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Home My WebLink About200-198Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/17/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221117 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU 05-24A 50029222040100 204218 10/13/2022 AK E-Line PPROF MPU F-73A 50029227440100 200198 11/10/2022 READ CaliperSurvey Please include current contact information if different from above. T37269 T37270MPU F-73A 50029227440100 200198 11/10/2022 READ CaliperSurvey Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.17 14:01:49 -09'00' David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/3/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220930 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU I-17 500292321200 204098 3-Aug-22 READ CaliperSurvey MPU B-24 500292264200 196009 7/19/2022 READ CaliperSurvey MPU F-38 500292261400 195168 9/19/2022 READ CaliperSurvey MPU F-73A 500292274401 200198 7/31/2022 READ CaliperSurvey MPU I-01 500292206500 190090 8/31/2022 READ CaliperSurvey MPU I-30 500292371000 222023 7/12/2022 READ Inj_Profile MPU J-27 500292355700 215153 8/11/2022 READ CaliperSurvey MPU L-47 500292355000 215117 7/23/2022 READ CaliperSurvey Please include current contact information if different from above. T37121 T37122 T37123 T37124 T37125 T37126 T37127 T37128 MPU F-73A 500292274401 200198 7/31/2022 READ CaliperSurvey Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.05 13:20:28 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 Ifdenrli Alark*,T.M. E-mail: kaitlyn.barcelona@hilcorp.com DATE:3/24/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-73A (PTD 200-198) MFC 3/12/2022 Name Type Size 3DViewCentered File folder MPU_F-73A_MFC_12MAR22 PDF Document 5,412 KB MPU_F-73A_MFC_12MAR2a_Centered LAS File 294,6Z5 KB [91 MPU_F-73A_MFC_12MAR22_img TFF File 14,a16 KB MPU_F-73A_MFC_12MAR22_Unc entered LAS File 294,625 KB MPU_F-73A_MFCa4_12MAR2Z_Report PDF Document 9,102 KB LL] ReadMe_3DView_WIVA_V4.05 Text Document 1 KB C9 WIVA_V4.05_Setup zip Archive 23,972 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal 200-198 T36447 Received By: Date: Digitally signed by Meredith Guhl Meredith G u h I Date: 2022.04.06 13:59:18-08'00' PTD: 2001980 E-Set: 36131 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Ifdrnrli Alarka-i,I ; E-mail: kaitlyn.barcelona@hilcorp.com RECEIVED DATE: 12/29/2021 By Abby Bell at 12:56 pm, Dec 29, 2021 To: Department of Natural Resources Resource Evaluation 550 W 7th Ave, Suite 1100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-73A (PTD 200-198) Chemical Cut Record 11/19/2021 Hanie Type Size MPU_F-73A_Cut_19-Nov-2421_(3574) LAS File 111 KB tv1PU_F 73'_Cut_19 Nav- 0 1_(3574) PDF Document 1,223 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: 4'q -4z _& 12/29/2021 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS ay Samantha Carlisle at 12:59 pm, Dec 01, 2021 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ] Pull Tubing C Operations shutdown C Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool Repair Well ❑ Re-enter Susp Well ❑ Other: Complete 0 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: Hilcorp Alaska LLC Development ❑� Stratigraphic ❑ Exploratory ❑ Service ❑ 200-198 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage, AK 99503 50-029-22744-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: MILNE PT UNIT F-73A 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): ADL0025509 & ADL0355018 MILNE POINT / KUPARUK RIVER OIL 11. Present Well Condition Summary: 14,614 SFD 12/3/2021 Total Depth measured 14,,-.+,! feet Plugs measured 12,638 feet true vertical 8,879 feet Junk measured N/A feet Effective Depth measured 12,638 feet Packer measured 10,421 & 10,492 feet true vertical 8,761 feet true vertical 6,984 & 7,047 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Surface 5,873' 9-5/8" 5,904' 4,577' 5,750psi 3,090psi Production 11,049' 7" 11,080' 7,571' 7,240psi 5,410psi Liner 2,129' 4-1/2" 12,696' 8,789' 8,430psi 7,500psi Liner 2,201' 2-7/8" 14,614' 8,879' 10,570psi 11,170psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 6.5 / L-80 / Hyd563 10,561' 7,108' HES TNT Pkr Packers and SSSV (type, measured and true vertical depth) 7" x 4-1/2" S-3 N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 10 74 447 3,067 330 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑ Development 0 Service ] Stratigraphic ] Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ] • Gas ❑ WDSPL ❑ Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 321-549 Digitally signed by David David Haakinson Haakinson(3533) (3533) D" on -David Haakinson (3533), Authorized Name and ousers u= Contact Name: Taylor Wellman y Digital Signature with Date: Date:2021.12.01 12:52:29-09'00' Contact Email: twellman@hllcorp.com Authorized Title: Operations Manager Contact Phone: 777-8449 Sr Pet Eng: MGR04FEB2022 ISr Pet Geo: SFD 12/3/2021 1 Isr Res Eng: DS RBDMS HE 12/1/2021 Form 10-404 Revised 10/2021 Submit Within 30 days of Operations Hilearp Alaska, LIX KBE = 42.10' Doyon 141 TD=14,615' (MD) / TD = 8,879'(TVD) SCHEMATIC WELLHEAD Milne Point Unit Well: MPU F-73A Last Completed: 11/21/2021 PTD: 200-198 Tree 3-1/8" - 5 M 11" 5M Gen. 5 w/ 3-1/2" FMC Tbg Wellhead Hng.3-1/2" NSCT thread on bottom. 3 CIW "H" BPV Profile --- HOLE / CEMENT DETAIL : of Arctic Set (Approx) in 24" Hole sx PF 'E' , 411sx Class 'G' in a 12-1/4" Hole K Class "G" in 8-1/2" Hole K Class "G" in 6-1/8" Hole Class "G" in 3-3/4" Hole CASING DETAIL WELL INCLINATION DETAIL KOP @ 400' MD Hole Angle at Jet Pump 28.5 deg @ 10,461' MD Hole Angle 64 to 66 Deg. f/ 4,445' t/ 8,627' Hole Angle +72.95 deg f/ 12,758' t/ 14,614' MD Hole Angle perfs = 68-82 deg f/ 12720' t/ 13,500' Type Wt/ Grade/ Conn I D Top Btm Conductor 91.1 / H-40 N/A Surface 112' Surface 40 / L-80 / BTC 8.835 Surface 5,904' Production 26 / L-80 / BTC-M 6.276 Surface 11,080' Liner 12.6 / L-80 / BTC 3.958 10,568' 12,696' Liner 6.16 / L-80 / STL 2.441 12,413' 14,614' TUBING DETAIL Tubing 9.2 / L-80 / Hyd563 1 2.992 1 Surface 10,561' JEWELRY DETAIL Depth Item 2,498' XNipple-2.813"ID 10,393' Carrier Gauge Mandrel 10,400' Halliburton Sliding Sleeve w/ Ports Plugged - 2.813" ID 10,406' Zenith Ported Discharge Gauge 10,421' HES TNT Packer 10,449' 3-1/2" XN-Nipple- ID=2.75" No Go w/ RHC-M 10,469' Overshot with Muleshoe Guide -Btm @ 10,477' 10,492' 7"x4-1/2" Baker Model S-3 Packer 10,521' 3-1/2" XN Nipple - ID=2.75" (XXN plug set 04/16/21) 10,560' 3-1/2" NSCT 9 CR W LEG - Bottom @ 10,561' 10,568' Baker ZXP Packer 10,583' RS Nipple - ID= 4.25" 10,585' Baker Flexlock Hanger 12,414' Baker Deployment Sleeve 12,421' 2-7/8" STL Box x 2-7/8" FL4S Pin XO - I D=2.34" 12,423' 2-7/8" FL4S Box x 2-7/8" STL Pin XO - I D=2.34" 12,638' 2-7/8" Composite Bridge Plug w/ 32' of cement (plug 12,670') 13,825' Baker Float Collar 13,853' 2-7/8" Tubing, Perforated (4) 3/8" holes pert/ft- Btm @ 14,613' 14,613' BKR Guide Shoe - Btm @ 14,614' PERFORATION DETAIL Top MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size SPF D,634' 10,668' 7,173' 7,203' 34' 3/12/18 Open 2-1/2" 6 D,712' 10,726' 7,242' 7,255' 14' 3/12/18 Open 2-1/2" 6 D,731' 10,751' 7,259' 7,277' 20' 3/12/18 Open 2-1/2" 6 D,756' 10,786' 7,282' 7,308' 30' 1 3/11/18 Open 2-1/2" 6 2,720' 13,190' 8,799' 8,827' 470' 1 4/18/2001 Closed 2" 4 3,220' 13.500' 8,828' 8,869' 280' 1 4/18/2001 Closed 2" 4 Ref Log: SLB SCMT Log Dated: March 1, 2001 GENERAL WELL INFO API: 50-029-22744-01-00 Drilled March 1997 Deepen to the Sag River formation - December 2000 CTU Horizontal Sidetrack Nordic#1-4/21/2001 Jet Pump Completion - April 2001 Plug Back and Add Kuparuk Perfs - 3/12/2018 Remove and Replace Completion-11/21/2021 PBTD=14,614' (MD) / PBTD = 8,879"(TVD) Revised By: TDF 11/30/2021 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-73A Eline/ASR 50-029-22744-01-00 1 200-198 11/4/2021 11/23/2021 11/3/2021 - Wednesday No operations to report. 11/4/2021 - Thursday Well Shut in upon Arrival. Make up 2-5/8" chemical cutter, correlate to tubing tally dated 4-21-2001. Fire cutter and cut tubing @ 10,482' ELMD (2' below collar in 10' pup above packer), good electrical indication of cutter spent, release slips and hang up in sleeve, worked free and pooh w/ tools. On surface cutter shows good indication of good cut, bow spring cam back with chunks of rubber from patch. RDMO. 11/5/2021 - Friday No operations to report. 11/6/2021 - Saturday No operations to report. 11/7/2021 - Sunday No operations to report. 11/8/2021 - Monday No operations to report. 11/9/2021 - Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date ASR #1 / MP F-73A 50-029-22744-01-00 200-198 11/4/2021 11/23/2021 Slickline 11/15/2021 - Monday C/o with relief, meet LRS on location. r/u LRS to 300bbl vac truck and 500bbl circ. tank to circulate the long way on well F-73 . r/u methanol tank for freeze protection. Walk down all lines. Initial pressures on F-73, Tbg press=0 psi, IA=-1 psi, OA=22 psi, start kill @4.90 Bpm, at 93bbls pumped observed returns, taking rates and pressures every 5 minutes. ICP=70 psi @ 117bbl away, etc. FCP=56 psi @ 445bbl away,IA=21 psi @ 471bbl away -pump slowed down, 471bbl pumped total with a 59bbl loss after returns observed. Tbg press=0, IA=-12, OA=559 psi drop to 463 in 10min. Pump methanol to freeze protect lines and tree. Set BPV w/wellhead tech, use empty 300bbl vac truck to suck out 500bbl circ. tank. Drill support r/d tanks and line. Trucks showing up with rig floor etc. and crane. Mobilize all major components to location for ASR Rig. Rig down tree landings. Bleed void on tree. Spot mud boat, disconnect electrical pots from shore power and road to F-Pad. Spot pits, crane and start N/D tree. Wellhead hand inspect LDS and install test dart in BPV. Terminate tech wire, crane well house on. Nipple up BOP's, crane floor and install koomey hoses, stairs, spot Co. Man shack and doghouse. 11/16/2021 - Tuesday Continue to rig up on F-73. Repair glycol heater hose fitting, replace damaged hoses on system. Clean "Y" screens on accumulator system, check pre -charge and nitrogen back ups. A few bottle and bladders low. Call for nitrogen rack, rack bottle to low to re -charge system, expedite another rack. Top off bladders, onload 180bbls produced H2o and c/o elevator. Pick up mandrel to time closures on BOP and shell test, before State inspector arrives. 11/17/2021 - Wednesday Troubleshoot Annular closing time. Lift Koomy lines onto timbers and wrap with plastic sheeting. Move heaters to keep Koomy lines warm. Attempt to shell test and unable to get water to test pump - troubleshoot and look for frozen line in pits. Disconnect Koomy lines from Annular and flush Hydraulic fluid in lines. Mobilize additional heaters for Pits and Koomey lines. Re -connect Kommy lines, increase Annular closing pressure to 1400 psi and perform closing test - good test 27 sec to close. Continue to thaw water lines in Pits. Fill stack and perform shell test. Re -Torque BOP bolts per spec. Finish re-torgueing bolts. Call AOGCC Rep. Start test as per state rep. Start test #1, chasing leak. C/o valve on choke manifold and greased valves, re- test failed. Trace all lines out in and underneath all module for leaks -none found. checked sensator and pumped up the same. Re -test fail. Change out valves C-2 and K-6 and re -check sensator-bad. Call out well head tech. Rebuild sensator and pump and purge hose. Flood and purge air from manifold again, re -test -fail. leak on C-2 stem, repaired same and re -test -fail. Pull test joint and close blinds and re -test and hold for 15minuts to flat line -good. Rules out dart and hanger, we will proceed with longer test moving forward. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date ASR #1 / MP F-73A 50-029-22744-01-00 200-198 11/4/2021 11/23/2021 Slickline 11/18/2021 - Thursday Continue to troubleshoot testing issues. Pull and lay down test joint. Close Blinds and test below blinds 250/2500. Pressure stabilized above 2500 psi after 15 min and held for 5 min. Opened blinds and rigged back up to test annular with 3.5" test joint. Test BOPE with 3.5" test joint to 250/2500 psi for 5 charted min each. AOGCC Adam Earl on location to witness testing. 4 Fail/Pass components: Choke manifold valve C2 and C8 leaked removed and replaced - Pass on re -test. Kill manifold valve K6 leaked: remove and replaced - Pass on re -test. TIW valve leaked, replaced - Pass on re -test. Perform drawdown test and time annular/ram closing. Annular closed in 20 sec, rams closed in 6.5 sec., HCR closed in 1 sec. Blow down and rig down all lines and test equipment, Pull test dart, verify no pressure and pull BPV and lay down. Circulate 95 bbls of produced water down the tubing with no returns, P/u and M/u landing joint and floor valve to hanger, back out LDS. Pull from 120k down to 70k and work string 3-4ft for 30min. Pull 140k to 70k and work string 4-5ft for 30min. Pull 155k to 70k and work string for 6ft. call E-line for cutter @2200hrs, continue working string at 140k to 70k until E-line arrive -ETA early morning. Note: took on 150bbl 8.3ppb produce H2O, fuel, continue working string at 140k to 70k, until E-line arrive -ETA early morning. filling hole with 5bbl every hrs. 11/19/2021 - Friday Continue to wait on E-Line unit from Deadhorse. Spot and rig up E-line. Make up toolstring and hold PJSM prior to loading explosives or chemicals. Noted ID of landing joint XO smaller than required for OD of chemical cutter during PJSM. Land hanger and break down landing joint. Attempt to locate landing joint and XO combination back to 3-1/2" NSTC hanger thread with no reduction in ID. Mobilizing XO's, pup joints and tubing joints to location. Decision made to attempt a cut with string landed while mobilizing tools to location. E-line crew has enough time to make 2 attempts before timing out for the day. Rig E- line back up. Hold PJSM for loading explosives and chemical into tool string. Load explosives and chemical and run in the hole on E-line, Wait 1hr to allow chemical to warm downhole. Correlate depths to previous run and cut depth. Set chemical cutter on depth at 10483' and fire. POOH with E-Line f/ 10483' to surface. Break down and lay down CCL and Chemical cutting assembly. R/D E-Line sheave from elevators. Make up landing joint with XO's & pup jts. Engage Hanger & BOLDS. Pull Hanger to rig floor. 80k PUW break over, 75k free travel. Lay down Hanger and break down landing Joint. Rig up to pull tubing. Dress elevators for NSCT collars. Spot Centrilift spooler & mobilize thread protectors to rig floor. Troubleshoot Spooler controls not functioning. Found to have froze air lines. POOH laying down laying down 3-1/2", 9.2#, L-80, NSCT tubing from cut @ 10483' to 7594'. Fill hole with double calculated fill every 15 jts. Tubing, control line and clamps are all in good condition with no excessive corrosion, scale or abnormalities noted. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-73A ASR #1 / Slickline 50-029-22744-01-00 200-198 11/4/2021 11/23/2021 11/20/2021 - Saturday POOH laying down laying down 3-1/2", 9.2#, L-80, NSCT tubing from cut @ 7594' to surface. Fill hole with double calculated fill every 1S jts. Tubing, control line and clamps are all in good condition with no excessive corrosion, scale or abnormalities noted. Recovered 323 jts, 275 CC clamps, 5 bands, 1 pup jt, and 1 cut jt — 2.79'. 1x GLM, Discharge sub, sliding sleeve and Multi -sensor each with pup jts above and below, Count pipe, pups and jewelry to confirm numbers. Clear and clean pipe shed. Load Shed with new upper completion jewelry. Record all info and straps. Count New tubing delivered to location. Load 3- 1/2" H563 tubing in shed and tally. M/U FOSV to H563 XO. Swap out Tec wire spool and mob Centrilift equipment to rig floor. Service rig, and generators. Hang Tec Wire sheave. PJSM for M/U upper completion assembly. Prep slips for 4-1/2" swap and observe locking mechanism to be broken. Mobilize dog collar and back-up slips to rig. Dress slips for 3-1/2". SimOps: Prep catwalk for picking up jewelry and tubing. M/U Overshot w/ muleshoe guide (Shear pins @ 1.95' & 6.62'), XN Nipple w/ RHC- M installed, HES TNT Packer (6x pins @ 323 each - 1938 psi), Zenith Ported discharge sub, HES sliding sleeve, and gauge carrier mandrel t/ 90'. Centrilift rep connect Tec Wire to gauge and test wire. Good Test. RIH with 3-1/2" 9.2# L-80 H563 tubing f/ 90' t/ 2096' . Tq 3-1/2" tubing to 2900 ft/lbs. Install cannon clamp every connection for first 20 jts. Install cannon clamp every other connection from jt #20 on. Test cable every 1000'. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-73A ASR #1 / Slickline 50-029-22744-01-00 200-198 11/4/2021 11/23/2021 11/21/2021 - Sunday RIH with 3-1/2" 9.2# L-80 H563 tubing f/ 2096' t/ 6075' . Tq 3-1/2" tubing to 2900 ft/Ibs. Install cannon clamp every other connection. Test cable every 1000'. RIH with 3-1/2" 9.2# L-80 H563 tubing f/ 6075' t/ 10095'. Tq 3-1/2" tubing to 2900 ft/Ibs. Install cannon clamp every other connection. Test cable every 1000'. Service Rig & Generators. Cont RIH with 3-1/2" 9.2# L-80 H563 tubing f/ 10095' t/ 10478' . Tq 3-1/2" tubing to 2900 ft/Ibs. Install cannon clamp every other connection. Observe 3k wt bobble @ 10473' & 10477' suggesting shear screws in overshot. Take wt and set 12k at 10478', 5' in on jt #331. P/U 15' and S/O, clean coming down until set down with 18k @ 10478', indicating No -Go. P/U 1.5' to neutral wt and mark pipe for space - out. 80k P/U, 49k S/O, Space out - Pull and Lay down jts #331, 330 & 329. M/U 7.81' & 2.81' pup jts. Run in hole with jt #329. Partial jt to Tag mark = 3.65', Jt #330 = 31.45', jt #329=31.64' - Total 66.74'. RKB = 16.92', Hanger and Pups = 7.22', 2x space - out pups = 10.62', jt #329 = 31.64' - Total 66.40'. Spaced out 0.34' off No -Go. Make up Hanger, XO and FOSV. Terminate Tec Wire at Hanger. RIH and Land Hanger, RILDS. 49k on Hanger. Total of 329 jts, 179 CC Clamps. L/D Landing Jt. Rig up to circulate down IA and tubing. Shut blinds rams, line up and reverse circulate down IA taking returns throu 110 bbls source water @ 3 BPM until returns at stack. LRS pump 60 bbls diesel freeze protect down IA, take returns to pits. Well on Vac initially, catch pressure @ 9 bbls pumped. FCP 406 psi @ 2.5 BPM. Swap to rig and pump 60 bbls source water. 345 psi @ 2 BPM. Line up LRS to tubing through kill line. Bullhead 5 bbls diesel freeze protect down tubing, 2 BPM Well on Vac initially catching pressure with 3 bbls pumped. FCP 700 psi @ 1.5 BPM. Swap to Rig & pump 5 bbls source. Bleed pressures down. Open blind rams and install landing jt. Drop 1-5/16" Ball & Rod. Shut in IA pressure @ 110 psi. Lay down landingjt. Fill hole and bleed air. Close blinds and engage pumps to circulate ball and rod down. Pump 0.25 bbls and pressure up to 500 psi. Hold for 5 min. SimOps: Start Rig down pipe shed and catwalk. Pressure up to 3000 psi and hold for 5 min setting HES TNT packer. Good indication of shear and set @ 2000 psi. 1 bbl pumped. Pressure up to 3500 psi to test 3-1/2" tubing. Hold for 30 charted min - Good Test. Bleed tbg down to 750 psi and shut in. Line up on IA, fill and purge air. MIT -IA to 3500 psi for 30 min- Good test. Tbg pressure increase to 1200 psi and held. Bleed pressures down. Blow down lines. Install BPV. Continue rig down all equipment and prep to move off well. 11/22/2021 - Monday Rig down ASR rig. Blow down and rig down all lines. Finish Rig down pipe racks, pipe skate and catwalk. Rig down rig floor and pump. Lay over derrick. Move rig off location to A -Pad. Nipple down BOPE & Nipple up Tree. Pressure test tubing hanger void to 500/5000 psi - Good test. Centrilift perform final checks - Good test . Secure tree and release rig and stage all equipment to middle row of pad. Final report. Refer to MPU F-65 for further details. Slickline: WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/2500H. SHIFT XD-SS OPEN WITH 3-1/2 42-BO (keys down) AT 10426' SLM/10400' MD (42-130 pin not sheared). PULL BALL & ROD FROM RHC IN XN-NIP AT 10466' SLM. PULL 3- 1/2 RHC FROM XN-NIP AT 10473' SLM/10447' MD. DRIFT THROUGH OVERSHOT (10469' MD) TO 10516' SLM/10490' MD (-26' SLM correction, no restrictions). CONTINUE TICKET 11-23-21. 11/23/2021 - Tuesday CONTINUE TICKET FROM 11-22-21. 24 HOUR CREW CHANGE OUT ALLISON TO HOGAN, NOTIFY PAD -OP, PT PCE 250L/2500H. SET 3" JET PUMP (serial# BP-1111, ratio: 10A, screen, OAL=69") IN XD-SS AT 10,426' SLM/10,400' MD. RDMO, CLOSE PERMIT W/PAD-OP. PTD : 2001980 E-Set: 35961 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Ifi1mrii:tlarka-i,I ; E-mail: kaitlyn.barcelona@hilcorp.com RECEIVED By Abby Bell at 12:33 pm, Nov 22, 2021 DATE:11/19/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-73A (PTD 200-198) CCL11/04/2021 Name Type Size MPU_F-73k_Chemical Cutter_04-Nov-70a1_(3555) LAS File 1,831) KB M101-1_F-73k_Chemical Cutter_-Nov-2021_(3555) PDF Document 1,385 K6 Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: .A66 l3 11 /22/2021 STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I. Supry tL BOPE Test Report for: MILNE PT UNIT F-73A Comm Contractor/Rig No.: Hilcorp ASR 1 PTD#: 2001980 DATE: 11/18/2021 - Inspector Adam Earl Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: Anderson/Dambacher Rig Rep: Beshea/Haberthur Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopAGE211122202545 Rams: Annular: Valves: MASP: Type Test: INIT 321-549 250/2500 ' 250/2500 250/2500 1082 ✓ Related Insp No: MISC. INSPECTIONS: P/F Location Gen.: P ' Housekeeping: P PTD On Location P ' Standing Order Posted P ' Well Sign P " Drl. Rig P Hazard Sec. NA_ Misc NA TEST DATA MUD SYSTEM: ACCUMULATOR SYSTEM: Visual Alarm Time/Pressure P/F Trip Tank NA NA - System Pressure __ 3050 P . Pit Level Indicators P P - Pressure After Closure 1850 P - Flow Indicator P " P 200 PSI Attained 15 P " Meth Gas Detector P P Full Pressure Attained 69 P " H2S Gas Detector P P _ Blind Switch Covers: All Stations " P - MS Misc _0 NA Nitgn. Bottles (avg): _4@a 2250 P ' ACC Misc 0 NA I FLOOR SAFTY VALVES: BOP STACK: Quantity P/F I Quantity Size P/F Upper Kelly 0 NA- Stripper 0 NA Lower Kelly 0 NA, Annular Preventer 1 11" P - Ball Type 1 FP 1 #I Rams 1" 2 7/8 X 5 P Inside BOP 1 P '' #2 Rams 1 blind P FSV Misc 0 NA 43 Rams 0 NA #4 Rams 0 NA 45 Rams _ 0 NA #6 Rams _ 0 NA _ Choke Ln. Valves 1 , 2 1/16 P " HCR Valves 1 ' 2 1/16 P Kill Line Valves 3 '2 1/16 - P ' Check Valve 0 _ _ NA _ BOP Misc 0 NA CHOKE MANIFOLD: Quantity P/F No. Valves 15 FP Manual Chokes I _ P Hydraulic Chokes _ 1 P_ CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Number of Failures: 4 ' Test Results ✓. Test Time 20 Remarks: Choke manifold valve 2 and 8, K-6, and TIW valve failed all replaced. Koomy bottle bladders: 10 @ 1050psi closing times: Annular-20secs. Rams-6.5secs HCR-1 sec —�— STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION By Samantha Carlisle at 11:54 am, Oct 19, 2021 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑./ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Complete ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ Stratigraphic ❑ Service ❑ 200-198 3. Address: 6. API Number: 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22744-01-00 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 El No 0 MILNE PT UNIT F-73A 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025509 & 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): 14,614' 8,879' 12,638' 8,761' 1,082 12,638' N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Surface 5,873' 9-5/8" 5,904' 4,577' 5,750psi 3,090psi Production 11,049' T' 11,080' 7,571' 7,240psi 5,410psi Liner 2,129' 4-1/2" 12,696' 8,789' 8,430psi 7,500psi Liner 2,201' 2-7/8" 14,614' 8,879' 10,570psi 11,170psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 3-1/2" 9.2 / L-80 / NSCT 10,561' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): S-3 7" x 3.5" & 7" ZXP Packer and N/A 10,492 MD/ 7,047 TVD & 10,568 MD/ 7,114 TVD and N/A 12. Attachments: Proposal Summary 0 Wellbore schematic 0 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: CommencingOperations: 10/28/2021 p OIL WINJ WDSPL ❑ ❑ ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: AOGCC Representative: GINJ ElOp Shutdown ElAbandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Digitally signed by David Contact Name: Taylor Wellman David Haakinson Haakinson (3533) Authorized Name and (3533) DN: cn=Da—Usersvid Haakinson (3533), Users Digital Signature with Date: Date: 2021.10.1911: 19:35-08'00' Contact Email: twellman hilcor .Corn Contact Phone: 907-777-8449 Authorized Title: Operations Manager AOGCC USE ONLY Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: 321-549 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: BOPE test to 2500 psi. RBDMS HEW 10/26/2021 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ® Subsequent Form Required: 10-404 Digitally signed by Jeremy "iCe APPROVED BY 10/25/21 Jeremy Price Date: 201.102,,,,251 Approved by: -e80e COMMISSIONER THE AOGCC Date: Comm.dts 10/22/2021 lcoml 10/22/2021 Isr Pet EngMGR190cT2021 I 1Sr Pet GeoDLB 10/19/2021 1 1SrResEl Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. Ilileorp Alaska, LL RWO — Tbg Swap Well: MPU F-73A Date: 14 October 2021 Well Name: MPU F-73A API Number: 50-029-22744-01-00 Current Status: SI Producer [Failed ESP] Pad: F-Pad Estimated Start Date: October 28, 2021 Rig: ASR 1 Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Darci Horner Permit to Drill Number: 200-198 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: David Gorm (907) 777-8333 (0) (505) 215-2819 (M) Current Bottom Hole Pressure: MPSP: Max Inclination Max Dogleg: Brief Well Summary: 1,806 psi @ 7,240' TVD 1,082 psi 65' Sail Angle 3.3°/100ft @ 6,815' MD SBHPS: 10/16/21 (6mo SI) 14.80 PPGE Gas Column Gradient (0.1 psi/ft) MPU producer F-73 is completed in 2001 in the Kuparuk formation as a jet pump producer. The well was shut- in in April 2021 due to a tubing leak after the power fluid rate increased beyond design. A caliper and LDL were completed and identified the tubing leak at 8,540' MD. 2 attempts to set tubing patches were attempted. The lower element patch element failed and slipped downhole causing both patches to fail to restore integrity. Notes Regarding Wellbore Condition • Combo MIT -IA Passed at 3,592 psig on 4/17/2021. • Single Tubing leak confirmed at 8,540' MD on 7/20/2021 with slickline memory leak detect. • Tubing Caliper indicated 60%wall loss in the area. • A secondary caliper run on 8/16/21 indicates that there are multiple holes in joint 264 (8,518'-8,551' md). Objective: Cut, pull and recover all tubing / Run stacker packer jet pump completion Pre -Rig Procedure (No sundry required): Slickline E-Line 1. RU SL and pressure test to 250psi low/ 2,500psi high. 2. Fish and recover all tbg patch from 8,573' md. 3. Drift to 10,500' and for 3-1/2" Chemical Cutter. 4. RD SL. 5. RU EL unit and pressure test PCE to 250psi low/ 2,500psi high. 6. RIH and chemical cut tubing at 10,482' and (2' below the top collar of the 10' pup joint above the packer, see tubing tally dated 04/21/01). 7. POOH and RD EL unit. RWO — Tbg Swap Well: MPU F-73A i ileorp Alaska, LL Date: 14 October 2021 Pumping & Well Support 8. Clear and level pad area in front of well. Spot rig mats and containment. 9. RD well house and flowlines. Clear and level area around well. 10. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 11. Pressure test lines to 3,000 psi. 12. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. 13. Confirm well is dead. Contact the operations engineer if freeze protection is needed depending on ASR arrival. 14. RD Little Red Services and reverse out skid. 15. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 16. NU BOPE house. Spot mud boat. Brief RWO Procedure: 17. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines. 18. 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/ produced water prior to pulling BPV. Set TWC. 19. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre -charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 3-1/2" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 20. 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. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 21. Bleed any pressure off casing to the returns tank. Pull TWC. Kill well with produced water as needed. 22. MU landing joint or spear and PU on the tubing hanger. IIileoru Alaska, LL RWO — Tbg Swap Well: MPU F-73A Date: 14 October 2021 a. The PU weight during the 2001 completion was 75 K Ibs and S/O Wt = 58 K lbs. b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 23. 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. 24. POOH and lay down the 3-1/2" tubing. All tubulars and equipment recovered will be junked. 25. PU new 3-1/2" Jet Pump Completion w/ non -sealing overshot and run: a. ±10,482' and 4-1/2" overshot w/ xo to 3-1/2" pup joint (shear pins at 24" and 70" from the bottom of the overshot to help with space out). b. 2 pup joints 3-1/2", 9.2#, L-80 tubing c. 3-1/2" XN (2.75" ID No -Go) Nipple d. 2 pup joints 3-1/2", 9.2#, L-80 tubing e. 3-1/2" x 4-1/2" crossover f. 7"x4-1/2" Production Packer g. 4-1/2"x 3-1/2" crossover h. 2 pup joints 3-1/2", 9.2#, L-80 tubing i. Baker Zenith Multi -sensor Intake Gauge j. 1 pup joints 3-1/2", 9.2#, L-80 tubing k. Sliding Sleeve w/ ports plugged for tec-wire for Baker Gauges I. 1 pup joints 3-1/2", 9.2#, L-80 tubing m. Baker Zenith Discharge Gauge n. 1 pup joints 3-1/2", 9.2#, L-80 tubing o. Full joints 3-1/2", 9.2#, L-80 tubing p. ±2,500' and 3-1/2" X (2.813" ID) Nipple 26. Space out and land tubing hanger. PU and MU the 3-1/2" tbg hanger. Make final splice of the TEC wire. Note PU (Pick Up) and SO (Slack Off) weights on tally. a. Land out and pick up —1'. Attempt to keep PU short and note in tally for future records for wireline passthrough. 27. Load well and drop ball and rod. Pressure up on tubing to set packer as per manufacturer procedures. MIT-T to 3,500psi (charted). Perform MIT -IA to 3,500psi (charted). a. Use diesel at final end of pumping for freeze protection of tubing and IA. 28. Set BPV. Post -Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU existing 3-1/8" 5,000# tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. Ilileorp Alaska, LL Slickline 5. Replace gauge(s) if removed. 6. Turn well over to production. RU well house and flowlines. 7. RU and pressure test PCE to 250/2,OOOpsi. 8. Pull ball & rod and RHC test plug body. 9. Drift through overshot at ±10,482' md. 10. RD SL. Attachments. 1. As -built Schematic 2. Proposed Schematic 3. BOPE Schematic RWO — Tbg Swap Well: MPU F-73A Date: 14 October 2021 Hilcorp Alaska, LLC KBE = 42.10' Doyon 141 SCHEMATIC WELLHEAD Milne Point Unit Well: MPU F-73A Last Completed: 4/22/2001 PTD: 200-198 Tree 3-1/8" - 5M 11" 5M Gen. 5 w/ 3-1/2" FMC Tbg Wellhead Hng. 3-1/2" NSCT thread on bottom. 3 CIW "H" BPV Profile --- HOLE / CEMENT DETAIL : of Arctic Set (Approx) in 24" Hole sx PF 'E' , 411sx Class 'G' in a 12-1/4" Hole K Class "G" in 8-1/2" Hole K Class "G" in 6-1/8" Hole Class "G" in 3-3/4" Hole CASING DETAIL WELL INCLINATION DETAIL KOP @ 400' MD Hole Angle at Jet Pump 28.5 deg @ 10,461' MD Hole Angle 64 to 66 Deg. f/ 4,445' t/ 8,627' Hole Angle +72.95 deg f/ 12,758' t/ 14,614' MD Hole Angle perfs = 68-82 deg f/ 12720' t/ 13,500' Type Wt/ Grade/ Conn I D Top Btm Conductor 91.1 / H-40 N/A Surface 112' Surface 40 / L-80 / BTC 8.835 Surface 5,904' Production 26 / L-80 / BTC-M 6.276 Surface 11,080' Liner 12.6 / L-80 / BTC 3.958 10,568' 12,696' Liner 6.16 / L-80 / STL 2.441 12,413' 14,614' TUBING DETAIL Tubing 9.2 / L-80 / NSCT 2.992 1 Surface 10,561' JEWELRY DETAIL Depth Item 2,482' 3.5" x 1" KBUG GLM w/ DGLV 04/30/01 10,454' Phoenix Discharge Pressure Sub (Not operable) 10,461' Baker Model CMU Sliding Sleeve (Sleeve open 7-21-21 10 A set 7-21-21) 10,471' Phoenix Multisensor (Not operable) 10,492' Baker Model S-3 Packer 10,521' 3-1/2" XN Nipple -I D=2.75" 10,560' 3-1/2" NSCT 9 CR WLEG - Bottom @ 10,561' 10,568' Baker ZXP Packer 10,583' RS Nipple - ID= 4.25" 10,585' Baker Flexlock Hanger 12,414' Baker Deployment Sleeve 12,421' 2-7/8" STL Box x 2-7/8" FL4S Pin XO - ID=2.34" 12,423' 2-7/8" FL4S Box x 2-7/8" STL Pin XO - ID=2.34" 12,638' 2-7/8" Composite Bridge Plug w/ 32' of cement (plug 12,670') 13,825' Baker Float Collar 13,853' 2-7/8" Tubing, Perforated (4) 3/8" holes pert/ft- Btm @ 14,613' 14,613' BKR Guide Shoe - Btm @ 14,614' PERFORATION DETAIL fop MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size SPF 1,634' 10,668' 7,173' 7,203' 34' 3/12/18 Open 2-1/2" 6 1,712' 10,726' 7,242' 7,255' 14' 3/12/18 Open 2-1/2" 6 1,731' 10,751' 7,259' 7,277' 20' 3/12/18 Open 2-1/2" 6 1,756' 1 10,786' 1 7,282' 1 7,308' 30' 1 3/11/18 1 Open 2-1/2" 6 ;720' 13,190' 1 8,799' 1 8,827' 470' 1 4/18/2001 1 Closed 2" 4 i,220' 13.500' 1 8,828' 1 8,869' 280' 1 4/18/2001 1 Closed 2" 4 Ref Log: SLB SCMT Log Dated: March 1, 2001 GENERAL WELL INFO API: 50-029-22744-01-00 Drilled March 1997 Deepen to the Sag River formation - December 2000 CTU Horizontal Sidetrack Nordic#1-4/21/2001 Jet Pump Completion - April 2001 Plug Back and Add Kuparuk Perfs - 3/12/2018 TD=14,615' (MD) / TD = 8,879'(TVD) PBTD=14,614' (MD) / PBTD = 8,879"(TVD) Revised By: DLW 04/19/2021 Hilcorp Alaska, LLC KBE = 42.10' Doyon 141 PROPOSED WELLHEAD Milne Point Unit Well: MPU F-73A Last Completed: 4/22/2001 PTD: 200-198 Tree 3-1/8" - 5M 11" 5M Gen. 5 w/ 3-1/2" FMC Tbg Wellhead Hng. 3-1/2" NSCT thread on bottom. 3 CIW "H" BPV Profile --- HOLE / CEMENT DETAIL : of Arctic Set (Approx) in 24" Hole sx PF 'E' , 411sx Class 'G' in a 12-1/4" Hole K Class "G" in 8-1/2" Hole K Class "G" in 6-1/8" Hole Class "G" in 3-3/4" Hole CASING DETAIL WELL INCLINATION DETAIL KOP @ 400' MD Hole Angle at Jet Pump 28.5 deg @ 10,461' MD Hole Angle 64 to 66 Deg. f/ 4,445' t/ 8,627' Hole Angle +72.95 deg f/ 12,758' t/ 14,614' MD Hole Angle perfs = 68-82 deg f/ 12720' t/ 13,500' Type Wt/ Grade/ Conn ID Top Btm Conductor 91.1 / H-40 N/A Surface 112' Surface 40 / L-80 / BTC 8.835 Surface 5,904' Production 26 / L-80 / BTC-M 6.276 Surface 11,080' Liner 12.6 / L-80 / BTC 3.958 10,568' 12,696' Liner 6.16 / L-80 / STL 2.441 12,413' 14,614' TUBING DETAIL Tubing 9.2 / L-80 / Hyd563 1 2.992 1 Surface ±10,561' JEWELRY DETAIL Depth Item ±2,500' X Nipple ±10,390' Baker Zenith Discharge Gauge ±10,405' Baker Model CMU Sliding Sleeve ±10,420' Baker Zenith Multisensor ±10,435 7"x4-1/2" Production Packer ±10,462 3-1/2" XN-Nipple- ID=2.75" No Go ±10,482 Non -sealing overshot 10,492' 7"x4-1/2" Baker Model S-3 Packer 10,521' 3-1/2" XN Nipple - ID=2.75" (XXN plug set 04/16/21) 10,560' 3-1/2" NSCT 9 CR WLEG - Bottom @ 10,561' 10,568' Baker ZXP Packer 10,583' RS Nipple - ID= 4.25" 10,585' Baker Flexlock Hanger 12,414' Baker Deployment Sleeve 12,421' 2-7/8" STL Box x 2-7/8" FL4S Pin XO - ID=2.34" 12,423' 2-7/8" FL4S Box x 2-7/8" STL Pin XO - ID=2.34" 12,638' 2-7/8" Composite Bridge Plug w/ 32' of cement (plug 12,670') 13,825' Baker Float Collar 13,853' 2-7/8" Tubing, Perforated (4) 3/8" holes pert/ft- Btm @ 14,613' 14,613' BKR Guide Shoe- Btm @ 14,614' PERFORATION DETAIL Top MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size SPF 0,634' 10,668' 7,173' 7,203' 34' 3/12/18 Open 2-1/2" 6 D,712' 10,726' 7,242' 7,255' 14' 3/12/18 Open 2-1/2" 6 D,731' 10,751' 7,259' 7,277' 20' 3/12/18 Open 2-1/2" 6 D,756' 10,786' 7,282' 1 7,308' 30' 1 3/11/18 1 Open 2-1/2" 6 2,720' 13,190' 8,799' 1 8,827' 470' 1 4/18/2001 1 Closed 2" 4 3,220' 13.500' 8,828' 1 8,869' 280' 1 4/18/2001 1 Closed 2" 4 Ref Log: SLB SCMT Log Dated: March 1, 2001 GENERAL WELL INFO API: 50-029-22744-01-00 Drilled March 1997 Deepen to the Sag River formation - December 2000 CTU Horizontal Sidetrack Nordic#1-4/21/2001 Jet Pump Completion - April 2001 Plug Back and Add Kuparuk Perfs - 3/12/2018 TD=14,615' (MD) / TD = 8,879'(TVD) PBTD=14,614 (MD) / PBTD = 8,879"(TVD) Revised By: TDF 10/19/2021 Milne Point ASR Rig 1 BOPE /8" x 5" VB R fl es STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION By Samantha Carlisle at 12:55 pm, Oct 19, 2021 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool Repair Well ❑ Re-enter Susp Well ❑ Other: Install Patch ❑� 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: Hilcorp Alaska LLC Development Q - Stratigraphic ❑ Exploratory ❑ Service ❑ 200-198 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage, AK 99503 50-029-22744-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025509 & ADL0355018 MILNE PT UNIT F-73A 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 14,614 feet Plugs measured 12,638 feet true vertical 8,879 feet Junk measured N/A feet Effective Depth measured 12,638 feet Packer measured 10,492 & 10,568 feet true vertical 8,761 feet true vertical 7,047 & 7,114 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Surface 5,873' 9-5/8" 5,904' 4,577' 5,750psi 3,090psi Production 11,049' 7" 11,080' 7,571' 7,240psi 5,410psi Liner 2,129' 4-1/2" 12,696' 8,789' 8,430psi 7,500psi Liner 2,201' 2-7/8" 14,614' 8,879' 10,570psi 11,170psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / L-80 / NSCT 10,561' 7,108' Baker S-3 Packers and SSSV (type, measured and true vertical depth) Baker ZXP N/A See Above N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 2,984 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Daily Report of Well Operations ❑ Exploratory ❑ Development ]r Service ❑ Stratigraphic ] Copies of Logs and Surveys Run ] 16. Well Status after work: Oil 0 Gas ❑ WDSPL _ Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG �f 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 321-363 Digitally signed by David David Haakinson Haakinson (3533) Authorized Name and (3533) D" on=David Haakinson (3533), .-Users Contact Name: Taylor Wellman Digital Signature with Date: Date: 2021.10.1911:12:46-o3'o0' Contact Email: twellman(d)hilcorp.com Authorized Title: Operations Manager Contact Phone: 907-777-8449 Sr Pet Eng: MGR190CT2021 ISr Pet Geo: SFD 10/20/2021 1 ISrResEng: DSR 10/1 P RBDMS HEW 10/19/2021 Form 10-404 Revised 10/2021 Submit Within 30 days of Operations IIilcorp Alaska. LLC KBE = 42.10' Doyon 141 SCHEMATIC WELLHEAD Milne Point Unit Well: MPU F-73A Last Completed: 4/22/2001 PTD: 200-198 Tree 3-1/8" - 5M 11" 5M Gen. 5 w/ 3-1/2" FMC Tbg Wellhead Hng.3-1/2" NSCT thread on bottom. 3 CIW "H" BPV Profile --- HOLE / CEMENT DETAIL : of Arctic Set (Approx) in 24" Hole sx PF 'E' , 411sx Class 'G' in a 12-1/4" Hole K Class "G" in 8-1/2" Hole K Class "G" in 6-1/8" Hole Class "G" in 3-3/4" Hole CASING DETAIL WELL INCLINATION DETAIL KOP @ 400' MD Hole Angle at Jet Pump 28.5 deg @ 10,461' MD Hole Angle 64 to 66 Deg. f/ 4,445' t/ 8,627' Hole Angle +72.95 deg f/ 12,758' t/ 14,614' MD Hole Angle perfs = 68-82 deg f/ 12720' t/ 13,500' Type Wt/ Grade/ Conn ID Top Btm Conductor 91.1 / H-40 N/A Surface 112' Surface 40 / L-80 / BTC 8.835 Surface 5,904' Production 26 / L-80 / BTC-M 6.276 Surface 11,080' Liner 12.6 / L-80 / BTC 3.958 10,568' 12,696' Liner 6.16 / L-80 / STL 2.441 12,413' 14,614' TUBING DETAIL Tubing 9.2 / L-80 / NSCT 2.992 1 Surface 10,561' JEWELRY DETAIL Depth Item 2,482' 3.5" x 1" KBUG GLM w/ DGLV 04/30/01 10,454' Phoenix Discharge Pressure Sub (Not operable) 10,461' Baker Model CMU Sliding Sleeve (Sleeve open 7-21-21 10 A set 7-21-21) 10,471' Phoenix Multisensor (Not operable) 10,492' Baker Model S-3 Packer 10,521' 3-1/2" XN Nipple -I D=2.75" 10,560' 3-1/2" NSCT 9 CR WLEG - Bottom @ 10,561' 10,568' Baker ZXP Packer 10,583' RS Nipple - ID= 4.25" 10,585' Baker Flexlock Hanger 12,414' Baker Deployment Sleeve 12,421' 2-7/8" STL Box x 2-7/8" FL4S Pin XO - I D=2.34" 12,423' 2-7/8" FL4S Box x 2-7/8" STL Pin XO - I D=2.34" 12,638' 2-7/8" Composite Bridge Plug w/ 32' of cement (plug 12,670') 13,825' Baker Float Collar 13,853' 2-7/8" Tubing, Perforated (4) 3/8" holes perf/ft- Btm @ 14,613' 14,613' BKR Guide Shoe - Btm @ 14,614' PERFORATION DETAIL fop MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size SPF 1,634' 10,668' 7,173' 7,203' 34' 3/12/18 Open 2-1/2" 6 1,712' 10,726' 7,242' 7,255' 14' 3/12/18 Open 2-1/2" 6 1,731' 10,751' 7,259' 7,277' 20' 3/12/18 Open 2-1/2" 6 1,756' 10,786' 7,282' 7,308' 30' 1 3/11/18 Open 2-1/2" 6 .,720' 13,190' 8,799' 8,827' 470' 1 4/18/2001 Closed 2" 4 i,220' 13.500' 8,828' 8,869' 280' 1 4/18/2001 Closed 2" 4 Ref Log: SLB SCMT Log Dated: March 1, 2001 GENERAL WELL INFO API: 50-029-22744-01-00 Drilled March 1997 Deepen to the Sag River formation - December 2000 CTU Horizontal Sidetrack Nordic#1-4/21/2001 Jet Pump Completion - April 2001 Plug Back and Add Kuparuk Perfs - 3/12/2018 TD=14,615' (MD) / TD = 8,879'(TVD) PBTD=14,614' (MD) / PBTD = 8,879"(TVD) Revised By: DLW 04/19/2021 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-73A Slickline 50-029-22744-01-00 1 200-198 8/13/2021 10/16/2021 8/11/2021 - Wednesday No operations to report. 8/12/2021 - Thursday No operations to report. 8/13/2021 - Friday GR/CCL and 3.5" paragon packer and set packer mid -element @ ±8 555' MD. 8/14/2021 - Saturday WELL S/I ON ARRIVAL, DSO NOTIFIED, PT PCE 250L/3500H*** (set patch). RAN 1.69" DPU (start: 08:38, programed for 200min) W/ 3.5" TOP PARAGON PACKER, 25' 1.9" PATCH SECTION, LATCH SEAL ASSY (oal: 27') & SET IN LOWER PACKER @ 8,572' SLM (8,566' MD), GOOD PULL TEST. RAN PARAGON PACKER TEST TOOL & S/D IN UPPER PACKER @ 8,546' SLM (8,540' MD), LRS PUMPED ATTEMPTED TO PRESSURE UP TUBING, GOT UP TO 200psi & FLUID PUMPS AWAY, SHEARED RB IN 10min, PACKER APPEARED TO MOVE DOWN HOLE 14' DOWN TO 8,560' SLM (8,554' MD). RAN 3.5" D&D HOLE FINDER & S/D HIGH @ 8,360' SLM (8,354' MD), LRS PRESSURED UP TUBING TO 600psi, PRESSURE FALLS OFF SLOWLY, BOTH ELEMENTS ON D&D INTACT. RAN 2.78" CENT, 2.5" JUS (steel) & PULLED PATCH TEST TOOL FROM 8,561' SLM (8,555' MD), ALL ORINGS RECOVERED. WELL S/I ON DEPARTURE, DSO NOTIFIED. CONTINUE ON 8-15-21 WSR. 8/15/2021 - Sunday CONTINUE FROM 08-14-21 WSR. WELL S/I ON ARRIVAL, DSO NOTIFIED, PT PCE 250L/3500H*** (pull patch). PULLED UPPER PACKER W/ PATCH SECTION & STINGER FROM 8,561' SLM (8,555' MD), PACKER ELEMENTS INTACT. PULLED LOWER PACK OFF FROM 8,590' SLM (8,584' MD), PACK OFF MOVED SLIGHTLY UPHOLE EACH HIT, CAME FREE @ 8,585' SLM (8,579' MD), MISSING 2 FULL ELEMENTS. RAN 2'x1-7/8" STEM, 3-1/2" 3 PRONG WIRE GRAB DOWN TO JET PUMP @ 10,467' SLM (10,461' MD), RECOVERED 1 FULL ELEMENT, STILL MISSING 1 FULL ELEMENT & BOTH ELEMENT SPRINGS. RAN 3-1/2" GR (steel) & ATTEMPTED TO PULL JET PUMP @ 10,467' SLM (10,461' MD), GR SHEARED AFTER 50 min. WELL S/I ON DEPARTURE, DSO NOTIFIED. CONTINUE ON 8-16-21 WSR. 8/16/2021 - Monday WELL S/I ON ARRIVAL, DSO NOTIFIED, PT PCE 250L/3,500H (pull jp / caliper). PULLED 3" JET PUMP 3" JET PUMP (sn: HC-00028, ratio: 10A) W/ SCREEN, ALL PACKING & PINS RECOVERED, PACKER ELEMENT RECOVERED IN PUMP, UNABLE TO DISLODGE RUBBER FROM PUMP NOZZLE. RAN READ 24 ARM CALIPER & LOGGED TUBING FROM 10,500' SLM (10,494' MD) UP TO 8,300' SLM (8,294' MD) AS PER CUSTOMER REQUEST (good data). WELL S/I ON DEPARTURE, DSO NOTIFIED. 8/17/2021-Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-73A Slickline 50-029-22744-01-00 1 200-198 8/13/2021 10/16/2021 10/6/2021 - Wednesday No operations to report. 10/7/2021 - Thursday No operations to report. 10/8/2021 - Friday CONTINUE WSR FROM 10-7-21, PT PCE 300L / 3000H. SET 3" JETPUMP (serial#-BP-1111, ratio: 10A) IN CMU-XD AT 10,461' MD. RAN 2.65" CENT, 1-3/4" SAMPLE BAILER (with horsetail) TO 8,700' SLM(unable to locate hole). LRS PUMPED 30bbls CRIELSEL BUT UNABLE TO GAIN TUBING PRESSURE (went on vac). CONTINUE WSR ON 10-9-21. 10/9/2021 - Saturday CONTINUE WSR FROM 10/08/21, PT PCE 300L / 3000H. RAN IN TO SET 3-1/2" D&D HOLEFINDER, BUT SET DOWN HIGH @ 8400' AND UNABLE TO WORK PAST. RAN 3-1/2" BRUSH, 2.75" GAUGE RING TO 8,700' SLM MAKE SEVERAL PASSES(appears clear). ATTEMPT TO SET 3-1/2" D&D HOLEFINDER AT 8,700' SLM (unable to shear sb so pull D&D back out). 10/10/2021 - Sunday CONTINUE WSR FROM 10-09-21, PT PCE 300L / 3000H. SET 3-1/2" D&D HOLEFINDER AT 8,714' SLM / 8,722' MD. LRS PUMP 30 BBLS CRIESEL .(well went on a vac). RAN 2.65" CENT, 1-3/4" SAMPLE BAILER(with horsetail) TO 8,700' SLM .(unable to identify any leaks due to fluid going by D&D). PULL 3-1/2" D&D HOLEFINDER FROM 8,714' SLM / 8,722' MD. SET 3-1/2" TUBING STOP AT 8,562' SLM / 8,575' MD. (tagged jet pump and pulled into position -13' correction). CONTINUE WSR ON 10-11-21. 10/11/2021 - Monday CONTINUE WSR FROM 10-10-21, PT PCE 300L / 3000H. SET LOWER PACKER AT 8,560' SLM / 8,573' MD. SET 3-1/2" G- FISHNECK, STAND PIPE, STINGER AT 8,536' SLM / 8,549' MD. SET 3-1/2" UPPER PACKER, STANDPIPE, STINGER AT 8,513, SLM / 8,526' MD. SET AND PULL 3-1/2" TEST TOOL FROM PATCH ASSEMBLY AT 8,513' SLM. LRS PUMPED 40 BBLS FLUID (unable to catch pressure). CONTINUE WSR ON 10-12-21. 10/12/2021-Tuesday CONTINUE WSR FROM 10-11-21, PT PCE 300L / 3000H. RAN 3-1/2" D&D HOLFINDER FROM PATCH AT 8,526' SLM(— 13 deeper) TO SURFACE. STOP @ 8,508', 8000', 7000', 4000', 3000, 2000' 1000' (all stops failed). LRS PUMPED 70bbls WATER AND 15bbls 60/40. CONTINUE WSR ON 10-13-21. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-73A Slickline 50-029-22744-01-00 1 200-198 8/13/2021 10/16/2021 10/13/2021 - Wednesday CONTINUE WSR FROM 10-12-21. WEATHER HOLD DUE TO HIGH WINDS. CONTINUE WSR ON 10-14-21. 10/14/2021 - Thursday No operations to report. 10/15/2021 - Friday WELL SHUT-IN ON ARRIVAL, PT PCE 300L / 3000H. PULL UPPER PACKER, STANDPIPE, STINGER FROM 8,528' SLM (15' deeper than initial set). CONTINUE WSR ON 10-16-21. 10/16/2021 - Saturday CONTINUE WSR FROM 10-15-21, PT PCE 300L/ 3000H. 2 FOR 1. G-FISHNECK, STANDPIPE, STINGER+ LOWER PACKER(missing rubber element) AT 8,550' MD. PULL 3-1/2" TUBING STOP FROM 8,570' SLM. PULL 3" JET PUMP (serial# - BP-1111, ratio: 10A) FROM CMU-SSD AT 10,461' MD. RAN SBHPS AS PER RPOGRAM(good data). WELL SHUT-IN ON DEPARTURE, NOTIFIED PAD OP. 10/17/2021 - Sunday No operations to report. 10/18/2021 - Monday No operations to report. 10/19/2021-Tuesday No operations to report. PTD : 2001980 E-Set: 35805 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 IFilenris Aiarka_ ILL E-mail: kaitlyn.barcelona@hilcorp.com RECEIVED By Abby Bell at 3:06 pm, Oct 14, 2021 DATE:10/14/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-73A (PTD 200-198) Caliper 08/16/2021 Name Type Size AutoPlay Filefolder Data to View Filefolder Installation Files Filefolder -; autorun Application 6,253 KB autorun Setup Information 1 KB F-73A 2071-M-16 READ Microsoft Edge PDF Document 2,670 KB Iua5.1.dll Application extension 319 KB Iua5l.dll Application extension 11 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: ,rQ�� 10/14/2021 PTD: 2001980 E-Set: 35569 David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 11 Anchorage, AK 99503 Hilcorp North Slope, i_LC Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Date: 08/25/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 RECEIVED By Abby Bell at 9:09 am, Aug 26, 2021 SFTP DATA TRANSMITTAL: MPU F-73A Set Packer (PTD 200-198) FTP Folder Contents: Log Print Files and LAS Data Files: Name Date modified T:pE Size MPU_F-73A_SET PAC KERREC0RD_13-AU GUST-2021(3469),pdf 8/20/20214,03 P M 41 MPU_F-73A_SETPACKER REcaRD_13-AUGUST-2021(3469),las 8/20/20214;0BPM Please include current contact information if different from above. Please acknowledge receipt and return one copy of this transmittal. Received By: Date: '41 l3 10/15/2021 PDF Document 1,462KB L�:S HE 59 KB PTD : 2001980 E-Set: 35494 David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Hileorp Norm slope, LLc Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Date: 08/06/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 01 SFTP DATA TRANSMITTAL RECEIVED MPU F-73A (PTD 200-198) By Abby Bell at 3:28 pm, Aug 06, 2021 FTP Folder Contents: Log Print Files and LAS Data Files: Name Date modified Type Size LAS 8/6,12021 3:06 PM s 2021-07-20 21039 MPU F-73A LeakDetec... 7/23/2021 9:17AM ❑ 2021-07-20 21039 MPU F-73A LeakDetec... 7/23/2021 9:17AM Please include current contact information if different from above. HE folder PDF Document 8,551 K6 11F File 5,751 K6 Please acknowledge receipt and return one copy of this transmittal. Received By: Date: 08/10/2021 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED By Meredith Guhl at 11:47 am, Jul 21, 2021 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Install Tubing Patch ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ ' Stratigraphic ❑ Service ❑ 200-198 ' 3. Address: 6. API Number: 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22744-01-00 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-73A 9. Property Designation (Lease Number): SFD 7/21/2o2i 10. Field/Pool(s): ADL0355018, ADL 0025509 MILNE POINT / KUPARUK RIVER OIL ' 1 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14,614' 8,879' 12,638' 8,761' 2,098 12,638' N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Surface 5,873' 9-5/8" 5,904' 4,577' 5,750psi 3,090psi Production 11,049' 7" 11,080' 7,571' 7,240psi 5,410psi Liner 2,129' 4-1/2" 12,696' 8,789' 8,430psi 7,500psi Liner 2,201' 2-7/8" 14,614' 8,879' 10,570psi 11,170psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 3-1/2" 9.2 / L-80 / NSCT 10,561' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): S-3 7" x 3.5" & 7" ZXP Packer and N/A 10,492 MD/ 7,047 TVD & 10,568 MD/ 7,114 TVD and N/A 12. Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: CommencingOperations: 8/4/2021 p OIL WINJ WDSPL ❑ � ❑ ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: David Haakinson Authorized Title: Operations Manager Contact Email: dhaakinsonC@hilcorp.com Chad Helgeson (1517) Contact Phone: 777-8343 Authorized Signature: 2021.07.21 11:06:11 - Date: 08'00' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 321-363 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS HEW 7/26/2021 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 0 Subsequent Form Required:10-404 APPROVED BY Jeremy Price oa" 20„9o;'31216,37 0800 7/23/21 Approved by: COMMISSIONER THE COMMISSION Date: Comm.dts 7/23/2021 ComrrLJLC 7/23/2021 JSr Pet EngMGR23JUL211 ISrPetGeo SFD 7/21/2021 Sr Res Eng Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. IIilcorp Alaska, LL Tubing Patch Well: MPU F-73 Date: 07-21-2021 Well Name: MPU F-73A API Number: 50-029-22744-01-00 Current Status: Shut In- JP Producer Pad: F-Pad Estimated Start Date: August 41", 2021 Wellwork unit: SL/EL Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 200-198 First Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) Second Call Engineer: David Gorm (907) 777-8333 (0) (505) 215-2819 AFE Number: Job Type: Tubing Patch Current Bottom Hole Pressure: 2,640 psi @ 7,020' TVD Downhole Gauge: 6/20/21 1 7.23 PPGE Maximum Expected BHP: 2,800 psi @ 7,020' TVD 30-day PBU Extrapolation 1 7.67 PPGE MPSP: 2,098 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 65' Sail Angle Max Dogleg: 3.3°/100ft @ 6,815' MD Brief Well Summary: MPU producer F-73 is completed in the Kuparuk formation as a jet pump producer. The well was shut-in in April 2021 due to a tubing leak after the power fluid rate increased beyond design. Consideration for a possible RWO, and conversion to injection were considered but ultimately an attempt to patch the tubing leak was determined. A caliper and LDL were completed and identified the tubing leak at 8,540' MD. Notes Regarding Wellbore Condition • Combo MIT -IA Passed at 3,592 psig on 4/17/2021. • Single Tubing leak confirmed at 8,540' MD on 7/20/2021 with slickline memory leak detect. • Tubing Caliper indicated 60% wall loss in the area. This is anticipated to be a short 1-2 year solution. Objective: • Set Paragon packer tubing patch (Sundry Approval Required) Prnrarh irp E-line 1. MIRU EL. PT lubricator to 200 psig low, 3,500 psig high. 2. RIH with GR/CCL and 3.5" paragon packer and set packer mid -element @ ±8,555' MD a. Correlate to SL Memory Spin ner/GR/CCL log dated 7-20-2021 Slickline 3. MIRU SL. PT lubricator to 200 psig low, 3,500 psig high. 4. RIH with latch seal assembly, +/- 25' of 1.9" spacer pipe, and top 3.5" paragon packer. 5. Land in lower paragon packer and set top packer mid -element @ ±8,530' MD 6. RIH with 3.5" paragon packer test tool and land in upper packer. 7. PT tubing to 2,500 psig to confirm upper packer and up -hole tubing integrity. 8. RDMO Slick -line IIiloorp Alaska, LL Attachments: 1) Current Schematic 2) Proposed Schematic Tubing Patch Well: MPU F-73 Date: 07-21-2021 Hilcorp Alaska, LLC KBE = 42.10' Doyon 141 SCHEMATIC WELLHEAD Milne Point Unit Well: MPU F-73A Last Completed: 4/22/2001 PTD: 200-198 Tree 3-1/8" - 5M 11" 5M Gen. 5 w/ 3-1/2" FMC Tbg Wellhead Hng. 3-1/2" NSCT thread on bottom. 3 CIW "H" BPV Profile --- HOLE / CEMENT DETAIL : of Arctic Set (Approx) in 24" Hole sx PF 'E' , 411sx Class 'G' in a 12-1/4" Hole K Class "G" in 8-1/2" Hole K Class "G" in 6-1/8" Hole Class "G" in 3-3/4" Hole CASING DETAIL WELL INCLINATION DETAIL KOP @ 400' MD Hole Angle at Jet Pump 28.5 deg @ 10,461' MD Hole Angle 64 to 66 Deg. f/ 4,445' t/ 8,627' Hole Angle +72.95 deg f/ 12,758' t/ 14,614' MD Hole Angle perfs = 68-82 deg f/ 12720' t/ 13,500' Type Wt/ Grade/ Conn I D Top Btm Conductor 91.1 / H-40 N/A Surface 112' Surface 40 / L-80 / BTC 8.835 Surface 5,904' Production 26 / L-80 / BTC-M 6.276 Surface 11,080' Liner 12.6 / L-80 / BTC 3.958 10,568' 12,696' Liner 6.16 / L-80 / STL 2.441 12,413' 14,614' TUBING DETAIL Tubing 9.2 / L-80 / NSCT 2.992 1 Surface 10,561' JEWELRY DETAIL Depth Item 2,482' 3.5" x 1" KBUG GLM w/ DGLV 04/30/01 10,454' Phoenix Discharge Pressure Sub (Not operable) 10,461' Baker Model CMU Sliding Sleeve (Sleeve closed 04/16/21) 10,471' Phoenix Multisensor (Not operable) 10,492' Baker Model S-3 Packer 10,521' 3-1/2" XN Nipple - ID=2.75" (XXN plug set 04/16/21) 10,560' 3-1/2" NSCT 9 CR WLEG - Bottom @ 10,561' 10,568' Baker ZXP Packer 10,583' RS Nipple - ID= 4.25" 10,585' Baker Flexlock Hanger 12,414' Baker Deployment Sleeve 12,421' 2-7/8" STL Box x 2-7/8" FL4S Pin XO - ID=2.34" 12,423' 2-7/8" FL4S Box x 2-7/8" STL Pin XO - ID=2.34" 12,638' 2-7/8" Composite Bridge Plug w/ 32' of cement (plug 12,670') 13,825' Baker Float Collar 13,853' 2-7/8" Tubing, Perforated (4) 3/8" holes pert/ft- Btm @ 14,613' 14,613' BKR Guide Shoe - Btm @ 14,614' PERFORATION DETAIL fop MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size SPF 1,634' 10,668' 7,173' 7,203' 34' 3/12/18 Open 2-1/2" 6 1,712' 10,726' 7,242' 7,255' 14' 3/12/18 Open 2-1/2" 6 1,731' 10,751' 7,259' 7,277' 20' 3/12/18 Open 2-1/2" 6 1,756' 1 10,786' 1 7,282' 1 7,308' 1 30' 1 3/11/18 1 Open 2-1/2" 6 ;720' 13,190' 1 8,799' 1 8,827' 1 470' 1 4/18/2001 1 Closed 2" 4 i,220' 13.500' 1 8,828' 1 8,869' 1 280' 1 4/18/2001 1 Closed 2" 4 Ref Log: SLB SCMT Log Dated: March 1, 2001 GENERAL WELL INFO API: 50-029-22744-01-00 Drilled March 1997 Deepen to the Sag River formation - December 2000 CTU Horizontal Sidetrack Nordic#1-4/21/2001 Jet Pump Completion - April 2001 Plug Back and Add Kuparuk Perfs - 3/12/2018 TD=14,615' (MD) / TD = 8,879'(TVD) PBTD=14,614' (MD) / PBTD = 8,879"(TVD) Revised By: NLW 04/19/2021 Hilcorp Alaska, LLC KBE = 42. VY Doyon 141 PROPOSED WELLHEAD Milne Point Unit Well: MPU F-73A Last Completed: 4/22/2001 PTD: 200-198 Tree 3-1/8" - 5M 11" 5M Gen. 5 w/ 3-1/2" FMC Tbg Wellhead Hng. 3-1/2" NSCT thread on bottom. 3 CIW "H" BPV Profile HOLE / CEMENT DETAIL : of Arctic Set (Approx) in 24" Hole sx PF 'E' , 411sx Class 'G' in a 12-1/4" Hole K Class "G" in 8-1/2" Hole K Class "G" in 6-1/8" Hole Class "G" in 3-3/4" Hole CASING DETAIL WELL INCLINATION DETAIL KOP @ 400' MD Hole Angle at Jet Pump 28.5 deg @ 10,461' MD Hole Angle 64 to 66 Deg. f/ 4,445' t/ 8,627' Hole Angle +72.95 deg f/ 12,758' t/ 14,614' MD Hole Angle perfs = 68-82 deg f/ 12720' t/ 13,500' Type Wt/ Grade/ Conn ID Top Btm Conductor 91.1 / H-40 N/A Surface 112' Surface 40 / L-80 / BTC 8.835 Surface 5,904' Production 26 / L-80 / BTC-M 6.276 Surface 11,080' Liner 12.6 / L-80 / BTC 3.958 10,568' 12,696' Liner 6.16 / L-80 / STL 2.441 12,413' 14,614' TUBING DETAIL Tubing 9.2 / L-80 / NSCT 2.992 1 Surface 10,561' JEWELRY DETAIL Depth Item 2,482' 3.5" x 1" KBUG GLM w/ DGLV 04/30/01 10,454' Phoenix Discharge Pressure Sub (Not operable) 10,461' Baker Model CMU Sliding Sleeve (Sleeve closed 04/16/21) 10,471' Phoenix Multisensor (Not operable) 10,492' Baker Model S-3 Packer 10,521' 3-1/2" XN Nipple - ID=2.75" (XXN plug set 04/16/21) 10,560' 3-1/2" NSCT 9 CR WLEG - Bottom @ 10,561' 10,568' Baker ZXP Packer 10,583' RS Nipple - ID= 4.25" 10,585' Baker Flexlock Hanger 12,414' Baker Deployment Sleeve 12,421' 2-7/8" STL Box x 2-7/8" FL4S Pin XO - ID=2.34" 12,423' 2-7/8" FL4S Box x 2-7/8" STL Pin XO - ID=2.34" 12,638' 2-7/8" Composite Bridge Plug w/ 32' of cement (plug 12,670') 13,825' Baker Float Collar 13,853' 2-7/8" Tubing, Perforated (4) 3/8" holes pert/ft- Btm @ 14,613' 14,613' BKR Guide Shoe- Btm @ 14,614' PERFORATION DETAIL 'op V1D) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size SPF ,634' 10,668' 7,173' 7,203' 34' 3/12/18 Open 2-1/2" 6 ,712' 10,726' 7,242' 7,255' 14' 3/12/18 Open 2-1/2" 6 ,731' 10,751' 7,259' 7,277' 20' 3/12/18 Open 2-1/2" 6 ,756' 10,786' 7,282' 1 7,308' 30' 1 3/11/18 1 Open 1 2-1/2" 6 ,720' 13,190' 8,799' 1 8,827' 470' 1 4/18/2001 1 Closed 2" 4 ,220' 13.500' 8,828' 1 8,869' 280' 1 4/18/2001 1 Closed 2" 4 Ref Log: SLB SCMT Log Dated: March 1, 2001 GENERAL WELL INFO API: 50-029-22744-01-00 Drilled March 1997 Deepen to the Sag River formation - December 2000 CTU Horizontal Sidetrack Nordic#1-4/21/2001 Jet Pump Completion - April 2001 Plug Back and Add Kuparuk Perfs - 3/12/2018 TD=14,615' (MD) / TD= 8,879'(TVD) PBTD=14,614 (MD) / PBTD = 8,879"(TVD) Revised By: TDF 7/21/2021 PTD: 2001980 E-Set: 35083 Hilrnrr A14ipkm,1 JAL: DATE: 05/04/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-73A (PTD 200-198) Multi Finger Caliper Survey Log 04/19/2021 Name Type LAS File folder t MPU_F-73,E_19-Apr-21_CaliperSurre.,,rLog PDF Document ® MPU_F-73A_19-Apr-21_CaliperSur,eyLoq 11F File Please include current contact information if different from above. Received by the AOGCC 05/04/2021 Size 19,549 KB 14,372 KB Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: 4'�4 l3 05/04/2021 PTD:2001980 E-Set: 35042 Samuel 80orp Alaska, LLC GeoTechnician ician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 udrnq. u:,.l,a. i.tx, Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com DATE: 04/23/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Q MPU i-8 �PTD 6) Multi Finger Caliper Log 04/19/2021 flame AutoPlay Data to View Installation Files autorun u� autorun F-73A 2021-04-19 READ J lua5.1.dll 1ua51,dIl Type Size Filefolder Filefolder Filefolder Application 6,253 KB Setup Information 1 KB PDF Document 4,287 KB Application extension 319 KB Application extension 11 KB Please include current contact information if different from above. Received by the AOGCC 04/23/2021 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received 6y: Date: AZZ_. DD 04/26/2021 9 STATE OFALASKA SKA OIL AND GAS CONSERVATION CO MISSION R ORT OF SUNDRY WELL OPERATIONS S'.4r4 MAY 10 201 1. Operations Abandon LJ Plug Perforations ✓ Fracture Stimulate Ll Pull Tubing Li erations h o Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑✓ Alter Casing ❑ Chang rr Plug for Redrill ❑ Perf New Pool Q Repair Well ❑ Re-enter Susp Well ❑ Other: t❑� u 2. Operator k-., Name: Hilcorp Alaska LLC 4. Well Class Before Work: Development ❑ Exploratory ❑ Stratigraphic ❑ Service Q 5. Permit to Drill Number: 200-198 L 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-22744-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0355018 MILNE PT UNIT F-73A 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 14,614 feet Plugs measured 12,638 feet true vertical 8,879 feet Junk measured N/A feet Effective Depth measured 12,638 feet Packer measured 10,492 & 10,568 feet true vertical 8,761 feet true vertical 7,047 & 7,114 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Surface 5,873' 9-5/8" 5,904' 4,577' 5,750psi 3,090psi Production 11,049' 7" 11,080' 7,571' 7,240psi 5,410psi Liner 2,129' 4-1/2" 12,696' 8,789' 8,430psi 7,500psi Liner 2,201' 2-7/8" 14,614' 8,879' 10,570psi 11,170psi JUN 2 Perforation depth Measured depth See Schematic feet a'Iidt True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / L-80 / NSCT 10,561' 7,108' Baker S-3 10,492' / 7,047' Packers and SSSV (type, measured and true vertical depth) Baker ZXP 10,568' / 7,114' N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10,634' to 10,786' Treatment descriptions including volumes used and final pressure: 285 BBLS 2% KCL. Final Pressure= 1,834psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 560 0 Subsequent to operation: 137 67 635 3,333 328 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory ❑ Development Q Service ❑ Stratigraphic Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil L✓j Gas WD PL Lj Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPL JIG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-047 Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pchan@hilcorp.com Authorized Signature: Date: 5/16/2018 Contact Phone: 777-8333 /I Form 10-404 Revised 4/2017 RBDMSd-l-\ MAY L l 1018 44�i Submit Original Only • Ifileorp Alaska, L1,C KBE =42.10' Doyon 141 • Milne Point Unit Well: MPU F-73A SCHEMATIC Last Completed: 4/22/2001 PTD: 200-198 WELLHEAD Tree 3-1/8" - 5M 11" 5M Gen. 5 w/ 3-1/2" FMC Tbg Wellhead Hng. 3-1/2" NSCT thread on bottom. 3 CIW "H" BPV Profile I HOLE / CEMENT DETAIL c of Arctic Set (Approx) in 24" Hole isx PF'E' , 411sx Class 'G' in a 12-1/4" Hole x Class "G" in 8-1/2" Hole x Class "G" in 6-1/8" Hole Class "G" in 3-3/4" Hole NOTE: Well requires the installation of a SSSV during the next RWO WELL INCLINATION DETAIL KOP@400'MD Hole Angle at Jet Pump 28.5 deg @ 10,461' MD Hole Angle 64 to 66 Deg. f/ 4,445' t/ 8,62 ' Hole Angle +72.95 deg f/ 12,758' t/ 14,61L ' MD Hole Angle perfs = 68-82 deg f/ 12720' t/'13,500' CASING DETAIL Type Wt/ Grade/ Conn ID Top Btm Conductor 91.1 / H-40 N/A Surface 112' Surface 40/ L-80/ BTC 8.835 Surface 5,904' Production 26 / L-80 / BTC-M 6.276 Surface 11,080' Liner 12.6 / L-80 / BTC 3.958 10,568' 12,696' Liner 6.16 / L-80 / STL 2.441 12,413' 1 14,614' TUBING DETAIL Tubing 9.2 / L-80 / NSCT 2.992 1 Surface 10,561' JEWELRY DETAIL Depth Item 2,482' 3.5" x 1" KBUG GLM w/ RP Shear 10,454' Phoenix Discharge Pressure Sub (Not operable) 10,461' Baker Model CMU Sliding Sleeve (11D JP installed 3-31-18 10,471' Phoenix Multisensor (Not operable) 10,492' Baker Model S-3 Packer 10,521' 3-1/2"XNNipple -ID=2.75" 10,560' 3-1/2" NSCT 9 CR W LEG - Bottom @ 10,561' 10,568' Baker ZXP Packer 10,583' RS Nipple - ID= 4.25" 10,585' Baker Flexlock Hanger 12,414' Baker Deployment Sleeve 12,421' 2-7/8" STL Box x 2-7/8" FL4S Pin XO - ID=2.34" 12,423' 2-7/8" FL4S Box x 2-7/8" STL Pin XO - ID=2.34" 12,638' 2-7/8" Composite Bridge Plug w/ 32' of cement (plug 12,670') 13,825' Baker Float Collar 13,853' 2-7/8" Tubing, Perforated (4) 3/8" holes perf/ft- Btm @ 14,613' 14,613' BKR Guide Shoe - Btm @ 14,614' PERFORATION DETAIL Fop AD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size SPF 1,634' 10,668' 7,173' 7,203' 34' 3/12/18 Open 2-1/2" 6 1,712' 10,726' 7,242' 7,255' 14' 3/12/18 Open 2-1/2" 6 1,731' 10,751' 7,259' 7,277' 20' 3/12/18 Open 2-1/2" 6 1,756' 10,786' 1 7,282' 7,308 30' 3/11/18 1 Open 2-1/2" 6 ;720' 13,190' 1 8,799' 8,827' 470' 4/18/2001 Closed 2" 4 i,220' 13.500 1 8,828' 8,869' 280' 4/18/2001 Closed 2" 4 Ref Log: SLB SCMT Log Dated: March 1, 2001 GENERAL WELL INFO API: 50-029-22744-01-00 Drilled March 1997 Deepen to the Sag River formation - December 2000 CTU Horizontal Sidetrack Nordic#1 - 4/21/2001 Jet Pump Completion -April 2001 Add Kuparuk Perfs-3/12/2018 TD=14,615' (MD) / TD = 8,879 (TVD) PBTD=14,614' (MD) / PBTD = 8,879"(TVD) Revised By: TDF 5/16/2018 E • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-73A E-Line 50-029-22744-00-00 200-198 3/7/18 4/27/18 ism 3/7/2018- Wednesday Pollard E-Line arrive and check in at Milne. PJSM. Discuss traffic and simops out at F-Pad. MIRU E-Line, MU tools and Magnum 2-7/8" Composite Bridge plug. CCL to COE = 15ft. Stab on well, PT PCE to 4,000psi. RIH. Set down at 10,560' ELM. Make several attempts to pass with no luck. Tagging top of 4-1/2" Liner. POOH. Tag up. Off well. Modify bottom of composite plug - add tapered swage to bottom. Back on well. RIH. Pass into 4-1-2" liner with no problem. Correlate to get on depth tieing into cement bond log. Set bridge plug with CCL depth at 12,655' putting center of element at 12,670'. Good indication with loss in line tension. Log off plug. Park eline at 12,328'. PT plug to 2,500psi. Passing Test. BD to 600psi. POOH with E-line. Initial T/I/O = 674psi/631psi/2psi.Starting PT pressures - 2,520psi / 663psi/2psi. (1.1 bbls to pressure up). 1st 15 min -pressures - 2,489psi / 664psi / 2psi. 2nd 15 min-pressures-2,467psi/663psi/2psi. (observed a sudden 10psi drop then TP flatlined. carry out test 15 more minutes). 3rd 15min- pressures - 2,448psi/ 663psi / 2psi. At surface. L/D plug setting tools. MU cement dump bailers. Load bailer with 3 gallons cement (16.4 ppg). Perform MITIA to 3,000psi. 2.9 bbls to pressure up to 3,062psi. 3,014psi after 15 min. 3,004psi after 30 min. Passing test. Bleed IA down to 300psi. (4 bbls). On well with Eline and dump bailer (3 gal cement). PT QTS to 4,000psi. RIH and again unable to pass into 4-1/2" liner. Make several attempts to pass with no luck. Decide to POOH and see if modifications can be made to bottom of bailer to assist getting into liner. At surface. Close SV, BD and Lay down tools and lubricator. Take tools apart, Night cap PCE. SDFN. 3/8/2018 - Thursdayl; Make modifications to bottom of cement dump bailer to enable tools to pass into 4-1/2" liner top. MU empty bailer BHA with modified bottom and make drift run. Successfully pass into 4-1/2" liner with no problem. Continue in hole and tag composite BP at 12,670'. POOH, night cap PCE. L/D lubricator, secure well and SDFN. Return tomorrow to dump cement. 3/9/2018 - Friday Make 4 dump bailer runs (3 gallons each run) and dump cement on top of 2-7/8" Composite BP set at 12,670' to provide minimum of 25' cement on top of plug. Estimated TOC at 12,638' (32' of cement on top of plug). Secure well, SDFN. Will WOC for 24 hours. 3/10/2018 -Saturday WOC 24 hrs after E-Line dump bailed cement on top of 2-7/8" Composite BP set at 12,670'. 3/11/2018 - Sunday No Activity. Dig out from blow. MU gun run #1 - 20 FT gun. 2.5" OD, 6 SPF, 60 degree phasing, GEODynamics Connex 11 gram XDP charges. Stab on well. PT QTS to 4,000psi. CCL to Top Shot = 3'. RIH, Make tie in pass, pull into position with CCL at 10,763' ELM. Shoot gun run # 1- 10,766'- 10,786'. Good indication by line tension drop. MU gun run #2 - 10 FT gun. 2.5" OD, 6 SPF, 60 degree phasing, GEODynamics Connex 11 gram XDP charges. Stab on well. PT QTS to 4,000psi. CCL to Top Shot = 3'. RIH, Make tie in pass, pull into position with CCL at 10,753' ELM. Shoot gun run # 2 - 10,756'- 10,766'. No Night Activity. SDFN • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-73A E-Line 50-029-22744-00-00 200-198 3/7/18 4/27/18 Dai[y7pet"pansng ,, 3/12/2018 - Monday MU gun run #3 - 20 ft of 2.5" OD, 6 SPF, 60 degree phasing, GEODynamics Connex 11 gram XDP charges. CCL to TS = 3'. Stab on well. PT QTS to 4,OOOpsi. RIH, Make tie in pass, pull into position with CCL at 10,728' ELM. Shoot gun run # 3 - 10,731'- 10,751'. Good indication by line tension drop. MU gun run #4 - 20 ft (with 14' of charges) of 2.5" OD, 6 SPF, 60 degree phasing, GEODynamics Connex 11 gram XDP charges. CCL to TS = 3'. Stab on well. PT QTS to 4,OOOpsi. RIH, Make tie in pass, pull into position with CCL at 10,709' ELM. Shoot gun run # 4 - 10,712'- 10,726'. Good indication by line tension drop. MU gun run #5 - 20 ft of 2.5" OD, 6 SPF, 60 degree phasing, GEODynamics Connex 11 gram XDP charges. CCL to TS = 3'. Stab on well. PT QTS to 4,OOOpsi. RIH, found FL at 220'. Make tie in pass, pull into position with CCL at 10,645' ELM. Shoot gun run # 5 - 10,648'- 10,668'. Good indication by line tension drop. MU gun run #6 - 20 ft (with 14' of charges) of 2.5" OD, 6 SPF, 60 degree phasing, GEODynamics Connex 11 gram XDP charges. CCL to TS = 3'. Stab on well. PT QTS to 4,OOOpsi. RIH, found FL at 270'. Make tie in pass, pull into position with CCL at 10,631' ELM. Shoot gun run # 6 - 10,634'- 10,648'. Good indication by line tension drop. POOH. During entire perf operations WHP remained at Opsi. When out of hole, well on vac. When on bottom, slight positive WHP. Fluid level in well slowly falling. All shots fired on all guns. L/D lubricator. SDFN. Secure well. Return tomorrow to RDMO. 3/13/2018 - Tuesday RDMO Pollard E-Line equipment :7 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-73A E-Line 50-029-22744-00-00 200-198 3/7/18 4/27/18 Daily Operations: j 3/14/2018 - Wednesday No activity to report. 3/15/2018 - Thursday No activity to report. 3/16/2018 - Friday **WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H**. OPEN CMU-SS AT 10,452' SLM/10,461' MD. SET 3" JET PUMP (serial# BP-1063, ratio: 9D, spartek gauges, OAL=131") IN CMU-SS AT 10,461' MD. 3/17/2018 - Saturday No activity to report. 3/18/2018 - Sunday No activity to report. 3/19/2018 - Monday No activity to report. 3/20/2018 - Tuesday No activity to report. C. i Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-73A E-Line 50-029-22744-00-00 200-198 3/7/18 4/27/18 �tperations: 3/21/2018 - Wednesday No activity to report. 3/22/2018 - Thursday No activity to report. 3/23/2018 - Friday No activity to report. 3/24/2018 - Saturday No activity to report. 3/25/2018 - Sunday No activity to report. 3/26/2018 - Monday No activity to report. 3/27/2018-Tuesday **WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H**. RUN 10' x 2.25" HYDROSTATIC BAILER, FLAT BALL BTM TO 10,455' SLM, BAILER FULL OF FLUID, METAL MARKS ON BAILER BTM. MAKE TWO ATTEMPTS W/ 3-1/2" GR & GS TO PULL JET PUMP @ 10,457' SLM / 10,461' MD, UNSUCCESSFUL. *BTM SHEAVE BROKE & WIRE KINKED @ 10,470' SLM, WIRE OUT OF TOP SHEAVE (MAN BASKET TO ASSIST)*. • 0 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date =nd Date MP F-73A E-Line 50-029-22744-00-00 1 200-198 3/7/18 1 4/27/18 mj Daily era �: �7 3/28/2018 - Wednesday WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H. PULL 3" JET PUMP (SER #: BP-1063, RATIO 9D, DUAL SPARTEK GAUGES, OAL= 131"), @ 10,457' SLM / 10,461' MD. RECOVER ALL NUBBINS, MISSING 1 PIECE OF PACKING, DISCONNECT BATTERIES @ 13:37, PUMP APPEARS TO BE PLUGGED. RUN 3-1/2" 42BO POSITIONING TOOL (keys down to close) & SHIFT CMU SSD DOWN @ 10,461' SLM / 10,461' MD. DRIFT TBG W/ KN, 2.12" CENT, Tx 1-1/2" STEM, 1.75" SAMPLE. 3/29/2018 - Thursday **WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H**. **LRS PUMP 42BBLs OF 60/40 & MIT IA TO 3,800psi, GOOD TEST**. RUN 3-1/2" 42BO POSITIONING TOOL (keys up to open) & SHIFT CMU SSD UP @ 10,454' SLM / 10,461' MD, *OPEN*. 3/30/2018 - Friday No activity to report. 3/31/2018 - Saturday **WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H**. SET 3" JET PUMP (SER #: BP-J25, RATIO 11D, FLOW THRU SUB, 1.25" SOFT SET & DUAL SPARTEC GAUGES, OAL=131"), IN 3-1/2" CMU SSD @ 10,457' SLM / 10,461' MD, GOOD SET. 4/1/2018 - Sunday No activity to report. 4/2/2018 - Monday No activity to report. 4/3/2018 - Tuesday No activity to report. 0 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig = API Number =Well Permit Number Start Date End Date MP F-73A E-Line 50-029-22744-00-00 1 200-198 3/7/18 4/27/18 t 4/11/2018- Wednesday No activity to report. 4/12/2018 - Thursday No activity to report. 4/13/2018 - Friday No activity to report. 4/14/2018 - Saturday No activity to report. 4/15/2018 - Sunday No activity to report. 4/16/2018 - Monday **WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H**. ATTEMPT TO PULL JET PUMP FROM CMU-SS AT 10,461' MD (unsuccessful). **L/D FOR THE NIGHT, NOTIFY PAD -OP**. 4/17/2018 - Tuesday **WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H**. PULL 3" JET PUMP W/GAUGES (serial # BP-J25, ratio: 11D, recovered all packing & nubbins, WSL check data) FROM CMU-SS AT 10,461' MD. CLOSE CMU-SS AT 10,461' MD WITH 42BO (pin not sheared). **RDMO, NOTIFY PAD -OP**. s ri Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-73A E-Line 50-029-22744-00-00 1 200-198 3/7/18 4/27/18 Daily Operations: 4/18/2018 - Wednesday No activity to report. 4/19/2018 - Thursday No activity to report. 4/20/2018 - Friday No activity to report. 4/21/2018 - Saturday HPBD- Pump 20 bbls 2% Kcl at 1.8 to 2 bpm. 60 bbls 2% Kcl at 4 bpm. 205 bbls 2% Kcl at 5 bpm. 285 bbls Total 2% Kcl pumped down Tbg. Freeze protect Tbg w/ 25 bbls 60/40. 4/22/2018 - Sunday **WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H**. RUN 2.10" CENT, 5' x 1-1/2" STEM, 2.25" CENT, 1.75" SAMPLE BAILER, DRIFT TUBING & TAG TD @ 12,546' SLM, RECOVER SAMPLE OF THICK MUD & METAL CHUNKS. 4/23/2018 - Monday No activity to report. 4/24/2018 - Tuesday No activity to report. • x; Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number =Well Permit Number Start Date End Date MP F-73A E-Line 50-029-22744-00-00 1 200-198 1 3/7/18 4/27/18 Daily Operations: 4/25/2018 - Wednesday No activity to report. 4/26/2018 - Thursday No activity to report. 4/27/2018 - Friday No activity to report. 4/28/2018 - Saturday **WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H**. RUN 3-1/2" 42BO POSITIONING TOOL (keys up to open) & SHIFT CMU SSD UP @ 10,454' SLIA / 10,461' MD, *OPEN*. SET 3" JET PUMP (SER #: BP-J25, RATIO 13B, FLOW THRU SUB, 1.25" SOFT SET & DUAL SPARTEC. GAUGES, OAL=131"), IN 3-1/2" CMU SSD @ 10,457' SLM / 10,461' MD, GOOD SET, PAD OP BRINGS WELL ON. 4/29/2018 - Sunday No activity to report. 4/30/2018 - Monday No activity to report. 5/1/2018 - Tuesday No activity to report. Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, April 18, 2018 9:04 AM To: 'Paul Chan' Cc: Bo York; Alaska NS - Wells Foreman Subject: RE: MP F-73A (PTD 200-198 / Sundry 318-047) Paul, The below HPBD procedure is approved. Please update MOC form as required. The procedure will appended to sundry 318-047 as we discussed. 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 (Guv Schwartz@alaska gov). From: Paul Chan <pchan@hilcorp.com> Sent: Tuesday, April 17, 20181:58 PM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Cc: Bo York <byork@hilcorp.com>; Alaska NS - Wells Foreman<AlaskaNS-WellsForeman@hilcorp.com> Subject: MP F-73A (PTD 200-198 / Sundry 318-047) Guy We plugged the Sag River perforations and perforated the Kuparuk sands as per the sundry. The well was placed on jet pump with gauges. The jet pump was pulled shortly thereafter due to apparent cycling of the power fluid. The jet pump was plugged with perf debris. A second jet pump and gauge was run but the well continues to cycle power fluid (confirmed by shake outs with no oil and salinity checks). The assumption is that the 2-1/2" perforating guns had limited penetration through the 4-1/2" liner and 7" production casing. Hilcorp Alaska proposes a high pressure breakdown in an attempt to establish connectivity to the reservoir. We are also evaluating re -perforating the well with strip guns, Please let me know if the AOGCC concurs with performing the high pressure breakdown as shown on the attached pump schedule. Regards • • Paul Chan Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC (907) 777 — 8333 (w) (907) 444 — 2881(c) C 0 Fullbore Pumping Program for Field Well Name MP F-73A -------------------------------------------------------- High Pressure Breakdown Job Scope Well Type - Date --j------------------------------------------ -------------------------------------- -----------------Inect---o---r--AFE 1820777 4/13/2018 IOR Engineer -------------- Paul Chan -------------- ------- Phone-------- 907:444 2881--------- --------- H2S Job Objective Establish connection to the reservoir (post -pert). Pump at maximum rate (without exceeding 3500 psi surface injection pressure) during the later stages if possible, especially if the surface injection pressure is low. Place 1000 -1500 psi on IA during breakdown. Fullbore Pumping Schedule Stage Fluid Type Pump Into Volume (bbls) Rate (bpm) Max Pressure 1 Load 2% KCI Tb 10 3500 21 Rate 1 1 2% KCI Tb 10 3500 3 Rate 2 2% KCI Tb 60 2-4 3500 4 Rate 3 2% KCI Tb 210 5+ 3500 5 Freeze Protect Methanol 60/40 Tb 17 3500 Detailed Pumping Procedure 1. Fluid pack well and pressure test tubing to 1500 psi to confirm ........... .. »..... . ................ ,.....,..,.....,....,..,..........................,...,...................,......... ....... ....... ....... -.......»........... _....................... ._.,......._... sllding sleeve is closed (SUPumping) ........ ....... ........ ....... ....... ... .......................... ..... -.__............. ........ ........ ............. ....... __................. _............ ....... ....... ........ _.... _.............. ...... _._......... ....... _......_ ..... ............... ... ....................... ... .... ....... __......... .................. __._............. ....... .... -....... __._._....._..»..._......_ 2. Perform high pressure breakdown. Monitor and record ».:::::::,:....,...».....:..:::.::..::.».,,.....-._.:.:.,::.... ...:»:...,.........::.:».:..:.»,:..,....:,..».»...:,:...»:.::.:,:,:,,,..::».,.:.::........:,.:.::,.....».:...n.»....,::,.....- _.___..... ..... .......... ..... N..»� »-:,......:.:._.......:::,:.» - .� ,.,m..-_...,..-.....-... pressures. ........... ..-...........-:..::.................:._,-.............. _.............. _.... _.... .......... ........ _..... ............. ......................................... ..... ..._ _.._..__........ __ _ _._._..__._....._.:.-.........___.._...,..._�,...-.. 3. Freeze protect well diesel or meth - no pref) (diesel _ m.,..,.. ,::x:: � � � �._..._,_....-..-.,............_....,.........,...,.... ,...........,:,..........:,.................. ... ........ .................. _...._...... ..,,,..»....... .._..a ........... ........ Additional Details N/A N/A N/A Recent Tbg Fluid Level (ft) Integrity Issues? No Recent IA Fluid Level (ft) Select Recent OA Fluid Level (ft) Input Depth THE STATE V 0 W a J453 WAI k GOVERNOR BILL WALKER Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission NED Re: Milne Point Unit, Sag River/Kuparuk River Oil Pool, MPU F-73A Permit to Drill Number: 200-198 Sundry Number: 318-047 Dear Mr. York: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov 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, /�& P'�4 Cathy . Foerster Commisssioner DATED this /Z day of February, 2018. • I FEB U 5 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑✓ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate J Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ *e-E Plug for Redrill El Perforate New Pool nter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ Stratigraphic ❑ Service ❑✓ 200-198 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-22744-01-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 423 ` a Will planned perforations require a spacing exception? Yes ❑ No Q MILNE PT UNIT F-73A 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0355018 MILNE POINT / SAG RIVER OIL � 0001t 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): 14,614' - 8,879' 11,614' 8,879' 3,416 10,520' N.A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Surface 5,873' 9-5/8" 5,904' 4,577' 5,750psi 3,090psi Production 11,049' 7" 11,080' 7,571' 7,240psi 5,410psi Liner 2,129' 4-1/2" 12,696' 8,789' 8,430psi 7,500psi Liner 2,201' 2-7/8" 14,614' 8,879' 10,570psi 11,170psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 3-1/2" 9.2 / L-80 / NSCT 10,561' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): S-3 7" x 3.5" & 7" ZXP Packer and N/A t 10,492 MD/ 7,047 TVD & 10,568 MD/ 7,114 TVD and N/A 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: 2/10/2018 OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAGIN ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. (/ Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: Pchan(@hilcorp.com ` Contact Phone: 777-8333 ' Authorized Signature: Date: J^pq-i COMMISSION USE ONLY Conditions of approval: Nfitify Commission 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 [j�' Subsequent Form Required: i ®'- y (g� FZBDMS L,- F❑ 1,3 cJ10110o APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 4/2017 Approved applicati ORdmjINALe date of appyval. Submit Form and Attachments in Duplicate Well Prognosis Well: MPU F-73A Date:1/26/2018 Well Name: MPU F-73A API Number: 50-029-22744-01 Current Status: SI Injector Pad: F-Pad Estimated Start Date: February 101h,2018 Rig: n/a Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 200-198 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) ANurilbr.JobT= If' Rra�r Current Bottom Hole Pressure: 4,302 psi @ 8,858' TVD (SBHPS 12/23/2017 / 9.35 ppg EMW) MPSP: S A611 1- m_ 3,41E psi (0.1 psi/ft gas gradient) Maximum Expected BHP: 2,700 psi @ 7,000' TVD (Estimated Kuparuk reservoir pressure) MPSP after perforating: 2,000 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-73 was drilled in March 1997, fracture stimulated and completed in June 1997 as a Kuparuk River producer. ESP installation history: June 1997 (initial), August 1997, and May 1998. The Kuparuk interval was plugged and abandoned with a 25 bbl 15.8 ppg cement plug in preparation for the sidetrack to the Sag River formation in December 2000. The F-73 well was re -drilled to the Sag River formation as F-73A by Doyon 141 in Decembe__r_2000: In April 2001, coiled tubing drilling drilled a 2200' horizontal pre -produced well into the Sag River formation. The well was completed with 3-1/2" tubing in April 2001. The well was converted to injection in July 2002 to support the MP F-33A Sag River well. MP F-33A was suspended in April 2014 due to an unsuccessful RWO to replace tubing. MP F-73A was shut in in October 2012. Notes Regarding Wellbore Condition .;c«,tr k.�''7 I Well operated under Administrative .. p _ 9ppr_Q_v_al AIO 10B.005 while injecting water. Passing MIT -IA to 3950 psi on June 3, 2012. Hilcorp Alaska respectfully requests AOGCC approval to produce this reverse flow jet pumped well up the annulus as per 20 AAC 25.200 (d) Obiective• Set composite bridge plug and dump cement to isolate the 2-7/8" liner in the Sag River formation. Perforate the Kuparuk interval and return the well to production as a reverse flow jet pumped oil well. Procedure: 1. Fluid pack wellbore. 2. Bullhead 10 bbls of diesel down the tubing. 3. RU SL and PT. 4. Drift 2-7/8" liner w/ 2.25" OD drift in preparation for setting composite bridge plug. CBP OD is 2.15". 5. RD SL 6. Notify AOGCC 24 hours in advance for the a -line plugging operation. Well Prognosis Well: MPU F-73A Ifilrurp Alaska, LL Date:1/26/2018 7. RU e-line and PT to 4000 psi. 8. MU and RIH with 2-7/8" composite bridge plug. 9. Set bridge plug at+12,670' MD (top perforation at 12,720' MD) a. Set plug within 50' of top perf as per 20 AAC 25.1%12 (c) (1) (E) b. Avoid setting plug in connection. G'A" 10. Pressure test bridge plug to 2500 psi for 30 minutes. 11. Dump bail 25' of cement on top of bridge plug. TIA A 3000 p S`' 12. RD e-line. 13. WOC. 14. RU e-line and PT to 2500 psi. 15. Perforate the following intervals with 2-1/2" 6 SPF 60' phasing GEODynamics Connex 11 gram XDP charges. Note: The first gun run will be perforated underbalanced. a. 10756'-10786' MD (30') b. 10731'-10751' MD (20') ItAS Ic. 10712'-10726' MD (14') d. 10634'-10668' MD (34') 16. RD a -line. 17. RU SL unit and PT 18. RIH and open Baker SMU sliding sleeve 19. Set jet pump. 20. RD SL unit. 21. Turn well over to Operations Attachments: Schematics • Iiilcorp Alaska, LLC KBE = 42.1Y Doyon 141 • Milne Point Unit Well: MPU F-73A SCHEMATIC Last Completed: 4/22/2001 PTD: 200-198 WELLHEAD Tree 3-1/8" - 5M 11" 5M Gen. 5 w/ 3-1/2" FMC Tbg Wellhead Hng. 3-1/2" NSCT thread on bottom. 3 CIW "H" BPV Profile OPEN HOLE / CEMENT DETAIL 20" 260sx of Arctic Set (Approx) in 24" Hole 9-5/8" 1,496sx PF 'E' , 411sx Class 'G' in a 12-1/4" Hole 7" 300 sx Class "G" in 8-1/2" Hole 4-1/2" 280 sx Class "G" in 6-1/8" Hole 2-7/8" 56 sx Class "G" in 3-3/4" Hole CASING DETAIL Type Wt/ Grade/ Conn ID Top Btm Conductor 91.1 / H-40 N/A Surface 112' Surface 40 / L-80 / BTC 8.835 Surface 5,904' Production 26 / L-80 / BTC-M 6.276 Surface 11,080' " Liner 12.6 / L-80 / BTC 3.958 10,568' 12,696' Liner 6.16 / L-80 / STL 2.441 12,413' 14,614' TUBING DETAIL Tubing 9.2 / L-80 / NSCT 2.992 1 Surface 1 10,561' WELL INCLINATION DETAIL KOP @ 400' MD Hole Angle 64 to 66 Deg. f/ 4,445' to 8,627' and +72.95 deg from 12,758' to 14,614' MD Hole Angle thru perfs = 68 to 82 deg from 12,720' to 13,500' JEWELRY DETAIL Vo Depth Item 1 2,482' 3.5" x 1" KBUG GLM w/ RP Shear 2 10,454' Phoenix Discharge Pressure Sub 3 10,461' Baker Model SMU Sliding Sleeve 4 10,471' Phoenix Multisensor 5 10,492' Baker Model S-3 Packer 6 10,521' 3-1/2" XN Nipple- ID=2.75" 7 10,560' 3-1/2" NSCT 9 CR WLEG - Bottom @ 10,561' 8 10,568' Baker ZXP Packer 9 10,583' RS Nipple- ID= 4.25" 10 10,585' Baker Flexlock Hanger 11 12,414' Baker Deployment Sleeve 12 12,421' 2-7/8" STL Box x 2-7/8" FL4S Pin XO - ID=2.34" 13 12,423' 2-7/8" FL4S Box x 2-7/8" STL Pin XO - ID=2.34" 14 13,825' Baker Float Collar 15 13,853' 2-7/8" Tubing, Perforated (4) 3/8" holes pert/ft- Btm @ 14,613' 16 14,613' 1 BKR Guide Shoe - Btm @ 14,614' PERFORATION DETAIL )) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size SPF 13,190' 8,799' 8,827' 470' 4/18/2001 Open 2" 4 13.500' 8,828' 8,869' 280' 4/18/2001 Open 1 2" 4 GENERAL WELL INFO API: 50-029-22744-01-00 Drilled March 1997 Deepen to the Sag River formation - December 2000 CTU Horizontal Sidetrack Nordic#1 - 4/21/2001 Jet Pump Completion -April 2001 NOTE: Well requires the installation of a SSSV during the next RWO TD=14,615' (MD) / TD = 8,87Y(TVD) PBTD=14,614' (MD) / PBTD = 8,879"(TVD) Revised By: TDF 2/1/2018 Milne Point Unit Well: MPU F-73A PROPOSED Last Completed: 4/22/2001 I ileorp Alaska, LLC PTD: 200-198 KBE =42.10" Doyon 141 WELLHEAD Tree 3-1/8" - 5M 11" 5M Gen. 5 w/ 3-1/2" FMC Tbg Wellhead Hng. 3-1/2" NSCT thread on bottom. 3 CIW "H" BPV Profile N HOLE / CEMENT DETAIL >x of Arctic Set (Approx) in 24" Hole 6sx PF 'E' , 411sx Class 'G' in a 12-1/4" Hole sx Class "G" in 8-1/2" Hole sx Class "G" in 6-1/8" Hole K Class "G" in 3-3/4" Hole NOTE: Well requires the installation of a SSSV during the next RWO CASING DETAIL WELL INCLINATION DETAIL KOP @ 400' MD Hole Angle 64 to 66 Deg. f/ 4,445' to 8,627' and +72.95 deg from 12,758' to 14,614' MD Hole Angle thru perfs = 68 to 82 deg from 12720' to 13,500' Type Wt/ Grade/ Conn ID Top Btm Conductor 91.1 / H-40 N/A Surface 112' Surface 40 / L-80 / BTC 8.835 Surface 5,904' Production 26 / L-80 / BTC-M 6.276 Surface 11,080' Liner 12.6 / L-80 / BTC 3.958 10,568' 12,696' Liner 6.16 / L-80 / STL 2.441 12,413' 14,614' TUBING DETAIL Tubing 9.2 / L-80 / NSCT 2.992 1 Surface 10,561' JEWELRY DETAIL No Depth Item 1 2,482' 3.5" x 1" KBUG GLM w/ RP Shear 2 10,454' Phoenix Discharge Pressure Sub 3 10,461' Baker Model SMU Sliding Sleeve 4 10,471' Phoenix Multisensor 5 10,492' Baker Model S-3 Packer 6 10,521' 3-1/2" XN Nipple- ID=2.75" 7 10,56(Y _ 3-1/2" NSCT 9 CR W LEG - Bottom @ 10,561' 8 10,568' Baker ZXP Packer 9 10,583' RS Nipple - ID= 4.25" 10 10,585' Baker Flexlock Hanger 11 12,414' Baker Deployment Sleeve 12 12,421' 2-7/8" STL Box x 2-7/8" FL4S Pin XO - ID=2.34" 13 12,423' 2-7/8" FL4S Box x 2-7/8" STL Pin XO - I13=2.34" 14 13,825' Baker Float Collar 15 13,853' 2-7/8" Tubing, Perforated (4) 3/8" holes pert/ft- Btm @ 14,613' 16 14,613' BKR Guide Shoe - Btm @ 14,614' PERFORATION DETAIL op AD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size SPF 720' 13,190' 8,799' 8,827' 470' 4/18/2001 Closed 2" 4 220' 13.500' 8,828' 8,869' 280' 4/18/2001 Closed 2" 4 ,634' ±10,668' 7,173' 7,203' 34' Proposed 2-1/2" 6 ,712' ±10,726' 7,242' 7,255' 14' Proposed 2-1/2" 6 ,731' ±10,751' 7,259' 7,277' 20' Proposed 2-1/2" 6 ,756' ±10,786' 7,282' 7,308' 30' Proposed 2-1/2" 6 Ref Log: SLB SCMT Log Dated: March 1, 2001 GENERAL WELL INFO API: 50-029-22744-01-00 Drilled March 1997 Deepen to the Sag River formation - December 2000 CTU Horizontal Sidetrack Nordic## - 4/21/2001 Jet Pump Completion - April 2001 TD=14,615' (MD) / TD = 8,879 (TVD) PBTD=14,614' (MD) / PBTD = 8,879"(TVD) Revised By: PC 1/26/2018 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Wednesday, May 29, 2013 7:19 PM To: Wallace, Chris D (DOA); Regg, James B (DOA); AK, OPS MPU Fac O&M TL; AK, OPS MPU Field Ops TL; AK, OPS MPU OSM; AK, OPS MPU OSS; AK, OPS MPU Well Ops Coord; AK, D&C MPU WSL; Cismoski, Doug A, Daniel, Ryan; Stone, Christopher Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; Weiss, Troy D Subject: NOT OPERABLE: Injector MPF-73A Due for AOGCC Compliance MITIA Al I, SCANNED OCT 2 3 2014 Injector MPF-73A (PTD #2001980) operates under Administrative Approval 1013.005, and is due for its annual AOGCC compliance MIT -IA on 06/05/2013. The well is currently shut in and will not be placed on injection prior to the AOGCC MIT -IA anniversary date. There is no plan to place the well on injection in the near future. The well is reclassified as Not Operable and will be added to the Quarterly AOGCC Not Operable Injector Report. Please call with any questions. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator Global VVells u Organization Office: 907.659.5102 WIC Email: AKDCWeIIlntegrityCoordinator@bp.com MEMORANDUM TO: Jim Regg P.I. Supervisor�� 7r2j/z FROM: Chuck Scheve Petroleum Inspector SCANNED 0 C T 2 3 2014 NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 02, 2012 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F-73A MILNE PT UNIT SR F-73A Src: Inspector Reviewed By: P.I. Supry Comm Well Name MILNE PT UNIT SR F-73A API Well Number 50-029-22744-01-00 Permit Number: 200-198-0 Insp Num: mitCS120604061844 Rel Insp Num: Inspector Name: Chuck Scheve Inspection Date: 6/3/2012 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well F-73A Type Inj I w' TVD 7047 IA 890 3950 - 3894 3880 - TD 2001980 IType Test SPT' Test psi 3600 OA 22 313 313 307 - nterval REQvAR - P/F P Tubing 3063 3066 3066 3066 Notes: A�,To log cv)S Monday, July 02, 2012 Page 1 of 1 r-I u MEMORANDUM TO: Jim Regg / P.I. Supervisor ��z iol ��lv FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 06, 2012 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F-73A MILNE PT UNIT SR F-73A Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT SR F-73A API Well Number 50-029-22744-01-00 Inspector Name: Chuck Scheve Permit Number: 200-198-0 Inspection Date: 6/3/2012 Insp Num: mitCS120604061844 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min eU F-73A Type Inj � W `TVD 7047 IA 890 3950 3894 3880 " TD 2001980 Type Test SPT Test psi 176] OA 22 313 313 307 Interval IREQvAR P/F P ' Tubing 3063 3066 3066 3066 _ Notes: ,;, J � UIZ Wednesday, June 06, 2012 Page 1 of 1 0 0 by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 December 30, 2011 SLANNEO FF-B 9, 1 ZU1Z rl Mr. Tom Maunder Alaska Oil and Gas Conservation Commission /� }7 r 333 West 7th Avenue I ,,�f Y 1 F 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 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) MPF-Pad 101=011 Well Name PTD # API # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date It bbls It gal MPF-01 1 1950450 500292255200M 10.2 N/A 10.2 WA 122.4 8/7/2011 MPF-02 1960700 50029226730000 4 WA 4 WA 35.7 8/82011 MPF-05 1970740 50029227620000 1.3 N/A 1.3 WA 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 WA 1.2 WA 15.3 822011 MPF-09 1971040 50029227730000 5.0 WA 5.0 WA 54.4 8/9/2011 MPF-10 1960940 50029226790000 1.7 WA 1.7 N/A 20.4 8/2/2011 MPF-13 1950270 50029225490000 0.2 WA 0.2 N/A 8.5 10/6/2011 MPF-14 1952120 50029226360000 0.1 WA 0.1 N/A 8.5 lasw11 MPF-17 1971960 50029228230000 4.1 N/A 4.1 WA 37.4 8/6/2011 MPF-18 1961000 50029226810000 8.3 N/A 8.3 WA 91.8 8/2/2011 MPF-21 1961350 50029226940000 1.8 WA 1.8 WA 15.3 8/OM MPF-22 1952010 50029226320000 4 WA 4 WA 13.6 8/1/2011 MPF-25 1950160 50029225460000 0.3 WA 0.3 WA 6.8 10/29/2011 MPF-26 1970840 50029227670000 1.8 WA 1.8 WA 11.9 8/12011 MPF-29 1961170 50029226880000 6.7 WA 6.7 N/A 56.1 8/9/2011 MPF-30 1951840 50029226230000 0.8 WA 0.8 N/A 6.8 8/12011 MPF-33 2010620 50029226890000 23 Need b MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/12oll MPF-37 1950250 50029225480000 0.2 WA 0.2 N/A 8.5 10/6/2071 MPF 38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/52011 MPF-41 1970950 50029227700000 0.8 WA 0.8 WA 8.5 8192011 MPF42 7970200 50029227410000 1.8 WA 1.8 WA 73.6 8/12011 MPF-45 1950580 50029225560000 8 WA 8 WA 78.2 8/112011 MPF-46 1940270 500292245000M Sealed Conductor WA WA WA N/A WA MPF-49 1970030 50029227320000 2.3 WA 2.3 WA 18.7 8/11/2011 MPF-50 1970580 50029227560000 1.7 WA 1.7 WA 6.8 7/31/2011 MPF-53 1951080 50029225780000 2.8 WA 2.8 N/A 11.9 9/19/2011 MPF-54 1961920 50029227260000 1.7 WA 1.7 WA 10.2 8112011 MPF-57A 2031670 50029227470100 1.3 WA 1.3 WA 13.6 8/112011 MPF-58 1961560 50029227060000 1.7 WA 1.7 N/A 13.6 7/312011 MPF-01 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NA/ 2.0 WA 13.6 9/12011 MPF-65 1970490 50029227520000 1.5 WA 1.5 N/A 13.6 8/11/2011 MPF-66A 1961620 50029226970100 0.8 WA 0.8 N/A 8.5 7/312011 MPF-69 1951250 50029225860000 0.8 WA 0.8 WA 8.5 8/4/2011 MPF-70 1951530 50029226030000 1.7 WA 1.7 N/A 15.3 7/31/2011 MPF-73A 2001980 50029227440100 1.5 WA 1.5 WA 13.6 8/112011 MPF-74 1961080 50029226820000 1.7 WA 1.7 N/A 13.6 7/312011 MPF-77 1951360 50029225940000 0.2 WA 0.2 WA 6.8 10/5/2011 MPF-78 1951440 50029225990000 0.7 N/A 0.7 WA 5.1 7/312011 MPF-79 19718W 50029228130000 0.6 WA 0.6 WA 6.8 8/32ol1 MPF-80 1982170 50029229280000 0.5 WA 0.5 WA 3.4 8/3/2011 MPF-81 2000660 5W29229590000 0.9 WA 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 WA 1.7 WA 15.3 8/3/2011 MPF-83 2000930 50029229630000 1.2 NIA 12 WA 13.6 8/32011 MPF-84B 2001760 50029229310200 1.2 WA 12 WA 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 WA 0.1 WA 7.7 9/12011 MPF-86 2010870 50029230180000 0.8 N/A 0.8 NIA 6.8 8/122011 MPF-87A 2032130 50029231840100 1.3 N/A 1.3 WA 11.9 8/132011 MPF-88 2031930 500292318500M 1.3 WA 1.3 N/A 15.3 8/3/2011 MPF-89 2050900 50029232680000 1.2 WA 1.2 N/A 10.2 8/32011 MPF-90 20121 00 50029230510000 1.8 WA 1.8 N/A 18.7 8/3/2011 MPF-91 2051100 50029232710000 1.7 WA 1.7 WA 11.9 8/132011 MPF-92 1981930 50029229240000 0.8 WA 0.8 WA 5.1 8/132011 MPF-93 205W70 50029232860000 0.3 WA 0.3 WA 7.7 9/12011 MPF-94 2011700 MM9230400000 1.8 WA 1.8 WA 13.6 8/132011 MPF-95 1981790 50029229180000 1 0.5 WA 0.5 WA 3.4 8/132011 MPF-96 2081860 50029234060000 1 0.1 1 WA 0.1 WA 6.0 9/12011 MPF-99 2061560 50029233320000 1 1.3 1 WA 1.3 WA 11.9 8/112011 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 01, 2011 TO: Jim Regg 3 6(Z� i/ SUBJECT: Mechanical Integrity Tests P.I. Supervisor BP EXPLORATION (ALASKA) INC F-73A FROM: Bob Noble MILNE PT UNIT SR F-73A Petroleum Inspector Sre: Inspector NON -CONFIDENTIAL Reviewed By: P.I. Suprv,TaL Comm Well Name: MILNE PT UNIT SR F-73A API Well Number: 50-029-22744-01-00 Inspector Name: Bob Noble Insp Num: mitRCN110601052758 Permit Number: 200-198-0 Inspection Date: 513112011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well T F-73A �ype Irij. �—W TVD —�7047 IA 1240 3900 3860 3850 2001980 SFT --t P.T.D, TypeTest�_ Test psi 3900 OA 20 320 320 320 Interval REQvAR z P/F P Tubing 2890 1 2893 2893 2893 Notes: 10V> i CC"S iia- tom c1AA1t-,,C( 4-r- U,6-K Ct A,4'�C (Pkk-d � �1r�� ,� P �essoti-)C-- Wednesday, June 01, 2011 Page 1 of 1 0 10 MEMORANDUM TO: Jim Regg P.I. Supervisor r FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 07, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F-73A MILNE PT UNIT SR F-73A Sre: Inspector NON -CONFIDENTIAL Reviewed By: P.I. Supry Comm Well Name: MILNE PT UNIT SR F-73A Insp Num: mitJJ100818170023 Rel Insp Num: API Well Number: 50-029-22744-01-00 Permit Number: 200-198-0 Inspector Name: Jeff Jones Inspection Date: 8/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well F-73A '�pe Inji. W TVD 7047 IA 850 3900 3830 3820 ' P.T.D1 2001980 iTypeTest sPT Test psi 1761 QA 0 330 1 330 320 Interval REQvAR P/F P ' Tubing 3035 3035 3035 3035 Notes: MIT required by AIO 10B.005. 3.5 BBLS diesel pumped. One well inspected; no exceptions noted. Tuesday, September 07, 2010 Page 1 of 1 0 MEMORANDUM TO: Jim Regg P.I. Supervisor i �('% J 1 Z FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 24, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F-73A MILNE PT UNIT SR F-73A Src: Inspector NON -CONFIDENTIAL Reviewed By: P.I. Suprv2 Comm Well Name: MILNE PT UNIT SR F-73A API Well Number: 50-029-22744-01-00 Inspector Name: John Crisp Insp Num: mitJCr090820160507 Permit Number: 200-198-0 Inspection Date: 8/20/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well F-73A Type Inj. W TVD 7047 ✓ IA 580 2020 1980 1980 P.T.D 2001980 TypeTest SPT Test psi 1761.75 OA 10 140 140 140 Interval REQVAR P/F P Tubing 3000 3000 3000 3000 Notes: 1.8 bbls diesel pumped for test. y{� 10B, co J 1 t{rhef� rg �.Z �,. PS �k-.O-A4-)Gi�tveu Monday, August 24, 2009 Page I of 1 MPF-73A (PTD #2001980) Slow increase in IA repressurization Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, November 24, 2008 12:19 PM r ,tl ItIZ4 (zo3G To: 'Dube, Anna T' Subject: RE: MPF-73A (PTD #2001980) Slow increase in IA repressurization I concur with not performing a MITIA at this time; continued monitoring of TIO pressures and reporting in monthly injector integrity report is sufficient. If repressure rate increases, please notify the Commission. Jim Regg AOGCC SCAWhEb, tV U � C � � 5 ZQrt�f 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Dube, Anna T [mailto:Anna.Dube@BP.com] Sent: Sunday, November 23, 2008 3:37 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Wells Ops Coord2 Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany; Wellman, Taylor T; Holt, Ryan P (ASRC); NSU, ADW Well Operations Supervisor; Engel, Harry R Subject: MPF-73A (PTD #2001980) Slow increase in IA repressurization Hi Jim and Tom, Milne Point well MPF-73A (PTD #2001980) is approved for continued water infection operations with slow IA repressurization under AOGCC Administrative Approval AIO 1013.005. Since the AOGCC witnessed MITIA passed on 8/16/08, the well has exhibited a slow increase in IA pressure that is different from previous trends. The increase is pressure is slow enough that it is not believed that there is a change in the mechanical integrity of the tubing. Milne Point Operations will bleed the IA pressure and monitor the pressure post -bleed. At this point an additional MITIA is not scheduled. The well will remain on the Monthly Injection Report and the IA pressure will be maintained under 2000 psi. Please let us know if you feel further action is needed at this time. A TIO plot and wellbore schematic have been included for reference. «MPF-73 TIO Plot.doc>> «MPF-73A.pdf>> Thank you, Anna (Dube, P.E. Pager:111'ell Integrity Coordinator GPB Wells Group .l. • ' it 11 /24/2008 MPF-73A PTD 200-198 TIO Pressures — 11/23/2008 000 r---------------------------------------- 000 • 2 nOn 1,000 06/07/J8 06/21/08 07/05/08 07/19/08 08/02/08 08/16/08 08/30/03 09/13108 09�27/08 10/11/08 10/25/08 11/08/08 Tree: FMC 3-1/8" x 5M M P U F-73a Odg. KB Be,. = 41.4 ' (N 22E) Wellhead: 11" x 7 1/16" 5M Gen 5a Orig. GL Elev. = 11.5' w/ 2 7/8" FMC tbg hng., 3" LHacme KB To Tbg. Spool = 28.50' (N 22E) lift threads x 2 7/8" 8rd on bottom, 2.5" CIW 'H' BPV profile. 20" 91.1 ppf, H-40 112' KOP @ 400' Max. hole angle = 64 to 66 deg. f/ 4,445' to 8,627' Hole angle thru' perfs = 26.45 f9 5/8", 40 ppf, L-80 Btrc. S g04' 3.5" 9.3 #/ft , L-80 , NSCT. Bbls/ft = .0087 ID = 2.992" 7" 26 ppf, L-80, BTC-Mod production csg. ( drift ID = 6,151 ", cap. = 0.0383 bpf ) Two 7" x 21' marker joints f/ 10,547'-10,588' 7" Baker ZXP packer 10,568' 7" Baker flexlock hanger 10,585' 7" float collar (PBTD) 10,997' 7" Float shoe 11,080' 45' 12.6#, L-80, BTC casing 4.5" Whipstock @ 12,707' 4.5" Halliburton latch collar 12671' 4.5" Hallibunon float collar 12714' 4.5" Halliburton float shoe 12758' DATE REV. BY COMMENTS 08 / 16 / 97 MD O # 2 ESP Completion 4ES 5 0 98 M. Linder P t 12/30/00 M. Linder Recompleted into SAG River 04/21/01 MDO CTU Horizontal sidetrack Nordic #1 3.5" X 1" Cameo KBUG GLM 2481' I Tail pipe inside hanger 7' above 4.5" X-Over *Measure depths differ between rigs* Phoenix Discharge PSI sub ( 2.95" id) 11 0,454 3.5" Baker Sliding sleeve SMU 10,461' Phoenix MulGsensor (2.95" id) 10,471' Baker S-3 pkr. 7" x 3.5" 10,492' 3.5" HES XN-Nipple ( 2.813" Pkg) 10,520' ( Min. id 2.75" ) WLEG 10,561' Top of 2-718" liner @ 12,413 Baker landing collar 13,811' float collars 13,814' & 13,825, Shoe 14,614' pbtd — -- 14,615' 2 7/8" st-I pre -drill liner (13,81 V-14,614') Size SPF Interval (TVD) 2" 2" 4 4 12,720'-13,190' 13,220'43,50 ' MILNE POINT UNIT WELL F-73a API NO: 50-029-22744-00 BP EXPLORATION (AN NOT OPERABLE: 11-35 (PTD #1940650) Injection unavailable for Compliance Testing Page 1 of 1 0 0 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer[NSUADWWeI[lntegrityEngineer@BP.com] itJZAIzZ46 Sent: Wednesday, November 19, 2008 9:01 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS2 DS Ops Lead; GPB, FS2 DS Operators; GPB, FS2/COTU OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Quy, Tiffany; Chivvis, Robert Subject: NOT OPERABLE: 11-35 (PTD #1940650) Injection unavailable for Compliance Testing Hi all, ./ Well 11-35 (PTD #1940650) is a produced water injector currently under AOGCC Administrative Approval for slow TxIA communication. Due to repairs to the water injection lines scheduled for 1 Q200A, injection is unavailable to complete the MITIA compliance testing with the well on injection. The well has been reclassified as Not Operable until the injection lines are available. The well has been added to the quarterly report of shut-in injectors sent to the AOGCC. The plan forward for the well is as follows: 1. Operations: Repair injection lines 2. Slickline: Pull TTP to unsecure well 3. Well Integrity Coordinator: Reclassify well as Under Eval to place well on injection for compliance testing 4. Operations: Place well on injection (estimated to occur in 2Q2009) 5. Fullbore: AOGCC MITIA for AA compliance (estimated to occur in 2Q2009) Please call with any questions. Thank you, Anna Du6e, �P. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 11 /24/2008 MEMORANDUM . State of Alaska Alaska Oil and Gas Conservation Commis TO: Jim Regg 3�ZA)`b P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector DATE: Monday, August 18, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F-73A MILNE PT UNIT SR F-73A Src: Inspector NON -CONFIDENTIAL Reviewed By: P.I. Supry f a_ Comm Well Name: MILNE PT UNIT SR F-73A API Well Number: 50-029-22744-01-00 Inspector Name: Chuck Scheve Insp Num• mitCS080817163605 Permit Number: 200-198-0 Inspection Date: 8/16/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well F-73A Type Inj. I w TVD 7047 IA 260 3940'- 3860 3850 P.T. 2001990 TypeTest ISPT Test psi 1761.75 OA 0 360 360 360 Interval OTHER P/F P Tubing 3180 3180 3180 3180 Notes: Test performed for AA complance. Pretest pressures observed and found stable., ;�►NNED S E P 1 0 2008 Monday, August 18, 2008 Page 1 of 1 MEMORANDUM State of Alaska 0 Alaska Oil and Gas Conservation Commission To: Jim Regg q;f -:5ciO7 P.I. Supervisor I FROM: John Crisp Petroleum Inspector DATE: Monday, August 27, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F-73A MILNE PT UNIT SR F-73A Src: Inspector NON -CONFIDENTIAL Reviewed By: P.I. Suprv� 9s- Comm Well Name: MILNE PT UNIT SR F-73A API Well Number: 50-029-22744-01-00 Inspector Name: John Crisp Insp Num: mitJCr070827071836 Permit Number: 200-198-0 Inspection Date: 8/22/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well F-73A Type Inj. I W TVD 7047 IA 820 3500 3440 3430 P.T. i 200198u ITYPeTest Test psi n6L7s pA o 300 300 300 Interval REQVAR PAF P Tubing ztso 2150 2150 ztso Notes: 3.1 bbl's pumped for test. �JeSd- -)-n klq ke- � .reS&Ajte Ajo 1OB-00' S1�A1 NED SEP 1 0 2007 Monday, August 27, 2007 Page 1 of 1 MEMORANDUM 0 TO: Jim Regg G P.I. Supervisor' �� FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Friday, August 17, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F-73A MILNE PT UNIT SR F-73A Src: Inspector NON -CONFIDENTIAL Reviewed By: P.I. Suprv� Comm Well Name: MILNE PT UNIT SR F-73A API Well Number: 50-029-22744-01-00 Inspector Name: Bob Noble Insp Num• mitRCN070804173713 Permit Number: 200-198-0 Inspection Date: 8/4/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well F-73A ''Type Inj. W TVD 7047 IA 340 2070 1 2050 2045 j p Z zool9so ITypeTest sPT Test psi zo7o pA I7s aoo aoo 400 Interval REQVAR P/F P Tubing 2600 2600 2600 2600 Notes: I year per AIO 1013.005 A30 IC)S.Ot75 re"u5 bay d 6>q Zr:w - 44t -T-A 1-ife,L r LQ�e,— 4,c, -1:3>.6x& AUG 2320? Friday, August 17, 2007 Page I of I MEMORANDUM . State of Alaska • Alaska Oil and Gas Conservation Commission TO: DATE: Thursday, August 31, 2006 Jim Regg P.I. Supervisor i1�/�/ 1 �i (' SUBJECT: Mechanical Integrity Tests ,. BP EXPLORATION (ALASKA) INC F-73A FROM: Chuck Scheve MILNE PT UNIT SR F-73A Petroleum Inspector Src: Inspector NON -CONFIDENTIAL Reviewed By: P.I. Suprv" Comm Well Name: MILNE PT UNIT SR F-73A Insp Num: mitCS060825075411 Rel Insp Num API Well Number Permit Number: 50-029-22744-01-00 200-198-0 Inspector Name: Chuck Scheve Inspection Date: 8/24/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj. W TVD 7047 IA 150 3000 2950 2950 ��E00198F-73A 0 TypeTest I SPT Test psi 1761.75 OA 200 580 580 580 Interval REQVAR P/F P Tubing 1350 1350 1350 i 1350 Notes Annual MITIA required by AA. CANNED SEP 0 8 2006 Thursday, August 31, 2006 Page I of I ALA IWA ®IL AND GAS CONSERVATION COMMISSION • ! *FRANK H. MURKOWSKI, GOVERNOR 333 W. 7"AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 10B.005 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: Request for Administrative Approval Milne Point Unit F-73A (PTD 200-198) Sag River Oil Pool Dear Mr. Rossberg: JAN 0 4 2008 By letter application received May 18, 2006 BP Exploration (Alaska) Inc. ('`BPXA") requested administrative approval to resume water injection into MPF-73. MPF-73 (197- 030) was plugged and abandoned effective November 30, 2000 and MPF-73A was drilled. Based on an evaluation of the submitted information and review of the well file, the Alaska Oil and Gas Conservation Commission grants BPXA's request for administrative approval to resume water injection in the subject well. AOGCC finds that BPXA has performed diagnostic well work on Milne Point Unit F- 73A and based upon reported results of that work, the well exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to resume water injection in Milne Point Unit F-73A is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. BPXA shall record wellhead pressures and injection rates daily as well as any pressure bleed events; ADMINISTRATIVE APPROVAL AIO 10B.005 June 5, 2006 Pa41 ge 2 of 2 0 3. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates with any pressure bleed events annotated in the record; 4. BPXA shall perform a MIT - IA annually to 1.2 times the maximum anticipated injection pressure; 5. BPXA shall limit the well's IA operating pressure to 2000 psi; 6. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; and 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. } DONE at„AWchouff2e, Alaska and dated June 5, 2006. J ON 03 Cathy . Foerster Commissioner STATE OF ALASKA ALAS. OIL AND GAS CONSERVATION COMM,.,1ION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JAN 2 4 Z006 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Alaska Oil611BfDons. Colmmissien Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time ExtenA rage O erat. Shutdown ❑ Perforate Change Approved Program Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development r7l Exploratory Stratigraphic Service"+'; 200-1980 3. Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-22744-01-00 7. KB Elevation (ft): 9. Well Name and Number: 42.1 KB MPF-73A 8. Property Designation: 10. Field/Pool(s): ADL-355018 Milne Point Field/ Sag River Oil Pool 11. Present Well Condition Summary: Total Depth measured 14614 feet Plugs (measured) 10520 XXN true vertical 8879.45 feet Junk (measured) None Effective Depth measured 14614 feet true vertical 8879.45 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.1# H-40 32 - 112 32 - 112 1490 470 Surface 5873 9-5/8" 40# L-80 31 - 5904 31 - 4577.08 5750 3090 Production 11049 7" 26# L-80 31 - 11080 31 - 7571.4 7240 5410 Liner 2129 4-1/2" 12.6# L-80 10568 - 12697 7114.02 - 8789.05 8430 7500 Liner 2201 2-7/8" 6.16# L-80 12413 - 14614 8629.08 - 8879.45 13450 13890 Perforation depth: Measured depth: 12720 - 13190 13220 - 13500 True Vertical depth: 8798.95 - 8826.1 8827.86 - 8868.19 Tubing: (size, grade, and measured depth) 3-1/2" 9.3# L-80 30 - 10561 Packers and SSSV (type and measured depth) 3-1/2" Baker S-3 Packer 10492 G NNEV ,YIN 25 2006 12. Stimulation or cement squeeze summary: Intervals treated (measured): r) .S8FL JAN 2 5 2006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory r Development Service W Daily Report of Well Operations X 16. Well Status after proposed work: Oil r Gas r WAG 17 GINJ r WINJ r- WDSPL r 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Sharmaine Vestal Title Data Mgmt Engr Phone 564-4424 Date 1/23/2006 Form 10-404 Revised 04/2004 i Submit Original Only MPF-73A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 12/26/2005 *** WELL INJECTING ON ARRIVAL *** SET XXN PLUG @ 10520' MD. SET WITH 1600 PSI BELOW. GOOD PRESSURE TEST. *** WELL LEFT SI *** 12/29/2005 T/1/0=300/260/0. MIT - T to 3000 psi FAILED. MIT - IA to 3000 psi PASSED. CMIT - T x IA to 3000 psi FAILED. Pressured TBG to 3000 psi three times with 2 bbls of diesel. TBG lost 550 psi in the 1st 15 min of the 1st test and 380 psi in the 1st 15 min of the 2nd test. TBG lost 275 psi in the 1st 15 min and 240 psi in the 2nd 15 min on the 3rd test. MIT - IA to 3000 psi PASSED. Pressured IA to 3000 psi with 16.6 bbls. IA lost 80 psi in the 1st 15 min and 30 psi in the 2nd 15 min for a total loss of 110 psi. CMIT- T x IA FAILED. Pressured TBG and IA to 3000 psi. IA lost 0 psi in 30 min. TBG lost 360 psi in the 1 st 15 min and 250 psi in the 2nd 15 min. Bled pressures back. Final WHP's = 500/750/100 FLUIDS PUMPED BBLS .5 Diesel 24 Meth 24.5 TOTAL MPF-7-APTD #2001980) IA repressurization KPF —73A • l ZsI`�`tlQ� Subject: MPF-73 (P'I'D 4--`2001980) IA repressurization From: "NSU. ADW Well Integrity Engineer"<NSUADWWell Inte�,rityEno incer(i;BP.com Date: I�ri, 23 Dec 2005 18:51:04 -0900 To: "A(:)GC(. Winton Aubert (Ei-inail)" <:wintori....aubert(i. adniin.state.ak.us>, "AOGCC Jim Regg (E-mail)" regg(r;.admin.state. ak.us>, "MI"U, Well Operations Supervisor" < wclloperationssupervisor(:BP.co►n "MPU, Wells Ops Coord" <MPLJWellsOpsCoord(, BP.coiii>, "Rossbcrg, R Steven" <Stcven.Rossberg(r,BF'.com'>. "NSU, ADW Well Operations Supervisor" <:NSl1ADWWeIIOperationsSupervisor(a;:BP.com>, "NSU, ADW W'1 Tech" <NSUAM,V WlTech@l3l'.corn>, "NSU, ADW Well Integrity Engineer" <NSUADWWell IntegrityE:ngincer(@;BP.com:> Jim, Winton, Recent bleed events indicate TAA communication has developed in WAG injection well MPF-73A (PTD #2001980). Bleed events confirm consistent IA repressurization, with gas being bled out of the inner ✓ .... annulus. TIO pressures were 3600/1550/150 on 12/22/05. The well will be added to the monthly injection report. The plan forward is as follows: 1. MP: Swap well to water injection - DONE 2. SL: Set TTP 3. FMC: Evaluate wellhead 4. FB: MITIA, LLR if fails. MIT-T, LLR if fails. A wellbore schematic is included for reference. «MPF-73A.pdf>> Rob Mielke Well Integrity Engineer, BP Exploration, (Alaska) Inc. Office: 1-907-659-5102 Pager: 1-907-659-5100 #1154 robert.mielke@bp.com Content -Description: MPF-73A.pdf !MPF-73A.pdf Content -Type: application/octet-stream Content -Encoding: base64 of 1 12/27/2005 9:08 AM IEM Wellhead3-1/87 1 16" 5M Gen 5a M P U F-73a Orig. KB Elev. = 41.4 ' (N 22E) vv/ 2 7/8" FMC tbg hng., 3" LHacme Orig. GL Elev. = 11.5' lift threads x 2 7/8" Srd on bottom, KB To Tbg. Spool = 28.50' (N 22E) 2.5" CIW'H' BPV profile. 20" 91.1 ppf, H-40 112' KOP @ 400' Max. hole angle = 64 to 66 deg. f/ 4,445' to 8,627' Hole angle thru' perfs = 26.45 9 5/8", 40 ppf, L-80 Btrc. 5,904' 3.5" 9.3 #/ft , L-80 , NSCT. Bbls/ft = .0087 ID = 2.992" 17" 26 ppf, L-80, BTC-Mod production csg. ( drift ID = 6.151", cap. = 0.0383 bpf ) Two 7" x 21' marker joints f/ 10,547' - 10,588' 7" Baker ZXP packer 10,568' 7" Baker flexlock hanger 10,585' 7" float collar (PBTD) 10,997' 7" float shoe 11,080, 4.5" 12.6#, L-80, BTC casing 4.5" Whipstock @ 12,707' k " Halliburton latch collar 12671' " Halliburton float collar 12714' ,1 " Halliburton float shoe 12758' REV. BY COMMENTS Moo # 2 ESP Completion 4ES M. Under p h n M. Linder Recompleted into SAG River 04/21/01 1 MDO I CTU Horizontal sidetrack Nordic #1 3.5" X 1" Camco KBUG GLM 2481' I Tail pipe inside hanger 7' above 4.5" X-Over *Measure depths differ between rigs* Phoenix Discharge PSI sub (2.95" id) 10,454' 3.5" Baker Sliding sleeve SMU 10,461' Phoenix Multisensor ( 2.95" id) 10,471' Baker S-3 pkr. 7" x 3.5" 10,492' 3.5" HES XN-Nipple ( 2.813" Pkg) 10,520' ( Min. id 2.75" ) WLEG 11 0.561' I Tap of 2-7/8" liner @ 12,413 Baker landing collar 13,81 V float collars 13,814' & 13,825' Shoe 14,614' \ = btd 14,6 14,615' 2 7/8" st-I pre -drill liner (13,811'-14,614') Size SPF Interval (TVD) 2" 2" 4 4 12,720'-13,190' 13,220'-13,50C' MILNE POINT UNIT WELL F-73a API NO: 50-029-22744-00 BP EXPLORATION (AK) Milne Point MIT's e S 1b <<MIT MPU E-26, E-29 MITIA 9-20-05.xls>> <<MIT MPU F-73 MITIA 9-20-05.xls>> <<MIT MPU K-22 MITIA 9-20-05.xls>> Bob, The three wells E-26 / E-29 / F-73 were four year MIT's and K-22 was the Initial. You may already have the information from the K-22 well. Joe, Had E-Mail issue yesterday that prevented this information being sent. Thanks, Mark O'Malley ACT! MPU Well Ops Coord. Office: 670-3387 Cell: 659-0560 e-mail: omallemd@bp.com � G 11NEL_ P 11" r, % G r Content -Description: MIT MPU F-73 MITIA 9-20-05.xls MIT MPU F-73 MITIA 9-20-05.xls'Content-Type: application/vnd.ms-excel Content -Encoding: base64 Content -Description: MIT MPU K-22 MITIA 9-20-05.xls MIT MPU K-22 MITIA 9-20-05.xls'' Content -Type: application/vnd.ms-excel Content -Encoding: base64 I of 1 9/27/2005 8:56 AM STATE OFALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: BP Exploration (Alaska) Inc. FIELD / UNIT I PAD: Milne Point Unit/F-Pad DATE: 09/20/05 OPERATOR REP: Jeff Rea AOGCC REP: Chuck Scheve declined to witness had pervious engagement s Packer Depth I Pretest Initial 15 Min. 30 Min. WellIMPF-73A--F Typelnj.1 w I TVD 1 7,047'1 Tubingj 3,9001 3,9001 3,9001 3,9001 Intervall 4 PT - Type testj P I Test psi 1 1,7621 Casing 1 1,500 1,900 1,8301 1,8301 PIFJ Pass Notes: Zw_-. (4 00 50 100 100 100 Well I I Type In'. I TVD I I Tubingj I I I I Interval P.T.D.1 Type test I I Test psi I I Casing I I I P/F Notes: Well P.T.D. Notes: Well Type Inj. TVD Tubing I Interval P.T.D.1 l Type testj I Test psi I I Casing I P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D.1 I Type testj I Test psi I I Casing I I I P/F Notes: Test Details: TYPE INJ Codes TYPE TEST Codes F = Fresh Water Inj M = Annulus Monitoring G = Gas Inj P = Standard Pressure Test S = Salt Water Inj R = Internal Radioactive Tracer Survey N = Not Injecting A = Temperature Anomaly Survey D = Differential Temperature Test Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. INTERVAL Codes 1= Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MICROFILMED 04/01105 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\MicrofiIm_Marker.doc 3 DATA SUBMITTAL COMPLIANCE REPORT 4l18l2003 , ! , kdAo Permit to Drill 2001980 Well Name/No. MILNE PT UNIT SR F-73A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22744-01-00 MD 14614 r TVD 8879 Completion Dat 4/22/2001 — Completion Statu 1-OIL Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Sample No Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name Log Log Scale Media Run No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments R R Directional Survey FINAL OH 5/1/2001 Directional Survey, Paper Copy D IIFR Survey FINAL OH 5/1/2001 IIFR Survey, Digital Data j R R Directional Survey FINAL OH 5/1/2001 Directional Survey, Paper Copy I� C 10341 FINAL 10468 12614 CH 9/28/2001 4—M341 10468-12614 Digital Data ` E1Y_ D Ver LIS Verification 1 11052 14215 Open 1/17/2002 G1t04 I I EI!T- C Ver LIS Verification 1 11052 14573 Case 5/9/2002 4,092-5 ED- D Ver LIS Verification 1 11052 12720 Open 1/11/2002 4A530 EIS D Ver LIS Verification 1 11043 14567 Open 12/28/2001 L40512 I ED C Ver LIS Verification 1 11052 14215 Case 5/9/2002 AA0827 P62 R R MWD Survey Report FINAL 11009 12758 1/9/2001 i 11009-12758 Paper Copy 1 9� D IFR Survey Report FINAL 11009 12758 1/9/2001 i 11009-12758 Digital Data i R R IFR Survey Report FINAL 11009 12758 1/9/2001 11009-12758 Paper Copy I3-- D MWD Survey Report FINAL 11009 12758 1/9/2001 11009-12758 Digital Data I L CBL w/ SCMT 5 FINAL 10500 12600 ch 3/23/2001 I 10500-12600 Color Print L CBL w/ SCMT 5 FINAL 10500 12600 ch 3/23/2001 10500-12600 Color Print D MWD Survey FINAL OH 5/1/2001 MWD Survey, Digital Data R R Directional Survey FINAL OH 5/1/2001 Directional Survey, Paper Copy D MWD Survey FINAL OH 5/1/2001 MWD Survey, Digital Data j R R Directional Survey FINAL OH 5/1/2001 Directional Survey, Digital Data j�A` D MWD Survey FINAL OH 5/1/2001 MWD Survey, Digital Data Permit to Drill 2001980 Wei MD 14614 TVD 8879 ED Ver LIS Verification ED D-" Ver LIS Verification Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y / Chips Received? Analysis Received? Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4/18/2003 ie/No. MILNE PT UNIT SR F-73A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22744-01-00 Completion Dat 4/22/2001 Completion Statu 1-OIL Current Status WAGIN UIC Y 1 11052 12720 Case 5/9/2002 408826 P61 1 11052 14573 Open 1 /11 /2001 L't0533 10468 12614 Open 9/28/2001 %A�0341 10468-12614 Interval Dataset Start Stop Sent Received Number Comments Daily History Received? 0X�/ N Formation Tops C1►/ N Date: Mk,�� STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Conversion f/ Prod to WAG In' Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development _ Exploratory_ RKB 42 feet 3. Address 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchora e, AK 99519-6612 Senrice_X Milne Point Unit 4. Location of well at surface 8. Well number 3129' FNL, 2486' FEL, Sec. 06, T13N, R10E, UM (asp's 542076, 6035603) MPF-73A At top of productive interval 9. Permit number / approval number 939' FNL, 932' FEL, Sec. 31, T14N, R10E, UM (asp's 543558, 6043081) 200-198 / 301-284 At effective depth 10. API number 4413' FNL, 590' FEL, Sec. 30, T14N, R10E, UM (asp's 543883, 6044889) 50-029-22744-01 At total depth 11. Field / Pool 4413' FNL, 591' FEL, Sec. 30, T14N, R10E, UM (asp's 543883, 6044889) Milne Point Unit / Sag River 12. Present well condition summary Total depth: measured 14615 feet Plugs (measured) - true vertical 8880 feet Effective depth: measured 14614 feet Junk (measured) true vertical 8879 feet Alaska p1ak oy Casing Length Size Cemented Measured Depth K.�'eee7lli�i�.y; Conductor 112 2011 250 sx Arcticset (Approx) 143 143' Surface 5873' 9-5/8" 1496sx PF 'E', 411 sx 'G' 5904' 4577' Intermediate 11049' 7" 229 sx Class 'G' 11080, 7571' Liner 2129' 4-1/2" 280 sx Class 'G' 10568' - 12697' 7114' - 8789' Side Track Liner 1398' 2-7/8" 56 sx Class 'G' 12413' - 13811' 8629' - 8886' Slotted Liner 804' 2-7/8" uncemented 13811' - 14615' 8886' - 8879' Perforation depth: measured Open Perfs 12720'-13190', 13220'-13500'; Slotted Liner 13853'-14613' true vertical Open Perfs 8798'-8825', 8827'-8867'; Slotted Liner 8885'-8914'. Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 TBG @ 10492' MD. Tubing Tail @ 10561' Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker S-3 Packer @ 10492' MD. 3-1/2" Camco KBUG GLM @ 2481' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Infection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut -In Subsequent to operation 07/01/2002 3000 1703 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ Oil _ Gas _ Suspended _ Service WAG Iniector 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Technical Assistant Date August 22, 2002 DeWa ne R. Sc norr Prepared by DeWa ne R. Schnorr 564-5174 HUMS UMS B F L Form 10-404 Rev 06/15/88 • �,,,,, SUBMIT IN DUPLICATE M P F-73A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/01/2002 WATER INJECTION STARTUP. EVENT SUMMARY 07/01/02 FIRST DAY FOR WATER INJECTION. WELL WAS CONVERTED FROM A PRODUCTION WELL TO A WAG WELL. Page 1 WELL LOG TRANSMITTAL To: State of Alaska February 19, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7 h Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPF-73A, AK-MW-10120 MPF-73A: Digital Log Images: 50-029-22744-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Services BP Exploration (Alaska) Inc. Attn: Jim Galvin Petro -technical Data Center LR2-1 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: Signe _„ t Alaska Oil &GasCorsoCo miftn Anchorage i�nsa-I�5�3 �a� WELL LOG TRANSMITTAL To: State of Alaska January 09, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPF-73 A PB 1, AK-NM-00316 1 LIS formatted Disc with verification listing. API#: 50-029-22744-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL .LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Services BP Exploration (Alaska) Inc. Attn: Jim Galvin Petro -technical Data Center LR2-1 6900 Arctic Blvd. 900 E. Benson, Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99519-6612 r Date: Signe RE' G E I V" F. D 9 Anchorage 11 05aw /070I 14a D I -- 09-oo WELL LOG TRANSMITTAL To: State of Alaska February 19, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7 h Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPF-73A PB2, AK-MW-10120 MPF-73A PB2: Digital Log Images: 50-029-22744-71 aoo-I9 8 /oga 7 1 CD Rom PLEASE ACKNOWLEDGE .RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Services BP Exploration (Alaska) Inc. Attn: Jim Galvin Petro -technical Data Center LR2-1 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: Sign<: �ECErvEo Alaska OU Gas Cons. Commis*n Anchorage WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7" Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPF-73A PB 1, MPF-73A PB1: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22744-70 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22744-70 February 19, 2002 AK-MM-00316 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date RECEIVED FEB 2 c 2002 A m*8Oil&GasCons.Comn bft Anfto BP Exploration (Alaska) Inc. Petro -technical Data Center LR2-1 900 E. Benson. Blvd. Anchorage, Alaska 99508 WELL LOG TRANSM TTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 3 3 3 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPF-73A PB2, 1 .LIS formatted Disc with verification listing. API#: 50-029-22744-71 January 11, 2002 AK-MW-10120 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 REC'El V Date: JAj 1 ; 2002 Al Oil&CasCans.COMM n And e BP Exploration (Alaska) Inc. Petro -technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 r WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPF-73A PB 1, 1 LIS formatted Disc with verification listing. API#: 50-029-22744-70 January 09, 2002 AK-MM-00316 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 4 Date: Sign BP Exploration (Alaska) Inc. Petro technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECEIVEa v 02 Alask8 Oil & Gas Gans. Coalmission Ancharese WELL LOG TRANSMTITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPF-73A, 1 LIS formatted Disc with verification listing. API#: 50-029-22744-01 January 09, 2002 AK-MW-10120 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro -technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: Signe 4 6 J21� RECEIVED AN 1 1 2002 Ala,,,, Oil I Gas C011& Commission Anchorage WELL LOG TRANSMMAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPF-73A, 1 LIS formatted Disc with verification listing. API#: 50-029-22744-01 December 19, 2001 AK-MM-00316 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 9951.8 Date: Sign BP Exploration (Alaska) Inc. :Petro -technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECE9!/ED DE-C 2 8 2-001 Alaska Oil & Gas Cons. COHU issioil &,&rage 9/25/2001 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 1472 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Milne Point (Cased Hole) Well Job # Log Description Date CD Sepia 5L ' PLEASE ACKNOWLEDGE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED SEP282001 Ai;t 00 & Gas Cons. COMMISM": chMF Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie Received b STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Conversion Conversion from Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Prod to Inject Prod to Inject Well Change approved program _ Pull tubing _ Variance— Perforate _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development _X Exploratory _ RKB 42.1 feet 3. Address 7. Unit or Property name P. O. Box 196612 Stratigraphic _ Anchorage, AK 99519-6612 Service_ Milne Point Unit 4. Location of well at surface 8. Well number 2149' FSL, 2485' FEL, Sec. 06, T13N, R10E, UM (asp's 542076, 6035603) MPF-73A 9. Permit number / approval number At top of productive interval 4340' FSL, 932' FEL, SEC 31, T14N, R10E, UM (asp's n/a) 200-198 10. API number At effective depth 866' FSL, 590' FEL, Sec. 30, T14N, R10E, UM (asp's 543883, 6044889) 50-029-22744-01 11. Field / Pool At total depth 867' FSL, 590' FEL, Sec 30 T14N, R10E, UM (asp's 543882, 6044889) 1 Milne Point Unit / Sag River 12. Present well condition summary Total depth: measured 14615 feet Plugs (measured) true vertical 8880 feet Effective depth: measured 14614 feet Junk (measured) true vertical 8879 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 112' 20" 250 sx Arcticset I (Approx 143' 143' Surface 5873' 9-5/8" 1496sx PF 'E',411 sx 'G' 5904' 4577' Intermediate 11049' 7" 229 sx Class 'G' 11080' 7571' Liner 2129' 4-1/2" 280 sx Class 'G' 10568' - 12697' 7114' - 8789' Side Track Liner 1398' 2-7/8" 56 sx Class 'G' 12413' - 13811' 8629' - 8886' Slotted Liner 804' 2-7/8" uncemented 13811' - 14615' 8886' - 8879' Perforation depth: measured Open Perfs 12720' - 13190', 13220' - 13500'; Slotted Liner 13853' - 14613' true vertical Open Perfs 8798' - 8825', 8827' - 8867'; Slotted Liner 8885' - 8914' RECEIVED Tubing (size, grade, and measured depth 3-1/2", 9.3#, L-80 TBG @ 10492' MD. Tubing Tail @ 10561'. SEP 2 8 2001 Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker S-3 Packer @ 10492' MD. AlasiaOil & Gas Cons. Commission 3-1/2" x 1" Camco KBUG GLM @ 2481' MD. 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: 09/28/2001 Oil _ X Gas _ Suspended 16. If proposal was verbally approved Name of approver Zl-Date proved Service 17. 1 hereby certify that the foregoin is tr corr t he b st of my knowledge. Questions? Call Michael Aivano @ 564-5943. Signed Titl : Milne Point Petroleum Engineer Date September 27.,2001 Michael Aivano Prepared by DeWa ne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no. Plug integrity _ BOP Test ^ Location clearance _ Mechanical Integrity Test Subsequent form required 10-AUA- Original Sigilea 0p Cammy Oechsli Tayl0 G' Approved by order of the Commission Commissioner Date p. Form 10-403 Rev 06/15/88 • ORIG INAL SUBMIT IN TRIPLICATE bp .•. .:��,;ut. O AV BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 27, 2001 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for MPF-73A Conversion from Producer to Injector BP Exploration Alaska, Inc. proposes to convert well MPF-73A from a shut-in producer to an active injector as part of the Milne Point Sag River Flood Development project. Well MPF-73A was drilled in April of 2001 as a high angle coiled tubing sidetrack. The well was pre -produced for less than 2 months. It has remained shut-in since July 210 2001. As part of the Milne Point Sag River Flood Development project, well MPF-73A is part of the water and miscible injectant flood. The objectives of this project are to reduce produced gas by injecting water to sweep out the expanded gas cap and provide additional oil recover through flood displacement, and access additional reserves through MI injection. Well MPF-73A will be used to inject both water and MI (WAG flood). The plan to prepare for injection and to show that MPF-73A is capable of accepting water and MI injection is attached. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5943 or e-mail me at AivanoMJ@bp.com. Sincer y icheal Aivano Milne Point Unit Petroleum Engineer J 0 Well MPF-73A Current Status: • Jet pump has been pulled. • Pumped corrosion inhibitor and shifted sleeve to closed position @ 10455. • Pressure tested 3-1/2" tubing / 7" casing annulus to 3500 psi and bled to 0 psi with no leaks. • Well has been freeze protected, shut-in and safed out. • Removed flow lines, power fluid line and riser. Installed blinds and torqued Plan Forward: 1. Install new piping to covert well to an injector.' 2. CMIT TAX Obtain State witness of CMIT and MITOA. 3. Pull plug from tailpipe. ,_ 4. Obtain a cement bond log (SCMT) to show adequate cement coverage between the top Sag River and the next highest hydrocarbon zone (Kuparuk). 5. Put well on water injection and perform scheduled surveillance logging. Monitor the IA and wellhead pressures. H U D D A. '_7 -7 cET 7 .1 rz 7 1-iPuHANICAL INTEGRITY 1E-*_PORT OPER & FIELD 411,11 vEl-L NUMBER k4P F - 77A IS '7U -F-BTD: MD,-T-ELL DA.T-k TD: 7 Shoe: /1010'MD I'S 71 TVD i DV: TOP -71/t/ _71'D --:ter - L�-.hoe: 6,?7 %11M 'P - t7 1-M TVD: Ser- at 1 E7'// Z- C_ %.- - and P e r I -s 0 1 e S z e [O C 'g _A jq-C A 7NTEGRITY - PART il t 0 TV 1.',' A Press Test. 7P p4l, min 0 min Co=ents: 17A cjt4t. OtA I I - ' ECRANTCrA _L INTEGRITY - PART 12 if ► 7 Cement Volumesv. Amt. I.Liner k Cs cr DV CCott-jol to cover Der-tX s C,ar vt, +-.(Soo 7-- heoret'cal TOC IdC Idl Cement Bond Log (Yes or No) In AOGCC File e CBL "Evaluation, -one above perfs Production Log: Type Evaluation CONCLUSIONS art A4 -t IT j vo Exhibit 1-1 Tree: FMC 3-1/8" x 5M M P U F ? 3a Ong' KB Elev. = 41.4 ' (N 22E) Wellhead, 11" x 71/16" 5M Gen 5a Orig. GL Elev. = 11.5' w/ 2 7/8" FMC tbg hng., 3" LHacme KB To Tbg. Spool = 28.50' (N 22E) lift threads x 2 7/8" 8rd on bottom, 2.5" CIW'H' BPV profile. 3 20" 91.1 ppf, H-40 112' KOP @ 400' Max. hole angle = 64 to 66 deg. f/ 4,445' to 8,627' Hole angle thru' perfs = 26.45 9 5/8', 40 ppf, L-80 Btrc. 5,904' 3.5" 9.3 #/ft , L-80 , NSCT. Bbls/ft = .0087 ID = 2.992" 7" 26 ppf, L-80, BTC-Mod production csg. ( drift ID = 6.151 ", cap. = 0.0383 bpf ) Two 7" x 21' marker joints f/ 10,547' - 10,588' 7" Baker ZXP packer 10 568' 7" Baker flexlock hanger 10,585' 7' float collar (PBTD) 10,99T 7" float shoe 11,080, 4.5" 12.6#, L-80, BTC casing 4.5" Whipstock ® 12,707' k " Halliburton latch collar 12671' " Halliburton float collar 12714' Halliburton float shoe 12758' REV. BY COMMENTS Moo # 2 ESP completion 4ES M. Linder M. Linder Recompleted into SAG River 04/21/01 MDO CTU Horizontal sidetrack Nordic #1 i -- - 3.5" X 1' Camco KBUG GLM 2481' I Tail pipe inside hanger 7' above 4.5" X-Over *Measure depths differ between rigs" Phoenix Discharge PSI sub (2.95" id) 10,454' 3.5" Baker Sliding sleeve SMU Phoenix Multisensor ( 2.95" id) 10,471' Baker S-3 pkr. 7" x 3.5" 10,492' 3.5" HES XN-Nipple ( 2.813" Pkg) 10,520' ( Min. id 2.75" ) WLEG 10,561' Top of 2-7/8" liner ® 12,413 Baker landing collar 13,811' float collars 13,814' d, 13,825' Shoe 14,614' pbtd 14,615' 2 7/8" st-I pre -drill liner (13,811'-14,614') Size SPF Interval (TVD) 2" 2" 4 4 12,7201-13,19a 13,220'-13,50 MILNE POINT UNIT WELL F-73a API NO: 50-029-22744-00 BP EXPLORATION (AN r. Exhibit 1-1 r2-5"CIW'H'BPV 3-1/8" x 5M M p U F-73a Orig. KB Elev. = 41.4 ; (N 22E) Wellhead: 1 x 7 1/16 5M Gen 5a Orig. GL Elev. = 11.5 C tbg hng., 3" LHacme KB To Tbg. Spool = 28.50' (N 22E) x 2 7/8" 8rd on bottom, c 'BPV profile. pf, H-40 112' KOP @ 400' Max. hole angle = 64 to 66 deg. f/ 4,445' to 8,627' Hole angle thru' perfs = 26.45 9 518", 40 ppf, L-80 Btrc. 5904' 3.5" 9.3 #/ft , L-80 , NSCT. Bbls/ft = .0087 ID = 2.992" 7" 26 ppf, L-80, BTC-Mod production csg. ( drift ID = 6.151 ", cap. = 0.0383 bpf ) Two 7" x 21' marker Joints f/ 10,547' - 10,588' 7" Baker ZXP packer 10 568' 7" Baker flexlock hanger 10,585' 7" float collar (PBTD) 10,997' 7" float shoe 11,080' 4.5" 12.6#, L-80, BTC casing 4.5" Whipstock ® 12,707' 4.5" Halliburton latch collar 12671' 4.5" Halliburton float collar 12714' 4.5" Halliburton float shoe 12758' DATE REV. BY COMMENTS 08 / 16 / 97 MDO # 2 ESP Completion 4ES 05120/98 M. Linder ESP Chang "I 12/30/00 M. Linder Recompleted into SAG River 04/21/01 MDO CTU Horizontal sidetrack Nordic #1 3.5" X 1" Camco KBUG GLM 2481' I Tail pipe inside hanger 7' above 4.5" X-Over "Measure depths differ between rigs' Phoenix Discharge PSI sub ( 2.95" id) 10,454' 3.5" Baker Sliding sleeve SMU 10 461' , Phoenix Multisensor ( 2.95" id) 10,471' Baker S-3 pkr. 7" x 3.5" 10,492' 3.5" HES XN-Nipple (2.813" Pkg) 10,520' ( Min. id 2.75" ) WLEG 10,56V Top of 2-7/8" liner® 12,413 Baker landing collar 13,811' float collars 13,814' & 13,825' Shoe 14,614' pbtd — ---- 14,615' 2 7/8" st-I pre -drill liner (13.81 V-14,614') Size SPF Interval (TVD) 2" 2" 4 4 12,720'43,19 13,220'-13,50 MILNE POINT UNIT WELL F-73a API NO: 50-029-22744-00 BP EXPLORATION (AN STATE OF ALASKA' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ® Oil ❑Gas ❑Suspended ❑Abandoned ❑Service 2. Name of Operator BP Exploration (Alaska) Inc. 7. Permit Number 200-198 3. Address P.Q. Box 196612, Anchorage, Alaska 99519-6612 _ . 8. API Number 50-029-22744-01 4. Location of well at surface,, C''r,f _�,,,,, 2149 NSL 2485 WEL, SEC. 6, T13N, R10E, UM VERIFIEO � ;,,,..4 ` � :., �,y�.� At top of productive interval S:r - 4340' NSL, 932' WEL, SEC. 31, T14N, R10E, UM At total depth VERIFfED k 8 866' NSL, 590' WEL, SEC. 30, T14N, R10E, UM 9. Unit or Lease Name Milne Point Unit 10. Well Number 5. Elevation in feet (indicate KB, DF, etc.) KBE = 42.10' 6. Lease Designation and Serial No. ADL 355018 11. Field and Pool Milne Point Unit /Sag River 12. Date Spudded 12/22/2000 13. Date T.D. Reached 4/16/2001 14. Date Comp., Susp., or Aband. 4/2 72O 15. Water depth, if offshore N/A MSL 16. No. of Completions One 17. Total Depth (MD+TVD) 14614 8879 FT 18. Plug Back Depth (MD+TVJF)T 14614 8879 19. Directional Survey ® Yes ❑ No 20. Depth where SSSV set 21. N/A MD Thickness of Permafrost 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, CBL 2 • CASING LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE SETTING DEPTH HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM 20" 91.1 # H-40 Surface 112' 24" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 31' 5904' 12-1/4" 1496 sx PF 'E' 411 sx Class 'G' 7" 26# L-80 31' 11080, 8-1/2" Class 'G' 4-1/2" 12.6# L-80 10568' 12697' 6-1 /8" 80 x Class 'G' 2-7/8" 6.16# L-80 12414' 14614' 3-3/4" sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 2-7/8" Slotted Liner Section 2" Gun Diameter, 4 spf MD TVD MD TVD 13853' - 14613' 8885' - 8880' 12720' - 13190' 8799' - 8826' 13220' - 13500' 8828' - 8868' 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2", 9.2#, L-80 10561' 10492' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 12696' Set Packer and Whipstock on top Freeze Protect with 85 Bbls of Diesel 27. PRODUCTION TEST Date First Production May 26, 2001 Method of Operation (Flowing, gas lift, etc.) Jet Pump Date of Test 6/21 /2001 Hours Tested 12 PRODUCTION FOR TEST PERIOD OIL-BBL 174 GAS-MCF 115 WATER-BBL 118 CHOKE SIZE GAS -OIL RATIO 661 Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR BATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (CORR) 28• CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECENED JUL U 2 ?0111 Alaska Oil & Gas Cons. Commission Form 10-407 Rev. 07-01-80 G I IN A Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Sag River 12635' 8760' Sag River B 13130, 8824' Sag River A 13535' 8873' RECEIVED JUL D 2 2001 Alaska Oil &Gas Cons. Commission Anchorage 31, List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak -Off Test Summary 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terris Hubble �� Title Technical Assistant Date ' CI CIO MPF-73A 200-198 Prepared By Name/Number: Terrie Hubble, 564-4628 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. 07-01-800 R G BP EXPLORATIN Page 1 of 1 Leak - Off Test Summary Legal Name: MPF-73 Common Name: MPF-73A Test Date 'Tes#.Type' Test Depth (TIMID) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 12/22/2000 FIT 11,080.0 (ft) 7,555.0 (ft) 11.10 (ppg) 950 (psi) 5,306 (psi) 13.52 (ppg) 12/30/2000 FIT (ft) (ft) (ppg) (psi) (psi) 13.52 (ppg) Printed: 6/28/2001 2:16:16 PM BP EXPLORATION Operations Summary Report Page 1 of 6 1 Legal Well Name: MPF-73 Common Well Name: MPF-73 Spud Date: 2/15/1997 Event Name: RE ENTER Start: 12/20/2000 End: 12/31 /2000 Contractor Name: DOYON Rig Release: 12/31/2000 Group: RIG Rig Name: DOYON 141 Rig Number: Date From -To Hours Task Sub Code Phase Description of Operations 12/20/2000 06:00 - 16:00 10.00 RIGU PRE Move rig from MPF-84 to MPF-73 and rig up. ACCEPTED RIG AT 1600 HRS 12/20/2000. Held PreSpud meeting with rig crew. 16:00 - 18:00 2.00 WHSUR DECOMP Checked and found no pressure on annulus nor tubing. Pulled BPV and installed TWC. Filled annulus with 26 bbls. Pressure tested bottom of TWC to 1000 psi -OK. Tested TWC from the top to 1000 psi -OK. 18:00 - 19:30 1.50 WHSUR DECOMP Nipple down tree and tubing head adapter flange. Connection in top of hanger 3" LH Acme Thds. 19:30 - 21:30 2.00 BOPSUR LNR1 Nipple up 7-1/16" x 13-5/8" 5M DSA. Nipple up 13-5/8" BOP stack. 21:30 - 22:00 0.50 BOPSUP LNR1 Pressure tested blind rams, HCR(kill) and breaks below blinds to 250 psi low for 5 minutes and 4000 psi high for 10 minutes. 22:00 - 22:30 0.50 WHSUR LNR1 Backed out lock down screws and pulled TWC and tubing hanger. 22:30 - 00:00 1.50 BOPSUF LNR1 Installed test plug. Rigged up and began testing BOPE to 250 psi low and 4000 psi high. 12/21/2000 00:00 - 04:00 4.00 BOPSUF LNR1 Finished testing BOPE. Tested all rams and valves 250 psi low for 5 minutes and 4000 psi high for 10 minutes. Tested annular preventor 250 psi low for 5 minutes and 2500 psi high for 15 minutes. Conducted accumulator test. Right to witness test waived by AOGCC Inspector, John Spaulding. 04:00 - 05:00 1.00 BOPSUP LNR1 Thawed ice plug in kelly hose. 05:00 - 06:00 1.00 DRILL LNR1 Made up used 6-1/8" bit and ran in hole 90' for gauge run on casing hanger. Pulled out of hole and laid down bit. 06:00 - 07:30 1.50 DRILL LNR1 Picked up mule shoe and singled in hole to 887'. Tagged ice plug. 07:30 - 08:00 0.50 DRILL LNR1 Circulated out diesel from 887'. 08:00 - 08:30 0.50 DRILL LNR1 . Pulled out of hole and racked back 3-1/2" drill pipe in derrick. 08:30 - 12:00 3.50 DRILL LNR1 Picked up drilling BHA #1. Ran in hole and tagged ice plug at 887'. Shallow pulse tested MWD. 12:00 - 12:30 0.50 DRILL LNR1 Reamed out ice plug from 887'-1000'. 12:30 - 16:00 3.50 DRILL LNR1 Single in drill pipe from pipe shed. Racked an additional 14 stands in 'the derrick for drilling. Continued singling in hole to 2205'. 16:00 - 16:30 0.50 DRILL LNR1 Displaced diesel from wellbore. 16:30 - 23:00 6.50 DRILL LNR1 Singled in drill pipe from pipe shed to 10,000'. Stand back 11 stands. `Picked up 33 additional joints. 23:00 - 00:00 1.00 DRILL LNR1 Slip and cut drill line. Printed: 1/12/2001 3:43:51 PM BP EXPLORATION Operations Summary Report Page 2of61 Legal Well Name: MPF-73 Common Well Name: MPF-73 Spud Date: 2/15/1997 Event Name: RE ENTER Start: 12/20/2000 End: 12/31/2000 Contractor Name: DOYON Rig Release: 12/31/2000 Group: RIG Rig Name: DOYON 141 Rig Number: Date I From - To Hours I Task Code Sub Phase Description of Operations 12/22/2000 00:00 - 00:30 0.50 DRILL LNR1 Finished cutting drill line and rig service. 00:30 - 01:00 0.50 DRILL LNR1 Continued running in hole and tagged cement at 10367'. 01:00 - 02:00 1.00 DRILL LNR1 Washed and reamed from 10367'-10425'. 02:00 - 05:00 3.00 DRILL LNR1 Drilled good cement from 10425'-10870'. 05:00 - 06:00 1.00 DRILL LNR1 Washed and reamed fill from 10870' to float collar at 10990' DPM. Pumped sweeps as needed to clean hole. 06:00 - 07:00 1.00 DRILL LNR1 Drilled float collar, shoe joints and shoe at 11073'. Cleaned out 13' of rat hole to 11086'. 07:00 - 08:30 1.50 DRILL LNR1 Circulated bottoms up. Pumped high vis sweep and displace seawater with 11.3 ppg KCL/LSND mud. Clean hole ECD with 11.3 ppg mud at \ 230 gpm is 12.7 EMW. \/ 08:30 - 10:30 2.00 DRILL LNR1 Drill new hole from 11086-11108'. Stalled motor. Pipe stuck. Jarred pipe free with 40K over pick up weight. Worked back to bottom with frequent stalls. Drilled from 11,108'-11,119' at about 40 ft/hr. Parameters: 200 gpm at 3000 psi, 30 rpm at 12,000 ftlbs torque, 5-1 OK WOB. 10:30 - 11:30 1.00 DRILL LNR1 Mixed and pumped nut plug sweep to unball bit. Circulated sweep around. 11:30 - 12:00 0.50 DRILL LNR1 Pulled out of the hole from 11,119' to 10,956'. Ran back into hole to 11,114'. Tagged fill. 12:00 - 13:00 1.00 DRILL LNR1 Pulled into casing shoe. Performed FIT to 13.5 ppg EMW. Closed rams and pressured up on formation to 950 psi, TVD-7555', mud weight 11.1 ppg. Pressured up to 950 psi and shut down pumps. Pressure slowly decreased to 840 psi in 10 minutes. Good test. 13:00 - 00:00 11.00 DRILL LNR1 Rotate and slide from 11,119'-11,173'. Very difficult sliding and rotating. Adding lubetex and drill & slide to assist sliding. Difficult maintaining toolface. Experiencing packing off after stalling. Had to jar pipe free during slide attempts. Reduced MW from 11.3 ppg to 10.8 ppg. Reduce YP 22 to 18. Reduced ECD from 12.6 to 11.8. Rotate and slide from 11,173'-11,282'. Continued adding EP mudlube, drill and slide and lubetex. Increased oil content to 3%. Average drill rate approximately 15-30ft/hr. Drilling parameters: 215 gpm @ 3680 psi, 60 RPM @ 12,000 ft/lbs, WOB 5-10K, ROP 15-30 ft/hr. 12/23/2000 00:00 - 12:30 12.50 DRILL LNR1 Rotate and slide from 11,282'-11469'. Very difficult sliding. Hole conditions somewhat better with mud weight reduced from 11.3 ppg to 10.8 ppg. Still experiencing some packing off after stalls. Due to difficult sliding and poor response from slide, decision was made to change bits. Drilling Parameters: 225 gpm at 3920 psi/4020 psi, 50 RPM at 10,000 ftlbs torque, ROP average 30'/hr when able to slide and 807hr rotating. Up weight 155, SO weight 120K and Rot weight 137K. Printed: 1/12/2001 3:43:51 PM BP EXPLORATION Operations Summary Report Page 3 of 6 1 Legal Well Name: MPF-73 Common Well Name: MPF-73 Spud Date: 2/15/1997 Event Name: RE ENTER Start: 12/20/2000 End: 12/31 /2000 Contractor Name: DOYON Rig Release: 12/31/2000 Group: RIG Rig Name: DOYON 141 Rig Number: Date From -To Hours Task Sub Code Phase Description of Operations 12/23/2000 12:30 - 13:30 1.00 DRILL LNR1 Circulated bottoms up. Circulating at 220 gpm with 11.9 ppg ECD. 13:30 - 19:00 5.50 DRILL LNR1 Pulled 5 stands into shoe. Flow check negative. Slug and pulled out of hole. Drain motor and break off bit. Download MWD. 19:00 - 00:00 5.00 DRILL LNR1 Change out MWD. Orient and intall new probe and load MWD. RIH with BHA and shallow pulse test tool. Ran in hole to 5600' and break circulation then continued running in hole. 12/24/2000 00:00 - 00:30 0.50 DRILL LNR1 00:30 - 01:00 0.50 DRILL LNR1 01:00 - 01:30 0.50 DRILL LNR1 01:30 - 02:30 1.00 DRILL LNR1 02:30 - 09:30 7.00 DRILL LNR1 09:30 - 11:00 1.50 DRILL LMWD LNR1 11:00 - 16:00 5.00 DRILL LMWD LNR1 16:00 - 19:00 1 3.001 DRILL I LMWD I LNR1 19:00 - 22:30 1 3.501 DRILL I LMWD I LNR1 22:30 - 00:00 1.50 DRILL LMWD LNR1 112/25/2000 00:00 - 11:00 11.00 DRILL LNR1 11:00 - 12:00 1.00 DRILL LNR1 12:00 - 18:00 6.00 DRILL LNR1 18:00 - 19:00 1 1.001 DRILL I I LNR1 19:00 - 22:30 1 3.501 DRILL I I LNR1 Continued running in hole to 11,340'. Wash and ream from 11,340'-11,469' as a precaution. No problems. Rotary drill from 11,469'-11,500'. Pulled up and took check shots at 11,402', 11,434' and 11,466'to satisfy Jorps. Rotate and slide from 11540'-11719'. Had MWD failure. Drilling parameters: 225 gpm at 3920 psi, 80 RPM at 10000 ftlbs torque, ROP average 257hr sliding and 60'/hr rotating. Up weight 160K, SO weight 120K and rotating weight 137K. Circulated bottoms up to clean hole. Flow check negative. Pulled 7 stands into shoe with no problems. Flow check -negative. Slug pipe and pulled out of hole. Download MWD. Laid out MWD. Picked up new MWD and uploaded. RIH with MWD and performed shallow surface test. Ran back in hole breaking circulation at 5610' and 10860'. Continued in hole to 11550'. Tight hole. Washed and reamed from 11530'-11719'. Check shot @ 11626'. Rotate and slide from 11719'-11913'. ROP rotating approximately 60'hr. ROP sliding 107hr with questionable results. Toolface 120 degree to the right and left with frequent stalls. Decision was made to pull bit due to build rate required and inability to slide with present drilling assembly. Drilling parameters: 90 RPM with 11000 ftlbs torque, WOB 5-1 OK, 220 gpm 3960/4050 psi, PU weight 155K SO weight 11 OK Rot weight 130K. Circulated bottoms up. Pulled one stand every 30 minutes. Observed well and pulled into casing. Observed well and pumped dry job. Pulled out of hole and download MWD and laid down motor. Picked up new motor (low speed/high torque) set at 1.5 degree. RIH with BHA and shallow pulse test MWD. Ran in hole with 3-1/2" drill pipe breaking circulation at 3690', 7035' and Printed: 1/12/2001 3:43:51 PM BP EXPLORATION Operations Summary Report Legal Well Name: MPF-73 Common Well Name: MPF-73 Event Name: RE ENTER Contractor Name: DOYON Rig Name: DOYON 141 Date From -To Hours Task Sub Code Phase 12/25/2000 19:00 - 22:30 3.50 DRILL LNR1 22:30 - 23:30 1.00 DRILL LNR1 23:30 - 00:00 0.50 DRILL LNR1 12/26/2000 00:00 - 00:30 0.50 DRILL LNR1 00:30 - 0.00 DRILL LNR1 112/27/2000 100:00 - 10:30 1 10.501 DRILL I I LNR1 10:30 - 14:00 1 3.501 DRILL I I LNR1 14:00 - 20:00 1 6.001 DRILL I I LNR1 20:00 - 23:30 1 3.501 DRILL I I LNR1 23:30 - 00:00 1 0.501 DRILL I I LNR1 112/28/2000 100:00 - 02:00 1 2.001 DRILL I I LNR1 02:00 - 06:00 1 4.001 DRILL I I LNR1 06:00 - 07:30 1 1.501 DRILL I I LNR1 07:30 - 21:00 1 13.501 DRILL I I LNR1 Page 4 of 6 1 Spud Date: 2/15/1997 Start: 12/20/2000 End: 12/31/2000 Rig Release: 12/31/2000 Group: RIG Rig Number: Description of Operations 10850'. Slip and cut drill line. Continued running in hole. Ream tight hole f/11530'-11620', 11730'-11810' and 11845'-11940'. Rotate and slide from 11940'-12315'. Attempting to build angle to 55 degrees and turn the azimuth to the left. Drill rates are slow but consistent. ROP while sliding is averaging 15-20'/hr and rotating is 20-30'/hr. Hole appears to be in good shape. No fill or drag on connections. Drilling parameters: 225 gpm at 3600 psi, 80 rotary at 9000 ftlbs torque, WOP 15-30K, PU weight 165K, SO weight 130K, Rot weight 145K. Rotate and slide from 12315'-12480'. Attempting to build angle to 55 degrees and turn azimuth to the left. Slide from 12288'-12328' @ 35 left with no result. Slide from 12385'-12435' @ 50 left again with no result. Drilling parameters: 225 gpm at 3600 psi, 80 rotary with 9000 ftlbs torque, WOB 15-30K, PU weight 165K, SO weight 130K, Rot weight 145K. Circulated and raised mud weight from 10.8 ppg to 11.0 ppg. Spotted 10 bbl baratrol pill in open hole. Flow check -negative. Pulled wet into casing. Max pull 10-15K in first 5 stand coming off bottom. Flow check at shoe. Slug and pulled out of hole. Set back BHA. Break bit. Down load MWD and pulled probe. Pulled wear ring and installed test plug. Test all rams and valves 250 psi low for 5 minutes and 4500 psi high for 10 minutes. Annular preventer was tested to 250 psi low for 5 minutes and 2500 psi high for 10 minutes. Function tested accumulator. Rigged down test equipment and installed wear ring. Choke manifold was tested on trip out of hole to same specifications. Stack test was witnessed by AOGCC Inspector, Jeff Jones. Check orientation. Changed out motor stab sleeve. Adjust motor to 1.83 degree. Orient BHA. Install probe and upload. RIH with BHA and shallow pulse test MWD. Trip in hole with 3-1/2" drill pipe. Broke circulation at 3690', 7035' and 10380'. Ran check shot at 11347'. RIH to 12100'. Washed and reamed from 12100'-12480'. Pumping 200 gpm and reamed slowly in hole. Easy reaming max weight at any one time 5K. Rotate and slide from 12480'-12618'. Attempting to turn azimuth from 16 degrees left to 10 degree and build from 48 degrees inclination to 55 degrees inclination. Printed: 1/12/2001 3:43:51 PM BP EXPLORATION Operations Summary Report Page 5 of 6 1 Legal Well Name: MPF-73 Common Well Name: MPF-73 Spud Date: 2/15/1997 Event Name: RE ENTER Start: 12/20/2000 End: 12/31/2000 Contractor Name: DOYON Rig Release: 12/31/2000 Group: RIG Rig Name: DOYON 141 Rig Number: Date Sub From - To Hours Task Code I Phase Description of Operations 112/28/2000 107:30 - 21:00 1 13.501 DRILL I I LNR1 21:00 - 00:00 1 3.001 DRILL I PIPE I LNR1 112/29/2000 100:00 - 03:00 1 3.001 DRILL I PIPE I LNR1 03:00 - 04:00 1 1.001 DRILL 1 PIPE LNR1 04:00 - 09:00 1 5.001 DRILL I PIPE 1 LNR1 09:00 - 10:30 1.50 DRILL PIPE LNR1 10:30 - 14:30 4.00 DRILL LNR1 14:30 - 16:00 1.50 DRILL CIRC LNR1 16:00 - 17:30 1 1.501 DRILL I CIRC LNR1 Slide 12480'-12550' 45 L - saw walk to left w/short surveys Slide 12550'-12570' HS-observed build on short surveys Rotate 12570-12576' Rotated ahead Slide 12576'-12602' 20R-to build angle Rotate 12602'-12618' Lost 500 psi of pump pressure. Checked surface equipment and determined leak was downhole. Observed well. Pulled out of hole to shoe looking for washout. Observed well. Pulled out of hole wet and found wash out in top single to stand #105. Laid down washed out joint and continued out of hole to change BHA. Finished pulling out of hole. Set back BHA, break bit and stab sleeve. Adjust motor to 0 degree and laid down motor. Download MWD. Picked up 5" high speed motor and set at 0 degree. Upload MWD. Made up used 6-1/8" Sec. 2543 PDC bit. RIH with BHA and shallow pulse test MWD. Run in hole with 3-1/2" drill pipe filling drill pipe every 35 stands. Ran in hole to 12480' with no problems. Washed and reamed from 12480'-12618'. Reamed with 3-5K weight on bit to TD. Backreamed with no problems. Rotary drilled from 12618'-12758'. ROP 60-70ft/hr, 80 RPM at 12000 ftlbs, 220 gpm at 3750 psi, Up weight 175K, SO weight 125K, Rot weight 135K. Lost total returns at 12758'. Observed well. Well standing full. Reduced pump rate to 50 gpm and well would not circulate. Mixed and spotted 32 bbl LCM pill with 28 ppb barafibre. No returns while spotting pill. Lost a total of 142 bbls of mud to formation. Pulled out of hole slowly to shoe at 11080'. 17:30 - 18:00 0.50 DRILL Circ LNR1 Attempted to break circulation. Pumped 10 bbl without returns. 18:00 - 19:00 1.00 DRILL CIRC LNR1 POOH to 8812'. 19:00 - 19:30 0.50 DRILL CIRC LNR1 Attempted to break circulation. Pumped 10 bbl without returns. 19:30 - 20:00 0.50 DRILL CIRC LNR1 POOH to 6544'. 20:00 - 20:30 0.50 DRILL CIRC LNR1 Attempted to break circulation. Pumped 10 bbl without returns. 20:30 - 23:00 2.50 DRILL CIRC LNR1 POOH without problems. 23:00 - 00:00 1.00 DRILL CIRC LNR1 Download and lay down BHA. 12/30/2000 00:00 - 01:00 1.00 DRILL LNR1 Lay down BHA. 01:00 - 01:30 0.50 CASE LNR1 Rig up casing tools. 01:30 - 02:00 0.50 CASE LNR1 PJSM. 02:00 - 04:30 2.50 CASE LNR1 Run 52 jts of 4 1/2", 12.6#, L80, IBT liner. Make up liner Baker Flex Lock hanger and ZXP liner top packer. 04:30 - 05:00 0.50 CASE LNR1 Circulate liner volume. Pumped 35 bbl, had 12 bbl returns. 05:00 - 16:00 11.00 CASE LNR1 Run liner on drillpipe, rabbiting each stand, filling every 10 stands. 16:00 - 20:00 4.00 CEMT LNR1 RU cement lines and break circulation. Had full returns. Stage pumps Printed: 1/12/2001 3:43:51 PM BP EXPLORATION Operations Summary Report Legal Well Name: MPF-73 Common Well Name: MPF-73 Event Name: RE ENTER Contractor Name: DOYON Rig Name: DOYON 141 Date From - To I Hours I Task I Code I Sub Phase 112/30/2000 16:00 - 20:00 4.00 CEMT LNR1 20:00 - 21:00 1.00 CEMT LNR1 21:00 - 21:30 0.50 CEMT LNR1 21:30 - 22:30 1.00 CEMT LNR1 22:30 - 00:00 1.50 CEMT LNR1 12/31/2000 00:00 - 00:30 0.50 CEMT LNR1 00:30 - 02:00 1.50 CEMT LNR1 02:00 - 06:00 4.00 CASE LNR1 06:00 - 06:30 0.50 CASE LNR1 06:30 - 09:30 3.00 CASE LNR1 09:30 - 10:00 0.50 CASE LNR1 10:00 - 11:00 1.00 CASE LNR1 11:00 - 12:30 1.50 CASE LNR1 12:30 - 16:00 3.50 CASE LNR1 16:00 - 16:30 0.50 WHSUR LNR1 16:30 - 17:30 1.00 WHSUR LNR1 17:30 - 18:30 1.00 WHSUR LNR1 18:30 - 20:30 2.00 WHSUR LNR1 20:30 - 22:30 2.00 WHSUR LNR1 22:30 - 23:30 1.00 WHSUR LNR1 23:30 - 00:00 0.50 WHSUR LNR1 Page 6 of 6 1 Spud Date: 2/15/1997 Start: 12/20/2000 End: 12/31/2000 Rig Release: 12/31/2000 Group: RIG Rig Number: Description of Operations up to 49 spm w/ full returns. Circulate and condition mud. Held PJSM. Cement liner as follows. 5 bbl ter, test lines 4500psi, 15 bbl water, 50 bbl Mudpush XL @ 12.5ppC,,98x Class G + 0.2gps D047 +.3% D065 +.1% D800 +.4% D167 m@ 15.8ppg w/ fresh water for 60 bbl slurry (1.16cuft/sk). Flush cement line and drop dart. Displace w/ 40 bbl 10.Oppg brine then 68 bbl mud. Bumped plug. CIP @ 20:50 hrs. Set Baker liner hanger w/ 4000psi, set Baker ZXP packer w/ 50, OOOIbs. Release running tool. Circulate 150% annulus volume, returned 31 bbls of cement contaminated mud. Pump spacer and displace to 10.Oppg brine. Continue displacing to 10.0 brine. Observe well. LID cement head. Pulled out of hole laying down 3-1/2" drill pipe. Service rig and top drive. Finished pulling out of hole laying down 3-1/2" drill pipe and laid down liner setting tool. Close blinds and test caisng to 3500psi f/ 30 min. TIH to 2200'. Freeze protect w/ 73 bbls of diesel. Lay down drillpipe. Pull wear bushing. Install 7" back pressure valve and test same to 1000psi. Slip and cut 87' of drill line. ND BOP. NU tree. Test tree to 3500psi f/ 10min. Bleed pressure f/ casing. Secure rig and prepare for rig move. Rig released @ 00:00 hrs 12/31/00. Printed: 1/12/2001 3:43:51 PM MILNE POINT, ALASKA TO: Troy Weiss FROM: Matthew Linder WELL# F-73 Main Category: E-Line Sub Category: SCMT Log Operation Date: 03/02/01 Objective: Run SWS cement mapping tool to PBTD and log to 10500'. Tie in log will be SWS gamma ray collar log dated March 13,1997. Operation: Rig up SWS. Pressure test lubricator to 2500 psi. RIH w/ Slimhole cement mapping tool tie into SWS GR-CCL log dated March 13, 1997. Depth offset by —7'. RIH to PBTD 12610', log up at 1800 fph for repeat section. Drop back to log main pass from 12610'- 10500' at 1800 fph. Estimate cement top at 11595' Conclusion: Completed SCMT log without problems. Estimated cement top at 11595' SIWHP:0 IA:O OA: Note: All measurements are slickline depths unless otherwise noted. Diesel Used I I Methanol Used Diesel / Methanol cost tracking: BP EXPLORATION Operations Summary Report Page 1 of 9 1 Legal Well Name: MPF-73 Common Well Name: MPF-73A Spud Date: 2/15/1997 Event Name: REENTER+COMPLETE Start: 4/5/2001 End: Contractor Name: NORDIC CALISTA Rig Release: 4/19/2001 Group: COIL Rig Name: NORDIC 1 Rig Number: Date From -To Hours Task Sub Code Phase Description of Operations 4/5/2001 08:30 - 10:30 2.00 RIGU PRE ACCEPT RIG AT 08:30 HRS, 04/05/01. R/U Tanks with berms and R/U hardline. Double valved all annulus outlets since well does not have tubing. 10:30 - 13:00 2.50 BOPSUP DECOMP N/U BOPE. Thawed master valve and greased tree. 13:00 - 15:30 2.50 BOPSU DECOMP Performed initial pressure / function test of BOPE. Ordered Peak vac trucks to haul fluids. All Peak trucks busy. 15:30 - 16:30 1.00 BOPSUF DECOMP Held weekly rig crew Safety Meeting. Reviewed BP 8 Golden Rules, LCIR's and reviewed spill and accident records for last 2 months. 16:30 - 20:00 3.50 BOPSUF DECOMP Continued BOPE pressure / function test. Sent test report to AOGCC. No failures. 20:00 - 23:59 3.98 BOPSUF TRAN DECOMP Wait on Peak vac trucks for mud. 4/6/2001 00:00 - 13:00 13.00 BOPSUF TRAN DECOMP Wait for Peak Vac trucks to deliver FloPro. Grind and Inject is down for maintenance, causing delays at Pad 3 to off load. 13:00 - 15:10 2.17 BOPSUP DECOMP RIH with Milling BHA #1 with 3.80" diamond mill and 3.80" string reamer. 15:10 - 15:30 0.33 BOPSUF DECOMP Up Wt at 10,500 ft = 36K with KCL water in well. Cont. RIH. Up Wt at 12,400 ft = 36K with KCL water in well. 15:30 - 16:00 0.50 BOPSUF DECOMP Ream down with 3.80" mill and string reamer. 2.7 BPM, 2120 psi. Swap well over to FloPro while reaming down. 16:00 - 17:00 1.00 BOPSUP DECOMP Mill cement, first motor work at 12,643 ft CTD. Up Wt = 46K. Milled to 12,651 ft at 10-20 FPH, Progress slowed drastically at 12,651' CTD Assume milling 4.5" Latch CLLR at 12,686 ft BKB, ref. Well Schematic. Correct depth to 12,686 ft. Flag CT at 12,686 ft. at top of latch collar. 17:00 - 18:00 1.00 BOPSUF DECOMP Milling Latch CLLR. 2.3 BPM, 2900 psi, full returns, Up Wt. = 42K. Milling at 12,686 ft. 5 stalls so far. 18:00 - 20:00 2.00 BOPSUP DECOMP Milling latch collar at 12686.5'. 2600 psi@2.5bpm. Stall several times. Through at 12688'. 20:00 - 22:15 2.25 BOPSUF DECOMP Mill to 12728'. Stall out on float collar at (per CBL corrected depth). Back ream to 12680'. Ream to btm. Paint EOP flag at 12600'. 22:15 - 23:59 1.73 BOPSUP DECOMP Circulate OOH. 42K# off btm. Rubber and aluminum cuttings in returns. 4/7/2001 00:00 - 00:30 0.50 CLEAN DECOMP At surface. Active mud system: 696 bbls. 00:30 - 01:00 0.50 CLEAN DECOMP Change out string mill to 3.90" od and btm mill to diamond window finishing mill (long gauge), 3.80" od. 01:00 - 02:45 1.75 CLEAN DECOMP RIH with milling assy. 02:45 - 04:45 2.00 CLEAN DECOMP Tag TOL at 10583'. Mill through same. 04:45 - 05:15 0.50 CLEAN DECOMP Tagging 4-1/2" BTC liner collars. Bounce through some. Begin milling at 10678'. Catching each liner collar with 3.90" string reamer. 05:15 - 06:45 1.50 CLEAN DECOMP POOH. 06:45 - 07:10 0.42 CLEAN DECOMP Change out 3.90" string reamer to 3.80" string reamer. M/U long gauge 3.8" finishing mill. 07:10 - 09:10 2.00 CLEAN DECOMP RIH with milling BHA #3. 09:10 - 10:20 1.17 CLEAN DECOMP Ream 4.5" liner from 10,550-12,725' CTD. No motor work getting back to PBTD. [Top of Halco Float CLLR]. 10:20 - 11:30 1.17 CLEAN DECOMP Back ream up to 12,550'. 2.7 bpm, 2530 psi, 4 fpm. Up Wt. = 42K. Ream back down to flag. Correct depth to flag at 12,600' EOP. Add 4' CTD. Ream down to PBTD at 5 FPM, 2.7 bpm, 2550 psi. No motor work. Tag TD at 12,728 ft. Mill on btm, no progress. Definite top of Flt CLLR. 11:30 - 12:00 0.50 CLEAN DECOMP Circulate in very high viscosity pill at PBTD of 12,728 ft. [top of fit cllr]. Back ream to 12,600 ft EOP and flag CT with red flag. 12:00 - 13:45 1.75 CLEAN DECOMP POOH. 80 fpm, 2.5 bpm, 2300 psi. Printed: 5/1/2001 10:30:28 AM BP EXPLORATION Operations Summary Report Page 2 of 9 Legal Well Name: MPF-73 Common Well Name: MPF-73A Spud Date: 2/15/1997 Event Name: REENTER+COMPLETE Start: 4/5/2001 End: Contractor Name: NORDIC CALISTA Rig Release: 4/19/2001 Group: COIL Rig Name: NORDIC 1 Rig Number: Date From -To Hours Task Sub Code Phase Description of Operations 4/7/2001 13:45 - 14:00 0.25 CLEAN DECOMP UO milling BHA. 14:00 - 14:30 0.50 CLEAN DECOMP Held EMS / 8 Golden Rules training. Held Pre Job Safety Meeting. Reviewed procedure to M/U BHA. 14:30 - 15:00 0.50 STWHIP WEXIT M/U Baker Torque Master Pkr, setting tool, ESS and MHA. BHA #4. 15:00 - 17:15 2.25 STWHIP WEXIT RIH with 4.5" Packer setting BHA. 17:15 - 18:10 0.92 STWHIP WEXIT Slow down to 10 FPM at 10550 ft. Ran in 4.5" liner top with no wt loss. RIH at 40 FPM. Pump 0.5 bpm, 980 psi. Fluid exiting above packer thru circ sub. 18:10 - 19:00 0.83 STWHIP WEXIT Stop at red flag at 12600' EOP. Correct CTD. RIH and tag PBTD at 12,728'. Drop 5/8" steel ball. Position top of Baker Torque Master 4.5" Packer at 12,705 ft. Pump ball on seat at 53 bbls. 19:00 - 19:20 0.33 STWHIP WEXIT Pressure coil to 4400 psi. Saw shear after holding for 4 minutes (flo pro effect ?). Rest tool for 10 minutes to record ESS surveys. PU wt 420. Free. Set do 3k# on packer. Appears to be set. 19:20 - 21:30 2.17 STWHIP WEXIT POOH for whipstock tray. Held pit gain drill while tripping. 21:30 - 22:30 1.00 STWHIP WEXIT Down load Sperry orientation data. Showed 40L of high side. Set Baker latch & tray to same. 22:30 - 23:00 0.50 STWHIP WEXIT MU whipstock BHA with 2 jts PH6 23:00 - 23:59 0.98 STWHIP WEXIT RIH with whipstock assy. 4/8/2001 00:00 - 01:30 1.50 STWHIP WEXIT RIH with Baker whipstock assy. 46k# up, 20k# do wt. at 12600'. Latch and shear off from packer. 61 k# up weight. 15k# to shear. Top of whipstock at 12691.' 01:30 - 03:30 2.00 STWHIP WEXIT POOH. Left previous run's Red flag at 12600' EOP. 03:30 - 04:30 1.00 STWHIP WEXIT Inspect Whipstock BHA. Install replacement shear pin. 04:30 - 05:00 0.50 STWHIP WEXIT Hold EMS and 8 Golden Safety Rule training in dog house. 05:00 - 07:30 2.50 STWHIP WEXIT RIH with whipstock assy. 07:30 - 08:00 0.50 STWHIP WEXIT Set down on packer at 12,705 ft. Set down 12K, pick up 3 times, pulled off. Set down full wt on packer. Pick up. Latched OK. Pull up 3 times. Sheared off with 14K overpull [62K]. Tray appears to be set OK. 08:00 - 10:00 2.00 STWHIP WEXIT POOH. 10:00 - 10:15 0.25 STWHIP WEXIT L/O Whipstock running BHA. Whipstock set on packer OK. M/U Baker starter mill and straight motor BHA. 10:15 - 12:30 2.25 STWHIP WEXIT RIH with BHA V. Tagged top of whipstock at 12691 ft, corrected to 12696' 12:30 - 14:10 1.67 STWHIP WEXIT Milling window in 4.5" liner. 2.6 bpm, 2500 psi, Up Wt = 43K. Milled 3.70" window from 12,696 - 12,698 ft. 14:10 - 16:00 1.83 STWHIP WEXIT POOH 16:00 - 16:15 0.25 STWHIP WEXIT Change out mill and add string reamer. 3.80" mill and 3.80" reamer. 16:15 - 18:45 2.50 STWHIP WEXIT RIH with BHA #8, 3.80" six bladed mill, 3.80" string reamer and straight motor 18:45 - 21:30 2.75 STWHIP WEXIT Tag at 12697'. 2.5/2400. Begin milling by weight/time. Into open hole at 12703'. 21:30 - 23:00 1.50 STWHIP WEXIT Mill open hole to 12713'. Back ream twice. Tag TD dry. Window smooth. 23:00 - 23:59 0.98 STWHIP WEXIT POOH for build assy. 4/9/2001 00:00 - 01:15 1.25 STWHIP WEXIT COntinue to POOH with window mill. Hole took 4 bbls mud during trip out. 01:15 - 02:00 0.75 DRILL PROD1 LD milling BHA. 02:00 - 03:30 1.50 DRILL PROD1 CHange packoffs. Cut coil. Install and test coil connector. 03:30 - 05:00 1.50 DRILL PROD1 MU open hole build assy with resistivity sub. (1.4 deg & DS 49) Printed: 5/1/2001 10:30:28 AM BP EXPLORATION Operations Summary Report Page 3 of 9 1 Legal Well Name: MPF-73 Common Well Name: MPF-73A Spud Date: 2/15/1997 Event Name: REENTER+COMPLETE Start: 4/5/2001 End: Contractor Name: NORDIC CALISTA Rig Release: 4/19/2001 Group: COIL Rig Name: NORDIC 1 Rig Number: Date I From - To I Hours I Task I Code I Sub Phase I Description of Operations 4/9/2001 05:00 - 06:00 1.00 DRILL PROD1 RIH with drilling assy. Shallow test MWD. Continue in hole. 06:00 - 07:00 1.00 DRILL PROD1 RIH. Test new orientor in hole. Did not orient. 07:00 - 07:45 0.75 DRILL BHA PROD1 POOH to change from 16/32 to 13/32 equalizer port. 07:45 - 08:30 0.75 DRILL BHA PROW C/O equalizer ports. M/U 13/32" port. 08:30 - 09:15 0.75 DRILL BHA PROD1 RIH with drilling BHA. Test orientor at 2100 ft. No luck. POOH. 09:15 - 10:00 0.75 DRILL BHA PROD1 Change out orientor. Use 13/32" port. RIH to 2100 ft and test orientor. OK. 10:00 - 12:00 2.00 DRILL PROW RIH with drilling BHA. 12:00 - 12:30 0.50 DRILL PROW Log tie-in with GR. Added 5 ft CTD. 12:30 - 13:15 0.75 DRILL PROW Attempt to exit liner with 10L TF, 1 OR TF, 30R, 60R, 80R, 11 OR, all the way around. No luck. Set dwn wt at 12,694 ft. 5-10K overpull each pick up. Spud at 20R. No change. Same pick up. Motor stalls on bottom. 13:15 - 16:00 2.75 DRILL PROD1 POOH for mill and string reamer. C/O bit for mill and string reamer. 16:00 - 18:00 2.00 DRILL PROD1 RIH with BHA #10, 1.4 deg. motor, 3.80" string reamer, 3.,80" diamond window mill. Corrected CTD at 12,000' EOP. [-2 ft CTD]. 18:00 - 21:00 3.00 DRILL PROD1 Cont. RIH. TF = 3R, First motor work at 12,691 ft. Ream window. 2.5 bpm, 3250 psi, Steady reaming about 10 FPH with first pass at highside TF. Mill to 12715'. Back ream w/ no motor work. 21:00 - 22:15 1.25 DRILL PROD1 Orient to 90R, 167L, 90L. Ream down & up through window. No motor work. RIH dry & tag TD. 22:15 - 23:59 1.73 DRILL PROD1 POOH for drilling assy. 4/10/2001 00:00 - 01:30 1.50 DRILL PROW Change out window mill for DS49 bit. Check mwd batteries. Check chains. 01:30 - 04:00 2.50 DRILL PROD1 RIH with build assembly., 04:00 - 06:00 2.00 DRILL PROW Window smooth. Orient to HS.-Tag TD at 12715'. Drill ahead. 46k# up, 20k# do wt. 2.3/3200/80 fph. Pump up survey. 06:00 - 07:00 1.00 DRILL PROD1 Drilling build section, TF = 30L, 2.5 bpm, 3100 psi, 45 fph. Drill to 12,850 ft. 07:00 - 07:20 0.33 DRILL PROW Orient around to reduce build. Short trip to window. 07:20 - 09:00 1.67 DRILL PROD1 Drilling, TF = 74L, 2.5 bpm, 3100 psi, 40 fph, Full returns. Drilled to 12,925 ft. 09:00 - 09:20 0.33 DRILL PROD1 Drilling, TF = 38L, Drilled to 12,946 ft. Projected Incl. at bit = 92.0 deg. Getting 16 deg. DLS consistantly. Pull for less degree motor. 09:20 - 12:00 2.67 DRILL PROD1 POOH for motor. 12:00 - 13:30 1.50 DRILL PROD1 C/O motor to 1.03 deg motor. Down load resistivity data. 13:30 - 16:15 2.75 DRILL PROW RIH to 12640 ft. 16:15 - 17:00 0.75 DRILL PROD1 Log tie-in with GR. Subtract 4 ft CTD. 17:00 - 17:10 0.17 DRILL PROW RIH. Tag TD at 12,946 ft BKB. 17:10 - 18:20 1.17 DRILL PROD1 Drilling, TF = 80R, 2.5 bpm, 3100 psi, Drilled to 13,002 ft. 18:20 - 18:45 0.42 DRILL PROW Drilling, TF = 80R, 2.5 bpm, 3100 psi. 18:45 - 19:40 0.92 DRILL PROW 13025', Drilling, 2.5 bpm in, 2.5 bpm out. 3500 psi, Drilling at 84R TF. 20klbs while RIH. 19:40 - 20:00 0.33 DRILL PROD1 13100', wiper trip to window. PU clean at 44klbs. PUH to shoe with no problems. RIH to resume drilling. 20:00 - 20:35 0.58 DRILL PROD1 13100', Drilling 2.5 bpm in, 2.5 bpm out. 3400 psi, drilling at 90 R TF, No losses in last hour. Pit volume = 266 bbls. 20:35 - 21:10 0.58 DRILL PROD1 13250', wiper trip to shoe. Clean pick up at 44 klbs. No problems on wiper trip. 21:10 - 22:50 1.67 DRILL PROW 13250', return to drilling. 22:50 - 23:40 0.83 DRILL DS PROD1 13330', Pickup to orient. Heavy pickup. Can't pull up, can work back in the hole ok. Work pipe, pulling max. Can't get free. RIH to neutral Printed: 5/1/2001 10:30:28 AM BP EXPLORATION Operations Summary Report Legal Well Name: MPF-73 Common Well Name: MPF-73A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From -To Hours Task Sub I Code Phase 4/10/2001 22:50 - 23:40 0.83 DRILL DS PROD1 23:40 - 00:00 0.33 DRILL PROD1 4/11/2001 00:00 - 00:20 0.33 DRILL PROD1 00:20 - 02:00 1.67 DRILL PROD1 02:00 - 02:45 0.75 DRILL PROD1 02:45 - 04:55 2.17 DRILL PROW 04:55 - 06:00 1.08 DRILL PROD1 06:00 - 06:30 0.50 DRILL CIRC PROD1 06:30 - 07:00 0.50 DRILL CIRC PROD1 07:00 - 11:00 4.00 DRILL CIRC PROD1 11:00 - 11:30 0.50 DRILL CIRC PROD1 11:30 - 12:40 1.17 DRILL PROD1 12:40 - 13:15 0.58 DRILL CIRC PROD1 13:15 - 14:30 1.25 DRILL CIRC PROD1 14:30 - 15:10 0.67 DRILL CIRC PROD1 15:10 - 19:00 3.83 DRILL CIRC PROD1 19:00 - 20:20 1.33 DRILL CIRC PROD1 20:20 - 21:00 0.67 DRILL CIRC PROD1 21:00 - 21:45 0.75 DRILL CIRC PROD1 21:45 - 00:00 2.25 DRILL CIRC PROW 4/12/2001 00:00 - 00:30 0.50 DRILL CIRC PROD1 00:30 - 02:15 1.75 DRILL CIRC PROD1 02:15 - 04:55 2.67 DRILL CIRC PROD1 04:55 - 05:00 0.08 DRILL CIRC PROD1 05:00 - 05:45 0.75 DRILL CIRC PROD1 Page 4 of 9 1 Spud Date: 2/15/1997 Start: 4/5/2001 End: Rig Release: 4/19/2001 Group: COIL Rig Number: Description of Operations weight, getting 1 for 1 returns. Wait 15 minutes while pumping 0.7 bpm. Pull 85klbs. Still stuck. Slack off to neutral weight. SI pumps. Wait 15 minutes. Pull 80klbs, popped free. Kick pumps on. Wiper trip to shoe. Up weight 47klbs with pumps on. RIH smooth with 17klbs down weight. Tag bottom pick up smooth at 49klbs, pumps on. Orient around. 13330', Resume drilling 2.5 bpm in, 2.5 bpm out. 3600 psi, 75 R TF, Lost 5 bbls mud in last 1 1/2 hours. 13480', wiper trip to shoe. Clean pickup off bottom. Pulling at 47klbs. RIH clean, no drag. 13480', Resume drilling. 2.5/2.6 out. 3860 psi, 72R TF. 100 fph, ROP. 13630', wiper trip to shoe. Clean pickup, 48klbs. Smooth while RIH. 13636', Drilling break. Lost returns. Pumping 2.5 bpm, getting 0.2 bpm back. Drop pump rate to 1 bpm, lost all returns. PUH at 30 fpm, pumping at 2.5, getting 0.4 bpm back. Continue POH. Pull above window to 12,200 ft. Circ at min. rate while waiting for FloPro and Formaset pill. Wait for FloPro to be delivered. RIH to 13,400 ft. Orient TF. Drilling, TF = 0 deg. 2.6 BPM / 1.7 BPM returns, losses have reduced. TF = 1 L, 50 FPH. Drilled to 13,685 ft. Prepare to pump Form -A -Set pill. Pump 20 bbls Form -A -Set. 2.5 / 1.7 bpm. Stop 20 min. while adding XL to 27 more bbls of Form -A -Set. Pump 47 bbls to bit. 1.6 BPM, 4100 psi. Lay in pill at 1.0 bpm. Full returns at 1 BPM. Pull at 70 fpm. lay in 14 bbls. Squeeze in 38 bbls Form -A -Set to fault. Sqz 26 bbls at 1.5 bpm, 470 psi WHP. Sqz 12 bbls at 1.0 bpm, 450 psi WHP. Stop pump with 10 bbls Form -A -Set in open hole. Bleed off WHP slowly to zero. POOH to 12300' Wait 4 hrs for Form -A -Set to set up. Log tie in pass. Getting 1 for 1 returns at 2.3 bpm. Make +12' correction. RIH, did not see any loss of weight or motor work at expected gel top. RIH to TD. Started loosing returns at 13400'. Got worse as we approached TD. At TD, 2.2 in, 0.7 out. Pick up hole 200', call town monitor losses. Waiting at 13450', pumping 1.5, returns 0.7 bpm. POOH to lay down drilling BHA, pick up cement nozzle. Continue to POH with drilling BHA. Lay down BHA #12, pick up cementing nozzle, 2 joints of 2 3/8 PA6, NRJ, disc. (BHA #13) RIH with BHA #13, to lay in cement data. Hold PJSM with rig crew, Dowell CT crew, Dowell Pumpers while RIH. Tag bottom. Pumping 0.8, getting back 0.2. Can not get completely to bottom. Tag up at 13612'. Batch up cementers, PT hardlines to 4000 psi, ok. Online with cement slurry. Pump 5 bbls neat bentonite cement, 20 bbls of bentonite cement plus 16 #/bbl aggregate, 10 bbls bentonite cement + agg + 1/4 #/sx celaflake, 1 bbl of neat bentonite cement. Swap to rig pumps. Chase cement slurries with flopro mud. Displace at 1 bpm, getting back 0.5 bpm. Speed up rate to 1.7, getting back 1.2. Total of 36 bbls CMT Pumped. Printed: 5/1/2001 10:30:28 AM BP EXPLORATION Operations Summary Report Legal Well Name: MPF-73 Common Well Name: MPF-73A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From -To Hours Task Sub I Code Phase 4/12/2001 05:45 - 06:30 0.75 DRILL CIRC PROD1 06:30 - 08:00 1 1.501 DRILL I CIRC I PROD1 08:00 - 09:00 1 1.001 DRILL I CIRC 1 PROD1 09:00 - 12:30 1 3.501 DRILL I CIRC 1 PROD1 12:30 - 22:30 1 10.001 DRILL I I PROD1 22:30 - 00:00 1 1.501 DRILL I COIL I PROD1 4/13/2001 00:00 - 03:45 3.75 DRILL COIL PROD1 03:45 - 05:30 1.75 DRILL CIRC PROD1 05:30 - 07:50 2.33 DRILL CIRC PROD1 07:50 - 08:15 0.42 DRILL CIRC PROW 08:15 - 08:30 0.25 DRILL CIRC PROD1 08:30 - 10:30 2.00 DRILL CIRC PROW 10:30 - 11:00 0.50 DRILL CIRC PROW 11:00 - 12:00 1.00 DRILL CIRC PROD1 12:00 - 14:00 2.00 DRILL CIRC PROW 14:00 - 15:30 1.50 DRILL CIRC PROW 15:30 - 16:00 0.50 DRILL PROD1 16:00 - 16:30 0.50 DRILL PROW 16:30 - 18:45 2.25 DRILL BHA PROW 18:45 - 19:10 0.42 DRILL BHA PROD1 19:10 - 21:55 2.75 DRILL BHA PROD1 21:55 - 22:00 0.08 DRILL BHA PROD1 22:00 - 00:00 1 2.001 DRILL I I PROW 4/14/2001 00:00 - 02:00 2.00 DRILL PROW 02:00 - 02:10 0.17 DRILL PROW 02:10 - 03:00 0.83 DRILL PROW 03:00 - 04:00 1.00 DRILL PROW 04:00 - 05:00 1.00 DRILL PROD1 05:00 - 06:00 1.00 DRILL PROW 06:00 - 07:30 1.50 DRILL PROW 07:30 - 08:30 1.00 DRILL PROD1 08:30 - 09:00 0.50 DRILL PROD1 09:00 - 09:30 0.50 DRILL PROD1 Page 5 of 9 1 Spud Date: 2/15/1997 Start: 4/5/2001 End: Rig Release: 4/19/2001 Group: COIL Rig Number: Description of Operations Swap to rig pumps. Chase cement slurries with flopro. Displace at 1 bpm, getting back 0.5 bpm. Speed up rate to 1.7 bpm, getting back 1.0 bpm. Displace cement out of nozzle at 1.3 bpm, getting back 0.8 bpm laying in at 50 fpm. Loosing cement to formation while laying it in. POOH to Safety. Park at 10,800 ft. Squeezed total of 26 bbls Cement to fault. Held squeeze pressure of 1200 psi. for 1 hour. RIH with nozzle and cleanout cement to 12,800 ft. No cement indications seen while doing cleanout. RIH at 30 FPM, 2.5 bpm. Full returns. POOH at 20 fpm to 12400 ft. POOH. 3.0 bpm, Discard cement contaminated FloPro. L/O Cmtg BHA. Perform weekly pressure / function test of ROPE. Send test report to AOGCC. Begin work on Dowell Schlumberger injector. Skates and chains are damaged and can not safely be used for another trip in the hole. Continue repair operations on injector. Injector repairs completed. Begin making up BHA. RIH with BHA #14. Resistivity tool, 1.0 deg motor and new DS49, 3.75" bit. Log tie-in with GR. Added 15 ft to CTD. RIH and tagged cement at 12,916 ft. Ream cement at 150 FPH. Keep correct TF to follow old hole. 2.6 bpm, 3300 psi, several stalls, possibly due to aggregate in cement plug. Reamed to 13110 ft, still in original hole. Treating mud for cement contamination. Ream cement at 180 FPH to 13200 ft. Wiper trip to window. OK. RIH. Orient TF. Ream cement at 230 FPH with 90R TF. Still in original hole. Reamed past fault at 13,636 ft with full returns. Drilled out cement to last TD of 13,696 ft. Still have full returns. Wiper trip to window. Tied -in with GR. Added 4 ft CTD. RIH to TD. Drilling, TF = 46R, 2.6 bpm, 3200 psi, 55 FPH, Drilled to 13706 ft. Attempt to Orient TF. Orientor is locked, no response. POOH for orientor. Tag up at surface with BHA #14. Change out orienter. RIH with BHA #15. Tag bottom at 13716', should be 13706' based on last tie in and tag. Make -8' correction. And take 3 clicks on orienter. Return to drilling. 2.5 in, 2.5 out. 1 for 1 returns. 3700 psi drilling. 80 fph, 30 deg L TF. 13794', wiper trip to shoe. Orienting 13794', on bottom drilling. 2.5 in, 2.5 out. 3650 psi, TF 27L, ROP=98 fph. Started mud swap at 01:40. 13834', 03:00 update. Drilling 2.6 in/2.6 out. 3680 psi, TF 30L, 90 fph. 13897', 04:00 update. Drilling 2.5 in/2.5 out, 3650 psi, TF 65L, 80 fph. 13950', wiper trip to the shoe. 13950', resume drilling. 2.5 in/2.5 out. 3680 psi, TF 71 L, ROP 70 fpm. Drilled to 14,100 ft. Wiper trip to shoe. Hole in good condition. Log tie-in with GR. Add 8 ft to CTD. RIH to TD. Hole in good condition. Printed: 5/1/2001 10:30:28 AM BP EXPLORATION Operations Summary Report Legal Well Name: MPF-73 Common Well Name: MPF-73A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date Sub I From - To I Hours I Task I Code I Phase 4/14/2001 09:30 - 11:20 1.83 DRILL PROD1 11:20 - 13:00 1.67 DRILL PROD1 13:00 - 13:20 0.33 DRILL PROD1 13:20 - 14:30 1.17 DRILL PROD1 14:30 - 15:00 0.50 DRILL PROD1 15:00 - 15:15 0.25 DRILL PROD1 15:15 - 17:00 1.75 DRILL PROD1 17:00 - 19:15 2.25 DRILL PROD1 19:15 - 21:15 2.00 DRILL PROD1 21:15 - 21:45 0.50 DRILL PROD1 21:45 - 22:20 0.58 DRILL PROD1 22:20 - 22:35 0.25 DRILL PROD1 22:35 - 00:00 1.42 DRILL PROW 4/15/2001 00:00 - 02:20 2.33 DRILL PROD1 02:20 - 04:00 1.67 DRILL PROD1 04:00 - 07:20 3.33 DRILL PROD1 07:20 - 09:00 1.67 DRILL PROD1 09:00 - 10:30 1.50 DRILL PROD1 10:30 - 11:00 0.50 DRILL PROD1 11:00 - 11:30 0.50 DRILL PROD1 11:30 - 12:00 0.50 DRILL PROD1 12:00 - 15:00 3.00 DRILL PROD1 15:00 - 15:30 0.50 DRILL PROD1 15:30 - 15:35 0.08 DRILL PROD1 15:35 - 17:30 1.92 DRILL PROD1 17:30 - 18:10 0.67 DRILL PROD1 18:10 - 18:20 0.17 DRILL PROD1 18:20 - 18:50 0.50 DRILL PROD1 18:50 - 08:50 14.00 DRILL PROW 08:50 - 10:30 1.67 DRILL PROD1 10:30 - 00:00 13.50 DRILL PROD1 4/16/2001 00:00 - 00:30 0.50 DRILL PROD1 00:30 - 01:30 1.00 DRILL PROD1 Page 6of91 Spud Date: 2/15/1997 Start: 4/5/2001 End: Rig Release: 4/19/2001 Group: COIL Rig Number: Description of Operations Drilling, TF = 60L, 2.5in / 2.5 out. 3500 psi, Incl = 93 deg. Drilled to 14250' Wiper trip to window. Motor work at 13,800 ft. RIH to TD. Orient TF to lowside. Attempt to drill, low motor work, very little progress. No change in pressure. 14256', POOH to inspect BHA. SAFETY Fire drill in mud hopper room. POOH. Fill well from backside. Check BHA. Recovered 100% of BHA. Bit was balled with clay. Down load Sperry Resistivity data. Adjust motor to 1.6 deg. M/U M09 bit for undercut open hole sidetrack. RIH with BHA #16 to sidetrack well. Log tie in pass from 12645'. Logging down. Make plus 2' correction. Continue RIH to begin sidetrack. Orient to 168R TF. Begin troghing. 14075'-14045'. Make 2 passes up at 0.5 fpm. Run back in to 14075' slick. Back ream up to 14040' at 0.5 fpm. RIH to 14074', time drill at 0.1'/ minute. Time drill down to 14080'. Attempt to drill at 4 fpm. No motor work. Run in to 14090' without seeing anything. Trough from 14090' to 14080'. Continue to hold the tool face at 165R. Make 5 passes at .5 fpm. 14089.5, begin time drilling 0.173 minutes. TF 162R. Drill to 14096 ft. Seeing motor work every 0.2 ft. Time drilling 0.1 ft / 2 min. TF = 160R. Drill to 14099 ft. Seeing motor work. Time drilling 0.1 ft / 1 min. TF = 160R, Drill to 14106 ft. Seeing motor work. Time drilling 0.2 ft / 1 min. TF = 160R, Drill to 14110 ft. Seeing motor work. Start drilling. TF = 160R, 20 FPH, 2.6 in / 2.6 out, 3500 psi. Drill to 14120 ft. 1.5 deg Incl. difference with last hole Back ream to 14070 ft. Ream down to 14120 ft. Tag TD at 14,120 ft. POOH for 1.0 deg motor and DS49 bit. Lay out motor, M/U 11.0 deg motor and DS 49 re -run bit. SAFETY, Kick while trip drill. Stab open TIW valve, close annular, OK. RIH with BHA #17, 1.0 deg motor and Bit #5RR, DS49. Stop at flag, subtract 5.5 ft at flag. RIH. 2.0 bpm, 40 fpm, Orient TF before Running thru sidetrack. Attempt to run thru sidetrack at TF of 11 OR. Tag up at 14080', lost weight, saw motor work. Pick up get 2 more clicks. RIH at a TF of 135 R, ran in to sidetrack TD at 14120', ok. Tagged up at 14111', set depth to 14120'. Resume drilling. Orient to 65L. Resume drilling. 14300', Short trip to shoe. Clean pickup off bottom. Pulling off bottom at 42klbs. Ran in slick at 173R. Ran through sidetrack ok. 14300', Return to drilling 2.5/2.5, no losses. 3500 psi ctp, TF 70L. Depth at midnight 14402'. 14414', Drilling ahead. 2.5 in/2.5 out, 3570 psi ctp, TF 70L. 14452', Wiper trip to shoe. Slight overpull and motor work pulling back through sidetrack. TF was 29L. Printed: 5/1/2001 10:30:28 AM BP EXPLORATION Operations Summary Report Page 7 of 9 1 Legal Well Name: MPF-73 Common Well Name: MPF-73A Spud Date: 2/15/1997 Event Name: REENTER+COMPLETE Start: 4/5/2001 End: Contractor Name: NORDIC CALISTA Rig Release: 4/19/2001 Group: COIL Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Sub Code Phase 4/16/2001 01:30 - 01:45 0.25 DRILL PROD1 01:45 - 02:45 1.00 DRILL PROD1 02:45 - 03:00 0.25 DRILL PROD1 03:00 - 03:30 0.50 DRILL PROD1 03:30 - 03:45 0.25 DRILL PROD1 03:45 - 05:40 1.92 DRILL PROD1 05:40 - 07:30 1.83 DRILL PROW 07:30 - 08:45 1.25 DRILL PROD1 08:45 - 10:00 1.25 DRILL PROD1 10:00 - 10:30 0.50 DRILL PROD1 10:30 - 11:30 1.00 DRILL PROD1 11:30 - 13:00 1.50 DRILL PROD1 13:00 - 15:00 2.00 DRILL PROD1 15:00 - 17:00 2.00 DRILL PROD1 17:00 - 19:45 2.75 CASE PROD1 19:45 - 20:15 0.50 CASE PROW 20:15 - 23:15 3.00 CASE PROD1 23:15 - 23:45 0.50 CASE PROD1 23:45 - 00:00 0.25 CASE PROD1 4/17/2001 00:00 - 01:25 1.42 CASE PROD1 01:25 - 02:00 0.58 CASE PROD1 02:00 - 02:40 0.67 CASE PROD1 02:40 - 05:30 2.83 CASE PROW 05:30 - 05:50 0.33 CASE PROD1 05:50 - 06:20 0.50 CASE PROD1 06:20 - 06:30 0.17 CASE PROD1 06:30 - 07:20 1 0.831 CASE I I PROD1 Description of Operations Log tie in at 12645', Make +13' correction, RIH. RTIH, orient 175R, no problems at sidetrack while RIH. 14461', return to drilling. 14472', pick up to orient, stuck at 14452'. Appear to be differentially stuck. Work pipe. Pulled as much at 85klbs. Can't get free. Attempt relax method. SI pumps at 03:10. Waited 15 minutes, pulled free at 65klbs. Short wiper trip up to 14120' and back to bottom. After pulling free, pulled smooth at 44klbs up. No problems running back in the hole. 14472', return to drilling. TF = 90 - 110 deg R. 14607', Wiper trip to shoe. Clean pickup off bottom. Clean hole. RIH. Drilling, TF = 176R, Trying to drop Incl. from 95 deg. 2.6 in / 2.6 out. 3500#. No proress. Drilling clay. Total depth called by Anc. Geology. TD = 14,607 ft BKB. Short trip to window. Up wt off bottom = 42K, Dwn wt. = 12K. Log down tie-in with GR. Add 10 ft to CTD. RIH to TD. Tag Final corrected TD at 14,614 ft BKB. Log mad pass up with Sperry Resistivity / GR at 20 FPM to window. POOH. Down load Resistivity data. Check calibration on resistivity at surface, tested within specs. L/O BHA. Finished Loading liner in pipe shed. Drift and tally liner. Install STL turbos. Load Baker liner equipment in pipe shed. PJSM covering liner running, safety deployment sleeve, lifting, proper BHA spaceout, etc. Running 2-7/8" liner for Banzai completion as per proceedure. Pull test CTC to 35klbs, PT to 3500 psi, passed ok. Make up deployment tool, and MHA to coil. Run in the hole with liner BHA. Continue RIH with liner BHA. Weight check at 4 1/2" shoe is 49klbs up 22klbs down wt. Checked EOP flag at 10300'. We were 7' shallow. Continue RIH. Circulating at 0.6 bpm. RIH ok. Nice and clean in Open hole. Ran through side track area with no problems. Tagged up at bottom at 14605', PU at 52klbs. Set down again at same depth. Set depth to 14615' based on last tie in tag. Drop 5/8" ball to release CTLRT. Chase with mud. Good circulation, 100% returns. Drop rate to 0.5 bpm with 42 bbls away. (Coil volume=59.6 bbls with a dart). Land ball at 49 bbls away. Got good indication of shear. PU at 36klbs. Run back down. Swap to water, circulating mud OOH. Taking mud to clean vacs for shipment back to MI. Displacing with 2% KCL water. Hold PJSM with cementers and rig hands. Continue to circulate KCL while waiting for cementers to batch up. Cement up to weight at 06:20. Pump 2 bbls of water, PT cementers hardlines to 4000 psi, ok. Pump 11.5 BBL, 15.8 PPG, G Cement. Insert Dart. Displace cement at 3.1 bpm, full returns, 1900 psi. Slow pump at 55 bbls to 1.0 bpm. Dart on seat at 59.5 bbls. Sheared LWP at 3400 psi, displace CMT around at 3.1 in / 3.1 out. 2600 psi, Slow to 1 bpm at 66.5 bbls, Bumped LWP at 67.6 bbls. Held 1520 psi, Tested floats - OK. Sting out top of liner sleeve. 33K up wt. Printed: 5/1/2001 10:30:28 AM BP EXPLORATION Page 8 of 9 Operations Summary Report Legal Well Name: MPF-73 Common Well Name: MPF-73A Spud Date: 2/15/1997 Event Name: REENTER+COMPLETE Start: 4/5/2001 End: Contractor Name: NORDIC CALISTA Rig Release: 4/19/2001 Group: COIL Rig Name: NORDIC 1 Rig Number: Sub Date I From - To I Hours I Task Code Phase I Description of Operations 4/17/2001 06:30 - 07:20 0.83 CASE 07:20 - 08:10 0.83 CASE 08:10 - 10:30 2.33 CASE 10:30 - 11:00 0.50 CASE 11:00 - 12:30 1.50 CASE 12:30 - 16:00 3.50 CASE 16:00 - 17:00 1.00 CASE 17:00 - 20:45 3.75 CLEAN 20:45 - 23:00 2.25 CLEAN 23:00 - 23:20 0.33 CLEAN 23:20 - 00:00 0.67 CLEAN 4/18/2001 00:00 - 01:30 1.50 CLEAN 01:30 - 03:30 2.00 CLEAN 03:30 - 05:40 2.17 CLEAN 05:40 - 05:50 0.17 CLEAN 05:50 - 07:30 1.67 CLEAN 07:30 - 07:45 0.25 CLEAN 07:45 - 08:30 0.75 CLEAN 08:30 - 09:15 09:15 - 09:45 09:45 - 12:45 12:45 - 13:15 13:15 - 15:00 15:00 - 15:30 15:30 - 17:30 17:30 - 18:15 18:15 - 18:45 18:45 - 20:30 20:30 - 20:45 0.75 CLEAN 0.50 CLEAN 3.00 CLEAN 0.50 CLEAN 1.75 CLEAN 0.50 PERF 2.00 PERF 0.75 PERF 0.50 PERF 1.75 PERF 0.25 PERF 20:45 - 21:10 0.42 PERF 21:10 - 23:30 2.33 PERF 23:30 - 00:00 0.50 PERF 4/19/2001 00:00 - 00:15 0.25 PERF 00:15 - 03:15 3.00 PERF 03:15 - 04:50 1.58 REST PROW PROD1 PROD1 PROW PROD1 PROD1 PROD1 COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP Circulate at top of liner. 3.5 bpm / 3.5 bpm, 2600 psi. POOH while chasing cement to surface. 3.5 bpm. 2600 psi. Lay out Baker tools. M/U 2.30" diamond mill, 2.13" motor, disconn, and circ sub. RIH with mill / motor on 25 stds of 1.25" CSH workstring. M/U DS MHA. BHA #18. Total length = 1579.4 ft. RIH with BHA #18 on CT. No trouble entering top of liner at 12,413 ft BKB. Tag PBTD at 13,801' CTD. Actual PBTD = 13,810 ft. Correct CTD + 9 ft. CMT sample in DS UCA = 1400 psi at 14:30 hrs. Pressure test liner lap to 2200 psi, for 30 min. Chart test. No pressure loss. Mill float equipment at 13810'. Circulate 10 bbls flovis sweep at 13818'. Mill thru float equipment and RIH to 13863' (add T to CTD after baffle sub milled out) 1.7/2240 PUH backreaming milled area, clean, 46K. Flag CT @ 12000' EOP POOH to PU workstring Fin POOH PU 22 CSH singles, rehead leaking CTC. PT 35K, 3500 psi RIH w/CT RIH clean thru milled float equipment. Start 56 bbl hi vis sweep. Add 16.0' at flag. RIH to tagged PBD at 14612.8' where motor stalled. On depth with tally Circ mud to mill while washing back thru slotted liner. Displace mud with KCI. PJSM to review risk assessment for pumping bleach. Phz 1 Pump 15 bbls bleach into coil. Shut down. Back load truck with 30 bbls kcl water. Displace downhole. Lay in bleach 1:1 to TOL. Paint EOP flag at 12000'. Drop 5/8" ball to open circ sub at 12300'. Chase ball with 50 bbl flo-vis sweep. 3600 psi at 1.9 BPM before, 2.5 bpm@ 4000 psi after opening circ sub. Circulate OOH at 80%. At CSH, Phz 2 Continue to circulate at surface until clean kcl water returns. Stand back CSH work string. LD motor & mill assy. Hold PJSM regarding running perf guns. MU 2" SWS perf guns. 814', 2" HSD PJ 2006 4 spf charges MU 7 stands CSH. Stab on inj Crew change/safety mtg re: Phz 2 driving RIH w/ pert guns (1259.73' OA) Corr to flag at 12000' EOP (add 21.1'). RIH to perf depth 46.4K, 18.5k. Load 5/8" steel ball Displace ball to firing head w/ 2% KCI 2.7/2380, 0.6/180. Fired at 2900 psi. Perforated 12720-13190' and 13220-13500' No fluid loss noted. POOH, filling from BS 46.5K Standback CSH Safety mtg re: pert guns LD perf guns -all shots fired. Load out guns. Fill hole w/ 4 bbls Jet stack. RIH w/ jet nozzle and freeze protect from 2000' w/ 70 bbls Printed: 5/1/2001 10:30:28 AM BP EXPLORATION Page 9 of 9 Operations Summary Report Legal Well Name: MPF-73 Common Well Name: MPF-73A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task Sub Phase Code 4/19/2001 03:15 - 04:50 1.58 REST COMP 04:50 - 05:00 0.17 REST COMP 05:00 - 08:00 3.00 RIGID OTHR COMP 08:00 - 09:00 1.00 RIGID COMP 09:00 - 10:00 1.00 RIGID COMP 10:00 - 14:00 4.00 RIGID COMP 14:00 - 17:00 3.00 RIGID COMP 17:00 - 18:30 1.50 RIGID COMP 18:30 - 00:00 5.50 RIGID COMP Spud Date: 2/15/1997 Start: 4/5/2001 End: Rig Release: 4/19/2001 Group: COIL Rig Number: Description of Operations 60/40 McOH. Phz 1 /2 SI three tree valves (25 turns ea). Well is secure WO N2 Attempt to set 7" BPV. Would not fit through Nordic 7-1/16" stack. Blow down coil with N2. Secure well. Begin ND. Rig released. Begin Standby due to MPU road construction Move to MPU L Pad for crew change Head to PBU S-08a with stops to let traffic by along the way Printed: 5/1/2001 10:30:28 AM BP EXPLORATION Operations Summary Report Legal Well Name: MPF-73 Common Well Name: MPF-73A Event Name: WORKOVER Contractor Name: NABORS Rig Name: NABORS 4ES Date Sub I From - To I Hours I Task I Code I Phase 4/20/2001 00:00 - 06:00 6.00 MOB 06:00 - 08:30 2.50 MOB 08:30 - 10:00 1.50 MOB 10:00 - 10:30 0.50 WHSUR 10:30 - 14:00 3.50 BOPS 14:00 - 18:00 4.00 PULL 18:00 - 21:00 3.00 PULL 21:00 - 00:00 3.00 BOPS 4/21/2001 100:00 - 00:30 1 0.501 BOPS 4/22/2001 00:30 - 02:30 02:30 - 04:30 04:30 - 05:00 05:00 - 06:00 06:00 - 07:30 07:30 - 10:30 10:30 - 14:30 14:30 - 15:30 15:30 - 23:30 23:30 - 00:00 00:00 - 01:30 01:30 - 03:00 03:00 - 04:00 04:00 - 05:30 2.001 KILL 2.00 PULL 0.50 PULL 1.00 PULL 1.50 RUNC 3.00 RUNC 4.00 RUNCO 1.00 RUNCO 8.00 RUNCO 0.50 RUNCO 1.50 RUNCO 1.50 RUNCO 1.00 RUNCO 1.50 RUNCO PRE PRE PRE COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP 05:30 - 06:00 0.50 WHSUR COMP 06:00 - 08:00 2.00 BOPSU COMP 08:00 - 09:00 1.00 WHSUR COMP 09:00 - 10:00 1.00 WHSUR COMP 10:00 - 10:30 0.50 DHEQP COMP 10:30 - 12:30 2.00 DHEQP COMP 12:30 - 13:30 1.00 RUNCO COMP 13:30 - 15:00 1.50 RUNCO COMP Page 1 of 1 Spud Date: 2/15/1997 Start: 4/19/2001 End: 4/22/2001 Rig Release: 4/22/2001 Group: RIG Rig Number: Description of Operations MOVE FROM MPE-09 TO MPF-73 LOCATION. SPOT & BERM RIG. RAISE & SCOPE DERRICK. RIG UP EQUIP. BLEED OFF WELLHEAD PRESSURE. N/D ADAPTER FLANGE ASSY. N/U BOPE. LOAD PIPE SHED W/ 4 1/2" TBG & 3 1/2" DP. THAW OUT FROZEN CHOKE LINE TO GAS BUSTER. INSTALL VARIABLE RAMS. PRESSURE TEST BOPE. LP 250 PSI, HP 3500 PSI. ANN 2500 PSI. WITNESSING WAIVED BY CHUCK SHEVE W/ AOGC. FINISH FULL BOP TEST. LP 250 PSI, HP 3500 PSI. ANNULAR LP 250 PSI, HP 2500 PSI. SET & BERM TIGER TANK. M/U RETRIEVING TOOL & LOAD PIPE SHED W/ 3 1/2" DP. RIH TO 1040'. LATCH ON TO RBP, EQUALIZE & MONITOR WELL. POOH & L/D 3 1/2" DP. L/D RBP. CLEAR FLOOR. R/U TO RUN 3 1/2" COMPLETION. M/U TAILPIPE ASSY, PKR & SPLICE CONTROL LINE F/ MULTISENSOR. RIH W/ 3 1/2" COMPLETION STRING. CIRCULATE OUT METHANOL FREEZE PROTECTION FLUID. CON'T RIH W/ 3 1/2" COMPLETION STRING. M/U CONTROL LINE SPLICE F/ SENSOR. FINISH MAKING CONTROL LINE SPLICE F/ SENSOR. CON'T RIH W/ 3 1/2" COMPLETION. SPACE OUT WLEG 4 1/2" HANGER ASSY. M/U & LAND COMPLETION STRING. TEST CONTROL LINE TO 5000 PSI, OK. RILDS. SET TWC. N/D BOPE. N/U X-MAS TREE & ADAPTER FLANGE. PULL TWC DROP BALL. R/U LINE TO TREE & PRESSURE TEST TO 4000 PSI. PRESSURE UP ON TBG & SET PKR. HOLD 30 PRESSURE TEST F/ 30 MIN & RECORD SAME. BLED OFF TO 1500 PSI, PRESSURE UP ON ANNULUS TO 3500 PSI & TEST FOR 30 MIN. RECORD SAME. BLED OFF TBG SLOWLY & SHEAR RP VALVE. FREEZE PROTECT TBG & ANNULUS W/ DIESEL. R/D HB&R. R/U LUBRICATOR. INSTALL BPV. SECURE WELL. CLEAN CELLAR. RELEASE RIG @ 1500 HRS 4-22-01. Printed: 5/1/2001 10:30:50 AM 26-Apr-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Survey Re: Distribution of Survey Data for Well MPF-73A 200-19S Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie -on Survey: Window / Kickoff Survey: Projected Survey: 14,044.85' MD 'MD (if applicable 14,614.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECFIVPIJ MAY 01 2001 OI& GUCWt;- w*oW1 *ft AOd DEFINITIVE Milne Point Unit Alaska Drilling & Wells Milne Point MPF, Slot MPF-73 -- MPF-73A Job No. AKMW10120, Surveyed: 16 April, 2001 SURVEY REPORT 26 April, 2001 Your Ref.• API 500292274401 Surface Coordinates: 6035602.71 N, 542076.45 E (70° 30' 29.3320" N, 149° 39' 20.6760" K9 Kelly Bushing: 42.10ft above Mean Sea Level sperrny-Mun ORiLL NG SIEN-VICeS A Halliburton Company Survey Ref: svy9825 Sperry -Sun Drilling Services Survey Report for MPF-73A Your Ref: AP1500292274401 Job No. AKMW10120, Surveyed: 16 April, 2001 DEFINITIVE Alaska Drilling & Wells Milne Point Unit Milne Point MPF Measured Sub -Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (-1100ft) 14044.85 93.130 5.840 8833.19 8875.29 8732.90 N 1980.91 E 6044346.69 N 544007.87 E 8954.71 Tie On Point ,j 14078.00 92.630 2.420 8831.52 8873.62 8765.91 N 1983.29 E 6044379.72 N 544010.06 E 10.41 8987.45 Window Point 14113.35 87.750 3.020 8831.40 8873.50 8801.21 N 1984.97 E 6044415.03 N 544011.54 E 13.91 9022.26 14154.55 87.140 6.550 8833.24 8875.34 8842.22 N 1988.40 E 6044456.05 N 544014.74 E 8.69 9063.03 14192.75 87.750 1.610 8834.94 8877.04 8880.28 N 1991.12 E 6044494.12 N 544017.24 E 13.02 9100.76 14224.35 87.220 356.860 8836.33 8878.43 8911.83 N 1990.70 E 6044525.68 N 544016.64 E 15.11 9131.46 14260.95 86.610 352.630 8838.30 8880.40 8948.22 N 1987.35 E 6044562.04 N 544013.09 E 11.66 9166.24 14293.95 88.190 349.100 8839.80 8881.90 8980.76 N 1982.12 E 6044594.55 N 544007.67 E 11.71 9196.85 14329.75 87.670 343.990 8841.09 8883.19 9015.54 N 1973.80 E 6044629.29 N 543999.15 E 14.34 9228.98 14366.15 87.840 339.760 8842.52 8884.62 9050.10 N 1962.48 E 6044663.78 N 543987.64 E 11.62 9260.24 14395.15 88.550 336.240 8843.43 8885.53 9076.97 N 1951.63 E 6044690.59 N 543976.63 E 12.38 9284.09 14426.75 88.280 333.420 8844.31 8886.41 9105.56 N 1938.19 E 6044719.10 N 543963.04 E 8.96 9309.05 14457.55 87.840 331.480 8845.35 8887.45 9132.85 N 1923.96 E 6044746.31 N 543948.65 E 6.46 9332.58 14489.75 89.430 331.660 8846.12 8888.22 9161.16 N 1908.63 E 6044774.53 N 543933.16 E 4.97 9356.86 14524.35 92.690 334.130 8845.48 8887.58 9191.94 N 1892.87 E 6044805.23 N 543917.23 E 11.82 9383.46 14554.95 94.690 336.780 8843.51 8885.61 9219.72 N 1880.19 E 6044832.93 N 543904.39 E 10.84 9407.80 14585.15 95.770 339.590 8840.75 8882.85 9247.63 N 1869.01 E 6044860.78 N 543893.06 E 9.93 9432.60 14614.00 95.770 339.590 8837.85 8879.95 9274.54 N 1859.00 E 6044887.63 N 543882.89 E 0.00 9456.67 Projected Survey All data is in Feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.2830 (08-Apr-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 12.610" (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14614.00ft., The Bottom Hole Displacement is 9459.01ft., in the Direction of 11.334° (True). 26 April, 2001 - 14:37 Page 2 of 3 DrillQuest 2.00.08.005 Milne Point Unit Comments Measured Depth (ft) 14044.85 14078.00 14614.00 Sperry -Sun Drilling Services Survey Report for MPF-73A Your Ref: API 500292274401 Job No. AKMW10120, Surveyed: 16 April, 2001 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8875.29 8732.90 N 1980.91 E 8873.62 8765.91 N 1983.29 E 8879.95 9274.54 N 1859.00 E Survey tool program for MPF-73A Comment Tie On Point Window Point Projected Survey From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 11009.40 7508.02 AK-1 BP_HG (MPF-73) 11009.40 7508.02 11125.20 7612.53 MWD Magnetic (MPF-73) 11125.20 7612.53 12654.76 8769.82 AK-6 BP_IFR-AK (MPF-73APB1) 12654.76 8769.82 14614.00 8879.95 MWD Magnetic (MPF-73APB2) 26 April, 2001 - 14:37 Page 3 of 3 ot" Alaska Drilling & Wells Milne Point MPF DrillQuest 2.00.08.005 aoo-�9g f 08-Jan-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Wel MPF-73A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie -on Survey: 11,009.20' MD Window / Kickoff Survey 11,100.50' MD (if applicable Projected Survey: 12,758.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Milne Point Unit Alaska Drilling & Wells Milne Point MPF, Slot MPF-73 MPF- 73A MWD Surveyed: 29 December, 2000 SURVEY REPORT 8 January, 2001 Your Ref.- AP1500292274401 Surface Coordinates: 6035602.71 N, 542076.45 E (700 30' 29.3320" N, 1490 39' 20.6760" V) Kelly Bushing: 42.1Oft above Mean Sea Level �per�r-�-st�ri DRILLING SERVICES A Halliburton Company Survey Ref: svy9744 Sperry -Sun Drilling Services Survey Report for MPF-73A MWD Your Ref: API 500292274401 Surveyed: 29 December, 2000 Alaska Drilling & Wells Milne Point Unit Milne Point MPF Measured Sub -Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 11009.20 25.960 13.850 7465.73 7507.83 6482.21 N 1354.96 E 6042092.49 N 543394.67 E 6622.31 TIE ON POINT 11100.50 25.960 13.850 7547.82 7589.92 6521.01 N 1364.53 E 6042131.35 N 543404.02 E 0.00 6662.25 WINDOW POINT 11125.20 25.050 13.640 7570.11 7612.21 6531.34 N 1367.06 E 6042141.69 N 543406.49 E 3.70 6672.88 MWD Magnetic 11157.88 25.470 12.700 7599.66 7641.76 6544.92 N 1370.23 E 6042155.29 N 543409.59 E 1.78 6686.82 11187.67 25.630 12.490 7626.54 7668.64 6557.46 N 1373.03 E 6042167.84 N 543412.32 E 0.62 6699.66 11224.58 27.660 9.750 7659.53 7701.63 6573.70 N 1376.21 E 6042184.10 N 543415.41 E 6.43 6716.21 11258.48 28.410 8.380 7689.45 7731.55 6589.43 N 1378.72 E 6042199.85 N 543417.82 E 2.92 6732.12 11284.76 28.660 8.200 7712.54 7754.64 6601.86 N 1380.53 E 6042212.28 N 543419.56 E 1.01 6744.65 11315.57 30.470 7.170 7739.34 7781.44 6616.92 N 1382.56 E 6042227.36 N 543421.51 E 6.10 6759.82 11347.57 30.950 7.270 7766.85 7808.95 6633.13 N 1384.61 E 6042243.58 N 543423.47 E 1.51 6776.11 11379.42 31.910 7.450 7794.03 7836.13 6649.60 N 1386.74 E 6042260.06 N 543425.50 E 3.03 6792.66 11411.82 33.570 6.220 7821.28 7863.38 6667.00 N 1388.82 E 6042277.47 N 543427.49 E 5.52 6810.12 11445.21 35.010 6.750 7848.87 7890.97 6685.69 N 1390.95 E 6042296.17 N 543429.51 E 4.40 6828.85 11476.13 35.530 6.610 7874.11 7916.21 6703.43 N 1393.02 E 6042313.92 N 543431.48 E 1.70 6846.63 11573.59 35.560 7.050 7953.41 7995.51 6759.68 N 1399.76 E 6042370.21 N 543437.90 E 0.26 6903.07 11663.88 34.770 6.820 8027.22 8069.32 6811.30 N 1406.04 E 6042421.86 N 543443.89 E 0.89 6954.89 11760.62 34.130 6.380 8106.99 8149.09 6865.66 N 1412.33 E 6042476.26 N 543449.87 E 0.71 7009.39 11853.49 34.800 8.020 8183.56 8225.66 6917.80 N 1418.93 E 6042528.43 N 543456.17 E 1.23 7061.77 11949.27 35.350 8.680 8261.95 8304.05 6972.25 N 1426.92 E 6042582.93 N 543463.86 E 0.70 7116.71 12045.86 41.420 9.170 8337.63 8379.73 7031.47 N 1436.24 E 6042642.20 N 543472.84 E 6.29 7176.58 12141.45 45.150 11.410 8407.20 8449.30 7095.93 N 1447.98 E 6042706.73 N 543484.22 E 4.22 7242.08 12236.41 49.650 9.540 8471.47 8513.57 7164.65 N 1460.65 E 6042775.52 N 543496.49 E 4.96 7311.93 12331.43 48.670 12.930 8533.61 8575.71 7235.14 N 1474.63 E 6042846.09 N 543510.08 E 2.89 7383.80 12428.57 49.370 13.060 8597.32 8639.42 7306.60 N 1491.13 E 6042917.63 N 543526.17 E 0.73 7457.11 12525.80 51.690 5.900 8659.17 8701.27 7380.55 N 1503.40 E 6042991.66 N 543538.02 E 6.16 7532.01 12620.79 61.560 9.810 8711.37 8753.47 7458.99 N 1514.37 E 6043070.15 N 543548.55 E 10.94 7611.04 12654.76 62.150 9.380 8727.40 8769.50 7488.52 N 1519.36 E 6043099.72 N 543553.37 E 2.06 7640.97 12758.00 62.150 9.380 8775.63 8817.73 7578.58 N 1534.24 E 6043189.86 N 543567.74 E 0.00 7732.17 PROJECTED SURVEY 8 January, 2001- 15:19 Page 2 of 4 DrillQuest 2.00.06 Sperry -Sun Drilling Services Survey Report for MPF-73A MWD Your Ref: API 500292274401 Surveyed: 29 December, 2000 Milne Point Unit All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.383' (19-Dec-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 11.8070 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12758.00ft., The Bottom Hole Displacement is 7732.32ft., in the Direction of 11.445' (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 11009.20 7507.83 6482.21 N 1354.96 E TIE ON POINT 11100.50 7589.92 6521.01 N 1364.53 E WINDOW POINT 12758.00 8817.73 7578.58 N 1534.24 E PROJECTED SURVEY Alaska Drilling & Wells Milne Point MPF 8 January, 2001 - 16:19 Page 3 of 4 DrillQuest 2.00.06 Milne Point Unit Survey tool program for MPF-73A MWD From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 11125.20 11125.20 7612.21 12758.00 Vertical Depth (ft) Sperry -Sun Drilling Seiv ces Survey Report for MPF-73A MWD Your Ref; API 500292274401 Surveyed: 29 December, 2000 Survey Tool Description 7612.21 AK-1 BP_FIG (MPF-73) 8817.73 MWD Magnetic (MPF-73A MWD) Alaska Drilling & Wells Milne Point MPF 8 January, 2001- 16:19 Page 4 of 4 DrillQuest 2.00.06 26-Apr-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Name Change Re: Distribution of Survey Data for Well MPF-73APB1 2C�O —N"b Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie -on Survey: Window / Kickoff Survey: Projected Survey: 11,009.40' MD 'MD (if applicable 12,758.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEI\/r-n MAY 01 2001 Alma iAl a %2M Cons. cwmwaion AndV48 DEFINITIVE Milne Point Unit Alaska Drilling & Wells Milne Point MPF, Slot MPF-73 MPF-73APB 1 Job No. AKZZ00324, Surveyed: 29 December, 2000 SURVEY REPORT 26 April, 2001 Your Ref: API 500292274470 Surface Coordinates: 6035602.71 N, 542076.45 E (70° 30' 29.3320" N, 149' 39' 20.6760" K9 Kelly Bushing: 42.10ft above Mean Sea Level sperrg/-sun DRIL-LANG SERVICES Survey Ret: svy9745 A Hailiburton Company Sperry -Sun Drilling Services Survey Report for MPF-73APB1 Your Ref.• API 500292274470 Job No. AKZZ00324, Surveyed: 29 December, 2000 Milne Point Unit Measured Sub -Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) - (ft) (ft) 11009.40 25.960 13.900 7465.92 7508.02 6482.25 N 1354.97 E 6042092.53 N 543394.69 E 11125.20 25.050 13.380 7570,43 7612.53 6530.70 N 1366.74 E 6042141.05 N 543406.17 E 11157.88 25.470 12.310 7599.99 7642.09 6544.30 N 1369.84 E 6042154.66 N 543409.20 E 11187.67 25.630 12.190 7626.86 7668.96 6556.86 N 1372.56 E 6042167.24 N 543411.85 E 11224.58 27.660 9.490 7659.85 7701.95 6573.11 N 1375.66 E 6042183.51 N 543414.86 E 11258.48 28.410 8.980 7689.78 7731.88 6588.84 N 1378.22 E 6042199.25 N 543417.33 E 11284.76 28.660 8.750 7712.86 7754.96 6601.24 N 1380.15 E 6042211.66 N 543419.19 E 11315.57 30.470 7.840 7739.66 7781.76 6616.28 N 1382.34 E 6042226.72 N 543421.29 E 11347.57 30.950 7.830 7767.17 7809.27 6632.47 N 1384.57 E 6042242.92 N 543423.43 E 11379.42 31.910 8.000 7794.35 7836.45 6648.92 N 1386.86 E 6042259.38 N 543425.62 E 11411.82 33.570 6.660 7821.60 7863.70 6666.30 N 1389.09 E 6042276.77 N 543427.76 E 11445.21 35.010 7.090 7849.19 7891.29 6684.98 N 1391.34 E 6042295.46 N 543429.90 E 11476.13 35.530 6.930 7874.43 7916.53 6702.70 N 1393.52 E 6042313.19 N 543431.98 E 11573.59 35.560 7.380 7953.73 7995.83 6758.91 N 1400.58 E 6042369.45 N 643438.72 E 11663.88 34.770 7.190 8027.54 8069.64 6810.50 N 1407.17 E 6042421.07 N 543445.02 E 11760.62 34.130 6.720 8107.32 8149.42 6864.82 N 1413.80 E 6042475.42 N 543451.34 E 11853,49 34.800 8.400 8183.89 8225.99 6916.91 N 1420.72 E 6042527.56 N 543457.97 E 11949.27 35.350 9.110 8262.27 8304.37 6971.31 N 1429.10 E 6042582.00 N 543466.04 E 12045.86 41.420 9.840 8337.95 8380.05 7030.43 N 1438.99 E 6042641.18 N 543475.60 E 12141.45 45.150 11.790 8407.53 8449.63 7094.78 N 1451.32 E 6042705.60 N 543487.57 E 12236.41 49.650 9.990 8471.79 8513.89 7163.41 N 1464.49 E 6042774.30 N 543500.34 E 12331.43 48.670 13.300 8533.94 8576.04 7233.80 N 1478.98 E 6042844.77 N 543514.43 E 12428.57 49.370 14.180 8597.64 8639.74 7305.03 N 1496.40 E 6042916.10 N 543531.45 E 12525.80 51.690 6.530 8659.50 8701.60 7378.78 N 1509.79 E 6042989.92 N 543544.42 E 12620.79 61.560 10.150 8711.70 8753.80 7457.13 N 1521.42 E 6043068.33 N 543555.61 E 12654.76 62.150 9.620 8727.72 8769.82 7486.63 N 1526.56 E 6043097.87 N 543560.58 E 12758.00 62.150 9.620 8775.95 8818.05 7576.63 N 1541.81 E 6043187.95 N 543575.33 E Dogleg Rate pi 00ft) 0.81 1.90 0.56 6.40 2.32 1.04 6.05 1.50 3.03 5.59 4.37 1.71 0.27 0.88 0.72 1.25 0.71 6.30 4.14 4.94 2.83 0.99 6.52 10.86 2.22 0.00 06 DEFINITIVE Alaska Drilling & Wells Milne Point MPF Vertical Section Comment 6622.35 Tie On Point MWD Magnetic 6672.19 AK-6 BP_IFR-AK 6686.13 6698.98 6715.52 6731.44 6743.98 6759.15 6775.45 6792.02 6809.49 6828.23 6846.02 6902.49 6954.33 7008.86 7061.27 7116.23 7176.13 7241.64 7311.50 7383.37 7456.66 7531.59 7610.66 7640.59 7731.81 PROJECTED SURVEY 26 April, 2001 - 15:03 Page 2 of 3 DrillQuest 2.00.08.005 Sperry -Sun Drilling Services 6 Survey Report for MPF-73APB1 Your Ref: API 500292274470 Job No. AKZZ00324, Surveyed: 29 December, 2000 Milne Point Unit All data is in Feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.383' (19-Dec-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 11.8070 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12758.00ft., The Bottom Hole Displacement is 7731.92ft., in the Direction of 11.502' (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 11009.40 7508.02 6482.25 N 1354.97 E Tie On Point 12758.00 8818.05 7576.63 N 1541.81 E PROJECTED SURVEY Survey tool program for MPF-73APB1 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 11009.40 7508.02 11125.20 7612.53 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 11009.40 7508.02 AK-1 BP_HG (MPF-73) 11125.20 7612.53 MWD Magnetic (MPF-73) 12758.00 8818.05 AK-6 BP_IFR-AK (MPF-73APB1) f US Alaska Drilling & Wells Milne Point MPF 26 April, 2001 - 15:03 Page 3 of 3 DrillQuest 2.00.08.005 26-Apr-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Name Change Re: Distribution of Survey Data for Well MPF-73APB1 MWD "Laa' fA?> Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie -on Survey: Window / Kickoff Survey: Projected Survey: 11,009.40' MD 'MD (if applicable 121758.00', MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) R,ECEIVPn MAY 012001 Alaska �A, & uas Cons. Commmion Anchorage DEFINITIVE Milne Point Unit Alaska Drilling & Wells Milne Point MPF, Slot MPF-73 MPF-73APB 1 MWD Job No. AKMM00316, Surveyed: 29 December, 2000 SURVEY REPORT 26 April, 2001 Your Ref: API 500292274470 Surface Coordinates: 6035602.71 N, 542076.45 E (700 30' 19.3320" N, 149° 39' 20.6760" VV) Kelly Bushing: 42.10ft above Mean Sea Level Sperry -sun DRILLING Sr=RV-1Cr=9 Survey Ref: svy9744 A Hailiburlon Company Sperry -Sun Drilling Services Survey Report for MPF-73APB1 MID Your Ref: API 500292274470 Job No. AKMM00316, Surveyed: 29 December, 2000 Milne Point Unit Measured Sub -Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11009.40 25.960 13.900 7465.92 7508.02 6482.25 N 1354.97 E 6042092.53 N 543394.69 E 11100.50 25.244 13.697 7548.07 7590.17 6520.48 N 1364.36 E 6042130.81 N 543403.86 E 11125.20 25.050 13.640 7570.43 7612.53 6530.68 N 1366.85 E 6042141.03 N 543406.28 E 11157.88 25.470 12.700 7599.99 7642.09 6544.26 N 1370.02 E 6042154.62 N 543409.38 E 11187.67 25.630 12.490 7626.86 7668.96 6556.80 N 1372.82 E 6042167.18 N 543412.11 E 11224.58 27.660 9.750 7659.85 7701.95 6573.04 N 1376.00 E 6042183.43 N 543415.20 E 11258.48 28.410 8.380 7689.78 7731.88 6588.77 N 1378.51 E 6042199.18 N 543417.62 E 11284.76 28.660 8.200 7712.86 7754.96 6601.19 N 1380.32 E 6042211.61 N 543419.36 E 11315.57 30.470 7.170 7739.66 7781.76 6616.26 N 1382.35 E 6042226.69 N 543421.30 E 11347.57 30.950 7.270 7767.17 7809.27 6632.47 N 1384.40 E 6042242.91 N 543423.26 E 11379.42 31.910 7.450 7794.35 7836.45 6648.94 N 1386.53 E 6042259.40 N 543425.30 E 11411.82 33.570 6.220 7821.60 7863.70 6666.34 N 1388.61 E 6042276.81 N 543427.28 E 11445.21 35.010 6.750 7849.19 7891.29 6685.03 N 1390.74 E 6042295.51 N 543429.30 E 11476.13 35.530 6.610 7874.43 7916.53 6702.76 N 1392.81 E 6042313.25 N 543431.28 E 11573.59 35.560 7.050 7953.73 7995.83 6759.02 N 1399.55 E 6042369.54 N 543437.70 E 11663.88 34.770 6.820 8027.54 8069.64 6810.64 N 1405.83 E 6042421.20 N 543443.68 E 11760.62 34.130 6.380 8107.32 8149.42 6865.00 N 1412.12 E 6042475.60 N 543449.67 E 11853.49 34.800 8.020 8183.89 8225.99 6917.13 N 1418.72 E 6042527.77 N 543455.96 E 11949.27 35.350 8.680 8262.27 8304.37 6971.59 N 1426.71 E 6042582.27 N 543463.65 E 12045.86 41.420 9.170 8337.95 8380.05 7030.81 N 1436.03 E 6042641.54 N 543472.63 E 12141.45 45.150 11.410 8407.53 8449.63 7095.26 N 1447.77 E 6042706.06 N 543484.01 E 12236.41 49.650 9.540 8471.79 8513.89 7163.98 N 1460.44 E 6042774.85 N 543496.29 E 12331.43 48.670 12.930 8533.94 8576.04 7234.48 N 1474.42 E 6042845.42 N 543509.87 E 12428.57 49.370 13.060 8597.64 8639.74 7305.93 N 1490.92 E 6042916.97 N 543525.96 E 12525.80 51.690 5.900 8659.49 8701.59 7379.88 N 1503.19 E 6042990.99 N 543537.81 E 12620.79 61.560 9.810 8711.70 8753.80 7458.32 N 1514.16 E 6043069.49 N 543548.34 E 12654.76 62.150 9.380 8727.72 8769.82 7487.86 N 1519.15 E 6043099.05 N 543553.17 E 12758.00 62.150 9.380 8775.95 8818.05 7577.92 N 1534.03 E 6043189.20 N 543567.54 E DEFINITI'V'NE Alaska Drilling & Wells Milne Point MPF Dogleg Rate (°/100ft) 0.79 0.79 1.78 0.62 6.43 2.92 1.01 6.10 1.51 3.03 5.52 4.40 1.70 0.26 0.89 0.71 1.23 0.70 6.29 4.22 4.96 2.89 0.73 6.16 10.94 2.06 0.00 Vertical Section Comment 6622.35 MWD Magnetic 6661.69 WINDOW POINT 6672.18 6686.12 6698.97 6715.52 6731.43 6743.96 6759.12 6775.41 6791.97 6809.43 6828.16 6845.94 6902.38 6954.19 7008.69 7061.07 7116.01 7175.89 7241.38 7311.24 7383.10 7456.42 7531.32 7610.34 7640.27 7731.47 PROJECTED SURVE) DrillQuest 2.00.08.005 26 April, 2001 - 15:08 Page 2 of 3 Sperry -Sun Drilling Services • r Survey Report for MPF-73APB1 MID Your Ref: AP! 500292274470 Job No. AKMM00316, Surveyed: 29 December, 2000 Milne Point Unit All data is in Feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.383' (19-Dec-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 11.807° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12758.00ft., The Bottom Hole Displacement is 7731.63ft., in the Direction of 11.4440 (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 11100.50 7590.17 6520.48 N 1364.36 E WINDOW POINT 12758.00 8818.05 7577.92 N 1534.03 E PROJECTED SURVEY Survey toot program for MPF-73APB1 MID From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 11009.40 7508.02 AK-1 BP_HG (MPF-73) 11009.40 7508.02 12758.00 8818.05 MWD Magnetic (MPF-73) 26 April, 2UU7 - 75:U6 Page 3 of 3 Alaska Drilling & Wells Milne Point MPF DrillQuest 2,00.08.005 26-Apr-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Survey Re: Distribution of Survey Data for Well MPF-73APB2 2b0 -[J9 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie -on Survey: Window / Kickoff Survey: Projected Survey: 12,654.76' MD 'MD (if applicable 14,256.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECERIP n. MAY 01 2001 AVft0iI & C-M5. AnIge DEFINITIVE Milne Point Unit Alaska Drilling & Wells Milne Point MPF, Slot MPF-73 MPF-73APB2 , Job No. AKMW10120, Surveyed: 9 April, 2001 SURVEY REPORT 26 April, 2001 Your Ref: API 500292274471 Surface Coordinates: 6035602.71 N, 542076.45 E (70° 30' 29.3320" N, 149° 39' 20.6760" M Kelly Bushing: 42.10ft above Mean Sea Level sperry-sun D R t LING sERVICE39 Survey Ref: svy9823 A Halliburton Company Sperry -Sun Drilling Services y Survey Report for MPF-73APB2 Your Ref: API 500292274471 Job No. AKMW10120, Surveyed: 9 April, 2001 Milne Point Unit Measured Sub -Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 12654.76 62.150 9.620 8727.72 8769.82 7486.63 N 1526.56 E 6043097.87 N 543560.58 E 12697.00 62.150 9.620 8747.46 8789.56 7523.46 N 1532.80 E 6043134.73 N 543566.61 E 12727.87 68.460 8.000 8760.35 8802.45 7551.16 N 1537.08 E 6043162.45 N 543570.74 E 12757.87 72.950 6.460 8770.26 8812.36 7579.24 N 1540.64 E 6043190.55 N 543574.14 E 12789.67 77.540 4.840 8778.36 8820.46 7609.83 N .1543.66 E 6043221.16 N 543576.99 E 12825.07 83.270 4.370 8784.25 8826.35 7644.61 N 1546.46 E 6043255.96 N 543579.59 E 12857.87 85.640 2.670 8787.42 8829.52 7677.19 N 1548.47 E 6043288.55 N 543581.41 E 12888.07 87.580 0.380 8789.21 8831.31 7707.33 N 1549.27 E 6043318.69 N 543582.04 E 12917.67 89.600 357.030 8789.94 8832.04 7736.90 N 1548.60 E 6043348.26 N 543581.20 E 12946.97 92.160 352.800 8789.49 8831.59 7766.08 N 1546.00 E 6043377.42 N 543578.44 E 12977.77 92.860 356.330 8788.14 8830.24 7796.70 N 1543.09 E 6043408.03 N 543575.35 E 13008.17 92.690 0.730 8786.67 8828.77 7827.05 N 1542.31 E 6043438.37 N 543574.40 E 13043.17 92.510 1.260 8785.08 8827.18 7862.01 N 1542.92 E 6043473.33 N 543574.81 E 13075.17 92.120 5.830 8783.79 8825.89 7893.91 N 1544.90 E 6043505.25 N 543576.61 E 13112.97 91.190 8.310 8782.69 8824.79 7931.41 N 1549.55 E 6043542.76 N 543581.05 E 13156.37 87.930 12.360 8783.03 8825.13 7974.09 N 1557.33 E 6043585.49 N 543588.59 E 13219.17 86.260 17.120 8786.21 8828.31 8034.72 N 1573.28 E 6043646.21 N 543604.19 E 13281.37 83.520 19.590 8791.75 8833.85 8093.51 N 1592.78 E 6043705.11 N 543623.36 E 13318.57 80.620 22.940 8796.89 8838.99 8127.84 N 1606.14 E 6043739.52 N 543636.53 E 13372.17 80.350 26.110 8805.75 8847.85 8175.93 N 1628.08 E 6043787.73 N 543658.19 E 13406.77 80.700 30.510 8811.45 8853.55 8205.97 N 1644.26 E 6043817.86 N 543674.20 E 13439.57 80.350 31.750 8816.85 8858.95 8233.66 N 1660.98 E 6043845.65 N 543690.77 E 13473.57 80.530 36.150 8822.50 8864.60 8261.46 N 1679.70 E 6043873.56 N 543709.33 E 13503.37 81.760 36.860 8827.08 8869.18 8285.13 N 1697.22 E 6043897.32 N 543726.72 E 13534.77 84.140 38.620 8830.94 8873.04 8309.77 N 1716.29 E 6043922.07 N 543745.65 E 13563.77 84.490 40.030 8833.81 8875.91 8332.09 N 1734.58 E 6043944.49 N 543763.81 E 13596.37 83.960 41.970 8837.09 8879.19 8356.57 N 1755.86 E 6043969.09 N 543784.95 E 13628.37 84.490 43.910 8840.31 8882.41 8379.88 N 1777.55 E 6043992.52 N 543806.50 E 13659.17 86.610 39.150 8842.70 8884.80 8402.86 N 1797.90 E 6044015.62 N 543826.72 E 13694.25 88.990 44.430 8844.05 8886.15 8428.98 N 1821.25 E 6044041.87 N 543849.93 E 26 April, 2001 - 14:32 Page 2 of 4 DEF11`N'1`1"ffE Alaska Drilling & Wells Milne Point MPF Dogleg Vertical Rate Section Comment (°/100ft) 7639.31 Tie On Point MWD Magnetic 0.00 7676.61 Interpolated Az 20.99 7704.58 15.73 7732.76 15.25 7763.28 16.24 7797.83 8.88 7830.06 9.93 7859.64 13.21 7888.36 16.87 7916.26 11.67 7945.51 14.47 7974.96 1.60 8009.21 14.32 8040.77 7.00 8078.38 11.98 8121.73 8.02 8184.38 5.92 8246.01 11.85 8282.43 5.85 8334.15 12.58 8366.99 3.88 8397.67 12.77 8428.89 4.75 8455.81 9.40 8484.02 4.99 8509.79 6.14 8538.33 6.25 8565.81 16.87 8592.67 16.50 8623.27 DrillQuesi 2.00,08.005 Sperry -Sun Drilling Services Survey Report for MPF-73APB2 Your Ref: API 500292274471 Job No. AKMW10120, Surveyed: 9 April, 2001 Milne Point Unit Measured Sub -Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 13733.65 91.010 42.850 8844.05 8886.15 8457.49 N 1848.44 E 6044070.54 N 543876.95 E 6.51 13770.05 89.780 40.910 8843.80 8885.90 8484.59 N 1872.73 E 6044097.77 N 543901.10 E 6.31 13803.45 89.600 35.450 8843.98 8886.08 8510.84 N 1893.37 E 6044124.13 N 543921.58 E 16.36 13840,05 90.250 31.930 8844.03 8886.13 8541.28 N 1913.67 E 6044154.70 N 543941.71 E 9.78 13879.05 92.330 25.400 8843.15 8885.25 8575.47 N 1932.36 E 6044188.99 N 543960.21 E 17.57 13911.85 93.220 23.110 8841.56 8883.66 8605.34 N 1945.82 E 6044218.94 N 543973.50 E 7.48 13943.45 93.660 19.410 8839.66 8881.76 8634.73 N 1957.26 E 6044248.39 N 543984.77 E 11.77 13983.45 93.740 15.180 8837.08 8879.18 8672.84 N 1969.12 E 6044286.56 N 543996.41 E 10.55 14014.45 93.830 11.660 8835.03 8877.13 8702.92 N 1976.30 E 6044316.68 N 544003.42 E 11.33 14044.85 93.130 5.840 8833.19 8875.29 8732.90 N 1980.91 E 6044346.69 N 544007.87 E 19.25 14086.45 92.510 1.610 8831.14 8873.24 8774.35 N 1983.61 E 6044388.15 N 544010.33 E 10.26 14119.45 92.070 358.270 8829.82 8871.92 8807.32 N 1983.57 E 6044421.12 N 544010.11 E 10.20 14150.65 92.250 354.040 8828.64 8870.74 8838.42 N 1981.48 E 6044452.21 N 544007.84 E 13.56 14180.65 92.330 351.390 8827.44 8869.54 8868.15 N 1977.68 E 6044481.92 N 544003.87 E 8.83 14216.25 92.510 347.170 8825.94 8868.04 8903.09 N 1971.07 E 6044516.82 N 543997.06 E 11.85 14256.00 92.510 347.170 8824.20 8866.30 8941.81 N 1962.25 E 6044555.49 N 543988.02 E 0.00 All data is in Feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.2840 (08-Apr-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 12.610° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14256.00ft., The Bottom Hole Displacement is 9154.58ft., in the Direction of 12.377° (True). Alaska Drilling & Wells Milne Point MPF Vertical Section Comment 8657.03 8688.78 8718.89 8753.04 8790.48 8822.57 8853.75 8893.52 8924.45 8954.71 8995.75 9027.92 9057.81 9085.99 9118.65 9154.51 Projected Survey 26 April, 2001 - 14:32 Page 3 of 4 DrillQuest 2.00.08.005 Sperry -Sun Drilling Services Survey Report for MPF-73APB2 Your Ref: API 500292274471 Job No. AKMW10120, Surveyed: 9 April, 2001 Milne Point Unit Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 12654.76 8769.82 7486.63 N 1526.56 E Tie On Point 12697.00 8789.56 7523.46 N 1532.80 E Interpolated Az 14256.00 8866.30 8941.81 N 1962.25 E Projected Survey Survey tool program for MPF-73APB2 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 11009.40 7508.02 AK-1 BP_HG (MPF-73) 11009.40 7508.02 11125.20 7612.53 MWD Magnetic (MPF-73) 11125.20 7612.53 12654.76 8769.82 AK-6 BP_IFR-AK (MPF-73APB1) 12654.76 8769.82 14256.00 8866.30 MWD Magnetic (MPF-73APB2) Alaska Drilling & Wells Milne Point MPF 26 April, 2001- 14:32 Page 4 of 4 DrillQuest 2.00.08.005 , STATE OF ALASKA T. ALASK4 _ AND GAS CONSERVATION COMO, 3ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: ❑ Operation Shutdown ❑ Stimulate ❑ Plugging ❑ Perforate ❑ Pull Tubing ❑ Alter Casing ❑ Repair Well ® Other FCO: Sidetrack Prep 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. ❑ Development KBE = 42.10' 7. Unit or Property Name Milne Point Unit ❑ Exploratory ❑ Stratigraphic 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 ❑ Service 4. Location of well at surface 8. Well Number 2149' NSL, 2485' WEL, SEC. 6, T13N, R10E, UM MPF-73A 9. Permit Number / Approval No. At top of productive interval 4463' NSL, 933' WEL, SEC. 31, T14N, R10E, UM 200-198 10. API Number At effective depth 50- 029-22744-01 11. Field and Pool At total depth Milne Point Unit / Sag River 1357' NSL, 300' WEL, SEC. 30, T14N, R10E, UM 12. Present well condition summary Total depth: measured 12758 feet Plugs (measured) true vertical 8818' feet Effective depth: measured 12713 feet Junk (measured) true vertical 8797 feet Casing Length Size Cemented MD TVD Structural Conductor 112' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface Intermediate Production 11049' 7" 229 sx Class 'G' 31' - 11080' 31' - 7551' Liner 2190' 4-1/2" 280 sx Class'G' 10568' - 12758' 7114' - 8818' Perforation depth: measured None 1�'Z, EC I VE E."), true vertical None J' J N 2001 Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) , ,sit; a9e. 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: ❑ Copies of Logs and Surveys run ❑ Daily Report of Well Operations ❑Oil ❑Gas ❑Suspended Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed Michael Williams Title CT Drilling Engineer Date Prepared By Name/Number D Way SGhnorr 654-51 vim i i i v-,+v,+ n1ay. vvi i vioa � � .„. r �., .I � b u mi n je Dup ica r MPF-73A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/18/2001 DRILL -PREP WORK — FCO: SIDETRACK PREP SUMMARY MIRU DS CTU #8. WAIT ON WEATHER (-85 WIND CHILL). RU REMAINING SUPPORT EQUIPMENT. COMPLETE EQUIPMENT RIG UP. MU BAKER BHA. RIH WITH 2 7/8"MOTOR AND 3.750" MILL. TAG LINER TOP & ROLL MOTOR TO GET INTO LINER. TAG CEMENT TOP AT 12604' CTM. MILL AHEAD W/500# WOB, 30 FPM, 2.5 BPM. MILL TO 126451, PUH ABOVE LINER TOP. WAIT FOR FLUID DELIVERY/UNLOAD RETURNS. RESUME MILLING AHEAD. MILL TO HES LATCH COLLAR AT 12670' CTM. FLUSH LINER W/BIO SWEEP. DROP 3/4" BALL TO OPEN C-SUB. BEGIN REVERSING FILL. REVERSED OUT TO 12,666' CTMD (PU @ 12,660' CTMD). POH. FREEZE PROTECT WELL WITH METHANOL TO 2000'. RD DS CTU #8. *** JOB COMPLETE - WELL TO REMAIN SHUT-IN FOR UPCOMING SIDETRACK *** Fluids Pumped BBLS. Description 1350 2% KCL W/DOUBLE J-313 20 60/40 METHANOL WATER 100 1.5# BIOZAN 170 60/40 METHANOL-WTR 150 1 % KCL 2X SLICK 1790 Total 3/19/01 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATM Sherrie NO. 1085 Company Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Milne Point (Cased Hole) Well Job # Log Description Date Color 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 9951 RECEIVED Date Delivered: MAR 2'3 2001 AL*a 00 & Gas Cons. Cmm�ft Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATfN: Sherrie Received by- 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 9951 RECEIVED Date Delivered: MAR 2'3 2001 AL*a 00 & Gas Cons. Cmm�ft Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATfN: Sherrie Received by- A A A A 00.) -1 A A z A ALA.SSiIi OII. A11TI1 GAS CONSERVATION COMM5SION Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 9951-6612 Re: Milne Point Unit MPF-73A BP Exploration (Alaska) Inc. Permit No: 200-198 Sur Loc: 2149'NSL, 2485'WEL, Sec 6, T13N, R10E, UM Btmhole Loc. 1357'NSL, 300'WEL, Sec. 30, T14N, R10E, UM Dear Mr. Stagg: TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 .Enclosed is the approved revised application for permit to drill the above referenced well. The revision is for a change in bottom -hole location. The provisions of the original approved permit dated December 14, 2000, are in effect for this revision. Sincerely, Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this / 5'-''t day of March, 2001 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. TA.TE OF ALASKA Z44615-1 ALASKA' AND 3 CONSERVATION COMO 3ION PERMIT TO DRILL Revised Pernik, Post Rotary Portion of Sidetrack 20 AAC 25.005 1 a. Type of work ❑ Drill ® Redrill ❑ Re -Entry ❑ Deepen 1 b. Type of well ❑ Exploratory ❑ Stratigraphic Test ❑ Development Oil ® Service ❑ Development Gas ❑ Single Zone ❑ Multiple Zone 2. Name of Operator BP Exploration (Alaska) Inc. 5. Datum Elevation (DF or KB) KBE = 42.10' 10. Field and Pool Milne Point Unit / Sag River 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Property Designation 625S17 ADL 355018 4. Location of well at surface 2149' NSL, 2485' WEL, SEC. 6, T13N, R10E, UM At top of productive interval 4463' NSL, 933' WEL, SEC. 31, T14N, R10E, UM At total depth 1357' NSL, 300' WEL, SEC. 30, T14N, R10E, UM 7. Unit or Property Name Milne Point Unit 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Amount $200,000.00 8. Well Number MPF-73A 9. Approximate spud date 03/15/01 12. Distance to nearest property line ADL 355017, 300' 13. Distance to nearest well 1 No Close Approach 14. Number of acres in property 5083 15. Proposed depth (MD and TVD) 1 15233' MD / 8898' TVD 16. To be completed for deviated wells Kick Off Depth 12645' MD Maximum Hole Angle 90 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)) Maximum surface 2956 psig, At total depth (TVD) 8700' / 4000 psig 18. Casing Program Size Specifications Setting Depth ToD Bottom Quantity of Cement Hole Casing Wei ht Grade Coupling Len th MD TVD MD TVD include stage data 3-3/4" 2-7/8" 6.16# L-80 ST-L 12575' 8686' 15233' 8898' Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary F E B 2 1 2001 Total depth: measured 12758 feet Plugs (measured) true vertical 8818' feet Alaska Oil & Gas Cons. Commission Effective depth: measured 12713 feet Junk (measured) Anchorage true vertical 8797 feet Casing Length Size Cemented MD TVD Structural Conductor 112' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 5873' 9-5/8" 1496 sx PF 'E', 411 sx Class 'G' 5904' 4555' Intermediate Production 11049' 7" 229 sx Class 'G' 11080' 7551' Liner 2190' 4-1/2" 280 sx Class'G' 10568' - 12758' 7114' - 8818' Perforation depth: measured None true vertical None 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: Ted Stagg, 564-4694 Prepared By Name/Number., Terrie Hubble, 564-4628 21. 1 hereby certify that the fore o' g is true and correct to the best of my knowledge Signed Ted Stagg Title CT Drilling Engineer Date omm Permit Number API Number 1 Approval Date See cover letter 200-198 50- 029-22744-01 for other requirements Conditions of Approval: Samples Required ❑ Yes Q No Mud Log Required ❑ Yes KNO to Hydrogen Sulfide Measures ❑ Yes `�No Directional Survey Required R*Yes Required Working Pressure for BOPE ❑ 2K ❑ 3K ❑ 4K ❑ 5K ❑ 1 OK ❑ 15K 143.5K psi for CTU Other by order of i.1 .I. 8 i 0 Y :,.;1 "�' �, � Y"I' 9 r Y 1.1 d l'G Approved By Commissioner the commission Date 3 Form 10-401 Rev. 12-01-85 "' R I G IN A L Submit In Triplicate by MPF-73a Sidetrack Summary of Operations: MPF-73 was a Kuparuk producer that is being re -drilled as a Sag R. producer that will be converted to Sag R. injection when production declines. The Kuparuk perfs have been squeezed off and a rotary rig recently deepened the well to the Sag R. and cemented 4 1/2" liner into the Sag. River. A cement evaluation log on the 4'/2" liner has been requested but not yet run. The results of the cement evaluation log will determine if the 4 1/2" liner cement quality meets injection well requirements. A mechanical whipstock will be set with a -line. SLB/Nordic 1 will then mill the window, drill approx. 2600 ft in the Sag R. formation and complete with a slotted liner. SLB/Nordic will move off after installing the slotted liner and 4ES will move back onto the well to install production tubing set up for a jet pump. Phase 1: Run CBL log, drift & set whipstock anchor on E-Line. Planned for March 5, 2001. A cement evaluation log will be run on the existing 4 1/2" liner. A dummy whipstock drift will be run. A Baker whipstock anchor will be set in the 4 1/2" liner at approx. 12,645' (8723ss). Phase 2: Mill window, Drill and Complete sidetrack: Planned for March 15, 2001. Drilling coil will be used to mill the window and drill the directional hole as per attached plan. The sidetrack will be completed with a slotted liner. Top of 2 7/8" liner to be approx. 12,575' MD (8686' ss). Mud Program: • Phase 1: 9.2 ppg brine • Phase 2: Flo -Pro (9.2 ppg) RECEIVED" Disposal: FEB 2 1 2001 • All drilling and completion fluids and all other Class II wastes will go to KRU 1 R Pad. Alaska Oil & Gas Cons. Commission • All Class I wastes will go to Pad 3 for disposal. Anchorage Casing Program: • 2 7/8" slotted liner will be run from TD to approx. 12,575 (8686ss). An MIT will be performed post - sidetrack to confirm casing integrity for injection service. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. • The annular preventer will be tested to 400 psi and 2000 psi. Directional • See attached directional plan. BHL (State Plane): 544,168; 6,045,382. Max. hole angle is 90 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging • An MWD Gamma Ray log will be run over all of the open hole section. • A real time Resistivity Log will be run in open hole. Hazards • The highest 112S recorded to date on MPF Pad is less than 5 ppm. • Lost circulation risk is low. • Length of hole to drill is high (2588' with TD at 15,233') and may not be achievable. • Small faults may cause the wellbore to exit the Sag River formation. Reservoir Pressure si at 8700ss in offset well MPF-33. The estimate for res. pressure in Res. press. is know to be 3000 p MPF-73a is 4000 psi at 8700'ss. A mud weight of 9.2 ppg will be used and adjusted upward if needed. Max. surface pressure with gas (0.12 psi/ft) to surface is 2956 psi, assuming 4000 psi pore pressure. RECEIVED FEB 2 1 2001 Alaska Oil & Gas Cons. Commission Anchorage Tree: RVC2 9/16" x 5M Mh4hPart 11" x 71/16' SMGen 5a w/ 2 7B" FMCtbg hng, T LHacme ift threads x 2 7/8" 8rd on b ottom, 2H aW H' BPd profile MPF-73a Proposed Completion 20" 91.1 ppf, H-40 112' KOP @ 400' Max. hole arije}=64to 66 deg f/ 4,44 6 to 8,627 I-ble angle thru' erfs = 26.45 9 59' , 40 ppf, L- 80 Bt rc . 7" 26 ppf, L,80, BTGMod production csg ( drift ID=6.151", cap. = 0.06133 bpf ) 17--r - e- s• i/e,fr Top of 2 7/8" liner to be approx. 12,575'. 4 1 /2" mechanical whipstock to be set at approx. 12,635' for CTD sidetrack into Sag R. 4 1 /2" 12.6# L-80 113T-Mod 12,758' DAT E REV. BY COMM ENT S 2/13U MkTddo AMA Flost Dbyon 141 Org. KB Bev. = 41.4' (N22I) Orig. GL Bev = 115' KB To Tbg Spool =28.50' (N22Q D W 141 KB B.ev =42 R E ur" E NE- FEB 2 1 2001 Alaska Oil & Gas Cons. Commis�i Anchorage 1Q0 pgbinefrcrnTDtoZ20U IVD DeEe! ficrn 2XU Wtosurfaoe CL. Proposed 2 7/8" jet pump a tubing to be installed by 4ES w1 ` following CTD completion. Two Tx 21' marker johis f/ 10547-10,589 B4er7` X4.1/2' l.nertcpFbcker I 1QMS ND T'Cadngshoe 11,081) MD 2 7/8" ST-L Slotted Liner to be installed in the 3.75" open hole (1 110 =I:X'IkIIlldl' kill t BP EXPLORATION (AIq MPF-73A Well Name MPF-73A 500 1,000 1,500 2,000 2,500 3,000 3,500 4,000 X distance from Sic Loc CLOSURE Distance 10,001 it Az 12 de NEW HOLE E/W M N/S Kick Off 1,482 7,488 To 2,0921 9,779 State Plane 544,1681 6,045,382 Surface Loc 542,077 6,035,602 US den/1 no Teel Fnna Lannih Curve 1 12 -30 245 Curve 2 12 90 555 Curve 3 12 -110 245 Curve 4 12 -40 115 Curve 5 12 -90 480 Curve 6 12 91 610 Curve 7 1 12 -781 119 Curve 8 1 12 -901 219 Drawn: 2/ 15/2001 10:06 Plan Name: Case 122 MPF-73A Vertical Section Path Distance (Feet) 500 1,000 1,500 2,000 2,500 3,000 3,500 4,000 4,500 5,000 8600 — II i I I ONO 8700 8750 8800 8850 8900 8950 Marker Depths Co)Orig Wellbore Tsag D 8,709 ft ND Sag C F 8,736 ft ND 8,7861 8,786 ft ND Sag B F-8—,7481 ft ND Kick Off 8,723 ft ND 12,645 ft MD De rfr TKO 7,649 ft MD KO Pt 12,645 MD New Hole 2588 Total MD 15,233 ND TD 81898 DLS .inn/inn T-1 C-- I ... u. Curve 1 12 -30 245 Curve 2 12 90 555 Curve 3 12 -110 245 Curve 4 12 -40 115 Curve 5 12 -90 480 Curve 6 12 91 610 Curve 7 1 12 -781 119 Curve 8 1 -901 219 Drawn: 2/15/2001 10:06 Plan Name: Case 122 0 HCR 2 3/8" CT f 0,000 psi Pack -Off Lubricator Iiii 71 /16" Annular 71/16" 5000 psi Blind/Shear 7 1/16" Pipe/Slip 71/16" x 5,000 psi FLOW TEE 4 71/16" x 5,000 psi Pipe/Slips 71/16" Pipe/Slips RECEIVED FEB 2 1 2001 Alaska Oil & Gas Cons. Commission Anchorage M PF-73a CT Drilling & Completion BOP .40 2 3/8" SWAB OR MASTER VALVE 2 7/8" 2 3/8" H 182850 DATE CHECK NO. VENDOR ALASKAO I LA 00 DATE INVOICE / CREDIT MEMO DESCRIPTICN GROSS DISCOUNT NET 012901 iCK012901 A 100.00 100.00 PYMTCOMMENTS: Permit To Drill Fee HANDLING INST: S/H — Terrie Hub le X4628 73e4 CIE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. 100.001 100.00] �7 AIASSA OIL AND GAS CONSERVATION COMMISSION Steve Schultz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPF-73A F, TONY KNOWLES, GOVERNOR t l. t, f�. ,,' 3001PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 BP Exploration (Alaska) Inc Permit No: 200-198 Sur Loc: 21.49'NSL, 2485'WEL, Sec. 6, T13N, R10E, UM Btmhole Loc. 4702'NSL, 899'WEL, Sec. 315T14N, R1 OE, UM Dear Mr. Schultz: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPS) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. �- Sincerely, Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this / 1�- -k-A day of December, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. I STATE OF ALASKA13-� ALASKA OIL AND GAS CONSERVATION COMM16SION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work ❑ Drill ® Redrill 1 b. Type of well ❑ Re -Entry ❑ Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2149' NSL, 2485' WEL, SEC. 6, T13N, R10E, UM At top of productive interval 4463' NSL, 933' WEL, SEC. 31, T14N, R10E, UM At total depth 4702' NSL, 899' WEL, SEC. 31, T14N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 355017 1 No Close Approach 16. To be completed for deviated wells Kick Off Depth 11080, Maximum Hole Angle 18. Casing Program 0;- ^ I Specifications ❑ Exploratory ❑ Stratigraphic Test ® Development Oil ❑ Service ❑ Development Gas ❑ Single Zone ❑ Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 42.0' Milne Point Unit / K 6k 5�,d Riverj 6. Property Designation 65D I DL 355018 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) Milne Point Unit 8. Well Number MPF-73A Number 2S100302630-277 Amount $200,000.00 9. Approximate spud date 12/06/00 14. Number of acres in property 15. Proposed depth (MD and TVD) 1 5083 13043' MD / 8956' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)) 50, Maximum surface 3452 psig, At total depth (TVD) 8850' / 4470 psi Setting Depth Too Bottom Quantity of Cement 1 6-1/8" 1 4-1/2" 1 12.6# 1 L-80 I IBT-MOD 12500' 1 10550' 1 13043' 1 13043' 1 8956' 1310 sx Class'G' I 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 11080 feet • Plugs (measured) true vertical 7571 feet Effective depth: measured 10997 feet Junk (measured))"" true vertical 7497 feet Casing Length Size Cemented MD TVD Structural Conductor 112' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 5873' 9-5/81, 1496 sx PF 'E', 411 sx Class 'G' 5904' 4555' Intermediate Production 11049' 7" 229 sx Class 'G' 11080' 7551' Liner RECEIVED Perforation depth: measured 10634' - 10786' (four intervals) NOV 2 2 2nn9 true vertical 7173' - 7308' (four intervals) Alaska Oil & Gas Cons. Commission Anchorage 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. Michael Tri01o, 564;5774 Prepared By Name/Number, Sondra Stewman, 564-4750 21. 1 hereby certify that the foregoi g is true nd orr ct to the best of my knowledge Signed Steve Shultz �~ 1 �`Title Senior Drilling Engineer Date lCom.lmissipn: Use:Onl , Y. Permit Number API Number [-7fprov I Date See cover letter 6'8 50- 029-22744-01 '" for other requirements Conditions of Approval: Samples Required ❑ Yes 1 No Mud Log Required ❑ Yes ®No Hydrogen Sulfide Measures ® Yes ❑ No Directional Survey Required ® Yes [:]No Required Working Pressure for BOPE ❑ 2K ❑ 3K $,4K ❑ 5K 1OK ❑ 15K ❑ 3.5K psi for CTU G. �� QvG��. �..o M, vic— �h¢ n�,c��►• �� 4oc- � ' � tdr Sccn11C� . Other. � S� Q by order of O�(Cif'�I.'',�i.i.�� the commission Date A roved B Commissioner Form 10-401 Rev. 12-01-85 °f'j'`-: Submit In Triplicate 12/1V00 THU 11:53 FAX 907 564 4441 10002/002 MPF-73a Rigsite Hazards MPF-73a Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE 1. Well Control 1.1. The 6.1/8" hole will be drilled with a13-5/8", 5M 80P on the well. MPF-73a is being drilled in a partially depleated fault block. Reservoir pressure is expected to be underpressured or virgin 6.6 - 9.8 lb/gal equivalent. The planned mud weight is 11 — 12 lb/gal, which provides a 1.2 — 2.2 lb/gal overbalance. 1.2. Abnormal pressures are present both in and sometimes above the Kuparuk reservoir zone and have required significantly higher mud weights then originally expected_ We are drilling below the Kuparuk interval in this well and do not expect there to be any overpressured shales as there is no injection at this time into the Sag intervals_ This fault block is expected to be underpressured or virgin 6.6 - 9.8 lb/gal EMW due to production from MPF-33 (3,000 psi on 12/01/99). 2. Hydrates and Shallow gas 2. t. There has never been any hydrates, shallow gas, or unexpected shallow hydrocarbon problems on F-pad. 3. Lost Ch-culation/Breathing 3.1. Lost circulation is unlikely. Tf it does happen it will be in the Saga There are no LCM restrictions. 3.2. .Breathing is not anticipated on this well. 4. Stuck Pipe 4.1. We do not expect stuck pipe, The risks of drilling through the Kingak shale have been identified and the appropriate M W and good drilling practices will be followed. Ref. "Kingak Wellbore Stability Study, Pnidhoe Bay, Alaska". 5. Hydrogen Sulfide 5.1. MPF-Pad is not a designated H2S Pad from a drilling perspective. Opprn H2S as of Qct. 2000 from offset production well data. For more H2S info, consult the expanded Hazards and Risks section of the wellplan. 6. Faults 6.1. The planned directional trajectory crosses two faults. These faults have been Tapped and identified and there are no expected problems associated with crossing them. CONSULT THE F PAD DATA SHEET AND THE WEL1, PLAN FOR ADDITIONAL Version -01,11/2712000 Tree: FMC 2 9/16" x 5MM P U F �� Orig. KB Bev. = 41.4 ' (N22E) Wellhea,ct 11 x 7 1/1 6', 5MGen 5a Orig. GL Bev. = 11 .5' w / 2 7/8" FMC tbg hn g. , 3" LHac me 11 t KB To T threads x 2 7/8" 8rd on bottom, 2.6' b9 Spool = 28.50' (N 22E) CIW H' BPV profile. Doyon 141 KB ELev. = 42` 20" 91.1 ppf, , H-40 1 12' KOP 0 400' Max. hole angle = 64 to 66 deg. f/ 4, 445' to 8,627 Hole angle thru' perfs = 26.45 9 5/8" , 40 ppf, , L- 80 Bt rc . 5,90 4 ' 7" 26 ppf, L-80, BTC-Mod production ( drift ID= 6.1 51", cap. = 0.0383 bpf ) Perforations abandoned by 4ES Bring cement back up to the liner top packer. 4 1 /2", 12.6#/ft, L-80 I BT-Mod Post 22E joints )p Packer 10,550` MD I 11,080` MD I Liner TD 13,043` MD I 6-1 /8" OH TD 13,043` MD DATE REV. BY COMMENTS 11/22/00 Mik Triolo Proposed Post 22E .m 1Lrl�.PS211�1Z��12 Well MPF-73a AP 11�14��4� 2�_2,2Z 44�4 BP EXPLORATION (AK) MPF-73a Permit Rom RMPF-73a Sag Permit To Drill BP Exploration Alaska Inc. 1. Well Plan Summary: Well Name: I MPF-73a Type of Well(producer or injector): I Pre -Produced Injector Surface Location: 2149' FSL (3129' FNL), 2485' FEL (2673' FWL), Sec. 06, T13N, R10E X = 542,076.45 Y = 6,035,602.71 Sag Target Start: 4463' FSL (815' FNL), 933' FEL (4192' FWL), Sec. 31, T14N, R10E X = 543,555 Y = 6,043,205 Z = 8,775' TVDss TD Target End: 4702, FSL (577' FNL), 899' FEL (4225' FWL), Sec. 31, T14N, R10 E X = 543 587.57 Y = 6,043,443.54 Z = 8,914' TVDss AFE Number: Estimated Start Date: I Dec. 6 In2000 Rig: Doyon 141 Operating days to complete-, 9.33 Original Well PBTD 10,997' TVDrkb (TD) 7,481' 1 Max. Inc. 660 KBE 42' J New Well TD 13,043' TVDrkb (TD) 8,956' Max. Inc. 600 Well Design (conventional, slim hole, etc.): Rotary sidetrack to deepen to Sag. Coil tubing to KO & drill horizontal in Sag. ESP completion. Objective: Drill 6-1/8" hole to +/- 13,043' MD gaining complete penetration through the Sag reservoir. Run and cement 4-1/2" liner. Release Drilling rig. MIRU Coil Drilling Rig, drill horizontal reservoir section in the Sag, run slotted liner. Release Coil Drilling rig. MIRU 4ES, complete well with a 2-7/8" tubing ESP completion. Target Estimates: Estimated Reserves: .9 mm bbls RECEIVED NOV 2 2. ?n+r.n Alaska Oil & Gas Cons. Commission Anchorage Version #11 11/22/2000 MPF-73a Permit 2. Current Well Information 2.1 General Well Name: MPF-73a API Number: 50-029-22744-00 Well Type: Sag Development Pre -Produced Injector Current Status: All open Kuparuk Perfs to be P&A'd by 4ES Last H2s Sample: 0 ppm Cement: 7" casing cemented to 1,000' above shoe. BHP: 1,665 psi @ 7,240' TVDss (Kup) & 3,010 - 4,470 psi @ 8,850' TVDss (Sag) BHT: 1650F @ 7,000' TVD Estimated (SOR) 2.2 Mechanical Condition MPF-73a: Doyon 141: Conductor: Tubing: Liner: Wellhead: Tubing Hanger: Tree: 7" casing fluids: 2.3 Materials Needed Cellar Box above MSL = 12.1' KB/MSL=29.9+12.1 =42.0' 20", 91.1 Ib/ft, H-40 Welded set at 112' RKB 4ES to remove ESP completion on 2-7/8" tubing None 11" X 7-1/16" 5M Gen 5a FMC 11" X 2-7/8" EUE top and bottom 2-1/2" CIW `H' Type BPV profile Cameron 5M, 2-9/16" SW with a diesel cap down to-2,300' MD No Kill String installed Production Liner: 2,500' 4 1/2", 12.6#, L-80, IBT-Mod Solid Liner 63 of 4 %" x 5 3/4" x 8" Rigid Straight Blade Centralizers 7" x 5" Baker liner top packer 4 1/2" Halliburton float collar 4 1/2" Halliburton HPDJ float shoe 2 )) o,�N - 0 � vv%Sh MPF-73a Permit 3. Drilling Program Overview 4.1. Surface and Anti -Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPF-73a. Close Approach Wells: None Well Name Current Status Production Priority Precautions None Abandoned None Well is shut in and secured 4.2. Well Control Expected BHP Max Exp Surface Pressure BOPE Rating Planned BOPE Test Pres. 4,470psi @8,850' TVD estimated 3,452 psi 0.115psi/ft gasgradient) 5,000 psi WP entire stack & valves 4,000/250psi Rams and Valves 01250 psi Annular aSOq/a it j lbo 4.3. Mud Program 6 %" Hole Mud Properties: I LSND Freshwater Mud Density Funnel vis YP HTHP pH API Filtrate LG Solids 11 -12 45-65 15-30 >12cc 8.5-9.5 <6 ji <6.577777777 NOTE: See attached Baroid mud recommendation LCM Restrictions: See Baroid's LCM Decision Tree. Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes should be taken to Phillips KRU 1 R. 4.4. Formation Markers Formation Tops ft MD ft TVDss Pore psi EMW Comments Top Miluveach 7,298 3,643 9.6 KOP 11,080 7,545 3,766 9.6 Planned KO Point Top Kin ak 7,598 3,793 9.6 TJF 7,600 3,833 9.7 TJC 8,350 4,255 9.8 TJB 8,575 4,370 9.8 TJA TSGR (top Sag) 12,765 8,775 2,990-4,440 6.6-9.8 Top Sag SGC 8,798 2,990-4,440 6.6-9.8 SGB 8,812 3,000-4,450 6.6-9.8 SGA 8,850 3,010-4,470 6.6-9.8 Top Shublik 8,870 4,520 9.8 TD 13,043 8,914 4,543 9.8 TD, including rathole 3 MPF-73a Permit 4.5. Casing/Tubing Program Hole Size Csg / Tbg O.D. WVFt Grade Conn Length Top MD / TVDrkb Bottom MD / TVDrkb 6 %$" 4 1/2" 12.6# L-80 IBT-Mod 2,500' 10,550' / 13,043' 13,043' / 8,956' 4.6. Cement Calculations Liner Size 4-1/2" 12.6 Ib/ft L-80 IBT-Mod Basis 50% excess over entire open hole. Bring cement up into liner lap and over liner top packer. Liner top packer above abandoned Ku aruk perfs (top perf: 10,634' MD). 7" casing shoe @ 11,080 MD Total Cement Volume: Spacer 50 bbls B-45 (MudPUSH) Spacer weighted to 12.5 ppg Tail 310 sx 64.5 bbl 15.8 lb/gal Class G + .42% D167 + .27% D65 + .22% D800 + .02 qps D47 + .5% D20, Yield 1.17 cuft/sk, Water 5.102 al/sk Temp BHST 165 F from SOR, BHCT 170° F estimated b Dowel II l 4.6.1. 41/2" Solid Liner Centralizer Placement a) Run one straight blade rigid centralizer per joint with no stop collar (i.e. free floating across the whole length of the joint) for the whole string. 4.7. Survey and Logging Program 6-1/8" Hole Section: Open Hole: MWD / GR/Res / PWD NB. MWD inclination sensor to be placed directly above motor „. Cased hole: CBL with CC 4.8. Bit Recommendations BHA Hole Size Depths (MD) Bit Type Nozzles K-Revs Hours Number and Section 1 6-1/8" 10,550'—13,043' PDC 4.9. Motors and Required Doglegs Drilling Motor Size and Motor Required Flow Rate RPMs Required Doglegs BHA No. 1 4 3/4" Sperrydrill 4/5, 6.3 stg FTC Performance, 250 gpm 100 Maximum build = 81/100` 1.150 ad' with 5.88" sleeve (max.) 4 5. MPF-73a Operations Summary 5.1. Nabors 4ES Procedure: 1. MIRU 4ES 2. Circulate the well to seawater 3. Set TWC, test to 1,000 psi 4. ND Tree/NU BOP, test/Pull TWC 5. Pull ESP Completion 6. RIH with 3-1/2" DP and 2-7/8" stinger to 10,620' MD (800'/hr) 7. Circulate, pump cement, squeeze into perfs �j 8. POOH with 3-1/2" DP, LD (8007hr) to 2,200' MD 9. Freeze protect, POH, LD stinger 10. Drift 7" casing hanger with 6-1/16" string mill 11. Install tubing hanger & BPV 12. ND BOP/NU Tree, test to 5,000 psi 13. RDMO 4ES 5.2. Nabors 22E Procedure: 1. MIRU Nabors 22E 2. Pull BPV, Set TWC, Test to 1,000 psi 3. ND Tree/NU BOP, test 4. Pull & LD tubing hanger 5. Pick up 6-1/8" drilling assembly on 3-1/2" DP, RIH to TOC:-10,620' MD 6. Drill out cement plug, shoe track, and float equipment 7. Displace out to 9.8 ppg LSND mud 8. Drill 20' of new formation/FIT 9. Drill to TD as per the directional plan. Proposed TD: 12,633' MD 10. Circulate & Condition the hole, make a wiper trip to the shoe and back 11. POH with the drilling assembly 12. Run 4-1/2" liner and cement (500' liner lap to cover Kup perforation) 13. Set liner top packer, circulate the casing out to 10 ppg brine 14. POH to 2,200' MD, freeze protect 15. Install BPV, ND/NU, test tree to 5,000 psi 16. Release Rig 6. Coil Tubing Procedure: 1. MIRU E-line Unit 2. Run GR/JB to TD 3. Run Bond Log w/CCL 4. Run and set CTD whipstock 5. RD E-line 7. Coil Tubing Procedure: 6. MIRU Nordic 1 7. ND/NU 8. Drill to TD: 15,348' MD 9. Run liner (if not open hole completion) 10. POH 11. ND/NU ILI MPF-73a Permit 5 MPF-73a Permit 8. Nabors 4ES Procedure: 1. MIRU Nabors 4ES 2. Set TWC, test to 1,000 psi 3. ND Tree/NU BOP, test/Pull TWC 4. RU E-line, make a GR/JB run to below packer setting depth. 5. Run Jet pump completion (10,500' MD), land hanger & run in lock down screws 6. Drop steel ball, pump down if necessary, taking returns up the annulus 7. Test tubing, test casing, shear out RP shear valve in lower GLM 8. Set TWC, test to 1,000 psi from above and below 9. ND BOP/NU Tree, test to 5,000 psi 10. Remove TWC, freeze protect 11. Install BPV 12. RDMO 4ES 9. Post Rig Work Procedure: 1. Retrieve Ball and RHC plug. 2. Install dummy plug in lower Gas Lift Mandrel. 3. Open Sliding Sleeve. 4. Install Jet Pump. Scott Rohleder on 564-5409 will write the Post Rig program with the POT team. 6. Drilling Hazards and Conti ngencies 6.1. Well Control MANDATORY WELL CONTROL DRILLS: Drill Type Frequency Comments D1 Tripping 1per week, per crew Conducted only inside casing. D2 Drilling 1per week, per crew Either in cased or open hole. DO NOT shut-in well in open hole. D3 Diverter Prior to spud, per crew Once per week per crew while drilling with diverter in place. D4 Accumulator Prior to spud or RWO Approx. every 30 days, thereafter at convenient times. D5 Well Kill Prior to drill out, per crew Prior to drill out the intermediate and production strings. Never carry out this drill when open hole sections are exposed. 6.1.1. The 6-1/8" hole will be drilled with a BOP on the well. MPF-73a is being drilled in a partially depleated fault block. Reservoir pressure is expected to be underpressured or virgin 6.6 - 9.8 lb/gal equivalent. The planned mud weight is 11 —12 lb/gal, which provides a 1.2 — 2.2 lb/gal overbalance. 6.1.2. Abnormal pressures are present both in and sometimes above the Kuparuk reservoir zone and have required significantly higher mud weights then originally expected. We are drilling below the Kuparuk interval in this well and do not expect there to be any overpressured shales as there is no injection at this time into the Sag intervals. This fault block is expected to be underpressured or virgin 6.6 - 9.8 lb/gal EMW due to production from MPF-33 (3,000 psi on 12/01/99). R MPF-73a Permit 6.2. Hydrates and Shallow gas 6.2.1. There has never been any hydrates, shallow gas, or unexpected shallow hydrocarbon problems on F-pad. 6.3. Lost Circulation/Breathing 6.3.1. Lost circulation is unlikely. If it does happen it will be in the Sag. There are no LCM restrictions. 6.3.2. Breathing is not anticipated on this well. 6.4. Stuck Pipe 6.4.1. We do not expect stuck pipe. The risks of drilling through the Kingak shale have been identified and the appropriate MW and good drilling practices will be followed. Ref. "Kingak Wellbore Stability Study, Prudhoe Bay, Alaska". 6.5. Hydrogen Sulfide 6.5.1. MPF-Pad is not a designated 1-12S Pad from a drilling perspective. Oppm 1-12S as of Oct. 2000 from offset production well data. 6.6. Faults 6.6.1. The planned directional trajectory crosses one fault. This fault has been mapped and identified and there are no expected problems associated with crossing it. CONSULT THE F PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL N �s�pMilne Point Unit >7 a2F,C,ehVe td�aciAi 3Y',• Alaska D r i l l i n a lE Proposal Data for MPF-73A Wp08 vertical origin: well Horizontal Origin: Well Measurement Units: North Reference : it True North Dogleg severity : Degrees per 100 feet Vertical Section Azinwth : 1.472" Vertical Section Description: Well Vertical Section Origin : 0.00 N,0.00 E Measured Incl. Azure. Vertical Northing& Eastings Vertical Dogleg Depth Depth Section Rate 11100.70 26AN I'' 160 75K9.76 6522.05 N 1163.39E 6554,92 11160.70 26.4(H) 12.160 7643.50 6548.13 N 1369.01 E 6581.14 0.00 11271.36 3.5033 12045.59 35.033 8.283 8.2K3 7738.56 8372.51 6603,72 N 7043.53 N 1378.71) F 1442.81 1: 6636.96 7078.27 9.00 0.00 12544.94 60.000 8.091) 8707.:0 7405.17 N 1494.751: 7441.12 5,(x) 12764.94 60.(x)08817.() 759,1.79 N 1521.591: 7630.37 0.(x) 13042.94 60.(x)0 K.099 9956.10 7832.15 N 1555.50 E 7869.52 00) Current Well Properties Well: MPF•73A WPS Horizontal Coordinates: Rat. Global Coordinates: 6035602.71 N, 542076,45 E Ref. Structure Reference Ref. Geographical Coordinates : 5586.00 N. 10293.82 E 70" 30' 29.4507" N, 149" 39' 20.6421' W RKB Elevation : 42.10h above Mean Sea Level 42.10ft above Structure Reference North Reference : True North nits: Feet' Milne Point MPF rill test' MPF-73A WP08 Eastings Scale: 1 inch = 800ft 1200 2000 2800 9600 8800 1 z:(,,Y r., &M 8800 i f.'ari 'r''i E O • ah.'i. t tt 7 !t.:';', 1•r.. M :V. �"£5:+', , i 0 z 8000 8000 z Y If`• " trtrt(ft' p°u.p;;f+fr i<tr.,r't Total Depth : 13042.94ft MD, 8956.1 Of TVD v 4 1/2" Casing m 8700.00 o End Dir: 12544.94ft MD, 8707.1 Oft TVD 3a 7200 M 7200 r372.51ft a 8200.00 Begin Dir @ 5.000°/100ft : 12045.59ft MD, TVD End Dir : 11271.36ft MD 7738.56ft TVD 7600. Begin Dir @ 8.000°/100ft : 11160.70ft MD, 7 43,50ft TVD ST EXIt @ 0.000°/100ft, 0.000' TF : 11100,70f MD, 7589.76ft TVD 6400 f1'1_7" Casing - 11100.70 MD, 7589.76 TVD 6400 1200 2000 2800 Scale: 1 inch = 800ft Reference is True North Eastings - - • - - - - - , - ____ . __._ - • - - • - - , - - - -. .. - - - . - - , - _..... - - • - - - - - -'f';rr�,ttiiu)��irrh 7" Casing - 11100.70 MD, 7589.76 TVD ?�\ ST Exit @ 0.000°/100ft, 0.000' TF : 11100.70ft MD 7589.76ft TVD Begin Dir @ 8.000°/100ft : 11160.70ft MD, 7643.80ft TVD 7600 7'r+p Kiri;ut End Dlr : 11271.36ft MD, 7738.56ft TVD L Q N 0 1700.00 V Begin Dir @ 5.0000/100ft : 12045.59ft MD, 8372.51 ft TVD N = 8400 ._._......... ....... _ ...... .._._..................... _ _ .._._ . _.._......._ ...... _ ._............. ....... ..... __ ,_.._... .....__ .....__ ...... .... _.....__..___...._........... ..2200.00 ...._....... _ ......... r:;c: . s.r,)z :n 0 r) > O �pF� . ... ...............End D1r••:•12644:•94ft••MD-;.6707:•1Oft ..TVD ... ........ ......... ....... ......... ....... . ........ ....... ......... ....... , ................ rxr rvrl 14 L 2700.00 ...... ........ ........ ......... ....... ......... ........ ....... ........ ....... . ........ ....._, . .. ....... :........ N ..i. .. G„ 7 ''`I r. C.,..... ........ ........ ........ ........ ........ ....... ........ ... .... ...._.:.::..:. .......... ........ ....... ., ........ ..__ ....... _..__ _..... ___ ._.... ._.._ ......_, .._.... . ....._, ._.... ......... ......_ ......_ ....._ ................... _...................... e.,•) i t•i;}? .............._ ....... •::::: :.::::: , ::::::::::. , ::::::.-:::::.:::::::::::::::: ,.,, <t:rlt.r,i t` r Total Depth : 13042.94ft'VIp,::8:::•::::.:::ft , a, 3.:Ir.... 956.10ft TVD l a^ dj nk y 'o TtJk , �. "63" %? A, °:t•,<;., ,I /: 4 1/2" Casing (,. "41 _ Cn ;<:C S..!+J {';ii.-i'!•d•t.?•1:i'. !:?rr,).7i #: 6000 6800 7600 8400 9200 10000 Scale: 1 inch = 800ft ection Azimuth, Nc "C MAJ10 l Section Date/Time:2N Checked: 2 November, 2000 - 9:0 Milne Point Unit Alaska Drilling & Wells Milne Point MPF MPF-73A WPS - MPF-73A Wp08 Revised: 30 October, 2000 PROPOSAL REPORT 22 November, 2000 Surface Coordinates: 6035602.71 N, 542076.45 E (700 30' 29.4507" N, 1490 39' 20.6421 " W) Kelly Bushing: 42.10ft above Mean Sea Level O R F L-LING � e F V§17— e-'� Proposal Ref. pro9641 A twfbvion Game_ Milne Point Unit Measured Depth Incl. (ft) 11100.70 26.400 11156.91 26.400 11159.14 26.400 11160.70 26.400 Sperry -Sun Drilling Services Proposal Report for MPF-73A WPS - MPF-73A Wp08 Revised: 30 October, 2000 Sub -Sea Vertical Local Coordinates Global Coordinates Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) 12.160 7547.66 7589.76 6522.05 N 1363.39 E 6042132.38 N 543402.88 E 12.160 7598.00 7640.10 6546.48 N 1368.65 E 6042156.84 N 543408.00 E 12.160 7600.00 7642.10 6547.45 N 1368.86 E 6042157.81 N 543408.21 E 12.160 7601.40 7643.50 6548.13 N 1369.01 E 6042158.49 N 543408.35 E 11200.00 29.452 10.548 7636.12 7678.22 6566.17 N 1372.62 E 6042176.55 N 543411.86 E 11271.36 35.033 8.283 7696.46 7738.56 6603.72 N 1378.79 E 6042214.14 N 543417.81 E 11300.00 35.033 8.283 7719.90 7762.00 6619.99 N 1381.16 E 6042230.42 N 543420.09 E 11400.00 35.033 8.283 7801.79 7843.89 6676.79 N 1389.43 E 6042287.27 N 543428.03 E 11500.00 35.033 8.283 7883.67 7925.77 6733.60 N 1397.70 E 6042344.12 N 543435.98 E 11600.00 35.033 8.283 7965.55 8007.65 6790.41 N 1405.96 E 6042400.97 N 543443.93 E 11700.00 35.033 8.283 8047.43 8089.53 6847.21 N 1414.23 E 6042457.82 N 543451.88 E 11800.00 35.033 8.283 8129.32 8171.42 6904.02 N 1422.50 E 6042514.67 N 543459.83 E 11900.00 35.033 8.283 8211.20 8253.30 6960.82 N 1430.77 E 6042571.53 N 543467.77 E 12000.00 35.033 8.283 8293.08 8335.18 7017.63 N 1439.04 E 6042628.38 N 543475.72 E 12045.59 35.033 8.283 8330.41 8372.51 7043.53 N 1442.81 E 6042654.30 N 543479.34 E 12069.69 36.238 8.269 8350.00 8392.10 7057.43 N 1444.83 E 6042668.21 N 543481.29 E 12100.00 37.753 8.253 8374.20 8416.30 7075.47 N 1447.45 E 6042686.27 N 543483.80 E 12200.00 42.753 8.208 8450.50 8492.60 7139.40 N 1456.70 E 6042750.25 N 543492.69 E 12300.00 47.753 8.170 8520.87 8562.97 7209.68 N 1466.81 E 6042820.58 N 543502.40 E 12383.96 51.951 8.143 8575.00 8617.10 7273.19 N 1475.92 E 6042884.15 N 543511.15 E Alaska Drilling & Wells Milne Point MPF Dogleg Vertical Rate Section Comment pi 00ft) 6554.92 ST Exit ® 0.000°/100ft, 0.0000 TF : 11100.70ft MD, 7589.76ft TVD 7" Casing 0.00 6579.48 Top Kingak 0.00 6580.45 TJF 0.00 6581.14 Begin Dir @ 8.000°/100ft : 11160.70ft MD, 7643.50ft TVD 8.00 6599.27 8.00 6636.96 End Dir: 11271.36ft MD, 7738.56ft TVD 0.00 6653.28 0.00 6710.28 0.00 6767.28 0.00 6824.28 0.00 6881.28 0.00 6938.28` 0.00 6995.28 0.00 7052.28 0.00 7078.27 Begin Dir @ 5.0000/100ft: 12045.59ft MD, 8372.51ft TVD 5.00 7092.21 TJC 5.00 7110.32 5.00 7174.47 5.00 7244.98 5.00 7308.71 TJB Continued... 22 November, 2000 - 9.29 - 2 - DrillQuest 2.00.05 Sperry -Sun Drilling Services Proposal Report for MPF-73A WPS - MPF-73A Wp08 Revised: 30 October, 2000 Alaska Drilling & Wells Milne Point Unit Milne Point MPF Measured Sub -Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 12400.00 52.753 8.138 8584.79 8626.89 7285.76 N 1477.71 E 6042896.73 N 543512.87 E 5.00 7321.32 12500.00 57.753 8.110 8641.77 8683.87 7367.08 N 1489.32 E 6042978.11 N 543524.02 E 5.00 7402.91 12544.94 60.000 8.099 8665.00 8707.10 7405.17 N 1494.75 E 6043016.23 N 543529.23 E 5.00 7441.12 End Dir : 12544.94ft MD, 8707.10ft TVD 12600.00 60.000 8.099 8692.53 8734.63 7452.37 N 1501.46 E 6043063.47 N 543535.68 E 0.00 7488.49 12700.00 60.000 8.099 8742.53 8784.63 7538.11 N 1513.66 E 6043149.28 N 543547.39 E 0.00 7574.51 12764.94 60.000 8.099 8775.00 8817.10 7593.79 N 1521.59 E 6043205.00 N 543555.00 E 0.00 7630.37 TSGR (Top Sag) Target - MPF-73A rotary 12800.00 60.000 8.099 8792.53 8834.63 7623.85 N 1525.86 E 6043235.08 N 543559.11 E 0.00 7660.53 12810.95 60.000 8.099 8798.00 8840.10 7633.24 N 1527.20 E 6043244.47 N 543560.39 E 0.00 7669.95 SGC 12838.95 60.000 8.099 8812.00 8854.10 7657.24 N 1530.62 E 6043268.50 N 543563.67 E 0.00 7694.04 SGB 12900.00 60.000 8.099 8842.53 8884.63 7709.59 N 1538.06 E 6043320.89 N 543570.82 E 0.00 7746.56 12914.94 60.000 8.099 8850.00 8892.10 7722.40 N 1539.89 E 6043333.71 N 543572.57 E 0.00 7759.41 SGA 12954.94 60.000 8.099 8870.00 8912.10 7756.69 N 1544.77 E 6043368.03 N 543577.26 E 0.00 7793.82 Top Shublik 13000.00 60.000 8.099 8892.53 8934.63 7795.33 N 1550.27 E 6043406.70 N 543582.54 E 0.00 7832.58 13042.94 60.000 8.099 8914.00 8956.10 7832.15 N 1555.50 E 6043443.54 N 543587.57 E 0.00 7869.52 Total Depth : 13042.94ft MD, 8956.10ft TVD 4 1/2" Liner All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 1.4720 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13042.94ft., The Bottom Hole Displacement is 7985.12ft., in the Direction of 11.2330 (True). Continued... 22 November, 2000 - 9.29 - 3 - DrillQuest 2.00.05 Milne Point Unit Comments Measured Depth (ft) 11100.70 11160.70 11271.36 12045.59 12544.94 Formation Tops Sperry -Sun Drilling Services Proposal Report for MPF-73A WPS - MPF-73A Wp08 Revised: 30 October, 2000 Station Coordinates ND Northings Eastings (ft) (ft) (ft) 7589.76 6522.05 N 1363.39 E 7643.50 6548.13 N 1369.01 E 7738.56 6603.72 N 1378.79 E 8372.51 7043.53 N 1442.81 E 8707.10 7405.17 N 1494.75 E Formati on Plane (Below Well Origin) Sub -Sea Dip Dip Dir. (ft) Deg. Deg. 7298.00 0.000 0.000 7598.00 0.000 0.325 7600.00 0.000 0.325 8350.00 0.000 0.325 8575.00 0.000 0.325 8775.00 0.000 0.325 8798.00 0.000 0.325 8812.00 0.000 0.325 8850.00 0.000 0.325 8870.00 0.000 0.325 Comment ST Exit @ 0.000°/100ft, 0.0000 TF : 11100.70ft MD, 7589.76ft TVD Begin Dir @ 8.0000/100ft : 11160.70ft MD, 7643.50ft TVD End Dir: 11271.36ft MD, 7738.56ft TVD Begin Dir @ 5.000°/100ft : 12045.59ft MD, 8372.51ft TVD End Dir : 12544.94ft MD, 8707.1 Oft TVD P r o f i l e P e n e t r a t i o n P o i n t Measured Vertical Sub -Sea Depth Depth Depth Northings Eastings Formation Name (ft) (ft) (ft) (ft) (ft) 10821.58 7340.10 7298.00 6399.91 N 1337.63 E Top Miluveach 11156.91 7640.10 7598.00 6546.48 N 1368.65 E Top Kingak 11159.14 7642.10 7600.00 6547.45 N 1368.86 E TJF 12069.69 8392.10 8350.00 7057.43 N 1444.83 E TJC 12383.96 8617.10 8575.00 7273.19 N 1475.92 E TJB 12764.94 8817.10 8775.00 7593.79 N 1521.59 E TSGR (Top Sag) 12810.95 8840.10 8798.00 7633.24 N 1527.20 E SGC 12838.95 8854.10 8812.00 7657.24 N 1530.62 E SGB 12914.94 8892.10 8850.00 7722.40 N 1539.89 E SGA 12954.94 8912.10 8870.00 7756.69 N 1544.77 E Top Shublik Alaska Drilling & Wells Milne Point MPF Continued... 22 November, 2000 - 9.29 - 4 - DrillQuest 2.00.05 Milne Point Unit Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) <Surface> <Surface> <Run-TD> <Run-TD> 11100.70 7589.76 11100.70 7589.76 Targets associated with this wellpath Target Name Coil T1 Coil T2 Coil T3 MPF-73A Drillers Sperry -Sun Drilling Services Proposal Report for MPF-73A WPS - MPF-73A Wp08 Revised: 30 October, 2000 Casing Detail 41/2" Liner 7" Casing Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Alaska Drilling & Wells Milne Point MPF Target Entry Coordinates TVD Northings Eastings Target Target (ft) (ft) (ft) Shape Type 8865.10 8144.74 N 1708.71 E Point Geological 8823.00 6043757.00 N 543739.00 E 700 31' 49.5577" N 1490 38' 30.2572" W 8922.10 8720.46 N 1936.98 E Point Geological 8880.00 6044334.00 N 543964.00 E 700 31' 55.2197" N 1490 38' 23.5219" W 8969.10 9844.95 N 2383.35 E Point Geological 8927.00 6045461.00 N 544404.00 E 700 32' 06.2785" N 1490 38' 10.3479" W 8859.10 7634.77 N 1448.33 E Polygon 8817.00 6043245.56 N 543481.51 E 700 31' 44.5423" N 1490 38' 37.9380" W Continued... 22 November, 2000 - 9.29 - 5 - DrillQuest 2.00.05 Tree" FMC 2 9/16" x 5MA PU �� 6rig. KB Bev. = 41.4 ' (N22E� Wellhead: 11 x 7 1/1 6', 5MGen 5a M Orig. GL Bev. = 11 .5' w/ 2 7/8" FMC tbg hng., 3" LHacme It KB To Tbg. Spool = 28.50' (N 22E) threads x 2 7/8" 8rd on bottom, 2.5" CIW H' BPV profile. 20" 91.1 ppf, , H-40 1 12' KOP 0 400' Max. hole angle = 64 to 66 deg. f/ 4, 445' to 8, 627' Hole angle thru' perfs = 26.45 9 5/8" , 40 p pf , L- 80 Bt rc . 1 5,9047]4 2 7/8" 6.5 ppf, L-80, 8 rd EUEtbg. ( drift ID = 2.347" , cap. = 0.00592 bpf ) 7" 26 ppf, L-80, BTGMod production csg. ( d rift ID = 6.151 ", c ap. = 0.0383 b pf ) 5_UmWa1i.Qn_Bamm.a" 06/07/97 - 148.5 K& 16/20 to f lush Eg irfQm11Qn_Bm mm.au BmfJoW GR/CCL 03/1 3/97 Size S PF Interval (TVD) .EL -panda 4.5" 5 10,634'-10,66 ' (7159' -718 83=Rands 4.5" 5 10,712'-10,72 ' (7228' - 7241 B2--SandA 4.5" 6 10,731'-10,75 ' (7246' - 7264 Al_ -Sands 4.5" 5 10 ,7 56'-10, 78 ' (7 268' - 7 395 6 spf 24 gm RDX big hole charges (0.78" EH D, IT P = 7. 88") at 60 de g. p has in g. 5 spf 37 gm RDX Ultra jet charges (0.46" B-ID, TTP= 34.58") at 60 deg. phasing. DAT E REV. BY COMMENTS 03 -10 - 97 BDB Cased hole completion 22E 06/09/97 JBF Initial Completion Nabors 4ES L08 / 16 / 97 MDO # 2 ESP Completion Nabors 4ES 05,'12 M Linder ESP Chan eout Nabors 5S Camco 2 7/8" x 1 " 138' I side pocket KBMM GL M Current Condition 11 /22/00 Centrilift PHD Tw o 7" x 21' marker joints f/ 10,547' - 10,588' 7" float collar (PBTD) 7" float shoe 103 10 430' 10444' 1 O 458' 10463' 10 476'] 10487' 10,997' 11,0 80' m ILNE.POINT UN11 WELL_E=Z.3 AP I J1S2�-54_-Q 2_Q_2?.Z 4,4_-Q4 BP EXPLORATION (A PAY ORDER:. 1'YIPF--13A 11' L 76409no 1:04 L 20 389 5,: 00844 L9ii' WELL PERMIT CHECKLIST COMPANY WELL NAME t- 3 PROGRAM: exp dev redrll V sery wellbore seg ann. disposal para req FIELD &POOL INIT CLASS GEOL AREA UNIT# / /32.ff� ON/OFF SHORE_ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . 2. Lease number appropriate.S�� aold ;e� y- . /.U.- y� I N , N X, 3. Unique well name and number... . . . . . . . .� . . . . . . . T. D • a ,-e- �-k A� c_SSD/8° lf.�o 4. Well located in a defined pool .. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . JN / r � 7. Sufficient acreage available- in drilling unit.. . . . . . . . . . . ,` i 8. If deviated, is wellbore plat included .. . . . . . . . . . . . . . 9. Operator only affected party .. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force . . . . . . . . . . . . . 11. Permit be issued N// I can without conservation order. o! APREZ D TE 12. Permit can be issued without administrative approval.. 1j 13. Can be before 15-day N NHS �'�"'' ��lG °`'�� -" ��'��►'/� C permit approved wait.. . . . . . . . . _� ENGINEERING 14. Conductor string provided . . . . . . . . . . . . . . . . . . . 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. . . 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 . A GI E 26. BOPE press rating appropriate; test tosig. 5 " 27. Choke manifold complies w/API RP-53 (May 84) . . . . . . . , 28. Work will occur without operation shutdown. . . . . . . . . . 29. Is presence of H2S gas probable .. . . . . . . . . . . . . . . . Y N " N Y N Y N N Y N S V4 N N N Y Y NN GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. N 31. Data presented on potential overpressure zones . . . . . . . Y N 32. Seismic analysis of shallow gas zones . . . . . . . . . . . . . Y N AP PR TE 33. Seabed condition survey (if off -shore) . . . . . . . . . . . . . _�� 34. Contact name/phone for weekly progress reports [exploratory ontk7 WN !? ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste. .. Y N to surface; J (C) will not impair mechanical integrity of the well used for disposal; Y N ,J (D) will not damage producing formation or impair recovery from a Y N,.' pool; and E will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: EENNGINEERING: UIC/Annular COMMISSION: Comments/Instructions: Sput- JDH WM DTS TE _3JLA JMH ,•rnn ,l ltd O Z -I M Z M- c:\msoffice\wordian\diana\checklist (rev. 11/01//00) WELL PERMIT CHECKLIST COMPANY �"� WELL NAME ' % PROGRAM: exp dev redrll sery wellbore seg ann. disposal para req FIELD & POOL INIT CLASS .-DV �01e- GEOL AREA UNIT# ON/OFF SHORE d a) ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate.-Ik . . . . . . . . . . . . . . . . . 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. . . . . . . . APPR DATE 12. Permit can be issued without administrative approval.. . /,(2-1.4D 13. Can permit be approved before 15-day wait.. . . . . . . . . . N N�i v�-ti �� : ,1� lv A'. .�X lS�is� )el- p_ N. i�t % r� % [.r ,��--�.e- Z Len %/ , c. � Q fNN V /�2S' ,� �l�,�G .>:r /s?�' l i o� 1QP 6.,TZla_ 8/�S ENGINEERING 14. Conductor string provided . . . . . . . . . . . . . . Y N 15. Surface casing protects all known USDWs. . . . . . Y N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y 18. CMT will cover all known productive horizons. . . . . . . . . . ovc�� rc cvcnobr 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N 20. Adequate tankage or reserve pit .. . . . . . . . . . . . . . . . N 21. If a re -drill, has a 10-403 for abandonment been approved. . . N U - a -SS pcoca�sscti ��laa 22. Adequate wellbore separation proposed .. . . . . . . . . . . . Q. N 23. If diverter required, does it meet regulations . . . . . 24. Drilling fluid program schematic & equip list adequate . . . . . N 25. BOPEs, do they meet regulation . . . . . . . . . Y N �c�,J��-�d►�� PR DATE 26. ROPE press rating appropriate; test to tl�6 psig. N N11 ��C' s�� e S` Sa' cgyL � tt 27. Choke manifold complies w/API RP-53 (May 84) . . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. . . . . N 31. Data presented on potential overpressure zones . . . j 32. Seismic analysis of shallow gas zones. . . . . . . N AP R ATEr 33. Seabed condition survey (if off -shore) . . . . . . . . . . . . ' & Y N �`f C 34. Contact name/phone for weekly progress reports [explorat only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste . .. Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N / GEOLOGY: ENGINEERING: UICYAnnular COMMISSION: SF �W WM OpDTS� �E t, JM 1 llc Q0 Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 11/01//00) 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. 4 Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jan 08 13:17:41 2002 Reel Header Service name.............LISTPE Date .....................02/01/08 origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments.................STS LIS Writing Library. Tape Header Service name.............LISTPE Date .....................02/01/08 Origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Previous Tape Name....... UNKNOWN Comments.................STS LIS Writing Library. Physical EOF Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: MPF-73A API NUMBER: 500292274401 OPERATOR: BP Exploration (Alaska), Inc LOGGING COMPANY: Sperry -Sun Drilling Services TAPE CREATION DATE: 08-JAN-02 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: AK-MW-10120 AK-MW-10120 AK-MW-10120 LOGGING ENGINEER: H. COOMANSIN H. COOMANSIN H. COOMANSIN OPERATOR WITNESS: E. VAUGHN E. VAUGHN E. VAUGHN MWD RUN 4 MWD RUN 5 MWD RUN 6 JOB NUMBER: AK-MW-10120 AK-MW-10120 AK-MW-10120 LOGGING ENGINEER: H. COOMANSIN R. PUDDIPHAT R. PUDDIPHAT OPERATOR WITNESS: E. VAUGHN E. VAUGHN E. VAUGHN MWD RUN 7 MWD RUN 8 MWD RUN 9 JOB NUMBER: AK-MW-10120 AK-MW-10120 AK-MW-10120 LOGGING ENGINEER: S. LATZ B. JAHN B. JAHN OPERATOR WITNESS: WHITLOW/GOOD WHITLOW/SARB WHITLOW / SA MWD RUN 10 MAD RUN 10 JOB NUMBER: AK-MW-10120 AK-MW-10120 LOGGING ENGINEER: B. JAHN B. JAHN OPERATOR WITNESS: WHITLOW / SA WHITLOW / SA SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 6.125 2ND STRING 3.750 3RD STRING PRODUCTION STRING REMARKS: 6 13N 10E 2149 2485 .00 42.10 12.10 CASING DRILLERS SIZE (IN) DEPTH (FT) 7.000 11080.0 4.500 12697.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH SUBSEA (TVDSS). 3. THIS LOG IS A COMPOSITE OF THREE SEPARATE ATTEMPTS. THE FIRST ATTEMPT (MPF-73A PB1) WAS DRILLED IN DECEMBER 2000 WITH A ROTARY RIG TO A TD OF 12758'MD/8775' TVDSS. THIS WELL SECTION WAS TD'D PREMATURELY DUE TO LOST RETURNS. A LINER WAS RUN AND A CTD UNIT WAS RIGGED UP IN APRIL 2001 FOR A SECOND ATTEMPT - (MPF-73A PB2). THIS SECTION KICKED OFF FROM PB1 AT 12697'MD/8747'TVDSS. IT, TOO, WAS TD'D EARLY DUE TO LOST RETURNS (AND POOR RESERVOIR QUALITY) - AT 14256'MD/8824'TVDSS. AN OPEN -HOLE SIDETRACK (MPF-73A) WAS EFFECTED AT 14078'MD/8831'TVDSS. 4. MWD RUNS 1-10 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). A MAD PASS WAS COMPLETED AFTER REACHING THE FINAL TD. 5. DIGITAL DATA ONLY ARE SHIFTED TO THE SCHLUMBERGER CASED -HOLE GAMMA RAY LOG RUN IN MPF-73A P31, ON 01 MARCH 2O01. THIS LOG WAS SUPPLIED TO SSDS BY DEWAYNE SCHNORR ON 20 DECEMBER 2001. ALL LOG AND HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 6. MWD RUNS 1-10 REPRESENT WELL MPF-73A WITH API# 50-029-22744-01. THIS WELL REACHED A TOTAL DEPTH OF 14614'MD/8837'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (EXTRA -SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 11052.0 RPS 11076.0 RPX 11076.0 RPM 11076.0 FET 11076.0 RPD 11076.0 ROP 11094.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) all bit runs merged. STOP DEPTH 14573.5 14584.5 14584.5 14584.5 14584.5 14584.5 14620.5 --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 11052.0 11043.0 11058.0 11049.0 11060.5 11050.5 11084.5 11074.0 11094.5 11087.0 11114.5 11102.0 11130.5 11119.5 11149.5 11140.5 11175.0 11167.0 11195.0 11185.0 11206.0 11197.5 11215.0 11206.5 11233.0 11220.0 11263.0 11253.0 11271.0 11259.5 11299.5 11288.5 11308.0 11297.0 11355.0 11347.0 11383.0 11373.0 11414.5 11426.5 11447.5 11464.5 11483.5 11518.0 11523.5 11531.0 11690.5 11698.5 11829.5 11866.5 11897.5 11966.5 11976.5 11992.5 12026.5 12035.0 12040.0 12058.5 12076.5 12084.5 12104.5 12140.5 12191.0 12214.0 12222.5 12228.5 12237.5 12250.0 12252.0 12264.0 12311.0 12390.5 12448.5 12493.0 12534.5 12553.5 12588.0 12607.0 14573.5 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD REMARKS: 11402.5 11412.5 11438.5 11455.0 11474.5 11507.0 11515.5 11520.0 11677.0 11686.5 11816.0 11851.5 11883.0 11959.0 11967.5 11982.0 12017.5 12024.5 12029.5 12048.0 12065.5 12074.0 12094.5 12128.5 12181.0 12202.5 12211.0 12216.5 12227.0 12239.0 12241.0 12254.0 12299.0 12379.5 12437.0 12484.5 12526.0 12545.0 12582.0 12601.0 14567.5 BIT RUN NO MERGE TOP MERGE BASE 1 11043.0 11469.0 2 11469.0 11718.5 3 11718.5 11940.0 4 11940.0 12480.0 5 12480.0 12617.5 6 12617.5 12697.0 7 12697.5 12945.5 8 12945.5 13688.5 9 13688.5 14078.0 10 14078.0 14614.5 MERGED MAIN PASS. Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11052 14620.5 12836.3 7138 11052 14620.5 ROP MWD FT/H 0.07 2602.36 73.9504 7027 11094.5 14620.5 GR MWD API 54.06 260.16 95.7548 7044 11052 14573.5 RPX MWD OHMM 0.17 663.48 3.87632 7018 11076 14584.5 RPS MWD OHMM 0.18 873.55 3.94964 7018 11076 14584.5 RPM MWD OHMM 0.56 1796.4 5.16668 7018 11076 14584.5 RPD MWD OHMM 0.76 2000 6.34721 7018 11076 14584.5 FET MWD HOUR 0.27 57.78 3.36723 7018 11076 14584.5 First Reading For Entire File .......... 11052 Last Reading For Entire File ........... 14620.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY all MAD runs merged using earliest passes. PBU TOOL CODE START DEPTH STOP DEPTH GR 12623.5 14568.0 RPS 12632.0 14580.0 FET 12632.0 14580.0 RPM 12632.0 14580.0 RPX 12632.0 14580.0 RPD 12632.0 14580.0 RAT 12665.0 14616.5 MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MWD 10 1 12617.5 14614.5 REMARKS: MERGED MAD PASS. Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12623.5 14616.5 13620 3987 12623.5 14616.5 RAT MAD FT/H 948.89 3600 1329.99 3839 12665 14616.5 GR MAD API 48.85 243 74.0763 3890 12623.5 14568 RPX MAD OHMM 0.17 2000 6.51394 3897 12632 14580 RPS MAD OHMM 0.23 2000 19.6373 3897 12632 14580 RPM MAD OHMM 0.25 2000 24.5854 3897 12632 14580 RPD MAD OHMM 0.03 2000 27.7143 3897 12632 14580 FET MAD HOUR 6.48 169.18 91.3072 3897 12632 14580 First Reading For Entire File .......... 12623.5 Last Reading For Entire File ........... 14616.5 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11043.0 11425.5 FET 11065.5 11432.5 RPD 11065.5 11432.5 RPM 11065.5 11432.5 RPS 11065.5 11432.5 RPX 11065.5 11432.5 ROP 11087.0 11469.0 LOG HEADER DATA DATE LOGGED: 23-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11469.0 TOP LOG INTERVAL (FT): 11080.0 BOTTOM LOG INTERVAL (FT): 11469.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 25.0 MAXIMUM ANGLE: 33.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY pb01735grv4 EWR4 ELECTROMAG. RESIS. 4 pb01735grv4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 11.10 MUD VISCOSITY (S): 60.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 32000 FLUID LOSS (C3): 2.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .200 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .094 135.3 MUD FILTRATE AT MT: .110 60.0 MUD CAKE AT MT: .140 60.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11043 11469 11256 853 11043 11469 ROP MWD010 FT/H 0.07 2602.36 58.8319 765 11087 11469 GR MWD010 API 57.91 144.5 109.049 766 11043 11425.5 RPX MWD010 OHMM 0.17 663.48 3.98982 735 11065.5 11432.5 RPS MWD010 OHMM 0.18 873.55 4.49833 735 11065.5 11432.5 RPM MWD010 OHMM 0.56 2000 17.7284 735 11065.5 11432.5 RPD MWD010 OHMM 0.76 2000 27.419 735 11065.5 11432.5 FET MWD010 HOUR 0.795 6.64517 2.75148 735 11065.5 11432.5 First Reading For Entire File .......... 11043 Last Reading For Entire File ........... 11469 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11426.0 11674.0 RPM 11433.0 11682.0 RPX 11433.0 11682.0 RPS 11433.0 11682.0 FET 11433.0 11682.0 RPD 11433.0 11682.0 ROP 11469.5 11718.5 LOG HEADER DATA DATE LOGGED: 24-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11719.0 TOP LOG INTERVAL (FT): 11469.0 BOTTOM LOG INTERVAL (FT): 11719.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 35.0 MAXIMUM ANGLE: 35.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY pb01735grv4 EWR4 ELECTROMAG. RESIS. 4 pb01735grv4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.65 MUD VISCOSITY (S): 60.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 30000 FLUID LOSS (C3): 1.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order DEPT ROP MWD020 GR MWD020 RPX MWD020 RPS MWD020 RPM MWD020 RPD MWD020 FET MWD020 .210 60.0 .095 141.2 .130 60.0 .130 60.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11426 11718.5 11572.3 586 11426 11718.5 ROP MWD020 FT/H 2.13 260.63 61.8117 499 11469.5 11718.5 GR MWD020 API 78.95 228.56 117.294 497 11426 11674 RPX MWD020 OHMM 1.38 4.05 2.31042 499 11433 11682 RPS MWD020 OHMM 1.38 3.86 2.29132 499 11433 11682 RPM MWD020 OHMM 1.38 3.78 2.2796 499 11433 11682 RPD MWD020 OHMM 1.42 3.74 2.34178 499 11433 11682 FET MWD020 HOUR 0.602167 14.8345 3.2212 499 11433 11682 First Reading For Entire File .......... 11426 Last Reading For Entire File ........... 11718.5 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11674.5 11897.0 FET 11682.5 11904.0 RPD 11682.5 11904.0 RPM 11682.5 11904.0 RPS 11682.5 11904.0 RPX 11682.5 11904.0 ROP 11719.0 11940.0 LOG HEADER DATA DATE LOGGED: 25-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11940.0 TOP LOG INTERVAL (FT): 11719.0 BOTTOM LOG INTERVAL (FT): 11940.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 6.8 MAXIMUM ANGLE: 8.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY pb01735grv4 EWR4 ELECTROMAG. RESIS. 4 pb01735grv4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.80 MUD VISCOSITY (S): 54.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 28000 FLUID LOSS (C3): 1.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .250 60.0 MUD AT MAX CIRCULATING TERMPERATURE MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 .112 142.2 .160 60.0 .170 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11674.5 11940 11807.3 532 11674.5 11940 ROP MWD030 FT/H 0.11 90.96 49.0163 443 11719 11940 GR MWD030 API 82.05 155.42 115.022 446 11674.5 11897 RPX MWD030 OHMM 1.46 3.32 2.42529 444 11682.5 11904 RPS MWD030 OHMM 1.46 3.27 2.40273 444 11682.5 11904 RPM MWD030 OHMM 1.4 3.17 2.38617 444 11682.5 11904 RPD MWD030 OHMM 1.5 3.24 2.45637 444 11682.5 11904 FET MWD030 HOUR 0.5385 16.036 4.01872 444 11682.5 11904 First Reading For Entire File .......... 11674.5 Last Reading For Entire File ........... 11940 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name.............STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11897.5 12442.5 RPS 11904.5 12449.5 FET 11904.5 12449.5 RPX 11904.5 12449.5 RPM 11904.5 12449.5 RPD 11904.5 12449.5 ROP 11940.5 12480.0 LOG HEADER DATA DATE LOGGED: 27-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12480.0 TOP LOG INTERVAL (FT): 11940.0 BOTTOM LOG INTERVAL (FT): 12480.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 35.3 MAXIMUM ANGLE: 49.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 1735GRV4/1774W4 EWR4 ELECTROMAG. RESIS. 4 1735GRV4/1774W4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.80 MUD VISCOSITY (S): 54.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3): 2.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .280 62.0 MUD AT MAX CIRCULATING TERMPERATURE: .307 56.0 MUD FILTRATE AT MT: .200 62.0 MUD CAKE AT MT: 1.500 62.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11897.5 12480 12188.8 1166 11897.5 12480 ROP MWD040 FT/H 1.48 99.46 21.3854 1080 11940.5 12480 GR MWD040 API 80 164.16 125.529 1091 11897.5 12442.5 RPX MWD040 OHMM 1.61 6.41 2.775 1091 11904.5 12449.5 RPS MWD040 OHMM 1.66 6.5 2.77933 1091 11904.5 12449.5 RPM MWD040 OHMM 1.67 6.68 2.84661 1091 11904.5 12449.5 RPD MWD040 OHMM 1.71 7.2 2.93954 1091 11904.5 12449.5 FET MWD040 HOUR 1.08483 17.3105 2.86629 1091 11904.5 12449.5 First Reading For Entire File .......... 11897.5 Last Reading For Entire File ........... 12480 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name.............STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12443.0 12580.0 RPX 12450.0 12587.0 RPS 12450.0 12587.0 RPM 12450.0 12587.0 RPD 12450.0 12587.0 FET 12450.0 12587.0 ROP 12480.5 12617.5 LOG HEADER DATA DATE LOGGED: 28-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12618.0 TOP LOG INTERVAL (FT): 12480.0 BOTTOM LOG INTERVAL (FT): 12618.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 51.7 MAXIMUM ANGLE: 51.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 1735GRV4/1774W4 EWR4 ELECTROMAG. RESIS. 4 1735GRV4/1774W4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.80 MUD VISCOSITY (S): 48.0 MUD PH: 8.6 MUD CHLORIDES (PPM): 29500 FLUID LOSS (C3): 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .290 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .104 180.3 MUD FILTRATE AT MT: .200 60.0 MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order DEPT ROP MWD050 GR MWD050 RPX MWD050 RPS MWD050 RPM MWD050 RPD MWD050 FET MWD050 1.400 60.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12443 12617.5 12530.3 350 12443 12617.5 ROP MWD050 FT/H 3 140.02 15.7961 275 12480.5 12617.5 GR MWD050 API 116.96 155.18 139.629 275 12443 12580 RPX MWD050 OHMM 1.01 3.34 2.07436 275 12450 12587 RPS MWD050 OHMM 1.23 4.02 2.37796 275 12450 12587 RPM MWD050 OHMM 1.36 6.12 2.8396 275 12450 12587 RPD MWD050 OHMM 1.61 6.07 2.80822 275 12450 12587 FET MWD050 HOUR 2.47717 24.128 7.67276 275 12450 12587 First Reading For Entire File .......... 12443 Last Reading For Entire File...... ....12617.5 File Trailer Service name.............STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name.............STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12580.5 12697.0 RPX 12587.5 12697.0 FET 12587.5 12697.0 RPD 12587.5 12697.0 RPS 12587.5 12697.0 RPM 12587.5 12697.0 ROP 12618.0 12697.0 LOG HEADER DATA DATE LOGGED: 29-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12697.0 TOP LOG INTERVAL (FT): 12618.0 BOTTOM LOG INTERVAL (FT): 12697.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 61.6 MAXIMUM ANGLE: 62.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 1735GRV4/1774W4 EWR4 ELECTROMAG. RESIS. 4 1735GRV4/1774W4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 11.00 MUD VISCOSITY (S): 47.0 MUD PH: 8.6 MUD CHLORIDES (PPM): 27500 FLUID LOSS (C3): 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .200 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .080 180.0 MUD FILTRATE AT MT: .120 68.0 MUD CAKE AT MT: .330 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order DEPT ROP MWD060 GR MWD060 RPX MWD060 RPS MWD060 RPM MWD060 RPD MWD060 FET MWD060 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12580.5 12697 12638.8 234 12580.5 12697 ROP MWD060 FT/H 1.45 87.47 55.1845 159 12618 12697 GR MWD060 API 94.32 190.14 138.307 234 12580.5 12697 RPX MWD060 OHMM 1.36 10.2 5.28818 220 12587.5 12697 RPS MWD060 OHMM 2.25 10.86 5.86277 220 12587.5 12697 RPM MWD060 OHMM 3.22 12.59 6.99255 220 12587.5 12697 RPD MWD060 OHMM 3.26 13.26 7.29927 220 12587.5 12697 FET MWD060 HOUR 0.698167 16.6722 5.25412 220 12587.5 12697 First Reading For Entire File .......... 12580.5 Last Reading For Entire File ........... 12697 File Trailer Service name.............STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name.............STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 12697.5 12909.5 RPD 12697.5 12909.5 RPM 12697.5 12909.5 RPS 12697.5 12909.5 RPX 12697.5 12909.5 GR 12697.5 12898.5 ROP 12710.5 12945.5 LOG HEADER DATA DATE LOGGED: 10-APR-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12947.0 TOP LOG INTERVAL (FT): 12697.0 BOTTOM LOG INTERVAL (FT): 12947.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 62.2 MAXIMUM ANGLE: 89.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1856RF3 EWR4 ELECTROMAG. RESIS. 4 PBO1856RF3 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: Flo -Pro MUD DENSITY (LB/G): 8.55 MUD VISCOSITY (S): 60.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3): 7.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .160 89.3 MUD AT MAX CIRCULATING TERMPERATURE: .097 152.0 MUD FILTRATE AT MT: .180 89.3 MUD CAKE AT MT: .180 89.3 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order DEPT ROP MWD070 GR MWD070 RPX MWD070 RPS MWD070 RPM MWD070 RPD MWD070 FET MWD070 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12697.5 12945.5 12821.5 497 12697.5 12945.5 ROP MWD070 FT/H 0.99 128.48 64.5027 471 12710.5 12945.5 GR MWD070 API 56.6 260.16 79.4797 403 12697.5 12898.5 RPX MWD070 OHMM 3.99 6.87 4.74642 425 12697.5 12909.5 RPS MWD070 OHMM 4.09 6.88 4.74383 425 12697.5 12909.5 RPM MWD070 OHMM 3.98 6.77 4.77711 425 12697.5 12909.5 RPD MWD070 OHMM 4.33 6.85 4.92508 425 12697.5 12909.5 FET MWD070 HOUR 0.46 15.54 0.967929 425 12697.5 12909.5 First Reading For Entire File .......... 12697.5 Last Reading For Entire File ........... 12945.5 File Trailer Service name.............STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name.............STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12899.0 13641.5 RPS 12910.0 13652.5 FET 12910.0 13652.5 RPX 12910.0 13652.5 RPD 12910.0 13652.0 RPM 12910.0 13652.5 ROP 12946.0 13688.5 LOG HEADER DATA DATE LOGGED: 11-APR-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13688.0 TOP LOG INTERVAL (FT): 12947.0 BOTTOM LOG INTERVAL (FT): 13688.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.3 MAXIMUM ANGLE: 92.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1856RF3 EWR4 ELECTROMAG. RESIS. 4 PBO1856RF3 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: Flo -Pro MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 62.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 20000 FLUID LOSS (C3): 7.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .190 72.7 MUD AT MAX CIRCULATING TERMPERATURE: .085 170.0 MUD FILTRATE AT MT: .280 63.5 MUD CAKE AT MT: .230 61.2 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order DEPT ROP MWD080 GR MWD080 RPX MWD080 RPS MWD080 RPM MWD080 RPD MWD080 FET MWD080 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12899 13688.5 13293.8 1580 12899 13688.5 ROP MWD080 FT/H 15.34 534.56 109.896 1486 12946 13688.5 GR MWD080 API 54.06 106.16 76.8365 1486 12899 13641.5 RPX MWD080 OHMM 2.59 7.36 5.3435 1486 12910 13652.5 RPS MWD080 OHMM 2.66 7.24 5.36066 1486 12910 13652.5 RPM MWD080 OHMM 2.94 7.32 5.37871 1486 12910 13652.5 RPD MWD080 OHMM 2.71 7.33 5.39803 1485 12910 13652 FET MWD080 HOUR 0.27 8.67 1.34273 1486 12910 13652.5 First Reading For Entire File .......... 12899 Last Reading For Entire File ........... 13688.5 File Trailer Service name.............STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name.............STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13642.0 14017.0 RPD 13652.5 14028.5 FET 13653.0 14028.5 RPX 13653.0 14028.5 RPS 13653.0 14028.5 RPM 13653.0 14028.5 ROP 13689.0 14078.0 LOG HEADER DATA DATE LOGGED: 14-APR-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14078.0 TOP LOG INTERVAL (FT): 13688.0 BOTTOM LOG INTERVAL (FT): 14078.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEC MINIMUM ANGLE: 89.0 MAXIMUM ANGLE: 93.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1856RF3 EWR4 ELECTROMAG. RESIS. 4 PBO1856RF3 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: Flo -Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 52.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 18000 FLUID LOSS (C3): 7.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .190 73.0 MUD AT MAX CIRCULATING TERMPERATURE: .085 170.7 MUD FILTRATE AT MT: .280• 64.0 MUD CAKE AT MT: .230 61.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 2 GR MWD090 API 4 1 68 8 3 RPX MWD090 OHMM 4 1 68 12 4 RPS MWD090 OHMM 4 1 68 16 5 RPM MWD090 OHMM 4 1 68 20 6 RPD MWD090 OHMM 4 1 68 24 7 FET MWD090 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13642 14078 13860 873 13642 14078 ROP MWD090 FT/H 11.85 196.52 93.993 779 13689 14078 GR MWD090 API 55.82 111.03 71.5921 751 13642 14017 RPX MWD090 OHMM 3.76 5.63 4.28415 752 13653 14028.5 RPS MWD090 OHMM 3.65 5.57 4.27649 752 13653 14028.5 RPM MWD090 OHMM 3.56 5.62 4.30096 752 13653 14028.5 RPD MWD090 OHMM 3.26 5.44 4.35529 753 13652.5 14028.5 FET MWD090 HOUR 0.33 57.78 7.30815 752 13653 14028.5 First Reading For Entire File .......... 13642 Last Reading For Entire File ........... 14078 File Trailer Service name.............STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.012 Physical EOF File Header Service name.............STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.011 Comment Record FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14017.5 14567.5 FET 14029.0 14578.5 RPD 14029.0 14578.5 RPM 14029.0 14578.5 RPS 14029.0 14578.5 RPX 14029.0 14578.5 ROP 14078.5 14614.5 LOG HEADER DATA DATE LOGGED: 16-APR-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14614.0 TOP LOG INTERVAL (FT): 14078.0 BOTTOM LOG INTERVAL (FT): 14614.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 95.8 MAXIMUM ANGLE: 86.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1856RF3 EWR4 ELECTROMAG. RESIS. 4 PBO1856RF3 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: Flo -Pro MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 52.0 MUD PH: 10.5 MUD CHLORIDES (PPM): 18000 FLUID LOSS (C3): 8.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .200 90.4 MUD AT MAX CIRCULATING TERMPERATURE: .104 179.5 MUD FILTRATE AT MT: .310 68.9 MUD CAKE AT MT: .360 64.2 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD100 FT/H 4 1 68 4 2 GR MWD100 API 4 1 68 8 3 RPX MWD100 OHMM 4 1 68 12 4 RPS MWD100 OHMM 4 1 68 16 5 RPM MWD100 OHMM 4 1 68 20 6 RPD MWD100 OHMM 4 1 68 24 7 FET MWD100 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14017.5 14614.5 14316 1195 14017.5 14614.5 ROP MWD100 FT/H 0.47 673.06 111.095 1073 14078.5 14614.5 GR MWD100 API 54.73 85.41 67.6824 1101 14017.5 14567.5 RPX MWD100 OHMM 1.92 7.2 4.05575 1100 14029 14578.5 RPS MWD100 OHMM 2.47 6.56 4.06916 1100 14029 14578.5 RPM MWD100 OHMM 2.63 6.31 4.09463 1100 14029 14578.5 RPD MWD100 OHMM 2.58 5.94 4.03173 1100 14029 14578.5 FET MWD100 HOUR 0.31 28.74 3.7821 1100 14029 14578.5 First Reading For Entire File .......... 14017.5 Last Reading For Entire File ........... 14614.5 File Trailer Service name.............STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.013 Physical EOF File Header Service name.............STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.012 Comment Record FILE HEADER FILE NUMBER: 13 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 10 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12617.5 14562.0 FET 12626.0 14574.0 RPD 12626.0 14574.0 RPM 12626.0 14574.0 RPS 12626.0 14574.0 RPX 12626.0 14574.0 RAT 12659.0 14610.5 LOG HEADER DATA DATE LOGGED: 16-APR-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14614.0 TOP LOG INTERVAL (FT): 12617.0 BOTTOM LOG INTERVAL (FT): 14614.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 95.8 MAXIMUM ANGLE: 86.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1856RF3 EWR4 ELECTROMAG. RESIS. 4 PBO1856RF3 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: Flo -Pro MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 52.0 MUD PH: 10.5 MUD CHLORIDES (PPM): 18000 FLUID LOSS (C3): 8.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .200 90.4 MUD AT MAX CIRCULATING TERMPERATURE: .104 179.5 MUD FILTRATE AT MT: .310 68.9 MUD CAKE AT MT: .360 64.2 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD101 FT/H 4 1 68 4 2 GR MAD101 API 4 1 68 8 3 RPX MAD101 OHMM 4 1 68 12 4 RPS MAD101 OHMM 4 1 68 16 5 RPM MAD101 OHMM 4 1 68 20 6 RPD MAD101 OHMM 4 1 68 24 7 FET MAD101 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12617.5 14610.5 13614 3987 12617.5 14610.5 RAT MAD101 FT/H 948.89 3600 1329.99 3839 12659 14610.5 GR MAD101 API 48.85 243 74.0763 3890 12617.5 14562 RPX MAD101 OHMM 0.17 2000 6.51394 3897 12626 14574 RPS MAD101 OHMM 0.23 2000 19.6373 3897 12626 14574 RPM MAD101 OHMM 0.25 2000 24.5854 3897 12626 14574 RPD MAD101 OHMM 0.03 2000 27.7143 3897 12626 14574 FET MAD101 HOUR 6.48 169.18 91.3072 3897 12626 14574 First Reading For Entire File .......... 12617.5 Last Reading For Entire File ........... 14610.5 File Trailer Service name.............STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.014 Physical EOF Tape Trailer Service name.............LISTPE Date .....................02/01/08 Origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date .....................02/01/08 Origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments.................STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. Scientific Technical Services Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jan 11 13:22:23 2002 Reel Header Service name.............LISTPE Date .....................02/01/11 Origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date .....................02/01/11 Origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Previous Tape Name....... UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS ' WELL NAME: MPF-73 A PB2 API NUMBER: 500292274471 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry -Sun Drilling Services TAPE CREATION DATE: 11-JAN-02 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: AK-MM-00316 AK-MM-00316 AK-MM-00316 LOGGING ENGINEER: H. COOMANSIN H. COOMANSIN H. COOMANSIN OPERATOR WITNESS: E. VAUGHN E. VAUGHN E. VAUGHN MWD RUN 4 MWD RUN 5 MWD RUN 6 JOB NUMBER: AK-MM-00316 AK-MM-00316 AK-MM-00316 LOGGING ENGINEER: H. COOMANSIN R. PUDDIPHAT R. PUDDIPHAT OPERATOR WITNESS: E. VAUGHN E. VAUGHN E. VAUGHN MWD RUN 7 MWD RUN 8 MWD RUN 9 JOB NUMBER: AK-MW-10120 AK-MW-10120 AK-MW-10120 LOGGING ENGINEER: S. LATZ B. JAHN B. JAHN OPERATOR WITNESS: WHITLOW/GOOD WHITLOW/SARB WHITLOW / SA SURFACE LOCATION SECTION: 6 TOWNSHIP: 13N RANGE: 10E FNL: FSL: 2149 i FEL: 2485 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 42.10 DERRICK FLOOR: GROUND LEVEL: 12.10 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 11080.0 3.750 4.500 12697.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH SUBSEA (TVDSS). 3. MWD DATA FOR MPF-73A PB2 REPRESENT THE SECOND OF THREE ATTEMPTS TO SIDETRACK MPF-73. A CTD UNIT WAS RIGGED UP IN APRIL 2001 FOR THIS SECTION, WHICH KICKED OFF FROM PB1 AT 12697'MD/8747'TVDSS. IT, TOO, WAS TD'D EARLY DUE TO LOST RETURNS (AND POOR RESERVOIR QUALITY) - AT 14256'MD/8824'TVDSS. AN OPEN -HOLE SIDETRACK (MPF-73A) WAS EFFECTED AT 14078'MD/8831'TVDSS (A SEPARATE PRESENTATION). 4. MWD RUNS 1-9 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 ( EWR4) . 5. DIGITAL DATA ONLY ARE SHIFTED TO THE SCHLUMBERGER CASED -HOLE GAMMA RAY LOG RUN IN MPF-73A PB1, ON 01 MARCH 2O01. THIS LOG WAS SUPPLIED TO SSDS BY DEWAYNE SCHNORR ON 20 DECEMBER 2001. ALL LOG AND HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 6. MWD RUNS 1-9 REPRESENT WELL MPF-73A PB2 WITH API# 50-029-22744-71. THIS WELL REACHED A TOTAL DEPTH OF 14256'MD/8824'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (EXTRA -SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 11052.0 14215.5 FET 11076.0 14226.5 RPD 11076.0 14226.5 RPM 11076.0 14226.5 RPS 11076.0 14226.5 RPX 11076.0 14226.5 ROP 11094.5 14262.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 11052.0 11043.0 11058.0 11049.0 11060.5 11050.5 11084.5 11074.0 11094.5 11087.0 11114.5 11102.0 11130.5 11119.5 11149.5 11140.5 11175.0 11167.0 11195.0 11185.0 11206.0 11197.5 11215.0 11206.5 11233.0 11220.0 11263.0 11253.0 11271.0 11259.5 11299.5 11288.5 11308.0 11297.0 11355.0 11347.0 11383.0 11373.0 11414.5 11402.5 11426.5 11412.5 11447.5 11438.5 11464.5 11455.0 11483.5 11474.5 11518.0 11507.0 11523.5 11515.5 11531.0 11520.0 11690.5 11677:0 11698.5 11686.5 11829.5 11816.0 11866.5 11851.5 11897.5 11883.0 11966.5 11959.0 11976.5 11967.5 11992.5 11982.0 12026.5 12017.5 12035.0 12024.5 12040.0 12029.5 12058.5 12048.0 12076.5 12065.5 12084.5 12074.0 12104.5 12094.5 12140.5 12128.5 12191.0 12181.0 12214.0 12202.5 12222.5 12211.0 12228.5 12216.5 12237.5 12227.0 12250.0 12239.0 12252.0 12241.0 12264.0 12254.0 12311.0 12299.0 12390.5 12379.5 12448.5 12437.0 12493.0 12484.5 12534.5 12526.0 12553.5 12545.0 12588.0 12582.0 12607.0 12601.0 14215.5 14209.5 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 11043.0 11469.0 MWD 2 11469.0 11718.5 MWD 3 11718.5 11940.0 MWD 4 11940.0 12480.0 MWD 5 12480.0 12617.5 MWD 6 12617.5 12697.0 MWD 7 12697.0 12945.5 MWD 8 12945.5 13688.5 MWD 9 13688.5 14256.5 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/F 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11052 14262.5 12657.3 6422 11052 14262.5 ROP MWD FT/F 0.07 2602.36 69.3535 6311 11094.5 14262.5 GR MWD API 54.06 260.16 99.3247 6328 11052 14215.5 RPX MWD OHMM 0.17 663.48 3.9293 6302 11076 14226.5 RPS MWD OHMM 0.18 873.55 4.01303 6302 11076 14226.5 RPM MWD OHMM 0.56 1796.4 5.36594 6302 11076 14226.5 RPD MWD OHMM 0.76 2000 6.69318 6302 11076 14226.5 FET MWD HOUR 0.27 57.78 3.14354 6302 11076 14226.5 First Reading For Entire File .......... 11052 Last Reading For Entire File ........... 14262.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11043.0 11425.5 RPX 11065.5 11432.5 RPS 11065.5 11432.5 RPM 11065.5 11432.5 RPD 11065.5 11432.5 FET 11065.5 11432.5 ROP 11087.0 11469.0 LOG HEADER DATA DATE LOGGED: 23-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11469.0 TOP LOG INTERVAL (FT): 11080.0 BOTTOM LOG INTERVAL (FT): 11469.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 25.0 MAXIMUM ANGLE: 33.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY pb01735grv4 EWR4 ELECTROMAG. RESIS. 4 pb01735grv4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value .................... -999 Depth Units ....................... Datum Specification Block sub -type ... 0 I -IN ►A61 LSND 11.10 60.0 9.2 32000 2.5 .200 60.0 .094 135.3 .110 60.0 .140 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11043 11469 11256 853 11043 11469 ROP MWD010 FT/H 0.07 2602.36 58.8319 765 11087 11469 GR MWD010 API 57.91 144.5 109.049 766 11043 11425.5 RPX MWD010 OHMM 0.17 663.48 3.98982 735 11065.5 11432.5 RPS MWD010 OHMM 0.18 873.55 4.49833 735 11065.5 11432.5 RPM MWD010 OHMM 0.56 2000 17.7284 735 11065.5 11432.5 RPD MWD010 OHMM 0.76 2000 27.419 735 11065.5 11432.5 FET MWD010 HOUR 0.795 6.64517 2.75148 735 11065.5 11432.5 First Reading For Entire File .......... 11043 Last Reading For Entire File ........... 11469 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11426.0 11674.0 RPS 11433.0 11682.0 RPM 11433.0 11682.0 FET 11433.0 11682.0 RPX 11433.0 11682.0 RPD 11433.0 11682.0 ROP 11469.5 11718.5 LOG HEADER DATA DATE LOGGED: 24-DEC-00 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) Insite 4.15 Memory 11719.0 11469.0 11719.0 35.0 35.6 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY pb01735grv4 EWR4 ELECTROMAG. RESIS. 4 pb01735grv4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.65 MUD VISCOSITY (S): 60.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 30000 FLUID LOSS (C3): 1.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .210 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .095 141.2 MUD FILTRATE AT MT: .130 60.0 MUD CAKE AT MT: .130 60.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11426 11718.5 11572.3 586 11426 11718.5 ROP MWD020 FT/H 2.13 260.63 61.8117 499 11469.5 11718.5 GR MWD020 API 78.95 228.56 117.294 497 11426 11674 RPX MWD020 OHMM 1.38 4.05 2.31042 499 11433 11682 RPS MWD020 OHMM 1.38 3.86 2.29132 499 11433 11682 RPM MWD020 OHMM 1.38 3.78 2.2796 499 11433 11682 RPD MWD020 OHMM 1.42 3.74 2.34178 499 11433 11682 FET MWD020 HOUR 0.602167 14.8345 3.2212 499 11433 11682 First Reading For Entire File .......... 11426 Last Reading For Entire File ........... 11718.5 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11674.5 11897.0 FET 11682.5 11904.0 RPX 11682.5 11904.0 RPS 11682.5 11904.0 RPD 11682.5 11904.0 RPM 11682.5 11904.0 ROP 11719.0 11940.0 LOG HEADER DATA DATE LOGGED: 25-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11940.0 TOP LOG INTERVAL (FT): 11719.0 BOTTOM LOG INTERVAL (FT): 11940.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 6.8 MAXIMUM ANGLE: 8.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY pb01735grv4 EWR4 ELECTROMAG. RESIS. 4 pb01735grv4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.80 MUD VISCOSITY (S): 54.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 28000 FLUID LOSS (C3): 1.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .250 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .112 142.2 MUD FILTRATE AT MT: .160 60.0 MUD CAKE AT MT: .170 60.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11674.5 11940 11807.3 532 11674.5 11940 ROP MWD030 FT/H 0.11 90.96 49.0163 443 11719 11940 GR MWD030 API 82.05 155.42 115.022 446 11674.5 11897 RPX MWD030 OHMM 1.46 3.32 2.42529 444 11682.5 11904 RPS MWD030 OHMM 1.46 3.27 2.40273 444 11682.5 11904 RPM MWD030 OHMM 1.4 3.17 2.38617 444 11682.5 11904 RPD MWD030 OHMM 1.5 3.24 2.45637 444 11682.5 11904 FET MWD030 HOUR 0.5385 16.036 4.01872 444 11682.5 11904 First Reading For Entire File .......... 11674.5 Last Reading For Entire File ........... 11940 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.004 Comment Record 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: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11897.5 12442.5 RPD 11904.5 12449.5 RPM 11904.5 12449.5 RPS 11904.5 12449.5 RPX 11904.5 12449.5 FET 11904.5 12449.5 ROP 11940.5 12480.0 LOG HEADER DATA DATE LOGGED: 27-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 i DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12480.0 TOP LOG INTERVAL (FT): 11940.0 BOTTOM LOG INTERVAL (FT): 12480.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 35.3 MAXIMUM ANGLE: 49.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 1735GRV4/1774W4 EWR4 ELECTROMAG. RESIS. 4 1735GRV4/1774W4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.80 MUD VISCOSITY (S): 54.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3): 2.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .280 62.0 MUD AT MAX CIRCULATING TERMPERATURE: .307 56.0 MUD FILTRATE AT MT: .200 62.0 MUD CAKE AT MT: 1.500 62.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11897.5 12480 12188.8 1166 11897.5 12480 ROP MWD040 FT/H 1.48 99.46 21.3854 1080 11940.5 12480 GR MWD040 API 80 164.16 125.529 1091 11897.5 12442.5 RPX MWD040 OHMM 1.61 6.41 2.775 1091 11904.5 12449.5 RPS MWD040 OHMM 1.66 6.5 2.77933 1091 11904.5 12449.5 RPM MWD040 OHMM 1.67 6.68 2.84661 1091 11904.5 12449.5 RPD MWD040 OHMM 1.71 7.2 2.93954 1091 11904.5 12449.5 FET MWD040 HOUR 1.08483 17.3105 2.86629 1091 11904.5 12449.5 First Reading For Entire File .......... 11897.5 Last Reading For Entire File ........... 12480 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name.............STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12443.0 12580.0 FET 12450.0 12587.0 RPD 12450.0 12587.0 RPM 12450.0 12587.0 RPS 12450.0 12587.0 RPX 12450.0 12587.0 ROP 12480.5 12617.5 LOG HEADER DATA DATE LOGGED: 28-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12618.0 TOP LOG INTERVAL (FT): 12480.0 BOTTOM LOG INTERVAL (FT): 12618.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 51.7 MAXIMUM ANGLE: 51.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 1735GRV4/1774W4 EWR4 ELECTROMAG. RESIS. 4 1735GRV4/1774W4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.80 MUD VISCOSITY (S): 48.0 MUD PH: 8.6 MUD CHLORIDES (PPM): 29500 FLUID LOSS (C3): 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .290 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .104 180.3 MUD FILTRATE AT MT: .200 60.0 MUD CAKE AT MT: 1.400 60.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12443 12617.5 12530.3 350 12443 12617.5 ROP MWD050 FT/H 3 140.02 15.7961 275 12480.5 12617.5 GR MWD050 API 116.96 155.18 139.629 275 12443 12580 RPX MWD050 OHMM 1.01 3.34 2.07436 275 12450 12587 RPS MWD050 OHMM 1.23 4.02 2.37796 275 12450 12587 RPM MWD050 OHMM 1.36 6.12 2.8396 275 12450 12587 RPD MWD050 OHMM 1.61 6.07 2.80822 275 12450 12587 FET MWD050 HOUR 2.47717 24.128 7.67276 275 12450 12587 First Reading For Entire File .......... 12443 Last Reading For Entire File ........... 12617.5 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name.............STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12580.5 12697.0 RPX 12587.5 12697.0 RPS 12587.5 12697.0 RPM 12587.5 12697.0 RPD 12587.5 12697.0 FET 12587.5 12697.0 ROP 12618.0 12697.0 LOG HEADER DATA DATE LOGGED: 29-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12697.0 TOP LOG INTERVAL (FT): 12618.0 BOTTOM LOG INTERVAL (FT): 12697.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 61.6 MAXIMUM ANGLE: 62.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 1735GRV4/1774W4 EWR4 ELECTROMAG. RESIS. 4 1735GRV4/1774W4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 11.00 MUD VISCOSITY (S): 47.0 MUD PH: 8.6 MUD CHLORIDES (PPM): 27500 FLUID LOSS (C3): 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .200 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .080 180.0 MUD FILTRATE AT MT: .120 68.0 MUD CAKE AT MT: .330 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12580.5 12697 12638.8 234 12580.5 12697 ROP MWD060 FT/H 1.45 87.47 55.1845 159 12618 12697 GR MWD060 API 94.32 190.14 138.307 234 12580.5 12697 RPX MWD060 OHMM 1.36 10.2 5.28818 220 12587.5 12697 RPS MWD060 OHMM 2.25 10.86 5.86277 220 12587.5 12697 RPM MWD060 OHMM 3.22 12.59 6.99255 220 12587.5 12697 RPD MWD060 OHMM 3.26 13.26 7.29927 220 12587.5 12697 FET MWD060 HOUR 0.698167 16.6722 5.25412 220 12587.5 12697 First Reading For Entire File .......... 12580.5 Last Reading For Entire File ........... 12697 File Trailer Service name.............STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name.............STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 12697.5 12909.5 GR 12697.5 12898.5 RPM 12697.5 12909.5 RPD 12697.5 12909.5 FET 12697.5 12909.5 RPX 12697.5 12909.5 ROP 12710.5 12945.5 LOG HEADER DATA DATE LOGGED: 10-APR-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12947.0 TOP LOG INTERVAL (FT): 12697.0 BOTTOM LOG INTERVAL (FT): 12947.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 62.2 MAXIMUM ANGLE: 89.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1856RF3 EWR4 ELECTROMAG. RESIS. 4 PBO1856RF3 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: Flo -Pro MUD DENSITY (LB/G): 8.55 MUD VISCOSITY (S): 60.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3): 7.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .160 89.3 MUD AT MAX CIRCULATING TERMPERATURE: .097 152.0 MUD FILTRATE AT MT: .180 89.3 MUD CAKE AT MT: .180 89.3 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12697.5 12945.5 12821.5 497 12697.5 12945.5 ROP MWD070 FT/H 0.99 128.48 64.5027 471 12710.5 12945.5 GR MWD070 API 56.6 260.16 79.4797 403 12697.5 12898.5 RPX MWD070 OHMM 3.99 6.87 4.74642 425 12697.5 12909.5 RPS MWD070 OHMM 4.09 6.88 4.74383 425 12697.5 12909.5 RPM MWD070 OHMM 3.98 6.77 4.77711 425 12697.5 12909.5 RPD MWD070 OHMM 4.33 6.85 4.92508 425 12697.5 12909.5 FET MWD070 HOUR 0.46 15.54 0.967929 425 12697.5 12909.5 First Reading For Entire File .......... 12697.5 Last Reading For Entire File ........... 12945.5 File Trailer Service name.............STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name.............STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12899.0 13641.5 FET 12910.0 13652.5 RPX 12910.0 13652.5 RPS 12910.0 13652.5 RPD 12910.0 13652.0 RPM 12910.0 13652.5 ROP 12946.0 13688.5 LOG HEADER DATA DATE LOGGED: 11-APR-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13688.0 TOP LOG INTERVAL (FT): 12947.0 BOTTOM LOG INTERVAL (FT): 13688.0 �l BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 80.3 92.9 TOOL NUMBER PBO1856RF3 PBO1856RF3 3.750 Flo -Pro 8.50 62.0 9.0 20000 7.6 .190 .085 .280 .230 Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 72.7 170.0 63.5 61.2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12899 13688.5 13293.8 1580 12899 13688.5 ROP MWD080 FT/H 15.34 534.56 109.896 1486 12946 13688.5 GR MWD080 API 54.06 106.16 76.8365 1486 12899 13641.5 RPX MWD080 OHMM 2.59 7.36 5.3435 1486 12910 13652.5 RPS MWD080 OHMM 2.66 7.24 5.36066 1486 12910 13652.5 RPM MWD080 OHMM 2.94 7.32 5.37871 1486 12910 13652.5 RPD MWD080 OHMM 2.71 7.33 5.39803 1485 12910 13652 FET MWD080 HOUR 0.27 8.67 1.34273 1486 12910 13652.5 First Reading For Entire File .......... 12899 Last Reading For Entire File ........... 13688.5 File Trailer Service name.............STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name.............STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13642.0 14209.5 RPD 13652.5 14220.5 RPM 13653.0 14220.5 RPS 13653.0 14220.5 RPX 13653.0 14220.5 FET 13653.0 14220.5 ROP 13689.0 14256.5 LOG HEADER DATA DATE LOGGED: 14-APR-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14256.0 TOP LOG INTERVAL (FT): 13688.0 BOTTOM LOG INTERVAL (FT): 14256.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 89.0 93.8 TOOL NUMBER PBO1856RF3 PBO1856RF3 3.750 Flo -Pro 8.60 52.0 9.0 18000 7.6 .190 .085 .280 .230 Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 2 GR MWD090 API 4 1 68 8 3 RPX MWD090 OHMM 4 1 68 12 4 RPS MWD090 OHMM 4 1 68 16 5 RPM MWD090 OHMM 4 1 68 20 6 RPD MWD090 OHMM 4 1 68 24 7 FET MWD090 HOUR 4 1 68 28 8 73.0 170.7 64.0 61.0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13642 14256.5 13949.3 1230 13642 14256.5 ROP MWD090 FT/H 1.61 312.51 97.2405 1136 13689 14256.5 OR MWD090 API 55.82 111.03 72.4593 1136 13642 14209.5 RPX MWD090 OHMM 3.76 5.84 4.61395 1136 13653 14220.5 RPS MWD090 OHMM 3.65 5.93 4.63338 1136 13653 14220.5 RPM MWD090 OHMM 3.56 5.95 4.66089 1136 13653 14220.5 RPD MWD090 OHMM 3.26 6.09 4.70547 1137 13652.5 14220.5 FET MWD090 HOUR 0.27 57.78 5.13678 1136 13653 14220.5 First Reading For Entire File .......... 13642 Last Reading For Entire File ........... 14256.5 File Trailer Service name.............STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/11 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.011 Physical EOF Tape Trailer Service name.............LISTPE Date .....................02/01/11 Origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date .....................02/01/11 Origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File 00 Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Dec 18 09:41:30 2001 Reel Header Service name.............LISTPE Date .....................01/12/18 Origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date .....................01/12/18 Origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Previous Tape Name....... UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MPF-73A 500292274401 BP Exploration (Alaska), Inc Sperry -Sun Drilling Services 18-DEC-01 MWD RUN 1 MWD RUN 2 MWD RUN 3 AK-MM-00316 AK-MM-00316 AK-MM-00316 H. COOMANSIN H. COOMANSIN H. COOMANSIN E. VAUGHN E. VAUGHN E. VAUGHN MWD RUN 4 MWD RUN 5 MWD RUN 6 AK-MM-00316 AK-MM-00316 AK-MM-00316 H. COOMANSIN R. PUDDIPHAT R. PUDDIPHAT E. VAUGHN E. VAUGHN E. VAUGHN MWD RUN 7 MWD RUN 8 MWD RUN 9 AK-MW-10120 AK-MW-10120 AK-MW-10120 S. LATZ B. JAHN B. JAHN WHITLOW/GOOD WHITLOW/SARB WHITLOW / SA MWD RUN 10 MAD RUN 10 AK-MW-10120 AK-MW-10120 B. JAHN B. JAHN WHITLOW / SA WHITLOW / SA DI(, ? 8 2001 Aaska Oil & Gas Cons. Commission SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL. ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 6.125 2ND STRING 3.125 3RD STRING PRODUCTION STRING REMARKS: 6 13N 10E 2149 2485 42.10 12.10 CASING DRILLERS SIZE (IN) DEPTH (FT) 7.000 11080.0 4.500 12697.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH SUBSEA (TVDSS). 3. THIS LOG IS A COMPOSITE OF THREE SEPARATE ATTEMPTS. THE FIRST ATTEMPT (MPF-73A PB1) WAS DRILLED IN DECEMBER 2000 WITH A ROTARY RIG TO A TD OF 12758'MD/8775' TVDSS. THIS WELL SECTION WAS TD'D PREMATURELY DUE TO LOST RETURNS. A LINER WAS RUN AND A CTD UNIT WAS RIGGED UP IN APRIL 2001 FOR A SECOND ATTEMPT - (MPF-73A PB2). THIS SECTION KICKED OFF FROM PB1 AT 12697'MD/8747'TVDSS. IT, TOO, WAS TD'D EARLY DUE TO LOST RETURNS (AND POOR RESERVOIR QUALITY) - AT 14256'MD/8824'TVDSS. AN OPEN -HOLE SIDETRACK (MPF-73A) WAS EFFECTED AT 14078'MD/8831'TVDSS. 4. MWD RUNS 1-10 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). A HAD PASS WAS COMPLETED AFTER REACHING THE FINAL TD. 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM DEWAYNE SCHNOOR (GEOQUEST/BP) TO BUSTER BRYANT (SSDS) DATED 12/11/01. 6. MWD RUNS 1-10 REPRESENT WELL MPF-73A WITH API# 50-029-22744-01. THIS WELL REACHED A TOTAL DEPTH OF 14614'MD/8837'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (EXTRA -SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 11043.0 FET 11065.5 RPM 11065.5 RPD 11065.5 RPS 11065.5 RPX 11065.5 ROP 11087.0 all bit runs merged. STOP DEPTH 14567.5 14578.5 14578.5 14578.5 14578.5 14578.5 14614.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 11043.0 11469.0 MWD 2 11469.0 11718.5 MWD 3 11718.5 11940.0 MWD 4 11940.0 12480.0 MWD 5 12480.0 12617.5 MWD 6 12617.5 12697.0 MWD 7 12697.0 12945.5 MWD 8 12945.5 13688.5 MWD 9 13688.5 14078.0 MWD 10 14078.0 14614.5 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction .................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 FET MWD HOUR 4 1 68 16 5 GR MWD API 4 1 68 20 6 ROP MWD FT/H 4 1 68 24 7 RPX MWD OHMM 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11043 14614.5 12828.8 7144 11043 14614.5 RPD MWD OHMM 0.76 2000 6.52057 7027 11065.5 14578.5 RPM MWD OHMM 0.56 2000 5.46654 7027 11065.5 14578.5 RPS MWD OHMM 0.18 873.55 4.00846 7027 11065.5 14578.5 FET MWD HOUR 0.27 57.78 3.33165 7027 11065.5 14578.5 GR MWD API 54.06 260.16 95.8006 7050 11043 14567.5 ROP MWD FT/H 0.07 2602.36 73.958 7056 11087 14614.5 RPX MWD OHMM 0.17 663.48 3.92295 7027' 11065.5 14578.5 First Reading For Entire File .......... 11043 Last Reading For Entire File ........... 14614.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 k , FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 12612.0 14561.5 RPS 12620.5 14573.5 FET 12620.5 14573.5 RPM 12620.5 14573.5 RPX 12620.5 14573.5 RPD 12620.5 14573.5 RAT 12656.5 14610.0 MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MWD 10 1 12612.0 14614.5 REMARKS: MERGED MAD PASS. Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12612 14610 13611 3997 12612 14610 RAT MAD FT/H 948.89 3600 1328.45 3850 12656.5 14610 GR MAD API 48.85 243 74.1859 3899 12612 14561.5 RPX MAD OHMM 0.17 2000 6.50745 3905 12620.5 14573.5 RPS MAD OHMM 0.23 2000 19.6011 3905 12620.5 14573.5 RPM MAD OHMM 0.25 2000 23.516 3905 12620.5 14573.5 RPD MAD OHMM 0.03 2000 27.133 3905 12620.5 14573.5 FET MAD HOUR 6.48 169.18 91.4826 3905 12620.5 14573.5 First Reading For Entire File .......... 12612 Last Reading For Entire File ........... 14610 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11043.0 11425.5 FET 11065.5 11432.5 RPD 11065.5 11432.5 RPM 11065.5 11432.5 RPS 11065.5 11432.5 RPX 11065.5 11432.5 ROP 11087.0 11469.0 LOG HEADER DATA DATE LOGGED: 23-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11469.0 TOP LOG INTERVAL (FT): 11080.0 BOTTOM LOG INTERVAL (FT): 11469.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 25.0 MAXIMUM ANGLE: 33.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY pb01735grv4 EWR4 ELECTROMAG. RESIS. 4 pb01735grv4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 11080.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 11.10 MUD VISCOSITY (S): 60.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 32000 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 2.5 .200 60.0 .094 135.3 .110 60.0 .140 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD010 API 4 1 68 4 2 ROP MWD010 FT/H 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11043 11469 11256 853 11043 11469 GR MWD010 API 57.91 144.5 109.049 766 11043 11425.5 ROP MWD010 FT/H 0.07 2602.36 58.8319 765 11087 11469 RPX MWD010 OHMM 0.17 663.48 3.98982 735 11065.5 11432.5 RPS MWD010 OHMM 0.18 873.55 4.49833 735 11065.5 11432.5 RPM MWD010 OHMM 0.56 2000 17.7284 735 11065.5 11432.5 RPD MWD010 OHMM 0.76 2000 27.419 735 11065.5 11432.5 FET MWD010 HOUR 0.795 6.64517 2.75148 735 11065.5 11432.5 First Reading For Entire File .......... 11043 Last Reading For Entire File ........... 11469 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11426.0 11674.0 RPX 11433.0 11682.0 RPM 11433.0 11682.0 RPS 11433.0 11682.0 FET 11433.0 11682.0 RPD 11433.0 11682.0 ROP 11469.5 11718.5 LOG HEADER DATA DATE LOGGED: 24-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11719.0 TOP LOG INTERVAL (FT): 11469.0 BOTTOM LOG INTERVAL (FT): 11719.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 35.0 MAXIMUM ANGLE: 35.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY pb01735grv4 EWR4 ELECTROMAG. RESIS. 4 pb01735grv4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 11080.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.65 MUD VISCOSITY (S): 60.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 30000 FLUID LOSS (C3): 1.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .210 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .095 141.2 MUD FILTRATE AT MT: .130 60.0 MUD CAKE AT MT: .130 60.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11426 11718.5 11572.3 586 11426 11718.5 GR MWD020 API 78.95 228.56 117.294 497 11426 11674 ROP MWD020 FT/H 2.13 260.63 61.8117 499 11469.5 11718.5 RPX MWD020 OHMM 1.38 4.05 2.31042 499 11433 11682 RPS MWD020 OHMM 1.38 3.86 2.29132 499 11433 11682 RPM MWD020 OHMM 1.38 3.78 2.2796 499 11433 11682 RPD MWD020 OHMM 1.42 3.74 2.34178 499 11433 11682 FET MWD020 HOUR 0.602167 14.8345 3.2212 499 11433 11682 First Reading For Entire File .......... 11426 Last Reading For Entire File ........... 11718.5 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11674.5 11897.0 FET 11682.5 11904.0 RPD 11682.5 11904.0 RPM 11682.5 11904.0 RPS 11682.5 11904.0 RPX 11682.5 11904.0 ROP 11719.0 11940.0 LOG HEADER DATA DATE LOGGED: 25-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11940.0 TOP LOG INTERVAL (FT): 11719.0 BOTTOM LOG INTERVAL (FT): 11940.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 6.8 MAXIMUM ANGLE: 8.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY pb01735grv4 EWR4 ELECTROMAG. RESIS. 4 pb01735grv4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 11080.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.80 MUD VISCOSITY (S): 54.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 28000 FLUID LOSS (C3): 1.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .250 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .112 142.2 MUD FILTRATE AT MT: .160 60.0 MUD CAKE AT MT: .170 60.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11674.5 11940 11807.3 532 11674.5 11940 GR MWD030 API 82.05 155.42 115.022 446 11674.5 11897 ROP MWD030 FT/H 0.11 90.96 49.0163 443 11719 11940 RPX MWD030 OHMM 1.46 3.32 2.42529 444 11682.5 11904 RPS MWD030 OHMM 1.46 3.27 2.40273 444 11682.5 11904 RPM MWD030 OHMM 1.4 3.17 2.38617 444 11682.5 11904 RPD MWD030 OHMM 1.5 3.24 2.45637 444 11682.5 11904 FET MWD030 HOUR 0.5385 16.036 4.01872 444 11682.5 11904 First Reading For Entire File .......... 11674.5 Last Reading For Entire File ........... 11940 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name.............STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11897.5 12442.5 RPS 11904.5 12449.5 RPX 11904.5 12449.5 RPM 11904.5 12449.5 RPD 11904.5 12449.5 FET 11904.5 12449.5 ROP 11940.5 12480.0 LOG HEADER DATA DATE LOGGED: 27-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12480.0 TOP LOG INTERVAL (FT): 11940.0 BOTTOM LOG INTERVAL (FT): 12480.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 35.3 MAXIMUM ANGLE: 49.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY pb01735grv4 EWR4 ELECTROMAG. RESIS. 4 pb01735grv4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 11080.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.80 MUD VISCOSITY (S): 54.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3): 2.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .280 62.0 MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order DEPT GR MWD040 ROP MWD040 RPX MWD040 RPS MWD040 RPM MWD040 RPD MWD040 FET MWD040 .307 56.0 .200 62.0 1.500 62.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 API 4 1 68 4 2 FT/H 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11897.5 12480 12188.8 1166 11897.5 12480 GR MWD040 API 80 164.16 125.529 1091 11897.5 12442.5 ROP MWD040 FT/H 1.48 99.46 21.3854 1080 11940.5 12480 RPX MWD040 OHMM 1.61 6.41 2.775 1091 11904.5 12449.5 RPS MWD040 OHMM 1.66 6.5 2.77933 1091 11904.5 12449.5 RPM MWD040 OHMM 1.67 6.68 2.84661 1091 11904.5 12449.5 RPD MWD040 OHMM 1.71 7.2 2.93954 1091 11904.5 12449.5 FET MWD040 HOUR 1.08483 17.3105 2.86629 1091 11904.5 12449.5 First Reading For Entire File .......... 11897.5 Last Reading For Entire File ........... 12480 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name.............STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12443.0 12580.0 RPS 12450.0 12587.0 RPM 12450.0 12587.0 RPD 12450.0 12587.0 FET 12450.0 12587.0 RPX 12450.0 12587.0 ROP 12480.5 12617.5 LOG HEADER DATA DATE LOGGED: 28-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12618.0 TOP LOG INTERVAL (FT): 12480.0 BOTTOM LOG INTERVAL (FT): 12618.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 51.7 MAXIMUM ANGLE: 51.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY pb01735grv4 EWR4 ELECTROMAG. RESIS. 4 pb01735grv4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 11080.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.80 MUD VISCOSITY (S): 48.0 MUD PH: 8.6 MUD CHLORIDES (PPM): 29500 FLUID LOSS (C3): 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .290 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .104 180.3 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 .200 60.0 1.400 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD050 API 4 1 68 4 2 ROP MWD050 FT/H 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12443 12617.5 12530.3 350 12443 12617.5 GR MWD050 API 116.96 155.18 139.629 275 12443 12580 ROP MWD050 FT/H 3 140.02 15.7961 275 12480.5 12617.5 RPX MWD050 OHMM 1.01 3.34 2.07436 275 12450 12587 RPS MWD050 OHMM 1.23 4.02 2.37796 275 12450 12587 RPM MWD050 OHMM 1.36 6.12 2.8396 275 12450 12587 RPD MWD050 OHMM 1.61 6.07 2.80822 275 12450 12587 FET MWD050 HOUR 2.47717 24.128 7.67276 275 12450 12587 First Reading For Entire File .......... 12443 Last Reading For Entire File ........... 12617.5 File Trailer Service name.............STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name.............STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12580.5 12714.5 RPM 12587.5 12721.5 RPD 12587.5 12721.5 RPS 12587.5 12721.5 RPX 12587.5 12721.5 FET 12587.5 12721.5 ROP 12618.0 12757.5 LOG HEADER DATA DATE LOGGED: 29-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12697.0 TOP LOG INTERVAL (FT): 12618.0 BOTTOM LOG INTERVAL (FT): 12697.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 61.6 MAXIMUM ANGLE: 62.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY pb01735grv4 EWR4 ELECTROMAG. RESIS. 4 pb01735grv4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 11080.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 11.00 MUD VISCOSITY (S): 47.0 MUD PH: 8.6 MUD CHLORIDES (PPM): 27500 FLUID LOSS (C3): 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .200 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .080 180.0 MUD FILTRATE AT MT: .120 68.0 MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 .330 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD060 API 4 1 68 4 2 ROP MWD060 FT/H 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12580.5 12757.5 12669 355 12580.5 12757.5 GR MWD060 API 82.7 257.03 139.247 269 12580.5 12714.5 ROP MWD060 FT/H 1.35 90.66 53.9314 280 12618 12757.5 RPX MWD060 OHMM 1.36 10.2 5.28249 269 12587.5 12721.5 RPS MWD060 OHMM 2.25 10.86 5.8358 269 12587.5 12721.5 RPM MWD060 OHMM 3.22 12.59 6.79454 269 12587.5 12721.5 RPD MWD060 OHMM 3.26 13.26 7.10115 269 12587.5 12721.5 FET MWD060 HOUR 0.698167 16.6722 4.44257 269 12587.5 12721.5 First Reading For Entire File .......... 12580.5 Last Reading For Entire File ........... 12757.5 File Trailer Service name.............STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name.............STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12662.5 12898.5 RPM 12674.5 12909.5 RPX 12674.5 12909.5 FET 12674.5 12909.5 RPD 12674.5 12909.5 RPS 12674.5 12909.5 ROP 12710.5 12945.5 LOG HEADER DATA DATE LOGGED: 10-APR-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12947.0 TOP LOG INTERVAL (FT): 12697.0 BOTTOM LOG INTERVAL (FT): 12947.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 62.2 MAXIMUM ANGLE: 89.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1856RF3 EWR4 ELECTROMAG. RESIS. 4 PBO1856RF3 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.125 DRILLER'S CASING DEPTH (FT): 12697.0 BOREHOLE CONDITIONS MUD TYPE: Flo -Pro MUD DENSITY (LB/G): 8.55 MUD VISCOSITY (S): 60.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3): 7.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .160 89.3 MUD AT MAX CIRCULATING TERMPERATURE: .097 152.0 MUD FILTRATE AT MT: .180 89.3 MUD CAKE AT MT: .180 89.3 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12662.5 12945.5 12804 567 12662.5 12945.5 ROP MWD070 FT/H 0.99 128.48 64.5027 471 12710.5 12945.5 GR MWD070 API 56.6 260.16 83.3454 473 12662.5 12898.5 RPX MWD070 OHMM 0.65 6.87 4.64811 471 12674.5 12909.5 RPS MWD070 OHMM 3.86 2000 27.8852 471 12674.5 12909.5 RPM MWD070 OHMM 3.93 34.37 5.01603 471 12674.5 12909.5 RPD MWD070 OHMM 3.54 18.12 5.03395 471 12674.5 12909.5 FET MWD070 HOUR 0.46 16.18 2.42724 471 12674.5 12909.5 First Reading For Entire File .......... 12662.5 Last Reading For Entire File ........... 12945.5 File Trailer Service name.............STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name.............STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12899.0 13641.5 RPM 12910.0 13652.5 RPX 12910.0 13652.5 RPS 12910.0 13652.5 RPD 12910.0 13652.0 FET 12910.0 13652.5 ROP 12946.0 13688.5 LOG HEADER DATA DATE LOGGED: 11-APR-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13688.0 TOP LOG INTERVAL (FT): 12947.0 BOTTOM LOG INTERVAL (FT): 13688.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.3 MAXIMUM ANGLE: 92.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1856RF3 EWR4 ELECTROMAG. RESIS. 4 PBO1856RF3 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 3.125 12697.0 Flo -Pro 8.50 62.0 9.0 20000 7.6 .190 72.7 .085 170.0 .280 63.5 .230 61.2 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12899 13688.5 13293.8 1580 12899 13688.5 ROP MWD080 FT/H 15.34 534.56 109.896 1486 12946 13688.5 GR MWD080 API 54.06 106.16 76.8365 1486 12899 13641.5 RPX MWD080 OHMM 2.59 7.36 5.3435 1486 12910 13652.5 RPS MWD080 OHMM 2.66 7.24 5.36066 1486 12910 13652.5 RPM MWDO80 OHMM 2.94 7.32 5.37871 1486 12910 13652.5 RPD MWD080 OHMM 2.71 7.33 5.39803 1485 12910 13652 FET MWD080 HOUR 0.27 8.67 1.34273 1486 12910 13652.5 First Reading For Entire File .......... 12899 Last Reading For Entire File ........... 13688.5 File Trailer Service name.............STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name.............STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13642.0 14209.5 RPD 13652.5 14220.5 RPX 13653.0 14220.5 RPS 13653.0 14220.5 RPM 13653.0 14220.5 FET 13653.0 14220.5 ROP 13689.0 14256.5 LOG HEADER DATA DATE LOGGED: 14-APR-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14078.0 TOP LOG INTERVAL (FT): 13688.0 BOTTOM LOG INTERVAL (FT): 14078.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.0 MAXIMUM ANGLE: 93.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1856RF3 EWR4 ELECTROMAG. RESIS. 4 PBO1856RF3 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.125 DRILLER'S CASING DEPTH (FT): 12697.0 BOREHOLE CONDITIONS MUD TYPE: Flo -Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 52.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 18000 FLUID LOSS (C3): 7.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .190 73.0 MUD AT MAX CIRCULATING TERMPERATURE: .085 170.7 MUD FILTRATE AT MT: .280 64.0 MUD CAKE AT MT: .230 61.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 2 GR MWD090 API 4 1 68 8 3 RPX MWD090 OHMM 4 1 68 12 4 RPS MWD090 OHMM 4 1 68 16 5 RPM MWD090 OHMM 4 1 68 20 6 RPD MWD090 OHMM 4 1 68 24 7 FET MWD090 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13642 14256.5 13949.3 1230 13642 14256.5 ROP MWD090 FT/H 1.61 312.51 97.2405 1136 13689 14256.5 GR MWD090 API 55.82 111.03 72.4593 1136 13642 14209.5 RPX MWD090 OHMM 3.76 5.84 4.61395 1136 13653 14220.5 RPS MWD090 OHMM 3.65 5.93 4.63338 1136 13653 14220.5 RPM MWD090 OHMM 3.56 5.95 4.66089 1136 13653 14220.5 RPD MWD090 OHMM 3.26 6.09 4.70547 1137 13652.5 14220.5 FET MWD090 HOUR 0.27 57.78 5.13678 1136 13653 14220.5 First Reading For Entire File .......... 13642 Last Reading For Entire File ........... 14256.5 File Trailer Service name.............STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.012 Physical EOF File Header Service name.............STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.011 Comment Record FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14017.5 14567.5 FET 14029.0 14578.5 RPD 14029.0 14578.5 RPM 14029.0 14578.5 RPS 14029.0 14578.5 RPX 14029.0 14578.5 ROP 14064.5 14614.5 LOG HEADER DATA DATE LOGGED: 16-APR-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14614.0 TOP LOG INTERVAL (FT): 14078.0 BOTTOM LOG INTERVAL (FT): 14614.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 95.8 MAXIMUM ANGLE: 86.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1856RF3 EWR4 ELECTROMAG. RESIS. 4 PBO1856RF3 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 3.125 12697.0 Flo -Pro 8.50 52.0 10.5 18000 8.6 .200 90.4 .104 179.5 .310 68.9 .360 64.2 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .11N Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD100 FT/H 4 1 68 4 2 GR MWD100 API 4 1 68 8 3 RPX MWD100 OHMM 4 1 68 12 4 RPS MWD100 OHMM 4 1 68 16 5 RPM MWD100 OHMM 4 1 68 20 6 RPD MWD100 OHMM 4 1 68 24 7 FET MWD100 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14017.5 14614.5 14316 1195 14017.5 14614.5 ROP MWD100 FT/H 0.47 673.06 109.085 1101 14064.5 14614.5 GR MWD100 API 54.73 85.41 67.6824 1101 14017.5 14567.5 RPX MWD100 OHMM 1.92 7.2 4.05575 1100 14029 14578.5 RPS MWD100 OHMM 2.47 6.56 4.06916 1100 14029 14578.5 RPM MWD100 OHMM 2.63 6.31 4.09463 1100 .14029 14578.5 RPD MWD100 OHMM 2.58 5.94 4.03173 1100 14029 14578.5 FET MWD100 HOUR 0.31 28.74 3.7821 1100 14029 14578.5 First Reading For Entire File .......... 14017.5 Last Reading For Entire File ........... 14614.5 File Trailer Service name.............STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.013 Physical EOF File Header Service name.............STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.012 Comment Record FILE HEADER FILE NUMBER: 13 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 10 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12612.0 14561.5 FET 12620.5 14573.5 RPX 12620.5 14573.5 RPS 12620.5 14573.5 RPM 12620.5 14573.5 RPD 12620.5 14573.5 RAT 12656.5 14610.0 LOG HEADER DATA DATE LOGGED: 16-APR-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14614.0 TOP LOG INTERVAL (FT): 14078.0 BOTTOM LOG INTERVAL (FT): 14614.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 95.8 MAXIMUM ANGLE: 86.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1856RF3 EWR4 ELECTROMAG. RESIS. 4 PBO1856RF3 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.125 DRILLER'S CASING DEPTH (FT): 12697.0 BOREHOLE CONDITIONS MUD TYPE: Flo -Pro MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 52.0 MUD PH: 10.5 MUD CHLORIDES (PPM): 18000 FLUID LOSS (C3): 8.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .200 90.4 MUD AT MAX CIRCULATING TERMPERATURE: .104 179.5 MUD FILTRATE AT MT: .310 68.9 MUD CAKE AT MT: .360 64.2 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD101 FT/H 4 1 68 4 2 RPD MAD101 OHMM 4 1 68 8 3 RPM MAD101 OHMM 4 1 68 12 4 RPS MAD101 OHMM 4 1 68 16 5 RPX MAD101 OHMM 4 1 68 20 6 FET MAD101 HOUR 4 1 68 24 7 GR MAD101 API 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12612 14610 13611 3997 12612 14610 RAT MAD101 FT/H 948.89 3600 1328.45 3850 12656.5 14610 RPD MAD101 OHMM 0.03 2000 27.133 3905 12620.5 14573.5 RPM MAD101 OHMM 0.25 2000 23.516 3905 12620.5 14573.5 RPS MAD101 OHMM 0.23 2000 19.6011 3905 12620.5 14573.5 RPX MAD101 OHMM 0.17 2000 6.50745 3905 12620.5 14573.5 FET MAD101 HOUR 6.48 169.18 91.4826 3905 12620.5 14573.5 GR MAD101 API 48.85 243 74.1859 3899 12612 14561.5 First Reading For Entire File .......... 12612 Last Reading For Entire File ........... 14610 File Trailer Service name.............STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/18 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.014 Physical EOF Tape Trailer Service name.............LISTPE Date .....................01/12/18 Origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date .....................01/12/18 Origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments.................STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. Scientific Technical Services o�oo -/ 9g Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jan 09 15:04:29 2002 Reel Header Service name.............LISTPE Date .....................02/01/09 Origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments.................STS LIS Writing Library Tape Header Service name.............LISTPE Date .....................02/01/09 Origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Previous Tape Name....... UNKNOWN Comments.................STS LIS Writing Library. Physical EOF Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: MPF-73A PB1 API NUMBER: 500292274470 OPERATOR: BP Exploration (Alaska), Inc. LOGGING COMPANY: Sperry -Sun Drilling Services TAPE CREATION DATE: 09-JAN-02 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: AK-MM-00316 AK-MM-00316 AK-MM-00316 LOGGING ENGINEER: H. COOMANSIN H. COOMANSIN H. COOMANSIN OPERATOR WITNESS: E. VAUGHN E. VAUGHN E. VAUGHN MWD RUN 4 MWD RUN 5 MWD RUN 6 JOB NUMBER: AK-MM-00316 AK-MM-00316 AK-MM-00316 LOGGING ENGINEER: H. COOMANSIN R. PUDDIPHAT R. PUDDIPHAT OPERATOR WITNESS: E. VAUGHN E. VAUGHN E. VAUGHN SURFACE LOCATION SECTION: 6 TOWNSHIP: 13N RANGE: 10E FNL: FSL: 2149 FEL: 2485 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 42.10 GROUND LEVEL: 12.10 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 11080.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH SUBSEA (TVDSS). 3. MWD DATA FOR MPF-73A PB1 REPRESENT THE FIRST OF THREE ATTEMPTS TO SIDETRACK MPF-73. THIS SECTION WAS DRILLED IN DECEMBER 2000 WITH A ROTARY RIG TO A TD OF 12758'MD/8775'TVDSS. THIS WELL SECTION WAS TD'D PREMATURELY DUE TO LOST RETURNS. A LINER WAS RUN AND A CTD UNIT WAS RIGGED UP IN APRIL 2001 FOR A SECOND ATTEMPT - (MPF-73A PB2). THIS SECTION KICKED OFF FROM PB1 AT 12697'MD/8747'TVDSS. IT, TOO, WAS TD'D EARLY DUE TO LOST RETURNS (AND POOR RESERVOIR QUALITY) - AT 14256'MD/ 8824'TVDSS. AN OPEN -HOLE SIDETRACK (MPF-73A) WAS EFFECTED AT 14078'MD/ 8831'TVDSS. 4. MWD RUNS 1-6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 5. DIGITAL DATA ONLY ARE SHIFTED TO THE SCHLUMBERGER CASED -HOLE GAMMA RAY LOG RUN IN MPF-73A PB1, ON 01 MARCH 2O01. THIS LOG WAS SUPPLIED TO SSDS BY DEWAYNE SCHNORR ON 20 DECEMBER 2001. ALL LOG AND HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 6. MWD RUNS 1-6 REPRESENT WELL MPF-73A PB1 WITH API# 50-029-22744-70. THIS WELL REACHED A TOTAL DEPTH OF 12758'MD/8775'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (EXTRA -SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/09 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 11052.0 12720.5 FET 11076.0 12727.5 RPD 11076.0 12727.5 RPM 11076.0 12727.5 RPS 11076.0 12727.5 RPX 11076.0 12727.5 ROP 11094.5 12763.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------ BASELINE DEPTH GR 11052.0 11043.0 11058.0 11049.0 11060.5 11050.5 11084.5 11074.0 11094.5 11087.0 11114.5 11102.0 11130.5 11119.5 11149.5 11140.5 11175.0 11167.0 11195.0 11185.0 11206.0 11197.5 11215.0 11206.5 11233.0 11220.0 11263.0 11253.0 11271.0 11259.5 11299.5 11288.5 11308.0 11297.0 11355.0 11347.0 11383.0 11373.0 11414.5 11402.5 11426.5 11412.5 11447.5 11438.5 11464.5 11455.0 11483.5 11474.5 11518.0 11507.0 11523.5 11515.5 11531.0 11520.0 11690.5 11677.0 11698.5 11686.5 11829.5 11816.0 11866.5 11851.5 11897.5 11883.0 11966.5 11959.0 11976.5 11967.5 11992.5 11982.0 12026.5 12017.5 12035.0 12024.5 12040.0 12029.5 12058.5 12048.0 12076.5 12065.5 12084.5 12074.0 12104.5 12094.5 12140.5 12128.5 12191.0 12181.0 12214.0 12202.5 12222.5 12211.0 12228.5 12216.5 12237.5 12227.0 12250.0 12239.0 12252.0 12241.0 12264.0 12254.0 12311.0 12299.0 12390.5 12379.5 12448.5 12437.0 12493.0 12484.5 12534.5 12526.0 12553.5 12545.0 12588.0 12582.0 12607.0 12601.0 12720.5 12714.5 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 1 11043.0 MWD 2 11469.0 MWD 3 11718.5 MWD 4 11940.0 MWD 5 12480.0 MWD 6 12617.5 REMARKS: MERGED MAIN PASS. MERGE BASE 11469.0 11718.5 11940.0 12480.0 12617.5 12757.5 Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11052 12763.5 11907.8 3424 11052 12763.5 ROP MWD FT/H 0.07 2602.36 41.888 3339 11094.5 12763.5 GR MWD API 57.91 257.03 121.359 3338 11052 12720.5 RPX MWD OHMM 0.17 663.48 2.97244 3304 11076 12727.5 RPS MWD OHMM 0.18 873.55 3.12486 3304 11076 12727.5 RPM MWD OHMM 0.56 1796.4 5.68635 3304 11076 12727.5 RPD MWD OHMM 0.76 2000 8.17961 3304 11076 12727.5 FET MWD HOUR 0.5385 24.0783 3.51322 3304 11076 12727.5 First Reading For Entire File .......... 11052 Last Reading For Entire File ........... 12763.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/09 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/09 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11043.0 11425.5 FET 11065.5 11432.5 RPX 11065.5 11432.5 RPS 11065.5 11432.5 RPD 11065.5 11432.5 RPM 11065.5 11432.5 ROP 11087.0 11469.0 LOG HEADER DATA DATE LOGGED: 23-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11469.0 TOP LOG INTERVAL (FT): 11080.0 BOTTOM LOG INTERVAL (FT): 11469.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 25.0 MAXIMUM ANGLE: 33.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY pb01735grv4 EWR4 ELECTROMAG. RESIS. 4 pb01735grv4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order DEPT ROP MWD010 GR MWD010 RPX MWD010 RPS MWD010 RPM MWD010 RPD MWD010 FET MWD010 6.125 LSND 11.10 60.0 9.2 32000 2.5 .200 60.0 .094 135.3 .110 60.0 .140 60.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11043 11469 11256 853 11043 11469 ROP MWD010 FT/H 0.07 2602.36 58.8319 765 11087 11469 GR MWD010 API 57.91 144.5 109.049 766 11043 11425.5 RPX MWD010 OHMM 0.17 663.48 3.98982 735 11065.5 11432.5 RPS MWD010 OHMM 0.18 873.55 4.49833 735 11065.5 11432.5 RPM MWD010 OHMM 0.56 2000 17.7284 735 11065.5 11432.5 RPD MWD010 OHMM 0.76 2000 27.419 735 11065.5 11432.5 FET MWD010 HOUR 0.795 6.64517 2.75148 735 11065.5 11432.5 First Reading For Entire File .......... 11043 Last Reading For Entire File ........... 11469 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/09 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/09 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11426.0 11674.0 FET 11433.0 11682.0 RPD 11433.0 11682.0 RPM 11433.0 11682.0 RPS 11433.0 11682.0 RPX 11433.0 11682.0 ROP 11469.5 11718.5 LOG HEADER DATA DATE LOGGED: 24-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): Memory M TD DRILLER (FT): 11719.0 TOP LOG INTERVAL (FT): 11469.0 BOTTOM LOG INTERVAL (FT): 11719.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 35.0 MAXIMUM ANGLE: 35.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY pb01735grv4 EWR4 ELECTROMAG. RESIS. 4 pb01735grv4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.65 MUD VISCOSITY (S): 60.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 30000 FLUID LOSS (C3): 1.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .210 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .095 141.2 MUD FILTRATE AT MT: .130 60.0 MUD CAKE AT MT: .130 60.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order DEPT ROP MWD020 GR MWD020 RPX MWD020 RPS MWD020 RPM MWD020 RPD MWD020 FET MWD020 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11426 11718.5 11572.3 586 11426 11718.5 ROP MWD020 FT/H 2.13 260.63 61.8117 499 11469.5 11718.5 GR MWD020 API 78.95 228.56 117.294 497 11426 11674 RPX MWD020 OHMM 1.38 4.05 2.31042 499 11433 11682 RPS MWD020 OHMM 1.38 3.86 2.29132 499 11433 11682 RPM MWD020 OHMM 1.38 3.78 2.2796 499 11433 11682 RPD MWD020 OHMM 1.42 3.74 2.34178 499 11433 11682 FET MWD020 HOUR 0.602167 14.8345 3.2212 499 11433 11682 First Reading For Entire File .......... 11426 Last Reading For Entire File ........... 11718.5 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/09 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/09 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11674.5 11897.0 RPX 11682.5 11904.0 RPS 11682.5 11904.0 FET 11682.5 11904.0 RPD 11682.5 11904.0 RPM 11682.5 11904.0 ROP 11719.0 11940.0 LOG HEADER DATA DATE LOGGED: 25-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11940.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 11719.0 11940.0 6.8 8.0 TOOL NUMBER pb01735grv4 pb01735grv4 6.125 LSND 10.80 54.0 8.8 28000 1.8 .250 60.0 .112 142.2 .160 60.0 .170 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11674.5 11940 11807.3 532 11674.5 11940 ROP MWD030 FT/H 0.11 90.96 49.0163 443 11719 11940 GR MWD030 API 82.05 155.42 115.022 446 11674.5 11897 RPX MWD030 OHMM 1.46 3.32 2.42529 444 11682.5 11904 RPS MWD030 OHMM 1.46 3.27 2.40273 444 11682.5 11904 RPM MWD030 OHMM 1.4 3.17 2.38617 444 11682.5 11904 RPD MWD030 OHMM 1.5 3.24 2.45637 444 11682.5 11904 FET MWD030 HOUR 0.5385 16.036 4.01872 444 11682.5 11904 First Reading For Entire File .......... 11674.5 Last Reading For Entire File ........... 11940 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/09 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/09 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.004 Comment Record 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: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11897.5 12442.5 FET 11904.5 12449.5 RPD 11904.5 12449.5 RPM 11904.5 12449.5 RPS 11904.5 12449.5 RPX 11904.5 12449.5 ROP 11940.5 12480.0 LOG HEADER DATA DATE LOGGED: 27-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12480.0 TOP LOG INTERVAL (FT): 11940.0 r' BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order DEPT ROP MWD040 GR MWD040 RPX MWD040 RPS MWD040 RPM MWD040 RPD MWD040 FET MWD040 12480.0 35.3 49.7 TOOL NUMBER 1735GRV4/1774W4 1735GRV4/1774W4 6.125 LSND 10.80 54.0 8.5 25000 2.3 .280 .307 .200 1.500 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 62.0 56.0 62.0 62.0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11897.5 12480 12188.8 1166 11897.5 12480 ROP MWD040 FT/H 1.48 99.46 21.3854 1080 11940.5 12480 GR MWD040 API 80 164.16 125.529 1091 11897.5 12442.5 RPX MWD040 OHMM 1.61 6.41 2.775 1091 11904.5 12449.5 RPS MWD040 OHMM 1.66 6.5 2.77933 1091 11904.5 12449.5 RPM MWD040 OHMM 1.67 6.68 2.84661 1091 11904.5 12449.5 RPD MWD040 OHMM 1.71 7.2 2.93954 1091 11904.5 12449.5 FET MWD040 HOUR 1.08483 17.3105 2.86629 1091 11904.5 12449.5 First Reading For Entire File .......... 11897.5 Last Reading For Entire File ........... 12480 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/09 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name.............STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/09 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12443.0 12580.0 RPX 12450.0 12587.0 RPS 12450.0 12587.0 RPM 12450.0 12587.0 RPD 12450.0 12587.0 FET 12450.0 12587.0 ROP 12480.5 12617.5 LOG HEADER DATA DATE LOGGED: 28-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12618.0 TOP LOG INTERVAL (FT): 12480.0 BOTTOM LOG INTERVAL (FT): 12618.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 51.7 51.7 TOOL NUMBER 1735GRV4/1774W4 1735GRV4/1774W4 6.125 LSND 10.80 48.0 8.6 29500 2.0 .290 .104 .200 1.400 Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 60.0 180.3 60.0 60.0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12443 12617.5 12530.3 350 12443 12617.5 ROP MWD050 FT/H 3 140.02 15.7961 275 12480.5 12617.5 GR MWD050 API 116.96 155.18 139.629 275 12443 12580 RPX MWD050 OHMM 1.01 3.34 2.07436 275 12450 12587 RPS MWD050 OHMM 1.23 4.02 2.37796 275 12450 12587 RPM MWD050 OHMM 1.36 6.12 2.8396 275 12450 12587 RPD MWD050 OHMM 1.61 6.07 2.80822 275 12450 12587 FET MWD050 HOUR 2.47717 24.128 7.67276 275 12450 12587 First Reading For Entire File .......... 12443 Last Reading For Entire File ........... 12617.5 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/09 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name.............STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/09 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12580.5 12714.5 RPD 12587.5 12721.5 RPM 12587.5 12721.5 RPS 12587.5 12721.5 RPX 12587.5 12721.5 FET 12587.5 12721.5 ROP 12618.0 12757.5 LOG HEADER DATA DATE LOGGED: 29-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12758.0 TOP LOG INTERVAL (FT): 12618.0 BOTTOM LOG INTERVAL (FT): 12758.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): •BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 61.6 62.2 TOOL NUMBER 1735GRV4/1774W4 1735GRV4/1774W4 6.125 LSND 11.00 47.0 8.6 27500 2.0 .200 .080 .120 .330 Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 68.0 180.0 68.0 68.0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12580.5 12757.5 12669 355 12580.5 12757.5 ROP MWD060 FT/H 1.35 90.66 53.9314 280 12618 12757.5 GR MWD060 API 82.7 257.03 139.247 269 12580.5 12714.5 RPX MWD060 OHMM 1.36 10.2 5.28249 269 12587.5 12721.5 RPS MWD060 OHMM 2.25 10.86 5.8358 269 12587.5 12721.5 RPM MWD060 OHMM 3.22 12.59 6.79454 269 12587.5 12721.5 RPD MWD060 OHMM 3.26 13.26 7.10115 269 12587.5 12721.5 FET MWD060 HOUR 0.698167 16.6722 4.44257 269 12587.5 12721.5 First Reading For Entire File .......... 12580.5 Last Reading For Entire File ........... 12757.5 File Trailer Service name.............STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/09 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name.............LISTPE Date .....................02/01/09 Origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments.................STS LIS Writing Library. Reel Trailer Service name.............LISTPE Date .....................02/01/09 Origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments.................STS LIS Writing Library Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File