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195-098
/44 -as" T I i'O ys9 Regg, James B (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> _ Sent: Tuesday, March 31, 2015 5:03 PM ( Z�' ' 5l/' To: Regg,James B (DOA) 1 Subject: MPH-05 (PTD# 1950980) Tree Growth &Wellhouse Subsidence Attachments: H-05_2009.JPG; H-05_2014.JPG; H-05_Flowline.JPG; H-05_SRiser.JPG Jim, On 3/29/15, during SVS testing of MPH-05 (PTD#1950980), it was observed that a combination of tree growth and well house subsidence may be stressing the well's S riser and high pressure spool.The attached pictures show a vertical misalignment of the S riser with respect to the lateral flow line. Also attached are pictures of the inside of the well house from 8/10/2009 and 7/26/2014 in which the tree's height has noticeably increased with respect to the wellhouse. The inspector suggested and field foreman agreed that the well be shut in until the S riser could be repositioned.The well was shut-in and freeze protected on 3/29/15.The plan forward is to: 1) Remove snow from flow-lines. 2) Disconnect flow-lines from riser. 3) Lower flow-lines to grade. 4) Fabricate new, longer, S riser piping to eliminate stress from the system. 5) Reconnect S riser to flow-lines. 6) Well will be ready for inspection and return to production. Weather and parts permitting, we expect to have the modification completed within two weeks. Please call with any questions. Thank You, Wyatt Rivard Well Integrity Engineer 0: (9O7) 777-R 517 1 C: (SO9)670-8O0I 1 wrivard@hilcorp.com 3800 Centcr'poinl Drive,Suite I‘1001 Anc.hora;t_, \I<0050:3 rI' h #4�ralll �t4'Ld_ li.i,( 1 f yy 4 ' x F I ,.,...---# .:1, 1 - ' ; ; '''',, aii 7,4, ,pi 1 ) co o `. � + o 4 rn i �1 1 &a 1 ,> o . 1 'N 411 —''.1 .,r o fi rti� �, • ` ZI .1 O • N 4-y O a V bA ca q '1 .,.t 0 (.. ' • , , r N ,/ , : ,,iii. • • .- _______„1. ,.‘,,,,,: 0 .; ..., M '-".,."( :4 --u .„,, ill ,__.._ AC Fr • J ,f, \ ' C r p ,—,c..1 . . ''''' ll' -Ili .4 .".....,''''',;: ....n, .. ...1 c, ____ . • .._ ..., ._ I. - , ir, ,,. - ...._ .. A+ ' - 0 ,,„, - ..,sw-.'. 8:.' - -' --'' :1,, . • O : AN r• �i O 0 ' l'''';''''':. •r• SAI h+M y'fi'` T�tl' ripVJ • x,i .. r i _ ' __ �- MPU H-05—stressed Section of the riser that }/ t ' S-riser; misalignment will be removed from valve and 1/ , ; with flowline re-fabricated. '\\ `�� , \.`: t above flow-line will be lowered `►► _ ISI iti 1 g-- 1111r.,sis* '14411V,.. ,. ti t� (� ► II! MPU H-OS—stressed �. 7r:fr-€.4.-....-r- flowline 1 3/29/15 Da' =�a- „- >" ii. rd 4ten A •...... .• ..r Page 2 of 2 KPH. 4-cs 12 r - 6 tq Soct so Regg, James B (DOA) From: AK, OPS MPU Well Ops Coord [AKOPSMPUWellOpsCoord @bp.com] Sent: Thursday, March 07, 2013 3:48 PM To: DOA AOGCC Prudhoe Bay Cc: AK, OPS MPU Field Ops TL; AK, OPS FF Well Ops Comp Rep Subject: FW: Attached Image / C -24 SVS testing Attachments: 0035_001.pdf Lou, Here is the information for MPH -05 leaning tree you requested. We had DHD crew and also the site engineer look at it when it was removed and there was no tension on the piping. MPC -24 / The test unit rigged down early as the well is not producing any solids. Is anyone available to witness the testing. I'm available anytime. PSLL and SSV Thanks Brian From: MPU mailroom [mailto:161.99.65.10] Sent: Thursday, March 07, 2013 3:38 PM To: Bixby, Brian D Subject: Attached Image «0035_001.pdf» SCANNED • 1 • WSR - MPH-05 - 12/8/2011. Page 1 of 1 WELL SERVICE REPORT Prb ii50q60 , - WELL DATE JOB SCOPE DAY SUPV MPH-05 12/8/2011 ANN-COMM BRYAN AFE Code DAILY WORK NIGHT SUPV AMKHPDWLO5 MIN WH-WH MAINT IN ID DEPTH TTL SIZE KEY PERSON UNIT 0 " 0 FT 0 " CH2-TRAMMELL NONE DAILY SUMMARY T/I/0=2001160/200. Conducted MM. Verified Energy ISO. Disconnected S-riser upstream of the divert valve to evaluate stress on flowlines & riser piping. All piping in satisfactory condition. Flow lines raised & hurdles adjusted accordingly. Torqued ,/ flange to spec & service tested connection. JOB COSTS SERVICE COMPANY - SERVICE DAILY COST CUMUL TOTAL CH2NTHILLLABoiR $1,500 $1,500 TOTAL FIELD ESTIMATE: $1,500 $1,500 file://C:\Program Files (x86)\AWGRS\Reports\Report.htm 3/7/2013 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 December 30, 2011 SLANNED FEB i+ `I 2W2 Mr. Tom Maunder G� Alaska Oil and Gas Conservation Commission q S _ - o 333 West 7th Avenue f_+ 5 Anchorage, Alaska 99501 �� P +I - 0 Subject: Corrosion Inhibitor Treatments of MPH -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPH -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 • . I I BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPH -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPH -01 1900860 50029220610000 Dust Cover NA NA NA 6.8 9/4/2011 MPH -02 1900870 50029220620000 Sealed Conductor NA NA NA NA NA MPH -03 1900880 50029220630000 Sealed Conductor NA NA NA NA NA MPH-04 1900890 50029220640000 Sealed Conductor NA NA NA NA NA - MPH -05 1950980 50029225720000 1.3 NA 1.3 NA 11.9 8/17/2011 MPH -06 1951150 50029225800000 0.2 NA 0.2 NA 5.1 10/9/2011 MPH -07A 2020240 50029225970100 6 NA 6 NA 59.5 10/31/2009 MPH -08B 2010470 50029228080200 1.2 NA 1.2 NA 17.0 9/4/2011 MPH-09 1971650 50029228040000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -10 1971490 50029227950000 1.2 NA 1.2 NA 11.9 10/31/2009 MPH -11 1971630 50029228020000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -12 1971700 50029228070000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -13A 2021670 50029228180100 0.8 NA 0.8 NA 8.5 8/17/2011 MPH -15 2051590 50029232840000 0.5 NA 0.5 NA 5.1 8/17/2011 MPH -16 2041900 50029232270000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -17 2070660 50029233580000 1.3 NA 1.3 NA 13.6 8/17/2011 MPH -18 2041740 50029232240000 18.6 NA Need top job MPH -19 2071360 50029233710000 0.1 NA 0.1 NA 2.6 9/4/2011 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 0 Abandon 0 Alter Casing 0 ChanQe Approved ProQram 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 65.60' 0 Suspend IS! Repair Well IS! Pull TubinQ 0 Operation Shutdown 0 Perforate 0 Plug Perforations 0 Stimulate 0 Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: Ii Development 0 Exploratol) 0 Stratigraphic Test 0 Service 0 Waiver ~ Other 0 TIme Extension Change Out ESP 0 Annular Disposal 5. Permit To Drill Number 195-098 6. API Number: 50-029-22572-00-00 -- 9. Well Name and Number: MPH-O5 8. Property Designation: ADL 380109 11. Present well condition summary Total depth: measured true vertical 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands Effective depth: measured true vertical 14130 6991 14017 6983 feet feet feet Plugs (measured) Junk (measured) NIA NIA feet Casing Structural Conductor Surface Intermediate Production Liner Length Size MD TVD Burst Collapse 80' 5306' 20" 9-5/8" 112' 5335' 112' 3700' 5750 3090 14079' 7" 14108' 6983' 7240 5410 1WEce, \lED JAN () n2'C' "!,n ~7 jl i it --8I'~~ L-80 ' 13306' Perforation Depth MD (ft): Perforation Depth TVD (ft): 13436' - 13520' 6724' - 6758' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 2-7/8",6.5# None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casino Pressure 18 2308 74 2342 Tubina Pressure 265 267 Oil-Bbl Prior to well operation: 26 Subsequent to operation: 476 14. Attachments: 0 Copies of Logs and Surveys run aa Daily Report of Well Operations aa Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory Ii Development 0 Service 16. Well Status after proposed work: aa Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman t ~. I Si{{nature ~ v' ('.ð-J:f-i'cÀA'ü.A--.. /,.P99~1 " '. f. ~6+-4f5Q Form 10-404 Revised 12/2003 i'W 111 ';) \I!~'~, ,,' ",,{ ! ~_:} ¡ ~ \~ F"'\ ~ BfL .... J.I, ~ 1- Title Technical Assistant ~ . ('" ""L j' Prepared By Name/Number: -k",.Pq~~, LJl-,-Oð'~Cnso.ndra Stewman, 564-4750 \.":»~lr'~U"{j(! ¡ì,"-~¡ ~ i, ¿;~ I,:il !¿;L Jt!;;,,¡ ,'jl/iìiJ'tl"I; <->¡"""-""" Tree: 2-9/16" - 5M FMC Wellhead: 11" 5M FMC wI 2-7/8" FMC Tubing Hanger, NSCT lift threads, 2.5" CIW H BPV profile 20" 91,1 ppf, H-40 II~' I KOP @ 900' Max Hole Angle = 68-70 deg, fl 3600' to 14,108' 9-5/8" 40#/ft., L-80 BTC. surf to 3357' 47 ppf 3357' to 5335' 15335' I Mid-perf TVD = 6741' Mid-perf MD = 13518' Stimulation Summary Perforation Summary Ref. Log LWD CDR 8-11-95 Size SPF Interval (TVD) 3-3/8 6 13436-13520' 6724'-6758' ALPHA Jet Charges @ 60 deg. phasing" DATE COMMENTS REV. BY 2/23/01 12/2/03 RWO Nabors 4ES RWO Nabors 4ES GMH Lee Hulme MPU H-O5 Orig. KB Elev. = 65.6' (N22E) Orig. GL Elev. = 36.0' RKB to Csg Spool = 26.2' (N22E I 13051' I I 13192' I Tandem Pump, 67 & 74 stg. I 13234' I GC3500, Mdl- GPMTAR 1:1 13265' I I 13266' I 13280' I Camco 2-7/8" x 1" KBMM GLM Camco 2-7/8" x 1" KBMM GLM HES 2-7/8" 8rd. "XN" Profile Nipple (ID 2.205"). Standard Bolt-On Intake Model - GPINTAR Intake @ (TVD) Tandem Seal Section GSB3 DB UT/LT IL H6 PFS AFLAS/HSN Motor, 266 HP, 2345 volt, 69 amp, Model KMH PumpMate w/6 fin Centralizer Intake @ (TVD) ORIG. (PBTD) 7", 26# 1-80 BTRC. 1140' I I 6655' I I I 1330,'lJ I 6670' PBTD TVD = 7006' 14018' I 14108' I MILNE POINT UNIT WELL H-05 API NO. 0-029-22 72 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/29/2003 11/30/2003 12/1/2003 From - To Hours 00:00 - 06:00 06:00 - 10:00 10:00 -14:00 14:00 -15:00 15:00 - 16:00 16:00 -18:00 18:00 - 20:30 20:30 - 21 :00 21:00-21:30 21 :30 - 00:00 00:00 - 01 :00 01 :00 - 02:00 02:00 - 03:00 03:00 - 04:30 04:30 - 05:30 05:30 - 06:00 06:00 - 06:30 06:30 - 07:00 07:00 - 09:00 09:00 - 15:00 15:00 -16:00 16:00 - 20:30 20:30 - 22:30 22:30 - 00:00 00:00 - 03:00 03:00 - 06:30 Page 1 of 2 BP EXPLORATION Operations Summary Report MPH-05 MPH-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 11/30/2003 Spud Date: 7/30/1995 End: Start: Rig Release: Rig Number: I NPT Phase Task Code 6.00 MOB 4.00 MOB 4.00 RIGU P P P PRE PRE PRE 1.00 KILL P DECOMP 1.00 KILL 2.00 KILL DECOMP DECOMP P P 2.50 KILL DECOMP P 0.50 KILL 0.50 KILL 2.50 KILL DECOMP DECOMP DECOMP P P P 1.00 KILL P DECOMP 1.00 KILL P DECOMP 1.00 WHSUR P 1.50 BOPSUR P 1.00 BOPSUR P DECOMP DECOMP DECOMP 0.50 BOPSUR P 0.50 BOPSUF P 0.50 BOPSUF P DECOMP DECOMP DECOMP 2.00 WHSUR P DECOMP 6.00 PULL DECOMP P 1.00 PULL DECOMP P 4.50 PULL P DECOMP 2.00 PULL DECOMP P 1.50 PULL DECOMP P 3.00 RUNCO~,p 3.50 RUNCO~,p COMP COMP Description of Operations RDMO from MPL-25. Move Rig and Equipment from MPL-Pad to MPH-05 Well. Spot Sub over Well. Spot Pits and Pipe Shed. Raise and scope Derrick. Lay lines to Tiger Tank. Accept Rig at 14:00 hrs. Hook up Lines to Production Tree. Take on first load of 9.0 Ib/ga1100 deg F. Brine in Rig Pits. Rig up Lubricator. Pull BPV. Lay down same. TP = 300 psi. Finish hook up lines. Work on Rotery Table alignment and chain guard while waiting for remaining Brine Take on second load of Brine in Rig Pits. Finish up on Rotery Table. Final load of Brine arrives on location. Pressure test lines to 3,500 psi. Blow down lines. PJSM with Co Rep, Tool Pusher, Mud Man, and Crew. TP = 300. CP = 670 psi. Start pumping 9.0 Brine at 100 deg F. down Tbg at 4 bpm/1200 psi. Finish killing Well at 4 bpm/1 ,200 psi. Pumped 510 bbl. Continue to circulate Well at 3 bpm/700 psi to clean up. Total Vol pumped = 750 bbls. Monitor Well. Well on slight vaG. Install TWC. Test at 2,500 psi. Blow down lines. Nipple down Production Tree. Nipple up BOPE. Rig up test equipment. Perform BOP body test at 250/3500 psi. Function test Rams. Perform Koomey test. State's right to witness test waived by J. Chrisp. Rig down test equipment. Blow down lines. Service Rig. Rig up Lubricator. Pull TWC. Lay down same. Monitor Well...Dead. PJSM with all. Pick-up Landing Jt. BOLDS. Pull Tbg Hanger to Floor. Pulled to 100K. Broke back to 93K. Tbg moving freely. Finish rigging up ESP handling equipment. Start POH with 2 7/8" 6.5 Ib/ft L-80 EUE 8rd Tbg and ESP Assy. Single down Tbg in Pipe Shed. Inspect Tbg...found some Jts with shallow internal pitting. Many Jts have pitting on the Pin End extending into the Starting Tnread. Stop to change out ESP cable Reels in Spooling Unit. Empty Clamp basket. Finished laying down Tbg. Tubing inspection same as mentioned above. Outside of Tbg showed very little Scale. Total 419 jts, 2 GLMs, and one XN-Nipple. Lay down ESP Assy. Motor OK. Pump turned free. Very little scale on outside of ESP Assy. C&C Floor. Remove Cable Reel from Spooling Unit and Install Reel with new #1 Cable. Prep to pick-up new ESP Assy. Begin to load Pipe Shed with new 27/8" Tbg. Pick-up and service ESP Assembly. Continue to load and tally 27/8" Tbg in Pipe Shed. Secure ESP Cable to ESP Assy. Finished loading and tally Tbg in Pipe Shed. Printed: 12/8/2003 8:51:57 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12/1/2003 12/2/2003 Date Page 2 of 2 BP EXPLORATION Operations Summary Report MPH-05 MPH-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Task Code NPT Phase 06:30 - 15:00 From - To Hours COMP 15:00 - 17:30 17:30 - 23:00 23:00 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 03:30 03:30 - 06:00 8.50 RUNCOI\,p 2.50 RUNCOI\,p 5.50 RUNCOI\,p COMP COMP 1.00 RUNCOI\,p 1.50 RUNCOI\ P COMP COMP 0.50 RUNCOI\ P 1.50 BOPSUR P 2.50 WHSUR P COMP COMP COMP Start: 11/30/2003 Rig Release: Rig Number: Spud Date: 7/30/1995 End: Description of Operations TIH with 75 joints B cond and 343 joints A cond 2-718", L-80 tubing and new ESP and cable. Make ESP cable splice. Slip and cut drilling line. TIH with 75 joints B cond and 343 joints A cond 2-7/8", L-80 tubing and new ESP and cable. MU landing joint and tubing hanger. Install penetrator and start upper ESP splice connection to pigtail. MU landing joint and tubing hanger. Install penetrator and complete upper ESP splice connection to pigtail. RIH wI landing jt, tubing hanger, RILDS. PUW = 96,000 Ibs; SOW = 27,000 Ibs. Land hanger, RILDS. Set and test TWC to 2500 psi. Drain BOP Stack. Blow down lines. Nipple down BOPE. Nipple up Production Tree. Test Tree and adaptor to 5K. Good test. Test ESP conductivity and downhole sensors--passed. Makeup lubricator and pull TWC, set BPV. Secure Cellar. Released Rig at 06:00hrs. Printed: 12/8/2003 8:51 :57 AM ANNULAR INJECTION DATA ENTRY SCREEN Asset Nliln.e. .......................................... Rig Name ~.~b.QI'.~..~F,, ............................. Inj Well Name M..P...H..:.0.~ ..................................... Sur Csg Dep ~.~.:~.~. ................ Legal Desc 3.8.~'.[~.L.4.0.~.8.'.~.EI, o..~.e.q..:3.4.,.T.~.;~.bI.,.B.~.0~ .................................. Research Permit Start ........ .~..1.~.~/.~.~ ........ Permit End ....... ~.;~/.:~.1/~.5. ....... Cumulative Data Rig. Completion Formation Intermittant Final Well Total MUd/Ctg Wash Fluids . FlUids Freeze FreeZe Daily Data ' MPH-05 08/19/95 438 438 '0'1~'~ ............................. :~"§'§~'"'~'~i:'i~'~8"'~,'[J'~'~'h'i:~; .......................... ~' .............. MPH-05 08/20/95 1,303 1,303 MPH-05 08/21/95 45 45 MPH-05 08/22/95 122 ,: 122 MPH-05 08/23/95 95 95 MPH-05 08/24/95 120 120 ....................................... / ......................... t .................................................. 1 ................................................................................................................................................................................................. 1 ................................................... 1 ................................................................................................................................................... MPH-O6 08/31/95 210 210 MPH-06 09/01/95 100 100 MPH-06 09/02/95 135 135 MPH-06 09/03/95 420 420 MPH-06 09/04/95 250 250 MPH-06 09/05/95 225 225 MPH-06 09/06/95 1,225 1,225 M P H-06 09/07/95 1,255 65 1,320 ared rvices rilling 900 East Benson Boulevard, MB 8-1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 December 14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission - 3001 Porcupine Dr. Anchorage, AK 99501-3192 Re: Annular Disposal Information Request Dear Ms. Mahan: RECEIVED DEC 114 11998 Alaska 0il & Gas Cons. Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular Disposal Records from July 25, 1995 through present time. We compared your list with our records and are able to provide yOu with the following data: Individual Annular Disposal Logs from the ssD database which coincide with the approved wells on your attached AOGCC Annular Log. The.SSD records are provided to you in the same order as listed on your log. · There were some wells on your list which were not injected into. These wells are identified as follows: · Endicott wells 1-03/P-16, 1-65/~-25, 1-59/0-24 · Exploration well Pete's Wicked #1 · Milne Point wells E-22, E-23, F-O1, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & K-05, K-02, H-07, K-25, K-37, E-17, F-21, K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F-49i, K-18 · PBU Wells E-38, 18-34, 15-42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because' the waste materials generated from these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disposal. · The wells listed above in BOLD were not permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be permitted with a Sundry Approval (1'0-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. · We also provide you with a cumulative report from our database of records from July 25, 1995 through the present. From those records, we show the following wells not listed on your report were used for annular disposal: ,, ,.Annular Disposal Letter .', 12/14/98 · Endicott wells 1-23/O-15, 1-61/Q-20, 2-40/S-22 · Exploration well Sourdoueh #3 - ~z°° ~ }~.~ ' · - Mime }'~nt wells F-06, H-05, H-06, J'13, L-24 - qs-o2 o · PBU wells-18-30, 18-31, 14~-4,,f~-43, E-34, E-36, G-04A, and S-33- 5z-Joz. · Individual logs are provided to ~ou ~ tties~ ~-ogs ~ We~l. · Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these records. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Enviromental Advisor at 564-4305. Sincerely, . . Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) RECEIVED :ii,"' Maska Oii & Gas Cons, CommissJo~ Anch0ra~0 f' , mr(~d SerVice DHIling in'ar Injection Volumes ily 25, 1995 until December 1998 ~mulative Report Surface Casing ' Inj Well Depth Jicott ,on 15 1-19/I-18 5000 'on 15 1-23/O-15 4246 'on 15 1-33/M-23 5013 Cum Mud Cum Rig Legal Desc Cum Total & Ctgs Wash Sec. 36, T12N, R16E 8,960 7,848 992 2020'FNL, 2087'FEW, SEC.36,T12N,R16E 32,084 30,604 1,160 3217'NSL, 2114'WEL, Sec 36,T12N, R16E 9,879 9,729 150 Cum Compl Cum Form Cumlnterm Cum Final Disposal Period Annulus Fluids FluidS Fleece Freeze Start End StatUs 120 12/5/95 12/5/96 Open 200 120 9/30/95 12/31/95 Open 8/31/95 12/31/95 Broached on 1..5 1-61/Q-20 4236 . 3075'NSL, 2207'WEL, Sec 13,T12N, R16E 25,228 21,379 2,613 1,176 60 12/5/95 12/5/96 Open on 15 2-40/S-22 4531 2020'FNL, .2289'FEL, Sec 36,T12N, R16E 31,195 29,952 1,063 120 60 7/25/95 12/31/95 'Open .o..n.....!.~ ....................... !.~:~? .............................. ~ !..~ .......................... .3...6..~.8...,...N..S...L.~...~..9..5.F.~.E.E. ~?..2..2.,..T..!..!.U,.....R.!.~.E.. ............................. 3...,...o..0...2. .................................... .9...o..~ ............................. ..2.,? ................................................................................................................................................................................................ .9.._o.. ................ o..n...!..~ ............................. p.s......!.. ~:~ ....................... ~.8.~.9... ................................ ~7. ~..9...'......N.~..L.,......5...! ~..O..L..W...~.L.~....S..e.?..2..,.....T..!..!' N..., ............................................ .1. ,.?~ .............................. !?..9. ~ .................................... !..3..~ .............................................................................................................................................................................................. .5j ................... on 14 DS 15-48 3548 Sec. 22, T11N, R14E 3,385 216 820 2,283 66 12/21/95 12/21/96 Open :)n 14 DS 15-49 3667 4676' NSL, 5165' WEL, Sec. 22, T11N, 4,669 1,559 1,141 1,904 65 2/21/96 2/21/97 Open 3n 9 · 18-30 3930 1499'SNL, 26'WEL, Sec 24,T11N, R14E .2,266 936 380 800 150 7/25/95 12/31/95 Open 3n 9 18-31 3680 3719'NSL, 64'WEL, Sec 24,T11N, R14E 6,086 2,250 1,100 2,565 171 7/26/95 12/31/95 Open :)n 9 18-32 3830 3632'NSL, 41'WEL, Sec 24,T11N, R14E 3,311 1,861 200 1,i00 150 8/24/95 12/31/95 Open :)n 9 18-33 4140 3690'NSL, 56'WEL, Sec 24,T11N, R14E 5,215 2,050 3 035 10 120 9/28/95 12/31/95 Open :)rs 18E 12-35 3543 348'NSL, 705'WEL, Sec 18,T10N, R14E 3,723 3,436 137 150 9/1/95 12/31/95 Open ~rs 18E 12-36 3452 63'FSL, 899'FEL, Sec 18,T10N, R15E 4,002 1,961 50 1,871 120 10/13/95 12/31/95 Open ~rs 18E 13-36 3431 1585'NSL, 5187'WEL, Sec 13,T10N, R14E 4,137 3,523 464 150 10/26/95 12/31/95 Open )rs 18E 14-44 3288 2829'NSL, 1617'WEL, Sec 9,T10N, R14E 3,974 2,319 1,535 120 8/17/95 12/31/95 Open Ioration 4 Sourdough #3 4236 2245'FSL, 5067' FEL, Sec. 29, T9N, R24E 5,786 4,630 1,156 1/26/96 1/26/97 Closed e -' MPK-17 3508 3648'NSL,2100'WEL, Sec.03,T12NR 11E 19,608 18,538 285 685 !00 4/18/96 4/18/97 Open 130 1/25/96 1/25/97 Open ~rs 22E MPC-25 8595 1143'FNL, 2436'FWL, Sec 10,T13N, R10E 1,905 1,465 300 140 1/5/96 1/5/97 Open ~rs 22E MPC-26 4704 1086 NSL, 2419 WEL, Sec 10,T13N, 5,228 4,483 555 190 12/19/95 12/19/96 Open ~rs 22E MPC-28 5405 Sec 10,T13N, R10E 425 350 75 2/15/96 2/15/97 Open Page 1 DEC 1 4. 1998 ;ha,,r~d Service DHIling knn[~l"ar Injection Volumes ruly 25, 199S until December 1998 :umulative Report Surface Casing ig Inj Well, Depth abors 22E MPF-06 8766 , . ~bors 22E MPF-14 6690 ~bors 22E MPF-70 7919 ~bors 22E MPH-05 5335 Cum Mud Cum Rig CumCompl Cum Form Cum Interm, Cum Final Disposal Period Legal Desc Cum Total & Ctgs Wash Fluids Fluids , Freeze Freeze start End, Sec 06,T13N, R10E 1,927 1,731. 196 1/25/96 1/25/97 Sec06,T13N, R10E UM 18,717 17,107 1,270 ' .....37 ....... 6/3/96 6/3/97 ......... 2189'NSL, 2591'WEL, Sec 6,T13N, R10E 19,775 18,794 735 . 190 56 6/17/96 6/17/97 2882'NSL, 4028'WEL, Sec 34,T13N, R10E 8,283 7,711 382 190 8/19/95 12/31/95 Annulus Slalus Open Open Open Open ~bors 22E MPH-06 7304 2824'NSL, 4044'WEL, Sec 34,T13N, R10E 8,515 8,335 180 8/5/95 12/31/95 Open ~b°rs 22E MPI-07 2680 2339'NSL, 3906'WEL, Sec 33,T13N, R10E 1,680 1,280 250 80 70 9/21/95 12/31/95 ,Open ~b°rs 22E MPJ-13 2835 2319'NSL, 3179'WEL, Sec 28,T13N, R10E 14,127 13,292 645 60 130 10/17/95 12/31195 Open ~b°rs. 22E .... ?~J'.! 6 .......... 3!.!2 ~.!.7...'...N..~L.,.....~.33..61v~!~.t~C ~,T!.3N,.....R..!~..O.E ............................. ~.8,? ........................... 9..? 70 11112/95 12/31195 . open ~bors 27E B-24 4080 Sec 18,T13N, R11E UM 1,468 1,396 72 . 1/25/96 1/25/97 Open ~bors 27E MPF-22 8841 Sec06,T13N, R10E UM 6,536 6,466 . 70 12/12/95 12/12/96 Open tbors 27E MPF-25 3405 1857'NSL, 2696'WEL, Sec 6,T13N, R10E ' 9,897 9,357 250 225 65 12/26/95 12/26/96 Open tbors 27E MPF-37 6621 1931'NSL, 2643'WEL, Sec 6,T13N, R10E 7,032 6,887 70 75 7/25/95 12/31/95 Open ' ~bors 27E MPF-38 8561 1994'NSL, 2731'WEL Sec 6 T13N R10E 9,232 9,157 ' 75 12/6/95 12/31/95 Open ~bors 27E MPF-45 6678 1979'NSL, 2608'WEL, Sec 6,T13N, R10E 17,562 17,381 181 7/31/95 12/31/95 ' Open ~bors 27E MPF-53 6750 2028'NSL 2572'WEL Sec 6 T13N R10E 6 051 5 671 165 75 60 80 8/19/95 12/31/95 Open ........................................................................................................................................................................................................ · ....~ ............................................ .'. ......................... .'. ....................... ~ .................................................................... .'. .................................................... ,. ........................................................................................................................................................................................................................................................................................................................................ ~ ......................................................................................................... ~bors 27E MPF-61 6585 2077'NSL, 526'WEL Sec 31,T14N, R10E 5,732 5,657 75 8/31/95 12/31/95 Open ~bors 27E MPF-62 6059 2141'NSL, 2627'WEL, Sec 6,T13N, R10E 386 316 70 10/13/95 12/31/95 Open ~bors 27E MPF-69 5772 2125'NSL, 2502'WEL, Sec 6,T13N, R10E 9,740 9;665 75 8/31/95 12/31/95 Open ~bors 27E MPF-78 7085 2237'NSL, 2555'WEL, Sec 6,T13N, R10E 8,476 7,456 40 775 65 140 9/12/95 12/31/95 Open .bors 27E MPL-24 6515 3654'NSL, 5180'WEL, Sec 8,T13N, R10E 6,790 4,900 1,320 165 335 70 11/27/95 12/31/95 Open 3A E F-33 3570 3332'NSL 2174'WEL Sec2T11N R13E 1 468 183 660 465 160 2/21/96 2/21/97 Open E F-36 3691 2642'NSL, 2878'WEL, Sec 2,T11N, R13E 6,963 1,998 1,359 3,471 135 12/18/95 12/18/96 Open yon 9 D-30 3456' 3625' NSL, 1066' WEL, SEC. 23, T11N, 5,261 2,811 1,275 1,035 140 1/31/96 1/31/97 Open yon 9 D-31 3215 SEC. 26 T11N, R13E 150 150 4/20/96 ' 4/10/97 Open yon 9 D-33 3222 2965' NSL, 1067' WEL, SEC. 23, TllN, 4,661 2,425 2,106 130 2/21/96 2/21/97 Open bors 18E S-43 3121' 4211'NSL,4503'WEL,SEC35,T12N,R12E 5,943 2,636 1,716 1,511 80 5/7/97 5/7/98 OPEN Page 2 Shared S~i;~ice Dr..illing ~,nn1~i~'r injection Volumes July 25, 1995. until December 1998 ;umulative Report labors 28E 'abors 28E , . abors 28E abors 28E abors 28E , , abors 28E ~..~,E.,.. abors 28E Inj Well B-33 E-34 E-36 E-37 Sudace Casing Depth 3504' 3664 ..... 3648 ,, 3810 E-39 3638 G-O4A 3509 G-21 3509 S-24 275O Cum Mud Cum Rig Cum Compl Cum Form Cum Inlerm Cum Final Disposal Period Annulus Legal Desc .. Cum To~a!. & Ctgs Wash Fluids Fluids Freeze Freeze Start End. Status 969'SNL, 1898'EWL, Sec 31, T11N, R14E 3,974 2,842 857' 195 80 5/1/96 12/31/96 Broached 168'SNL, 500'WEL, Sec6, TllN, R14E 9,656 7,228 1,420 858 40 110 8/23/95 12/31/95 Open 1706'SNL, 822'WEL, Sec. 6,TllN, R14E 9,271 4,417 1,293 3,096 365 100 7/25/95 12/31/95 Open 3391'NSL, 881'WEL, Sec 6,T11N, R14E 4,695 4,241 374 80 9/16/95 12/31/95 Open 3358'..N,~L 5.01,1~,E.L! Sec 6~.T.! !....N, R1.4E ............................... ~.,..2.5(~ ............................. 9~8..' ..........2?? ............!..~.o...22 ............................................. 80.. 8~28/95 ....... !2/3!!~5 .. ......... ~)..p.~[~ ..... 2917'NSL 1974'WEL, Sec 12,T11N, R13E 5,937 1',798 1,824 2,315 10/20/95 12/31/95 Open 2911'NSL 2368'WEL, Sec 12,T11N, R14E 11,430 3,956 3,072 4,270 70 '62 9/8/95 12/31/95 Open 1633'SNL 4228'WEL, Sec 35,T12N, R 12E 20,261 11,773 2,177 5,751 275 285 12/9/95 12/9/96 Open abors 28E S-33 2958 1639'SNL. 1487'WEL, Sec 35,T12N, R12E 18,014 6,613 2,431 8,392 270 308 12/1/95 12/1/96 Open abors 28E S-41 3331 4152' NSL 4504' WEL, Sec 35,T12N, 8,062 4,159 2,034 1,754 115 2/8/96 2/8/97 Open ~?.~...2.8....E. ....................... ..s...-.~.2 ............................................. ~.0...7.7.. ................................. ~.e_o...~.~,.....T. 1...2.~.,......R_.!.~.E. ........................................................................................................ !~.8. ...................................... ??., ................................................................................................................................................................................................................. ~ ................ ~,/,?.~ .......................... ,3.,!,!..3.!..9...7.. ......................... .O_p.?.,.,n. ............ abors 2ES H-35 3157 4535'NSL, 1266'WEL, Sec 21,T11N, R13E 4,860 3,725 555 480 20 80 10/26/95 12/31/95 Open abors 2ES H-36 3550 4478'NSL, 1265'WEL, Sec 21,T11N, R13E 1,452 857 100 410 85 10/26/95 12/31/95 Open Page 3 rii.!Jing TO: Blair Wondzeil FROM: Chris West DATE: October 27, 1995 SUBJECT: APl # MPB-24 Well Suspension 50"029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20- AAC 25.110. As discussedthis morning We propose'setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8" x 7" annulus available for the injection of liquid wastes. There are no other well annulii on this pad for injection. The annulus for MPB-24 was approved for injection as Part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call me if I may be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 -. STATE OF ALASKA -~ ALASK/ _ AND GAS cONSERVATION COMN REPORT OF SUNDRY WELL OPERATIONS ,ION 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 65.60' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2882' NSL, 4027' WEL, Sec. 34, T13N, R10E, UM MPH-05 At top of productive interval 9. Permit Number / Approval No. 195-098 3086' SNL, 4510' EWL, Sec. 01, T12N, R10E, UM 10. APl Number At effective depth 50-029-22572-00 3399' SNL, 4936' EWL, Sec. 01, T12N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 3462' SNL, 5021' EWL, Sec. 01, T12N, R10E, UM Sands 12. Present well condition summary Total depth: measured 14130 feet Plugs (measured) true vertical 6991 feet Effective depth: measured 14017 feet Junk (measured) true vertical 6950 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 5306' 9 5/8" 1250 sx Permafrost 'E', 435 sx 'G' 5335' 3700' Intermediate Production 14079' 7" 461 sx Class 'G' 14108' 6983' Liner "~ ,~ . '~'~ ,~'~ ...... Perforation depth: measured 13436' - 13520' R E true vertical 6724' - 6758' F E B ~ '~ ~ 0 01 Tubing (size, grade, and measured depth) 2 7/8% 6.5#, L-80 to 13310' Alaska Oil & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~/"~¢ ~ Title Technical Assistant Date ¢ '''~' ~-~' '0/ Prepared By Name/Number: Terrie Hubble, 564-4628 . Form 10-404 Rev. 06/15/88 0 ~ i ~ i~'~i~%~' ' ' ?'~' [ [ .~ ,t~,~, L~ ~'i Submit In Duplicate .~ ~ BP EXPLORATION Page 1 of 1 Operations Summary Report Legal Well Name: MPH-05 Common Well Name: MPH-05 Spud Date: 7/30/1995 Event Name: REPAIR Start: 2/22/2001 End: Contractor Name: NABORS Rig Release: 2/24/2001 Group: RIG Rig Name: NABORS 4ES Rig Number: 4 Date From-TO Hours TaSk Code Phase Description of Operations 2/22/2001 00:00 - 02:00 2.00 MOB PRE MOVE ON MPU H-5. L/D MATTING & BERM AROUND RIG. 02:00 - 03:30 1.50 MOB PRE RAISE & SCOPE DERRICK. ACCEPTED RIG @ 0300 HRS, 2-22-01. 03:30 - 04:30 1.00 MOB PRE SET & BERM TIGER TANK. RUN & TEST HARD LINES. 04:30 - 05:30 1.00 MOB PRE R/U HCR VALVE TO TREE. TAKE ON KILL FLUID. 05:30 - 06:00 0.50 WHSUR DECOMP P/U LUBRICATOR & PULL BPV. L/D SAME. 06:00 - 07:30 1.50 WHSUR DECOMP PRESSURE TEST SURFACE LINES TO TREE. 3500 PSI, OK. HELD PRE-JOB SAFETY MTG PRIOR TO KILLING WELL. 07:30 - 12:00 4.50 KILL DECOMP KILL WELL @ 3 BPM 1600 PSI. W/10 PPG FLUID. SITP 400 PSI, SICP 650 PSI. S/D & MONITOR WELL. WELL DEAD. 12:00 - 12:30 0.50 WHSUR DECOMP INSTALL & TEST TWC VALVE. 12:30 - 15:00 2.50 WHSUR DECOMP NIPPLE DOWN X-MAS TREE. 15:00 - 20:00 5.00 BOPSUF~ DECOMP NIPPLE UP BOPE. 20:00 - 20:30 0.50 BOPSUF~ DECOMP P/U LANDING JT & TEST PLUG. R/U TO TEST BOPE. 20:30 - 22:00 1.50 BOPSUF~ DECOMP HSE STAND DOWN. HELD SAFETY REVIEW W/BOTH CREWS. 22:00 - 00:00 2.00 BOPSUR DECOMP PRESSURE TEST BOPE. HP 3500 PSI, LP 250 PSI, OK. TEST i WITNESSING WAIVED BY JOHN CRISP W/AOGCC. 2/23/2001 00:00 - 00:30 0.50 BOPSUF' DECOMP I FINISH TESTING BOPE. 00:30 - 01:30 1.00 WHSUR DECOMP i P/U EXTENSION & PULL TWC VALVE. 01:30 - 02:30 1.00 PULL DECOMP CHECK ANNULUS. WELL DEAD. BOLDS. PULL HGR. P/U WT 93K. TEST PENETRATOR, OK. SHOOT FLUID LEVELS. 02:30 - 07:30 5.00 PULL DECOMP PULL 2 7/8" COMPLETION STRING. 07:30 - 08:30 1.00 PULL DECOMP CHANGE OUT ESP CABLE SPOOLS. 08:30 - 14:00 5.50 PULL DECOMP CONTINUE TO PULL 2 7/8" COMPLETION SPOOL, 14:00- 16:00 2.00 PULL DECOMP L/D & INSPECT ESP. CLEAR FLOOR. 16:00 - 19:00 3.00 PULL DECOMP BOTTOM 32 STANDS OF TBG VERY CORRODED & PITTED. TIH HOLE & L/D 97 JTS TBG. 19:00 - 21:30 2.50 RUNCOI~I COMP P/U SERVICE ESP. CLAMP CABLE. 21:30 - 00:00 2.50 RUNCOAI COMP P/U 97 JTS OF 2 7/8" TBG ("B" CONDITION) RIH W/SAME. 2/24/2001 00:00 - 01:30 1.50 RUNCOAI COMP FINISH PICKING UP & REPLACING 97 JTS OF 2 7/8" TBG. 01:30 - 04:30 3.00 RUNCOi~I COMP RIH WI 2 7/8" COMPLETION TO 7300'. 04:30 - 08:00 3.50 RUNCOI~I COMP CHANGE OUT ESP CABLE SPOOLS. MAKE MID-RUN CABLE SPLICE & TEST SAME. 08:00 - 11:00 3.00 RUNCOrtrl COMP CON'T TO RIH W/2 7/8" COMPLETION. FLUSH PUMP EVERY 2000'. 11:00 - 11:30 0.50 RUNCO.~. COMP M/U HANGER & LANDING JT. 11:30- 13:30 2.00 RUNCON1 COMP SPLICE EFT CONNECTOR & TEST SAME. 13:30 - 14:00 0.50 RUNCOIVq COMP LAND & RILDS. SET & TEST TWC CHECK. L/D LANDING JT. P/U WT 94K S/O WT 27K. 14:00 - 16:00 2.00 BOPSUF COMP DRAIN STACK & N.D BOPE. 16:00 - 17:00 1.00 WHSUR COMP N/U X-MAS TREE. 17:00 - 17:30 0.50 WHSUR COMP TEST X-MAS TREE & HANGER VOID TO 5000 PSI, OK. 17:30 - 19:30 2.00 WHSUR COMP P/U LUBRICATOR. PULL TWC VALVE. INSTALL BPV & L/D LUBRICATOR. 19:30 - 21:00 1.50 DEMOB COMP R/U HB&R FREEZE PROTEST TBG W/15 BBLS DIESEL. PROTECT ANNULUS WI 67 BBLS DEAD CRUDE. 21:00 - 22:30 1.50 DEMOB COMP CLEAN PITS & OFFLOAD EXCESS BRINE. 22:30 - 23:00 0.50 DEMOB COMP CLEAN CELLAR & SECURE WELL. RELEASE RIG @ 2300 HRS 2-24-01. FEB Alaska Oil & Gas Cons. i;~E~fj:li,~;~l¢i~oo~ 3:07:03 PM Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION L;OMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Pull Tubing [] Operation Shutdown [] Stimulate [] Plugging 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 i--lAIter Casing [] Repair Well [~Other 4. Location of well at surface 2882' NSL, 4028' WEL, Sec. 34, T13N, R10E, UM At top of productive interval 3081' SNL, 4515' EWL, Sec. 2, T12N, R10E, UM At effective depth 3394' SNL, 4943' EWL, Sec. 2, T12N, R10E, UM At total depth 3457' SNL, 5026' EWL, Sec. 2, T12N, R10E, UM 5. Type of well: [] Development I--] Exploratory [] Stratigraphic I--I Service [] Perforate Replace ESP Completion 6. Datum Elevation (DF or KBE) KBE = 66' 7. Unit or Property Name Milne Point Unit 8. Well Number MPH-05 9. Permit Number / Approval No. 95-98 10. APl Number 50- 029-22572 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 14130' feet 6992' feet 14017' feet 6950' feet Length 80' 5306' 14079' Size 20" 9 5/8" 11 Plugs (measured) Junk (measured) Cemented 250 sx AS1 (approx.) 1250 sx PF 'EY435 sx 'G' 461 sx Class 'G' MD TVD 112' 112' 5335' 3687' 141 O8' 7041' Perforation depth: measured 13436'-13520' true vertical (Subsea) 6659' - 6693' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 13295' Packers and SSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments I-'] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [~ Oil I-1 Gas I--I Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~¢~~ (~/. ,/(~z~¢¢_-~ Title,t--~----~c~r(~¢/ 7~_-~Z /2~~ Date ~' ~'~ Prepared By Name/Number: Submit In Duplicate'~ Form 10-404 Rev. 06/15/88 Facility M Pt H Pad Progress Report Well MPH-05 Page 1 Rig Nabors 5S Date 08 September98 Date/Time 30 Aug 98 31 Aug 98 01 Sep 98 02 Sep 98 03 Sep 98 06:00-06:30 06:30-17:00 17:00-18:00 18:00-18:30 18:30-19:00 19:00-23:00 23:00-23:30 23:30-01:30 01:30-03:00 03:00-04:30 04:30-06:00 06:00-06:30 06:30-11:30 11:30-13:00 13:00-14:00 14:00-16:00 16:00-18:00 18:00-20:00 20:00-23:00 23:00-00:00 00:00-00:30 00:30-02:30 02:30-06:00 06:00-06:30 06:30-00:30 00:30-05:00 05:00-06:00 06:00-06:30 06:30-10:00 10:00-15:00 15:00-15:30 15:30-18:00 18:00-18:30 18:30-21:30 21:30-00:30 00:30-05:30 05:30-06:00 06:00-06:30 06:30-10:00 10:00-11:00 11:00-13:00 13:00-14:00 14:00-15:00 15:00-16:00 Duration 1/2 hr 10-1/2 hr lhr 1/2 hr 1/2 hr 4hr 1/2 hr 2hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 5hr 1-1/2 hr lhr 2hr 2hr 2hr 3hr lhr 1/2 hr 2hr 3-1/2 hr 1/2 hr 18hr 4-1/2 hr lhr 1/2 hr 3-1/2 hr 5hr 1/2 hr 2-1/2 hr 1/2 hr 3hr 3hr 5hr 1/2 hr 1/2 hr 3-1/2 hr lhr 2hr lhr lhr lhr Activity Held safety meeting Rig moved 100.00 % Rigged up High pressure lines Held safety meeting Rigged up High pressure lines Bullhead well Flow check Bullhead well Monitor wellbore pressures Circulated at 5700.0 ft Monitor wellbore pressures Held safety meeting Rig waited · Materials Circulated at 8000.0 ft Monitor wellbore pressures Removed Xmas tree Installed BOP stack Repaired Choke line Tested BOP stack Rigged down Lubricator Retrieved Tubing hanger Removed Tubing hanger Retrieved ESP Held safety meeting Retrieved ESP Conducted slickline operations on Slickline equipment - Tool run Rigged up sub-surface equipment - ESP Held safety meeting Installed ESP Ran Tubing to 3700.0 ft (2-7/8in OD) Circulated at 3700.0 ft Ran Tubing to 5600.0 ft (2-7/8in OD) Held safety meeting Ran Tubing to 8200.0 ft (2-7/8in OD) Installed Electric cable Ran Tubing to 11200.0 ft (2-7/8in OD) Circulated at 11200.0 ft Held safety meeting Ran Tubing to 13295.0 ft (2-7/8in OD) Circulated at 13295.0 ft Installed Electric cable Installed Tubing hanger Removed BOP stack Installed Xmas tree STATE OF ALASKA ALASK,~ OIL AND GAS CONSERVATION L;L)MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other Replace ESP Completion 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2882' NSL, 4028' WEL, Sec. 34, T13N, R10E, UM At top of productive interval 3081' SNL, 4515' EWL, Sec. 2, T12N, R10E, UM At effective depth 3394' SNL, 4943' EWL, Sec. 2, T12N, R10E, UM At total depth 3457' SNL, 5026' EWL, Sec. 2, T12N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KBE) KBE = 66' 7. Unit or Property Name Milne Point Unit 8. Well Number MPH-05 9. Permit Number / Approval No. 95-98 10. APl Number 50- 029-22572 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 14130' feet 6992' feet 14017' feet 6950' feet Length 80' 5306' 14079' Size Plugs (measured) Junk (measured) Cemented 20" 9 5/8" 250 sx AS1 (approx.) 1250 sx PF 'E'/435 sx 'G' 1, 461 sx Class 'G' MD TVD 112' 112' 5335' 3687' 14108' 7041' Perforation depth: measured 13436'-13520' true vertical 6724'-6758' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 13118' APR '1 ]998 Packers and SSV (type and measured depth) None Gas Cons. C0r,q~issi0n A.qch¢,a~e 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 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord ,~~ ~ (/'-)~ Title Engineering Supervisor Date · / Prepared By Name/Number: Mary Youngers 564-5242 Form 10-404 Rev. 06/15/88 Submit In Duplicate r,:, E R H I T Geolog{cal Hai:er"ials Inven'f;or"y D A T A T D A T A_P L IJ 8 JR IJ i"..l Ii P., 'F E ..... [:i: E C V 95-098 9 B ...... 098 9 5 - 0 9 8 6 s 2 a cF/~ t 6 s 7 - i (SR/CCL. ~ 11677 ..... 1 S B T / G R / ,3 ,'2 L (-- % N I 0 .... h. 0 7 C ~,~, DALLY WELL OPS Ar"e dt'"y ditch sampies r"equir'ed? yes ~And r' e c e 'i v e d '? 09/'1 a/'95 )~i~)~i" 0 9 / I a. / 9 5 Was the well cor'ed? yes ~;~na'iysis & descr"ip't:i'on r'-eceived? ~_._ Received? ye SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPH-05 Rig Name: N-4ES AFE# 339037 Accept Date: 01/31/97 Spud Date: - Release Date: 02/03/97 JANUARY 31, 1997 RIG ACCEPTED @ 0600 HRS. RIG, BERM & TAKE ON 8.7 PPG BRINE & RIG LINES TO TREE PULL BPV W/LUB. KL WLL W/8.7 PPG. THROUGH CHOKE TO '1-1-. SHUT IN & MONITOR AFTER ALL INFLUX OUT & TBG. SIP =190 PSI. INCREASE BRINE WT. TO 9.0 PPG. & CIRC. @ 3-BPM SITP =130 SICP 170 INCREASE BRINE WT TO 9.2 PPG. SITP -110 PSI. TALK TO MPU ASSET & AGREED TO SHUT IN MPU H-O6i INJECTOR FOR H-05. BUILDING BRINE WT. TO 9.6 PPG. & CIRC. SAME. FEBRUARY 01, 1997 CONT. TO CIRC. WELL BORE W/9.7 PPG. NACL & MONITOR SAME. SET TWC & ND TREE, NU BOP;S & INSTALL NEW KILL LINE. SET TEST PLUG & TEST BOP'S TO 250 LOW & 5000 HIGH WITNESS (CHUCK SHEVEY W/AOGC). PULL HANGER TO FLOOR & CK OUT. CBU & MONITOR WELL FOR 15-MIN. POOH W/ESP COMPLETION. FEBRUARY 02, 1997 CONT. POOH & LD ESP ASSY. RIG HES WIRE LINE TRK & RIH W/5.9" GR/JB TO 3690' & STOPPED POOH & REC. 4 BANDS RUN #2 RIH W/SAME TO 7074', POOH, REC 1 BAND RIH #3 W/3.75" GAUGE TO GET TD & STOPPED @ 13400' & POOH & RD. MU MULE SHOE SCRAPER SPACED TO ABOVE PERFS & RIH TO 14003' (4ES) REV CIRC 2 VOLUMES F/LOSS 36 BPH WHILE REVERSING & MONITOR WELL FLOWING. POOH TO ABOVE PERFS & MONITOR WELL (FLOWING SLIGHTLY) MONITOR SLIGH FLOW F/ANNULUS TBG STATIC CBU CONV. @ 5BPM MONITOR FLOW & FLOWED 1 ~ BBLS F/ANNULUS & TBG. WT. UP TO 9.7+ & CIRC. TO BALANCE WELL BORE. FEBRUARY 03, 1997 CONTINUE TO CIRC & RAISE NACL WT TO 9.7+ & MONITOR. POOH. MU & SERVICE ESP. RIH W/ESP ASSY. SLIP 42' DRLG. MAKE SPLICE @ ESP CABLE. TIH W/ESP COMPLETION & MU HANER & LANDING JT. MAKE SPLICE IN ESP CABLE @ HANGER. FEBRUARY 04, 1997 MAKE SPLICE IN ESP CABLE @ HANGER. LAND TUBING RILDS LD LANDING JT. & SET TWC. ND BOP'S & NU TREE, TEST HANGER, TREE TO 5000 PSI. PULL TWC, SET BPV & FREEZE PROTECT WELL W/DIESEL. RIG DOWN LINES & SECURE TREE. RIG RELEASED @ 1200 HRS 02/03/97. Page 1 of 1 -MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 31, 1997 THRU: BlairWondzell, ~ FILE NO: P. I. Supervisor ~.J6 awpka5ee, doc FROM: Chuck Scheve, ~'~c SUBJECT: Petroleum Inspector BOPE Test Nabors 4ES MPU H-05 PTD # 95-98 Friday January 31, 1997: ! traveled to BPX's MPU H-05 Well being worked over by Nabors Rig 4ES and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE test report shows, the test lasted 3.5 hours with two failures. One valve downstream of the manual choke developed a slow leak. This valve was repaired and retested by Nabors personel latter in the day. The high alarm on the methane gas detectors was set at 60% these were recalibrated and set at 40% during the test. The testing went well with good test procedures being employed by the Nabors crews. The rig was clean and all related equipment appeared to be in good working order.' The location though crowded was well organized. Summary: failures. ! witnessed the initial BOPE on Nabors rig 4ES test time 3.5 hours two Attachment: awpka5ee.xls X Unclassified Confidential Confidential (Unclassified if doc. removed ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg:_____ Ddg Contractor: Operator. Well Name: Casing Size: Test: Initial Workover: X Nabors Rig No. 4ES PTD # 95-98 BPX Rep.: H-05 Set@ X Weekly Other DATE: 1/31/97 Rig Ph.# 659-4154 Larry Myers Rig Rep.: Gene Sweat Location: Sec. 34 T. 13N R. IOE Meri~lian UM Test MISC. INSPECTIONS: Location Gen.: OK Well Sign N/A Housekeeping: OK (Gen) Dri, Rig OK PTD On Location YES · Hazard Sec. YES · Standing Order Posted YES , FLOOR SAFETY VALVES: Quan. Pressure P/F Upper Kelly / IBOP I ! 250/5,000 I P Lower Kelly / IBOP I Ball Type ~ ~' 250/5,000 P Inside BOP -~ ,, 250/5,000 BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 ..... Lower Pipe Rams Blind Rams Choke Ln. Valves 1 HCR Valves 2 Kill Line Valves 1"' Check Valve Test Press 250/3O00 N/A N/A P/F MUD SYSTEM: ~r~ual Alarm Tdp Tank OK OK Pit Level Indicators OK OK Flow Indicator "(~K ' oK Meth Gas Detector F/P ~K', H2S Gas Detector OK 'OK~ CHOKE MANIFOLD: No. Valves . No. Flanges 2/2. Manual Chokes ' Hydraulic Chokes 1. Test Pressure 250/5,000 250/5, O00 Functioned Functfoned PIF ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3oo0I 1800 minutes 30 sec. , 2 minutes 25 sec. ,, OK Remote: OK 4 ~ 1900 Psi Psig. Number of Failures: 2 ,Test Time: 3.5 Hours. Number of valves tested 18 Repair or Replacement of Failed Equipment will be made v~ithin 3 daYs. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office afc Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 if your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 '1 I II I I I I I II I I I I REMARKS: One valve down stream of manuel choke had a slow leak to be repaired or replaced and inspectors notified High alarm on methane gas detectors set at 60% these were recalibrated to 40% at the #me of the test. " Distribution: odg-Well File c - OperJRig c- Database c- T dp Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO I I I . II I II I Waived By: Witnessed By: Chuck Scheve FI-O21L (Rev. 12/94) AWPKA5EE.XLS 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 [] 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc 95-98 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o-029-22572 4. Location of well at surface 9. Unit or Lease Name 2882' NSL, 4028' WEL, SEC. 34, T13N, RIOE ~ ...................... '1~'2'~,,~-,.,,~ Milne Point Unit At Top Producing Interval ~ ~;[~,~::..?i~[~T!0b,~ i~ 10. Well Number MPH-05 11. Field and Pool At Total Depth i ~;~ MilnePoint/KuparukRiverSands 3457'SNL, 5026' EWL, SEC. 2, T12N, RIOE ~= ~ ......... .--~: . 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 65.6' I ADL 380109 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions I 07/30/95 08/16/95 08/24/95 N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+'I-VDI 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 14130' MD/6992' 7'VD 14017' MD/6950' TVD YES [] ND []I N/A feet MD 1800' (Approx.) 22. Type Electric or Other Logs Run GR/RES/NEU/DEN 23. CASING, LINER AND CEMENTING RECCXC~ SE'I-rING DEFTH MD CASING SIZE VVT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 sx AS I (Approx.) 9-5/8" 40#/47# L-80 29' 5335' 12-1/4" 1250 sx PF "E'Y435 sx "G" 7" 26# L-80 29' 14108' 8-1/2" 461 sx Class "G" 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) 3-3/8" gun diameter, 6 spf 2-7/8", L-80 13118' N/A MD TVD 26. ACID, FRACTURE, CEMENT SQUF-F-TF. ETC. 13436'- 13520' 6724'- 6758' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect w/ 55 bbls diesel 27. PRODUCT]ON TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 09/04/95 I ESP Date of Test Hours Tested PRODUCTION FO~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED,.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE =~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED Alaska 011 & Ga~ Cons, Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 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. Subsea Top Kuparuk 13111' 6531' Top KC1 13443' 6662' Top Kuparuk 'B' '13515' 6691' ;) 31. UST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _ _ Title SeniorDrillino Enoineer Date // - _ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in-item 16, and in-item 24-show-the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing 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 ORI$1NAL MICROFIL EO ..... NARRATIVE' D'ESORIPTIO'N' Cement Well: Color, consolidated, unconsolidated, grain size, friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accesson/ Approximate Also Percentage of Sample. j/: of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Dep!h'.A Sam. pie. Litholo.Qy. descriptions see car.bonat.e, charts) . . Cement in SST Shows Tar ' 'Visual Stain: 'Flusrescence: J m m Cut Fluorescence: Visual StaiaJ ...... ~' ~;x ~ Fluorescence: Cut Fluoresce~ce: Cut: ............................... Visual Stain~ ..... , : . Fluorescence~ . . ~ ¢&~ ,~q~Or Cut Flu°resconce: NARRATIVE DESCRIPTION Well: m{:'l~-O,5' Page Cement Tar Color, consolidated, unconsolidated, grain size, friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth Sample Litholo.qy descriptions see carbonate charts) Cement in SST Shows ... Tar "7 q 4~0 i% ¢~,~ O[.~..r 4"- n~~'~ c.~..~e, ( ~,~= s'a,-, ~{.. Visualr~aAStain:e. t,,.,~.~, - ~;~,-'~'J~ i w~,~ - ,',,~^-,LaJ IFiuorescence: · '¥do,,<~ { ~[~' Cut Fluorescence: · . OAP. ~- .~, CUt: .... 'Visual Stain: Fluorescence: a cc c..,o, ra'~. Ir ~£<r ~kt '~" '(7c(~{ ,/o ,,t,r- :cut Fluorescence: O~,e. .... '7 .e o,,~? (e- Visual ~Stain: ~ ~ p ) Fluorescence: ..... ~ '.,~ ~Cc ~l~ ~t ~ Cut Fluorescence: Cut: ~ .... Visual 'Stai~: ~3g 0 < ~,,~ ct ~ .~r '~' Flu'orescen~e: Cut Fluorescence: · v NARRATIVE DESCRIPTION Well:/~F~'"0 Cement Tar Color, consolidated, unconsolidated, grain size, friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth Sample Lithology descriptions see carbonate charts) Cement in SST Shows Tar 'g'zg'o ~- I,i~4. ir~1~ ,,,..,s ,.,,,.t{ c~,,,-,t~J,,,4oJ ,. v-t5 xs. ,.,, Io :'- ~-~,,~,-.,-,:. V~sua~,,~Sta~n: ~' .... -/.~-~-.l,1 so,-{'.~ Cut Fluorescence: .. ~Or~ ~; Cut: o<c .)lq~'~g,~e or &10h~e- '? Fluorescence: t,3l,~, ~-{~r-o~,'~ ~-I~'.,'~ Cut Fluorescence: '" Cut: Fluorescence: O~..,r,,,.t p.~o,~ ~'~_(~ r~r~c~ Cut Fluoresce,Ce: ';" Cut: ........... '~...5',{r~ ~ ~c~ ~,e~ ~c,~trS"~ ¢4.,--,,,J Visual Stain: · . Fluorescence: Cut Fluorescence: ' Cut: NARRATIVE DESCRIPTION Well:~i~/-~-0~ [Pawe~.- of Lo Cement Tar Color, consolidated, unconsolidated, grain size, friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains Wi~h Depth Sample Litholo§y descriptions see carbonate charts) Cement in SST Shows Tar 3760 ~'~..1 ~,.it,,~ y'~ '.,,,~,,.~,~ ~i'::..-F'. r~J~ ,,,,,.,tl-.,.o,-[-,~ visua~oncStain: . : Cut Fluorescence: · Cut: y'([~, Jl, oo,:- pt/r', t¢ 9io~'.,'~r') Fluorescence: rllo~t rt~ Fluorescence: r~o ,,,, ,z., ,.;.. Cut Fluoresce.ce: cbt: , ., ,,. Visual Slain: · Fluorescence: Cut Fluorescencei Cut: ' .,, . ,, NARRATIVE DESCRIPTION Well: ~,f'H-O,J" Page~ of ~.O Cement Tar Color, consolidated, unconsolidated, grain size. friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth Sample Litholog¥ descriptions see carbonate charts) Cement in SST Shows Tar £[~5 Ga /'-,.,.,~.,~[~,~ ~+-z. Fluorescence: ~-~'~c~ ~ [~q~c, Cut Fluorescence: Cut: . '. Visual Siain: ' Cut Fl'uorescence: Cut: . Visual Stain: Cut Fluorescence: Cut: ..' ~ ~.~ ' Visual Stain: ' FlUorescence: Cut Fluorescence: ' Cut: ,,, NARRATIVE DESCRIPTION Well: ~.10}'/-0--(' Pa.qe ~I, of )....o ... .. Cement Tar Color, consolidated, unconsolidated, grain size, friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth Sample Lith. ology descriptions see carbonate charts) Cement in SST Shows Tar ~isual Stain: . Fluorescence~ Cut Fluorescence: .. Cut: Visual Stain: Fluorescence: &~,c~ 3 ['~ ¢. CUt Fluorescence: Cut: ~ Visual Stain: . FJuorescence: '" Cut Fluoresce~ce: ~Cut: Visual Stain: . FJuorescence: . Cut Fluorescence: Cut: ,, NARRATIVE DESCRIPTION Well:/~,[~-6~' Pa,qe'~r of Cement Tar Color, consolidated, unconsolidated, grain size, friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosi~ - Accessory Approximate Aisc Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth Sample Litholog¥ descriptions see carbonate charts) Cement in SST Shows .., Tar Fluorescence: Cut Fluorescence: Cut: ~O0~b 5~ {~ )c~: ~[~ ~..[ ~ ~ Visualno~Stain: Fluorescence: Cut Fluorescence: ,, . ' Cut: , Fluorescence: Cut Fluorescence: Cut: , Fluorescence: Cut Fluorescence: Cut: NARRATIVE DESCRIPTION We~l: ,¢,h,,1~I-05' Pa.~e '~5 of 20 Cement Tar Color, consolidated, unconsolidated, grain size, friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth Sample Litholo,qy , descriptions see carbonate charts) Cementin SST Shows Tar . TC.r.~.~ Fluorescence: : Cut Fluorescence: cut Flu~escence: '" Cut: Visual Stain: Cut Fluoresce~ce: Cut: , ~ ~ ~ /'l~'' Cut: , NARRATIVE DESCRIPTION Well: Cement Tar Color, consolidated, unconsolidated, grain size, friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains Wi[h Depth Sample Litholo.qy descriptions see carbonate charts) Cement in SST Shows Tar Visual Stain: FIb~rescence: ~ Cut Fluorescence: Cut: ~ o~., ~ ,, Flu~)rescence: Cut Fluorescence: '" Cut: Visual Stain: Fluorescence: ~ ~ ',;.. Cut Fluorescence: Cut: Visual Stain: , Fluorescence: . .' Cut Fluorescence: Cut: NARRATIVE DESCRIPTION Well: P,q~H-O~' Paqe/~ of ~-~) ,, , Cement Tar Color, consolidated, unconsolidated, grain size, friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth Sample Lithology descriptions see carbonate charts) Cement in SST Shows Tar Visual Stain: Fluorescence: 10 TM ~r'_ 1/~:..z. ~-',~,,~ , U,,~l.i-r~.~z~) Cut Fluorescence: .. " Cut: '~: , )1 '2.fo O ~"~q ~i,.,.r~ ..~t',~ ~¼~-('~- "7-"~ ;,t', Visual,,.o~qStain: ~,~Lc~ J,~ .~.~h ~Z Fluorescence: Cut Fluorescence: " Cut: . Visual Stain: Fluorescence: ~..5~ ..,.:. Cut Fluorescence: Cut: · ...... [,~[~ N0~ ' Fluorescence: .' Cut Fluorescence: Cut: NARRATIVE DESCRIPTION Well,; (~',(~{'t"0~-' Page ,It of -~0 · Cement Tar ,, Color, consolidated, unconsolidated, grain size, friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosib/ - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth Sample Lithology' des,criptions see carbonate charts) Cement in SST Shows Tar Cut Fluorescence: .. Cut: ,, ~l ~ ~ ~, ~0 ~2 ~- m~[ ~'~ ~t '~-,~,J t 7v~~n~ ~)~"~ visual~:n~stain: tOk A~ J~ ¢~¢~ 'Fluorescence: Cut FluoresCence: . cUt:~ Fluorescence: Cut Fluoresce~ce: Cut: .. ,0~,~.~ ,,- . ' [0'~; XS~'~ ~¢~ ": t Fluorescence: Cut: I . NARRATIVE DESCRIPTION Well: r,P,j~H-op Cement Tar Color, consolidated, unconsolidated, grain size, friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth Sample Litholo,qy descriptions see carbonate charts) Cement in SST Shows Tar Visual Stain: Fluorescence: -z..O?: t~[" J~ .,'"l J~'5~ Cut Fluorescence: ira i,;~4 Jo,,, f(4j~" Fluorescence: o ~. m~ fI~-~ '.~t~. Cut Fluorescence: i " Cut: ~-g ~'l'~r~' ' ('; Fluorescence: Cut Fluoresceuce: Cut: Visual Stain: '~ . Fluorescence: Cut Fluorescence: NARRATIVE DESCRIPTION Well: ~P{-{~6~' Page ~ of · · ~ Cement Tar Color, consolidated, unconsolidated, grain size, friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth Sample Litholo,qy descriptions see carbonate charts) Cement in SST Shows Tar Visual Stain: Fluorescence: : Cut Fluorescence: Cut: ; ... ~ . '"' Fluorescence: t o/. s..,,J ,,, A. ~'"'~' / Cut Fluorescence: '" Cut: ~ ~ 5Lr,.t LO'~ 'q['"'"~ ~i'~ ~,~x~.'~ ~,cLj-r,~,-~t-~ ~,,,,~t,[-¢~r'~0~ Visual Stain: , .'~'-~. ,..r'q~ J Fluorescence: ~, ~.,-, ~ ,.,;.. Cut Fluorescence: . ~,.,te,~ c.t,~,l~ ,,ai'~;~J (\05..) Cut: Fluorescence: : (~ ~c~ ' Cut Fluorescence: P,o~, ~ Cut: NARRATIVE DESCRIPTION Well: r-.~,,¢~t.{,o$ Paqe (~ of ~ Cement Tar Color, consolidated, unconsolidated, grain size, friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth Sample Litholo,qy descriptions see carbonate charts) Cement in SST Shows Tar ?r Z g,~,,~c.)c,~ ~'kd" Fluorescence: 'i 0 ~ ~'l~)~ ~ m~.,(- c., ,~rs~ Cut Fluorescence: f ~. ,~ ~ ~ ~,,, ~ cut: : Visual Stain: Fluorescence: Cut Fluorescence: ' Cuti ikq (~q ..T.h/y[is)0 ~'a;": ~t. ~ yk"h Visual Stain: , J"O >' t(.ji, x~ [', ,~:,t)t'J~;"~e Fluorescence: - ~,~n ¢ '.,~. Cut Fluorescence: Cut: Fluorescence: ~cc '("u'~ ~/w..~,t r~J ~ c'~'tt~ Cut Fluorescence: c¢: . .... ,,- NARRATIVE DESCRIPTION Well: ~'¢'~-0. ~ Page ~ Cement Tar Color. consolidated, unconsolidated, grain size. friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth sample Litholo§y descriptions see carbonate charts) Cement in SST Shows Tar Visual Stain: 1"~ i(C~ S,',~,~ \ ~0'~,' ¢~ ~,^ ~,~,~ \ ~_~ ,,,~ ,~.~. -,,.' ~.~,~ $~-~ r~'} ~.;.~. Fluorescence: ~,C "", ~, ¥~' (~'¥";~*' Cut Fluorescence: Cut: ; '~:~'0 s'~'~'~'/~, ~ o~" ~ ~ ~ v~.~ st~.: ' Fluorescence: Cut Fluorescence: Cut: I Fluorescence: ; Cut Fluoresce.ce: ' . c.t: , C~t: ' , .o NARRATIVE DESCRIPTION Well: /'¢,~ ..0..~" Pa,qe J ~) of ?----(~ Cement Tar Color, consolidated, unconsolidated, grain size. friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth sample Lilholo§y descriptions see carbonate charts) Cement in SST Shows Tar t'~".~(3 . r~'~,,~ C\~.c ¥~ ~.,~-~ ~,'~ \~,^~,,~,~,~,~L~rJ rq~,.-. ~,-~ .r~.,~ Visual Stain: ~,~Ior -.r~:-,~ ~ ~J)~ ~'~'~,~ Fluorescence: ~ ~v'~ "~'~ t t'fd'~" ~ ~t ~ ,~,,d [Cut FluoresCence: ' Cut: ~'d~¢ -'~,~ ,' ~' '~''~ ~ ~',~2 Fluorescence: .vf~;[~. :'. Cut: ~ ' ' Visua~ Stain: Fluorescence: ¢C~ ~c ~,u~,.t~ z~ Cut Fluoresce~ce: ' . Visu~ Stain: ~: (,~,~ ~, ¢~ ~ 4~ Fluorescence: . . .~' ~ t,;~ ~'~ 51~z~ Cut Fluorescence: ~/. Cut: ~ ,. NARRATIVE DESCRIPTION Well: P~'H,~o~ Page I'7' of ~._0 Cement Tar Color. consolidated, unconsolidated, grain size. friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth sample Lithology descriptions see carbonate charts) Cement in SST Sho~s Tar . ~ Visual Stain: r'w ~,1,~/ Fluorescence: " :Cut Fluorescence: 5" Cut:~ ~J I 3(~0 rko3' ~.0~' ~'"~t ~,/~ Visu~ Stain: ~ {~ ~~'~ ~.~ Fluorescence: ,~,~ Cut Fluorescence: " Cut: ~ q Z b ~ ... i Visual Stain: Fluorescence: Cut Fluorescence: ' Cut: m~}~ Visual Stain: ~¢~J ~ 0Z' ~'"t~r b, [~ ~ ~ t A Fluorescence: ~0~ ~ O ~ i,3~ ~. Cut Fluorescence: Cut: ~ ' ' " i~RI~ATIVE DESCRIPTION lWelh ,('Y~-(~' Page l'~ of 2.0 : Cement Tar Color. consolidated, unconsolidat~, grain size, friable to well cement~. Ty~ and Trace to Abundant; Percentage roundness, so~ng, dominant mineralogy, estimated porosi~ - Accesso~ Approximate Also Percentage of Sample of Total minerals - Contaminan~ in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth sample Lithology descriptions see cat. hate charts) Cement in SST Sho~ Tar ,, , , Visual Stain: Fiuorescence: ~ , Cut Fluorescence: Cut:' ~ I ~ . 0~5 x~ Fluorescence: Cut Fluorescence: " Cut: ~ ~ I Visual Stain: Fluorescence: [ Y X' [t~ ) ~ ~ :Cut Fluorescence: ' .. Cut:~ ~ t Visual Stain: , Fluorescence: . , Cut Fluorescence: Cut~ ~ ~ NARRATIVE DESCRIPTION Well: ~,1~-o~ !Paqe Cement Tar Color, consolidated, unconsolidated, grain size, friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth Sample Litholo.q¥ .. descriptions see carbonate charts) Cement in SST Shows Tar ~ ~. i(,.~ht~ 5~,V S~,~,t~ · Fluorescence: Cut Fluorescence: 5/ /~' ) "'~ S~... Fluorescence: Cut Fluorescence: Cut:¢ ~ ~ " ") ' '~iuorescence: ~ 0 ~ [.'~h* )~ ' Cut Fluorescence: Cut: ~ i Visual Slain: ~d ~' ~{ :' ~ IFluorescence: Cut Fluorescence: NAR.RATIVE DESCRIPTION Well: ~l~-0 Cement Tar . , , Color, consolidated, unconsolidated, grain size. friable to well cemented, Type and Trace to Abundant; Percentage roundness, sorting, dominant mineralogy, estimated porosity - Accessory Approximate Also Percentage of Sample of Total minerals - Contaminants in sample - General Comments - (For carbonate Percentage of Hydrocarbon Sand Grains With Depth sample ... Litholo.qy descriptions see carbonate charts) . . Cementin SST Shows Tar i'X~r...~ F~.~,.~ ~C~ ~' ~.~,~- ~.',~ i,~J~. --~ ,~,~t.,~' m,,,d ',.-~-//~,'~'A, ~'.~/ ~ r',.,'~)," - VisualT;,, ,Stain: C'.~' . Fluorescence: \ d ~; ~.~.~ ~"~ yL~.~ ~:'ut Fluorescence: cut:, , ,. ................. Visual Staia: F:luoros~:ence: ~fit Fluorescence: c~t: .... Visual Stain: FhJorescence: · Cut Fluoresce~,ce: . ..... Visual Fluores~:ence: · Cut Fiu°rescence: Cut: ....... 9ate~PROVISIONAL LOG GEOLOGIST(S); AREA DRILLED BY: ~ "4jo or'~ 7...~' TOTAL DEPTH !4'!~_ 0 ' SCALE: 2' = 100' i/ INVERSE RATE OF PENETRATION (MINUTES PER $ FT INTERVAL)' PERCENTAGE i LOG LITHOLOGY AND REMARKS HYDROCARBON INDICATIONS s-Jccrm ., ~n C n C ~ C~ Ct:' n C. ,,., A ~o~' C n C.. ,.-, ~' q C" CL r', I~0 cc' BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MP H-05 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 07/29/95 12:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 22E WO/C RIG: NABORS 22E 07/15/95 (1) TD: 0 PB: 0 07/16/95 ( 2) TD: 0 PB: 0 07/17/95 ( 3) TD: 0 PB: 0 07/18/95 (4) TD: 0 PB: 0 07/19/95 (5) TD: 0 PB: 0 07/20/95 (6) TD: 0 PB: 0 07/21/95 ( 7) TD: 0 PB: 0 RIG MAINTENANCE MW: 0.0 MOVE RIG AND CAMP FROM MP E-23 TO MP H PAD AND MP G PAD. SPREAD HERCULITE UNDER MODULES. MAKE ELETRICAL JUMPERS FOR COMPLEXES. RIG MAINTENANCE MW: 0~0 FINISH BUILDING BERMS AROUND SUB, MOTORS AND PITS. TELESCOPE WIND WALLS ON DERRICK AND BUILD BERM UNDER DERRICK. PIT ROOM MODIFICATION. ANNUAL RIG MAINTENANCE MW: 0.0 REMOVE BOP STACK FOR INSPECTION. REMOVE WOOD CROWN BLOCKS TO INSTALL WIRE MESH GRATING. RIGHTEN BOLTS ON CROWN. CHANGE VALVES IN SUCTION PIT. CONTINUE PIT MODIFICATION. CLEANING RIG FOR PAINTING. ANNUAL RIG MAINTENANCE MW: 0.0 REPAIR VALVES IN PIT ROOM. WASH AND CLEAN RIG AND DERRICK. PAINT SUB AND PIT ROOFS. BLOW DOWN ACCUMULATOR LINES AND REPLACE SAME. PREP TO REMOVE DERRICK FOR INSPECTION. ANNUAL RIG MAINTENANCE MW: 0.0 REMOVE DERRICK. MAGNAFLUX PIN POCKS AND A-LEGS, NO CRACKS. REPIN DERRICK. SCRAPE PAINT ON SUB BASE. WASH DERRICK AND PREP FOR PAINT. CONTINUE PIT MODIFICATION. INSTALL CROWN BLOCK W/ WIRE MESH. ANNUAL RIG MAINTENANCE MW: 0.0 WORK ON PIT MODIFICATION. CHIP AND PREP PITS AND SUB FOR PAINT. MAGNAFLUX ELEVATORS. QUDCO, PVT SYSTEM. INSTALL RELIEF VALVE ON TOP DRIVE. SCRUB AND CLEAN DERRICK. EMSCO, MUD PUMP INSPECTION. ANNUAL RIG MAINTENANCE MW: 0.0 CONTINUE PIT MODIFICATION. CONTINUE CLEAN, PREP, PRIME AND PAINT RIG. REMOVE DOORS F/ BAD BOP BODY. REASSEMBLE PUMPS AFTER INSPECTION. ASSIST QUADCO W/ PVT SUSTEM. REMOVE PURGE SYSTEM DUCT WORK F/ MOTORS FOR CLEANING. WELL : MP H-05 OPERATION: RIG : NABORS 22E PAGE: 2 07/22/95 (8) TD: 0 PB: 0 07/23/95 (9) TD: 0 PB: 0 07/24/95 (10) TD: 0 PB: 0 07/25/95 (11) TD: 0 PB: 0 ANNUAL RIG MAINTENANCE MW: 0.0 CONTINUE CLEAN AND PAINT RIG. ASSIST QUADCO W/ PVT SUSTEM. WELD ON DERRICK HOUSE. REPLACE FLOOR PLATE ON RIG FLOOR. MAGNAFLUX ON TOP DRIVE. WORK ON DRAWWORKS AND SCR. ANNUAL RIG MAINTENANCE MW: 0.0 CONTINUE CLEAN AND PAINT RIG. REPAIR DERRICK BOARD AND DERRICKMAN HOUSE. CONTINUE SERVICE BOP. PIT MODIFICATION. PVT SYSTEM. 3 ANNUAL RIG MAINTENANCE MW: 0.0 CONTINUE PRIME AND PAINT RIG. REBUILD DERRICK HOUSE ELECTRICAL PANEL. INSTALLING DUCT WORK FOR DECON SYSTEM. REPLACE HINGES ON DERRICK BOARD. REPLACING RIG FLOOR PLATING. REMOVE FLOOR PLATE IN PIPE SHOOT. PRESSURE WASH TOP DRIVE. RIG MAINTENANCE MW: 0.0 RIG MAINTENANCE 07/26/95 (12) TD: 0 PB: 0 RIG MAINTENANCE RIG MAINTENANCE MW: 0.0 07/27/95 (13) TD: 0' ( 07/28/95 (14) TD: 0 PB: 0 o) RIG MAINT. RIG MAINT. MW: 0.0 VIS: 0 RIG MAINT. MW: 0.0 RIG MAINT. 07/29/95 (15) TD: 0'( 0) RIG MAINT. RIG MAINT. MW: 0.0 VIS: 0 07/30/95 (16) TD: 112'( 112) CLEANING RIG MW: 0.0 VIS: 0 FIN R/U FLOOR, R/U STABBING BOARD. FIN TROUBLE SHOOTING TOP DRIVE & FUNCTION TEST SAME. FUNCTION TEST DIVERTER SYSTEM. JOHN SPAULDING W/AOGCC WITNESSED. PICK UP AND CLEAN RIG. ACCEPT RIG @ 1200 HRS. 7/29/95 WELL : MP H-05 OPERATION: RIG : NABORS 22E PAGE: 3 07/31/95 (17) TD: 1153' (1041) 08/01/95 (18) TD: 2563'(1410) 08/02/95 (19) TD: 3825'(1262) 08/03/95 (20) TD: 5360'(1535) 08/04/95 (21) TD: 5360'( 0) 08/05/95 (22) TD: 5360' ( 0) DRILLING MW: 0.0 VIS: 0 FIN PICKING & CLEANING RIG. PRE-SPUD MEETING. M/U BHA #1. SPUD & DRILL FROM 112-242'. TOP DRIVE SHORTED OUT. POOH. REPAIR ELECT. PLUG ON TOP DRIVE. ORIENT AND TIH. ATTEMPT TO TEST MWD. PLUGGED. CK SURFACE EQUIP. POOH. TEST MWD-OK. DRILL AND SURVEY 12 1/4" HOLE FROM 242'1153'. CHANGING OUT MWD MW: 0.0 VIS: 0 DRILL FROM 1153'-1821~. CIR. OUT GAS AND INCREASE MUD WT TO 10.6 PPG. DRILL FROM 1821-1925' CIR. OUT GAS AND INCREASE MUD. SHORT TRIP TO HWDP. UNPLUG FLOW LINE. DRILL FROM 1925-2563'__ CIRB/U AFTER EACH STAND DRILLED. POOH WET LOOKING FOR WASHOUT. DWOB PORT WASHED OUT ON MWD TOOL. CHANGE OUT MWD TOOL. TIH W/BHA #3 MW: 0.0 VIS: 0 FIN. M/U BHA #2. ORIENT & TEST MWD. TIH. CIR AND CON MUD. DRILL FROM 2563-3731'. CIR AND COND MUD. SHORT TRIP 20 STANDS. CIR B/U. AFTER BOTTOMS UP, GAS DROPPED OUT 11.5 IN AND OUT. DRILL FROM 3731-3825'. MWD FAILURE, CIR B/U. MONITOR WELL. POOH, L/D MWD AND BIT. M/U BHA #3. ORIENT AND TEST MWD. TIH WITH BHA #3 BUILDING MUD MW: 0.0 VIS: 0 FINISH TIH. PUMP & ROTATE THRU TIGHT SPOTS. REAM 80' T/BTTM. DRILL 12-1/4" HOLE F/3825 T/4790. CIRC & COND MUD. SHORT TRIP T/2310. RIH. CBU. GAS DROPPED OUT. DRILL T/5360. LOST RETURNS. TOOK 20 BBLS T/FILL HOLE. MONITOR THE WELL & BUILD 100 BBLS LCM PILL. HOLE TAKING 40 BPH T/KEEP FULL. SPOT LCM IN OPEN HOLE. NO RETURNS. TOTAL LOSSES 266 BBLS. MONITOR WELL & BUILD MUD VOL. TOTAL LOSSES = 309 BBLS. STAGING IN HOLE MW: 0.0 ViS: 0 MIX LCM PILL. ATTEMPT T/CBU. NO RETURNS. LOST 40 BBLS. TIH W/6 STNDS. LOST 40 BBLS WHILE TIH. SPOT 150 BBLS LCM PILL IN OPEN HOLE. 40 PPB. NO RETURNS WHILE PUMPING PILL. LOST 275 BBLS. POOH. SWAB. ROTATE & PUMP OUT T/1800. LD BHA #2. MU BHA #3. W/HOLE OPENER. STAGE INTO HOLE T/800' CBU @ 5 BPM. LOST 10 BBLS. STAGE IN T/1750. CBU @ 5-4 BPM. LOST 25 BBLS. RUNNING 9 5/8" CASG SLOW MW: 0.0 VIS: 0 CIR B/U @4700 FROM 2-9 BPM. CIR AND COND MUD @ 13 BPM W/1300 PSI & NO LOSSES. POOH, L/D BHA. HOLE TOOK 10 BBLS OVER CALCULATED VOLUME. RUNNING 9 5/8" CASING SLOW. RECEIVED Alaska Oil & Gas Cons. Commission Anchoralle WELL : MP H-05 OPERATION: RIG : NABORS 22E PAGE: 4 08/06/95 (23) TD: 5360' ( 0) 08/07/95 (24) TD: 5360'( 0) 08/08/95 (25) TD: 5360' ( 0) 08/09/95 (26) TD: 5375'( 15) 08/10/95 (27) TD: 6855' (1480) 08/11/95 (28) TD: 8283' (1428) N/U 13 5/8" BOPE MW: 0.0 VIS: 0 FIN RUNNING 129 JTS. 9 5/8" 47/40# L-80 BTC. CIR AND COND MUD. TEST LINES. OPEN ES CEMENTER WITH 2800 PSI. WAIT ON CEMENT. FIRST 2 HOURS HOLE TOOK 46 BBLS. NEXT 4.5 -HRS. THE HOLE TOOK 12 BBLS. ATTEMPT TO CIR. PUMPED 50 BBLS. PUMP 100 BLS. LCM PILL. BUMP PLUG TO 3000 PSI AND HOLD FOR 15 MINUTES. DOUG AMOS WITH AOGCC AGREED TO PUMP TOP JOB AND THEN RUN CBL TO CONFIRM CEMENT CIP @2145 HRS. L/D LANDING JT AND N/D 20~ DIVERTER. R/U AND PUMP 160 SXS "E" TOP JOB @ 12.0 PPG. FLUSH ANNULUS W/50 BBLS. WATER AND PUMP 60 BBLS CEMENT. N/U SPEED HEAD, TUBING HEAD AND ADAPTER FLANGE. N/U 13 5/8" 5M BOPE. POOH TO RUN CBL MW: 0.0 VIS: 0 N/U 13 5/8" 5M BOPE. HAMMER UP ALL BOLTS, CHANGE OUT ALL CONTROL LINES TO BOPE. INSTALL TEST PLUG & TEST BOPE. DOUG AMOS W/AOGCC WITNESSED TEST. PULL TEST PLUG & INSTALL WEAR RING. TIH TO ES CEMENTER @4301' DRILL CEMENTER. TIH TO LANDING COLLAR @5246'. DRILL LC, CEMENT, FC AND CEMENT TO 5324' CIR AND COND MUD TO 11.4 PPG. POOH TO RUN CBL. WAITING ON CEMENT MW: 0.0 VIS: 0 R/U AND RUN CBL FROM 5320'-3500'. R/U AND RUN 8.5" GAGE RING/JUNK BASKET. RIH W/SQUEEZE PERF GUN. POOH TIH TO 5320'. M/U MULE SHOE AND TIH TO 5320'. TEST LINES 3000 PSI. POOH 10 STANDS. REVERSE CIR HOLE CLEAN. ATTEMPT TO SQUEEZE. DRILLING CMT MW: 0.0 VIS: 0 WOC W/1000. BLLED OFF PRESS. POOH. MU BHA #6 & TIH T/2930. TIH T/4353. CBU. TAG TOP OF CMT @4608. DRILL FIRM CMT F/4608 T/5315. RUN GYRO SURVEY MW: 0.0 VIS: 0 MU BHA RIH & DRILL T/5630. CBU & INCREASE MUD WT T/9.6. DRILL T/6377. CBU. DRILL T/6855, CBU F/SHORT TRIP T/RUN GYRO SURVEY. DRILLING MW: 0.0 VIS: 0 CBU. CHANGE T/LONG ELEVATOR BAILS. RIH CBU & DRILL T/7040. CBU. RU & RUN GYRO TF/6720 T/SURF. DRILL T/7711. CBU. DRILL T/8223. WELL : MP H-05 OPERATION: RIG : NABORS 22E PAGE: 5 08/12/95 (29) TD: 8662' ( 379) 08/13/95 (30) TD:10743' (2081) 08/14/95 (31) TD:11883' (1140) 08/15/95 (32) TD:13301' (1418) 08/16/95 (33) TD:14118' ( 817) 08/17/95 (34) TD:14130' ( 12) 08/18/95 (35) TD:14130' ( 0) 08/19/95 (36) TD:14017' ( 0) DRILLING MW: 0.0 VIS: 0 DRILL T/8662. CBU. POOH LD BHA. SERVICE THE WEAR BUSHING. BU BHA #8 SHALLOW TEST THE MWD @ 1200' & RIH T/7410. MAD PASS F/7410 T/5625. RIH T/DRILL . DRILLING MW: 0.0 VIS: 0 REAM 100' T/BTTM. DRIL~ T/9695. CBU. MONITOR WELL PUMP DRY JOB. POOH T/8662. DRILL T/10743. DRILLING MW: 0.0 VIS: 0 CBU - MONITOR WELL - PUMP PILL. DRILL T/11504. CBU. DRILL T/11883. TRIPPING MW: 0.0 VIS: 0 DRILL T/12454. CBU. PUMP PILL. DRILL T/13301. CBU. PUMP PILL. SHORT TRIP T/12450. OK. SHORT TRIP MW: 0.0 VIS: 0 DRILL T/13804. MONITOR WELL. PUMP PILL. DRILL T/14118. PUMP HI/LO VIS. SWEEPS. CBU. MONITOR & PUMP PILL. POOH T/CASG SHOE. CHANGE RAMS MW: 0.0 VIS: 0 FINISH POOH SERV. TOP DRIVE. RIH DRILL T/14130. CBU. SPOT 100 BBLS CLEAN MUD. POOH W/BHA. PULL WB. CHANGE RAMS. DISPLACE CMT ' MW: 0.0 VIS: 0 TEST DOOR SEALS T/2500PSI. RU & RUN CASG T/5335. CBU. RIH W/7" CASG T/14108. LC @ 14017.. CBU. PUMP 10 BBLS WATER TEST LINES T/3500. PUMP 10 BBLS WATER & DROP THE BTTM PLUG. PUMP 70 BBLS SPACER @ 11.4 PPG. 263 SX OF G CMT @ 15.8 PPG. DROP TOP PLUG. DISPLACE W/10 BBLS WATER & 525 BBLS MUD. PBUMP PLUG T/1500. PRESS T/2750. CBU. PUMP 20 BBLS WATER, 70 BBLS SPACER @ 11.4 PPG. 198 SX OF G CMT @ 15.8 PPG. & DROP PLUG. DISPLACE W/10 BBLS H20. PU DP & RIH TO PBTD MW: 0.0 VIS: 0 FINISH DISPLACING, CLOSE ES CEMENTER W/2000 PSI, BLED OFF PRESS. RD CSG EQUIP AND LD LDG JT. CHANGE RAMS & TOP DRIVE T/3-1/2". SET PACKOFF & TEST T/5000 PSI. RU & TEST BOP & CHOKE MANIFOLD, CHANGE BOOT ON FLOW NIPPLE. PU BHA & DP, RIH T/7086'. DRILL 18' CEMENT & ES CEMENTER. TEST CSG T/3500 PSI FOR 30 MIN. CONTINUE PU DP & RIH. WELL : MP H-05 OPERATION: RIG : NABORS 22E PAGE: 6 08/20/95 (37) TD:14017' ( 0) 08/21/95 (38) TD:14130' ( 113) 08/22/95 (39) TD:t4140' ( 10) 08/23/95 (40) TD: 0 PB: 0 08/24/95 (41) TD: 0 PB: 0 RIH W/ GYRO/GR MW: 0.0 VIS: 0 RIH PU 3-1/2" DP. CBU F/13903' T/13997', TAG CEMENT. DRLG CEMENT F/13997' T/14017'. PUMP 40 BBLS WATER, 25 BBLS BARAVIS, 50 BBLS DIRT MAGNET, 25 BBLS BARAVIS, 300 BBLS WATER. DISPLACE W/ BRINE WHILE RECIPROCATING & ROTATING OVER 60 @ 7 BPM. REVERSE CIRC. BRINE @ 6 BPM, DTU 20 & LESS AFTER 1.5 CIRC. CIRC CORE EXIT DH LAST CIRC. PUMP PILL. POOH LD 40 JTS. DP, 6 DC, SCRAPERS, X-O'S & BIT, STAND BACK DP. RU ATLAS. RIH W/ ~RO. POOH W/ GR TIE IN LOG MW: 0.0 VIS: 0 RUN GYRO F/PBTD T/SURFACE, RD LOGGERS, PBTD BY LOGGERS 14012'. CUT & SLIP DRILLING LINE. RIH W/ PERF GUNS, 6 JTS TBG, RA TAG, 27 JTS TBG, PORTED FLOW SUB, 2 JTS TBG, X-O, SAFETY JT,PKR, JARS,ANNULAR SHEAR SUB, 4 DC, RA SUB, DP T/13520'. RU WIRELINE, RIH COULDN'T GET BELOW DC'S,LOG RA SUB, POOH DROP OFF ROLLER BAR 1.9". RIH W/ ALL 1-11/16" TOOL STRING T/13360'. LOG UP CORRELATION. LD PERF ASSY MW: 0.0 VIS: 0 FINISH POOH W/ CORRELATION LOG. RD ATLAS. PU DP PUP SPACEOUT. RU CHOKE MANIFOLD ON FLOOR & LINES TO FRAC TANK. SET PKR. TEST LINES T/7500 PSI. OPEN BYPASS. DISPLACE TBG TO BYPASS 84 BBLS OF N2. CLOSE BYPASS. SHUT PIPE RAMS. PRESS ANNULAS T/1500 PSI. PRESSURE UP W/ N2 T/5800 PSI. GUNS FIRED @ 5800 PSI SURFACE PRESS. LET PRESSURE STABILIZE F/5800 T/2800. STABLE LAST 15 MIN. OPEN BYPASS. REVERSE N2 OUT OF TBG. BULLHEAD 35 BBLS DOWN BACKSIDE. BULLHEAD 65 BBLS DOWN TBG. CIRC COMPLETE THRU CHOKE. OPEN BAG. CIRC THRU FLOWLINE. MONITOR WELL PUMP PILL. RD HALLIBUTON CHOKE MANIFOLD & LINES. POOH LD DP. RIH W/ ESP MW: 0.0 POOH LD PERF BHA. ALL GUNS FIRED. TOOK 18 BBLS OVER CALC DISPL. PULL BEAR BUSHING. CHANGE RAMS. TEST DOOR SEAS T/3000 PSI. RU TO RUN ESP. PU SERVICE PUMP. RIH W/ TBG & CABLE. INSTALL LASALLE CLAMPS EVERY 2ND JT. REPAIR ESP CABLE SHEAVE. RIH W/ ESP CABLE & TBG. LOOSING .5 TO 1 BPH. RIG RELEASED @ 0600 HRS MW: 0.0 RUN 319 JTS & MAKE FIRST SPLICE. CONT RUNNING ESP,CHECK EVERY 30 JTS. MU GAS LIFT MANDEL. FINISH RUNNING TBG & MAKE FINAL SPLICE TO HANGER. LEFT 6 JTS OF TBG OUT INSTEAD OF MAKING ANOTHER SPLICE. LAND HANGER, TOTAL OF 414 JTS OF TBG RUN. LD LANDING JT,CHANGE RAMS TO 5" AND ND BOPE. NU TREE & TEST SAME T/5000 PSI FOR 15 MIN. OK. PULL 2-WAY CHECK VALVE. FREEZE PROTECT 2-7/8" X 7" W/ 60 BBLS. SET BPV & PUMP 12 BBLS DIESEL DOWN TBG. PUMP 55 BBLS DOWN 9-5/8" X 7" ANNULUS. CHANGE TOP DRIVE TO 5". RELEASE RIG @ 0600 HRS. RECEIVED MAY 0 3 199~ A~.~k~ 011 & G~ Omm, Commis~io~ WELL : MP H-05 OPERATION: RIG : PAGE: 7 SIGNATURE: (drilling sup~/rintendent) DATE: gyro/data RECEIVED MAY 0 3 1996 Alaska 0il & Gas Cons. Commission Anchorage B.P. EXPLORATION ~'~""'- H PAD, WELL NO. MPH-05 IVllLNE POINT FIELD, ALASKA Gyro Multishot Survey in 7.625" Casing Survey date: 20-August, 1995 Job number · AK0895G287 SR106.DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 August 24, 1995 Ms. Sharmaine V. Copeland B.P. Exploration (Alaska) inc. Petrotechnical Data Center, MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 Re: H Pad, Well # MPH-05, Milne Point Field, Alaska Enclosed please find one (1) original and five copies (5) of the completed survey of Well #MPH-05 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely Operations Manager RS/gr Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data CONTENTS JOB NUMBER :AK0895G287 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR106.DOC gyro/data 1. DISCUSSION, SURVEY CERTIFICATION SHEET SR106.DOC gyro/data DISCUSSION JOB NUMBER' AK0895G287 Tool 722 was run in MPH-05 on ATLAS 15/16" Wireline inside 7 7/8: casing. The survey was run without problems. SR106.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK0895G287 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS ENGINEER SR106.DOC gyro/data 2. SURVEY DETAILS SR106.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK0895G287 CLIENT: B.P. EXPLORATION RIG: ATLAS LOCATION: MILNE POINT WELL: MPh-05 LATITUDE: 70.438 N LONGITUDE: W SURVEY DATE: SURVEY TYPE : 20-august, 1995 MULTISHOT IN 7 7/8" casing DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE EVELATION 66.4 asl 14000 SURVEY TIED ONTO: N/A SURVEY INTERVAL: 100' UTM CO-ORDINATES: TARGET DIRECTION: 125.31 GRID CORRECTION: CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: STODDARD SR106.DOC gyro/data 3. OUTRUN SURVEY LISTING SR106.DOC A Gyro da t a D i r e c t i on a i S u rve y for B.P. EXPLORATION WELL: MILNE POINT MPH 05, 7 5/8" CASING Location: H PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G287 Run Date: 20-Aug-95 06:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.438000 deg. N Sub-sea Correction from Vertical Reference: 66.4 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 125.310 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MILNE POINT MPH Location: H PAD, MILNE Job Number: AK0895G287 05, 7 5/8" CASING POINT FIELD, ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 0.0 0.00 0.00 0.0 0.0 -66.4 0.00 0.0 0.0 0.00 N 0.00 E MEASURED DEPTHS ARE REFERENCED TO NABORS 22 E R.K.B. HEIGHT OF 66.4 FEET. 0.0 - 14000.0 FT. GYRO SURVEY RUN IN 7 5/8 INCH CASING. 100.0 .13 116.87 100.0 .1 33.6 .13 .1 200.0 .13 82.16 200.0 .3 133.6 .08 .3 300.0 .12 19.25 300.0 .4 233.6 .13 .5 400.0 .11 337.05 400.0 .2 333.6 .08 .5 500.0 .16 351.73 500.0 .1 433.6 .06 .6 600.0 .17 25.29 600.0 -.1 533.6 .10 .9 700.0 .34 38.12 700.0 -.1 633.6 .18 1.3 800.0 .55 56.04 800.0 .1 733.6 .25 2.0 900.0 1.10 88.24 900.0 1.0 833.6 .69 3.2 1000.0 2.59 110.04 999.9 4.0 933.5 1.62 5.8 1100.0 4.14 120.19 1099.8 9.8 1033.4 1.66 11.0 1200.0 5.19 122.56 1199.4 17.9 1133.0 1.07 18.8 1300.0 7.25 124.88 1298.8 28.7 1232.4 2.07 29.3 1400.0 9.26 125.81 1397.8 43.1 1331.4 2.02 43.5 1500.0 10.12 125.24 1496.4 59.9 1430.0 .86 60.2 1600.0 11.88 124.78 1594.5 79.0 1528.1 1.76 79.2 1700.0 14.94 120.71 1691.8 102.1 1625.4 3.20 102.4 1800.0 17.84 120.21 1787.7 130.2 1721.3 2.91 130.6 1900.0 19.85 121.26 1882.3 162.4 1815.9 2.04 162.9 2000.0 21.77 120.29 1975.8 197.8 1909.4 1.95 198.4 116.9 105.6 86.5 64.4 41.5 .05 S .10 E .09 S .31 E .03 N .46 E .22 N .46 E .45 N .40 E 31.3 .73 N .44 E 32.2 1.10 N .69 E 38.5 1.60 N 1.27 E 54.2 1.90 N 2.62 E 78.6 1.15 N 5.70 E 97.5 107.6 113.6 117.5 119.7 1.44 S 10.94 r 5.69 S 17.87 L 11.73 S 26.86 E 20.04 S 38.56 E 29.82 S 52.27 E 121.0 40.77 S 67.90 E 121.3 53.22 S 87.44 E 121.1 67.51 S 111.76 E 121.1 84.03 S 139.51 E 121.0 102.19 S 170.04 E A Gyro da t a D i r e c t i ona i S u rv e y B.P. EXPLORATION WELL: MILNE' POINT MPH 05, 7 5/8" CASING Location: H PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G287 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2100.0 24.94 121.18 2067.6 2200.0 28.22 123.45 2157.0 2300.0 29.52 123.13 2244.6 2400.0 31.19 123.40 2330.9 2500.0 34.65 122.37 2414.8 237.3 282.0 330.3 380.8 435.1 2001.2 3.19 238.0 121.0 2090.6 3.44 282.7 121.2 2178.2 1.31 331.0 121.5 2264.5 1.67 381.5 121.7 2348.4 3.50 435.8 121.9 122.47 S 204.09 E 146.42 S 241.87 ~ 172.92 S 282.23 il 200.64 s. 324.49 E 230.13 S 370.13 E 2600.0 39.26 122.90 2494.7 2700.0 42.95 121.93 2570.1 2800.0 43.53 122.07 2642.9 2900.0 45.89 122.22 2714.0 3000.0 49.38 122.17 2781.3 495.1 560.7 629.1 699.4 773.1 2428.3 4.62 495.9 122.0 2503.7 3.75 561.7 122.0 2576.5 .58 630.2 122.0 2647.6 2.36 700.5 122.0 2714.9 3.49 774.4 122.0 262.55 S 420.73 E 297.77 S 476.24 E 334.07 S 534.33 E 371.50 S 593.89 E 410.86 S 656.40 E 3100.0 52.40 121.09 2844.4 3200.0 55.41 120.47 2903.3 3300.0 58.83 119.44 2957.6 3400.0 62.05 118.73 3006.9 3500.0 65.09 119.29 3051.4 850.5 931.1 1014.7 1101.1 1190.1 2778.0 2836.9 2891.2 2940.5 2985.0 3.14 852.0 122.0 3.05 932.7 121.9 3.53 1016.7 121.7 3.28 1103.5 121.5 3.08 1193.0 121.3 451.53 S 722.47 E 492.87 S 791.89 E 534.78 S 864.64 E 577.05 S 940.65 E 620.48 S 1018.95 E 3600.0 68.40 118.81 3090.9 3700.0 69.87 120.98 3126.6 3800.0 69.60 118.45 3161.2 3900.0 69.33 118.97 3196.3 4000.0 68.83 119.26 3232.0 1281.5 1374.5 1467.8 1560.8 1653.7 3024.5 3060.2 3094.8 3129.9 3165.6 3.34 1284.8 121.2 2.50 1378.2 121.1 2.39 1472.0 121.0 · 55 1565.6 120.9 .57 1658.9 120.8 665.08 S 711.65 S 758.14 S 803.12 S 848.56 S 1099.26 r 1180.25 E '1261.72 E 1343.86 E 1425.47 E 4100.0 69.00 120.47 3268.0 4200.0 68.85 120.56 3303.9 4300.0 69.19 120.25 3339.7 4400.0 69.98 120.47 3374.6 4500.0 69.71 120.09 3409.1 1746.6 1839.6 1932.6 2026.0 2119.5 3201.6 3237.5 3273.3 3308.2 3342.7 1.15 1752.2 120.7 .17 1845.5 120.7 .44 1938.9 120.7 .81 2032.6 120.7 .44 2126.5 120.7 895.02 S 942 . 40 S 989.65 S 1037.01 S 1084.35 S 1506.38 E 1586.77 E 1667.30 E 1748.17 E 1829.24 E A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MILNE POINT MPH 05, 7 5/8" CASING Location: H PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G287 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH 'feet deg. deg. feet VERTICAL SECTION feet 4600.0 69.23 121.54 3444.1 4700.0 68.60 122.83 3480.1 4800.0 69.64 123.90 3515.7 4900.0 69.82 125.25 3550.4 5000.0 69.10 124.80 3585.5 5100.0 70.12 124.85 3620.3 5200.0 69.98 1.25.58 3654.4 5300.0 70.70 126.48 3688.1 5400.0 69.43 124.92 3722.2 5500.0 67.86 125.18 3758.6 5600.0 65.72 126.00 3798.0 5700.0 70.01 127.79 3835.7 5800.0 69.82 129.18 3870.0 5900.0 70.88 129.86 3903.6 6000.0 70.61 130.32 3936.6 6100.0 70.80 130.05 3969.7 6200.0 70.39 129.16 4002.9 6300.0 69.16 127.92 4037.5 6400.0 68.51 127.26 4073.6 6500.0 67.47 126.37 4111.0 6600.0 67.20 126.01 4149.6' 6700.0 67.44 126.29 4188.1 6800.0 67.26 125.50 4226.6 6900.0 68.22 127.30 4264.5 7000.0 68.16 125.81 4301.7 2212.8 2306.0 2399.4 2493.2 2586.8 2680.5 2774.5 2868.7 2962.7 3055.8 3147.7 3240.3 3334.1 3428.0 3522.1 3616.1 3710.2 3803.8 3897.0 3989.7 4082.0 4174.2 4266.5 4359.0 4451.8 SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 3377.7 1.44 2220.1 120.7 3413.7 1.35 2313.4 120.7 3449.3 1.44 2406.7 120.8 3484.0 1.29 2500.3 121.0 3519.1 .83 2593.8 121.1 3553.9 1.01 2687.3 121.2 3588.0 .69 2781.1 121.4 3621.7 1.11 2875.0 121.5 3655.8 1.93 2968.7 121.7 3692.2 1.58 3061.7 121.8 3731.6 2.27 3153.4 121.9 3769.3 4.60 3245.6 122.0 3803.6 1.33 3339.0 122.2 3837.2 1.23 3432.4 122.4 3870.2 .50 3526.0 122.6 3903.3 .32 3619.6 122.8 3936.5 .94 3713.2 123.0 3971.1 1.69 3806.6 123.1 4007.2 .89 3899.6 123.2 4044.6 1.32 3992.1 123.3 4083.2 .43 4084.3 123.4 4121.7 .35 4176.5 123.4 4160.2 .75 4268.7 123.5 4198.1 1.92 4361.1 123.5 4235.3 1.39 4453.8 123.6 Page HORIZONTAL COORDINATES feet 1132.33 S 1909.66 E 1182.02 S 1988.62 E 1233.41 S 2066.66 1286.64 S 2143.89 m ' 1340.39 S 2220.58 E 1393.91 S 1448.11 S 1503.50 S 1558.36 S 1611.84 S 1665.32 S 1720.93 S 1779.38 S 1839.31 S 1900.11 S 1961.01 S 2021.14 S 2079.60 S 2136.48 S 2192.04 S 2246.53 S 2300.96 S 2355.06 S 2409.98 S 2465.27 S 2297.52 E 2374.32 E 2450.48 E 2526.81 E 2603.05 E 2677.79 E 2751.84 E 2825.36 E 2898.00 E 2970.22 E 3042.32 F 3114.99 h 3188.38 E 3262.27 E 3336.49 E 3410.97 E 3485.47 E 3560.23 E 3634.71 E 3709.29 E A Gyro d a t a D i r e c t i o na i Survey B.P. EXPLORATION WELL- MILNE POINT MPH 05, 7 5/8" CASING Location: H PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G287 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 7100.0 68.10 125.68 4338.9 7200.0 68.60 125.90 4375.8 7300.0 69.42 124.54 4411.6 7400.0 68.60 124.45 4447.5 7500.0 68.84 124.89 4483.8 4544.6 4637.6 4731.0 4824.3 4917.5 4272.5 4309.4 4345.2 4381.1 4417.4 .13 4546.5 123.7 .54 4639.4 123.7 1.50 4732.8 123.7 .83 4826.1 123.7 .48 4919.3 123.8 2519.49 S 3784.61 E 2573.84 S 3860.01 E 2627.68 S 3936.28 2680.56 S 4013.23 E 2733.57 S 4089.86 E 7600.0 68.68 124.43 4520.0 7700.0 67.91 126.22 4557.0 7800.0 67.43 125.40 4595.0 7900.0 67.28 126.62 4633.5 8000.0 67.44 126.62 4672.0 5010.7 5103.6 5196.1 5288.4 5380.6 4453.6 4490.6 4528.6 4567.1 4605.6 .46 5012.5 123.8 1.83 5105.4 123.8 .90 5197.8 123.8 1.14 5290.0 123.9 .16 5382.2 123.9 2786.57 S 4166.53 E 2840.29 S 4242.33 E 2894.41 S 4317.34 E 2948.67 S 4392.00 E 3003.73 S 4466.07 E 8100.0 67.80 126.27 4710.0 8200.0 68.49 126.04 4747.3 8300.0 68.46 125.88 4784.0 8400.0 67.98 126.98 4821.1 8500.0 68.13 126.36 4858.4 5473.1 5565.9 5658.9 5751.7 5844.5 4643.6 4680.9' 4717.6 4754.7 4792.0 .49 5474.6 124.0 .71 5567.3 124.0 .15 5660.3 124.0 1.12 5753.1 124.1 .59 5845.7 124.1 3058.66 S 4540.45 3113.41 S 4615.40 3168.03 S 4690.69 3223.17 S 4765.41 3278.56 S 4839.81 8600.0 68.12 127.16 4895.7 8700.0 67.97 126.34 4933.1 8800.0 68.03 126.81 4970.5 8900.0 68.33 126.69 5007.7 9000.0 69.01 126.80 5044.1 5937.2 6030.0 6122.7 6215.5 6308.6 4829.3 4866.7 4904.1 4941.3 4977.7 .74 5938.4 124.2 .78 6031.1 124.2 .44 6123.7 124.2 .32 6216.5 124.3 .68 6309.5 124.3 3334.10 S 4914.16 F 3389.59 S 4988.47 E 3444.84 S 5062.93 E 3500.39 S 5137.32 E 3556.11 S 5211.95 E 9100.0 68.85 126.30 5080.0 9200.0 67.49 124.67 5117.2 9300.0 67.62 124.17 5155.4 9400.0 67.45 124.20 5193.6 9500.0 65.74 123.21 5233.3 6401.9 6494.7 6587.1 6679.5 6771.2 5013.6 5050.8 5089.0 5127.2 5166.9 .48 6402.8 124.3 2.04 6495.6 124.4 .48 6588.0 124.4 .17 6680.4 124.4 1.94 6772.2 124.3 3611.69 S 5286.92 E 3665.58 S 5362.49 E 3717.82 S 5438.74 E 3769.74 S 5515.18 E 3820.67 S 5591.52 E A Gyrodata B.P. EXPLORATION WELL: MILNE POINT MPH 05, 7 5/8" CASING Location: H PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G287 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 9600.0 65.57 122.72 5274.6 9700.0 65.53 122.22 5316.0 9800.0 66.12 122.24 5356.9 9900.0 66.57 122.24 5397.1 10000.0 67.00 123.29 5436.5 10100.0 67.40 123.25 5475.2 10200.0 67.48 125.16 5513.6 10300.0 68.06 125.52 5551.4 10400.0 68.50 125.33 5588.4 10500.0 68.99 125.69 5624.7 10600.0 67.69 126.56 5661.6 10700.0 68.28 127.25 5699.1 10800.0 68.36 126.66 5736.0 10900.0 68.34 127.61 5772.9 11000.0 68.04 126.65 5810.1 11100.0 68.14 126.83 5847.4 11200.0 68.44 126.56 5884.4 11300.0 68.87 127.46 5920.8 11400.0 67.53 126.80 5957.9 11500.0 67.82 126.94 5995.9 11600.0 68.21 127.00 6033.3 11700.0 68.73 127.43 6070.0 11800.0 69.19 126.95 6105.9 11900.0 68.57 127.33 6142.0 12000.0 68.43 127.08 6178.6 6862.3 6953.2 7044.3 7135.7 7227.5 7319.7 7412.0 7504.6 7597.5 7690.7 7783.6 .7876.3 7969.2 8062.1 8154.8 8247.6 8340.5 8433.6 8526.4 8618.8 8711.5 8804.5 8897.8 8991.0 9084.0 Directional Survey SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 5208.2 .48 6863.3 124.3 5249.6 .45 6954.3 124.3 5290.5 .59 7045.4 124.3 5330.7 .45 7137.0 124.2 5370.1 1.06 7228.8 124.2 5408.8 .40 7321.0 124.2 5447.2 1.77 7413.3 124.2 5485.0 .66 7505.9 124.2 5522.0 .48 7598.8 124.2 5558.3 .59 7692.0 124.3 5595.2 1.53 7784.8 124.3 5632.7 .87 7877.5 124.3 5669.6 .56 7970.3 124.3 5706.5 .89 8063.1 124.4 5743.7 .95 8155.9 124.4 5781.0 .20 8248.6 124.4 5818.0 .40 8341.4 124.5 5854.4 .94 8434.4 124.5 5891.5 1.47 8527.2 124.5 5929.5 .32 8619.6 124.5 5966.9 .39 8712.3 124.6 6003.6 .66 8805.2 124.6 6039.5 .64 8898.4 124.6 6075.6 .71 8991.6 124.6 6112.2 .27 9084.6 124.7 Page HORIZONTAL COORDINATES feet 3870.24 S 5667.96 E 3919.11 S 5744.75 E 3967.77 S 5821.92 4016.63 S 5899.40 E 4066.36 S 5976.68 E 4116.93 S 6053.76 E 4168.84 S 6130.14 E 4222.38 S 6205.64 E 4276.23 S 6281.34 E 4330.37 S 6357.21 E 4385.16 S 4440.83 S 4496.70 S 4552.81 S 4608.85 S 4664.34 S 4719.86 S 4775.92 S 4831.96 S 4887.46 S 4943.23 S 4999.49 S 5055.90 S 5112.22 S 5168.47 S 6432.28 E 6506.41 E 6580.67 E 6654.76 E 6728.78 E 6803.13 F 6877.62 E 6952.00 E 7026.02 E 7100.03 E 7174.11 E 7248.19 E 7322.54 E 7396.90 E 7471.01 E A Gyro da t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: MILNE POINT MPH 05, 7 5/8" CASING Location: H PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G287 Page MEASURED I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 12100.0 67.51 127.84 6216.1 9176.6 12200.0 67.34 127.35. 6254.5 9268.9 12300.0 67.51 126.57 6292.9 9361.2 12400.0 67.62 127.06 6331.1 9453.6 12500.0 67.78 126.05 6369.0 9546.1 6149.7 1.16 9177.1 124.7 6188.1 .48 9269.4 124.7 6226.5 .75 9361.6 124.8 6264.7 .46 9454.0 124.8 6302.6 .95 9546.5 124.8 5224.85 S 7544.59 E 5281.19 S 7617.75 E 5336.71 S 7691.54 ~. 5392.09 S 7765.54 E 5447.19 S 7839.86 E 12600.0 67.91 126.56 6406.7 9638.7 12700.0 67.93 126.38 6444.3 9731.3 12800.0 68.03 126.42 6481.8 9824.0 12900.0 68.13 125.83 6519.1 9916.8 13000.0 68.60 125.81 6556.0 10009.7 6340.3 .49 9639.1 124.8 6377.9 .17 9731.7 124.8 6415.4 .11 9824.4 124.8 6452.7 .56 9917.1 124.8 6489.6 .47 10010.1 124.9 5502.02 S 7914.50 E 5557.10 S 7989.02 E 5612.12 S 8063.64 E 5666.81 S 8138.57 E 5721.20 S 8213.95 E 13100.0 68.64 126.82 6592.5 10102.8 13200.0 67.23 126.21 6630.0 10195.5 13300.0 66.59 126.38 6669.3 10287.5 13400.0 65.78 126.00 6709.6 10378.9 13500.0 66.29 126.09 6750.3 10470.3 6526.1 .94 10103.1 124.9 6563.6 1.52 10195.8 124.9 6602.9 .65 10287.7 124.9 6643.2 .88 10379.2 124.9 6683.9 .52 10470.6 124.9 5776.35 S 8288.98 E 5831.50 S 8363.46 E 5885.95 S 8437.60 E 5939.96 S 8511.43 E 5993.73 S 8585.32 E 13600.0 66.47 126.14 6790.3 10561.9 13700.0 66.88 125.98 6829.9 10653.7 13800.0 67.46 126.29 6868.7 10745.9 13900.0 67.89 126.89 6906.7 10838.4 14000.0 68.65 126.34 6943.7 10931.2 6723.9 .19 10562.2 124.9 6763.5 .43 10654.0 124.9 6802.3 .64 10746.1 125.0 6840.3 .70 10838.6 125.0 6877.3 .92 10931.4 125.0 6047.73 S 8659.34 6101.79 S 8733.57 6156.14 S 8808.00 6211.28 S 8882.27 6266.69 S 8956.83 Final Station Closure: Distance: 10931.43 ft Az: 124.98 deg. A Gy r o da t a D i r e c t i ona 1 S u rve y for B.P. EXPLORATION WELL: MILNE POINT MPH 05, 7 5/8" CASING Location: H PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G287SS Run Date: 20-Aug-95 06:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.438000 deg. N Sub-sea Correction from Vertical Reference: 66.4 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 125.310 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gy r o da t a D i r e c t i ona I Survey B.P. EXPLORATION WELL: MILNE POINT MPH 05, 7 5/8" CASING Location: H PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G287SS Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG CLOSURE DEPTH DEPTH SECTION SEVERITY DIST. AZIMUTH feet deg. deg. feet feet deg./ feet deg. 100 ft. HORIZONTAL 'COORD I NATES feet -66.4 0.00 0.00 0.0 0.0 0.00 0.0 0.0 0.00 N 0.00 E MEASURED DEPTHS ARE REFERENCED TO NABORS 22 E R.K.B. HEIGHT OF 66.4 FEET. 0.0 - 14000.0 FT. GYRO SURVEY RUN IN 7 5/8 INCH CASING. 100.0 .13 93.82 166.4 .2 .10 .3 109.4 200.0 .12 40.39 266.4 .3 .11 .5 92.9 300.0 .12 351.23 366.4 .3 .10 .5 71.8 400.0 .15 346.80 466.4 .1 .07 .6 49.2 500.0 .17 14.02 566.4 -.0 .08 .9 34.8 600.0 .28 33.81 666.4 -.1 .15 1.3 31.9 700.0 .48 50.02 766.4 .1 .22 2.0 36.4 800.0 .91 77.43 866.4 .7 .55 3.2 48.9 900.0 2.09 102.72 966.4 3.0 1.31 5.8 70.4 1000.0 3.62 116.80 1066.4 7.8 1.64 11.0 91.2 1100.0 4.84 121.77 1166.4 15.2 1.27 18.8 104.3 1200.0 6.58 124.12 1266.4 25.2 1.74 29.3 111.7 1300.0 8.62 125.51 1366.4 38.5 2.04 43.5 116.2 1400.0 9.86 125.41 1466.4 54.8 1.22 60.2 119.0 1500.0 11.38 124.91 1566.4 73.5 1.50 79.2 120.6 1600.0 14.14 121.77 1666.4 96.1 2.82 102.4 121.2 1700.0 17.19 120.32 1766.4 124.0 2.97 130.6 121.2 1800.0 19.51 121.08 1866.4 157.0 2.19 162.9 121.1 1900.0 21.58 120.39 1966.4 194.3 1.96 198.4 121.0 2000.0 24.90 121.17 2066.4 236.8 3.17 238.0 121.0 .08 S .24 E .05 N .41 E .16 N .46 E .37 N .42 E .63 N .43 E .97 N .61 E 1.43 N 1.08 E 1.80 N 2.17 E 1.40 N 4.67 E 1.34 S 9.19 E 4.28 S 15.57 E 9.76 S 23.93 E 17.41 S 34.85 E 26.85 S 48.10 E 37.63 S 63.42 E 49.97 S 82.34 E 64.34 S 106.36 E 81.25 S 134.83 E 100.36 S 166.96 E 122.20 S 203.64 E A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MILNE POINT MPH 05, 7 5/8" CASING Location: H PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G287SS Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG SEVERITY deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2100.0 28.36 123.41 2166.4 287.2 2200.0 29.94 123.20 2266.4 343.0 2300.0 32.65 122.96 2366.4 403.7 2400.0 37.62 122.71 2466.4 473.8 2500.0 42.77 121.98 2566.4 557.6 3.21 1.40 2.45 4.22 3.79 331.0 121.2 381.5 121.6 435.8 121.8 495.9 121.9 561.7 122.0 149.25 S 246.19 E 179.92 S 292.91 E 213.11 S 343.80 E 251.06 S 402.80 E 296.06 S 473.54 E 2600.0 44.31 122.12 2666.4 652.3 2700.0 48.60 122.18 2766.4 756.8 2800.0 53.52 120.86 2866.4 880.6 2900.0 59.40 119.32 2966.4 1030.1 3000.0 66.34 119.11 3066.4 1224.7 1.17 3.24 3.10 3.48 3.18 700.5 122.0 774.4 122.0 932.7 122.0 1103.5 121.7 1284.8 121.3 346.45 S 554.02 E 402.13 S 642.53 E 466.95 S 748.37 E 542.31 S 878.18 E 637.37 S 1049.37 E 3100.0 69.56 118.52 3166.4 1481.6 3200.0 69.00 120.42 3266.4 1742.6 3300.0 69.79 120.42 3366.4 2004.0 3400.0 68.84 122.34 3466.4 2270.5 3500.0 69.49 125.05 3566.4 2535.9 2.12 1.12 .73 1.39 1.08 1565.6 121.0 1752.2 120.7 2032.6 120.7 2313.4 120.7 2593.8 121.0 764.81 S 1273.90 E 893.02 S 1502.89 E 1025.88 S 1729.17 E 1163.08 S 1958.53 E 1311.17 S 2178.89 E 3600.0 70.24 I25.90 3666.4 2808.0 3700.0 67.44 125.34 3766.4 3074.1 3800.0 69.84 129.04 3866.4 3324.2 3900.0 70.78 130.08 3966.4 3606.8 4000.0 68.64 127.39 4066.4 3878.5 .84 1.72 1.67 .33 1.05 2875.0 121.4 3153.4 121.8 3339.0 122.2 3619.6 122.8 3899.6 123.2 1467.81 S 1622.45 S 1773.24 S 1955.00 S 2125.18 S 2401.41 E 2617.87 E 2817.63 E 3035.20 E 3247.59 E 4100.0 67.30 126.13 4166.4 4122.2 4200.0 68.22 127.23 4266.4 4363.7 4300.0 68.47 125.84 4366.4 4613.8 4400.0 68.73 124.68 4466.4 4872.9 4500.0 67.79 126.02 4566.4 5126.5 .40 1.90 .44 .64 1.60 4176.5 123.4 4453.8 123.5 4639.4 123.7 4919.3 123.7 5197.8 123.8 2270.28 S 2412.76 S 2559.95 S 2708.22 S 2853.72 S 3443.47 E 3638.46 E 3840.73 E 4053.21 E 4260.94 E A Gyro da t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: MILNE POINT MPH 05, 7 5/8" CASING Location: H PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G287SS Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG CLOSURE DEPTH DEPTH SECTION SEVERITY DIST. AZIMUTH feet deg. deg. feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 4600.0 67.41 126.62 4666.4 5367.3 4700.0 68.47 125.95 4766.4 5614.4 4800.0 68.13 126.53 4.866.4 5864.3 4900.0 68.02 126.76 4966.4 6112.4 5000.0 68.91 126.49 5066.4 6366.5 .30 5382.2 123.9 .42 5660.3 124.0 .62 5938.4 124.1 .48 6123.7 124.2 .56 6402.8 124.3 2995.77 S 4455.36 E 3141.89 S 4.654.65 E 3290.43 S 4855.69 E 3438.73 S 5054.69 E 3590.59 S 5258.47 E 5100.0 67.57 124.18 5166.4 6613.7 5200.0 65.60 122.82 5266.4 6844.2 5300.0 66.22 122.24 5366.4 7065.9 5400.0 67.31 123.26 5466.4 7298.7 5500.0 68.24 125.45 5566.4 7542.2 .39 6680.4 124.4 .77 6863.3 124.3 .56 7137.0 124.3 .55 7321.0 124.2 .59 7598.8 124.2 3732.76 S 5460.73 E 3860.41 S 5652.81 E 3979.30 S 5840.21 E 4105.41 S 6036.21 E 4244.18 S 6236.28 E 5600.0 67.77 126.65 5666.4 7795.5 5700.0 68.34 127.45 5766.4 8045.7 5800.0 68.29 126.69 5866.4 8295.4 5900.0 67.59 126.83 5966.4 8547.0 6000.0 68.68 127.39 6066.4 8795.3 1.44 7877.5 124.3 .83 8063.1 124.4 .30 8341.4 124.4 1.22 8619.6 124.5 .64 8805.2 124.6 4392.31 S 6441.81 E 4542.93 S 6641.72 E 4692.89 S 6841.44 E 4844.37 S 7042.57 E 4993.92 S 7240.87 E 6100.0 68.48 127.16 6166.4 9053.0 6200.0 67.39 127.11 6266.4 9297.4 6300.0 67.77 12'6.12 6366.4 9539.7 6400.0 67.99 126.40 6466.4 9785.9 6500.0 68.61 126.10 6566.4 10036.2 .42 9084.6 124.7 .56 9361.6 124.7 .91 9546.5 124.8 .13 9824.4 124.8 .60 10103.1 124.9 5149.71 S 7446.29 E 5298.36 S 7640.58 E 5443.38 S 7834.72 E 5589.50 S 8032.97 E 5736.91 S 8235.31 E 6600.0 66.64 126.36 6666.4 10280.8 6700.0 66.36 126.11 6766.4 10507.2 6800.0 67.42 126.27 6866.4 10740.4 6877.3 68.65 126.34 6943.7 10931.2 .72 10287.7 124.9 · 39 10562.2 124.9 · 63 10746.1 125.0 .92 10931.4 125.0 5881.97 S 8432.19 E 6015.48 S 8615.14 E 6152.90 S 8803.56 E 6266.69 S 8956.83 E Final Station Closure: Distance: 10931.43 ft Az: 124.98 deg. gyro/data 4. QUALITY CONTROL SR106.DOC Quality Control Comparisons B.P. EXPLORATION WELL: MILNE POINT Location: H PAD, MPH 05, 7 5/8" CASING MILNE POINT FIELD, ALASKA Job Number : AK0895G287 / AK0895G287 / Comparison Depth Inc Inc Delta Az Az 1000.0 2.62 2.59 .035 114.89 110.04 2000.0 21.64 21.77 -.130 120.62 120.29 3000.0 49.08 49.38 -.296 122.68 122.17 14000.0 68.51 68.65 -.138 126.68 126.34 For Inclinations Greater than 10 degrees: Average Inclination Difference = -.1881 deg. Average Azimuth Difference = .39357 deg. Delta 4.856 .332 .510 .339 gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK0895G287 TOOL NUMBER: 722 MAXIMUM GYRO TEMPERATURE: 79.8c MAXIMUM AMBIENT TEMPERATURE: 95 c MAXIMUM INCLINATION: 70.7 AVERAGE AZIMUTH: 124.98 WIRELINE REZERO VALUE: no correction REZERO ERROR / K: n/a CALIBRATION USED FOR FIELD SURVEY: 7/24/95 CALIBRATION USED FOR FINAL SURVEY: 7/24/95 PRE JOB MASS BALANCE OFFSET CHECK: POST JOB MASS BALANCE OFFSET CHECK~: CONDITION OF SHOCK WATCHES -.40 -.35 -.38 USED-.39 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS: M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 14000 68.65 126.34 6943.7 6241.5S 8973.6E FINAL SURVEY 14000 68.65 126.34 6943.7 6266.69 8956.83E SR106.DOC gyro/data FUNCTION TEST JOB NUMBER' AK0895G287 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft I 2 3 4 5 5600 65.58 65.57 65.57 65.57 65.57 AZIMUTH M.D.~ 1 2 3 4 5 5600 125.59 125.67 125.68 126.02 125.77 SR106.DOC gyro/data EQUIPMENT AND CHRONOLOGICAL REPORT SR106.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK0895G278 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 722 GYRO SECTION A0012 DATA SECTI ON A0032 POWER SECTION A0027 BACKUP TOOL No. 725 GYRO SECTION A0054 DATA S ECTI O N A0025 POWER SECTION A0052 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0074 A0079 A0071 A0122 A0074 A0082 A0035 WIRELINE COMPANY: CABLE SIZE: ATLAS WIRELINE 15/16 RUNNING GEAR 3" System TOTAL LENGTH OF TOOL: MAXIMUM O.D.: TOTAL WEIGHT OF TOOL: 23.5 feet 3 INCHES 240Lbs SR106.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK0895G287 8/17/95 1145 8/18/95 1133 0445 0525 0540 0750 1910 0915 8/19/95 1800 ARRIVE ON THE SLOPE LEAVE FOR M.P. PU TOOL. ZERO TO OL.. START INRUN. 3000'. 3500' RU TO PUMP TOOL. 14000 FT. 8800 FT. 4000'. RTN ANCHORAGE SR106.DOC u 0 0 -.;;t co N a: (j) c: 00 0 ~ O.~ Ü' ....J c.ø 0 ( LJ,.J ~ ~ CD ~ > ~ ~~ tn - ~ 8,g \\' Q) Z u.J 0 ~g c.. ..-- U >- :< <C "0.. L() (!) LU <( - =e a Lt)~=o> --- eX .¡ q en "¡:: 0> ~ :¡:<C"'C~ ;æ ze..-JQ)+-Ï 0 -0-- O:E<C~~ - en t- .. c: C) <C . C .- :J 0:: 0 -J ~« oz!:!:!~o -J-JLL:J~ e..-Jt-C/)Q) ><Wz.......... W~-orn . O.c-c e.. .. e.. "~~ a:iCW~Q) <Cz~2: e..-J :J :¡:-oC/) :E~ (9 '=-" J! i ~ ~ Q) . Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 August 21, 1995 Ms. Terrie Hubble B.P. Exploration Prudhoe Bay Drilling Department 900 E. Benson Blvd. Anchorage, AK 99508 MB 12-1 Re: H Pad, Well # MPH-05 Milne Point field, Alaska Dear Ms. Hubble, Enclosed please find one (1) original and three copies (3) of the completed survey of Well #MPH-05 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the furore. Sincerely , /? t/' ,...- ?../ Robert J. Shoup Operations Manager RS/gr Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data CONTENTS JOB NUMBER :AK0895G284 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR284.DOC gyro/data 1. DISCUSSION, SURVEY CERTIFICATION SHEET SR284.DOC gyro/data DISCUSSION JOB NUMBER' AK0895G284 Tool 080 was run in MPH-05 on ATLAS 5/16" Wireline inside 5.5" drill pipe. The survey was run without problems. SR284.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK0895G284 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- VICTOR O. LABOY OPERATIONS ENGINEER SR284.DOC gyro/data 2. SURVEY DETAILS SR284.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK0895G284 CLIENT: B.P. EXPLORATION RIG: H-PAD LOCATION: WELL: MILNE POINT H PAD MPH-05 LATITUDE: 70.4380 N LONGITUDE: 149.5 W S U RVEY DATE: SURVEY TYPE : 10-August, 1995 MULTISHOT IN 5.5" drill pipe DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE EVELATION 66.4 FT. 6720' SURVEY TIED ONTO: N/A SURVEY INTERVAL: 100' UTM CO-ORDINATES: TARGET DIRECTION: 125.310 GRID CORRECTION: CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: STODDARD SR284.DOC gyro/data 3. OUTRUN SURVEY LISTING SR284.DOC gyro/data 4. QUALITY CONTROL SR284.DOC gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK0895G284 TOOL NUMBER: 080 MAXIMUM GYRO TEMPERATURE: 74.45c MAXIMUM AMBIENT TEMPERATURE: 38.0 c MAXIMUM INCLINATION: 71.31 AVERAGE AZIMUTH: 123.1566 WIRELINE REZERO VALUE: zero correction added REZERO ERROR/K: n/a CALIBRATION USED FOR FIELD SURVEY: 1192 CALIBRATION USED FOR FINAL SURVEY: 1192 PRE JOB MASS BALANCE OFFSET CHECK: POST JOB MASS BALANCE OFFSET CHECK] ' CONDITION OF SHOCK WATCHES .01 .05 USED .05 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 6720.0 67.57 125.39 4182.90 2324.80S 3500.10E MWD 6781.5 67.40 126.00 4209.11 2403.22S 3532.87E SR284.DOC gyro/data FUNCTION TEST JOB NUMBER' AK0895G284 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 2800 43.56 43.56 43.56 43.56 43.56 AZIMUTH M.D. ff 1 2 3 4 5 .. 2800 122.75 123.06 I 122.94 122.93 122.87 SR284.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR284.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK0895G284 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 080 GYRO SECTION A0094 DATA S ECTI O N A0025 POWER SECTION A0027 BACKUP TOOL No. 713 GYRO SECTION A0073 DATA S ECTI ON A0032 POWER SECTION A0052 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0085 A0029 A0035 A0122 A0055 A0079 A0071 WIRELINE COMPANY: CABLE SIZE: ATLAS WIRELINE 5/16" RUNNING GEAR 2 1/4" System TOTAL LENGTH OF TOOL: MAXIMUM O.D.: 34.5 feet 2.25 INCHES TOTAL WEIGHT OF TOOL: 240Lbs SR284.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK0895G284 8/10/95 0500 0630 0800 1145 1220 1310 1350 1610 700 LEAVE ATLAS ARRIVED AT LOCATION SPOT UNIT, MAKE UP TOOL PULL UP TOOL, MAKE UP PUMPING DUB RUNNING IN HOLE PUMP TOOL DOWN HOLE 6720' SURVEYING OUT LAY DOWN AND BREAK DOWN TOOL PROCESS SURVEY, DEPARTING TO F-PAD SR284.DOC A Gyro da t a D i r e c t i ona i Survey for B.P. EXPLORATION WELL: MPH-05 Job Number: AK0895G284 Location: H PAD, MILNE POINT, ALASKA Run Date: 10-Aug-95 07:09:46 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.438000 deg. N Sub-sea Correction from Vertical Reference: 66.4 ft. Azimuth Corrected:: Gyro: Bearings are Relative to True North Proposed Well Direction: 125.310 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: MPH-05 Location: H PAD, MILNE POINT, Job Number: AK0895G284 ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 0.0 0.00 0.00 0.0 0.0 -66.4 0.00 0.0 0.0 0 - 6720 FT. GYRODATA MULTISHOT SURVEY RUN INSIDE DRILL PIPE ALL MEASURED DEPTHS AND COORDINATES ARE REFERENCED FROM H-PAD R.K.B. Page 1 HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .22 145.28 100.0 .2 33.6 .22 .2 145.3 200.0 .14 210.73 200.0 .4 133.6 .21 .5 159.0 300.0 .19 160.38 300.0 .5 233.6 .15 .7 167.0 400.0 .15 281.33 400.0 .5 333.6 .30 .8 174.2 500.0 .50 23.34 500.0 .3 433.6 .56 .4 161.6 600.0 .58 6.90 600.0 -.0 533.6 .17 .6 34.3 700.0 .65 14.69 700.0 -.5 633.6 .11 1.7 19.7 800.0 .73 56.96 800.0 -.4 733.6 .50 2.8 26.7 900.0 1.51 99.15 900.0 1.0 833.6 1.09 4.0 49.7 1000.0 2.52 109.91 999.9 4.3 933.5 1.07 6.7 75.6 1100.0 4.02 118.57 1099.7 9.9 1033.3 1.58 11.6 93.8 1200.0 5.12 122.43 1199.4 17.8 1133.0 1.14 19.1 104.7 1300.0 7.13 124.00 1298.8 28.5 1232.4 2.02 29.4 111.4 1400.0 9.31 123.82 1397.8 42.8 1331.4 2.17 43.4 115.5 1500.0 10.19 125.40 1496.4 59.7 1430.0 .92 60.2 118.0 1600.0 11.90 125.58 1594.5 78.9 1528.1 1.72 79.2 119.8 1700.0 14.80 119.97 1691.8 101.9 1625.4 3.17 102.3 120.4 1800.0 17.68 120.40 1787.8 129.8 1721.4 2.88 130.2 120.4 1900.0 19.77 120.51 1882.5 161.7 1816.1 2.09 162.3 120.4 2000.0 21.95 119.72 1975.9 197.2 1909.5 2.20 197.9 120.3 .16 S .11 E .42 S .16 E .68 S .16 E .81 S .08 E .38 S .13 E .53 N .36 E 1.58 N .56 E 2.47 N 1.24 E 2.61 N 3.08 E 1.66 N 6.45 E .77 S 11.59 4.84 S 18.44 E 10.70 S 27.35 E 18.67 S 39.22 E 28.30 S 53.14 E 39.42 S 68.74 E 51.80 S 88.19 E 65.87 S 112.36 E 82.14 S 140.03 E 99.99 S 170.83 E A Gyro da t a D i r e c t i o n a i Survey B.P. EXPLORATION WELL: MPH-05 Location: H PAD, MILNE POINT, Job Number: AK0895G284 ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2100.0 24.83 121.51 2067.7 2200.0 28.31 123.25 2157.1 2300.0 29.86 124.53 2244.5 2400.0 30.99 124.58 2330.8 2500.0 34.41 122.76 2414.9 236.8 281.4 330.0 380.7 434.7 2001.3 2.97 237.6 120.4 2090.7 3.57 282.3 120.7 2178.1 1.67 330.9 121.2 2264.4 '1.13 381.4 121.6 2348.5 3.56 435.4 121.9 120.23 S 204.97 E 144.22 S 242.72 ' 171.34 S 283.07 m 200.06 S 324.78 E 229.97 S 369.75 E 2600.0 39.06 123.34 2495.0 2700.0 42.63 123.33 2570.6 2800.0 43.56 122.75 2643.7 2900.0 46.02 122.56 2714.6 3000.0 49.32 122.32 2782.0 494.4 559.8 628.0 698.4 772.2 2428.6 4.66 495.2 122.0 262.59 S 419.86 E 2504.2 3.57 560.6 122.2 298.53 S 474.49 E 2577.3 1.00 628.9 122.3 335.78 S 531.77 E 2648.2 2.46 699.3 122.3 373.79 S 591.08 E 2715.6 3.31 773.3 122.3 413.43 S 653.46 E 3100.0 52.16 122.98 2845.2 3200.0 55.12 121.42 2904.5 3300.0 58.58 120.52 2959.2 3400.0 62.22 120.30 3008.6 3500.0 65.34 120.29 3052.8 3600.0 68.61 120.87 3091.9 3700.0 70.16 121.31 3127.1 3800.0 69.78 120.78 3161.3 3900.0 69.46 120.92 3196.2 4000.0 69.03 120.54 3231.6 849.6 930.0 1013.4 1100.0 1189.4 1281.1 1374.4 1468.1 1561.6 1654.8 2778.8 2.89 850.7 122.4 2838.1 3.21 931.2 122.3 2892.8 3.54 1014.9 122.2 2942.2 3.64 1101.8 122.1 2986.4 3.12 1191.4 121.9 3025.5 3060.7 3094.9 3129.8 3165.2 3.31 1283.4 121.8 1.60 1377.0 121.8 .62 1471.0 121.7 .35 1564.7 121.7 .56 1658.2 121.6 455.21 S 718.65 E 498.10 S 786.79 E 541.16 S 858.57 E 585.16 S 933.55 E 630.41 S 1011.00 E 677.23 S 1090.22 725.56 S 1170.37 E 774.01 S 1250.86 E 822.08 S 1331.34 E 869.85 S 1411.72 E 4100.0 69.28 121.47 3267.2 4200.0 69.26 121.16 3302.6 4300.0 69.39 121.36 3337.9 4400.0 70.19 122.25 3372.4 4500.0 69.78 122.06 3406.7 1748.0 1841.3 1934.6 2028.3 2122.1 3200.8 3236.2 3271.5 3306.0 3340.3 .91 1751.6 121.6 .29 1845.2 121.6 .23 1938.7 121.6 1.15 2032.6 121.6 .44 2126.5 121.6 917.99 S 1491.82 E 966.60 S 1571.73 E 1015.15 S 1651.70 E 1064.61 S 1731.45 E 1114.62 S 1810.99 E A Gyro da t a D i r e c t i o na i Survey B.P. EXPLORATION WELL: MPH-05 Location: H PAD, MILNE POINT, Job Number: AK0895G284 ALASKA Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 4600.0 4700.0 4800.0 4900.0 5000.0 69.41 122.37 3441.5 68.97 122.57 3477.1 69.84 122.90 3512.2 70.14 124.40 3546.4 69.60 124.58 3580.9 2215.7 2309.0 2402.6 2496.5 2590.4 3375.1 3410.7 3445.8 3480.0 3514.5 .47 2220.2 121.6 .48 2313.7 121.7 .93 2407.3 121.7 1.44 2501.2 121.8 .57 2595.0 121.9 1164.59 S 1890.29 E 1214.78 S 1969.15 ~ ~ 1265.40 S 2047.89 m 1317.46 S 2126.10 E 1370.63 S 2203.49 E 5100.0 5200.0 5300.0 5400.0 5500.0 70.27 125.00 3615.2 70.03 123.73 3649.1 70.65 123.98 3682.8 69.62 123.99 3716.7 68.43 125.77 3752.5 2684.3 2778.3 2872.5 2966.5 3059.9 3548.8 3582.7 3616.4 3650.3 3686.1 .78 2688.8 122.0 1.22 2782.8 122.1 .67 2876.9 122.1 1.03 2970.9 122.2 2.03 3064.2 122.3 1424.23 S 2280.63 E 1477.32 S 2358.26 E 1529.79 S 2436.46 E 1582.36 S 2514.45 E 1635.75 S 2591.04 E 5600.0 5700.0 5800.0 5900.0 6000.0 66.17 125.25 3791.1 70.47 128.15 3828.1 70.06 127.43 3861.8 71.03 127.92 3895.1 71.00 128.81 3927.7 3152.1 3245.0 3339.0 3433.2 3527.6 3724.7 3761.7 3795.4 3828.7 3861.3 2.31 3156.3 122.4 5.07 3248.9 122.5 .80 3342.7 122.6 1.07 3436.6 122.8 .84 3530.7 122.9 1689.34 S 2666.14 E 1744.89 S 2740.59 E 1802.56 S 2814.98 E 1860.19 S 2889.61 E 1918.88 S 2963.75 E 6030.0 6060.0 6090.0 6120.0 6150.0 70.97 129.31 3937.4 71.01 129.33 3947.2 70.98 128.97 3957.0 71.12 128.40 3966.7 71.31 129.51 3976.4 3555.9 3584.2 3612.5 3640.9 3669.2 3871.0 3880.8 3890.6 3900.3 3910.0 1.58 3558.9 123.0 .13 3587.1 123.0 1.14 3615.3 123.1 1.85 3643.5 123.1 3.55 3671.8 123.2 1936.75 S 2985.77 1954.72 S 3007.71 E 1972.63 S 3029.71 E 1990.37 S 3051.86 E 2008.22 S 3073.94 E 6180.0 6210.0 6240.0 6270.0 6300.0 71.17 129.26 3986.0 70.86 129.18 3995.8 70.30 128.90 4005.8 69.92 127.35 4016.0 69.79 129.71 4026.3 3697.5 3725.8 3754.1 3782.2 3810.4 3919.6 3929.4 3939.4 3949.6 3959.9 .91 3700.0 123.2 1.07 3728.2 123.3 2.05 3756.4 123.3 5.03 3784.5 123.3 7.40 3812.6 123.4 2026.25 S 3095.90 E 2044.19 S 3117.88 E 2062.01 S 3139.85 E 2079.42 S 3162.04 E 2096.97 S 3184.07 E A Gyro da t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: MPH-05 Location: H PAD, MILNE POINT, Job Number: AK0895G284 ALASKA Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 6330.0 69.07 126.95 4036.9 6360.0 69.01 126.15 4047.6 6390.0 69.23 127.69 4058.3 6410.0 68.52 127.19 4065.5 6450.0 67.68 124.98 4080.4 3838.4 3866.4 3894.4 3913.1 3950.2 3970.5 3981.2 3991.9 3999.1 4014.0 8.93 3840.5 123.4 2.52 3868.5 123.4 4.87 3896.5 123.5 4.26 3915.1 123.5 5.53 3952.2 123.5 2114.39 S 3206.10 E 2131.07 S 3228.61 % 2147.91 S 3251.02 m 2159.25 S 3265.83 E 2181.10 S 3295.82 E 6480.0 67.73 125.65 4091.8 6510.0 67.66 125.50 4103.2 6530.0 67.69 124.38 4110.8 6570.0 67.61 125.54 4126.0 6600.0 67.77 124.75 4137.4 3977.9 4005.7 4024.2 4061.2 4088.9 4025.4 4036.8 4044.4 4059.6 4071.0 2.06 3979.9 123.5 .52 4007.6 123.5 5.14 4026.1 123.5 2.67 4063.1 123.5 2.49 4090.9 123.6 2197.15 S 2213.29 S 2223.89 S 2245.09 S 2261.06 S 3318.47 E 3341.04 E 3356.21 E 3386.53 E 3409.22 E 6630.0 67.76 125.21 4148.7 6660.0 67.71 125.15 4160.1 6690.0 67.69 124.63 4171.5 6720.0 67.57 125.39 4182.9 4116.7 4144.5 4172.2 4200.0 4082.3 4093.7 4105.1 4116.5 1.42 4118.6 123.6 · 24 4146.4 123.6 1.62 4174.1 123.6 2.38 4201.9 123.6 2276.98 S 2292.98 S 2308.85 S 2324.77 S 3431.98 E 3454.67 E 3477.44 E 3500.16 E Final Station Closure: Distance: 4201.87 ft Az: 123.59 deg. A Gyro da t a D i r e c t i ona i Survey for B.P. EXPLORATION WELL: MPH-05 Location: H PAD, MILNE POINT, ALASKA Job Number: AK0895G284SS Run Date: 10-Aug-95 07:09:46 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.438000 deg. N Sub-sea Correction from Vertical Reference: 66.4 ft. Azimuth Corrected:: Gyro: Bearings are Relative to True North Proposed Well Direction: 125.310 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyr oda t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MPH-05 Location: H PAD, MILNE POINT, Job Number: AK0895G284SS ALASKA SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. -66.4 0.00 0.00 0.0 0.0 0.00 0.0 0.0 0 - 6720 FT. GYRODATA MULTISHOT SURVEY RUN INSIDE DRILL PIPE ALL MEASURED DEPTHS AND COORDINATES ARE REFERENCED FROM H-PAD R.K.B. Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .17 188.74 166.4 .3 200.0 .17 177.29 266.4 .5 300.0 .16 240.69 366.4 .5 400.0 .39 110.02 466.4 .4 500.0 .55 12.42 566.4 .1 600.0 .62 12.07 666.4 -.3 700.0 .70 42.77 766.4 -.4 800.0 1.25 84.99 866.4 .5 900.0 2.18 106.30 966.4 3.2 1000.0 3.52 115.68 1066.4 8.0 1100.0 4.76 121.15 1166.4 15.2 1200.0 6.48 123.48 1266.4 25.0 1300.0 8.62 123.88 1366.4 38.3 1400.0 9.92 124.92 1466.4 54.6 1500.0 11.41 125.53 1566.4 73.4 1600.0 14.04 121.43 1666.4 95.9 1700.0 17.04 120.30 1766.4 123.6 1800.0 19.41 120.49 1866.4 156.3 1900.0 21.72 119.80 1966.4 193.6 2000.0 24.79 121.48 2066.4 236.2 .21 .17 .25 .47 .30 .13 .37 .89 1.07 1.41 1.28 1.73 2.12 1.30 1.49 .5 154.4 .7 164.3 .8 171.8 .4 165.8 .6 77.0 1.7 2.8 4.0 6.7 11.6 .33 S .15 E .59 S .16 E .76 S .11 E .52 S .11 E .48 N .28 E 2.79 102.3 120.3 48.57 S 83.12 E 2.95 130.2 120.4 62.73 S 106.97 E 2.22 162.3 120.4 79.37 S 135.32 E 2.19 197.9 120.3 98.17 S 167.69 E 2.96 237.6 120.4 119.94 S 204°48 E 19.1 101.1 3.49 S 16.17 E 29.4 109.2 8.79 S 24.44 E 43.4 114.2 16.14 S 35.45 E 60.2 117.3 25.37 S 48.91 E 79.2 119.3 36.23 S 64.27 E 24.6 1.23 N .50 E 24.3 2.17 N 1.02 E 42.0 2.57 N 2.47 E 66.9 1.98 N 5.32 E 87.7 1.06 S 9.87 E A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MPH-05 Location: H PAD, MILNE POINT, Job Number: AK0895G284SS ALASKA Page SUBSEA I N C L AZIMUTH DEPTH feet dego deg. VERTICAL VERTICAL DOGLEG CLOSURE DEPTH SECTION SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2100.0 28°48 123.39 2200.0 30.15 124.54 2300.0 32.44 123.81 2400.0 37.40 123.13 2500.0 42.43 123.33 2166.4 286.6 3.36 330.9 120.8 2266.4 342.9 1.53 381.4 121.3 2366.4 403.5 2.16 435.4 121.7 2466.4 473.1 4.27 495.2 122.0 2566.4 556.1 3.64 560.6 122.2 147.09 S 247.00 E 178.62 S 293.65 E 212.73 S 343.83 E 250.94 S 401.97 E 296.51 S 471.43 E 2600.0 44.35 122.69 2700.0 48.56 122.38 2800.0 53.22 122.42 2900.0 59.11 120.48 3000.0 66.48 120.49 2666.4 650.6 1.47 699.3 122.3 2766.4 755.2 3.11 773.3 122.3 2866.4 878.3 3.00 931.2 122.3 2966.4 1026.1 3.56 1101.8 122.2 3066.4 1221.4 3.19 1283.4 121.9 347.96 S 550.77 E 404.27 S 639.05 E 470.52 S 742.98 E 547.58 S 869.51 E 646.73 S 1038.62 E 3100.0 69.74 120.80 3200.0 69.28 121.45 3300.0 70.05 122.10 3400.0 69.10 122.51 3500.0 69.82 124.51 3600.0 70.35 123.86 3700.0 67.62 125.58 3800.0 70.19 127.49 3900.0 71.12 128.42 4000.0 68.47 127.05 3166.4 1481.7 .58 1564.7 121.7 3266.4 1745.9 .90 1751.6 121.6 3366.4 2011.9 .99 2032.6 121.6 3466.4 2281.1 .48 2313.7 121.7 3566.4 2550.9 .94 2595.0 121.8 3666.4 2826.6 .94 2876.9 122.1 3766.4 3093.0 2.13 3156.3 122.3 3866.4 3352.0 .83 3436.6 122.7 3966.4 3639.9 1.83 3643.5 123.1 4066.4 3915.3 4.34 3952.2 123.5 781.01 S 1262.57 E 916.93 S 1490.07 E 1055.98 S 1717.52 E 1199.73 S 1945.51 E 1348.29 S 2170.97 E 1504.25 S 2398.40 E 1655.00 S 2618.02 E 1810.48 S 2825.24 E 1989.76 S 3051.11 E 2160.58 S 3267.66 E 4100.0 67.70 124.86 4116.5 67.57 125.39 4166.4 4159.9 1.01 4174.1 123.6 4182.9 4200.0 2.38 4201.9 123.6 2301.78 S 3467.29 E 2324.77 S 3500.16 E Final Station Closure: Distance: 4201.87 ft Az: 123.59 deg. Quality Control Comparisons B.P. EXPLORATION WELL: MPH-05 Location: H PAD, MILNE POINT, ALASKA Job Number : AK0895G284 / AK0895G284 INRUN/OUTRUN Comparison INRUN OUTRUN Depth Inc Inc Delta 1500.0 10.16 10.19 -.026 2000.0 21.85 21.95 -.093 2500.0 34.11 34.41 -.301 3000.0 49.17 49.32 -.153 3600.0 68.68 68.61 .070 4000.0 69.22 69.03 .192 6720.0 67.57 67.57 -.001 INRUN Az 124.42 119.52 123.22 121.82 120.02 120.27 125.39 For Inclinations Greater than 10 degrees: Average Inclination Difference = -.0443 deg. Average Azimuth Difference = -.3313 deg. OUTRUN Az 125.40 119.72 122.76 122.32 120.87 120.54 125.39 Delta -.980 -.194 .455 -.497 -.848 -.262 .007 BoP. EXPLORATION WELL: MPH-05 Location' H PAD~ MILNE POINT~ ALASKA AK0895G284 DEFINITIVE Z -F h- Z O,ON 30,08 500,0S 750,0S iO00,OS laSO,OS 1500,0S 1750,0S aO00,OS aaso,os ~5oo,os 900 '" ~ ~'s00: : ...... : .... : ..... : : : ...... : ..... : ..... ( .... :"' ~,,~, ,,~h~ ~.ooo 300,0W O,OW 300,OE 600,OE 900,OE laOO,OE 1500,OE 1800,OE alOO,OE a4OO,OE a7OO,OE 3000,OE 3300,0E 3600,0E EASTING Il B,P. EXPLORATION WELL' MPH-06 10,0 Location' H PAD~ 9,0 8,0 7,0 6,0 5,0 4,0 3,0 0,0 -],0 MILNE POINT~ ALASKA AK0895G284 DEFINITIVE 0,0 500,0 1000,0 1500,0 SO00,O ~500,0 3000,0 3500,0 4000,0 4500,0 5000,0 5500,0 ~000,0 ~500,0 MEASURF-21 DF-PTH (~4s) 10;~,0 BoP. EXPLORATION WELL' MPH-05 Location' H PAD, MILNE POINT, ALASKA AKO895G284 DEFINITIVE 100,0 98,0 %0 94,0 9~,0 90,0 88,0 86,0 500,0 1000,0 1500,0 $O00,O 2500,0 3000,0 3500,0 4000,0 4500,0 5000,0 5500,0 6000,0 6500,0 7000,0 0,0 PLEASURES ;OEPTH (-?-t;) 80,0 B.P. EXPLORATION WELL: MPH-05 Location' H PAD~ MILNE POINT, ALASKA AKO895G284 DEFINITIVE 75,0 70,0 65,0 60,0 55,0 50,0 45,0 40,0 35,0 30,0 25,0 ?0,0 15,0 lO,O 5,0 ~'nnn 5900 ..... , / / / / o,o !~ ~ o,oI ~ 'soo,o ~ooo,o 1500,0 aO00,O aSO0,O 3000,0 3500,0 4000,0 4500,0 5000,0 5500,0 6000,0 6500,0 I'vIEASURED I)EPTH (-F'4:;) 4500,0 B.P. EXPLORATION WELL' MPH-05 Location' H PAD, MILNE POINT, ALASKA AK0895G284 DEFINITIVE 4000,0 3500,0 3000,0 2500,0 2000,0 1500,0 1000,0 500,0 -500,0 SBTTBH HBLE 'LBCaTED MD: 6720,00 0,0 500,0 1000,0 1500,0 2000,0 2500,0 3000,0 3500,0 4000,0 4500,0 5000,0 5500,0 PIE~SURF-D DF-PTR 6000,0 6500,0 7000,0 13,5,0 132,0 12~,0 126,0 123,0 117,0 -V t-- D 114,0 111,0 i08,0 BoP. EXPLORAT~ON WELL' MPH-05 Locatien' H PAD, MILNE POINT, ALASKA AKO895G284 DEFINITIVE 900 1000,0 1500,0 aooo,o 2500,0 3000,0 3500,0 4000,0 HE-ASUF~F-D DEPTH (C~C) 4500,0 5000,0 5500,0 6000,0 6500,0 7000,0 Schlumberger- GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) November 28, 1995 TO: BP Exploration (Alaska)Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the Depth shifted CDRICDN,CDR/CDN TVD'S for well MPH-05 Job # 95300 was sent to: BP Exploration (Alaska) Inc. 1 OH LIS Tape Petrotechnical Data Center, MB3-3 3 Bluelines each 900 E. Benson Blvd. 1 Film each Anchorage, Alaska 99519-6612 ...................... .l __ _D . _e _p_ t. h shift display State-of Alaska ..... Alaska Oil & Gas Conservation Comm. ;,.-" Attn: Larry Grant / ~ 3001 Porcupine Drive ~,,, Anchorage, Alaska 99501 1 Blueline each 1 RF Sepia_~each OXY USA, Inc Attn: Darlene Fairly P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail Z 777 937 356 PLEASE ACKNOWLEDGE RECEI ONE COPY EACH TO' BP EXpLORATION (ALASKA) INC. P FC~IvED SCHLUMBERGER GEOQuEST PETROTEOHNIOAL DATA CENTER, MB3-3 500 WEST INTERNATIONAL AIRPORT ROAD 900 EAST BENSON BLVD. DEC 0 1 199,5 ANCHORAGE. ALASKA99518-1199 ANCHORAGE, ALASKA 99519-6612 ~as'Ka ui~ ~ :;:as C'afls. Coffl~jS$[Oi~' An~omgo Schlumberger Couder: Date Delivered: Received By: BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 28, 1995 Mr. Robert Crandall Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Lease Well H-05 Requirements for 20 AAC 25.071 Dear Mr. Crandall: ~ Per the requirements of 20 AAC 25.071, ple~ fin, d ,e.n.closed for Lease Well H- 05 a copy of the lithology log, CDN/CDR Iogsl and a list of geological markers encountered in the wellbore. The set of washed and dried cuttings has been shipped under separate cover. Please contact Barbara McMullen at 564-4464 if you have questions or require additional information. Sinc, crely, ////~/~ Bruce J. Policky ,~ Milne Point Unit Extdloitation Manager Milne Point Well H-05 APl#: 50-029-2257200 Base HRZ Kalubik Kuparuk Kupauk D Kupauk C Kuparuk Cl Kuparuk B Kuparuk B6 Kuparuk B5 Kuparuk B4 Kuparuk B3 Kuparuk B2 Kuparuk B1 Kuparuk A Top Miluveach MD 12479 12695 13111 13111 13330 13443 13515 13515 13554 13664 13731 13803 13865 1396O NR TVDSS 6295 6377 6531 6531 6616 6662 6691 6691 6706 6750 6776 6804 6828 6863 NR LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. ~ Date: I September 1995 Transmittal of Data '-'~' Sent by: HAND CARRY Dear Sir/Madam, ' Enclosed, please find the data as described below: -'. -"''i '- ..... (~- : . _ .- , ...~. .......... ~.. .... ~'- ' ' ;- i ." "-' '- .' '--' T -r ~--~ Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 ~chorage, ~ 99518 Or F~ to (907) 563-7803 Date: RECEIVED SEP 1 4 1995 AJaska Oil & Gas Cd,is. Anchorage LARRY GRANT Attn. ALASKA OIL + GAs CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 24 August 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS _.. Dear =; /x~ ,; ,,r,..a-am, _ . ....... . . _.- Enclosed, please f~d the data as descried below: .... ...................... ........ /. ~ - - - --_ -~;.~:~.~x-~'-'~---. _~ ~ - . -. . . - :-.~ "-- -~-~}-- ~ A~ ~E-23 :-~-_~'~-~:~ ~:~..:-;-.-~ '.' 1 SBT/GR FIN~ BL+~ - ?.Run ~ . i .:t~:'~ ' · 6473.00 .~~~ -.w,- : ,. _ -. . . '.. u'~:'~ 'i-Please sign and return, to: Attn. Rodney D. Paulson _.!' :~:-/:: :_"i{.'~'i-'R E C E IV D " .... - ....... ~ ..... - ..... < Atlas Wireline Services i." ...... 5600 B Street -' ........ .... -'~---" ----- .u~. ~_o~ '~: .... ~ -'- ..... s~p'~ 4"'i~SS' :-- -_-.----'- - . .......... Anchorage, AK 99518 .. . (:~ FAX to (907) 563-7803 Received b _.~_ Date: -. \ , : LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 14 August 1995 Transmittal of Data ECC #: 6469.00 Sent by: ANCH.EXPRESS Data: SBT/GR Dear Sir/Madam, Reference: f A ~' H-05 :~:~¢~-~'~:"~ NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 SBT/GR FINAL BL+RF Run # 1 Received by: ~~ Please sign and return to: Attn. Rodney D. Paulson Atlas Wi~ _ ~reet nchorage, AK 99518 AX~63-7803 Date: BP EXPLORATION . BP Exploration (Alaska) Inc. PO Box 196612 Armhorage, Alaska 99519-6612 TELECOPY COMMUNICATIONS CENTER MESSAGE# TO: Name: 'Company: Location: Fax # ~,7 ~ ,"J5'¥ 2_. Confirm # Department: Mail Stop: ...... l~ - ! PAGES TO FOLLOW REC. EIV g (Do Not Include Cover Sheet) AIJ(~ 0 8 ~-cJ9,5 ~t~ & 6as Cons. SECUF:IrI'Y OI_~S$1FIC~TiON PRIVATE SECRET CONFIDENTIAL For Communications Center Use Only Telecopy # Time In Time Sent Confirm # Time Confirmed Confirmed By ,' Operator Cement Squeeze Procedure MPH-05 9-5/8" casing squeeze 1, 3~ 4~ . . Perform casing test to 3000 PSI. Shoot 3 foot perf gun, 6 SPF at 5220' MD RIH with open ended drill pipe to 5320 ft MD and pump 250 sx class G cement. Pull up 10 stands and reverse out 150% of dp volurnc minimum or until clean. Monitor volumes while circulating to make sure the cement is not being displaced Slowly hesitate squeeze cement into perfs. Monitor both pressure and displacement of cement. Do not exceed casing displacement down to 100 feet above squeeze perfs or 500 PSI. possible hold pressure 3 - 4 hours after final displacement. If m POOH, pick up rotary BHA, and TIH. Total WOC time after final placement is 12 hours, Note: If there is any indication that all cement is pumped into loss zone, we may evaluate additional squeeze before drilling out cement. Drill out cement past perfs to 20 feet above casing shoe and change over to 9.4 ppg mud. 8. Drill out casing shoe and rathole a~.d 10 feet of new hole. g, Perform formation leakoff test as per drilling program to 11.5 EMW. Cement interval behind casing 500 ft * .3115 cu ft/ft = 156 cu ft. Capacity of 9-5 / 8" 47 # casing 0.4110cu ft / ft Class O Cement with 2% CaC12 Yield of 1,15 cu ft/sk Slurry weight of 15.8 PPG Water requirement. 5,0 gal/sk . O.' Blair Wono'zell Z DOUG AMOS 907-659-Z714 As the attached AOGCC BOPE Test Form indicates,there were no failures. The Rig and all BOP Equipment was in excellent condition. The stack and all related components had just been rebuilt, inspected and reassembled prior to this BOPE test. During the testing the mud weight was being increased to 11.6 PPG in anticipation of a cement squeeze job on the Surface Casing. Monday, August 7, 1996: I contacted Jimmy P)~t)n this date for an update on the CBL operation and was informed that the logging would commence around noon today. I instructed Jimmy to Fax a copy of the CBL to the AOGCC office, in care of Blair Wondzell and to keep Jerry Herring and Bobby Foster updated with information on the cementing operation. SUMMARY: Witnessed the successful BOPE test at BPX MPU H-05 well on Nabors Rig 22E. I worked with Shared Services representative Jimmy Pyron to resolve the failed 9 5~8" Surface Casing cement job. 4 Test Hfs., No Failures, 23 Valves Tested. Attachment: AWOHHFCD.XLS MEMORANDUM state of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Blair Wondzell, ~ P. I. Supervisor FROM: Doug Amos, ~___~ SUBJECT: - Petroleum Inspector DATE: FILE NO: August 6, 1995 awohhfcd.doc BOPE Test Nabors 22E BPX MPU H-05 Kuparuk Rv. Field PTD No. 95-0098 i was contacted by Bobby Foster and informed that the 9 5/8" Surface Casing cement job on BPX MPU H-05 well was unacceptable. Bobby ~elated the following information given to him by Shared Services representative, Steve Scholtz; during the first stage 9 5/8" Surface Casing Shoe cement job (depth 5,335') good returns were received at surface. The hole was then circulated and conditioned for six hours. After the-CC operation, the H-Cementing Collar (depth 4, 300') was opened, this required 2800 psi, the resulting pressure surge fractured the formation and caused lost circulation. Bobby Foster, acting-P.I. Supervisor, was contacted in Anchorage and asked if a LCM pill could be pumped ahead of the second stage cement in an attempt to heal the Lost Circulation Zone. Bobby contacted me and we agreed to this procedure with the understanding that if no returns were received at surface during this operation a Cement Bond Log would be required. ! waS contacted at 11:00 PM. by Jimmy Pylon and informed that the second stage cement job was a failure and asked if a top job could be performed before the CBL was run. Jimmy had talked with the FMC well head representative who advised him, with his current Diverter configuration, the metal to metal seal on the casing hanger could be damaged during the logging operations. He recommended that the Diverter be nippled down, the top job performed, the BOPE Stack nippled up and tested, before running the-CBL, t concurred with this scenario and the top job was performed. Sunday, Au_~ust 6,. 1995: I traveled to BPX MPU H-05 well to witness, the BOPE Test on Nabors Rig 22E. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: DATE: Drig Contractor: NABORS Rig No. 22E PTD # g5-g8 Rig Ph.# Operator: BP Exploration Rep.: Jimmy P. yron Well Name: MPU H-05 Rig Rep.: Lenord Schillard Casing Size: g 5/8" Set @ 5,335 Location: Sec. 34 T. Test: Initial X Weekly Other 8/6/95 659-4446 13N R. 10E Meridian Umiat Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes Well Sign Yes Drl. Rig OK Hazard Sec. Yes FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F I 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve N lA Test Press. P/F 300/3,000 P 5OO/5,00O P 500/5,0OO P 500/5, 000 P 500/5,000 P 500/5,000 P 500/5,000 P CHOKE MANIFOLD: No. Valves 17 No. Flanges 36 Manual Chokes 1 Hydraulic Chokes I Test Pressure P/F 500/5,000 P 500/5,000 Functioned Functioned ACCUMULATOR SYSTEM: N/A N/A System Pressure 3,000 I P Pressure After Closure 1,300 I P MUD SYSTEM: Visual Alarm :200 psi Attained After Closure 0 minutes 22 Trip Tank OK OK System Pressure Attained 2 minutes 58 Pit Level Indicators OK OK Blind Switch Covers: Master: Yes Rem(~{e: Flow Indicator OK OK Nitgn. Btl's: 8 ~ 2,100 Avg. Meth Gas Detector OK OK Psig. H2S Gas Detector OK OK sec. sec. Yes Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I REMARKS: Good test all equipment is in good condition. Distribution: orig-Weli File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: F1-021L (Rev. 12J94) AWOHHFCD.XLS MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission DATE: August 1, 1995 THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor els/~' FROM: John Spauiding, ,~~ SUBJECT: Petroleum Insp. EWOLG3CD.doc Diverter Function Test Nabors 22E BPX / MPU Kuparuk River Field PTD. # 95- 98 Thursday July 27, 1995: I witnessed the Diverter Function Test on Nabors 22E at BPX's MPU well MPF-53, the AOGCC Diverter Function Test report is attached for reference. The 10" diverter vent line is 70' in total length and is bifurcated and tied down to the rig mats with chain and binders. The pad area is quite small and is a challenge to keep people and equipment away from the end of the vent line, a pipe bunk full of pipe is currently being used as a blockade. Summary: ! witnessed the successful diverter function test on Nabors 22E. Attachments: EWOLG3CD.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Operation: Development Yes Exploratory: Drlg Contractor: Nabors Rig No. 27E PTD # 95-108 Rig Ph. # Operator: BPX Oper. Rep.: James Robertson Well Name: MPF-53 Rig Rep.: Brian Buzby Location: Sec. 6 T. 13N R. 10E Merdian Umiat 659-4373 MISC. INSPECTIONS: ACCUMULATOR SYSTEM' Location Gen.: ok Well Sign: ok Systems Pressure: 2800 psig Housekeeping: ok (Gen.) Drlg. Rig: ok Pressure After Closure: 1700 psig Reserve Pit: na Flare Pit: na 200 psi Attained After Closure: ~min' 15 sec. Systems Pressure Attained: min. 57 sec. Nitrogen Bottles: 8 average 2300 DIVERTER SYSTEM INSPECTION: Diverter Size: 20 in. Divert Valve(s) Full Opening: yes Valve(s) Auto & Simultaneous: yes Vent Line(s) Size: 10 in. Vent Line(s) Length: 105 ft. Line(s) Bifurcated: yes Line(s) Down Wind: yes Line(s) Anchored: yes Turns Targeted / Long Radius: yes psig MUD SYSTEM INSPECTION: Light Trip Tank: ok Mud Pits: ok Flow Monitor: ok Alarm ok ok Alarm ok ok GAS DETECTORS: Light Methane ok Hydrogen Sulfide: ok Camp South North Rig 10" Diverter Vent Line Total Length 105' ~Pipe Shed Prevaling Wind Distribution orig. - Well File c - Oper/Rep c- Database c - Trip Rpt File c-Ins~c(~22 AOGCC REP.' OPERATOR REP.: EWQLG3CD.XLS John H. Spaulding James Robertson ALASKA OIL AND GAS CONSERVATION COMMISSION l' TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 26, 1995 Terry Jordan, Drlg. Engineer Supvr. BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Milne Point Unit MPH-05Rev BP Exploration (Alaska), Inc. 95-98 2882'NSL, 4028'WEL, Sec 34, T13N, R10E, UM 1816'NSL, 329'WEL, Sec 01, T12N, R10E, UM Dear Mr Jordan: Enclosed is the approved revised application for permit to drill the above referenced well. dated July 11, 1995, are in effect for this revision. BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA Revision: 07/21/95 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type ofwork Drill[] Redrilll-Illb. TypeofwelI. Exploratoryl-1 Stratigraphic Testr-I DevelopmentOil[] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of .Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. 66 feet Milne Point / Kuparuk River 3. Address 6. Property Designation Sands P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 380109 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 2882' NSL, 4028' WEL, SEC 34, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 2328' NSL, 1053' WEL, SEC 01, T12N, RIOE MPH-05 2S100302630-277 At total depth 9. Approximate spud date Amount 1816'NSL, 329' WEL, SEC 01, T12N, RIOE 07/28/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and mVD) property line ADL 380110 329 feet No Close Approach feet 2560 14116'MD/6942' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 8co feet Maximum hole angle 89 o Maximum su,~ace 2810 psig At total depth (TVD) 6955'/$510 ps,g 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx AS I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 7388' 31' 31' 7419' 4566' 1373 sx PF 'E', 737 sx 'G' 8-1/2" 7" 26# L-80 Btrc 14086' 30' 30' 14116' 6942' 295 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production :.ii.~fi._ ~ ~,- Liner Perforation depth: measured ,~,i.5.'~!~.~ {J~i .& Gas C0,q!~. true vertical : ~J1,1;h0,, 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements• 21. I hereby certify that the f,o~going is true and correct to the best of my knowledge Signed ~/~. ~' '~.~.~.--. TitleDrillin~TEn~ineeringSupervisor Commission Use Only Permit Number IA~t"number Approval date See cover letter 95-98 150-50.029.22572 07-11-95 for other requirements Conditions of approval Samples required [] Yes j~l No Mud Icg required []Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ,~ Yes [] No Required working pressure for DOPE [] 2M; []3M; ~5M; I-I10M; I-'115M; Other: Original Signed By by order of _Approved by David W. Johnston Commissioner tne comm,ssion Date/?/~_~ ~./ Form 10-401 Rev. 12-1-85 Submit 3licate Well Name: I MPH-05 I Well Plan Summary Type of Well (producer or injector): [ Kuparuk Producer I Surface Location: Target Location: Bottom Hole Location: 2882 NSL 4028 WEL Sec 34 T13N R10E UM., AK. 2328 NSL 1053 WEL Sec 01 T12N R10E UM., AK. 1816 NSL 0329 WEL Sec 01 T12N R10E UM., AK. ]AFE Number: [ 330144 Estimated Start Date: [ 7/28/95 [ Rig: [Nabors 22-E Operating days to complete: [ 18 MD: [ 14116' [ [ TVD: Well Design (conventional, slimhole, etc.): 1 6942' bkb I IKBE: I Milne Point Ultra Slimhole 7LS 166' Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1826 1816 NA 5842 4006 Top of Schrader Bluff Sands (8.3 ppg) OB 6632 4286 (8.3 ppg) Seabee Shale 7233 4500 Base of Schrader Bluff Sands (8.3 ppg) HRZ 11492 6011 High Resistivity Zone Top Kup 12717 6446 Kuparuk Cap Rock Top C1 Sand--Target 13168 6606 Target Sand (9.9 ppg) · JUL '~ :-~"~'-' Total Depth 14116 6942 t,.~dta ~il ?~ 'gas f',,nr!~, r:q,-qmJssloll . -- Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD]TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 7388 31/31 7419/456{ 8 1/2" 7" 26# L-80 btrc 14086 30/30 14116/694: Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7000 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3510 psi is 2810 psi, well below the internal yield pressure rating of the 7" casing. ...~- Logging Program: Open Hole Logs: Surface Intermediate Final Cased Hole Logs: MWD Directional and CDR (Gr/Res) N/A 1. PDC Bit f/Seabee to TD w/MWD Dir and LWD (GR/CDR/CDN). GR/CCL will be run in 7" casing to locate the TCP Guns. Ltihology logs will be done from the Seabee Top to TD. Mud Program: Special design considerations I None- SPUD MUD Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.4 100 35 15 30 10 15 Intermediate Mud Properties: N/A Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I None- LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 tO tO tO to tO tO to 10.4 50 15 10 20 9.5 4-6 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 OP: I soo' Maximum Hole Angle: Close Approach Well: 69.21 (No Shut Ins) Disposal: Cuffings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluid Handling: All drilling and completion fluids can be annular injected. Only the MPH-05 well is permitted for annular injection. Inject all fluids at CC-2A until this annulus is available. Request to AOGCC for Annular Pumping Approval for MPH-05: 1. Approval is requested for Annular Pumping into the MPH-05 9-5/8" x 7" casing annulus. 2. Aquifers in the Milne Point Unit have been exempted from Class II injection activities 15y the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 7416' md (4566' tvd) which is below the Schrader Bluff Sands and into the Seabee formation which has a long established history of annular pumping at Milne Point. 4. The burst rating (80%) for the 9-5/8" 40# L80 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Seabee formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping is .calculated according to the following equation and is 2300 psi for a 10.4 ppg fluid in this well. MASP - 4325 psig - ((fluid density ppg - 1.9) X 0.052 X 9-5/8" Casing Shoe TVD AREA WELL PREV VOL PERMITTED PERMITTED ~j=~'r~,'~ (BBLS) (BBLS) Milne Point MPH-05 0 0 Submitted for ' DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. FREEZE PROTECTION: The annulii are kept open by ensuring that an adequate volume (65 bbls) is injected every 6-12 hours which is more enconomical than pumping 65 bbls of diesel freeze protection every time the pumps are shut down. The drillers must communicate to each other the last time the annulus was injected into to avoid freezing. MPH-05 Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. NU and test 20" Diverter system. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan and run and cement 9-5/8" casing. Run only Dir MWD and LWD CDR (Gr/Res). 6. ND 20" Diverter, NU and Test 13-5/8" BOPE. 7. MU a on a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out FE and 10' of new formation -- Perform LOT. 8. Drill 8.5" hole to TD and Run and Cement 7" casing. This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). Freeze Protect Top 2000' of with diesel. 9. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. 10. MIRU Nabors 4ES. NU & Test 13-3/8" BOPE to 5000 psig. 11. RIH while PU 3-1/2" drill pipe and 7" 26# scraper and bit. RIH to PBTD, perform a casing wash while displacing the hole with 10.4 ppg brine. Filter brine water to 2 micron absolute. 12. POOH & PU Drill Pipe Conveyed Perforating Guns. RIH and Set Packer. Perforate the well underbalance. Kill well while circulating 10.4 ppg kill weight brine. 13. POOH laying down 3-1/2" Drill Pipe. 14. Change Rams and run Electric Submersible Pump on 2-7/8" threaded tubing. 15. Install Surface Lines and Wellhouse and put the well on production. Drilling Hazards and Risks: 1. No drilling hazzards or risks have been identified for this weft. MPH-05 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON STAGE I CEMENT JOB ACROSS THE Schrader Bluff Formation: CIRC. TEMP: SPACER: LEAD CEMENT TYPE: 60° F BHST 80° F 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 529 TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 687 FLUID LOSS: 100-150 cc YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 3-4 hrs at 60° F. MIX WATER: 5.0 gal/sk THICKENING TIME: 3-4 hours @ 60° F. FREE WATER: 0cc @ 45 degree angle. STAGE II CEMENT JOB ACROSS Prince Creek to Surface' CIRC. TEMP: 60° F BHST 40° F SPACER: LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 594 TAIL CEMENT TYPE: ADDITIVES: 2% CaCI2 WEIG'RT: 15.8ppg APPROX # SACKS: 50 FLUID LOSS: 100-150 cc 75 bbls fresh water. Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 3-4 hrs at 60° F. Premium G TOP JOB CEMENT TYPE' Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx APPROX NO SACKS: 250 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk THICKENING TIME: 3-4 hours @ 60° F. FREE WATER: 0cc @ 45 degree angle. E MIX WATER: 11.63 gal/sk CENTRALIZER PLACEMENT: I 9-5/8" x 12" Straight '~"-'~" ~I"~ c,..,,,:,~-,~,o,_ ,. ...... ~.,=.., 'h" bottom q--,' j,~i~;~ r,f c~_.~m,, (74 total). This will cover 200' above the Na Sand. 2. Run one 9-5/8" x 12"Straight Blade Rigid Centralizer on each side of ES Cementer (2 Total). 4. Total 9-5/8" x 12"Straight Blade Rigid Centralizers needed is 76. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud progra ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to p, job requirement. Displace at 8-10 bpm. Batch mixing is not necessary, CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 500' md above the Na Sand with 30% excess. 2. Stage 2 cement volume is calculated to cover from the top of Stage 1 to 1500' md with 30% excess and from 1500' md to surface with 100% excess. CIRC. TEMP: SPACER: MPH-05 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON 140° F BHST:170 deg F at 7040' TVDSS. 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. 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: N o ne THICKENING TIME: Greater than 3-4 hrs at 180° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 295 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7-1/8 .... x 8-1/4" Straight Blade Turbulators -- 54 Total (2 per'joint on bottom 27 joints). 2. Run one 7-1/8" x 8-1/4" Straight Blade Centralizer 60' above the 9-5/8" casing shoe. 3. Total 7-1/8 .... x 8-1/4" RH Turbulators needed is 55. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacedmud 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 cement volume is calculated to cover 1000' md above the C1 Sand with 30% excess. hs red er'vices ri!II 'ing TO: FROM: DATE: DAVID W. JOHNSTON, Chairman -- AOGCC Joe Polya, Drilling Engineer--- BPX July 21, 1995 SUBJECT: Changes to the MPH-05 Permit to Drill (Permit # 95-98) Dear Sir: We are requesting to make some changes to the MPH-05 permit to drill which was approved on July 11, 1995. The well has not spudded yet and is expected to spud on Friday July 28, 1995. The bottom h~le location has not changed. The surface location was changed in older to plan three additional wells which were received after the MPH-05 permit request was submitted. Also, the Milne Point Asset requested that the surface casing be set deeper to allow for well to be utilized as a Schrader Bluff Injector or Producer (depending on the presence of hydrocarbons) in the event the Kuparuk target is watered out. The Schrader Bluff contingency well would then be patterned after the single casing string well design approved by AOGCC in the MPE-15 permit # 94-153. Therefore, the surface location, surface casing setting depths, and cement programs been revised. Thank you for your assistance in this matter. If you have any questions please call Tim Schofield at 564-5242. Respectfully, Joe Polya Drilling Engineer-- BPX ..JUL ~4 ~9~5 Oil & Gas Con!;. Commiss:or: Ancho.. ALASKA OIL AND GAS · CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 11, 1995 Adrian Clark, Drilling Engineering Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPH-05 BP Exploration (Alaska), Inc. Permit No 95-98 Surf Loc 2824'NSL, 4044'WEL, Sec. 34, T13N, R10E, UM Btmhole Loc 1867'NSL, 392'WEL, Sec. 01, T12N, R10E, UM Dear Mr Clark: : Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of lhe BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may wilness the test. Notice may be spector 659-3607. · Chairman ~ BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl June 28, 1995 OXY USA, Inc. PO Box 50250 Midland, TX 79710-0250 Mr. Bob Crandall Alaska Oil and Gas Conservation Commission fax 907-276-7542 Subject: Application for Spacing Exception for the Milne Point H-05 Well OXY USA, Inc., an affected party, has no objection to the drilling of the Milne Point H-05 well as proposed in Joe Polya's memo to you dated June 23, 1995. Should you have any questions, please give me a call at 915-685-5673. Respectfully, Ed Behm, Asset Lead RECEIVED . - JUl.. 1 1 1995 Alask~ Oil & Gas Cons. Commission Anchora ~, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill FIIlb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. 67 feet Milne Point./ Kuparuk River 3. Address 6. Property Designation Sands P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 380109 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 ^AC 25.025) - 2824' NSL, 4044' WEL, SEC 34, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 2328' NSL, 1053' WEL, SEC 01, T12N, RIOE MPH-05 2S100302630-277 At total depth 9. Approximate spud d~te Amount 1867' NSL, 392' WEL, SEC 01, T12N, RIOE 07/15/95 $200,000.00 12. Distance to nearest i13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and'rVD) property line ADL 380110 392 feet No CloseApproach feet 2560 13793'MD/6955' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle 6z o Maximum surface 2810 psig At total depth (TVD) 6955'/3510 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 12-1/4" 9-5/8" 40# L-80 Btrc 3319 31' 31' 3350' 2801' 7675x PF'Et 2505x 'G', 250sxPF'E' , 8-1/2" 7" 26# L-80 Btrc 13763' 30' 30' 13793' 6955 583 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductorRECEIVED Surface Intermediate JUN 2 7 ]~,~,~_qo Production Liner Alaska 0ii & 8as Cons. Commission Perforation depth: measured Anchor. true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid prograr~ [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby cert~(,J~C/4t///~/3[oreg~, g is true and correct to the best of my knowledge /2 /~ Signed ~,.,,, ~,¢/,,Jc~.~'P//~ Title Drilling Engineering Supervisor Date ~ ~, .~ I Commission Use Only Permit Number IAPI number IApproval date .. See cover letter ~'~'--- ~:~ 150- O.~Z ~ ~ ~.%'-~.Z._ I '7--"///'"'¢,~..~--~- for other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required []Yes J~ No Hydrogen sulfide measures [] Yes J~ No Directional survey required [] Yes [] No Required working pressure for DOPE F12M; FI3M; FI5M; 1-110M; [-115M; Other: Original Signed By by order of Approved by David W. Johnston Commissioner ~ne commission Date ~"///'-'/~ Form 10-401 Rev. 12-1-85 Submit in triplicate [Well Name: I MPH.05 I Well Plan Summary ] Type of Well (producer or injector): I Kuparuk Producer Surface Location: 2824 NSL 4044 WEL Sec 34 T13N R10E UM., AK. Target Location: 2328 NSL 1053 WEL Sec 01 T12N R10E UM., AK. Bottom Hole Location: 1867 NSL 0392 WEL Sec 01 T12N R10E UM., AK. ]AFE Number: ]330144 I Estimated Start Date: ] 7/15/95 I I Rig: ]N~abors 22-E I Operating days to complete: I 18 IMD: I 13793 I I TVD: 16955' bkb I [KBE: 166' I Well Design (conventional, slimhole, etc.): I Milne Point Ultra Slimhole 7LS Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1822 1805 NA 6072 4005 Top of Schrader Bluff Sands (8.3 ppg) OB 6820 4285 (8.3 ppg) Seabee Shale 8370 4865 Base of Schrader Bluff Sands (8.3 ppg) HRZ 11429 6010 High Resistivity Zone Top Kup 12591 6445 Kuparuk Cap Rock Top C1 Sand--Target 12915 6606 Target Sand (9.7 ppg) Total Depth 13793 6955 Casing/Tubing Program: Hole Size Csg/ WffFt Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.14/ H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 3319 31/31 3350/2801 8 1/2" 7" 26# L-80 btrc 13763 30/30 13793/6955 Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7000 TVDSS. Maximum anticipated surface pressure in this case assuming areservoir pressure of 3510 psi is 2810 psi, well below the internal yi_eld..p~se, u{o~ ! 12 ~[" rating of the 7" casing. Logging Program: Open Hole Logs: Surface MWD Directional Only . Intermediate N/A A~s~,a ..... ,~ r~,'h f:'": " Final 1. Insert Bit to Seabee Top w/w/MWD Dir and LWD (GR/CDR/CDN):.'~ ' 2. PDC Bit f/Seabee to TD w/MWD Dir and LWD (GR/CDR/CDN). Cased Hole Logs: GR/CCL will be run in 7" casing to locate the TCP Guns. Mud Logging will be required from the Seabee Top to TD. Mud Program: Special design considerations ] None- SPUD MUD ] Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel 'Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.4 100 35 15 30 10 - 15 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min f pH Fluid (PP G) Viscosity Point gel gel Loss Production Mud Properties: I None- LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to ., to to , 10.4 50 15 10 20 9.5 4-6 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: IKoP: I5oo' I I Maximum Hole Angle: 1 66.s6° Close Approach Well: (No Shut Ins) Disposal: Cuttings Handling: Central Reserve Pit while the Kuparuk Bridge is out; otherwise CC2A. Fluid Handling: All drilling and completion fluids can be annular injected. Annular Injection- The MPH-05 annulus is permitted for drilling & completion fluid injection. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (aBES) (BBLS) Milne Point MPH-05 0 0 Submitted for 1995 FCFI\/FD JUN 2 7 t995 Alaska Oil & Gas Cons. 6ornmission 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 annulus was injected into to avoid freezing, RECEIVED Alaska Oil & Gas Cons, rt. nmmio~'inn MPH-05 Proposed Summary of Operations 1'. Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. . 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. NU and test 20" Diverter system. Build Spud Mud. 5. Drill a 12-1/4" surface hole and run and cement 9-5/8" casing. Run only Dir MWD (No LWD Required). 6. ND 20" Diverter, NU and Test 13-5/8" BOPE. 7. RIH w/Insert bit on Low Speed/High Torque Motor, and Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). Test 9-5/8" casing to 3000 psig, Drill out float equipment and 10 feet of new formation, Perform a LOT (Do not exceed 12.5 ppg). 8. Drill ahead to the base of the Schrader Bluff (West Sack) into the Seabee Shale, CBU, Wiper Trip to the BHA, POOH. LD the Insert Bit and Motor. Send Schrader Bluff Logs to town -- ASAP. 9. MU a Hughes R417G PDC bit on a turbine, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH. 10. Drill 8.5" hole to TD and Run and Cement 7" casing.~(2 Stage Cement Job to cover the Schrader Bluff). This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). Freeze Protect Top 2000' of with diesel. 1 1. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. 12. MIRU Nabors 4ES. NU & Test 13-3/8" BOPE to 5000 psig. 13. RIH while PU 3-1/2" drill pipe and 7" 26# scraper and bit. Drill out the 7" ES Cementer. RIH to PBTD, perform a casing wash while displacing the hole with 10.4 ppg brine. Filter brine water to 2 micron absolute. 14. POOH & PU Drill Pipe Conveyed Perforating Guns. RIH and Set Packer. Perforate the well underbalance. Kill well while circulating 10.4 ppg kill weight brine. 15. POOH laying down 3-1/2" Drill Pipe. 16. Change Rams and run Electric Submersible Pump on 2-7/8" threaded tubing. 17. Install Surface Lines and Wellhouse and put the well on production. Drilling Hazards and Risks: 1. No drilling hazzards or risks have been identified for this well RECEIVED JUy! 2 7 Ala, ska Oil & Gas Cons. Commission MPH-05 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE' 9-5/8" SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 767 CIRC. TEMP 50 deg F at 2500' TVDSS. YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: ADDITIVES: 2.0% CaCI2 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc Premium G YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE' Permafrost E ADDITIVES: Retarder YIELD:2.17 ft3/sx WEIGHT: 12.0 ppg APPROX NO SACKS: 250 RECEIVED Ab. ska Oil ° ~ Gas Cons. 6.'om. mission .,'!,h,.;i~u,": , MIX WATER: 11.63 gal/sk CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing required). 2. Place all centralizers in middle of joints using stop collars. (15 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 calculated to cover 500' md above the 9-5/8" Casing Shoe 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. MPH-05 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140© F BHST 170 deg F at 7040' TVDSS. SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. '~ CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 238 FLUID LOSS: < 50cc/30 min @ 140° F MIX WATER: 5.0 gal/sk THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. STAGE II CEMENT JOB ACROSS THE SCHRADER BLUFF SANDS: CIRC. TEMP: SPACER: 60© F BHST 80 deg F at 7040' TVDSS. 20bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: NONE Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 345 FLUID LOSS: 100-150 cc MIX WATER: 5.0 gal/sk THICKENING TIME: 4 hours @ 50 FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 17 joints of 7" Casing (36 total). This will cover 200' above the C Sand. 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 6550' - 5700' to cover the Schrader Bluffs Sands (25 Total). 3. Run one 7"x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7" x 8-1/4"Straight Blade Rigid Centralizers needed is 62. , - OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacedmud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate_ relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 1000' md above'~he C Sand with 30% excess. 2. Stage 2 cement volume is calculated to cover from the OG base to the to 1000' above the NA. Top with 30% excess. RECEIVED,,.; ii i_ _ ii · . SHA'RED' SERICES .DRILLING i I I · iii i I IIII i iii i i i ~ ~.,,,~.~o~. ~ ,, s~c~ ~, MPH-05 (P41 ,i ~,~u~[,u~oo ~oo .soo , o.oo VERTICAL SECTION VIE~ O] BUILD 3/tO0 1500 ~49t ~og t5.O0 section at: ~24.B9 E! END 3/t00 BUILD 3EIg 2749 ~1194 B6.56 Ft TARGET 1~9~§ 'G606 10090 F~.~' TVD Scale · I ~nch = ~600 feet G) ID :13793 6955 t0896 66.56 Oep Scale.' I inch = ~§00 leet · · i' i · i i ii ii 0 .-.. t)(X) IGOO 2400 3EO~ 4000 4800 ~OO .5400 7~.00 BO00 Bl~. gl(K) 11)400 I~,L:~)O 12(M)I) t2800 . 13600 ' Section Oep~rture m I '" SHARED SERICES ORILLIN$ ~na~ri]] sc~u~r~r I ~ ~ ....... i · i iii i i--iiii i i ii i i i iii i i i i i · ii i · ~iiii ~ i i __ MPH-05 (P4) PLAN VIEW ~RE .... · 10896 feet at Azimuth ~4.89 9 BO0 ~ ' : I,NATION.: 2I].870 E ,L ' ~ inch: ~200 feet ' -, ' : ,.......: 06/23~95 ~ · ~ F Id~t ification ~ ~S E/~ " 0 0 0 ~, VBUILD l/tO0 5~ 0 0 iD 3/100 t5~ ~ Bg 1200 i , 100 ~ILO 3219 ~ 979 t~gt5 5~ ~76 ; ~ ~ 137~ ~ .~37 I~0 ; ~oo I , F~;IBIL ~~P~Iq., ~ ', ~ ~ lOT, ~PPi[OVED. F( )R J '" ' EKEC ~I'ON ~' , . ~ PL,~N ....... ~ ..... ~ .... , ' ~" ' '~. ~ ~/~ .... ~ ~ ~ ! .. ,- x~:. ~. · ~. ..... ~ · . ~,, ......... ~ " , , i I~ ~ ...j, .. ~.- : ~ , .. · . J . . . , '~'?" ~" '" / I : " fi~ ..... ~ .... ~ ~- . ~0 'O ~ I~ teD0 2~ ~00 ~ 4~ ~. ~ ~0 ~ ~ ~ ~ ~ ~ 102~ <- ~F' .E~ -) ~11 ~ ~ l,~ ~'~ ~ I) · . BP EXPLORATION To,· From: Date: Subject: Bob Crandall, AOGCC f Joe Polya, BP (Shared Services Drilling) June 23, 1995 Application for Spacing Exception for the Milne Point H-05 Well (20 AAC 25.055) The MPH-05 well is planned to drill into the Kuparuk River formation in the South East Quarter of Section T12N and R10E. This section is located to the South of the Milne Point Unit Boundary. This quarter section is bounded on the North, NorthWest, West, Southwest, and South by quarter sections within ADL 380109 for which the operators are BPX 91.19 and Oxy USA 8.81. This quarter section is bounded on the Northeast, East, and Southeast by quarter sections within ADL 380110 for which the operators are BPX 91.19 and Oxy USA 8.81. See the Attached Map. The MPH-05 well is planned as a high angle producer to be completed with an electric submersible pump. Entry-Point in the Kuparuk formation (C1 Sand) is 2328' FSL and 1053' FEL in Section 01, T12N, R10E and TD at 1867' FSL and 0392' FEL Section 01, T12N, R10E. We have notified all owners and operators via registered mail as per the AOGCC Regulation 20 AAC 25.055 -- See Attached Plats and Registered Mail Notice. Thank you for your assistance in this matter. Please direct any questions to Mark Bendersky at 564-4666. Respectfully, Joe Polya c c: BPX Oxy USA RECEIVED Z ~8t q44~ 131 Receipt for Certified Mail No insurance Coverage Provided Do not use for International Mail (See Reverse) E.O., S~ate and WP Code - Special Delivery Fee Restricted Delive~ ~e , Return Receipt Showing to Whom & Date Delivered Return Receipt Showing lo Whom, Date, and Addressee's Address TOTAL Postage ' · / &Fees /~ Postmark or Date /~/ RECEIVED JUN 2'? i995 Alaska Oil & Gas g0ns. co:mmJssi0n MPU Boundary Section 2 .... ~ection 11 KRU Boundary PBU Boundary 380110 15?X 9l.~ 9 OXY ~x$~ 8.~1 Section 5 Section 8 I I I Tract Development Drilling Block Proposal Tract Wells H-05, H-06, E-24i Mile' 14 June 1995 "1 BSMc ........,SHA'RED' SERICES ,DRILLING '1 "_ I i i i ! i i ii iiii i ii i I I I I ii i ii i ± i i II i i '~ ~ o o oo.o0 , , ,~ ~/~u~ ~/,- ~ ,s~o.o.~ 'VERTICAL SECTION VIE~ i _ O) BUILD 3/100 i~ ~49~ ~09 ~5.~ SeCtion at: 124.89 El ~ 3/~00 ~ILD 3~t9 2749 ~194 ~.~ Fl TA~T 129[5 '66~ 10090 ~.~' T~ Scale' I inch = 1600 feet G) I0 13793 8~5 ~0898 ~.~ Oep Scale ' t inch = t600 leer Oeam .... ' 06/~3/95 , i i' i i i i il ! SHARE~) SE.R'~'C'ES 'O ........... ' ................. - RILLING ~~]] sc~]~e~~ ! 111 I Il I I Il It nil II I I I Ill I [II I II I I ll_ I Il ~ I I n [[1[] [ I [ [[ I I [ ] [[[ [ [[ [iii [ [[I [ I [[ I [ III MPH-05 (P41 4~~., PLAN 'VIEW ii i Boo ............... E .... · lOB96,feet at Azimuth ~24.B9 , : i.NATION.: 28.870 E L ': ...... ~- inch = ~200 feet ~ ~ ,.,, ............ :.-- ,, " , · , .,~ ............ ~ Idmtif~cation ~ ~S E/~ , 0 0 O ~200~- ,, , ~ "- · ~D 3/~00 ' 15~ ~ BB '~ ~100 ~ILO 32i9 ~ 979 i2915 5~ . ~76 ; ~ ..... ~ 137~ ~ ,~37 1~0~..... '~4~ " ...... .. ~ . PL,~N. 42~-- '~ ; ..... -· ~ ...... ' ..... '~ - .... . ~ ~'-~ ~ e ; '~0 ' ? .... ; .... ~ '" ~ - ~ ..... ~ , I ..... :~. .., ~ ~ ~ .~_ :'......~ :.; ':,.,~f'. ~ . . . :'2 . . ~ ' ' } · -. · . ;~:~.:, ~..:.:' [ { -' , , ,.. ~D 'O '- ~ !~ t800 2~ ~00 ~ 4~ ~, ~ ~0 ~ ~ ~ ~ ~ ~. t0~' U~'~ m '"'. ................ ' ' WELL PERMIT CHECKLIST F, .LD , UNIT# PROGRAM= exp [] dev~ redrll [] ?/[./, ~ , ON/OFF SHORE serv [] ADMINISTRATION ENGINEERING 2. Lease number appropriate ................ ' 3. Unique well name and number ............... 4. Well located in a defined pool .............. 5. Well located proper distance from drlg unit bounda~. 6. Well located proper distance from other wells ..... ' 7. Sufficient acreage available in drilling unit ...... 8. If deviated, is wellbore plat included ......... 9. Operator only affected party ............... 10. Operator has appropriate bond in force .......... 11. Pe~it can be issued without conse~ation order ..... 12. Pe~it can be issued without administrative approval. 13. Can pe.~it be approved before 15-day wait ....... APPR D~~ GEOLOGY 14. Conductor string provided ............... Y~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg.. N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N ~9. 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 ........... Y N 24. Drilling fluid program schematic & equip list adequate . ~ N 25. BOPEs adequate ............ ~ ........ ~ N 26. BOPE press rating adequate; test to F~O~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdow~ ....... ~ N 29. Is presence of H2S gas probable ............ ~ N 30. Permit can be issued w/o hydrogen sulfide measures .... Y ___ 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysts of shallow gas zones ......... 33. Seabed condition survey (if off-shore) ....... /. Y N ' - ' ' 34. Contact name/phone for weekly progress reports . ./.. Y N [exploratory only] GEOL~_Y: ENGINEERING: COMMISSION: Cumments/Instructions: A:%FORMS%cheldist rev 03/94 PERMIT CHECKLIST ~S~,R~,6, .............. PROGRAM: exp [] dev~ redrll [] aery [] ,/~/- ~, ON/OFF S~ORE ~ ~ APPR DATE GEOLOGY 1. 2. 3. 4. 5. 6. · 8. 9. 10. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Lease number appropriate ............... Unique well name and number ............... Well located in a defi ed pool ............. Well located proper distance from drlg unit boundary. Well located proper distance from ~ther wells ...... Sufficient acreage available in drilling unit ...... If deviated, is wellbore plat included ........ Operator only affected party ............... Operator has appropriate bond in force ......... Permit. can be issued without conservation order ..... Permit can be issued without admi~istrative approval. Can permit be approved before 15-day wait ........ ........................... onductor string provided ................. Surface casing protects all known USDW, ........ CMT vol adequate to circulate on conductor & surf =ag. CMT vol adequate to tie-in long string to surf csg. CMT Will cover all known productive horizons ...... Adequate tankage or reserve pit ............. If a re-drill, has a 10-403 for abndnmnt been approved. ~ Adequate wellbore separation proposed .......... ~ N If diverter required, is it adequate .......... ~ N Drilling fluid program schematic & equip list adequate .~ N BOPEs adequate ..................... ~ N BOPE press rating adequate; ~est to ~O OO psig. Y N Choke manifold complies w/API P~:-53 (May 84) ...... ~ N Work will occur without operation shutdown ....... ~ N Is presence of H2S gas probable ............. Y ~ 30. 31. 32. 33. 34. Permit can be issued w/o hydrogen sulfide measures .... Y N/ Data presented on potential overpressure zones ..... Y /4~ Seismic analysis of shallow gas zones .......... Y// N Seabed condition survey (if off-shore) ........ /Y N Contac~ name/phone for weekly progress reports . . . ./. Y N [ explorator~ only] GEOLOG~: ENGINEERING: COMMISSION: DWJ~ TAB Comments/Instructions: A:~ORMS%cheklist mq 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. MPH - 05 MILNE POINT ~D Gas C~s, Commission Run 1' 20 - August - 1995 Marked Line GR Cased Hole 11687 3357 WESTERN ATLAS Logging Ser~,ices Tape Subfile 2 is type LIS TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: 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 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING MPH - 05 500292257200 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 30-AUG-95 6469.01 K. RICHARDS D. MOUNTJOY 34 13N 10E 2824 4044 66.00 66.00 36.10 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 5335.0 47.00 7.000 14108.0 26.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ REMAR/{S: Marked Line GR. GR GRCH 1 1 20-AUG-95 WESTERN ATLAS LOGGING SERVICES EQUIVALENT UNSHIFTED DEPTH *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** TIE-IN PASS WAS NOT DEPTH SHIFTED SINCE THIS PASS IS THE DEPTH REFERENCE FOR THIS WELL. LOG WAS RUN WITH MARKED LINE FOR PRIMARY DEPTH CONTROL. FINAL DATA WAS SHIFTED DOWN 10 FEET TO TAKE OUT THE SHIFT APPLIED IN THE FIELD. FIELD DA WAS RESET UP 10 FEET TO COMPANY REPRESENTATIVE'S REQUEST TO MWD LOG AT DID NOT LOG REPEAT AT COMAPNAY REPRESENTATIVE'S REQUEST. LOG RUN THRU DRILL PIPE TO SPOT TCP GUNS. RECORDED COLLARS ARE DRILL PIPE COLLARS & CCL CURVE IS THERFORE NOT INCLUDED IN THIS FINAL OUTPUT. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 11687.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: i STOP DEPTH 13357.0 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: TIE-IN PASS. THE GAMMA RAY FROM THIS PASS IS THE DEPTH REFERENCE FOR THIS WELL. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPH - 05 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 4 4 30 310 01 1 * DATA RECORD (TYPE# 0) 1022 BYTES * Total Data Records: 27 Tape File Start Depth = 13370.000000 Tape File End Depth = 11670.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6803 datums Tape Subfile: 2 129 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11687.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 13357.0 20-AUG- 95 FSYS J1V2.0 UPDATE1 500 21-AUG- 95 14017.0 13361.0 11687.0 13357.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR SBAR SINKER BAR PCM PCM/CCL GR GAMMA RAY $ TOOL NUMBER 8250EA/8248EA 8220XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER' S CASING DEPTH (FT): .O00 14108.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SODIUM BROMIDE .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): .0 BASE NORMALIZ~ '- WINDOW (FT) : .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 0 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): .0 TIE-IN PASS. REPORTED LOG DEPTHS HAVE BEEN SHIFTED DOWN 10' FROM WHAT IS REPORTED ON BLUELINE. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPH - 05 : MILNE POINT/KUPARUK : NORTH SLOPE ·· ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 SPD GR 68 3 TEN GR 68 1 GAPI 4 1 F/MN 4 1 LB 4 4 30 310 01 1 4 30 636 99 1 4 30 635 99 1 12 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 108 Tape File Start Depth = 13370.000000 Tape File End Depth = 11670.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 27205 datums Tape Subfile: 3 184 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS 95/ 8/30 01 **** REEL TRAILER **** 95/ 8/31 01 Tape Subfile: 4 2 records..'. Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 31 AUG 95 ll:01a Elapsed execution time = 1.10 seconds. SYSTEM RETURN CODE = 0 ALASKA COMPUTING CENTER * COMPANY NAME : B.P. EXPLORATION WELL NAME : MPH-O5 FIELD NAME : MILNE POINT BOROUGH :NORTH SLOPE STATE : ALASKA APl NUMBER : 50-029-22572-0~ REFERENCE NO : 95300 RECEIVED ..LIS Ta~e Verification Listing Schlumberger Alaska Computing Center 22-NOV-1995 13:18 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 95/11/22 ORIGIN : FLIC REEL NAME : 95300 CONTINUATION ~ : PREVIOUS REEL : COMMENT : BP EXPLORATION, MILNE POINt MPH-05, API# 50-029-22572-00 **** TAPE HEADER *=.. SERVICE NAME : EDIT DATE : 95/11/22 ORIGIN : FLIC TAPE NAME : 95500 CONTINUATION ~ : ~ PREVIOUS TAPE : COMMENT : BP EXPLORATION, MILNE POINT MPH-05, API# 50-029-22572-90 TAPE HEADER MILNE POINT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MPH-95 599292257209 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES 22-NOV-g5 BIT RUN 1 BIT RUN 2 BIT RUN 3 JOB NUMBER: 95399 95399 LOGGING ENGINEER: DENNETT ST. AMOUR OPERATOR WITNESS: PYRON LUTRICK SURFACE LOCATION SECTION: 34 TOWNSHIP: ~3N RANGE: ~gE FNL: FSL: 2882 FEL: 4928 FWL: ELEVATZON(FT FROM MSL 9) KELLY BUSHING: 66.99 DERRICK FLOOR: 66.99 GROUND LEVEL: 36.10 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 29.909 2ND STRING 8.599 9.625 5335.9 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-NOV-~g95 ~3:~8 3RD STRING PRODUCTION STRING REMARKS: Well drilled 02-AUG through 16-AUG-95 with CDR and CDN. All data was collected in two bit runs, with MAD data on Bit Run #2. The CDN was run only on Bit Run #2 drill section. $ $ **** FILE HEADER ~*** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : ~01C9! DATE : 95/~1/22 MAX REC SIZE : ~924 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: ~ EDITED MERGED MWD/MAD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 9.5990 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD/MAD 14~30.9 3790.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MWD 88888.9 8899~.9 13334.5 13347.5 ~3253.5 ~3265.5 13193.5 132~4.5 ~3~85.0 13~88.9 131~4.5 ~3~25.~ ~3075.5 13986.9 13955.9 ~3964.9 ~3927.9 13937.0 ~2969.5 12970.5 ~2949.0 ~2959,5 ~2932,9 ~2942,9 ~2899,5 12998,5 ~2878.~ ~2889,5 ~2839,5 ~2849,0 ~2766.9 ~2776,5 ~274.9,5 12758,5 .LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-NOV-1995 13:18 12711.0 12720.0 12692.0 12700.0 12557.0 12565.5 12462.5 12472.0 12414.5 12425,9 12383.5 12394.9 12320,5 12331.5 12111.5 12129.9 118~$.S 11875.9 11818.9 1182S.$ 11742.S 11749.S ll?I$.S ll?21.S 8545.9 8553.9 $ MERGED DATA SOURCE LDWG TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE MWD 2 8454.9 14139.9 MAD 2 5555.9 7349.9 MWD 1 3799.9 5399.9 $ REMARKS: The depth adjustments shown above reflect the MWD OR to the GR logged by SWS for Bi~ Run ~2 drilled da~a only. All o~her MWD curves for Bit Run #2 drilled data were carried with the GR. This file also contains the Very Enhanced ~RO resisitivity with 2~ average that was reprocessed at Geoquest for all files. LIS FORMAT DATA PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT .LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-NOV-1995 13:18 PAge: TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 0 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOg TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630156 00 000 00 0 1 I 1 4 68 0000000000 RA MWD OHMM 630156 00 000 ~0 0 1 1 I 4 68 0000000000 RP MWD OHMM 630156 00 00~ 00 0 1 1 I 4 68 ~00~00000 VRA MWD OHMM 630156 00 000 00 0 I I I 4 68 0000~00000 VRP MWD OHMM 630156 00 000 ~0 0 I I I 4 68 0000000000 DER MWD OHMM 630156 00 000 00 0 I I I 4 68 0000000000 ROP MWD FPHR 630156 00 000 ~0 0 1 I I 4 68 0000~00~00 FET MWD HR 630156 00 000 00 0 1 1 1 4 68 0000000000 GR MWD GAPI 630156 00 000 00 0 I I 1 4 68 0000000000 RHOB MWD G/C3 630156 00 000 00 0 1 I 1 4 68 ~000000000 DRHO MWD G/C3 630156 00 ~00 00 0 1 1 I 4 68 0000000000 PEF MWD BN/E 630156 ~0 000 00 0 1 1 I 4 68 0000~00~00 CALN MWD IN 630156 00 0~0 ~0 0 1 1 I 4 68 0000000000 NPHI MWD PU-S 630156 00 000 00 0 1 1 1 4 68 0000~00000 GRCH GRCH GAPI 630156 00 000 00 0 1 I I 4 68 0000~00000 ** DATA ** DEPT. 14142.500 RA,MWD -999.250 RP,MWD -999.250 VRA,MWD VRP,MWD -999.250 DER,MWD -999,250 ROP.MWD 92,097 FET,MWD gR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD -999.250 gRCH.gRCH -999.250 DEPT, 1400~.000 RA.MWD 3,437 RP,MWD 3,720 VRA.MWD VRP.MWD 3.909 DER.MWD 3.613 ROP.MWD 104.504 FET.MWD GR.MWD 63.697 RHOB.MWD 2.391 DRHO.MWD 0.023 PEF.MWD CALN.MWD 8.774 NPHI.MWD 28.500 gRCH.GRCH -999.250 DEPT, 13500,000 RA.MWD 38.315 RP.MWD 29,322 VRA.MWl) VRP,MWD 25.232 DER,MWD 31,543 ROP.MWD 32,848 FET,MWD GR.MWD 52.061 RHOB.MM) 2.349 DRHO.MWD 0.071 PEF.MWD CALN.MWD 8.851 NPHI,MWD 26.400 gRCH.GRCH -999.250 DEPT. 13000.000 RA.MWD 2.047 RP.MWD 3.443 VRA.MWD VRP.MWD 3.382 DER.MWD 2.579 ROP.MWD 58.098 FET.MWD gR.MWD 131.913 RHOB.MWD 2.453 DRHO.MWD 0.025 PEF.MWD CALN.MWD 8.916 NPHI.MWD 39.300 GRCH.GRCH 57.849 -999.250 -999.250 -999.250 3.777 0.737 3,380 28.119 1,489 3.833 .036 068 .690 .LIS Ta~e Verification Listing Schlumberger Alaska Computing Center DEPT. z2590.eee RA.MWD VRP.MWD 5.299 DER.MWD GR.MWD 147.669 RHOB.MWD CALN.MWD 9.993 NPHZ.MWD DEPT. 12999.999 RA.MWD VRP.MWD 9.686 DER.MWD GR.MWD 129.825 RHOB.MWD CALN.MWD 8.898 NPHZ.MWD DEPT. 11599.999 RA.MWD VRP.MWD 4.841 DER.MWD GR.MWD 126.389 RHOB.MWD CALN.MWD 9.461 NPHZ.MWD 22-NOV-1995 13:18 3.527 RP.MWD 5.415 4.946 ROP.MWD 114.344 2.447 DRHO.MWD 0.944 39.761 GRCH.GRCH 71.663 5.922 RP.MWD 11.564 8.317 ROP.MWD 143.156 2.453 DRHO.MWD 0.918 34.993 GRCH.GRCH 36.372 3.243 RP.MWD 4.497 3.879 ROP.MWD 199.564 2.494 DRHO.MWD 0.949 35.699 GRCH.GRCH -999.259 DEPT. 1~999.999 RA.MWD 3.193 RP.MWD 16.567 VRP.MWD 591.854 DER.MWD 4.438 ROP.MWD 46.929 GR.MWD 91.956 RHOB.MWD 2.473 DRHO.MWD 9.921 CALN.MWD 8.964 NPH~.MWD 26.199 GRCH.GRCH -999.259 DEPT. 19599.999 RA.MWD VRP.MWD 2.736 DER.MWD GR.MWD 85.223 RHOB.MWD CALN.MWD 8.992 NPH~.MWD DEPT. 19999.999 RA.MWD VRP.MWD 4.321 DER.MWD GR.MWD 114.194 RHOB.MWD CALN.MWD 9.966 NPHI.MWD DEPT. 9599.999 RA.MWD VRP.MWD 3.112 DER.MWD GR.MWD 99.182 RHOB.MWD CALN.MWD 8.971 NPHZ.MWD DEPT. 9999.999 RA,MWD VRP.MWD 3.438 DER.MWD GR.MWD 96.552 RHOB.MWD CALN.MWD 8.592 NPHZ.MWD 2.633 RP.MWD 2.715 ROP.MWD 2.436 DRHO.MWD 39.790 GRCH.GRCH 2.766 75.988 0.915 -999.259 3.696 RP.MWD 4.145 3.972 ROP.MWD 124.531 2.433 DRHO.MWD 9.937 36.299 GRCH.GRCH -999.259 2.841 RP.MWD 3.916 ROP.MWD 2.422 DRHO.MWD 34.299 GRCH.GRCH 3.352 RP.MWD 3.439 ROP.MWD 2.393 DRHO.MWD 35.699 GRCH,GRCH 3.133 114.356 9.921 -999.259 3.473 313.929 9.947 -999.259 DEPT. 8599.990 RA.MWD -999.250 RP.MWD -999.259 VRP.MWD -999.259 DER.MWD -999.250 ROP.MWD -999.259 GR.MWD -999.250 RHOB.MWD -999.25~ DRHO.MWD -999.259 CALN.MWD -999.25e NPHZ.MWD -999.250 GRCH.GRCH -999.259 DEPT. 8909.00e RA.MWD -999.250 RP.MWD VRP.MWD -999.25~ DER.MWD -999.250 ROP.MWD GR.MWD -999.259 RHOB.MWD -999.25e DRHO.MWD CALN.MWD -999.259 NPHI.MWD -999.25~ GRCH.GRCH -999.25~ RP.MWD -999.250 ROP.MWD -999.250 DRHO.MWD -999.250 GRCH.GRCH DEPT. 7509.999 RA.MWD VRP.MWD -999.259 DER.MWD GR.MWD -999.259 RHOB.MWD CALN.MWD -999.250 NPHZ.MWD -999.259 -999.259 -999.259 -999.250 -999.250 -999.259 -999.259 -999.259 VRA. MWD FET. MWD PEF. MWD VRA.MWD FET.MWD PEF.MWD VRA.MWD FET.MWD PEF.MWD VRA.MWD FET.MWD PEF.MWD VRA.MWD FET.MWD PEF.MWD VRA.MWD FET.MWD PEF.MWD VRA.MWD FET.MWD PEF.MWD VRA. MWD FET. MWD PEF. MWD VRA.MWD FET.MWD PEF.MWD VRA.MWD FET.MWD PEF.MWD VRA. MWD FET. MWD PEF. MWD PAGE: 3. 484 2. 966 4.361 5.559 9.498 3.826 3.435 9.483 3.693 4.641 1.199 3.855 2.674 9.861 3.175 3.917 0.339 3.290 2. 993 9.617 3.428 3.279 9.388 3.351 -999.259 -999.259 -999.250 -999.259 -999.259 -999.259 -999.250 -999.259 -999.250 .LIS Ta.pe Verification Listing Schlumberger Alaska Computing Center 22-NOV-1995 13:18 PAGE: DEPT. 7000.000 RA.MWD 4.449 RP.MWD 4.096 VRP.MWD 4.072 DER.MWD 4.198 ROP.MWD 494.970 GR.MWD 81.785 RHOB.MWD -999.250 DRHO.MWD -999.250 CALN.MWD -999.250 NPHI.MWD -999.250 GRCH.GRCH -999.250 DEPT. 650e.000 RA.MWD 4.845 RP.MWD 4.352 VRP.MWD 4.153 DER.MWD 4.487 ROP.MWD 732.~42 GR.MWD 93.616 RHOB.MWD -999.250 DRHO.MWD -999.250 CALN.MWD -999.250 NPHI.MWD -999.250 GRCH.GRCH -999.250 DEPT. 600e.0~0 RA.MWD VRP.MWD 6.6~4 DER.MWD GR.MWD 64.842 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 5500.000 RA.MWD VRP.MWD -999.250 DER.MWD GR.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 500e.000 RA.MWD VRP.MWD 4.256 DER.MWD GR.MWD 65.425 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 4500.e00 RA.MWD VRP.MWD 6.087 DER.MWD GR.MWD 81.220 RHOB.MWD CALN.MWD -999.250 NPHI,MWD DEPT. 4000.000 RA.MWD VRP.MWD 6.054 DER.MWD GR.MWD 102.718 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 3700.000 RA.MWD VRP.MWD -999.250 DER.MWD GR.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD 8.198 RP.MWD 7.739 ROP.MWD -999.250 DRHO.MWD -999.250 GRCH.GRCH -999.250 RP.MWD -999.250 ROP.MWD -999.250 DRHO.MWD -999.250 GRCH.GRCH 5.37e RP.MWD -999.250 ROP.MWD -999.250 DRHO.MWD -999.250 GRCH.GRCH 7.110 RP.MWD -999.25e ROP.MWD -999.250 DRHO.MWD -999.250 GRCH.GRCH 6.630 RP.MWD -999.250 ROP.MWD -999.250 DRHO.MWD -999.250 GrCH.GRCH -999.250 RP.MWD -999.250 ROP.MWD -999.250 DRHO.MWD -999.250 GRCH.GRCH 7.571 840.034 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.660 142.000 -999.250 -999.250 6.030 289.10e -999.250 -999.250 5.97~ 185.300 -999.250 -999.250 -999.250 397.000 -999.250-999.250 VRA.MWD FET.MWD PEF.MWD VRA.MWD FET.MWD PEF.MWD VRA.MWD FET.MWD PEF.MWD VRA.MWD FET.MWD PEF.MWD VRA.MWD FET.MWD PEF.MWD VRA.MWD FET.MWD PEF.MWD VRA.MWD FET.MWD PEF.MWD VRA.MWD FET.MWD PEF.MWD 4.395 -999.250 -999.250 4.486 -999.250 -999.250 6.859 -999.250 -999.250 -999.250 -999.250 -999.250 4.708 -999.250 -999.250 6.893 -999.250 -999.250 6.979 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .0~1 SERVICE : FLIC VERSION : OOlCO1 DATE : 95/11/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : .LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE HEADER .~** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 22-NOV-1995 13:18 PAGE: FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MAD $ MERGED DATA SOURCE LDWG TOOL CODE 7349.0 5555.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE $ REMARKS: This MAD data was acquired on BIT Run 42 during a wash up pass. There was no data acquired between this MAD pass and the Bit Run 42 drill data. $ LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 .LIS Ta. pe Verification Listing Schlumberger Alaska Comput|ng Center 22-NOV-1995 13:18 PAGE: tYPE REPR CODE VALUE 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 ** SET TYPE - CHAN ** NAME SERV ID UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) DEPT RA RP VRA VRP DER ROP FET MAD MAD MAD MAD MAD MAD MAD FT 639156 99 999 99 9 2 I I 4 68 OHMM 639156 99 999 99 9 2 I 1 4 68 OHMM 639156 99 999 99 9 2 1 1 4 68 OHMM 639156 99 999 99 9 2 I I 4 68 OHMM 639156 99 999 99 9 2 I 1 4 68 OHMM 639156 99 999 99 9 2 1 1 4 68 FPHR 639156 99 999 99 9 2 I 1 4 68 HR 639156 99 999 99 9 2 1 1 4 68 ** DATA DEPT. VRP,MAD DEPT. VRP,MAD DEPT. VRP.MAD DEPT. VRP.MAD DEPT. VRP.MAD 7359.999 332.681 7999.999 4.972 6599.999 4.153 6999.999 6.694 5555.999 -999.250 RA. DER. RA. DER, RA DER RA DER RA DER MAD MAD MAD MAD . MAD . MAD . MAD . MAD . MAD . MAD -999.259 -999.250 4.449 4.198 4.845 4.487 8.198 7.739 -999.259 -999.25~ RP.MAD ROP.MAD RP.MAD ROP.MAD RP.MAD ROP.MAD RP.MAD ROP.MAD RP.MAD ROP.MAD -999.259 2519.977 4.996 494.979 4.352 732.942 7.571 849. 934 -999.259 -999.25~ VRA.MAD FET.MAD VRA.MAD FET.MAD VRA.MAD FET.MAD VRA.MAD FET.MAD VRA.MAD FET.MAD 331.398 -999.259 4.395 81.785 4.486 93.616 6.859 64.842 -999.259 25.269 ** END OF DATA ,LIS Ta.pe Verification Listing Schlumberger Alaska Computing Center **** FILE TRAILER ***= FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/22 MAX REC SIZE : i024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : ~0~C01 DATE : 95/1~/22 MAX REC SIZE : ~024 FILE TYPE : LO LAST FILE : 22-NOV-1995 i3:i8 PAGE: FILE HEADER FILE NUMBER: 3 EDITED MAD PASS Clipped curves; for each pass of each run in separate files. MAD RUN NUMBER: 2 MAD Pass NUMBER: DEPTH INCREMENT: FILE SUMMARY LDWQ TOOL CODE START DEPTH STOP DEPTH MAD 7349.0 5555.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MAD $ REMARKS: This MAD data was acquired on BIT Run #2 during a wash up pass. There was no data acquired between this MAD pass and the Bit Run ~2 drill data. $ LIS FORMAT DATA ,LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-NOV-1995 13:18 ** DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 SET TYPE - CHAN ** PAGE: 10 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630156 00 000 00 0 3 1 1 4 68 000~00000 RA MAD OHMM 630156 00 00~ 00 0 3 1 1 4 68 ~00000000~ RP MAD OHMM 630156 00 000 ~0 0 3 1 1 4 68 00~0000000 VRA MAD OHMM 630156 00 000 00 0 3 1 1 4 68 000~000 VRP MAD OHMM 630156 00 000 00 0 3 1 1 4 68 ~0~0000000 DER MAD OHMM 630156 00 0~0 00 0 3 1 1 4 68 00000~0000 ROP MAD FPHR 63~156 00 000 00 0 3 1 ~ 4 68 0000000000 FET MAD HR 630156 00 000 ~0 0 3 1 1 4 68 0000000000 ** DATA DEPT. 735~,000 RA.MAD -999.250 RP.MAD -999.25~ VRA.MAD VRP.MAD 332.681 DER.MAD -999.250 ROP.MAD 2519.077 FET.MAD DEPT. 7000.000 RA.MAD 4.449 RP.MAD 4.096 VRA.MAD VRP.MAD 4.072 DER.MAD 4.198 ROP.MAD 494.970 FET.MAD DEPT. 6500.0~0 RA.MAD 4.845 RP.MAD 4.352 VRA.MAD VRP.MAD 4.153 DER.MAD 4.487 ROP.MAD 732.042 FET.MAD DEPT. 60~¢.000 RA.MAD 8.198 RP.MAD 7.571 VRA.MAD VRP.MAD 6.6¢4 DER.MAD 7.739 ROP.MAD 840.034 FET.MAD 331.308 -999.250 4.395 81.785 4.486 93.616 6.859 64.842 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-NOV-~995 13:18 PAGE: DEPT. 5555.000 RA.MAD -999.250 RP.MAD VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD ** END OF DATA ** -999.250 VRA.MAD -999.250 FET.MAD -999.250 25,269 **** FILE TRAILER **** FILE NAME : EDIT .093 SERVICE : FLIC VERSION : 991C91 DATE : 95/11/22 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .994 SERVICE : FLIC VERSION : 991C91 DATE : 95/11/22 MAX RE¢ SIZE : 1924 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: 9.5999 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 14139.9 $ 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) 8545.0 17-AUG-95 5.3B 4.9C MEMORY 14130.9 8545.9 14139.9 70 .LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-NOV-~995 13:18 PAGE: 12 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 68.1 68.8 TOOL NUMBER CDR RESISTIVITY CDN NEUT./DENS. $ RGS055 NDS022 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 8.5 5335.0 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 CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): LSND 10.41~ 45.0 23000 2.380 2.130 76.0 76.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20¢00 REMARKS: ************ RUN 1 RES TO BIT: 48.57~, GR TO BIT:58.99' CDR ONLY, DRILLED INTERVAL 3824~ TO 5359~ REALTIME DATA PRESENTED DUE TO MEM FAILURE ************ RUN 2 RES TO BIT: 54.88~, GR TO BIT: 65.30~ DEN TO BIT: 109.52~, NEUT TO BIT: 116.46' WASH-UP 5520~ TO 7404~, DRILLED @659~ TO 14130 $ LIS FORMAT DATA .LIS Tape Verification List|ng Schlumberger Alaska Computing Center 22-NOV-1995 13:18 DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB *~ TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 $ 68 0.5 9 65 FT 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 SET TYPE - CHAN ** PAGE: 13 NAME SERV UNIT SERVICE AP1 AP1 API AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630156 00 000 00 0 4 1 1 4 68 0000000000 RA LWl OHMM 630156 00 00~ 0~ 0 4 1 1 4 68 00000~0000 RP LW1 OHMM 63~156 00 0~ ~ ~ 4 1 1 4 68 00000~0000 DER LWl OHMM 630156 ~0 00~ 00 0 4 1 1 4 68 0000000000 ROP LWl FPHR 630156 00 000 00 0 4 1 1 4 68 0~000000~0 FET LW1 HR 630156 00 000 00 0 4. 1 1 4 68 ~00000000 GR LWl GAPI 630156 00 000 0~ 0 4 1 1 4 68 0000000000 RHOB LWl G/C3 630156 ~0 000 00 0 4 1 1 4 68 0~00000000 DRHO LW1 G/C3 630156 ~0 00~ 00 0 4 1 1 4 68 0~00000000 PEF LW1 BN/E 63~156 ~0 0~ ~0 ~ 4 1 1 4 68 0~00000000 CALN LWl IN 63~156 00 000 0~ 0 4 1 1 4 68 0000000000 NPHI LW1 PU-S 630156 00 000 00 0 4 1 ! 4 68 0~000000e0 ** DATA ** DEPT. 14142.50~ RA.LWI -999.250 RP.LW1 ROP.LWI -999.259 FET.LWI -999.25e GR.LW1 DRHO.LWl -999.250 PEF.LW1 -999.250 CALN.LWl DEPT. 14000.000 RA.LW1 3.437 RP.LW1 ROP.LW1 104.504 FET.LW1 0.737 GR.LW1 DRHO.LWl 0.023 PEF.LW1 3.380 CALN.LWl -999.250 DER.LW1 -999.250 RHOB.LW1 -999.250 NPHI.LW1 3.72e DER.LW1 63.697 RHOB.LW1 8.774 NPHI.LWl -999.250 -999.250 -999.250 3.613 2.391 28.500 ,LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-NOV-1995 13:18 PAGE: 14 DEPT. 13500.000 RA.LWl ROP.LWl 32.848 FET.LW1 DRHO.LWl 0.071 PEF.LW1 DEPT. 13000.000 RA.LW1 ROP.LW1 58.~98 FET.LWl DRHO.LW1 0.025 PEF.LW1 DEPT. 12500.000 RA.LW1 ROP.LWl 114.344 FET.LW1 DRHO.LWl 0.e44 PEF.LWl DEPT. 120eo.e00 RA.LWl ROP.LW1 143.156 FET.LWl DRHO.LW1 ~.018 PEF.LW1 DEPT. 11500.e00 RA.LW1 ROP.LW1 19e.564 FET.LW1 DRHO.LW1 ~.~40 PEF.LW1 DEPT. 11000.e00 RA.LW1 ROP.LW1 46.020 FET.LW1 DRHO.LW1 0.~21 PEF.LW1 DEPT. 1~50e.00~ RA.LWl ROP.LW1 75.~88 FET.LW1 DRHO.LW1 0.015 PEF.LWI DEPT. 1000e.e~o RA.LWl ROP.LW1 124.531 FET.LW1 DRHO.LWl 0.037 PEF.LWl DEPT. 950~.e0~ RA.LWl ROP.LWl 114.356 FET.LW1 DRHO.LWl 0.021 PEF.LW1 DEPT. 9000.000 RA.LW1 ROP.LW1 313.920 FET.LW1 DRHO.LW1 e.047 PEF.LW1 DEPT. 8553.000 RA.LW1 ROP.LW1 -999.250 FET.LW1 DRHO.LWl -999.25e PEF.LW1 38.315 RP.LW1 1.489 GR.LW1 3.833 CALN.LWl 2.047 RP.LWI 1.068 GR.LWl 3.690 CALN.LW1 3.527 RP.LW1 2.966 GR.LW1 4.361 £ALN.LW1 29.322 52.061 8.851 3. 443 131.913 8.916 5.415 147.660 9.093 5.922 RP.LWl !1.564 0.408 GR.LW1 120.825 3.826 CALN.LWl 8.898 3.243 RP.LW1 4.497 9.483 GR.LWI 126.389 3.603 ¢ALN.LWl 9.461 3.193 RP.LWl 1.190 GR.LW1 3.855 CALN.LW1 2.633 RP.LW1 0.861 GR.LW1 3.175 CALN.LW1 3,696 RP.LW1 0.339 GR.LW1 3.290 ¢ALN.LW1 16.567 91.956 8.964 2.766 85.223 8.992 4.145 114.194 9.~66 2.841 RP.LW1 3.133 0.617 GR.LW1 90.182 3.428 CALN.LW1 8.971 3.352 RP.LW1 3.473 0.388 GR.LW1 96.552 3.351 CALN.LWl 8.592 -999.250 RP.LW1 -999.250 -999.25~ GR.LW1 -999.25~ -999.250 CALN.LW1 -999.250 DER.LW1 RHOB.LWl NPHI.LW1 DER.LW1 RHOB.LW1 NPHI.LW1 DER.LW1 RHOB.LWl NPHI.LW1 DER.LW1 RHOB.LW1 NPHI.LW1 DER.LW1 RHOB.LW1 NPHI.LW1 DER.LWI RHOB.LW1 NPHI.LW1 DER.LW1 RHOB.LW1 NPHI.LW1 DER.LW1 RHOB.LWl NPHI.LW1 DER.LW1 RHOB.LW1 NPHI.LW1 DER.LWl RHOB.LWl NPHI.LW1 DER.LW1 RHOB.LW1 NPHI.LW1 31.543 2.349 26.400 2.579 2.453 39.300 4.946 2.447 39.761 8.317 2.453 34.~03 3.879 2.4~4 35.600 4.438 2.473 26.100 2.715 2.436 30.700 3.972 2.433 36.200 3.016 2.422 34.200 3.430 2.393 35.600 -999.250 -999.250 38.30~ ** END OF DATA ** ,LIS Tape Verificagion Lisging Schlumberger Alaska Compuging Cenger **** FILE TRAILER **~ FILE NAME : EDIT .004 SERVICE : FLIC VERSION : ~01C~1 DATE : 9S/11/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 22-NOV-1995 15:18 PAGE: 15 **** FILE HEADER FILE NAME : EDIT .00S SERVICE : FLIC VERSION : DATE : 95/11/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW MWD Curves and log header daga Cot each big run in separage ¢|les, BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD $ LOG HEADER DATA 3700.0 5300.0 DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 03-AUG-95 5.3B 4.0C REAL-TIME 14130.0 3700.0 5300.0 8~ 69.7 69.8 TOOL NUMBER CDR RESISTIVITY $ RGSOSS ,LIS Tape Verification List|ng Schlumberger Alaska Comput|ng Center 22-NOV-1995 13:18 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 112.0 LSND 11.80 75.0 200e0 REMARKS: ************ RUN RES TO BIT: 48.57', GR TO BIT:58.99' CDR ONLY, DRILLED INTERVAL 3824' TO 5359' REALTIME DATA PRESENTED DUE TO MEM FAILURE ************ RUN 2 RES TO BIT: 54.88', GR TO BIT: 65.30~ DEN TO BIT: 1e9.52', NEUT TO BIT: 116.46' WASH-UP 5620~ TO 74~4', DRILLED 8559' TO 14130' $ LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ,~ TYPE REPR CODE VALUE i 66 0 2 66 0 3 73 20 4 66 [ 5 66 6 73 7 65 8 68 0.5 9 65 FT LIS Tape Veri~ica%ion Lis%ing Schlumberger Alaska Computing Cen%er 22-NOV-1995 13:18 PAGE: TYPE REPR CODE VALUE 12 68 lS 66 0 14 65 FT 15 66 68 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 API AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT 'FT 630156 00 000 00 0 5 1 1 4 RA LW2 OHMM 630156 00 000 00 0 5 1 1 4 RP LW2 OHMM 630156 00 000 00 0 5 1 1 4 DER LW2 OHMM 630156 00 000 00 0 5 1 1 4 ROP LW2 FPHR 630156 00 000 00 0 5 1 1 4' ** DATA DEPT. 5300.000 RA.LW2 -999.250 RP.LW2 ROP.LW2 -999.250 DEPT. 5000.000 RA.LW2 5.370 RP.LW2 ROP.LW2 65.425 DEPT. 4500.000 RA.LW2 7.110 RP.LW2 ROP.LW2 81.220 DEPT. 4000.000 RA.LW2 6.630 RP.LW2 ROP.LW2 102.718 DEPT. 3700.000 RA.LW2 -999.250 RP.LW2 ROP.LW2 -999.250 -999.250 DER.LW2 4.660 DER.LW2 6.030 DER.LW2 5.970 DER.LW2 -999.250 DER.LW2 321.000 142. 000 289.100 185.300 397.000 ** END OF DATA ** ,LIS Tape Ver|fication Listing Schlumberger Alaska Computing Center **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT ,006 SERVICE : FLIC VERSION : ~01C01 DATE : 95/11/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 22-NOV-3.995 13:18 PAGE: 3.8 FILE HEADER FILE NUMBER 6 RAW MAD Curves and log header data for each pass of each run in separate files, MAD RUN NUMBER: 2 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MAD $ LOG HEADER DATA 7349.0 5555.0 DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 17-AUG-g5 5.3B 4.0C MEMORY 3700.0 14130.~ 67.3 70.9 TOOL NUMBER GR GAMMA RAY RGS055 GR GAMMA RAY NDS022 ,LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-NOV-1995 13:18 PAGE: 19 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): LSND 10.40 45.0 2.380 2,130 76.0 76.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: ************ RUN RES TO BIT: 48.57', GR TO BIT:58.99' CDR ONLY, DRILLED INTERVAL 3524~ TO 5359~ REALTIME DATA PRESENTED DUE TO MEM FAILURE ************ RUN 2 RES TO BIT: 54.88~, GR TO BIT: 65.30' DEN TO BIT: 109.52', NEUT TO BIT: 116.46~ WASH-UP 5620~ TO 7404~, DRILLED 8659~ TO [4130 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 2 66 3 73 4 66 5 66 6 73 7 65 0 0 20 1 .LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-NOV-1995 15:18 PAGE: 20 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT ll 66 51 12 68 15 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 SET TYPE - CHAN *~ NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630156 00 000 00 0 6 1 1 4 ATR MA1 OHMM 630156 00 000 00 0 6 1 1 4 PSR MA1 OHMM 630156 00 000 00 0 6 1 1 4 ROPE MA1 F/HR 630156 00 000 ~0 0 6 1 1 4 GR MA1 ~API 630156 00 000 00 0 6 1 1 4 ** DATA ~* DEPT. 7350.00~ ATR.MA1 GR,MA1 -999.250 DEPT. 7000.000 ATR.MA1 GR.MA1 81.785 DEPT. 65~0.000 ATR.MA1 GR.MA1 93.616 DEPT. 6000.0~ ATR.MA1 GR.MA1 64.842 DEPT. 5555.000 ATR.MA1 GR.MA1 25.269 -999.250 PSR.MA1 4.449 PSR.MA1 4.845 PSR.MAI 8.198 PSR.MA1 -999.250 PSR.MA1 -999.25e ROPE.MA1 4.096 ROPE.MA1 4.352 ROPE.MA1 7.571 ROPE.MA1 -999.25~ ROPE.MA1 2519.077 494.970 732.042 840.034 -999.250 ** END OF DATA ** ,LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-NOV-1995 13:18 PAGE: **** FILE TRAILER FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 00[C0[ DATE : 95/~/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/11/22 ORIGIN : FLIC TAPE NAME : 9530~ CONTINUATION # : ~ PREVIOUS TAPE : COMMENT : BP EXPLORATION, MILNE POINT MPH-05, AP1 # 50-029-22572-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/1~/22 ORIGIN : FLIC REEL NAME : 95300 CONTINUATION ~ : PREVIOUS REEL : COMMENT : BP EXPLORATION, MILNE POINT MPH-05, API# 50-029-22572-00
