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Home My WebLink About197-1801. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP Swap Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 18,776 feet N/A feet true vertical 7,098 feet N/A feet Effective Depth measured 18,401 feet 1,850 & 13,247 feet true vertical 7,135 feet 1,790 & 6,558 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5 / L-80 / EUE 8rd 12,608' 6,314' Viking Dual Vent Packers and SSSV (type, measured and true vertical depth)Baker N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: Burst N/A Collapse N/A 3,090psi 7,500psi 5,750psi 7,240psi 8,430psi 13,410' 6,594' 5,410psi Conductor 7,111'18,645' 13,379' 7,340'Surface Production Liner 20" 9-5/8" 7" 74' 7,304' MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT F-79 Plugs Junk measured measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-180 50-029-22813-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025509, ADL0355018 & ADL0388235 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 112' Size 112' 4,311' Length 5,398' Casing N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 100 0 1530 010 0 3420 347 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 323-534 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.06.25 12:51:39 - 08'00' Taylor Wellman (2143) By Grace Christianson at 2:20 pm, Jun 25, 2024 RBDMS JSB 062724 DSR-6/26/24WCB 12-3-2024 _____________________________________________________________________________________ Revised By TDF 6/17/2024 SCHEMATIC Milne Point Unit Well: MPU F-79 Last Completed: 5/27/2024 PTD: 197-180 TD =18,776 (MD) / TD = 7,098’(TVD) 20” Orig. KB Elev.: 44.55/ GL Elev.: 11.5’(N27E) 4-1/2” 6 7 12 & 13 11 15 14 16 9-5/8” 1 MIN ID= 2.205” @ 12,485’ PBTD =18,401 (MD) / PBTD = 7,135’(TVD) 9 & 10 8 KUP A Sands 7” 2 3 4 5 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 N/A Surface 112' 0.0355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 7,340’ 0.0759 7" Production 29 / L-80 / Hydril 563 6.184 Surface 2,149’ 0.0371 7" Production 29 / L-80 / Hydril 511 6.276 2,149’ 13,246’ 0.0371 7" Production 26 / L-80 / BTC 6.276 13,246’ 13,410’ 0.0383 4-1/2” Liner 12.6 / L-80 / EUE 8rd 3.958 13,247 18,645’ 0.0152 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 12,608 0.00579 JEWELRY DETAIL No Depth Item 1 178’ST 4: GLM 2-7/8” X 1'' BK Dummy Valve 2 1,789’ST 3: GLM 2-7/8” X 1'' BK Dummy Valve 3 1,850’ Viking Packer w/ Dual Vent Valves 4 1,905’ST 2: GLM 2-7/8” X 1'' BK Dummy Valve 5 1,964’ 2-7/8” X-Nipple:2.313” No-go ID 6 12,426’ST 1: GLM 2-7/8” X 1'' BK Dummy Valve 7 12,485’ 2-7/8” XN-Nipple:2.205” No-go ID 8 12,538’ Discharge Head & Zenith Ported Sub 9 12,539’ Pump #2: 538/PMSXD 119 P23M FER NO PNT 10 12,556’ Pump #1: 538/PMSXD 20 GINPSHH H6 FER 12 11 12,566’ Gas Separator: 538/GM2T/HVEVXMTHS FER 12 12,572’ Upper Tandem Seal: P/N 500010180 13 12,579’ Lower Tandem Seal: P/N 500010180 14 12,586’ Motor: 562/ XP/250/2505/61/208/2090 10R 15 12,603’ Guage w/ Centralizer: Bottom @ 12,608’ 16 13,247’ Baker Liner Hanger and Packer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Date Statu s Kup. A Sands 15,880’ 15,968’ 7,116’ 7,128’ 88 2-7/8” 11/29/97 Open 16,080’ 16,400’ 7,138’ 7,146’ 320 2-7/8” 11/29/97 Open 16,499’ 16,850’ 7,144’ 7,147’ 331 2-7/8” 11/29/97 Open 17,090’ 17,800’ 7,158’ 7,176’ 710 2-7/8” 11/29/97 Open 17,850’ 18,170’ 7,173 7,155’ 320 2-7/8” 11/29/97 Open Ref Log: Based off Measured Depth – SWS 34J Deep Penetrating Charges (EHD=.029’/ TTP=20.57” Phasing 60°/ 120° OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in a 24” Hole 9-5/8" 1,720 sx PF ‘E’, 529 sx Class ‘G’’ in a 12-1/4” Hole 7” 495 sx Class ‘G’ in a 8-1/2” Hole 4-1/2” 1,050 sx Class ‘G’ in a 6” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 96° @ PBTD Hole Angle through perf interval = 84° to 93° TREE & WELLHEAD Tree Cameron 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A w/ 2-7/8” FMC Tbg. Hngr., 3” LH Acme on Top and 2-7/8” EUE 8rd on Bottom, 2.5” CIW BPV profile. GENERAL WELL INFO API: 50-029-22813-00-00 Drilled and Completed by Nabors 27E - 12/4/1997 ESP Swap by Nabors 4ES - 4/9/1998 ESP Swap by Nabors 4ES - 12/18/2003 Convert to Gas Lift by Nabors 3S - 5/18/2009 ESP Swap by ASR#1 – 2/1/2018 ESP Swap by ASR#1 – 5/27/2024 Well Name Rig API Number Well Permit Number Start Date End Date MP F-79 ASR#1 50-029-22813-00-00 197-180 5/23/2024 5/29/2024 5/24/2024 - Friday Fill pits & gas buster with 10.4 ppg brine. Pull CTS & BPV. Tubing on a vacuum. L/D tee bar. P/U landing jt & M/U kelly hose. Engage hanger with L/H acme threads. 9 1/2 turns. BOLDS. Attempt to pull hanger. Seeing overpull from previous recorded work up to p/u WT = 96K Last recorded P/U wt = 74K Pump dw tubing for 20 bbls at 2 bpm w/ 400 psi. Observed wt decrease from 90K to 78K. Shut down pumps & pull up to 96K, same mark. Mobilize lube. Pump 17 bbls NXS lubed 10.4 ppg brine down backside. Well full. P/U to 100K Completion pulling free. Drag from 89K to 82K Clean P/U = 84K. Hanger at rig floor. Cut ESP cable & secure to spooler. B/O & L/D hanger. Blow down lines. POOH w/ 2-7/8" 6.5# L-80 EUE ESP completion F/ 12,565. Pump double displacement. POOH T/ 3,911' P/U wt = 25K S/O wt = 13K . Pump Single displacement. 5/22/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 5/23/2024 - Thursday Begin testing BOPE as per approved sundry. AOGCC waived witness to testing. Test to 250 psi low & 3000 psi high for 5/5 M/U hanger to string terminate cap line into hanger, S/B for penerator splice. Landed hanger with BPV and RILDS. Rig released from F-79 at 06:00 5-28-2024. POOH w/ 2-7/8" 6.5# L-80 EUE ESP F/ 3,911' T / DS head. L/D ESP assy. ; pump, gas sep. upper & lower seal, motor, motor sensor & cent. Shaft sheared at gas sep. Prep for slick line. Spot in slick line unit. P/U SL tools & equip. to rig floor. Rais e SL sheave, safety off. RIH w/ slick line w/ 6.1" GR & JB. Tagged at 2142' with 6.1" GR POOH. OOH w/ SL. Changeover to 5.9" GR & JB, RIH. AT 13,093' w/ GR. POOH. Monitor well ( on losses ) OOH w/ SL. All tools accounted for. R/D slick line. P/U & M/U new ESP ASSY. M/U cent to motor sensor & motor. Service motor & upper & lower seal. P/U Intake - Gas sep. & pump #2 & pump #1. Zenith ported sub , DS head & 2-7/8" pup. RIH w/ 2-7/8" 6.5# L-80 EUE ESP completion. f/ 80' . Pumping single displacement. Running in at 60 FPM. Current depth at 00:00 = 164' S/O wt = 3K dw. 5/25/2024 - Saturday RIH w/ 2-7/8" 6.5# L-80 EUE ESP completion. f/ 8,983'- T 10,700'. P/U Jewelry as follows X nipple, GLM, Viking PKR. Begin PKR splice. Test ESP cable. (good) Make up CAP line to vent valve assembly. Pressure & function test, (good) Hold 500 PSI on CAP line while RIH. Cont. RIH w/ 2-7/8" 6.5# L-80 EUE ESP completion. f/ 10,700' T/ 12,558'. Perform hanger splice with ALS rep. Terminate Cap line. Test ESP cable (good). Land hanger on seat Final S/O wt= 32K P/U wt = 72K. RILDS w/ wellhead rep. Secure cellar. (Hanger landed with BPV installed). Remove well work fluid from rig. Clean & clear rig floor of ESP equip. & tools. 5/28/2024 - Tuesday 5/26/2024 - Sunday RIH w/ 2-7/8" 6.5# L-80 EUE ESP completion. F/ 164' - T/ 7,590'. Pumping single displacement. Running in at 60 FPM. Test ESP cable every 1000' S/O wt = 24 K. Perform reel to reel ESP cable splice. Test cable (good) Continue RIH w/ 2-7/8" 6.5# L-80 EUE ESP completion. T/ 8,983'. 5/27/2024 - Monday RIH w/ 2-7/8" 6.5# L-80 EUE ESP completion. f/ 8,983'- T 10,700'. P/U Jewelry as follows X nipple, GLM, Viking PKR. Begin PKR splice. Test ESP cable. (good) Make up CAP line to vent valve assembly. Pressure & function test, (good) Hold 500 PSI on CAP line while RIH. Cont. RIH w/ 2-7/8" 6.5# L-80 EUE ESP completion. f/ 10,700' T/ 12,558'. Perform hanger splice with ALS rep. Terminate Cap line. Test ESP cable (good). Land hanger on seat Final S/O wt= 32K P/U wt = 72K. RILDS Well Name Rig API Number Well Permit Number Start Date End Date MP F-79 ASR#1 50-029-22813-00-00 197-180 5/23/2024 5/29/2024 5/31/2024 - Friday No operations to report. 5/29/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Wellhead: Landed 7 x 2-7/8 tubing hanger, RILDS and set BPV, DEMOB ASR, Remove BOPs, nipple up adapter and tree, Tested adapter to 500 / 5000 psi for 5/10 mins. Pull BPV with dry rod. 5/30/2024 - Thursday No operations to report. No operations to report. No operations to report. 6/1/2024 - Saturday No operations to report. 6/4/2024 - Tuesday 6/2/2024 - Sunday No operations to report. 6/3/2024 - Monday Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/04/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231004 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# IRU 41-01 50283200880000 192109 9/17/2023 HALLIBURTON Coilflag KBU 32-06 50133206580000 216137 9/8/2023 HALLIBURTON PPROF LRU C-02 50283201900000 223057 9/13/2023 HALLIBURTON RBT MPU E-37 50029236160000 218158 9/24/2023 READ Caliper Survey MPU F-53A 50029225780100 213136 9/27/2023 READ Caliper Survey MPU F-79 50029228130000 197180 9/26/2023 READ Caliper Survey MPU L-57 50029236090000 218072 9/26/2023 READ Caliper Survey MPU S-06 50029231630000 203109 9/29/2023 READ Caliper Survey MPU B-32 50029235700000 216151 9/12/2023 HALLIBURTON Perf TBU K-09 50733201100000 1068038 10/1/2023 READ Caliper Survey Please include current contact information if different from above. T38028 T38029 T38030 T38031 T38032 T38033 T38034 T38035 T38036 T38037 10/4/2023 MPU F-79 50029228130000 197180 9/26/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.04 13:03:04 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Swap 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 18,776'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 13,247 MD/ 6,558 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 4-1/2"5,398' 13,379' Perforation Depth MD (ft): 18,645' See Schematic See Schematic 2-7/8" 7,340' 13,410' 74' 20" 9-5/8" 7" 7,304' N/A 8,430psi 5,750psi 7,240psi 4,311' 6,594' 7,111' Length Size Proposed Pools: 112' 112' 6.5# / L-80 / EUE 8rd TVD Burst 12,595' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509, ADL0355018 & ADL0388235 197-180 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22813-00-00 Hilcorp Alaska LLC C.O. 432E AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/15/2023 Baker LTP and N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT F-79 MILNE POINT KUPARUK RIVER OIL N/A 7,098' 18,401' 7,135' 2,687 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 1:06 pm, Sep 28, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.09.28 08:59:21 - 08'00' Taylor Wellman (2143) SFD 10/2/2023 DSR-9/28/23 10-404 2,687 MGR29SEP23 * BOPE test to 3000 psi. Annular to 2500 psi. *&:JLC 10/3/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.03 11:27:22 -08'00' RBDMS JSB 100323 Well: MPF-79 PTD: 197-180 API: 50-029-22813-00-00 Well Name:MPF-79 API Number:50-029-22813-00-00 Current Status:Shut-in Producer Rig:ASR #1 Estimated Start Date:10/15/2023 Estimated Duration:6 days Regulatory Contact:Tom Fouts Permit to Drill Number:197-180 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 3,309 psi @ 6,219’ TVD SBHPS taken 09/26/2023 |10.2 PPGE Maximum Expected BHP:3,309 psi @ 6,219’ TVD SBHPS taken 09/26/2023 |10.2 PPGE Max Potential Surface Pressure: 2,687 psi Gas Column Gradient (0.1 psi/ft) Max Angle:74.6° @ 13,240’ MD Brief Well Summary: MPU F-79 was drilled and completed in December 1997 as a horizontal Kuparuk River producer. ESP installation history: December 1997 (initial), April 1998, December 2003, May 2009, and February 2018. The ESP has performed well until a field power bump caused the ESP to become grounded. Objectives: Pull failed ESP completion, run new ESP completion. Notes Regarding Wellbore Condition: - 7” casing test to 2,000 psi on 1/31/2018. Pre-Rig Procedure (Non Sundried Work) Slickline 1. RU slickline, pressure test PCE to 250psi low / 2,500psi high. 2. RIH with 24-arm caliper and BHP gauge to the XN nipple @ 12,435’ MD stop for 10 min. 3. PU to 12,050’ MD and 11,800’ MD stopping 5 min each. Log OOH to surface. 4. RDMO. Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 10.4 ppg brine down tubing, taking returns up casing to 500 barrel returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH or diesel. 7. RD Little Red Services and reverse out skid. 8. Set BPV. 9. ND tree. NU BOPE. Brief RWO Procedure (Begin Sundried Work) SBHPS taken 09/26/2023 |10.2 PPGE 3000 -mgr Well: MPF-79 PTD: 197-180 API: 50-029-22813-00-00 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 3. Test BOPE to 250 psi low/ 3,000 psi high. Test annular to 250 psi low/ 2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with 10.4 ppg brine as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out Centrilift for ESP pull. 6. RU spoolers to handle ESP cable. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. 2018 tubing PU weight on ASR #1 recorded as 74 kip. Slack off weight recorded as 17 kip. b. 2-7/8” L-80 EUE yield is 144 kip. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8” tubing. a. Contact OE for caliper report and to keep vs scrap. b. Keep ported discharge head and centralizer for future use. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Recorded Clamp Totals: i. Canon Clamps: 216 ii. Protectolizers: 4 iii. Bands: 2 10. Lay Down ESP. 11. RIH with new 2-7/8” 6.5# L-80 ESP completion to +/- 12,595’ and obtain string weights. a. Check electrical continuity every 1000’. b. Note PU and SO weights on tally. c. Install ESP clamps per Baker, and cross coupling clamps every other joint. d. Photograph vent packer prior to running in hole. Well: MPF-79 PTD: 197-180 API: 50-029-22813-00-00 Nom. (OD)Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 ~12,595’ MD 4.5 2 Intake Sensor 30 5.62 34 Motor 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 8 Gas Separator 52 5.38 ~57 Pump 45 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 2-7/8” XN-nipple 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" ~9,310 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 XO 2-7/8" X 2-3/8” EUE 8rd Pup Jt 6.5 L-80 2-3/8"2 2-3/8” X-nipple with RHC profile 6.5 L-80 RHC Installed 2-7/8"10 XO 2-7/8" X 2-3/8” EUE 8rd Pup Jt 6.5 L-80 2-7/8" 31 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 31 2-7/8" EUE 8rd Jt 6.5 L-80 30 Packer, Reduced ID Viking ESP Retr. Dual Vent ~3,000 MD 3-1/2” 10 2-7/8" EUE 8rd x 3-1/2" EUE 8rd Jt 9.3 L-80 3-1/2" ~2,650 3-1/2" EUE 8rd Jt 9.3 L-80 3-1/2"10 3-1/2" EUE 8rd Pup Jt 9.3 L-80 3-1/2"8 3-1/2" x 1" GLM, DV installed 9.3 L-80 ~150 MD 3-1/2"10 3-1/2" EUE 8rd Pup Jt 9.3 L-80 3-1/2" 150 3-1/2" EUE 8rd Jt 9.3 L-80 3-1/2" 10 Space out pup 9.3 L-80 3-1/2" 30 Tubing Hanger with full joint 9.3 L-80 12. PU and MU Reduced ID Viking vented packer. Verify that there are four (4) setting shear pins and confirm with OE number of release shear pins. a. Target release pins to shear at 20,000 pounds overpull. Well: MPF-79 PTD: 197-180 API: 50-029-22813-00-00 13. Terminate the ESP cable and make up the ESP penetrator to the ESP cable. Ensure the 3/8” NPT control line feed thru port is dummied off. 14. Make up the control line to the dual vent valves. Pressure up on the control line to 5,000 psi and hold for 5 minutes checking for leaks (note the opening pressure in the daily report). Bleed the pressure to 500 psi and maintain 500 psi while running in hole. a. Periodically confirm control line is maintaining 500 psi. 15. Continue running ESP completion per plan. 16. PU and MU the 3-1/2” tubing hanger. Make final splice of the ESP cable to the penetrator. MU the control line to the tubing hanger and dummy off any additional control line ports if present. 17. Land tubing hanger, avoiding any damage to ESP cable or control line. RILDS. Lay down landing joint. Note PU and SO weights on tally and in daily report. 18. Drop ball and rod. 19. Pressure up on tubing to 4,000 psi and hold for 15 minutes to set the ESP packer. 20. Bleed tubing to 0 psi. 21. Pressure up on tubing to 4,000 psi and hold for 5 more minutes and then bleed to 0 psi. 22. Bleed packer control line to 0 psi, closing packer vent valves. 23. Slowly pressure up IA at 50 psi/min to 1,500 psi and hold for 30 minutes. Chart test. Bleed off at the same 50 psi/min rate posttest to ensure we do not decompress the ESP cable. 24. Lay down landing joint. 25. Set BPV. 26. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Slickline 1. Retrieve ball and rod, pull RHC plug 2. Set screen OV in top GLM Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By TDF 4/23/2019 SCHEMATIC Milne Point Unit Well: MPU F-79 Last Completed: 2/1/2018 PTD: 197-180 TD =18,776 (MD) / TD = 7,098’(TVD) 20” Orig. KB Elev.: 44.55/ GL Elev.: 11.5’ (N27E) 4-1/2” 2 3 7 &8 6 10 9 11 9-5/8” 1 MIN ID= 2.205” @ 12,435’ PBTD =18,401 (MD) / PBTD = 7,135’(TVD) 5 4 KUP A Sands 7” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 N/A Surface 112' 0.0355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 7,340’ 0.0759 7" Production 29 / L-80 / Hydril 563 6.184 Surface 2,149’ 0.0371 7" Production 29 / L-80 / Hydril 511 6.276 2,149’ 13,246’ 0.0371 7" Production 26 / L-80 / BTC 6.276 13,246’ 13,410’ 0.0383 4-1/2” Liner 12.6 / L-80 / EUE 8rd 3.958 13,247 18,645’ 0.0152 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surf 12,595 0.00579 JEWELRY DETAIL No Depth Item 1139’ST 2: Camco 2-7/8” X 1'' Side Pocket w/ Orifice 2 12,325’ST 1: Camco 2 7/8 X 1'' Side pocket,W/Dummy 3 12,435’ 2-7/8” XN-Nipple: 2.205” No-go ID 4 12,539’ Discharge Head: GPDIS 5 12,540’ Pump: 119P23 / SXD 6 12,557’ Gas Separator: GRS FER N AR 7 12,560’ Upper Tandem Seal: GSB3DBUT SB/SB PFSA 8 12,567’ Lower Tandem Seal: GSB3DBLT SB/SB PFSA CL5 9 12,574’ Motor: XP – 250Hp/ 2,505V/ 61A 10 12,591’ WellLiftSensor w/ Centralizer: Bottom @ 12,595’ 11 13,247’ Baker Liner Hanger and Packer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Date Statu s Kup. A Sands 15,880’ 15,968’ 7,116’ 7,128’ 88 2-7/8” 11/29/97 Open 16,080’ 16,400’ 7,138’ 7,146’ 320 2-7/8” 11/29/97 Open 16,499’ 16,850’ 7,144’ 7,147’ 331 2-7/8” 11/29/97 Open 17,090’ 17,800’ 7,158’ 7,176’ 710 2-7/8” 11/29/97 Open 17,850’ 18,170’ 7,173 7,155’ 320 2-7/8” 11/29/97 Open Ref Log: Based off Measured Depth – SWS 34J Deep Penetrating Charges (EHD=.029’/ TTP=20.57” Phasing 60°/ 120° OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in a 24” Hole 9-5/8" 1,720 sx PF ‘E’, 529 sx Class ‘G’’ in a 12-1/4” Hole 7” 495 sx Class ‘G’ in a 8-1/2” Hole 4-1/2” 1,050 sx Class ‘G’ in a 6” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 96° @ PBTD Hole Angle through perf interval = 84° to 93° TREE & WELLHEAD Tree Cameron 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A w/ 2-7/8” FMC Tbg. Hngr., 3” LH Acme on Top and 2-7/8” EUE 8rd on Bottom, 2.5” CIW BPV profile. GENERAL WELL INFO API: 50-029-22813-00-00 Drilled and Completed by Nabors 27E - 12/4/1997 ESP Swap by Nabors 4ES - 4/9/1998 ESP Swap by Nabors 4ES - 12/18/2003 Convert to Gas Lift by Nabors 3S - 5/18/2009 ESP Swap by ASR#1 – 2/1/2018 _____________________________________________________________________________________ Revised By TDF 9/20/2023 PROPOSED Milne Point Unit Well: MPU F-79 Last Completed: 2/1/2018 PTD: 197-180 TD = 18,776 (MD) / TD = 7,098’(TVD) 20” Orig. KB Elev.: 44.55/ GL Elev.: 11.5’ (N27E) 4-1/2” 3 4 8 & 9 7 11 10 12 9-5/8” 1 MIN ID= 2.205” @ ±12,435’ PBTD =18,401 (MD) / PBTD = 7,135’(TVD) 6 5 KUP A Sands 7” 2 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 N/A Surface 112' 0.0355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 7,340’ 0.0759 7" Production 29 / L-80 / Hydril 563 6.184 Surface 2,149’ 0.0371 7" Production 29 / L-80 / Hydril 511 6.276 2,149’ 13,246’ 0.0371 7" Production 26 / L-80 / BTC 6.276 13,246’ 13,410’ 0.0383 4-1/2” Liner 12.6 / L-80 / EUE 8rd 3.958 13,247 18,645’ 0.0152 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surf 12,595 0.00579 JEWELRY DETAIL No Depth Item 1 ±200’ST 2: GLM 2-7/8” X 1'' w/ ¼” OV 2 ±3,000’ Reduced ID Viking ESP Retr. Dual Vent 3 ±12,325’ST 1: GLM 2-7/8 X 1'', DV Installed 4 ±12,435’ 2-7/8” XN-Nipple: 2.205” No-go ID 5 ±12,539’ Discharge Head: 6 ±12,540’ Pump: 7 ±12,557’ Gas Separator: 8 ±12,560’ Upper Tandem Seal: 9 ±12,567’ Lower Tandem Seal: 10 ±12,574’ Motor: 11 ±12,591’ Sensor w/ Centralizer: Bottom @ ±12,595’ 12 13,247’ Baker Liner Hanger and Packer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Date Statu s Kup. A Sands 15,880’ 15,968’ 7,116’ 7,128’ 88 2-7/8” 11/29/97 Open 16,080’ 16,400’ 7,138’ 7,146’ 320 2-7/8” 11/29/97 Open 16,499’ 16,850’ 7,144’ 7,147’ 331 2-7/8” 11/29/97 Open 17,090’ 17,800’ 7,158’ 7,176’ 710 2-7/8” 11/29/97 Open 17,850’ 18,170’ 7,173 7,155’ 320 2-7/8” 11/29/97 Open Ref Log: Based off Measured Depth – SWS 34J Deep Penetrating Charges (EHD=.029’/ TTP=20.57” Phasing 60°/ 120° OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in a 24” Hole 9-5/8" 1,720 sx PF ‘E’, 529 sx Class ‘G’’ in a 12-1/4” Hole 7” 495 sx Class ‘G’ in a 8-1/2” Hole 4-1/2” 1,050 sx Class ‘G’ in a 6” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 96° @ PBTD Hole Angle through perf interval = 84° to 93° TREE & WELLHEAD Tree Cameron 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A w/ 2-7/8” FMC Tbg. Hngr., 3” LH Acme on Top and 2-7/8” EUE 8rd on Bottom, 2.5” CIW BPV profile. GENERAL WELL INFO API: 50-029-22813-00-00 Drilled and Completed by Nabors 27E - 12/4/1997 ESP Swap by Nabors 4ES - 4/9/1998 ESP Swap by Nabors 4ES - 12/18/2003 Convert to Gas Lift by Nabors 3S - 5/18/2009 ESP Swap by ASR#1 – 2/1/2018 Milne Point ASR Rig 1 BOPE 2023 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30'Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR 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. From:AOGCC Permitting (CED sponsored) To:Brooks, James S (OGC) Subject:FW: MP F-79 10-403 Withdrawal Request for Sundry # 323-247, PTD: 197-180 Date:Monday, September 25, 2023 1:37:42 PM FYI From: Tom Fouts <tfouts@hilcorp.com> Sent: Monday, September 25, 2023 1:13 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Ryan Lewis <Ryan.Lewis@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com> Subject: MP F-79 10-403 Withdrawal Request for Sundry # 323-247, PTD: 197-180 Hello, Hilcorp Alaska LLC requests the withdrawal of the 10-403 submittal for MP F-79, Sundry # 323-247. We will be submitting another 10-403 for this well to perform an ESP Swap. Regards, Tom Fouts | Senior Ops/ Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907) 777-8398 Mobile: (907) 351-5749 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert to Jet Pump 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? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 18,776'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 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: AOGCC USE ONLY twellman@hilcorp.com 777-8449 Taylor Wellman STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355018 197-180 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22813-00-00 Hilcorp Alaska LLC KUPARUK RIVER OIL N/A C.O. 432E MILNE PT UNIT F-79 Length Size Proposed Pools: 112' 112' TVD Burst PRESENT WELL CONDITION SUMMARY 7,098' 18,401' 7,135' 1,893 N/A 74' 20" MILNE POINT MD N/A 8,430psi 5,750psi 7,240psi 4,311' 6,594' 7,111' 7,340' 13,410' 18,645' 7,304' 13,379' Perforation Depth MD (ft): 4-1/2"5,398' Perforation Depth TVD (ft): Tubing Size: 9-5/8" 7" Tubing Grade: Tubing MD (ft): 6.5# / L-80 / EUE 8rd 12,595' 5/10/2023 Baker LTP and N/A 13,247 MD/ 6,558 TVD and N/A See Schematic See Schematic 2-7/8" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-247 By Kayla Junke at 11:26 am, Apr 21, 2023 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.04.21 10:51:48 -08'00' David Haakinson (3533) MGR19MAY2023 * Per alignment with CO 390A: BHPE is less than 8.55 ppg implies no packer. With sliding sleeve open for jet pump function, results in no packer function. BHP must remain below 8.55 PPGE to operate jet pump. * Per CO 390A and 20 AAC 265 (d) 8.55 ppg assumes that reservoir is NOT capable of unassisted flow to surface. * Approved for forward circulating jet pump. * 24 hour notice for opportunity for AOGCC to witness MIT-IA to maximum power fluid injection pressure. * IA SSV high pressure trip pressure not to exceed more than 10% of proposed steady state power fluid injection pressure. * IA low pressure trip pressure not to be lower than 50% of proposed steady state power fluid injection pressure. * Production tubing SSV low pressure trip not to be lower than 100 psi. * SSV closure on IA will initiate closure within 2 minutes on SSV on production tubing and visa versa. *Quadrennial MIT-IA to maximum proposed header pressure. 10-404 * BOPE pressure test to 2500 psi. DSR-4/26/23 1,893 SFD 4/24/2023 ADL0025509, ADL0388235,SFD GCW 05/23/23JLC 5/23/2023 5/23/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.23 16:46:09 -05'00' RBDMS JSB 052423 Well: MPU F-79 Scope: Conv to JP Date: 04/17/2023 Well Name:MPU F-79 API Number:50-029-22813-00 Current Status:Oil Well Pad:F-Pad Estimated Start Date:May 10th, 2023 Rig:ASR 1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:197-180 First Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Second Call Engineer:Scott Pessetto (907) 564-4373 (O) (801) 822-2203 (M) AFE Number:Job Type:RWO – Conv to JP Current Bottom Hole Pressure: 2,513 psi @ 6,200’ TVD SBHPS taken 04/19/2023 |7.79 PPGE Max Potential Surface Pressure: 1,893 psi Gas Column Gradient (0.1 psi/ft) Max Angle (above liner):74.6° @ 13,240’ MD Brief Well Summary: MPU F-79 was drilled and completed in December 1997 as a horizontal Kuparuk River producer. ESP installation history: December 1997 (initial), April 1998, December 2003, May 2009, and February 2018. The ESP has performed well until a field power bump caused the ESP to become grounded. The future utility of this well Objective: Pull failed ESP / Run Casing Scraper / Test Packer & Test Csg to 3,500psi / Run 3-1/2” Jet Pump Completion Notes Regarding Wellbore Condition: Last production casing test at 9,975’ MD to 2,000 psi on 1/31/2018. Pre-Rig Procedure Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure 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.Lubricate valve if risk of trapped pressure. - mgr Well: MPU F-79 Scope: Conv to JP Date: 04/17/2023 a. If needed, kill well with produced water prior to setting CTS. 3. Test BOPE to 250 psi low/ 2,500 psi high. Test annular to 250 psi low/ 2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” and 3-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. RU spoolers to handle ESP cable. 6. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. The PU weight during the 2018 ESP swap was 72k to unseat the hanger and 68K lbs to free pipe. b. The current completion was landed with 17K slack off wt and a PUW of 74K. 7. Confirm hanger free, lay down tubing hanger. 8. POOH and lay down the 2-7/8” tubing. Number all joints. a. Contact OE for caliper results and what to do with 2-7/8” tubing. b. Note any sand or scale inside or on the outside of the ESP on the morning report. c. Look for over-torqued connections from previous tubing runs, trash these joints. 216 Cross collar clamps 4 Protectolizer Clamps 2 Flat Guard Clamps 9. Lay Down ESP. 10. PU 3-1/2” workstring and MU 7” casing scraper. TIH to 13,250’ md. Reciprocate around 12,900’ – 13,000’ and TOOH. 11. RIH with 7” test packer to 12,900’ MD. Test casing to 3,500 psi. 12. RIH with new 3-1/2”, 12.6# L-80 completion to +/- 13,150’ and obtain string weights. Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Lb/ft Material Notes 3-1/2” WLEG L-80 Place at ±13,175’ md 3.5''Joints 9.2 L-80 3.5''10'Pup Joint 9.2 L-80 3.5''XN Nip with RHC profile 9.2 L-80 Place at ±12,950’ md 3.5''10'Pup Joint 9.2 L-80 3.5'' 1 joint 9.2 L-80 Or maximum power fluid inj pressure. -mgr Well: MPU F-79 Scope: Conv to JP Date: 04/17/2023 3.5''10'Pup Joint 9.2 L-80 7'' 7” x 3-1/2” Packer 9.2 L-80 Packer set ±12,900' MD 3.5''10'Pup Joint 9.2 L-80 3.5'' 1 joint 9.2 L-80 3.5''10'Pup Joint 9.2 L-80 4.5''Gauge Mandrel 9.2 L-80 3.5''10'Pup Joint 9.2 L-80 3.5'' 1 joint 9.2 L-80 3.5''10'Pup Joint 9.2 L-80 3.5''Sliding Sleeve 9.2 L-80 ±12,780' MD 3.5''10'Pup Joint 9.2 L-80 3.5''Joints 9.2 L-80 3.5''10'Pup Joint 9.2 L-80 3.5''SSSV 9.2 L-80 SSSV set ±2,200' MD 3.5''10'Pup Joint 9.2 L-80 3.5''Space out PUPS 9.2 L-80 3.5'' 1 joint 9.2 L-80 3.5''PUP 9.2 L-80 3.5''Tubing Hanger 9.2 L-80 13. Spot corrosion inhibited packer fluid in the IA between the sliding sleeve and the packer. IA volumes based on proposed depths: a. Surface to sliding sleeve: 0.02636bpf x 12,780’ = 337 bbls b. Sliding sleeve to packer: 0.02636bpf x 120’ = 3.2 bbls c. IA Surface to 2,000’ (freeze protect): 0.02636bpf x 2,000’ = 53 bbls d. Tbg Surface to 2,000’ (freeze protect): 0.0087bpf x 2,000’ = 18 bbls 14. Drop ball and rod and complete loading tubing with FP and hydraulically set the packer as per manufacturers setting procedure. 15. Pressure up and test the tubing to 3,000 psi for MIT-T with positive pressure on the IA. Bleed off the tubing to 1000psi. Test the IA to 3,500 psi for MIT-IA. Record and notate all pressure tests (30 minutes) on chart. 16. Set BPV. 17. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. * 24 hour notice for opportunity of AOGCC to witness. Well: MPU F-79 Scope: Conv to JP Date: 04/17/2023 Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By TDF 4/23/2019 SCHEMATIC Milne Point Unit Well: MPU F-79 Last Completed: 2/1/2018 PTD: 197-180 TD =18,776 (MD) / TD = 7,098’(TVD) 20” Orig. KB Elev.: 44.55/ GL Elev.: 11.5’ (N27E) 4-1/2” 2 3 7 &8 6 10 9 11 9-5/8” 1 MIN ID= 2.205” @ 12,435’ PBTD =18,401 (MD) / PBTD = 7,135’(TVD) 5 4 KUP A Sands 7” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 N/A Surface 112' 0.0355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 7,340’ 0.0759 7" Production 29 / L-80 / Hydril 563 6.184 Surface 2,149’ 0.0371 7" Production 29 / L-80 / Hydril 511 6.276 2,149’ 13,246’ 0.0371 7" Production 26 / L-80 / BTC 6.276 13,246’ 13,410’ 0.0383 4-1/2” Liner 12.6 / L-80 / EUE 8rd 3.958 13,247 18,645’ 0.0152 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surf 12,595 0.00579 JEWELRY DETAIL No Depth Item 1139’ST 2: Camco 2-7/8” X 1'' Side Pocket w/ Orifice 2 12,325’ST 1: Camco 2 7/8 X 1'' Side pocket,W/Dummy 3 12,435’ 2-7/8” XN-Nipple: 2.205” No-go ID 4 12,539’ Discharge Head: GPDIS 5 12,540’ Pump: 119P23 / SXD 6 12,557’ Gas Separator: GRS FER N AR 7 12,560’ Upper Tandem Seal: GSB3DBUT SB/SB PFSA 8 12,567’ Lower Tandem Seal: GSB3DBLT SB/SB PFSA CL5 9 12,574’ Motor: XP – 250Hp/ 2,505V/ 61A 10 12,591’ WellLiftSensor w/ Centralizer: Bottom @ 12,595’ 11 13,247’ Baker Liner Hanger and Packer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Date Statu s Kup. A Sands 15,880’ 15,968’ 7,116’ 7,128’ 88 2-7/8” 11/29/97 Open 16,080’ 16,400’ 7,138’ 7,146’ 320 2-7/8” 11/29/97 Open 16,499’ 16,850’ 7,144’ 7,147’ 331 2-7/8” 11/29/97 Open 17,090’ 17,800’ 7,158’ 7,176’ 710 2-7/8” 11/29/97 Open 17,850’ 18,170’ 7,173 7,155’ 320 2-7/8” 11/29/97 Open Ref Log: Based off Measured Depth – SWS 34J Deep Penetrating Charges (EHD=.029’/ TTP=20.57” Phasing 60°/ 120° OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in a 24” Hole 9-5/8" 1,720 sx PF ‘E’, 529 sx Class ‘G’’ in a 12-1/4” Hole 7” 495 sx Class ‘G’ in a 8-1/2” Hole 4-1/2” 1,050 sx Class ‘G’ in a 6” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 96° @ PBTD Hole Angle through perf interval = 84° to 93° TREE & WELLHEAD Tree Cameron 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A w/ 2-7/8” FMC Tbg. Hngr., 3” LH Acme on Top and 2-7/8” EUE 8rd on Bottom, 2.5” CIW BPV profile. GENERAL WELL INFO API: 50-029-22813-00-00 Drilled and Completed by Nabors 27E - 12/4/1997 ESP Swap by Nabors 4ES - 4/9/1998 ESP Swap by Nabors 4ES - 12/18/2003 Convert to Gas Lift by Nabors 3S - 5/18/2009 ESP Swap by ASR#1 – 2/1/2018 _____________________________________________________________________________________ Revised By TDF 4/17/2023 PROPOSED Milne Point Unit Well: MPU F-79 Last Completed: 2/1/2018 PTD: 197-180 TD =18,776 (MD) / TD =7,098’(TVD) 20” Orig. KB Elev.: 44.55/ GL Elev.: 11.5’(N27E) 4-1/2” 2 3 6 7 9-5/8” 1 MIN ID= 2.250” PBTD =18,401 (MD) / PBTD = 7,135’(TVD) 5 4 KUP A Sands 7” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / H-40 N/A Surface 112' 0.0355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 7,340’ 0.0759 7" Production 29 / L-80 / Hydril 563 6.184 Surface 2,149’ 0.0371 7" Production 29 / L-80 / Hydril 511 6.276 2,149’ 13,246’ 0.0371 7" Production 26 / L-80 / BTC 6.276 13,246’ 13,410’ 0.0383 4-1/2” Liner 12.6 / L-80 / EUE 8rd 3.958 13,247 18,645’ 0.0152 TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / EUE 8rd 2.992 Surface ±13,200 0.0058 JEWELRY DETAIL No Depth Item 1 ±2,200’ SSSV 2 ±12,780’ Sliding Sleeve 3 ±12,850’ BHP Gauge 4 ±12,900’ 7” x 4.5” Packer 5 ±12,950’ XN Nipple (Min ID= 2.250” No-Go) 6 ±13,173’ WLEG: Bottom @ ±13,175’ 7 13,247’ Baker Liner Hanger and Packer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Date Statu s Kup. A Sands 15,880’ 15,968’ 7,116’ 7,128’ 88 2-7/8” 11/29/97 Open 16,080’ 16,400’ 7,138’ 7,146’ 320 2-7/8” 11/29/97 Open 16,499’ 16,850’ 7,144’ 7,147’ 331 2-7/8” 11/29/97 Open 17,090’ 17,800’ 7,158’ 7,176’ 710 2-7/8” 11/29/97 Open 17,850’ 18,170’ 7,173 7,155’ 320 2-7/8” 11/29/97 Open Ref Log: Based off Measured Depth – SWS 34J Deep Penetrating Charges (EHD=.029’/ TTP=20.57” Phasing 60°/ 120° OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in a 24” Hole 9-5/8" 1,720 sx PF ‘E’, 529 sx Class ‘G’’ in a 12-1/4” Hole 7” 495 sx Class ‘G’ in a 8-1/2” Hole 4-1/2” 1,050 sx Class ‘G’ in a 6” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 96° @ PBTD Hole Angle through perf interval = 84° to 93° TREE & WELLHEAD Tree Cameron 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A w/ 2-7/8” FMC Tbg. Hngr., 3” LH Acme on Top and 2-7/8” EUE 8rd on Bottom, 2.5” CIW BPV profile. GENERAL WELL INFO API: 50-029-22813-00-00 Drilled and Completed by Nabors 27E - 12/4/1997 ESP Swap by Nabors 4ES - 4/9/1998 ESP Swap by Nabors 4ES - 12/18/2003 Convert to Gas Lift by Nabors 3S - 5/18/2009 ESP Swap by ASR#1 – 2/1/2018 Updated 8/11/2020 Milne Point ASR Rig 1 BOPE 2023 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30'Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR ' �a 'ts STATE OF A AKA OIL AND GAS CONSERVATION COMSPSION REPORT OF SUNDRY WELL OPERATIONS czd 2 8 2018 1.0 Operations AbandonLJ p Li Plug Perforations U Fracture StimulateU Pull Tubing LI o n Performed: Suspend 0 Perforate ❑ Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ ?.rforate New Pool ❑ Repair Well❑✓ Re-enter Susp Well❑ Other: ESP Change-out ❑✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Exploratory DevelopmentEx ❑ p ry ❑ 197-180 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-22813-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0355018 MILNE PT UNIT F-79 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured 18,776 feet Plugs measured N/A feet true vertical 7,098 feet Junk measured N/A feet Effective Depth measured 18,401 feet Packer measured N/A feet true vertical 7,135 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 74' 20" 112' 112' N/A N/A Surface 7,304' 9-5/8" 7,340' 4,311' 5,750psi 3,090psi Production 13,379' 7" 13,410' 6,594' 7,240psi 5,410psi Liner 5,398' 4-1/2" 18,645' 7,111' „ ,$,4 psi 7,500psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 12,595' 6,309' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 148 59 1,836 150 217 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑✓ Exploratory❑ Development❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-562 Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pchan@hllcorp.com Authorized Signature: // Date: 21-36/2e1a Contact Phone: 777-8333 3-7—/V RE r,trS * ,�. - l �t18 Form 10-404 Revised 4/2017 Submit Original Only • � Milne Point Unit SCHEMATIC well: MPU F-79 Last Completed: 2/1/2018 14 Hilcorp Alaska,LLC PTD: 197-180 TREE&WELLHEAD Tree Cameron 2-9/16"5M Orig.KB Elev.:44.55/GL Elev.:11.5'(N27E) 11"x 7-1/16"5M FMC Gen 5A w/2-7/8"FMC Tbg.Hngr.,3"LH Wellhead Acme on Top and 2-7/8"EUE 8rd on Bottom,2.5"CIW BPV profile. 20',1 OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I(Approx)in a 24"Hole 1 9-5/8" 1,720 sx PF`E',529 sx Class'G"in a 12-1/4"Hole ' 7" 495 sx Class'G'in a 8-1/2"Hole 4-1/2" 1,050 sx Class'G'in a 6"Hole CASING DETAIL . ,i Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.1/H-40 N/A Surface 112' 0.0355 , 9-5/8" Surface 40/L-80/BTC 8.835 Surface 7,340' 0.0759 9-5/8 a II 7" Production 29/L-80/Hydril 563 6.184 Surface 2,149' 0.0371 7" Production 29/L-80/Hydril 511 6.276 2,149' 13,246' 0.0371 7" Production 26/L-80/BTC 6.276 13,246' 13,410' 0.0383 4-1/2" Liner 12.6/L-80/EUE 8rd 3.958 13,247 18,645' 0.0152 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 7,739' 0.00579 WELL INCLINATION DETAIL KOP @ 350' Max Hole Angle=96°@ PBTD Hole Angle through perf interval=84°to 93° JEWELRY DETAIL 2 No Depth Item MIN 11:: 2.205"C 12,a35' 1 139' ST 2:Camco 2-7/8"X 1"Side Pocket w/Orifice 3 2 12,325' ST 1:Camco 2 7/8 X 1"Side pocket,W/Dummy 3 12,435' 2-7/8"XN-Nipple:2.205"No-go ID a 4 12,539' Discharge Head:GPDIS 5 12,540' Pump:119P23/SXD 5 6 12,557' Gas Separator: GRS FER N AR 7 12,560' Upper Tandem Seal:GSB3DBUT SB/SB PFSA NI I 6 - 8 12,567' Lower Tandem Seal:GSB3DBLT SB/SB PFSA CL5 7&8 9 12,574' Motor: XP-250Hp/2,505V/61A 10 12,591' WeIILiftSensor w/Centralizer:Bottom @ 12,595' r-0 A 11 13,247' Baker Liner Hanger and Packer s PERFORATION DETAIL trh Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Size Date Statu s 10 15,880' 15,968' 7,116' 7,128' 88 2-7/8" 11/29/97 Open 7" 81 IE 11 16,080' 16,400' 7,138' 7,146' 320 2-7/8" 11/29/97 Open Kup.A Sands 16,499' 16,830' 7,144' 7,147' 331 2-7/8" 11/29/97 Open 17,090' 17,800' 7,158' 7,176' 710 2-7/8" 11/29/97 Open 17,850' 18,170' 7,173 7,155' 320 2-7/8" 11/29/97 Open Ref Log: Based off Measured Depth-SWS 341 Deep Penetrating Charges(EHD=.029'/TTP=20.57"Phasing 60°/120° GENERAL WELL INFO API:50-029-22489-01-00 Sidetracked,Perfed&Frac'd by Nabors 4ES -1/1/96 ESP Swap by Nabors 4E5-8/19/1998 KUP A Sands ESP Swap by Nabors 4ES-10/30/1998 Convert to Gas Lift by Nabors 4ES-9/23/2002 SLB Frac Job-8/16/2010 Convert to ESP by Doyon 16-3/17/2011 ESP Swap by Doyon 16-07/06/2016 41/2"� >, ;-0;, ESP Swap by ASR#1-2/1/2018 TD=18,776(MD)/TD=7,098'(TVD) PBTD=18,401(MD)/PBTD=7,135'(TVD) Revised By TDF 2/26/2018 �� _~ Hilcorp Alaska, LLC �� . Summary �� ~��Ux Operations ^� Well Name Rig API Number Well Permit Number Start Date End Date MP F-79 A3R#1 58'029'22813'00'00 197'180 1/26/18 2/1/18 Daily Operations: - 1/24/2017 Wednesday No activity to report. 1/25/2017 No activity to report. /26 s+, "^",` , Order KWF f/ Baroid for kill on F-79. Rig crew set rig mats in place on F-70 spot mud boat in position for rig up, back mud pits into place, spot flow back tank down wind of personnel operations, spot circulation trailer by wellhead and rig up hard line from circulation trailer to flow back tank. Waiting on kill fluid. R/Ll LRS, P/T lines good, pump 568 bbls 10.6 brine @ 5 BPM, 1,880psi,taking returns t/flow back tank until 10.6 brine returns, Monitor well, went on vac, in 20 mn,freeze protect surface lines release LRS truck Unload 10.6 Brine in pits, blow down surface circulating lines& r/d, spot Eq.for rig up.Test tree void good, install BPV. N/D tree, N/U BOPE, spot well house,floor, & rig. -Saturday Continue to R/Ll on well F-79. Hydraulic power on rig not responding.Trouble shoot. SIMOPS: spot TP/accumulator trailer into position, L/D hydraulic lines to BOP's as well as electric lines and wrap in tarp. Spot dog house and company rep trailer into position on well F-79. Continue to R/U on F-79. Prostar on location to trouble shoot hydraulic shut down. Found a bad sensor that was tripping the breaker controlling the hydraulic unit ESD. Raise mast into position, R/| mast lock pins, R/U choke and kill lines and wrap w/ heat trace, set escape stairs in place, L/D herculite, spot in catwalk, and heat rig cellar. SIMOPS: Conam, Prostar, and Canrig on location to install systems. Cont. R/U & prep for BOPE test,test fire &gas upgrade, had programing failure, troubleshoot & repair program, test gas alarms good,flood surface lines &eq. for shell test. Shell test, troubleshooting leaks. gland nut started leaking, repair. 1/2 -S�` Continue to look for leaks on BOPE test. Gland nut found to be leaking.Tighten and re-test.Test still leaking off. Pump 10.6ppg brine out of pit# 1 and take on fresh water. Conam on location to complete fire and gas audible and visual alarm installation.Test BOPE asper Sundry and ASR test procedure.Test w/J'7/8" and 3'1/I" test joints to25Opsilow and /\L�'/ 3,S08pd high for 5 charted mins each. Blow down BOPE, taking fluids outside to the cuttings tank. Well head reps on �(/ location to pull TWC and BOLDS. SIMOPS: Prostar and Canrig on location to perform rig watch system installation. M/U landing joint to TBG hanger and pull hanger to the floor. 72klbs to move pipe, weight broke over at 68klbs.Prep to POOH w/ ESP completion, disconnect ESP cable from penetrator and tie off ESP cable to spooler starting line. POOH w/ ESP completion on 2-7/8" EUE TBG f/surface to —1,700'md. Perform Kick While Tripping drill w/day crew. Shut in and secure well in 4min 30s.Turn the rig over to Prostar and Canrig to perform installations. Prostar and Canrig work on installations. Hands preform rig maintenance . & housekeeping. Circulate oil cap off well, blow down Cont. POOH w/ ESP completion on 2'7/8" EUETBG f/ 1'7UO''t/~6,U80'' swap cable spools Cont. POOH w/ ESP completion on ]-7/8" EUETBG t/8,9S0' • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-79 ASR#1 50-029-22813-00-00 197-180 1/26/18 2/1/18 Daily Operation's: c 1/29/2017- Monday Continue to POOH w/ ESP completion on 2-7/8" EUE to discharge head.400 total joints recovered. Fill hole prior to pulling BHA into BOPE (20bbls to fill) L/D ESP completion. Swap over pipe handling equipment f/2-7/8" to 3.5" clean and clear floor. M/U Weatherford 7" CSG scraper BHA. RIH w/Weatherford 7" CSG scraper on 3.5" work string f/surface down to 10,100'md. Wipe PKR setting depth @ 10,000'md. R/U to reverse circulate.Service rig& maintenance while loading fluids to pits, CBU @ 3 BPM, 275psi, took 26 bbls t/fill hole, fluid loss @ 2:1, shut down blew down lines. POOH w/scraper assy. C/0 BHA, L/D scraper, P/U 7" Scraper assembly RIH, with 7" scraper assy. 1/30/2017 -Tuesday Continue to RIH on 3.5" NC-31 work string w/Weatherford CSG packer down to"10,000'md.Set Weatherford CSG PKR on joint 249 (9,975'md). Fill IA, allow air to work out of system, close VBR's and prepare to test annulus.Test 7" 29#CSG w/ 10.6ppg brine to 2000psi f/30 charted mins. (Good Test). Bleed pressure off system, and allow well to balance out. POOH w/Weatherford CSG PKR on 3.5" NC-31 work string from ^'9,975'md. POOH w/Weatherford 7" retrievable Test PKR on 3.5" NC-31 work string t/surface, L/D same C/O Handling Eq. Prep t/o P/U ESP assy. P/U &Service Baker ESP Assembly. Rack&tally pipe,Test cable good RIH w/ ESP Assy on 2 7/8" EUE 8rd tubing. r,,Lt G x • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-79 ASR#1 50-029-22813-00-00 197-180 1/26/18 2/1/18 Daily Operations: 1/31/2017 -Wednesday Continue to RIH w/ ESP completion on 2-7/8" EUE TBG f/"800'md to "8,300'md.;R/U and circulate down TBG w/10.5ppg brine. Catch pressure @ 3bbls away. Circulate @ 0.75BPM = 550psi. Baker Centrilift perform reel to reel ESP cable splice. Continue to RIH w/ ESP completion on 2-7/8" EUE TBG t/12,435', testing cable every 2,000' good. Pump down tubing, catch fluid &4 bbls, pump 1 BPM, 700 psi, blow down lines. Continue to RIH w/ ESP completion on 2-7/8" EUE TBG t/12,573', test cable every good. M/U hanger w/landing jt, m/u penetrator splice, Test good, land same placing assembly tail & 12,594'up wt 74k, do wt 17k, pull landing jt, set BPV. Flush all surface lines. start R/d Eq. 2/1/2017-Thursday Continue to R/D on F-79 and relocate to A pad for storage. Wellhead reps on location to N/U and test production tree. Release rig from well @ 17:00 on 2/1/2018. 2/2/2017 - Friday No activity to report. 2/3/2017-Saturday No activity to report. 2/4/2017-Sunday No activity to report. 2/5/2017 - Monday No activity to report. Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday,January 26, 2018 8:29 AM To: 'Paul Chan' Cc: Bo York;Cody Rymut- (C); Harold Soule- (C) Subject: RE: MP F-79 ESP Swap (PTD 197-180/Sundry 317-562) Paul, Per our phone conversation you may go ahead and move rig to F-79. After reviewing the shut-in data from last September the well clearly shows an average reservoir pressure under 8.55 ppg EMW. By not getting offset injection shut-in the localized wellbore pressure is now higher but would be expected to drop to normal levels within weeks of production. As a condition of approval to omit packer(per C0390A)for this completion I will require a 24 hour shut-in of the well within 60 days of production to verify well is actually trending toward normal pressures as seen on the ESP pressure plots supplied. Hilcorp may also be able to trend ESP intake pressures/flow rates and verify the IP for the well is also trending toward typical pre RWO values. Please update the MOC form to reflect this discussion also. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Paul Chan [mailto:pchan@hilcorp.com] Sent:Thursday,January 25, 2018 4:41 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc: Bo York<byork@hilcorp.com>;Cody Rymut-(C)<crymut@hilcorp.com>; Harold Soule-(C)<hsoule@hilcorp.com> Subject: MP F-79 ESP Swap(PTD 197-180/Sundry 317-562) Guy During the well kill operations for the MP F-79 ESP swap, pressure was still noted on the tubing and annulus after circulating the wellbore over to 8.5 ppg seawater. The calculated brine weight to kill the well was^'10.2 ppg. Hilcorp Alaska then elected to move to the next approved well on the schedule in order to evaluate the reservoir pressure in MP F-79. Upon further review, Hilcorp had not reduced or shut in enough offset injection support since the ESP failure on November 23,2017 to maintain the reservoir pressure below 8.55 ppg EMW. 1 • Attached for your reference are the approved sundry,screen shot of the ESP BHP readings in September from a five day shut down,and the SBHPS taken today. Hilcorp Alaska respectfully requests a waiver to run an ESP packer as per CO 390A on the MP F-79 well. Sincerely Paul Chan Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC (907)777—8333 (w) (907)444—2881 (c) 2 OF TFj • wA\� I X7,1 sv THE STATE Alaska Oil and Gas w --ti-aa�—' fALAS�o Conservation Commission Witt _ ^ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0FX"4 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager jAN 0 S Hilcorp Alaska, LLC SCOE 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU F-79 Permit to Drill Number: 197-180 Sundry Number: 317-562 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. • As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ADOCI" -- Hollis S. French Chair DATED this�day of November, 2017. L:S € .f..7 �rr��.� V tam w J `�ui! • . RECEWED NOV 2 8 2017 STATE OF ALASKA a�S i t ! 7 ALASKA OIL AND GAS CONSERVATION COMMISSION g'� APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑✓ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q. 197-180 " 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic EIService ❑ 6.API Number: Anchorage Alaska 99503 50-029-22813-00-00 , 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D , Will planned perforations require a spacing exception? Yes ❑ No ❑� . MILNE PT UNIT F-79 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0355018 MILNE POINT/KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 18,776' , 7,098' . 18,388' . 7,137' , 1,855 18,401' N/A Casing Length Size MD TVD Burst Collapse Conductor 74' 20" 112' 112' N/A N/A Surface 7,304' 9-5/8" 7,340' 4,311' 5,750psi 3,090psi Production 13,379' 7" 13,410' 6,594' 7,240psi 5,410psi Liner 5,398' 4-1/2" 18,645' 7,111' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic ' See Schematic 2-7/8" 6.5#/L-80/EUE 8rd 12,616' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic❑ Development❑, • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 12/16/2017 Commencing Operations: OIL D ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTORCI❑ SPLUG Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. �l, Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pCh2rltC7l hIICOrp.00171 Contact Phone: 777-8333 Authorized Signature: / Date: 11/27/2017 f COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: rs •— ' /ryZ5-00 r5i �0If 1r:-S Post Initial Injection MIT Req'd? Yes � No ❑ RB •Spacing Exception Required? Yes ❑ No yr Subsequent Form Required: /0 —4-/©c( r" ° .i C r'" r d ly LU 11 APPROVED BY I Approved by: daLZ"---\__ COMMISSIONER THE COMMISSION Date: f t 3 ll q ..?/4/3 it/ 9/ 7- 4ri,'(i ORIGINAL /i q-, ' Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • 1/1 Well Prognosis Well: MPU F-79 Ililcorp Alaska,LD Date: 11/27/2017 Well Name: MPU F-79 API Number: 50-029-22813-00 Current Status: Oil Well Pad: F-Pad Estimated Start Date: December 16th, 2017 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 197-180 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907)947-9533 (M) APE:Number: Job Type: 4 )SPRepair Current Bottom Hole Pressure: 2,482 psi @ 6,268'TVD (ESP Gauge 09/19/2017/7.61 ppg EMW) Maximum Expected BHP: 2,482 psi @ 6,268'TVD (No new perfs being added) / MPSP: 1,855 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-79 was drilled and completed in December 1997 as a horizontal Kuparuk River producer. ESP installation history: December 1997 (initial),April 1998, December 2003, and May 2009. The ESP has failed. Notes Regarding Wellbore Condition • The 7" production casing was tested on November 21, 1997. • CO 390A: Hilcorp Alaska respectfully requests that a packer not be required on this ESP completion as the reservoir pressure is less than 8.55 ppg EMW. Objective: Pressure test 7" casing and replace failed ESP. / Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. • • Well Prognosis Well: MPU F-79 fficort,Alaska.LI) Date:11/27/2017 Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg sea water prior to pulling BPV. Set TWC. 12. 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 dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" and 3-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. 00-1 b. With stack out of the test path,test choke manifold per standard procedure tom,! c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor l the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking (i;,J� 6 anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection,etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg sea water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2009 ESP swap was 70K lbs. (block weight not noted on report) b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 16. Recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8" tubing. Number all joints. Tubing will be re-used as noted. Lay down ESP. a. Replace bad joints of tubing as necessary and note on tally new tubing run. b. Note any sand or scale inside or on the outside of the ESP on the morning report. c. Look for over-torqued connections from previous tubing runs. 18. PU & RIH with 7" 26#scraper assembly to 10,100' MD on 3-1/2" workstring. Reciprocate scraper across packer setting depth of—10,000' MD. Circulate the well clean. S Well Prognosis Well: MPU F-79 Bacon)Alaska,LLI Date: 11/27/2017 19. POOH. L/D scraper assembly and 3-1/2" workstring. 20. PU test packer and RIH on 3-1/2" workstring to"'10,000' MD. 21. Set test packer and pressure test 7" casing to 2000 psi for 30 charted minutes. K� 22. Unseat test packer and POOH. 23. PU new ESP and RIH on 2-7/8"tubing. Set base of ESP assembly at± 12,612' MD. a. Upper GLM @ ± 140' MD w/SO b. Lower GLM @ ± 12,475' MD w/ DGLV c. 2-7/8" XN (2.205" No-Go) @ ±12,522' MD d. Base of ESP centralizer @ ± 12,612' MD 24. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off)weights on tally. 25. Set BPV. Post-Rig Procedure: 26. RD mud boat. RD BOPE house. Move to next well location. 27. RU crane. ND BOPE. 28. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 29. RD crane. Move 500 bbl returns tank and rig mats to next well location. 30. Replace gauge(s) if removed. 31. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Blank RWO MOC Form Tree: Cameron 2 9/16"50 79 Orig.•EIev. = 44.55' (N 27E) MPU F- Wellhead: 11" x 7 1/16"5M FMC Gen Orig. GL Elev. = 11.5' 5A,w/2 7/8" FMC tbg. hng., 3" LH acme on top and 2 7/8" EUE 8 rd on DF To Tbg. Spool = 30.90' (N 27E) bottom, 2.5" CIW BPV profile 20" 91.1 ppf, H-40 115' Camco 2 7/8"x 1" sidepocket KBMM GL 141` KOP @ 350' t Max. hole angle =96 deg. @ PBTD ( )� 0 9 5/8" Howco 'ES' Hole angle thru' perfs=84 to 93 cementer deg. 2159' and 9 5/8", 40 ppf, L-80 Btrc. 7340' and A 11 1.--',e,pir 2 7/8"6.5 ppf, L-80, 8 rd EUE tbg. A./ (drift ID =2.347", cap. = 0.00592 bpf) `' Centrilift No. 2 SOL power cable 1 Camco 2 7/8"x 1" 12,475' sidepocket KBMM GI ta Hes XN-Nipple (2.205" id) 12,522' 7"26 ppf, L-80, Btrc. prod. casing i f/13,246'to 13,408' WeIILift DGU 12,533' (drift ID =6.151", cap. = 0.0383 bpf) OM Centrilift Tandem ESP 7"29 ppf, L-80, Hyd. 511. prod. casing W 74-P31SXD-74 P-31SXD 12,539' f/2149' to 13,246' md' ja Centrilift gas separator 12,568' (drift ID =6.059", cap. = 0.0371 bpf) ka GRSFTXARH6 7"29 ppf, L-80, Hyd. 563. prod. casing Centrilift tandem seal section 12,573' f/surface to 2149' md' GSB3DBUT/LT SB/SB PFSA (drift ID=6.059", cap. = 0.0371 bpf) am r Centrilift KMH Motor 12,586' 304 hp motor, 2290 v. /81a AIMIL Stimulation Summary WeIlLift MGU-sensor 12,612' Centralizer none performed Mid-pert= 7144' TVD 17025' and 4.5" Baker liner hgr./pkr. 13,247' and Perforation Summary i Ref log: based off of measured depth A 7"float shoe 13,410' and Size SPF Interval (TVD) Intake 5613' Kup. 'A' Sand12525' and 2 7/8" 4 15,880-15,986' (7117'-7130') r_1 2 7/8" 4 16,080'-16,400' (7139'-7147') 4.5" 12.6 ppf, L-80 IBT liner 2 7/8" 4 16,499'-16,850' (7146'-7148') 2 7/8" 4 17,090'-17,800' (7160'-7177') (drift= 3.833", cap.=0.0152 bpi 2 7/8" 4 17,850'-18,170' (7172'-7156') SWS 34J 15.2 gm.RDX deep penetrating charges (EHD = 0.29"TTP =20.57") 7246' tvd 60/ 120 deg. phasing 4.5' landing collar(PBTD) 18,401' and 4.5' float collar 18,521' and 4.5' float shoe 18,645' and DATE REV.BY COMMENTS MILNE POINT UNIT 12/05/97 JBF Drilled and Completed by Nabors 27E WELL F-79 04/11/98 MDO ESP RWO Nabors 4es _ API NO: 50-029-22813 12/18/03 MDO ESP RWO Nabors 4es 5/18/09 REH ESP RWO Nabors 3S HI LCORP ALASKA LLC Tree: Cameron 2 9/16"ill 79 Orig.SElev. = 44.55' (N 27E) MPU F— Wellhead: 11" x 7 1/16"5M FMC Gen Orig. GL Elev. = 11.5' 5A, w/2 7/8" FMC tbg. hng., 3" LH 1 4 DF To Tbg. Spool =30.90' (N 27E) acme on top and 2 7/8" EUE 8 rd on bottom, 2.5" CIW BPV profile PROPOSED SCHEMATIC 20" 91.1 ppf, H-40 115' Camco 2 7/8"x 1" sidepocket KBMM GL +141' KOP @ 350' Max. hole angle =96 deg. @ PBTD 0 9 5/8" Howco 'ES' Hole angle thru' perfs= 84 to 93 cementer deg. 2159' and 9 5/8", 40 ppf, L-80 Btrc. 7340' and I k I i 2 7/8"6.5 ppf, L-80, 8 rd EUE tbg. (drift ID =2.347", cap. = 0.00592 bpf) t' Centrilift No. 2 SOL power cable Camco 2 7/8"x 1" ±12,475' sidepocket KBMM GI II XN-Nipple (2.205" id ) ±12,522` 7"26 ppf, L-80, Btrc. prod. casing f/ 13,246'to 13,408' I (drift ID =6.151", cap. = 0.0383 bpf) Tandem ESP 7"29 ppf, L-80, Hyd. 511. prod. casing ±12,539' f/2149' to 13,246' md' IC Centrilift gas separator (drift ID =6.059", cap. = 0.0371 bpf) i'` ±12,568` 7"29 ppf, L-80, Hyd. 563. prod. casing II eak. Centrilift tandem seal section f/surface to 2149' md' i±12,573' (drift ID =6.059", cap. =0.0371 bpf) Motor 1±12,586' WeIILift MGU-sensor I±12,612' Stimulation Summary Centralizer none performed Mid-pert= 7144' TVD 17025' and 4.5" Baker liner hgr./pkr. 13,247' and Perforation Summary Ref log: based off of measured depth A , 7"float shoe 13,410' and Size SPF Interval (TVD) Intake 5613' Kup. 'A' Sand 12525' and 2 7/8" 4 15,880'-15,986' (7117'-7130') 2 7/8" 4 16,080'-16,400' (7139'-7147') 2 7/8" 4 16,499'-16,850' (7146'-7148') 4.5" 12.6 ppf, L-80 IBT liner 2 7/8" 4 17,090'-17,800' (7160'-7177') (drift= 3.833", cap.=0.0152 bpi 2 7/8" 4 17,850'-18,170' (7172'-7156') SWS 34J 15.2 gm.RDX deep penetrating charges (EHD = 0.29"TTP =20.57") 7246' tvd 60/120 deg. phasing 4.5' landing collar(PBTD) 18,401' and 4.5" float collar 18,521' and 4.5" float shoe 18,645' and DATE REV.BY COMMENTS MILNE POINT UNIT 12/05/97 JBF Drilled and Completed by Nabors 27E WELL F-79 04/11/98 MDO ESP RWO Nabors 4es API NO: 50-029-22813 12/18/03 MDO ESP RWO Nabors 4es 5/18/09 REH ESP RWO Nabors 3S H I LCO R P ALASKA LLC • 0 Milne Point ASR Rig 1 BOPE 2017 ilikorp Atoka,!.l.t 11" BOPE MI Stripping Head 4.48' / tydril GK " n" - 5000 , w, iiiimiii iii fii i iiinliia IA III NI III III III 06U ri \, 4.54' milli o ' ®° VBR or Pipe Rams 11"- 5000 Ai ��'m° Blind MIL ...grim -ut. * lit 11i iii 111 111 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves 1- 111911'111'111'111 :ir _Iv 2.00' )\it (off101 — a •1#I.Iill11I.iIit —� Manual Manual Manual HCR Updated 11/20/2017 • Swab Valve-Cameron FLS-2 9/16" 5K,manual gate valve,EE PSL2, MP F-79 PR2 11/27/2018 Current configuratiojn s Wing Valve,Cameron FLS 2 9/16" 4. Noir 5K,reverse acting,actuated gate `� valve,w/Baker actuator,EE PSL2 �a PR2 Arifp 2 9/16"5K tree with „ ,,, SSV Cameron FLS 2 9/16"5K, reverse acting,actuated gate 2 7/8"FMC Tubing Hanger t valve,w/Baker actuator,EE lea ESP only 1 a�*1 [ PSL2 PR2 No control lines = wtamatirf Master Cameron FLS FLS 2 9/16" " 05K,manual gate valve,EE PSL2 PR2 "t "' Tbg Hd Adpter,FMC 7"%K x 11" 5K,rotating flanges top and bottom,w/no control lines.lea ESP mandrel.No Heat trace. Bottom prepped for 2 7/8"seal sleeve ism t ENl Milililli:;;-': ,', 'I /•rl IIIIII<' IMM Kt _•!,1 lir - - U. „ iii �� i�s . _ _ . . . . . . . _. . .. _ _ 0 0 c22 a) J % k £ tWC D CO 0 _ 7 / , o0 E $ < 22 § ® « � E £ E e of '0C1) % E Y > d / 2 f k� f / < � co ,_ .- = o / / Q � 76 CL CL Ia)� ase � 03 § .D ■ ■ \ A k k ccrho C.)(13 2 � ƒ W R B O UI k\ lc 00 0 % ® a)§ cu E % o_ a) o c / : L / 2 / o a - = II to � EY @ cu '-0csi tti - 43 ccr IA r: / � - Q ■ o » o o - E c . . 0 k O k 0 0 0 all U) o 0§ 0® _0 a / .. 7 co -U v g/ >0. o2311 0 co 0 k a /> Ci m m < < < a. 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. / ~/'/--/,~(2 File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: GraYScale, halftones, pictures, graphs, charts - Pages: Poor Quality Original'- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type 'OVERSIZED [] [] ,Logs of various kinds Other COMMENTS: Sca n ned by~ildred, Daretha Nalhan Lowell Date' '~, ~, Is/ TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /si • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 , Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 `LOrt WANED F Mr. Tom Maunder f Alaska Oil and Gas Conservation Commission Y 1 333 West 7 m a Avenue 1 I Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD it API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF -02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF-05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/62011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/92011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top job MPF -34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF-37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF-38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/52011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/12011 MPF -45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/112011 MPF-58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/312011 MPF-61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/12011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/312011 MPF-69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/312011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/52011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 } MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 WA 0.5 N/A 3.4 8/3/2011 MPF-81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF-83 2000930 50029229630000 12 N/A 1.2 N/A 13.6 8/32011 MPF -84B 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 , 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF-88 2031930 50029231850000 1.3 N/A 1.3 WA 15.3 8/32011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/32011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 WA 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 WA 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9112011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 STATE OF ALASKA ALI~A OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPE~TIONS 1. Operations Performed: ^ Abandon ~ Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ~ Pull Tubing - ^ Perforate New Pool ^ Waiver ~ Other ^ Change Approved Program ^ Operation Shutdown Replace ESP , ^ PerForate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Deveiopment ^ Exploratory 797-180- 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22813-00-00 • 7. KB Elevation (ft): KBE = 47.3' • 9• ~Nell Name and Number: M PF-79 8. Property Designation: 10. Field / Pool(s): ADL 355018 Milne Point Unit / Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 18776 ~ feet true vertical 7098 feet Plugs (measured) N/A Effective depth: measured 18388 feet Junk (measured) N/A true vertical 7137 feet Casing Length Size MD ND Burst Collapse Structural Conductor 74' 20" 112' 112' Surface 7304' 9-5/8" 7340' 4311' 5750 3090 Intermediate Production 13379' 7" 13410' 6594' 7240 5410 Liner 5398' 4-1/2" 13247' - 18645' 6558' - 7111' 8430 7500 i~ar~"'iL~T~~^~ s ' i~~ ~~J ~ L : ., .. . Perforation Depth MD (ft): 15880' - 18170' Perforation Depth TVD (ft): 7116' - 7155' 2-7/8", 6.5# L-80 12616' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): NONE 12. Stimulation or cement squeeze summary: Intervalstreated(measured): ~jE~~ ~ ~ ~~~~ Treatment description including volumes used and final p ressure: ~~~~~~ ~~~~ F~ ~~,~ ~r~ns, ~~~mjSSi01i An~h~rage 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 316 811 137 340 268 Subsequent to operation: 430 . 179 962 288 320 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ~ Oil ~^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Mehrdad Nadem, 564-5941 N/A Printed Name ndra Stewman Title Drilling Technologist ~--- Prepared By Name/Number: S nature Phone 564-4750 Date T.~~ l.l~- Sondra Stewman 56a-a750 Form 70-404 Revised 04/2006 i~_ ~.. ~ _ ~~ . ~.3~ ~~ ~ 7~0~ Submit Original Only G~a~~ .~ c.~ ` ~~ ~ ~~"~/~~ L._ • • ~ r e: Cameron 2 9/16" 5M M P U F-79 Wellhead: 11" x 7'I/16" 5M FMC Gen 5A, w/ 2 7/8" FMC tbg. hng., 3" LH ', ;1~ acme on top and 2 7/8" EUE 8 rd on bottottz, 2.5" CIW BPV profile 20" 91.1 ppf, H-40 115' `,~ ~'. KOP @ 350' Max. hole angle = 96 deg. @ PBTD Hole angle thru' perfs = 84 to 93 deg. ? '': I 9 5/8", 40 ppf, L-80 Btrc. 7340' md 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. (drift ID = 2.347", cap. = 0.00592 bpf) Centrilift No. 2 SOL power cable 7" 26 ppf, L.-80, Btrc. prod. casing f/ 13,246' to 13,408' ( drift 1D = 6.151", cap. = 0.0383 bpf ) 7" 29 ppf, L-80, Hycf. 511. procf. casing f/ 2149' to 13,246' md' • ( drift ID = 6.059", cap. = 0.0371 bpf ) 7" 29 ppf, L-8p, Hyd. 563. prod. casing f/ surface to 2149' md' ( drift ID = 6.059", cap. = 0.0371 bpf ) Stimulatlon Summary none performed Mid-perf = 7144' TVD 97025' md Perforation Summary Ref loa: based off of ineasured depth 5ize SPF lnterval (TVD) Kup. 'A' Sand 2 7/8" 4 15,880'-15,986' (7'117'-7130') 2 7/8" 4 16,080'-16,400' (7139'-7147') 2 7/8" 4 16,499'-16,850' (7146'-7148') 2 7/8" 4 17,090'-17,800' (7160'-7177') 2 7/8" 4 17,850'-18,170' (7172'-7156') Orig. DF Elev. = 44.55' (N 27E) Orig. GL Elev. = 11.5' DF To Tbg. Spool = 30.9~' (N 27E) Camco 2 7/8" x 1" sidepocket KBMM GL 141' 9 5/8" Howco 'ES' cementer 2159' md Camco 2 7!8" x 1" 12,475' sidepocket KBMM Gt Hes XN-Nipple ( 2.205" id } 12,522' WeIILift DGU 12,533` Centrilift Tandem ESP ~2 539' 74-P31 SXD - 74 P-31 SXD , Centrilift gas separator 12,568' GRSFTXARH6 Centrilift tandem seal section 573' 12 GS63DBUT/LT 56l56 PFSA , Centrilift KMH Motor ~2586~ 304 hp rnotor, 2290 v. / 81a WeIILift MGU-sensor 12 612~ Centralizer 4.5" Baker liner hgr./pkr. 13,247' md 7" floa# shoe 13,410' md Intake - 5613' 12525' md 4.5" 12.6 ppf, L-80 fBT liner (drift = 3.833", cap.=0.0152 bpf SWS 34J 15.2 gm.RDX deep penetrating ~ " 7246' Nd charges (EHD = 0.29" TTP = 2~.57") 60 / 120 deg. phasing _ 4.5" landing collar (PBTD) 18,401' md 4.S' float collar 18,521' md 4.5' float shoe 18,645' md DATE REV. BY COMMENTS ~~~NE POINT UNIT 12/05/97 JBF Drilled and Completed by Nabors 27E WELL F-79 04/11/98 MDO ESP RWO Nabors 4as API NO: 50-029-22813 12/18/03 MDO ESP RWO Nabors 4es 5/18/09 REH EsP Rwo Nabors 3s BP EXPLORATION (AK) • • BP EXPLORATI~N Page 1 of 3 Operations Summary Report Legal Well Name: MPF-79 Common Well Name: MPF-79 Spud Date: Event Name: WORKOVER Start: 5/8/2009 End: 5/19/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/19/2009 Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description caf Operatians 5/14/2009 00:00 - 01:30 1.50 RIGD P PRE Scope and lay down Derrick. Disconnect steam and electrical. Jack down pits and pipe shed and pull away from carrier. 01:30 - 05:00 3.50 RIGD P PRE Pull carrier off well slot MPF-86 with pad-operator witness. Move BOPE components and cradle out from behind well. Spot rig mats around MPF-79. Spot BOPE components on mats behind well. Set kill manifold behind well. Lay herculite around well. 05;00 - 08:30 3.50 RIGU P PRE Move in spot carrier over F-79 well slot. Jack into position. Spot pits and pipe shed to carrier, jack up into position. Pad-op witness carrier spotting over well. 08:30 - 10:00 1.50 RIGU P PRE Raise and scope up Derrick. 10:00 - 11:00 1.00 RIGU P PRE Build berm and spot Up- Right tank. Take on 10.8 ppg NaBr. Accept rig at 1030 hrs on 5-14-09. 11:00 - 12:30 1.50 RIGU P DECOMP NU second annulus valve, kill manifold and hard line to Tiger tank. 12:30 - 13:30 1.00 RIGU P DECOMP Test surface lines and valves to 3,500 psi and down stream of the choke to the Tiger tank to 500 psi. 13:30 - 14:30 1.00 WHSUR P WHDTRE PU/MU and test lubricator with diesel to 500 psi. Pull BPV. WHP's - Tbg = 1080 , IA = 1280 , OA = 0. 14:30 - 20:00 5.50 KILL P DECOMP Held pre-well kill meeting. Open well to closed Choke. WHP's: Tubing = 1080 psi, IA = 1280 psi. Bleed IA and tubing to 820 psi on the Tubing and 880 psi on the IA. Pump 75 bbls of 10.8 ppg, 120 degF NaBr at 3-4 bpm / 1380 psi down the tubing up the IA through the choke to the Tiger tank and recovered 50 bbls crude. Close the Choke and bullhead down the tubing 126 bbls at 4 bpm / 1780 psi. Open the Choke and finish circulating 10.8 ppg NaBr around the long way until clean returns observed on surface. Pumped a total of 489 bbls at 5 / 1950 psi down the tubing up the IA through the choke to the Tiger Tank during final circulation. Total returns on surface minutes. TBG = 110 IA = 130 si. Circulate 100 bbls at 2.5 bpm / 650 psi and gained 3 bbis. Shut-in 30 minutes TBG = 50, IA = 70 psi. 20:00 - 23:00 3.00 KILL P DECOMP Confer with ADW RWO engineers, circulate 100 bbls at 2.5 bpm / 650 psi. Monitor WHP's for 30 minutes, TBG = 30, IA = 50. Calculate kill weight fluid with RWO engineer and mud engineer. Call out 12.4 ppq spike fluid to weiqht svsterr~un to 23:00 - 00:00 1.00 KILL N FLUD DECOMP Wait on kill fluid from MI mud plant. Service rig. 5/15/2009 00:00 - 06:00 6.00 KILL N FLUD DECOMP Continue to wait on 12.4 ppg spike fluid to weight up system to 11.2 ppg. Service rig and hang elephant trunk. 06:00 - 12:00 6.00 KILL P DECOMP Increase fluid weiqht in Pits to 11.2 ppg NaBr. Pump 73 bbls 11.2 ppg NaBr down the tubing up the IA through the choke / gasbuster to Pits at 4 bpm / 1250 psi. Bullhead 126 bbls 11.2 ppg NaBr into formation. Circulate 365 bbis down the tubing up the IA through open choke / gasbuster to Pits at 4 bpm / 1320 psi. Lost 7 bbls. TBG and IA on a sliaht vacuum. 12:00 - 13:00 1.00 WHSUR P DECOMP Blow down lines and valves. RD Tiger tank. 13:00 - 15:00 2.00 WHSUR P DECOMP D rod TWC with FMC wellhead tech. Pressure test TWC from above to 3 500 si for 10 charted minutes. Pum ed 8 I~bls to catch fluid. Test from below to 500 psi for 10 charted. minutes by iniectina into formation at 3 bpm /-400 psi. Printed: 5/26/2009 2:28:32 PM ~ • BP EXPLQRATION Page 2 af 3 ; Operations Summary Repart Legal Well Name: MPF-79 Common Well Name: MPF-79 Spud Date: Event Name: WORKOVER Start: 5/8/2009 End: 5/19/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/19/2009 Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Code ~ NPT ~ Phase Deserintion of Ooeratic~ns 5/15/2009 13:00 - 15:00 2.00 WHSUR P DECOMP Pumped 45 bbls and recovered 6 bbls. TBG and IA on a slight ', vacuum with a loss rate of -3 bpm. I 15:00 - 16:30 1.50 WHSUR P DECOMP FMC wellhead tech, bleed off tubing hanger void. Blow down and RD kill manifold and surface lines. ND production tree. Inspect hanger threads with pup joint - 7 turns by hand. At 1530 hrs 5/15/2009 Chuck Scheve, AOGCC inspector waived states right to witness BOPE test. 16:30 - 00:00 7.50 BOPSU P DECOMP NU DSA, Single gate and mud cross to wellhead. NU BOPE assembly stack with double gate and single gate. Monitor IA during NU - IA on vac. 5/16/2009 00:00 - 07:00 7.00 BOPSU P DECOMP Continue to NU BOPE double stack configuration: Annutar, Double Gate~(?_-7/8" x 5" VBR to~ - Blinds bottoml. Mud cross, Sinale Gate with 2-7/8" fixed rams, DSA. Fluid shot at 0100 hrs shows fluid level at 140'. Monitor IA during NU - IA on vac. Function test BOP components and double check flange connections. Take second fluid level shot at 0700 hrs shows fluid at -100' with IA on a slight vacuum. 07:00 - 12:00 5.00 BOPSU P DECOMP Pressure test BOPE to 250 si low and 3 500 si hi h er BP AOGCC Regulations. Each test held for 5 minutes. The top VBRs (2-7/8" X 5"), Blind rams, lower pipe rams (2-7/8") and Annular were tested with a 2-7/8" Test Joint against TWC. The test was witnessed by the Toolpusher and Well Site Leader. The State's right to witness the test was waived by Chuck Scheve at 1730 hrs on 5/15/2009. 12:00 - 13:00 1.00 BOPSU P DECOMP Blow down lines and valves, BO/LD test joint and test equipment. Void BOP stack of fluid. 13:00 - 14:00 1.00 WHSUR P DECOMP PU/MU Opso Lopso and lubricator, test to 500 psi with diesel. Well support techs pulled TW~. Tbg and IA on a vacuum. 14:00 - 15:00 1.00 WHSUR P TUBHGR MU 2-7/8" landing joint with TIW valve. FMC wellhead tech, BOLDS. Pull tubing hanger free at 65K, PUW = 70K, SOW = 30K. 15:00 - 17:00 2.00 PULL P DECOMP Circulate down the tubing up the IA to the Pits, couqht fluid after pumpinq 14 bbls Pumoed 365 bbls 11 2 ~oa NaBr at ~ bom / 1300 osi. lost 44 bbls (8%1 durina circulation. No aas in 17:00 - 18:00 1.00 PULL P DECOMP LD landing joint, TIW valve and tubing hanger. 18:00 - 00:00 6.00 PULL P DECOMP POH with 2-7/8" tubing, standing back in Derrick. Visually inspect all tubing for corrosion or scale. Maintain continuous hole fill with 11.2 ppg brine, losses = 9 bbl/hr. 110 stands out at 24:00 hrs. 5/17/2009 00:00 - 05:00 5.00 PULL P DECOMP Continue to POH with 2-7/8" tubing standing back in Derrick. Losses = 9 bbl/hr. Recovered 400 joints 2-7/8" tbg, 2-GLM's, XN, 207 LaSalle clamps, 5 Protectolizers, 3 Flat Guards. 05:00 - 08:00 3.00 PULL P DECOMP LD ESP um with Centrilift 08:00 - 09:00 1.00 PULL P DECOMP RD ESP cable trunk, change out ESP spools in Spooler Unit. 09:00 - 10:00 1.00 PULL P DECOMP Clean and clear Rig floor. 10:00 - 15:00 5.00 RUNCO P RUNCMP PU / MU and service ESP pump and motor assembly with Centrilift rep. 15:00 - 17:00 2.00 RUNCO RUNCMP Casing hydraulic pump failed. Repair hydraulic pump. 17:00 - 00:00 7.00 RUNCO RUNCMP RIH with 2-7/8" 6. #-rd tubin out of Derrick. Install LaSalle Clamps on first 9 joints then every other to surface. MU torque = 2,300 ft-Ibs, use Best-O-Life pipe dope on connections. Check conductivity every 2,000'. Maintain continuous hole fill, Printed: 5/26/2009 2:28:32 PM ! ! BP EXPL~RATIQN Page 3 af 3 Operations Summary Report 'Legal Well Name: MPF-79 Common Well Name: MPF-79 ', Event Name: WORKOVER 'Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 3S i ~ i i Start: 5/8/2009 Rig Release: 5/19/2009 Rig Number: I Spud Date: End: 5/19/2009 Date From - To Hours 5/17/2009 17:00 - 00:00 7.00 5/18/2009 00:00 - 02:30 2.50 02:30 - 06:00 3.50 06:00 - 07:00 1.00 07:00 - 08:00 1.00 08:00 - 09:00 1.00 09:00 - 11:00 2.00 11:00 - 12:00 1.00 BOPSU~ P 12:00 - 16:00 4.00 BOPSU P 16:00 - 18:00 I 2.001 WHSUR I P 18:00 - 19:30 1.50 WHSUR P 19:30 - 21:00 1.50 WHSUR P 21:00 - 00:00 3.00 RIGD P 5/19/2009 00:00 - 01:30 1.50 RIGD P 01:30 - 04:00 2.50 WHSUR C 04:00 - 06:30 I 2.501 WHSUR I C 06:30 - 08:00 I 1.501 WHSUR I C RUNCMP losses = 9 bbl/hr. 126 stands at 24:00 hrs. RUNCMP Centrilift make reel to reel splice. Check conductivity. RUNCMP Continue to RIH with 2-7/8" tubing out of Derrick. Fluid losses = 9 bbl/hr. Ran 400 joints 2-7/8" tbg, 2ea GLM's, XN with XXN installed, 208 LaSalle clamps, 6 Protertolizer, 3 Flat Guards, 2ea Mi-joint MLE/TEC clamps. RUNCMP PU / MU landing joint with TIW valve and tubing hanger. RUNCMP Centrilift rep perform tubing hanger penetrator splice and installed shipping cap. RUNCMP Land tubin han er and FMC Ilhead te h RIL . PUW = 62K, SOW = 30K. RUNCMP Dry rod TWC with FMC wellhead tech. Pressure test TWC from above to 3,500 psi for 10 charted minutes. Pumped 8 bbls to catch fluid. Test from below to 200 psi for 10 charted minutes by injecting into formation at 1 bpm / 250 psi. Pumped 24 bbls and recovered 3 bbls. RUNCMP Flush BOPE and Choke manifold with fresh water and blow down. Void BOP stack of water. RUNCMP ND BOPE, LD Annular and double gate on to shipping cradle. And remove from cellar. ND Lower pipe rams and 13-5/8" X 7-1/16" Flanged adaptor. RUNCMP NU tree and adapter flange. Centrilift make final checks on ESP cable. Test hanger void to 5,000 psi for 30 min with FMC rep. Test tree to 5,000 psi with diesel for 5 min - charted. RUNCMP RU lubricator with Well Support. Test to 500 psi with di~el. Pull TWC, set BPV. TBG = 0 psi. RUNCMP Remove double annulus IA valve, replace with 1502 flange. Normal up tree and cellar. POST Disconnect lines and power. Remove fluids from upright and spot in new position for MPF-80 RWO. Flush pits and remove fluids. Disconnect pipe shed and pits with sow. Jack down carrier. POST Move carrier and rig modules off MPF-79 with pad-op witness. Remove BOPE components from behind well. POST PJSM with ri crew Slickline and vac truck drivers on 112 brine recovery plan. RU scaffold around F-79. RU lubricator with Slickline and ull BPV. SimOps with Slickline due to wireline work on neighbor well F-80. RU hardline from F-79 to choke house to Tiger tank. Spot LRS unit and seawater vac trucks and connect to well. Pressure test lines to choke to 3,000 psi and downstream of choke to 500 psi. POST Perform Brine recovery from MPF-79 with LRS. Circulate 8.45 ppg seawater with LRS down tubing taking returns thru choke house to Tiger tank at 4 BPM / 2000 psi. Returns 11.2 ppg at surface, fluid weight slowly dropped to 11.0 ppg then fell quickly to 9.4 ppg. Shut down pumps and isolate well. Circulate a total of 445 bbls and returned 414 bbls (9~ returns POST Blow down lines from LRS to Tiger tank. RD hardline from F-79 to Tiger tank. Normal up tree and wellhead valve~s• Rig Printed: 5/26/2009 2:28:32 PM - ~ ~ ~ I~I MPF-79 Well History Date Summary 04/11/09 T/I/0=300/300/0. (Freeze protect for demobe) Freeze protect & flush FL w/ 2 bbls 60/40 meth, 3 bbis diesel, & 2 bbls 60/40 meth. Bleed tbg pressure down to 0 psi. Freeze protect tbg w/ 15 bbis 60/40 meth. FW HP=400/300/0. 04/12/09 RAN SWIVEL, OK-6 W/1.25" JDC TO ST #1, UNSUCCESSFUL. RAN 2.30" CENT, SWIVEL, OK-6 W/1.25" JDC, UNSUCCESSFUL. RAN 2.30" CENT, 2-7/8" BLB, OK-6 W/1.25" JDC, UNSUCCESSFUL. RIH W/ 2-7/8" BLB, SW IVEL, OK-6 W/ 1.25" JDC, CONT. 04/13/09 PUI I FI~ 1° RK-I~GI V FROM ST #1 Ca~ 12.474~ MD. PULL 1" BEK-DPSOV FROM ST #2 C~ 140' MD. SET 1" BK-DGLV ST #2 C~ 140' MD. SET 2.313" X-LOCK (no keys, no packing) W/FLOW THRU SUB (2.31" NG) S. ABSORBER, DUAL SPARTEK GAUGES. LIH= 97". C~3 12,549' SLM 04/19/09 The Well Support Techs rigged up and removed the wellhouse, flowline and foundation. The then installed the work platform for slickline work. NOTE: The BPV was left OUTfor upcoming slickline work! Note : There was a charge of $12724.12 for the Lubricator Yoke for MPU for rig work overs, per MPU Wells OP CORD Rob Handy. 04/23/09 PU~L GAUGES FROM 12540' SLM SET BPV ~~ ~~ 05/01/09 MPU Well Support tech PULLED BPV for slickline to do a static. 05/04/09 MPU Well Suport Techs «««<....SET BPV.....»»»» 05/04/09 RUN 2.15" CENT, SOFT SET, DUAL SPARTEK GAUGES. 05/14/09 RU on MPF-79. Pull BPV. Circulate well clean. Order / build kill weight fluid. 05/15/09 Kill well with 11.2 ppg brine. SeUtest TWC. ND tree. NU BOPE. 05/16/09 Test BOPE. Pull hanger. CBU. POH with 2-7/8" tubing. 05/17/09 POH with ESP. MU new ESP. RIH with 2-7/8" tubing. 05/18/09 Land compietion. SeUtest TWC. ND BOPE. NU/test tree. RDMO. 05/19/09 Circulated well with seawater to recover 11.2 ppg brine. Wait on Slickline for static. 05/25/09 MPU Well Support Techs, assisted ASRC in rehooking flow-Lines do to the tree do to the fact Valves on header lecked by, ST greased valves, bleed down flow-line to zero, it held . While the crane was there they just set the well house also for ASRC.TQ Blinds to spec. Note DBBV was installed on latterel line bottom studs ran in as fare as profile would allow. Talked to Tom Bellmyer and Jeff Herrington about the profill of the stud holes asked his guys to dubble check. POS~ ~~ 05/29/09 PULL XXN PLUG FROM 12540' SLM SET BK-DMY IN STA #1 C~3 12474' MD 05/30/09 RUN QC, 2 7/8" BRUSH, SWIVEL, QC, 2.5" OK-6 ( catcher tray ), 8" EXT, 1.25" LIB, LOC SD C«~ 12500' SLM, IMP OF UNKNOWN OBJECT. RUN QC, 2 7/8" BRUSH, SWIVEL, QC, 2.5" OK-6 ( catcher tray ), 8" EXT, 1.25" LIB, LOC SD C~3 12500' SLM, APPEARS TO BE METAL JUNK, LIB IN QUESTION RUN QC, 2 7/8" BRUSH, QC, 2.10" CENT, 2' x 1.5" STEM, 2" LIB, S/D 12550' SLM, IMP OF PUMP SHAFT RUN QC, 2 7/8" BRUSH, QC, 2.5" GR ( steel pin )& CAT STANDING VALVE. SD C«~ 12540' SLM PRESSURE UP 2000 PSI ON TUBBING. PULL 1" BK DUMMY/ SET 1" DPSOV C 123' SLM . Page 1 of 1 STATE OF ALASKA si,zios O IL AND GAS CONSERVATION COMMISSION BOPS Test Report Submit to: Contractor: Nabors Rig No.: 3S DATE: 5/16/09 Rig Rep.: J.Greco/R.Bjorhus Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: BP Op. Phone: 659-4485 Op. Fax: 659-0628 Rep.: D.Rhodes t V.Volpe E-Mail adwd~'3snsu crvDbp.com Well Name: MPF 79 PTD # 197-1800 Operation: Drlg: Workover x Explor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular. 250/3500 Valves: 250/3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 0 NT Housekeeping: P Drl. Rig P Lower Kelly 0 NT PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Misc P Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity SizelType Test Result MUD SYSTEM: Visual Alarm Stripper 0 NT Trip Tank P P Annular Preventer 1 3 5/8 5000p< P Pit Level Indicators P P #1 Rams 1 2 7/8 x 5" P Flow Indicator P P #2 Rams 1 blind P Meth Gas Detector P P #3 Rams 1 2 7/8" P H2S Gas Detector P P #4 Rams 0 NA MS Misc P P #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 0 NA HCR Valves 2 ? 1116", 3 1/8 P Kill Line Valves 1 2 1/16" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 1600 P Quantity Test Result 200 psi Attained 22 sec P No. Valves 13 P Full Pressure Attained 1min.45 sec P Manual Chokes 1 NT Blind Switch Covers: All stations Yes Hydraulic Chokes 1 NT Nitgn. Bottles (avg): 4 2000 i CH Misc 0 NA ACC Misc NA Test Results Number of Failures: 0 Test Time: 5.0 Hours Repair or replacement of equipment will be made within days. Notify the North Slope Ins ector 659-3607, follow with written confirmation to Su rvisor at: Remarks: 24 HOUR NOTICE GIVEN YES x NO Waived By Chuck Scheve Date 5/14/09 Time 18:00 Witness Test start 07:00 Finish 12:00 BOP o5/12/a9 Nabors 3S BOP lest MPU F-79 5-16-2009 .xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 0 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Waiver 181 Other 0 Alter Casing 181 Repair Well 0 Plug Perforations 0 Stimulate 0 Time Extension Replace ESP 0 ChanQe Approved ProQram 181 Pull TubinQ 0 Perforate New Pool 0 Re-Enter Suspended Well 0 Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. iii Development 0 Explorator) 197-180 3. Address: 0 Stratigraphic Test 0 Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22813-00-00 7. KB Elevation (ft): KBE = 473' 9. Well Name and Number: . MPF-79 8. Property Designation: 10. Field 1 Pool(s): ADL 355018 Milne Point Unit 1 Kuparuk River Sands 11. Present well condition summary Total depth: measured 18776 feet true vertical 7098 feet Plugs (measured) NIA Effective depth: measured 18388 feet Junk (measured) NIA true vertical 7137 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 112' 112' Surface 7304' 9-5/8" 7340' 4311' 5750 3090 Intermediate Production 13379' 7" 13410' 6594' 7240 5410 Liner 5398' 4-1/2" 13247'-18645' 6558'-7111' Perforation Depth MD (ft): 15880' - 18170' Perforation Depth TVD (ft): 7116' - 7155' Tubing Size (size, grade, and measured depth): 2-7/8",6.5# 1-80 12595' Packers and SSSV (type and measured depth): NONE RECE\VED . 12. Stimulation or cement squeeze summary: NIA JAN 2 11 LUU't Intervals treated (measured): C m'SS\Cm A\aska 0\\ & Gas Cons. om Treatment description including volumes used and final pressure: Anchorage 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: 477 80 990 336 Subsequent to operation: 493 81 977 320 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: a D "I R rt f W II 0 t. 0 Exploratory a Development 0 Service II.'1II al y epo 0 e pera Ions a W II S h t. D. 16. Well Status after proposed work: II.'1II e C ema IC lag ram a Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing IS true and correct to the best of my knowledge. ¡Sundry Number or N/A if C.O. Exempt: Contact David Reem; 564""-'57:43 -.... .. N/A Printed Name Sondra Stewman Title Technical Assistant ---1 ~~t~ . .< r","",- ~, --..;:, . Prepared By Name/Number: S~ture ~ .-t- A. Phone 564-4750 Date 01- ¡q"OL Sondra Stewman, 564-4750 Form 10-404 Revised 12/2003 On \ G \ N A . I~ÇAN~~El) Jf~N 2 ~) 2004;\ RBOMS 8ft JAM 2 :;:~ 200~ li'ee: Cameron 29/16" 5M M P U F 79 Orig. DF Elev. = 44.55' (N 27E) Wellhead: 11" x 7 1/16" 5M FMC Gen - Orig. GL Elev. = 11.5' SA, w/2 7/8" FMC tbg. hng., 3" LH DF To Tbg. Spool = 30.90' (N 27E) acme on top and 2 7/8" EUE 8 rd on bottom, 2.5" CIW BPV profile 20" 91.1 ppf, H-40 I ~- I Cameo 27/8" x 1" ŒÐ i '-. J 140' 10\ sidepocket KBMM GL KOP @ 350' 9 5/8" Howco 'ES' Max. hole angle = 96 deg. @ PBTD cementer Hole angle thru' perfs = 84 to 93 I 1 d 2159' md ego 95/8",40 ppf, L-80 Btrc. 17340' md I 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. (drift ID = 2.347", cap. = 0.00592 bpf) Centrilift NO.2 SOL power cable Cameo 27/8" x 1" I 12,474' I sidepocket KBMM GL Hes XN-Nipple ( 2.25" id ) I 12,522' I 7" 26 ppf, L-80, Btrc. prod. casing f/13,246' to 13,408' ( drift ID = 6.151", cap. = 0.0383 bpf ) Centrilift GC 1700 ESP, I 12,537' I 7" 29 ppf, L-80, Hyd. 511. prod. casing series 513, GPMTAR 1:1, 151 Stg. f/ 2149' to 13,246' md' Cøntrilift gas tandem separator I 12,555' I ( drift ID = 6.059", cap. = 0.0371 bpf) GRSFTXAR 7" 29 ppf, L-80, Hyd. 563. prod. casing Centrilift tandem seal section I 12560' I fl surface to 2149' md' GSB3DBUTILH6PFSACL5' ( drift ID = 6.059", cap. = 0.0371 bpf) GSB3DBLTH6FSACL5 Centrilift KMH 562 series, I 12589' I 171 hp motor, 2390 v. I 44. ' . . Phoenix Multi-sensor I 12,595' I Stimulation Summary Centralizer none performed Mid-perf = 7144' TVD 17025' md 1 1 4.5" Baker liner hgr./pkr. 13,247' md Perforation Summary Ref loa: based off of measured depth h 113 410' d 1 7" float s oe , m Size SPF Interval (TVD) Intake - 5613' KUD. 'A'Sand 12525' md 2 7/8" 4 15,880'-15,986' (7117'-7130') 27/8" 4 16,080'-16,400' (7139'-7147') " . 2 7/8" 4 16,499'-16,850' (7146'-7148') 4.~ 12.6 PPf'"L-80 IBT liner. 27/8" 4 17,090'-17,800' (7160'-7177') (dnft = 3.833 , cap.=0.0152 bpf 2 7/8" 4 17,850'-18,170' (7172'-7156') SWS 34J 15.2 gm.RDX deep penetrating 46' t;vd charges (EHD = 0.29" TTP = 20.57") r'rtcl 60/120 deg. phasing 4.5" landing collar (PBTD) ie;48t' md 4.5" float collar 18,521' md 4.5" float shoe 18,645' md DATE E\I. BY COMMENTS MILNE POINT UNIT 12/05/97 JBF Drilled and Completed by Nabors 27E WELL F-79 04/11/98 MDO ESP RWO Nabors 4es API NO: 50-029-22813 12/18/03 MOO ESP RWO Nabors 4es BP EXPLORATION (AK) BPExploration Page 10f 2 Operations Summary Report Legal Well Name: MPF-79 Common Well Name: MPF-79 Spud Date: Event Name: WORKOVER Start: 12/14/2003 End: 12/18/2003 Contractor Name: NABORS ALASKA DRILLING I Rjg Release: 12/18/2003 Rig Name: NABORS 4ES Rig Number: Date From-To Hours Task Code NPT Phase Description of Operations 12/14/2003 18:00 - 19:30 1.50 MOB P PRE Scope & lower derrick. 19:30 - 21 :00 1.50 MOB P PRE RID & prep rig for move from MPG - 06 to MPF - 79. 21 :00 - 23:00 2.00 MOB P PRE Move Rig sub & Pits to MPF - 79. 23:00 - 00:00 1.00 MOB P PRE Lay mats & spot in rig sub over well. 12/15/2003 00:00 - 01 :00 1.00 RIGU P PRE Con't to lay matting & spot in rig. 01 :00 - 02:00 1.00 RIGU P PRE Raise & scope up derrick. 02:00 - 03:00 1.00 RIGU P PRE Spot in pipe shed & camp. 03:00 - 04:00 1.00 RIGU P PRE R/U lines to tree. 04:00 - 06:00 2.00 KILL P DECOMP Accepted rig @ 0400 hrs. R/U tiger tank & take on Seawater to circulate well. 06:00 - 08:00 2.00 KILL P DECOMP PJSM. R/U lubricator, pull BPV. SITP = 450 psi, SICP = 1125 psi, OIA = 0 psi. Install secondary valve on I/A. Line up pump lines & pressure test same to 2500 psi, OK. 08:00 - 11 :30 3.50 KILL P DECOMP PJSM. Bleed gas off 27/8" x 7" annulus. Pump down tubing @ 4.5 bpm I 1600 psi with seawater, taking returns thru choke to tiger tank. Pump tubing volume & bullhead 78 bbls into formation @ 3 bpm I 1700 psi. Continue circulating seawater around to clean seawater returns, 525 bbls. (Phase 3 on all Milne Point Roads). 11 :30 - 14:00 2.50 KILL P DECOMP Monitor shut in pressures. SITP = 260 psi, SICP = 250 psi. Call for 9.5 ppg NaCI brine & wait for phase 3 to downgrade. 14:00 - 18:30 4.50 KILL P DECOMP Phase 3 lifted, kill weight brine on the way. Circulate remaining seawater from pits downhole & out to tiger tank. 18:30 - 20:30 2.00 KILL P DECOMP Wait on 9.5 ppg kill fluid. Take on 9.5 ppg fluid in rig pits. 20:30 - 23:30 3.00 KILL P DECOMP Kill well. SIP 260 psi. Open well & pump in @ 5 BPM, 1700 psi. Pumped 470 Bbls. SI & bullhead down tbg. Pumped 71 Bbls 2-3 BPM, 1400 psi. 23:30 - 00:00 0.50 KILL P DECOMP SID & monitor well. Well has slight flow from formation exhaling. Allow well to flow. 12/16/2003 00:00 - 00:30 0.50 KILL P DECOMP Monitor well. Flow decreased, then stopped. Well dead. 00:30 - 01 :00 0.50 WHSUR P DECOMP Install TWC & test to 3500 psi. Blow lines & N/D kill lines to tree. 01 :00 - 02:00 1.00 WHSUR P DECOMP Bleed off hanger void & NID X-mas tree. 02:00 - 03:30 1.50 BOPSU P DECOMP N/U BOPE. 03:30 - 04:30 1.00 BOPSU P DECOMP Pressure test BOP body & all breaks. Low Pressure 250 psi, High Pressure 3500 psi, OK. State AOGCC rep Check Scheve waived witnessing full test of BOPE. 04:30 - 06:00 1.50 WHSUR P DECOMP M/U lubricator & pull TWC. LID lubricator. Some difficulty due to cement on top of two way check valve. Circulate out same. 06:00 - 07:00 1.00 PULL P DECOMP M/U landing jt into tbg hanger. BOLDS. 07:00 - 08:30 1.50 PULL P DECOMP PJSM. Pull hanger to floor. Maximum up weight = 105K. Stabilized around 90K up wt. Break out Landing joint & rig up to pull ESP completion. Hole fill (9) bbls. 08:30 - 12:00 3.50 PULL P DECOMP PJSM. POOH wI 2 7/8" ESP completion; 84 stands out. 12:00 - 13:00 1.00 PULL P DECOMP Cut ESP cable; change out spools in spooling unit. 13:00 -15:30 2.50 PULL P DECOMP Continue TOH wI 2-7/8", ESP; 133 stands total out. 15:30 - 18:00 2.50 PULL P DECOMP LID Centrilift ESP equipment. Change over spool to new ESP cable. Remove elephant trunk. String rope through sheave. 18:00 - 19:00 1.00 RUNCO COMP R/U to run 2-7/8" tbg and ESP completion. Hold PJSM wI Co. Rep., Pusher, and crew. 19:00 - 23:30 4.50 RUNCO COMP P/U motor, pump and service. Test dischge line to 3000 psi. Pull cable over sheave. Test ESP prior to RIH. 23:30 - 00:00 0.50 RUNCO COMP TIH wI 2-7/8", L-80, EUE 8 RD tubing and new ESP. Printed: 12/22/2003 9: 19: 17 AM BPExploration Page2of2 Operations Summary' Report Legal Well Name: MPF-79 Common Well Name: MPF-79 Spud Date: Event Name: WORKOVER Start: 12/14/2003 End: 12/18/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/18/2003 Rig Name: NABORS 4ES Rig Number: Date From- To Hours Descriptjon ofOþ~rations 12/17/2003 00:00 - 05:30 5.50 RUNCO RIH wI new ESP and 133 stands re-used 2-7/8" L-80, EUE 8RD tubing. Meg cable & pump down tubing 5 - 10 bbls every 2000' @ 3/4 bpm 11500 psi. 05:30 - 07:30 2.00 RUNCO COMP PJSM. Perform reel to reel splice. 07:30 - 09:00 1.50 RUNCO COMP Continue in hole wI 27/8" ESP completion, megging cable & pumping 5-10 bbls down tubing every 2000' @ 3/4 bpm 11500 psi. 70K up wt, 30k down. Excessive drag being experienced to the point of the pipe stopping. Pump @ 9700', 09:00 - 14:00 COMP PJSM. Mix & pump (2) bbls EP Lube mixed in 50 bbls 9.5 ppg brine. Chase with 135 bbls brine, all pumped @ 3/4 bpm /1500 psi. Able to go in hole OK now. 14:00 - 16:00 COMP Continue in hole wI ESP completion string, megging cable & pumping 5 -10 bbls every 2000'. 16:00 - 20:00 COMP M/U landing jt. and hanger. P/U wt = 72,000 Ibs. and S/O wt. = 28,000 Ibs. RILDS. Checkout penetrator and RID ESP line and sheave. Drain stack and clear rig floor. Used (208) La Salle Clamps, (3) Flat Guards, & (4) Protectolizers. 20:00 - 23:00 3.00 BOPSU P COMP PJSM, set TWCV and NID BOPE. 23:00 - 00:00 1.00 WHSUR P COMP PJSM. Nipple up & test tree @ 5000 psi, OK. Test ESP conductivity, OK. Pull TWCV, Set BPV. 12/18/2003 00:00 - 01 :00 1.00 WHSUR P COMP Secure wellhead tree and cellar. Well to be freeze protected by MP Wells group. Release rig at 01 :00, 12/18/2003. Printed: 12/22/2003 9: 19: 17 AM AOGCC Geological Materials Inventory PERMIT 97-180 BP EXPLORATION Log Data Sent Received 8900 bT~'~' SCHLUM CDR/ADN PB1 9/24/1998 10/2/1998 ADN-M D 7400-17500 PB 1 9/24/1999 10/2/1998 ADN-MD ~'"'~300-18776 9/21/1998 9/24/1998 ADN-TVD y 4300-7100 PB1 9/24/1999 10/2/1998 ADN-TVD ~'~ 4300-7180 9/21/1998 9/24/1998 CDR-MD I~ 5400-17500 PB1 9/24/1999 10/2/1998 CDR-MD ~ 5339-18776 9/21/1998 9/24/1998 C DR-TVD ~3500-7100 PB 1 9/24/1999 10/2/1998 CDR-TVD ~" 3500-7180 9/21/1998 9/24/1998 SRVY ~T ~SCHLUM 0-17461.95 PB 1 1/31/1998 2/2/1998 SRVY ~T ~SCHL~ 0-18776. 1/31/1998 2/2/1998 ~0-407 Completion Date ) 3-.} ? / V 7 Daily well ops /~/~/~? ~ Are d~ ditch samples required? yes ~no ~d received? :~ Was thc well cored? yes ~o ~alysis ~description received? Are tests required? year__no Received? y~~oo Well is in compliance Comments Initial Box no Wednesday, October 13, 1999 Page 1 of 1 ,}eare'd rvloes rilling BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: February 26, 1999 From: Subject: Terrie Hubble Technical Assistant Miscellaneous Surveys Enclosed, in duplicate, are a number of directional surveys that I have come across while clearing out Ms. Campoamor's desk. I have verified that these surveys do not affect the previously calculated TVD's and below surface locations of these wells, so it was not necessary to correct the 10-407's. They are simply being submitted for your records. If they are duplicates, please discard them. Thank you. /tlh Endicott MPI 1-09A/L-21 Milne Point MPC-09 Milne Point MPF-21 Milne Point MPF-37 Milne Point MPF-45 Milne Point MPF-69 Milne Point MPF-79 Permit #97-29 Permit #85-36 Permit #96-135 Permit #96-25 Permit #95-58 Permit #95-125 Permit #97-180 STATE OF ALASKA ALASKA O--,-~ND GAS CONSERVATION COMM~.~-JSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Pull Tubing I~AlterCasing [~ Repair Well []Other 5. Type of well: ~ Development I~ Exploratory 3. Address [] Stratigraphic P.O. Box 196612, Anchorage, Alaska 99519-6612 I--IService 2. Name of Operator BP Exploration (Alaska)Inc. I--I Operation Shutdown [] Stimulate [] Plugging [] Perforate Change,.. :.O.~n!~ ~, KBE = 47.3' 7. Unit or Property Name Milne Point Unit 4. Location of well at surface 1919' NSL, 3064' WEL, SEC. 6, T13N, R10E, UM At top of productive interval 4932' NSL, 2764' WEL, SEC. 35, T14N, R9E, UM At effective depth 1191" NSL, 4748' WEL, SEC. 26, T14N, R9E, UM At total depth 1371' NSL, 5113' WEL, SEC. 26, T14N, R9E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 18776 feet 7100 feet 18388 feet 7138 feet Plugs (measured) Junk (measured) 8. Well Number MPF-79 9. Permit Number / Approval No. 97-18O 10. APl Number 50-029-22813 11. Field and Pool Milne Point Unit / Kuparuk River Sands Casing Length Size Structural Conductor 74' 20" Surface 7304' 9-5/8" Intermediate Production 13379' 7" Liner 5398' 4-1/2" Cemented MD TVD 250 sx Arcticset I (Approx.) 112' 112' 1720 sx PF 'E', 529 sx Class 'G' 7340' 4311' 495 sx Class 'G' 13410' 6594' 1050 sx Class 'G' 13247' - 18645' 6558' - 7111' Perforation depth: measured true vertical 15880' - 18170' (five intervals) 7116' - 7155' (five intervals) Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE tubing to 12562' Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments i--I Copies of Logs and Surveys run [~ Daily Report of Well Operations I 16. Status of well classifications as: [~ Oil I--I Gas [--I Suspended 7. I hereby certify that~egoing is true n orrect to the best of my knowledge Signed TerrieHubble'~-- "''"1~~ ~- Title TechnicalAssistant Ill Prepared By Name/Number: Service Date Terrie Hubble,s::4r~i~SDuplicat Form 10-404 Rev. 06/15/88 Facility M Pt F Pad Progress Report Well MPF-79 Page 1 Rig Nabors 4ES Date 10 February 99 Date/Time 06 Apr 98 07 Apr 98 08 Apr 98 09 Apr 98 09:00-12:30 12:30-15:30 15:30-18:00 18:00-18:15 18:15-20:30 20:30-23:00 23:00-23:30 23:30-23:45 23:45-03:00 03:00-03:30 03:30-05:15 05:15-05:30 05:30-06:00 06:00-06:15 06:15-06:30 06:30-07:00 07:00-08:30 08:30-11:00 11:00-12:30 12:30-13:00 13:00-13:15 13:15-18:00 18:00-18:15 18:15-19:30 19:30-20:00 20:00-01:00 01:00-02:30 02:30-06:00 06:00-06:15 06:15-09:00 09:00-13:00 13:00-15:00 15:00-20:00 20:00-20:30 20:30-22:30 22:30-23:00 23:00-00:00 00:00-01:30 01:30-02:00 02:00-02:30 02:30-03:30 03:30-04:00 Duration 3-1/2 hr 3hr 2-1/2 hr 1/4 hr 2-1/4 hr 2-1/2 hr 1/2 hr 1/4 hr 3-1/4 hr 1/2 hr 1-3/4 hr 1/4 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 1/4 hr 4-3/4 hr 1/4 hr 1-1/4 hr 1/2 hr 5hr 1-1/2 hr 3-1/2 hr 1/4 hr 2-3/4 hr 4hr 2hr 5hr 1/2 hr 2hr 1/2 hr lhr 1-1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr Activity Rigged down Drillfloor / Derrick Rig moved 100.00 % Installed High pressure lines Held safety meeting Installed Stock tank Tested High pressure lines Held safety meeting Bleed down well Circulated closed in well at 13000.0 ft Bullhead well Circulated at 13000.0 ft Flow check Cleared Chicksan lines Held safety meeting Installed Hanger plug Removed Xmas tree Installed BOP stack Tested All functions Removed Hanger plug Retrieved Tubing hanger Held safety meeting Pulled Tubing in stands to 4253.0 ft Held safety meeting Pulled Tubing in stands to 5000.0 ft Serviced Completion string handling equipment Pulled Tubing in stands to 0.0 ft Retrieved Electrical submersible pumps Installed Electric cable Held safety meeting Rigged up sub-surface equipment - Electrical submersible pumps Ran Tubing in stands to 4700.0 ft Installed Electric cable Ran Tubing in stands to 12561.0 ft Rigged up Tubing hanger Installed Electric cable Ran Tubing on landing string to 12561.0 ft Removed BOP stack Installed Xmas tree Tested Xmas tree Retrieved Hanger plug Freeze protect well - 80.000 bbl of Diesel Removed High pressure lines Sept. 24, 1998 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the Depth Corrected CDR/ADN, CDR/ADN TVD'S for ~ well MPF-79 PB1, Job # 97513 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 E-TRANS- 9/22/98 3 Bluelines each I Film each State of Alaska ,- - Alaska Oil & Gas Conservation · Attn: Loft Taylor "'--,..,,,,3001 Porcupine Drive Anchorage, AK 99501 1 OH LIS Tape I Biueline each I RF Sepia each OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 I OH LIS Tape 1 Blueline each I RF Sepia each- Sent Certified Mail: P 067 695 493 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 995.19,,6~3~"_?~ Date Delivered: r~r.~,T 0 ?. ~098 Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 A'I-i'N: Sherrie Received [ 1 Sept. 21, 1998 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the Measured Depth CDR/ADN6, CDR/ADN6 TVD'S for well MPF-79, Job # 97536 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Bird, Anchorage, AK 99519-6612 E-TRANS- 9/16/98 3 Bluelines each I film each _. State' of Alaska Alaska Oil & Gas Conservation ; Attn: Lori Taylor 3001 Porcupine Drive Anchorage_, AK 99501 I OH LIS Tape I Blueline each I RFolded Sepia each OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 I OH LIS Tape I Blueline each 1 RFolded Sepia each . Sent Certified Mail: P 067 695 494 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson BIvd. 995~'''~ r''- '~''~'f~l'~-l~.t2¢ ~'' '" ~f'"'~ ~ Anchorage, Alaska · . ~V~LJ Date Delivered: SEP £4 1998 Atas~a L;~i & L~as Cons. Co~,,mission Anchorage Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received .... STATE OF ALASKA - ,- i'~ E. ,. ~',/ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO~3 ©;:~ -(998 1. Status of Well Classificationj~~j~ Cons. [~ Oil E] Gas l--I Suspended F-I Abandoned I--I Service Anchorage 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-180 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22813 4. Location of well at surface~'?~'i'?/i'i~:?ii~ '~ ~ 9. Unit or Lease Name 1919' NSL, 3064' WEL, SEC. 6, T13N, R10E, UM '..ii-~i;:::/"~'"~~'~'t¢l~;~.. Milne Point Unit At top of productive interval ~ ~~ ) i ! ~~ 'Il i - ' 10. Well Number NS., w.., s.c. OM I . At total depth ~~ 11. Field and Pool 1371' NSL, 5113' WEL, SEC. 26, T14N, R9E, UM ~-'~'~_%%-;~:: ........ Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 47.3'I ADL 355018 12. Date Spudded 113. Date I.D. Reached I 14. Date Comp., Susp., or Aband. I15. Water depth, if offshore I16. No. of Completions 10/8/97 11/11/97 12/4/97 N/A MSLI One 17. Total Depth (MD+TVD)18776 7100 FT,]18' Plug Back Depth (MD+-I-VD)I19' Directi°nal SurveY ]20' Depth where SSSV set]21' Thickness °f Permafr°st18388 7138 FTI ¢;;~]Yes [--[No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run ORIGINAl MWD, LWD, Gyro ........ 23. CASING, LINER AND CEMENTING RECORD CASING SKI-I-lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 38' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 36' 7340' 12-1/4" 1720 sx PF 'E', 529 sx 'G' 7" 26#/29# L-80 31' 13410' 8-1/2" 495 sx Class 'G' 4-1/2" 12.6# L-80 13247' 18645' 6" 1050 sx Class 'G' 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) 2-3/4" Gun Diameter, 4 spf 2-7/8", 6.5#, L-80 13047' MD TVD MD TVD 15880'-18170' 7117'-7156' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 135 bbls diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) December 25, 1997I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD i Flow Tubing Casing Pressure CALCULATED OIL-DEL iGAS-MCF WATER-BEE OIL GRAVITY-APl (CORE) 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. ion 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. TKUP 15858' 7113' TKUP 18072' 7162' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and cot,re, ct to the b~est of my knowledge Title Engineering Supervisor Date F~/ J ! MPF-79 '~ 97-180 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Performance Enquiry Report Operator BP Exploration Date 03:38, 01 Feb 98 Page The analysis is from - 18:00, 14 Oct 97 - to - 18:00, 14 Oct 97 Programs in Result Table: MPF-79 Drill and Complete Well Type Time From Time To Duration Description E.M.W. (equivalent mud weight) MPF-79A Event 18:00, 14 Oct 97 18:00, 14 Oct 97 0 hr 0 min Obtained leak off 12.7 Hole Size MDR 8-1/2 Facility M Pt F Pad Progress Report Well MPF-79A Rig Nabors 27E Page Date 1 31 January 98 Date/Time 06 Oct 97 07 Oct 97 08 Oct 97 09 Oct 97 10 Oct 97 11 Oct 97 12 Oct 97 13 Oct 97 06:00-08:00 08:00-09:00 09:00-09:30 09:30-12:00 12:00-18:00 18:00-18:30 18:30-03:30 03:30-06:00 06:00-10:30 10:30-12:00 12:00-17:30 17:30-18:30 18:30-23:30 23:30-00:30 00:30-02:00 02:00-04:30 04:30-06:00 06:00-03:00 03:00-03:30 03:30-04:00 04:00-04:30 04:30-05:00 05:00-06:00 06:00-13:00 13:00-13:30 13:30-17:00 17:00-18:30 18:30-19:00 19:00-19:30 19:30-06:00 06:00-10:30 10:30-12:00 12:00-15:00 15:00-16:00 16:00-17:30 17:30-20:00 20:00-06:00 06:00-15:30 15:30-17:00 17:00-19:00 19:00-20:00 20:00-20:30 20:30-22:30 22:30-03:00 03:00-05:30 05:30-06:00 06:00-08:00 08:00-10:00 10:00-16:30 16:30-18:30 18:30-21:00 21:00-00:00 00:00-02:00 02:00-04:00 Duration 2hr lhr 1/2 hr 2-1/2 hr 6hr 1/2 hr 9hr 2-1/2 hr 4-1/2 hr 1-1/2 hr 5-1/2 hr lhr 5hr lhr 1-1/2 hr 2-1/2 hr 1-1/2 hr 21hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr lhr 7hr 1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 10-1/2 hr 4-1/2 hr 1-1/2 hr 3hr lhr 1-1/2 hr 2-1/2 hr 10hr 9-1/2 hr 1-1/2 hr 2hr lhr 1/2 hr 2hr 4-1/2 hr 2-1/2 hr 1/2 hr 2hr 2hr 6-1/2 hr 2hr 2-1/2 hr 3hr 2hr 2hr Activity Installed Xmas tree Rigged down Lines / Cables Held safety meeting Rig moved 30.00 % Rig moved 75.00 % Held safety meeting Rig moved 100.00 % Rigged up Annular preventor Rigged up Divertor Serviced Top drive Racked back drill pipe Held safety meeting Racked back drill pipe Tested Divertor Drilled to 271.0 ft Made up BHA no. 1 Drilled to 400.0 ft Drilled to 2121.0 ft Circulated at 2121.0 ft Pulled out of hole to 1000.0 ft Serviced Top drive R.I.H. to 2121.0 ft Drilled to 2215.0 ft Drilled to 3154.0 ft Serviced Mud pumps Drilled to 3721.0 ft Circulated at 3721.0 ft Pulled out of hole to 1749.0 ft R.I.H. to 3721.0 ft Drilled to 4844.0 ft Drilled to 5410.0 ft Circulated at 5410.0 ft Pulled out of hole to 220.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 5410.0 ft Drilled to 6468.0 ft Drilled to 7360.0 ft Circulated at 7360.0 ft Pulled out of hole to 2521.0 ft Backreamed to 1864.0 ft Pulled out of hole to 1020.0 ft R.I.H. to 7360.0 ft Circulated at 7360.0 ft Pulled out of hole to 242.0 ft Pulled BHA Pulled BHA Rigged up Casing handling equipment Ran Casing to 7340.0 ft (9-5/8in OD) Circulated at 7340.0 ft Mixed and pumped slurry - 390.000 bbl Circulated at 2159.0 ft Mixed and pumped slurry - 463.000 bbl Serviced Handling equipment Facility Date/Time 14 Oct 97 15 Oct 97 16 Oct 97 17 Oct 97 18 Oct 97 19 Oct 97 M Pt F Pad Progress Report Well MPF-79A Rig Nabors 27E 04:00-06:00 06:00-07:30 07:30-14:30 14:30-15:30 15:30-21:30 21:30-22:00 22:00-00:30 00:30-02:00 02:00-04:00 04:00-06:00 06:00-07:30 07:30-08:30 08:30-13:30 13:30-14:30 14:30-15:30 15:30-16:30 16:30-17:00 17:00-18:00 18:00-06:00 06:00-07:00 07:00-07:30 07:30-09:00 09:00-10:00 10:00-11:00 11:00-05:30 05:30-06:00 06:00-06:30 06:30-07:00 07:00-08:30 08:30-09:30 09:30-10:30 10:30-17:00 17:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-16:30 16:30-18:00 18:00-18:30 18:30-20:30 20:30-21:30 21:30-23:30 23:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-00:00 00:00-01:00 01:00-01:30 01:30-02:00 02:00-06:00 06:00-06:30 Duration 2hr 1-1/2 hr 7hr lhr 6hr 1/2 hr 2-1/2 hr 1-1/2 hr 2hr 2hr 1-1/2 hr lhr 5hr lhr lhr lhr 1/2 hr lhr 12hr lhr 1/2 hr 1-1/2 hr lhr lhr 18-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr lhr lhr 6-1/2 hr lhr 1/2 hr 11-1/2 hr 1/2 hr 2-1/2 hr 1/2hr 7hr 1-1/2 hr 1/2 hr 2hr lhr 2hr 6-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 5-1/2 hr lhr 1/2 hr 1/2 hr 4hr 1/2 hr Activity Rigged down Divertor Installed Casing head Rigged up BOP stack Installed BOP test plug assembly Tested BOP stack Installed Wear bushing Made up BHA no. 3 R.I.H. to 2159.0 ft Drilled installed equipment - DV collar R.I.H. to 4900.0 ft R.I.H. to 7254.0 ft Tested Casing Took Gyro multi-shot w/line survey Serviced Top drive Tested Casing Drilled installed equipment - Float shoe Circulated at 7380.0 ft Performed formation integrity test Drilled to 8850.0 ft Drilled to 8909.0 ft Circulated at 8909.0 ft Pulled out of hole to 7340.0 ft Serviced Top drive R.I.H. to 8909.0 ft Drilled to 10969.0 ft Circulated at 10969.0 ft Held safety meeting Circulated at 10969.0 ft Pulled out of hole to 7340.0 ft Serviced Top drive R.I.H. to 10969.0 ft Drilled to 11493.0 ft Repaired Mud pumps Held safety meeting Drilled to 12250.0 ft Held safety meeting Drilled to 12447.0 ft Circulated at 12447.0 ft Pulled out of hole to 1000.0 ft Downloaded MWD tool Held safety meeting R.I.H. to 7340.0 ft Serviced Block line R.I.H. to 12447.0 ft Drilled to 13128.0 ft Held safety meeting Drilled to 13691.0 ft Held safety meeting Drilled to 14164.0 ft Circulated at 14164.0 ft Pulled out of hole to 12440.0 ft R.I.H. to 14164.0 ft Drilled to 14484.0 ft Held safety meeting Page Date 2 31 January 98 Facility Date/Time 20 Oct 97 21 Oct 97 22 Oct 97 23 Oct 97 24 Oct 97 25 Oct 97 M Pt F Pad Progress Report 06:30-15:30 15:30-16:30 16:30-22:30 22:30-00:00 00:00-01:30 01:30-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-10:00 10:00-14:30 14:30-22:30 22:30-23:30 23:30-03:30 03:30-05:00 05:00-06:00 06:00-06:30 06:30-10:30 10:30-18:00 18:00-18:30 18:30-21:30 21:30-00:00 00:00-01:00 01:00-04:00 04:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-10:30 10:30-11:00 11:00-12:00 12:00-12:30 12:30-18:00 18:00-22:30 22:30-03:00 03:00-03:30 03:30-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-11:00 11:00-13:00 13:00-14:30 14:30-20:00 20:00-20:30 20:30-06:00 06:00-06:30 06:30-09:30 09:30-10:30 10:30-11:00 11:00-12:30 12:30-15:30 Duration 9hr lhr 6hr 1-1/2 hr 1-1/2 hr 2hr lhr 1-1/2 hr 1/2 hr 3-1/2 hr 4-1/2 hr 8hr lhr 4hr 1-1/2 hr lhr 1/2 hr 4hr 7-1/2 hr 1/2 hr 3hr 2-1/2 hr lhr 3hr 2hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2hr 4hr 1/2 hr lhr 1/2 hr 5-1/2 hr 4-1/2 hr 4-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 2-1/2 hr 2hr 1-1/2 hr 5-1/2 hr 1/2 hr 9-1/2 hr 1/2 hr 3hr lhr 1/2 hr 1-1/2 hr 3hr Well MPF-79A Rig Nabors 27E Activity Drilled to 15290.0 ft Circulated at 15290.0 ft Pulled out of hole to 1000.0 ft Downloaded MWD tool Installed BOP test plug assembly Tested BOP stack Installed Wear bushing R.I.H. to 2000.0 ft Held safety meeting R.I.H. to 13864.0 ft Washed to 15170.0 ft Pulled out of hole to 0.0 ft Serviced Top drive R.I.H. to 15176.0 ft Washed to 15245.0 ft Circulated at 15245.0 ft Held safety meeting Circulated at 15290.0 ft Pulled out of hole to 0.0 ft Held safety meeting Made up BHA no. 7 R.I.H. to 7340.0 ft Serviced Block line R.I.H. to 15290.0 ft Drilled to 15391.0 ft Held safety meeting Drilled to 16138.0 ft Held safety meeting Drilled to 16890.0 ft Held safety meeting Drilled to 16985.0 ft Circulated at 16985.0 ft Pulled out of hole to 15290.0 ft R.I.H. to 16985.0 ft Drilled to 17297.0 ft Drilled to 17606.0 ft Circulated at 17606.0 ft Pulled out of hole to 17172.0 ft Circulated at 17210.0 ft Held safety meeting Drilled to 17191.0 ft R.I.H. to 17606.0 ft Circulated at 17606.0 ft Pumped out of hole to 15000.0 ft R.I.H. to 17606.0 ft Circulated at 17606.0 ft Held safety meeting Pulled out of hole to 12000.0 ft Held safety meeting R.I.H. to 13793.0 ft Reamed to 14238.0 ft Pulled out of hole to 13500.0 ft R.I.H. to 17606.0 ft Circulated at 17606.0 ft Page Date 3 31 January 98 Facility Date/Time 26 Oct 97 27 Oct 97 28 Oct 97 29 Oct 97 30 Oct 97 31 Oct 97 M Pt F Pad Progress Report Well MPF-79A Rig Nabors 27E Page Date Duration Activity 15:30-23:30 23:30-01:00 01:00-06:00 06:00-06:30 06:30-07:00 07:00-10:00 10:00-11:00 11:00-12:00 12:00-14:00 14:00-15:00 15:00-19:30 19:30-21:30 21:30-01:00 01:00-02:00 02:00-06:00 06:00-06:30 06:30-07:30 07:30-10:30 10:30-11:00 11:00-12:00 12:00-13:30 13:30-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-19:00 19:00-20:00 20:00-20:30 20:30-21:30 21:30-22:00 22:00-23:30 23:30-00:30 00:30-01:00 01:00-01:30 01:30-06:00 06:00-06:30 06:30-08:00 08:00-11:30 11:30-18:00 18:00-18:30 18:30-06:00 06:00-06:00 06:00-07:00 07:00-09:00 09:00-14:00 14:00-20:00 20:00-22:00 22:00-03:00 03:00-06:00 06:00-07:00 07:00-09:00 09:00-09:30 09:30-16:00 16:00-18:00 8hr 1-1/2 hr 5hr 1/2 hr 1/2 hr 3hr lhr lhr 2hr lhr 4-1/2 hr 2hr 3-1/2 hr lhr 4hr 1/2 hr lhr 3hr 1/2 hr lhr 1-1/2 hr 3hr lhr 1/2 hr 1/2 hr 1/2hr lhr 1/2 hr lhr 1/2 hr 1-1/2 hr lhr 1/2 hr 1/2hr 4-1/2 hr 1/2 hr 1-1/2 hr 3-1/2 hr 6-1/2 hr 1/2 hr 11-1/2 hr 24 hr lhr 2hr 5hr 6hr 2hr 5hr 3hr lhr 2hr 1/2 hr 6-1/2 hr 2hr Pulled out of hole to 440.0 ft Downloaded MWD tool R.I.H. to 13000.0 ft Held safety meeting R.I.H. to 17606.0 ft Circulated at 17606.0 ft Mixed and pumped slurry - 100.000 bbl Pulled out of hole to 16475.0 ft Circulated at 16475.0 ft Rest hole at 16475.0 ft Pulled out of hole to 7340.0 ft Circulated at 7340.0 ft Pulled out of hole to 0.0 ft Installed BOP test plug assembly Tested BOP stack Held safety meeting Tested BOP stack Repaired HCR valve Tested HCR valve Installed Wear bushing Made up BHA no. 9 R.I.H. to 7340.0 ft Serviced Block line Circulated at 7340.0 ft Held safety meeting R.I.H. to 9149.0 ft Circulated at 9149.0 ft R.I.H. to 10272.0 ft Circulated at 10272.0 ft R.I.H. to 12156.0 ft Circulated at 12156.0 ft R.I.H. to 13559.0 ft Circulated at 13559.0 ft Pulled out of hole to 13388.0 ft Reamed to 13600.0 ft Held safety meeting Reamed to 13653.0 ft Pulled out of hole to 7340.0 ft Rigged down Top drive Held safety meeting Repaired Top drive Repaired Top drive Tested Top drive R.I.H. to 13089.0 ft Washed to 13670.0 ft Pulled out of hole to 12995.0 ft Circulated at 12995.0 ft Pulled out of hole to 0.0 ft R.I.H. to 9100.0 ft R.I.H. to 13492.0 ft Circulated at 13550.0 ft Mixed and pumped slurry - 57.000 bbl Pulled out of hole to 0.0 ft Serviced Drillfloor / Derrick 4 31 January 98 Facility Date/Time 01 Nov 97 02 Nov 97 03 Nov 97 04 Nov 97 05 Nov 97 06 Nov 97 07 Nov 97 08 Nov 97 09 Nov 97 M Pt F Pad Progress Report Well MPF-79A Rig Nabors 27E Page Date Duration Activity 18:00-19:00 19:00-22:00 22:00-22:30 22:30-01:30 01:30-06:00 06:00-08:30 08:30-17:00 17:00-20:00 20:00-02:00 02:00-04:00 04:00-06:00 06:00-10:00 10:00-11:30 11:30-12:30 12:30-20:00 20:00-21:00 21:00-22:00 22:00-01:00 01:00-06:00 06:00-07:00 07:00-13:00 13:00-16:00 16:00-03:30 03:30-06:00 06:00-06:00 06:00-10:00 10:00-11:30 11:30-12:00 12:00-13:00 13:00-19:00 19:00-03:00 03:00-05:00 05:00-06:00 lhr 3hr 1/2 hr 3hr 4-1/2 hr 2-1/2 hr 8-1/2 hr 3hr 6hr 2hr 2hr 4hr 1-1/2 hr lhr 7-1/2 hr lhr lhr 3hr 5hr lhr 6hr 3hr 11-1/2 hr 2-1/2 hr 24 hr 4hr 1-1/2 hr 1/2 hr lhr 6hr 8hr 2hr lhr Installed BOP test plug assembly Tested BOP stack Installed Wear bushing Made up BHA no. 11 R.I.H. to 9300.0 ft R.I.H. to 12319.0 ft Washed to 13142.0 ft Circulated at 13142.0 ft Pulled out of hole to 218.0 ft Pulled BHA R.I.H. to 2525.0 ft R.I.H. to 13190.0 ft Circulated at 13190.0 ft Mixed and pumped slurry - 73.000 bbl Pulled out of hole to 0.0 ft Serviced Top drive Serviced Block line Made up BHA no. 13 R.I.H. to 11638.0 ft Circulated at 11638.0 ft Washed to 12285.0 ft Drilled cement to 12630.0 ft Drilled to 12803.0 ft Drilled to 12818.0 ft Drilled to 13265.0 ft Drilled to 13612.0 ft Circulated at 13612.0 ft Pulled out of hole to 11921.0 ft R.I.H. to 13612.0 ft Drilled to 13953.0 ft Pulled out of hole to 218.0 ft Pulled BHA Installed BOP test plug assembly 06:00-09:00 09:00-09:30 09:30-10:30 10:30-12:00 12:00-18:00 18:00-06:00 06:00-10:00 10:00-12:00 12:00-13:30 13:30-14:30 14:30-06:00 06:00-15:30 15:30-17:00 17:00-20:30 20:30-21:30 21:30-00:30 00:30-02:30 02:30-03:00 03:00-06:00 06:00-13:00 13:00-14:30 3hr 1/2 hr lhr 1-1/2 hr 6hr 12hr 4hr 2hr 1-1/2 hr lhr 15-1/2 hr 9-1/2 hr 1-1/2 hr 3-1/2 hr lhr 3hr 2hr 1/2 hr 3hr 7hr 1-1/2 hr Tested BOP stack Installed Wear bushing Serviced Top drive Made up BHA no. 14 R.I.H. to 13953.0 ft Drilled to 14831.0 ft Drilled to 15207.0 ft Circulated at 15207.0 ft Pulled out of hole to 13191.0 ft R.I.H. to 15207.0 ft Drilled to 15922.0 ft Drilled to 16239.0 ft Circulated at 16239.0 ft Pulled out of hole to 7295.0 ft Serviced Top drive R.I.H. to 16239.0 ft Drilled to 16365.0 ft Serviced Mud pumps Drilled to 16614.0 ft Drilled to 16913.0 ft Pulled out of hole to 15875.0 ft 5 31 January 98 Facility Date/Time 10 Nov 97 11 Nov 97 12 Nov 97 13 Nov 97 14 Nov 97 15 Nov 97 16 Nov 97 M Pt F Pad Progress Report Well MPF-79A Rig Nabors 27E Page Date 14:30-15:30 15:30-05:30 05:30-06:00 06:00-07:30 07:30-10:00 10:00-12:00 12:00-13:00 13:00-13:30 13:30-17:00 17:00-19:30 19:30-06:00 06:00-18:30 18:30-21:00 21:00-21:30 21:30-22:00 22:00-00:00 00:00-01:30 01:30-05:00 05:00-06:00 06:00-21:00 21:00-22:00 22:00-23:00 23:00-00:00 00:00-03:30 03:30-06:00 06:00-07:00 07:00-10:00 10:00-10:30 10:30-16:00 16:00-18:30 18:30-23:30 23:30-02:30 02:30-06:00 06:00-06:30 06:30-13:00 13:00-16:00 16:00-18:00 18:00-18:30 18:30-20:00 20:00-06:00 06:00-06:30 06:30-09:30 09:30-11:00 11:00-13:00 13:00-13:30 13:30-22:30 22:30-01:30 01:30-06:00 06:00-06:30 06:30-07:30 07:30-10:30 10:30-13:30 13:30-15:30 15:30-18:00 Duration lhr 14 hr 1/2 hr 1-1/2 hr 2-1/2 hr 2hr lhr 1/2 hr 3-1/2 hr 2-1/2 hr 10-1/2 hr 12-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 2hr 1-1/2 hr 3-1/2 hr lhr 15hr lhr lhr lhr 3-1/2 hr 2-1/2 hr lhr 3hr 1/2 hr 5-1/2 hr 2-1/2 hr 5hr 3hr 3-1/2 hr 1/2 hr 6-1/2 hr 3hr 2hr 1/2 hr 1-1/2 hr 10hr 1/2hr 3hr 1-1/2 hr 2hr 1/2 hr 9hr 3hr 4-1/2 hr 1/2 hr lhr 3hr 3hr 2hr 2-1/2 hr Activity R.I.H. to 16913.0 ft Drilled to 17557.0 ft Circulated at 17557.0 ft Circulated at 17557.0 ft Pulled out of hole to 13235.0 ft R.I.H. to 17557.0 ft Drilled to 17665.0 ft Circulated at 17665.0 ft Drilled to 17800.0 ft Circulated at 17800.0 ft Drilled to 18150.0 ft Drilled to 18776.0 ft Circulated at 18776.0 ft Pulled out of hole to 18111.0 ft R.I.H. to 18776.0 ft Repaired Top drive Repaired Standpipe manifold Circulated at 18776.0 ft Pulled out of hole to 18016.0 ft Pulled out of hole to 7100.0 ft Serviced Top drive Repaired Standpipe manifold Serviced Block line Pulled out of hole to 126.0 ft Pulled BHA Made up BHA no. 15 R.I.H. to 7250.0 ft Circulated at 7250.0 ft R.I.H. to 14950.0 ft Circulated at 14950.0 ft R.I.H. to 18114.0 ft Washed to 18776.0 ft Circulated at 18776.0 ft Held safety meeting Pulled out of hole to 13500.0 ft R.I.H. to 18776.0 ft Circulated at 18776.0 ft Held safety meeting Circulated at 18776.0 ft Pulled out of hole to 7340.0 ft Held safety meeting Pulled out of hole to 0.0 ft Worked on BOP - Pipe ram Rigged up Casing handling equipment Held safety meeting Ran Casing to 6800.0 ft (7in OD) Circulated at 6800.0 ft Flow check Held safety meeting Flow check Circulated at 6800.0 ft Ran Casing to 8900.0 ft (7in OD) Circulated at 8900.0 ft Ran Casing to 11365.0 ft (7in OD) 6 31 January 98 Facility Date/Time 17 Nov 97 18 Nov 97 19 Nov 97 20 Nov 97 21 Nov 97 22 Nov 97 M Pt F Pad Progress Report Well MPF-79A Rig Nabors 27E Page Date 18:00-18:30 18:30-20:30 20:30-00:30 00:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:30 19:30-22:00 22:00-00:30 00:30-06:00 06:00-06:30 06:30-08:00 08:00-12:00 12:00-18:00 18:00-18:30 18:30-19:00 19:00-06:00 06:00-06:30 06:30-10:00 10:00-11:00 11:00-14:00 14:00-18:00 18:00-18:30 18:30-22:00 22:00-23:00 23:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-10:30 10:30-12:00 12:00-13:30 13:30-03:30 03:30-04:00 04:00-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-09:30 09:30-10:00 10:00-11:30 11:30-13:30 13:30-18:30 18:30-19:00 19:00-22:00 22:00-23:00 23:00-02:00 02:00-06:00 06:00-06:30 06:30-07:00 07:00-18:30 18:30-19:00 19:00-19:30 Duration 1/2hr 2hr 4hr 5-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr lhr 2-1/2 hr 2-1/2 hr 5-1/2 hr 1/2hr 1-1/2 hr 4hr 6hr 1/2hr 1/2 hr llhr 1/2 hr 3-1/2 hr lhr 3hr 4hr 1/2 hr 3-1/2 hr lhr 5hr lhr lhr 1/2 hr 4hr 1-1/2 hr 1-1/2 hr 14 hr 1/2 hr 2hr 1/2 hr lhr lhr lhr 1/2 hr 1-1/2 hr 2hr 5hr 1/2 hr 3hr lhr 3hr 4 hr 1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1/2 hr Activity Held safety meeting Circulated at 11365.0 ft Ran Casing to 13406.0 ft (7in OD) Circulated at 13406.0 ft Held safety meeting Worked stuck pipe at 13410.0 ft Held safety meeting Rigged up Handling equipment Mixed and pumped slurry - 60.000 bbl Rigged down Handling equipment Laid down 5000.0 fl of Drillpipe Held safety meeting Serviced BOP stack Monitor wellbore pressures Installed Wellhead integral components Held safety meeting Rigged up BOP stack Laid down 13500.0 ft of Drillpipe Held safety meeting Rigged up All rams Serviced Well control Tested BOP stack Repaired Annular preventor Held safety meeting Repaired Annular preventor Tested Annular preventor Repaired High pressure lines Rigged up Flowline Removed BOP test plug assembly Held safety meeting Ran Drillpipe to 5500.0 ft (4in OD) Pulled Drillpipe in stands to 0.0 ft Made up BHA no. 16 R.I.H. to 13326.0 fl Tested Casing Drilled installed equipment - Float collar Held safety meeting R.I.H. to 13535.0 ft Circulated at 13535.0 ft R.I.H. to 16630.0 fl Pulled out of hole to 15700.0 fl Circulated at 15700.0 ft R.I.H. to 18736.0 ft Circulated at 18645.0 ft Held safety meeting Pulled out of hole to 13410.0 ft Serviced Block line R.I.H. to 18645.0 ft Circulated at 18645.0 ft Held safety meeting Circulated at 18645.0 ft Pulled out of hole to 0.0 ft Rigged up Handling equipment Held safety meeting 7 31 January 98 Facility Date/Time 23 Nov 97 24 Nov 97 25 Nov 97 26 Nov 97 27 Nov 97 28 Nov 97 M Pt F Pad Progress Report Well MPF-79A Rig Nabors 27E Page Date Duration Activity 19:30-03:00 03:00-06:00 06:00-06:30 06:30-11:30 11:30-12:30 12:30-13:30 13:30-19:30 19:30-23:30 23:30-02:30 02:30-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-12:30 12:30-13:30 13:30-14:30 14:30-18:00 18:00-18:30 18:30-22:30 22:30-23:30 23:30-06:00 06:00-06:30 06:30-07:30 07:30-09:30 09:30-15:30 15:30-16:30 16:30-18:30 18:30-19:00 19:00-22:30 22:30-23:30 7-1/2 hr 3hr 1/2 hr 5hr lhr lhr 6hr 4hr 3hr 1/2 hr lhr 2hr 1/2 hr 6hr lhr lhr 3-1/2 hr 1/2 hr 4hr lhr 6-1/2 hr 1/2 hr lhr 2hr 6hr lhr 2hr 1/2 hr 3-1/2 hr lhr Ran Liner to 5400.0 ft (4-1/2in OD) Ran Drillpipe in stands to 8000.0 ft Held safety meeting Ran Drillpipe in stands to 13319.0 ft Circulated at 13319.0 ft Rigged up sub-surface equipment - Setting tools Ran Drillpipe in stands to 18645.0 ft Circulated at 18645.0 ft Mixed and pumped slurry - 238.000 bbl Functioned Liner hanger Circulated at 13245.0 ft Pulled Drillpipe in stands to 10000.0 ft Held safety meeting Pulled Drillpipe in stands to 0.0 ft Serviced Top drive Made up BHA no. 17 R.I.H. to 10000.0 ft Held safety meeting R.I.H. to 13242.0 ft Circulated at 13242.0 ft Pulled out of hole to 0.0 ft Held safety meeting Pulled BHA Rigged up Top ram Tested BOP stack Removed BOP test plug assembly Ran Drillpipe in stands to 5000.0 ft Held safety meeting Laid down 5000.0 ft of Drillpipe Rigged up Handling equipment 23:30-04:30 04:30-06:00 06:00-09:30 09:30-10:30 10:30-12:00 12:00-18:00 18:00-21:00 21:00-22:00 22:00-04:00 04:00-04:30 04:30-06:00 06:00-07:30 07:30-12:30 12:30-14:00 14:00-19:00 19:00-19:30 19:30-21:00 21:00-22:00 22:00-00:30 00:30-02:00 02:00-02:30 02:30-06:00 06:00-09:00 09:00-13:00 5hr 1-1/2 hr 3-1/2 hr lhr 1-1/2 hr 6hr 3hr lhr 6hr 1/2 hr 1-1/2 hr 1-1/2 hr 5hr 1-1/2 hr 5hr 1/2 hr 1-1/2 hr lhr 2-1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 3hr 4hr Made up BHA no. 18 R.I.H. to 10000.0 ft R.I.H. to 18388.0 ft Tested Liner Circulated at 18388.0 ft Reverse circulated at 18388.0 ft Circulated at 18388.0 ft Rigged up Gyro survey instruments Took Gyro multi-shot w/line survey Rigged down Gyro survey instruments Circulated at 18388.0 ft Circulated at 18388.0 ft Pulled out of hole to 5499.0 ft Held drill (Stripping) Pulled out of hole to 0.0 ft Removed Wear bushing Rigged down BOP stack Installed Tubing head spool Rigged up BOP stack Tested BOP stack Installed Wear bushing R.I.H. to 1100.0 ft R.I.H. to 2290.0 ft R.I.H. to 5246.0 ft 8 31 January 98 Facility Date/Time 29 Nov 97 30 Nov 97 01 Dec 97 02 Dec 97 03 Dec 97 04 Dec 97 M Pt F Pad Progress Report Well MPF-79A Page 9 Rig Nabors 27E Date 31 January 98 Duration Activity 13:00-15:00 15:00-23:30 23:30-02:30 02:30-03:00 03:00-05:00 05:00-05:30 05:30-06:00 06:00-07:30 07:30-08:30 08:30-09:30 09:30-12:00 12:00-12:30 12:30-20:00 20:00-21:30 21:30-00:30 00:30-06:00 06:00-09:00 09:00-09:30 09:30-18:30 18:30-20:30 20:30-00:00 00:00-03:00 03:00-04:00 04:00-05:30 05:30-06:00 06:00-12:00 12:00-12:30 12:30-18:00 18:00-01:00 01:00-01:30 01:30-03:30 03:30-05:00 05:00-06:00 06:00-09:00 09:00-22:00 22:00-01:00 01:00-06:00 06:00-09:00 09:00-11:30 11:30-12:30 12:30-13:30 13:30-16:00 16:00-17:00 17:00-20:00 20:00-22:00 22:00-00:30 03:30-04:30 04:30-06:00 06:00-07:00 2hr 8-1/2 hr 3hr 1/2 hr 2hr 1/2 hr 1/2 hr 1-1/2 hr lhr lhr 2-1/2 hr 1/2 hr 7-1/2 hr 1-1/2 hr 3hr 5-1/2 hr 3hr 1/2 hr 9hr 2hr 3-1/2 hr 3hr lhr 1-1/2 hr 1/2 hr 6hr 1/2 hr 5-1/2 hr 7hr 1/2 hr 2hr 1-1/2 hr lhr 3hr 13hr 3hr 5hr 3hr 2-1/2 hr lhr lhr 2-1/2 hr lhr 3hr 2hr 2-1/2 hr lhr 1-1/2 hr lhr Serviced Setting tools R.I.H. to 18388.0 ft Rigged up Drillfloor / Derrick Set Retrievable packer at 12901.0 ft with 2500.0 psi Reverse circulated at 12901.0 ft Rest hole at 12901.0 ft Circulated at 12901.0 ft Circulated at 12901.0 ft Rest hole at 12901.0 ft Rigged up Top drive Circulated at 12901.0 ft Rest hole at 12901.0 ft Pulled out of hole to 5284.0 ft Serviced Retrievable packer Pulled out of hole to 2290.0 ft Serviced Perforating tools Serviced Perforating tools Made up BHA no. 20 R.I.H. to 13247.0 ft Reverse circulated at 13247.0 ft R.I.H. to 18288.0 ft Reverse circulated at 18288.0 ft Rest hole at 18288.0 ft Pulled out of hole to 15775.0 ft Laid down 100.0 ft of 4in OD drill pipe Laid down 9500.0 ft of 4in OD drill pipe Rest hole at 8788.0 ft Laid down 4450.0 ft of 4in OD drill pipe Laid down 5355.0 ft of 2-7/8in OD drill pipe Removed Wear bushing Serviced Drillfloor / Derrick Rigged up Completion string handling equipment Installed Electrical submersible pumps Installed ESP Ran Tubing to 7950.0 ft (2-7/8in OD) Installed Electric cable Ran Tubing to 11850.0 ft (2-7/8in OD) Ran Tubing to 13046.0 ft (2-7/8in OD) Installed Electric cable Installed Tubing hanger Rigged down Handling equipment Serviced Drillfloor / Derrick Serviced Fluid system Serviced BOP stack Removed BOP stack Installed Xmas tree Installed Xmas tree integral components Serviced Fluid system Serviced Xmas tree integral components Survey_.ASCII_FILE ANADRILL SCHLUMBERGER Survey report 8-Jan-98 15:00:22 Page 1 of 8 Client ................... : BP Exploration Field .................... : Milne Point Well ...................... API number ................ Job number ................ Rig ....................... County/State .............. State/Country ............. MPF-79 5002922813 4001510 27-E COUNTY: STATE: Survey calculation methods .............. Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : GROUND LEVEL Depth reference .......... : GL above permanent ....... : 17.20 ft KB above permanent ....... : 50.25 ft DF above permanent ....... : 50.25 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 311.73 degrees Spud date ................ : Last survey date ......... : il-Nov-97 Total accepted surveys...: 200 MD of first survey ....... : 0.00 ft MD of last survey ........ : 18776.00 ft Geomagnetic data ..................... Magnetic model ........... : BGGM 1996 version Magnetic date ............ : 1-Aug-1997 Magnetic field strength..: 1148.75 HCNT Magnetic dec (+E/W-) ..... : 27.73 degrees Magnetic dip ............. : 80.68 degrees MWD survey Reference Criteria . Reference G .............. : 1002.00 mGal Reference H .............. : 1148.00 HCNT Reference Dip ............ : 80.74 degrees Tolerance of G ........... : (+/-) 3.00 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.30 degrees Corrections Magnetic dec (+E/W-) ..... : 27.97 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 27.97 degrees (Total az corr = magnetic dec - grid conv) Sag applied Y/N) ........ : No degree: 0.00 ORIGINAL RECEIVED JAN I 4 199 BPXA PDO Page 1 . . Survey_.ASCII_FILE [(c)1998 Anadrill IDEAL I:/id5 0a 33]v ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.0 0.00 2 207.10 0.14 7.8 207.10 3 298.11 0.56 349.1 91.00 4 388.24 1.27 337.4 90.10 5 478.83 1.72 322.5 90.60 6 567.65 2.17 313.1 88.90 7 657.36 3.66 314.6 89.70 8 747.85 6.55 317.4 90.40 9 842.39 9.02 315.0 94.60 10 940.33 13.53 306.6 97.90 11 1023.64 15.55 304.0 83.30 12 1116.96 15.43 304.4 93.40 13 1210.56 16.83 306.3 93.60 14 1305.32 19.87 310.3 94.70 15 1397.68 21.40 312.0 92.40 16 1492.41 19.94 312.5 94.70 17 1584.57 21.86 313.3 92.20 18 1678.12 25.51 313.0 93.50 19 1770.40 26.20 314.3 92.30 20 1864.28 25.93 313.3 93.90 21 1956.35 26.60 312.7 92.00 22 2053.28 30.33 311.9 97.00 23 2145.11 34.12 311.4 91.80 24 2239.62 37.46 311.6 94.50 25 2333.40 40.77 311.6 93.80 26 2428.78 43.88 311.7 95.40 27 2522.92 46.97 310.6 94.10 28 2617.40 49.91 311.3 94.50 29 2712.51 52.58 312.~ 95.10 30 2806.18 54.74 311.7 93.70 TVD depth (ft) 0.00 207.10 298.10 388.19 478.76 567.60 657.19 747.22 840.94 936.93 1017.56 1107.57 1197.48 1287.36 1373.83 1462.43 1548.56 1634.17 1717.23 1801.58 1884.06 1969.34 2046.99 2123.63 2196.40 2266.92 2332.96 2395.64 2455.17 2510.69 8-Jan-98 15:00:22 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 0.00 0.14 0.56 1.81 4.05 7.04 11.60 19.61 32.39 51.47 72.24 96.97 122.81 152.55 185.11 218.53 251.42 288.96 329.18 370.41 411.12 457.34 506.28 561.54 620.70 684.93 751.95 822.65 896.80 972.27 0.00 0.00 0.25 0.03 0.80 -0.03 2.15 -0.50 4.16 -1.72 6.37 -3.76 9.54 -7.04 15.36 -12.58 24.58 -21.48 36.84 -36.11 48.89 -53.19 62.91 -73.82 77.97 -95.01 96.50 -118.34 117.94 -142.85 140.41 -167.60 162.81 -191.68 188.48 -219.08 216.27 -248.20 244.83 -277.98 272.59 -307.76 303.68 -341.96 336.20 -378.54 372.82 -419.92 412.10 -464.16 454.79 -512.16 498.88 -562.63 545.22 -616.03 594.51 -671.43 644.86 -727.65 Page 2 of Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 0.00 0.00 0.00 TIP 0.25 7.80 0.07 MWD_M 0.80 357.51 0.47 MWD_M 2.21 346.88 0.81 MWD_M 4.50 337.58 0.65 MWD_M 7.39 329.46 0.62 MWD_M 11.85 323.58 1.66 MWD_M 19.85 320.68 3.21 MWD_M 32.64 318.85 2.63 MWD_M 51.58 315.57 4.89 MWD_M 72.25 312.59 2.55 MWD_M 96.99 310.44 0.17 MWD_M 122.91 309.37 1.60 MWD_M 152.70 309.19 3.47 MWD_M 185.24 309.54 1.78 MWD_M 218.64 309.96 1.55 MWD_M 251.49 310.34 2.11 MWD_M 289.00 310.71 3.91 MWD_M 329.21 311.07 0.97 MWD_M 370.42 311.37 0.55 MWD_M 411.12 311.53 0.78 MWD_M 457.34 311.61 3.87 MWD_M 506.28 311.61 4.14 MWD_M 561.54 311.60 3.54 MWD_M 620.71 311.60 3.53 MWD_M 684.93 311.60 3.26 MWD-M 751.95 311.56 3.39 MWD_M 822.65 311.51 3.16 ~.MWD_M 896.81 311.52 2.87 NfWD_M 972.28 311.55 2.32 MWD_M Page 2 Survey_.ASCII_FILE [(c)1998 Anadrill IDEAL I:/id5_0a_33]v AIqADRILL SCHLLIMBERGER Survey Report Seq Measured Incl Azimuth Course TVD % depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 31 2898.89 57.35 311.0 92.70 32 2990.73 60.90 311.4 91.80 33 3082.08 63.86 312.3 91.40 34 3178.50 66.03 312.4 96.40 35 3273.11 66.55 313.0 94.60 36 3367.52 66.85 312.7 94.40 37 3461.06 67.21 312.6 93.60 38 3554.93 67.89 312.6 93.80 39 3647.91 67.93 313.3 93.00 40 3741.88 68.41 313.2 94.00 41 3835.21 68.87 311.7 93.30 42 3929.71 69.25 311.9 94.50 43 4025.07 69.06 310.2 95.40 44 4120.82 69.28 310.8 95.70 45 4215.09 67.84 309.9 94.30 46 4308.08 68.13 308.4 93.00 47 4399.91 69.25 308.8 91.80 48 4493.34 69.90 308.7 93.40 49 4586.93 68.39 308.9 93.60 50 4678.99 66.70 309.2 92.10 51 4773.31 66.93 308.4 94.30 52 4868.24 67.82 308.5 94.90 53 4960.95 68.76 308.4 92.80 54 5055.44 67.90 308.3 94.40 55 5149.84 68.27 308.4 94.40 56 5243.37 68.02 307.9 93.60 57 5337.83 68.05 307.4 94.40 58 5431.62 67.47 308.5 93.80 59 5522.80 67.86 308.~ 91.20 60 5618.14 67.28 310.1 95.30 2562.46 2609.57 2651.94 2692.76 2730.80 2768.14 2804.66 2840.48 2875.46 2910.41 2944.40 2978.17 3012.12 3046.15 3080.62 3115.48 3148.84 3181.44 3214.76 3249.93 3287.06 3323.57 3357.90 3392.75 3427.99 3462.83 3498.14 3533.64 3568.30 3604.66 8-Jan-98 15:00:22 Vertical Displ Displ Total section +N/S- +E/W- displ (ft) (ft) (ft) (ft) Page 3 of 8 At DLS Srvy Tool Azim (deg/ tool qual (deg) i00f) type type 1049.15 695.65 -785.37 1049.16 311.53 1127.93 747.49 -844.69 1127.94 311.51 1208.90 801.47 -905.05 1208.91 311.53 1296.22 860.30 -969.58 1296.23 311.58 1382.82 919.04 -1033.23 1382.82 311.65 1469.51 1555.67 1642.36 1728.51 1815.74 1902.62 1990.88 2080.03 2169.45 2257.19 2343.32 2428.72 2516.13 2603.48 2688.50 2775.07 2862.52 2948.59 3036.16 3123.58 978.00 -1096.80 1036.39 -1160.18 1095.07 -1224.00 1153.73 -1287.12 1213.46 -1350.73 1469.51 1555.68 1642.36 1728.52 1815.75 311.72 311.77 311.82 311.87 311.94 1272.10 -1414.84 1330.87 -1480.69 1389.36 -1547.97 1447.45 -1615.99 1504.28 -1682.88 1902.64 1990.90 2080.04 2169.45 2257.20 311.96 311.95 311.91 311.85 311.79 1558.71 -1749.74 1612.07 -1816.57 1666.86 -1884.83 1721.66 -1953.00 1775.28 -2019.10 2343.32 2428.72 2516.15 2603.52 2688.57 311.70 311.59 311.49 311.40 311.32 1829.60 -2086.65 1884.07 -2155.26 1937.62 -2222.82 1991.99 -2291.67 2046.27 -2360.40 2775.17 2862.66 2948.78 3036.41 3123.89 2.88 MWD_M - 3.88 MWD_M - 3.38 MWD_M - 2.25 MWD_M - 0.80 MWD_M - 2099.87 -2428.76 2153.35 -2498.08 2206.74 -2566.54 2259.14 -2632.65 2314.81 -2700.91 3210.66 3298.08 3384.80 3469.09 3557.15 0.43 MWD_M - 0.40 MWD_M - 0.72 MWD_M - 0.60 MWD_M - 0.51 MWD_M - 3210.28 3297.61 3384.24 3468.45 3556.45 1.58 MWD_M - 0.41 MWD_M - 1.58 MWD_M - 0.63 MWD_M - 1.77 MWD_M - 1.53 MWD_M - 1.29 MWD_M - 0.70 MWD_M - 1.63 MWD_M - 1.86 MWD_M - 311.24 0 . 82 MWD_M - 311.16 0.94 MWD_M - 311.08 1.03 MWD_M - 311.00 0.91 MWD_M - 310.92 0.39 MWD_M - 310.85 310.76 310.69 310.63 310.60 0.48 MWD_M - 0.49 MWD_M - 1.25 ~.MWD_M - 0.47 MWD_M - 1.85 MWD_M - Page 3 Survey_.ASCIi_FILE [(c)1998 Anadrill IDEAL I:/id5_0a_33]v ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 61 5711.01 66.37 309.7 92.90 62 5807.23 66.12 310.5 96.20 63 5901.96 64.32 310.2 94.80 64 5993.97 61.45 312.3 92.00 65 6088.13 60.46 312.6 94.10 66 6183.66 60.69 314.4 95.60 67 6280.84 61.45 314.9 97.10 68 6375.40 64.88 316.9 94.60 69 6469.57 66.90 316.8 94.20 70 6563.14 66.89 317.6' 93.50 71 6655.33 67.77 317.4 92.20 72 6748.27 68.42 317.7 93.00 73 6843.06 68.89 316.4 94.80 74 6937.66 69.00 316.3 94.60 75 7032.23 68.38 315.3 94.50 76 7125.17 68.08 314.4 93.00 77 7218.72 68.14 314.8 93.50 78 7265.24 68.21 315.2 46.50 79 7412.87 68.16 314.7 147.70 80 7507.15 66.78 313.3 94.20 81 7598.81 66.35 312.5 91.70 82 7692.37 66.86 311.6 93.60 83 7785.79 66.81 312.9 93.40 84 7879.63 66.29 313.2 93.80 85 7972.16 66.63 313.1 92.60 86 8065.30 67.43 313.1 93.10 87 8159.08 66.77 312.2 93.80 88 8250.75 66.88 312.5 91.70 89 8346.14 67.25 312.0 95,30 90 8440.00 66.63 311.7 93.90 TVD depth (Et) 3641.22 3679.98 3719,71 3761.64 3807,33 3854.29 3901.27 3943.97 3982.45 4019.14 4054.67 4089.37 4123~.88 4157.86 4192.20 4226.70 4261.56 4278.84 4333.73 4369.83 4406.30 4443.46 4480.21 4517.53 4554.52 4590.85 4627.35 4663.44 4700.57 4737.35 8-Jan-98 15:00:22 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 3641,81 3729.82 3815.86 3897,73 3979.99 4063.21 4148.08 4232.25 4317.89 4403.50 4488.14 4573.98 4661,90 4749.89 4837.71 4923.95 5010.60 5053.69 5190.60 5277.54 5361.65 5447.55 5533.42 5619.45 5704.31 5790.01 5876.40 5960.70 6048.46 6134.86 2369.54 -2766.48 2426,19 -2833.88 2481.92 -2899.47 2535.89 -2961.04 2591.41 -3021.74 Page 4 of 2648.72 -3082.14 2708.45 -3142.59 2769.07 -3201.31 2831.80 -3260.11 2894.90 -3318.54 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 2957.62 -3376.02 3021.29 -3434.25 3085.91 -3494.42 3149.79 -3555.35 3212.91 -3616.73 3642.54 310.58 1.10 MWD_M 3730.59 310.57 0.89 MWD_M 3816.65 310.56 1.92 MWD_M 3898.52 310.58 3.72 MWD_M. 3980.74 310.62 1.09 MWD_M 3273.82 -3677.96 3334.74 -3739.73 3365.26 -3770.26 3462.14 -3867.30 3522.58 -3929.88 4063.90 310.68 1.66 MWD_M 4148.68 310.76 0.90 MWD_M 4232.74 310.86 4.09 MWD_M 4318.26 310.98 2.15 MWD_M 4403.76 311.10 0.79 MWD_M 3579.85 -3991.52 3637.39 -4055.30 3695.12 -4118.87 3753.86 -4181.75 3811.92 -4243.68 4488.32 311.22 0.98 MWD_M 4574.09 311.34 0.76 MWD_M 4661.95 311.45 1.37 MWD_M 4749.92 311.54 0.15 MWD_M 4837.72 311.62 1.18 MWD_M 3870.49 -4306.27 3929.03 -4369.82 3985.82 -4432.12 4044.83 -4497.09 4102.48 -4561.45 4923.95 311.67 0.95 MWD 5010.60 311.72 0.40 MWD 5053.69 311.75 0.81 MWD 5190.61 311.84 0.32 MWD 5277.55 311.87 2.01 MWD 5361.67 311.89 0.93 MWD 5447.58 311.89 1.04 MWD 5533.44 311.90 1,28 MWD 5619.48 311.91 0.63 MWD 5704.35 311.93 0,38 MWD 5790.05 311.95 0.86 MWD 5876.45 311.96 1.13 MWD 5960.75 311.97 0.32 MWD 6048.51 311.97 0.62 MWD 6134.91 311.97 0.72 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis Page 4 Survey_.ASCIi_FILE [(c)1998 Anadrill IDEAL I:/id5_0a_33]v ANADRILL SCHLUMBERGER Survey Report ___ Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) ___ 91 8533.43 66.47 311.5 93.40 92 8628.83 67.27 312.3 95.40 93 8723.95 67.67 313.6 95.10 94 8818.77 67.97 315.2 94.90 95 8914.77 67.55 315.9 96.00 96 9008.73 66.78 313.9 93.90 97 9102.30 67.28 314.0 93.60 98 9193.49 69.94 313.8 91.20 99 9286.16 72.57 313.8 92.70 100 9380.02 72.18 314.3 93.80 101 9474.63 71.42 313.2 94.60 102 9566.13 71.21 310.5 91.50 103 9660.18 70.64 309.8 94.10 104 9754.61 70.60 309.4 94.40 105 9848.67 69.80 309.7 94,10 106 9944.31 69.18 309.2 95.60 107 10039.21 68.98 309.1 94.90 108 10129.30 68.29 309.0 90.10 109 10222.91 67.32 308.8 93.60 110 10316.37 66.02 308.1 93.50 111 10412.00 65.67 308.0 95.60 112 10503.44 65.93 308.4 91.40 113 10595.29 66.99 309.5 91.90 114 10690.13 67.44 309.5 94.80 115 10785.09 68.79 310.3 95.00 116 10879.79 68.30 310.3 94.70 117 10973.68 67.58 308.8 93.90 118 11067.51 66.77 309.0 93.80 119 11161.71 66.17 309.4' 94.20 120 11254.41 66.10 310.4 92.70 TVD depth (ft) 4774.52 4812.00 4848.44 4884.27 4920.60 4957.05 4993.57 5026.83 5056.62' 5085.02 5114.57 5143.89 5174.64 5205.96 5237.84 5271.33 5305.22 5338.04 5373.40 5410.43 5449.55 5487,02 5523.72 5560.43 5595.84 5630.48 5665.75 5702.14 5739.75 5777.25 Vertical section (ft) 6220.54 6308.27 6396.09 6483.87 6572.53 6658.93 6745.04 6829.89 6917.61 7006.93 7096.74 7183.41 7272.31 7361.30 7449.77 , 7539.24 7627.79 7711.61 7798.17 7883.88 7970.93 8054.14 8138.29 8225.63 8313.73 8401.84 8488.80 8575.15 8661.43 8746.16 8-Jan-98 15:00:22 Displ Displ +N/S- +E/W- (ft) (ft) 4159.37 -4625.52 4217.96 -4690.82 4277.81 -4755.11 4339.29 -4817.89 4402.72 -4880.12 4463.81 -4941.41 4523.62 -5003.46 4582.49 -5064.64 4643.25 -5127.99 4705.40 -5192,24 4767.55 -5257.16 4825.37 -5321.72 4882.71 -5389.69 4939.48 -5458.31 4995,85 -5526.57 5052.75 -5595.71 5108.71 -5664.46 · 5161.57 -5729.62 5216.00 -5797.06 5269.38 -5864.30 5323.15 -5932.99 5374.70 -5998.50 5427.67 -6064.02 5483.26 -6131.46 5539.81 -6199.09 5596.82 -6266.31 5652.23 -6333.41 5706.52 -6400.69 5761.10 -6467.62 5815.48 -6532.65 Page 5 of 8 Total At DLS displ Azim (deg/ (ft) (deg) 100f) 6220.59 311.96 0.26 6308.32 311.96 1.14 6396.15 311.98 1.33 6483,94 312.01 1.59 6572.63 312.06 0.80 6659.06 312.09 2.13 6745.20 312.12 0.54 6830.07 312.14 2.92 6917.81 312.16 2.84 7007.15 312.18 0.66 7096.99 312.20 1.37 7183.65 312.20 2.80 7272.53 312.17 0.93 7361.49 312.14 0.40 7449.94 312.11 0.90 7539.38 312.08 0.81 7627.91 312.05 0.23 7711.70 312.01 0.77 7798.24 311.98 1.06 7883.93 311.94 1.55 7970.96 311.90 0.38 8054.16 311.86 0.49 8138.30 311.83 1.59 8225.63 311.81 0.47 8313.73 311.79 1.62 8401.84 311.77 0.52 8488.80 311.75 1.67 8575.15 311.72 0.89 8661.43 311.69 0.75 8746.17 311.68 0.99 Srvy Tool tool qual type type MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD. 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis Page 5 Survey_.ASCII_FILE [(c)1998 Anadrill IDEAL I:/id5_0a_33]v ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 121 11347.93 65.62 310.0 93.50 122 11442.45 65.27 310.0 94.50 123 11537.06 67.06 309.8 94.70 124 11632.34 66.56 310.0 95.20 125 11726.95 65.69 309.0 94.70 126 11820.48 64.99 309.1 93.50 127 11912.43 66.66 310.1 91.90 128 12006.24 67.04 309.7 93.80 129 12097.12 66.24 308.5 90.90 130 12191.33 65.98 307.8 94.20 131 12285.99 66.56 307.8 94.70 132 12381.56 68.95 308.0 95.60 133 12476.07 68.73 307.9 94.50 134 12569.67 68.54 308.4 93.60 135 12663.32 68.36 307.4 93.60 136 12774.81 65.51 307.7 111.50 137 12865.58 62.41 305.1 90.80 138 12959.69 64.78 304.5 94.10 139 13053.37 67.19 304.1 93.70 140 13144.58 70.95 303.4 91.20 141 13240.26 74.77 302.2 95.70 142 13335.54 78.01 302.6 95.20 143 13428.27 78.18 302.5 92.80 144 13523.17 77.90 302.0 94.90 145 13618.38 77.69 301.5 95.20 146 13709.37 77.81 300.9 91.00 147 13804.42 77.30 300.6 95.00 148 13896.81 77.22 300.~ 92.40 149 13991.65 77.69 301.4 94.90 150 14083.63 78.30 300.6 91.90 8-Jan-98 15:00:22 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 5815.49 5854.76 5893.03 5930.51 5968.84 6007.86 6045.49 6082.37 6118.41 6156.56 6194.67 6230.86 6264.97 6299.07 6333.45 6377.13 6416.99 6458.84 6496.97 6529.54 6557.74 6580.14 6599.28 6618.95 6639.07 8831.45 8917.37 9003.94 9091.41 9177.94 9262.81 9346.59 9432.79 9516.15 9602.11 9688.60 9776.88 9864.82 9951.82 10038.68 10140.98 10222.19 10305.86 10390.72 10475.06 10565.38 10656.67 10746.31 10837.88 10929.53 11016.95 11108.02 11196.36 11287.28 11375.60 6658.38 6678.85 6699.23 6719.85 6738.96 5870.55 -6597.82 5925.80 -6663.67 5981.37 -6730.12 6037.50 -6797.25 6092.58 -6864.07 Page 6 of 6146.11 -6930.06 6199.56 -6994.65 6254.88 -7060.82 6307.51 -7125.57 6360.71 -7193.30 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 6413.85 -7261.81 6468.20 -7331.62 6522.39 -7401.11 6576.24 -7469.66 6629.72 -7538.36 8831.46 311.66 0.64 MWD 6-axis 8917.38 311.65 0.37 MWD 6-axis 9003.96 311.63 1.90 MWD 6-axis 9091.42 311.61 0.56 MWD 6-axis 9177.96 311.59 1.33 MWD 6-axis 6692.23 -7619.68 6740.65 -7685.32 6788.75 -7754.52 6836.97 -7825.23 6884.28 -7896.04 9262.85 311.57 0.75 FfWD 6-axis 9346.64 311.55 2.07 MWD 6-axis 9432.85 311.54 0.56 MWD 6-axis 9516.22 311.52 1.50 MWD 6-axis 9602.20 311.48 0.73 MWD 6-axis 6933.80 -7972.90 6983.38 -8051.01 7032.23 -8127.55 7081.77 -8206.07 7130.74 -8285.19 9688.72 311.45 0.61 MWD 6-axis 9777.03 311.42 2.51 MWD 6-axis 9865.00 311.39 0.25 MWD 6-axis 9952.03 311.36 0.54 MWD 6-axis 10038.92 311.33 1.01 MWD 6-axis 7176.80 -8361.26 7224.23 -8440.98 7269.70 -8518.80 7317.00 -8598.45 7363.29 -8675.50 10141.28 311.29 2.57 MWD 6-axis 10222.55 311.25 4.27 MWD 6-axis 10306.29 311.20 2.58 MWD 6-axis 10391.26 311.14 2.60 MWD 6-axis 10475.73 311.08 4.18 MWD 6-axis 10566.21 311.01 4.17 MWD 6-axis 10657.69 310.94 3.43' MWD 6-axis 10747.53 310.87 0.21 MWD 6-axis 10839.33 310.79 0.59 MWD 6-axis 10931.23 310.72 0.56 MWD 6-axis 11018.95 310.64 0.66 MWD 6-axis 11110.35 310.56 0.62 MWD 6-axis 11199.04 310.48 0.64 "MWD 6-axis 11290.34 310.40 1.52 MWD 6-axis 11379.03 310.32 1.08 MWD_M - Page 6 ,, Survey_.ASCII_FILE [(c)1998 Anadrill IDEAL I:/id5 0a 33]v ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD # depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 151 14175.03 78.24 300.0 91.40 152 14270.80 79.38 301.5 95.80 153 14365.18 79.09 300.7 94.40 154 14458.32 79.00 301.6 93.10 155 14552.42 78.62 302.4 94.10 156 14647.31 78.47 302.1 94.90 157 14740.86 77.95 302.2 93.60 158 14834.16 77.66 301.9 93.30 159 14926.97 77.36 302.4 92.80 160 15021.82 77.25 302.4 94.80 161 15117.65 78.62 303.4 95.90 162 15214.06 78.39 303.0 96.40 163 15308.16 77.81 303.2 94.10 164 15401.82 76.87 302.6 93.60 165 15493.37 76.05 302.8 91.60 166 15586.22 76.64 304.0 92.80 167 15676.89 75.67 303.5 90.70 168 15771.17 76.58 303.8 94.30 169 15865.33 79.35 305.0 94.10 170 15961.14 83.62 304.5 95.80 171 16055.83 85.74 304.8 94.70 172 16150.27 87.03 304.7 94.50 173 16242.93 88.91 305.3 92.60 174 16336.57 90.23 304.6 93.70 175 16430.68 90.91 304.3 94.10 176 16525.27 90.94 304.8 94.60 177 16618.53 89.69 305.5 93.20 178 16712.32 88.74 305.5 93.80 179 16807.29 88.94 305.4 95.00 180 16900.22 88.89 306.0 92.90 6757 54 6776 13 6793 77 6811 46 6829 72 6848 57 6867 69 6887 40 6907 47 6928 31 6948.35 6967.56 6986.97 7007.48 7028.92 7050.83 7072.54 7095.15 7114.77 7128.95 7137.73 7143.69 7146.97 7147.67 7146.74 7145.21 7144.70 7145.98 7147.91 7149.67 8-Jan-98 15:00:22 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 11463.31 11555.57 11646.71 11736.56 11827.55 11919.29 12009.63 12099.53 12188.87 12280.13 12372.79 12466.22 12557.25 12647.49 12735.44 12824.66 12911.88 13002.51 13093.78 13187.80 13281.37 13374.98 13466.88 13559.92 13653.26 13747.10 13839.68 13932.92 14027.33 14119.70 Page 7408.44 7456.49 7504.40 7551.68 7600.59 7 of Total At DLS Srvy Tool displ Azim (deg/ tool cfual (ft) (deg) 100f) type type 7650.23 7698.98 7747.38 7795.59 7845.14 -8752.76 11467.17 -8833.52 11559.86 -8912.93 11651.45 -8991.16 11741.75 -9069.44 11833.16 310.25 0.65 MWD 6-axis 310.17 1.94 MWD 6-axis 310.10 0.89 MWD 6-axis 310.03 0.95 MWD 6-axis 309.96 0.93 MWD_M - 7896.08 7947.81 7998.09 8047.70 8095.81 -9148.10 11925.34 -9225.67 12016.13 -9302.97 12106.49 -9379.68 12196.29 -9457.76 12288.03 309.90 0.35 MWD 6-axis 309.85 0.57 MWD 6-axis 309.79 0.44 MWD 6-axis 309.73 0.62 MWD 6-axis 309.68 0.12 MWD 6-axis 8145.45 8194.38 8245.10 8297.10 8351.08 -9536.50 12381.16 -9615.55 12475.03 -9692.68 12566.53 -9769.36 12657.24 -9844.30 12745.68 8404.69 8458.45 8511.53 8565.20 8618.43 309.62 1.76 MWD 6-axis 309.58 0.47 MWD 6-axis 309.53 0.65 MWD 6-axis 309.48 1.18 MWD 6-axis 309.43 0.92 MWD 6-axis 8672.07 8725.73 8780.19 8835.28 8889.48 -9919.58 12835.36 309.39 1.41 MWD -9992.80 12923.00 309.35 1.20 MWD -10069.01 13014.09 309.31 1.01 MWD -10144.93 13105.78 309.28 3.20 MWD -10222.76 13200.21 309.25 4.49 MWD -10300.33 13294.19 309.21 2.26 MWD -10377.82 13388.22 309.18 1.37 MWD -10453.62 13480.51 309.15 2.13 MWD -10530.42 13573.96 309.12 1.59 MWD -10608.01 13667.74 309.09 0.79 MWD -10685.91 13762.03 309.06 0.53 MWD -10762.11 13855.01 309.03 1.54 MWD -10838.47 13948.63 309.01 1.01 MWD -10915.84 14043.43 308.99 0.24 MWD -10991.27 14136.16 308.97 0.65 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis Page 7 Survey_.ASCII_FiLE [(c)1998 Anadrill IDEAL I:/id5_0a_33]v ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) ___ 181 16993.67 86.95 305.7 93.50 182 17087.30 85.23 306.7 93.60 183 17181.28 84.91 307.3 94.00 184 17275.93 85.17 305.8 94.60 185 17371.59 88.09 305.8 95.70 186 17467.28 87.86 305.6 95.70 187 17561.78 91.11 306.9 94.50 188 17654.80 91.71 307.3 93.00 189 17748.06 92.23 308.1 93.30 190 17841.91 93.66 308.3 93.80 191 17935.21 93.80 308.9 93.30 192 18028.74 92.86 309.2 93.50 193 18124.49 92.66 308.9 95.80 194 18218.93 94.49 307.1 94.40 195 18310.76 95.60 306.5 91.90 196 18404.88 95.26 305.8 94.10 197 18497.88 95.78 306.0' 93.00 198 18592.31 95.66 305.6 94.40 199 18686.92 95.69 306.1 94.60 200 18776.00 95.69 306.0 89.10 8-Jan-98 15:00:22 TVD Vertical depth section (ft) (ft) 7153.06 14212.64 7159.44 14305.59 7167.52 14398.92 7175.70 14492.78 7181.32 14587.79 Page 8 of Displ Displ Total At DLS Srvy Tool +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (deg) i00f) type type 8944.20 -11067.00 14229.45 308.94 2.10 MWD 6-axis 8999.35 -11142.36 14322.72 308.93 2.12 MWD 6-axis 9055.71 -11217.15 14416.32 308.91 0.72 MWD 6-axis 9111.83 -11292.86 14510.49 308.90 1.60 MWD 6-axis 9167.71 -11370.34 14605.87 308.88 3.05 MWD 6-axis 71'84.71. 14682.90 9223 7185.56 14776.95 9279 7183.27 14869.62 9335 7180.06 14962.63 9392 7175.24 15056.13 9450 .52 -11448.01 14701.37 308.86 0.32 MWD .39 -11524.20 14795.75 308.84 3.70 MWD .47 -11598.35 14888.68 308.83 0.78 MWD .49 -11672.13 14981.90 308.82 1.02 MWD .42 -11745.74 15075.57 308.82 1.54 MWD 7169.17 15149.09 9508 7163.74 15242.33 9567 7159.13 15337.91 9627 7153.24 15431.92 9685 7145.16 15523.13 9740 .50 -11818.50 15168.67 308.82 0.66 MWD .31 -11890.99 15262.01 308.82 1.06 MWD .59 -11965.30 15357.70 308.82 0.38 MWD .59 -12039.54 15451.90 308.82 2.72 MWD .43 -12112.84 15543.39 308.80 1.37 MWD 7136.25 15616.36 9795 7127.31 15708.45 9849 7117.90 15801.88 9904 7108.54 15895.52 9960 7099.71 15983.74 10012 .69 -12188.48 15636.96 308.79 0.82 MWD .97 -12263.47 15729.42 308.77 0.60 MWD .92 -12339.65 15823.22 308.75 0.44 MWD .05 -12415.95 15917.24 308.74 0.53 MWD .22 -12487.63 16005.80 308.72 0.11 MWD_M 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis -- [(c)1998 Anadrill IDEAL I:/id5_0a_33] Page 8 Survey_01.ASCII_FILE ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration Field .................... : Milne Point Well ..................... : MPF-79 PB-1 API number ............... : 5002922813 Job number ............... : 4001510 Rig ...................... : 27-E County/State ............. : COUNTY: State/Country ............ : STATE: Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : GROUND LEVEL Depth reference .......... : GL above permanent ....... : 17.20 ft KB above permanent ....... : 50.25 ft DF above permanent ....... : 50.25 ft Vertical section origin- Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point ................. Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 311.73 degrees Page 1 8-Jan-98 14:58:53 Page 1 of 8 Spud date ................ : Last survey date ......... : 24-Oct-97 Total accepted surveys...: 186 MD of first survey ....... : 0.00 ft MD of last survey ........ : 17461.95 ft Geomagnetic data Magnetic model ........... : BGGM 1996 version Magnetic date ............ : 1-Aug-1997 Magnetic field strength..: 1148.75 HCNT Magnetic dec (+E/W-) ..... : 27.73 degrees Magnetic dip ............. : 80.68 degrees MWD survey Reference Criteria Reference G .............. : 1002 00 mGal Reference H .............. : 1148 00 HCNT Reference Dip ............ : 80 74 degrees Tolerance of G ........... : (+/-) 3 00 mGal Tolerance of H ........... : (+/-) 6 00 HCNT Tolerance of Dip ......... : (+/-) 0 30 degrees Corrections Magnetic dec (+E/W-) ..... : 27.97 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 27.97 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 ORIGINAL RECEIVED ,IAI I 4 1998 EIPXA PDO · Survey_01.ASC!I_FILE [(c)1998 Anadrill IDEAL I:/id5_0a_33]v ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.0 0.00 2 207.10 0.14 7.8 207.10 3 298.11 0.56 349.1 91.00 4 388.24 1.27 337.4 90.10 5 478.83 1.72 322.5 90.60 6 567.65 2.17 313.1 88.90 7 657.36 3.66 314.6 89.70 8 747.85 6.55 317.4 90.40 9 842.39 9.02 315.0 94.60 10 940.33 13.53 306.6 97.90 11 1023.64 15.55 304.0 83.30 12 1116.96 15.43 304.4 93.40 13 1210.56 16.83 306.3 93.60 14 1305.32 19.87 310.3 94.70 15 1397.68 21.40 312.0 92.40 16 1492.41 19.94 312.5 94.70 17 1584.57 21.86 313.3 92.20 18 1678.12 25.51 313.0 93.50 19 1770.40 26.20 314.3 92.30 20 1864.28 25.93 313.3 93.90 21 1956.35 26.60 312.7 92.00 22 2053.28 30.33 311.9 97.00 23 2145.11 34.12 311.4 91.80 24 2239.62 37.46 311.6 94.50 25 2333.40 40.77 311.6 93.80 26 2428.78 43.88 311.7 95.40 27 2522.92 46.97 310.6 94.10 28 2617.40 49.91 311.3 94.50 29 2712.51 52.58 312.0 95.10 30 2806.18 54.74 311.7 93.70 8-Jan-98 14:58:53 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 0.00 207.10 298.10 388.19 478.76 567.60 657.19 747.22 840.94 936.93 1017.56 1107.57 1197.48 1287.36 1373.83 1462.43 1548.56 1634.17 1717.23 1801.58 1884.08 1969.34 2046.99 2123.63 2196.40 0.00 0.14 0.56 1.81 4.05 7.04 11.60 19.61 32.39 51.47 72.24 96.97 122.81 152.55 185.11 218.53 251.42 288.96 329.18 370.41 411.12 457.34 506.28 561.54 620.70 684.93 751.95 822.65 896.80 972.27 2266.92 2332.96 2395.64 2455.17 2510.69 0.00 0.00 0.25 0.03 0.80 -0.03 2.15 -0.50 4.16 -1.72 6.37 -3.76 9.54 -7.04 15.36 -12.58 24.58 -21.48 36.84 -36.11 48.89 -53.19 62.91 -73.82 77.97 -95.01 96.50 -118.34 117.94 -142.85 140.41 -167.60 162.81 -191.68 188.48 -219.08 216.27 -248.20 244.83 -277.98 272.59 -307.76 303.68 -341.96 336.20 -378.54 372.82 -419.92 412.10 -464.16 454.79 -512.16 498.88 -562.63 545.22 -616.03 594.51 -671.43 644.86 -727.65 Page 2 of Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 0.00 0.00 0.00 TIP 0.25 7.80 0.07 MWD_M 0.80 357.51 0.47 MWD_M 2.21 346.88 0.81 MWD_M 4.50 337.58 0.65 MWD_M 7.39 329.46 0.62 MWD_M 11.85 323.58 1.66 MWD_M 19.85 320.68 3.21 MWD_M 32.64 318.85 2.63 MWD_M 51.58 315.57 4.89 MWD_M 72.25 312.59 2.55 MWD_M 96.99 310.44 0.17 MWD_M 122.91 309.37 1.60 MWD_M 152.70 309.19 3.47 MWD_M 185.24 309.54 1.78 MWD_M 218.64 309.96 1.55 MWD_M 251.49 310.34 2.11 MWD_M 289.00 310.71 3.91 MWD_M 329.21 311.07 0.97 MWD_M 370.42 311.37 0.55 MWD_M 411.12 311.53 0.78 MWD_M 457.34 311.61 3.87 MWD_M 506.28 311.61 4.14 MWD_M 561.54 311.60 3.54 MWD_M 620.71 311.60 3.53 MWD_M 684.93 311.60 3.26 MWD_M 751.95 311.56 3.39 MWD_M 822.65 311.51 3.16 MWD_M 896.81 311.52 2.87 ~..MWD_M 972.28 311.55 2.32 MWD_M Page 2 Surve!i_01.ASCII_FILE [(c)1998 Anadrill IDEAL I:/id5_0a_33]v ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD # depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 31 2898.89 57.35 311.0 92.70 2562.46 32 2990.73 60.90 311.4 91.80 2609.57 33 3082.08 63.86 312.3 91.40 2651.94 34 3178.50 66.03 312.4 96.40 2692.76 35 3273.11 66.55 313.0 94.60 2730.80 36 3367.52 66.85 312.7 94.40 2768.14 37 3461.06 67.21 312.6 93.60 2804.66 38 3554.93 67.89 312.6 93.80 2840.48 39 3647.91 67.93 313.3 93.00 2875.46 40 3741.88 68.41 313.2 94.00 2910.41 41 3835.21 68.87 311.7 93.30 2944.40 42 3929.71 69.25 311.9 94.50 2978.17 43 4025.07 69.06 310.2 95.40 3012.12 44 4120.82 69.28 310.8 95.70 3046.15 45 4215.09 67.84 309.9 94.30 3080.62 46 4308.08 68.13 308.4 93.00 3115.48 47 4399.91 69.25 308.8 91.80 3148.84 48 4493.34 69.90 308.7 93.40 3181.44 49 4586.93 68.39 308.9 93.60 3214.76 50 4678.99 66.70 309.2 92.10 3249.93 51 4773.31 66.93 308.4 94.30 3287.06 52 4868.24 67.82 308.5 94.90 3323.57 53 4960.95 68.76 308.4 92.80 3357.90 54 5055.44 67.90 308.3 94.40 3392.75 55 5149.84 68.27 308.4 94.40 3427.99 56 5243.37 68.02 307.9 93.60 3462.83 57 5337.83 68.05 307.4 94.40 3498.14 58 5431.62 67.47 308.5 93.80 3533.64 59 5522.80 67.86 308.3 91.20 3568.30 60 5618.14 67.28 310.1 95.30 3604.66 8-Jan-98 14:58:53 Page 3 of Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) i00f) type type 1049.15 695.65 -785.37 1049.16 1127.93 747.49 -844.69 1127.94 1208.90 801.47 -905.05 1208.91 1296.22 860.30 -969.58 1296.23 1382.82 919.04 -1033.23 1382.82 1469.51 1555.67 1642.36 1728.51 1815.74 1902.62 1990.88 2080.03 2169.45 2257.19 2343.32 2428.72 2516.13 2603.48 2688.50 311.53 311.51 311.53 311.58 311.65 978.00 -1096.80 1036.39 -1160.18 1095.07 -1224.00 1153.73 -1287.12 1213.46 -1350.73 1469.51 1555.68 1642.36 1728.52 1815.75 311.72 311.77 311.82 311.87 311.94 1272.10 -1414.84 1330.87 -1480.69 1389.36 -1547.97 1447.45 -1615.99 1504.28 -1682.88 1902.64 1990.90 2080.04 2169.45 2257.20 311.96 311.95 311.91 311.85 311.79 1558.71 -1749.74 1612.07 -1816.57 1666.86 -1884.83 1721.66 -1953.00 1775.28 -2019.10 2343.32 2428.72 2516.15 2603.52 2688.57 311.70 311.59 311.49 311.40 311.32 1829.60 -2086.65 1884.07 -2155.26 1937.62 -2222.82 1991.99 -2291.67 2046.27 -2360.40 2775.17 2862.66 2948.78 3036.41 3123.89 311.24 311.16 311.08 311.00 310.92 2099.87 -2428.76 2153.35 -2498.08 2206.74 -2566.54 2259.14 -2632.65 2314.81 -2700.91 3210.66 3298.08 3384.80 3469.09 3557.15 310.85 310.76 310.69 310.63 310.60 2775.07 2862.52 2948.59 3036.16 3123.58 2.88 3.88 3.38 2.25 0.80 0.43 0.40 0.72 0.60 0.51 1.58 0.41 1.58 0.63 1.77 1.53 1.29 0.70 1.63 1.86 0.82 0.94 1.03 0.91 0.39 0.48 0.49 1.25 0.47 1.85 3210.28 3297.61 3384.24 3468.45 3556.45 MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M ...MWD_M MWD_M Page 3 Survey_01.ASCII_FILE [(c)1998 Anadrill IDEAL i:/id5_0a_33]v ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD % depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 61 5711.01 66.37 309.7 92.90 62 5807.23 66.12 310.5 96.20 63 5901.96 64.32 310.2 94.80 64 5993.97 61.45 312.3 92.00 65 6088.13 60.46 312.6 94.10 66 6183.66 60.69 314.4 95.60 67 6280.84 61.45 314.9 97.10 68 6375.40 64.88 316.9 94.60 69 6469.57 66.90 316.8 94.20 70 6563.14 66.89 317.6 93.50 71 6655.33 67.77 317.4 92.20 72 6748.27 68.42 317.7 93.00 73 6843.06 68.89 316.4 94.80 74 6937.66 69.00 316.3 94.60 75 7032.23 68.38 315.3 94.50 76 7125.17 68.08 314.4 93.00 77 7218.72 68.14 314.8 93.50 78 7265.24 68.21 315.2 46.50 79 7412.87 68.16 314.7 147.70 80 7507.15 66.78 313.3 94.20 81 7598.81 66.35 312.5 91.70 82 7692.37 66.86 311.6 93.60 83 7785.79 66.81 312.9 93.40 84 7879.63 66.29 313.2 93.80 85 7972.16 66.63 313.1 92.60 86 8065.30 67.43 313.1 93.10 87 8159.08 66.77 312.2 93.80 88 8250.75 66.88 312.5 91.70 89 8346.14 67.25 312.0 95.30 90 8440.00 66.63 311.7 93.90 3641.22 3679.98 3719.71 3761.64 3807.33 3854.29 3901.27. 3943.97 3982.45' 4019.14 4054.67 4089.37 4123.88 4157.86 4192.20 4226.70 4261.56 4278.84 4333.73 4369.83 4406~.30 4443.46 4480.21 4517.53 4554.52 4590.85 4627.35 4663.44 4700.57 4737.35 8-Jan-98 14:58:53 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 3641.81 3729.82 3815.86 3897.73 3979.99 4063.21 4148.08 4232.25 4317.89 4403.50 4488.14 4573.98 4661.90 4749.89 4837.71 4923.95 5010.60 5053.69 5190.60 5277.54 5361.65 5447.55 5533.42 5619.45 5704.31 5790.01 5876.40 5960.70 6048.46 6134.86 2369.54 -2766.48 2426.19 -2833.88 2481.92 -2899.47 2535.89 -2961.04 2591.41 -3021.74 2648.72 -3082.14 2708.45 -3142.59 2769.07 -3201.31 2831.80 -3260.11 2894.90 -3318.54 2957.62 -3376.02 3021.29 -3434.25 3085.91 -3494.42 3149.79 -3555.35 3212.91 -3616.73 3273.82 -3677.96 3334.74 -3739.73 3365.26 -3770.26 3462.14 -3867.30 3522.58 -3929.88 3579.85 -3991.52 3637.39 -4055.30 3695.12 -4118.87 3753.86 -4181.75 3811.92 -4243.68 3870.49 -4306.27 3929.03 -4369.82 3985.82 -4432.12 4044.83 -4497.09 4102.48 -4561.45 Page 4 of Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 3642.54 310.58 1.10 MWD_M 3730.59 310.57 0.89 MWD_M 3816.65 310.56 1.92 MWD_M 3898.52 310.58 3.72 MWD_M 3980.74 310.62 1.09 MWD_M 4063.90 310.68 1.66 MWD_M 4148.68 310.76 0.90 MWD_M 4232.74 310.86 4.09 MWD_M 4318.26 310.98 2.15 MWD_M 4403.76 311.10 0.79 MWD_M 4488.32 311.22 0.98 MWD_M 4574.09 311.34 0.76 MWD_M. 4661.95 311.45 1.37 MWD_M 4749.92 311.54 0.15 MWD_M 4837.72 311.62 1.18 MWD_M 4923.95 311.67 0.95 MWD 5010.60 311.72 0.40 MWD 5053.69 311.75 0.81 MWD 5190.61 311.84 0.32 MWD 5277.55 311.87 2.01 MWD 5361.67 311.89 0.93 MWD 5447.58 311.89 1.04 FiWD 5533.44 311.90 1.28 MWD 5619.48 311.91 0.63 MWD 5704.35 311.93 0.38 MWD 5790.05 311.95 0.86 MWD 5876.45 311.96 1.13 MWD 5960.75 311.97 0.32 MWD 6048.51 311.97 0.62 MWD 6134.91 311.97 0.72 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis Page 4 Survel,_01.ASCI!_FiLE [(c)1998 Anadrill IDEAL I:/idS_0a_33]v ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD # depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 91 8533.43 66.47 311.5 93.40 92 8628.83 67.27 312.3 95.40 93 8723.95 67.67 313.6 95.10 94 8818.77 67.97 315.2 94.90 95 8914.77 67.55 315.9 96.00 96 9008.73 66.78 313.9 93.90 97 9102.30 67.28 314.0 93.60 98 9193.49 69.94 313.8 91.20 99 9286.16 72.57 313.8 92.70 100 9380.02 72.18 314.3 93.80 101 9474.63 71.42 313.2 94.60 102 9566.13 71.21 310.5 91.50 103 9660.18 70.64 309.8 94.10 104 9754.61 70.60 309.4 94.40 105 9848.67 69.80 309.7 94.10 106 9944.31 69.18 309.2 95.60 107 10039.21 68.98 309.1 94.90 108 10129.30 68.29 309.0 90.10 109 10222.91 67.32 308.8 93.60 110 10316.37 66.02 308.1 93.50 4774.52 4812.00 4848.44 4884.27 4920.60 4957.05 4993.57 5026.83 5056.62 5085.02 5114.57 5143.89 5174.64 5205.96 5237.84 5271.33 5305.22. 5338.04 5373.40 5410.43 111 10412.00 65.67 308.0 95.60 5449.55 112 10503.44 65.93 308.4 91.40 5487.02 113 10595.29 66.99 309.5 91.90 5523.72 114 10690.13 67.44 309.5 94.80 5560.43 115 10785.09 68.79 310.3 95.00 5595.84 116 10879.79 68.30 310.3 94.70 5630.48 117 10973.68 67.58 308.8 93.90 5665.75 118 11067.51 66.77 309.0 93.80 5702.14 119 11161.71 66.17 309.4 94.20 5739.75 120 11254.41 66.10 310.4 92.70 5777.25 8-Jan-98 14:58:53 Page 5 of Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool c/ual (ft) (ft) (ft) (ft) (deg) 100f) type type 6220.54 6308.27 6396.09 6483.87 6572.53 6658.93 6745.04 6829.89 6917.61 7006.93 7096.74 7183.41 7272.31 7361.30 7449.77 7539.24 7627.79 7711.61 7798.17 7883.88 4159.37 -4625.52 6220.59 4217.96 -4690.82 6308.32 4277.81 -4755.11 6396.15 4339.29 -4817.89 6483.94 4402.72 -4880.12 6572.63 311.96 311.96 311.98 312.01 312.06 4463.81 -4941.41 6659.06 4523.62 -5003.46 6745.20 4582.49 -5064.64 6830.07 4643.25 -5127.99 6917.81 4705.40 -5192.24 7007.15 312.09 312.12 312.14 312.16 312.18 4767.55 -5257.16 7096.99 4825.37 -5321.72 7183.65 4882.71 -5389.69 7272.53 4939.48 -5458.31 7361.49 4995.85 -5526.57 7449.94 312.20 312.20 312.17 312.14 312.11 5052.75 -5595.71 7539.38 5108.71 -5664.46 7627.91 5161.57 -5729.62 7711.70 5216.00 -5797.06 7798.24 5269.38 -5864.30 7883.93 312.08 312.05 312.01 311.98 311.94 5323.15 -5932.99 7970.96 5374.70 -5998.50 8054.16 5427.67 -6064.02 8138.30 5483.26 -6131.46 8225.63 5539.81 -6199.09 8313.73 311.90 311.86 311.83 311.81 311.79 5596.82 -6266.31 8401.84 5652.23 -6333.41 8488.80 5706.52 -6400.69 8575.15 5761.10 -6467.62 8661.43 5815.48 -6532.65 8746.17 311.77 311.75 311.72 311.69 311.68 7970.93 8054.14 8138.29 8225.63 8313.73 0.26 1.14 1.33 1.59 0.80 2.13 0.54 2.92 2.84 0.66 1.37 2.80 0.93 0.40 0.90 0.81 0.23 0.77 1.06 1.55 0.38 0.49 1.59 0.47 1.62 0.52 1.67 0.89 0.75 0.99 8401.84 8488.80 8575.15 8661.43 8746.16 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis Page 5 Survey_01.ASCiI_FILE [(c)1998 Anadrill IDEAL I:/id5_0a_33]v ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 121 11347.93 65.62 310.0 93.50 122 11442.45 65.27 310.0 94.50 123 11537.06 67.06 309.8 94.70 124 11632.34 66.56 310.0 95.20 125 11726.95 65.69 309.0 94.70 126 11820.48 64.99 309.1 93.50 127 11912.43 66.66 310.1 91.90 128 12006.24 67.04 309.7 93.80 129 12097.12 66.24 308.5 90.90 130 12191.33 65.98 307.8 94.20 131 12285.99 66.56 307.8 94.70 132 12381.56 68.95 308.0 95.60 133 12476.07 68.73 307.9 94.50 134 12569.67 68.54 308.4 93.60 135 12663.32 68.36 307.4 93.60 136 12759.16 68.05 306.6 95.90 137 12852.19 67.66 306.5 93.00 138 12945.71 67.03 305.7 93.50 139 13040.11 66.54 305.3 94.40 140 13133.56 68.18 305.9 93.50 141 13226.63 69.79 304.9 93.00 142 13323.12 72.86 305.5 96.50 143 13415.65 73.98 307.5 92.60 144 13509.44 74.48 308.1 93.70 145 13603.65 74.44 307.4 94.20 146 13697.92 76.81 307.1 94.30 147 13793.19 79.78 305.4 95.30 148 13888.46 79.75 305.4 95.30 149 13982.41 79.23 304.7 93.90 150 14076.43 79.17 305.1 94.00 8-Jan-98 14:58:53 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 5815.49 585~.76 5893.03 5930.51 5968.84 6007.86 6045.49 6082.37 6118.41 6156.56 6194.67 6230.86 6264.97 6299.07 6333.45 6369.06 6404.11 6440.13 6477.34 6513.33 6546.68 6577.58 6604.00 6629.47 6654.71 8831.45 8917.37 9003.94 9091.41 9177.94 9262.81 9346.59 9432.79 9516.15 9602.11 9688.60 9776.88 9864.82 9951.82 10038.68 10127.42 10213.21 10299.08 10385.32 10471.12 10557.40 10648.21 10736.59 10826.55 10917.08 11008.15 11101.02 11194.24 11285.93 11377.61 6678.12 6697.45 6714.38 6731.51 6749.12 5870.55 -6597.82 5925.80 -6663.67 5981.37 -6730.12 6037.50 -6797.25 6092.58 -6864.07 Page 6 of 6146.11 -6930.06 6199.56 -6994.65 6254.88 -7060.82 6307.51 -7125.57 6360.71 -7193.30 6413.85 -7261.81 6468.20 -7331.62 6522.39 -7401.11 6576.24 -7469.66 6629.72 -7538.36 6683.31 -7609.47 6734.60 -7678.67 6785.44 -7748.39 6835.82 -7819.01 6886.06 -7889.18 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type __ 8831.46 311.66 0.64 MWD 6-axis 8917.38 311.65 0.37 MWD 6-axis 9003.96 311.63 1.90 MWD 6-axis 9091.42 311.61 0.56 MWD 6-axis 9177.96 311.59 1.33 MWD 6-axis 9262.85 311.57 0.75 MWD 6-axis 9346.64 311.55 2.07 MWD 6-axis 9432.85 311.54 0.56 MWD 6-axis 9516.22 311.52 1.50 MWD 6-axis 9602.20 311.48 0.73 MWD 6-axis 6936.34 -7959.94 6989.04 -8034.63 7041.83 -8105.97 7097.09 -8177.22 7152.66 -8248.97 9688.72 311.45 0.61 MWD 6-axis 9777.03 311.42 2.51 MWD 6-axis 9865.00 311.39 0.25 MWD 6-axis 9952.03 311.36 0.54 MIND 6-axis 10038.92 311.33 1.01 MWD 6-axis 7207.94 -8321.68 7263.11 -8396.93 7317.44 -8473.38 7370.46 -8548.96 7423.29 -8624.69 10127.72 311.29 0.84 MWD 6-axis 10213.56 311.25 0.43 MWD 6-axis 10299.50 311.21 1.04 MWD 6-axis 10385.83 311.16 0.65 MWD 6-axis 10471.72 311.12 1.85 MWD 6-axis 10558.10 311.07 2.00 MWD 6-axis 10649.03 311.02 3.24 MWD 6-axis 10737.50 310.98 2.40 MWD 6-axis 10827.54 310.96 0.82 MWD 6-axis 10918.15 310.93 0.72 MWD 6-axis 11009.31 310.90 2.53 MWD 6-axis 11102.31 310.86 3.57 MWD 6-axis 11195.67 310.81 0.03 MWD 6-axis 11287.53 310.77 0.92 MWD 6-axis 11379.39 310.72 0.42 "' MWD 6-axis Page 6 Survey_PB.ASCI!_FILE [(c)1998 Anadrill IDEAL I:/id5_0a_33]v ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 151 14170.16 78.96 304.0 93.80 152 14263.30 78.73 304.0 93.10 153 14356.89 78.30 304.0 93.60 154 14451.46 78.85 305.5 94.60 155 14545.67 79.17 304.5 94.20 156 14639.91 80.10 304.8 94.20 157 14732.33 80.01 304.6 92.40 158 14825.95 79.46 305.6 93.60 159 14920.23 78.80 305.0 94,30 160 15013.43 79.49 304.8 93.20 161 15107.60 80.21 304.4 94.20 162 15202.59 80.27 304.6 95.00 163 15301.63 80.68 305.6 99.00 164 15396.22 80.82 306.1 94.60 165 15486.73 80.25 305.5 90.50 166 15580.95 79.73 304.8 94.30 167 15671.67 80.77 303.5 90.70 168 15766.14 81.35 303.1 94.40 169 15860.00 80.57 303.2 93.90 170 15955.21 80.34 303.0 95.20 171 16050.42 79.73 302.8 95.20 172 16144.63 79.99 301.8 94.20 173 16237.26 81.95 301.7 92.70 174 16331.13 83.28 302.3 93.80 17'5 16425.08 83.97 302.2 94.00 176 16519.29 84.52 302.2 94.20 177 16612.82 85.08 302.5 93.50 178 16705.27 85.40 302.0' 92.50 179 16800.51 86.17 301.8 95.20 180 16896.48 87.20 301.3 96.00 TVD depth (ft) 6766.92 6784.93 6803.57 6822.31 6840.26 6857.21 6873.17 6889.85 6907.63 6925.19 6941.,79 6957.89 6974.27 6989.48 7004.36 7020.75 7036.11 7050.78 7065.54 7081.32 7097.80 7114.38 7128.93 7140.99 7151.42 7160.87 7169.34 7177.02 7184.02 7189.57 Vertical section (ft) 11468.99 11559.50 11650.39 11742.42 11834.26 11926.21 12016.54 12108.03 12200.05 12290.93 12382.94 12475.82 12572.80 12665.68 12754.47 12846.72 12935.33 13027.57 13119.27 13212.09 13304.74 13396.21 13486.37 13578.05 13670.20 13762.63 13854.50 13945.42 14038.97 14133.30 8-Jan-98 14:58:53 Displ Displ +N/S- +E/W- (ft) (ft) Page 7 of Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 7475.52 -8700.54 11470.95 7526.59 -8776.26 11561.68 7577.89 -8852.31 11652.80 7630.74 -8928.49 11745.05 7683.78 -9004.24 11837.09 310.67 1.17 MWD 6-axis 310.62 0.25 MWD 6-axis 310.56 0.46 MWD~ 6-axis 310.52 1.66 MWD 6-axis 310.48 1.10 MIND 6-axis 7736.46 -9080.47 11929.28 7788.27 -9155.29 12019.84 7841.23 -9230.65 12111.55 7894.74 -9306.23 12203.80 7947.11 -9381.30 12294.93 310.43 1.04 MWD 6-axis 310.39 0.23 MWD 6-axis 310.35 1.20 MWD 6-axis 310.31 0.94 MWD 6-axis 310.27 0.77 MWD 6-axis 7999.77 -9457.62 12387.21 8052.80 -9534.78 12480.37 8108.94 -9614.66 12577.62 8163.62 -9690.34 12670.73 8215.84 -9762.74 12759.75 310.23 0.87 MWD 6-axis 310.18 0.22 MWD 6-axis 310.14 1.08 MWD 6-axis 310.11 0.54 MWD 6-axis 310.08 0.91 MWD 6-axis 8269.30 -9838.67 12852.27 310.05 0.92 MWD 8319.48 -9912.65 12941.18 310.01 1.82 MWD 8370.68 -9990.59 13033.80 309.96 0.74 MWD 8421.39 -10068.23 13125.89 309.91 0.84 MWD 8472.66 -10146.87 13219.11 309.86 0.32 MWD 8523.58 -10225.60 13312.19 309.81 0.67 MWD 8573.13 -10303.98 13404.13 309.76 1.08 MWD 8621.31 -10381.82 13494.78 309.71 2.12 MWD 8670.60 -10460.71 13586.97 309.65 1.55 MWD 8720.45 -10539.71 13679.61 309.60 0.74 MWD 8770.39 -10619.03 13772.56 309.55 0.58 MWD 8820.22 -10697.69 13864.95 309.51 0.68 ~,~MWD 8869.41 -10775.65 13956.40 309.46 0.64 MWD 8919.58 -10856.25 14050.52 309.41 0.84 MWD 8969.72 -10937.92 14145.46 309.35 1.19 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis Page 7 " ~ Survey_PB.ASCiI_F!LE , [(c)1998 Anadrill IDEAL I:/id5_0a_33]v ANADRILL SCHLUMBERGER Survey Report 8-Jan-98 14:58:53 Page 8 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool ~ depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -- _ 181 16991.26 89.14 301.1 94.80 7192.60 14226.45 9018.81 -11018.97 14239.26 309.30 2.06 MWD 6-axis 182 17083.95 90.43 300.8 92.60 7192.94 14317.41 9066.43 -11098.38 14330.88 309.25 1.43 MWD 6-axis 183 17177.72 92.06 299.8 93.80 7190.90 14409.33 9113.74 -11179.34 14423.52 309.19 2.04 MWD_M - 184 17272.62 94.26 300.0 94.90 7185.67 14502.06 9160.97 -11261.48 14517.04 309.13 2.33 MWD_M - 185 17368.38 95.83 300.7 95.80 7177.25 14595.61 9209.19 -11343.83 14611.35 309.07 1.79 MWD_M - 186 17461.95 96.81 301.1 93.50 7166.96 14686.89 9256.91 -11423.57 14703.34 309.02 1.13 MWD_M - [(c)1998 Anadrill IDEAL I:/id5_0a_33] Page 7 Schlumberger ANADRILL Survey Report Client: BP Exploration (Alaska) Inc. Field: Milne Point . Well Name: MPF-79~ Permanent datum Mean Sea Level Depth measured from Drill Floor Elevation of kelly bushing Elevation of drill floor Elevation of ground level Magnetic Declination 27.94 DEG Grid Convergence 0.00 DEG Total Correction 27.94 DEG Survey_02.ASCII_FILE Il-NOV-97 18:47:44 44.55 FT 44.55 FT 11.50 FT Page 001 TIE IN POINT Measured depth True vertical depth N/S disp (-ye for S) E/W disp (-ve for W) 0.00 FT 0.00 FT 0.00 FT 0.00 FT Inclination 0.00 DEG Azimuth 0.00 DEG Azimuth from rotary table to the target 311.73 DEG MEASURED INTERVAL VERTICAL DEPTH DEPTH FT FT FT 0.0 0.00 0.00 207.1 207.10 207.10 298.1 91.00 298.10 388.2 90.10 388.19 478.8 90.60 478.76 Minimum Curvature Method TARGET SECTION FT 0.00 0.14 0.56 1.81 4.05 STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS INCLN. N/-S E/-W CEMENT DEG DEG FT FT FT DEG D/HF 0.00 0.0 0.00 0.00 0.00 0.00 0.00 0.14 7.8 0.25 0.03 0.~25 7.80 0.07 0.56 349.1 0.80 -0.03 0.80 357.51 0.47 1.27 337.4 2.15 -0.50 2.21 346.88 0.81 1.72 322.5 4.16 -1.72 4.50 337.58 0.65 567.7 88.90 567.60 657.4 89.70 657.19 747.8 90.40 747.22 842.4 94.60 840.94 940.3 97.90 936.93 7.04 2.17 313.1 6.37 -3.76 11.60 3.66 314.6 9.54 -7.04 19.61 6.55 317.4 15.36 -12.58 32.39 9.02 315.0 24.58 -21.48 51.47 13.53 306.6 36.84 -36.11 7.39 329.46 0.62 11.85 323.58 1.66 19.85 320.68 3.21 32.64 318.85 2.63 51.58 315.57 4.89 1023.6 83.30 1017.56 1117.0 93.40 1107.57 1210.6 93.60 1197.48 1305.3 94.70 1287.36 1397.7 92.40 1373.83 72.24 96.97 122.81 152.55 185.11 15.55 304.0 48.89 -53.19 15.43 304.4 62.91 -73.82 16.83 306.3 77.97 -95.01 19.87 310.3 96.50 -118.34 21.40 312.0 117.94 -142.85 72.25 312.59 2.55 96.99 310.44 0.17 122.91 309.37 1.60 152.70 309.19 3.47 185.24 309.54 1.78 1492.4 94.70 1462.43 1584.6 92.20 1548.56 1678.1 93.50 1634.17 1770.4 92.30 1717.23 1864.3 93.90 1801.58 218.53 251.42 288.96 329.18 370.41 19.94 312.5 140.41 -167.60 21.86 313.3 162.81 -191.68 25.51 313.0 188.48 -219.08 26.20 314.3 216.27 -248.20 25.93 313.3 244.83 -277.98 218.64 309.96 1.55 251.49 310.34 2.11 289.00 310.71 3.91 329.21 311.07 0.97 370.42 311.37 0.55 1956.3 92.00 1884.08 2053.3 97.00 1969.34 2145.1 91.80 2046.99 2239.6 94.50 2123.63 2333.4 93.80 2196.40 411.12 457.34 506.28 561.54 620.70 26.60 312.7 272.59 -307.76 30.33 311.9 303.68 -341.96 34.12 311.4 336.20 -378.54 37.46 311.6 372.82 -419.92 40.77 311.6 412.10 -464.16 411.12 311.53 0.78 457.34 311.61 3.87 506.28 311.61 4.14 561.54 311.60 3.54 620.71 311.60 3.53 2428.8 95.40 2266.92 2522.9 94.10 2332.96 2617.4 94.50 2395.64 2712.5 95.10 2455.17 2806.2 93.70 2510.69 684.93 751.95 822.65 896.80 972.27 43.88 311.7 454.79 -512.16 46.97 310.6 498.88 -562.63 49.91 311.3 545.22 -616.03 52.58 312.0 594.51 -671.43 54.74 311.7 644.86 -727.65 684.93 311.60 3.26 751.95 311.56 3.39 822.65 311.51 3.16 896.81 311.52 2.87 972.28 311.55 2.32 2898.9 92.70 2562.46 1049.15 57.35 311.0 695.65 -785.37 Page 1 1049.16 311.53 2 .88 !~,:,~,~ i~,,d~.'' Survey_02.ASCII_FILE Schlumberger ANADRILL Survey Report Il-NOV-97 18:47:44 Page 002 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 2990.7 91.80 2609.57 1127.93 60.90 311.4 747.49 -844.69 1127.94 311.51 3.88 3082.1 91.40 2651.94 1208.90 63.86 312.3 801.47 -905.05 1208.91 311.53 3.38 3178.5 96.40 2692.76 1296.22 66.03 312.4 860.30 -969.58 1296.23 311.58 2.25 3273.1 94.60 2730.80 1382.82 66.55 313.0 919.04 -1033.23 1382.82 311.65 0.80 3367.5 94.40 2768.14 1469.51 66.85 312.7 978.00 -1096.80 1469.51 311.72 0.43 3461.1 93.60 2804.66 1555.67 67.21 312.6 1036.39 -1160.18 1555.68 311.77 0.40 3554.9 93.80 2840.48 1642.36 67.89 312.6 1095.07 -1224.00 1642.36 311.82 0.72 3647.9 93.00 2875.46 1728.51 67.93 313.3 1153.73 -1287.12 1728.52 311.87 0.60 3741.9 94.00 2910.41 1815.74 68.41 313.2 1213.46 -1350.73 1815.75 311.94 0.51 3835.2 93.30 2944.40 1902.62 68.87 311.7 1272.10 -1414.84 1902.64 311.96 1.58 3929.7 94.50 2978.17 1990.88 69.25 311.9 1330.87 -1480.69 1990.90 311.95 0.41 4025.1 95.40 3012.12 2080.03 69.06 310.2 1389.36 -1547.97 2080.04 311.91 1.58 4120.8 95.70 3046.15 2169.45 69.28 310.8 1447.45 -1615.99 2169.45 311.85 0.63 4215.1 94.30 3080.62 2257.19 67.84 309.9 1504.28 -1682.88 2257.20 311.79 1.77 4308.1 93.00 3115.48 2343.32 68.13 308.4 1558.71 -1749.74 2343.32 311.70 1.53 4399.9 91.80 3148.84 2428.72 69.25 308.8 1612.07 -1816.57 2428.72 311.59 1.29 4493.3 93.40 3181.44 2516.13 69.90 308.7 1666.86 -1884.83 2516.15 311.49 0.70 4586.9 93.60 3214.76 2603.48 68.39 308.9 1721.66 -1953.00 2603.52 311.40 1.63 4679.0 92.10 3249.93 2688.50 66.70 309.2 1775.28 -2019.10 2688.57 311.32 1.86 4773.3 94.30 3287.06 2775.07 66.93 308.4 1829.60 -2086.65 2775.17 311.24 0.82 4868.2 94.90 3323.57 2862.52 67.82 308.5 1884.07 -2155.26 2862.66 311.16 0.94 4961.0 92.80 3357.90 2948.59 68.76 308.4 1937.62 -2222.82 2948.78 311.08 1.03 5055.4 94.40 3392.75 3036.16 67.90 308.3 1991.99 -2291.67 3036.41 311.00 0.91 5149.8 94.40 3427.99 3123.58 68.27 308.4 2046.27 -2360.40 3123.89 310.92 0.39 5243.4 93.60 3462.83 3210.28 68.02 307.9 2099.87 -2428.76 3210.66 310.85 0.48 5337.8 94.40 3498.14 3297.61 68.05 307.4 2153.35 -2498.08 3298.08 310.76 0.49 5431.6 93.80 3533.64 3384.24 67.47 308.5 2206.74 -2566.54 3384.80 310.69 1.25 5522.8 91.20 3568.30 3468.45 67.86 308.3 2259.14 -2632.65 3469.09 310.63 0.47 5618.1 95.30 3604.66 3556.45 67.28 310.1 2314.81 -2700.91 3557.15 310.60 1.85 5711.0 92.90 3641.22 3641.81 66.37 309.7 2369.54 -2766.48 3642.54 310.58 1.10 5807.2 96.20 3679.98 3729.82 66.12 310.5 2426.19 -2833.88 3730.59 310.57 0.89 5902.0 94.80 3719.71 3815.86 64.32 310.2 2481.92 -2899.47 3816.65 310.56 1.92 5994.0 92.00 3761.64 3897.73 61.45 312.3 2535.89 -2961.04 3898.52 310.58 3.72 6088.1 94.10 3807.33 3979.99 60.46 312.6 2591.41 -3021.74 3980.74 310.62 1.09 6183.7 95.60 3854.29 4063.21 60.69 314.4 2648.72 -3082.14 4063.90 310.68 1.66 6280.8 97.10 3901.27 4148.08 61.45 314.9 2708.45 -3142.59 4148.68 310.76 0.90 6375.4 94.60 3943.97 4232.25 64.88 316.9 2769.07 -3201.31 4232.74 310.86 4.09 6469.6 94.20 3982.45 4317.89 66.90 316.8 2831.80 -3260.11 4318.26 310.98 2.15 6563.1 93.50 4019.14 4403.50 66.89 317.6 2894.90 -3318.54 4403.76 311.10 0.79 6655.3 92.20 4054.67 4488.14 67.77 317.4 2957.62 -3376.02 4488.32 311.22 0.98 6748.3 93.00 4089.37 4573.98 68.42 317.7 3021.29 -3434.25 4574.09 311.34 0.76 6843.1 94.80 4123.88 4661.90 68.89 316.4 3085.91 -3494.42 4661.95 311.45 1.37 6937.7 94.60 4157.86 4749.89 69.00 316.3 3149.79 -3555.35 4749.92 311.54 0.15 7032.2 94.50 4192.20 4837.71 68.38 315.3 3212.91 -3616.73 4837.72 311.62 1.18 7125.2 93.00 4226.70 4923.95 68.08 314.4 3273.82 -3677.96 4923.95 311.67 0.95 Page 2 Survey_02.ASCII_FILE Schlumberger ANADRILL Survey Report Il-NOV-97 18:47:44 Page 003 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 7218.7 93.50 4261.56 5010.60 68.14 314.8 3334.74 -3739.73 5010.60 311.72 0.40 7265.2 46.50 4278.84 5053.69 68.21 315.2 3365.26 -3770.26 5053.69 311.75 0.81 7412.9 147.70 4333.73 5190.60 68.16 314.7 3462.14 -3867.30 5190.61 311.84 0.32 7507.1 94.20 4369.83 5277.54 66.78 313.3 3522.58 -3929.88 5277.55 311.87 2.01 7598.8 91.70 4406.30 5361.65 66.35 312.5 3579.85 -3991.52 5361.67 311.89 0.93 7692.4 93.60 4443.46 5447.55 66.86 311.6 3637.39 -4055.30 5447.58 311.89 1.04 7785.8 93.40 4480.21 5533.42 66.81 312.9 3695.12 -4118.87 5533.44 311.90 1.28 7879.6 93.80 4517.53 5619.45 66.29 313.2 3753.86 -4181.75 5619.48 311.91 0.63 7972.2 92.60 4554.52 5704.31 66.63 313.1 3811.92 -4243.68 5704.35 311.93 0.38 8065.3 93.10 4590.85 5790.01 67.43 313.1 3870.49 -4306.27 5790.05 311.95 0.86 8159.1 93.80 4627.35 5876.40 66.77 312.2 3929.03 -4369.82 5876.45 311.96 1.13 8250.8 91.70 4663.44 5960.70 66.88 312.5 3985.82 -4432.12 5960.75 311.97 0.32 8346.1 95.30 4700.57 6048.46 67.25 312.0 4044.83 -4497.09 6048.51 311.97 0.62 8440.0 93.90 4737.35 6134.86 66.63 311.7 4102.48 -4561.45 6134.91 311.97 0.72 8533.4 93.40 4774.52 6220.54 66.47 311.5 4159.37 -4625.52 6220.59 311.96 0.26 8628.8 95.40 4812.00 6308.27 67.27 312.3 4217.96 -4690.82 6308.32 311.96 1.14 8723.9 95.10 4848.44 6396.09 67.67 313.6 4277.81 -4755.11 6396.15 311.98 1.33 8818.8 94.90 4884.27 6483.87 67.97 315.2 4339.29 -4817.89 6483.94 312.01 1.59 8914.8 96.00 4920.60 6572.53 67.55 315.9 4402.72 -4880.12 6572.63 312.06 0.80 9008.7 93.90 4957.05 6658.93 66.78 313.9 4463.81 -4941.41 6659.06 312.09 2.13 9102.3 93.60 4993.57 6745.04 67.28 314.0 4523.62 -5003.46 6745.20 312.12 0.54 9193.5 91.20 5026.83 6829.89 69.94 313.8 4582.49 -5064.64 6830.07 312.14 2.92 9286.2 92.70 5056.62 6917.61 72.57 313.8 4643.25 -5127.99 6917.81 312.16 2.84 9380.0 93.80 5085.02 7006.93 72.18 314.3 4705.40 -5192.24 7007.15 312.18 0.66 9474.6 94.60 5114.57 7096.74 71.42 313.2 4767.55 -5257.16 7096.99 312.20 1.37 9566.1 91.50 5143.89 7183.41 71.21 310.5 4825.37 -5321.72 7183.65 312.20 2.80 9660.2 94.10 5174.64 7272.31 70.64 309.8 4882.71 -5389.69 7272.53 312.17 0.93 9754.6 94.40 5205.96 7361.30 70.60 309.4 4939.48 -5458.31 7361.49 312.14 0.40 9848.7 94.10 5237.84 7449.77 69.80 309.7 4995.85 -5526.57 7449.94 312.11 0.90 9944.3 95.60 5271.33 7539.24 69.18 309.2 5052.75 -5595.71 7539.38 312.08 0.81 10039.2 94.90 5305.22 7627.79 68.98 309.1 5108.71 -5664.46 7627.91 312.05 0.23 10129.3 90.10 5338.04 7711.61 68.29 309.0 5161.57 -5729.62 7711.70 312.01 0,77 10222.9 93.60 5373.40 7798.17 67.32 308.8 5216.00 -5797.06 7798.24 311.98 1.06 10316.4 93.50 5410.43 7883.88 66.02 308.1 5269.38 -5864.30 7883.93 311.94 1.55 10412.0 95.60 5449.55 7970.93 65.67 308.0 5323.15 -5932.99 7970.96 311.90 0.38 10503.4 91.40 5487.02 8054.14 65.93 308.4 5374.70 -5998.50 8054.16 311.86 0.49 10595.3 91.90 5523.72 8138.29 66.99 309.5 5427.67 -6064.02 8138.30 311.83 1.59 10690.1 94.80 5560.43 8225.63 67.44 309.5 5483.26 -6131.46 8225.63 311.81 0.47 10785.1 95.00 5595.84 8313.73 68.79 310.3 5539.81 -6199.09 8313.73 311.79 1.62 10879.8 94.70 5630.48 8401.84 68.30 310.3 5596.82 -6266.31 8401.84 311,77 0.52 10973.7 93.90 5665.75 8488.80 67.58 308.8 5652.23 -6333.41 8488.80 311.75 1.67 11067.5 93.80 5702.14 8575.15 66.77 309.0 5706.52 -6400.69 8575.15 311.72 0.89 11161.7 94.20 5739.75 8661.43 66.17 309.4 5761.10 -6467.62 8661.43 311.69 0.75 11254.4 92.70 5777.25 8746.16 66.10 310.4 5815.48 -6532.65 8746.17 311.68 0.99 11347.9 93.50 5815.49 8831.45 65.62 310.0 5870.55 -6597.82 8831.46 311.66 0.64 Page 3 Survey_02,ASCII_FILE Schlumberger ANADRILL Survey Report Il-NOV-97 18:47:44 Page 004 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION DEPTH DEPTH SECTION INCLN. FT FT FT FT DEG 11442,4 94.50 5854.76 8917,37 65,27 11537,1 94.70 5893.03 9003,94 67,06 11632.3 95,20 5930,51 9091,41 66,56 11727.0 94.70 5968.84 9177.94 65.69 11820,5 93,50 6007,86 9262,81 64,99 AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH N/-S E/-W CEMENT DEG FT FT FT DEG 310,0 5925,80 -6663,67 8917,38 311.65 309,8 5981,37 -6730,12 9003,96 311,63 310,0 6037,50 -6797,25 9091.42 311.61 309.0 6092,58 -6864,07 9177.96 311.59 309.1 6146,11 -6930.06 9262.85 311.57 11912,4 91,90 6045,49 9346,59 66,66 12006.2 93,80 6082,37 9432,79 67,04 12097.1 90.90 6118,41 9516.15 66,24 12191,3 94,20 6156.56 9602,11 65,98 12286,0 94,70 6194,67 9688,60 66,56 310,1 6199,56 -6994,65 9346,64 311,55 309,7 6254,88 -7060,82 9432,85 311.54 308,5 6307,51 -7125,57 9516.22 311,52 307,8 6360.71 -7193.30 9602,20 311.48 307,8 6413,85 -7261,81 9688.72 311.45 12381,6 95,60 6230,86 9776,88 68,95 12476,1 '94,50 6264,97 9864,82 68,73 12569.7 93,60 6299.07 9951,82 68.54 12663.3 93.60 6333,45 10038,68 68,36 12774.8 111,50 6377.13 10140,98 65,51 308,0 6468,20 -7331,62 9777,03 311,42 307,9 6522,39 -7401,11 9865,00 311,39 308.4 6576.24 -7469,66 9952,03 311.36 307,4 6629,72 -7538.36 10038.92 311.33 307,7 6692,23 -7619,68 10141,28 311,29 12865,6 90,80 6416,99 10222,19 62,41 12959.7 94,10 6458,84 10305.86 64.78 13053,4 93.70 6496,97 10390,72 67,19 13144.6 91.20 6529,54 10475,06 70,95 13240,3 95,70 6557.74 10565,38 74,77 305,1 6740,65 -7685.32 10222,55 311,25 304.5 6788,75 -7754,52 10306,29 311,20 304,1 6836,97 -7825,23 10391.26 311.14 303..4 6884,28 -7896,04 10475,73 311.08 302,2 6933,80 -7972,90 10566,21 311,01 13335.5 95,20 6580,14 10656.67 78,01 13428,3 92,80 6599,28 10746,31 78,18 13523,2 94,90 6618,95 10837,88 77,90 13618,4 95,20 6639,07 10929,53 77,69 13709,4 91,00 6658,38 11016,95 77,81 302,6 6983,38 -8051,01 10657,69 310.94 302,5 7032,23 -8127.55 10747,53 310.87 302,0 7081,77 -8206,07 10839,33 310.79 301,5 7130,74 -8285,19 10931,23 310,72 300,9 7176,80 -8361,26 11018,95 310,64 13804,4 95.00 6678,85 11108,02 77,30 13896,8 92,40 6699.23 11196,36 77,22 13991,7 94,90 6719,85 11287,28 77,69 14083.6 91,90 6738,96 11375,60 78,30 14175.0 91,40 6757,54 11463,31 78,24 300,6 7224,23 -8440,98 11110,35 310.56 300,0 7269.70 -8518,80 11199.04 310.48 301,4 7317,00 -8598,45 11290,34 310,40 300,6 7363,29 -8675,50 11379,03 310.32 300,0 7408,44 -8752,76 11467,17 310,25 14270,8 95,80 6776,13 11555,57 79.38 14365,2 94,40 6793,77 11646,71 79,09 14458,3 93,10 6811,46 11736,56 79,00 14552,4 94,10 6829,72 11827,55 78,62 14647.3 94.90 6848,57 11919.29 78,47 301,5 7456.49 -8833.52 11559,86 310,17 300,7 7504,40 -8912,93 11651,45 310.10 301,6 7551,68 -8991,16 11741,75 310,03 302,4 7600,59 -9069,44 11833,16 309,96 302,1 7650,23 -9148,10 11925,34 309.90 14740,9 93.60 6867,69 12009,63 77,95 14834.2 93.30 6887,40 12099,53 77,66 14927,0 92,80 6907,47 12188,87 77,36 15021.8 94.80 6928.31 12280.13 77,25 15117,7 95.90 6948.35 12372.79 78.62 302.2 7698,98 -9225,67 12016.13 309.85 301,9 7747,38 -9302,97 12106,49 309.79 302,4 7795,59 -9379,68 12196.29 309.73 302,4 7845,14 -9457,76 12288.03 309,68 303.4 7896,08 -9536,50 12381.16 309,62 15214,1 96,40 6967,56 12466,22 78,39 15308,2 94,10 6986,97 12557,25 77,81 15401,8 93,60 7007,48 12647,49 76,87 15493,4 91,60 7028.92 12735,44 76,05 15586,2 92,80 7050,83 12824,66 76,64 303,0 7947,81 -9615,55 12475,03 309,58 303,2 7998,09 -9692,68 12566,53 309,53 302,6 8047,70 -9769,36 12657,24 309,48 302,8 8095.81 -9844.30 12745,68 309,43 304,0 8145,45 -9919,58 12835,36 309.39 DLS D/HF 0.37 1.90 0.56 1.33 0.75 2,07 0.56 1,50 0,73 0'.61 2.51 0.25 0.54 1.01 2.57 4.27 2.58 2.60 4.18 4.17 3.43 0.21 0.59 0,56 0.66 0,62 0.64 1,52 1.08 0.65 1.94 0.89 0,95 0,93 0,35 0.57 0.44 0.62 0.12 1.76 0.47 0.65 1.18 0.92 1.41 Page 4 Schlumberger ANADRILL MEASURED DEPTH FT 15676.9 15771.2 15865.3 15961.1 16055.8 Survey_02.ASCII_FILE Survey Report Il-NOV-97 18:47:44 INTERVAL VERTICAL DEPTH FT FT Minimum Curvature Method TARGET STATION AZIMUTH LATITUDE SECTION INCLN. N/-S FT DEG DEG FT Page 005 90.70 7072.54 12911.88 94.30 7095.15 13002.51 94.10~ 7114.77 13093.78 95.80 7128.95 13187.80 94.70 7137.73 13281.37 75 67 76.58 79 35 83.62 85 74 DEPARTURE DISPLA- 303.5 303.8 305.0 304.5 304.8 E/-W CEMENT FT FT 8194.38 -9992.80 12923.00 8245.10 -10069.01 13014.09 8297.10 -10144.93 13105.78 8351.08 -10222.76 13200.21 8404.69 -10300.33 13294.19 16150 16242 16336 16430 16525 .3 .9 .6 .7 .3 94.50 7143.69 13374.98 92.60 7146.97 13466.88 93.70 7147.67 13559.92 94.10 7146.74 13653.26 94.60 7145.21 13747.10 87 03 88.91 90 23 90.91 90 94 304.7 305.3 304.6 304.3 304.8 8458.45 -10377.82 13388.22 8511.53 -10453.62 13480.51 8565.20 -10530.42 13573.96 8618.43 -10608.01 13667.74 8672.07 -10685.91 13762.03 16618 16712 16807 16900 16993 .5 .3 ,3 .2 .7 93.20 7144.70 13839.68 93.80 7145.98 13932.92 95.00 7147.91 14027.33 92.90 7149.67 14119.70 93.50 7153.06 14212.64 89 69 88.74 88.94 88.89 86.95 305.5 8725.73 305.5 8780.19 305.4 8835.28 306.0 8889.48 305.7 8944.20 at AZIMUTH 17087 17181 17275 17371 17467 .3 .3 .9 .6 .3 93.60 7159.44 14305.59 94.00 7167.52 14398.92 94.60 7175.70 14492,78 95.70 7181.32 14587.79 95.70 7184.71 14682.90 85.23 84.91 85.17 88.09 87.86 306.7 8999.35 307.3 9055.71 305.8 9111.83 305.8 9167.71 305.6 9223.52 DEG 309.35 309.31 309.28 309.25 309.21 17561.8 17654.8 17748.1 17841.9 17935.2 94.50 7185.56 14776.95 93.00 7183.27 14869.62 93.30 7180.06 14962.63 93.80 7175.24 15056.13 93.30 7169.17 15149.09 91.11 91.71 92.23 93.66 93.80 306.9 9279.39 307.3 9335.47 308.1 9392.49 308.3 9450.42 308.9 9508.50 309.18 309.15 309.12 309.09 309.06 18028 18124 18218 18310 18404 7 93.50 7163.74 15242.33 5 95.80 7159.13 15337,91 9 94.40 7153.24 15431.92 8 91.90 7145.16 15523.13 9 94.10 7136.25 15616.36 92.86 92.66 94.49 95.60 95.26 309.2 9567.31 308.9 9627.59 307.1 9685.59 306.5 9740.43 305.8 9795.69 -10762.11 13855.01 309.03 -10838.47 13948.63 309.01 -10915.84 14043.43 308.99 -10991.27 14136.16 308.97 -11067.00 14229.45 308.94 18497.9 93.00 7127.31 15708.45 18592.3 94.40 7117.90 15801.88 18686.9 94.60 7108.54 15895.52 95.78 95.66 95.69 306.0 9849.97 305.6 9904.92 306.i 9960.05 -11142.36 14322.72 308.93 -11217.15 14416.32 308.91 -11292.86 14510.49 308.90 -11370.34 14605.87 308.88 -11448.01 14701.37 308.86 Survey Projected to TD: 18776.0 89.10 7099.71 15983.74 95.69 -11524.20 14795.75 308.84 -11598.35 14888.68 308.83 -11672.13 14981.90 308.82 -11745.74 15075.57 308.82 -11818.50 15168.67 308.82 -11890.99 15262.01 308.82 -11965.30 15357.70 308.82 -12039.54 15451.90 308.82 -12112.84 15543.39 308.80 -12188.48 15636.96 308.79 -12263.47 15729.42 308.77 -12339.65 15823.22 308.75 -12415.95 15917.24 308.74 306.0 10012.22 -12487.63 16005.80 308.72 DLS D/HF 1.20 1.01 3.20 4.49 2.26 1.37 2.13 1.59 0.79 0.53 1.54 1.01 0.24 0.65 2.10 2.12 0.72 1.60 3.05 0.32 3.70 0.78 1.02 1.54 0.66 1.06 0.38 2.72 1.37 0.82 0.60 0.44 0.53 0.11 Page 5 /77 .... i~ B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Gyro Continuous Multishot Survey Inside 5" DRILL PIPE Survey date: 28-NOVEMBER, 1997 Job number :Al 197GCE431 CONTENTS JOB NUMBER :A1197GCE431 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1, DISCUSSION, SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER · A1197GCE431 Tool 777 was run in WELL# MPF-79 on ATLAS 5/16" wireline inside DRILL PIPE. The survey was run without problems. SURVEY CERTIFICATION SHEET JOB NUMBER: A1197GCE431 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER 2. SURVEY DETAILS ¢ SURVEY DETAILS JOB NUMBER: A1197GCE431 CLIENT: B.P. EXPLORATION RIG: NABORS 27E LOCATION: F PAD, ALASKA WELL: MPF-79 LATITUDE: 70.507 N LONGITUDE: 149.5 W SURVEY DATE: SURVEY TYPE : 28-NOVEMBER, 1997 GYRO CONTINOUS MULTISHOT IN 5" DRILL PIPE DEPTH REFERENCE: 44.55' MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 12934' SURVEY TIED ONTO: NA SURVEY INTERVAL: 0-12934' APl NUMBER: 050-029-22813 TARGET DIRECTION: 311.73 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. OUTRUN SURVEY LISTING A Gyro da t a D i r e c t i ona i Survey for B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: Al197GCE431 Run Date: 26-Nov-97 22:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 44.55 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 311.730 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i re c t i on a i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: Al197GCE431 Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. H 0 R I Z O N T A L COORDINATES feet 0 01 00 00 00 .0 .0 .0 .0 .0 0.00 0.00 0.0 · 34 310.35 101.0 · · 45 8.79 200.0 .70 354.14 300.0 1.34 324.00 400.0 0.0 0.00 0.0 0.0 · 3 .34 .3 310.3 · 8 .40 .9 332.8 1.5 .28 1.8 347.3 3.1 .82 3.5 340.9 0.00 N 0.00 E .20 N .23 W .77 N .40 W 1.77 N .40 W 3.32 N 1.15 W 00 00 00 01 00 .0 .0 .0 .0 .0 2.00 312.80 499.9 2.42 311.14 599.9 5.12 315.79 699.6 7.77 315.40 800.0 11.44 308.74 897.6 6.0 .73 6.3 330.2 9.8 .43 10.0 323.3 16.4 2.71 16.5 319.7 27.7 2.63 27.8 318.0 44.2 3.87 44.3 315.6 5.45 N 3.12 W 8.03 N 5.99 W 12.61 N 10.69 W 20.70 N 18.63 W 31.62 N 30.99 W 1000.0 14 1050.0 15 1100.0 15 1150.0 15 1200.0 16 1250.0 17 1300.0 19 1350.0 20 1400.0 21 1450.0 20 .97 304.20 994.9 .19 304.53 1043.2 .55 305.09 1091.4 .85 305.01 1139.6 .41 306.34 1187.6 .62 308.29 1235.4 .41 310.65 1282.8 .93 311.80 1329.7 .22 311.87 1376.4 .29 312.20 1423.1 66.9 3.68 66.9 312.4 79.8 .47 79.8 311.1 92.9 .79 93.0 310.2 106.4 .60 106.5 309.5 120.2 1.34 120.3 309.1 134.8 2.67 135.0 308.9 150.7 3.88 150.8 309.0 167.9 3.14 168.1 309.2 185.9 .57 186.0 309.5 203.6 1.86 203.7 309.7 45.09 N 49.42 W 52.43 N 60.15 W 60.00 N 71.03 W 67.77 N 82.11 W 75.87 N 93.39 W 84.75 N 105.02 W 94.85 N 117.27 W 106.22 N 130.23 W 118.21 N 143.63 W 130.07 N 156.79 W 15 15 16 16 17 00.0 50.0 00.0 50.O 00.0 20.22 312.12 1470.1 20.60 312.29 1516.9 22.34 312.67 1563.4 23.92 313.30 1609.4 25.43 313.91 1654.9 220.9 .16 221.0 309.9 238.3 .77 238.4 310.0 256.6 3.49 256.7 310.2 276.3 3.20 276.3 310.4 297.1 3.05 297.2 310.6 141.69 N 169.62 W 153.41 N 182.54 W 165.77 N 196.03 W 179.16 N 210.40 W 193.56'N 225.51 W A Gyroda t a D i r e c t i ona I Survey B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: Al197GCE431 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 1750.0 26.13 313.94 1699.9 1800.0 25.76 313.93 1744.8 1850.0 25.61 313.01 1789.9 1900.0 25.52 313.18 1835.0 1950.0 26.34 312.53 1880.0 318.9 1.41 318.9 310.9 340.7 .74 340.7 311.1 362.4 .85 362.4 311.2 384.0 .23 384.0 311.3 405.8 1.74 405.8 311.4 208.64 N 223.82 N 238.73 N 253.48 N 268.35 N 241.17 W 256.92 W 272.65 W 288.41 W 304.44 W 2000.0 27.99 311.82 1924.5 2050.0 29.99 311.43 1968.2 2100.0 31.96 311.34 2011.1 2150.0 34.02 311.22 2053.0 2200.0 35.58 311.15 2094.0 428.6 3.35 428.6 311.4 452.9 4.02 452.9 311.4 478.6 3.94 478.6 311.4 505.8 4.12 505.8 311.4 534.4 3.11 534.4 311.4 283.67 N 299.76 N 316.77 N 334.73 N 353.52 N 321.35 W 339.47 W 358.77 W 379.23 W 400.71 W 2250.0 37.56 311.18 2134.2 2300.0 38.91 311.64 2173.5 2350.0 41.13 312.12 2211.8 2400.0 42.14 312.12 2249.1 2450.0 44.14 311.82 2285.6 2500.0 45.61 311.54 2321.1 2550.0 47.28 311.31 2355.5 2600.0 48.96 311.53 2388.9 2650.0 50.35 312.36 2421.2 2700.0 51.72 312.91 2452.7 564.1 3.97 564.1 311.4 595.1 2.75 595.1 311.4 627.2 4.49 627.2 311.4 660.4 2.02 660.5 311.5 694.6 4.03 694.6 311.5 729.9 2.97 729.9 311.5 766.1 3.35 766.2 311.5 803.4 3.38 803.4 311.5 841.5 3.06 841.5 311.5 880.4 2.88 880.4 311.6 373.13 N 393.59 N 415.06 N 437.34 N 460.20 N 483.65 N 507.63 N 532.26 N 557.73 N 584.06 N 423.13 W 446.34 W 470.27 W 494.91 W 520.33 W 546.68 W 573.85 W 601.76 W 630.11 W 658.71 W 2750.0 52.88 312.97 2483.3 2800.0 53.82 312.88 2513.1 2850.0 55.02 312.68 2542.2 2900.0 56.69 312.46 2570.3 2950.0 58.85 312.42 2596.9 919.9 2.31 919.9 311.6 960.0 1.89 960.0 311.7 1000.7 2.42 1000.7 311.7 1042.0 3.35 1042.0 311.8 1084.3 4.33 1084.3 311.8 611.01 N 638.33 N 665.95 N 693.95 N 722.49 N 687.67 W 717.04 W 746.89 W 777.37 W 808.58 W A Gyroda t a D i r e c t i ona I Survey B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: Al197GCE431 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 3000.0 60.56 312.49 2622.1 3050.0 62.09 312.50 2646.1 3100.0 63.78 312.81 2668.9 3150.0 64.63 313.02 2690.6 3200.0 66.11 313.13 2711.5 1127.5 3.41 1127.5 311.8 1171.4 3.07 1171.4 311.8 1215.9 3.41 1215.9 311.9 1260.9 1.75 1260.9 311.9 1306.3 2.97 1306.3 311.9 751.63 N 840.43 W 781.26 N 872.78 W 811.43 N 905.52 W 842.08 N 938.49 W 873.12 N 971.69 W 3250.0 66.27 313.20 2731.7 3300.0 66.62 313.19 2751.6 3350.0 66.84 313.29 2771.4 3400.0 66.82 313.19 2791.1 3450.0 67.22 313.26 2810.6 1352.1 .34 1352.1 312.0 1397.9 .71 1397.9 312.0 1443.8 .47 1443.8 312.1 1489.7 .19 1489.8 312.1 1535.8 .81 1535.8 312.1 904.41 N 935.78 N 967.25 N 998.74 N 1030.27 N 1005.05 W 1038.47 W 1071.93 W 1105.41 W 1138.95 W 3500.0 67.26 313.18 2829.9 3550.0 67.87 313.17 2849.0 3600.0 67.79 313.13 2867.9 3650.0 67.65 313.20 2886.9 3700.0 68.23 313.24 2905.6 3750.0 68.30 313.42 2924.1 3800.0 68.89 313.03 2942.4 3850.0 68.81 312.16 2960.4 3900.0 68.80 311.72 2978.5 3950.0 69.35 311.77 2996.4 1581.8 .17 1581.9 312.2 1628.0 1.22 1628.1 312.2 1674.3 .17 1674.4 312.2 1720.6 .30 1720.7 312.2 1766.9 1.16 1767.0 312.3 1813.3 .36 1813.4 312.3 1859.9 1.38 1860.0 312.3 1906.5 1.62 1906.6 312.3 1953.1 .82 1953.2 312.3 1999.8 1.10 1999.9 312.3 1061.84 N 1093.46 N 1125.13 N 1156.78 N 1188.52 N 1220.39 N 1252.27 N 1283.83 N 1314.99 N 1346.09 N 1172.55 W 1206.26 W 1240.03 W 1273.78 W 1307.55 W 1341.33 W 1375.25 W 1409.58 W 1444.26 W 1479.11 W 4000.0 69.48 311.53 3013.9 4050.0 69.30 310.51 3031.5 4100.0 69.29 310.61 3049.2 4150.0 69.10 310.72 3067.0 4200.0 69.11 310.47 3084.8 2046.6 .52 2046.7 312.3 2093 . 4 1 . 94 2093 . 5 312 . 3 2140.2 .18 2140.3 312.2 2186.9 .42 2187.0 312.2 2233.6 .47 2233.7 312.2 1377.19 N 1407.91 N 1438.32 N 1468.78 N 1499.17 N 1514.08 W 1549.39 W 1584.92 W 1620.38 W 1655.85 W A Gyrodata B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: Al197GCE431 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 4250.0 67.48 309.40 3103.3 4300.0 68.16 309.23 3122.2 4350.0 68.45 309.20 3140.7 4400.0 68.88 309.15 3158.8 4450.0 69.47 309.13 3176.6 4500.0 69.61 308.98 3194.1 4550.0 70.28 309.10 3211.2 4600.0 68.62 309.36 3228.8 4650.0 67.94 309.49 3247.3 4700.0 66.47 309.41 3266.7 4750.0 66.45 309.39 3286.6 4800.0 67.08 309.26 3306.4 4850.0 67.31 309.26 3325.7 4900.0 68.24 309.11 3344.7 4950.0 68.49 309.00 3363.1 5000.0 68.85 308.92 3381.3 5050.0 68.59 308.80 3399.4 5100.0 67.66 308.79 3418.1 5150.0 68.17 308.68 3436.9 5200.0 68.20 308.75 3455.4 5250.0 68.19 308.80 3474.0 5300.0 67.82 308.62 3492.7 5350.0 67.66 308.66 3511.7 5400.0 67.88 308.58 3530.6 5450.0 67.51 308.58 3549.6 2280.1 2326.3 2372.7 2419.3 2465.9 2512.7 2559.7 2606.4 2652.8 2698.9 2744.7 2790.6 2836.6 2882.9 2929.3 2975.8 3022.4 3068.7 3115.0 3161.3 3207.7 3254.0 3300.°2 3346.4 3392.6 Directional DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 3.81 2280.1 312.1 1.39 2326.3 312.1 .59 2372.8 312.0 .87 2419.3 311.9 1.18 2465.9 311.9 .39 2512.7 311.8 1.35 2559.7 311.8 3.35 2606.4 311.7 1.37 2652.8 311.7 2.95 2698.9 311.7 .05 2744.7 311.6 .27 2790.6 311.6 .47 2836.7 311.6 .87 2882.9 311.5 .54 2929.3 311.5 .74 2975.9 311.4 .56 3022.4 311.4 .87 3068.8 311.4 .05 3115.0 311.3 .13 3161.4 311.3 .09 3207.8 311.2 .81 3254.1 311.2 .32 3300.3 311.2 .45 3346.6 311.1 .73 3392.8 311.1 Survey HORIZONTAL COORDINATES feet 1529.00 N 1558.33 N 1587.70 N 1617.12 N 1646.62 N 1676.13 N 1705.72 N 1735.33 N 1764.83 N 1794.12 N 1823.21 N 1852.33 N 1881.50 N 1910.74 N 1940.02 N 1969.31 N 1998.54 N 2027.61 N 2056.60 N 2085.63 N 2114.70 N 2143.70 N 2172.59 N 2201.48 N 2230.33 N 1691.46 W 1727.28 W 1763.28 W 1799.39 W 1835.64 W 1872.01 W 1908.49 W 1944.76 W 1980.64 W 2016.23 W 2051.65 W 2087.19 W 2122.88 W 2158.75 W 2194.84 W 2231.06 W 2267.34 W 2303.50 W 2339.64 W 2375.86 W 2412.06 W 2448.23 W 2484.38 W 2520.53 W 2556.70 W Page A Gyroda t a D i re c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: Al197GCE431 Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 55 55 56 56 57 00 5O 00 5O 00 .0 .0 .0 .0 .0 68.23 308.49 3568.4 68.00 308.47 3587.0 68.03 308.43 3605.8 67.26 309.06 3624.8 66.14 309.72 3644.6 3438.8 1.45 3439.1 311.1 3485.2 .46 3485.4 311.0 3531.4 .09 3531.7 311.0 3577.6 1.94 3577.9 311.0 3623.5 2.53 3623.8 310.9 2259.18 N 2288.06 N 2316.89 N 2345.83 N 2374.97 N 2592.93 W 2629.25 W 2665.56 W 2701.62 W 2737.11 W 57 58 58 59 59 5O 00 5O 00 50 .0 .0 .0 .0 .0 66 · 90 309 · 69 3664 · 5 66.37 309.88 3684.3 65.43 310.41 3704 · 7 64.64 310 · 63 3725.8 63.52 310.68 3747.7 3669.3 1.52 3669.7 310.9 3715.2 1.12 3715.6 310.9 3760.8 2.11 3761.2 310.9 3806.2 1.63 3806.5 310.9 3851.1 2.23 3851.5 310.9 2404.27 N 2433.64 N 2463.06 N 2492.51 N 2521.81 N 2772.39 W 2807.67 W 2842.55 W 2877.01 W 2911.13 W 60 60 61 61 62 62 63 63 64 64 00 5O 00 5O 00 50 00 50 00 50 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 62.22 311.22 3770.5 60.78 312.50 3794.3 60.86 312.67 3818.7 60.77 313.44 3843.1 60.47 314.40 3867.6 60.75 315.07 3892.2 61.78 315.69 3916.2 63.61 316.43 3939.1 65.27 316.96 3960.7 66.56 317.25 3981.1 3895.6 2.77 3896.0 310.9 3939.5 3.66 3940.0 310.9 3983.2 .35 3983.6 310.9 4026.8 1.35 4027.2 311.0 4070.4 1.79 4070.7 311.0 4113.9 1.29 4114.2 311.0 4157.6 2.33 4157.9 311.1 4201.9 3.89 4202.2 311.1 4246.9 3.46 4247.1 311.2 4292.3 2.63 4292.5 311.2 2550.97 N 2580.29 N 2609.83 N 2639.63 N 2669.86 N 2700.52 N 2731.72 N 2763.71 N 2796.54 N 2829.98 N 2944.74 W 2977.47 W 3009.61 W 3041.51 W 3072.89 W 3103.83 W 3134.63 W 3165.45 W 3196.39 W 3227.46 W 65 65 66 66 67 00.0 50.0 00.0 50.0 00.0 67.37 317.68 4000.7 66.90 318.02 4020.1 67.38 318.21 4039.5 67.64 318.10 4058.7 67.92 317.60 4077.6 4338.1 1.80 4338.2 311.3 4383.9 1.13 4384.0 311.4 4429.7 1.02 4429.7 311.4 4475.6 .57 4475.6 311.5 4521.6 1.08 4521.6 311.6 2863.88 N 2898.04 N 2932.34 N 2966.75 N 3001.07 N 3258.57 W 3289.49 W 3320.25 W 3351.07 W 3382.13 W A Gyr oda t a D i r e c t i on a i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: Al197GCE431 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 6750.0 68.66 317.46 4096.1 6800.0 68.55 317.40 4114.3 6850.0 69.10 316.84 4132.4 6900.0 69.25 316.48 4150.1 6950.0 69.11 316.52 4167.9 4567.8 1.50 4567.8 311.6 4614.2 .25 4614.2 311.7 4660.6 1.53 4660.6 311.8 4707.1 .74 4707.1 311.8 4753.7 .30 4753.7 311.9 3035.33 N 3069.62 N 3103.78 N 3137.77 N 3171.67 N 3413.50 W 3444.99 W 3476.72 W 3508.80 W 3540.97 W 7000.0 69.24 316.40 4185.7 7050.0 68.32 315.70 4203.8 7100.0 68.72 315.42 4222.1 7150.0 68.07 314.82 4240.5 7200.0 68.43 314.79 4259.0 4800.3 .34 4800.3 311.9 4846.8 2.25 4846.8 311.9 4893.2 .96 4893.2 312.0 4939.6 1.71 4939.7 312.0 4986.0 .72 4986.0 312.0 3205.55 N 3239.10 N 3272.32 N 3305.26 N 3337.98 N 3573.16 W 3605.51 W 3638.08 W 3670.89 W 3703.84 W 7250.0 68.31 314.85 4277.5 7300.0 67.95 314.92 4296.1 7350.0 68.41 314.70 4314.7 7400.0 66.72 314.00 4333.7 7450 . 0 67 . 92 313 . 85 4353 . 0 7500.0 67.81 313.55 4371.9 7550.0 66.66 312.99 4391.2 7600.0 66.35 312.87 4411.1 7650.0 66.65 312.99 4431.1 7700.0 67.58 313.02 4450.5 5032.4 .26 5032.5 312.1 5078.7 .74 5078.8 312.1 5125.1 1.00 5125.2 312.1 5171.2 3.61 5171.3 312.1 5217.3 2.41 5217.5 312.1 5263.6 .59 5263.8 312.2 5309.7 2.53 5309.9 312.2 5355.5 .65 5355.7 312.2 5401.4 .64 5401.6 312.2 5447.4 1.86 5447.6 312.2 3370.75 N 3403.49 N 3436.20 N 3468.51 N 3500.51 N 3532.51 N 3564.12 N 3595.35 N 3626.58 N 3658.00 N 3736.81 W 3769.68 W 3802.61 W 3835.66 W 3868.89 W 3902.37 W 3935.94 W 3969.51 W 4003.09 W 4036.78 W 7750.0 66.80 312.99 4469.9 7800.0 66.83 313.28 4489.6 7850.0 67.08 313.54 4509.2 7900.0 66.06 313.41 4529.0 7950.0 66.34 313.46 4549.2 5493.5 1.56 5493.7 312.2 5539.5 .53 5539.7 312.2 5585.5 .68 5585.7 312.2 5631.3 2.05 5631.5 312.2 5677.0 .56 5677.3 312.2 3689.43 N 3720.86 N 3752.48 N 3784.04 N 3815.50 N 4070.48 W 4104.02 W 4137.44 W 4170.74 W 4203.95 W A Gyrodata B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: Al197GCE431 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 8000.0 66.59 313.62 4569.2 8050.0 67.33 313.61 4588.7 8100.0 67.64 313.64 4607.9 8150.0 67.08 313.27 4627.1 8200.0 67.15 313.08 4646.6 8250.0 66.94 312.93 4666.1 8300.0 67.51 312.81 4685.4 8350.0 67.27 312.75 4704.7 8400.0 66.92 312.57 4724.1 8450.0 66.85 312.38 4743.8 8500.0 66.19 312.22 4763.7 8550.0 67.04 312.53 4783.5 8600.0 67.16 313.00 4803.0 8650.0 67.22 313.71 4822.4 8700.0 68.13 314.03 4841.4 8750.0 67.56 314.24 4860.2 8800.0 68.27 314.87 4879.0 8850.0 68.06 315.72 4897.6 8900.0 67.36 315.86 4916.6 8950.0 67.62 315.63 4935.7 9000.0 67.07 315.38 4955.0 9050.0 67.41 315.14 4974.3 9100.0 66.64 315.05 4993.8 9150.0 68.56 314.97 5012.9 9200.0 70.07 314.95 5030.5 5722.9 5768.8 5815.0 5861.1 5907.2 5953.2 5999.3 6045.5 6091.5 6137.5 6183.3 6229.2 6275.3 6321.4 6367.6 6413.8 6460.1 6506.4 6552.6 6598.7 6644.7 6690.7 6736.7 6782.8 6829.5 Directional DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. .58 5723.1 312.2 1.48 5769.1 312.2 .62 5815.3 312.3 1.29 5861.4 312.3 .38 5907.5 312.3 .49 5953.5 312.3 1 . 15 5999 . 6 312 . 3 .49 6045.7 312.3 .78 6091.8 312.3 .38 6137.8 312.3 1.34 6183.6 312.3 1.78 6229.5 312.3 .90 6275.6 312.3 1.32 6321.7 312.3 1.92 6367.9 312.3 1.20 6414.2 312.3 1.84 6460.5 312.3 1.63 6506.8 312.4 1.42 6553.0 312.4 .66 6599.1 312.4 1.19 6645.2 312.4 .79 6691.3 312.5 1.54 6737.3 312.5 3.83 6783.4 312.5 3.03 6830.2 312.5 Survey HORIZONTAL COORDINATES feet 3847.07 N 3878.81 N 3910.68 N 3942.42 N 3973.94 N 4005.34 N 4036.70 N 4068.05 N 4099.26 N 4130.31 N 4161.18 N 4192.11 N 4223.38 N 4255.02 N 4287.08 N 4319.32 N 4351.83 N 4384.82 N 4417.99 N 4451.07 N 4483.98 N 4516.73 N 4549.34 N 4582.03 N 4615.09 N 4237.19 W 4270.50 W 4303.94 W 4337.43 W 4371.03 W 4404.70 W 4438.49 W 4472.36 W 4506.23 W 4540.15 W 4574.07 W 4607.97 W 4641.78 W 4675.30 W 4708.64 W 4741.87 W 4774.89 W 4807.54 W 4839.79 W 4872.03 W 4904.37 W 4936.82 W 4969.31 W 5001.99 W 5035.09 W Page B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: Al197GCE431 A G y r o d a t a Directional Survey Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 9250.0 69.88 314.68 5047.7 9300 . 0 72 . 22 314 . 68 5063 . 9 9350.0 72.55 314.52 5079.0 9400 . 0 72 . 40 314 . 26 5094 . 1 9450.0 71.83 314.10 5109.4 6876.4 6923.7 6971.3 7018.9 7066.4 .63 6877.1 312.5 4.68 6924.4 312.5 .73 6972.0 312.6 .59 7019.6 312.6 1.17 7067.2 312.6 4648.20 N 4681.45 N 4714.91 N 4748.26 N 4781.42 N 5068.42 W 5102.04 W 5135.97 W 5170.05 W 5204.17 W 9500.0 71.14 313.49 5125.3 9550.0 71.45 312.63 5141.3 9600.0 71.10 311.61 5157.4 9650.0 71.07 310.80 5173.6 9700.0 70.91 310.39 5189.9 7113.8 7161.2 7208.5 7255.8 7303.1 1.80 7114.6 312.6 1.74 7162.0 312.6 2.07 7209.3 312.6 1.53 7256.6 312.6 .85 7303.8 312.6 4814.23 N 4846.57 N 4878.33 N 4909.49 N 4940.25 N 5238.40 W 5273.00 W 5308.12 W 5343.70 W 5379.60 W 9750.0 70.36 310.06 5206.5 9800.0 70.73 310.07 5223.1 9850.0 69.73 309.87 5240.0 9900.0 69.83 309.78 5257.3 9950.0 69.60 309.74 5274.7 10000.0 68.77 309.59 5292.4 10050.0 69.25 309.40 5310.3 10100.0 68.77 309.18 5328.3 10150.0 68.63 308.92 5346.4 10200.0 68.21 308.81 5364.8 7350.2 7397.4 7444.4 7491.3 7538.1 7584.9 7631.5 7678.1 7724.7 7771.1 1 . 25 7351 . 0 312 . 5 . 73 7398 . 1 312 . 5 2.04 7445.1 312.5 .26 7491.9 312.5 .47 7538.8 312.5 , 68 7585.5 312.5 04 7632.1 312.4 05 7678.7 312.4 56 7725.2 312.4 86 7771.6 312.4 4970.71 N 5001.05 N 5031.28 N 5061.33 N 5091.32 N 5121.15 N 5150.84 N 5180.40 N 5209.75 N 5238.92 N 5415.62 W 5451.70 W 5487.76 W 5523.79 W 5559.85 W 5595.82 W 5631.85 W 5667.98 W 5704.15 W 5740.36 W 10250.0 67.28 308.44 5383.7 10300.0 66.72 308.23 5403.3 10350.0 65.78 307.86 5423.4 10400.0 65.55 307.77 5444.0 10450.0 65.87 308.27 5464.6 7817.3 7863.3 7908.9 7954.4 7999.9 , 97 7817.8 312.4 20 7863.7 312.3 00 7909.3 312.3 48 7954.8 312.3 10 8000.2 312.3 5267.81 N 5296.36 N 5324.56 N 5352.49 N 5380.56 N 5776.51 W 5812.61 W 5848.65 W 5884.64 W 5920.55 W A Gyr oda t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: Al197GCE431 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 10500.0 66.18 308.79 5484.9 10550.0 66.16 308.94 5505.1 10600.0 66.21 309.41 5525.3 10650.0 67.15 309.80 5545.1 10700.0 66.99 309.92 5564.6 8045.5 1.14 8045.8 312.2 8091.2 .28 8091.5 312.2 8136.9 .86 8137.1 312.2 8182.7 2.03 8183.0 312.2 8228.8 .39 8229.0 312.2 5409.02 N 5437.72 N 5466.61 N 5495.88 N 5525.40 N 5956.29 W 5991.90 W 6027.36 W 6062.74 W 6098.09 W 10750.0 68.56 310.51 5583.5 10800.0 69.01 310.51 5601.6 10850.0 68.36 310.59 5619.7 10900.0 68.51 310.51 5638.1 10950.0 67.68 310.29 5656.8 8275.0 3.32 8275.3 312.2 8321.6 .89 8321.9 312.2 8368.2 1.31 8368.4 312.2 8414.7 .33 8414.9 312.1 8461.1 1.71 8461.3 312.1 5555.28 N 5585.56 N 5615.84 N 5646.07 N 5676.13 N 6133.43 W 6168.87 W 6204.27 W 6239.60 W 6274.92 W 11000.0 67.52 309.91 5675.8 11050.0 67.36 309.69 5695.0 11100.0 66.64 309.47 5714.5 11150.0 66.60 309.43 5734.4 11200.0 65.83 309.61 5754.6 11250.0 66.17 309.80 5774.9 11300.0 66.02 310.66 5795.2 11350.0 65.61 310.79 5815.6 11400.0 65.67 310.60 5836.3 11450.0 65.40 310.49 5857.0 8507.3 .76 8507.5 312.1 8553.4 .53 8553.6 312.1 8599.4 1.49 8599.6 312.1 8645.3 .11 8645.4 312.1 8691.0 1.57 8691.1 312.1 8736.6 .77 8736.8 312.1 8782.3 1.61 8782.5 312.0 8827.9 .84 8828.1 312.0 8873.5 .37 8873.6 312.0 8919 . 0 . 58 8919 . 1 312 . 0 5705.91 N 5735.47 N 5764.79 N 5793.95 N 5823.07 N 5852.25 N 5881.77 N 5911.53 N 5941.23 N 5970.81 N 6310.28 W 6345.76 W 6381.23 W 6416.67 W 6451.96 W 6487.10 W 6522.00 W 6556.57 W 6591.10 W 6625.69 W 11500.0 65.87 310.53 5877.6 11550.0 67.23 310.38 5897.5 11600.0 66.60 310.12 5917.1 11650.0 66.83 310.05 5936.9 11700.0 66.08 309.76 5956.8 8964.5 .95 8964.6 312.0 9010.4 2.73 9010.5 312.0 9056.4 1.34 9056.5 312.0 9102.3 .47 9102.4 312.0 9148.1 1.59 9148.2 312.0 6000.40 N 6030.16 N 6059.88 N 6089.45 N 6118.85 N 6660.31 W 6695.22 W 6730.32 W 6765.46 W 6800.62 W A Gyroda t a D i re c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: Al197GCE431 Page 10 MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 11750.0 11800.0 11850.0 11900.0 11950.0 66.22 309.73 5977.1 65.52 309.58 5997.5 64.39 309.45 6018.7 65.55 309.59 6039.8 66.54 309.84 6060.1 9193.8 .29 9193.9 312.0 9239.4 1.44 9239.4 312.0 9284.6 2.26 9284.7 311.9 9329.9 2.34 9330.0 311.9 9375.6 2.03 9375.6 311.9 6148.09 N 6177.21 N 6206.03 N 6234.86 N 6264.06 N 6835.79 W 6870.92 W 6905.86 W 6940.81 W 6975.96 W 12000.0 12050.0 12100.0 12150.0 12200.0 66.89 310.02 6079.9 66.68 309.56 6099.6 67.02 309.40 6119.3 66.28 308.98 6139.1 65.44 308.66 6159.5 9421.5 .77 9421.5 311.9 9467.4 .94 9467.4 311.9 9513 . 3 . 74 9513 . 4 311 . 9 9559.2 1.66 9559.2 311.9 9604 . 8 1 . 78 9604 . 8 311 . 9 6293.54 N 6322.94 N 6352.17 N 6381.18 N 6409.78 N 7011.18 W 7046.48 W 7081.97 W 7117.55 W 7153.10 W 12250.0 12300.0 12350.0 12400.0 12450.0 12500.0 12550.0 12600.0 12650.0 12700.0 66.93 308.71 6179.7 66.71 308.89 6199.4 66.68 308.68 6219.2 68.23 308.32 6238.3 68.57 308.17 6256.7 68.96 308.08 6274.9 68.48 307.93 6293.0 68.76 307.87 6311.2 68.63 308.43 6329.4 67.74 307.55 6348.0 9650.4 2.99 9650.5 311.8 9696.4 .56 9696.4 311.8 9742.2 .39 9742.2 311.8 9788.3 3.19 9788.3 311.8 9834.7 .72 9834.7 311.8 9881.2 .80 9881.2 311.8 9927.7 1.00 9927.7 311.8 9974.2 .58 9974.2 311.7 10020.7 1.08 10020.7 311.7 10067.0 2.43 10067.0 311.7 6438.37 N 6467.17 N 6495.94 N 6524.68 N 6553.46 N 6582.24 N 6610.93 N 6639.53 N 6668.30 N 6696.88 N 7188.80 W 7224.62 W 7260.42 W 7296.56 W 7333.07 W 7369.73 W 7406.44 W 7443.18 W 7479.81 W 7516.39 W 12750.0 12800.0 12850.0 12900.0 12935.0 67.72 308.12 6366.9 65.93 307.59 6386.6 62.81 307.15 6408.2 62.41 306.38 6431.2 64.30 305.47 6446.9 10113.2 1.06 10113.2 311.7 10159.0 3.70 10159.0 311.7 10204.0 6.29 10204.0 311.6 10248.2 1.59 10248.2 311.6 10279.3 5.87 10279.3 311.6 6725.26 N 6753.46 N 6780.82 N 6807.40 N 6825.75 N 7552.94 W 7589.23 W 7625.05 W 7660.61 W 7685.94 W A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: Al197GCE431 MEASURED I N C L AZIMUTH VERTICAL VERTICAL DOGLEG CLOSURE DEPTH DEPTH SECTION SEVERITY DIST. AZIMUTH feet deg. deg. feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet Final Station Closure: Distance: 10279.33 ft Az: 311.61 deg. Page 11 A Gyroda t a Di re c t i ona I Survey for B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: SUB431 Run Date: 26-Nov-97 22:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 44.55 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 311.730 deg Vertical Section Calculated from Well' Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: SUB431 SUBSEA I N C L AZIMUTH DEPTH feet deg. deg. -44.6 0.00 0.00 100.0 .39 336.06 200.0 .56 2.26 300.0 .98 340.71 400.0 1.63 319.01 500.0 2.19 312.06 600.0 3.63 313.22 700.0 6.31 315.61 800.0 9.45 312.35 900.0 13.14 306.55 1000.0 15.20 304.55 1100.0 15.91 305.15 1200.0 17.97 308.74 1300.0 21.02 311.83 1400.0 20.26 312.16 1500.0 21.64 312.51 1600.0 25.08 313.78 1700.0 25.76 313.93 1800.0 25.69 313.04 1900.0 28.91 311.64 2000.0 33.61 311.24 2100.0 37.92 311.30 2200.0 42.01 312.12 2300.0 46.75 311.38 2400.0 51.37 312.77 A Gy r o d a t a VERTICAL VERTICAL DEPTH SECTION feet feet 0.0 0.0 144.6 .5 244.6 1.1 344.6 2.2 444.6 4.4 544.6 7.7 644.6 12.7 744.6 21.4 844.6 35.2 944.6 55.1 1044.6 80.2 1144.6 107.8 1244.6 137.9 1344.6 173.6 1444.6 211.5 1544.6 249.2 1644.6 292.4 1744.6 340.6 1844.6 388.6 1944.6 439.8 2044.6 500.3 2144.6 572.3 2244.6 656.4 2344.6 754.6 2444.6 870.3 Directional DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 0.00 0.0 0.0 .37 .9 320.2 .35 1.8 339.3 .52 3.5 344.4 .78 6.3 336.1 .59 10.0 327.1 1.45 16.5 321.7 2.67 27.8 319.0 3.19 44.3 316.9 3.78 66.9 314.0 .47 93.0 311.1 .67 120.3 309.5 2.90 150.8 308.9 2.33 186.0 309.3 1.08 221.0 309.8 2.39 256.7 310.1 3.09 297.2 310.6 .75 340.7 311.1 .55 405.8 311.3 3.66 452.9 311.4 4.09 505.8 311.4 3.65 595.1 311.4 2.32 660.5 311.5 3.23 766.2 311.5 2.92 880.4 311.5 Survey Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E .45 N .30 W 1.22 N .40 W 2.46 N .73 W 4.27 N 2.03 W 6.60 N 4.40 W 10.08 N 8.09 W 16.23 N 14.24 W 25.69 N 24.27 W 38.12 N 39.88 W 52.64 N 60.46 W 68.61 N 83.28 W 86.70 N 107.39 W 110.03 N 134.49 W 135.38 N 162.64 W 160.75 N 190.55 W 190.29 N 222.08 W 223.73 N 256.82 W 256.63 N 291.81 W 291.06 N 329.68 W 331.12 N 375.11 W 378.52 N 429.25 W 434.60 N 491.88 W 500.01 N 565.21 W 577.25 N 651.30 W B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: SUB431 SUBSEA I N C L AZIMUTH DEPTH feet deg. deg. 2500.0 55.16 312.66 2600.0 61.99 312.50 2700.0 66.50 313.19 2800.0 67.72 313.17 2900.0 68.88 312.92 3000.0 69.29 310.58 3100.0 68.54 309.19 3200.0 68.04 309.47 3300.0 68.23 309.11 3400.0 68.19 308.71 3500.0 67.61 308.58 3600.0 66.14 309.72 3700.0 63.68 310.68 3800.0 60.75 313.50 3900.0 64.03 316.56 4000.0 67.45 318.18 4100.0 69.20 316.59 4200.0 68.15 314.81 4300.0 67.39 313.91 4400.0 67.30 313.01 4500.0 66.27 313.45 4600.0 67.14 313.10 4700.0 66.82 312.38 4800.0 68.03 314.07 4900.0 67.37 315.52 A Gy r o d a t a D i VERTICAL VERTICAL DEPTH SECTION feet feet r e c t DOGLEG SEVERITY deg. / 100 ft. 2544.6 1004.1 2.50 2644.6 1168.5 3.09 2744.6 1381.6 .58 2844.6 1617.2 .97 2944.6 1865.5 1.41 3044.6 2127.8 .64 3144.6 2382.7 .65 3244.6 2645.9 1.67 3344.6 2882.6 1.86 3444.6 3134.2 .67 3544.6 3380.4 .66 3644.6 3623.5 2.53 3744.6 3844.7 2.15 3844.6 4029.4 1.38 3944.6 4213.2 3.78 4044.6 4441.7 .90 4144 . 6 4692 . 5 . 99 4244 . 6 4949 . 7 1.50 4344.6 5197.1 2.94 4444.6 5433.3 1.49 4544.6 5666.5 .91 4644.6 5902.4 .47 4744.6 6139.3 .41 4844.6 6375.4 1.80 4944.6 6619.8 .91 i o n a 1 CLOSURE DIST. AZIMUTH feet deg. 1042.0 311.7 1171.4 311.8 1397.9 312.0 1628.1 312.2 1906.6 312.3 2140.3 312.2 2419.3 312.0 2652.8 311.7 2882.9 311.5 3161.4 311.3 3392.8 311.1 3623.8 310.9 3851.5 310.9 4070.7 311.0 4247.1 311.1 4475.6 311.5 4707.1 311.8 4986.0 312.0 5217.5 312.1 5447.6 312.2 5677.3 312.2 5907.5 312.3 6183.6 312.3 6414.2 312.3 6645.2 312.4 Survey Page HORIZONTAL COORDINATES feet 668.30 N 779.31 N 924.64 N 1086.05 N 1256.06 N 1430.29 N 1594.00 N 1760.44 N 1910.57 N 2068.62 N 2222.70 N 2374.97 N 2517.61 N 2641.43 N 2771.95 N 2941.38 N 3127.11 N 3312.42 N 3486.44 N 3648.35 N 3808.22 N 3970.64 N 4131.55 N 4292.53 N 4466.18 N 749.45 W 870.65 W 1026.60 W 1198.36 W 1379.37 W 1575.54 W 1771.01 W 1975.30 W 2158.55 W 2354.64 W 2547.13 W 2737.11 W 2906.24 W 3043.37 W 3173.22 W 3328.34 W 3498.73 W 3678.10 W 3854.28 W 4026.43 W 4196.27 W 4367.51 W 4541.50 W 4714.26 W 4886.88 W B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: SUB431 SUBSEA I N C L AZIMUTH DEPTH feet deg. deg. 5000.0 69.92 314.73 5100.0 71.38 312.43 5200.0 69.7'5 309.84 5300.0 68.64 308.95 5400.0 65.56 307.78 5500.0 67.13 309.79 5600.0 68.22 310.43 5700.0 66.21 309.52 5800.0 65.56 310.56 5900.0 66.54 309.94 6000.0 65.78 309.65 6100.0 66.06 308.89 6200.0 68.35 308.27 6300.0 67.90 307.71 6400.0 64.01 305.61 6402.4 64.30 305.47 A Gy r o d a t a VERTICAL VERTICAL DEPTH SECTION feet feet D i r e c DOGLEG SEVERITY deg./ 100 ft. 5044.6 6867.9 1.07 5144.6 7170.6 1.80 5244.6 7456.6 1.58 5344.6 7719.9 .61 5444.6 7955.6 .49 5544.6 8181.5 1.99 5644.6 8430.7 .81 5744.6 8668.3 .84 5844.6 8891.7 .45 5944.6 9119.9 .90 6044.6 9340.5 2.27 6144.6 9571.4 1.69 6244.6 9804.0 2.36 6344.6 10058.4 2.18 6444.6 10274.6 5.22 6446.9 10279.3 5.87 t i o n a 1 Survey Page CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 6877.1 312.5 7209.3 312.6 7491.9 312.5 7725.2 312.4 8000.2 312.3 8183.0 312.2 8461.3 312.1 8691.1 312.1 8919.1 312.0 9148.2 312.0 9375.6 311.9 9604.8 311.9 9834.7 311~8 10067.0 311.7 10279.3 311.6 10279.3 311.6 4642.18 N 4852.90 N 5039.12 N 5206.74 N 5353.23 N 5495.10 N 5656.44 N 5808.62 N 5953.07 N 6100.76 N 6241.66 N 6388.83 N 6534.39 N 6691.60 N 6822.97 N 6825.75 N 5062.36 W 5280.00 W 5497.16 W 5700.44 W 5885.58 W 6061.80 W 6251.78 W 6434.45 W 6604.95 W 6778.99 W 6949.00 W 7127.07 W 7308.87 W 7509.64 W 7682.11 W 7685.94 W Final Station Closure: Distance: 10279.33 ft Az: 311.61 deg. 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: A1197GCE431 TOOL NUMBER: 777 MAXIMUM GYRO TEMPERATURE: 76.1 C MAXIMUM AMBIENT TEMPERATURE: 64.89 C MAXIMUM INCLINATION: 72.6 AVERAGE AZIMUTH: 311.61 WIRELINE REZERO VALUE: N/A REZERO ERROR / K: N/A CALIBRATION USED FOR FIELD SURVEY: 2040 CALIBRATION USED FOR FINAL SURVEY: 2040 PRE JOB MASS BALANCE OFFSET CHECK: .35 POST JOB MASS BALANCE OFFSET CHECK]: USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES .28 UPON ARRIVAL AT RIG: 1 OFF UPON COMPLETION OF SURVEY: I OFF UPON RETURN TO ATLAS 1 OFF BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING MWD 12865 62.41 305.1 6416 6741 -7685 FINAL SURVEY 12900 62.41 306.38 6431 6807 -7660 FUNCTION TEST JOB NUMBER: A1197GCE431 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 999 15.00 15.00 15.00 15.00 15.00 AZIMUTH M.D. ft 1 2 3 4 5 999 304.32 304.51 304.38 304.46 304.58 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: A1197GCE431 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 777 GYRO SECTION DATA SECTION POWER SECTION BACKUP TOOL No. 742 GYRO SECTION DATA SECTION POWER SECTION A0169 C0111 C0112 A0124 C0089 C0086 COMPUTER A0433 POWER SUPPLY PRINTER A0079 INTERFACE A0143 COMPUTER A0349 POWER SUPPLY PRINTER A0029 INTERFACE A0055 A0085 A0107 WIRELINE COMPANY: CABLE SIZE: 5/16" ATLAS RUNNING GEAR 2.25" HOUSING W/ATLAS ROLLERS AND ECCENTRIC BAR TOTAL LENGTH OF TOOL :27' MAXIMUM O.D.: 2.25 INCHES TOTAL WEIGHT OF TOOL: 200 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: A1197GCE431 TUESDAY, 11/25/97 16:40 TO SLOPE 19:00 CHECK TOOLS, STANDBY WEDNESDAY, 11/26/97 16:00 18:00 18:30 21:30 22:00 23:00 TO LOCATION ARRIVE LOCATION MU TOOL, RU ATLAS PU GYRO. START INRUN SURVEY WO NABORS TO PUMP TOOL THURSDAY, 11/27/97 00:00 01:30 04:30 05:00 06:30 13:00 '16:00 19:00 PUMP TOOL SURVEY INRUN TO 12934' OUTRUN CONTINUOUS TO 1000' LD TOOL RETURN TO ATLAS CHECK TOOL, PROCESS SURVEY RETURN TO RIG W/RESULTS STANDBY FOR NEXT JOB FRIDAY, 11/28/97 13:00 JOB ON POOL 7 NOT UNTIL NEXT WEEK 16:15 RETURN TO ANCHORAGE B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Gyro Continuous Multishot Survey Inside 5" DRILL PIPE Survey date: 14 -October, 1997 Job number :A1097GCE422 CONTENTS JOB NUMBER :A1097GCE422 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION, SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER' A1097GCE422 Tool 777 was run in WELL# MPF-79 on SCHLUMBERGER 15/32" wireline inside DRILL PIPE. The survey was run without problems. SURVEY CERTIFICATION SHEET JOB NUMBER: A1097GCE422 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true. and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: A1097GCE422 CLIENT: B.P. EXPLORATION RIG: SCHLUMBERGER LOCATION: F PAD, ALASKA WELL: MPF-79 LATITUDE: 70.507 N LONGITUDE: 149.5 W SURVEY DATE: SURVEY TYPE : 14 OCTOBER, 1997 GYRO CONTINOUS MULTISHOT IN 5" DRILL PIPE DEPTH REFERENCE: 44.55' MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 7000' SURVEY TIED ONTO: NA SURVEY INTERVAL: 0-7000' APl NUMBER: 050-029-22813 TARGET DIRECTION: 311.73 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. OUTRUN SURVEY LISTING A Gyroda t a Di r ec t i ona i Sur~vey Job Number: A1097GCE422 Run Date: 14-0ct-97 09:30:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.507000 deg. N for B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 311.730 deg Vertical Section Calculated from well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyrodata B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: A1097GCE422 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 0.0 0.00 0.00 0.0 100.0 .50 292.62 100.0 201.0 .33 326.89 201.0 300.0 .59 335.93 300.0 401.0 1.28 328.35 401.0 500.0 1.80 318.15 499.9 601.0 2.32 315.14 600.9 700.0 4.89 317.51 699.7 800.0 7.72 316.70 799.1 900.0 11.23 309.88 897.7 1000.0 14.91 304.50 995.1 1050.0 15.18 304.29 1043.4 1100.0 15.53 304.08 1091.6 1150.0 15.74 304.08 1139.7 1200.0 16.20 305.20 1187.8 1250.0 17.43 307.50 1235.7 1300.0 19.07 309.76 1283.1 1350.0 20.93 310.94 1330.1 1400.0 21.11 311.14 1376.8 1450.0 20.40 311.31 1423.6 1500.0 20.33 311.31 1470.4 1550.0 20.49 311.48 1517.3 1600.0 22.15 311.86 1563.9 1650.0 23.69 312.46 1609.9 1700.0 25.37 312.88 1655.4 Directional DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 0.0 0.00 0.0 0.0 .4 .50 .4 292.6 1.1 .29 1.1 301.0 1 . 8 . 28 1.8 314 . 0 3.4 .69 3.5 321.9 6.0 9.6 15.8 26.8 43.2 65.7 78.6 91.7 105.1 118.7 133.1 148.7 165.8 183.8 201.5 218.9 236.3 254.5 274.0 294.7 .60 6.1 322.1 .52 9.7 320.0 2.60 15.9 318.7 2.83 26.9 318.0 3.67 43.3 316.0 3.88 65.7 312.9 .55 78.6 311.5 .71 91.7 310.4 .42 105.1 309.6 1.10 118.8 309.0 2.80 133.3 308.7 3.56 148.9 308.7 3.81 166.0 308.9 .39 184.0 309.1 1.42 201.7 309.3 .15 219.1 309.5 .36 236.5 309.6 3.33 254.7 309.7 3.10 274.1 309.9 3.38 294.8 310.1 Survey HORIZONTAL COORDINATES feet 0.00 N 0.00 E .17 N .40 W .58 N .96 W 1.28 N 1.33 W 2.72 N 2.13 W 4.82 N 3.75 W 7.45 N 6.25 W 11.98 N 10.52 W 20.02 N 18.01 W 31.16 N 30.09 W 44.69 N 48.17 W 52.02 N 58.88 W 59.46 N 69.83 W 67.01 N 81.00 W 74.84 N 92.31 W 83.42 N 103.96 W 93.20 N 116.18 W 104.28 N 129.21 W 116.05 N 142.74 W 127.73 N 156.06 W 139.22 N 169.13 W 150.75 N 182.21 W 162.84 N 195.79 W 175.91 N 210.22 W 189.98 N 225.48 W Page A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: A1097GCE422 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 1750.0 25.97 313.00 1700.5 1800.0 25.69 313.12 1745.5 1850.0 25.69 313.10 1790.5 1900.0 25.45 312.82 1835.6 1950.0 26.16 312.58 1880.6 316.4 1.21 316.5 310.3 338.2 .57 338.2 310.5 359.8 .01 359.9 310.6 381.4 .54 381.5 310.8 403.2 1.43 403.2 310.9 204.74 N 241.34 W 219.61 N 257.26 W 234.43 N 273.08 W 249.14 N 288.88 W 263.90 N 304.87 W 2000.0 27.81 312.08 1925.2 2050.0 29.70 311.67 1969.0 2100.0 31.86 311.58 2012.0 2150.0 33.85 311.49 2054.0 2200.0 35.64 311.43 2095.1 425.9 3.33 425.9 311.0 449.9 3.80 450.0 311.0 475.5 4.31 475.5 311.0 502.6 3.99 502.7 311.1 531.1 3.59 531.2 311.1 279.17 N 321.65 W 295.23 N 339.56 W 312.22 N 358.68 W 330.20 N 378.98 W 349.07 N 400.34 W 2250.0 37.53 311.48 2135.2 2300.0 38.82 311.74 2174.5 2350.0 41.03 312.12 2212.9 2400.0 42.05 312.08 2250.3 2450.0 44.29 311.76 2286.7 560.9 3.76 561.0 311.1 591.8 2.61 591.9 311.1 623.9 4.44 623.9 311.2 657.1 2.03 657.1 311.2 691.3 4.50 691.3 311.3 368.80 N 422.68 W 389.32 N 445.78 W 410.76 N 469.65 W 432.99 N 494.25 W 455.84 N 519.70 W 2500.0 45.46 311.57 2322.2 2550.0 47.29 311.31 2356.7 2600.0 48.83 311.55 2390.1 2650.0 50.17 312.47 2422.6 2700.0 51.81 312.92 2454.0 726.5 2.36 726.6 311.3 762.7 3.68 762.8 311.3 799.9 3.10 800.0 311.3 837.9 3.03 838.0 311.3 876.8 3.35 876.8 311.4 479.29 N 546.06 W 503.24 N 573.19 W 527.85 N 601.07 W 553.30 N 629.32 W 579.65 N 657.87 W 2750.0 52.74 313.02 2484.6 2800.0 54.03 312.93 2514.4 2850.0 54.92 312.80 2543.5 2900.0 56.60 312.51 2571.6 2950.0 59.02 312.56 2598.3 916.3 1.87 916.3 311.5 956.5 2.57 956.5 311.5 997.1 1.80 997.1 311.6 1038.5 3.40 1038.5 311.6 1080.8 4.84 1080.8 311.7 606.61 N 686.81 W 633.96 N 716.18 W 661.65 N 746.00 W 689.65 N 776.40 W 718.26 N 807.57 W B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA JOb Number: A1097GCE422 A Gy r o da t a Directional Survey Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH de~. / feet deg. 100 ft. HORIZONTAL COORDINATES feet 3000.0 60.43 312.52 2623.5 3050.0 62.09 312.56 2647.5 3100.0 63.76 312.85 2670.3 3150.0 64.93 313.10 2691.9 3200.0 66.06 313.23 2712.7 1124 1167 1212 1257 1302 .0 .8 .3 .4 .8 2 . 82 1124 . 0 311 . 7 3.31 1167.8 311.7 3.39 1212.3 311.8 2.37 1257.4 311.8 2 . 27 1302 . 8 311 . 8 747.46 N 839.39 W 777.10 N 871.69 W 807.29 N 904.41 W 838.02 N 937.38 W 869.14 N 970.56 W 3250.0 66.47 313.36 2732.8 3300.0 66.53 313.44 2752.7 3350 . 0 67.10 313.47 2772.4 3400.0 67.21 313.41 2791.8 3450.0 67.15 313.46 2811.2 1348 1394 1440 1486 1532 .6 .4 .4 .4 .5 · 87 1348 . 6 311 . 9 · 18 1394 . 4 311 . 9 1 . 14 1440 . 4 312 . 0 · 25 1486 . 4 312 . 0 .17 1532.5 312.1 900.53 N 1003.87 W 932.04 N 1037.19 W 963.65 N 1070.55 W 995.33 N 1104.01 W 1027.01 N 1137.48 W 3500.0 67.48 313.43 2830.5 3550.0 67.97 313.41 2849.4 3600.0 67.86 313.33 2868.2 3650.0 67.97 313.43 2887.0 3700.0 68.23 313.46 2905.7 3750.0 68.29 313.52 2924.2 3800.0 68.92 313.23 2942.5 3850.0 68.97 312.34 2960.4 3900.0 68.97 311.99 2978.4 3950.0 69.55 311.94 2996.1 1578 1624 1671 1717 1763 1810 1856 1903 1950 1996 .6 .8 .2 .5 .8 .3 .8 .5 .1 .9 68 1578.6 312.1 97 1624.9 312.2 27 1671.2 312.2 29 1717.5 312.2 52 1763.9 312.3 16 1810.4 312.3 36 1856.9 312.3 67 1903.6 312.3 64 1950.2 312.3 17 1997.0 312.3 1058.74 N 1170.97 W 1090.54 N 1204.58 W 1122.36 N 1238.25 W 1154.18 N 1271.93 W 1186.08 N 1305.61 W 1218.04 N 1250.01 N 1281.71 N 1313.04 N 1344.30 N 1339.31 W 1373.15 W 1407.39 W -1441.98 W 1476.75 W 4000.0 69.28 311.62 3013.6 4050.0 69.30 310.51 3031.3 4100.0 69.29 310.51 3049.0 4150.0 69.10 310.72 3066.8 4200.0 69.29 310.47 3084.5 2043.7 2090.5 2137.2 2183.9 2230.7 80 2043.8 312.3 08 2090.5 312.3 02 2137.3 312.2 55 2184.0 312.2 60 2230.7 312.2 1375.49 N 1406.21 N 1436.59 N 1467.02 N 1497.43 N 1511.65 W 1546.92 W 1582.48 W 1617.96 W 1653.45 W A Gyrodata B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: A1097GCE422 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 4250.0 67.64 309.51 3102.9 4300.0 68.13 309.33 3121.7 4350.0 68.78 309.27 3140.1 4400.0 68.97 309.28 3158.1 4450.0 69.88 309.19 3175.7 4500.0 69.81 309.12 3192.9 4550.0 70.31 309.25 3209.9 4600.0 68.67 309.47 3227.4 4650.0 67.63 309.61 3246.1 4700.0 66.83 309.58 3265.4 4750.0 66.69 309.44 3285.1 4800.0 67.34 309.38 3304.7 4850.0 67.61 309.40 3323.8 4900.0 67.88 309.27 3342.7 4950.0 68.90 309.19 3361.2 5000.0 68.87 309.01 3379.2 5050.0 68.72 308.93 3397.3 5100 . 0 67 . 94 309 . 01 3415 . 7 5150 . 0 67 . 96 308 . 92 3434 . 5 5200 . 0 68 . 67 308 . 99 3453 . 0 5250 . 0 67 . 88 308 . 93 3471.5 5300 . 0 68 . 08 308 . 85 3490 . 2 5350 . 0 68 . 07 308 . 85 3508 . 9 5400 . 0 67 . 59 308 . 78 3527.8 5450 . 0 67 . 98 308 . 74 3546 . 7 2277.2 2323.4 2369.9 2416.5 2463.3 2510.2 2557.1 2603.9 2650.3 2696.4 2742.3 2788.3 2834.4 2880.6 2927.1 2973.7 3020.2 3066.6 3112.9 3159.3 3205.7 3252.0 3298.4 3344.6 3390.8 Directional DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. 3.76 2277.2 312.1 1.03 2323.5 312.1 1.32 2369.9 312.0 .37 2416.5 312.0 1.84 2463.3 311.9 .19 2510.2 311.9 1.03 2557.1 311.8 3.31 2603.9 311.8 2.10 2650.3 311.7 1.61 2696.4 311.7 .37 2742.3 311.7 1.31 2788.3 311.6 .53 2834.4 311.6 .60 2880.7 311.5 2.04 2927.1 311.5 .35 2973.7 311.5 .32 3020.3 311.4 1.57 3066.7 311.4 .17 3113.0 311.4 1.41 3159.4 311.3 1.58 3205.8 311.3 .42 3252.1 311.3 .03 3298.5 311.2 .95 3344.7 311.2 .77 3391.0 311.2 Survey HORIZONTAL COORDINATES feet 1527.32 N 1556.73 N 1586.19 N 1615.72 N 1645.32 N 1674.96 N 1704.66 N 1734.36 N 1763.90 N 1793.29 N 1822.52 N 1851.74 N 1881.05 N 1910.38 N 1939.77 N 1969.19 N 1998.50 N 2027.72 N 20'56.87 N 2086.08 N 2115.28 N 2144.38 N 2173.48 N 2202.50 N 2231.48 N 1689.08 W 1724.87 W 1760.85 W 1796.96 W 1833.22 W 1869.61 W 1906.05 W 1942.25 W 1978.04 W 2013.57 W 2049.01 W 2084.58 W 2120.27 W 2156.07 W 2192.08 W 2228.27 W 2264.52 W 2300.65 W 2336.68 W 2372.81 W 2408.93 W 2445.01 W 2481.13 W 2517.21 W 2553.30 W Page B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: A1097GCE422 A Gy r o d a t a Direct i o n a 1 Survey Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 5500.0 67.83 308.67 3565.5 5550.0 68.23 308.64 3584.2 5600.0 68.17 308.75 3602.7 5650.0 66.73 309.46 3621.9 5700.0 66.69 309.91 3641.7 3437.1 3483.4 3529.8 3575.9 3621.8 .31 3437.3 311.1 .79 3483.6 311.1 .23 3530.0 311.1 3.16 3576.1 311.0 .84 3622.1 311.0 2260.45 N 2289.41 N 2318.44 N 2347.56 N 2376.89 N 2589.46 W 2625.67 W 2661.90 W 2697.73 W 2733.08 W 5750.0 66.70 309.95 3661.5 5800.0 66.61 310.21 3681.3 5850.0 65.46 310.77 3701.6 5900.0 64.40 310.87 3722.8 5950.0 64.08 311.00 3744.5 3667 3713 3759 3804 3849 .7 .6 .2 .5 .5 08 3668.0 311.0 50 3713 . 9 311.0 53 3759.6 311.0 13 3804.8 311.0 68 3849 . 9 311 . 0 2406.36 N 2435.92 N 2465.58 N 2495.19 N 2524.69 N 2768.29 W 2803.42 W 2838.16 W 2872.44 W 2906.45 W 6000 . 0 61 . 75 311 . 74 3767.3 6050 . 0 61 . 02 312 . 88 3791.2 6100 . 0 60 . 78 313 . 16 3815 . 5 6150 . 0 60 . 51 313 . 88 3840 . 0 6200 . 0 61 . 06 314 . 78 3864.4 3894 3937 3981 4025 4068 .1 .9 .6 .2 .8 o 84 3894.4 311.0 47 3938.3 311.0 69 3981.9 311.0 36 4025.5 311.0 91 4069.0 311.1 2554.11 N 2583.66 N 2613.46 N 2643.47 N 2673.97 N 2939.86 W 2972.32 W 3004.26 W 3035.86 W 3067.08 W 6250.0 60.55 315.56 3888.8 6300.0 61.92 316.21 3912.9 6350.0 64.06 316.96 3935.6 6400.0 65.23 317.53 3957.0 6450.0 67.34 317.74 3977.1 4112 4156 4200 4245 4290 .3 .1 .4 .4 .9 . 2. 4. 2. 4. 71 4112.6 311.1 96 4156.3 311.2 49 4200.6 311.2 55 4245.5 311.3 24 4291.0 311.4 2704.92 N 2736.39 N 2768.75 N 2801.93 N 2835.75 N 3097.85 W 3128.36 W 3158.97 W 3189.64 W 3220.48 W 6500.0 67.18 318.19 3996.4 6550.0 66.93 318.55 4015.9 6600.0 67.45 318.79 4035.3 6650.0 67.55 318.60 4054.5 6700.0 68.58 318.06 4073.1 4336.8 4382.5 4428.3 4474.1 4520.2 88 4336.8 311.4 84 4382.6 311.5 14 4428.3 311.6 41 4474.1 311.7 28 4520.2 311.7 2870.00 N 2904.42 N 2939.03 N 2973.73 N 3008.38 N 3251.36 W 3281.95 W 3312.38 W 3342.87 W 3373.70 W A Gyroda t a D i re c t iona i Survey for B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: SUB422 Run Date: 14-Oct-97 09:30:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.507000 deg. N Sub-sea Correction from Vertical Reference: 44.55 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 311.730 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i re c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: SUB422 Page 1 SUBSEA DEPTH feet LAMBERT COORDINATES feet AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH SECTION SEVERITY deg. feet feet deg./ 100 ft. CLOSURE H 0 R I Z DIST. AZIMUTH C 0 0 R D I feet deg. fee -44 100 200 300 400 .6 0.00 0.00 .0 .35 -.65 .0 .89 -1.12 .0 1.92 -1.68 .0 3.64 -2.84 0.00 0.0 0.0 0.00 307.74 144.6 .7 .41 330.87 244.6 1.4 .28 332.58 344.6 2.5 .46 323.86 444.6 4.5 .65 0.0 0.0 1.1 296.3 1.8 306.7 3.5 317.5 6.1 322.0 0.00 N .35 .89 1.92 N 3.64 N 50 60 70 80 90 0.0 5.98 -4.86 0.0 9.45 -8.14 0.0 15.61 -13.90 0.0 25.16 -23.58 0.0 37.67 -38.79 316.82 544.6 7.6 .56 316.19 644.6 12.4 1.44 317.14 744.6 20.8 2.71 313.56 844.6 34.3 3.22 307.29 944.6 54.0 3.77 9.7 321.2 15.9 319.4 26.9 318.4 43.3 317.1 65.7 314.5 5.98 9.45 15.61 25.16 37.67 N N N N N 100 110 120 130 140 0.0 52.20 -59.15 0.0 67.80 -82.13 0.0 85.25 -106.24 0.0 107.92 -133.39 0.0 132.88 -161.92 304.29 1044.6 78.9 .55 304.19 1144.6 106.4 .49 307.92 1244.6 136.0 2.94 311.00 1344.6 171.4 2.75 311.31 1444.6 209.3 .85 91.7 311.4 118.8 309.5 148.9 308.7 184.0 309.0 219.1 309.4 52.20 67.80 85.25 107.92 132.88 N N N N N 150 160 170 180 190 0.0 157.83 -190.16 0.0 186.63 -221.84 0.0 219.31 -256.93 0.0 252.06 -292.05 0.0 286.26 -329.56 311.71 1544.6 247.0 2.10 312.78 1644.6 289.8 3.32 313.12 1744.6 337.7 .59 312.77 1844.6 385.7 .71 311.90 1944.6 436.5 3.54 254.7 309.7 294.8 310.1 338.2 310.5 403.2 310.8 450.0 311.0 157.83 186.63 219.31 252.06 286.26 N N N 200 210 220 230 240 0.0 326.16 -374.42 0.0 373.67 -428.16 0.0 429.58 -490.48 0.0 494.82 -563.65 0.0 571.71 -649.27 311.51 2044.6 496.5 4.06 311.54 2144.6 568.3 3.49 312.09 2244.6 652.0 2.40 311.40 2344.6 750.0 3.22 312.78 2444.6 865.1 3.25 502.7 311.1 591.9 311.1 657.1 311.2 762.8 311.3 876.8 311.4 326.16 373.67 429.58 494.82 571.71 N N N N N A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-79 MILNE POINT FIELD, ALASKA Job Number: SUB422 Page 2 SUBSEA DEPTH feet LAMBERT COORDINATES AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH SECTION SEVERITY feet deg. feet feet deg./ 100 ft. CLOSURE H 0 R I Z DIST. AZIMUTH C 0 0 R D I feet deg. fee 250 260 270 280 290 0.0 662.69 0.0 773.45 0.0 919.13 0.0 1082.33 0.0 1253.72 -747.13 312.79 2544.6 998.7 1.86 -867.71 312.55 2644.6 1162.4 3.25 -1023.54 313.41 2744.6 1375.6 .46 -1195.90 313.42 2844.6 1612.9 .90 -1377.15 313.13 2944.6 1862.3 1.39 1038.5 311.6 1167.8 311.7 1394.4 311.9 1624.9 312.1 1903.6 312.3 662.69 N 773.45 N~ 919.13 ! 1082.33 N 1253.72 N 300 310 320 330 340 0.0 1428.94 0.0 1593.55 0.0 1761.52 0.0 1913.26 0.0 2072.78 -1573.52 310.51 3044.6 2125.4 .54 -1769.85 309.27 3144.6 2381.5 1.08 -1975.15 309.60 3244.6 2646.5 2.20 -2159.60 309.26 3344.6 2885.2 .74 -2356.36 308.96 3444.6 3138.2 .85 2137.3 312.2 2416.5 312.0 2650.3 311.7 2927.1 311.5 3159.4 311.3 1428.94 N 1593.55 N 1761.52 N 1913.26 N 2072.78 N 350 360 370 380 390 0.0 2228.24 0.0 2381.16 0.0 2524.75 0.0 2649.10 0.0 2782.62 -2549 . 27 308 . 74 3544 . 6 3385 . 7 . 79 -2738.18 309.92 3644.6 3628.4 .73 -2906 . 52 311.01 3744 . 6 3849 . 6 . 69 -3041.63 314.04 3844.6 4033.2 1.46 -3171.79 317.20 3944.6 4219.2 3.68 3391.0 311.2 3668.0 311.0 3894.4 311.0 4069.0 311.1 4245.5 311.3 2228.24 N 2381.16 N 2524.75 N 2649.10 N 2782.62 N 400 410 413 420 0.0 2955.76 0.0 3144.64 6.1 3214.84 0.0 3339.27 -3327.08 318.70 4044.6 4450.4 .79 -3497.67 317.04 4144.6 4703.4 .79 -3562.95 317.00 4180.6 4798.9 .32 -3678.68 316.46 4244.6 4968.1 .43 4474.1 311.6 4705.7 312.0 4798.9 312.1 4798.9 312.2 2955.76 ~' 3144.64 ,, 3214.84 N 3339.27 N Final Station Closure: Distance: 4798.94 ft Az: 312.24 deg. 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: AI097GCE422 TOOL NUMBER: 777 MAXIMUM GYRO TEMPERATURE: 77.5 C MAXIMUM AMBIENT TEMPERATURE: 24.8 C MAXIMUM INCLINATION: 70.31 AVERAGE AZIMUTH: 312.06 WIRELINE REZERO VALUE: N/A REZERO ERROR / K: N/A CALIBRATION USED FOR FIELD SURVEY: 2040 CALIBRATION USED FOR FINAL SURVEY: 2040 PRE JOB MASS BALANCE OFFSET CHECK: .22 POST JOB MASS BALANCE OFFSET CHECKz: USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES .25 UPON ARRIVAL AT RIG: 1 OFF UPON COMPLETION OF SURVEY: 1 OFF UPON RETURN TO ATLAS 1 OFF BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING MWD 7032 69.00 315.3 4192 3213 -3616 FINAL SURVEY 7000 69.35 317.00 4181 3214.8 -3563 FUNCTION TEST JOB NUMBER: A1097GCE422 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 1000 14.91 14.91 14.91 14.91 14.91 M.D. ft 1 2 3 4 5 1000 304.41 304.5 304.51 304.61 304.50 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: A1097GCE422 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 777 GYRO SECTION DATA SECTION POWER SECTION BACKUP TOOL No. 772 GYRO SECTION DATA SECTION POWER SECTION A0169 C0111 C0112 A0160 C0089 C0086 COMPUTER A0349 POWER SUPPLY PRINTER A0079 INTERFACE A0143 COMPUTER A0230 POWER SUPPLY PRINTER A0029 INTERFACE A0055 A0085 A0107 WIRELINE COMPANY: CABLE SIZE: 15/32" SCHLUMBERGER RUNNING GEAR 2.25" HOUSING W/ECCENTRIC BAR TOTAL LENGTH OF TOOL :32' MAXIMUM O.D.: 2.25 INCHES TOTAL WEIGHT OF TOOL: 200 POUNDS CHRONOLOGICAL REPORT JOB NUMBER' A1097GCE422 MONDAY, 10/13/97 12:00 STANDBY FOR H PAD AND MPF 79 TUESDAY, 10/14/97 02:00 04:00 04:30 09:30 09:45 11:00 12:30 13:15 14:00 17:00 20:00 21:00 22:00 TO LOCATION ARRIVE LOCATION MU TOOL, RU SCHLUMBERGER PU GYRO. START INRUN SURVEY SURVEY CONTINUOUS TO 7000'(PUMP TOOL) OUTRUN CONTINUOUS TO 1000' LD TOOL TO H PAD TO ORIF~NT WHIPSTOCK FINISH H PAD CHECK TOOL, PROCESS SURVEY RETURN TO RIG W/RESULTS STANDBY FOR NEXT JOB MEMORANDUM TO: State of Alaska ~.Aiaska Oil and Gas Conservation Commission David Johnsto~ DATE: November 19, 1997 Chairman /'~' THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor awqkksee, doc FROM: Chuck Scheve, c 9 SUBJECT: Petroleum Inspector BOPE Test Nabors 27E PTD #9-7---04-- Wednesday November 19, 1997: I traveled to BPX's MPU F-79 Well being drilled by Nabors Rig 27E and witnessed the weekly BOPE test on this well. As the attached AOGCC BOPE test report shows the test lasted 10 hours with three failures. The annular preventer failed to pressure test and required a new element. The casing pressure gauge on the remote choke panel wouldn't register, and the H2S gas detectors, which had failed the previous day, were in the process of being repaired. The lower pipe rams could not be tested at the time of this test due to the length of the required crossover subs. Thursday November 20, 1997: I was notified by Nabors Tool Pusher Richard Larkin that the necessary repairs and retests were completed on the annular preventer and the H2S detection systems. The electronic pressure gauge on the choke panel could not be repaired in the field so a temporary hyd gauge was installed in its place. In addition to these repairs, a short crossover sub had been manufactured and a pressure test had been performed on the lower pipe rams. Summary: F-79 Well. Nabors 27E Attachment: I witnessed the weekly BOPE on Nabors rig 27E drilling BPXs MPU 11119197 Test Time 10 hours 3 failures awqkksee.xis X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA ....... OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7' Test: Initial X Workover: DATE: 11119/97 Nabors Rig No. 27E PTD # 97-I80 Rig Ph.# 659-4373 SSD Rep.: JC Pyron MPU F-79 Rig Rep.: Richard Larkin Set @ f3,410 Location: Sec. 6 T. f3N R. fOE Meridian UM Weekly X Other Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign OK Drl. Rig OK Hazard Sec. OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type 1 Inside BOP Quan. Pressure P/F f 250/5,000 P 250/5,000 P P 250/5,000 250/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F I F 1 25O/5, OOO P 250/3500 250/5,000 I 250/5,000 P 2 250/5,000 P I 250/5,000 P CHOKE MANIFOLD: No. Valves 16 No. Flanges Manual Chokes 2 Hydraulic Chokes I Test Pressure P/F 250/5,000 P 32 250/5,000 P Functioned Functioned P ACCUMULATOR SYSTEM: . N/A System Pressure 3000 ! . Pressure After Closure 1500i. MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 20 Trip Tank OK OK System Pressure Attained I minutes 53 Pit Level Indicators OK OK Blind Switch Covers: Master: OK Remote: Flow Indicator OK OK Nitgn. Btl's: 8 @ 2300 PSI Meth Gas Detector OK OK Psig. H2S Gas Detector F F sec. sec. OK Number of Failures: 3 ,Test Time: 10.0 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within 0 d'ays. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: ~ The ann, ular preventer failed to pressure test. The casing pressure gauge on the remote choke panel was not working7. The H2S gas dete, ctors were not working as the Electrician wa~s working on the control panel."The Lower pipe rams could not be tested at this time due to the length of?ross-over subs. , All items to repaired and tested before drilling ca. sing sh. oe. " Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE wITNEss REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Chuck Scheve FI-021 L (Rev. 12/94) Awqkksee TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 19. 1997 Chip Alvord Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re~ Milne Point Unit MPF-79 BP Exploration (Alaska) Inc. Permit No. 97-180 Sur. Loc: 1919'NSL. 3064'WEL. Sec. 6. T13N. RIOE. UM Btmhole Loc: 1251'NSL. 5174'WEL. Sec. 26, T14N, R9E, UM Dear Mr. Alvord: Enclosed is thc approved application for permit to drill thc above referenced well. The permit to drill does not exempt you from obtaining additional permits required bx' law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling bcloxv the surface casing shoe must be given so that a representative of thc Commission mav witness the test. 'Notice may be given bv contacting thc Commission petroleum ficld inspector on the North Slope David W.. Johnston \ Chairman~~.,) BY ORDER OF THE COMMISSION dlf/enclosures cc[ Department of Fish & Game. l Iabitat Section w,o encl. Department of' Envinommcnt Conscn'ation w, o cncl. STATE OF ALASKA ALASKA L.~,L AND GAS CONSERVATION COM,vilSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work I~ Drill [-'1Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI E]Service [] Development Gas r'-ISingle Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 44.5' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 355018 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1919' NSL, 3064' WEL, SEC. 6, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 25100302630-277 5241' NSL, 2988' WEL, SEC. 35, T14N, R9E, UM MPF-79 At total depth 9. Approximate spud date Amount $200,000.00 1251' NSL, 5174' WEL, SEC. 26, T14N, R9E, UM 09/21/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 355021, 4029't No Close Approach 5083 18783' MD / 7031' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' Maximum HoleAngle 98.97° Maximum surface 2873 psig, At total depth (TVD) 7196'/3592 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.) .... 12-1/4" 9-5/8" 40# L-80 Btm 7322' 31' 31' 7353' 4298' 1720 sx PF 'E', 529 sx 'G' 8-1/2" 7" 29# L-80 Hydrill 511 18753' 30' 30' 18783' 7031' 495 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: true measured vertical feet feet Plugs(measured) ORIGINAL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate ~ ~ ~, .~.. ' Production - ~. ,~ Liner ' 199.7 Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Lance Spencer, 564-5042 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 Commission Use Only Permit Number I APl Number A, Dp reval D~a~.e,~ I See cover letter ~/~--/o~:;:~ 50- 4::~22.¢- 2. ~ ~',,/~,~ ~/~ for other requirements Conditions of Approval: Samples Required I--lYes .[~No Mud Log Required I'-IYes ,~No Hydrogen Sulfide Measures I~Yes]~lNo Directional Survey Required ~Yes [] No Required Working Pressure for BOPE r-]2M; 1--13M; []SM; I--I 10M; I-I 15M Other: dr~gina~ ~Sigl!uU by order of Approved By David W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: I Well Name: Type of Well (producer or injector): Lance Spencer I MPF-79 Well Plan Summary 564-5042 I Kuparuk Producer Surface Location: 1918' NSL, 3064' WEL, Sec. 06, T13N ,R10E, UM., AK Target TKUA2 5241' NSL, 2988' WEL, Sec. 35, T14N, R09E, UM., AK Target TKUA1 624' NSL, 4110' WEL, Sec. 26, T14N, R09E, UM., AK Target TKUC 1125' NSL, 4962' WEL, Sec. 26, T14N, R09E, UM., AK Bottom Hole Location: 1251' NSL, 5174' WEL, Sec. 26, T14N, R09E, UM., AK I AFE Number: Rig: I Nabors 27-E Estimated Start Date: 1 21 Sept 97 I I Operating days to complete: I MD: 118,783' I I TVD: 17,031' Bkb I IKBE: 123 144.50' I Well Design: Ultra Slim Hole Long String HAW I 9-5/8", 40# Surface X 7", 26# Longstring Formation Markers: Formation Tops MD TVD (bkb) EMW Formation Pressure Base Permafrost ¢390 ~0'/ -3e0~5' 8.4 ppg 806 psi Top Ugnu 5114 3445 8.4 ppg 1505 psi NA Top Schrader Bluff 6439 3950 8.4 ppg 1725 psi OA Base Schrader Bluff 7203 4241 8.4 ppg 1852psi Top HRZ 13696 6660 8.8 ppg 3047 psi Base HRZ 14010 6720 8.8 ppg 3075 psi TKLB(MK-19) 14560 6825 9.2 ppg 3265psi TKUD 15425 6990 9.2 ppg 3344 psi TKUP A2 16228 7125 9.6 ppg 3557 psi Top Kup A1 16330 7140 9.6 ppg 3564 psi ~;.: ' Base Kup A1 17536 7190 9.6 ppg 3589 psi "-':~7,.~ .. TKUC 18533 7070 9.6 ppg 3529psi TARGET4/Total Depth 17783+ 7031 _ 9.6 ppg 3510 psi *These are estimated maximum pressures and the actual pressures may be lower. t, as,n~/, uD,n~l ~'ro_c ram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btm 7322 31/31 7353/4298 8-1/2" 7" 29# L-80 Hyd rill 18753 30/30 18783/7031 511 The internal yield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at _ 7,196 TVDbkb In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +7,196 TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,592 psi is 2,873 psi using a 0.1 psi/ft gas gradient, well below the internal yield pressure rating of the 7" casing. MP F-79 (ERD E) Drilling Permit 1 9/16/97 Cementing Program: Halliburton Cementing Services Hole Casing Interval Volume~ Spacer Type of Cement Propertiesz Cate~lory Size/Depth S u rface Lead'~ Lead Lead Lead First 9-5/8" @ 2107-5939' 719 sx 70 bbls Permafrost "E' Den 12.0 ppg Stage 7,353' 278 bbls Fresh water Yield 2.17 ft 3/sx Water 11.63 gps 'IT 4.0 hrs 5939-7353' Tail5 Tail Tail 529 sx Premium Class "G" w/ Den 15.8 ppg 108 bbls 0.2 % CaCI, 0.15 #/sk Celoflakes Yield 1.15 ft 3/sx Water 4.9 gps TT 4.0 hrs ........................................................................................... Second Stagje i'~'~6 ............. ~'~'~J~ ...................... i"~'~a ..................................... '1~1' ........................................................ stage collar" @ 0-1907 1001 sx 75 bbls Permafrost "E" Same as above 2,107' 1907-2207 387 bbls Fresh water Wellhead If Lead' Le. ad Lead Stability necessary 150 sx Permafrost "E" Same as above Cmt Production 7" @ 14,500- Lead" Lead Lea__d Den 15.0 ppg First 18,783' 18,783 495 sx 50 bbls. Foamed Premium Yield 1.46 ft 3/sx Stage 129 bbls Alpha Class "G' w/ Water 3.95 gps Spacer 15%Silicate, 'IT 3.5-4.5 hrs @ 140° F 50 bbls 0.45% Halad 344 FL 30-40cc/30 min Foamed 0.1% CFR-3 @140° F Alpha 2 gps Latex 2000 Spacer 0.5ps C434B 0.1 gps D-Air-# 0.1% HR-5 1. Volumes are rounded u3 to the nearest 10 sacks. 2. Ensure thickening times are adequate relative to pumping job requirement. Actual times should be based on job requirements and lab tests. Perform lab tests on mixed cements, spacers and muds to ensure compatibility prior to pumping job. 3. A Type H ES Cementer will be installed in the 9-5/8" csg. 200' md below the base of the Permafrost at 2,107'MD_+ 4. The surface hole First Stage LEAD Cement Volume. Interval from 2,107-5,939' md. The estimated first stage lead cement volume from 2,107-5,939' md and is equivalent to the annular volume calculated from the 9-5/8" ES Cementer at 2,033' md which is 200 ft md below Base of the Permafrost at 1,907' md (1,800 TVD bkb) to 5,939' md which is 500' above the NA top plus 30% Excess. 5. The surface hole First Stage TAIL Cement Volume covers the interval from 5,939-7,353' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from the 5,939-7,353' (500' md above the NA top) to surface TD at 7,353' md (4,298' TVD bkb) plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 9-5/8", 40# casing. 6. The surface hole Second Stage Lead Cement Volume covers the interval from 0-2,107' md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 2,107' MD (2,015' TVDbkb) to surface. From 1907' to surface include 250% open hole excess and from 1,907-2,107' use 30% open hole excess. ...... rt to 8. Install one(l) Bow Spring Centralizers per joint on the bottom 10 joints of 9-5/8" casing (required). 9. If the Schrader Bluff is productive install one(l) Bow Spring Centralizers per joint from 6,400-7300 of 9-5/8" casing to cover the top of the NA to Base OB. 10. The production hole will be cemented in a single stage. The Cement Volume covers the interval from 14,500-18,783' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from 14,500' which is 1000'+_ above the Kuparuk D Shale to TD at 18,783' plus 30% open hole excess and the shoe joint volume, The estimated shoe joint volume is equivalent to the capacity of 80'md of 7", 29# casing. 11. Use 7" x 8-1/4" Straight Blade Rigid Centralizers and install TWO per joint from 120' below to 120' above any potential hydrocarbon bearing sands. 12. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing. 13. Install two 7" marker joints and position three joints above the Kuparuk C sand. 14. Place all centralizers in middle of joints using stop collars. 15. Mix all cement slurries in the surface and production holes on the fly - batch mixing is not necessary. MP F-79 (ERD E) Drilling Permit 2 9/16/97 Logging/Formation Evaluation Program: Anadrill Schlumberger Open Hole Logs: None Surface-12-1/4" 1. M10 Power Plus MWD Directional from top to bottom of surface hole.. 2. LWD (CDR/GR/ROP) from TOP Schrader Bluff to TD of surface hole. 3. DWOB/DTOQ from top to bottom of surface hole. Intermediate N/A Final Production 1. M10 Power Plus MWD Directional 8-1/2" 2. LWD (CDR/AND/GR/ROP) (Real Time) 3. DWOB/DTOQ Cased Hole Logs: N/A Mud Logging Schlumberger IDEAL System in the surface and production holes. SPIN Log: Record: GR, Depth, Surface Torque and DWOB/DTOQ, ROP, Hook Load, RPM, Pump Pressure, GPM (in and out) during all operations. 12-1/4" and 8-1/2" Hole M10 PowerPlus IWOB: GR: CDR: ADN: ROP: Directional Inclination and Azimuth DWOBB/DTOQ Gamma Ray Compensated Dual Resitivity Azimuthal Density Neutron (Density, Porosity, and Sonic Caliper) Rate of penetration Mud Program: Baroid Drilling Fluids Inc. Surface Mud Properties: LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH Fluid Solids (PPG) Viscosity Point gel gel Loss % 8.6-9.6 50-150 15-35 8-15 10-30 9-10 8-15 <9 Production Mud Properties to Change LSND Freshwater Seawater Mud Over Depth at TKUD Density Marsh Yield 10 sec 10 min pH APl HTH P Solids (PPG) Viscosity Point gel gel Filtrate %LGS 8.6-10.6 35-45 6-20 3-10 7-20 8.5-9.5 6-12 8-10 for <6 <4 Miluveach Production Mud Properties For Kuparuk 2% KCL BaraDrillN Mud Interval Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point gel gel Filtrate %LGS 9.8-10 45-55 30-40 8-12 15-25 9.0 4-6 10-15 <3 <4 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The diverter, BOPE and drilling fluid system schematics are on file with AOGCC. MP F-79 (ERD E) Drilling Permit 3 9/16/97 Directional: KOP1 300' Start Variable @ 1.0°- 3.0 °/100 and Az 311.72°. EOB @ 3250' md. Tangent Hole An~lle 67.60° from 3,250-7,353' Curve 2 13,107' Start Curve @ 2.5°/100 to 79° incl. and 302 Az o EOB 13,696' md Curve 3 15,604' Start Curve @ 1.0°/100 to 81.03° incl. and 302 Az o EOB 15,807' md Curve 4 16,228' Start Curve @ 1.0°/100 to 91.18° incl. and 299.73 Az o EOB 17,268' md Curve 5 17,536' Start Curve @ 1.5 °/100 to 98.97° incl. and 300.8 Az ° EOB 18,060' md 98.97° from 18,060-18,783' Maximum Hole Angle Close Approach Wells Survey Program All wells may remain flowing while drilling F-79 and no shut-ins are required. 1. Surface to 7,353' MWD surveys. 2. 7,353-9,353' GYRO to surface 3. 9,353'-TD MWD with in hole reference. Disposal: No "Drilling Wastes" will be injected or disposed into F-79 while drilling this well. Cuttin_qs Handlin_q: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations. GENERAL DISCUSSION Well Objective: MPF-79 is planned as a 18,783' md, 15,955' departure, U-Shaped horizontal Kuparuk River A and C Sand producer. At total depth the U-shaped well profile has a planned final angle of 99°. With the U-shaped design the well bore will intersect the Kuparuk A2-A1 on the entry side of the "U", flatten in the A1 sand, and then invert up cross an unconformity and enter the Kuparuk C sand. The well bore will enter the D shale at target point 1, enter the top of the A2 at target point 2, exit the A2, then go through the A1 sand and exit the A2 at target point 3, enter the C sand and intersect target 4 and the top of the C sand. With this well profile the Miluveach should not be intersected. This profile will facilitate optimum injection into two separate fault blocks from a single well bore. The surface casing will be deep set below the Schrader Bluff at 7,353 feet measured depth to isolate the Ugnu and Schrader Bluff from the Kuparuk interval. The Kuparuk may be partially pressure depleted with an estimated pore pressure of 9.6 ppg EMW due to nearby production from F-01, F-06 and F-14. Injection support for the fault block in which the F-79 well path intersects in the target interval in provided by F-461 and F-10i. Low pressures from depletion and high pressure from injection should not cause drilling problems. Geolo_qv F-79 (ERD E) will cross a number of faults through the Kuparuk section. The primary targets are the Kupauuk A2 and A1 sands but has some potential in the Kuparuk C sands.. The deepest known oil in the area is at F-46 to a depth of 7,216 tvd ss. No water contact is expected at the F-79 location. The HRZ interval in some nearby wells is missing. In other nearby wells the HRZ was thin or truncated. In this well a full section is assumed, but the zone my be truncated. The vertical margin of uncertainty is approximately 50-~_ ft TVDbkb associated with the Kuparuk targets due to seismic time conversion. Reserves associated with this injector are estimated at 2.0 MMBO assuming a 240 acre drainage area. DRILLING HAZARDS AND RISKS SUMMARY: Formation pressures are expected to be normal (9.6 ppg EMW) or partially depleted and not be affected by Kuparuk injection. The deep set surface casing design is recommended to alleviate potential problems of differential sticking and lost circulation in the Ugnu and Schrader Bluff while drilling the Kuparuk. The well profile has been designed to avoid close approaches and no wells will be shut in while drilling this well. Lost circulation and stuck pipe have occurred but not recently and are not expected. Close Approaches There are no close approaches associated with the drilling of MP F-79, however, tolerance lines should be carefully monitored and deviations from the proposed well path minimized. Water, Gas and WAG Injection MP F-79 (ERD E) Drilling Permit 4 9/16/97 Formation pressures are expected to be partially depleted at a maximum of 9.6 ppg EMW pore pressure in the Kuparuk while drilling F-79. F-10i and F-46i are the only other injectors expected to be in communication with the proposed F-79 BHL but it injected is not expected to have abnormally pressured the reservoir due to offtake for producers F-01, F-06 and F-14. Annular Injection Currently annular injection is not permitted on F-Pad. Lost Circulation: Lost circulation has been most prevalent while running casing and cementing in the surface as well as production hole. Losses are extremely probable while cementing the long string in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing. Major losses have also occurred while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. Since the F-79 well bore will pass through a number of faults the potential for lost circulation is higher. Contingencies have been incorporated to well program remedy loses if encountered. Stuck Pipe Potential: Running gravel's, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occurred while drilling the 12 1-4" surface holes on F-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing after drilling the surface hole. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole and bridging, and the 9-5/8" casing has been stuck. While drilling the surface hole additional time has been spent reaming and conditioning the hole prior to cementing because of tight hole. With the possibility that the HRZ will be truncated or absent the potential for stuck pipe the transition interval from Colville(SeeBee) to Kulubik is recognized. Shale instability in the Miluveach may result in tight hole or packing off so preventative measures must be taken to alleviate this risk. While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk. This is a common occurrence has often causes difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Attention should be given to The Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations with higher mud's weights needed to keep the HRZ and Kuparuk formations in balance. Differential sticking is most likely while running the production string. Formation Pressure: KUPARUK A1 SAND 7190' TVDss 3589 PSI 9.6 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at __. 7,190 TVDbkb. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of __.7,190' TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,589 psi is 2,870 psi. The maximum expected pore pressure for this well is 9.6 ppg EMW (3,589 psi @ 2,870' TVDbkb). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for information on F pad and review recent wells drilled on F Pad. MP F-79 (ERD E) Drilling Permit 5 9/16/97 MP F-79 Kuparuk Producer Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5A Well head on conductor as well as a nipple to aid in performing potential well head stability cement job. 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. 4. NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD/LWD (GR/DIR/CDR/DWOB/DTOQ) from surface to 12-1/4" TD. 6. Run 9-5/8" casing. Space out ES Type H Cementer to 2107' md. 7. Perform Two Stage Cement Job. Complete the surface casing cementing check list. 8. ND 20" Diverter, NU and Test 13-5/8" BOP 9. MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/DIR/CDR/DWOB/DTOQ). RIH, Drill out Float Equipment and 20' of new formation. Perform Leak Off Test as per Recommended Practices Manual. Record pressure versus cumulative volume for LOT test for the well file. 10. Drill 8.5" hole to TD as per directional plan. Make sure sufficient footage is drilled to provide 250' of production rat hole between the base of the Kuparuk C sand and PBTD before running the 7" casing. 11. Run 7" casing. Space out ES Type H Cementer and ECP (external casing packer) to 17,100' md. 12. Perform Single Stage Cement Job. Complete the production casing cementing check list. 13. Displace cement with 8.4 ppg filtered sea water and enough diesel to cover from the base of permafrost to surface (+-2100' MD). 14. Test casing to 3500 psig. 15. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. 16. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. MP F-79 (ERD E) Drilling Permit 6 9/16/97 Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPF-79 (P03) Field ........ : Milne Point Computation..: Minimum Curvature Units ........ : FEET Surface Lat..: 70.50755034 N Surface Long.: 149.66046056 W Legal Description Surface ...... : 1918 FSL 3064 FEL Target 1 ..... : 4863 FSL 2382 FEL Target 2 ..... : 5241 FSL 2988 FEL Target 3 ..... : 624 FSL 4110 FEL Target 4 ..... : 1125 FSL 4962 FEL BHL .......... : 1251 FSL 5174 FEL LOCATIONS - ALASKA Zone: X-Coord S06 T13N R10E %TM S35 T14N R09E UM S35 T14N R09E %TM S26 T14N R09E UM S26 T14N R09E %TM S26 T14N R09E UM 541500 05 531700 00 531092 00 529966 00 529112 00 528899 21 4 Y-Coord 6035368.73 6043545.00 6043920.00 6044578.00 6045075.00 6045200.26 PROPOSED WELL PROFILE Prepared ..... : 10 Sep 1997 Vert sect az.: 311.73 KB elevation.: 44.50 ft Magnetic Dcln: +27.944 (E) Scale Factor.: 0.99990196 Convergence..: +0.32007931 ANADRILL AKA-DPC APPROVED SEP 1 1 1997' 'NITIAL_~ STATION MEASURED IDENTIFICATION DEPTH KB 0.00 KOP/CURVE 1.00/100 300.00 400.00 CURVE 1.50/100 500.00 600.00 CURVE 2.00/100 700.00 800.00 900.00 1000.00 1100.00 INCLN DIRECTION VERTICAL-DEPTHS SECTION AigGLE AZIMUTH TVD SUB-SEA DEPART COORDINATES-FROM WELLHEAD 0.00 0.00 0.00 -44.50 0.00 0.00 N 0.00 E 0.00 311.72 300.00 255.50 0.00 0.00 N 0.00 E 1.00 311.72 399.99 355.49 0.87 0.58 N 0.65 W 2.00 311.72 499.96 455.46 3.49 2.32 N 2.61 W 3.50 311.72 599.84 555.34 8.29 5.52 N 6.19 W 5.00 311.72 699.56 655.06 15.70 10.45 N 11.72 W 7.00 311.72 799.01 754.51 26.15 17.40 N 19.52 W 9.00 311.72 898.03 853.53 40.07 26.66 N 29.91 W 11.00 311.72 996.51 952.01 57.43 38.22 N 42.87 W 13.00 311.72 1094.32 1049.82 78.22 52.05 N 58.39 W ALASKA Zone 4 TOOL DL/ X Y FACE 100 541500.05 6035368.73 48L 0.00 541500.05 6035368.73 48L 0.00 541499.40 6035369.31 48L 1.00 541497.43 6035371.04 48L 1.00 541493.83 6035374.21 48L 1.50 541488.27 6035379.11 541480.43 6035386.02 541470.00 6035395.22 541456.97 6035406.70 541441.38 6035420.45 48L 1.50 HS 2.00 HS 2.00 HS 2.00 HS 2.00 (Anadrill (c)97 MPF79P03 3.0C 2:29 PM P) MPF-79 (P03) 10 Sep 1997 Page 2 PROPOSED WELL PROFILE STATION IDENTIFICATION END 2.00/100 CURVE BASE PERMAFROST CURVE 3.00/100 ANADRILL AKA-DPC APPROVED SEP 1 1 1997 INITIAL_~ END 3.00/100 CURVE TOP UGNU MEASURED DEPTH INCLN DIRECTION VERTICAL-DEPTHS ANGLE AZIMUTH TVD SUB-SEA SECTION DEPART COORDINATES-FROM ALASKA Zone 4 WELLHEAD X Y 1200.00 15.00 311.72 1191.34 1146.84 102.41 68.15 N 76.45 W 1300.00 17.00 311.72 1287.46 1242.96 129.97 86.49 N 97.02 W 1400.00 19.00 311.72 1382.56 1338.06 160.88 107.05 N 120.09 W 1500.00 21.00 311.72 1476.53 1432.03 195.08 129.81 N 145.62 W 1600.00 23.00 311.72 1569.24 1524.74 232.53 154.74 N 173.58 W 1700.00 1800.00 1884.29 1906.52 1952.69 273.21 181.80 N 203.94 W 317.04 210.97 N 236.66 W 356.41 237.16 N 266.04 W 367.08 244.26 N 274.01 W 389.24 259.01 N 290.55 W 25.00 311.72 1660.59 1616.09 27.00 311.72 1750.47 1705.97 28.69 311.72 1825.00 1780.50 28.69 311.72 1844.50 1800.00 28.69 311.72 1885.00 1840.50 2000.00 30.11 311.72 1926.22 1881.72 412.46 274.46 N 307.88 W 2100.00 33.11 311.72 2011.38 1966.88 464.86 309.33 N 347.00 W 2200.00 36.11 311.72 2093.68 2049.18 521.65 347.12 N 389.38 W 2300.00 39.11 311.72 2172.89 2128.39 582.66 387.73 N 434.93 W 2400.00 42.11 311.72 2248.80 2204.30 647.74 431.04 N 483.50 W 2500.00 45.11 311.72 2321.21 2276.71 716.70 476.93 N 534.97 W 2600.00 48.11 311.72 2389.90 2345.40 789.35 525.29 N 589.20 W 2700.00 51.11 311.72 2454.70 2410.20 865.50 575.97 N 646.03 W 2800.00 54.11 311.73 2515.42 2470.92 944.94 628.84 N 705.32 W 2900.00 57.11 311.73 2571.90 2527.40 1027.45 683.75 N 766.90 W 3000.00 60.11 311.73 2623.99 2579.49 1112.80 740.56 N 830.60 W 3100.00 63.11 311.73 2671.54 2627.04 1200.76 799.11 N 896.24 W 3200.00 66.11 311.73 2714.42 2669.92 1291.09 859.23 N 963.65 W 3249.82 67.60 311.73 2734.00 2689.50 1336.89 889.72 N 997.84 W 5114.28 67.60 311.73 3444.50 3400.00 3060.67 2037.07 N 2284.31 W TOP SB NA TOP 6439.48 67.60 311.73 3949.50 3905.00 4285.88 BASE SB OB BASE 7203.11 67.60 311.73 4240.50 4196.00 4991.89 9-5/8" CASING POINT 7353.11 67.60 311.73 4297.66 4253.16 5130.57 2852.57 N 3198.69 W 3322.49 N 3725.59 W 3414.80 N 3829.08 W 541423.23 6035436.44 541402.56 6035454.67 541379.38 6035475.10 541353.73 6035497.71 541325.63 6035522.48 541295.12 6035549.37 541262.24 6035578.35 541232.71 6035604.38 541224.71 6035611.44 541208.09 6035626.09 541190.67 6035641.44 541151.36 6035676.09 541108.77 6035713.64 541063.01 6035753.98 541014.20 6035797.02 540962.48 6035842.62 540907.99 6035890.67 540850.87 6035941.03 540791.30 6035993.56 540729.42 6036048.12 540665.41 6036104.57 540599.45 6036162.74 540531.71 6036222.48 540497.35 6036252.77 539204.63 6037392.81 538285.79 6038203.11 537756.33 6038670.04 537652.33 6038761.75 TOOL DL/ FACE 100 HS 2.00 HS 2.00 HS 2.00 HS 2.00 HS 2.00 HS 2.00 HS 2.00 HS 2.00 HS 0.00 HS 0.00 HS 3.00 HS 3.00 HS 3.00 HS 3.00 HS 3.00 HS 3.00 HS 3.00 HS 3.00 HS 3.00 HS 3.00 HS 3.00 HS 3.00 HS 3.00 HS 3.00 HS 0.00 HS 0.00 HS 0.00 HS 0.00 (Anadrill (c)97 MPF79P03 3.0C 2:29 PM P) MPF-79 (P03) 10 Sep 1997 Page 3 PROPOSED WELL PROFILE STATION IDENTIFICATION MEASURED INCLN DIRECTION DEPTH ANGLE AZIMUTH VERTICAL-DEPTHS TVD SUB-SEA CURVE 2.50/100 13106.72 67.60 311.73 13200.00 69.37 310.10 13300.00 71.29 308.40 13400.00 73.22 306.73 13500.00 75.17 305.10 SECTION DEPART >>TOP HRZ<< END 2.50/100 CURVE >>BASE HRZ<< MK-19 13600.00 77.12 303.49 13695.51 79.00 301.99 13695.51 79.00 301.99 14009.96 79.00 301.99 14560.25 79.00 301.99 6490.21 6445.71 10450.04 6524.42 6479.92 10536.80 6558.08 6513.58 10630.87 6588.55 6544.05 10725.85 6615.79 6571.29 10821.57 TKUD TARGET #1'******* CURVE 1.00/100 15424.99 79.00 301.99 15503.60 79.00 301.99 15603.60 79.00 301.99 15700.00 79.96 301.99 15800.00 80.96 301.99 COORDINATES-FROM WELLHEAD END 1.00/100 CURVE 15806.54 81.03 301.99 CURVE 1.00/100 16228.10 81.03 301.99 KUPARUK C/B/A/A3/A2 ~16228.10 81.03 301.99 TARGET ~2'********* L 16228.10 81.03 301.99 16300.00 81.73 301.83 6955.46 N 7799.04 W 7012.28 N 7864.62 W 7071.84 N 7937.54 W 7129.89 N 8013.03 W 7186.32 N 8090.96 W TKA1 ,NADRILL AKA-DPC APPROVED 16329.89 82.02 301.76 16400.00 82.71 301.61 16500.00 83.68 301.39 16600.00 84.66 301.17 16700.00 85.64 300.96 SEP 1 1 199]' 16800.00 86.61 INITIALz~ ~..~. 16900.00 87.59 17000.00 88.57 nadrill (c)97 MPF79P03 3.0C 2:29 PM P) 300.74 300.52 300.31 6639.74 6595.24 10917.83 7241.02 N 8171.17 W 6659.50 6615.00 11010.12 7291.55 N 8249.76 W 6659.50 6615.00 11010.12 7291.55 N 8249.76 W 6719.50 6675.00 11314.35 7455.05 N' 8511.57 W 6824.50 6780.00 11846.73 7741.19 N 8969.74 W 6989.50 6945.00 7004.50 6960.00 7023.58 6979.08 7041.18 6996.68 7057.74 7013.24 12683.34 12759.39 12856.14 12949.55 13046.75 7058.77 7014.27 13053.11 7124.50 7080.00 13463.51 7124.50 7080.00 13463.51 7124.50 7080.00 13463.51 7135.28 7090.78 13533.55 7139.50 7095.00 13562.70 7148.81 7104.31 13631.12 7160.66 7116.16 13728.84 7170.82 7126.32 13826.67 7179.28 7134.78 13924.59 7186.03 7141.53 7191.09 7146.59 7194.45 7149.95 ALASKA Zone 4 TOOL DL/ X Y FACE 100 14022.57 14120.57 14218.57 533663.05 6042279.83 41L 0.00 533597.16 6042336.28 40L 2.50 533523.91 6042395.43 40L 2.50 533448.10 6042453.05 39L 2.50 533369.87 6042509.03 39L 2.50 533289.37 6042563.28 38L 2.50 533210.50 6042613.36 HS 2.50 533210.50 6042613.36 HS 2.50 532947.80 6042775.39 HS 0.00 532488.08 6043058.93 HS 0.00 8190.83 N 9689.73 W 531765.67 6043504.49 HS 0.00 8231.70 N 9755.18 W 531700.00 6043545.00 HS 0.00 8283.70 N 9838.44 W 531616.46 6043596.53 HS 0.00 8333.90 N 9918.83 W 531535.80 6043646.27 HS 1.00 8386.14 N 10002.47 W 531451.87 6043698.04 HS 1.00 8389.56 N 10007.95 W 531446.37 6043701.43 HS 1.00 8610.13 N 10361.13 W 531092.00 6043920.00 13L 0.00 8610.13 N 10361.13 W 531092.00 6043920.00 13L 0.00 8610.13 N 10361.13 W 531092.00 6043920.00 13L 0.00 8647.71 N 10421.48 W 531031.45 6043957.23 13L 1.00 8663.30 N 10446.63 W 8699.79 N 10505.76 W 8751.67 N 10590.43 W 8803.33 N 10675.45 W 8854.74 N 10760.80 W 531006.21 6043972.68 13L 1.00 530946.88 6044008.84 13L 1.00 530861.94 6044060.24 13L 1.00 530776.64 6044111.42 12L 1.00 530691.01 6044162.35 12L 1.00 8905.90 N 10846.46 W 8956.78 N 10932.39 W 9007.38 N 11018.58 W 530605.08 6044213.02 12L 1.00 530518.87 6044263.42 12L 1.00 530432.41 6044313.53 12L 1.00 MPF-79 (P03) 10 Sep 1997 Page 4 __ STATION IDENTIFICATION END 1.00/100 CURVE CURVE 1.50/100 TARGET ~3'********** MEASURED INCLN DEPTH ANGLE PROPOSED WELL PROFILE 17100.00 89.54 17200.00 90.52 17267.92 91.18 17536.31 91.18 17536.31 91.18 17600.00 92.13 17700.00 93.61 17800.00 95.10 17900.00 96.59 18000.00 98.07 END 1.50/100 CURVE 18060.45 98.97 TARGET ~4'********** 18532.76 98.97 TD 18782.76 98.97 TMLV DIRECTION VERTICAL-DEPTHS SECTION AZIMUTH TVD SUB-SEA DEPART 300.09 7196.10 7151.60 14316.54 299.88 7196.05 7151.55 14414.44 299.73 7195.04 7150.54 14480.89 299.73 7189.50 7145.00 14743.36 299.73 7189.50 7145.00 14743.36 299.86 7187.66 7143.16 14805.65 300.06 7182.65 7138.15 14903.42 300.27 7175.05 7130.55 15001.11 300.47 7164.87 7120.37 15098.64 300.68 7152.11 7107.61 15195.94 300.80 7143.15 7098.65 15254.63 300.80 7069.50 7025.00 15712.70 300.80 7030.51 6986.01 15955.16 7199.50 7155.00 COORDINATES-FROM ALASKA Zone 4 WELLHEAD X Y 9057.67 N 11105.00 W 9107.65 N 11191.61 W 9141.41 N 11250.54 W 9274.48 N 11483.55 W 9274.48 N 11483.55 W 9306.11 N 11538.80 W 9355.99 N 11625.32 W 9406.09 N 11711.53 W 9456.38 N 11797.36 w 9506.83 N 11882.75 W 9537.39 N 11934.13 W 9776.29 N 12334.85 W 9902.75 N 12546.95 W ANADRILL AKA-DPC APPROVED SEP 1 1 1997 530345.72 6044363.33 530258.84 6044412.82 530199.73 6044446.24 529966.00 6044578.00 529966.00 6044578.00 TOOL DL/ FACE 100 12L 1.00 12L 1.00 HS 1.00 8R 0.00 8R 0.00 529910.58 6044609.32 8R 1.50 529823.79 6044658.71 8R 1.50 529737.31 6044708.33 8R 1.50 529651.22 6044758.13 8R 1.50 529565.55 6044808.10 8R 1.50 529514.00 6044838.37 529112.00 6045075.00 528899.21 6045200.26 HS 1.50 HS 0.00 0.00 (Anadrill (c)97 MPF79P03 3.0C 2:29 PM P) SHARED SERVICES ANADRILL AKA-DPC APPROVED SEP 1 1 1997 INITIAL/~5..:, ~--_____~% DRI'LLTNG Anadri ]] Schlumberger MPF-79 (P03) VERTICAL SECTION VIEW Section at: 31].73 TVD Scale.' ~ inch = 2000 feet Dep Scale' ] inch = 2000 feet Drawn · 10 Sep 1997 Marker Identification MD BKB SECTN INCLN A) KB 0 0 0 0.00 B) KOP/CURVE .1.00/200 300 300 0 0 O0 C) CURVE .1.50/200 500 500 3 2 O0 D) CURVE 2.00/200 700 700 26 5 00 E) END 2.00/.100 CURVE 2884 2825 356 28 69 F) CURVE 3.00/.100 `1953 `1885 389 28 69 G) END 3 00/]00 CURVE 3250 2734 2337 67 60 A H) 9-5/8" CASING POINT 7353 4298 523`1 67. B -- C '- I) CURVE 2.50/`100 .13.107 6490 `10450 67.~ D ~- J) END 2.50/100 CURVE `13696 6659 21020 79.C K) TARGET #2~~ 25504 7004 .12759 79.C L) CURVE 2.00/200 25604 7024 .12856 79.C M) END .1.00/`100 CURVE .15807 7059 23053 ,, l~.qF-pr~f'-~m] N) CURVE 2.00/100 ~622B 7`124 ~3464, B'l.( O) TARGET #2~~ 26228 7~24 23464 82.( P) END 1.00/200 CURVE 27268 7295 1448.1 9~. ~) CURVE !.50/200 27536 7~89 24743 92. R) TARGET #3~*~*~* .17536 7'189 24743 ~ S) END 2.50/~00 CURVE '18060 7'143 '15255 98.(. L'TD'P-U~LT- ~4'~ ........ ~ T) TARGET #4,***~***** 28533 7069 '157`13 98,(. ~ U) TD '18783 703.1 '15955 98.(. '8~s[' ~-oE ~s'E - ~h ....... .,~- ........... f. ~¢~ L :: ::::::: ..... ~ ................ -- ,_ ..........-' ........... ,~A~-'~5: .......... ~ - ~ 4 8 ~ Q S T L 0 ]000 2000 3000 4000 5000 6000 7000 8000 9000 '10000 2 .1000 22000 `13000 `14000 15000 26000 '17000 Section Departure (Anadr~]] (c)g7 MPF79P03 3.0C 2:29 PM P) 200 Marker Identification A) CURVE 2.50/100 B) END 2.50/100 CURVE C) TARGET #1~*~*~ D) CURVE 1.00/100 E) END 1.00/100 CURVE F) CURVE 1.O0/100 MD BKB SECTN INCLN 13107 6490 10450 67.60 13696 6659 11010 79.00 15504 7004 12759 79.00 15604 7024 12856 79.00 15807 7059 13053 81.03 16228 7124 13464 81.03 G) TARGET #2.********* 16228 7124 13464 81.03 H) END 1.00/100 CURVE 17268 7195 14481 91.18 I) CURVE 1.50/100 17536 7189 14743 9t.18 J) TARGET #3~~ 17536 7189 14743 91.18 K) END 1.50/100 CURVE 18060 7143 15255 98.97 L) TARGET #4.****~***** 18533 7069 15713 98.97 M) TD 18783 7031 15955 98.97 ANADRILL AKA-DPC APPROVED SEP 1 1 1997 INITIAL~ Anadr] ]1 $ch]umberger MPF-79 (PO3) VERTICAL SECTION VIEW Section at: 311.73 TVD Scale.: 1 inch = 400 feet Oep Scale.: 1 inch = 400 feet Drawn ..... : lO Sep 1997 12400 12600 12800 13000 13200 13400 13600 13800 14000 14200 14400 14600 14800 15000 15200 Sect ion Departure (Ra ~ius feet ) (AnadrJl! (c)97 MPF7gP03 3.0C 2:39 PM P) ~' SHARED SERVTCES DRTLLTN6 Narker Identification NB N/S E/H ~) ~o~/cu,v[ ~.00/~00 ~00 0, c) cu,v~ ~.50/~00 500 ~, 3 ~) cu,vE ~.00/~00 700 ~0, ~ E) E,O ~.00/~00 CU,V~ m,4 ~7, ~ee F) CURVE 3.00/100 1953 259 N 291 ~1 E~ ~.00/~00 cu,v~ 3~50 ~90, ~ ~1 CU,VE ~.50/~00 ~3~07 ~955, 779~ J) END 2.50/100 CURVE 13696 7292 N 8250 K) TARGET #1~~ 15504 8232 N 9755 LI CURVE 1.00/100 15604 8284 N 9838 M) END t.00/100 CURVE 15807 8390 N 10008 N) CURVE 1.00/100 16228 8610 N 10361 O) TARGET #2~~ 16228 8610 N 10361 P) END t.00/100 CURVE 17268 9t41N 11251 Q) CURVE 1.50/100 17536 9274 N 11484 R) TARGET #3~~ 17536 9274 N 11484 S) END 1.50/100 CURVE 18060 9537 N 11934 T) TAR6ET #4~~ 18533 9776 N 12335 U) TD 18783 9903 N 12547 MPF-79 (PO3) PLAN VTEN CLOSURE ..... : 15984 feet at Azimuth 308.28 DECLINATION.: +27.944 (E) SCALE ....... : 1 inch = 2000 feet DRAWN ....... : 10 Sep 1997 Anadrj ]] Schlumberger ANADRILL AI(A-DPC APPROVED SEP 1 1 1997 INiT,'AL_/,& r~) ~l~~ -- 7- : Targ~,t 4 (Rad us 200 :eet ) __ ~~et 3 (Radials 200 f,et ) eL 2 (Rudtu~ 200 euL ) -- ~ (Radius 200 feet ) X,,,, -- -- '%,,, __ __ :13000 12000 1:1000 10000 9000 [t000 7000 6000 5000 4000 3000 2000 1000 0 1000 <- WEST' EAST -> Anadri]] (c)97 NPF79P03 3.0C 2:29 PN P) · WELL PERMIT CHECKLISTCOMPANY WELL ? FIELD & POOL ._~j-_...?_,~...J~j INIT CLASS ._~_~_.¢/ 1 -,:::>,2,~/' GEOL AREA PROGRAM: exp [] dev~redrll [] serv [] wellbore seg El ann. disposal para req [] ~'F~_~ UNIT# /,23 .~,..<~" ON/OFF SHORE C3a2 ADMINISTRATION ,,PR n~TE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... N N N N N N N N N N N N N ENGINEERING APPR DATE 14. Conductor string provided ................... Y(,~ N 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 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... ,,~_N 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ..... ~ ...... 26. BOPE press rating appropriate; test to ~:~c,,'¢,-c,-,' psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... ~NN//'.,~?,2.~/2~'/'7 31. Data presented on potential overpressure zones ....... Y , ,,. 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. /Y N 34. Contact name/phone for weekly ,progress reDo, rts ..... .// Y N ~exp~ora~ory omyj / REMARKS GEOLOGY: ENGINEERING' COMMISSION: RP~~,.--_, JDH BEW/~~/¢ 9 ''~ ' RNC~ DWJ CO Commentsllnstructions: HOW/lit- 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. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... . ............................ * OCT 02 !998 COMPANY NAFIE : B.P. EXPLORATION WELL NA_WlE : MPF-79PB1 FIELD NANiE : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUM~ER : 50-029-22813-70 REFERENCE NO : 97513 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/09/21 ORIGIN : FLIC REEL NAME : 97513 CONTINUATION # : PREVIOUS REEL COM~F2~T : B.P. EXPLORATION, MILNE POINT MPF-79PB1, API #50-029-22813-70 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/09/21 ORIGIN : FLIC TAPE NAME : 97513 CONTINUATION # : 1 PREVIOUS TAPE : COM~tENT · B.P. EXPLORATION, MILNE POINT MPF-79PB1, API #50-029-22813-70 TAPE HEADER MILNE POINT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: BIT RUN 1 97513 BOSSE WILSON TOWNSHIP: RANGE: FNL: FSL: FEL: FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD IST STRING 2ND STRING MPF-79PB1 500292281370 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES 15-SEP-98 BIT RUN 2 BIT RUN 3 6 13N IOE 1919 3064 44.55 11.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. 500 9. 625 7340.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 3RD STRING PRODUCTION STRING REMARKS: Well drilled 10-OCT through 26-0CT-97 with CDR/ADN. Ail data was collected in four bit runs. The well was plugged back at 12630' in the original hole. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIJMBER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (FZEASUREDDEPTH) START DEPTH STOP DEPTH 5339.0 17606.5 BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: .......... EQUIVALENT UNSHIFTED DEPTH .......... ....... BIT RUN NO. MERGE TOP MERGE BASE 1 5339.0 7360.0 2 7148.0 12447.5 3 12320.0 15290.0 4 15165.0 17606.0 No depth adjustments were made to this data as it is the PDC GR for this well. The ADN quadrant outputs are as follows: ROBB/ROBU/ROBL/ROBR are bottom, upper, left, and right quadrant density; and are also listed as RHO1, RH02, RH03, RH04 in the LDWG listing. The other outputs (Delta Rho, PEF) are listed with their quadrants as DRHB/DRHU/DRHL/DRHR, PEB/PEU/PEL/PER. The LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: LDWG outputs of CALA and CALS are HDIA and VDIA respec ti vel3,. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 255 $ 66 6 73 7 65 8 68 O. $ 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OHP~I O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OH~4M O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 RHO1 ~ G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH02 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH03 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH04 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E O0 000 O0 0 1 1 1 4 68 0000000000 CALSMWD IN O0 000 O0 0 1 1 1 4 68 0000000000 CALAMWD IN O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S O0 000 O0 0 1 1 1 4 68 0000000000 TRPMMWD RPM O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: ** DATA ** DEPT. 5339.000 FET.MWD -999.250 RA.MWD -999.250 RP.MWD ROP.MWD -999.250 GR.MWD 61.230 RHO1.MWD -999.250 PJqO2.MWD RHO3.MWD -999.250 RHO4.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALS.MWD -999.250 CALA.MWD -999.250 NPHI.MWD -999.250 TRPM. MWD DEPT. 6000.000 FET.MWD 0.419 RA.MWD 1.070 RP.MWD ROP.MWD 174.760 GR.MWD 34.700 RHO1.MWD -999.250 RHO2.MWD RHO3.MWD -999.250 RHO4.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALS.MWD -999.250 CALA.MWD -999.250 NPHI.MWD -999.250 TRPM. MWD DEPT. 7000.000 FET.MWD 1.056 RA.MWD 2.280 RP.MWD ROP.MWD 316.030 GR.MWD 79.290 RHO1.MWD -999.250 RHO2.MWD RHO3.MWD -999.250 RHO4.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALS.MWD -999.250 CALA.MWD -999.250 NPHI.MWD -999.250 TRPM. MWD DEPT. 8000.000 FET.MWD 0.326 RA.MWD 3.330 RP.MWD ROP.MWD 383.120 GR.MWD 102.870 RHO1.MWD 2.340 RHO2.MWD RHO3.MWD 2.310 RHO4.MWD 2.310 DR3fO.MWD 0.000 PEF.MWD CALS.MWD 10.260 CALA.MWD 10.350 NPHI.MWD 38.000 TRPM. MWD DEPT. 9000.000 FET.MWD 0.830 RA.MWD 2.310 RP.MWD ROP.MWD 168.270 GR.14WD 106.570 RHO1.MWD 2.290 RHO2.MWD RHO3.MWD 2.290 RHO4.MWD 2.290 DRHO.MWD 0.120 PEF. MWD CALS.MWD 8.720 CALA.MWD 7.600 NPHI.MWD 41.000 TRPM. MWD DEPT. 10000.000 FET.MWD 0.622 RA.MWD 3.040 RP.MWD ROP.MWD 189.660 GR.MWD 109.060 RHO1.MWD 2.420 RHO2.MWD RHO3.MWD 2.370 RHO4.MWD 2.380 DRHO.MWD 0.020 PEF.MWD CALS.MWD 9.910 CALA.MWD 10.500 NPHI.MWD 38.000 TRPM.MWD DEPT. 11000.000 FET.MWD 0.786 RA.MWD 2.380 RP.MWD ROP.MWD 207.060 GR.MWD 107.870 RHO1.MWD 2.440 RHO2.MWD RHO3.MWD 2.400 RHO4.MWD 2.390 DRHO.MWD 0.060 PEF.MWD CALS.MWD 11.130 CALA.MWD 11.020 NPHI.MWD 37.000 TRPM. MWD DEPT. 12000.000 FET.MWD 0.498 RA.MWD 3.930 RP.MWD ROP.MWD 230.910 GR.MWD 103.810 RHO1.MWD 2.460 RHO2.MWD RHO3.MWD 2.410 RHO4.MWD 2.390 DRHO.MWD 0.000 PEF. MWD CALS.MWD 8.530 CALA.MWD 8.600 NPHI.MWD 39.000 TRpM. MWD DEPT. 13000.000 FET.MWD 0.600 RA.MWD 3.480 RP.MWD ROP.MWD 142.850 GR.MWD 117.340 RHO1.MWD ~ 2.430 RHO2.MWD RHO3.MWD 2.430 RHO4.MWD 2.430 DRHO.MWD 0.140 PEF.MWD CALS.MWD 7.910 CALA.MWD 8.040 NPHI.MWD 33.000 TRPM. MWD DEPT. 14000.000 FET.MWD 0.377 RA.MWD 4.320 RP.MWD ROP.MWD 225.120 GR.MWD 157.410 RHO1.MWD 2.500 RHO2.MWD RHO3.MWD 2.420 RHO4.MWD 2.420 DRHO.MWD 0.000 PEF.MWD CALS.MWD 8.600 CALA.MWD 8.330 NPHI.MP~ 45.000 TRPM. MWD -999.250 -999.250 -999.250 -999.250 1.370 -999.250 -999.250 -999.250 2.150 -999.250 -999.250 -999.250 3.010 2.260 3.140 112.000 2.730 2.290 2.960 0.000 3. 050 2.390 3. 080 63. 571 2.780 2.400 2.950 59.000 4.680 2.440 3.110 64.250 3.540 2.430 3.070 0.000 7.560 2.390 3.470 59.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: DEPT. 15000.000 FET.MWD ROP.MWD 73.190 GR.MWD RHO3.MWD 2.380 RHO4.MWD CALS.MWD 9.140 CALA.MWD DEPT. 16000.000 FET.MWD ROP.MWD 131.390 GR.MWD RHO3.MWD 2.510 RHO4.MWD CALS.MWD 10.270 CALA.MWD DEPT. 17000.000 FET.MWD ROP.MWD 26.550 GR.MWD RHO3.MWD 2.420 RHO4.MWD CALS.MWD 8.130 CALA.MRrD DEPT. 17606.000 FET.MWD ROP.MWD 19.110 GR.MWD RHO3.MWD -999.250 RHO4.MWD CALS.FfWD -999.250 CALA.MWD 1.201 RA.MWD 130.690 RHO1.MWD 2.380 DRHO.MWD 8.800 NPHI.MWD 0.878 ~RA.MWD 116.260 RHO1.MWD 2.510 DRHO.MWD 10.940 NPHI.MWD 1.205 RA.MWD 81.730 RHO1.MWD 2.420 DRHO.MWD 7.600 NPHI.I~WD -999.250 RA.M~FD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 NPHI.MWD 3.210 RP.MWD 2. 430 RH02 .MWD -0. 010 PEF.MWD 50. 000 TRPM. MWD 3.310 RP.MWD 2. 640 RHO2.MWD O. 090 PEF.MWD 29. 000 TRPM. MWD 16.390 RP.MWD 2. 420 RHO2.MWD O . 010 PEF. MWD 30. 000 TRPM. MWD -999.250 RP.MWD -999.250 RHO2.MWD -999.250 PEF.MWD -999.250 TRPM.MWD 9.970 2.290 3.270 69.000 4.790 2.380 2.700 45.250 19.690 2.420 2.380 0.000 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 98/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 98/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O. 5000 LIS Tape Veri-fication Listing Schlumberger Alaska Computing Center 21-SEP-i998 10:22 PAGE: FILE SU~W~RY VENDOR TOOL CODE START DEPTH MWD 5339.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIM~E) : TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE '. MAXIMUM ANGLE: STOP DEPTH 7360.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 13-NOV-97 REMARKS: ORIGINAL HOLE PLUGGED BACK TO 12630' BIT RUN1 CDR 5410'-7360' BIT RUN2 CDR/ADN 7360'-12447' BIT RUN3 CDR/ADN 12447'- 15290' 5B36 4.0C FH~MORY 18776.0 5339.0 18776.0 60 60.3 69.4 TOOL NUMBER CDR 8039 8.500 7340.0 LSND 10.20 72.0 3.500 67.0 2. 310 67.0 4.250 67.0 20000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: BIT RUN 4 CDR/ADN 15290'- 17606' WELL PASSED HORIZONTAL AT 17500' DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 OH~ O0 000 O0 0 2 1 1 4 68 0000000000 PSR LWl OH~4~ O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW1 F/HR O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI O0 000 O0 0 2 1 1 4 68 0000000000 TAB LW1 HR O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 5338. 500 ATR. LW1 2. 033 GR. LW1 71 . 921 TAB. LW1 O. 000 PSR.LW1 2.131 ROPE. LW1 1947283.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: DEPT. 6000. 000 ATR. LW1 GR . LW1 44. 066 TAB. LW1 DEPT. 7000. 000 ATR . LW1 GR. LW1 99. 091 TAB. LWl DEPT. 7359. 500 ATR. LW1 GR. LW1 126. 298 TAB. LW1 1. 066 0.419 2. 294 1. 056 3. 634 O. 836 PSR . LW1 PSR.LWl PSR.LW1 1.370 ROPE.LW1 2.145 ROPE. LW1 3. 645 ROPE. LWl 191. 481 310.491 110. 422 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 98/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 98/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE VENDOR TOOL CODE START DEPTH MWD 7360.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (M~MORY or REAL-TIME): STOP DEPTH 12447.0 13-NOV-97 5B36 4.0C I~EMORY LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-i998 10:22 PAGE: TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 18776.0 5339.0 18776.0 60 60.3 69.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR ADN AZIM. DEN./NEUT. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): TOOL NUMBER CDR 7045 ADN 045 8.500 7340.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S) : 72.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 3. 500 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2.310 MUD CAKE AT (MT): 4. 250 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 20000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: ORIGINAL HOLE PLUGGED BACK TO 12630' BIT RUN 1 CDR 5410'-7360' BIT RUN 2 CDR/ADN 7360'-12447' BIT RUN 3 CDR/ADN 12447'- 15290' BIT RUN 4 CDR/ADN 15290'- 17606' WELL PASSED HORIZONTAL AT 17500' DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA 67.0 67.0 67.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 100 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 ATR LW2 OP~4~ O0 000 O0 0 3 1 1 4 68 0000000000 PSR LW2 OH~q O0 000 O0 0 3 1 1 4 68 0000000000 ROPE LW2 F/HR O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI O0 000 O0 0 3 1 1 4 68 0000000000 TAB LW2 HR O0 000 O0 0 3 1 1 4 68 0000000000 TABD LW2 O0 000 O0 0 3 1 1 4 68 0000000000 ROBB LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBU LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBL LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBR LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHB LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHU LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHL LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHR LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 PEB LW2 O0 000 O0 0 3 1 1 4 68 0000000000 PEU LW2 O0 000 O0 0 3 1 1 4 68 0000000000 PEL LW2 O0 000 O0 0 3 1 1 4 68 0000000000 PER LW2 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH LW2 PU O0 000 O0 0 3 1 1 4 68 0000000000 TNRA LW2 O0 000 O0 0 3 1 1 4 68 0000000000 DCAL LW2 IN O0 000 O0 0 3 1 1 4 68 0000000000 HDIA LW2 IN O0 000 O0 0 3 1 1 4 68 0000000000 VDIA LW2 IN O0 000 O0 0 3 1 1 4 68 0000000000 RPM LW2 RPM O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: 11 ** DATA ** DEPT. 7148. 000 ATR. LW2 GR. LW2 52. 089 TAB. LW2 ROBU. LW2 2. 323 ROBL. LW2 DRHU . LW2 -0.285 DRHL . LW2 PEU. LW2 16.306 PEL. LW2 TNRA. LW2 28.472 DCAL. LW2 RPM. LW2 19. 000 DEPT. GR. LW2 ROBU. LW2 DRHU. LW2 PEU. LW2 TNRA . LW2 RPM. LW2 DEPT. GR.LW2 ROBU. LW2 DRHU. LW2 PEU. LW2 TNRA. LW2 RPM. LW2 DEPT. GR. LW2 ROBU. LW2 DRHU. LW2 PEU. LW2 TNRA . LW2 RPM. LW2 DEPT. GR.LW2 ROBU. LW2 DRHU. LW2 PEU. LW2 TNRA. LW2 RPM. LW2 DEPT. GR. LW2 ROBU. LW2 DRHU. LW2 PEU. LW2 TNRA . LW2 RPM. LW2 8000 000 ATR. LW2 102 867 TAB.LW2 2 2 63 ROBL. LW2 0 139 DRHL.LW2 2 834 PEL. LW2 22 884 DCAL. LW2 112 000 9000 000 ATR LW2 106 572 TAB LW2 2 291 ROBL LW2 0 117 DRHL LW2 2 962 PEL LW2 23 839 DCAL LW2 0 000 10000 000 ATR.LW2 109 061 TAB.LW2 2 388 ROBL.LW2 0 094 DRHL.LW2 3 087 PEL.LW2 22 776 DCAL.LW2 63 571 11000 000 ATR.LW2 107 866 TAB.LW2 2 398 ROBL. LW2 0 1 O1 DRHL. LW2 2 791 PEL. LW2 22 368 DCAL.LW2 59 000 12000 000 ATR.LW2 103 810 TAB.LW2 2 444 ROBL. LW2 0 081 DRHL. LW2 3 176 PEL. LW2 23 265 DCAL. LW2 64 250 0 304 PSR.LW2 0 000 TABD.LW2 2 348 ROBR.LW2 -0 300 DRHR.LW2 16 037 PER.LW2 0 000 P~DIA.LW2 3 334 PSR.LW2 0 326 TABD.LW2 2 310 ROBR.LW2 0 071 DRHR.LW2 2 955 PER. LW2 0 013 I{DIA.LW2 2.312 PSR.LW2 O . 830 TABD . LW2 2. 291 ROBR. LW2 0.117 DRHR . LW2 2. 962 PER.LW2 O. 013 PZDIA.LW2 3. 044 PSR.LW2 O . 622 TABD. LW2 2.373 ROBR. LW2 O. 057 DRHR. LW2 3. 008 PER.LW2 O. O13 HDIA. LW2 2.382 PSR.LW2 O. 786 TABD. LW2 2. 400 ROBR. LW2 O. 074 DRHR. LW2 2. 860 PER.LW2 O. O13 HDIA. LW2 3. 928 PSR. LW2 O. 498 TABD. LW2 2.409 ROBR. LW2 O. 028 DRHR. LW2 3. 422 PER. LW2 O . 014 BiDIA. LW2 2. 855 ROPE. LW2 O. 000 ROBB. LW2 2. 436 DRHB.LW2 - 0 . 323PEB. LW2 17. 487 TNPH. LW2 8. 805 VDIA. LW2 3. 015 ROPE. LW2 1678. 000 ROBB.LW2 2.307 DRHB . LW2 O. 073 PEB.LW2 2.791 TNPH. LW2 10. 350 VDIA. LW2 2. 729 ROPE. LW2 5648. 000 ROBB.LW2 2.291 DRHB . LW2 O . 117 PEB . LW2 2. 962 TNPH. LW2 7. 601 VDIA. LW2 3. 045 ROPE. LW2 3200. 000 ROBB. LW2 2.379 DRHB . LW2 O . 032 PEB . LW2 2. 878 TNPH.LW2 10. 496 VDIA. LW2 2. 776 ROPE.LW2 4063 . 219 ROBB. LW2 2.394 DRHB. LW2 O. 079 PEB.LW2 2.974 TNPH. LW2 11. O18 VDIA. LW2 4. 685 ROPE. LW2 3150. 563 ROBB. LW2 2.388 DRHB.LW2 O. O16 PEB. LW2 3.231 TNPH. LW2 8. 602 VDIA. LW2 -999. 250 2. 429 -0.315 17. 439 54. 605 8. 868 383.122 2.337 -0. 001 3.143 38.195 10.256 168.267 2.291 0.117 2. 962 41. 024 8. 717 189. 661 2.417 O. 017 3. 076 37. 883 9. 905 207. 064 2. 438 O. 063 2. 952 36. 727 11.126 230. 908 2. 458 -0. 004 3. 114 39. 303 8.535 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: 12 DEPT. 12447 . 500 ATR. LW2 GR. LW2 96. 505 TAB. LW2 ROBU. LW2 2. 429 ROBL. LW2 DRHU. LW2 O. 055 DRHL. LW2 PEU. LW2 2. 748 PEL.LW2 TN-RA. LW2 21 . 831 DCAL. LW2 RPM. LW2 O. 000 4. O15 PSR. LW2 1. 492 TABD.LW2 2 . 429 ROBR. LW2 O. 055 DRHR. LW2 2.748 PER. LW2 O. O13 I{DIA. LW2 4.143 ROPE. LW2 11836.531 ROBB.LW2 2. 428 DRHB.LW2 O . 051 PEB . LW2 2. 755 TNPH. LW2 8.135 VDIA. LW2 53. 264 2. 430 0. 058 2. 738 35.249 7. 842 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SD2wJ4ARY VENDOR TOOL CODE START DEPTH MWD 12447.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : STOP DEPTH 15290.0 13-NOV-97 5B36 4.0C MiEMORY 18776.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: 13 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 5339.0 18776.0 6O CDR RESIST./GR ADN AZIM. DEN./NEUT. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 60.3 69.4 TOOL NUblBER CDR 7045 ADN 045 8.500 7340.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S) : 72.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~Pq) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 3. 500 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2.310 MUD CAKE AT (MT): 4. 250 20000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REM_ARKS: ORIGINAL HOLE PLUGGED BACK TO 12630' BIT RUN 1 CDR 5410'-7360' BIT RUN 2 CDR/ADN 7360'-12447' BIT RUN 3 CDR/ADN 12447'- 15290' BIT RUN 4 CDR/ADN 15290'- 17606' WELL PASSED HORIZONTAL AT 17500' DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA 67.0 67.0 67.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: 14 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 100 4 66 255 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD 1913MB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 4 1 1 4 68 0000000000 ATR LW3 OH~4~ O0 000 O0 0 4 1 1 4 68 0000000000 PSR LW3 Ot{MM O0 000 O0 0 4 1 1 4 68 0000000000 ROPE LW3 F/HR O0 000 O0 0 4 1 1 4 68 0000000000 GR LW3 GAPI O0 000 O0 0 4 1 1 4 68 0000000000 TAB LW3 HR O0 000 O0 0 4 1 1 4 68 0000000000 TABD LW3 O0 000 O0 0 4 1 1 4 68 0000000000 ROBB LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 ROBU LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 ROBL LW3 G/CS O0 000 O0 0 4 1 1 4 68 0000000000 ROBR LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 DRHB LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 DRHU LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 DRHL LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 DRHR LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 PEB LW3 O0 000 O0 0 4 1 1 4 68 0000000000 PEU LW3 O0 000 O0 0 4 1 1 4 68 0000000000 PEL LW3 O0 000 O0 0 4 1 1 4 68 0000000000 PER LW3 O0 000 O0 0 4 1 1 4 68 0000000000 TNPH LW3 PU O0 000 O0 0 4 1 1 4 68 0000000000 TNRA LW3 O0 000 O0 0 4 1 1 4 68 0000000000 DCAL LW3 IN O0 000 O0 0 4 ! 1 4 68 0000000000 HDIA LW3 IN O0 000 O0 0 4 1 1 4 68 0000000000 VDIA LW3 IN O0 000 O0 0 4 1 1 4 68 0000000000 RPM LW3 RPM O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: 15 ** DATA ** DEPT. 12320. 500 ATR . LW3 3 . 906 PSR. LW3 3. 833 ROPE. LW3 GR.LW3 88.131 TAB.LW3 O. 000 TABD.LW3 O. 000 ROBB.LW3 ROBU. LW3 2.333 ROBL.LW3 2.245 ROBR.LW3 2.314 DRHB.LW3 DRHU. LW3 0.171 DRHL . LW3 0.155 DRHR . LW3 0.144 PEB . LW3 PEU. LW3 3.357 PEL.LW3 3.239 PER.LW3 2.967 TNPH. LW3 TNRA.LW3 21.307 DCAL.LW3 0.000 ~DIA.LW3 9.269 VDIA.LW3 RPM. LW3 43. 000 DEPT. 13000.000 ATR.LW3 3.478 PSR.LW3 3.541 ROPE.LW3 GR.LW3 117.342 TAB.LW3 0.600 TABD.LW3 5934.000 ROBB.LW3 ROBU. LW3 2. 426 ROBL. LW3 2. 426 ROBR. LW3 2.42 6 DRHB. LW3 DRHU. LW3 O . 136 DRHL . LW3 O . 13 6 DRHR . LW3 O . 13 6 PEB . LW3 PEU. LW3 3. 070 PEL.LW3 3. 070 PER.LW3 3 . 070 TNPH. LW3 TNRA.LW3 20. 868 DCAL.LW3 O. 000 HDIA.LW3 8. 040 VDIA.LW3 RPM. LW3 O. 000 DEPT. 14000. 000 ATR.LW3 4. 316 PSR.LW3 7.565 ROPE. LW3 GR.LW3 157. 408 TAB.LW3 0.377 TABD.LW3 3828.000 ROBB.LW3 ROBU. LW3 2.387 ROBL.LW3 2. 419 ROBR.LW3 2. 423 DRHB.LW3 DRHU. LW3 O . 137 DRHL . LW3 O . 064 DRHR . LW3 O . 034 PEB . LW3 PEU. LW3 3. 077 PEL.LW3 3 . 033 PER.LW3 3.186 TNPH. LW3 TNRA.LW3 25.153 DCAL.LW3 0.013 HDIA.LW3 8.335 VDIA.LW3 RPM. LW3 59. 000 DEPT. 15000.000 ATR.LW3 3.214 PSR.LW3 9.974 ROPE.LW3 GR.LW3 130. 694 TAB.LW3 1.201 TABD.LW3 6384. 000 ROBB.LW3 ROBU. LW3 2.292 ROBL.LW3 2.382 ROBR.LW3 2.380 DRHB.LW3 DRHU. LW3 0.219 DRHL.LW3 O. 086 DRHR.LW3 O. 049 PEB.LW3 PEU. LW3 3.592 PEL.LW3 3.300 PER.LW3 3.643 TNPH. LW3 TNRA.LW3 26. 417 DCAL.LW3 O. 013 HI)IA.LW3 8. 802 VDIA.LW3 RPM. LW3 69. 000 DEPT. 15290. 000 ATR. LW3 2. 993 PSR . LW3 5. 925 ROPE. LW3 GR.LW3 150.462 TAB.LW3 0.617 TABD.LW3 4370.000 ROBB.LW3 ROBU. LW3 2.438 ROBL. LW3 2. 491 ROBR. LW3 2. 454 DRHB. LW3 DRHU. LW3 0.146 DRHL.LW3 0.072 DRHR.LW3 0.027 PEB.LW3 PEU. LW3 3. 696 PEL.LW3 3. 090 PER.LW3 3. 079 TNPH.LW3 TNRA.LW3 22.675 DCAL.LW3 0.014 HDIA.LW3 8.401 VDIA.LW3 RPM. LW3 67.143 -999.250 2.443 0.067 2.915 33.845 9.335 142. 850 2. 426 0.136 3.070 32.698 7.911 225.121 2.499 -0.002 3.470 45.206 8.602 73.192 2.425 -0.006 3.268 49.594 9.135 119.286 2.494 0.005 2.882 37.593 8.806 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: 16 * * * * FILE TRAILER * ** * FILE NANiE : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 98/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE : 98/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREFiENT : O . 5000 FILE SUb~qARY VENDOR TOOL CODE START DEPTH STOP DEPTH 15290.0 17606.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIldE) 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 CDR RESIST./GR ADN AZIM. DEN./NEUT. $ 13-NOV-97 5B36 4.0C MEMORY 18776.0 5339.0 18776.0 60 60.3 69.4 TOOL NUMBER CDR 7045 ADN 045 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: 17 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 8.500 7340.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S) : 72.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHFff4) AT TEMPERATTrRE (DEGF): MUD AT MEASURED TEMPERATURE (MT): 3.500 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2.310 MUD CAKE AT (MT): 4. 250 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: ORIGINAL HOLE PLUGGED BACK TO 12630' BIT RUN 1 CDR 5410'-7360' BIT RUN 2 CDR/ADN 7360'-12447' BIT RUN 3 CDR/;2~N 12447'- 15290' BIT RUN 4 CDR/ADN 15290'- 17606' WELL PASSED HORIZONTAL AT 17500' DATA FROM DOWNHOLE M~MORY, V4. OC SOFTWARE $ LIS FORMAT DATA 67.0 67.0 67.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 100 4 66 255 5 66 6 73 7 65 8 68 O. 5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: 18 TYPE REPR CODE VALUE 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE ~ NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NI]M~ SAMP ELE~ CODE (HEX) DEPT FT A TR LW4 OH~I PSR LW4 OH~I ROPE LW4 F/HR GR LW4 GAPI TAB LW4 HR TABD LW4 ROBB LW4 G/C3 ROBU LW4 G/C3 ROBL LW4 G/C3 ROBR LW4 G/C3 DRHB LW4 G/C3 DRHU LW4 G/C3 DRHL LW4 G/C3 DRHR LW4 G/C3 PEB LW4 PEU LW4 PEL LW4 PER LW4 TNPH LW4 PU TNRA LW4 DCAL LW4 IN HDIA LW4 IN VDIA LW4 IN RPM LW4 RPM O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 O0 000 O0 0 5 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 15165. 000 ATR. LW4 2. 939 PSR.LW4 4. 811 ROPE. LW4 GR.LW4 137.290 TAB.LW4 O. 000 TABD.LW4 O. 000 ROBB.LW4 ROBU. LW4 1. 952 ROBL. LW4 1. 994 ROBR. LW4 2. 252 DRHB. LW4 DRHU. LW4 0.173 DRHL.LW4 O. 045 DR3{R.LW4 O. 051 PEB.LW4 PEU. LW4 3.206 PEL.LW4 3.261 PER.LW4 2.966 TNPH.LW4 TNRA.LW4 27. 004 DCAL.LW4 O. 000 RDIA.LW4 11. 069 VDIA.LW4 RPM. LW4 82. 000 4327. 927 2. 476 O. 024 2. 662 51. 063 10. 536 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: 19 DEPT. 16000. 000 ATR. LW4 GR. LW4 116. 257 TAB. LW4 ROBU. LW4 2.378 ROBL . LW4 DRHU. LW4 O . 071 DRHL . LW4 PEU. LW4 2. 572 PEL. LW4 TNRA.LW4 19.430 DCAL.LW4 RPM. LW4 45 . 250 DEPT. 17000. 000 ATR. LW4 GR. LW4 81. 727 TAB. LW4 ROBU. LW4 2.416 ROBL. LW4 DRHU. LW4 O . O11 DRHL . LW4 PEU. LW4 2.383 PEL. LW4 TNRA. LW4 19. 878 DCAL. LW4 RPM. LW4 O . 000 DEPT. 17606. 500 ATR. LW4 GR. LW4 121.104 TAB. LW4 ROBU. LW4 2. 322 ROBL. LW4 DRHU. LW4 O . 000 DRHL . LW4 PEU. LW4 1.983 PEL . LW4 TNRA. LW4 19. 595 DCAL. LW4 RPM. LW4 O . 000 3 306 0 878 2 508 0 119 2 718 0 013 16.393 1.205 2.416 O. 011 2. 383 O. 000 3.216 1. 444 2. 315 O. 000 1. 962 O. 014 PSR.LW4 TABD. LW4 ROBR. LW4 DR3{R . LW4 PER. LW4 ~ZDIA . LW4 PSR. LW4 TABD. LW4 ROBR. LW4 DRHR . LW4 PER.LW4 PiDIA. LW4 PSR. LW4 TABD. LW4 ROBR. LW4 DRHR . LW4 PER. LW4 H~IA. LW4 4. 791 ROPE. LW4 5028. 000 ROBB.LW4 2. 513 DRHB . LW4 O. 023 PEB. LW4 2.540 TNPH. LW4 10. 936 VDIA. LW4 19. 688 ROPE. LW4 7822. 000 ROBB. LW4 2. 416 DRHB.LW4 O . 011 PEB . LW4 2.383 TNPH. LW4 7. 601 VDIA. LW4 3.206 ROPE. LW4 6230. 000 ROBB. LW4 2.313 DRHB . LW4 0.000 PEB.LW4 1.957 TNPH. LW4 7. 935 VDIA. LW4 131.387 2.642 0.093 2.699 29.122 10.269 26. 551 2. 416 O. 011 2. 383 30.209 8.127 16.499 2.315 0.000 1.962 29.520 7.601 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 98/09/21 ORIGIN · FLIC TAPE NAME : 97513 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : B.P. EXPLORATION, MILNE POINT MPF-79PB1, API #50-029-22813-70 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-SEP-1998 10:22 PAGE: 2O **** REEL TRAILER **** SERVICE NAM~ : EDIT DATE : 98/09/21 ORIGIN : FLIC REEL NAME : 97513 CONTINUATION # .' PREVIOUS REEL : COM~E2qT : B.P. EXPLORATION, MILNE POINT MPF-79PB1, API #50-029-22813-70 * ALASKA COMPUTING CENTER . . ............................ * ....... SCHLUMBERGER ....... . ............................ COMPANY NAI~E : B.P. EXPLORATION WELL NAFiE : MPF-79 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE · ALASKA API NUM~ER : 50-029-22813-00 REFERENCE NO : 97536 oate~ LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/09/15 ORIGIN ' FLIC REEL NAFiE : 97536 CONTINUATION # : PREVIOUS REEL : CO~9~EIVT : B.P. EXPLORATION, MILNE POINT MPF-79, API #50-029-22813-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/09/15 ORIGIN · FLIC TAPE NAI~E : 97536 CONTINUATION # : 1 PREVIOUS TAPE : COFk~_2Fr : B.P. EXPLORATION, MILNE POINT MPF-79, API #50-029-22813-00 TAPE HEADER MILNE POINT 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 O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MPF-79 500292281300 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES 15-SEP-98 BIT RUN 1 97536 BOSSE WILSON BIT RUN 2 BIT RUN 3 6 13N 10E 1919 3064 44.55 11.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. 500 9. 625 7340.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 3RD STRING PRODUCTION STRING Well drilled 02-NOV through 13-NOV-97 with CDR/ADN. All data was collected in five bit runs. The final well was sidetracked at 12630' in the original hole. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 1 EDITED~4~RGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUFk~ARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 5339.0 18775.5 BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD BIT RUN NO. MERGE TOP MERGE BASE 1 5339.0 7360.0 2 7148.0 12447.5 3 12320.0 12630.0 4 12488.0 13950.0 5 13787.0 18775.5 No depth adjustments were made to this data as it is the PDC GR for this well. This file does not contain the Very Enhanced QRO resisitivity with 2' average due to deviation beyond horizontal. The ADN quadrant outputs are as follows: ROBB/ROBU/ROBL/ROBR are bottom, upper, left, and right quadrant density; and are also listed LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: as RHO1, RH02, RH03, RH04 in the LDWG listing. The other outputs (Delta Rho, PEF) are listed with their quadrants as DRHB/DRHU/DRHL/DRH~, PEB/PEU/PEL/PER. The LDWG outputs of CALA and CALS are HDIA and VDIA respectively. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NTJMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OH~ O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OPI~ O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 RHO1 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH02 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH03 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 Rtt04 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E O0 000 O0 0 1 1 1 4 68 0000000000 CALSMWD IN O0 000 O0 0 1 1 1 4 68 0000000000 CALAMWD IN O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) NPHIMWD PU-S O0 000 O0 0 1 1 1 4 68 0000000000 TRPMMWD RPM O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 5339,000 FET.MWD -999.250 RA.MWD -999.250 RP.MWD ROP.MWD -999,250 GR.MWD 61.230 RHO1.MWD -999.250 RtIO2.MWD RHO3.MWD -999,250 RHO4.MW -999.250 DRHO.MWD -999.250 PEF.MWD CALS.MWD -999,250 CALA.MWD -999.250 NPHI.MWD -999.250 TRPM. MWD DEPT. 6000.000 FET.MWD 0.419 RA.MWD 1.070 RP.MWD ROP.MWD 174,760 GR.MWD 34.700 RHO1.MWD -999.250 RHO2.MWD RHO3.MWD -999,250 RHO4.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALS.MWD -999,250 CALA.MWD -999.250 NPHI.MWD -999.250 TRPM. MWD DEPT. 7000,000 FET.MWD 1.056 RA.MWD 2.280 RP.MWD ROP.MWD 316,030 GR.MWD 79.290 RHO1.MWD -999.250 RHO2.MWD RHO3.MWD -999,250 RHO4.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALS.MWD -999,250 CALA.MWD -999.250 NPHI.MWD -999.250 TRPM. MWD DEPT. 8000,000 FET.MWD 0,326 RA.MWD 3.330 RP.MWD ROP.MWD 383,120 GR.MWD 102.870 RHO1.MWD 2,340 RHO2.MWD RHO3.MWD 2,310 RHO4.MWD 2.307 DRHO.MWD 0.000 PEF.MWD CALS.MWD 10,260 CALA.MWD 10.350 NPHI.MWD 38.000 TRPM. MWD DEPT. 9000,000 FET.MWD 0.830 RA.MWD 2.310 RP.MWD ROP.MWD 168,270 GR.MWD 106.570 RHO1.MWD 2.290 RHO2.MWD RHO3.MWD 2,291 RHO4.MWD 2.291 DRHO.MWD 0.120 PEF.MWD CALS.MWD 8,720 CALA.MWD 7.600 NPHI.MWD 41.000 TRPM.MWD DEPT. 10000. 000 FET.MWD O. 622 RA.MWD 3. 040 RP.MWD ROP.MWD 189. 660 GR.MWD 109. 060 RHO1 .MWD 2. 420 RH02 .MWD RHO3 .MWD 2,373 RHO4 .MWD 2.379 DRHO.MWD 0.020 PEF.MWD CALS.MWD 9. 910 CALA.MWD 10. 500 NPHI.MWD 38. 000 TRPM. MWD DEPT. 11000.000 FET.MWD 0.786 RA.MWD 2.380 RP.MWD ROP.MWD 207.060 GR.MWD 107.870 RHO1.MWD 2.440 RHO2.MWD RHO3.MWD 2.400 RHO4.MWD 2.394 DRHO.MWD 0.060 PEF.MWD CALS.MWD 11,130 CALA.MWD 11,020 NPHI.MWD 37.000 TRPM.MWD DEPT. 12000.000 FET.MWD 0.498 RA.MWD 3.930 RP.MWD ROP.MWD 230.910 GR.MWD 103.810 RHO1.MWD 2.460 RHO2.MWD RHO3.MWD 2.409 RHO4.MWD 2.388 DRHO.MWD 0.000 PEF.MWD CALS.MWD 8,530 CALA.MWD 8.600 NPHI.MWD 39.000 TRPM. MWD DEPT. 13000.000 FET.MWD 1.392 RA.MWD 3.383 RP.MWD ROP.MWD 28.760 GR.MWD 119.009 RHO1.MWD 2.360 RHO2.MWD RHO3.MWD 2.450 RHO4.MWD 2.410 DRHO.MWD 0.030 PEF.MWD CALS.MWD 7.601 CALA.MWD 8.488 NPHI.MWD 36.000 TRPM. MWD -999.250 -999.250 -999.250 -999.250 1.370 -999.250 -999.250 -999.250 2,150 -999,250 -999.250 -999.250 3.010 2.263 3.140 112,000 2. 730 2. 291 2. 960 O. 000 3. 050 2.388 3. 080 63. 571 2.780 2.398 2.950 59.000 4.680 2.444 3.110 64.250 3.481 2.400 3.870 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: DEPT. 14000.000 FET.MWD ROP.MWD 119.200 GR.MWD RHO3.MWD 2.430 RHO4.MWD CALS.MWD 8.535 CALA.MWD DEPT. 15000.000 FET.MWD ROP.MWD 125.840 GR.MWD RHO3.MWD 2.390 RHO4.MWD CALS.MWD 8.868 CALA.MWD DEPT. 16000.000 FET.MWD ROP.MWD 18.520 GR.MWD RHO3.MWD 2.320 RHO4.MWD CALS.MWD 8.802 CALA.MWD DEPT. 17000.000 FET.MWD ROP.MWD 127.740 GR.MWD RHO3.MWD 2.460 RHO4.MWD CALS.MWD 8.710 CALA.MWD DEPT. 18000.000 FET.MWD ROP.MWD 36.510 GR.MWD RHO3.MWD 2.150 RHO4.MWD CALS.MWD 8.468 CALA.MWD DEPT. 18775.500 FET.MWD ROP.MWD 75.310 GR.MWD RHO3.MWD -999.250 RHO4.MWD CALS.MWD -999.250 CALA.MWD 1.069 RA.MWD 185.072 RHO1.MWD 2.420 DRHO.MWD 8.468 NPHI.MWD 0.658 R~.MWD 145.540 RHO1.MWD 2.450 DRHO.MWD 8.935 NPHI.MWD 0.806 RA.MWD 91.733 RHO1.MWD 2.360 DRHO.MWD 8.802 NPHI.MWD 1.830 RA.MWD 119.297 RHO1.MWD 2.590 DRHO.MWD 8.868 NPHI.MWD 1.406 RA.MWD 63.521 RHO1.MWD 2.180 DRHO.MWD 8.468 NPHI.MWD -999.250 RA.MWD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 NPHI.MWD 4. 829 RP.MWD 2.380 RHO2.MWD 0.150 PEF.MWD 49. 000 TRPM. MWD 3.174 RP.MWD 2.400 RHO2.MWD 0.020 PEF.MWD 48.000 TRPM. MWD 13. 625 RP.MWD 2. 400 RH02 .MWD -0. 020 PEF. MWD 28. 000 TRPM. MWD 3.262 RP . MWD 2. 540 RH02 .MWD O . 010 PEF. MWD 31. 000 TRPM. MWD 38.798 RP.MWD 2.330 RHO2.MWD 0.040 PEF.MWD 35.000 TRPM. MWD -999.250 RP.MWD -999.250 RHO2.MWD -999.250 PEF. MWD -999.250 TRPM. MWD 11. 019 2. 360 4.530 73. 000 8.653 2.420 3.560 59.500 16.506 2.380 2.590 60.000 3.854 2.470 3.110 81.300 64. 949 2.210 3. 520 82. 000 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: FILE HEADER FILE AU3MBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMeNT: 0.5000 FILE SUM~Nh~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 5339.0 7360.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) '. BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH : MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OPH~4) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 13-NOV-97 5B36 4.0C ~fbl~ORY 18776.0 5339.0 18776.0 60 60.3 69.4 TOOL NUMBER ........... CDR 7045 8.500 7340.0 LSND 10.90 72.0 1.660 70.0 0.970 70.0 1.930 70.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: TOOL STANDOFF (IN) EWR FREQUENCY (HZ) 20000 RE~UUA~S: ORIGINAL HOLE SIDETRACKED AT 12630' BIT RUN 1 CDR 5410'-7360' BIT RUN 2 CDR/ADN 7360'-12447' BIT RUN 3 CDR/ADN 12447'- SIDETRACK POINT BIT RUN4 CDR/ADN 12630'-13955' BIT RUN5 CDR/ADN 13955'-18776' WELL PASSED HORIZONTALAT 17500' DATA FROM DOWNHOLE MEMOR~ V4. OC SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 OHM~ O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW1 OH~4 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW1 F/HR O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI O0 000 O0 0 2 1 1 4 68 0000000000 TAB LW1 HR O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: ** DATA ** DEPT. 5338.500 A TR . LW1 GR. LW1 71. 921 TAB. LW1 DEPT. 6000. 000 ATR. LW1 GR. LW1 44. 066 TAB. LW1 DEPT. 7000. 000 ATR . LW1 GR. LW1 99. 091 TAB. LW1 DEPT. 7359. 500 A TR . LW1 GR. LW1 126. 298 TAB. LW1 2. 033 0.000 1. 066 0.419 2. 294 1. 056 3. 634 O. 836 PSR.LW1 PSR.LW1 PSR. LW1 PSR. LWl 2.131 ROPE. LW1 1.370 ROPE. LW1 2.145 ROPE. LW1 3. 645 ROPE. LW1 1947283.000 191. 481 310. 491 110.422 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NA~E : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 7148.0 12447.5 $ LOG HEADER DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: DATE LOGGED: SOFTWARE '. SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 13-NOV-97 5B36 4.0C FI~MORY 18776.0 5339.0 18776.0 60 64.9 80.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR ADN AZIM. DEN./NEUT. $ TOOL NUM~ER CDR 7045 ADN 044 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 7340.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.90 MUD VISCOSITY (S) : 72.0 MUD PH: MUD CHLORIDES (PPM) : 800 FLUID LOSS (C3): RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 1. 660 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): O. 970 MUD CAKE AT (MT): 1.930 70.0 70.0 70.0 NEUTRON TOOL MA TRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN) '. TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 ORIGINAL HOLE SIDETRACKED AT 12630' BIT RUN 1 CDR 5410'-7360' BIT RUN 2 CDR/ADN 7360'-12447' BIT RUN 3 CDR/ADN 12447'- SIDETRACK POINT BIT RUN 4 CDR/ADN 12630'-13955' BIT RUN 5 CDR/ADN 13955'-18776' WELL PASSED HORIZONTAL AT 17500' DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: 10 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 100 4 66 255 5 66 6 73 7 8 9 11 12 13 14 15 16 0 0.5 FT 10 65 68 65 66 68 66 0 65 FT 66 68 66 1 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NTgMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 ATR LW2 OH~M O0 000 O0 0 3 1 1 4 68 0000000000 PSR LW2 OH~M O0 000 O0 0 3 1 1 4 68 0000000000 ROPE LW2 F/HR O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI O0 000 O0 0 3 1 1 4 68 0000000000 TAB LW2 HR O0 000 O0 0 3 1 1 4 68 0000000000 TABD LW2 O0 000 O0 0 3 1 1 4 68 0000000000 ROBB LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBU LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBL LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBR LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHB LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHU LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHL LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHR LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 PEB LW2 O0 000 O0 0 3 1 1 4 68 0000000000 PEU LW2 O0 000 O0 0 3 1 1 4 68 0000000000 PEL LW2 O0 000 O0 0 3 1 1 4 68 0000000000 PER LW2 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH LW2 PU O0 000 O0 0 3 1 1 4 68 0000000000 TNRA LW2 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: 11 NAM~ SERV UNIT SERVICE API API API API FILE NUf4B NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DCAL LW2 IN O0 000 O0 0 3 1 1 4 68 0000000000 P~DIA LW2 IN O0 000 O0 0 3 1 1 4 68 0000000000 VDIA LW2 IN O0 000 O0 0 3 1 1 4 68 0000000000 RPM LW2 RPM O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 7148.000 ATR.LW2 0.304 PSR.LW2 2.855 ROPE.LW2 -999.250 GR.LW2 52. 089 TAB.LW2 O. 000 TABD.LW2 O. 000 ROBB.LW2 2. 429 ROBU. LW2 2.323 ROBL.LW2 2.348 ROBR.LW2 2. 436 DRHB.LW2 -0.315 DPJ4U. LW2 -0.285 DRHL.LW2 -0.300 DRHR.LW2 -0.323 PEB.LW2 17. 439 PEU. LW2 16.306 PEL.LW2 16. 037 PER.LW2 17. 487 TNPH.LW2 54. 605 TNRA.LW2 28. 472 DCAL.LW2 O. 000 t{DIA.LW2 8. 805 VDIA.LW2 8. 868 RPM. LW2 19. 000 DEPT. 8000. 000 ATR. LW2 GR. LW2 102. 867 TAB. LW2 ROBU. LW2 2. 263 ROBL. LW2 DRHU. LW2 O . 139 DRHL . LW2 PEU. LW2 2.834 PEL. LW2 T1VRA. LW2 22. 884 DCAL. LW2 RPM. LW2 112. 000 DEPT. 9000. 000 ATR. LW2 GR. LW2 106. 572 TAB . LW2 ROBU. LW2 2. 291 ROBL . LW2 DRHU. LW2 O . 117 DRHL . LW2 PEU. LW2 2. 962 PEL. LW2 TNRA . LW2 23. 839 DCAL . LW2 RPM. LW2 O. 000 DEPT. GR. LW2 ROBU. LW2 DRHU. LW2 PEU. LW2 TNRA. LW2 RPM. LW2 DEPT. GR. LW2 ROBU. LW2 DRHU. LW2 PEU. LW2 TNRA . LW2 RPM. LW2 10000 000 ATR.LW2 109 061 TAB.LW2 2 388 ROBL. LW2 0 094 DRHL. LW2 3 087 PEL. LW2 22 776 DCAL. LW2 63 571 11000. 000 ATR. LW2 107. 866 TAB. LW2 2. 398 ROBL. LW2 O . 1 O1 DRHL. LW2 2. 791 PEL. LW2 22.368 DCAL. LW2 59. 000 3.334 PSR.LW2 3 015 ROPE.LW2 0.326 TABD.LW2 1678 000 ROBB.LW2 2.310 ROBR.LW2 2 307 DRHB.LW2 0.071 DRH~.LW2 0 073 PEB.LW2 2. 955 PER. LW2 2 791 TNPH. LW2 0.013 HDIA.LW2 10 350 VDIA.LW2 383.122 2.337 -0. 001 3.143 38.195 10.256 2. 312 PSR. LW2 2. 729 ROPE. LW2 O. 830 TABD.LW2 5648. 000 ROBB.LW2 2. 291 ROBR. LW2 2. 291 DRHB. LW2 O . 117 DRHR . LW2 O . 117 PEB . LW2 2. 962 PER. LW2 2. 962 TNPH. LW2 O. 013 HDIA. LW2 7. 601 VDIA. LW2 168.267 2. 291 0.117 2. 962 41. 024 8. 717 3. 044 PSR.LW2 3. 045 ROPE.LW2 O. 622 TABD. LW2 3200. 000 ROBB. LW2 2.373 ROBR. LW2 2.379 DRHB. LW2 O. 057 DRHR. LW2 O. 032 PEB. LW2 3. 008 PER.LW2 2. 878 TNPH. LW2 O. 013 PIDIA.LW2 10. 496 VDIA.LW2 189. 661 2. 417 O. 017 3.076 37. 883 9.9O5 2.382 PSR.LW2 2. 776 ROPE.LW2 O. 786 TABD.LW2 4063.219 ROBB.LW2 2. 400 ROBR.LW2 2.394 DRHB.LW2 0.074 DRHR.LW2 0.079 PEB.LW2 2.860 PER.LW2 2.974 TNPH.LW2 O. 013 I{DIA.LW2 11 . 018 VDIA.LW2 207. 064 2. 438 O. 063 2. 952 36. 727 11.126 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-i998 15:18 PAGE: 12 DEPT. 12000 . 000 ATR. LW2 GR. LW2 103.810 TAB. LW2 ROBU. LW2 2.444 ROBL. LW2 DRHU. LW2 0.081 DRHL . LW2 PEU. LW2 3.176 PEL. LW2 TNRA. LW2 23.2 65 DCAL. LW2 RPM. LW2 64. 250 DEPT. 12447. 500 ATR. LW2 GR. LW2 96.505 TAB. LW2 ROBU. LW2 2. 429 ROBL. LW2 DRHU. LW2 O. 055 DRHL. LW2 PEU. LW2 2. 748 PEL. LW2 TNRA. LW2 21 . 831 DCAL. LW2 RPM. LW2 O. 000 3.928 PSR. LW2 O. 498 TABD. LW2 2.409 ROBR . LW2 O. 028 DRHR. LW2 3. 422 PER. LW2 0 . O14 HDIA. LW2 4. 015 PSR . LW2 1. 492 TABD. LW2 2. 429 ROBR. LW2 O . 055 DRHR . LW2 2.748 PER. LW2 O. 013 HI)IA.LW2 4. 685 ROPE. LW2 3150. 563 ROBB. LW2 2.388 DRHB. LW2 O . O16 PEB . LW2 3.231 TNPH. LW2 8. 602 VDIA . LW2 4. 143 ROPE. LW2 11836.531 ROBB.LW2 2. 428 DRHB. LW2 O. 051 PEB. LW2 2. 755 TNPH. LW2 8. 135 VDIA. LW2 230.908 2.458 -0.004 3.114 39.303 8.535 53.264 2.430 0.058 2.738 35.249 7.842 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREFIF2TT: O. 5000 FILE SUMmArY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 12320.0 12630.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE 13 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TI~E) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 13 -NOV-97 5B3 6 4. OC MEMORY 18776.0 5339.0 18776.0 60 62.4 65.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR ADN AZIM. DEN./NEUT. $ TOOL NUFiBER CDR 7045 ADN 044 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 7340.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.90 MUD VISCOSITY (S) : 72.0 MUD PH: MUD CHLORIDES (PPM) : 800 FLUID LOSS (C3): RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) : MUD AT I4EASURED TEMPERATURE (MT): 1. 660 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 0.970 MUD CAKE AT (MT): 1.930 70.0 70.0 70.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN) : TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: ORIGINAL HOLE SIDETRACKED AT 12630' BIT RUN 1 CDR 5410'-7360' BIT RUN 2 CDR/ADN 7360'-12447' BIT RUN 3 CDR/ADN 12447'- SIDETRACK POINT BIT RUN 4 CDR/ADN 12630'-13955' BIT RUN 5 CDR/ADN 13955'-18776' WELL PASSED HORIZONTAL AT 17500 ' DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: 14 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 100 4 66 255 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ArUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 4 1 1 4 68 0000000000 ATR LW3 OH~M O0 000 O0 0 4 1 1 4 68 0000000000 PSR LW3 OHI~ O0 000 O0 0 4 1 1 4 68 0000000000 ROPE LW3 F/HR O0 000 O0 0 4 1 1 4 68 0000000000 GR LW3 GAPI O0 000 O0 0 4 1 1 4 68 0000000000 TAB LW3 HR O0 000 O0 0 4 1 1 4 68 0000000000 TABD LW3 O0 000 O0 0 4 1 1 4 68 0000000000 ROBB LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 ROBU LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 ROBL LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 ROBR LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 DRHB LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 DRHU LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 DRHL LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 DRHR LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 PEB LW3 O0 000 O0 0 4 1 1 4 68 0000000000 PEU LW3 O0 000 O0 0 4 1 1 4 68 0000000000 PEL LW3 O0 000 O0 0 4 1 1 4 68 0000000000 PER LW3 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: 15 NAFIE SERV UNIT SERVICE API API API API FILE NUM~ AU]M~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TNPH LW3 PU O0 000 O0 0 4 1 1 4 68 0000000000 TNRA LW3 O0 000 O0 0 4 1 1 4 68 0000000000 DCALLW3 IN O0 000 O0 0 4 1 1 4 68 0000000000 HDIA LW3 IN O0 000 O0 0 4 1 1 4 68 0000000000 VDIA LW3 IN O0 000 O0 0 4 1 1 4 68 0000000000 RPM LW3 RPM O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 12320. 500 ATR . LW3 GR. LW3 88.131 TAB. LW3 ROBU. LW3 2. 333 ROBL . LW3 DRHU. LW3 O . 171 DRHL . LW3 PEU. LW3 3.357 PEL. LW3 TNRA.LW3 21 . 307 DCAL.LW3 RPM. LW3 43 . 000 3 906 PSR. LW3 0 000 TABD. LW3 2 245 ROBR. LW3 0 155 DRHR. LW3 3 239 PER.LW3 0 000 PIDIA.LW3 3. 833 ROPE.LW3 -999.250 O. 000 ROBB. LW3 2. 443 2. 314 DRHB.LW3 O. 067 O. 144 PEB. LW3 2. 915 2 . 967 TNPH. LW3 33 . 845 9. 269 VDIA. LW3 9. 335 DEPT. 13000. 000 ATR.LW3 -999.250 PSR.LW3 -999.250 ROPE.LW3 142. 850 GR.LW3 -999.250 TAB.LW3 -999.250 TABD.LW3 -999.250 ROBB.LW3 -999.250 ROBU. LW3 -999.250 ROBL.LW3 -999.250 ROBR.LW3 -999.250 DRHB.LW3 -999.250 DRHU. LW3 - 999. 250 DRHL. LW3 - 999. 250 DRHR. LW3 - 999. 250 PEB. LW3 - 999. 250 PEU. LW3 -999.250 PEL.LW3 -999.250 PER.LW3 -999.250 TNPH. LW3 -999.250 TNRA.LW3 -999.250 DCAL.LW3 -999.250 HDIA.LW3 -999.250 VDIA.LW3 -999.250 RPM. LW3 -999. 250 DEPT. 14000. 000 ATR.LW3 -999.250 PSR.LW3 -999.250 ROPE.LW3 225 121 GR.LW3 -999.250 TAB.LW3 -999.250 TABD.LW3 -999.250 ROBB.LW3 -999 250 ROBU. LW3 -999.250 ROBL.LW3 -999.250 ROBR.LW3 -999.250 DRHB.LW3 -999 250 DRHU. LW3 -999.250 DRHL.LW3 -999.250 DRHR.LW3 -999.250 PEB.LW3 -999 250 PEU. LW3 -999.250 PEL.LW3 -999.250 PER.LW3 -999.250 TNPH.LW3 -999 250 TNRA.LW3 -999.250 DCAL.LW3 -999.250 H~IA.LW3 -999.250 VDIA.LW3 -999 250 RPM. LW3 -999. 250 DEPT. 15000. 000 ATR. LW3 GR. LW3 -999 250 TAB.LW3 ROBU. LW3 - 999 250 ROBL. LW3 DRHU. LW3 -999 250 DRHL.LW3 PEU. LW3 -999 250 PEL.LW3 TNRA.LW3 -999 250 DCAL.LW3 RPM. LW3 -999 250 -999. 250 PSR. LW3 -999. 250 TABD. LW3 -999. 250 ROBR. LW3 -999. 250 DRHR. LW3 - 999. 250 PER . LW3 -999.250 P~DIA.LW3 -999.250 ROPE.LW3 73.192 - 999. 250 ROBB. LW3 - 999. 250 -999. 250 DRHB. LW3 -999. 250 -999. 250 PEB. LW3 -999. 250 -999 . 250 TNPH. LW3 -999. 250 -999. 250 VDIA. LW3 -999. 250 DEPT. 15290.000 ATR.LW3 -999.250 PSR.LW3 -999.250 ROPE.LW3 119.286 GR.LW3 -999.250 TAB.LW3 -999.250 TABD.LW3 -999.250 ROBB.LW3 -999.250 ROBU. LW3 -999.250 ROBL.LW3 -999.250 ROBR.LW3 -999.250 DR3{B.LW3 -999.250 DRHU. LW3 -999.250 DRHL.LW3 -999.250 DRHR.LW3 -999.250 PEB.LW3 -999.250 PEU. LW3 -999.250 PEL.LW3 -999.250 PER.LW3 -999.250 TNPH. LW3 -999.250 TNRA.LW3 -999.250 DCAL.LW3 -999.250 PiDIA.LW3 -999.250 VDIA.LW3 -999.250 RPM. LW3 -999. 250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: 16 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: O. 5000 FILE SUMbLARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12488.0 13950.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or R~-TIME) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 13-NOV-97 5B36 4.0C I~EMORY 18776.0 5339.0 18776.0 60 68.5 77.3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-i998 15:18 PAGE: 17 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR ADN AZIM. DEN./NEUT. $ TOOL AU3FiBER CDR 7045 ADN 044 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 8.500 7340.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.90 MUD VISCOSITY (S) : 72.0 MUD PH: MUD CHLORIDES (PPM) : 800 FLUID LOSS (C3): RESISTIVITY (Ot~4M) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): 1. 660 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): O. 970 MUD CAKE AT (MT): 1.930 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: ORIGINAL HOLE SIDETRACKED AT 12630' BIT RUN 1 CDR 5410'-7360' BIT RUN 2 CDR/ADN 7360'-12447' BIT RUN 3 CDR/ADN 12447 '- SIDETRACK POINT BIT RUN 4 CDR/ADN 12630'-13955' BIT RUN 5 CDR/ADN 13955'-18776' WELL PASSED HORIZONTAL AT 17500' DATA FROM DOWNHOLE M~qORY, V4. OC SOFTWARE $ LIS FORMAT DATA 70.0 70.0 70.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: 18 TYPE REPR CODE VALUE 3 73 100 4 66 255 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 5 1 1 4 68 0000000000 ATR LW4 OHT~4 O0 000 O0 0 5 1 1 4 68 0000000000 PSR LW4 OH~q O0 000 O0 0 5 1 1 4 68 0000000000 ROPE LW4 F/HR O0 000 O0 0 5 1 1 4 68 0000000000 GR LW4 GAPI O0 000 O0 0 5 1 1 4 68 0000000000 TAB LW4 HR O0 000 O0 0 5 1 1 4 68 0000000000 TABD LW4 O0 000 O0 0 5 1 1 4 68 0000000000 ROBB LW4 G/C3 O0 000 O0 0 5 1 1 4 68 0000000000 ROBU LW4 G/C3 O0 000 O0 0 5 1 1 4 68 0000000000 ROBL LW4 G/C3 O0 000 O0 0 $ 1 1 4 68 0000000000 ROBR LW4 G/C3 O0 000 O0 0 5 1 1 4 68 0000000000 DRHB LW4 G/C3 O0 000 O0 0 5 1 1 4 68 0000000000 DRHULW4 G/C3 O0 000 O0 0 5 1 1 4 68 0000000000 DRHL LW4 G/C3 O0 000 O0 0 5 1 1 4 68 0000000000 DRHR LW4 G/C3 O0 000 O0 0 5 1 1 4 68 0000000000 PEB LW4 O0 000 O0 0 $ 1 1 4 68 0000000000 PEU LW4 O0 000 O0 0 5 i 1 4 68 0000000000 PEL LW4 O0 000 O0 0 5 1 1 4 68 0000000000 PER LW4 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH LW4 PU O0 000 O0 0 5 1 1 4 68 0000000000 TNRA LW4 O0 000 O0 0 5 1 1 4 68 0000000000 DCALLW4 IN O0 000 O0 0 5 1 1 4 68 0000000000 HDIA LW4 IN O0 000 O0 0 5 1 1 4 68 0000000000 VDIA LW4 IN O0 000 O0 0 5 1 1 4 68 0000000000 RPM LW4 RPM O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: 19 DEPT. 12488. 000 ATR. LW4 GR. LW4 98. 331 TAB. LW4 ROBU. LW4 1.619 ROBL. LW4 DRHU. LW4 O. 075 DRHL.LW4 PEU. LW4 7. 906 PEL. LW4 TNRA. LW4 25.155 DCAL. LW4 RPM. LW4 O. 000 DEPT. 13000. 000 ATR. LW4 GR. LW4 119. 009 TAB. LW4 ROBU. LW4 2. 447 ROBL. LW4 DRHU. LW4 0.129 DRHL . LW4 PEU. LW4 4.218 PEL . LW4 TNRA. LW4 22.116 DCAL. LW4 RPM. LW4 O. 000 DEPT. 13950. 500 A TR . LW4 GR. LW4 231. 095 TAB. LW4 ROBU. LW4 2.407 ROBL. LW4 DRHU. LW4 O . 081 DRHL . LW4 PEU. LW4 4.117 PEL. LW4 TNRA.LW4 17. 820 DCAL.LW4 RPM. LW4 63. 000 3. 674 PSR. LW4 0 . 000 TABD. LW4 1 . 729 ROBR . LW4 O . 102 DR3~R . LW4 6. 919 PER.LW4 O. 000 HDIA.LW4 3.383 PSR. LW4 1.392 TABD. LW4 2.404 ROBR. LW4 O. 075 DRHR.LW4 3.912 PER. LW4 O. 013 PiDIA. LW4 4. 952 PSR. LW4 O. 632 TABD. LW4 2.3 61 ROBR. LW4 O. 044 DRHR. LW4 4. 009 PER.LW4 0.014 I{DIA.LW4 3. 681 ROPE. LW4 150. 000 ROBB. LW4 1. 685 DRHB. LW4 0.090 PEB.LW4 7.292 TNPH. LW4 9.936 VDIA.LW4 3.481 ROPE. LW4 12660. 000 ROBB. LW4 2.409 DRHB . LW4 O . 081 PEB . LW4 3.927 TNPH. LW4 8.488 VDIA. LW4 i0. 764 ROPE.LW4 3724. 031 ROBB. LW4 2.390 DRIIB. LW4 O. 045 PEB.LW4 4.295 TNPH.LW4 8.535 VDIA.LW4 - 999. 250 1. 685 O. 090 7. 292 45.213 7. 601 28. 755 2. 362 O. 035 3. 866 36. 026 7. 601 153.949 2.386 O. 026 4. 865 25. 401 8. 468 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER RAW MWD LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: 2O Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCRE~_2VT: 0.5000 FILE SUl4FL~RY VENDOR TOOL CODE START DEPTH MWD 13787.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TI~E) : TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR ADN AZIM. DEN./NEUT. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 18776.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHIVlM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) EWR FREQUENCY (HZ) 13-NOV-97 5B36 4.0C ~ORY 18776.0 5339.0 18776.0 8O 77.3 95.7 TOOL NUMBER CDR 7045 ADN 044 8.500 7340.0 LSND 10.90 72.0 800 1.660 70.0 0.970 70.0 1.930 70.0 SANDSTONE 2.65 1.0 20000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: 21 REM_ARKS: ORIGINAL HOLE SIDETRACKED AT 12630' BIT RUN 1 CDR 5410'-7360' BIT RUN 2 CDR/ADN 7360'-12447' BIT RUN 3 CDR/ADN 12447'- SIDETRACK POINT BIT RUN 4 CDR/ADN 12630'-13955' BIT RUN 5 CDR/ADN 13955'-18776' WELL PASSED HORIZONTAL AT 17500' DATA FROM DOWNHOLE MEMORY, V4.0C SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 100 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 6 1 1 4 68 0000000000 ATR LW5 OP~4~ O0 000 O0 0 6 1 1 4 68 0000000000 PSR LW5 OH~ O0 000 O0 0 6 1 1 4 68 0000000000 ROPE LW5 F/HR O0 000 O0 0 6 1 1 4 68 0000000000 GR LW5 GAPI O0 000 O0 0 6 1 1 4 68 0000000000 TAB LW5 HR O0 000 O0 0 6 1 1 4 68 0000000000 TABD LW5 O0 000 O0 0 6 1 1 4 68 0000000000 ROBB LW5 G/C3 O0 000 O0 0 6 1 1 4 68 0000000000 ROBU LW5 G/C3 O0 000 O0 0 6 1 1 4 68 0000000000 ROBL LW5 G/C3 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: 22 NAME SERV UNIT SERVICE API API API API FILE NUFZB NO?4~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) ROBR LW5 G/C3 DRHB LW5 G/C3 DRHU LW5 G/C3 DRHL LW5 G/C3 DRHR LW5 G/C3 PEB LW5 PEU LW5 PEL LW5 PER LW5 TNPH LW5 PU TNRA LW5 DCAL LW5 IN HDIA LW5 IN VDIA LW5 IN RPM LW5 RPM O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 13787. 000 ATR.LW5 4. 824 PSR.LW5 9. 084 ROPE.LW5 GR.LW5 234. 776 TAB.LW5 O. 000 TABD.LW5 O. 000 ROBB.LW5 ROBU. LW5 2. 354 ROBL. LW5 2. 223 ROBR. LW5 2. 350 DRHB. LW5 DRHU. LW5 O . 091 DRHL.LW5 O. 075 DRHR.LW5 O. 026 PEB.LW5 PEU. LW5 5. 434 PEL.LW5 5.247 PER.LW5 4.324 TNPH. LW5 TNRA.LW5 22. 744 DCAL.LW5 O. 000 HDIA.LW5 8. 868 VDIA.LW5 RPM. LW5 66. 000 DEPT. 14000. 000 ATR.LW5 4. 829 PSR.LW5 GR.LW5 185. 072 TAB.LW5 1. 069 TABD.LW5 ROBU. LW5 2. 426 ROBL. LW5 2. 358 ROBR. LW5 DRHU. LW5 O. 053 DRHL. LW5 O. 089 DRHR. LW5 PEU. LW5 3. 725 PEL . LW5 4.159 PER. LW5 TNRA. LW5 2 6. 232 DCAL. LW5 O. O13 HDIA. LW5 RPM. LW5 73. 000 DEPT. 15000. 000 ATR.LW5 3. 174 PSR.LW5 GR.LW5 145.540 TAB.LW5 0.658 TABD.LW5 ROBU. LW5 2. 393 ROBL. LW5 2. 415 ROBR. LW5 DRHU. LW5 O. 120 DRHL.LW5 O. 055 DRHR.LW5 PEU. LW5 4.807 PEL.LW5 3.949 PER.LW5 TNRA. LW5 25.918 DCAL. LW5 O. O13 ~DIA. LW5 RPM. LW5 59. 500 DEPT. 16000. 000 ATR.LW5 13. 625 PSR.LW5 GR. LW5 91 . 733 TAB. LW5 0 . 806 TABD. LW5 ROBU. LW5 2. 325 ROBL.LW5 2. 376 ROBR.LW5 DRHU. LW5 0.118 DRHL.LW5 0.059 DRHR.LW5 PEU. LW5 5.712 PEL . LW5 4.2 66 PER. LW5 TNRA.LW5 19. 027 DCAL.LW5 O. 014 H~IA.LW5 RPM. LW5 60. 000 11 019 ROPE.LW5 6880 000 ROBB. LW5 2 417 DRHB. LW5 0 060 PEB.LW5 3 908 TNPH.LW5 8 468 VDIA. LW5 8.653 ROPE.LW5 5470.000 ROBB.LW5 2.454 DRHB.LW5 0.052 PEB.LW5 3.938 TNPH. LW5 8.935 VDIA.LW5 16.506 ROPE.LW5 6989.984 ROBB.LW5 2.362 DRHB.LW5 0.048 PEB.LW5 4.007 TNPH. LW5 8.802 VDIA.LW5 -999.250 2.445 0.033 4.203 37.792 9.002 119. 205 2.376 0.148 4.525 48.927 8.535 125 843 2 402 0 017 3 558 47 815 8 868 18.518 2.400 -0. 016 2. 589 28.162 8. 802 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: 23 DEPT. 17000. 000 ATR. LW5 GR. LW5 119. 297 TAB. LW5 ROBU. LW5 2. 455 ROBL. LW5 DRHU. LW5 0.131 DRHL . LW5 PEU. LW5 4.830 PEL . LW5 TNRA. LW5 20.155 DCAL. LW5 RPM. LW5 81 . 333 DEPT. 18000. 000 ATR . LW5 GR. LW5 63 . 521 TAB. LW5 ROBU. LW5 2. 152 ROBL. LW5 DRHU. LW5 O . 099 DRHL . LW5 PEU. LW5 4.910 PEL . LW5 TNRA . L W5 21. 562 D CAL . L W5 RPM. LW5 82. 000 DEPT. 18775. 500 ATR. LW5 GR. LW5 143.828 TAB. LW5 ROBU. LW5 2.514 ROBL. LW5 DRHU. LW5 -0. 007 DRHL.LW5 PEU. LW5 3.231 PEL . LW5 TNRA . LW5 21 . 275 DCAL . LW5 RPM. LW5 100. 000 3.262 PSR.LW5 1.830 TABD. LW5 2.475 ROBR. LW5 O . 070 DRHR . LW5 3.747 PER. LW5 O. O13 ~DIA. LW5 38. 798 PSR. LW5 1. 406 TABD.LW5 2.214 ROBR.LW5 O. 089 DRHR. LW5 3.970 PER.LW5 O. 014 P~DIA. LW5 3. 029 PSR.LW5 1. 015 TABD. LW5 2. 609 ROBR. LW5 O. 042 DRHR.LW5 6. 544 PER.LW5 O. O14 HDIA. LW5 3. 854 ROPE. LW5 10003. 969 ROBB. LW5 2. 588 DRHB. LW5 0.069 PEB.LW5 4. 797 TNPH. LW5 8. 868 VDIA. LW5 64. 949 ROPE. LW5 7547. 906 ROBB. LW5 2.175 DRHB.LW5 O. 068 PEB.LW5 3. 886 TNPH. LW5 8.468 VDIA. LW5 4. 580 ROPE. LW5 7288. 313 ROBB. LW5 2.803 DRHB.LW5 - O. 060 PEB. LW5 6.194 TNPH. LW5 8. 693 VDIA. LW5 127. 745 2.544 O. 014 3.109 30. 892 8. 710 36.513 2.327 O. 036 3. 523 34. 521 8. 468 75.309 2.480 0.132 4. 747 33. 761 8. 771 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/09/15 ORIGIN : FLIC TAPE NAME : 97536 CONTINUATION # : 1 PREVIOUS TAPE : CO~94ENT : B.P. EXPLORATION, MILNE POINT MPF-79, API #50-029-22813-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 15:18 PAGE: 24 **** REEL TRAILER **** SERVICE NAM~ : EDIT DATE · 98/09/15 ORIGIN : FLIC REEL NAME : 97536 CONTINUATION # : PREVIOUS REEL : CO~4ENT : B.P. EXPLORATION, MILNE POINT MPF-79, API #50-029-22813-00