The URL can be used to link to this page

Home My WebLink About195-136Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /¢5"~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Diann~than Lowell Isl [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si • • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 "' Anchorage, Alaska 99519 -6612 December 30, 2011 S NED FEB t . Mr. Tom Maunder i q Alaska Oil and Gas Conservation Commission �" I 333 West 7 Avenue Anchorage, Alaska 99501 MY 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 111111 III BP Exploration Alaska P � ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF -02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top job MPF -34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF -45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 WA 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 WA 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NN 2.0 WA 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF -69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 ~ 9 11 ' MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF-79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF-81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF-83 2000930 50029229630000 1.2 N/A 1.2 N/A 13.6 8/3/2011 MPF -84B 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI N REPORTOF SUNDRY WELL OPERAONS Well Status after work: Water Source Well 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory ° 195 -136 3. Address: ® Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 a 50 -029- 22594 -00 -00 7. Property Designation: 8. Well Name and Number: ADL025509 � MPF - 9. Field / Pool(s): o� Milne Point Unit •2 I Q. 1 10. Present well condition summary Total depth: measured 3700 feet Plugs (measured) None true vertical 3270 feet Junk (measured) None Effective depth: measured 3592 feet Packer: measured 2688'& 3240' feet true vertical 3178 feet true vertical 2413'& 2880' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 75' 20" 110' 110' 1490 470 Surface 3644' 9 -5/8" 3678' 3251' 5750 3090 Intermediate Production Liner I►WAflfio GU �yG f IU Perforation Depth: Measured Depth: 2450'- 3226' True Vertical Depth: 2211' - 2868' Tubing (size, grade, measured and true vertical depth): 5 -1/2 ", 17# L -80 2282' MD 2068' TVD Packers and SSSV (type, measured and true vertical depth): 9.5/8" HES Verstrieve Packer 2688' MD 2413' TVD 9 HES BWD Sump Packer 3240' MD 2880' TVD 11. Stimulation or cement squeeze summary: d ,� Intervals treated (measured): E I Treatment description including volumes used and final pressure: 4 �� MCA Oil a 53 C am 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 280 2406 Subsequent to operation: 0 0 0 0 2411 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ® Daily Report of Well Operations ❑ Development ® Service ❑ Exploratory ❑ Stratigraphic ® Well Schematic Diagram 15. Well Status ❑ Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ Suspended after work: ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG WTR Q J 16. 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: Contact David Bjork, 564 -5683 1 NIA Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number. Signature Phone 564 -4750 Date Sondra Stewman, 564-4750 Fo Mse 00t ,lO Submit Original Only V AW Tree: CIW 4 1/16" 5M 'FLS'W MPU F-77 WSW Orig. KB el 46.8' (N 27E) Wellhead 11" x 12" 5M FMC Gen 6 Orig. GL lev. = 12.9' Unibore w/ two 2" 5M valves on side e 27E RKB To 7" landing ring = 33.97' ports 11 " 5M x 4 1/16" 5M adapter and 11 x 4.5" Tbg Hgr 4.5" NSCT thread top and bottom and 4" CIW-H BPV profile. 20" 91.1 ppf, H-40 Note: Restriction at tubing hanger Well is equipped with a 4-1/2" tree, tubing hanger & 4 1/2" pup joints KOP @ 250' while completed with 5-1/2" tubing. Max. hole angle= 32 deg. f/ 1200' to TD. Minimum ID through tubing hanger & Hole angle through perfs = 32 deg. pup joints at the top is 3.992". Note: Hanger was pulled for a RWO 03/08/98, Penetrator was found to Centrilift No. 1, CL-81 Cable be bad, cable checked out landed hangler. Did not pull pump. Casing weight change 9 2086' %L 5.5", 17 ppf, L-80 IBT Btr. tubing (cap. = 0.0233 bpf, drift = 4.767") Centrilift Tandem Pumps 9 5/8" Production Casing: HC 12500 ESP, MT SXD & UT SXD 47 ppf, N-80 BTC f/ 2086' to shoe 40 ppf, L-80 BTC f/ hgr to 2086' Centrilift Pump Intake (cap. = 0.0732 bpf, drift = 8.525" min) LT SXD Intake = 2011' TVD (cap w/ 5 1/2" inside = 0.0464) Centrilift Tandem Seals 223177 HS63DBUTPBEHLPFS & HSB3DBLTABCL61NVT, Gravel Pack Summary: Gravel packed w/ > 8,000 lbs of 20-40 Centrilift Motor HMI, 725 Series Carbolite. 800 hp /4225 v/ 114 amp 6 Fin Centralizer 2280' Minimum gravel pack restriction = 2.97" safety shear sub 9 2709' md. 9 5/8" HES Versatrieve pkr. 2688' and Closing sleeve ass'bly 2694' and Perforation Summary: 5 1/2", 20 ppf, N-80, LTC 2712' and Ref log: Open hole MWD - 09/14/95 blank pipe (ID = 4.778" 5 1/2", 0.01 Ga. pre-pack 2816' and Size SP F Interval (TVD) screen OD = 4.778" adng� San I HES Honed Tube �L 12 282 '- (2482' - 2518') (1 D = 6.071 3034' and — vc" Sand 4.5" 12 2947'- 2962' (2584' - 2598') 5 1/2", 0.01 Ga. screen 3036' and (ID = 4.778") 4.5" 12 2980'- 3008' (2612' - 2636') J L HES 9 5/8" 'BWD'sump pkr 3240' wlm 2832'TVD 4.5" 1 12 3113'- 3226' , (2726' - 2820) 26 gm. Jumbo Jet charges 9 60 deg. Float collar (PBTD) phasing (w/ 0.74" EHID and 5.8" TTP), MOMMA 3592' and w/ 135 / 45 deg. phasing 9.625" csg. shoe 3678' and DATE REV. BY COMMENTS MILNE POINT UNIT 09/16/95 JBF Drilled and Cased by Nabors 27E 01/26/96 JBF ESP Completion by Nabors 4ES WELL F-77 WSW 04/24/96 JBF Recompletion by Nabors 4ES API NO: 50-029-22594 12/17/96 MDO #3 ESP Completion 4 ES 10/6/10 L. Hulme Recompletion by Nabors 4ES I BP EXPLORATION (AK) • MPF -77 Well History Date Summary 09/24/10 T /1= 700/280 Temp =on line PPPOT -T (PASS) (Pre Rig) PPPOT -T : RU 1 HP BT onto THA 0 psi. Pressured to 5000 psi for 30 minutes, 5000/ 30 min. Bled void to 0 psi, cycle and torque LDS "ET style" all functioned with no problems. RD test equipment. 09/27/10 T/I = 0/320. Freeze protected flowline with 5bbls meth, 5bbls 60/40. Bled to zero. Freeze protected tubing w/ 5bbls meth, 60bbls 60/40. FWHP's = 0/230. Swab, laterals = shut. Wing, SSV, Master, IA = open. 09/28/10 Freeze protected flowline to injection header w/ 6bbls 60/40. Shut root valve and bled header to zero. 09/30/10 MPU Well Support Tech's « « < » » »» the demobed well house, flowlines and foundation and 2nd IA work valve installed. NOTE: well is a singel block on high pressure water side of boster pump discharge. we will have to take down the can pumps and maintain 2400 psi in order for the single block veryentc to be inacordence with policy to be legal. 10/07/10 T /1 =0/0 Post RWO Freeze Protect Pumped 115 bbls diesel down IA & 60 bbls 60/40 down Tbg. DSO notified swab wing ssv shut, master is open. FWHP's= 100/140 10/09/10 Load & Transport Diesel 10/12/10 The Well Support Techs rigged up and set the foundation, removed the 2nd IA valve, installed the flowline, installed the wellhouse, pulled the BPV and set a TWC to pressure test tree which had to be turned to hook the flowline up. They remove the TWC. Tree was tested to 5000 psi and the flowline to 3600 psi. NOTE: » » »» »All tests were GOOD and the BPV/TWC were left OUT « « « «« Page 1 of 1 Notch America;- ALASKA BP Page1''o# 1° b C?*atian Summary Report _ ' Common Well Name: MPF -77 AFE No Event Type: MOBILIZATION (MOB) Start Date: 10/3/2010 End Date: X4- OORN5 -E (50,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 10/3/2010 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292259400 Active Datum: 80: 77 3/7/1998 12:00 @59.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/4/2010 06:00 - 10:00 4.00 MOB P PRE PJSM AND RD RIG -SCOPE AND LOWER DERRICK -PREP FOR RIG MOVE AND PJSM WITH PEAK CREW 10:00 - 13:00 3.00 MOB P PRE PULL OFF OF MPU F -13, WITNESSED BY WSL AND TOOLPUSHER - MOBILIZE TO MPU F -77 13:00 17:30 4.50 MOB P PRE PULL OVER MP F -77 WITNESSED BY TOOLPUSHERAND WSL 17:30 21:00 3.50 MOB P PRE RU TO RAISE AND SCOPE DERRICK - WHILE SCOPING THE DERRICK UP, A DAVIT ARM THAT IS USED TO HANG A FALL ARREST, GOT HUNG UP ON A HAND RAIL ON THE CROWN, NOTHING FELL TO THE GROUNDM, AND NO PART OF THE DERRICK INTEGRITY WAS COMPRAMISED. TOOL PUSHER DID A FULL INSPECTION HIM SELF AND OK THE WORK TO CONTINUE. - TAKING ON FLUIDS, 8.4 PPG SOURCE WATER FROM MILNE PT ORT. RIG ACCEPTED AT 19:00 BOPE TEST WITNESSE WAIVED BY CHUCK SHEVE OF AOGCC @ 16:20 21:00 - 22:00 1.00 MOB P PRE PU MU AND PT LUBRICATOR TO 250 PSI LOW & 1200 PSI HIGH, CHARTED WELL SUPPORT TECH PULLED THE BPV WHP'S - TBG-30 PSI, 300 -I.A. - LID LUBRICATOR I Printed 11/4/2010 9:53:23AM N.orth "America - ALASKA BP Pam i 3 of Operation ; Summary - Report Common Well Name: MPF -77 AFE No Event Type: WORKOVER (WO) Start Date: 10/4/2010 End Date: X4- OORN5 -E (350,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 10/3/2010 12:00:OOAM Rig Release: Rig Contractor: N ABORS ALASKA DRILLING INC. UWI: 500292259400 Act ive Datum: 80 : 77 3/7/1 12 :00 @59.70ft (above Mean Sea Lev el) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/4/2010 22:00 22:30 0.50 KILLW P DECOMP TESTING SURFACE LINES TO 3500 PSI PT LINE TO TIGER TANK TO 1000 PSI. FLUID SHOT TAKEN BY WELLSUPPORT, FLUID LOOKS TO BE 500' DOWN. 22:30 - 00:00 1.50 KILLW P DECOMP PJSM FOR WELL KILL OPERAITONS - CIRCULATED 8.4 PPG SOURCE WATER DOWN THE TUBING TAKING RETURNS TO THE TIGER TANK. CIRCULATED A TOTAL OF 182 BBLS @ 4 BPM AT 580 PSI. - LOST TOTAL OF 109 BBLS DURING CIRCULATION. - SHUT IN AND MONITORED WELL FOR 1/2 HOUR. WELL IS DEAD AND ON A SLIGHT VAC. 10/5/2010 00:00 - 01:30 1.50 WHSUR P DECOMP FMC REP SET 4" CIW TWC - ATTEMPTED A ROLLING TEST FROM BELOW, - PUMPED @ 5 BPM REACHING 150 PSI, PUMPED TOTAL OF 50 BBLS. TESTED FROM ABOVE 3500 PSI FOR 10 CHARTED MIN 01:30 02:30 1.00 WHSUR P DECOMP PJSM: BARRIERS IN PLACE ARE THE TBG HANGER & THE TESTED TWC - MU THE 4 -1/2" NSCT CROSS OVER TO THE HANGER, & RECORD TURNS TO MU 8 FULL TURNS FOR MAKE UP. - EVACUATION DRILL: H2S DRILLER CALLED FOR A RIG EVACUATION DRILL, A MOC SHUT IN WAS INITIATED. CREW AND THIRD PARTY MUSTERED TO THE SHOP AT THE EDGE OF LOCATION. AAR: DRILL WENT WELL, CREWS MUSTERED IN A TIMELY FASHION AND LOCATED ROSTER & ACCOUNTED FOR EVERY ONE ON LOCATION. A MINOR MISTAKE ON THE DRILLERS PART WAS HE ANNOUNCED THE MUSTER AREA ONCE AS THE SHOP AND ONCE AS THE RIG CAMP, AS THEY ARE BOTH CLOSE TOGETHER. 02:30 - 04:00 1.50 BOPSUR P DECOMP NU 13 -5/8" 5K HYDRIL BOP NU BOP WITH 3 -1/2" BY 6" VBR'S - NU CHOKE & KILL LINES - HOOK UP KOOMEY LINES & TURN BUCKLES, INSTALL FLOW RISER CONTINUOUS HOLE FILL IN THE I.A. @ 20 BPH. FUNCTION TEST BOP & KOOMEY Printed 11/4/2010 9:53:47AM arth America - ALASKQ _BP Page Operation Summary ;Report Common Well Name: MPF -77 AFE No Event Type: WORKOVER (WO) Start Date: 10/4/2010 End Date: X4- OORN5 -E (350,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 10/3/2010 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292259400 Acti Datum: 80: 77 3/7/1998 12:00 @59.70ft (above Mean Sea Le vel) - - - - - - -- -- -- -- - - -- -- - -— -- -- - - - - - - -- Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 10:30 6.50 BOPSUR P DECOMP MU BOP TEST ASSEMBLY - FILL BOP STACK AND PURGE AIR FROM THE SYSTEM TEST 13-5/8", 5K, HYDRIL BOP. � - TEST BOPE & ANNULAR TO 250 PSI LOW AND 3500 PSI HIGH - TEST BLINDS, CHOKE MANIFOLD VALVES, CHOKE AND KILL LINE VALVES, 3 -1/2" X 6" VBR'S & ANNUAL PREVENTER. TEST ANNULAR AND VBR'S WITH 5 -1/2" TEST JOINT. - COMPLETE ACCUMULATOR SYSTEM DRAW DOWN TEST 200 PSI BUILD TO 1750 FROM 1550 PSI IN 41 SECONDS FULL BUILDUP TO 3000 PSI IN 171 SECONDS -4 BOTTLES @ 1975 PSI -BOPE TEST WITNESSED BY NABORS TOOLPUSHER AND BP WSL -TEST WITNESS WAIVED BY CHUCK SCHEVE OF AOGCC 10/4/10 @ 16:20 HELD FIRE DRILL AND TESTED ALARM AT 08:00 10:30 - 11:00 0.50 BOPSUR P DECOMP RD BOPE TEST EQUIPMENT 11:00 - 12:00 1.00 WHSUR P DECOMP WEEKLY SAFETY MEETING WITH CREWS ALSO ATTENDED BY ADW FIELD SUPERINTENDANT KEN MILLER. 12:00 - 12:30 0.50 WHSUR- P DECOMP PJSM FOR RU OF LUBRICATOR AND PULLING 2 WAY CHECK 12:30 - 14:00 1.50 WHSUR P DECOMP RU DSM LUBRICATOR TO BOP ANNULAR USING DUTCH RISER SYSTEM - PT RISER TO 250 PSI AND 1200 PSI FOR 5 MIN EACH, CHARTED - PULLED 2 WAY CHECK WITH LUBRICATOR -NO PRESSURE - WELL WAS ON A VAC -RD LUBRICATOR AND SEND OUT 14:00 - 15:00 1.00 PULL P DECOMP PJSM, MU LANDING JOINT WITH FLOOR VALVE -MU TO TUBING HANGER WITH 8 TURNS. -OPEN IA VALVE AND CONFIRM NO PRESSURE ON IA - WITNESSED BY WSL AND IA WAS STATIC. - BACK OUT LDS AND VERIFY IA IS STILL STATIC PRIOR TO SHUTTING IN IA. *SLOW PUMP RATES: 1 BPM @ 80 PSI 2 BPM @110 PSI 3 BPM @ 340 PSI 15:00 - 16:30 1.50 PULL P DECOMP PULL TUBING HANGER FREE WITH UP WT OF 47 K. -LD TUBING HANGER AND CROSS OVERS Printed 11/4/2010 9:53:47AM orth:America - ALASKA - BP-, _ Page Qperation Summary Report Co mmon Well Name: MPF -77 AFE No Event Type: WORKOVER (WO) Start Date: 10/4/2010 End Date: X4- OORN5 -E (350,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 10/3/2010 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292259400 Active Datum: 80: 77 3/7/1998 12 :00 @59.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 17:00 0.50 PULL P DECOMP ATTEMPTED TO CIRCULATE BU OF 118 BBLS -GOT SMALL RETURNS AFTER 39 BBLS -ONLY ACHIEVED —10% RETURN RATE - CONFFER WITH TOWN ENGINEER TO ABANDON BU AFTER --95 BBLS IN AND 83 BBLS LOST. - VERIFY TUBIING AND IA WERE DEAD -RD CURCULATING EQUIPMENT 17:00 - 22:00 5.00 PULL P DECOMP RU TO LD 5.5" TUBING AND ESP CABLE. PJSM, LD 5.5" TUBING AND CABLE WHILE CONTINUOSLY FILLING HOLE WITH CHARGE PUMP. LAID DOWN 54 JTS & RECOVERED 136 STEEL BANDS 22:00 00:00 2.00 PULL P DECOMP PJSM. L/D ESP PUMP ASSEMBLY. 10/6/2010 00:00 - 00:30 0.50 PULL P DECOMP CONTINUE TO L/D ESP ASSEMBLY. 00:30 - 01:30 1.00 PULL P DECOMP CLEAR / CLEAN RIG FLOOR. 01:30 - 07:30 6.00 RUNCOM P RUNCMP PJSM. PICKUP AND SERVICE ESP MOTOR ASSY. 07:30 - 08:00 0.50 RUNCOM P RUNCMP ESP POT HEAD (725 MLE) WILL NOT FEED THROUGH 'DOUBLE- SHEAVE' IN DERRICK. 08:00 - 10:00 2.00 RUNCOM P RUNCMP PJSM -DRY RUN ESP POT HEAD THROUGH SINGLE' SHEAVE AT GROUND LEVEL. OK HANG'SINGLE SHEAVE IN DERRICK AND PULL ESP CABLE OVER. 10:00 - 11:00 1.00 RUNCOM P RUNCMP MU ESP MOTOR LEAD 11:00 - 15:00 4.00 RUNCOM P RUNCMP PU USED 5 1/2" IBT 17# L -80 TUBING WITH NEW SEAL RINGS. RUN 27 JOINTS WHILE MAINTAINING CONTINUOS HOLE FILL AT — 20 BPH with 8.4 PPG LAKE WATER 15:00 - 15:30 0.50 RUNCOM P RUNCMP PERFORM CENTRALIFT CONDUCTIVITY TEST - PUMP 3 BPM AT 300 PSI, 10 BLS THROUGH PUMP PUMP 16 BBLS TO FILL 15:30 17:30 2.00 RUNCOM P RUNCMP CONTINUE TO RUN ESP COMPLETION FROM JOINT #27 TO 54 WITH CONTINOUSE HOLE FILL WITH 8.4 PPG LAKE WATER RAN 56 CANNON CLAMPS & 5 PROTECTROLIZERS. 1 17:30 - 18:30 1.00 RUNCOM P RUNCMP PU LANDING JOINT WITH TIW VALVE AND PU TUBING HANGER -MU TUBING HANGER TO TUBING 18:30 - 19:30 1.00 RUNCOM P RUNCMP MAKE PENETRATOR SPLICE AND INSTALL TO TUBING HANGER WITH CENTRILIFT AND FMC REPS 19:30 - 20:30 1.00 RUNCOM P RUNCMP LAND TUBING HANGER FMC RI LDS LD LANDING JOINT 20:30 - 22:00 1.50 RUNCOM P RUNCMP SET TWO WAY CHECK - TEST FROM ABOVE 3500 PSI / 10 MIN / CHARTED, OK. - TEST FROM BELOW, 5 BPM / 100 PSI, 70 BBLS PUMPED AWAY/ CHARTED 22:00 - 23:00 1.00 BOPSUR P RUNCMP PJSM. C/O RAMS IN BOP STACK - REMOVE 3 1/2" X 6" VBRS - INSTALL 2 7/8" X 5" VBRS 23:00 - 00:00 1.00 BOPSUR P RUNCMP PJS N/D 13 5/8" X 5M BOPE. . Printed 11/4/2010 9:53:47AM ,AWcrth America = ALASKA -ESP Pale 4 of ! opera #ion.Summary Report Common Well Name: MPF -77 AFE No Event Type: WORKOVER (WO) Start Date: 10/4/2010 End Date: X4- OORN5 -E (350,000.00 ) i Project: Milne Point Site: M Pt F Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 10/3/2010 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292259400 A cti ve Datum: 80: 77 3/7/1998 12: 00 @59.70ft (above Mean Sea Date From - To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/7/2010 � 00:00 01:00 1.00 BOPSUR P RUNCMP CONTINUE TO N/D 13 5/8" X 5M BOPE. 01:00 02:30 1.50 WHSUR P RUNCMP PJ N/U ADAPTER FLANGE & TREE. 02:30 - 03:30 1.00 WHSUR P RUNCMP PERFORM FINAL TESTS ON ESP CABLE, OK. - PRESSURE TEST HANGER & VOID, 5000 PSI / 30 MIN / CHARTED. - PRESSURE TEST TREE, 5000 PSI / 5 MIN / CHARTED, OK. 03:30 05:00 1.50 WHSUR P RUNCMP PJSM..P /U LUBRICATOR, P TEST @ 250 / 2000 PSI / CHARTED, OK PULL TWO WAY CHECK VALVE. - SET BPV. 05:00 06:00 1.00 WHSUR P RUNCMP TEST BPV FROM BELOW. - PUMP @ 5 BPM / 100 PSI, 75 BBLS - CHARTED TEST. - SECURE WELL, RIG RELEASED 06:00 010. Printed 11/4/2010 9:53:47AM RE: Milne Point K-pad water supply well MPK-34 (PTD #1961690)... e e Subject: RE: .l'v1ilnc Point K-pad water supply well MPK-34 (PTD #1961(90) and F-Pad \....aler supply wells M,P,F-02, 21, 58, and'V'7:{PTD # 1960700, :If 1961350, H1961560, and #..lß>':~i~,~~),:... From: "\1PLJ, Well Operations Supervisor" <\I\'clloperationssupcrvisor@ßP.com> Date: Thu. 29 Dee 2005 07:05:21 -0900 To: Thomas Maunder <tolll_111<lundcr@admin.state.ak.lIs> Thanks Tom! JRC ~t;I\NNEU G" ¡' /- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, December 29, 2005 6:50 AM To: MPU, Well Operations Supervisor Cc: MPU, Operations Manager; Jim Regg Subject: Re: Milne Point K-pad water supply well MPK-34 (PTD #1961690) and F-Pad water supply wells MPF-02, 21, 58, and 77 (PTD #1960700, #1961350, #1961560, and #1951360) Hi John, I did some checking as well. Your understanding regarding a regulatory requirement for SSV s on water supply wells is correct. There is no requirement to employ SSV s on such wells. Thanks for checking. Tom Maunder, PE AOGCC MPU, Well Operations Supervisor wrote, On 12/28/2005 6:12 PM: Hi Tom, As per our conversation yesterday, I am curious if we are required to have a functioning SSV on our water supply wells here at Milne Point. These wells produce from the Prince Creek and Ugnu formations and are not hydrocarbon producing. From what I can gather reading through the regulations, I can't see where we are required to have a functioning SSV on these wells, but wanted to check with you to make sure. The wells were equipped with SSVs when they were drilled, but we would like to remove the panels and use them elsewhere if they are not required on our source water wells. Our source water wells are not capable of unassisted flow and are produced with Electrical Submersible Pumps. These wells are equipped with pilots that will shut down the ESP if the flowline pressure drops below 500 psi (Le. we develop a leak). Thanks for your help on this Tom and please don't hesisitate to let me know if you need any further information. Best Regards, John R. Cubbon MPU Well Operations Supervisor 1-907 -670-3330 1 of! 12/29/20057:10 AM ~ S BEEN ON OR BEFOKE PERMIT 95-136 95-136 95-136 95-136 95-136 95-136 95-136 95-136 95-136 95-136 95-136 95-136 95-136 95-136 AOGCC Individual Well Geological Materials Inventory DATA 6802 7080 BHP DIFL/GR/SP GR - MD GR - TVD T DATA PLUS ~T/~850-3676 DIFL/ZDL/CN/GR · ~T~PERRY MWD ~'~1850-3676 J~1850-3676 J~SEPIA ~I~'SEPIA SSTVD ~L/1950-3676 ZDL/CNL/GR/CAL ~'1950-3676 GR/CCL/PERF GR/CCL - PERF PDK-iOO/GR/CCL CCL - PERF TBNG PUNCH GRAVEL SEPIA '~400-2663 ~357-3580 ~..~2017-2181 ~'~550-3240 Page: 1 Date: 07/21/98 RUN RECVD 1 09/28/95 05/15/96 1 09/28/95 1 09/28/95 1 03/12/96 1 03/12/96 1 09/28/95 1 09/28/95 1 02/08/96 FINAL 09/11/96 FINAL 09/11/96 FINAL 09/11/96 FINAL 01/24/97 FINAL 01/24/97 10-407 ~R~-COMPLET I ON DATE DAILY WELL OPS R ~/]~/Bt7 TO ~/3©/~/ Are dry ditch samPles required? yes ~_~And received? Was the well cored? yes .~.~_~_~alysis & description received? Are well tests required? ~es Well is in compliance Initial COMMENTS ~eceived? __Iz~-s---no ~ STATE OF ALASKA ALASK/-~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other ESP Changeout/Pull ESP Packer 2. Name of Operator BP Exploration (Alaska) Inc, 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2174' NSL, 2467' WEL, Sec. 6, T13N, R10E, UM At top of productive interval 2429' NSL, 1474' WEL, Sec. 6, T13N, R10E, UM At effective depth 2451' NSL, 2400' WEL, Sec. 6, T13N, R10E, UM At total depth 2502' WEL, 2391' WEL, Sec. 6, T13N, R10E, UM 5. Type of well: Eevelopment xploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE = 47' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-77 9. Permit Number / Approval No. 95-136 10. APl Number 50-029-22594 11. Field and Pool Milne Point Urcj~__. 12. Present well condition summary Total depth: measured 3700' feet true vertical 3270' feet Effective depth: measured 3592' feet true vertical 3178' feet Casing Length Structural Conductor Surface Intermediate Production Liner Plugs (measured) ~,P,,~ '1 Junk (measured) '-~LIE-~ 0~j & Gas Co~. Size Cemented MD - TVD 75' 20" 250 sx Arcticset (approx) 11 O' 11 O' 3644' 9 5/8" 561 sx PF 'E', 700 sx 'G' 3678' 3622' 250 sx PF 'E' Perforation depth: measured 2862'-2868', 2947'-2962', 29801'-3008', 3113'-3226', 2450'-2550', 2576'-2596', 2640'-2680' true vertical 2529'~2565'~2632'~2645'~266~'~2683'~2772'~2868'~2211'~2296'~2318'~2335'~2372~~24~6' Tubing (size, grade, and measured depth) Packers and SSV (type and measured depth) 5 1/2" 17# L-80 to 2276' 9 5/8" HES Versatrive Pkr @ 2298' & 2688', HES 9 5/8" 'BWD' SUMP Pkr @ 3240' WLM 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prince Creek Water Source 17. I hereby certify that the for.~oing is true and correct to the best of my knowledge Signed Chip Alvord /~/4~- L/' ~ Title Engineering Supervisor Date --~&~'(~ Prepared By Name/Number: Mary Youngers 564-5242 Submit In Duplicate~¢ Form 10-404 Rev. 06/15/88 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX/ARCO Well Name: MPF-77 Rig Name: N-4ES AFE# 339033 Accept Date: 12/16/96 Spud Date: . Release Date: 12/19/96 DECEMBER 16, 1996 ACCEPT RIG @ 0300 HRS. CLEAN PITS LOAD W/269 BBLS 8.6# SEAWATER, NU TO TREE - AOGCC WAIVE BOP WITNESS. DECEMBER 17, 1996 PULL BPV, SPOT TIGER TANK TEST LINES 3500#. PUMP 8.6 BRINE DOWN TUBING, TAKE DIESEL RETURNS TO TIGER TANK (SlTP 70#) (SICP #240) BEFORE PUMP BRINE, WELL ON VACCUM, SPOT 20 BBLS XANVIS PILL, ACROSS PERF, MONT WELL STATIC SET TWC ND TREE. NU BOPS CHANGE PIPE RAMS TO 4.5 - AOGCC WAIVE WITNESS TEST BOPS RIG DOWN TEST EQUIP PILL TWC. MU LANDING JT. BOLDS RELEASE PKR 87k OVER PULL. CIRC OUT GAS INFLUX FROM BOTTOM PACKER. POOH, LD 4.5 TBG W/ESP. RIG UP HWS, RIH W/8.7 GR & JB TO 2076. RIH W/2" DRIVE DOWN BAILER TO 3574' NO RESISTANCE, NO FILL. W/O/O FROM MPU PE, SWS ON WAY TO RUN GRAVEL PK LOG. DECEMBER 18, 1996 W/O SWS TO ARRIVE. RIG UP SWS, RUN GR CCL TTD, UNABLE TO GET THRU PKR @ 2304 POOH W/O SWS 3 HRS, INSTALL CENTRALIZER, RERUN OK RIG DOWN SWS (ICE OF CENTRALIZER). PU 5.5 TUBING RIH. CIRC HEATED FLUID @ 1067' RIH TO 2193. CIRC HEATED FLUID, W/O/O FROM GRAVEL PK EVALUATION ESP INSPECTION. POOH LD 5.5 TUBING, RIH TO RUN ESP MU ESP. W/O ESP EQUIP (WRONG POT HEAD). DECEMBER 19, 1996 RIG RELEASED @ 0200 HRS. WAIT ON WEATHER TO RIG DOWN. WAIT FOR CENTRALIFT TO MAKE NEW MOTOR LEAD SPLICE/WRONG SIZE CABLE ON POT HEAD (MOTOR HAD BEEN ON LOCATION 2 DAYS). PU 5.5 TBGFFIH W/ESP. PU HANGER MAKE HANGER ESP SPLICE. LD TUBING/RILDS LD LANDING JT SET TWC. ND BOPS, NU TREE. TEST PENETRATOR ADAPTER TREE TO 5000# SURFACE LINE TO 3000# FREEZE PROTECT WELL PUMP 70 BBLS DOWN ANNULUS. W/O DIELSE F/MPBC PEAK COULD NOT DELIVER - PHASE 2. FREEZE PROTECT INSTALL BPV, BULLHEAD 36 BBLS DIESEL DOWN TUBING RIG DOWN CLLR SECURE WELL. ** 40 MPH WIND GUST. Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: r-]Operation Shutdown i--]Stimulate [] Plugging [] Perforate [] Pull Tubing I--]Alter Casing [] Repair Well [] Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: D evelopment Exploratory [] Stratigraphic [] Service 4. Location of well at surface 2174' NSL, 2467' WEL, Sec. 6, T13N, R10E, UM At top of productive interval 2429' NSL, 1474' WEL, Sec. 6, T13N, R10E, UM At effective depth 2451' NSL, 2400' WEL, Sec. 6, T13N, R10E, %TM At total depth 2502' WEL, 2391' WEL, Sec. 6, T13N, R10E, UM ESP Changeout 16. Datum Elevation (DF or KBE) KBE = 47' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-77 9. Permit Number / Approval No. 95-136 10. APl Number 50- 029-22594 11. Field and Pool Milne Point Unit 12. Present well condition summary Total depth: measured 3?co' feet true vertical 3270' feet Effective depth: measured 3592' feet true vertical 3178' feet Casing Length Size Structural Conductor Sudace Intermediate Production Liner 75' 20" 3644' 9 5/8" Plugs (measured) Junk (measured) 250 sx Arcticset (approx) 110' 561 sx PF 'E', 700 sx 'G' 3678' ORIGII,3AL TVD 110 ' 3622' Perforation depth: measured true vertical 2450 -2550 , 2576 -2596 , 2637'-2680', 2826'-2868', 2947'-2962', 2980 -3008 , 3113 -3226 , 2166 -2251 , 2273 -2290 , 2324'-2361', 2484'-2520', 2587'-2599, 2615'-2638 , 2727 -2823 Tubing (size, grade, and measured depth) 5 1/2" 17# L-SO to 2192' Packers and SSV (~pe and measured depth) 9 5/8" HES Versatrive Pkr @ 2298' & 2688' , HES 9 5/8" SUMP Pkr ~ 3240' WLM 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments []Copies of Logs and Surveys []Daily Report of Well Operat 16. Status of well classifications as: [] Oil []Gas [] SuspendE Service Prince Creek Water 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed <'/~¢/'/Z-/'~- ~ ~ Title~ ',/~J-,~- ~_¢~ ~repared By Name/Number: Corm 10-404 Rev. 06/15/88 Submit In Duplicate Facility M Pt F Pad Progress Report Well MPF-77 Rig Nabors 5S Page Date 1 09 March 98 Date/Time 07 Mar 98 08 Mar 98 09 Mar 98 06:00-06:15 06:15-07:30 07:30-18:00 18:00-18:15 18:15-21:00 21:00-21:30 21:30-02:30 02:30-05:00 05:00-06:00 06:00-06:15 06:15-08:30 08:30-12:30 12:30-15:00 15:00-19:00 19:00-21:00 21:00-23:30 23:30-00:30 00:30-01:30 01:30-03:00 03:00-06:00 Duration 1/4 hr 1-1/4 hr 10-1/2 hr 1/4 hr 2-3/4 hr 1/2 hr 5hr 2-1/2 hr lhr 1/4 hr 2-1/4 hr 4hr 2-1/2 hr 4hr 2hr 2-1/2 hr lhr lhr 1-1/2 hr 3hr Activity Held safety meeting Rig moved 50.00 % Rig moved 95.00 % Held safety meeting Rig moved 100.00 % Held safety meeting Circulated at 2276.0 ft Circulated at 2275.0 ft Removed Xmas tree Held safety meeting Installed BOP stack Tested BOP stack Removed Tubing hanger Removed Tubing hanger Rigged up Tubing hanger Installed Tubing hanger Rigged down All rams Installed Xmas tree Installed Xmas tree Freeze protect well - 100.000 bbl of Diesel STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [~< Prince Creek Water Source Producer 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc 95-136 3. Address B. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o- 029-22594 4. Location of well at surface "-~,'~.~:., :~. ~. . · .. .., 9. Unit or Lease Name 2174' NSL, 2467' WEL, SEC. 6, T13N, RI OE -/,; ~4/. Milne Point Unit At Top Producing Interval ~ ~~ 10. Well Number 2429' NSL, 1474' WEL, SEC. 6, T13N, RIOE ~~ ~ '~ MPF-77 :. . 11. Field and Pool At Total Depth ~- : - ~-:~ '. ' ' ' tVlilne Point 2571' NSL, 932' WEL, SEC. 6, T13N, RIOE :5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 47' ADL 025509 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. o! Completions 09/12/95 09/14/95 08/29/96I N/A feet MSL One 17.3700, MD/3270, TvDTOtal Depth (MD+TVD) 18.3592, MD/3178, TvDPlUg Back Depth (MD+TVD) 19.YESDirectional[] SurveYNO [] 20. Depth whereN/A SSSVfeet MDSet 21.1800,(Approx.)Thickness of Permafrost 22. Type Electric or Other Logs Run MWD, DIFL, GR/NEU/DEN, PNL, GR/CCL, GR/JB 23. CASING, LINER AND CEMENTING RECORD SEFRNG DEPTH MD -. CASING SIZE WT. PER FT. GRADE TOP Bo-n'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# NT8OLHE 35' 110' 30" 250 sx Arcticset I (Approx.) 9-5/8" 40#/47# N-80/L-80 34' 3678' 12-1/4" 56~ sx PF 'E', 700 sx 'G', 250 sx PF 'E' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 12 spf 4-1/2", L-80 2254' 2110' MD TVD 2826'-2868' 2529'-2565' 2947'-2962' 2632'-2645' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 2980'-3008' 2660'-2683' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 3113'-3226' 2772'-2868' Freeze protect w~ 124 bbl diesel to 2200' MD 4-1/2" Gun Diameter, 12 spf - Add perfs 08/25/96 Gravel pack assy, 2298'-2686' 5900# 20/40 Carbolite behind pipe 2450'-2550' 2211'-2296' 2576'-2596' 2318'-2335' Gravel pack assy, 2688'-3240' 8000# 20/40 Carbolite behind pipe 2640'-2680' 2372'-2406' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 04/03/96 ESP Date of Test Hours Tested TEsTPRODUCTIONpERIOD FORi~ OIL-BBL GAS-MCF ~/ATER-BBL CHOKESIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ .. 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED ORIGINAL Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ($ubsea) Prince Creek A 2645' 2328' Prince Creek B 2832' 2486' Prince Creek C 2988' 2618' Prince Creek D $105' 2717' Base Prince Creek 3232' 2825' .. 31. LIST OF A'I-FACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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 a. ny 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 cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATION~ PAGE: 1 WELL: MPF-77 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 09/11/95 10:00 SPUD: 09/11/95 11:00 RELEASE: OPERATION: DRLG RIG: NABORS 27E WO/C RIG: 09/12/95 ( 1) TD: 527' ( 0) 09/13/95 (2) TD: 2044' (1517) 09/14/95 (3) TD: 3670' (1626) REAM OUT DOGLEG MW: 0.0 VIS: 0 MOVE RIG FROM MPF-69 TO MPF-77. MOVE IN & SPOT. SET HYDRIL & INSTALL DIVERTER LINES. RIG ACCEPTED @ 1000 HRS., 09/11/95. TAKE DIVERTER APART FROM PIPE SHED TO BEGIN MODIFYING IT. HOOK UP SKATE,INSTALL MOUSEHOLE,LOAD BHA INTO PIPESHED,NU RISER, FLOWLINE,TURNBUCKLES. CONT WORK ON DIVERTER. STRAP,CALIPER BHA. BEGIN PU BHA. CONT PU BHA. ORIENT MOTOR/MWD. SPUD IN @ 95' MD 09/11/95 @ 2300 HRS. DRILLING F/95'MD T/164'MD. DRILLING F/164' MD T/195' MD. DRAG CHAIN SPROCKET BOLTS CAME LOOSE. TIGHTED SAME. DRILLING F/195' MD T/527' MD. LD 6 JTS DP TO REAM 4.2 DEGREES DOGLEG. REAM F/378' MD T/467' MD. DRILLING MW: 0.0 VIS: 0 RE-SURVEY, STILL 4.28 DEGREES DOGLEG. CONT ATTEMPT TO WIPE OUT DOGLEG. DRILL F/527' T/1074'. SURVEY @ 1010 MD 7.27 DEGREES DOGLEG. DISCUSS. DRILL F/1074' T/1265'. CIRC HOLE CLEAN FOR TRIP. CHECK FOR FLOW. POOH. DOWNLOAD MWD. LD MOTOR. PU 1.5 DEGREES MOTOR, MU BIT,ORIENT MOTOR W/ BIT. RIH. KELLY UP 1225, WASH TO 1265. OK. NO FILL. DRILL F/1265' T/2044' CUT & SLIP LINE MW: 0.0 VIS: 0 DRILL F/2044' T/3184' PUMP LO-HI VIS SWEEP. CIRC TILL HOLE CLEAN. MONITOR WELL. PUMP DRY JOB. POOH T/1265'. MONITOR WELL. RIH, HIT BRIDGE @ 1365'. WORKED PIPE THRU, DID NOT SEE AGAIN. KELLY UP @ 3141, WASH TO 3184. NO FILL. DRILL F/3184' T/3670'. CIRC SWEEP FOR SHORT TRIP. MONITOR WELL. POOH T/2726'. MONITOR WELL. RIH T/3642'. KELLY UP, WASH TO 3670. OK. NO FILL. PUMP SWEEP, CIRC HOLE CLEAN. MONITOR WELL. PUMP PILL. POOH FOR LOGS. SLM, NO CORR. DOWNLOAD MWD, 15 MIN. RU ATLAS WL, RIH W/ LOGGING TOOL-STOPPED @ 1900'. COULD NOT GET DOWN. POOH. RIG DOWN ATLAS WL. LD BIT, MOTOR & MWD. SPACE OUT STABILIZERS, MU BIT. RIH W/ HWDP. CUT & SLIP DRILLING LINE. WELL · MPF-77 OPERATION: RIG : NABORS 27E PAGE: 2 09/15/95 ( 4) TD: 3700'( 30) 09/16/95 (5) TD: 3700' ( 0) RUN 9-5/8" CASING MW: 0.0 VIS: 0 RIH, TOOK WT @ 1900, WORKED PIPE, CLEARED UP. CIRCULATE. DRILL F/3670' T/ 3700'. PUMP SWEEP, CIRC HOLE CLEAN, MONITOR WELL, PUMP DRY JOB. POOH. OK. RU ATLAS WL, RUN GR/N/D LOG, RD ATLAS WL. RIH W/BHA #3 T/3676'. KELLY UP, WASH F/3676' T/3700'. OK. NO FILL. CIRC & CONDITION HOLE. MONITOR WELL, PUMP DRY JOB, POOH LAYING DOWN DP. LD BHA. RU TO RUN 9-5/8" CASING. MU SHOE JTS & RUN CASING MIRU MW: 0.0 VIS: 0 CIRC HOLE CLEAN. FLUSH RIG PUMPS & LINES W/ CLEAN WATER. TEST CMT LINES W/3000 PSI. PERFORM CMT JOB. BUMP PLUG W/ CALC STROKES. TEST CSG W/3000 PSI F/30 MIN. NO CMT TO SURFACE. LD LANDING JT & CSG TOOLS. ND FLOWLINE, MOUSEHOLE, RISER, HYDRIL & DIVERTER LINE. PERFORM TOP JOB. INSTALL GEN 6 WELLHEAD, SEAT SEALS, LOCKDOWN & TEST. NU ADAPTER, FLANGE & VALVE. TOP WELL OFF W/DIESEL. NU TREE CAP. RELEASE RIG @ 1800 HRS.,09/15/95. SET OUT RIG. MOVE TO MPF-78. SIGNATURE: (drilling superintendent) DATE: RECEIVED SEP I G 1996 Alaska Oil & Gas Cons. Commission Anchorage SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: M PF-77 Rig Name: N-4ES AFE: 3301 85 Accept Date: 01/20/96 Spud Date: Release Date: 01/27/96 JAN 20, 1996 MIRU JAN 21, 1996 MIRU. CHECK WELL FOR PRESSURE, ND XMAS TREE, NU BOPE, INSTALL 2" VALVE ON MUD CROSS, REPLACE 3" VALVE ON CHOKE MANIFOLD. LOAD & STRAP TUBING IN PIPE SHED & INSTALL STRAINER ON PUMP SUCTION LINE. HEAT BRINE. RU & TEST BOPE & INSTALL WR. MU BHA & RIH WITH TUBING. COULD NOT GO DOWN WITH SCRAPER THRU TOP OF 9-5/8" CASING. POOH & MU 3 DC'S & ATTEMPT TO PUSH SCRAPPERS THRU. UNABLE TO GO THRU. POOH. PULL & INSPECT WR. ND BOP'S. INSPECT CASING HEAD JAN 22, 1996 INSPECT CASING HEAD. NU BOPE. LD 9-5/8 CASING SCRAPERS & PU UNDERSIZE CASING SCRAPER. INSTALL TEST PLUG & TEST BOP'S. PULL TEST PLUG & IWR. RIH, PU TUBING TO ICE @ 1769'. WORK THRU ICE PLUG & CONT RIH TO 3589'. MIX DIRT MAGNET SWEEPS & PERFORM CASING WASH. TEST CASING. CIRC & COND BRINE. POOH LAYING DOWN TUBING & BHA. TEST CASING. ND FLOWLINE & RISER. JAN 23, 1996 INSTALL SHOOTING FLANGE & RU ATLAS. TEST LUB & FLANGE. PERFS RUN #1 THRU RUN #8. MU & RIH WITH HALLIBURTON PACKER & SET 3240'. POOH & RD ATLAS. ND SHOOTING FLANGE, NU RISER & FLOWLINE. LOAD & STRAP GRAVEL PACK ASSY. MU GRAVEL PACK ASSY & RIH ON TUBING. JAN 24, 1996 RIH WITH GRAVEL PACK ASSY. TAG BOTTOM PACKER @ 3240'. SPACE OUT, DROP BALL & SET TOP PACKER. TEST ANNULUS. SHEAR ANNULUS BALL, RELEASE FROM PACKER. REV CIRC & REVERSE OUT BALL. RU BJ. PRESSURE TEST LINES. REPAIR HYDRAULIC LINE ON PUMP TRUCK. PUMP PICKLE ACID AS PER PROGRAM. REV OUT SLOP TANK. REPAIR CONVEYOR BELT ON BJ EQUIP. PERFORM INJECTIVITY TEST. GRAVEL PACK AS PER WELL PLAN. PUMPED 20250# OF 20-40 Page CARBOLITE BEFORE SCREENS PACKED OFF. REV OUT A FULL COLUMN OF SLURRY & RESTRESSED THE PACK. HELD. RD BJ. POOH LAY DOWN TUBING & WASH PIPE ASSY. PWR. RU TO RUN ESP COMPLETION. JAN 25, 1996 MU ESP COMPLETION. WAIT ON CENTRILIFT EQUIP & RIH TO 2666' & CIRC TO KEEP HOLE FROM FREEZING. JAN 26, 1996 WAIT ON CENTRILIFT EQUIP & CIRC WELLBORE. POOH. MU ESP & TEST FLUIDS & MU BAKER CT PACKER. SPLICE ESP CABLE AT PACKER. RIH WITH ESP ASSY. SHEAVE IN DERRICK BROKE. CHANGE OUT SAME. CONT TO RIH WITH ESP COMPLETION & MU HANGER & LANDING JT. SPLICE ESP CABLE AT HANGER. LAND TUBING & RILDS & BACK OUT LANDING JT. ND BOP. JAN 27, 1996 NU TREE & TEST. TEST ADAPTER FLANGE. FREEZE PROTECT WELL. DROP SETTING BALL & PSI TUBING. ATTEMPT TO TEST ANNULUS. NO GOOD. RE-TEST TUBING & BLEED. ATTEMPT TO RE-TEST ANNULUS. CALL WIRELINE TRUCK OUT. RU & RIH. MADE 6 RUNS WITH DIFFERENT TOOLS ATTEMPTING TO PULL RHC PLUG & DID RECOVER PLUG & SETTING BALL. RIH WITH 2.25" PLUG & SET IN NO-GO & SET PACKER IN STAGES & TEST ANNULUS. OK. PU LUB & SET BPV & SECURE TREE & RIG DOWN CELLAR. RD TO MOVE OUT. Page 2 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPF-77 Rig Name: 4 ES AFE: 339008 Accept Date: 04/20/96 Spud Date: Release Date: 04/24/96 Apr 21 1996 MIRU. Pull BPV. Bullhead Zanvis pill, set TWC. ND tree. NU & test BOP. Change rams to 4-1/2". Rig accepted 04/20/96 @ 1600 hrs. Test BOP's. RD test equip & pull TWC. MU LJ. Apr 22 1996 Cont MU L J, attempt to pull pkr free. Was not successful. Rig Camco & RIH with plug & set in no-go profile. Tbg to 3500 psi & hold for 15 min. POOH & RD Camco. Displace diesel out of well. Pull hanger to floor & LD same. POOH w ESP compl, LD & check out same. Rig Camco & RIH with GR/JB, 2 runs & recover 2 bands on first run. T/2694' HES Versa-pkr. Made RIH with 2-1/8" pump bailer t/3577'. MU & service pump & motor. MU cable to motor & 9-5/8" CT-ESP pkr. Make cable splice at pkr. Apr 23 1996 Cont to splice cable at pkr. Cont to RIH w/ESP compl. MU LJ & hanger. Splice cable at hanger. Land tbg. RILDS. Back out LJ. Change rams to 3-1/2" & ND BOP's & riser. NU test tree & head to 5000 psi. Pull TWC. Freeze protect well w/175 bbl diesel. Drop 1-1/16" setting ball, attempt to set pkr. Appears ball leaking by. Bleed down & re- pressure & hold. Bleed tbg & attempt to test annulus. Re-pressure tbg & hold. Went through setting procedure a couple more time. No test. RU Camco & RIH & retrieve setting ball & plug. RIH with setting plug. Attempt to set pkr several times. Not successful in getting test. POOH with pkr, setting plug & RD CamccD~~(~i~l~llDCl~l diesel f/well bore to pull tbg & begin displacing tbg with brine, r~ L ~ Ew v ~..t~ S£P I G 1996 Apr 24 1996 Alaska 0il & (~as Cons. Comrnissior~ Displace out diesel with brine. Set TWC & ND tree. NU BOP's & chang~~ to 4-1/2". Test BOP's. Pull TVVC & install LJ. Back out LDS & PL hanger, LD same. Repair spooling unit. POOH w/ESP completion. LD pkr & ESP assy. RU Camco & RIH with GR/JB & re-run. No fill. POOH no rec. RIH w/1-3/4" drive down bailer t/3598'. POOH & rec 1/4 cup possible formation sand. MU & service ESP & MU Baker pkr. Make splice in ESP cable at pkr. RIH with ESP compl. Page Apr 25 1996 MU hanger & LJ. MU splice on hanger, land tbg, RILDS, back out LJ. Change rams to 3-1/2", ND riser, flowline & BOP. NU tree test same, pull 2-way check. Freeze protect w/140 bbl diesel down annulus, bull 40 bbls down tbg. RU Camco. RIH with pkr set plug, set plug & pressure up. Engage pkr. Bleed annulus & tbg, pull pkr setting plug, POOH with wireline, RU lub, set BPV, 180# on tbg, RD lub. Secure well, RD cellar. Rig released 04/24/96 @ 2030 hrs. Page 2 .. SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: M PF-77 Rig Name: 4 ES AFE: 33901 4 Accept Date: 08/23/96 Spud Date: Release Date: 08/29/96 Aug 24 1996 MIRU. Berm & trim herculite. Raise derrick. RU hard line to tree & tiger tank. Rig accepted 08/23/96 @ 2400 hrs. Pull BPV with lub. Pump brine down tbg, monitor well, well on vacuum-cut brine. Pump 40 bbls down tbg, well on vacuum. Monitor well. Cut brine wt. Aug 25 1996 Finish cutting brine. Circ down tbg. Monitor well, well no vacuum. Wait on water & brine from Baroid. Cut brine in pits. Mix & pump xanvis pill with liquid casing. Displace pill to perfs. Pressure increased, no returns. Attempt rev circ thru circ holes in tbg above pkr, could not circ. Pressure up to 3000 psi, no bleed off. Set 2-way check valve, ND CIW 4-1/16" 5000# tree. NU BOP stack, change pipe rams to 4-1/2". Test BOP, test all rams, lines & valves, test hydril, kelly, TIW, IBOP. Witness of test waived by Chuck Scheve w/AOGCC. MU LJ. Shear Baker CT pkr with over pull, work tbg attempt to circ. Cannot circ around pkr, swabbing. Appears to be no hole above pkr. Pkr will not go back down hole, POOH filing tbg with brine. Able to circ, circ @ 2300' with brine, monitor well. OK. Cont POOH with ESP laying down 4-1/2" tbg. Aug 26 1996 Finish POOH with ESP. LD Baker CT ESP pkr. Tbg was not perfed. Inspect & LD ESP, pump locked up, motor grounded, no solids found. Install WB. RIH with mule shoe to top of gravel pack @ 2692'. Circ above gravel pack @ 2687'. No sand in returns. POOH with 4-1/2" tbg. RU Atlas wireline. RIH with PNL log to PBTD. Log gravel pack, ok. POOH, RD Atlas. RIH with HES 'JP' pkr plug, set plug in pkr @ 2692' & test. ok. Spot 100# sand on top of plug. POOH with running tool, LD tbg. ND bell nipple, NU perf flange. RU Atlas wireline, MU 7" lubricator test, ok. RIH with GR/CCL & 20' of 4-1/2" RDX big hole charge per[ guns. Per[ @ 12 spf, no fluid loss. POOH. All shots fired. " Page Aug 27 1996 Finish perforating Prince Creek formation 2680'-2640',2596'-2576',2550'-2450'. Correlated to DIFL. RD lub flange, NU bell nipple. RIH with GR/JB, set down at 2462'. Recovered fine sand in junk basket, RIH with GR/JB - set down @ 2427'-- 23' above perfs. RD Atals wireline. Sand covered perfs. LD DP. TIH with HES pkr plug retrieving tool on 4-1/2" tbg to 2361'. Circ increase brine wt. Viscosity brine system with Xanvis. TIH tag fill at 2535'. Wash down circ, CBU. Sand in returns. POOH to 2425'. Monitor well. TIH to 2690', no fill. Circ high vis sweep, displace to clean viscosify brine with breaker. Spot high vis pill across perfs, retrieve pkr plug, monitor well. No loss. POOH with pkr plug. Prepare to PU gravel pack assy Aug 28 1996 Load pipe shed, PU gravel pack assy with 5-1/2" screen. TIH with assy on 4-1/2" L-80 tbg to 2250'. Cont TIH with gravel pack assy, snap into & out of pkr @ 2692' & space out with 4-1/2" tbg pups. Appeared to be clean pkr top, no fill. Drop 2" ball, RU BJ service lines. Pressure up & set HES 9-5/8" Versatrieve Pkr @ 2298'. Shear off pkr & reverse out ball. Pickle tbg & reverse out to slop tank. Spot brine water with breaker at tool. Gravel pack with Gel pad followed by gel with 20/40 ppa. Screened out with 5900# ppa behind screen. Rev circ out excess sand to slop tank. Stress pack with rig pump 3 times. RD BJ. Rev circ to clean filtered brine water. POOH with gravel pack tool, LD gravel pack wash string. Prepare to run ESP completion. Aug 29 1996 Load ESP in pipe shed, RU to run completion. MU & service ESP. MU pkr & pkr penetrator. Make 2 below & 1 above pkr ESP cable splice. RIH with ESP on tbg. MU tbg hanger. Splice ESP cable at hanger, test line & penetrator. Land tbg hanger, install 2 way check valve. ND BOP stack, NU adaptor spool. NU CIW tree. Aug 30 1996 Finish NU ClW tree, test tree & tbg hanger.ok. Freeze protect annulus with 124 bbls diesel, bullhead 32 bbls diesel down tbg. Freeze protected to 2200' MD. Drop 1-1/16" steel ball, pressure up to set pkr at 500 psi tbg pressure. Pressure failed, could not pressure up. Wait on slickline unit to pull pkr plug. Drop 1-1/8" steel ball, pressure up to 3500 psi & set packer at 2109'. Test annulus to 3500 psi. RU Camco slickline unit. RIH with GS pulling tool & pull pkr plug. Recovered pkr plug & 1-1/8" ball. (1-1/16" ball left in hole on top of ESP) Ball passed thru 1" ball seat in pkr plug. RD Camco slickline unit. Install BPV with lubricator. RD line. Secure well. Rig released 08/29/96 @ 2100 hrs. Page 2 .. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION (ALASKA) INC MILNE PT/MPF-77 500292259400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/20/95 DATE OF SURVEY: 091395 MWD SURVEY JOB NUMBER: AK-MM-950945 KELLY BUSHING ELEV. = 48.30 FT. OPERATOR' BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -48.30 129 129.48 81.18 195 195.45 147.15 283 283.14 234.84 371 371.69 323.39 0 0 N .00 E .00 0 19 N 53.43 W .25 0 40 S 80.87 W .76 1 27 N 53.32 E 2.36 4 56 N 59.99 E 3.96 .00N .00E .00 .22N .30W -.23 .27N .83W -.74 .86N .45W -.22 3.44N 3.77E 4.50 463 462.41 414.11 548 546.53 498.23 637 633.66 585.36 728 721.45 673.15 820 809.59 761.29 8 40 N 57.50 E 4.08 10 43 N 63.44 E 2.67 12 28 N 66.28 E 2.07 16 7 N 71.71 E 4.29 19 27 N 74.43 E 3.72 9 16 23 31 39 .12N 12.99E 14.85 .12N 25.52E 28.72 .68N 41.71E 46.29 .57N 62.62E 68.50 .75N 89.69E 96.75 915 898.66 850.36 1010 985.46 937.16 1104 1068.16 1019.86 1200 1150.02 1101.72 1292 1226.68 1178.38 20 19 N 74.99 E .93 27 3 N 78.58 E 7.27 30 9 N 79.81 E 3.35 33 23 N 78.75 E 3.40 32 32 N 78.16 E .99 48 56 65 74 84 .24N 120.77E 128.97 .79N 157.86E 167.02 .22N 202.18E 212.04 .67N 251.99E 262.64 .62N 300.70E 312.30 1385 1305.69 1257.39 1481 1386.27 1337.97 1574 1465.21 1416.91 1668 1545.73 1497.43 1765 1628.72 1580.42 32 20 N 78.92 E .49 32 22 N 78.89 E .04 32 5 N 77.91 E .63 30 44 N 77.82 E 1.44 31 28 N 78.00 E .77 94 104 114 124 135 .60N 349.91E 362.44 .42N 400.01E 413.41 .43N 448.77E 463.13 .77N 496.86E 512.28 .25N 545.83E 562.32 1857 1706.78 1658.48 1951 1787.20 1738.90 2046 1867.63 1819.33 2141 1948.67 1900.37 2237 2030.54 1982.24 31 17 N 74.84 E 1.81 32 8 N 73.90 E 1.04 31 58 N 73.39 E .34 31 27 N 74.74 E .92 31 1 N 73.50 E .81 146 159 174 187 201 .43N 592.10E 609.92 .82N 639.96E 659.60 .00N 688.29E 709.94 .75N 736.43E 759.99 .34N 784.18E 809.62 2332 2111.34 2063.04 2427 2191.59 2143.29 2519 2269.86 2221.56 2614 2349.86 2301.56 2708 2429.80 2381.50 32 10 N 76.76 E 2.17 32 5 N 75.33 E .81 31 54 N 74.99 E .28 32 11 N 76.75 E 1.03 32 19 N 76.71 E .15 214 226 238 250 262 .06N 832.21E 859.30 .22N 881.11E 909.69 .74N 928.39E 958.59 .96N 976.96E 1008.68 .55N 1026.07E 1059.12 2803 2509.85 2461.55 2898 2590.71 2542.41 2994 2671.68 2623.38 3088 2751.04 2702.74 3182 2830.82 2782.52 32 7 N 76.09 E .41 32 13 N 77.30 E .68 32 8 N 77.26 E .10 32 4 N 78.00 E .42 32 13 N 77.66 E .24 274.41N 1075. liE 1109.58 286.12N 1124.61E 1160.44 297.34N 1174.32E 1211.37 308.01N 1222.97E 1261.15 SEP 6 1996 Alaska Oil & Gas Cons. Commission Anchorage SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 BP EXPLORATION (ALASKA) INC MILNE PT/MPF-77 500292259400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/20/95 DATE OF SURVEY: 091395 MWD SURVEY JOB NUMBER: AK-MM-950945 KELLY BUSHING ELEV. = 48.30 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3275 2909.55 2861.25 32 3 N 72.35 E 3.04 331.36N 1319.72E 1360.66 3372 2992.23 2943.93 31 56 N 72.63 E .20 346.90N 1368.98E 1412.25 3465 3070.58 3022.28 32 1 N 72.57 E .10 361.53N 1415.67E 1461.11 3558 3149.31 3101.01 32 5 N 72.43 E .11 376.36N 1462.71E 1510.35 3606 3190.17 3141.87 32 0 N 74.22 E 1.98 383.70N 1487.22E 1535.92 3670 3244.24 3195.94 32 0 N 74.22 E .00 392.90N 1519.75E 1569.71 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1569.71 FEET AT NORTH 75 DEG. 30 MIN. EAST AT MD = 3670 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 75.62 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 BP EXPLORATION (ALASKA) INC MILNE PT/MPF-77 500292259400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/20/95 DATE OF SURVEY: 091395 JOB NUMBER: AK-MM-950945 KELLY BUSHING ELEV. = 48.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -48.30 1000 976.26 927.96 2000 1828.02 1779.72 3000 2676.44 2628.14 3670 3244.24 3195.94 .00 N .00 E .00 55.86 N 153.33 E 23.74 23.74 166.94 N 664.60 E 171.98 148.24 298.00 N 1177.24 E 323.56 151.58 392.90 N 1519.75 E 425.76 102.20 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE PT/MPF-77 500292259400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/20/95 DATE OF SURVEY: 091395 JOB NUMBER: AK-MM-950945 KELLY BUSHING ELEV. = 48.30 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -48.30 .00 N .00 E .00 48 48.30 .00 .00 N .00 E .00 .00 148 148.30 100.00 .29 N .39 W .00 .00 248 248.30 200.00 .33 N 1.16 W .01 .01 348 348.30 300.00 2.53 N 2.21 E .10 .09 448 448.30 400.00 8.02 N 11.27 E .69 .58 550 548.30 500.00 16.27 N 25.82 E 2.10 1.41 652 648.30 600.00 24.99 N 44.80 E 4.27 2.17 756 748.30 700.00 34.02 N 70.27 E 7.89 3.62 861 848.30 800.00 43.42 N 102.88 E 13.50 5.61 969 948.30 900.00 53.07 N 140.53 E 20.82 7.32 1081 1048.30 1000.00 63.18 N 191.00 E 33.33 12.51 1198 1148.30 1100.00 74.45 N 250.89 E 50.46 17.13 1317 1248.30 1200.00 87.45 N 314.20 E 69.53 19.07 1436 1348.30 1300.00 99.78 N 376.39 E 87.94 18.41 1554 1448.30 1400.00 112.21 N 438.40 E 106.26 18.32 1671 1548.30 1500.00 125.09 N 498.36 E 123.57 17.31 1788 1648.30 1600.00 137.75 N 557.56 E 140.47 16.90 1905 1748.30 1700.00 153.09 N 616.53 E 157.58 17.11 2023 1848.30 1800.00 170.56 N 676.73 E 175.60 18.02 2141 1948.30 1900.00 187.70 N 736.21 E 193.22 17.61 2258 2048.30 2000.00 204.37 N 794.42 E 210.12 16.91 2376 2148.30 2100.00 219.39 N 854.84 E 227.93 17.81 2494 2248.30 2200.00 235.26 N 915.42 E 245.93 18.00 2612 2348.30 2300.00 250.74 N 976.00 E 263.87 17.94 2730 2448.30 2400.00 265.24 N 1037.46 E 282.14 18.27 2848 2548.30 2500.00 280.17 N 1098.56 E 300.27 18.14 2966 2648.30 2600.00 294.10 N 1160.00 E 318.46 18.19 3084 2748.30 2700.00 307.65 N 1221.29 E 336.53 18.07 3202 2848.30 2800.00 321.05 N 1282.71 E 354.65 18.12 3320 2948.30 2900.00 338.71 N 1342.84 E 372.68 18.03 3438 3048.30 3000.00 357.36 N 1402.38 E 390.54 17.86 3556 3148.30 3100.00 376.17 N 1462.11 E 408.53 17.99 3670 3244.24 3195.94 392.90 N 1519.74 E 425.76 17.23 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 9 September 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL MPF-77 DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 PDK FINAL BL+RF 1 SBT FINAL BL+RF ECC No. Run # 1 6479.03 Run # 1 6479.04 Run # 1 6773.02 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite-201 Anchorage, AK 99518 ~ii, Or FAX to (907) 563-7803 SEP ] ] %996 I ECEiVED $£P 1 1 1996 alask~ Oil & Gas Cons, Commission ~orage HOW~ O~ Attn. ~S~ OIL + GAS CONSERVATION 3001 PORC~I~ DRI~ ~CHO~GE ~, 99501. Date: 4 September 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 PFC/PERF FINAL BL+RF ~_ i~3 MPF-33 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF ~_O~c~ MPF-02 MPF-29 ..- .. : . 1 PFC/PERF FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 PFC/PERF FINAL BL+RF ECC No. Run # 1 6479.02 Run # 1 Run # 1 6766.01 Run # 1 6774.01 Run # 1 6776.00 Run # 1 Please si~n and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street : Suite 201 ~ Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: WELL LOG TRANSMITTAL To: State of Alaska May 15, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Records Keeper 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPF-77 AK-MM-950945 The technical data listed below is being submitted herewith. Please acknowledge receipt by remming a signed copy of this transmittal letter to the attention off Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted LIS tape with verification listing. APIg: 50-029-22594-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Ino. Company DFII//ING SEFtL/I r- E S WELL LOG TRANSMITTAL To: State of Alaska March 08, 1996 Alaska Oil and Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MP F-77, AK-MM-950945 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2"x 5" MD Gamma Ray Logs: 2" x 5" TVD Gamma Ray Logs: 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 26 January 1996 Transmittal of Data ECC #: 6479.01 Sent by: HAND CARRY Data: PFC/PERF Dear Sir/Madam, Reference: BP MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PFC/PERF FINAL BL+RF ~un # 1 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 0r~/~907) 563-7803 Received by: Date: t c L clvtCO FEB 0 8 1995 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 19 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 DIFL FINAL BL+RF 1 ZDL/CN/GR FINL BL+RF 1 BH PRO FINAL BL+RF 1 SSVD FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 6479.00 Please sign and return to: Attn. Rodney. Do Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and return to, Petrotechnical Data Cente~ BP Exploration (Alaska) 900 East Benson Boulevard AnehoraEe, Alaska 99508 Received LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, .~;~0 ~ Reference: /~~/ BP MPF-77 . MILNE POINT NORTH SLOPE, AK Date: RE: 19 September 1995 Transmittal of Data ECC #: 6479.00 Sent by: HAND CARRY Data: OH-LDWG Enclosed, please find the data as described below: Tapes/Diskettes: LDWG TAPE+LIS Run # 1 to: Attn. Rodney D. Paulson Please sign and return Atlas Wireline Services 5600 B Street Anchorage, AK 99518 Or.F~ to (907) 563-7803 TONY KNOWLES, GOVERNOR tLAS & 0IL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 7, 1995 Randy Thomas Drlg Supt BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Milne Point Unit ~MPF-77 BP Exploration (Alaska) Inc. Permit No. 95-136 Sur. Loc 21742qSL, 2467'WEL, Sec. 06, T13N, R10E. UM Btmhole Loc. 2185'NSL. 958'WEL, Sec. 06. T13N. RIOE, UM . Dear Mr. Thomas: Enclosed is the appr6ved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integri .ty (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Chairman B?ORDER OF THE-COMMISSION dlf/Enclosure cc' Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. A gamma ray log will be obtained from surface to TD with LWD tools. Mud Logging is not required. August 30, 1995 Mud Program: ISpecial design considerations INone- LSND freshwater mud Surface Mud Properties: ] Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 80 15 8 10 9 8 tO tO tO tO to tO tO 9.6 100 35 15 30 10 15 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I}coy: 1200. I Maximum Hole Angle: 1 32 degrees Close Approach Well: None There are no close approach wells for drilling MPF-77. Disposal: Cuttings Handling: CC2A Fluid Handling: The other wells on this pad are MPF-01, MPF-25, MPF-13, MPF-37, MPF- 45, and MPF-46 (No. Point #1). MPF-46 has had it's annulus arctic packed making it unavailable for injection. Consequently the only annulus available for annular injection will be the 9-5/8" x 7" annulus on MPF-01, MPF-25, MPF-13, MPF-37, MPF-45, MPF-53, MPF-61, and MPF-69. The PEs may be perforating and fracing any of the wells on this pad while MPF-77 is being drilled. Check with the PE supervisor prior to injecting waste fluid down any other annulus to ensure injection will not interfere with their operations. Annular Injection: All cuttings from this well (MPF-77) will require trucking to CC2 for processing and disposal. Fluids may be injected into the 7" x 9-5/8" annulus on MPF-01, MPF- 25, MPF-13, MPF-37, MPF-45, MPF-53, MPF-61, and MPF-69.. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED (BBL) VOL (BBL) Milne Point F- 1 0 35,000 1/1/95- 1 2/31/95 Milne Point F - 13 684 35,000 1/1/95- 1 2/31/95 Milne Point F - 25 230 35,000 1/1/95- 1 2/31/95 Milne Point F - 37 35,000 1/1/95- 1 2/31/95 Milne Point F - 45 35,000 1/1/95-12/31/95 Milne Point F - 53 35,000 1/1/95- 1 2/31/95 Milne Point F - 61 35,000 1/1/95- 1 2/31/95 Milne Point F - 69 35,000 1/1/95- 1 2/31/95 FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annunlus was injected into to avoid freezing. AUG 3 t 1995 u~l & Gas Cons. C0mmissi0.r~ ~choraga August 30, 1995 Drilling Discussion The purpose of this section of the well plan is to point out potential problem areas. OBJECTIVE: The objective of this well is to drill a Water Source well in the Tertiary Prince Creek sands. The well will be drilled and cased by Nabors 27E. The MPU PEs will perforate, gravel pack, cleanout the wellbore with a completion rig and suspend the well once the drilling rig moves off. After the pad has been compacted and some production facilities are installed a completion rig will complete the well with new 4-1/2" tubing and an ESP. The earliest this final completion is expected to take place is October 1995. WELLHEAD MPF-77 will use FMC's Gen. 6 wellhead system. This wellhead system is designed and equipped with 9-5/8" mandrel casing hangers for production strings. Ensure the cement company uses the normal 9-5/8" cement wiper plugs for this wellhead system. Previous cement plugs were designed to be used with a 10-3/4" x 9-5/8" and 7-5/8" x 7" crossed over casing. Landing joints and running tools have already been made up to support this well. Ensure the FMC field rep is on location to check out and inspect these tools before the job. The PEs will be perforating, fracing and performing cleanouts on this well. Consequently the well will be left with a suspended tree that will enable the PEs to safely work per their policies. BITS It is recommended to use a 12.25" Smith M1ASL two cone bit jetted to allow 750 gpm flowrates while drilling the surface hole. Do not use a center jet nozzle any larger than a 12 unless a diffuser is used - this will prevent cone erosion at high flowrates. The depth of the surface hole will require 1 bit to finish this hole section. Plan to have a 12-1/4" hole opener on location if there is trouble getting the surface hole to clean up prior to running casing. MUD DISCUSSION 12-1/4" Monobore Hole: 1. Rheology - Use typical Kuparuk/Milne Point type viscosity, Funnel Visc at 100 at spud decreasing to 80 once you penetrate the permafrost. 2. Mud Weight - It is not necessary to weight up the spud mud by the base of the Permafrost to protect against any shallow gas or hydrates. Allow the mud weight to increase as required while drilling the 12-1/4" hole up to 9.6 ppg maximum. 3. Filtrate Control - Plan to decrease the APl Filtrate level to 8cc by casing point. 4. Misc. Issues - There tends to be large amounts of clay below the Permafrost. Use ConDet (drilling Soap) as required. Utilize mud from a previous well or from Nabors 22E to reduce spud mud costs. Short Trip and Mud Treatment Recommendations: Short trip guidelines will be left to the discretion of the rig supervisor but as a rule thumb these recommendations are offered. Short trip to the last short trip interval or a minimum of 1500 feet whichever is the greater distance when drilling below the top of the HRZ. Wipe thru any tight spots and record the results of all trips on the IADC and morning report -- note depths of intervals wiped or reamed. Even if there are no problems on short trips, record no problems on trip. /XUG l 1995 utt& Gas Cons. Commission ADch0rage August 30, 1995 DRILLING HAZARDS AND RISKS: See both the Milne Point F-Pad Data Sheet and L-Pad Data Sheet prepared by Pete Van Dusen for information on the No Point#1 (F-46), and review recent wells drilled on both F and L pads. The MPU PE group will be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities Lost Circulation: No Point #1 (MPF-46) did not experience any lost circulation while drilling on F-pad. The max mud weight reached on that well was 10.3 ppg. They did experience some mud losses while cementing 7" casing. Lost circulation while drilling the production interval has been a problem on 4 different L-pad wells, the closest pad to F- pad, although none of them have BHLs in the F-pad drilling area. The Kuparuk sands and a number of shallower intervals typically are highly fractured. Wells L-07, L-08, L-09 and L-11 lost varying amounts of mud (from 70 to 220 bbls) drilling through or near the top of the Kuparuk sands. Be prepared to treat these losses initially with LCM treatments. Stuck Pipe Potential: While drilling No Point #1 the 6" BHA was stuck in 8-1/2" hole section for several hours at 6882 ss (13608' MD) before jarring free. They became stuck after tripping back to bottom following a bit trip. Lack of proper hole cleaning parameters appears to have contributed to this problem. Stuck pipe has occurred on 3 L-pad wells at the interface between the Kalubik and D-shale (called the Kuparuk cap rock). These wells and the corresponding depths at which they were stuck were: L-06 @ 6871' ss, L-07 @ 6859' ss, L-11 @ 6835' ss. Kick Tolerance: There is not any kick tolerance for this well as we will only have a divertor on the wellhead. We will not penetrate any potential hydrocarbon bearing formations before we reach TD in the Tertiary Prince Creek. There has not been any shallow gas or hydrate on F pad to date. Formation Pressure: The maximum expected pore pressure for this well is 8.45 ppg EMW (1093 psi @ 2725' ssTVD). There has been any production or injection in this region, therefore the reservoir pressure should not exceed this estimate. WATER USAGE Have the water truck drivers track the water usage on a daily log. Send a copy of this log to Dennise Casey in the Anchorage Office on a monthly basis. EXCEPTIONS AND ADDITIONS TO RECOMMENDED PRACTICES: A) Recommended Practices for Drilling Surface Hole: 6. Land the surface casing and DO NOT attempt to reciprocate surface casing. 8.h use If surface casing sticks off bottom and does not permit landing the casing hanger, the FMC emergency slips and slip setting procedure. Pull 200 klbs tension when setting slips. 14. Conduct a stripping drill after testing BOP stack, while RIH with 8-1/2" bit to drill out 9-5/8" surface casing. See Stripping Drill instructions in Appendix: August 30, 1995 MP F-77 Proposed Summary of Operations o . 3. 4. 5. o . o . 10. 11. Drill and Set 20" Conductor. Weld an FMC landing ring for the FMC Gen 6 Wellhead on the conductor. Prepare location for rig move. MIRU Nabors 27E drilling rig. NU and function test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole to 3679' md (3245' tvd). (Note: This hole section will be LWD logged with GR/Res). Run and cement 9-5/8" casing. ND BOPE and NU dry hole tree. Release rig to MPF-61. Note: This well will be perforated, gravel packed and cleaned out with a completion rig and prior to running the ESP completion. Following the stimulation the well will be left with a retrievable bridge plug (RBP) set 500' above the perforations and kill weight brine in the wellbore. MIRU workover completion unit. ND dry hole tree. NU BOPs and test. PU and RIH with 2-7/8" EUE 8rd tubing with RBP retrieving tool. Release RBP and POH standing back tubing. RIH with Electric Submersible Pump (ESP) completion on 2-7/8" EUE 8rd tubing. Set BPV. ND BOPE and NU tree. Pull BPV and set two way check. Test tree. RDMO with workover/completion rig. POST RIG WORK . Complete the handover form and turn it and the well files over to production. Turn over the well files along with the handover form. . A SBT/GR/CCL is not required on this well and will only be run if there are problems on the production cement job. . The rig will not complete this well. PEs will perforate, frac and clean out this well with a completion rig. August 30, 1995 MPF-77 WELL 9-5/8" PRODUCTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 80 deg F at 4000' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: 539 THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES' 0.2% CFR-3, 0.2% Halad-344, 2.0% CaC12 WEIGHT: 15.8 ppg APPROX #SACKS: 600 FLUID LOSS: 100-150 cc YIELD:i.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 cu ft/sk. MIX WATER: 11.63 gal/sk APPROX NO SACKS' 250 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on the bottom 10 joints above the FS. 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is 600 sacks is calculated to cover the 9-5/8" Casing to the top of the Prince Creek Sands with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. August 30, 1995 o lOO ~oo 292 . _ 300 400 X-Shared Service Alaska 'State Plane: Milne Pt : MPF MPF-77 MPF-77 Wp5 VERTICAL VIEW SCALE 100 ft. / DSqSION VERTICAL SECTION REF: W~LLHEAD ~ 0.00' ~ 0 MD TIE ~N ~ ~, 20 In OD, ~ 125 MD, [25 TYD 0 '--~ i 0.00' ~ 200 MD 1 lO51 11o0 12o0 1400 1500 1845 1900 2100 2400 2600 2700 3000 3100 3200 3245 3300 Z ne4 8/17/95 2,08 pm HALL [ BURTON HOP.[ZONTAL VIEW (TRUE NORTH) SCALE lO0 ft./ DF~ISION SURVEY REF: ~ELLKEAD 600 0.00' ~ ~ MD KI~ / ST~T OF' ~J[L~ ! 4.00'/100 {:t 500-- 400-- 30 200-- lO0-- 4.00' ~ 392 MD 200-- 12.00' ~ 592 MD 300 16,00' ~ 692. MD lO0 0 100 200 300 400 500 600 700 800 900 1000 IlO0 1200 1300 1400 1500 1600 1700 0.00' e 792 MD · 00' ~ 892 MD 8.00' ~ 992 MD k32'00' ~ 1092 HD END OF ~U[LD ~ TIE IN 0 0.00' 75,78' D ~ OF BUILD ~ ~ 4.00'/~00 ~t ~ END DF BUILD 10~32.00' 75.7B' 1051 53 N 211 E ~ START ~ lglg 32.00' 75.7B' ~75~ lG1 N 636 E ~ ~URVE e ~_ 1.00'/~00 ?t ~ END DF CURVE 1933~.00' 75.50' 1765 163 N 643 E ~ B:se 2~32.00' 7~.50' IB45 17G N 692 E ~ PermaFrost ~ T~get 7/~/95 ~3~,00' 75.50' 2019 2~ N 797 E ~ T. Prince C~ek~ ~,00' 75.50' 23~ 24~ N ~77 E . 656 ... ~ 32 00' ~ 1919 ~ ST~T OF ~ E 1.00'/100 Ft - ~ 664 % ' - --' ~3E.oO' ~ 1~33 MD END ~F CURVE 714 - ~,00' ~ ~O~B MD B~se Perm~Fros~ BE3 ~~ e E~33 MD Targe~ 7/5/95 T. Prmnce Creek B, P~lnce ~ek 3~ O0 e 3679 ND [589 9 5/8 ~n ~D, e ~79 ~, 3~45 ~D ' ' -t00 0 100 ~00 300 400 500 600 700 B00 900 1000 IlO0 1200 1300 1400 1500 1600 CA~ING POINT DATA OD MD In¢ Az~ TYD N/~J E,A; 20 In 125 0.00' 0.00' 125 0 N 0 E 9 5/8 In 3679 32.00' 75.50' 3~45 395 N 1539 E [T~t N~me TVO NS EW Geld X G~ld Y [T~t 2130 625 ~ 33~ ~ [r~t 7/~/9~ 2019 aG3 N 797 C 5424~ 6035005 542890 6035B35 PROPOSED BI-IL T¥'D 32~.5.00 MI) 3679.08 V'~ 1{588.68 EN//~ 394.66 1538.88 Cre~ted By Checked By : Approved By , l)~te ' ~/7 4 Halliburton Energy Services - Drilling Systems PSL Proposal Report Date: 8/1, Tune: 2:1 ! Wellpath ID: MPF-77 ~rp5 Last Revision: 8/17/95 Survey Re~ea'ence: WELLHEAD Refexence World Co<ndinates: Lat. 70.30.30 N - Long. 149.39,20 W Relret-en~ GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (fl): 6035627.59 N 542094.08 E NotCh Aligned To: TRUE NORTH Vertical Section Reference: WELLHEAD Closure Refemenee: WELLHEAD TVD Refexemce: WELLHEAD Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2. I.B Vertical Section Plane: 75.62 deg. BPX-Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPF MPF-77 MPF-77 Wp5 Measured lncl Drift Subsea TVD Course Depth Dir. Depth Length (fl) (deg.) (deg.) (fl) (fl) TOTAL Rectangular Offsets (ft) (ft) TIE IN 0.00 0.00 0.00 -45.50 0.00 0.00 0.00N CASING POINT OD = 20 in, ID = 19.12 in, Weight = 94.00 lb/ft. 125.00 0.00 0.00 79.50 125.00 125.00 0.00 N 200.00 0.00 0.00 154.50 200.00 75.00 0.00N 0.00E 0.00E 0.00 E GRID Coordinates Northing Easting (ft) fit) Closure Vertical Dist. Dir. Section (ft) (deg.) (ft) 6035627.59 542094.08 0.00@ 0.00 0.00 6035627.59 542094.08 0.00@ 0.00 0.00 6035627.59 542094.08 0.00@ 0.00 0.00 Build Walk DLS Cmn. Rate Rate Dogleg (dg/lOOft) (dg/lOOft) (dg/lOOft) (deg) Expected Total Rectangular Coords (fl) fit) 0.~ 0.~ 0.~ 0.0 O.~N O.~E 0.~ 0.~ 0.00 0.0 O.~N O.~E 0.~. 0.~ 0.~ 0.0 O.~N O.~E Max Hot Min Hot Dir. Vert Error Error Max Err Error (ft) (ft) (deg.) (It) 0.00 0.00 0.00 0.00 0.23 Survey Tool MWD BPHM-PBD BPHM-PBD KOP I START OF BUILD @ 4.00 deg/100 ft 291.84 0.00 0.00 246.34 291.84 91.84 0.00N 391.84 4.00 75.78 346.26 391.76 100.00 0.86N 491.84 8.00 75.78 445.69 491.19 100.00 3.42N 0.00E 3.38 E 13.51 E 6035627.59 542094.08 0.00@ 0.00 0.00 6035628.47 542097.46 3.49@ 75.78 3.49 6035631.09 542107.57 13.94@ 75.78 13.94 0.00 0.00 0.00 0.0 0.00 N 0.00 E 4.00 0.00 4.00 4.0 0.83 N 3.39 E 4.00 0.00 4.00 8.0 3.29N 13.55 E 2.10 2.10 0.00 0.37 2.21 2.20 345.78 0.52 2.43 2.32 345.78 0.69 BPHM-PBD BPHM-PBD BPHM-PBD 591.84 12.00 75.78 544.15 589.65 100.00 7.69N 691.84 16.00 75.78 641.16 686.66 100.00 13.63N 791.84 20.00 75.78 736.25 781.75 100.00 21.22N 30.34 E 53.79 E 83.74 E 6035635.45 542124.37 31.30@ 75.78 31.30 6035641.53 542147.78 55.49@ 75.78 55.49 0035649.29 542177.69 86.38@ 75.78 86.38 4.00 0.00 4.00 12.0 4.00 0.00 4.00 16.0 4.00 0.00 4.00 20.0 7.30N 30.44 E 12.81N 54.00 E 19.73N 84.12E 2.88 2.48 345.78 0.87 3.66 2.68 345.78 1,08 4.82 2.91 345.78 1.32 BPHM-PBD BPHM-PBD BPHM-PBD 891.84 24.00 75.78 828.95 874.45 100.00 30.42N 120.04 E 991.84 28.00 75,78 918.81 964.31 100.00 41.19N 162.53 E END OF BUILD 1091.84 32.00 75.78 1005.40 1050.90 100.00 53.47N 210.99 E 6035658.69 542213.93 123.84@ 75.78 123.84 6035669.70 542256.35 167.67@ 75.78 167.66 6035682.25 542304.74 217.66@ 75.78 217.65 4.00 0.00 4.00 24.0 4.00 0.00 4.00 28.0 4.00 0.00 4.00 32.0 27.98N 120.66 E 37.48N 163.47 E 48.15N 212.33 E 6.37 3.19 345.78 1.59 8.32 3.51 345.78 1.92 10.69 3.87 345.78 2.30 BPHM-PBD BPHM-PBD BPHIVI-PBD START OF CURVE @ 1.00 deg/100 fl 1918.60 32.00 75.78 1706.53 1752.03 826.76 161.09N END OF CURVE 1933.41 32.00 75.50 1719.09 1764.59 14.81 163.04N Base Pexmagr~t 2028.23 32.00 75.50 1799.50 1845.00 94.82 175.62N Target 715/95 2233.41 32.00 T. Prince ~ 75.50 1973.50 2019.00 205.18 202.84N 635.67 E 643.28 E 691.93 E 797.19 E 6035792.30 542728.76 6035794.29 542736.35 6035807.15 542784.92 6035834.97 542890.02 655.77@ 75.78 655.77 663.62@ 75.78 663.61 713.87@ 75.76 713.86 822.59@ 75.72 822.59 0.00 0.00 0.00 32.0 0.00 -1.89 1.00 32.1 -0.00 0.00 0.00 32. ! -0.00 0.00 0.00 32.1 142.45 N 640.40 E 144.15N 648.07 E 155.21N 697.11E 179.13N 803.23 E 31.07 7.82 345.78 4.98 31.44 7.89 _345.77 5.03 33.80 8.37 345.75 5.35 38.9 1 9.42 345.72 6.05 B PHM-PB D BPHM-PBD BPHM-PBD BPHM-PBD ~alllDurton ~nergy ~ervlces - Drlllmg ~ystems t'~L Proposal Report Wellpa~h ID: MP~ Measured Incl Drift Subsea TVD Course T O T A L Depth Dh'. Depth Length Rectangular Offsets (fl) (deg.) (deg.) (fl) (ft) (it) (fl) (fl) GRID Cootdinates Northing Easting (ft) Closure Vertical Build Walk DLS Cunt Expected Total Max Hoc Min Hot Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Cootds Error Error Max Err Es-rot (It) (deg.) (ft) (dg/100ft) (dg/100ft) (dg/100ft) (deg) (ft) (fi) (ft) (ft) (deg.) (fi) Survey Tool 2583.63 32.00 75.50 2270.50 2316.00 350.22 249.31N 976.87 E 6035882.47 543069.40 1008.18@ 75.68 1008.18 B. Prince Creek 3172.04 32.00 75.50 2769.50 2815.00 588.41 327.38N 1278.74E 6035962.29 543370.79 1319.99@ 75.64 1319.99 CASING POINT OD = 9 5/8 in, ID = 8.84 m. Weight = 40.00 lb/ft. 3679.08 32.00 75.50 3199.50 3245.00 507.05 394.66N 1538.88E 6036031.08 543630.50 1588.68@ 75.62 1588.68 0.00 0.00 0.00 0.00 0.00 0.00 0.00 32.1 219.97N 984.36 E 47.64 11.21 345.68 7.25 BPHM-PBD 0.00 32.1 288.58N 1288.68 E 62.32 14.26 345.64 9.29 BPHM-PBD 0.00 32.1 347.70N 1550.92 E 74.98 16.90 345.61 11.04 . BPHM-PBD '' WELL PERMIT CHECKLIST ,, PROGRAM: exp [] der [] redrll [] serv~ ADMINISTRATION ENGINEERING 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N ' 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ....... N ~=~ 14. Conductor string provided ............... ~Y3 N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. ~ N 17o CMT vol adequate to tie-in long string to surf csg . . . Y N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ 22. Adequate wellbore separation proposed ......... .~ N 23. If diverter required, is it adequate .......... '~ N 24. Drilling fluid program schematic & equip list adequate N 25. BOPEs adequate ..................... Y N 26. BOPE press rating adequate; test to psig. Y N 27. Choke manifold complies w/API RP-53 (May 84) ....... Y N 28. Work will occur without operation shutdown ....... Y~ N 29. Is presence of H2S gas probable ............. Y ~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ....... yY N - -- ' 34. Contact name/phone for weekly progress reports . ./.. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMIS ..~~ C~mments/Instructions: HOW/jo - A:~FORMS~cheklist rev 03/94 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. Tape Subfile 2 is type: LIS TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 6598.00 M. HANIK J. GAFFANEY MPF-77 500292259400 BP EXPLORATION (ALASKA) INC SPERRY-SUN DRILLING SERVICES 04-MAY-96 MWD RUN 2 M. HANIK J. GAFFANEY 6 13N 10E 2174 2467 48.30 46.80 12.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 12.250 REMARKS: MWD - DGR. 20.000 112.0 3670.0 ALL DEPTHS ARE MEASURED BIT DEPTHS. MWD RUNS 1 & 2 WERE DIRECTIONAL WITH GAMMA RAY (DGR/ SGRC) . FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 54.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) all bit runs merged. BASELINE DEPTH GR 54.5 63.5 1855.5 1864.5 1885.0 1892.5 1904.5 1912.5 1954.0 1961.5 1978.0 1991.0 2051.5 2059.0 2081.5 2091.0 2132.5 2145.0 2142.5 2151.0 2173.0 2181.5 2193.0 2204.0 2225.0 2233.0 2266.5 2265.5 2300.0 2306.5 2333.5 2344.0 2429.0 2430.0 2499.5 2509.5 2579.5 2588.5 2636.5 2645.5 2644.5 2655.0 2667.5 2677.5 2727.0 2738.0 2757.0 2768.0 2801.0 2808.5 2810.5 2821.0 2824.5 2834.5 2840.5 2850.5 2917.5 2925.5 2952.0 2961.0 2979.0 2989.0 3011.0 3023.5 3230.0 3239.0 3246.0 3257.0 3307.0 3317.0 3384.5 3398.0 3481.0 3491.5 3494.0 3507.0 3510.0 3518.0 3599.5 3609.0 3606.5 3617.0 3660.0 3670.5 STOP DEPTH 3609.0 (WALS, 14-SEP-95). EQUIVALENT UNSHIFTED DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 114.0 1265.0 2 1265.0 3670.0 MERGED MAIN PASS. ROP WAS DEPTH SHIFTED WITH GR. CN WN FN COUN STAT /??SHIFT. OUT $ BP EXPLORATION (ALASKA) MPF-77 MILNE POINT NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 87 Tape File Start Depth = 3671.000000 Tape File End Depth = 50.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 21730 datums Tape Subfile: 2 207 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 63.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 1213.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 1. 12-SEP-95 ISC 2.11 / MPDS 1.22 3.93 / 3.94 MEMORY 1265.0 114.0 1265.0 0 .3 33.4 TOOL NUMBER P0419CG8 12.250 112.0 SPUD 8.60 88.0 10.5 250 9.6 .000 .000 .000 .000 .0 79.0 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-77 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 30 Tape File Start Depth = 1270.000000 Tape File End Depth = 50.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7324 datums Tape Subfile: 3 93 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 1214.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 3619.0 13-SEP-95 ISC 2.11 / MPDS 1.22 3.93 / 3.94 MEMORY 3670.0 1265.0 3670.0 0 30.7 32.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ TOOL NUMBER P0419CG8 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 12.250 112.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: SPUD 9.30 59.0 9.0 4OO 11.0 .000 .000 .000 .000 .0 85.0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 2. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-77 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length TIP TIP Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 59 Tape File Start Depth = 3671.000000 Tape File End Depth = 1210.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 36500 datums Tape Subfile: 4 122 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS 96/ 5/ 4 01 **** REEL TRAILER **** 96/ 5/ 4 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Sat 4 MAY 96 2:05a Elapsed execution time = 1.48 seconds. SYSTEM RETURN CODE = 0 MPF - 77 c(5~ I}¢: MILNE POINT ~7/ Run 1' 14 - September - 1995 DIFL/ZDL/CNIGR 1850 ~676 gg~ng Serwces Tape Subfile 2 is type: TAPE HEADER MILNE POINT UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER-. OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6479.00 K. RICHARDS J. GAFFNEY MPF - 77 500292259400 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 18-SEP-95 RUN 2 RUN 3 6 13N 10E 2174 2467 46.80 45.30 12.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 20.000 PRODUCTION STRING 12.250 REMARKS: DIFL/ZDL/CN/GR. CIRCULATION STOPPED 08:30, 14-SEP-95. 110.0 3670.0 PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CALIPER CORRECTED. THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DIL SDN 2435 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) depth shifted and clipped curves; .5000 START DEPTH STOP DEPTH 1851.0 3621.0 1906.0 3676.0 1880.0 3643.0 1916.0 3622.0 all EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH LL8 ILD RHOB NPHI 1899.5 1900.0 1912 . 0 1911.0 1912.5 1913.0 1913.0 1913.5 1921.5 1921.5 1930.0 1928.0 1936.0 1933.5 1941.0 1939.0 1949.0 1949.0 1950.0 1950.0 1950.5 1950.5 1951.5 1951.0 1953.5 1953.0 1954.0 1954.0 1954.5 1955.0 1955.0 1956.5 1955.5 1962.0 1961.0 1964.0 1964.0 1973.5 1973.0 1977.5 1977.0 1978.0 1979.0 1978.5 1978.5 1977.5 1979.5 1978.5 1980.0 1980.0 1981.0 1981.5 1981.5 1981.5 1981.5 1983.0 1984.0 1983.5 1984.0 1986.5 1986.5 1987.5 1994.5 1994.5 1995.0 1995.5 1995.5 1996.0 1996.5 1996.0 2003.5 2003.5 2004.0 2004.0 2003.5 2024.5 2024.5 2025.0 2025.0 2031.5 2031.5 2033.5 2034.0 2036.5 2036.5 runs merged; no case 2037.5 2038.0 2038.5 2040.0 2048.5 2049.5 2050.0 2051.5 2052.5 2053.0 2055.0 2055.5 2066.0 2066.5 2075.0 2135.0 2142.5 2143.0 2147.0 2152.5 2158.5 2159.5 2165.0 2169.0 2170.0 2170.5 2177.0 2207.0 2210.0 2210.5 2216.5 2219.0 2220.0 2220.5 2224.0 2229.0 2246.5 2253.0 2256.5 2270.0 2299.0 2312.5 2330.0 2333.0 2341.0 2344.0 2344.5 2345.0 2347.5 2360.0 2375.0 2379.0 2399.5 2401.0 2428.0 2436.0 2441.5 2445.5 2447.0 2467.0 2075.0 2144.0 2220.5 2246.5 2330.5 2428.0 2039.0 2040.0 2040.5 2048.0 2049.0 2050.0 2052.5 2053.5 2055.5 2056.5 2075.0 2143.5 2159.5 2160.5 2168.0 2169.0 2170.0 2207.0 2220.0 2225.5 2258.0 2344.0 2344.5 2401.5 2435.5 2444.0 2445.5 2039.5 2053.0 2066.5 2075.5 2147.5 2177.5 2210.5 2217.0 2220.5 2246.5 2313.0 2329.5 2333.5 2345.0 2360.0 2379.5 2400.0 2443.0 2466.5 2066.5 2134.5 2143.0 2147.0 2153.0 2158.5 2164.5 2207.5 2211.5 2220.5 2229.5 2253.0 2255.5 2270.0 2299.5 2330.0 2342.0 2345.5 2347.5 2375.5 . 2399.5 2428.0 2534. 2535. 2551. 2567. 2567. 2579. 2610. 2610. 2617. 2622. 2624. 2627. 2631. 2633. 2636. 2640. 2657. 2658. 2660. 2663. 2664. 2677. 2682. 2684. 2686. 2688. 26'89. 2708. 2719. 2724. 2724. 2736. 2752. 2752. 2755. 2758. 2764. 2765. 2769. 2773. 2776. 2781. 2781. 2798. 2803. 2807. 2809. 2811. 2818. 2819. 2823. 2824. 2827. 2829. 2835. 2836. 2840. 2841. 2843. 2847. 25~4.5 2633.5 2684.5 2724.0 2753.0 2769.5 2803.5 2824.0 2841.0 2844.0 2609.0 2609.5 2616.5 2724.5 2756.0 2759.5 2763.5 2764.0 2769.5 2774.0 2777.0 2781.5 2807.0 2818.0 2819.0 2824.0 2831.0 2834.5 2835.5 2841.0 2849.0 2535.0 2566.5 2579.5 2625.0 2627.5 2634.0 2640.5 2659.5 2661.5 2665.0 2677.0 2683.0 2685.0 2689.5 2724.5 2753.0 2769.5 2782.0 2840.5 Z534.5 2551.0 2566.5 2621.5 2631.5 2636.0 2640.0 2657.5 2663.5 2686.0 2688.5 2708.0 2721.5 2725.5 2738.0 2751.0 2781.5 2798.5 2808.5 2811.0 2828.5 2853.5 2856.0 2861.5 2877.0 2886.0 2888.5 2899.5 2903.5 2906.0 2906.5 2911.5 2913.0 2914.0 2916.5 2919.0 2926.0 2929.0 2943.5 2944.5 2945.0 2946.5 2952.5 2959.0 2962.5 2963.0 2963.5 2968.0 2971.0 2975.5 2979.5 2984.5 3002.5 3006.5 3019.5 3020.0 3022.0 3025.0 3025.5 3030.0 3058.5 3060.5 3065.5 3069.0 3076.5 3077.5 3078.0 3079.5 3087.5 3090.5 3107.5 3108.0 3110.0 3113.5 3115.0 3129.0 3138.5 3151.5 3184.0 3191.0 3201.5 2906.0 2916.5 2943.5 2947.0 2953.0 2959.5 2976.0 3019.5 3025.5 3076.5 3078.0 3110.0 2854.0 2911.5 2918.5 2925.5 2929.0 2944.5 2946.0 2947.5 2962.5 2963.5 2964.5 2968.0 2980.0 2986.0 3001.5 3006.0 3031.0 3058.5 3061.5 3116.0 3139.0 3191.5 2862.5 2878.0 2888.5 2906.0 2913.5 2947.5 2971.5 3022.0 3025.5 3058.5 3069.0 3079.5 3091.0 3108.0 3151.0 3201.0 2857.5 2886.0 2899.5 2903.0 2907.5 2914.0 2917.5 2948.0 2976.5 3020.5 3065.5 3068.5 3078.0 3088.0 3091.0 3108.0 3110.5 3114.0 3129.0 3184.5 3203.0 3224.5 3227.5 3228.0 3230.0 3238.5 3243.0 3246.0 3251.0 3251.5 3258.0 3267.0 3279.5 3280.0 3283.5 3287.5 3288.0 3289.0 3291.5 3295.5 3296.0 3301.0 3301.5 3302.5 3303.0 3308.5 3316.5 3323.0 3337.0 3339.5 3350.5 3356.0 3374.5 3377.0 3378.5 3379.0 3379.5 3382.5 3383.0 3383.5 3384.5 3399.0 3401.5 3408.5 3413.5 3416.0 3418.5 3442.5 3443.0 3450.5 3457.5 3459.5 3462.0 3464.5 3469.0 3469.5 3473.0 3473.5 3474.0 3482.5 3225.0 3230.0 3247.0 3279.5 3295.5 3317.0 3375.0 3378.5 3382.0 3399.0 3401.5 3443.0 3450.5 3462.0 3469.0 3243.0 3252.0 3252.5 3287.0 3288.5 3291.5 3300.5 3301.5 3302.5 3303.5 3309.0 3316.5 3350.5 3376.5 3378.0 3378.5 3379.0 3382.5 3384.0 3385.0 3413.5 3419.0 3457.0 3459.0 3474.0 3475.0 3475.5 3227.5 3230.5 3258.0 3280.0 3296.5 3337.0 3356.0 3383.0 3409.0 3416.5 3442.5 3451.0 3465.0 3469.5 .~203.5 3226.5 3228.5 3239.5 3267.5 3281.0 3284.0 3290.0 3296.5 3319.0 3324.5 3341.0 3409.0 3443.0 3470.0 3483.0 3487.0 3487.5 3491.0 3491.5 3495.5 3500.5 3501.5 3503.0 3503.5 3505.0 3505.5 3506.0 3508.0 3511.5 3517.0 3520.5 3532.0 3537.0 3537.5 3538.5 3539.5 3540.5 3545.5 3550.5 3560.0 3568.5 3573.0 3573.5 3575.5 3577.5 3578.0 3581.0 3582.5 3583.0 3587.5 3593.0 3599.5 3600.0 3604.0 3606.5 3614.0 3615.0 3615.5 3626.0 3626.5 3627.0 3637.0 3642.0 3642.5 3643.0 3647.5 3652.5 $ MERGED DATA SOURCE PBU TOOL CODE GR DIL SDN 2435 3500.5 3550.5 3600.0 3606.5 RUN NO. 1 1 1 1 3486.0 3487.0 3490.5 3491.5 3495.5 3502.5 3503.5 3505.5 3506.5 3508.5 3513.0 3516.5 3520.5 3531.5 3536.5 3537.5 3539.5 3540.0 3545.0 3560.0 3573.0 3573.5 3574.5 3576.5 3577.5 3582.0 3583.0 3587.5 3601.5 3613.5 3614.0 3615.0 3625.5 3626.5 3627.0 3636.5 3641.5 3642.5 3644.5 3646.5 3651.5 PASS NO. 4 4 4 4 3502.0 3506.0 3538.0 3550.5 3568.0 3580.5 3580.0 3605.0 3592.5 3598.5 MERGE TOP 1851.0 1906.0 1880.0 1916.0 MERGE BASE 3621.0 3676.0 3643.0 3622.0 $ REMARKS: MAIN PASS. MTEM, SP, TEND, & TENS WERE SHIFTED WITH LL8. ILM, RT, & DI WERE SHIFTED WITH ILD. DRHO, PEF, & CALl WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ??MATCH1. OUT / ? ?MATCH2. OUT / ? ?MATCH3. OUT / ? ?MATCH4. OUT $ : BP EXPLORATION (ALASKA) : MPF - 77 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIL 68 1 GAPI 4 2 LL8 DIL 68 1 OHMM 4 3 ILM DIL 68 1 OHMM 4 4 ILD DIL 68 1 OHMM 4 5 RT DIL 68 1 OHMM 4 6 DI DIL 68 1 IN 4 7 SP DIL 68 1 MV 4 8 MTEM DIL 68 1. DEGF 4 9 TEND DIL 68 1 LB 4 10 TENS DIL 68 1 LB 4 11 RHOB SDN 68 1 G/C3 4 12 DRHO SDN 68 1 G/C3 4 13 PEF SDN 68 1 BN/E 4 14 CALl SDN 68 1 IN 4 15 NPHI 2435 68 1 PU-S 4 16 FUCT 2435 68 1 CPS 4 17 NUCT 2435 68 1 CPS 4 4 08 310 01 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 43 995 99 1 4 43 995 99 1 4 43 995 99 1 68 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 265 Tape File Start Depth = Tape File End Depth = 3692.000000 1844.000000 Tape File Level Spa~ng = Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 66547 datums Tape Subfile: 2 698 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 0.500000 Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 4 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 1851.0 DIFL 1900.0 ZDL 1880.0 2435 1915.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT CABLEHEAD TENSION MODL MODAL SUB GR GAMMA RAY CN COMPENSATED NEUTRON ZDL Z-DENSITY TEMP TEMPERATURE PCM PULSE CODE MODULATOR DIFL DUAL INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): STOP DEPTH 3624.0 3680.0 3644.0 3622.0 14-SEP-95 FSYS REV. J001 VER. 1.1 830 14-SEP-95 1348 14-SEP-95 3670.0 3678.0 1850.0 3676.0 1500.0 TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 2222MA/2222EA 2806XA 3506XA 1503XA 12.250 110.0 .0 LSND 9.30 59.0 9.0 11.0 76.0 1.170 73.0 MUD AT BOTTOM Hu~,E TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF - 77 : MILNE POINT : NORTH SLOPE : ALASKA 1.x28 1.380 .000 1.570 .000 THERMAL SANDSTONE .00 .000 1.5 76.0 71.0 .0 69.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units 1 GR DIFL 2 RFOC DIFL 3 RILM DIFL 4 RILD DIFL 5 VILD DIFL 6 RT DIFL 7 DI DIFL 8 SP DIFL 9 TEMP DIFL 10 CHT DIFL 11 TTEN DIFL 12 SPD DIFL 13 ZDEN ZDL 14 ZCOR ZDL 15 PE ZDL 16 CAL ZDL 17 CNC 2435 18 CNCF 2435 19 CN 2435 20 LSN 2435 21 SSN 2435 68 1 GAPI 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 MV 68 1 OHMM 68 1 IN 68 1 MV 68 1 DEGF 68 1 LB 68 1 LB 68 1 F/MN 68 1 G/C3 68 1 G/C3 68 1 BN/E 68 1 IN 68 1 PU-S 68 1 PU-S 68 1 PU-L 68 1 CPS 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 07 310 01 1 4 4 07 220 06 1 4 4 07 120 44 1 4 4 07 120 46 1 4 4 07 995 46 1 4 4 07 120 46 1 4 4 07 120 44 1 4 4 07 010 01 1 4 4 07 660 99 1 4 4 07 635 99 1 4 4 07 635 99 1 4 4 07 636 99 1 4 4 46 350 01 1 4 4 46 356 99 1 4 4 46 358 01 1 4 4 46 280 99 1 4 4 43 995 99 1 4 4 43 995 99 1 4 4 43 890 01 1 4 4 43 334 31 1 4 4 43 334 30 1 84 * DATA RECORD (TYPE# 0) 974 BYTES * Total Data Records: 673 Tape File Start Depth = 3692.000000 Tape File End Depth = 1844.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 162647 datums Tape Subfile: 3 752 records... Minimum record length: 62 bytes Maximum record length: 974 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 3 .2500 VENDOR TOOL CODE START DEPTH GR 3342.0 DIFL 3392.0 ZDL 3371.0 2435 3406.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 3627.0 3683.0 3647.0 3625.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN ZDL TEMP PCM DIFL $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: 14-SEP-95 FSYS REV. J001 VER. 1.1 830 14-SEP-95 1230 14-SEP-95 3670.0 3678.0 1850.0 3676.0 1500.0 TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 2222MA/2222EA 2806XA 3506XA 1503XA 12.250 110.0 .0 LSND 9.30 59.0 9.0 11.0 76.0 1.170 1.128 1.380 73.0 76.0 71.0 MUD FILTRATE AT DHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF - 77 : MILNE POINT : NORTH SLOPE : ALASKA . v00 1.570 .000 THERMAL SANDSTONE .00 .000 1.5 .0 69.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIFL 68 1 GAPI 2 RFOC DIFL 68 1 OHM~ 3 RILM DIFL 68 1 OHMM 4 RILD DIFL 68 1 OHMM 5 VILD DIFL 68 1 MV 6 RT DIFL 68 1 OHMM 7 DI DIFL 68 1 IN 8 SP DIFL 68 1 MV 9 TEMP DIFL 68 1 DEGF 10 CHT DIFL 68 1 LB 11 TTEN DIFL 68 1 LB 12 SPD DIFL 68 1 F/MN 13 ZDEN ZDL 68 1 G/C3 14 ZCOR ZDL 68 1 G/C3 15 PE ZDL 68 1 BN/E 16 CAL ZDL 68 1 IN 17 CNC 2435 68 1 PU-S 18 CNCF 2435 68 1 PU-S 19 CN 2435 68 1 PU-L 20 LSN 2435 68 1 CPS 21 SSN 2435 68 1 CPS 4 4 07 310 01 1 4 4 07 220 06 1 4 4 07 120 44 1 4 4 07 120 46 1 4 4 07 995 46 1 4 4 07 120 46 1 4 4 07 120 44 1 4 4 07 010 01 1 4 4 07 660 99 1 4 4 07 635 99 1 4 4 07 635 99 1 4 4 07 636 99 1 4 4 46 350 01 1 4 4 46 356 99 1 4 4 46 358 01 1 4 4 46 280 99 1 4 4 43 995 99 1 4 4 43 995 99 1 4 4 43 890 01 1 4 4 43 334 31 1 4 4 43 334 30 1 84 * DATA RECORD (TYPE# 0) 974 BYTES * Total Data Records: 131 Tape File Start Depth = 3695.000000 Tape File End Depth = 3335.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 98250 datums Tape Subfile: 4 208 records... Minimum record length: Maximum record length: 62 bytes 974 bytes Tape Subfile 5 is type: LIS 95/ 9/18 01 **** REEL TRAILER **** 95/ 9/19 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 19 SEP 95 8:04a Elapsed execution time = 3.68 seconds. SYSTEM RETURN CODE = 0