged down Drillfloor / Derrick Held safety meeting Rig moved 100.00 % Held safety meeting Rigged up Divertor Made up BHA no. 1 Held safety meeting Held drill (Kick while drilling) Made up BHA no. 1 Drilled to 286.00 fl Made up BHA no. 1 Drilled to 660.00 ft Pulled out of hole to 256.87 ft Pulled BHA Held safety meeting Held drill (Kick while tripping) Made up BHA no. 2 R.I.H. to 660.00 ft Drilled to 1365.00 ft Held safety meeting Drilled to 2503.00 ft Held drill (H2S) Circulated at 2503.00 ft Pulled out of hole to 1177.00 ft Backreamed to 901.00 ft Pulled out of hole to 265.00 ft Held safety meeting Pulled BHA Made up BHA no. 3 R.I.H. to 721.00 ft Reamed to 721.00 ft Took MWD survey at 1177.00 ft Pulled out of hole to 265.00 fl Pulled BHA Made up BHA no. 4 R.I.H. to 1177.00 fl Drilled to 1273.00 ft Held safety meeting Drilled to 2408.00 ft Held safety meeting Held drill (Kick while drilling) Drilled to 2503.00 fl Circulated at 2503.00 ft Pulled out of hole to 1150.00 ft R.I.H. to 2503.00 fl Drilled to 3824.00 ft Held safety meeting Held drill (Fire) Circulated at 3824.00 ft Pulled out of hole to 2500.00 ft R.I.H. to 3824.00 fl Drilled to 4995.00 ft Held safety meeting Held drill (H2S) 1 27 August 97 Facility Date/Time 12 Aug 96 13 Aug 96 M Pt F Pad Progress Report Well MPF-21 Rig Nabors 22E Page Date Duration Activity 06:45-08:00 08:00-08:30 08:30-10:00 10:00-12:00 12:00-14:00 14:00-14:30 14:30-18:00 18:00-18:30 18:30-20:30 20:30-21:00 21:00-22:15 22:15-22:30 22:30-05:00 05:00-06:00 06:00-06:30 06:30-06:45 06:45-08:00 08:00-08:15 08:15-08:30 08:30-09:30 09:30-10:15 10:15-10:30 10:30-11:00 11:00-11:30 11:30-15:00 15:00-16:00 16:00-18:00 18:00-18:30 18:30-18:45 18:45-21:30 21:30-22:00 22:00-04:00 04:00-06:00 6-1/2 hr lhr 1/2hr 1/4 hr 1-1/4 hr 1/4 hr 1/4 hr lhr 3/4 hr 1/4hr 1/2hr 1/2hr 3-1/2 hr lhr 2hr 1/2hr 1/4 hr 2-3/4 hr 1/2hr 6hr 2hr Circulated at 4995.00 ft Flow check Pulled out of hole to 700.00 ft R.I.H. to 4995.00 ft Circulated at 4995.00 ft Took EMS survey at 4995.00 ft Laid down 3912.00 ft of 5in OD drill pipe Held safety meeting Pulled BHA Serviced Drillfloor / Derrick Rigged up Casing handling equipment Held safety meeting Ran Casing to 4970.00 ft (9-5/8in OD) Circulated at 4970.00 ft Held safety meeting Held drill (Fire) Circulated at 4969.00 ft Pumped 75.000 bbl spacers - volume (null) Tested High pressure lines Mixed and pumped slurry - 321.000 bbl Mixed and pumped slurry - 205.000 bbl Displaced slurry - 363.000 bbl Tested Casing Rigged down High pressure lines Rigged down Casing handling equipment Rigged up Rigging equipment Conducted electric cable operations Held safety meeting Held drill (Spill) Conducted electric cable operations Rigged down Logging/braided cable equipment Rigged down Divertor Rigged down Drillfloor / Derrick 2 27 August 97 SR,ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION (ALASKA), MILNE POINT / MPF-21 500292269400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 5/96 INC. DATE OF SURVEY: 081196 MWD SURVEY JOB NUMBER: AK-MM-60103 KELLY BUSHING ELEV. = 40.90 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DGMN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -40.90 149.18 149.18 108.28 201.95 201.95 161.05 262.61 262.60 221.70 324.07 324.05 283.15 0 0 0 12 0 27 0 45 1 51 N .00 E .00 .00N .00E S 68.74 E .13 .09S .24E S 51.99 E .50 .26S .49E S 33.97 E .59 .74S .90E S 26.36 E 1.79 1.96S 1.57E .00 .20 .46 1.08 2.47 354.03 353.99 313.09 420.64 420.48 379.58 444.00 443.78 402.88 534.62 534.06 493.16 565.69 564.98 524.08 24 0 19 34 5O S 26.24 E 1.87 2.96S 2.07E S 22.16 E 2.41 6.37S 3.56E S 23.15 E 1.44 7.93S 4.22E S 22.47 E 1.37 15.14S 7.24E S 21.80 E .92 18.01S 8.41E 3.59 7.30 8.98 16.77 19.84 578.82 578.04 537.14 624.08 623.04 582.14 656.40 655.12 614.22 686.42 684.81 643.91 715.75 713.67 672.77 5 53 S 20.84 E .80 19.26S 8.89E 6 25 S 22.22 E 1.22 23.77S 10.68E 7 26 S 24.22 E 3.27 27.35S 12.22E 9 18 S 26.92 E 6.30 31.29S 14.12E 11 16 S 27.18 E 6.75 35.96S 16.50E 21.17 25.99 29.88 34.25 39.48 748.60 745.78 704.88 807.31 802.69 761.79 897.92 889.43 848.53 986.40 971.60 930.70 1082.23 1056.33 1015.43 13 0 15 19 18 16 25 5 30 30 S 27.12 E 5.24 42.10S 19.65E S 27.44 E 3.97 54.87S 26.24E S 32.00 E -3.56 77.56S 39.29E S 32.29 E 7.70 105.22S 56.69E S 31.55 E 5.67 143.15S 80.29E 46.39 60.75 86.92 119.51 164.10 1176.52 1137.12 1096.22 1272.16 1217.54 1176.64 1367.53 1295.79 1254.89 1460.54 1369.81 1328.91 1556.38 1442.27 1401.37 31 34 33 55 35 47 38 43 43 0 S 29.68 E 1.53 185.00S 105.04E S 27.66 E 2.71 230.40S 129.83E S 26.29 E 2.12 278.98S 154.54E S 25.45 E 3.21 329.65S 179.09E S 25.65 E 4.46 386.21S 206.14E 212.68 264.41 318.90 375.15 437.78 1650.91 1508.76 1467.86 1746.23 1573.17 1532.27 1841.83 1636.48 1595.58 1935.96 1694.42 1653.52 2031.21 1746.65 1705.75 47 34 47 23 49 39 54 20 59 7 S 26.97 E 4.95 446.40S 235.93E S 27.59 E .52 508.84S 268.13E S 27.01 E 2.41 572.48S 300.97E S 26.23 E 5.04 638.78S 334.18E S 26.24 E 5.01 710.19S 369.38E 504.90 575.15 646.75 720.87 800.44 2126.12 1792.70 1751.80 2221.54 1835.60 1794.70 2314.57 1876.11 1835.21 2410.84 1916.29 1875.39 2501.58 1955.64 1914.74 62 49 63 44 64 38 66 0 62 35 S 26.80 E 3.93 784.43S 406.43E S 28.79 E 2.10 859.81S 446.17E S 27.92 E 1.28 933.51S 485.94E S 29.08 E 1.80 1010.38S 527.69E S 27.94 E 3.94 1082.21S 566.72E 883.38 968.59 1052.33 1139.80 1221.55 ORIGINAL S.~ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 BP EXPLORATION (ALASKA), INC. MILNE POINT / MPF-21 500292269400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 5/96 DATE OF SURVEY: 081196 MWD SURVEY JOB NUMBER: AK-MM-60103 KELLY BUSHING ELEV. = 40.90 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 2598.95 2000.61 1959.71 62 23 2691.63 2043.06 2002.16 63 5 2785.67 2083.43 2042.53 66 2 2880.20 2121.07 2080.17 67 1 2971.15 2156.91 2116.01 66 33 S 27.73 E .28 1158.57S 607.04E 1307.91 S 27.00 E 1.04 1231.74S 644.91E 1390.28 S 27.54 E 3.17 1307.22S 683.82E 1475.19 S 27.80 E 1.08 1384.01S 724.09E 1561.90 S 26.80 E 1.14 1458.29S 762.43E 1645.47 3070.13 2198.25 2157.35 64 3 3165.89 2242.05 2201.16 61 29 3256.20 2284.74 2243.84 62 5 3352.21 2327.48 2286.58 65 1 3445.93 2365.87 2324.97 66 35 S 26.17 E 2.59 1538.78S 802.53E 1735.36 S 26.04 E 2.69 1615.23S 840.00E 1820.44 S 25.45 E .89 1686.92S 874.57E 1899.95 S 27.62 E 3.66 1763.81S 912.99E 1985.87 S 26.52 E 1.99 1839.93S 951.88E 2071.33 3540.85 2403.20 2362.30 67 5 3635.69 2439.41 2398.51 68 0 3731.08 2475.03 2434.13 68 8 3824.31 2510.67 2469.77 66 54 3919.88 2548.41 2507.51 66 35 S 27.94 E 1.47 1917.52S 991.81E 2158.59 S 29.11 E 1.50 1994.53S 1033.67E 2246.23 S 27.62 E 1.46 2072.39S 1075.71E 2334.71 S 26.63 E 1.65 2149.05S 1114.98E 2420.83 S 27.12 E .57 2227.37S 1154.67E 2508.61 4013.97 2586.56 2545.66 65 33 4108.09 2626.644 2585.54 64 18 4202.93 2666.50 2625.60 65 43 4296.07 2703.82 2662.92 67 1 4390.89 2741.37 2700.47 66 18 S 27.15. E 1.10 2303.91S 1193.90E 2594.60 S 26.86 E 1.37 2379.86S 1232.61E 2679.83 S 27.86 E 1.79 2456.20S 1272.12E 2765.77 S 30.70 E 3.12 2530.62S 1313.85E 2851.08 S 30.05 E .99 2605.73S 1357.88E 2938.09 4485.87 2779.75 2738.85 66 1 4580.84 2818.15 2777.25 66 17 4675.65 2855.75 2814.85 66 58 4768.62 2892.65 2851.75 66 15 4859.60 2929.64 2888.74 65 46 S 29.59 E .54 2681.10S 1401.08E 3024.93 S 28.11 E 1.45 2757.18S 1442.99E 3111.78 S 29.56 E 1.58 2833.41S 1484.96E 3198.80 S 27.97 E 1.75 2908.21S 1526.03E 3284.12 S 28.43 E .71 2981.46S 1565.31E 3367.24 4905.18 2948.50 2907.60 65 19 S 29.05 E 1.57 4995.00 2985.99 2945.09 65 19 S 29.05 E .00 3017.84S 1585.26E 3408.73 3089.20S 1624.89E 3490.35 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3490.47 FEET AT SOUTH 27 DEG. 44 MIN. EAST AT MD = 4995 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 151.77 DEG. PROJECTED SURVEY AT 4,995.00' MD SPERRY-SUN DRILLING SERVICES PAGE 3 BP EXPLORATION (ALASKA), INC. MILNE POINT / MPF-21 500292269400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 5/96 DATE OF SURVEY: 081196 JOB NUMBER: AK-MM-60103 KELLY BUSHING ELEV. = 40.90 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTAi~GUL~ COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -40.90 1000.00 983.87 942.97 2000.00 1730.27 1689.37 3000.00 2168.55 2127.65 4000.00 2580.78 2539.88 .00 N .00 E .00 110.16 S 59.81 E 16.13 16.13 686.37 S 357.63 E 269.73 253.61 1481.87 S 774.29 E 831.45 561.72 2292.59 S 1188.10 E 1419.22 587.77 4995.00 2985.99 2945.09 3089.20 S 1624.89 E 2009.01 589.79 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SRERRY-SUN DRILLING SERVICES Ai~ICHORAGE AI_~A S KJ% PAGE 4 BP EXPLORATION (ALASKA), INC. MILNE POINT / MPF-21 500292269400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 5/96 DATE OF SURVEY: 081196 JOB NUMBER: AK-MM-60103 KELLY BUSHING ELEV. = 40.90 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICA.L DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -40.90 .00 N .00 E .00 40.90 40.90 .00 .00 N .00 E .00 .00 140.90 140.90 100.00 .08 S .22 E .00 .00 240.90 240.90 200.00 .50 S .74 E .00 .00 340.93 340.90 300.00 2.47 S 1.82 E .03 .03 441.11 440.90 400.00 7.73 S 4.13 E .21 .18 541.49 540.90 500.00 15.76 S 7.50 E .59 .38 642.06 640.90 600.00 25.66 S 11.46 E 1.16 .57 743.59 740.90 700.00 41.10 S 19.14 E 2.69 1.53 847.06 840.90 800.00 64.49 S 31.49 E 6.16 3.47 952.87 940.90 900.00 93.82 S 49.50 E 11.97 5.81 1064.43 1040.90 1000.00 135.59 S 75.63 E 23.53 11.55 1180.97 1140.90 1100.00 187.03 S 106.19 E 40.07 16.54 1300.31 1240.90 1200.00 244.32 S 137.12 E 59.41 19.34 1423.79 1340.90 1300.00 309.19 S 169.29 E 82.89 23.48 1554.54 1440.90 1400.00 385.09 S 205.60 E 113.64 30.74 1698.55 1540.90 1500.00 477.73 S 251.89 E 157.65 44.02 1848.72 1640.90 1600.00 577.20 S 303.37 E 207.82 50.17 2020.10 1740.90 1700.00 701.66 S 365.17 E 279.20 71.37 2233.51 1840.90 1800.00 869.22 S 451.34 E 392.61 113.42 2468.82 1940.90 1900.00 1056.42 S 552.90 E 527.92 135.31 2686.88 2040.90 2000.00 1227.97 S 642.99 E 645.98 118.06 2930.86 2140.90 2100.00 1425.31 S 745.72 E 789.96 143.98 3163.46 2240.90 2200.00 1613.31 S 839.06 E 922.56 132.60 3384.01 2340.90 2300.00 1789.36 S 926.35 E 1043.11 120.56 3639.67 2440.90 2400.00 1997.75 S 1035.46 E 1198.77 155.65 3900.98 2540.90 2500.00 2211.94 S 1146.77 E 1360.08 161.32 4141.45 2640.90 2600.00 2406.68 S 1246.19 E 1500.55 140.46 4389.71 2740.90 2700.00 2604.80 S 1357.34 E 1648.81 148.27 4637.71 2840.90 2800.00 2803.03 S 1467.76 E 1796.81 147.99 4886.94 2940.90 2900.00 3003.34 S 1577.22 E 1946.04 149.23 4920.00 2954.69 2913.79 3029.62 S 1591.80 E 1965.31 19.27 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS S~ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLOR3kTION (i~LASKA) INC MILNE POINT/MPF-21 500292669400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 5/96 DATE OF SURVEY: 081196 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60106 KELLY BUSHING ELEV. = 40.90 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DGMN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -40.90 172.95 172.95 132.05 263.81 263.80 222.90 354.67 354.60 313.70 445.53 445.27 404.37 0 0 0 21 0 56 2 41 4 30 N .00 E .00 .00N .00E S 54.41 E .21 .32S .45E S 38.99 E .65 1.07S 1.15E S 27.62 E 1.97 3.54S 2.61E S 25.04 E 1.99 8.66S 5.11E .00 .50 1.49 4.35 10.05 536.39 535.80 494.90 627.25 626.20 585.30 718.11 716.15 675.25 808.97 804.45 763.55 899.83 891.20 850.30 5 18 6 11 9 55 17 1 17 36 S 25.25 E .89 15.70S 8.41E S 22.32 E 1.03 24.04S 12.07E S 26.46 E 4.14 35.58S 17.42E S 29.97 E 7.86 54.13S 27.56E S 30.96 E .72 77.43S 41.27E 17.81 26.89 39.59 60.73 87.75 992.47 977.65 936.75 24 20 1087.00 1061.42 1020.52 30 43 1181.53 1142.58 1101.68 30 57 1276.06 1222.50 1181.60 33 35 1370.59 1300.40 1259.49 35 23 S 32.48 E 7.30 105.59S 58.75E S 31.14 E 6.79 142.74S 81.73E S 30.48 E .43 184.37S 106.56E S 27.73 E 3.19 228.49S 131.06E S 26.24 E 2.10 276.20S 155.34E 120.82 164.42 212.84 263.31 316.82 1465.12 1376.63 1335.73 37 4 1559.65 1449.92 1409.02 41 14 1654.18 1517.89 1476.99 46 46 1748.71 1582.04 1541.14 47 44 1843.24 1645.35 1604.45 48 9 S 25.99 E 1.79 326.37S 179.93E S 25.49 E 4.42 380.13S 205.84E S 27.03 E 5.96 438.97S 234.93E S 26.73 E 1.06 500.90S 266.31E S 26.81 E .44 563.57S 297.92E 372.66 432.28 497.88 567.28 637.46 1937.77 1705.25 1664.35 53 9 2032.30 1758.80 1717.90 57 48 2126.83 1805.96 1765.06 62 18 2221.36 1848.40 1807.50 64 19 2315.89 1889.65 1848.75 63 56 S 25.77 E 5.36 629.11S 330.27E S 26.44 E 4.95 699.04S 364.54E S 26.74 E 4.77 772.27S 401.21E S 27.57 E 2.26 847.40S 439.75E S 28.15 E .68 922.60S 479.50E 710.50 788.32 870.19 954.62 1039.67 2410.42 1929.51 1888.61 2504.95 1970.26 1929.36 2599.48 2013.40 1972.50 2694.01 2055.11 2014.21 2788.54 2093.82 2052.92 66 11 62 44 62 57 64 39 66 59 S 28.29 E 2.38 998.11S 520.03E S 27.54 E 3.72 1073.46S 559.96E S 27.18 E .42 1148.16S 598.62E S 27.58 E 1.85 1223.48S 637.62E S 27.31 E 2.47 1299.99S 677.36E 1125.37 1210.65 1294.75 1379.55 1465.77 2883.07 2130.37 2089.47 67 30 2977.60 2167.09 2126.19 66 46 3072.12 2206.78 2165.88 63 32 3166.66 2250.03 2209.13 62 0 3261.19 2293.37 2252.47 63 25 S 27.18 E .57 1377.50S 717.27E S 26.90 E .82 1455.08S 756.88E S 26.85 E 3.42 1531.58S 795.65E S 26.74 E 1.64 1606.61S 833.55E S 27.15 E 1.55 1681.49S 871.61E 1552.93 1640.02 1725.76 1809.79 1893.77 ORIGINAL .~.ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 BP EXPLORATION (ALASKA) INC MILNE POINT/MPF-21 500292669400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 5/96 DATE OF SURVEY: 081196 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60106 KELLY BUSHING ELEV. = 40.90 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3355.72 2333.82 2292.92 65 54 S 28.30 E 2.85 1757.11S 911.37E 3450.25 2371.94 2331.04 66 31 S 28.84 E .83 1833.07S 952.74E 3544.78 2409.00 2368.10 67 18 S 29.60 E 1.11 1908.97S 995.19E 3638.69 2444.77 2403.87 67 54 S 28.98 E .88 1984.69S 1037.67E 3733.84 2480.97 2440.07 67 21 S 29.07 E .58 2061.64S 1080.36E 1979.20 2065.70 2152.64 2239.46 2327.44 3828.37 2517.94 2477.04 66 35 S 28.26 E 1.13 2137.97S 1122.09E 3922.90 2555.54 2514.64 66 31 S 28.80 E .53 2214.17S 1163.51E 4017.43 2594.94 2554.04 64 11 S 27.91 E 2.62 2289.76S 1204.31E 4111.96 2635.64 2594.74 64 48 S 28.14 E .69 2365.08S 1244.40E 4206.49 2674.53 2633.63 66 35 S 29.84 E 2.50 2440.42S 1286.16E 2414.44 2501.16 2587.06 2672.38 2758.51 4301.02 2712.26 2671.36 66 21 S 29.30 E .58 2515.80S 1328.93E 4395.55 2750.11 2709.21 66 25 S 29.95 E .64 2591.10S 1371.74E 4490.08 2787.82 2746.92 66 33 S 30.00 E .15 2666.19S 1415.05E 4584.61 2825.12 2784.22 66 57 S 29.63 E .56 2741.55S 1458.24E 4679.14 2861.55 2820.65 67 42 S 30.10 E .91 2817.19S 1501.68E 2845.16 2931.76 3018.40 3105.22 3192.41 4773.67 2898.27 2857.37 66 34 S 29.45 E 1.35 2892.79S 1544.93E 4810.65 2913.11 2872.21 66 7 S 29.27 E 1.30 2922.32S 1561.54E 4905.18 2951.83 2910.93 65 30 S 29.53 E .70 2997.44S 1603.87E 5048.00 3011.03 2970.13 65 30 S 29.53 E .00 3110.53S 1667.94E 3279.48 3313.35 3399.56 3529.50 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3529.50 FEET AT SOUTH 28 DEG. 12 MIN. EAST AT MD = 5048 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 151.77 DEG. PROJECTED SURVEY AT 5,048.00' MD PAGE 3 S~ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION (ALASKA) INC MILNE POINT/MPF-21 500292669400 NORTH SLOPE BOROUGH COMPUTATION DATE:. 9/ 5/96 DATE OF SURVEY: 081196 JOB NUMBER: AK-EI-60106 KELLY BUSHING ELEV. = 40.90 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORT~t/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -40.90 .00 N .00 E .00 1000.00 984.49 943.59 108.24 S 60.43 E 15.51 15.51 2000.00 1741.21 1700.31 674.75 S 352.53 E 258.79 243.28 3000.00 2176.06 2135.16 1473.38 S 766.17 E 823.94 565.16 4000.00 2587.35 2546.45 2275.90 S 1196.97 E 1412.65 588.70 5000.00 2991.14 2950.24 3072.52 S 1646.40 E 2008.86 596.22 5048.00 3011.03 2970.13 3110.53 S 1667.94 E 2036.97 28.10 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S~-ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 BP EXPLORATION (ALASKA) INC MILNE POINT/MPF-21 500292669400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 5/96 DATE OF SURVEY: 081196 JOB NUMBER: AK-EI-60106 KELLY BUSHING ELEV. = 40.90 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -40.90 .00 N .00 E .00 40.90 40.90 .00 .00 N .00 E .00 .00 140.90 140.90 100.00 .20 S .28 E .00 .00 240.91 240.90 200.00 .78 S .92 E .01 .01 340.95 340.90 300.00 2.97 S 2.31 E .05 .04 441.14 440.90 400.00 8.35 S 4.96 E .24 .19 541.51 540.90 500.00 16.12 S 8.61 E .61 .37 642.05 640.90 600.00 25.59 S 12.73 E 1.15 .54 743.33 740.90 700.00 39.86 S 19.62 E 2.43 1.28 847.09 840.90 800.00 63.81 S 33.15 E 6.19 3.77 952.60 940.90 900.00 92.51 S 50.52 E 11.70 5.51 1063.34 1040.90 1000.00 132.68 S 75.61 E 22.44 10.74 1179.57 1140.90 1100.00 183.50 S 106.04 E 38.67 16.23 1298.15 1240.90 1200.00 239.31 S 136.75 E 57.25 18.58 1420.33 1340.90 1300.00 302.09 S 168.10 E 79.43 22.18 1547.74 1440.90 1400.00 373.10 S 202.49 E 106.84 27.41 1687.78 1540.90 1500.00 460.78 S 246.05 E 146.88 40.04 1836.57 1640.90 1600.00 559.13 S 295.68 E 195.67 48.79 1999.44 1740.90 1700.00 674.34 S 352.32 E 258.54 62.88 2204.05 1840.90 1800.00 833.58 S 432.53 E 363.15 104.61 2438.06 1940.90 1900.00 1020.31 S 531.92 E 497.16 134.01 2660.80 2040.90 2000.00 1196.87 S 623.72 E 619.90 122.74 2910.59 2140.90 2100.00 1400.12 S 728.89 E 769.69 149.80 3147.21 2240.90 2200.00 1591.27 S 825.82 E 906.31 136.61 3373.07 2340.90 2300.00 1771.05 S 918.88 E 1032.17 125.86 3628.41 2440.90 2400.00 1976.36 S 1033.05 E 1187.51 155.34 3886.14 2540.90 2500.00 2184.63 S 1147.27 E 1345.24 157.74 4124.31 2640.90 2600.00 2374.93 S 1249.68 E 1483.41 138.17 4372.52 2740.90 2700.00 2572.81 S 1361.21 E 1631.62 148.21 4624.98 2840.90 2800.00 2773.84 S 1476.63 E 1784.08 152.46 4878.81 2940.90 2900.00 2976.57 S 1592.04 E 1937.91 153.83 5048.00 3011.03 2970.13 3110.53 S 1667.94 E 2036.97 99.05 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEkREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS CI FI I I_1... I I~ G WELL LOG TRANSMITF~ To: State of Alaska April 2, 1997 Alaska Oil and Gas Conservation Comm. _~ Atm.: Lori Taylor 3001 Porcupine Dr. ~(0 / A~ Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPF-21 RE: AK-MM-60103 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22694-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I::t i Ll--I I~ G WELL LOG TRANSMITTAL To: State of Alaska February 26, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPF-21, AK-MM-60103 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention oft Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ICG, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22694-00 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22694-00 1 Blueline l Rev. Folded Sepia l Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc, Company ~-"~J ~ [!1 ail e[~ [=] -J GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO, 10814 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 2/21/97 Well Job # Log Description Date BL RF Sepia LIS Tape M P F-21 ULTRASONIC IMAGER 9 701 04 1 1 : M PF-21 GR-CCL CORRELATION 9701 05 1 1 MPF-21 , CEMENT BOND LOG 9701 04 I 1 MPF-21 TDT GRAVEL PACK LOG 9701 08 I 1 MPF-21 9 5/8" PACKER RECORD 9701 05 I 1 MPU K-33 STATIC TEMPERATURE PRESSURE 9701 29 I 1 MPU K-33 BRIDGE PLUG SET 970207 I 1 MPU K-33 GR/CCL DEPTH LOG 9701 29 1 1 MPU F-54 GPJCCL DEPTH LOG 9701 31 1 1 M P H-07 GR/CCL CORRELATION LOG 9701 21 1 1 MPK-06 PERFORATION RECORD 97011 2 I 1 MPK-06 GR-CCL PRIMARY DEPTH LOG 97011 2 1 1 MPE-17 CEMENT BOND LOG 9701 07 I 1 M P E-17 COMPLETION RECORD 9 701 27 1 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David J o.b~'T;~ DATE: Chair~...~v---'- THRU: Blair Wondzelt, ~ FILE NO: P. !. Supervisor January 4, 1997 gwghaded.doc Confidential' Yes Attachment Only _, NoX, FROM: Doug Amos, '5~,-~-3 ¢~._~ SUBJECT: Petroleum Inspector TOC Verification Nabors 4ES BPX MPU F-21 96-0135 Saturday, January 4~ 1997: I traveled to BP× MPU F-21 well to verify the top of cement in the 20"X 9 5/8" annulus. The TOC of cement was verified with a homemade 1" bailer attached to a 100' steel measUring tape. Contaminated cement was encountered at approximately 77' and solid cement was tagged at 80'. The cement was solid enough to blunt the sharpened end of the 1" bailer. When Phenolphthalein was applied to test /__ the samples properties, the sample turned a deep purple color, which indicates/~' ~F- cement. ! accepted this test and allow the rig to commence operations. SUMMARY: i verified the TOC in the 20" X 9 5/8" casing on BPX MPU F-21 well. Attachment: Cement Sample STATE OF ALASKA OIL AND GAS CONSERVATIOK )MMISSION ,.PLICATION FOR SUNDRY APPROVAL 1. Type of Request: ~ ,~ban_don -6J Suspencl [] Plugging [] Time Extension [] Perforate [] Alter uasing [] Repair Well [] Pull Tubing E-'I Variance I~ Other [] Change Approved Program ..~ Operation ..qhutdown [] Re-Enter Su.~pencled Well ~ 8t~rnule~e 2. Name of Operator BP Exploration (Alaska) lnc, iS. Type of well; [] Development [] Exploratory [] Stratigraphic [] Service 6, Datum Elevation (DF or KB) Plan RTE = 41' 7. Unit or Property Name Miine Point Unit 8, Well Number MPF-21 '-~i -Permit Number 96-1;35 10, APl Number 50-029-22694 11, Field and Pool Miine Point/Prince Creek 3, Address P.O. Box 196612, Anchorage, Alaska 99519.6612 4. Location of well at surface 1833' NSL, 2714' WEL, SEC. 6, T13N, R10E At top of productive interval N/A At effective depth N/A At total cfepth 3089' SNL, 1089' WEL, SEC, 7, T13N, R10E 12. Present well condition summary Total depth: measured 4995 feet true vertical P-986 feet Effective depth: measured N/A feet true vertical N/A feet Casing Length Slructural Conductor Surface Intermediate Production Liner Size 80' 20~ 4940' Perforation depth', measured N/A true vertical Tubing (size, grade, end measured depth) N/A Packers and SSSV (type and measured depth) Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx.) 830 sx PF 'E', 1000 ex Class 'G' OF IG NAL. N/A MD TVD 11~-' 112' 4970' 2976' 13. Attachments [] Description summery of proposal [] Detailed oP'er;ilons program [] BOP sketch 4, Estimated date for commencing operation December 31, 1996 16. If proposal was verbally approved Jack H~rtz 12/3 !/96 Name o.f_a_p_prove._r_ .......... Date,_a_p_proved Con~act Engineer Name/Number'. Bob Laule, 564.5195 15, Status of well classifications as: [] Oil [] Ga~ [] Suspended Service Prince Creek Water Source Prepared By Name/Number; Kathy Carnpoamor, E64-$ I22 17, I hereby certify that the foEegoln_g Is~true and, cprrect to the best of my knowledge Signed ...-.r'".- '''~' ' .'nrn S~Id _.. Title Senior Drilling Engineer Date i .~ ~/-~ / Commission Use Only Conditions of Approval: Notify C~'r~i~i~n so representative .rn~y ~'it~ss -- I Approval No..~' Plug int~gri~ BOP Test ~,, Location clearance ~ M~chanical Integri~ Test ~ Sub. quant form required~ p- ~ _ ~roved b~ order o~ the Commi~lon Criginal Sig~ed By Commissioner oa~e Form 10-40S Rev, 06/15/88 D~vid W. Johnston Submit In Triplicate Approved Copy Returned The objective of F-21 RWO is to thaw the outer annulus and run a bond Icg and perform remedial,cement job as required. Perforate and perform multiple single stage gravel-pack stimulations in the Prince Creek sands and complete the weJl with a Centrilift electrical submersible pump on 5-1/2" L-80 tubing as a Prince Creek water producer, _SCOPE: The Well was previously 8-13-96 suspended after the cementing of the mono bore failed to get cement returns to surface. The plug had been bumped with seawater displacement fluid and the casing tested to 3000 psi, A 20' spool with a instrument flange was installed. 1, Pre-rig; Level pad and prepare well site for rig move. 2. MIRU ND 20" flange NU wellhead. BOP and test. 1 RIH with 2-7/8' DP to 1700' Take on 140 degree water and circulate for 96 hours, 4, RU wireline make 9-5/8" gauge ring run to PBTD, RIH with combination USIT and CBT. Identify top of cement for remedial top off cement job. , PU 1" side srting and perform wellhead stabilization with Permafrost type cement. 1 RIH with 2-7/8 work string to PBTD and circulate well to clean 9,2 brine, Test casing to 3000 psi, POH, 8 RU wire line and run GR/CCL, ! Perforate lower Prince Creek, Set sub packer. Run gravel pack screen assembly, 10. 12, Gravel pack lower Prince Creek Set plug and perforate upper Prince Creek, Recover plug. Run screen and set packer, 13. Gravel pack upper Prince Creek intervel, 14. 15, Run ESP on 5-1/2" tubing with out packer, Install TWO ND BOP. NU and test tree. Pull TWO, Freeze protect well and release dg. dUK~ Jlfll',l Ut:) ' Z( f .L( I~U .MU~ MPU F-21 TOP JOB TO: A.O,G.C. FROM NABORS 4ES RAN 80' OF I" & FLUSHED WELL BORE WITH WATER & CEMENTED WITH 97--SX. PERMAFROST TYPE "E" 3'0 SURFACE. CEMENT STAYED IN PLACE NO FALL BACK. OP-.. 1-5-97 LARRY MYERS SSD-CR o~l 0 6 1997 ~aska Oil & Gas Cons, Commissior~ Ane. horage U IA Fl~ (~F ALASKA ALA$K~OIL AND GAS CONSFRVATION Gor ~ !881ON AP~ ~.~CATION FOR SUNDRY APPROVAL 1. Type of Reques~ ~ A~andon ~ ~uspena ~ Plugging ' ~ Time E~onslon ~ Pedorate ~ Al~er Casing ~ Repair We~ ~ Pull Tubing ~ Vadance ~ Other ~ Chanae Approval Proaram ~ Open,on Shutdown ~ R~-Enter Sus0ended Well ~ 81;mu~ate 2. Name of Operator BI= Exploration (Alaska) lnc, 3, Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1833' NSL, 2714' WEL, SEC. 6, T13N, R10E At top of productive intervaJ N/A At effective depth N/A At total depth 3089' SNL, 10B9' WEL, SEC. 7, T13N, Type cf well; F-; Developmen~ ~ Exploratory ,"-I StratJgraphic 121 Service 6, Datum E!evatlon (DF or KB) Plan RTE = 41' 7. Unit or Property Name Milne Poin! Unit 8, Well Number MPF-21 "9, -Permit riumber 96-135 10, APl Number 50-O29-22694 11. Field and Pool Milne Point/Prince Creek 12, Present well condition summary Total depth: measured true vertical Effective depth: measured tr~e vertical Casing Slructural Conductor Surface Intermediate Production Liner 4995 feet 2986 feet N/A feet N/A feet Length Size 80' 20' 4940' 9-~18" Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) NIA Packers and SSSV (type and measured depth) N/A Plugs (measured) Junk (measured) Cemented 250 sx Arctic~et I (Approx.) 830 sx PF 'E', 1000 sx Class 'G' ORIGINAL MD TVD 112' 112' 4970' 2976' 13. Attachments [] Description summary of proposal ~ Detailed operations progra.m ..~ BOP sketch 4. Estimated date for commencing operation December 31, 1996 16. If proposal was verbally approved Jack Had:,' Name o.f_a_p=prov_er :_ 12/31/96 Dale approved Status of well classifications as: 6~Oil t'"l Ga9 [Z] Suspended Service Prince Creek Water Source Contact Engineer Name/Number: Bob Laule, 564.$195 Prepared By Name/IVurnb~/?. Kathy Campoamor, ES4-6 f22 17. I hereby certify that the fo_~.regoln, is ~rue and cprrect to the best of my knowledge l Signed ~ms~,~ /~J __ Title Senior Drilling Engineer Date_ [~. //~o¢, , ....... /~/ Commission Use Only / / Conditions of Approval: Notify Commis~i0n so representative .m~y witness [Approval No.~' ~'~, -~.-~_ Plug integrity BOP Test 2~, Locadon clearance ~ M.echanical Integrity Test . Sub,.~quent form required.,19- /-~C"7 . _.-- ~ _ Ap_proved by order of the Commission flrirjinal Sjq~ed ~Y " Commissioner Date //-~-~' r~ Form 10-40S Rev, 06/15/88 David W..johnston Submit In Triplicate Approved Copy Returned MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston, DATE: Chairman THRU: FILE NO: Blair Wondzell, P. !. Supervisor FROM: Bobby Foster, SUBJECT: Petroleum lnsp4ctor December 9, 1996 ZW91LIDD.doc Surface Casing Cmt. BPX - MPU - F-21 PTD # 96-0135 Monday, December 9, 1996: Blair, this is the information that you requested concerning BPX's MPU well F-21. The surface hole was drilled and casing was run and cemented but no cement was circulated to surface. There are daily rig reports, cementing summary and a report concerning another log run on 8~27~96 which the log showed good "cement" to surface. My question is, wouldn't the well bore fluid show up as cement if it was freezing back or if the hole was sloughing in? It is my opinion that something should be done about the way that the oil companies get well information to the AOGCC office. The well history in the well files are not a very good source of information. It may be wise to require a daily drilling report such as the ones attached to this report be filed. They could be faxed to the North Slope office or to the Anchorage office. Summary: NONE Attachment: Daily drilling reports Cementing Summary Logging report - 8~27~96 Unclassified Confidential (Unclassified if doc. removed ) Confidential MILNE POINT, ALASKA TO: FROM: Well Name: Main Category: Sub Category: Operation Date: Hendrix/Stevens Mark O'Malley MPU F-21 Completion GR/CCL/SBT 8-27-96 Date: I 8/27/96 I OBJECTIVE: Run SBT confirm cement job to surface Marked line GR / CCL. IIwHSIP= 0psig I IAP=0psig I OAP= 0 psig I 8-27-96 0 9'0 0 MIRU HELD TAIL GATE SAFETY MEETING RIH. SBT , CCL/GR on MARKED LINE primary depth control. Tagged PBTD @ 3,579' ELMD. Start out of hole logging · Good to Excellent compression cement 1,000+ from TD to 3,100' Cement stayed constant from 3,100' to 2,400' compression of 250 + Compression dropped below 200 from 2,400' to 1,250' Cement compression picked up to a constant 200 to 300 from 1,250' to Surface. RD ATLAS 16:00 CREW: RESULTS: CEMENT LOOKED GOOD FROM PBTD TO SURFACE 9-5/8". MARKED LINE GR / CCL FROM PBTD TO SURFACE. l Diesel use: 0 MeOH use: 0 ~~~ ~ ~ ?i?!ii!~ii?!:.~:~i.:'~.~i:..-'..''~'.~.:.~-:::::/'''?-.-':~,:~.' .~..... ITEM ID OD LENGTH TOP BO'rTOM HOWCO 9-5/8" FLOAT SHOE 1.44 4968,17 4969.61 2 JT. (#1-#2) 9-5/8 47# L-80 BTC 77.48 4890:69 4968,17 HOWCO 9-5/8" FLOAT COLLAR 1,03 4889,66 4890.69 JTS(#3-#46) 9-5/8 47# L-80 BTC MOD 1779.74 3109,92' 4889,66 JTS,(#47-#75) 9-5/8 47# L-80 BTC 1178.26 1931,66 3109,92 JTS.(#76-#120) 9-518 40# L-80 BTC 1900.52 31,14 1931,66 FMC HANGER W/PUP 2,04 29,10 31,1 4 RKB 29.10 , 29,10 , , · · · · Run bow spring centralizers on its 1-15 ':. . & its 66-80 . ." · , , Run 120 its total , , · · · · · . PiPE TALLY SHEET PAGE: 1 CF 2 I WELL NUMBER: MPF-21 DATE: 8/7/96 Hole Section: SURFACE CASING J RANGF~ 3 CLASS: A I SIZE AND KIND (a): 9 5/8" 47/40# MOD BTC/BTC (b): (c): Co1.1 Col.2 Col.3 Col.4 Co1.$ Col.6 Col.7 Col.8 NO. Feet NO. Feet NO. Feet NO. Feet NO. Feet NO. Feet NO. Feet NO. Feet I 39.47 26 40.62 51 40.22 76 43.25 101 43. 87 126 X 41. 27 151 176 2 38.01 27 41.80 52 41.18 77 43.74 102 44. 46 127 X 39, 18 152 177 3 41.01 28~ 40.99 53 39.87 78 41.14 103 43. 17 128 X 41, 96 153 178 4 41.80 291 40.20 54 41.86 79 42.48 104 42. 70 129 X 41. 92 154 179 5 41.50 30 39.45 55 41.89 80 41.44 105 39. 80 130 X 41, 90 15S 180 i6 41.00 31 40.68 56 42.05 81 43.86 106 41. 04 131 156 181 7 40.86 32 40.84 57 41.91 82 42.61 107 41. 17 132 157 182 8 40.65 33 39.39 58 41.87 83 42.88 108 41. 22 133 158 183 19 38.39 34 40.68 59 41.01 84 43.24 109 41. 21 1341 159 184 I10 40.27 35 38.61 60i 41.14 85 41.75 110 41. 04 135 160 185 ill 41.00 36 40.63 61 41.10 86 42.86 111 41. 93 136 161 186 I 12 39.64 37 39.78 62i 39.78 87 43.67 112 41. 47 137 162 187 13 40.69 38 40,45 63 38.89 88 43.22 113 40. 71 138 163 188 t14 38.41 39 41,78 64 40.18 89 43.01 114 41. 78 139 164 189 15 38.46 40 40.40 65 40.53 90 44.51 115 41. 05 140 16S 190 16 40.65 41 40,68 66 41.88 91 43.74 116 41. 90 141 166 191 17 41.82 42 38.61 67 41.27 92 43.24 117 41. 49 142 167 192 18 40.60 43 40.50 68 37.59 93 43.00 118 40. 86 143 168 193 19 40.70 44 40.17 69 41.15 94 42.90 119 38. 47 144 169 194 20 40.69 45 40.67 70 40.63 95 42.35 120 37. 59 145 170 195 121 40.20 46 39.97 71 40.19 96 43.04 121 X 41, 13 146 171! 196 122 40.95 47 40.42 72 38.41 97 42.73 122~X 38. 19 147 172 197 · i23 40.66 48 39.61 73 41.65 98 43.89 1231X 41, 30 148 173 198 124 41.07 491 41.73 74 41.98 99 42.40 124 X 41. 93 149 174 199 25 41.82 50 40.32 75 37.99 100! 42.64 125 X 38, 17 150 175 200 "1 Tot 1010.32 Tot 1008.98 Tot 1016.22 Tot 1073.59 Tot 1027.65 Tot 206.23 Tot 0.00 Tot 0.00 x- 0.00 x- 0.00 x- 0.00 x- 0.00 x 200.72 x - 206.23 x- 0.00 x- 0.00 = 1010.32 = 1008.98 = 1016. 22 = 1073.59 = 826.93 = = = cum 1010.32 2019.30 3035.52 4109.11 4936.04 4936.04 4936.04 4936.04 TOTAL LENGTH THIS PAGE = EXCLUDING MARKED JOINTS = (INCLUDING JTS #1 & #2) TOTAL JOINTS THIS PAGE = LENGTH OF FS & FC JT$. = Io.oo I 5342.99 406.95 4936.04 130 77.48 DIRECTIONS: FLOAT SHOE = 1.40 FLOAT COLLAR = 1.00 L/C = NA ES CEMENTER = NA PUPJT = NA NA HANGER = 2.02 RI~ 29.10 RATHOLE = 25.39 AVERAGE JT = 41.10 lng/Liner Cementing Summary Well MPF-21 Started at 2230 On bottom at 500 Rig Date HRS 7/26/96 HRS 7/27/96 NABORS 22E 8/12/96 String wt on bottom 245 K lbs up wt. 130 K lbs down wt. CASINCdLINER SUMMARY: Size 9 5/8" Type 40# L-80 Connection: Jts BTC 120 Makeup Torque 9000 ft-lbs THREAD LOCK: on bottom 3 Jts CENTRALIZER SUMMARY: Size 9- 5/8" Type BOW SPRING Total Used 30 2/Jt on Jts - 1/Jt on Jts 1 - 15 None on Jts 66 - 80 . . INSERT FLOAT EQUIPMENT: Plug Catcher: BTM OF JT# Float Shoe: BTM OF J-i' # 1 @ ' Float Collar: TOP OF JT # 2 ~ 4649 ' 4969 ' Marker Jt: SIZE @ ' LINER HANGER AND PKR DESCRIPTION ID Hydraulic IJner Hanger Liner Top Packer Setting Sleeve Tie Back Extension: Length 13CR or L80 Manufacturer ' Manufacturer CEMENT SUMMARY Csg on bottom at Pumped spacer/sweep: from Pumped spacer/sweep: from Pumped spacer/sweep: from 500 HRS, Circulated for 2 Hrs/Min bbls of ~ PPg- to Circulated sweep at __ bpm. bbls of ~ PPg- to Circulated sweep at ~ bpm. bbls of ~ PPg- to Circulated sweep at ~ bpm. HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 9 September 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL MPF-77 DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 PDK FINAL BL+RF I SBT FINAL BL+RF ECC No. Run # 1 6479.03 Run # 1 6479.04 Run # i 6773.02 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite-201 Anchorage, AK 99518 ~~~A, 0~r FAx t° (907) 563-7803 Received by Date: Alaska Oil & Gas Cons, Commission. HOWARD OKLAND Attn. ~LLASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE A/<, 99501. Date: 22 August 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear sir/Madam, Enclosed, please find the data as described below: WELL MPK-38 MPK-17 MPK-37 MPF-21 ~-1~ MPF-21 ~))-- MPF-02 ~' $~0 DESCRIPTION k.%/PFC/PER~ FINAL BL+RF PLS FINAL BL+RF ~/PFC/PERF FINAL BL+RF I/ff/TEMP FINAL BL+RF ~SBT FINAL BL+RF GR/CCL FINAL BL+RF PFC/PERF FINAL BL+RF GR/CCL FINAL BL+RF ECC No. Run # 1 6638.03 Run ~ 1 6639.02 Run # 1 Run # 1 6729.01 Run ~ 1 6773.00 Run ~ 1 6773.01 Run # 1 Run # 1 Run $ 1 6774.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 563-7803 Received by: FA/~ to (907) AUG 30 199% Date: ,. .... ~or~ TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 2, 1996 Tim Schofield, Senior Drlg Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPF-21 BP Exploration (Alaska) Inc. Permit No. 96-135 Sur. Loc 1833'NSL, 2714'WEL, Sec. 6, T13N, R10E, UM Btmhole Loc. 3947'NSL, 1027'WEL, Sec. 7, T13N, R10E, UM Dear Mr. Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission rth Slope pager at 659-3607. David W.-Tohn~ton C hairm~% BY ORDER E COMMISSION dlf/Enclosure CC~ Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ..... STATE OF ALASKA ALASKA ~iL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepeni [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 41' Milne Point/Prince Creek 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025509 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1833' NSL, 2714' WEL, SEC. 6, T13N, R10E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 636' NSL, 2076' WEL, SEC. 6, T13N, R10E MPF-21 At total depth 9. Approximate spud date Amount $200,000.00 3947' NSL, 1027' WEL, SEC. 7, T13N, R10E 08/05/96 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025515, 1333'I No Close Approach 2533 5065' MD / 2985' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 300' Maximum Hole Angle 65.59 o Maximum surface 1024 psig, At total depth (TVD) 2985'/-roFSe psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement ~' Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 5034' 31' 31' 5065' 2985' 827 sx PF'E', 992 sx'G', 150 sx PF'E' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs(measured) ORIGINAL true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate R E C E IV E D Production Liner JUL ,~ 0 1996 Alaska 0il & g~qs Cons. Commission Perforation depth: measured An~,hor~,ge true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Robertson, 564-5159 Prepared By Name/Number Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is trlue andjcj)rrect to the best of my knowledge Signed ~ ~¢~'J~ ~//~ Tim Schofield /'U~ '--- ,~ _ Title Senior Drilling Engineer Date ~, r- Commission Use Only / Permit Number J APl Numb J Approval Date J See cover letter ~-'/,-~5 50-O~____.~:~-'' ~ 2.- ~'pd-Z<' q~_~ ..o)/,p for other requirements Conditions of Approval: Samples Required [] Yes ,.~ No Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures '~Y,,., [] No Directional Survey Required ~'Yes [] No Required Working Pressure for BOPE [] 2M; ~3M; [] SM; [] 10M; [] 15M Other: Original Signed By by order of Approved By David W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling I Well Contact: James E. Robertson Name: IMP F-21 Well Plan Summary 564-5159 IType of Well (producer or injector)- JPrince Creek SourceI Water Producer ISurface Location: Target Location: Bottom Hole Location' 1833 NSL 2714 WEL Sec 06 T13N R10E UM., AK 636 NSL 2076 WEL Sec 06 T13N R10E UM., AK 3947 NSL 1027 WEL Sec 07 T13N R10E UM., AK I AFE Number: 1337046 IEstimated Start 15AUG96 IDate' 5,065' ITVD: IWell Design (conventional, slimhole, etc .)' I Rig: I Nabors 22-E IOperating days to complete: 5 2,985' bkb IMilne Point Ultra Slimhole MONOBORE: 9-5/8", 40# CASING TO TD Formation Markers' Formation Tops MD TVD (bkb) base permafrost 2345 1861 Target 2611 1 971 T3 31 44 21 91 Prince Creek 'A' 3579 2371 Prince Creek 'B' 3942 2521 Prince Creek 'C' 4281 2661 Prince Creek 'D' 4546 2771 Total Depth 5065 2985 Casinq/Tubing ProI ram: Hol; C-sg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1 # H-40 Weld 80 32/32 11 2/11 2 12 1/4" 9-5/8" 40# L-80 btrc 5034 31/31 5065/2985 Internal yield pressure of the 9-5/8", 40# casing is 5750 psi. Worst case surface pressure would occur with a full column of gas from TD, assuming a normal pressure gradient of 8.6 ppg. Maximum anticipated surface pressure in this case would be 1024 psi, well below the internal yield pressure rating of the 9-5/8" casing. Logging Program: Open Hole Logs: Surface MWD Directional. LWD GR/RES Intermediate N/A Final N/A Cased Hole Logs: N/A Mudloggers are NOT required for this well. RECEIVED Mud Program- Ispecial design INOne'SPUD MUD I considerations Surface Mud Properties' I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 1 00 1 5 8 1 0 9 8 to to to to to to to 9.0 50 35 1 5 30 1 0 1 5 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss N/A N/A N/A N/A N/A N/A N/A to to to to to to to N/A N/A N/A N/A N/A N/A N/A Well Control- Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional' I KOP: I 00' IMaximum Hole Angle: Close Approach Well: Disposal' 65.59° (No Shut Ins) Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. 1. The base of the Permafrost for all wells located in the Milne Point Unit is _+1,850' TVD. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 2. There are +25 wells on Milne Pt. 'F' Pad. There may be additional unidentified wells within one quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 3. The wastes to be disposed of during drilling operations can be defined as "DRILLING WASTES". 4. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. MP F-21 , . . . . . . Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface/production hole as per directional plan. Run Directional MWD from surface to TD and run Gamma Ray/Res LWD from surface to TD. Run and cement 9-5/8" casing. Test casing to 3000 psig. 8. ND diverter, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. DRILLING HAZARDS AND RISKS: See both the updated Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for information on the No Point#1 (F-46), and review recent wells drilled on F Pad. Most of the trouble time on recent wells has been due to equipment mechanical problems with the surface equipment, rather than formation drilling problems. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. Close Approach: There are no close approaches associated with the drilling of MP F-21. Lost Circulation: There has not been any appreciable amount of lost circulation in surface hole on any of the F Pad wellls to date. Stuck Pipe Potential: Well MPF-53 was stuck coming out on the short trip at surface casing point. Proir to this incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed. Subsequent fishing operations were not successful and a very expensive BHA was lost in the hole from 2516 - 3342. Formation Pressure: The maximum expected pore pressure for this well is 8.6 ppg EMW (1335 psi @ 2985' TVD). There has been no injection in this region, therefore the reservoir pressure should not exceed this estimate. CASING SIZE: MP F-21 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON 9-5/8" CIRC. TEMP 60 deg F at 2840' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder + CELLO-FLAKES WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER' 11.63 gal/sk APPROX NO SACKS: 827 THICKENING TIME: Greater than 4 hrs at 50° F. LEAD CEMENT: ANUULAR VOLUME FROM TOP OF TAIL CEMENT TO BASE OF PERMAFROST + 30% EXCESS, AND ANNULAR VOLUME FROM BASE OF PERMAFROST TO SURFACE + 175% EXCESS TAIL CEMENT TYPE: Premium G ADDITIVES: WEIGHT: APPROX #SACKS: 0.2% CFR-3,0.2% HALAD-344, 2.0% CaCI2 + CELLO-FLAKES 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 992 THICKENING TIME: Greater than 4 hrs at 50° F. FLUID LOSS: 100-150 cc FREEWATER: 0 TAIL CEMENT FROM TD TO 100' TVD ABOVE TOP OF PRINCE CREEK WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE' WELLHEAD STABILITY CEMENT WILL BE PUMPED IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 65 joints of casing (65 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover from TD to 100' TVD above the top of the Schrader Bluff Formation. 2. The Lead Slurry volume is anuular volume from top of tail cement to base of permafrost + 30% excess, and annular volume from base of permafrost to surface + 175% excess. 3. 80'md 9-5/8", 40# capacity for float joints. 4. Wellhead stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the wellhead. Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 Well ......... : MPF-21(P1) Field ........ : MILNE POINT, FPAD Computation..: Minimum Curvature Units ........ : FEET Surface Lat..: 70.50731670 N Surface Long.: 149.65759541 W Legal Description Surface ...... : 1833 FSL 2714 FEL S06 T13N R10E UM TARGET ....... : 636 FSL 2076 FEL 'S06 T13N R10E UM BHL .......... : 3947 FSL 1027 FEL S07 T13N R10E UM :, DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord 541850.72 6035285,18 542500.00 6034092.00 543567.97 6032129.38 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONL -_ PLAN Prepared ..... : 07/19/S6 Vert sect az.: 151.77 KB elevation.: 41.30 ft Magnetic Dcln: +27.935 Scale Factor.: 0.99990199 Conv~r~.nce..: +0.32277979 STATION ~ INCI..~I IDENTIFICATION DEPTH ANGLE KB 0 0.00 KOP/BUILD 3.5/100 300 0.00 400 3.50 500 7.00 600 10,50 DIRECTION VERT'DEPTHS SECT COORDINATES-FROM STATE-PLANE TOOL DL/ AZIMUTH TVD SUB-S DIST WELLIiEAD X Y FACE 100 0,00 0 -41 0 0.00 N 0,00 E 541850.72 6035285,18 0.00 0.00 300 259 -0 0,00 N 0,00 E 541850.72 6035285.18 0.00 151.77 400 359 3 2,69 S 1.44 E 541852.18 6035282.50 HS 3.50 151.77 500 458 12 10.75 S 5.77 E 541856.55 6035274.46 HS 3.50 151.77 598 557 27 24.15 S 12.97 E 541863.82 6035261.10 HS 3.50 700 14.00 800 17.50 900 21.00 1000 24.50 1100 28.00 151.77 696 655 49 42.84 S 151.77 792 751 76 66.75 S 151.77 887 845 109 95.80 S 151.77 979 938 147 129.86 S 151.77 1069 1027 192 168,82 S 23.00 E 541873.96 6035242.47 HS 3.50 35,84 E 541886.93 6035218.64 HS 3.50 51.43 E 541902.69 6035189.68 HS 3.50 69.72 E 541921.16 6035155.72 HS 3.50 90.64 E 541942.30 6035116.89 HS 3.50 1200 31.50 1300 35.00 151,77 1155 1114 241 212.54 S 151.77 1239 1198 296 260.84 S 114.11 E 541966.01 6035073,31 HS 3,50 140.04 E 541992.21 6035025,16 HS 3,50 (lnadrill (c) 96 F21P1 3.0b.03 10:55 AM P) MPF-21 (Pl) STATION IDENTIFICATION ~NO 3. S/lO0 BOILO BASE PERMAFROST MEAS DEPTH 1400 1500 1600 1700 1800 1900 2000 2100 2174 2345 INCLN ANGLE 38.50 42.00 45,5O 49,00 52,50 56.00 59.50 63.00 65.59 65.59 TARGET 2611 65.59 T-3 3144 65.59 UNIT A PRINCE CREEK 3579 65.59 UNIT B PRINCE CREEK 3942 65.59 UNIT C PRINCE.CREEK 4281 65.59 UNIT D PRINCE CREEK 4547 65.59 BASE UNIT D 4765 65.59 9-5/8" CASING pOINT 5065 65.59 TI) 5065 65.59 DIRECTION AZIMUTH 151,77 151.77 151.77 151.77 151.77 PROPOSED WELL PROFILE VERT-DEPTHS SECT TVD SUB-S DIST 1319 1278 356 1395 1354 420 1468 1426 490 1535 1494 563 1599 1557 640 151.77 1657 1616 722 151.77 1711 1669 806 151.77 1759 1717 894 151.77 1791 1749 961 151.77 1861 1820 1116 151.77 1971 1930 1359 151.77 2191 2150 1843 151.77 2371. 2330 2240 151.77 2521 2480 2571 151.77 2661 2620 2879 151.77 2771 2730 3122 151.77 2861 2820 3320 151.77 2985 2944 3593 151.77 2985 2944 3593 COORDINATES-FROM WELLHEAD 313.54 S "168.34 E 370.46 S 198.89 E 431.38 S 231.60 E 496.07 S 266.33 E 564.28 S 302.95 E 635.78 S 341.34 710.28 S 381.33 787.51 S 422.80 846.33 S 454.38 983.35 S 527.94 1196.94 S 642.61 1624.11 S 871.95 1973.61 S 1059.59 2264.86 S 1215.96 2536.70 S 1361.90 2750.28 S 1476.57 2925.03 S 1570.39 3165.73 S 1699.62 3165.73 S 1699.62 07/19/96 Page 2 STATE-PLANE X Y TOOL DL/ FACE 100 HS 3.50 HS 3.50 HS 3.50 HS 3.50 HS 3.50 542020.80 6034972.62 542051.68 6034915.88 542084.72 6034855.15 542119.81 6034790.67 542156.82 6034722.67 542195.60 6034651.40 HS 3.50 542236.01 6034577.13 HS 3.50 542277.91 6034500.14 HS 3.50 542309.81 6034441.50 3.50 542384,14 6034304,92 0.00 542500.00 6034092.00 0.00 542731.72 6033666.17 0.00 542921.31 6033317.76 0.00 543079.30 6033027.43 0.00 543226.76 6032756.44 0.00 543342.62 6032543.53 0.00 543437.41 6032369.33 0.00 543567.97 6032129,38 0.00 543567.97 6032129.38 0.00 , , ANADRILL AKA-DPC APPROVED FOR PERMITTING PLAN (Anadrtll (c)96 F21P1 3.0b.03 10:55 AM PI Jul-22-96 09:34 Anadrill DPC 907 344 2160 P. 04 · i m m mi i Marker IUentification ME) BKB SECTN INCLN A) KB 0 0 0 0.00 B) KOP/BUILD 3.5/1D0 300 300 -0 0.00 C) END 3.5/100 BUILD 2174 t79! get 65.59 O) TARGET 2615 $97! $359 65.59 E) 9-5/B' CASING POINT 5065 ~9B5 3593 65.59 F) TO 5065 2985 3593 65.59 SI-:.[ARED SERV z cEs DR'I' L'L Z NG m mi i MPF-21 (P1) VERTICAL SECTION VIEW Section at: t51.77 , TVD Scale.' ~ inch = 600 feet Dep Scale · I inch = 600 feet iOrawn ..... : 07/19/96 , nadrjY'Y,.SchYu~'berger )- ~ - ANA,'""' AKA-£ PC ...,.~ APPRC)VED · ~:~ p~=RklITTING ) .... '~ m --,--,~ -' -!l ' " -.~¢ ...... ,- -~,~. ~_.__ ........ 't-'a' "'bi'bt' ..... ~'' ,~ 9 r ~e m mi', ...... '.--~- ~- - ','' '-~ : . ~.: ......... _'~,'~..- ... - .............. · ~qll'~-~ ~-~ - s~] .......................... ~_~u~t r ~ ~ · ~ ' ! ~1 .... ~ ............ '~t~g ~' ~f~ .......................... ~ ~ ~B 1 ' ~ ~ ..................... , . ~ m ..... 0 300 600 go0 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 Sect ion Departure (~aori]] (c)g6 F2iP! 3.00.03 ]0:59 AN P] ' ' ' Jul-22-96 09:35 Anadrill DPC 907 344 2160 P.05 SHARED SERVICES DRILLING Marker Identification MD N/S A) KB 0 0 N B) KOP/BUILD 3.5/100 300 0 N C) END 3.5/100 BUILD 2174 846 S D) TARGET 26ti li97 S E) 9-5/8' CASING'POINT 5065 3t66 S F) TD 5065 3166 S · i i i MPF-2 (P 643 [ t700 E 1700 E i PLAN VIE~ CLOSURE ..... : 3593 feet at Azimuth 151.77 DECLINATION.: +27.935 (E) SCALE .......: ! inch = 500 feet DRAWN .......: 07/19/g6 i Anadri ]l Schlumberger' i O- - - ~--"-------------- k ANADRILL )VE~ ..... .. .~ PPR( m 0 ....... ~ -- ~UK r~t~, .... l~ r~~ ~ ' - 3--O : ~ ~~TA ,~(lius E~O feet ) , ~' ~ ' , _ RECEI /ED ,, , ~ JU ~ 3 0 996 Ala ',k,~ Oil & ~as Cons, Cemmls~ . ~ ~t,~. .. ~ ~[ ' I 0 ~50 500 750 t000 t~0 t500 1750 2000 aa~ ~00 27~ 3000 3250 <- WEST · EAST -> (im)~il] {c)96 F2IPi 3.00.03 ii:02 AN P} ' ,, · WELL PERMIT CHECKLIST COMPANY//~ FIELD & POOL ~'-2_ ,_~' /3 ~ INIT CLASS ~..,~?' ADMINISTRATION WELL NAME/~~ ,~ f~,,,-,,-~_./,-'/:,.../ GEOL AREA 1. Permit fee attached ...................... 2. Lease number appropriate .................. 3. Unique well name and number ................ 4. Well located in a defined pool ................. 5. Well located proper distance from ddg unit boundary .... 6; Well located proper dislance from other wells ........ 7. Sufficient acreage available in drilling unit. ......... 8. If deviated, is weilbore plat included ............. 9. Operator only affected party .................. 10. Operator has appropriate bond in force ........... 11. Permit can be issued without conservation order ..... 12. Permit can be issued without administrative approval... 13. Can permit be approved before 15-day wait. ........ ENGINEERING 14. Conductor string provided .................. 15. Surface casing protects all known USDWs ~.'f~N 16. CUT vol adequate to circulate on conductor ~'s~r~ ~ '. '. '. N 17. CMT vol adequate to tie-in long s~ng to surf csg ....... 18. CMT will cover all known productive horizons ......... 19. Casing designs adequate for C, T, B & permafrost ..... ~) N 20. Adequate tankage or reserve pit ................ N 21. If a re-drill, has a 10-403 for abndnmnt been approved... Y 22. Adequate wellbore separation proposed ........... .~ N 23. If diverter required, is it adequate ................ ~ N 24. Ddlling fluid program schematic & equip list adequate .... .,~ 25. BOPEs adequate ........................ APPR ~D ./~c7(~ 26. BOPE press rating adequate; test to psig. ~ N ~i~-'~ 27. Choke manifold complies w/APl RP-53 (May84) ...... ~-~N 28. Work will occur without opem~on shutdown .......... 29. Is presence of H2S gas probable .............. ~.L.Y~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N~ z~ ,/~ 31. Data presented on potential overpressure zones ....... .Y. ~ ~ ~'./7~,./ , 32. Seismic analysis of shallow gas zones ............. _~_ .N ' 33. Seabed condition survey (if off-shore) ........... ./Z'. Y N 34. Contact name/phone for weekly progress, mpo~......~,,d... Y N lexpmmrory omyj APPR D~TE~ PROGRAM: exp [] dev [] reddl [] sew~l~ wellbore seg [] ann. disposal para req [] ~?'~"~ UNIT# ~/x'/~.~ ? ON/OFF SHORE C::~p..) REMARKS GEOLOGY: ENGINEERING: COMMISSION: RP~ BEW~7'/';~, DWJ~~--~-- JDH ~ JDN TAB~ .. Comments/Instructions: HOW/lib - A.-%cOR~list rev 4/96 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-bun Drilling Services LIS Scan Utility Fri Mar 28 12:12:50 1997 Reel Header Service name ............. LISTPE Date ..................... 97/03/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/03/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LI~~ting Services ~ ~%% ~D/MAD LOGSo,%e~/ WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-60103 M. HANIK J. CARLILE 1ST STRING Library. Scientific Technical R :CE!VED MWD RUN 2 AK-MM-60103 M. HANIK J. CARLILE MWD RUN 3 AK-MM-60103 M. HANIK J. CARLILE 6 13N 10E 1833 2714 .00 40.90 11.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2ND STRING 3.RD STRING PRODUCTION STRING 12.250 REMARKS: 20. 000 112.0 4995.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. THE WELL WAS INADVERTENTLY SIDETRACKED ON MWD RUN 3 WHICH RESULTED IN REDRILLING APPROXIMATELY 1500 FEET. DATA WAS MERGED AT l178'MD, l138'TVD. 4. MWD RUNS 1 THROUGH 3 ARE DIRECTIONAL, DUAL GAMMA RAY (DGR), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DAVID DOUGLAS FOR LARY VENDAL OF BP ON 11/21/96. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4995'MD, 2986'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .500O DEPTH INCREMENT: FILE SU74MARY PBU TOOL CODE RPD RPM RPS RPX GR FET ROP $ START DEPTH STOP DEPTH 41.5 4922.5 41.5 4922.5 41.5 4922.5 41.5 4922.5 50.0 4930.0 105.0 4922.5 105.5 4995.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $, MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 105.0 661.0 2 661.0 1178.0 3 1178.0 4995.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean DEPT 41.5 4995 2518.25 ROP 20.7308 1856.33 240.156 GR 13.2216 98.0778 51.3315 RPX 0.1037 2000 15.2641 RPS 0.0596 2000 20.8408 RPM 0.095 2000 29.5205 RPD 0.05 2000 38.465 FET 0.1303 6.3031 0.800418 Ns am 9908 9780 9761 9763 9763 9763 9763 9636 First Reading 41.5 105.5 50 41.5 41.5 41.5 41.5 105 Last Reading 4995 4995 4930 4922.5 4922.5 4922.5 4922.5 4922.5 First Reading For Entire File .......... 41.5 Last Reading For Entire File ........... 4995 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD 41.5 RPM 41.5 RPS 41.5 RPX 41.5 GR 50.0 FET 105.0 ROP 105.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 597 0 597 0 597 0 597 0 605 0 597 0 660.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE A2~D CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPEP~ATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 08 -AUG- 96 ISC 4.54 MWD 5.46 MEMORY 661.0 105.0 661.0 .0 5.9 TOOL NUMBER P0567CRG8 P0567CRG8 12.250 12.3 SPUD 8.60 90.0 10.0 1700 17.0 1.600 1.450 20.6 MUD FILTRATE ~-£ MT: P~UD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 1.600 2.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OH~M 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 FET MWD 1 HOUR 4 1 68 24 7 ROP MWD 1 FT/H 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 41.5 660.5 351 1239 41.5 GR 13.2216 67.6969 38.3581 1111 50 RPX 1.2134 2000 35.829 1112 41.5 RPS 0.9874 2000 46.4774 1112 41.5 RPM 1.158 2000 61.8113 1112 41.5 RPD 1.2633 2000 103.568 1112 41.5 FET 0.3003 2.1048 0.874273 985 105 ROP 20.7308 553.25 146.66 1111 105.5 Last Reading 660.5 605 597 597 597 597 597 660.5 First Reading For Entire File .......... 41.5 Last Reading For Entire File ........... 660.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 589.0 1178.0 RPD 589.0 1178.0 RPM 589.0 1178.0 RPS 589.0 1178.0 RPX 589.0 1178.0 GR 597.5 1178.0 ROP 662.0 1178.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMYJk RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OPRVR~) AT TE~4PERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 09-AUG-96 ISC 4.54 MWD 5.46 MEMORY 1178.0 661.0 1178.0 9.3 64.7 TOOL NUMBER P0567CRG8 P0567CRG8 12.250 12.3 SPUD 9.00 70.0 9.0 2200 15.0 1. 600 MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ............ Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 1.220 1.600 2.500 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 2 AAPI 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 28.4 Name Min Max Mean DEPT 589 1178 883.5 GR 13.8908 86.5997 48.3535 RPX 1.0544 13.7563 3.3909 RPS 1.1554 29.2009 4.76848 RPM 1.1761 52.9522 6.08431 RPD 1.3096 56.9384 6.62457 ROP 31.6483 459.016 171.798 FET 0.4295 6.3031 1.51387 Ns am 1179 1162 1179 1179 1179 1179 1033 1179 First Reading 589 597.5 589 589 589 589 662 589 Last Reading 1178 1178 1178 1178 1178 1178 1178 1178 First Reading For Entire File .......... 589 Last Reading For Entire File ........... 1178 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 1106.5 4922.5 RPM 1106.5 4922.5 RPS 1106.5 4922.5 RPX 1106.5 4922.5 GR 1114.5 4930.0 FET 1178.5 4922.5 ROP 1179.5 4995.0 $ LOG HEADER DATA DATE LOGGED: il-AUG-96 SOFTWARE SURFACE SOFTWARE VERSION: ISC 4.54 DOWNHOLE SOFTWARE VERSION: MWD 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 4995.0 TOP LOG INTERVAL (FT): 1178.0 BOTTOM LOG INTERVAL (FT): 4995.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 30.5 MAXIMUM ANGLE: 68.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0567CRG8 EWR4 ELECTROMAG. RESIS. 4 P0567CRG8 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 12.3 BOREHOLE CONDITIONS MUD TYPE: SPUD MUD DENSITY (LB/G) : 9.40 MUD VISCOSITY (S): 65.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 1000 FLUID LOSS (C3) : 5.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURSD TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction .................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 2.800 2.410 2.800 4.200 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MWD 3 OH/~4 4 1 68 12 4 RPM MWD 3 OHMM 4 1 68 16 5 RPD MWD 3 OHM~ 4 1 68 20 6 ROP MWD 3 FT/H 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 26.7 First Name Min Max Mean Nsam Reading DEPT 1106.5 4995 3050.75 7778 1106.5 GR 15.4458 98.0778 53.7123 7632 1114.5 RPX 0.1037 51.045 13.8597 7633 1106.5 RPS 0.0596 106.09 19.263 7633 1106.5 RPM 0.095 2000 27.9637 7633 1106.5 RPD 0.05 2000 33.2493 7633 1106.5 ROP 30.3164 1856.33 263.087 7632 1179.5 FET 0.1303 3.2771 0.690655 7489 1178.5 Last Reading 4995 4930 4922.5 4922.5 4922.5 4922.5 4995 4922.5 First Reading For Entire File .......... 1106.5 Last Reading For Entire File ........... 4995 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/03/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Reel Trailer Service name ............. LISTPE Date ..................... 97/03/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File