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Home My WebLink About197-1921. Type of Request: Abandon Plug Perforations Fracture Stimulate Cut Tubing 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 Install 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): 5,920'5,727' Casing Collapse Conductor N/A Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WSW 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 12.6 / L-80 / BTC R3 3,151' 4-1/2" 13.5 / L, TSH-625 (110) 2,994' 3,200 MD / 2,679 TVD, Tertiary Underf WTRSP 4,215' 5,852' 4,155' 893 N/A 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 I-08 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 4/10/2025 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 & ADL0025906 197-192 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22821-00-00 Hilcorp Alaska LLC Tertiary Undef WTRSP Size Proposed Pools: 112' 112' 9.2# / L-80 / TCII TVD Burst 4,016' MILNE POINT SCHRADER BLUFF OIL 112' 20" 7"5,895' MD N/A 7,240psi4,193'5,895' Length 7" x 4-1/2" TriPoint Perm, 7" Baker Premier (2) & 7" Baker S-3 and N/A 5,412 MD / 3,772 TVD, 5,528 MD / 3,872 TVD & 5,646 MD / 3,975 TVD and N/A Todd Sidoti todd.sidoti@hilcorp.com 777-8443 Perforation Depth MD (ft): See Schematic See Schematic 3-1/2" 4-1/2" No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:33 pm, Mar 21, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.03.21 14:40:38 - 08'00' Taylor Wellman (2143) 325-160 DSR-4/1/25 * BOPE test to 2500 psi. 10-404 A.Dewhurst 18MAR25MGR17APR25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.18 08:55:06 -08'00'04/18/25 RBDMS JSB 042125 RWO Well: MPU I-08 Well Name: MPU I-08 API Number: 50-029-22821-00-00 Current Status: Water Source Well Pad: I-Pad Estimated Start Date: 10 April 2025 Rig: ASR 1 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: TBD Regulatory Contact: Tom Fouts Permit to Drill Number: 197-192 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Formation Pressure: 1158 psi @ 2649’ TVD Live Gauge Data | 8.4 PPGE MPSP: 893 psi Gas Column Gradient (0.1 psi/ft) Max Inclination: 75° @ 3350’ MD (2725’ TVD) Max Dogleg: 5.3°/100ft @ 2035’ MD (1971’ TVD) Brief Well Summary: MPU I-08 was converted from an injector to a water source well in January 2025. The ESP suffered a mechanical failure after a short run time. It is believed that the coupling between ESP pumps has failed. The well is making less than half the total water required of it. Notes Regarding Wellbore Condition x CMIT-TxIA to 1710 psi on 10-25-2024 passed Objective: Pull ESP and inspect coupling in between pumps. Run new ESP completion. Pre-Rig Operations: 1) Clear and level pad area in front of well. Spot rig mats, 500 bbl tank and containment. 2) RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 3) Circulate at least one wellbore volume with 8.6 ppg brine down tubing, taking returns up casing to 500 bbl returns tank. 4) RD Little Red Services and reverse out skid. 5) RD well house and flowlines. Clear and level area around well. 6) RU crane. Set BPV. ND tree and NU BOPE. RD Crane. NU BOPE house. Spot mud boat. RWO Well: MPU I-08 RWO Procedure: MIRU/Test BOPE: 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well with 8.6 ppg prior to setting CTS. 3. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test pipe rams on 4-½” and 3-½” test joints e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with 8.6 ppg KWF as needed. Pull BPV. Lubricate if pressure is expected. Pull ESP Completion: 5. MU Spooler for ESP cable. 6. MU landing joint and pull hanger. 7. Recover the tubing hanger. 8. POOH and lay down the 4-1/2” tubing. Inspect all joints for re-run. a. PU weight was 44k / SO weight was 33k b. Plan to recover 4 protectolizers, 1 splice clamp and 44 cannon clamps Run ESP: 9. Ensure handling equipment is on-hand for running 3-1/2” L80 completion 10. MU Spooler to run ESP power cable 11. PU ESP assembly and RIH on 4-½, 12.6# BTCE tbg, making electrical checks on the cable every 1,500-ft installing clamps and cross-coupling clamps as specified. Note PU and SO weights on tally. a. Set base of ESP assembly at ±2800-ft MD. Nom. Size Length Item Lb/ft Material Notes XXX XXX Centralizer XXX XXX XXX Sensor XXX XXX XXX Motor - XXX HP XXX XXX XXX Lower Tandem Seal XXX XXX XXX Upper Tandem Seal XXX XXX XXX Pumps XXX XXX XXX Discharge Head XXX RWO Well: MPU I-08 b. (1) joint of 4-1/2” Tubing c. 4-1/2” XN (3.750” No-Go) d. ~2700’ of 4-½ tubing to surface 12. Land tubing hanger. RILDS. Lay down landing jt. Note PU and SO weights on tally. 13. Set BPV and RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. ASR BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 1/30/2025 SCHEMATIC Milne Point Unit Well: MP I-08 Last Completed: 12/30/2024 PTD: 197-192 TD =5,920’(MD) / TD =4,215’(TVD) 20” Orig. KB Elev.: 63.84’/ Orig. GL Elev.: 34.6’ RKB – Tbg Hngr: 22.50’ (Nabors 4ES) 7” 14 16 17 18 21 20 23 24 1 Minimum ID= 2.750” @ 5,680’ PBTD =5,852’ (MD) / PBTD = 4,155’(TVD) 15 19 OB Sands Two 7” x 20’ Marker Jts from 5,201’ to 5,242’ WLM 22 13 RA Tag in Packer 5,412’ MD Tubing Cut @ 4,460’ ELM 2 3 & 4 7 8 9, 10 & 11 5 & 6 12 TOC @ 4,879’ SLM Prince Creek Cement Retainer 5,407’ ELM OA Sands NB Sands CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124” Surface 115' 0.3550 7" Production 26 / L-80 / BTC 6.276” Surface 5,895’ 0.0383 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / BTC R3 3.958 Surface 3,151’ 0.0152 4-1/2” Screen 13.5 / L, TSH-625 (110ђ) 3.849’ 3,239’ 4,265’ N/A 3-1/2” Tubing 9.2 / L-80 / TC-II 2.992” 4,460’ 5,693’ 0.0087 TREE & WELLHEAD Tree 3-1/2” - 5M Wellhead 11” 5M FMC Gen 6 w/ 3.5” TC-II T&B Thread FMC Tubing Hanger 3.0” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-22821-00-00 Drilled & Cased by Nabors 22E –10/20/1997 Completed by Nabors 4ES –3/10/1998 ESP Change-out Nabors 5S –8/5/1998 ESP Change-out Nabors 4ES –8/16/2003 Convert to Injector Nabors 4ES –9/15/2004 Convert to WSW/ Install ESP by ASR: 12/30/2024 OPEN HOLE / CEMENT DETAIL 20” 250 sx Arctic Set (Approx.) in a 42” Hole 7”260 sx Class ‘G’/1,260 sx PF ‘E’/200 sx PF ‘C’ in a 9-7/8” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status PC 3,256’ 4,256’ 2,698’ 2,991’ 1,000 5 4.5” 12/25/2024 Open NB 5,436’ 5,456’ 3,792’ 3,810’ 20 4 4.5” 3/02/1998 Closed OA 5,590’ 5,615’ 3,926’ 3,948’ 25 4 4.5” 3/01/1998 Closed OB 5,660’ 5,680’ 3,987’ 4,005’ 20 4 4.5” 2/28/1998 Closed Ref Log: Sperry Sun EWR/GR LWD –Perf Guns 4.5” 4 spf WELL INCLINATION DETAIL KOP @ 800’ Max hole angle = 74.5 deg. At 3,350’ MD JEWELRY DETAIL No Depth Item Upper Completion 1 2,983’ 4.5 HES XN-Nipple (3.813-in Bore,3.725” No-Go) 2 3,048’ Discharge Sub & Head: 513X, 416/420 420 SS& VIGILANT 3 1/2'' IN SS 3 3,050’ Pump #2: 538 SERIES, 056 STAGE SJ11500 4 3,073’ Pump #1: 538 SERIES, 056 STAGE SJ11500 5 3,097’ Intake: 513,416SS 6 3,098’ Upper Tandem Seal: 513 Series, BPBSL, PREMIUM SEALS 7 3,107’ Lower Tandem Seal: 513 Series, BPBSL, PREMIUM SEALS 8 3,116’ Motor: KMS2-LT, 500HP/4160V/74A, 16 Rotor 9 3,147’ Sensor & Centralizer: 177C,8K PSI,SS –Btm @ 3,151’ Lower Completion 10 3,195’ 5.00" TriPoint Polished Bore Receptacle 11 3,200’ 7" x 4-1/2",23-32# TriPoint Perm. PKR LTC 12 3,225’ 4.5 XN Nipple, 3.813"/3.725" No-Go BTC BxP 13 4,303’ Bullnose: Bakerlok –Btm @ 4,306’ 14 5,331’Sta #6: Valve- MMG GLM 15 5,392’ 3.5” HES X-Nipple (2.813” Profile) 16 5,412’ 7” x 3.5” Baker Premier Packer (w/ Radioactive Tag) 17 5,439’Sta #5: Valve- MMG GLM 18 5,500’Sta #4: Valve- MMG GLM 19 5,528’ 7” x 3.5” Baker Premier Packer 20 5,555’Sta #3: Valve- MMG GLM 21 5,616’Sta #2: Valve- MMG GLM 22 5,646’ 7” x 3.5” Baker S-3 Packer 23 5,661’Sta #1: Valve- MMG GLM 24 5,680’3.5” HES XN-Nipple (2.813” Profile/2.750 No Go) PXN plug/prong Set 7/28/2006 25 5,692’ 3.5” WLEG –Bottom @ 5,693’ _____________________________________________________________________________________ Revised By: TCS 3/21/2025 PROPOSED SCHEMATIC Milne Point Unit Well: MP I-08 Last Completed: 12/30/2024 PTD: 197-192 TD =5,920’(MD) / TD =4,215’(TVD) 20” Orig. KB Elev.: 63.84’/ Orig. GL Elev.: 34.6’ RKB – Tbg Hngr: 22.50’ (Nabors 4ES) 7” 14 16 17 18 21 20 23 24 1 Minimum ID= 2.750” @ 5,680’ PBTD =5,852’ (MD) / PBTD = 4,155’(TVD) 15 19 OB Sands Two 7” x 20’ Marker Jts from 5,201’ to 5,242’ WLM 22 13 RA Tag in Packer 5,412’ MD Tubing Cut @ 4,460’ ELM 2 3 & 4 7 8 9, 10 & 11 5 & 6 12 TOC @ 4,879’ SLM Prince Creek Cement Retainer 5,407’ ELM OA Sands NB Sands CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124” Surface 115' 0.3550 7" Production 26 / L-80 / BTC 6.276” Surface 5,895’ 0.0383 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / BTC R3 3.958 Surface ~2,700’ 0.0152 4-1/2” Screen 13.5 / L, TSH-625 (110ђ) 3.849’ 3,239’ 4,265’ N/A 3-1/2” Tubing 9.2 / L-80 / TC-II 2.992” 4,460’ 5,693’ 0.0087 TREE & WELLHEAD Tree 3-1/2” - 5M Wellhead 11” 5M FMC Gen 6 w/ 3.5” TC-II T&B Thread FMC Tubing Hanger 3.0” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-22821-00-00 Drilled & Cased by Nabors 22E –10/20/1997 Completed by Nabors 4ES –3/10/1998 ESP Change-out Nabors 5S –8/5/1998 ESP Change-out Nabors 4ES –8/16/2003 Convert to Injector Nabors 4ES –9/15/2004 Convert to WSW/ Install ESP by ASR: 12/30/2024 OPEN HOLE / CEMENT DETAIL 20” 250 sx Arctic Set (Approx.) in a 42” Hole 7”260 sx Class ‘G’/1,260 sx PF ‘E’/200 sx PF ‘C’ in a 9-7/8” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status PC 3,256’ 4,256’ 2,698’ 2,991’ 1,000 5 4.5” 12/25/2024 Open NB 5,436’ 5,456’ 3,792’ 3,810’ 20 4 4.5” 3/02/1998 Closed OA 5,590’ 5,615’ 3,926’ 3,948’ 25 4 4.5” 3/01/1998 Closed OB 5,660’ 5,680’ 3,987’ 4,005’ 20 4 4.5” 2/28/1998 Closed Ref Log: Sperry Sun EWR/GR LWD –Perf Guns 4.5” 4 spf WELL INCLINATION DETAIL KOP @ 800’ Max hole angle = 74.5 deg. At 3,350’ MD JEWELRY DETAIL No Depth Item Upper Completion 1 ±2,680’4.5 HES XN-Nipple (3.813-in Bore,3.725” No-Go) 2 ±X,XXX’Discharge Sub & Head: 513X, 416/420 420 SS & VIGILANT 3 1/2'' IN SS 3 ±X,XXX’Pump #2: 538 SERIES, 056 STAGE SJ11500 4 ±X,XXX’Pump #1: 538 SERIES, 056 STAGE SJ11500 5 ±X,XXX’Intake: 513,416SS 6 ±X,XXX’Upper Tandem Seal: 513 Series, BPBSL, PREMIUM SEALS 7 ±X,XXX’Lower Tandem Seal: 513 Series, BPBSL, PREMIUM SEALS 8 ±X,XXX’Motor: KMS2-LT, 500HP/4160V/74A, 16 Rotor 9 2,779’ Sensor & Centralizer: 177C,8K PSI,SS –Btm @ ~2,800’ Lower Completion 10 3,195’ 5.00" TriPoint Polished Bore Receptacle 11 3,200’ 7" x 4-1/2",23-32# TriPoint Perm. PKR LTC 12 3,225’ 4.5 XN Nipple, 3.813"/3.725" No-Go BTC BxP 13 4,303’ Bullnose: Bakerlok –Btm @ 4,306’ 14 5,331’Sta #6: Valve- MMG GLM 15 5,392’ 3.5” HES X-Nipple (2.813” Profile) 16 5,412’ 7” x 3.5” Baker Premier Packer (w/ Radioactive Tag) 17 5,439’Sta #5: Valve- MMG GLM 18 5,500’Sta #4: Valve- MMG GLM 19 5,528’ 7” x 3.5” Baker Premier Packer 20 5,555’Sta #3: Valve- MMG GLM 21 5,616’Sta #2: Valve- MMG GLM 22 5,646’ 7” x 3.5” Baker S-3 Packer 23 5,661’Sta #1: Valve- MMG GLM 24 5,680’3.5” HES XN-Nipple (2.813” Profile/2.750 No Go) PXN plug/prong Set 7/28/2006 25 5,692’ 3.5” WLEG –Bottom @ 5,693’ Milne Point ASR Rig 1 BOPE 2024 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Cut Tubing Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP Install Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 5,920 feet N/A feet true vertical 4,215 feet N/A feet Effective Depth measured 4,879' SLM feet feet true vertical 3,335 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" 12.6 / L-80 / BTC R3 3,151' 2,661' 4-1/2"13.5 / L, TSH-625 (110ђ)4,265' 2,994' Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2 / L-80 / TC-II 5,693' 4,016' 7" x 4-1/2" TriPoint Perm 7" Baker Premier (2) Packers and SSSV (type, measured and true vertical depth)Baker S-3 N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WSW Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: 3,200, 5,412, 5,528 & 5,646 2,679, 3,772, 3,872 & 3,975 324-569 & 324-607 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Erik Nelson Erik.Nelson@hilcorp.com 907-564-5277 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 112' 0 Size 112' 4,193' 000 0 00 0 measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-192 50-029-22821-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025517 & ADL0025906 MILNE POINT / Tertiary Undef WTRSP MILNE PT UNIT I-08 Plugs Junk measured LengthCasing Conductor 5,895'Production 20" 7" 112' 5,895'7,240psi Burst N/A Collapse N/A 5,410psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 7:40 am, Jan 31, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.01.30 15:20:18 - 09'00' Taylor Wellman (2143) SFD 2/27/2025 DSR-1/31/25 RBDMS JSB 021825 _____________________________________________________________________________________ Revised By: TDF 1/30/2025 SCHEMATIC Milne Point Unit Well: MP I-08 Last Completed: 12/30/2024 PTD: 197-192 TD =5,920’(MD) / TD =4,215’(TVD) 20” Orig. KB Elev.: 63.84’/ Orig. GL Elev.: 34.6’ RKB – Tbg Hngr: 22.50’ (Nabors 4ES) 7” 14 16 17 18 21 20 23 24 1 Minimum ID= 2.750” @ 5,680’ PBTD =5,852’ (MD) / PBTD = 4,155’(TVD) 15 19 OB Sands Two 7” x 20’ Marker Jts from 5,201’ to 5,242’ WLM 22 13 RA Tag in Packer 5,412’ MD Tubing Cut @ 4,460’ ELM 2 3 & 4 7 8 9, 10 & 11 5 & 6 12 TOC @ 4,879’ SLM Prince Creek Cement Retainer 5,407’ ELM OA Sands NB Sands CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124” Surface 115' 0.3550 7" Production 26 / L-80 / BTC 6.276” Surface 5,895’ 0.0383 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / BTC R3 3.958 Surface 3,151’ 0.0152 4-1/2” Screen 13.5 / L, TSH-625 (110ђ) 3.849’ 3,239’ 4,265’ N/A 3-1/2” Tubing 9.2 / L-80 / TC-II 2.992” 4,460’ 5,693’ 0.0087 TREE & WELLHEAD Tree 3-1/2” - 5M Wellhead 11” 5M FMC Gen 6 w/ 3.5” TC-II T&B Thread FMC Tubing Hanger 3.0” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-22821-00-00 Drilled & Cased by Nabors 22E –10/20/1997 Completed by Nabors 4ES –3/10/1998 ESP Change-out Nabors 5S –8/5/1998 ESP Change-out Nabors 4ES –8/16/2003 Convert to Injector Nabors 4ES –9/15/2004 Convert to WSW/ Install ESP by ASR: 12/30/2024 OPEN HOLE / CEMENT DETAIL 20” 250 sx Arctic Set (Approx.) in a 42” Hole 7”260 sx Class ‘G’/1,260 sx PF ‘E’/200 sx PF ‘C’ in a 9-7/8” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status PC 3,256’ 4,256’ 2,698’ 2,991’ 1,000 5 4.5” 12/25/2024 Open NB 5,436’ 5,456’ 3,792’ 3,810’ 20 4 4.5” 3/02/1998 Closed OA 5,590’ 5,615’ 3,926’ 3,948’ 25 4 4.5” 3/01/1998 Closed OB 5,660’ 5,680’ 3,987’ 4,005’ 20 4 4.5” 2/28/1998 Closed Ref Log: Sperry Sun EWR/GR LWD –Perf Guns 4.5” 4 spf WELL INCLINATION DETAIL KOP @ 800’ Max hole angle = 74.5 deg. At 3,350’ MD JEWELRY DETAIL No Depth Item Upper Completion 1 2,983’ 4.5 HES XN-Nipple (3.813-in Bore,3.725” No-Go) 2 3,048’ Discharge Sub & Head: 513X, 416/420 420 SS & VIGILANT 3 1/2'' IN SS 3 3,050’ Pump #2: 538 SERIES, 056 STAGE SJ11500 4 3,073’ Pump #1: 538 SERIES, 056 STAGE SJ11500 5 3,097’ Intake: 513,416SS 6 3,098’ Upper Tandem Seal: 513 Series, BPBSL, PREMIUM SEALS 7 3,107’ Lower Tandem Seal: 513 Series, BPBSL, PREMIUM SEALS 8 3,116’ Motor: KMS2-LT, 500HP/4160V/74A, 16 Rotor 9 3,147’ Sensor & Centralizer: 177C,8K PSI,SS –Btm @ 3,151’ Lower Completion 10 3,195’ 5.00" TriPoint Polished Bore Receptacle 11 3,200’ 7" x 4-1/2",23-32# TriPoint Perm. PKR LTC 12 3,225’ 4.5 XN Nipple, 3.813"/3.725" No-Go BTC BxP 13 4,303’ Bullnose: Bakerlok –Btm @ 4,306’ 14 5,331’Sta #6: Valve- MMG GLM 15 5,392’ 3.5” HES X-Nipple (2.813” Profile) 16 5,412’ 7” x 3.5” Baker Premier Packer (w/ Radioactive Tag) 17 5,439’Sta #5: Valve- MMG GLM 18 5,500’Sta #4: Valve- MMG GLM 19 5,528’ 7” x 3.5” Baker Premier Packer 20 5,555’Sta #3: Valve- MMG GLM 21 5,616’Sta #2: Valve- MMG GLM 22 5,646’ 7” x 3.5” Baker S-3 Packer 23 5,661’Sta #1: Valve- MMG GLM 24 5,680’3.5” HES XN-Nipple (2.813” Profile/2.750 No Go) PXN plug/prong Set 7/28/2006 25 5,692’ 3.5” WLEG –Bottom @ 5,693’ Well Name Rig API Number Well Permit Number Start Date End Date MP I-08 ASR,FB &WH 50-029-22821-00-00 197-192 10/18/2024 12/31/2024 No operations to report. PULL 1.5" RK-DGLV FROM STA #2 @ 5,616' MD. PULL 1.5" RK-DGLV FROM STA #3 @ 5,555' MD. PULL 1.5" RK-DGLV FROM STA #4 @ 5,500' MD. PULL 1.5" RK-DGLV FROM STA #5 @ 5,439' MD. RUN SBHPT SURVEY STOPS @ 5,422' MD, 5,305' MD & 5,188' MD. WELL LEFT S/I ON DEPARTURE. 10/19/2024 - Saturday PT TO 300 LOW 2500 PSI HIGH. LOG CORRELATED TO TUBING SUMMARY DATED 9/14/2004. SET CEMENT RETAINER AT 5407' MID ELEMENT. TUBING PUNCH INTERVAL 5397-5400'. WELL LEFT SI ON DEPARTURE. JOB COMPLETED. 10/22/2024 - Tuesday 10/20/2024 - Sunday T/I/O=670/135/0 Step Rate Test down TBG. Loaded TBG with 50 bbls source water. Pumped 40 bbls source water down TBG to establish SRT of: 1 bpm @ 500 psi. 1.5 bpm @ 503 psi. 2 bpm @ 520 psi. Freeze protected TBG with 25 bbls diesel. Final Whps=670/590/0 10/21/2024 - Monday 10/18/2024 - Friday MIT-IA 1500 PSI=PASS (see log) DRIFT 2.80" CENT BARBELL TO 5,500' MD. PULL 1.5" RK-DGLV FROM STA #1 @5,661' MD. 10/16/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 10/17/2024 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP I-08 ASR,FB &WH 50-029-22821-00-00 197-192 10/18/2024 12/31/2024 No operations to report. WSR CONT'D FROM 10/25/2024 TUBING CUT IN PROGRESS. DECISION MADE TO CUT TBG AT 4460' (SHORT OF TARGET DEPTH:4850'). CUT 3.5" TBG @ 4460' (CCL STOP AT 4446.7'- OFFSET 13.25'). LRS PUMP/CIRCULATE BETWEEN TBG/IA - TUBING CUT SUCCESSFUL. RD HES ELINE 1122. LRS CIRCULATING TBG/IA ON DEPARTURE - JOB COMPLETE. Freeze Protect (Post Cement) Pumped 97 bbls 85* Diesel into IA taking returns up TBG out to tank. Pumped 25 bbls 85* Diesel into TBG taking returns up IA out to tank. 10/26/2024 - Saturday No operations to report. 10/29/2024 - Tuesday 10/27/2024 - Sunday No operations to report. 10/28/2024 - Monday 10/25/2024 - Friday RAN KJ, 2.74" CENT, 5' x 2-1/2" DRIVE DOWN BLR W/ MSFB, SD @4,430' SLM, WORK TOOLS FOR 30 MINUTES TO 4,461' SLM - RECOVERED PARTIAL FOAM BALL. RAN KJ, 2.74" CENT, 5' x 2-1/4" PUMP BLR W/ MSFB, SD @4,879' SLM, WORK TOOLS FOR 10 MINUTES - RECOVERED ~2 TABLESPOONS OF CEMENT. LRS PERFORMED PASSING CMIT TO 1,500 PSI. MIRU HES UNIT 1122, RIH 2.7" JET CUTTER. T/I/O=25/18 (Post Cement) CMIT-TxIA Passed to 1710 psi. (Witnessed by Kam StJohn) Pressured up TBG/IA to 1762/1762 psi. 1st 15 min T/IA lost 35/35 psi. 2nd 15 min T/IA lost 17/17 psi for a total loss of 52/52 psi in 30 min. Bled back .5 bbl.Final Whps=38/31. 10/23/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 10/24/2024 - Thursday PUMP 35 BBLS, 170 SKS 15.8 PPG, 1.152 YLD, 4.964 WR, 195.8 CU/FT, 20 BBLS FRESH WATER, 2.6 BPM @ 655 PSI. Est. TOC 5254' MD. Well Name Rig API Number Well Permit Number Start Date End Date MP I-08 ASR,FB &WH 50-029-22821-00-00 197-192 10/18/2024 12/31/2024 12/20/2024 - Friday No operations to report. 12/18/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 12/19/2024 - Thursday No operations to report. Pull 3-1/2" TC-II completion F/ 4,460' to cut joint - 14.31' OAL. PU/MU and RIH w/ 4-1/2", Geo - 5spf TCP Guns on 3-1/2" workstring T/ 4,050'. T/I/O=0/0 Well kill. Pumped 160 bbls of 100* 8.6 NaCl down TBG up IA taking returns to tank. Capped TBG with 2 bbls 60/40. Pumped 1 bbl60/40 into IA. Freeze protected surface lines with 5 bbls 60/40. Final Whps=0/0 12/21/2024 - Saturday Test Fire and Gas - good. Test BOPE 250/2500psi - 1 F/P - witness waived. Pull CTS/BPV - well static. Swap well to 8.7ppg NaCl. 12/24/2024 - Tuesday 12/22/2024 - Sunday WELLHEAD: Set 3'' BPV after well kill, Bled void to 0 psi N/D tree/adapter checked lift threds with X/over set CTS plug and tested 500 low 5000 high 5/5 min good test, set new R-54 ring gasket, cycled LDS. rig to N/U BOPE and test. 12/23/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP I-08 ASR & WH 50-029-22821-00-00 197-192 10/18/2024 12/31/2024 WELLHEAD: Completion, MU 4 1/2 ESP tbg hgr to TC11 LJ and comp. string (Bpv pre set). Summit install penn. and perform cable splice. Five ft RKB 21.23' into profile, RILDS and pull LJ to floor. SB for RU. BOP pulled, clean void and new RX54 gaske t. PU tree/adapter and land. Torque to spec and test 500/5000 5 and 10 min. (PASS). Pull Bpv with T bar. (WELL SECURE). BO/LD 6-1/8" Clean out BHA. Boot Baskets full of sand - sample obtained. RIH w/ Bull Nose, 4-1/2",13.5#,L, TSH-625 - 110micron screens, XN, TriPoint 7" x 4-1/2" Perm. PKR T/ 4,351' ORKB. Drop ball and set PKR at 3850psi. Test CSG to 1500psi - Good. POOH F/ 3,194' (PKR setting tool) T/ 333'. 12/28/2024 - Saturday Continue MU HNGR splice. Land hanger while monitoring ESP - good, RILDS. Begin RDMO. Blow down all fluid lines. Remove flow spool and spacer spools. Pull pipe sheds. Disconnect koomey hoses. Release rig 06:00 12/30/2024. Continue RDMO on MPI-08. 12/31/2024 - Tuesday 12/29/2024 - Sunday Continue POOH w/ PKR setting tool and LD. M/U and service ESP equipment. P/U M/U first joint and XN nipple. Begin RIH W/ 4-1/2",12.6#,L, BTC and ESP testing ESP systems every 1000' T/ TBG HNGR. Begin feed thru. 12/30/2024 - Monday 12/27/2024 - Friday Continue POOH w/ Bull Nose, 4-1/2",13.5#,L, TSH-625 - 110micron screens F/ 485'. RIH w/ 6-1/8" cleanout BHA , work through tight spots 3,285', 3,315', 3,350'. Wash and ream to 4,351'. CBU 2x, POOH T/ 228'. 12/25/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continue RIH w/ TriPoint 4-1/2", Geo - 5spf TCP Guns and 3-1/2" WS. Install 10' pup below last joint, drop 1.25" steel ball. MU JT#81, PUW = 37k, SOW = 22k. Pull into tension back to depth mark - Top shot = 3,256' - BTM Shot = 4,256' corrected to ORKB. Hole is full w/ 8.7ppg NaCl. Monitor well - on vac. POOH and LD guns - trace amount of very fine sand on guns. Sample collected. RIH w Bull Nose, 4-1/2",13.5#,L, TSH-625 - 110micron screens T/ 1,129'. 12/26/2024 - Thursday Continue RIH w/ Bull Nose, 4-1/2",13.5#,L, TSH-625 - 110micron screens XN and Packer F/ 1,129'. Work thru tight spot F/ 3,085' - 3,125'. Bullhead 85bbls 8.7ppg NaCl w/ NSX lube. Work completion down to 3,925' begin losing depth with tag depths. POOH w/ Sump PKR/Screen completion F/ 3,925' - T/2,484'. Fluid level 680', loss rate - 114bbls/hr. POOH T/ 1,125' and LD PKR and 14/25 screens. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/05/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241205 Well API #PTD #Log Date Log Company Log Type AOGCC ESet AN 15(GRANITE PT ST 18742 15) 50733200700000 167082 11/18/2024 AK E-LINE Perf BRU 221-26 50283202010000 224098 10/24/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 10/21/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 10/30/2024 AK E-LINE Perf BRU 241-23 50283201910000 223061 11/8/2024 AK E-LINE Perf BRU 241-26 50283201970000 224068 11/12/2024 AK E-LINE Plug/Perf END 2-72 50029237810000 224016 10/16/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 10/18/2024 HALLIBURTON COILFLAG MGS-ST 17595-05 50733100710000 165038 10/6/2024 AK E-LINE CBL MPU F-109 50029235960000 218014 10/28/2024 READ CaliperSurvey MPU J-02 50029220710000 190096 11/16/2024 READ CaliperSurvey MPU J-47 50029238010000 224120 11/9/2024 READ LeakPointSurvey MPU D-01 50029206640000 181144 10/23/2024 AK E-LINE TubingPunch MPU F-02 50029226730000 196070 11/18/2024 READ CaliperSurvey MPU I-08 50029228210000 197192 10/22/2024 AK E-LINE TubingPunch MPU I-08 50029228210000 197192 10/26/2024 HALLIBURTON JETCUT MPU L-60 50029236780000 220048 10/26/2024 HALLIBURTON MFC24 MRU M-25 50733203910000 187086 11/15/2024 AK E-LINE Plug NCIU A-21 50883201990000 224086 11/9/2024 AK E-LINE Perf NCIU A-21 50883201990000 224086 10/19/2024 AK E-LINE Perf NCIU A-21 50883201990000 224086 10/30/2024 AK E-LINE Perf NCIU A-21 50883201990000 224086 10/30/2024 AK E-LINE Plug/Perf PBU 06-07A 50029202990100 224043 9/30/2024 HALLIBURTON RBT PBU 14-41A 50029222900100 224076 11/8/2024 HALLIBURTON RBT PBU H-36A 50029226050100 200025 10/26/2024 HALLIBURTON RBT PCU 02A 50283200220100 224110 11/24/2024 AK E-LINE Perf Please include current contact information if different from above. T39808 T39809 T39810 T39810 T39811 T39812 T39813 T39813 T39814 T39815 T39816 T39817 T39818 T39819 T39820 T39820 T39821 T39822 T39823 T39823 T39823 T39823 T39824 T39825 T39826 T39827 MPU I-08 50029228210000 197192 10/22/2024 AK E-LINE TubingPunch MPU I-08 50029228210000 197192 10/26/2024 HALLIBURTON JETCUT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.05 14:52:46 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 33 Township: 13N Range: 10E Meridian: Umiat Drilling Rig: n/a Rig Elevation: n/a Total Depth: 5920 ft MD Lease No.: ADL0025906 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 112 Feet Csg Cut@ Feet Surface: O.D. Shoe@ Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 5895 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3-1/2" O.D. Tail@ 5693 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Retainer 5407 ft 4897 ft 8.6 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1762 1727 1710 IA 1762 1727 1710 OA N/A N/A N/A Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Per Sundry 324-569, abandonment of lower completion and recomplete uphole. This a monobore well no OA. I witnessed the top of cement tag with wireline. Intial tag was 4460 ft MD (foam balls for displacing cement; the were able to move the foam balls down to cement top at 4897 ft MD and get a good cement sample in the bailer) . 1500 psi CMIT TxIA required - good test. October 25, 2024 Kam StJohn Well Bore Plug & Abandonment MPU I-08 Hilcorp Alaska LLC PTD 1971920; Sundry 324-569 none Test Data: P Casing Removal: Roger Allison Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-1025_Plug_Verification_MPU_I-08_ksj 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 9 9 9 9 99 9 James B. Regg Digitally signed by James B. Regg Date: 2024.11.20 16:29:46 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Cut Tubing 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 Install 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): 5,920'5,727' Casing Collapse Conductor N/A Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WSW WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7" Baker Premier (2) & 7" Baker S-3 and N/A 5,412 MD / 3,772 TVD, 5,528 MD / 3,872 TVD & 5,646 MD / 3,975 TVD and N/A Erik Nelson Erik.Nelson@hilcorp.com 907-564-5277 Perforation Depth MD (ft): See Schematic See Schematic 3-1/2" 112' 20" 7"5,895' MD N/A 7,240psi4,193'5,895' Length Size Proposed Pools: 112' 112' 9.2# / L-80 / TCII TVD Burst 5,693' MILNE POINT SCHRADER BLUFF OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 & ADL0025906 197-192 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22821-00-00 Hilcorp Alaska LLC Tertiary Underf WTRSP AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/12/2024 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT I-08 Tertiary Underf WTRSP 4,215' 5,852' 4,155' 1,699 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 9:04 am, Oct 21, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.10.21 08:51:03 - 08'00' Taylor Wellman (2143) 324-607 DSR-10/23/24 * BOPE pressure test to 2500 psi. * AOGCC to witness Schrader Bluff reservoir abandonment plug integrity per program (CMIT- T x IA) and slickline tag. * Full bore cement retainer to have ball seat to assure no over displacement of cement. MGR08NOV24 10-404 X SFD 10/23/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.08 16:04:58 -09'00'11/08/24 RBDMS JSB 111424 RWO Well: MPU I-08 Date: TBD Well Name:MPU I-08 API Number:50-029-22821-00-00 Current Status:SI Inj Pad:I-Pad Estimated Start Date:12 October 2024 Rig:ASR 1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd:TBD Regulatory Contact:Tom Fouts Permit to Drill Number:197-192 First Call Engineer:Erik Nelson (XXX) XXX-XXXX (O)(907) 903-7407 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O)(907) 947-9533 (M) Schrader Bluff Reservoir (to be abandoned during Pre-Rig wellwork ) Current Bottom Hole Pressure: 2098 psi @ 3987’ TVD From SBHP (13Sep21) | 10.1 PPGE MPSP: 1699 psi Gas Column Gradient (0.1 psi/ft) Max Inclination: 75° @ 3350’ MD (2725’ TVD) Max Dogleg: 5.3°/100ft @ 2035’ MD (1971’ TVD) Prince Creek Formation (recompletion as WSW) Current Formation Pressure: 1145 psi @ 2638’ TVD From offset WSW MPU I-09 | 8.4 PPGE MPSP: 1801 psi Gas Column Gradient (0.1 psi/ft) Max Inclination: 75° @ 3350’ MD (2725’ TVD) Max Dogleg: 5.3°/100ft @ 2035’ MD (1971’ TVD) Brief Well Summary: MPU I-08 is a shut-in injector originally drilled and completed as an ESP producer in 1997/1998. A RWO was performed to convert it to an injector in September 2004. This well was selected as a good candidate for conversion to a WSW to provide additional freshwater for ongoing polymer injection at I-pad since the 7-in production casing was fully cemented to surface. This procedure details the below outline of the scope of this project: Isolate and abandon the existing lower completion in the Schrader Bluff OB, OA, and NB sands Pull the current production tubing Perforate the Prince Creek formation Run lower completion with erosion resistant screens Run upper completion with ESP Notes Regarding Wellbore Condition x MIT-T to 1500 psi on 20 Feb 2022 passed Objective: Perform reservoir abandonment of the Schrader Bluff NB, OA, and OB sands, perforate Prince Creek Formation, run new lower screen completion, run ESP and bring on as a high-volume freshwater source well. Pre-Rig Operations: freshwater RWO Well: MPU I-08 Date: TBD 1) MIRU Slickline a. Perform MIT-IA (1500 psi) b. Drift for poppet-style cmt retainer c. Pull DVs from GLM Sta #1 thru #5 and leave open. Leave GLM Sta #6 w/ DV in place. d. Obtain updated SBHP. 2) MIRU LRS a. Establish combined injection rate into open Schrader Bluff NB, OA, and OB Sands using 8.6 lb/gal fluid. b. FP well to await P&A of Schrader Bluff sands. 3) MIRU E-line a. RIH to set poppet-style cmt retainer ±5407-ft MD or mid-jt in 1st handling pup above upper Baker Premier Pkr (btm 5412-ft MD / top 5402-ft MD). b. RIH to w/ tbg punch to punch ±5397-ft MD or mid-jt in 2 nd handling pup above upper Baker Premier Pkr (btm 5402-ft MD / top 5392-ft MD). 4) MIRU Cementers a. Circ out FP in tbg and IA through tbg punch with hot 8.6 lb/gal fluid. b. Close tbg/IA annulus and establish injection rate through the cmt retainer into the Schrader Bluff NB, OA, and OB sands by bullheading down the tbg. c. Open IA and tbg and bleed well to 0 psi to ensure poppet in cmt retainer is holding. d. Commence bullheading ±35 bbls Class G neat (±15.8 lb/gal) through cmt retainer with the tbg/IA annulus closed. e. Drop cmt wiper balls to chase cmt tail and displace cmt with hot 8.6 lb/gal fluid. Once ±31 bbls are through the cmt retainer, slow displacement pump rate and open tbg/IA annulus to allow cmt to flow through the tbg punch. NOTE: Ensure returns from IA match cmt displacement rate f. After opening tbg/IA annulus displace cmt with an additional ±2.5 bbls and shut down the pumps. MU jumper line from IA to tbg and allow cmt to hydrostatically balance between the tbg and IA. Done - 22OCT-24 - per email 11-8-24 Done - 24OCT24 - TOC at 4879' MD Assure no over displacement past retainer. - mgr RWO Well: MPU I-08 Date: TBD 5) MIRU Slickline a. Provide 24-hr notification to AOGCC for possible witness b. Tag TOC in tbg per AOGCC c. Drift for explosive jet cutter d. Perform Combo MIT-IA (1500 psi) 6) MIRU E-Line a. RIH w/ explosive jet cutter and cut tbg ±5243-ft MD (mid jt on Jt #6 on Tbg Tally from Nabors 4ES (15Sep04)) NOTE: If conclusion of pre-rig wellwork is significantly before the scheduled arrival of ASR then we’ll need to RU LRS to FP the well. Ensure well is circulated over to 8.6 lb/gal fluid before ASR’s arrival. 7) Clear and level pad area in front of well. Spot rig mats, 500 bbl tank and containment. 8) RD well house and flowlines. Clear and level area around well. 9) RU crane. Set BPV. ND tree and NU BOPE. RD Crane. NU BOPE house. Spot mud boat. DONE 26OCT24 Eline cut tubing at 4460' MD Done 25OCT24 TOC 4879' MD RWO Well: MPU I-08 Date: TBD RWO Procedure: MIRU/Test BOPE: 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well with 8.6 #/gal prior to setting CTS. 3. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR on 3-½” and 4-½” test joints (3-½”workstring and 4-½”, 12.6# BTC production tubing) e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with 8.6 #/gal KWF as needed. Pull BPV. Lubricate if pressure is expected. Pull Prod Tbg: 5. MU landing jt or spear and unland tbg hgr 6. Recover the tbg hgr 7. Break circulation down the tbg, taking returns from the backside ensuring well has been circulated over to 8.6 #/gal fluid in order to be slightly overbalanced during the ensuing TCP run. NOTE: 1145 psi Prince Creek (8.4 #/gal equiv) reservoir pressure from offset well MPU I-09 8. POOH and lay down the old 3-½” tbg. Wash and trash all jts. Perf Run: 9. Arm and RIH with ±1000’ of (2-7/8” to 4-5/8”) TCP guns 10. TIH and perforating the following interval: a. ±3256 – 4275-ft MD b. Maintain tubing fill while TIH 11. Confirm well is dead after perforating. Bullhead 8.6 #/gal KWF as needed. 12. TOOH w/ and lay down TCP guns 13. Prep for lower screen completion run. Run Lwr Scrn Compl: 14. Pick up and RIH with lwr scrn compl: NOTE: Ensure 3-½” Safety Jt is on-hand a. 4-½” eccentric bullnose w/ 4-½” BTC Box (Bakerlok) b. (1) jt 4-½” Wedge 625 Box x 4-½” BTC Pin c. ~25 joints of 4-½” EnerG Ener-Armor screens i. 100 ђ RWO Well: MPU I-08 Date: TBD ii. 4-½”, 12.6 #/ft base pipe iii. 5.340-in Screen OD iv. 38 – 42 ft jt length v. Solid Centralizer near box end is 5.750-in OD d. 4-½” Wedge 625 Pin x 4-½” BTC/LTC Box x-over e. 4-½” XN Nipple w/ 10-ft 4-½” BTC/LTC handling pups f. 7” x 4-½” hyd set perm pkr w/ 4-½” LTC Box x Pin g. 5” 3-ft PBR w/ 4-½” LTC Pin h. 5” Anchor Latch Running Tool w/ 1-ft Seal and 4-½” LTC Box i. 3-½” IF Box x 4-½” LTC Pin x-over j. Hydraulic Packer Ball Drop Running Tool k. 3-½” IF Pin x XXX PH6 Box x-over to workstring l. 3-½” workstring to surface 15. TIH to pkr set depth (±3240-ft MD) ensuring workstring is filling properly. 16. Drop ball to set packer with Hyd Pkr Ball Drop Running Tool per vendor best practices. NOTE: Exact pkr set depth to be established from actual tbg tally of lwr compl 17. PT IA to 1500 psi to ensure pkr is set and prod csg integrity. 18. Shear seal assembly from PBR to release from packer 19. TOOH with 3-½” workstring and lay down running tools. Run ESP: 20. Ensure handling equipment is on-hand for running 4-½”, 12.6# L-80 BTC completion 21. MU Spooler to run ESP power cable 22. PU ESP assembly and RIH on 4-½”, 12.6# L-80 BTC tbg, making electrical checks on the cable every 2,000-ft installing clamps and cross-coupling clamps as specified. Note PU and SO weights on tally. a. ESP (TBD) NOTE: Set base of ESP assembly at ±3150-ft MD (~2663-ft TVD) Nom. Size Length Item Lb/ft Material Notes XXX XXX Centralizer XXX XXX XXX Sensor XXX XXX XXX Motor - XXX HP XXX XXX XXX Lower Tandem Seal XXX XXX XXX Upper Tandem Seal XXX XXX XXX Pumps XXX XXX XXX Discharge Head XXX b. (1) jt of 4-½”, 12.6# L-80 BTC Tubing c. 4-1/2” XN (3.813-in Bore, 3.725” No-Go) w/ 10-ft 4-½”, 12.6# L-80 BTC handling pups RWO Well: MPU I-08 Date: TBD d. XXX jts of 4-½”, 12.6# L-80 BTC tbg to surface e. 4-½”, 12.6# BTC-XTP x-over to tbg hgr 23. Land tbg hgr. RILDS. Lay down landing jt. Note PU and SO weights on tally. 24. Set BPV Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. ASR BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 9/30/2024 SCHEMATIC Milne Point Unit Well: MP I-08 Last Completed: 9/15/2004 PTD: 197-192 TD =5,920’(MD) / TD =4,215’(TVD) 20” Orig. KB Elev.: 63.84’/ Orig. GL Elev.: 34.6’ RKB – Tbg Hngr: 22.50’ (Nabors 4ES) 7” 3 5 6 7 10 9 12 13 1 Minimum ID= 2.750” @ 5,680’ PBTD =5,852’ (MD) / PBTD = 4,155’(TVD) 4 8 OB Sands Two 7” x 20’ Marker Jts from 5,201’ to 5,242’ WLM 11 2 RA Tag in Packer 5,412’ MD OA Sands NB Sands CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124” Surface 115' 0.3550 7" Production 26 / L-80 / BTC 6.276” Surface 5,895’ 0.0383 TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / TC-II 2.992” Surf 5,693’ 0.0087 JEWELRY DETAIL No Depth Item 1 3,027’ 3.5” HES X-Nipple (2.813” Profile) GLM DETAIL: 3.5” x 1.5” Camco MMG w/ 1.5” RK Latch 2 5,331’Sta #6: Valve- Dummy [MMG GLM] 3 5,392’ 3.5” HES X-Nipple (2.813” Profile) 4 5,412’ 7” x 3.5” Baker Premier Packer (w/ Radioactive Tag) 5 5,439’Sta #5: Valve- Dummy 3/12/20 [MMG GLM] 6 5,500’Sta #4: Valve- Dummy 5-24-13 [MMG GLM] 7 5,528’ 7” x 3.5” Baker Premier Packer 8 5,555’Sta #3: Valve- Dummy 9/13/2021 [MMG GLM] 9 5,616’Sta #2: Valve- Dummy 3-07-20 [MMG GLM] 10 5,646’ 7” x 3.5” Baker S-3 Packer 11 5,661’Sta #1: Valve- Dummy 9/13/2021 [MMG GLM] 12 5,680’3.5” HES XN-Nipple (2.813” Profile/2.750 No Go) PXN plug/prong Set 7/28/2006 13 5,692’ 3.5” WLEG – Bottom @ 5,693’ TREE & WELLHEAD Tree 3-1/2” - 5M Wellhead 11” 5M FMC Gen 6 w/ 3.5” TC-II T&B Thread FMC Tubing Hanger 3.0” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-22821-00-00 Drilled & Cased by Nabors 22E – 10/20/1997 Completed by Nabors 4ES – 3/10/1998 ESP Change-out Nabors 5S – 8/5/1998 ESP Change-out Nabors 4ES – 8/16/2003 Convert to Injector Nabors 4ES – 9/15/2004 OPEN HOLE / CEMENT DETAIL 20” 250 sx Arctic Set (Approx.) in a 42” Hole 7” 260 sx Class ‘G’/1,260 sx PF ‘E’/200 sx PF ‘C’ in a 9-7/8” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status NB 5,436’ 5,456’ 3,792’ 3,810’ 20 4 4.5” 3/02/1998 Open OA 5,590’ 5,615’ 3,926’ 3,948’ 25 4 4.5” 3/01/1998 Open OB 5,660’ 5,680’ 3,987’ 4,005’ 20 4 4.5” 2/28/1998 Open Ref Log: Sperry Sun EWR/GR LWD – Perf Guns 4.5” 4 spf WELL INCLINATION DETAIL KOP @ 800’ Max hole angle = 74.5 deg. At 3,350’ MD _____________________________________________________________________________________ Revised By: TDF 10/21/2024 PROPOSED Milne Point Unit Well: MP I-08 Last Completed: 9/15/2004 PTD: 197-192 TD = 5,920’ (MD) / TD =4,215’(TVD) 20” Orig. KB Elev.: 63.84’/ Orig. GL Elev.: 34.6’ RKB – Tbg Hngr: 22.50’ (Nabors 4ES) 7” 14 16 17 18 21 20 23 24 1 Minimum ID= 2.750” @ 5,680’ PBTD =5,852’ (MD) / PBTD = 4,155’(TVD) 15 19 OB Sands Two 7” x 20’ Marker Jts from 5,201’ to 5,242’ WLM 22 13 RA Tag in Packer 5,412’ MD Tubing Cut @ ±5,243’ 2 3 & 4 7 8 9, 10 & 11 5 & 6 12 TOC @ ±X,XXX’MD Prince Creek OA Sands NB Sands CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124” Surface 115' 0.3550 7" Production 26 / L-80 / BTC 6.276” Surface 5,895’ 0.0383 TUBING DETAIL 3-1/2” Tubing 12.6 / L-80 / BTC 2.992 ±X,XXX’ ±X,XXX’ 0.0087 4-1/2” Tubing 12.6 / L-80 / Wedge 625 3.958 ±X,XXX’ ±X,XXX’ 0.0152 3-1/2” Tubing 9.2 / L-80 / TC-II 2.992”±5,243’5,693’ 0.0087 TREE & WELLHEAD Tree 3-1/2” - 5M Wellhead 11” 5M FMC Gen 6 w/ 3.5” TC-II T&B Thread FMC Tubing Hanger 3.0” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-22821-00-00 Drilled & Cased by Nabors 22E – 10/20/1997 Completed by Nabors 4ES – 3/10/1998 ESP Change-out Nabors 5S – 8/5/1998 ESP Change-out Nabors 4ES – 8/16/2003 Convert to Injector Nabors 4ES – 9/15/2004 OPEN HOLE / CEMENT DETAIL 20” 250 sx Arctic Set (Approx.) in a 42” Hole 7” 260 sx Class ‘G’/1,260 sx PF ‘E’/200 sx PF ‘C’ in a 9-7/8” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status PC ±3,256’ ±4,275’ ±X,XXX’ ±X,XXX’ ±1,019 Future Future NB 5,436’ 5,456’ 3,792’ 3,810’ 20 4 4.5” 3/02/1998 Closed OA 5,590’ 5,615’ 3,926’ 3,948’ 25 4 4.5” 3/01/1998 Closed OB 5,660’ 5,680’ 3,987’ 4,005’ 20 4 4.5” 2/28/1998 Closed Ref Log: Sperry Sun EWR/GR LWD – Perf Guns 4.5” 4 spf WELL INCLINATION DETAIL KOP @ 800’ Max hole angle = 74.5 deg. At 3,350’ MD JEWELRY DETAIL No Depth Item Upper Completion 1 ±X,XXX’ 4.5 HES XN-Nipple (3.813-in Bore, 3.725” No-Go) 2 ±X,XXX’ Discharge Head 3 ±X,XXX’ Pump #2 4 ±X,XXX’ Pump #1 5 ±X,XXX’ Upper Tandem Seal 6 ±X,XXX’ Lower Tandem Seal 7 ±X,XXX’ Motor 8 ±X,XXX’ Sensor & Centralizer Lower Completion 9 ±X,XXX’ PBR 10 ±X,XXX’ Hydraulic Set Permanent Pkr 11 ±X,XXX’ 4.5 HES XN-Nipple Profile 12 ±X,XXX’ Bullnose 13 5,331’Sta #6: Valve- MMG GLM 14 5,392’ 3.5” HES X-Nipple (2.813” Profile) 15 5,412’ 7” x 3.5” Baker Premier Packer (w/ Radioactive Tag) 16 5,439’Sta #5: Valve- MMG GLM 17 5,500’Sta #4: Valve- MMG GLM 18 5,528’ 7” x 3.5” Baker Premier Packer 19 5,555’Sta #3: Valve- MMG GLM 20 5,616’Sta #2: Valve- MMG GLM 21 5,646’ 7” x 3.5” Baker S-3 Packer 22 5,661’Sta #1: Valve- MMG GLM 23 5,680’3.5” HES XN-Nipple (2.813” Profile/2.750 No Go) PXN plug/prong Set 7/28/2006 24 5,692’ 3.5” WLEG – Bottom @ 5,693’ 4-1/2” SCREEN DETAIL Top @ ±X,XXX’ MD & Bottom @ ±X,XXX’ MD CMT Retainer 5407' MD -mgr 4460' MD TOC 4879' MD Milne Point ASR Rig 1 BOPE 2024 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Erik Nelson - (C) To:Rixse, Melvin G (OGC) Subject:RE: [EXTERNAL] RE: Completion Tubing Size Change on RWO of MPU I-08 (PTD# 197-192) (Approved Sundry# 324-569)... Date:Friday, November 8, 2024 2:17:23 PM Attachments:MP I-08 PROPOSED 11-8-2024.pdf Mel, I’m responding in this email chain to your request for confirmation on the cement retainer setting depth and resultant TOC from our fullbore P&A of the Schrader Bluff OB, OA, and OB sands. We have executed the following pre-RWO wellwork which is represented in the attached schematic: 22 October – Set poppet-style cmt retainer on E-Line at 5407-ft MD (mid-element) 24 October – Fullbore pump 35-bbl (170 sks) cmt volume through retainer plus tbg and IA above cmt retainer 25 October – State witness tag TOC at 4879-ft SLMD and passing CMIT-TxIA 26 October – E-line cut tbg at 4460-ft MD Please let me know if you require anything else. Appreciate it! Q From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, November 8, 2024 10:39 AM To: Erik Nelson - (C) <Erik.Nelson@hilcorp.com> Subject: RE: [EXTERNAL] RE: Completion Tubing Size Change on RWO of MPU I-08 (PTD# 197-192) (Approved Sundry# 324-569)... I will make it today’s priority. Mel From: Erik Nelson - (C) <Erik.Nelson@hilcorp.com> Sent: Friday, November 8, 2024 10:14 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: Completion Tubing Size Change on RWO of MPU I-08 (PTD# 197-192) (Approved Sundry# 324-569)... CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Mel, Just wanted to check-in with you regarding this COP for MPU I-08 that we submitted. We’re planning on moving the rig to this well early next week so I just wanted to inquire as to where this might be sitting in your workflow. If there is anything else you might require from me, please let me know. Thank you for your time and consideration of my inquiry. Q From: Erik Nelson - (C) <Erik.Nelson@hilcorp.com> Sent: Monday, October 21, 2024 10:04 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: Completion Tubing Size Change on RWO of MPU I-08 (PTD# 197-192) (Approved Sundry# 324-569)... Mel, As instructed a 10-403 CAP was submitted this morning. Please let me know if there are any questions and/or concerns. Q From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, October 18, 2024 9:50 AM To: Erik Nelson - (C) <Erik.Nelson@hilcorp.com> Subject: [EXTERNAL] RE: Completion Tubing Size Change on RWO of MPU I-08 (PTD# 197-192) (Approved Sundry# 324-569)... Erik, For such a significant change you need to submit a 10-403 for ‘change to approved program’. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Erik Nelson - (C) <Erik.Nelson@hilcorp.com> Sent: Thursday, October 17, 2024 5:30 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Completion Tubing Size Change on RWO of MPU I-08 (PTD# 197-192) (Approved Sundry# 324-569)... Mel, I wanted to let you know that we have changed our re-complete plans for MPU I-08 (PTD# 197- 192). We are going to be running 4-½”, 12.6# L80 BTC tubing rather than the 3-½”, 9.3# L80 8rd EUE tbg as I wrote it up in the 10-403 Application for Sundry Approval (Approved Sundry# 324- 569). We made the decision to upsize the completion tubing in order to alleviate concerns regarding potential backpressure on the ESP. As a result of this change I’ve noted that our BOPE testing procedure in our submittal called for only testing the VBRs with a 3-½” test joint which would cover both our 3-½” workstring and 3- ½” completion tubing. We’ll now need to test those VBRs with both a 3-½” and 4-½” test joint. I’ve noted this change in the procedure and will discuss the change with our rig team when we move on to the well. Thank you for your time and please let me know if you have any questions and/or comments. Q Erik Q. Nelson Milne Point OE (Contract) O (907) 564 - 5277 C (907) 903 – 7407 Erik.Nelson@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Cut Tubing 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 Install 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): 5,920'5,727' Casing Collapse Conductor N/A Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WSW 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 PRINCE CREEK 4,215' 5,852' 4,155' 1,699 N/A 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 I-08 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/12/2024 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 197-192 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22821-00-00 Hilcorp Alaska LLC 477.07 Size Proposed Pools: 112' 112' 9.2# / L-80 / TCII TVD Burst 5,693' MILNE POINT SCHRADER BLUFF OIL 112' 20" 7"5,895' MD N/A 7,240psi4,193'5,895' Length 7" Baker Premier (2) & 7" Baker S-3 and N/A 5,412 MD / 3,772 TVD, 5,528 MD / 3,872 TVD & 5,646 MD / 3,975 TVD and N/A Erik Nelson Erik.Nelson@hilcorp.com 907-564-5277 Perforation Depth MD (ft): See Schematic See Schematic 3-1/2" No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:59 pm, Sep 30, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.09.30 15:53:30 - 08'00' Taylor Wellman (2143) 324-569 10-404 SFD 10/2/2024 W SW * MGR02OCT24 *BOPE pressure test to 2500 psi. * Per 20 AAC 25.112 (c)(1)(D) TOC to be a minimum of 50' above top of perforations requires TOC to be shallower than 5386' MD. * AOGCC to witness slick line tag of TOC and pressure test to 1500 psi. SFDADL0025906, DSR-10/2/24 Tertiary Undef WTRSP (525130) SFD Tertiary Undef WTRSP: Statewide Regs SFD SB: JLC 10/4/2024 (5386' or less) Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.10.07 13:10:22 -08'00' 10/07/24 RBDMS JSB 100824 RWO Well: MPU I-08 Date: TBD Well Name:MPU I-08 API Number:50-029-22821-00-00 Current Status:SI Inj Pad:I-Pad Estimated Start Date:12 October 2024 Rig:ASR 1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd:TBD Regulatory Contact:Tom Fouts Permit to Drill Number:197-192 First Call Engineer:Erik Nelson (XXX) XXX-XXXX (O) (907) 903-7407 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Schrader Bluff Reservoir (to be abandoned during Pre-Rig wellwork) Current Bottom Hole Pressure: 2098 psi @ 3987’ TVD From SBHP (13Sep21) |10.1 PPGE MPSP: 1699 psi Gas Column Gradient (0.1 psi/ft) Max Inclination: 75° @ 3350’ MD (2725’ TVD) Max Dogleg: 5.3°/100ft @ 2035’ MD (1971’ TVD) Prince Creek Formation (recompletion as WSW) Current Formation Pressure: 1145 psi @ 2638’ TVD From offset WSW MPU I-09 | 8.4 PPGE MPSP: 1801 psi Gas Column Gradient (0.1 psi/ft) Max Inclination: 75° @ 3350’ MD (2725’ TVD) Max Dogleg: 5.3°/100ft @ 2035’ MD (1971’ TVD) Brief Well Summary: MPU I-08 is a shut-in injector originally drilled and completed as an ESP producer in 1997/1998. A RWO was performed to convert it to an injector in September 2004. This well was selected as a good candidate for conversion to a WSW to provide additional freshwater for ongoing polymer injection at I-pad since the 7-in production casing was fully cemented to surface. This procedure details the below outline of the scope of this project: Isolate and abandon the existing lower completion in the Schrader Bluff OB, OA, and NB sands Pull the current production tubing Perforate the Prince Creek formation Run lower completion with erosion resistant screens Run upper completion with ESP Notes Regarding Wellbore Condition x MIT-T to 1500 psi on 20 Feb 2022 passed Objective: Perform reservoir abandonment of the Schrader Bluff NB, OA, and OB sands, perforate Prince Creek Formation, run new lower screen completion, run ESP and bring on as a high-volume freshwater source well. Pre-Rig Operations: RWO Well: MPU I-08 Date: TBD 1) MIRU Slickline a. Perform MIT-IA (1500 psi) b. Drift for poppet-style cmt retainer c. Pull DVs from GLM Sta #1 thru #5 and leave open. Leave GLM Sta #6 w/ DV in place. d. Obtain updated SBHP. 2) MIRU LRS a. Establish combined injection rate into open Schrader Bluff NB, OA, and OB Sands using 8.6 lb/gal fluid. b. FP well to await P&A of Schrader Bluff sands. 3) MIRU E-line a. RIH to set poppet-style cmt retainer ±5407-ft MD or mid-jt in 1 st handling pup above upper Baker Premier Pkr (btm 5412-ft MD / top 5402-ft MD). b. RIH to w/ tbg punch to punch ±5397-ft MD or mid-jt in 2 nd handling pup above upper Baker Premier Pkr (btm 5402-ft MD / top 5392-ft MD). 4) MIRU Cementers a. Circ out FP in tbg and IA through tbg punch with hot 8.6 lb/gal fluid. b. Close tbg/IA annulus and establish injection rate through the cmt retainer into the Schrader Bluff NB, OA, and OB sands by bullheading down the tbg. c. Open IA and tbg and bleed well to 0 psi to ensure poppet in cmt retainer is holding. d. Commence bullheading ±35 bbls Class G neat (±15.8 lb/gal) through cmt retainer with the tbg/IA annulus closed. e. Drop cmt wiper balls to chase cmt tail and displace cmt with hot 8.6 lb/gal fluid. Once ±31 bbls are through the cmt retainer, slow displacement pump rate and open tbg/IA annulus to allow cmt to flow through the tbg punch. NOTE: Ensure returns from IA match cmt displacement rate f. After opening tbg/IA annulus displace cmt with an additional ±2.5 bbls and shut down the pumps. MU jumper line from IA to tbg and allow cmt to hydrostatically balance between the tbg and IA. No shallower than 5386' MD. - mgr above 5386' MD Per email: Erik Nelson October 4, 2024 10:08: "With similar fluid above the cement column in both the inner annulus and tubing and the jumper hose allowing for hydrostatic equalization this should yield a column of cement of ±115-ft. Which corresponds to a top of cement at ±5282-ft MD using the tbg punch as the btm (or 5297-ft MD from the top of the uppermost Baker Premier packer)." 5407' MD okay - mgr 5397' MD okay - mgr RWO Well: MPU I-08 Date: TBD 5) MIRU Slickline a. Provide 24-hr notification to AOGCC for possible witness b. Tag TOC in tbg per AOGCC c. Drift for explosive jet cutter d. Perform Combo MIT-IA (1500 psi) 6) MIRU E-Line a. RIH w/ explosive jet cutter and cut tbg ±5243-ft MD (mid jt on Jt #6 on Tbg Tally from Nabors 4ES (15Sep04)) NOTE: If conclusion of pre-rig wellwork is significantly before the scheduled arrival of ASR then we’ll need to RU LRS to FP the well. Ensure well is circulated over to 8.6 lb/gal fluid before ASR’s arrival. 7) Clear and level pad area in front of well. Spot rig mats, 500 bbl tank and containment. 8) RD well house and flowlines. Clear and level area around well. 9) RU crane. Set BPV. ND tree and NU BOPE. RD Crane. NU BOPE house. Spot mud boat. TOC 5282' target. 5386' MD minimum. - mgr AOGCC witnessed. - mgr RWO Well: MPU I-08 Date: TBD RWO Procedure: MIRU/Test BOPE: 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well with 8.6 #/gal prior to setting CTS. 3. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test pipe rams on 3-½” test joints (3-½”, 9.2# completion tbg and workstring) e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with 8.6 #/gal KWF as needed. Pull BPV. Lubricate if pressure is expected. Pull Prod Tbg: 5. MU landing jt or spear and unland tbg hgr 6. Recover the tbg hgr 7. Break circulation down the tbg, taking returns from the backside ensuring well has been circulated over to 8.6 #/gal fluid in order to be slightly overbalanced during the ensuing TCP run. NOTE: 1145 psi Prince Creek (8.4 #/gal equiv) reservoir pressure from offset well MPU I-09 8. POOH and lay down the old 3-½” tbg. Wash and trash all jts. Perf Run: 9. Arm and RIH with ±1000’ of (2-7/8” to 4-5/8”) TCP guns 10. TIH and perforating the following interval: a. ±3256 – 4275-ft MD b. Maintain tubing fill while TIH 11. Confirm well is dead after perforating. Bullhead 8.6 #/gal KWF as needed. 12. TOOH w/ and lay down TCP guns 13. Prep for lower screen completion run. Run Lwr Scrn Compl: 14. Pick up and RIH with lwr scrn compl: NOTE: Ensure 3-½” Safety Jt is on-hand a. 4-½” eccentric bullnose w/ 4-½” BTC Box (Bakerlok) b. (1) jt 4-½” Wedge 625 Box x 4-½” BTC Pin c. ~25 joints of 4-½” EnerG Ener-Armor screens i. 100 ђ RWO Well: MPU I-08 Date: TBD ii. 4-½”, 12.6 #/ft base pipe iii. 5.340-in Screen OD iv. 38 – 42 ft jt length v. Solid Centralizer near box end is 5.750-in OD d. 4-½” Wedge 625 Pin x 4-½” BTC/LTC Box x-over e. 4-½” XN Nipple w/ 10-ft 4-½” BTC/LTC handling pups f. 7” x 4-½” hyd set perm pkr w/ 4-½” LTC Box x Pin g. 5” 3-ft PBR w/ 4-½” LTC Pin h. 5” Anchor Latch Running Tool w/ 1-ft Seal and 4-½” LTC Box i. 3-½” IF Box x 4-½” LTC Pin x-over j. Hydraulic Packer Ball Drop Running Tool k. 3-½” IF Pin x XXX PH6 Box x-over to workstring l. 3-½” workstring to surface 15. TIH to pkr set depth (±3240-ft MD) ensuring workstring is filling properly. 16. Drop ball to set packer with Hyd Pkr Ball Drop Running Tool per vendor best practices. NOTE: Exact pkr set depth to be established from actual tbg tally of lwr compl 17. PT IA to 1500 psi to ensure pkr is set and prod csg integrity. 18. Shear seal assembly from PBR to release from packer 19. TOOH with 3-½” workstring and lay down running tools. Run ESP: 20. Ensure handling equipment is on-hand for running 3-1/2” L80 completion 21. MU Spooler to run ESP power cable 22. PU ESP assembly and RIH on 3-½, 9.3# 8rd EUE tbg, making electrical checks on the cable every 2,000-ft installing clamps and cross-coupling clamps as specified. Note PU and SO weights on tally. a. ESP (TBD) NOTE: Set base of ESP assembly at ±3150-ft MD (~2663-ft TVD) Nom. Size Length Item Lb/ft Material Notes XXX XXX Centralizer XXX XXX XXX Sensor XXX XXX XXX Motor - XXX HP XXX XXX XXX Lower Tandem Seal XXX XXX XXX Upper Tandem Seal XXX XXX XXX Pumps XXX XXX XXX Discharge Head XXX b. (1) jt of 3-1/2” Tubing c. 3-1/2” XN (2.750” No-Go) w/ 10-ft 3-½, 9.3# 8rd EUE handling pups RWO Well: MPU I-08 Date: TBD d. XXX jts of 3-½, 9.3# 8rd EUE tbg to surface e. 3-½” 8rd EUE pin x 3-½” TCII x-over to tbg hgr 23. Land tbg hgr. RILDS. Lay down landing jt. Note PU and SO weights on tally. 24. Set BPV Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. ASR BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 9/30/2024 SCHEMATIC Milne Point Unit Well: MP I-08 Last Completed: 9/15/2004 PTD: 197-192 TD =5,920’(MD) / TD =4,215’(TVD) 20” Orig. KB Elev.: 63.84’/ Orig. GL Elev.: 34.6’ RKB – Tbg Hngr: 22.50’ (Nabors 4ES) 7” 3 5 6 7 10 9 12 13 1 Minimum ID= 2.750” @ 5,680’ PBTD =5,852’ (MD) / PBTD = 4,155’(TVD) 4 8 OB Sands Two 7” x 20’ Marker Jts from 5,201’ to 5,242’ WLM 11 2 RA Tag in Packer 5,412’ MD OA Sands NB Sands CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124” Surface 115' 0.3550 7" Production 26 / L-80 / BTC 6.276” Surface 5,895’ 0.0383 TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / TC-II 2.992” Surf 5,693’ 0.0087 JEWELRY DETAIL No Depth Item 1 3,027’ 3.5” HES X-Nipple (2.813” Profile) GLM DETAIL: 3.5” x 1.5” Camco MMG w/ 1.5” RK Latch 2 5,331’Sta #6: Valve- Dummy [MMG GLM] 3 5,392’ 3.5” HES X-Nipple (2.813” Profile) 4 5,412’ 7” x 3.5” Baker Premier Packer (w/ Radioactive Tag) 5 5,439’Sta #5: Valve- Dummy 3/12/20 [MMG GLM] 6 5,500’Sta #4: Valve- Dummy 5-24-13 [MMG GLM] 7 5,528’ 7” x 3.5” Baker Premier Packer 8 5,555’Sta #3: Valve- Dummy 9/13/2021 [MMG GLM] 9 5,616’Sta #2: Valve- Dummy 3-07-20 [MMG GLM] 10 5,646’ 7” x 3.5” Baker S-3 Packer 11 5,661’Sta #1: Valve- Dummy 9/13/2021 [MMG GLM] 12 5,680’3.5” HES XN-Nipple (2.813” Profile/2.750 No Go) PXN plug/prong Set 7/28/2006 13 5,692’ 3.5” WLEG – Bottom @ 5,693’ TREE & WELLHEAD Tree 3-1/2” - 5M Wellhead 11” 5M FMC Gen 6 w/ 3.5” TC-II T&B Thread FMC Tubing Hanger 3.0” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-22821-00-00 Drilled & Cased by Nabors 22E – 10/20/1997 Completed by Nabors 4ES – 3/10/1998 ESP Change-out Nabors 5S – 8/5/1998 ESP Change-out Nabors 4ES – 8/16/2003 Convert to Injector Nabors 4ES – 9/15/2004 OPEN HOLE / CEMENT DETAIL 20” 250 sx Arctic Set (Approx.) in a 42” Hole 7” 260 sx Class ‘G’/1,260 sx PF ‘E’/200 sx PF ‘C’ in a 9-7/8” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status NB 5,436’ 5,456’ 3,792’ 3,810’ 20 4 4.5” 3/02/1998 Open OA 5,590’ 5,615’ 3,926’ 3,948’ 25 4 4.5” 3/01/1998 Open OB 5,660’ 5,680’ 3,987’ 4,005’ 20 4 4.5” 2/28/1998 Open Ref Log: Sperry Sun EWR/GR LWD – Perf Guns 4.5” 4 spf WELL INCLINATION DETAIL KOP @ 800’ Max hole angle = 74.5 deg. At 3,350’ MD _____________________________________________________________________________________ Revised By: TDF 9/30/2024 PROPOSED Milne Point Unit Well: MP I-08 Last Completed: 9/15/2004 PTD: 197-192 TD = 5,920’ (MD) / TD =4,215’(TVD) 20” Orig. KB Elev.: 63.84’/ Orig. GL Elev.: 34.6’ RKB – Tbg Hngr: 22.50’ (Nabors 4ES) 7” 14 16 17 18 21 20 23 24 1 Minimum ID= 2.750” @ 5,680’ PBTD =5,852’ (MD) / PBTD = 4,155’(TVD) 15 19 OB Sands Two 7” x 20’ Marker Jts from 5,201’ to 5,242’ WLM 22 13 RA Tag in Packer 5,412’ MD Tubing Cut @ ±5,243’ 2 3 & 4 7 8 9, 10 & 11 5 & 6 12 TOC @ ±X,XXX’MD Prince Creek OA Sands NB Sands CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / N/A 19.124” Surface 115' 0.3550 7" Production 26 / L-80 / BTC 6.276” Surface 5,895’ 0.0383 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992 ±X,XXX’ ±X,XXX’ 0.0087 4-1/2” Tubing 12.6 / L-80 / Wedge 625 3.958 ±X,XXX’ ±X,XXX’ 0.0152 3-1/2” Tubing 9.2 / L-80 / TC-II 2.992”±5,243’5,693’ 0.0087 TREE & WELLHEAD Tree 3-1/2” - 5M Wellhead 11” 5M FMC Gen 6 w/ 3.5” TC-II T&B Thread FMC Tubing Hanger 3.0” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-22821-00-00 Drilled & Cased by Nabors 22E – 10/20/1997 Completed by Nabors 4ES – 3/10/1998 ESP Change-out Nabors 5S – 8/5/1998 ESP Change-out Nabors 4ES – 8/16/2003 Convert to Injector Nabors 4ES – 9/15/2004 OPEN HOLE / CEMENT DETAIL 20” 250 sx Arctic Set (Approx.) in a 42” Hole 7” 260 sx Class ‘G’/1,260 sx PF ‘E’/200 sx PF ‘C’ in a 9-7/8” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status PC ±3,256’ ±4,275’ ±X,XXX’ ±X,XXX’ ±1,019 Future Future NB 5,436’ 5,456’ 3,792’ 3,810’ 20 4 4.5” 3/02/1998 Closed OA 5,590’ 5,615’ 3,926’ 3,948’ 25 4 4.5” 3/01/1998 Closed OB 5,660’ 5,680’ 3,987’ 4,005’ 20 4 4.5” 2/28/1998 Closed Ref Log: Sperry Sun EWR/GR LWD – Perf Guns 4.5” 4 spf WELL INCLINATION DETAIL KOP @ 800’ Max hole angle = 74.5 deg. At 3,350’ MD JEWELRY DETAIL No Depth Item Upper Completion 1 ±X,XXX’ 3.5 HES XN-Nipple Profile 2 ±X,XXX’ Discharge Head 3 ±X,XXX’ Pump #2 4 ±X,XXX’ Pump #1 5 ±X,XXX’ Upper Tandem Seal 6 ±X,XXX’ Lower Tandem Seal 7 ±X,XXX’ Motor 8 ±X,XXX’ Sensor & Centralizer Lower Completion 9 ±X,XXX’ PBR 10 ±X,XXX’ Hydraulic Set Permanent Pkr 11 ±X,XXX’ 4.5 HES XN-Nipple Profile 12 ±X,XXX’ Bullnose 13 5,331’Sta #6: Valve- MMG GLM 14 5,392’ 3.5” HES X-Nipple (2.813” Profile) 15 5,412’ 7” x 3.5” Baker Premier Packer (w/ Radioactive Tag) 16 5,439’Sta #5: Valve- MMG GLM 17 5,500’Sta #4: Valve- MMG GLM 18 5,528’ 7” x 3.5” Baker Premier Packer 19 5,555’Sta #3: Valve- MMG GLM 20 5,616’Sta #2: Valve- MMG GLM 21 5,646’ 7” x 3.5” Baker S-3 Packer 22 5,661’Sta #1: Valve- MMG GLM 23 5,680’3.5” HES XN-Nipple (2.813” Profile/2.750 No Go) PXN plug/prong Set 7/28/2006 24 5,692’ 3.5” WLEG – Bottom @ 5,693’ 4-1/2” SCREEN DETAIL Top @ ±X,XXX’ MD & Bottom @ ±X,XXX’ MD Target TOC ~5282' Tubing and IA - mgr Milne Point ASR Rig 1 BOPE 2024 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg -Rep c DATE: Wednesday,September 07,2016 P.I.Supervisor ' ��j�b SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC I-08 FROM: Chuck Scheve MILNE PT UNIT SB I-08 Petroleum Inspector Src: Inspector Reviewed By: P.I. NON-CONFIDENTIAL Comm Comm Well Name MILNE PT UNIT SB I-08 API Well Number 50-029-22821-00-00 Inspector Name: Chuck Scheve Permit Number: 197-192-0 Inspection Date: 9/4/2016 Insp Num: mitCS160906110955 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-08 - Type Inj W' LTVD 3772 Tubing 891 895 - 898 ' 897 • PTD 1971920 ' Type Test'SPT!Test psi 1500 IA 97 1670 1616 - 1606 - Interval 4YRTST !P/F P / OA Notes: — -- -__— _------ — SCANNED N 2 0 2 D ', Wednesday,September 07,2016 Page 1 of 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: GraYScale, halftones, pictures, graphs, charts- Pages: Poor Quality Original'- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type 'OVERSIZED [] Logs of various kinds n Other co....,.: Scanned. by: Beverly Mildred Daretha ~Lowell Date.: /si TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is~ • S bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 December 30, 2011 54ic° 1 ct-- Mr. Tom Maunder (6 Alaska Oil and Gas Conservation Commission t 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPI -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPI -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, Q� Mehreen Vazir BPXA, Well Integrity Coordinator 0 • I BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPI -Pad 10/9/2011 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPI -01 1900900 50029220650000 0.1 NA 0.1 NA 8.5 9/5/2011 MPI-02 1900910 50029220660000 Sealed coductor NA NA NA NA NA MPI-03 1900920 50029220670000 Sealed coductor NA NA NA NA NA MPI -04A 2010920 50029220680100 Sealed coductor NA NA NA NA NA MPI-05 1951200 50029225830000 2.7 NA 2.7 NA 27.2 11/2/2009 MPI-06 1971950 50029228220000 Open Flutes - Treated NA NA MPI -07 1951510 50029226020000 1.7 NA 1.7 NA 16.2 8/21/2011 -"" MPH 1971920 , 50029228210000 1.3 NA 1.3 NA 15.3 11/2/2009 MPI-09 2001030 50029229640000 1.3 NA 1.3 NA 13.6 11/1/2009 MPI -10 2001090 50029229660000 Open Flutes - Treated NA NA MPI -11 2011370 50029230330000 1.3 NA 1.3 NA 10.2 8/19/2011 MPI -12 2011630 50029230380000 0.2 NA 0.2 NA 7.7 10/9/2011 MPI -13 2010750 50029230120000 0.85 NA 0.85 NA 8.5 9/5/2011 MPI -14 2041190 50029232140000 1.9 NA 1.9 NA 16.2 8/23/2011 MPI -15 2021520 50029231060000 1 NA 1 NA 9.4 8/19/2011 MPI -16 2041580 50029232210000 1.75 NA 1.75 NA 17.0 8/19/2011 MPI -17 2040980 50029232120000 1.75 NA 1.75 NA 13.6 8/23/2011 MPI -19 2041350 50029232180000 1.4 NA 1.4 NA 10.2 8/19/2011 MEMORANDUM Toy Jim Regg ~ / P.I. Supervisor K ~'~/ ~(~ ~( U`3 FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 16, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC I-08 MILNE PT UNIT SB I-08 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv j)~ Comm Well Name• MILNE PT UNIT SB I-08 Insp Num: mitJCr080916074746 Rel Insp Num: API Well Number: 50-029-22821-00-00 Permit Number: 197-192-0 .i Inspector Name• John Crisp Inspection Date: 9/10/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1-08 jType Inj. w ~ TVD 3772 I IA I 90o zzso zlao ~ zlza p.T_ ~ I9n9zo TypeTest i sPT ~ Test psi ~ Isoo pA ~ { I j Interval 4YRTST P/F P ~ Tubing use ~ use Ilso i Ilso NOteS' I.1 bbis pumped for test. Monobore Injector - no OA to monitor. ~ Tuesday, September 16, 2008 Page i of 1 MEMO RAND UM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg. K~a to/HIM P.I. Supervisor 1 t DATE: Wednesday, October 06, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 1-08 MILNE PT UNIT SB 1-08 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv cr~ Comm NON-CONFIDENTIAL Well Name: MILNE PT UNIT SB 1-08 API Well Number: 50-029-22821-00-00 Inspector Name: Chuck Scheve Insp Num: mitCSO41003191317 Permit Number: 197-192-0 Inspection Date: 1013/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1-08 Type Inj. S TVD 3772 IA 800 2000 1940 1920 P.T. 1971920 TypeTest SPT Test psi 943 OA Interval !NIT AL P/F P Tubing 1000 1000 1000 1000 Notes: This well was recently converted from producer to water injector. Pretest pressures were observed and found stable. Well demonstated good mechanical integrity. Wednesday, October 06, 2004 Page 1 of 1 dla!lka Oil & Gas on5. 1. Operations Performed: Conv D Abandon D Repair Well D Plug Perforations D Stimulate 1m Other D Alter Casing 1m Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operation Shutdown D Perforate D Re-Enter Suspended Well 2. Operator Name: 4. Current Well Class: 15. Permit To Drill Number: BP Exploration (Alaska) Inc. D Development D Exploratory 197-192 3. Address: D Stratigraphic 1m Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22821-00-00 7. KB Elevation (ft): KBE = 63.84' 9. Well Name and Number: MPI-O8 8. Property Designation: 10. Field 1 Pool(s): ADL 025517 Milne Point Unit 1 Schrader Bluff 11. Present well condition summary Total depth: measured 5920 feet true vertical 4215 feet Plugs (measured) N/A Effective depth: measured 5852 feet Junk (measured) Fish at 5727' true vertical 4155 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 115' 115' 1490 470 Surface Intermediate Production 5864' 7" 5895' 4193' 7240 5410 Liner Perforation Depth MD (ft): 5436' - 5680' Perforation Depth TVD (ft): 3792' -4005' Tubing Size (size. grade, and measured depth): 3-1/2", 9.2# L-80 5693' Packers and SSSV (type and measured depth): 7" x 3-1/2" Baker Premiar Packer w/radioactive tag 5412' 7" x 3-112" Baker Pramiar Packer 5528' 7" x 3-1/2" Baker S-3 Packer 5846' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS BfL SEP27 100~ 13. ReDresentative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: D Copies of Logs and Surveys run 15. Well Class after proposed work: 1m Daily Report of Well Operations D Exploratory D Development 1m Service 1m Well Schematic Diagram 16. Well Status after proposed work: DOil DGas DWAG DGINJ ImWINJ D WDSPL 17. I hereby certify that the foregoing IS true and correct to the best Of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 304-276 Printed Name Sondra Stewman Title Technical Assistant Si9~( ....... n ræJo :Ol\ Prepared By Nama/Number: .D./V'. ~ Phone -:~ f\ I ^ lJate a1-~ Sondra Stewman, 564-4750 Form 10-404 Revised 04/2004 '-"\lV/I\!t1L Submit Original Only ALASKA:L AND ~~~T~g~S~~;~ON COI~ISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONSJËP 2 3 2004 C Commission ------ ~ li'ee: 3.5" - 5M Wellhead: 11" 5M FMC Gen 6 Tho. Hna: 3.5"" x 11" FMC wI 2 7/8" TC-II T&B and 3" CIW H BPV 20" 91.1 ppf, H-40 ~ KOP @ 300' Max. hole angle = 72 to 74 deg. f/3300' to 4100' Hole anoia thru' perfs = 32 deQ 3.5" 9.2 ppf, L-80. TCII tubing ( Drift id = 2.992" , cap. = 0.0087 bpf ) 7" 26 ppf, L-80, Mod. Btrc. prod. casing ( drift 10 = 6.151 ", cap. = 0.0383 bpf ) Two 7" x 21' short joints from 5201' to 5242' md Stimulation Summary 02/28/98 "OB" Sand - 24.2 M# of PropLok coated 16/20 Carbolite proppant behind pipe. No dye - natural color. 03/01/98 "OA" Sand - 117. M# of PropLok coated 16/20 Carbolite proppant behind pipe. Red dye was used. 03/03/98 "Nn Sand - 124. M# of propLok coated 16/20 Carbolite proppant behind pipe. Blue dye was used. 07/31/98 "N" Sand - 92 M# of PropLok coated 16/30 Badger sand behind pipe. Perforation SUmmary Ref loa: Sperry Sun EWR / GR LWD Size SPF Interval (TVD) 'N' Sand 4.5" 4 5436' - 5456' (3792' - 3810') 'OA' Sand 4.5" 4 5590' - 5615' (3926' -3948') 'OB Sand 4.5" 4 5660' - 5680' (3987' -4005') Atlas AlphaJet ("big hole") charges @ 180 deg. phasing (EHO = 0.93", TTP = 5.2") DATE 10/20/97 03/10/98 09/15/04 Ev. BY JBF MOO MOO MPU I-OBi Fish .. Orig~ Elev. = 63.84' (N 22E) Orig. ~ Elev. = 34.5' OF To 7" csg. hgr. = 31.14' (N 22E) 3.5" HES X-Nipple (2.813" pkg.) I 3,027' I 7" Hawea "ES" Cementer 3.5" x 1.5" Cameo MMG GLM 3.5" HES X-Nipple (2.813" pkg.) 7"x 3.5" Baker Premier Packer wI radioactive tag 3.5" x 1.5" Cameo MMG GLM 3.5" x 1.5" Cameo MMG GLM I 5,331' I I 5,392' I I 5,412' I I 5,439' I I 5,500' I 7"x 3.5" Baker Premier Packer I 5,528' I 3.5" x 1.5" Cameo MMG GLM 3.5" x 1.5" Cameo MMG GLM 7"x 3.5" Baker S-3 Packer 3.5" x 1.5" Cameo MMG GLM I 5,555' I I 5,616' I I 5,646' I I 5,661' I I I 3.5" HES XN-Nipple (2.813" pkg.) I 5,680' 2.75" NO-~~" WLEG I 5,693' Portion of gravel pack sump packer & carbolite PBTO @ 5727' 7" Landing Collar (PBTO) 7" float collar 7" float shoe 5809' md 5852' md 5895' md MILNE POINT UNIT WELL 1-08 API NO: 50-029-22821 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/5/2004 9/6/2004 9/7/2004 01 :30 - 03:30 03:30 - 04:00 04:00 - 06:00 06:00 - 08:00 08:00 - 12:30 12:30 - 13:30 13:30 - 15:30 15:30 - 16:00 16:00 - 21 :30 21 :30 - 00:00 00:00 - 01 :00 01 :00 - 03:00 03:00 - 04:00 04:00 - 08:00 08:00 - 11 :00 11:00 - 12:30 12:30 - 13:00 13:00 - 14:00 14:00 - 17:00 17:00 - 18:00 18:00 - 20:00 .---- ~ BP EXPLORATION Operations Summary Report P P P 2.00 KILL P MPI-08 MPI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Ii _.~~~-~.~~- ~~~. Task ¡Code NPT 20:00 - 00:00 4.00 RIGU 00:00 - 01 :00 1.00 PULL 01 :00 - 01 :30 0.50 KILL 0.50 KILL P 2.00 WHSUR P 2.00 BOPSUF P 4.50 BOPSUF P 1.00 PULL 2.00 PULL P P 0.50 PULL 5.50 PULL P P 2.50 PULL P 1.00 PULL 2.00 PULL P P 1.00 FISH P 4.00 FISH P 3.00 FISH P 1.50 FISH P 0.50 FISH P 1.00 FISH P 3.00 FISH P 1.00 FISH P 2.00 FISH P Phase -------. PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Page 1 of 7 Start: 9/5/2004 Rig Release: 9/15/2004 Rig Number: Spud Date: 10/15/1997 End: 9/15/2004 Description of Operations RlU on MPI-08. Rig accepted @ 2300 hrs, 9/512004. P/U lubricator and pull BPV. PJSM wI all hands and Peak truck driver for Well Kill operations. PJSM. Bleed down well from SITP = 530 psi, SICP = 820 psi. Circulate 420 Bbls (bullhead 20 Bbls)of 120 F S/W, 3 to 5 BPM at TP 40 to 570 psi until fluid returns cleaned up. SI both sides and monitor pressures: 0 psi on Tubing and Annulus; well on vacuum when both sides opened. Install TWC and test. Nipple down Production Tree. NU BOPE. Test BOPE per BP/AOGCC requirements at 250/3,500 psi. Note Pipe Rams were tested to 4,000 psi as requested in Program. State's right to witness test waived by J. Spaulding. (Load 3 1/2" Drill Pipe in Pipe Shed. Tally same). Pick-up Lubricator. Pull TWC. Lay down same. Rig up double Sheave to handle ESP and Heat Trace Cables. Rig up Floor to pull 2 7/8' Completion. BOLDS. Pull Tubing Hanger to Floor (44K) with no problems. POOH laying down 2 7/8" Tubing and ESPIHT Completion. The last of the heat trace section was on the floor @ 2130 hrs. POOH & UD 2-718" tubing. Pump to floor at 2330 hrs. Begin to break out and UD ESP assembly. Break out and UD ESP assembly. Clear and clean rig floor. RID 2-7/8" handling equipment and Centrilift equipment. RlU 3-1/2" DP handling equipment. PJSM. M/U BHA #1: HES retrieving tool, XO, Bumper Jar, Oil Jar, 10 x 4-3/4' DCs (from Pipe Shed). RIH with BHA #1. Single in with 159 Jts. 3 1/2' Drill Pipe. PUW = 74K SOW = 58K. Make-up 10' Pup Jt and Circulating Hose. Bring Pump on line at 2 - 3 bpm/300 - 500 psi. Latch VL T Pkr at 5,381' with no problems. Shut down Pump. Attempt to pull Pkr free with a normal shear release (straight pull at 60K over String weight). No-joy. Begin light to medium Jar licks (unloading Jars at 60K over String Weight). Came free. POOH standing back Drill Pipe and Drill collars. BHA #1 to surface. No recovery. Inspect Halco Retrieving Tool. J-Slot showed that we stripped the internal lugs in Packer. WO proper size Grapple for Spear. Make-up BHA #2 as follows: 31/4' Spear w/3.885' Grapple, XO, Bumper Jar, Oil Jar, 10 ea 4 3/4' Drill Collars, Accelerator Jar. RIH wI BHA #2 to engage HES Versatrieve packer @ 5381'. P/U wt 75K, SIO wt 64K. Engaged in packer. Set off jars at 130K, then 150K and pull to 175K, no go. Set off jars @ 150K and pull to 175K, No- Joy. Recock jars, set off @ 175K and fish came free. P/U wt 80K, SIO wt 70K. RIH tag l' high, POH 10'. Crew change and PJSM. POH wI fish and BHA #2, SIB DP asd DCs. Recovered packer, bottom sub, upper extension, frac closing sleeve, seal bore, lower extension, and MSJ safety shear sub, total length 24.5'. Printed: 9120/2004 11:12:41 AM . r---. ~ ... BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: MPI-08 Common Well Name: MPI-08 Spud Date: 10/15/1997 Event Name: WORKOVER Start: 9/5/2004 End: 9/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/15/2004 Rig Name: NABORS 4ES Rig Number: I ' Date From - To Hours I Task Code NPT Phase Description of Operations 1----.---... ..-... .-..--.-.. ! .-- -'--.--'--- .---..-..-.--..- -.-- 9/7/2004 20:00 - 21 :00 1.00 FISH P DECOMP Break out fish and BOT BHA equipment. 21 :00 - 22:00 1.00 FISH P DECOMP M/U BHA #3: Wash Pipe Shoe, 3 its Wash Pipe, Washover Boot Basket, XO, 3 Boot Baskets, Bit Sub, Bumper Jar, Oil Jar, 10 x 4-3/4" DCs, and Accelerator Jar. 22:00 - 00:00 2.00 FISH P DECOMP RIH BHA #3 to WIO top of blank pipe fish @ 5402'. 9/8/2004 00:00 - 02:30 2.50 FISH P DECOMP Continue to RIH to 5396'. 02:30 - 04:00 1.50 FISH P DECOMP P/U and install Kelly. P/U wt 80K, SIO wt 62K. Circulate @ 3BPM, 500 psi and returns bring oil and gas to surface. Circulate out oil and gas to pits. 04:00 - 06:00 2.00 FISH P DECOMP P/U 1 jt 3-1/2" DP and slowly wash down over blank pipe, 40 RPM, 3-5 BPM, 500 to 800 psi. Hit no-go @ - 5465'. Mix Hi-Vis sweep and reverse circulate to clean up. 06:00 - 07:00 1.00 FISH P DECOMP Reverse circulate until clean. 07:00 - 09:00 2.00 FISH P DECOMP TOH standing back 3 1/2" drill Pipe and Drill Collars. 09:00 - 10:00 1.00 FISH P DECOMP Lay down BHA #3...5 3/4" Wash Pipe. 10:00 - 10:30 0.50 FISH P DECOMP Make-up BHA #4 as follows: 5 3/4" OS w/3.656 Basket Grapple, Top Sub, Bumper Jar, Oil Jar, 10 ea 4 3/4" Drill Collars, Accelerator Jar, Pump-Out Sub. 10:30 - 12:00 1.50 FISH P DECOMP TIH with BHA #4 and 3 1/2" Drill Pipe. 12:00 - 12:30 0.50 FISH P DECOMP Pick-up Kelly. PUW = 87 k SOW = 57K. Pump rate = 3 bpm/300 psi.. Engage Fish. Pump pres increased to -1,800 psi. Shut down Pump. Pulled 40K over. Fish came free. Verify Fish is on. Set Back Kelly. 12:30 - 15:30 3.00 FISH P DECOMP TOH standing back 3-1/2" Drill Pipe and 4-3/4" Drill Collars. Fish to Surface. 15:30 - 16:00 0.50 FISH P DECOMP Break out and UD fish. Recovered 29.6' of blank pipe, 29.9' of screen section, and 8.2' of seal assy; 100% recovery. UD remainder of BHA #4. 16:00.. 17:00 1.00 FISH P DECOMP M/U BHA #5: 6-1/8" Packer Mill wI 3-1/2", 3 ea Boot Baskets, Bit Sub, Bumper Jar, Oil Jar, and 10 ea 4-3/4" DCs. Clear and clean rig floor. 17:00 - 20:00 3.00 FISH P DECOMP TIH wI BHA #5 to +1- 5462'. 20:00 - 20:30 0.50 FISH P DECOMP P/U Kelly, break circulation, tag packer @ 5462'. P/U 84K, S/O 60K. Establish milling ops parameters: 60 RPM, 4 BPM @ 500 psi, Rot Wt 70 K, Torq -5K ft Ibs. Circulate oil and gas to surface, P/U to place DP in BOPE stack and continue circulating until returns clean up. 20:30 - 00:00 3.50 FISH P DECOMP Resume milling operations wI previously established parameters. Packer pushed free @ 2200 hrs. Push packer to -5715' very easily while rotating, then hard going. Keep milling until packer pushed to 5724' 4ES RKB. RKB for original tally was 29.00'. 9/9/2004 00:00 - 01 :30 1.50 FISH P DECOMP Reverse circulate @ 4 to 5 BPM, 400 to 500 psi until returns cleaned up. 01 :30 - 03:30 2.00 FISH P DECOMP POH, SIB DP and DCs; break out and UD BHA #5. 03:30 - 04:30 1.00 FISH P DECOMP M/U BHA #6: 6-1/8" Bit, 7" csg scraper, 3 ea Boot Baskets, Bit sub, Bumper Jar, Oil Jar, 10 ea 4-3/4" Dcs. 04:30 - 06:30 2.00 FISH P DECOMP RIH wI BHA #6 to -5670'. Tagged nothing however, Packer needed to be fished out of hole so it was decided not to go any deeper with the Bit and Scraper. 06:30 - 08:30 2.00 FISH P DECOMP TOH with BHA #6. 08:30 - 09:00 0.50 FISH P DECOMP Lay down Bit and Casing Scraper. Clean Boot Baskets...some sand and metal shavings. Printed: 9120/2004 11:12:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/9/2004 9/10/2004 .r--- ~ BP EXPLORATION Operations Summary Report MPI-08 MPI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To Hours I Task Code NPT I Phase --1----_. ' 09:00 - 09:30 0.50 FISH 09:30 -11:00 11 :00 - 12:00 12:00 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 - 16:30 16:30 - 21:30 21 :30 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 00:30 00:30 - 02:30 02:30 - 03:30 03:30 - 06:00 06:00 - 07:00 07:00 - 09:00 09:00 - 09:30 09:30 - 10:00 10:00 - 12:00 12:00 - 13:00 13:00 - 14:30 14:30 - 15:00 15:00 -16:00 1.50 FISH 1.00 FISH 2.00 FISH 0.50 FISH 0.50 FISH 1.50 FISH 5.00 FISH 1.00 FISH 1.00 FISH 0.50 FISH 0.50 FISH 2.00 FISH 1.00 FISH 2.50 FISH 1.00 FISH 2.00 FISH 0.50 FISH 0.50 FISH 2.00 FISH 1.00 FISH 1.50 FISH 0.50 FISH 1.00 FISH P DECOMP P DECOMP P DECOMP P P P DECOMP DECOMP DECOMP P DECOMP P DECOMP P DECOMP P DECOMP P DECOMP P DECOMP P P DECOMP DECOMP P DECOMP P DECOMP P P DECOMP DECOMP P DECOMP P P DECOMP DECOMP P P P DECOMP DECOMP DECOMP Page 3 of 7 Start: 9/5/2004 Rig Release: 9/15/2004 Rig Number: Spud Date: 10/15/1997 End: 9/15/2004 Description of Operations ----.........-- Make-up BHA #7 as follows: 33/4' Spear w/4.010" Grapple, XO, XO, Bumper Jar, Oil Jar, 10 ea. 43/4" Drill Collars, Accelerator Jar. TIH with BHA #7 and 31/2" Drill Pipe. Tagged high unexpectedly at 5,493-ft. (232' above where the milled-up Pkr was left). Pick-up Kelly. Wash down to 5,544'. However, unable to make much progress due to Carb falling right back in behind. BHA not set-up to a major Reverse-out due ID. POOH with BHA #7. LD BHA #7. Lost Grapple from Spear. Make-up BHA #8 as follows: 27/8' x 15' Mule Shoe Stinger. XO, Bumper Jar, Oil Jar, 10 ea 4 3/4' Drill Collars TIH with BHA #8 and 3 1/2" drill Pipe (163 Jts). Tagged at 5,509'. Circulating and working pipe down. Recovered a great amount of Carbolite frac sand with sweeps and circulation. Reverse circulate and continue to recover Carbolite frac sand, taking returns to pit 1. Work pipe down to 5720', within 4' of packer. P/U and rotate 4-1/2 turns and allow pipe torque to dissipate -1-1/2 turns to neutral. Try easy spudding through 5720', but No-Joy. Mix 30 Bbl Hi-Vis sweep. Reverse circulate Hi-Vis sweep. Sweep returns carry more carbo lite to surface. -8 Bbls are captured in Pit 1. Continue to reverse until returns clear up. POH, SIB 3 stands DP, UD 1 jt and wait for 30 minutes to determine whether fill is coming in from formation. RBIH w/3 stds DP = 1 it, slowly tag same depth of 5720', no additional fill. POH and UD 1 jt and SIB DP. Breakout and UD 15' x 2-7/8" muleshoe it. Muleshoed end showed damage from "spud" attempts. Clear and clean rig floor. RIH wI BHA #9, Reverse Circ Junk Basket, 3 ea Boot Baskets, Bit Sub, Bumper Jar, Oil Jar, 10 ea DCs. Pick-up Kelly and wash/work with Reverse Circulating Junk Basket from 5,707 down to 5,724'. POOH with BHA #9. Lay down BHA. Recovered a large piece of Packer Rubber from inside Reverse Circulating Junk Basket. Empty Boot Baskets.. .some Carb-O-Lite. Make-up BHA # 10 as follows: 61/8' Packer Mill wlStinger Mill, 3 ea Boot Baskets, Bit Sub, Bumper Jar, Oil Jar, 10 ea 4 3/4' Drill Collars. TIH with BHA #10. Tag at 5,724' (top of Pkr). Pick-up Kelly. Break circulation at 3 bpm/350 psi. Stack Packer Mill out on top of Packer with Stinger Mill inside of Packer body. Pressure increased to -1,800 psi. Repeat several times with same results. Set back Kelly. POOH with BHA #10. Lay down BHA #10. Clean Boot Baskets...some Carb-O-Lite. Clear and Clean Floor. Make-up BHA #11 as follows: 3 1/4' Spear w/4.01 0' Grapple, XO, XO, Bumper Sub, Oil Jar, 10 ea 4 Printed: 9/20/2004 11:12:41 AM .r--- ~ BP EXPLORATION Page 4 of 7 Operations Summary Report Legal Well Name: MPI-08 Common Well Name: MPI-08 Spud Date: 10/15/1997 Event Name: WORKOVER Start: 9/5/2004 End: 9/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/15/2004 Rig Name: NABORS 4ES Rig Number: ; , I From - To Hours Task ¡Code NPT Phase Description of Operations -.- --.-.... --.-......- -..---- - 9/10/2004 15:00 - 16:00 1.00 FISH P DECOMP 3/4" Drill Collars, Accelerator Jar. 16:00 - 17:00 1.00 FISH P DECOMP RIHwithBHA#11. 17:00 - 18:00 1.00 FISH P DECOMP Cut and slip drilling line. 18:00 -19:30 1.50 FISH P DECOMP Cont TIH wI BHA #11. Establish parameters just above 5724', P/U wt 94K, SIO wt 60K, 3 BPM @ 400 psi. Work inside packer, pressure increased quickly to 2000 psi, indicate entry, then P/U and pulled 35K overpull; packer came free, dragging uphole. 19:30 - 22:30 3.00 FISH P DECOMP POH and SIB DP, breakout BHA #11. No Fish on Spear, No-Joy in Dog House. 22:30 - 23:00 0.50 FISH P DECOMP Confer wI Baker and Halliburton. Redress Spear wI slightly smaller (3.947" vs 4.010") grapple. 23:00 - 00:00 1.00 FISH P DECOMP RBIH wI BHA #11 wi 3.947" grapple on spear. 9/11/2004 00:00 - 01 :00 1.00 FISH P DECOMP Continue to TIH wI BHA #12. 01 :00 - 01 :30 0.50 FISH P DECOMP P/U Kelly, M/U to DP, P/U wt 94K, SIO wt 60K, 3 BPM, 250 psi. Tag packer @ 5716', work into it, watch pressure increase to 800 psi. P/U to 135K, set off jars, slack off, P/U to 150K, set off jars. Repeat several times for two its of DP out. 01 :30 - 04:00 2.50 FISH P DECOMP POH with BHA #12, SIB DP, DCs. Did not recover the fish. 04:00 - 04:30 0.50 FISH P DECOMP Change out grapple on spear to 4.207" after conferring BOT fisherman conferred wI BOT personnel. 04:30 - 06:00 1.50 FISH P DECOMP TIH wI redressed spear. 06:00 - 06:30 0.50 FISH P DECOMP Lub Rig. 06:30 - 07:30 1.00 FISH P DECOMP Finish TIH with BHA #13 and 3 1/2" drill Pipe. Tagged Fish at 5,674' (Fish in lower set of Perfs). Push Fish back down to 5,724'. 07:30 - 09:00 1.50 FISH P DECOMP Pick-up Kelly. PUW = 93K SOW = 60K. Spear Fish. Moving Fish up hole at 175K. Continue working Fish up hole 150 - 175K. Made !60'. Lost Fish. Went back to bottom at 5,724'. Attempted to latch Fish again with No-Joy. Discuss Continuing options and next attempt with Anch Eng. 09:00 - 11 :00 2.00 FISH P DECOMP POOH with 3 1/2" Drill Pipe and BHA #13. No recovery. No real signs of why we can not hang on to Fish other than we might not be able to completly "plant" the Spear Grapple. 11 :00 - 11 :30 0.50 FISH P DECOMP Make up BHA #14 as follows: Short-Catch Spear w/4.010 Grapple, XO, XO, Bumper Jar, Oil Jar, 10 ea 4 3/4" Drill Collars, Accelerator Jar. 11:30-14:00 2.50 FISH P DECOMP TIH with BHA #14 and 31/2" Drill Pipe. Pick-up Kelly. Tag fish at -5,724' (Drill Pipe plugged off just befor tagging Fish). 14:00 - 14:30 0.50 FISH P DECOMP Work Spear. No real indication the Fish is on. 14:30 - 16:30 2.00 FISH P DECOMP TOH with BHA #14 (wet). 16:30 - 17:00 0.50 FISH P DECOMP Lay down BHA #14. Recovered a Packer ring. Unplug Spear...Plugged with SB Formation sand. Clear & Clean Floor. 17:00 - 18:00 1.00 FISH P DECOMP M/U BHA #15, same as #14, make crew changeout. 18:00 - 20:00 2.00 FISH P DECOMP RIH wI BHA #15, tag fish @ 5709', and push to 5724'. Work pipe and see indication that fish has been engaged. 20:00 - 23:00 3.00 FISH P DECOMP POH. See variable amounts of overpull while POH. No fish on Short-Catch Spear. No obvious indication that spear was buried in fish. 23:00 - 00:00 1.00 FISH P DECOMP M/U 217/8" x 4-3/4" Tapered Tap as part of BHA #16: 2-7/8" x 4-3/4" Tapered Tap, Safety Joint, Bumper Jar, Oil Jar, 10 ea 4-314" DCs, Accelerator Jar. Begin to RIH. 9/12/2004 00:00 - 01 :30 1.50 FISH P DECOMP Cont to RIH and P/U Kelly to tag packer @ 5724'. Printed: 9/20/2004 11:t2:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/12/2004 9/13/2004 r--- ~ BP EXPLORA TIQN Operations Summary Report MPI-08 MPI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To I Hours I Task Code , ; -.-.--..... ......-.... 01 :30 - 02:30 02:30 - 04:30 04:30 - 05:00 05:00 - 06:00 06:00 - 06:30 06:30 - 08:30 08:30 - 09:30 09:30 - 10:00 10:00 - 12:30 12:30 - 13:00 13:00 - 14:00 14:00. 15:30 15:30 - 19:00 19:00 - 21:00 21 :00 - 21 :30 21 :30 - 22:00 22:00 - 00:00 00:00 - 03:00 03:00 - 03:30 03:30 . 04:30 04:30 - 05:30 05:30 . 08:00 08:00 . 09:30 09:30 - 10:00 10:00 - 12:00 1.00 FISH P 2.00 FISH 0.50 FISH P P 1.00 FISH P 0.50 FISH 2.00 FISH 1.00 FISH P P P 0.50 FISH P 2.50 FISH 0.50 FISH P P 1.00 FISH P 1.50 FISH P 3.50 FISH P 2.00 FISH 0.50 FISH P P 0.50 BOPSUF P 2.00 BOPSUF P 3.00 BOPSUF P 0.50 CLEAN P 1.00 CLEAN P 1.00 CLEAN P 2.50 CLEAN P 1.50 CLEAN P 0.50 EVAL 2.00 EVAL P P Start: 9/5/2004 Rig Release: 9/15/2004 Rig Number: NPT I Phase I DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Page 5 of 7 Spud Date: 10/15/1997 End: 9/15/2004 Description of Operations .-...-.-.--. Establish parameters: P/U 80K, SIO 60K, 3 BPM, 400 psi. Set down and rotate the Tapered Tap into fish. P/U to check engagement, set down and rotate. Do this several times and P/U, pulling 90 to 95K. P/U one joint, then S/O. Packer stacked out when Kelly Bushing touched floor. Repeat and rotate several mor times. Resume POH for two joints and Pulling wt is now 100 to 105K. POH and SIB DP, DCs. Part of fish came to floor, the slip setting ring for the bottom slips and one slip from the upper slip section. Clear and clean rig floor, redress Tapered Tap, prepare to RIH to pull remaining packer section. Lub Rig. TIH with BHA #17 and 3 1/2" Drill Pipe. Rig up to reverse Circulate. Reverse down 2 it of Drill Pipe to top of fish at 5,724'. Reverse bottoms up (+) until clean. Returns were a fair amount of Garb-OoLite. Lay down 1 Jt of Drill Pipe. Pick-up Kelly. PUW = 84K SOW = 64K. Work Taper Tap. POOH. Had 30K over pull coming of bottom. No recovery. Lay down Taper Tap. Marks at 3.5" 00 and 3' OD on TT indicated that there are still misc sized pieces of junk still on top of or inside of Packer (10 = 4.0"). Discuss last chance effort with Anch Eng. Make-up BHA #18 as follows: 61/8" x 4 3/4' Wash Over Shoe, WP Ext, Boot Basket, XO, Boot Basket, Boot Basket, Bit Sub, Bumper Jar, Oil Jar, 10 ea 4 3/4' Drill Collars. TIH with BHA #18 and 31/2" Drill Pipe. Tagged Junk at 5,639' (10K set-down) fell through and contine in hole with BHA and 169 Jts Drill Pipe. Pick-up Kelly and tag Fish with 169 Jts (+14' on Kelly). Bring Pump on line at 4 bpm/500 psi. Rotate on fish in an attempt to mill over andlor wash out Garb-OoLite from underneath to make more Sump for Completion Tailpipe. Made progress to 5727' with no movement after the first 45 minutes. POH and SIB DP and DCs; break out BHA #18. Breakout and UD BHA #18, empty boot baskets. Found Carbolite, steel, and bronze shavings. Pull Wear Ring and P/U & install Test Plug. Ready BOPE for testing. Chuck Shieve, AOGCC, waived the right to witness. BOPE test 250 psi low and 4000 psi high. BOPE testing. MIU BHA #19: 6-1/8' bit, Bit Sub, 1 jt 3-1/2' DP, DIP XO, 7' Casing scraper, 3 ea Boot Baskets, Bit Sub, Bumper Jar, Oil Jar, 10 ea 4-3/4' Drill Collars. RIH to cleanout to 5727'. Found no tight spots all the way down to 5727'. Reverse circulate for 2 bottoms up. POOH wI BHA #19. Stand back Drill Pipe and Drill Collars. Lay down remaining BHA. Clear and Clean Floor. Clean Pits and Cuttings Bin. SWS arrives on Location. Spot E-Line Unit. Hold PJSM with All. Rig up SWS equipment. Pick-up US IT Logging Tool. Printed: 9/20/2004 11:12:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From -To .----.---. 2.50 EV AL 9/13/2004 12:00 - 14:30 14:30 - 15:30 15:30 -16:00 16:00 - 18:30 18:30 - 19:30 19:30 - 20:30 20:30 - 00:00 9/14/2004 00:00 - 02:00 02:00 - 06:00 06:00 - 06:30 06:30 - 11 :00 11:00 -12:30 12:30 - 13:30 13:30 - 16:00 16:00 - 16:30 16:30 - 19:30 19:30 - 20:00 20:00 - 23:00 23:00 - 00:00 9/15/2004 00:00 - 01 :00 01 :00 - 02:00 02:00 - 04:00 04:00 - 06:00 ~ ~ Page 6 of 7 BP EXPLORATION Operations Summary Report MPI-08 MPI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES I Hours I Task Spud Date: 10/15/1997 End: 9/15/2004 Start: 9/5/2004 Rig Release: 9/15/2004 Rig Number: I.code - ~_~T I Phase P DECOMP 1.00 EVAL 0.50 EV AL 2.50 EVAL DECOMP DECOMP DECOMP P P P 1.00 EVAL DECOMP P 1.00 EVAL DECOMP P 3.50 EVAL DECOMP P 2.00 RIGU P RUNCMP 4.00 RUNCO RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP 0.50 RUNCO 3.00 RUNCO 1.00 RUNCO RUNCMP RUNCMP RUNCMP 1.00 RUNCO 1.00 RUNCO RUNCMP RUNCMP 2.00 RUNCO RUNCMP 2.00 RUNCO RUNCMP Description of Operations ...--..---"-'-' Run in hole with Logging Tool (FL = 718'). Tie into Atlas GRlCCL...dated 02/28/1998. Run USIT Log from 5,716 up to 5,000-ft and beyond (never did find TOC). Send copy of Log to Town for their expert interpenetraton. Lightly tag bottom. E-Line tag = 5,726' (Driller's Tag = 5,727'). Rig down SWS E-Llne. Make-up Halco 7" RTTS Packer. TIH with Packer, Drill Collars, and 3 1/2' Drill Pipe. Spot RTTS packer elements @ 5412'. Establish circulation, SI tubing, pressure up on casing to 4000 psi, and hold and record for 30 minutes. Good test. Bleed down test lines and circulate wellbore, prepare to POH and UD DP and DCs. POH and UD 3-1/2" DP and 4-3/4" DC; breakout and UD Halco RTTS packer. Clear and clean rig floor. RlU 3-1/2" completion running equipment, Nabors Torque Turn equipment. PJSM. Set up TT computer. RIH w/3-1/2", 9.2#, L-80, TCII completion, 6 ea GLMs, 2 ea 7" Baker Premier Packers, 1 Baker 7" S-3 Packer, 2 X-nipples, and 1XN-nipple. Torque-Turn all connections to 2300 ft-Ib; use Best-O-Life 2000 NM thread compound on all threads. Baker-Lok on threads below bottom packer. Lube rig. Complete RIH wI new completion. P/U landing joint, M/U to tubing hanger, land hanger, RILDS, UD landing it, RID TT equipment. RlU SWS equipment and prep for RIH wI Gr/CCL run to correlate completion string spacing. RIH wI GRICCL. Found RIA "pip" @ 5412', W/L measurement, versus 5403' 4ES RKB. All packers located in solid pipe above perfs. Top packer element @ 5416' and top of "N" sand perfs @ 5436'; 2nd packer element @ 5532' and top of "OA" sand perfs @ 5590'; Bottom packer element @ 5648' and top of "OB" sand perfs @ 5660'. RID 8WS equipment. Test lines to 3500 psi for rev circ ops. Pump 200 Bbls 140 F seawater, chase wI 200 Bbl seawater mixed w/1 Bbl corrosion inhibitor, all at 3 BPM, 200 psi. P/U and install TWC. Blow down lines, N/D BOPE, N/U Tree. Pressure test tree and void to 5000 psi. Prepare to H/U HB&R for freeze protect and packer setting. Pull TWC. RlU HB&R to freeze protect. Pressure test lines to 4000 psi. Pump 75 Bbls Diesel down annulus. Re-align valves to allow U-tube of diesel down tubing. Drop ball and wait 20 mins, pressure up tubing to 4000 psi and hold for 30 mins and record; good test. 8-3 packer set @ -2500 psi, saw slight "bobble" in pressure. Premier Packers designed to set @ 4000 psi. Bleed off tubing to 2000 psi, pressure up annulus to 4000 psi and hold for 30 mins and record. Good test. Bleed off tubing and annulus, bleed lines, install BPV and test Printed: 9/20/2004 11:12:4t AM ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: From - To -- 9/15/2004 04:00 - 06:00 ............ Operations Summary Report MPI-08 MPI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Hours I Task I Code 2.00 RUNCO Start: 9/5/2004 Rig Release: 9/15/2004 Rig Number: .~_~T I~~se -- Page 7 of 7 Spud Date: 10/15/1997 End: 9/15/2004 Description of Operations .- --.----.--. RUNCMP to 1000 psi. Prepare to RDMO. Rig Released @ 06:00 hrs, 9/15/2004. Printed: 9/20/2004 t1:12:41 AM \S'-- \S:9- MECB...I\NI CAL INTEGRITY REPORT' ...... :: ~ U D i) ~. -:::: : to/~s-'11 OPER & FIELD ..~? t-\ 't \ I''\.C \> d",\\ -W-Ž:LL NUMBER \J\\, ~ - n <t< " TD: SCì)-(J ,till,. t-td-\ S TVD; ~BTD: 5'ð5) HD' l{ ( Sç TVD . . Shoe: S~~ HD TVD i DV: dO~~'l 110 ,TVD :. ~ GaEl.. =:. ;.::: ::.: . :~ ~LL DATA _:':1e!:" : fl ~~ Shoe: }ill 'I'lD i :OF:. ..' HD :".;7) Ca.si~g: :- \.J D :i.~ g : Packe:!:' . HI) I TVD i S e ç.,'" ê. L: ::ole S:..ze S 't~6' ê..n å \0~ P e,...;: - ./ --.::I ,.1 L:O // ~ ~C?~l~IC;'~ INTEGRITY - PART /1 :" .~ ì "7r' '(j \c_J \....l \ --' r .{ \q --.L_-{ .t!. ~fi~b~r I () 7 ~ ! 1.1].", e ..:rÅi ~ : ?' :J L}.- ':Jt)~ " I"'" <.Y l- ,.c:.t 0 d v ~rJ:,r. . ~~] Pfoåuc.tion Log: ~ 0 ~ ,I IAd£ /' " ~ [. ~ONCLUS-O " - I 0 \ \" . . .!. hS: ,v ¡J '" . I.ß vi'";) - .11 (DV"J-'_ar1.. r : 0'0 ~ c"" ~ - r- .12. : 1'. ..e v-a. .... r . : ~ eJ2 ' , :/ / /; IS min . ~ 0 m~n ,,/ '\20~~ '~~~I ~::J / \ ,.. // Î,\G( .~ r(C)~D~Cr.\f,C .I ",. \" ~CR1ün.C;'.L INTEGRITY - P' -{ #1 ~ r-T 4toD\:: '6OOt C emen t: Volumes :', Þ-f. 'Line.r N b. i Cs g d 00 G i DV aoo'C- C¡¡¡t: -Jol t:o covi perfs Q. "::.O~ 'f.. S 4~ 1cX- c.~-\~ ~\\ "o.~ ~\)J ~<L~"-\-~ \-C\' ~~ The.oreticaYTOC Annulus Press Test: ~p COW!:D.ents: ~. "fl ond Log (Yes or No) f'v"" ; In AOGCC File' :::.one ë..DOVe perfs Typ.e ¡Evaluation 7ÓLr\~~S bÐ~~ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL '. 20 AAC 25.280 1, Type of Request: 0 Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Alter Casing II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Change Approved Program 0 Operation Shutdown II Perforate 0 Re-Enter Suspended Well II Other 0 Time Extension A-- ~ 1/ ~~ \'1 'I¡ÎIl~¡' ~/ ~ ~ Convert to Single Injector 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7, KB Elevation (ft): KBE = 63,84' 4. Current Well Class: a Development D Exploratory D Stratigraphic D Service 5. Permit To Drill Number 197 -192 6, API Number: 50- 029-22821-00-00 9. Well Name and Number: M PI-OS 8. Property Designation: 10. Field 1 Pool(s): ADL 025517 Milne Point Unit 1 Schrader Bluff 11. Total Depth MD (ft): 5920 Casing Structural Conductor Surface Intermediate Production Liner PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 4215 5852 4155 N/A Length Size MD TVD Burst 82' 20" 115' 115' 1490 5864' 7" 5895' 4193' 7240 Junk (measured): Fish at 5435' Collapse 470 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5436' - 5680' 3792' -4005' 2-7/8",6.5# L-80 5319' Packers and SSSV Type: Sand Screen Assembly with a HES Versatrieve Packer at Packers and SSSV MD (ft): 5381' and 5465' 5381' and a HES BWD Sump Packer at 5465' D BOP Sketch 13, Well Class after proposed work: D Exploratory D Development a Service 12. Attachments: ISI Description Summary of Proposal D Detailed Operations Program 14, Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certif at the foregoing is true and correct to the best of my knowledge. Printed Nam David Reem Title Drilling Engineer {}~ August25,2004 Date: 15. Well Status after proposed work: DOil DGas D WAG D GINJ D Plugged ISI WINJ D Abandoned D WDSPL Contact David Reem, 564-5743 I Sundry Number: Jotj-r;?7b Conditions of approval: Notify Commission so that a representative may witness 0 Plug Integrüy ~OP Test .~eChanicallntegritYTest ~ Location Clearance ..... WAT\::.Q ~ ~ \... ~ Other: ~~\>~~Q' \o,\,,\~c\- s'()\".fC-\---\'ö s,.)~~\~\~ Co.. ~\'S.~~~ ~ 'OS, x: \'. ~ ~c.... ~ I:-.... Ç>«- .-0. ~ \-- ~ '\: I'.... CJ.. c...c..a ~ ~ { Þ. \ 0 \? ~~ I, ~OCL jUl ~ 1 -\'-\0 1 ~@' gtr. Oate f64~at: Signature Phone 564-5743 Commission Use Only Date -=f/I;/04 COMMISSIONER APPROVED BY THE COMMISSION OQJG\NAI Prepared By Name/Number: Sondra Stewman, 564-4750 Project: I\.lPI-08 Conversion from ESP Producer to Selective Single Injector l'vlPI-08 Status: Producing -187 bopd. -13 bwpd. -109 GOR I'Last test 1/3/2004) Scope of \Vork: Assume work wi II be performed by Doyon I..J. I) l'vIIRU Nabors Doyon 14 2 ) Kill \Ve II 3) Pull existing ESP fFC925') and Centrilift heat trace completion ..J.) l\.-1i II & retrieve N-Sand screens 5) Bit & scraper run. and FCO to PBTD 6') Run cen1ent bond log (USIT) to \'erify cement integrity If necessary: a) Cemem squeeze b) FCO to PBTD c) Run cement bond log I'USIT) d) Perforate - See Section 12 for imervals 7) Change out tubing hanger 8) Run selective single completion & set Baker packers 9) Install ne\\' tree 10) RDI\.IO Doyon 1-1- Pressure: 7/31/200..J. 13..J.3 psi @ ..J.OOO' TVDss = 0.3..J. psi/ft (6A6 ppg) Note: During the July R\VO Nabors ..J.ES lost -236 bbls using 8A3 ppg fluids Tree: '.2 9/16" - 5M Wellhead: 11" 5M FMC Gen 6 Tbg, Hng: 2 7/S" x 11" FMC wi 2 7/S" NSCT T&B and 2.5" CIW H BPV 20" 91,1 ppf, H-40 I 115' I" KOP @ 300' Max. hole angle = 72 to 74 deg, fl 3300' to 4100' Hole anqle thru' perfs = 32 deq 2 7/S" 6,5 ppf. L-SO, S rd EUE tbg.. ( drift 10 = 2,347", cap. = 0.00592 bpf 7" 26 ppf, L-SO, Mod. Btrc. prod. casing ( drift 10 = 6.151", cap. = 0.03S3 bpf ) Pump Intake @ 3653' TVD Stimulation Summary 02/28/98 "DB" Sand - 24.2 M# of PropLok coated 16/20 Carbolite proppant behind pipe, No dye - natural color. 03/01/98 "OA" Sand - 117. M# of PropLok coated 16/20 Carbolite proppant behind pipe. Red dye was used, 03/03/98 "N" Sand - 124, M# of propLok coated 16/20 Carbolite proppant behind pipe, Blue dye was used, 07/31/98 "N" Sand - 92 M# 01 PropLok coated 16/30 Badger sand behind pipe. Perforation Summary Ref log: Sperry Sun EWR / GR LWO Size SPF Interval (TVD) 'N' Sand 4.5" 4 5436' - 5456' (3792' - 3S10') 'OA' Sand 4.5" 4 5590' - 5615' (3926' -394S') 'OB Sand -14.5" 4 5660' - 56S0' (39S7' -4005') . lPU 1-08 .,1 ----- ---¡ I 1. ~I -' L... n ~ -'j ~ ~I I=-', . . ,"1 ,:,- -,- ~ . ¡ ~ _'~L k- "~ ~ -:==ill\=" ~' ~ Orig, OF Elev, = ~r"4' (N 22Eì Orig. GL Elev, = 34 OF To 7" csg. hgr, = 31,14' (N 22E) :2 7,'8" xl" KBMM GLI\.., 179' 0 I 2097' I 7" Hawea "ES" Cementer Centnlift Heat trace I 3465' I TwO 7" x 21' short Joints from 5201' to 5242' md 2 7/S" x 1" KBI'v1M GLM I 5085' I 2-7/8" XN nipple (2,250" No-Go 10) I 5226' I Pump, 214 Stg FC925 I Model - FPMTARM 1:2 5268' Tandem Gas Separator I 5287' FRSTXAR N H6 T ancIem Seal Soctim I GSB3 DB ur;LT IL H6 PFS 5291' AFLAS/Hsr J Motor 76 HP, 1360 volt, I 5305' 34 amp, Model KMH PumpMate w/6 fin Centralizer I 5313' HES Versalneve pkr. 5381' I 5390' I 5435' I 5465' I 5470' I . - Closing sleeve ass'bly - ~ ~- .020 30488 welded screen ~1Ç HES 'BWO' sump pl,r, - HES 2,313" X nipple I I Fish in screen: 12.13' of molded seal section left inside screen assembly. Atlas AlphaJet ("big hole") charges @ T 1 7" Landing Collar (PBTO) 180 deg. phasing (EHD = 0.93", TTP = .-. 7" float collar 5.2") 7" Uoat shoe COMMENTS Drilled and Cased by Nabors 22E Completed by Nabors 4. ES Updated post tbg part Completion I Screen assembly ESP change out ~ ~~;2~/9ì 03/10/98 515/98 08104/98 08/16/03 ::¡EV. BY JBF MOO OBR M. Linder Lee Hulme . 5809' md 5852' md 5895' md MILNE POINT UNIT WELL 1-08 API NO: 50-029-22821 BP EXPLORATION (AK) Tr-ee: 3-1/8" - 5M t Wellhead: 11 II 5M FMC Gell Ô Tbg, Hng: MPI-08i Proposed Or; :F Elev. = 63,~4' (N 22E) O~,~ ~L Elev, = 34,5 DF To 7" csg, hgr. = 31,14' (N 22E) 20" 91,1 ppf, H-40 115' I" KOP @ 300' Max, hole angle = 72 to 74 deg, fl 3300' to 4100' Hole anQle thru' perfs = 32 deQ 7" 26 ppf, L-80, Mod. Btrc. prod, casing ( drift ID = 6,151 ", cap, = 0,0383 bpf ) Two 7" x 21' short joints from 5201' to 5242' 3 1/2" 9.3 ppf L-80 TCII (Drift ID = 2.867, Cap, = 0,0087 bpf) Stimulation Summary 02/28/98 "OB" Sand - 24,2 M# of PropLok coated 16/20 Carbolite proppant behind pipe, No dye - natural color, 03/01/98 "OA" Sand - 117. M# of PropLok coated 16/20 Carbolite proppant behind pipe. Red dye was used, 03/03/98 "N" Sand - 124, MIf ot propLok coated 16/20 Carbolite proppant behind pipe, Blue dye was used. 07/31/98 "N" Sand - 92 M# ot PropLok coated 16/30 Badger sand behind pipe. Perforation Summary Ref log: Sperry Sun EWR I GR LWD Size SPF Interval 'N' Sand 5436' - 5456' 'OA'Sand 5590' - 5615' 'DB Sand 5660' - 5680' (TVD) 4.5" 4 (3792' - 3810') 4.5" 4 (3926' -3948') 4.5" 4 (3987' -4005') '~'.:.¥,:. ~ .~ ,~ ~~.. .-. , ..:. ~ .; ,.' L-.J I] ~ .~ ;.; L--.J I~ CJ .~ " - L-J .~ c= . ~ ..,...",.- :~j~~:~ "-- ,. - HES X-Nipple (2.813") 0 7" HaweD "ES" Cementer Cameo 3 1 /2" x 1 1/2" Sldepocket MMG GLM 1-2000i I 2097' I 1-2200'\ HES X-Nipple (2,813") 15358' I 7" X 3 1/2" Baker Premier Packer 15400' I 3 1/2' X 1 1/2" MMG GLM 3 1/2' X 1 1/2" MMG GLM - . T' X 3 1/2" Baker Premier Packer 3 1/2' X 1 1/2" MMG GLM 3 1/2' X 1 1/2" MMG GLM - 7" X 3 1/2" Baker 8-3 Packer 3 1/2' X 1 1/2" MMG GLM 3 1/2' X 1 112" MMG GLM HES Xr,!-r\Jipple :2 75" Min. id 2, ì /2" WLEG - Atlas AlphaJet ("big hole") charges @ 180 deg. phasing (EHD = 0,93", TTP = 5,2" ) ~ 7" Landing Collar (PBTD) 7" float collar 7" float shoe COMMENTS Drilled and Cased by Nabors 22E Completed by Nabors 4 ES Updated post tbg part Completion / Screen assembly ESP change out DATE 10/20/97 03/10/98 5/5198 ::¡EV. BY JBF MDO DBR 08104/98 08/16/03 M. Linder Lee Hulme . 15424' I 15480' I 15536' I 15560' I 15616' I 15642' I 15656' I 15682' I 15728' I 15730' I 5809' md 5852' md 15895' md I MILNE POINT UNIT WELL 1-08 API NO: 50-029-22821 BP EXPLORATION (AK) . BP EXPLORATION Page 1 of 2 Operations Summa Report Legal Well Name: MPI-08 Common Well Name: MPI-08 Spud Date: 10/15/1997 Event Name: WORKOVER Start: 8/14/2003 End: 8/16/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/16/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 8/14/2003 13:00 - 14:00 1.00 MOB P PRE Scope down & lower derrick. RID rig. 14:00 - 16:30 2.50 MOB P PRE Move from H-10 to 1-08. 16:30 - 17:00 0.50 MOB P PRE Move rig mats & P/U herculite from H-10. Clear & clean H-10 rig site. 17:00 - 18:30 1.50 RIGU P PRE Lay down Herculite & rig mats. Spot in rig sub, pipe shed & ~its. Berm same. 18:30 - 20:00 1.50 RIGU ~ DECOMP Rig up. Raise & scope derrick. 20:00 - 21:00 1.00 RIGU ~ DECOMP ACCEPTED RIG @ 2000 HRS, 8/14/1003. Spot tiger tank. N/U lines to tiger tank. 21:00 - 22:30 1.50 RIGU ~ DECOMP R/U hard line to X-mas tree. M/U lubricator & pull BPV. LID lubricator. Test lines to 3500 Psi, OK. 22:30 - 00:00 1.50 KILL ~ DECOMP Hold pre-spud & PJSM. Open well. SITP 800 psi, SI Ann Pressure 940 psi. Bleed off pressure & pump down tbg. Kill well @ 5 BPM 200 psi. Had only gas returns. Pumped 220 Bbls of 2% KCI water. SD & monitor well, well dead. 8/15/2003 00:00 - 01:00 1.00 KILL P DECOMP Finish killing & circulating well. S/D & monitor well, well dead. Had no liquid ( gas only) returns during kill operation. 01:00 - 01:30 0.50 KILL P DECOMP Install TWC & test same. 01:30 - 02:30 1.00 WHSUR P DECOMP Bleed off hanger void & nipple down adapter flange & tree. 02:30 - 04:00 1.50 BOPSUF:P DECOMP N/U BOPE. 04:00 - 06:00 2.00 BOPSUF'P DECOMP Begin presure testing BOPE. LP 250 psi HP 3500 psi. Test witnessing waived by John Crisp w/AOGCC. 06:00 - 07:00 1.00 BOPSUF P DECOMP Completed BOP Test per BP and AOGCC requirement. Rig down test equipment. 07:00 - 07:30 0.50 WHSUR P DECOMP Monitor Well. Well dead. Pick-up Lubricator and pull TWC. Lay down same. 07:30 - 08:30 1.00 WHSUR P DECOMP Make-up Landing JT. BOLDS. Pull Tubing Hanger to the floor. PUW = 50K. 08:30 - 11:30 3.00 PULL P DECOMP Begin to POOH with 2 7/8" Tubing and ESP/HT Completion. Stop at 2,200-ft. End of Heat Trace. Clear floor of extra equipment for pulling Heat Trace. 11:30 - 15:00 3.50 PULL P DECOMP Resume POOH with 2 7/8" Tubing and ESP Completion. 15:00 - 16:30 1.50 PULL P DECOMP LID ESP & motor, assy. Pump appeared to have twisted shaft. 16:30 - 17:30 1.00 PULL P 'DECOMP Clear & clean rig floor. R/U to run in hole. 17:30 - 19:30 2.00 RUNCOI~ COMP M/U new ESP. Service & same. 19:30 - 20:00 0.50 RUNCOI~ COMP Pull MLE over sheave & plug in to ESP. Test same. 20:00 - 23:00 3.00 RUNCOr~ COMP Trip in hole w/2 7/8" tbg. start heat trace after running 57 jts in hole @ 2725'. Test cable. Circulate thru pump; 8 Stks @ 800 23:00 - 00:00 1.00 RUNCOI~ COMP Con't to RIH w/2 7/8" tbg w/heat trace. 8/16/2003 00:00 - 02:30 2.50 RUNCOr~ COMP Con't to RIH w/2 7/8" tbg. w/heat trace. 02:30 - 05:00 2.50 RUNCOI~ COMP Con't to RIH w/2 7/8" tbg & heat trace to 3580'. Test cable. Circ thru pump. 8 Stks @ 800 psi. 05:00 - 06:00 1.00 RUNCOI~' COMP Con't to RIH w/2 7/8" tbg w/heat trace. 06:00 - 06:30 0.50 RUNCOr~ COMP Service & lube rig. 06:30 - 11:30 5.00 RUNCOI~ COMP Finish RIH w/2 7/8" tbg w/heat trace. Filled hole, FL @ 450'. 11:30 - 12:00 0.50 RUNCOI~ COMP M/U landing jt & install heat trace & ESP penetrators. 12:00 - 16:00 4.00 RUNCOI~ COMP Make final splices on heat trace & ESP cable. 16:00 - 16:30 0.50 RUNCOI~ COMP Land 2 7/8" completion string. RILDS. 16:30 - 17:00 0.50' WHSUR P COMP Set & test TWC. 17:00 - 19:30 2.50 BOPSUF:P COMP Change rams for 5 1/2" pipe. N/D BOPE. Printed: 8/18/2003 9:21:21 AM BP EXPLORATION Page 2 of 2 Operations Summary Report Legal Well Name: MPI-08 Common Well Name: MPI-08 Spud Date: 10/15/1997 Event Name: WORKOVER Start: 8/14/2003 End: 8/16/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/16/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 8/16/2003 19:30 - 21:00 1.50 WHSUR P COMP N/U & test X-mas tree to 5000 psi. 21:00 - 21:30 0.50 WHSUR P COMP M/U lubrcator, pull TWC & install BPV. LID lubricator. 21:30 - 22:00 0.50 WHSUR P COMP 'Secure well. Release rig @ 2200 Hrs, 8/16/2003. 22:00 - 00:00 2.00 WHSUR P COMP RD & wait on matting for F-pad access road. Printed: 8/18/2003 9:21:21 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Julie Heusser, Commissioner FROM' Chuck Scheve; SUBJECT' 'Petroleum Inspector DATE: April 22, 2001 Safety Valve Tests Milne Point Unit J& I Pads Sunday Apr!l 22, 20.0!' I traveled to BPXs MPU J & I Pads and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 17 wells and 34 components with no failures. Lee Hulme performed the testing today; he demonstrated good test procedures and was a pleasure to work with. I also inspected the well houses on these pads during the SVS testing. All the wellhouses were very clean and the equipment appeared to be in excellent condition. S, ummary: I witnessed SVS testing at BPXs MPU J & I Pads. MPU J Pad, ll~wells 22 components 0 failures MPU I Pad 6wells '12 components 0 failures 23 wellhouse inspections Attachment: SVS MPU J Pad 4-22-01 CS SVS MPU I Pad 4-22-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/U~ad: Miine Point / MPU / I Pad Separator psi: LPS 140 HPS 4/22/01 Well Permit Separ Set L/P Test Test Test Date oil WAG, GIN J, Number Number PSI PSI T~p Code Code Code Passed GAS or CYCLE 9oo90o ...... 1-02 1900910 140' 100 95 P ,p L ' oIL ~-03 1900920 140 100 95 P P " OIL 1-04 1900930 140: 100 95 P P OIL 1-06 1971950 140 100 95 P e OIL i~07 19515i0 140 i06 e ' 'P OIL , 1-08 1971920 '140 100 95 P P OIL , , . Wells: 6 Components: 12 Failures: 0 Failure Rate: 0.00% Dgo Day Remarks: RJF 1/16/01 Page 1 ofl SVS MPU I Pad 4-22-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee Huime AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/PM: Milne Point / MPU / J Pad Separator psi: LPS 140 .... I~S' 4/22/01 Well Pemit Separ Set ~ Test T~t T~t Date ~ WAG, G~J, Number Number PSI PSI . Trip Code Code Code Passed GAS or ~C[~ J-0~A ~99~0 140 ~00 95 P e 0m , , , , , , J-03 1900970 140 100 95 P P OIL - , , ,, , ,, , ,, J-04 1900980 140 1~ 95 P P OIL , , ,. ,, J-05 1910950 140 100 95 p p OIL , [ , -, ,. ,, J-06 1940950 140 100 125 P P OIL J-07 ' i9i0~70 ' 140 100 '95 ~ .... P ' OIL J-08A ~99~ ~70~40 ~00 9S e' ' ~ "' 0m , , , J-09A ~ 99 ~ ~ 40 ~ 40 ~ 00 ~ ~ 0P ~ O~ J2~ 0 ~ 94~ ~00 '~40 ~ 00 ' 95 P ~ .... O~U j'_ll 1941'140 .......... J-12 1941180 . J- 18 1972200 , , , ,, . , , ,, , J-19A 1951700 , , , j-20 ~972~50 ~2~ ' ~972000 ~40' ~00"'95 P " ~ ..... 0m j-22 1981240 140 .... 1'00' '9~ P ' P OIL j.23 ,, 200~200..... ,, ,, ,, , , ,, , Wells: 11 Components: 22 Failures: 0 Failure Rate: 0.00% ~ 9o oar Remarks: RJF 1/16/01 Page 1 ofl SVS MPU J Pad 4-22-01 CS Well Compliance Report File on Left side of folder 197-'i92-0 .......... MILNE PohNT'uNIT SB 1-08 50- 029-22821-00 Z Sm le MD 05920 TVD 04215 tionDate: 3/6/98 Completed Status: 1-OIL BP EXPLORATION Current: T Name Interval 13 8709 ~'-:SP~RRy MPT/GR/EwR4 OH L DGR/EWR4-MD *-'~n 2609-5920 L DGR/EWR4-TVD ~'AL 2382-4215 L GR/CCL ~AL 5350-5479 L GR/CCL L GR/CCL-DEPTH REF L GR/CCL-PERF L GR/CCL/PERF F'tl~L 5300-5560 ~q~L 4800-5660 -F~L 5600-5700-2/28/98 ~',~AL 5450-5595 3/1/98 R M~ SR~ ~~Y 0-5920. Daily Well Ops }~//~ Was the well cored? yes ~ Sent Received 9/2/98 9/2/98 OH 9/2/98 9/2/98 OH 9/2/98 9/2/98 CH 5 3/4/98 3/9/98 O.~t-- CH 5 8/3/98 8/5/98 CH 5 3/1/98 3/5/98 CH 5 3/1/98 3/5/98 CH 5 3/1/98 3/5/98 OH 4/27/98 4/27/98 Comments: Are Dry Ditch Samples Required? yes t~__~nd Received? Analysis Description Receiv_y. gfl2.-4u~--,~- Sample SeT# . .\ , T/C/D Tuesday, April 04, 2000 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: I--IOperation Shutdown [] Stimulate [] Plugging [--I Perforate [] PulI Tubing [-IAIter Casing {~ Repair Well []Other ESP Changeout 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2341' NSL, 3936' WEL, SEC. 33, T13N, R10E, UM At top of productive interval 4145' NSL, 1170' WEL, SEC. 32, T13N, R10E, UM At effective depth 4272' NSL, 1335' WEL, SEC. 32. T13N, R10E, UM At total depth 4292' NSL, 1361' WEL, SEC. 32, T13N, R10E, UM 5. Type of well: [] Development ~--I Exploratory [--I Stratigraphic r-I service 6. Datum Elevation (DF or KB) KBE = 64' 7. Unit or Property Name Milne Point Unit 8. Well Number MPI-08 9. Permit Number / Approval No, 97-192 10. APl Number 50- 029-22821 11. Field and Pool Milne Point Unit / Schrader Bluff 12, Present well condition summary Total depth: measured 5920' feet true vertical 4215' feet Effective depth: measured 5852' feet true vertical 4155' feet Casing Length Size Structural Conductor Sudace Intermediate Production Liner Plugs (measured) Junk (measured) Fish in screen: 12.13' of molded seal section left inside screen assembly Cemented 79' 20" 250 sx Arcticset 1 5864' 7" 1260 sx PF 'E', 260 sx Class 'G', 200 sx PF 'C' MD TVD 112' 112' 5895' 4184' Perforation depth: measured true vertical 5436' - 5456', 5590' - 5615', 5660' - 5680' (Subsea) 3729' - 3746', 3862' - 3884', 3923' - 3941' Tubing (size, grade, and measured depth) 2 7/8" 6.5 ppf, L-80 to 5291' RECEIVED 70 1998 AJa8~ Oil & Gas Cons. C0J~i~lJssi0r~ Anchorace Packers and SSSV (type and measured depth) HES Versatic packer at 5381', HES 'BWD' sump packer at 5470' 13. Stimulation or cement squeeze summary Intervals treated (measured) 5436' - 5456' 0 R I G! I~,IAL Treatment description including volumes used and final pressure 91,148# of PropLok coated 16/30 Badger sand behind pipe on July 31,1998; Final tubing pressure = 5163' 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: D Copies of Logs and Surveys run [] Oil I--] Gas r-] Suspended ~r. Daily Report of Well Operations 17. I hereby ce_dify that the foregoing is true and correct to the best of my knowledge Signed ~- ~ -'X~~c"4~'~ Title Staff Technical Assistant Casing Pressure Tubing Pressure Service Date Prepared By Name/Number: Jeanne L. Haas, 564-5225 Facility Date/Time 25 Apr 98 26 Apr 98 27 Apr 98 28 Apr 98 29 Apr 98 M Pt I Pad Progress Report Well MPI-08 Page 1 Rig Nabors 5S Date 11 May 98 06:00-06:15 06:15-08:00 08:00-08:30 08:30-09:30 09:30-12:30 12:30-14:00 14:00-15:30 15:30-18:00 18:00-18:15 18:15-19:30 19:30-20:30 20:30-22:30 22:30-23:30 23:30-00:30 00:30-02:00 02:00-06:00 06:00-06:15 06:15-08:00 08:00-10:30 10:30-13:30 13:30-15:00 15:00-17:00 17:00-20:30 20:30-02:30 02:30-06:00 06:00-06:15 06:15-08:30 08:30-10:00 10:00-10:30 10:30-14:30 14:30-16:30 16:30-18:00 18:00-19:00 19:00-22:30 22:30-01:00 01:00-03:00 03:00-04:30 04:30-06:00 06:00-06:15 06:15-09:00 09:00-11:00 11:00-21:00 21:00-00:00 00:00-03:00 03:00-06:00 Duration 1/4 hr 1-3/4 hr 1/2 hr lhr 3hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1/4 hr 1-1/4 hr lhr 2hr lhr lhr 1-1/2 hr 4hr 1/4 hr 1-3/4 hr 2-1/2 hr 3hr 1-1/2 hr 2hr 3-1/2 hr 6hr 3-1/2 hr 1/4 hr 2-1/4 hr 1-1/2 hr 1/2 hr 4hr 2hr 1-1/2 hr lhr 3-1/2 hr 2-1/2 hr 2hr 1-1/2 hr 1-1/2 hr 1/4 hr 2-3/4 hr 2hr 10hr 3hr 3hr 3hr Activity Held safety meeting Rigged up Tubing handling equipment Held safety meeting Retrieved Hanger plug Circulated closed in well at 5209.0 ft Removed Xmas tree Rigged up All rams Tested All rams Held safety meeting Functioned Kill manifold Retrieved Hanger plug Removed Tubing hanger Worked stuck pipe at 5135.0 ft Pulled out of hole to 125.0 ft Rigged up Lubricator Rig waited · Equipment Held safety meeting Rig waited · Equipment Fished at 137.0 ft Fished at 137.0 ft Laid down 137.0 ft of 2-7/8in OD drill pipe Rig waited · Equipment Fished at 125.0 ft Fished at 134.0 ft Fished at 134.0 ft Held safety meeting Fished at 140.0 ft Pulled out of hole to 0.0 fl Laid down 6.5 ft of 2-7/8in OD drill pipe Fished at 143.0 ft Fished at 136.0 ft Jarred stuck pipe at 136.0 ft Pulled BHA R.I.H. to 136.0 ft Pulled BHA Removed BOP stack Installed Xmas tree Displace treatment Held safety meeting Removed Xmas tree Rigged up All rams Conducted slickline operations on Slickline equipment - Tool run R.I.H. to 136.0 ft Rigged down All rams Rigged down Travelling block Facility Date/Time 19 Jul 98 20 Jul 98 21 Jul 98 22 Jul 98 23 Jul 98 24 Jul 98 25 Jul 98 M Pt I Pad Progress Report Well MPI-08 Page Date 10:00-19:30 19:30-01:00 01:00-04:00 04:00-04:30 04:30-06:00 06:00-07:00 07:00-08:30 08:30-09:30 09:30-10:30 10:30-14:00 14:00-16:30 16:30-18:00 18:00-18:30 18:30-19:00 19:00-20:30 20:30-06:00 06:00-07:00 07:00-12:00 12:00-14:00 14:00-16:00 16:00-18:00 18:00-01:00 01:00-06:00 06:00-06:15 06:15-12:00 12:00-15:00 15:00-21:00 21:00-01:30 01:30-03:30 03:30-06:00 06:00-06:15 06:15-09:00 09:00-14:30 14:30-15:30 15:30-17:00 17:00-02:30 02:30-04:00 04:00-06:00 06:00-06:15 06:15-09:00 09:00-11:00 11:00-13:30 13:30-14:30 14:30-19:00 19:00-20:00 20:00-22:00 22:00-01:00 01:00-02:00 02:00-03:00 03:00-05:30 05:30-06:00 06:00-06:15 06:15-23:30 23:30-03:00 Duration 9-1/2 hr 5-1/2 hr 3hr 1/2 hr 1-1/2 hr lhr 1-1/2 hr lhr lhr 3-1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 9-1/2 hr lhr 5hr 2hr 2hr 2hr 7hr 5hr 1/4 hr 5-3/4 hr 3hr 6hr 4-1/2 hr 2hr 2-1/2 hr 1/4 hr 2-3/4 hr 5-1/2 hr lhr 1-1/2 hr 9-1/2 hr 1-1/2 hr 2hr 1/4 hr 2-3/4 hr 2hr 2-1/2 hr lhr 4-1/2 hr lhr 2hr 3hr lhr lhr 2-1/2 hr 1/2 hr 1/4 hr 17-1/4 hr 3-1/2 hr Activity Rig moved 100.00 % Rigged up Draw works Rigged up Surface lines Removed Hanger plug Circulated at 5209.0 ft Circulated at 5209.0 ft Circulated at 5209.0 ft Removed Xmas tree Rigged up All rams Tested All rams Removed Hanger plug Laid down 137.0 ft of Tubing Ran Tubing to 137.0 ft (2-7/8in OD) Laid down 137.0 ft of Tubing Rigged up Tubing handling equipment Laid down 2300.0 ft of Tubing Laid down 2300.0 ft of Tubing Laid down 4987.0 ft of Tubing Tested Pipe ram Ran Drillpipe to 0.0 ft (3-1/2in OD) Ran Drillpipe to 283.0 ft (3-1/2in OD) Singled in drill pipe to 5110.0 ft Singled in drill pipe to 5118.0 ft Held safety meeting Pulled Drillpipe in stands to 5118.0 ft Made up BHA no. 3 R.I.H. to 5051.0 ft Washed to 5140.0 ft Reverse circulated at 5140.0 ft Pulled BHA Held safety meeting Pulled BHA R.I.H. to 5110.0 ft Installed Swivel Washed over string at 5135.0 ft Fished at 5133.0 ft Pulled out of hole to 4994.0 ft Pulled out of hole to 3400.0 ft Held safety meeting Pulled BHA Laid down fish Serviced BOP stack Laid down fish R.I.H. to 2035.0 ft Reverse circulated at 2035.0 ft R.I.H. to 4000.0 ft Reverse circulated at 4000.0 ft R.I.H. to 5100.0 ft Reverse circulated at 5100.0 ft Washed to 5200.0 ft Installed Swivel Held safety meeting Washed to 5800.0 ft Reverse circulated at 5800.0 ft 1 06 August 98 Facility Date/Time 26 Jul 98 27 Jul 98 28 Jul 98 29 Jul 98 30 Jul 98 31 Jul 98 M Pt I Pad Progress Report Well MPI-08 Rig (null) Page Date 2 06 August 98 03:00-05:30 05:30-06:00 06:00-06:15 06:15-08:30 08:30-13:30 13:30-15:30 15:30-19:30 19:30-22:00 22:00-23:00 23:00-03:00 03:00-06:00 06:00-06:15 06:15-08:30 08:30-09:00 09:00-11:00 11:00-12:30 12:30-13:30 13:30-15:00 15:00-16:00 16:00-20:00 20:00-21:00 21:00-02:30 02:30-05:30 05:30-06:00 06:00-06:15 06:15-09:30 09:30-10:00 10:00-11:00 11:00-13:30 13:30-15:30 15:30-20:30 20:30-23:00 23:00-04:30 04:30-06:00 06:00-06:15 06:15-12:30 12:30-14:00 14:00-19:00 19:00-23:00 23:00-01:00 01:00-04:00 04:00-06:00 06:00-06:15 06:15-09:30 09:30-10:30 10:30-13:00 13:00-14:00 14:00-15:00 15:00-16:30 16:30-00:00 00:00-02:00 02:00-06:00 06:00-06:15 06:15-18:00 Duration 2-1/2 hr 1/2 hr 1/4hr 2-1/4 hr 5hr 2 hr 4hr 2-1/2 hr lhr 4hr 3hr 1/4 hr 2-1/4 hr 1/2hr 2hr 1-1/2 hr lhr 1-1/2 hr lhr 4hr lhr 5-1/2 hr 3hr 1/2 hr 1/4 hr 3-1/4 hr 1/2 hr lhr 2-1/2 hr 2hr 5hr 2-1/2 hr 5-1/2 hr 1-1/2 hr 1/4 hr 6-1/4 hr 1-1/2 hr 5hr 4hr 2hr 3 hr 2hr 1/4 hr 3-1/4 hr lhr 2-1/2 hr lhr lhr 1-1/2 hr 7-1/2 hr 2hr 4hr 1/4 hr 11-3/4 hr Activity Pulled BHA Repaired Drillstring handling equipment Held safety meeting Repaired Drillstring handling equipment Laid down 4400.0 ft of 3-1/2in OD drill pipe Serviced BOP stack Conducted electric cable operations Conducted electric cable operations Rig waited: Equipment Conducted electric cable operations R.I.H. to 1000.0 ft Held safety meeting R.I.H. to 2000.0 ft Reverse circulated at 2000.0 ft R.I.H. to 3825.0 ft Reverse circulated at 3825.0 ft R.I.H. to 4777.0 ft Reverse circulated at 4777.0 ft R.I.H. to 5525.0 ft Reverse circulated at 5525.0 ft R.I.H. to 5767.0 ft Pulled out of hole to 0.0 ft Tested BOP stack Installed Permanent packer Held safety meeting Ran Tubing in stands to 3550.0 ft Held drill (Abandonment) Ran Tubing in stands to 5465.0 ft Conducted electric cable operations Set packer at 5465.0 ft with 2500.0 psi Pulled Tubing in stands to 0.0 ft Rigged up sub-surface equipment - Other sub-surface equipment Ran Tubing in stands to 5441.0 ft Space out tubulars Held safety meeting Functioned Hydraulic packer Rigged down High pressure lines Pulled Tubing in stands to 0.0 ft Ran Tubing in stands to 5382.0 ft Tested Hydraulic packer - Via annulus Pulled Tubing in stands to 0.0 ft Ran Tubing in stands to 1100.0 ft Held safety meeting Ran Tubing in stands to 5379.0 ft Functioned Locator seal assembly Mixed and pumped 440.000 bbl of treatment Worked stuck pipe at 5379.0 ft Laid down 180.0 ft of Tubing Circulated at 5319.0 ft Laid down 5319.0 ft of Tubing Rigged down Tubing handling equipment Rigged up sub-surface equipment - Drillpipe Held safety meeting Rigged up sub-surface equipment - Drillpipe Facility Date/Time 01 Aug 98 02 Aug 98 03 Aug 98 04 Aug 98 05 Aug 98 M Pt I Pad Progress Report Well MPI-08 Page 3 Rig (null) Date 06 August 98 18:00-04:30 04:30-06:00 06:00-06:15 06:15-08:00 08:00-10:00 10:00-14:30 14:30-20:30 20:30-21:30 21:30-22:30 22:30-23:00 23:00-00:00 00:00-06:00 06:00-06:15 06:15-10:30 10:30-12:00 12:00-17:00 17:00-18:00 18:00-20:00 20:00-23:30 23:30-06:00 06:00-06:15 06:15-06:45 06:45-11:00 11:00-13:00 13:00-21:30 21:30-23:00 23:00-06:00 06:00-06:15 06:15-09:30 09:30-11:00 11:00-23:00 23:00-00:00 00:00-03:00 03:00-04:30 04:30-05:30 05:30-06:00 06:00-07:00 07:00-08:30 08:30-18:00 18:00-06:00 Duration 10-1/2 hr 1-1/2 hr 1/4 hr 1-3/4 hr 2hr 4~1/2 hr 6hr lhr lhr 1/2 hr lhr 6hr 1/4 hr 4-1/4 hr 1-1/2 hr 5hr lhr 2hr 3-1/2 hr 6-1/2 hr 1/4 hr 1/2 hr 4-1/4 hr 2hr 8-1/2 hr 1-1/2 hr 7hr 1/4 hr 3-1/4 hr 1-1/2 hr 12hr lhr 3hr 1-1/2 hr lhr 1/2 hr lhr 1-1/2 hr 9-1/2 hr 12hr Activity Ran Drillpipe in stands to 5379.0 ft Fished at 5403.0 ft Held safety meeting Jarred stuck pipe at 5403.0 ft Fished at 5403.0 ft Fished at 5403.0 ft Fished at 5438.0 ft Fished at 5438.0 ft Jarred stuck pipe at 5438.0 ft Fished at 5438.0 ft Rigged down Swivel Pulled BHA Held safety meeting R.I.H. to 5379.0 ft Serviced Main engine Conducted slickline operations on Slickline equipment - Tool run Circulated at 5379.0 ft R.I.H. to 3921.0 ft Pulled BHA R.I.H. to 5379.0 ft Held safety meeting Fished at 5447.0 ft Pulled BHA Laid down fish Laid down 5000.0 ft of 3-1/2in OD drill pipe Worked on BOP - Pipe ram Ran Tubing to 1200.0 ft (2-7/8in OD) Held safety meeting Ran Tubing to 2900.0 ft (2-7/8in OD) Rigged up sub-surface equipment - Other sub-surface equipment Ran Tubing to 5301.0 ft (2-7/8in OD) Installed Tubing hanger Installed ESP Installed Tubing hanger Removed BOP stack Installed Xmas tree Tested Xmas tree Freeze protect well - 2.000 bbl of Diesel Rig moved 0.00 % Rig moved 100.00 % I'1 FI I I__1__ ! IM (3 WELL LOG TRANSMI2WAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Loft Taylor 3001 Porcupine Dr. ,-,c-'~ Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPI-08, AK-MM-70301 September 2, 1998 - MPI-08: 2" x 5" MD Resistivi~ and Gamma Ray Logs: 50-029-22821-00 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22821-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING TltE ATTACHED COPIES OF THE TRANSMITTAL LETYER TO TltE ATYENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. ,~chorage, Alaska 99518 Date: ~'~ BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company si emm -sur, 0 F:I I I_/I I~ I~ SEFtL~I I-- E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs ~MPI-08, September 2, 1998 AK-MM-70301 1 LDWG formatted LIS tape with verification listing. API#: 50-029-22821-00 PLEASE ACKNO~DGE RECEIFr BY SIGNING AND RETURNING THE ATrACitED COPIES OF THE TRANSMITTAL LETTER TO THI*~ AITENTION OF: Sperry-Sun Drilling Services Atto: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 · Date: BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, inc. Company State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 03-Aug-98 Transmittal of Final Prints. Please sign and return copy to the following- Western Atlas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 and BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 Well Name .iServices Bluelines R/F Sepia Film MPI-08 i GPJCCL Tie-In i 1! 1 I ' ' , ~ RECEIVED Bate Alaska 0it ~ Gas L;0ns. Anchorage Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. STATE OF ALASKA ALASKA uiL AND GAS CONSERVATION COIwMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: I-qAbandon I--ISuspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate ESP Changeout 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development i--I Exploratory I--1Stratigraphic [] Service 4. Location of well at surface 2341' NSL, 3936' WEL, SEC. 33, T13N, R10E, UM At top of productive interval 4145' NSL, 1170' WEL, SEC. 32, T13N, R10E, UM At effective depth 4272' NSL, 1335' WEL, SEC. 32. T13N, R10E, UM At total depth 4292' NSL, 1361' WEL, SEC. 32, T13N, R10E, UM 12. Present well condition summary Total depth: measured 5920' feet true vertical 4215' feet Effective depth: measured 5852' feet true vertical 4155' feet Casing Length Size Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) Cemented 79' 20" 250 sx Arcticset 1 5864' 7" 1260 sx PF 'E', 260 sx Class 'G', 200 sx PF 'C' Perforation depth: measured true vertical 5436'-5456',5590'-5615',5660'-5680' (Subsea) 3729'-3746',3862'-3884',3923'-3941' Tubing (size, grade, and measured depth) 2 7/8" 6.5 ppf, L-80 to 5232' Packers and SSSV (type and measured depth) None 6. Datum Elevation (DF or KB) KBE = 64' 7. Unit or Property Name Milne Point Unit 8. Well Number MPI-08 9. Permit Number 97-192 10. APl Number 50- 029-22821 11. Field and Pool Milne Point Unit / Schrader Bluff MD TVD 112' 112' 5895' 4184' 13. Attachments [~ Description summary of proposal [-] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation April 24, 1998 16. If proposal was verbally approved Jack Hartz Name of approver 4/24/98 Date approved Contact Engineer Name/Number: Jim Spearman~564-5099 15. Status of well classifications as: C~] Oil [] Gas [] Suspended Service Prepared By Name/Number: Jeanne L. Haas, 564-5225 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed je~~ /(~..¢~ Title Staff Technical Assistant Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity~ BOPTest ~ Mechanical Integrity Test __ .... u~'~gmal Signed By Approved by order of the~omm~sslo Location clearance J Approval No..~..../J T Subsequent form ~ed 10- ~. O~ . o,:oqeC-e6 /~ ~9~~~~?~~ Commissioner 1-08 History Summary MPU 1-08 is a recently drilled Schrader Bluff well. The well was drilled and cased by Nabors 22E on 7/28/97 across the Schrader Bluff. The well was then completed on March 6, 1998 using the Frac for Sand Control method. Each fracture (in each zone) utilized a different colored resin to identify proppant flowback if it were to occur. The downhole pump failed within 4 days of initial startup and cleanouts revealed the 'N' sands as the primary failure. The upcoming RWO will be performed by Nabors 5S. The old pump will be removed, a cleanout performed, and screens will be placed across the 'N' sands (Frac-Packed) to prevent sand ingress into the wellbore. A new pump will be rerun and the well broUght back on-line. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil [] Gas [--] Suspended r--I Abandoned r--I service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 97-192 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22821 4. Location of well at surface i'-~:i'i'ii..,i~;!, ~i;i-;!i~!,i' ! ~t.....,-......-- 9. Unit or Lease Name 2341' NSL, 3936' WEb, SEC. 33, T13N, R10E, UM Milne Point Unit At top of productive interval ! -~/~_'"_~_~! ! ~ 1'~. Well Number 4145' NSL, 1170' WEb, SEC. 32, T13N, R10E, uM ..... -,,:, ,~ ~": ' ! MPI-08 At total depth , ~ ~_".: i~ .; 4292' NSL, 1361 WEb, SEC. 32, T13N, R10E, M .... - ..... 1'i. Field and Pool ' . ' Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 63.84'I ADb 025517 i' 2. Date Spudded10/15/97 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if OffshOre I 16' NO' Of c°mpletiOnsl 0/18/97 3/6/98 N/A MSLI One ~"7. Total Depth (MD+TVD) t18. P,u9 Back Depth (MD+TVD)19. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost 5920 4215 FTI 5852 4155 FT [~Yes I~NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, GR/JB, GR/CCL 23. CASING, LINER AND CEMENTING RECORD CASING SE'FI-lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1 # H-40 33' 112' 24" 250 SX Arcticset I (Approx.) 7" 26# L-80 31' 5895' 9-7/8" 1260 sx PF 'E', 260 sx Class 'G', 200 sx PF 'C' 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) 4-1/2" Gun Diameter, 4 spf 2-7/8", 6.5#, L-80 5295' MD TVD MD TVD 5436'-5456' 3792'-3810' '~6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5590 '-5615' 3926 '-3948' 5660'-5680' 3987'-4005' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 80 bbls diesel Proplok Frac, 5660'-5680' 24200# 16/20 Carbolite behind pipe Proplok Frac, 5590'-5615' 1 17000# 16/20 Carbolite behind pipe Proplok Frac, 5436'-5456' 124000# 16/20 Carbolite behind pipe 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) April 15, 1998 I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBb GAS-MCF WATER-BBb CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I I~low Tubing Casing Pressure ;CALCULATED OIL-BBb GAS-MCF WATER-BBb 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. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. SBF1 5427' 3785' TSBD 5584' 3921' TSBB 5660' 3987' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32' I hereby certify that the f°r ,~y~, .n~,g is~..rI.~ ~/~_~_rrect t° the best °f my kn°wledge, Signed T. Brent Reeves .~ ~,,~ ,/:~ ~,4.,~- t, Title Drilling Engineering Supervisor Date w~PNI~0b8r 8'~," O_"~"¢/'r, 97-192 Prepared By Name/Number: Kathy Campoamor, 564-5 122 e u be /~_~d~¢/~ Permit No. / Approval No. INSTRUCTIONS GENERAb: 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 2?.' 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 M Pt I Pad Progress Report Well MPI-08 Rig Nabors'~¢~;2. ~?- G Page Date 1 27 April 98 Date/rime 14 Oct 97 15 Oct 97 16 Oct 97 17 Oct 97 18 Oct 97 19 Oct 97 02:00-06:00 06:00-07:00 07:00-07:30 07:30-11:00 11:00-12:00 12:00-14:00 14:00-16:00 16:00-18:00 18:00-21:00 21:00-23:00 23:00-04:00 04:00-06:00 06:00-08:00 08:00-09:30 09:30-13:30 13:30-14:00 14:00-17:30 17:30-18:30 18:30-19:00 19:00-20:00 20:00-21:30 21:30-23:00 23:00-06:00 06:00-19:00 19:00-19:30 19:30-22:00 22:00-23:15 23:15-00:00 00:00-01:00 01:00-02:00 02:00-03:00 03:00-06:00 06:00-11:00 11:00-12:00 12:00-15:30 15:30-16:30 16:30-18:00 18:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-16:00 16:00-17:30 17:30-19:30 19:30-20:30 20:30-21:30 21:30-22:30 22:30-01:00 01:00-02:00 02:00-04:00 04:00-05:30 05:30-06:00 06:00-13:30 Duration 4hr lhr 1/2hr 3-1/2 hr lhr 2hr 2hr 2hr 3hr 2hr 5hr 2hr 2hr 1-1/2 hr 4hr 1/2 hr 3-1/2 hr lhr 1/2 hr lhr 1-1/2 hr 1-1/2 hr 7hr 13hr 1/2 hr 2-1/2 hr 1-1/4 hr 3/4 hr lhr lhr lhr 3hr 5hr lhr 3-1/2 hr lhr 1-1/2 hr 10hr lhr lhr 1/2 hr lhr 8-1/2 hr 1-1/2 hr 2hr lhr lhr lhr 2-1/2 hr lhr 2hr 1-1/2 hr 1/2 hr 7-1/2 hr Activity Rig moved 10.00 % Rig moved 20.00 % Held safety meeting Rig moved 30.00 % Rig moved 40.00 % Rig moved 50.00 % Rig moved 60.00 % Rig moved 70.00 % Rig moved 80.00 % Rig moved 100.00 % Rig moved 100.00 % Rig moved 100.00 % Rig moved 100.00 % Serviced Block line Racked back drill pipe Tested Divertor Racked back drill pipe Rigged up Drillstring handling equipment Held safety meeting Made up BHA no. 1 Drilled to 205.0 ft Made up BHA no. 1 Drilled to 936.0 ft Drilled to 2609.0 ft Circulated at 2609.0 ft Pulled out of hole to 906.0 ft Pulled BHA Made up BHA no. 2 Serviced Top drive R.I.H. to 1934.0 ft Reamed to 2609.0 ft Drilled to 3041.0 ft Drilled to 3962.0 ft Circulated at 3962.0 ft Pulled out of hole to 3962.0 ft Serviced Top drive R.I.H. to 3962.0 ft Drilled to 5253.0 ft Circulated at 5253.0 ft Pulled out of hole to 3800.0 ft Pulled out of hole to 3100.0 ft R.I.H. to 5253.0 ft Drilled to 5920.0 ft Circulated at 5920.0 ft Pulled out of hole to 3000.0 ft Serviced Top drive R.I.H. to 5920.0 ft Circulated at 5920.0 ft Pulled out of hole to 925.0 ft Downloaded MWD tool Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 5895.0 ft (7in OD) Facility M Pt I Pad Progress Report Well MPI-08 Page 2 Rig Nabors ~'~9~-~ Date 27 April 98 Date/Time 20 Oct 97 13:30-17:30 17:30-18:00 18:00-18:45 18:45-19:15 19:15-22:15 22:15-22:30 22:30-23:15 23:15-23:30 23:30-00:00 00:00-00:30 00:30-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-10:00 Duration 4hr 1/2 hr 3/4 hr 1/2 hr 3hr 1/4 hr 3/4 hr 1/4 hr 1/2 hr 1/2 hr 2-1/2 hr lhr lhr lhr 1/2 hr 3-1/2 hr Activity Circulated at 5895.0 ft Pumped Water based mud spacers - volume 50.000 bbl Mixed and pumped slurry - 279.000 bbl Displaced slurry - 222.500 bbl Circulated at 2097.0 ft Pumped Water based mud spacers - volume 50.000 bbl Mixed and pumped slurry - 337.000 bbl Displaced slurry - 81.000 bbl Cleared Flowline Rigged down Cement head Rigged down Divertor Installed Casing head Installed Adapter spool Installed Xmas tree Tested Xmas tree Serviced Fluid system Facility M Pt I Pad Progress Report Well MPI-08 Page 1 Rig Nabors 5~:q-C,% Date 27 April 98 Date/Time 26 Feb 98 27 Feb 98 28 Feb 98 01 Mar 98 02 Mar 98 03 Mar 98 14:00-20:00 20:00-22:00 22:00-00:00 00:00-03:00 03:00-06:00 06:00-06:30 06:30-10:30 10:30-11:00 11:00-11:30 11:30-17:30 17:30-19:00 19:00-20:00 20:00-22:00 22:00-22:30 22:30-00:30 00:30-01:00 01:00-03:00 03:00-04:30 04:30-06:00 06:00-06:30 06:30-07:00 07:00-12:00 12:00-18:00 18:00-19:00 19:00-20:00 20:00-00:00 00:00-02:00 02:00-03:00 03:00-03:30 03:30-06:00 06:00-06:30 06:30-09:00 09:00-11:30 11:30-12:00 12:00-14:30 14:30-18:00 18:00-20:00 20:00-02:00 02:00-06:00 06:00-10:00 10:00-10:30 10:30-11:00 11:00-13:00 13:00-15:30 15:30-18:00 18:00-19:00 19:00-21:30 21:30-00:00 00:00-04:30 04:30-05:00 05:00-06:00 06:00-10:30 10:30-11:00 11:00-19:00 Duration 6hr 2hr 2hr 3hr 3hr 1/2 hr 4hr 1/2 hr 1/2 hr 6hr 1-1/2 hr lhr 2hr 1/2 hr 2hr 1/2 hr 2hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 5hr 6hr lhr lhr 4hr 2hr lhr 1/2hr 2-1/2 hr 1/2 hr 2-1/2 hr 2-1/2 hr 1/2hr 2-1/2 hr 3-1/2 hr 2hr 6hr 4hr 4hr 1/2 hr 1/2 hr 2hr 2-1/2 hr 2-1/2 hr lhr 2-1/2 hr 2-1/2 hr 4-1/2 hr 1/2 hr lhr 4-1/2 hr 1/2 hr 8hr Activity Rig moved 100.00 % Rigged down Xmas tree Rigged up BOP stack Tested BOP stack Made up BHA no. 1 Held safety meeting Singled in drill pipe to 2091.0 ft Drilled installed equipment - DV collar Tested Other sub-surface equipment - Via annulus and string Singled in drill pipe to 5798.0 ft Reverse circulated at 5798.0 ft Tested Casing - Via annulus and string Reverse circulated at 5798.0 ft Serviced Block line Pulled out of hole to 200.0 ft Pulled BHA Worked on BOP - Lubricator Perforated from 5660.0 ft to 5680.0 ft Conducted electric cable operations Conducted electric cable operations Worked on BOP - Bell nipple Ran Tubing to 5166.0 ft (3-1/2in OD) Injectivity test - 160.000 bbl injected at 3500.0 psi Displace treatment Reverse circulated at 5166.0 ft Monitor wellbore pressures Reverse circulated at 5640.0 ft Reverse circulated at 5630.0 ft Injectivity test - 10.000 bbl injected at 1100.0 psi Pulled Tubing in stands to 1500.0 ft Pulled Tubing in stands to 0.0 ft Worked on BOP - Lubricator Perforated from 5590.0 ft to 5615.0 ft Worked on BOP - Bell nipple Ran Tubing in stands to 5072.0 ft Performed formation integrity test Mixed and pumped 852.000 bbl of treatment Monitor wellbore pressures Reverse circulated at 5300.0 ft Reverse circulated at 5514.0 ft Injectivity test - 4.000 bbl injected at 1100.0 psi Held safety meeting Pulled Tubing in stands to 0.0 ft Worked on BOP - Lubricator Perforated from 5436.0 ft to 5456.0 ft Worked on BOP - Bell nipple Ran Tubing in stands to 4950.0 ft Performed formation integrity test Mixed and pumped 894.000 bbl of treatment Reverse circulated at 4950.0 ft Monitor wellbore pressures Monitor wellbore pressures Ran Tubing to 5110.0 ft (3-1/2in OD) Washed to 5602.0 ft Facility M Pt I Pad Progress Report Well MPI-08 Page 2 Rig Nabors$ffcJEc~ Date 27 April 98 Date/Time 04 Mar 98 05 Mar 98 06 Mar 98 19:00-22:00 22:00-04:00 04:00-06:00 06:00-06:15 06:15-06:30 06:30-07:30 07:30-13:00 13:00-16:15 16:15-16:30 16:30-17:30 17:30-18:00 18:00-20:30 20:30-22:00 22:00-23:00 23:00-04:00 04:00-06:00 06:00-06:15 06:15-06:30 06:30-07:00 07:00-07:30 07:30-09:30 09:30-12:30 12:30-15:00 15:00-16:45 16:45-17:00 17:00-03:00 03:00-04:00 04:00-06:00 06:00-08:00 08:00-08:45 08:45-09:00 09:00-10:00 10:00-12:00 12:00-13:00 13:00-13:30 13:30-15:00 Duration 3hr 6hr 2hr 1/4 hr 1/4 hr lhr 5-1/2 hr 3-1/4 hr 1/4 hr lhr 1/2 hr 2-1/2 hr 1-1/2 hr lhr 5hr 2hr 1/4 hr 1/4 hr 1/2 hr 1/2hr 2hr 3hr 2-1/2 hr 1-3/4 hr 1/4 hr 10hr lhr 2hr 2hr 3/4 hr 1/4 hr lhr 2hr lhr 1/2 hr 1-1/2 hr Activity Circulated at 5602.0 ft Laid down 5602.0 ft of Tubing R.I.H. to 4500.0 ft Held safety meeting Serviced Draw works R.I.H. to 5602.0 ft Washed to 5785.0 ft Reverse circulated at 5785.0 ft Flow check Laid down 1409.0 ft of 3-1/2in OD drill pipe Serviced Drillstring handling equipment Laid down 4156.0 ft of 3-1/2in OD drill pipe Pulled BHA Rigged up Tubing handling equipment Ran Tubing to 5100.0 ft (2-7/8in OD) Pulled Tubing in stands to 400.0 ft Held safety meeting Serviced Draw works Pulled Tubing in stands to 0.0 ft Retrieved Wear bushing Installed Electrical submersible pumps Installed Pressure gauge Ran Tubing in stands to 2973.0 ft Rigged up sub-surface equipment - Electric cable Held safety meeting Ran Tubing in stands to 5232.0 ft Rigged up Tubing hanger Installed Electric cable Installed Electric cable (cont...) Ran Tubing on landing string to 5294.0 ft Installed Hanger plug Removed BOP stack Installed Xmas tree Tested Xmas tree Retrieved Hanger plug Freeze protect well - 80.000 bbl of Diesel SP}~-~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING MPU / MPI-08 500292282100 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 4/97 PAGE DATE OF SURVEY: 101897 MWD SURVEY JOB NUMBER: AK-MM-70301 KELLY BUSHING ELEV. = 63.84 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -63.84 112.00 112.00 48.16 202.12 202.11 138.27 300.96 300.94 237.10 387.68 387.64 323.80 0 0 52 4 14 N .00 E .00 .00N .00E N .00 E .00 .00N .00E N 87.09 W .97 .03N .68W S 83.42 W .27 .03S 2.36W S 80.63 W .19 .28S 4.10W .00 .00 .57 1.89 3.16 477.27 477.21 413.37 1 30 565.85 565.75 501.91 1 34 657.28 657.15 593.31 1 36 746.22 746.05 682.21 1 55 837.80 837.54 773.70 2 54 N 85.60 W .47 .35S 6.23W 4.85 N 75.82 W .30 .04N 8.57W 6.97 N 79.14 W .11 .59N ll.05W 9.30 N 55.26 W .89 1.67N 13.50W 11.92 N 50.13 W 1.09 4.03N 16.54W 15.77 931.36 930.92 867.08 4 5 1022.69 1021.89 958.05 5 54 1115.32 1113.74 1049.90 8 53 1204.79 1201.64 1137.80 12 31 1299.19 1293.25 1229.41 15 21 N 47.46 W 1.28 7.80N 20.81W 21.44 N 49.97 W 2.01 13.03N 26.81W 29.37 N 52.84 W 3.24 20.42N 36.17W 41.28 N 52.85 W 4.07 30.46N 49.42W 57.90 N 57.07 W 3.18 43.45N 68.08W 80.63 1390.13 1380.95 1317.11 15 20 1481.18 1468.29 1404.45 17 23 1574.20 1556.19 1492.35 20 46 1665.45 1641.31 1577.47 21 26 1755.57 1724.64 1660.80 23 18 N 57.41 W .10 56.47N 88.32W N 56.42 W 2.28 70.49N 109.81W N 54.35 W 3.69 87.80N 134.81W N 52.86 W .94 107.30N 161.25W N 54.46 W 2.18 127.61N 188.89W 104.67 130.30 160.70 193.55 227.84 1849.61 1810.25 1746.41 1941.82 1891.86 1828.02 2035.21 1970.82 1906.98 2126.50 2044.63 1980.79 2215.79 2114.01 2050.17 25 31 29 54 34 35 37 29 40 31 N 55.90 W 2.44 149.79N 220.81W N 55.26 W 4.76 174.04N 256.17W N 52.11 W 5.32 203.61N 296.25W N 51.93 W 3.18 236.66N 338.58W N 51.81 W 3.39 271.35N 382.78W 266.71 309.57 359.38 413.04 469.19 2309.67 2183.48 2119.64 2399.26 2246.09 2182.25 2494.43 2309.25 2245.41 2543.19 2340.90 2277.06 2607.34 2381.25 2317.41 44 0 47 19 49 30 49 33 52 28 N 51.75 W 3.71 310.41N 432.37W N 51.77 W 3.71 35~.06N 482.69W N 53.17 W 2.54 393.40N 539.13W N 52.86 W .50 415.72N 568.76W N 53.01 W 4.56 445.77N 608.55W 532.26 596.27 667.40 704.48 754.33 2696.78 2434.57 2370.73 54 18 2789.98 2487.95 2424.11 55 48 2883.21 2538.44 2474.60 58 35 2976.55 2585.60 2521.76 60 41 3070.06 2628.74 2564.90 64 20 N 54.05 W 2.25 488.43N 666.29W N 53.14 W 1.80 533.77N 727.77W N 54.47 W 3.22 580.04N 791.01W N 54.96 W 2.28 626.55N 856.75W N 56.42 W 4.15 673.29N 925.27W 826.12 902.50 980.86 1061.39 1144.30 ORIGINAL PAGE 2 SP~'-'-EY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING MPU' / MPI-08 500292282100 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 4/97 DATE OF SURVEY: 101897 MWD SURVEY JOB NUMBER: AK-MM-70301 KELLY BUSHING ELEV. = 63.84 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3163.11 2666.08 2602.24 68 19 N 56.97 W 4.31 720.07N 996.49W 1229.43 3256.01 2698.28 2634.44 71 5 N 57.60 W 3.05 767.16N 1069.80W 1316.43 3349.99 2725.77 2661.93 74 52 N 57.13 W 4.05 815.62N 1145.46W 1406.14 3442.08 2749.92 2686.08 74 43 N 57.33 W .27 863.72N 1220.19W 1494.89 3530.16 2773.52 2709.68 74 11 N 57.67 W .71 909.31N 1291.76W 1579.60 3622.62 2799.56 2735.72 73 5. N 56.75 W 1.52 957.35N 1366.33W 1668.19 3716.58 2827.08 2763.24 72 49 N 57.00 W .38 1006.45N 1441.57W 1757.93 3807.46 2852.75 2788.91 74 21 N 56.23 W 1.87 1054.42N 1514.36W 1845.02 3898.18 2877.35 2813.51 74 10 N 55.42 W .88 1103.46N 1586.60W 1932.30 3994.76 2904.60 2840.76 73 3 N 55.01 W 1.23 1156.32N 1662.69W 2024.94 4088.00 2932.43 2868.59 72 13 N 55.89 W 1.27 1206.79N 1735.98W 2113.90 4178.92 2962.01 2898.17 69 48 N 53.81 W 3.42 1256.27N 1806.27W 2199.85 4268.61 2995.34 2931.50 66 33 N 53.35 W 3.67 1305.69N 1873.27W 2283.10 4361.28 3033.93 2970.09 64 13 N 52.34 W 2.70 1356.56N 1940.40W 2367.31 4453.68 3076.39 3012.55 61 3 N 52.42 W 3.42 1406.65N 2005.40W 2449.32 4547.09 3124.07 3060.23 57 32 N 51.32 W 3.90 1456.22N 2068.57W 2529.56 4639.74 3176.17 3112.33 54 1 N 50.85 W 3.82 1504.33N 2128.18W 2606.05 4733.46 3234.12 3170.28 49 33 N 51.85 W 4.83 1550.33N 2185.66W 2679.58 4824.97 3295.75 3231.91 45 45 N 51.82 W 4.15 1592.12N 2238.83W 2747.15 4916.75 3362.02 3298.18 41 46 N 51.30 W 4.36 1631.57N 2288.55W 2810.55 5007.94 3431.99 3368.15 37 58 N 51.43 W 4.16 1668.06N 2334.21W 2868.94 5100.85 3506.88 3443.04 34 34 N 51.84 W 3.68 1702.18N 2377.30W 2923.84 5189.32 3580.82 3516.98 32 1 N 53.71 W 3.11 1731.58N 2415.95W 2972.39 5282.15 3659.81 3595.97 31 21 N 53.46 W .72 1760.53N 2455.19W 3021.15 5373.84 3738.59 3674.75 30 10 N 53.58 W 1.29 1788.42N 2492.91W 3068.05 5468.03 3820.12 3756.28 29 54 N 52.68 W .56 1816.71N 2530.63W 3115.20 5563.69 3903.15 3839.31 29 38 N 52.22 W .37 184~.66N 2568.30W 3162.68 5657.45 3984.83 3920.99 29 10 N 52.22 W .49 1873.87N 2604.69W 3208.70 5755.35 4070.48 4006.64 28 45 N 52.58 W .47 1902.79N 2642.25W 3256.08 5850.37 4153.81 4089.97 28 42 N 51.79 W .40 1930.80N 2678.33W 3301.73 5920.00 4214.88 4151.04 28 42 N 51.79 W .03 1951.49N 2704.61W 3335.15 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3335.15 FEET AT NORTH 54 DEG. 11 MIN. WEST AT MD = 5920 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 305.82 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 5,920.00' MD PAGE 3 SP~ ~Y-SUN DRILLING SERVICES ANCHOR3~GE ALASKA SHARED SERVICES DRILLING MPU / MPI-08 500292282100 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 4/97 DATE OF SURVEY: 101897 JOB NUMBER: AK-MM-70301 KELLY BUSHING ELEV. = 63.84 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -63.84 .00 N .00 E 1000.00 999.32 935.48 11.53 N 25.02 W 2000.00 1941.53 1877.69 191.75 N 280.72 W 3000.00 2596.92 2533.08 638.29 N 873.61 W 4000.00 2906.13 2842.29 1159.20 N 1666.80 W .00 .68 .68 58.47 57.79 403.08 344.62 1093.87 690.79 5000.00 3425.74 3361.90 1665.01 N 2330.38 W 5920.00 4214.88 4151.04 1951.49 N 2704'.61 W 1574.26 480.38 1705.12 130.87 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SP? '~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MPU / MPI-08 500292282100 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 4/97 DATE OF SURVEY: 101897 JOB NUMBER: AK-MM-70301 KELLY BUSHING ELEV. = 63.84 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 -63.84 63.84 63.84 .00 163.84 163.84 100.00 263.85 263.84 200.00 363.87 363.84 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .01 N .10 W .00 .00 .05 N 1.66 W .01 .01 .20 S 3.59 W .03 .02 463.90 463.84 400.00 563.93 563.84 500.00 663.97 663.84 600.00 764.02 763.84 700.00 864.13 863.84 800.00 .38 S 5.88 W .03 N 8.52 W .62 N 11.23 W 2.01 N 13.99 W 4.89 N 17.56 W .06 .03 .09 .04 .13 .04 .18 .O5 .29 .11 964.36 963.84 900.00 1064.92 1063.84 1000.00 1166.19 1163.84 1100.00 1268.76 1263.84 1200.00 1372.39 1363.84 1300.00 9.41 N 22.56 W 16.10 N 30.58 W 25.74 N 43.18 W 39.14 N 61.58 W 53.95 N 84.37 W .52 .23 1.08 .56 2.35 1.27 4.92 2.58 8.55 3.63 1476.52 1463.84 1400.00 1582.39 1563.84 1500.00 1689.65 1663.84 1600.00 1798.26 1763.84 1700.00 1909.76 1863.84 1800.00 69.72 N 108.65 W 89.49 N 137.17 W 112.64 N 168.30 W 137.43 N 202.63 W 165.19 N 243.35 W 12.68 4.12 18.55 5.87 25.81 7.27 34.42 8.60 45.92 11.51 2026.78 1963.84 1900.00 2150.86 2063.84 2000.00 2282.61 2163.84 2100.00 2425.45 2263.84 2200.00 2579.18 2363.84 2300.00 200.72 N 292.50 W 245.91 N 350.38 W 298.88 N 417.75 W 361.98 N 497.81 W 432.44 N 590.88 W 62.94 17.01 87.03 24.09 118.77 31.74 161.61 42.84 215.33 53.73 2747.17 2463.84 2400.00 2932.34 2563.84 2500.00 3157.13 2663.84 2600.00 3494.57 2763.84 2700.00 3848.57 2863.84 2800.00 512.57 N 699.44 W 604.44 N 825.26 W 717.05 N 991.84 W 890.99 N 1262.83 W 1076.46 N 1547.24 W 283.33 67.99 368.50 85.18 493.29 124.78 730.73 237.45 984.73 254.00 4184.15 2963.84 2900.00 4427.32 3063.84 3000.00 4618.54 3163.84 3100.00 4778.41 3263.84 3200.00 4919.19 3363.84 3300.00 1259.17 N 1810.23 1392.51 N 1987.03 1493.45 N 2114.79 1571.16 N 2212.18 1632.58 N 2289.81 W 1220.31 235.58 W 1363.48 143.17 W 1454.70 91.22 W 1514.57 59.87 W 1555.35 40.78 !Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MPU / MPI-08 500292282100 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 4/97 DATE OF SURVEY: 101897 JOB NUMBER: AK-MM-70301 KELLY BUSHING ELEV. = 63.84 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 DIFFERENCE VERTICAL CORRECTION 5047.93 3463.84 3400.00 1683.11 N 2353.14 W 1584.09 5169.21 3563.84 3500.00 1725.16 N 2407.30 W 1605.37 5286.87 3663.84 3600.00 1761.99 N 2457.16 W 1623.03 5403.05 3763.84 3700.00 1797.13 N 2504.72 W 1639.21 5518.45 3863.84 3800.00 1831.95 N 2550.61 W 1654.61 28.74 21.28 17.66 16.18 15.40 5633.41 3963.84 3900.00 1866.68 N 2595.42 W 1669.57 5747.77 4063.84 4000.00 1900.58 N 2639.35 W 1683.93 5861.81 4163.84 4100.00 1934.19 N 2682.65 W 1697.97 5920.00 4214.88 4151.04 1951.48 N 2704.61 W 1705.12 14.95 14.36 14.04 7.15 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS Transmittal State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 of Final Prints. Please sign and return copy to: Western 'Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 04-Mar-98 Well Name Services Bluelines 'R/F Sepia Film MPI-08 GR/CCL PERF 1 1 0 :! Date Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to' Western ~,ltas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 :.Well Name Services Bluelines R/F Sepia 01-Mar-98 Film ;MPI-08 GR/CCL PERF 1 1 0 iMPI-08 GR/CCL PERF 1 1 0 i MPI-08 iGR/CCL DEPTH DET. : 1 1 0 -! .: ,. ,,: · .. :. Date Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. TONY KNOWLE$, GOVERNOR ~ALASKA OIL AND GAS CONSERVATION COMMISSION October 8. 1997 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Chip Alvord Senior Drilling Engineer BP Exploration (Alaska) Inc. POBox196612 Anchorage, AK 99519-6619 Milne Point Unit MPI-08 BP Exploration (Alaska). Inc. Permit No. 97-192 Sur. Loc. 2341 'NSL, 3936'WEL. Sec. 33. T13N. R10E. UM Btmnhole Loc. 4298'NSL. 1362'WEL. Sec. 32. T13N. R10E. UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed betbre drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. / o eft . Christenson Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .... STATE OF ALASKA ALASKA ~,,L AND GAS CONSERVATION CON.,.,~ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen ['-I 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 KBE = 64' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025517 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2341' NSL, 3936' WEL, SEC. 33, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 25100302630-277 4153' NSL, 1162' WEL, SEC. 32, T13N, R10E, UM MPI-08 At total depth 9. Approximate spud date Amount $200,000.00 4298' NSL, 1362' WEL, SEC. 32, T13N, R10E, UM 10/09/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025906, 1362'I No Close Approach 2555 5924' MD / 4191' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 500' MD Maximum Hole Angle 74.14° Maximum surface 1294 psig, At total depth ('rVD) 3698' / 1663 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 9-7/8" 7" 26# L-80 BTC-Mod 5893' 31' 31' 5924' 4191' 1216 sx PF 'E', 263 'G', 200 sx PF 'C' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate ~-, ~., ;~ Production '~ ;' '~ Liner Alas?,a 0il & Gas C0r~s, Perforation depth: measured Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Robertson, 564-5159 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAIvord ..~ ¢, (~ Title Senior Drilling Engineer Date .~lA~r~ Commission Use Only ,,, Permit Number I APl Number I Approv, al p...ate I See cover letter ~-/'~'.~.~ 50- 4:~ 2_ 9- ~-- ~ ~2'.~._ / / ~l~/~q for other requirements Conditions of Approval: Samples Required []Yes [] No Mud Log Required~ ~ -- []Yes ~ No Hydrogen Sulfide Measures []Yes ~]No Directional Survey Required ~Yes [] No Required Working Pressure for BOPE I~I2M; [-13M; l-ISM; I--IIOM; I-I15M Other: ORIGINAL SIGNEDBY by order of Approved By Robert N. Christenson Commissioner the commission Date / Form 10-401 Rev. 12-01-85 Submit 'iplicate Shared Services Drilling Contact: I Well Name: James E. Robertson IMP 1-08 Well Plan Summary IType of Well (producer or injector): ISCHRADER BLUFF PRODUCER 564-5159 Surface Location: 2341 FSL, 3936 FEL, S33 T13N R10E UM Target Location: 4153 FSL, 1162 FEL, S32 T13N R10E UM Bottom Hole Location: 4298 FSL, 1362 FEL, S32 T13N R10E UM I AFE Number: 1337106 I I Estimated Start Date: 109 OCT 97 I IMD: 15924, I ITvD: J Well Design: Formation Markers: Rig: Nabors 22E Operating days to complete: 4191' I 16.0 I KBE: 64.0 ft Schrader Bluff Producer Formation Tops MD TVDSS KOP Base of Permafrost 1884 1839 Top of Ugnu 4833 3278 Top M Sand 5130 3505 Top NA (Target) 5428 3762 Top of Schrader Bluff Sands (EMW 8.6 ppg) NB 5455 3785 NCND 5498 3822 NE 5520 3841 NF 5579 3892 OA 5625 3932 OA4 5662 3964 OB 5700 3997 Top of Seabee 5724 4018 Base of Schrader Bluff Sands (EMW 8.3 ppg) TD 5924 4191 TD at 200' MD past base of Schrader Casin.I/Tubing Program: Hole ~;ize Csg'/ Wt/Ft Grade Conn. Length Top Bottom Tbg O.D. MDrrVD MD/TVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112'/112' 9-7/8" 7" 26# L80 BTC-MOD 5893' 31 '/31' 5924' / 4191' Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/ft) to the reservoir at ___3698' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1663 psi (8.65 ppg EMW), is 1294 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: MWD from surface to TD LWD (GR/Resistivity/Neutron Density) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr through the Ugnu and Schrader Bluff intervals from 5428' - 5724' MD. Cased Hole Logs: NONE Mudloggers are NOT required for this well. Mud Program: Spud Mud ISpecial design considerations ISee "Drilling Hazards and Risks" section about dealing with the possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 80 15 8 10 9 10-15 (initial) to to to to to to to 10.2 100 35 15 30 10 8-10 (final) TOP OF SCHRADER BLUFF TO TD: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to 9.8 80 20 10 20 9.5 6 (as required) Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Line. A CompletionANorkover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1500' MD Maximum Hole Angle: Close Approach Well: t 74.14° NONE Waste Management: Cuffings Handling: All cuttings will be hauled to the CC-2A facility. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection.?~ ,.~ _,, ~.~ ¢.~. ~ .~"~ ~'...' ~; !"~..i .~-'~' Annular Injection: No wells on I-Pad have been permi~ed for annular injection. MP 1-08 Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. N/U and function test 21-1/4" Hydril MSP 2M diverter system. Build Spud Mud. 5. Drill 9-7/8" surface hole as per directional plan to 5924' MD / 4191' TVD. Run Directional MWD from surface to TD and run LWD GR/Resistivity/Neutron Density from the top of the Ugnu to TD. NOTE: Fill hole with mud and check diverter for leaks before spudding in. NOTE: Short trip no deeper than 300' md past the base of permafrost. NOTE: Utilize lubricants as necessary to enhance sliding performance. NOTE: Drill at a controlled rate of no more than 200 ft/hr through the Ugnu and Schrader Bluff sands to ensure good LWD readings. 6. At TD, make a wiper trip to the last bit trip depth and condition the hole, making sure to record any tight spots. 7. POOH and LD BHA. 8. Run and cement 7", 26#, L-80, BTC-Mod casing. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 200' MD below the permafrost. 9. N/D Diverter. N/U FMC Gen 6 Wellhead and Tree. Note that MP 1-08 will have 2-7/8" tubing. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) DRILLING HAZARDS AND RISKS: See the latest Milne Point I-Pad Data Sheet prepared by Pete Van Dusen for information on I pad. Particularly close attention should be paid to hydrate experiences on previous I-Pad wells. 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. 1. Hydrates: HYDRATES WERE ENCOUNTERED ON THE WELLS RECENTLY DRILLED ON MILNE POINT 'H' PAD DURING THE SUMMER OF 1997. H PAD IS RELATIVELY CLOSE TO I PAD AND HYDRATES WERE ENCOUNTERED ON I PAD WHILE DRILLING 1-05. PLAN ON LECITHIN TREATMENT AS WELL AS WEIGHTING UP TO AN APPROPRIATE MUD WEIGHT TO MANAGE THE HYDRATES. 9.8 PPG WORKED ON MP H-14, MP H-10, H-11i, AND H-12 THROUGH THE HYDRATE ZONE. The cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MP 1-08. 3. Lost Circulation: Lost circulation has been experienced while running casing. Maintain slow, steady running speeds while running casing and ensure mud is in good shape before POOH to run casing. LCM should be kept on hand, particularly if the mud is weighted up to counteract gas cut mud due to hydrates. 4. Stuck Pipe Potential: No stuck pipe incidents have occurred on I Pad to date. If heavy gravels are encountered while drilling the surface hole section, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. The past few wells on Milne Point 'H' Pad have encountered severe tight hole problems; especially swabbing problems while POOH. We will utilize a 9-7/8" bit to give a little more annular clearance between the hole and BHA in an effort to minimize the swabbing problem. We will also break circulation at the first indication of swabbing on short trips. 5. Formation Pressure: The expected pore pressure for this well is 8.6 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. 6. Directional Drillinq Concerns Due to the relatively shallow depth of the Schrader Bluff wells and the large stepouts, some directional drilling will have to be done in the permafrost. Note that care must be taken when drilling through the base of the permafrost as severe doglegs may develop. 7. Cement Because of the single casing string, the cement jobs will be critical to the success of the Schrader wells. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Drilling Engineer. Plan on using a 'C' cement for the second stage tail cement due to probability of hydrates. MP 1-08 7" SURFACE/PRODUCTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP: ~ 80°F SPACER: 50 BBL Weighted Spacer (Weighted to TD mudweight). STAGE1 LEAD: TYPE 'E' PERMAFROST ADDITIVES: WEIGHT: APPROX #SACKS: FLOCELE (0.25 #/sk) 12.0 ppg YIELD: 2.17 ft3/sk MIX WATER: 11.63 gal/sk 462 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE TOP OF THE STAGE1 TAIL AT 4630' MD TO THE ES CEMENTER STAGE TOOL (2100' MD > 200' MD BELOW BASE OF PERMAFROST) + 50% EXCESS. STAGE1 TAIL CEMENT TYPE: ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: PREMIUM SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%), CBL (0.1 #/sk), FLOCELE (0.1 #/sk) 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 263 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30 mins @ 80°F FREE WATER: TAIL CEMENT FROM TD (5924' MD) TO 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (5130' MD) + 50% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. EST TOC 4630' MD SPACER: STAGE2 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: 50 BBL Weighted Spacer (To weight of mud circulated before pumping Stage2). TYPE 'E' PERMAFROST Retarder 12.0 ppg 754 SACKS YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM TOP OF STAGE2 TAIL AT 1547' MD TO SURFACE +300% EXCESS. STAGE2 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'C' PERMAFROST YIELD:0.95 ft3/sk MIX WATER: 3.60 gal/sk 200 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 552' OF ANNULAR VOLUME AT 30% EXCESS FROM ES CEMENTER AT 2100' MD. EST TOP 'C' 1547' MD Retarder 15.6 ppg WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers - one (1) per joint on the bottom twenty-three (23) joints of 7" casing. Run two centralizers on the bottom joint of casing and on the top centralized joint of casing as well. (23+2 = 25 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Aisc perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8.0-10.0 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is not necessary. DISPLACEMENT OF CEMENT: Because Nabors 22E will be moving off of the well after the cement job, displacement fluid is an important consideration as the fluid will be left in the hole for some time. The proposed displacement procedure is as follows: 1. Pump away first stage as per the detailed cement program and displace with seawater a volume equal to the capacity of the 7" casing from TD up to the ES Cementer at 2100' md followed by mud weighted to the weight used to drill the hydrate section of the hole. 2. After bumping the plug, quickly check to ensure that the floats are holding and then shear the ES cementer to the open position. 3. Circulate the weighted mud through the ES cementer for two hours to clean and condition contaminated cement. 4. Pump the second stage as per the detailed cement program. When cement returns are seen at surface, drop the second stage plug and displace with diesel. The completion rig will recover the diesel freeze protection fluid for reuse on another well. Anad~ill Schlumberger Alaska District 111[ East 80th Avenue A~cl~Dra~e, A~ 99518 DIRECTIO14AL NEL~ PLAN for SHARED SERVICES DRILLING 5egaf Description Surface ...... : 2341 FSL 3936 FEL S33 T13N RIOE UM LOCATIONS - A/~ASKA Zone: X-Coord 551(34.44 54891~.00 ¥-Coord 6009455,~5 6011150.00 601139~.64 P~epared ..... : 17 Sep 1997 Vert sect az,: 305-82 KB elevation.: 64.00 ft Mmgaetic ~c~n: +2V,936 Scale Factor.: 0.99990301 Convergence..: +0.395[463 PROPOSED ANADRILL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION PLAN # ":": (, STATIOH MEASUREO ~NC~N DIRECTION VErTICAL-DEPTHS SECTION OOORDINAT~S-FROM ALASKA Zone 4 TOOL DL/ IDENTIFICATION DEPT"K A.~GGS AZI~JTH TVD SUB-SEA DEPART ~ellhead X Y PACE 100 i--i KB 0.00 fl,00 0.OO O.OO -64.00 0.00 0.00 ~ 0.00 E $51%3(.4( 6009~55.%5 8S 0.00 KOP/B~Ir.~ 1/100 500.00 ~,00 0.00 500.00 ~36.00 -0.00 0.00 N ~.00 E 551(~(.(( 6009%~S.45 54L 0.00 600.00 1,00 305.82 599.99 535.99 0.87 0.Si ~ 0.71 W 55t(33.73 6009455.96 54L BUXLD 1.5/100 ?00.00 2.00 305.82 699.96 635.~6 3.49 2.04 N 2.85 W 551(31.60 6009~57.4~ 54L 1.00 800.00 3.$0 305.82 799.84 735.84 8.29 4.~5 N 6,72 W 551(2~.69 6009460.25 545 .' /~LD 2/100 900.00 5.00 305.82 899.56 835-56 15.70 9-19 N 12.73 N 551(21.65 600946t.55 54L 1.50 :' ~ ..... 1000.00 7.00 305.82 999.01 955.01 26.L5 15.3i N 2L.20 N 551413.13 6009470.61 KS 2.00 ~'';' 1100,00 9.00 305.82 1098.03 ~0~(.03 40,07 23.45 N 39,49 W 551401.79 6009408.67 KS 2-00 = ~U. ILD 2.5/100 1200.00 [l,O0 505.82 1196.~1 1132.51 $7.43 33.61 N 46_57 W 5513~7.65 6e09488.74 ~S 2.00 ,. 1300.00 13-50 305.82 1294.22 [230 22 75.65 46,0~ N 63.77 W 551370,36 6009501.04 KS 2.50 '~'~ ~:'~; 1400.00 [6.00 505.82 1390.92 1326.92 104.11 6~.93 ~ 84.41 W 551349.62 6009515.79 ES 2.50 ~:.~.8 1500,00 iF-50 305.82 1486.4~ 1422.41 [~3.76 ~8.29 ~ 108.45 W 551325,(6 6009532-98 89 2.50 MPm-os(Pa) STATIO~ ~ 2.5/100 BOILD ]~1%S~ PEP.-MA~OST BOrLD 3 .g/zoo E~D 3.5/100 B~ILB DROP 4/100 MEASURED INCLN DBPTK ,AIgGL~ DIRECTION VERTICAL-DEPTF~q SECTION AZIMUTh{ TVD SUB-SEA DEPART 1600.00 21,00 305.82 1580.53 15/6.53 167.55 1700.00 23-50 305.82 1673.07 /609.07 205.41 1800.00 26.00 505.82 1763.88 1699.85 247.29 185{,36 27.36 305.52 1812.45 1748.45 ~?],68 1880.25 27-36 305.62 1839.00 1775.00 285.42 17 Sep 1997 COORDINATES-FROM ~ellkead 144.73 N 159.01 N 1914,36 27.36 305.89 1865.74 3801.74 299.25 175.15 2000.00 30.36 305.82 1940.74 ~876.74 340.58 199.34 2100.00 33.86 305-82 X025.43 1961.43 393.~ 230,48 2200.00 37.36 305.82 2~06.~2 2042.72 451.93 264,52 2300.00 40.86 305.82 21~4.)L 2120.31 ~15.00 3~1,43 Paga 2 2{00.00 44.36 305.82 2257.90 2193.90 552.69 2500.00 47,66 305.82 2600.00 51,36 305.82 2~9~.01 2328.01 730.89 2700.00 54,~6 305.82 2452.03 2388-03 %10.85 2800-00 58.36 305.82 2507.06 2443-06 894.33 2900.00 61.86 305.82 2556-90 2492.90 981.01 3000.00 65.36 305.8~ 2601-34 2537.34 10~0,57 3~00.00 66.86 305,82 2640.24 2576,24 1t62,68 3200.00 72.36 305,82 2673.44 2~09,44 1256,99 3250.91 74.14 305,S2 2688.11 2624.11 1305,73 ALASKA Zone { TOOL DL/ X Y FACE 100 4125.44 74.14 305.82 2927,14 2863.14 2146.97 4200.00 7i.16 305.$2 2949.37 2885.37 2218.13 4300.00 67.]6 305,62 2984.95 292Q,95 2311.56 4400,00 63-16 305.62 3026,96 2962,96 2{02.29 4500.00 59.16 305.~2 3075,19 3011,~9 2489.B? 135,~5 W 55129~.93 6009552.57 166.55 W 551267.08 6009574.51 HS 2.50 200.49 ~ 551232,98 60~9598.78 HS 2-50 2~0.28 W 551213,~9 6009612.95 H$ ~.50 23~.02 W 551201.90 6009620.89 [{S 0.00 341.03 383.22 474-59 523.45 242.64 W 551190.63 6009628.91 }IS 0.00 2~6.1~ ~ $51156.95 6009652.86 }IS 3.50 319,23 W $$1113.65 6009683.67 HB 3.50 366,43 W ~51066.23 6009717.%1 HS 3.50 417,57 ~ 551014.84 6009~53.97 HS 3.50 472,45 ~ 550959.7~ 6009793.20 ~S 3-50 530.87 N 550900.99 6009834.96 H$ 3-50 592.61 ~ 5508~8.95 6009879.10 H$ F.50 657.45 W 550773,80 6009925.45 HS 3.50 72~.13 ~ 550705.79 6009973.84 HS $.50 574.19 N 795.42 W 550635.16 6010024.08 HS 3.50 526-61 N 868.03 W 550562.19 6010076.00 }tS 3,50 680.52 N 942.72 W 550487.14 6010129.39 }{S 3,50 735.71 ~ 1019.19 W 550410.30 601018~.0~ I{S 3.50 76{.25 N 1058.71 W 550370.59 6010212.31 ~S 3.58 1256.63 N 1740.79 W 5096~5.19 6010699.93 LS 0.00 t298.2~ N 1798.49 W 54962q.22 60107{1.17 LS 4.00 1552,97 N i874.25 W ~49551.09 6010795.33 L$ 4.00 1006.07 K L9{7.$1 ~ 5494F7.~7 6010847.92 LS 4.0O 1457,33 N 2018.82 W 549405.82 6010898.68 LS 4.00 4600,00 55-16 305.$2 3129,41 3065.41 2573.86 1506,49 N 2086.92 ~ 549337,38 60~09~7.37 L$ ¢.00 4700.00 51.16 305.82 3189,36 3123.36 2653.88 1553.32 N 2151.80 ~ 549272,19 6010993.35 LS 4,00 4800.00 47.16 305.82 325~,75 3190.75 2729.51 1597.59 N 2213.t2 ~ 549210.57 6011037.59 I.$ 4,00 (Anadr~ll {0)97 MPIOSP~ 3.OC 2:39 P~] P) PROPOSED WEL5 PROFILE 17 Sep 1997 Page 3 STATION MEASURED INCH IDS~TIFICATIO~ DSPTH ANGLE TOP UGLY3 4835-76 45.81 4900.00 43.16 5000.00 39.16 5100.00 35.16 TOP M 8At4D 5130,09 33.95 DIRECTION VERTICAL-DEPTHS AZIMU~K TVO SUB-SEA 305.82 3278.80 3214.00 305.82 3325.26 3261-26 305.82 3400.53 3336.53 305.82 3480.22 3416.22 305.62 3505.00 3441.00 D~PART 2753.~9 1611.92 ~ ~232.9~ W 5~9190.~ ~OllOSL.?8 LS 2800.40 1639.08 N 2270.6~ W 549L52-81 6011018.68 I~ 2866.19 16~.60 N 2323.95 W 54~099.20 6011L16.82 LS 2926.58 1712.94 N 2372.91 W 549050-00 6011151.82 LS 2943.~5 1722.93 N 2356.75 ~ 549036.10 6011161.71 19 COORDINATES-FROM A~SKA Zone 4 'TO0~ DL/ ~eLi~ead X Y FACE 300 4.00 4.00 ~.00 4.80 4.00 E~D 4/L00 TARGET 5200.00 3~.16 5228-90 50.00 5428.90 $0.00 5428.90 ~455.45 30.00 305.82 5S63.92 3499.92 305.82 3588.79 3524.~9 305.82 3762.00 3698.00 305.82 3762.00 3698.00 305.82 3785.00 3721.00 2981.26 1744,~$ ~ 2417,25 W 5490Q5,45 6011183.52 LS 4,00 2995.96 1753,55 ~ 2429.17 W 548993.48 6013192.04 HS 4.00 3095.96 1812.08 ~ 2510.25 M 548912.D0 6011250.00 HS 3095.96 1812.08 E 2510.25 W 548912.00 6011250.00 H$ O.00 3109.24 1819.85 N 2521.0t W 54S901.L8 6011257,70 KS O.O0 OA OA4 ~498.18 30,00 5520.12 30,00 55~9.01 30,00 5625-39 30.00 5662-15 30,00 305.82 3822.00 3755.Q0 305.82 3841.00 3777.00 305.82 3~92.00 3828.00 305.82 3932.00 3868.00 505.82 3964.00 3900.00 3130.60 1832.36 N 2538.33 W 54888~.78 6011270.08 KS 3141.57 18~8.78 N 2547.23 ~ 54887&.8~ 6011276,44 H~ O.00 3171.02 1855.01 ~ 257~.1~ ~ 548850.85 60112~3.51 H$ 0.~0 3194.11 1869.53 N 2~9.83 ~ 548832.03 6011306.89 KS 0.00 3212.59 1880.34 N 2604.81 W 548816.98 6011317.60 KS 0.O0 OB TD 5700.25 30.00 5724.50 30.00 5924.50 30-00 5924.50 30.00 305.$2 3997.00 3933.00 ~05.82 4038.00 3954,00 105.82 4191.21 4L27.21 ~05.82 4191.21 4127,21 3231.64 1891.49 N 2620.26 W 548801.46 6021328.64 85 0.00 3243.~6 1898.59 N 2630.09 W 548791.58 6011335.67 H~ O.00 3343.V6 1957.12 N 2~11.17 W 5487L0.10 6011393.64 0.00 3343.96 1957.12 N 2011.1~ W 548710.10 601L393.64 0.00 ANADRILL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR, EXECUTION PLAN # (Anadrill (c) 95 MPI08F4 3.0C 2:39 PM P) SHARED SERVICES BRILLI'N6 ' - . [11 I]~flllll · I II '- ~ L VERTICAL SECTION VIEW Section at: 305.B2 TVD Scale.' ~ ~nch ~ BOO feet ~'' ..,Oep Scale.' ~ ~nch ~ 600 feet Or~n ..... - ~7 Sep ~997 ~ ~ ~nadr j ] ] ~ch] . . . . .... E ....... ,_ Harker ~dentif~cat)on ~O BED SECTN ~NCL~ A) KB 0 0 0 0,0( B) KOP/BUZLO t/~O0 500 500 -0 gl BUILD 1.5/t00 700 700 3 ~,0( ,,~ B) BUILD ~/~00 BO0 900 ~6 5,0( El BUILD 2.5/tO0 ~200 lt97 57 ti.O( FI END 2,5/~00 BUILD ~854 18t~ 272 27.3~ 61 BUILD ].5/tBO ~914 ~868 899 27.3~ ......... b-~ ~----- ~r~T- ~: HI END 3.5/~00 BU]LO 3~5~ 2688 ~306 74. ~) DROP 4/100 4~8~ ~9a7 2t47 74, d) END ~/~00 DROP 5229 3589 2996 30,0[ -- K) TARGET 5429 3752 3096 30.0( L) 7" CASING POINT 59~a 4~9t 3344 30.06 ~ M) TD 5924 4~9~ 3344 30.06 ... ........ '~¢~¢ '~~ ............. ......... . ----5:.... / ...... ~'-' . ._'T',..'- ~n ~ F lAS! 31LI~'Y Pt.AN ,,,~= . ~ EXECUTIOn4 ...... · .-. ..... i ~~~ ~--. . .... ~ -. : i ............. [AnadAi]l (0)97 MPIOUP4 :].OC 2:40 PM P) ]... 0 300 600 900 2200 t5D0 :~800 2100 2400 8700 3000 3300 3600 :3900 Section Departure .i I I1~1 ;.~ :eet OB/2B/1BB7 11:10 B07-~4-2160 13500 ANADRILL DPC PAGE I '" SHARED SERVICES DRILLING 1111 -- . I ---III - NPI-08 (P4) NN~ VERTICAL SECTION VIEW II i i i 3450 -' ~ ~ Section at' 305,82 TVD Scele,' ~ inch = ~00 feet ....... Bep Scale · ! ~nch = ~00 fee~ 35oo 'm,.:¢,c"m~'-'='' '~' ......... " ..... Brawn ..... ' ~.7 Sep :1997 3550X ....... Anadri ]] SchJumb~rg~r I I III Marker Identification MO BKB SECTN INCL~ 3600 " A) ENO 4/~00 O~OP 5229 ..3589 2996 30,0( 8) TARGET 54~cJ 3762 3096 30.0( ' C) 7" CASING POINT 5924 4'191 3344 30.0[ 3650 .. . .... B) TI] 5924 4~9~ 3344 30.0( V 3700 ....... X .... O :3250 ...... TAf~F_T. ~ - ~ ................................................... 3800 ~.. ...... 3850 '~ ' ~¢t .......... - ........... - .... 3900 '¢ ".~r¢¢ ......... 'X ....................... , · o~ - ~ ........... ''~ ............ 3950 ......... _~.__ ........ · oX4- -3¢-~ ............ ;r% 4000 ',~ ~ ' 4050 --. 4~00 ....................... --, t:EAS BILITY [~LAhi \ ,~o-- N D%!,PPROVED FC)R E)(ECLJTION ~oo PL/,N ,~' ~,r~ .---~ 42.50 43OO ..... 2,800 2850 2900 2950 3000 3050 3~ao 3150 3200 3250 3300 3350 3400 34,50 Sect ~on Oeparture ii I[I (/~a~ri]! (cig? ~IOBO4 3.06 2: 4i PM PI 86 11:18 987-344-2168 ANADRILL DPC 117 mn mm SHARED i i mmmmmmm --.. MarKer Ioenti f tcation MO N/S A) KB 0 0 N §} KOP/BUILD 1/100 ~00 0 N C] BUILO 1.5/t00 700 2 N O) BUILO 2/i00 BO0 9 N E) BUILD 2.5/100 1200 34 N F) END 2.5/~i00 BUILD t854 t59 N G) BUILD 3,5/100 194.4 175 N H) END 3.5/I00 BUILD 3251 764 N I) DROP 4/100 4t25 t257 N d) END 4/100 DROP 5229 175,1 N K) T.&RGET 5429 t812 N L) 7' CASINO POINT 5924 t957 N M) TO 592,4 1957 N SERVICES E/w 47 820 243 t059 2429 25t0 27tt 271J PAGE 87 DRILE'ING MPI-08 (P4) PLAN VIEW , __. CLOSURE ' 3344 feet at Azimuth 305.q DECLINATION,' +27.936 SCALE ' 1 inch : 500 feet DRAWN - ~7 SBp ~gg7 i mi 4nadri 77 Schlumberger III ANADRILL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION PLAN # ¢.':~ ":"::~ i~ ~-i.~r~-~.~.._ , . . ~ _- __ 100 fl et ) ~ -- .. ~ ,, ..-- 3250 3000 2750 2500 2250 2000 1750 iS00 t250 3000 750 500 250 0 25~ <- WEST' EAST -> i mm mmm .. . m ) (~Sdril! (0)97 ~I0~4 3.O~ ~4] ~ P) i N 14GD,~D -(- r( 1880.oo -)- m,m BP X HSE RK my m i .~. I PAD I-1 [] NO. 505 VICINLT¥. MAP N,T,S, LE(2ENB -~- AS-BUILT CONDUCTOR LOCATION i[ EXI$~NG WELL ,NOTES 1. DA~ oF SURVEY: APRIL 28, 199,5. 2. REFERreR FIELD BOOK: MP95-09 (pos. 9-12), 3. ALASKA STATE PEAN~ COORDINaTeS ARE ZONE ~, NAD 27. $, GEODETIC COORDINATES ARE NAD 19~7, 5. ¢=AD SCAL~ F^OTOR IS 6. HORIZONTAL/VErTICAL CO,NI'~OL ~S BASED ON MONUMBNI'~ I-1 AND LDOATED ~,ITHIN PFIOTRAC1'~D S£C, 33, T- 13 ID E,, UMIAT MERIPIAN, ALASKA ¢OOEDINATI~S C~OEDINA.TES [PO~IllON(_O,MS) PO.~IllON(~,OD) BOX ~LEV. OFFSETs Y=$,OO~,~lO N= 1,120.~B 70'~6'11,6~' 70.,~3657~7~' 2,337' FSL 551,3.2.4..96 £~-. 1,23q._D.~. 149'3.4'¢7..~_6_a_' 14B;579gOTA'__ 3+,~ 3,8.45' ~E.L ,, .SU._RvE;YOR'S CE:RTIFLCATE I H~RE~Y CERTIFY-i'HA~ I_AM PROP£RgY REGISTERED ~ND LICENSED TO pRACTICE LAND SURVE~NG IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A ~URVEY MADE BY ~E OR UNDER MY DIRECT SUPI~RvIBION ANP THAT ALL ~ DIMENSION$_ANO 01'hIE~ DETA. I~ ARE: CORRECT AS OF APRIL 28, 1995, 1,~,.~ ~ bIILNE POINT UNIT H126097 DATE VENDOR ALASKAST 14 OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET ........ ~ -~ ~¥ ,' --' .", :i. Ot). O0 i 00. O0 · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ,_~¢.,,/,4.//'(;;~ INIT CLASS ~ WELL NAME,/~f/ "' ~ Y GEOL AREA PROGRAM: exp [] dev~redrll [] serv [] wellbore seg [] ann. disposal para req [] ~'~ UNIT# ,//~'2_~ ON/OFF SHORE ~/%,) ADMINISTRATION . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE 12. Permit fee attached ....................... N Lease number appropriate ................... N Unique well name and number .................. N Well located in a defined pool .................. N Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE_/ 14. Conductor string provided ................... ~ N 15. Surface casing protects all known USDWs ........... (~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... N 17. CMT vol adequate to tie-in long string to surf csg ........ ~,~N 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... Y N 22. Adequate wellbore separation proposed ............. ~) N 23. N 24. N 25. N 26. N 27. N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. N If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to ?..~2~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ REMARKS GEOLOGY APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............ .//Y N 34. Contact name/phone for we,ekly,pro~lress re[)o, rts ..... .-:'. Y N lexp~ora~ory omyj GEOLOGY: ENGINEERL~IG: COMMISSION: RNC~ CO Commentsllnstructions: HOW/Ijt - A:\FORMS\cheklist rev 09/97 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-Sun Drilling Services LIS Scan Utility Sat Aug 29 14:57:57 1998 Reel Header Service name ............. LISTPE Date ..................... 98/08/29 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 ..................... 98/08/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) MWD RUN 2 AK-MM-70301 PIEPER BURLEY SEP 0 ?. MPI-08 500292282100 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 29-AUG-98 33 13N 10E 2341 3936 Date~ KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 63.80 34.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 9.875 5920.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. DEPTH CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM D. DOUGLAS FOR KATIE NITZBERG ON 08/20/98. MWD IS PDC. 3. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE- 4 (EWR4) . 5. ALL MWD RUNS REPRESENT MPI-08 WITH API# 50-029-22821-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5920'MD, 4215'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GA2e{A 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 FOR RESISTIVITY SENSOR. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/29 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. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH FET 2535.0 RPD 2535.0 RPM 2535.0 RPS 2535.0 RPX 2535.0 GR 2543.0 ROP 2609.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: STOP DEPTH 5845.5 5845.5 5845.5 5845.5 5845.5 5853.0 5920.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 2609.0 5920.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 GR MWD AP1 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHN~4 4 1 68 ROP MWD FT/H 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 2535 5920 4227.5 GR 7.5612 109.754 59.9762 RPX 1.7319 119.365 11.1156 RPS 1.8493 142.774 12.2969 Nsam 6771 6621 6622 6622 First Reading 2535 2543 2535 2535 Last Reading 5920 5853 5845.5 5845.5 RPM 1.8361 168.214 12.1253 6622 RPD 1.9877 219.515 12.8212 6622 ROP 6.6204 2039.91 269.168 6623 FET 0.183 8.9153 1.10486 6622 2535 2535 2609 2535 5845.5 5845.5 5920 5845.5 First Reading For Entire File .......... 2535 Last Reading For Entire File ........... 5920 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/29 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 ....... 98/08/29 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 2535.0 RPD 2535.0 RPM 2535.0 RPS 2535.0 RPX 2535.0 GR 2543.0 ROP 2609.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: STOP DEPTH 5845 5 5845 5 5845 5 5845 5 5845 5 5853 0 5920 0 18-OCT-97 5.07 5.46 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 GAMMA 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 (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED 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 MEMORY 5920.0 2609.0 5920.0 28.7 74.7 TOOL NUMBER 9.880 9.9 SPUD/LSND 9.10 65.0 9.0 8OO 5.6 3.000 3.000 2.900 4.000 22.8 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT GR RPX RPS RPM R?D ROP FET MWD 2 MWD 2 MWD 2 MWD 2 MWD 2 MWD 2 MWD 2 FT 4 1 68 API 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHM~ 4 1 68 FT/H 4 1 68 HOUR 4 1 68 0 4 8 12 16 2O 24 28 Name DEPT GR RPX RPS RPM RPD ROP FET Min 2535 7 5612 1 7319 1 8493 1 8361 1 9877 6 6204 0.183 Max Mean 5920 4227.5 109.754 59.9762 119.365 11.1156 142.774 12.2969 168.214 12.1253 219.515 12.8212 2039.91 269.168 8.9153 1.10486 Nsam 6771 6621 6622 6622 6622 6622 6623 6622 First Reading 2535 2543 2535 2535 2535 2535 2609 2535 Last Reading 5920 5853 5845.5 5845.5 5845.5 5845.5 5920 5845.5 First Reading For Entire File .......... 2535 Last Reading For Entire File ........... 5920 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/08/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/08/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Scientific Technical Next Reel Name ........... UNKNOWN Comments ................. STS LIS W~iting Library. Scientific Technical Sezvices Physical EOF Physical EOF End Of LIS File