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Home My WebLink About195-206Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Diann~ Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Be,~edy Dianna Vincent Nathan Lowell Date: Is/ Y ., c :, .. , . flth = r �^ m ,, .n , x. 2C+.. ,.-?Y .' , ..sos�:u! ; :cvra ara aw, :.,warrr .. ,, :. es , r,. m w • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 (6, (\/'\ ; Mr. Tom Maunder � , Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPC -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPC -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, c� • Mehreen Vazir BPXA, Well Integrity Coordinator �. ro • S BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPC -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 MPC-01 1811430 50029206630000 Sealed conductor NA NA NA NA NA MPC-02 1821940 50029208660000 Sealed conductor NA NA NA NA NA MPC-03 1820500 50029207860000 Sealed conductor NA NA NA NA NA MPC-04 1821260 50029208010000 Sealed conductor NA NA NA NA NA MPC-05A 1842430 50029212440100 Tanko conductor NA NA NA NA NA MPC-06 1842410 50029212570000 Tanko conductor NA NA NA NA NA MPC-07 1850020 50029212660000 Tanko conductor NA NA NA NA NA MPC -08 1850140 50029212770000 Tanko w/o top NA NA NA 3.4 10/9/2011 MPC -09 1850360 50029212990000 Tanko conductor NA NA NA NA NA MPC-10 1850150 50029212780000 Tanko conductor NA NA NA NA NA MPC-11 1850590 50029213210000 Tanko conductor NA NA NA NA NA MPC -12A 1990910 50029213730100 Tanko conductor NA NA NA NA NA MPC -13 1850670 50029213280000 Tanko conductor NA NA NA NA NA MPC-14 1850880 50029213440000 1.8 NA 1.8 NA 5.1 8/31/2011 MPC-15 1851030 50029213580000 Sealed conductor NA NA NA NA NA MPC-16 1851100 50029213640000 Sealed conductor NA NA NA NA NA MPC-17 1852630 50029214730000 Tanko conductor NA NA NA NA NA MPC-18 1852690 50029214790000 Abandoned NA NA NA NA NA MPC-19 1852960 50029215040000 Tanko conductor NA NA NA NA NA MPC-20 1890150 50029219140000 Tanko conductor NA NA NA NA NA MPC-21 1940800 50029224860000 4.6 NA 4.6 NA 8.5 8/29/2011 MPC -22A 1951980 50029224890100 38 NA Need top job MPC -23 1960160 50029226430000 1.9 NA 1.9 NA 17.0 8/28/2011 MPC -24 2010940 50029230200000 1.6 NA 1.6 NA 20.4 8/28/2011 MPC -25A 1960210 50029226380100 1.7 NA 1.7 NA 17.0 8/28/2011 * MPC-26 1952060 50029226340000 1.8 NA 1.8 NA 17.0 8/28/2011 MPC -28A 2051630 50029226480100 1.6 NA 1.6 NA 10.2 8/29/2011 MPC-36 1980010 50029228530000 4.5 NA 4.5 NA 45.9 8/29/2011 MPC-39 1972480 50029228490000 5.5 NA 5.5 NA 49.3 8/29/2011 MPC-40 2002130 50029228710000 0.75 NA 0.75 NA 5.1 8/29/2011 MPC-41 2010780 50029230140000 0.5 NA 0.5 NA 8.5 8/31/2011 MPC-42 2040280 50029231960000 1.5 NA 1.5 NA 13.6 8/30/2011 MPC-43 2040390 50029232000000 3.3 NA 3.3 NA 30.6 8/30/2011 F\\': I\IPC -:~ I and 1\1PC-26 Subject: F\V: l\1PC -21 and lV1PC-26 .,..-" From: "Green, l\.1att 0" <Greenl\10@"BP.com> Date: Tue, 27 Jul 2004 09:29: 13 -0800 To: "Tom l\Ilaunder (E-nlail)" <tom_maunder@'admin.state.ak.us> CC: "Frazier, Nicholas B" <fraznb@'BP.C0111> Tom, Attached is the wellwork history on these two wells. I hope that this is what you are after! If you need any further Information, please let me know. I am charged with looking after the C-Pad wells at the moment, hence the reply from myself! Cheers, Matt. -----Original Message----- From: Thomas Maunder [flldJl.r':):t.-.:;,rrl Sent: Monday, July 19, 2004 1:36 To: FrazIer, Nicholas B; Cubbon, Subject: MPC -21 and MPC-26 ri'ld u.nd~:' ('"~,,CJ dit'll n . :.; tat;;.:: . ,:i.k . U 2 ] PM John R; Reem, DavId C I am not sure who might be around, so the shotgun approach applies. It is planned to perform a workover and convert and convert MPP-17 to an injection well. In discussions with John and Lea on the North Slope, it was indicated that a coil jet pump was similarly retrieved from the two subject wells. I have looked at our well files and don't find any mention of this work in the documents there. I am requesting that a "summary listing" of the work performed on these wells be submitted. I am not sure if "summary listing" is the proper term, however a while back I believe that Sean Peterson had pulled some information on other wells and sent it in. The report I am referring to is essentially a daily 1 or 2 line summary of the well work performed. Thanks in advance for your assistance in the matter. Tom Maunder, PE AOGCC C-21 and C-26 History.xls Content-Description: C-21 and C-26 History.xIs Content-Type: appIication/vnd.nls-excel Content-Encoding: base64 I of I 7/~7'200-t 11: 16 AM ~:~ÏJ~te::i&::~ ,~",;~~:ti Còlmnents ' '," ,'{' ,,:: " .::','f:.;d~>::" , PULLED 9C JET PUMP (SER# BP-I089). PUMP IS IN GOOD WORKING CONDITION. DECIDED TO RERUN. BELIEVED THAT THE IA WAS FROZEN YESTERDA Y. DRlFTED TUBING WITH 2.18" SWAGE, AND TOOLS STOPPED FALLING ø~ 7211'WLM Subtnersible Pump (7232'CWLMD). ANGLE IN HIGH 80 DEGREES. FLUSHED IA W/ 160BBLS OF 120 DEGREE Maintenance POWER FLUID. AND RESET SAME 9C JET PUMP (SER# BP-l 089). RDMO. POP WELL. PULLED 9(' JET PUMP (SER# BP-I089). PUMP IS IN GOOD WORKING CONDITION. Slickline. E-Line DECIDED TO RERUN. BELIEVED THAT THE IA WAS FROZEN YESTERDAY. DRIFTED And Ct Tags TUBING WITH 2.18" SWAGE. AND TOOLS STOPPED FALLING (@ 72Il'WLM T/l/O= 250/350/260 TRY TO THAW POSSIBLE ICE PLUG IN IA. PUMPED 130 BBLS OF 180 DEG CRUDE DO\VN TBO. SWITCH TO IA AND PUMP 65 BBLS 90 DEG. MEOH ( 60/40 ) . CIRCULATED MEOH FROM IA TO TUBING DOWN FLOW LINE WITH LITTLE SUCCESS ( VERY LOW RATE). PUMPED FLUID AWA Y CONTACTED PAD OPERATOR. RDMO. FIN ALS/T /IJO= 200/3800/375. PULLED lOA JET PUMP (SER# BP-I040). AND UPON INSPECTION FOUND NO DAMAGE TO NOZZLE. OR THROAT. THERE APPEARED TO BE LARGE PLASTIC SHA VINGS WHICH IS BELIEVED TO BE ELECTRlCAL TAPE PACKED IN ROCK SCREEN BLOCKING OF A Submersible Pump MAJORITY OF THE FLUID PORTS. THIS PUMP HAD A PORTED ROCK SCREEN INSTEAD Maintenance OF THE NEWER SLOTTED T'{PE. SET 9(' JET PUMP (SER# BP-I 089). RDt\10. FREEZE PROTECT IA WITH 50 BBLS DEAD CRUDE / FREEZE PROTECT TUBING WITH 20 BBLS DEAD CRUDE IVIPC-26 \.;-- !:'-~ ""'''ot ~ : ..- , - MPC -26 03/13/04 MSP MPC-26 03/13/04 TAG MPC-2f 03/12/04 HOT MPC-26 03/10/04 MSP MPC-2602/25/04 TBW MPC-26 01/24/04 STA MPC-26 08/16/03 PRO .--. t'"'\ '¿: -I: "....-- Hot Oi l T reattnents Tubing Wash Static Pressure Survey Misc. Pressure Test SBHPSURVEY Good test on production/test and power tluid lines after sidetrack ops: C-26 is both gas lifted and a jet pump well. Well will be started as ajet pump tirst Set Submersible MPC-26 07/30/03 SSP PU111p Gas Lift Valve MPC-26 07/29/03 GLV Work Set Subn1ersible MPC-2E 07/15/03 SSP PUlnp IYfPC-26 06/15/03 LAT Lateral Field Operations Relevant To Well MPC-26 OS/21/03 DSO Work Field Operations Relevant To \Vell MPC-26 05/16/03 DSO Work Pull Submersible MPC-26 05/14/03 PSP Pun1p Field Operations Relevant To 'Nell MPC-26 05/13/03 DSO Work MPC-2E 05/12/03 TBW Tubing Wash Pull Subn1ersible MPC-2E 05/03/03 PSP Pun1p MPC-26 05/03/03 TBW Tubing Wash Field Operations Relevant To 'Nell MPC-2E 03/06/03 DSO Work Freeze protect for 2" sUlnp line pin hole leak repair Set lOA jet pUlnp w/5/8" sucker rod box on botton1 of rock screen (ill 6587' \vlm. Pull SPV, Pull ball and rod, RHC-IvL OCR, set OGL V in top SPI\tl opened SSD.I Redress II S jet pump BP-I 040 pulled fronl J-23 and set up as lOA in C-26 Prep well for R WOo Travel fron1 WOAlC Pad to l\1PUnvlPC-26. Stop en-route for Rig 4ES move. Stand by to relocate KJondike Rig 1.Pre Spud n1eeting \vith WOT/S\VS/BP l\..IPU Supv Safety Pad OperNeco Respot KJondike and spot CTU. Job in progress. Pull jet pump. Pipe swap to 1.5in for IvIPC-26. Punlp salt pill to kill well. Retrv jet pU111p and f/p well F /P \vell Pressure Test l\1PC-26 02/27/03 PTW Wellhead Packoffs Tubing hanger test passed to 5000 psi~ Inner casing hanger test passed to 3000 psi Set Subnlersible Punlp MPC-26 11/08/02 SSP Jet pun1p set Ser#8666 5C conlbo. #5 nozzle, #7 throat MPC-2E 09/15/02 PSP MPC-26 09/15/02 TBW MPC-2E 09/12/02 SSP MPC-2é 09/12/02 TBW MPC-26 09/09/02 TBW MPC-2é 08/23/02 TBW MPC-2é 08/07/02 TBW :rvlPC-2E 06/25/02 MSP MPC-26 05/13/02 TBW MPC-2é 05/09/02 TB V\' MPC-26 01/08/02 MSP MPC-26 OS/29/0 I MSP MPC-26 05/12/01 DSO 1\1PC-26 05/06/01 TBW MPC-2é 02/16/01 PRO MPC-2E 10/04/00 DSO Pull Subn1ersible PUlnp Retrv jet pump w/1 " gln1 n1ernory gauge Tubing Wash F/P coil annulus and flowline w/16 bbls meth Set Subn1ersible PlIInp Seat jet pun1p w/memory gauge for SBHP Tubing Wash F/P coil IA and coil w/4 bbls n1eoh Tubing Wash F/P coil tbg, po\\'er fluid line. test line and coil IA w/25 bbls meoh Tubing Wash F/P coil tbg and armulus \v/15 bbls n1eth Tubing Wash f/p ann/flo\v \v/I7 bbls n1eoh Subn1ersible PlIInp Rigged up jet pump lubricator and dropped 5C jet pump into receptacle, put P\\iT fluid on full open lvlaintenance choke. well taking 533 bbls of pwr fluid Tubing Wash Jet pump out of hole, frz protect w/18 bbls meth Tubing Wash F/P w/15 bbls n1eoh Subnlersible Pump lvlaintenance Jet pump pumped out of hole fo r inspection and well freeze protected. Subrnersible Pump lvlaintenance No Changes l\Ilade To PUlnp. Jet 5c And Nozzle 7 Field Operations Relevant To ,^'ell Work Atmular vent installed fron1 the irmer annulus to the cross block on the tree. Tubing Wash Well freeze protected after the water pump went dOWll. lV1isc. Pressure Test Field Operations Relevant To ,^'ell Work Pressure tested flo\vline and power fluid lines. Torqued up activation pins on Pede or CTU hanger. Pressure Test MPC-2é 08/13/00 PTW Wellhead Packoffs Pressure tested CTU hanger and freeze protected well. 1\1PC-26 08/12/00 COlvl Con1pletion Installed jet-pun1p recon1pletion. MPC-2E 07/11/00 CTM MPC-26 07/07/00 CTl\1 MPC-2E 05/31/00 PTT 1vlPC-2E 05/07/00 TAG MPC-2E 12/06/99 DSO MPC-2E 11/28/99 STA MPC-26 10/18/98 PTT 1v1PC-26 08/31/98 HOT MPC-2f 08/25/98 HOT MPC-2E 08/17/98 MSP MPC-26 08/09/98 HOT MPC-2E 08/06/98 HCL MPC-26 03/16/98 ANN MPC-26 01/10/98 STA l\Ilisc. Coiled Tubing Work Ivlisc. Coiled Tubing Work Pressure Test Tubing SlickJine. E-Line And Ct Tags Prepped well for jet pun1p conversion. Tagged top of ESP (?jj 6554'slm and set dv (l]!124'slm. Field Operations Relevant To ,^'ell Work Static Pressure Survey Pressure Test Tubing Hot Oil Treatments Hot Oi I Treatn1ents PUlllp 50 BBLS dead crud do\vn backside to warn1 up well Submersible Pump Ivlaintenance Flush ESP with dead cnlde, still nl0nitoring benefits Hot Oil PUlllp 90 BBLS dead cnlde down annulus to settle amp spikes occuring after acid job. Short term Treatments benefit Hcl Acid Stimulation Annular Co nml uni c at i on Work Static Pressure S ur\'ey Repunched tubing from 6550' to 6544' with 10 shots. Punched 2-7/8" tubing from 6550' to 6554', however charges rotated and shots went through heavy wall section. Tested tubing with D+D test tool, test good. The well was freetlowed for ten days, WC in 70's. SBHP survey. Test the SOY and tubing fron1 6561' WLIvID, both tests good Pump 50 BBLS dead crude down armulus Acidize ESP II BBLS down tubing flush IA with dead crude. SBHP 3359 psi @~ 6470' TVD (6560' l\'ID) MPC-26 12/29/97 RWO JvlPC -26 12/16/97 STA 1\1PC-26 08/28/97 HCL 1\1PC-26 OS/25/96 APF MPC-26 OS/22/96 FRC t\1PC-2E 03/0 I /96 STA MPC-260I/01/96 RFT Rig Workover RWO c/o ESP. Static Pressure Survey Hcl Acid Stinlldation Acidize ESP. Add Perf Band C-sand add perforations Flowback Hydraulic Frachlre Stin1 Frac stimulation across A-sand, prop-net used in frac. 95k# 16/20 blh pipe Static Pressure Survey Pressure Rft SBHP 3000 psi at 6525' TVD. sbhp 3,764# nlid-perf Polar de-completion Drilled and cased by 22E. RFT indicated pressures up to 4I40psig Initial completion installed, gas lift with TCP across A sand -- PRE-PRODUCTION '/' ~ ~ 95-éY°<O ¡ .. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, O,7f DATE: July 12, 2000 Commissioner Õ /Ieyóc.) THRU: Blair Wondzell, (g~ P. I. Supervisor ,tlf1(d:J FROM: ~ ttJ Jeff Jones ---- SUBJECT: Safety Valve Tests Petroleum'l sp c 'r Milne Point Unit B & C Pads July 9,2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU 8 & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU 8-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. :3 M:)~ r-<.--h-;;"f- 21 well houses were inspected, no failures. - 'þ" Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON.CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc '! ~ ~ /' / Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Submitted By: Date: 7/9/00 Operator Rep: Larry Niles FieldlUnit/Pad: Kuparuk River/MPU/C-Pad AOGCC Rep: Jeff Jones Separator psi: LPS 140 HPS ;~~~~ ~;¡~ w é ï [; Jj~lfi~;?~~f~ff Well Permit Separ Set LIP Test Test Test Number Number PSI PSI Trip Code Code Code Oil, WAG, GINJ, GAS or CYCLE þ; @..O'¡'<W~"> t 1811430 140 100 95 P P OIL ", " " " ,/ C-03 1820500 140 100 95 P P OIL C-04 1821260 140 100 100 P 4 OIL C-05A 1842430 140 100 100 P 4 OIL C-07 1850020 140 100 100 P P OIL C-08 1850140 C-09 1850360 140 100 120 P 4 OIL C-13 1850670 C-14 1850880 140 100 100 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C-22A 1951980 140 100 95 P P OIL C-23 1960160 C-25A 1960210 4000 2000 2000 P 4 WAG C-26 1952060 C-28 1960290 4000 2000 2000 P 43 WAG C-36 1980010 C-39 1972480 C-02 1821940 4000 1900 P P WAG C-06 1842410 4000 1900 P 4 WAG Wells: 12 Components: 23 Failures: 6 Failure Rate: 26.0%090 Day Remarks: Wells # C-02 & C-06 are listed as water injection wells, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap o-ring leaked. The SV on well # C-07 recorded a slow closing time;(2:27). Larry Niles, the BP representative, said he would have these items corrected. 8/7/00 Page 1 of 1 VI v7irqrn.xls h¢sred ri. lJjng TO: Blair Wondzell 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 discussed this 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 pad 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 SCANNED NOV ]1 3 2002-. i:... ANNULAR INJECTION DATA ENTRY SCREEN Asset Mila~....~ ...................................... Legal Desc .tQ~.fi.~.~L,.2,4.1.9...~EL,..~.e.~..1.Q0.T..I.~,..B.I.QE ................................. Rig Name ~.~tb.9.r.~..22F,, ............................. Inj Well Name M..P..G.:~.~. ..................................... SCANNED NOV 1 $ 2002, Research Sur Csg Dep .~[Q.4 ................ Cumulative Data Permit Start ....... .12~.1.~.~.~ ....... Permit End ....... :1.~.1..~/.~,6 ....... Well TOtal ......... ~,22~ ......... Rig Completion Mud/Ctg Wash Fluids ......... ..4,.41~;~. .................... .5.,5,5. ......................................... Formation Intermittant Final Flu:ids.. F~ee2e Freeze ...................................................................... 1.~.~ ........... Daily Data Source Date of ~nated Rig Wash ~ ~ Freeze Well Injection Drlg Mud Fluids Fluids Fluids Protecli~ MPC-26 01/04/96 180 180 MPC-26 01/05/96 120 120 MPC-26 01/06/96 125 125 MPC-26 01/07/96 230 230 MPC-26 01/08/96 105 105 MPC-26 01/09/96 133 133 MPC-26 01/10/96 600 600 MPC-26 01/11/96 530 I 530 -.~':~ ...................... 1'~''~''2'~''~'~ .................... 1'~ ........................................ 1 ................................................ 1 .............. .~....~..~.~...~..~.~.~....~...~...~.....T.~.........~.......T.~.~.~..~...~...]..~..~.......Z....~...~..~.~...~...~.....].~.~....~....~...~.~...~.~.....~..~....~..~.....~..~....~..~..~... MPC-23 02/16/96 1,500 100 .................................................................................................................................................................................................................................................................................. 176 ..... i~,.~6 ..................................................................................................................................................................................................................................................... ......................... ~ ........................................................................................................... ........................................ l ................................... 1 ........................................................................................................................................................................................... .......................................... . ........................................... . ................................................... , ...................................... ~ .................................... . ...................................... , ........................... . .................... ~ ......................... ...................................................... I ....................................................... ........................................................ . .......................................................... ~ Open ' [ _ hare. d , ,j erv ces 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 141998 Alaska Oil & 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/N-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 &//2, 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 (10-403) 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 i-23/O-15, 1-61/Q-20, 2-40/S-22 · Exploration well Sourdoueh #3 - · M~he PointwellsF-O6, H-OS,~-O6, J-13, L-24 · ~dividu~ logs are provided to you fo~ these ~ogs tis 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, Envirommental Advisor at 564-4305. Sincerely, Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) SCANNED NOV 1:3 2002 RECEIVED Alaska 0ii & Gas Cons, c0mmissi0,~ Anchorage I. e§ed uedo /_6/g U'8 96/~ ~Z 058 g~l~ BOH:I 'NSLL'0~ oes 901,g 8~-C)dl~l B~ s~oq uedo Z61glL 96/g/L 0iL 008 S9t'[ g06'L ~0[~ 'N8[1'0[ oas '3Md,9gtg 'qNJ,gP[ L g6S8 gg-Oa~ ggg sJoq ................................................................................................................................................................................................................................................................................................................................................................. :...: ............................................................................................................................................................................................................................................................................................................ uado Z6/gg/L 96/gg/L 0gL 08[ 008'L 090'g 'Ng[I'0[ oas 'q~M t0~g 'qSN 8g0L [t6t gg-Od~ 3gg sJoq uodO, z6/8 L/i~ 96/8 L/i~ 00 L 989 988 889'8 L 809'6 L B L 5 UNg LL'80'ooS "13M,00 L g"lSN,Si~98 8098 z L-)4d~ BZ aUl pesolo /.6/9~/L 96/9~/t 99L'L 089'1~ 98/.'9 ~gt~gl:l 'N6J. 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U'~db ............ 96)~ ~6i~[' 09 ~Z~'L ........ ~[~;~ 6'z~'L~ 8~z'g~ ' ag~u 'N~JZ"~J o~S 'q~M,~0~ ;]sN.~z0~ 9~ 0~-Q/~9-~ 9'~ UoA, ................................... u~dO .... g6/[S~[ ' ' G6/08/6 0~ .... 00~ ' ' 0~;L t0'9'0~ tS0'~C ~9~'N~I'9~'OaS 'MaJ',Le0~'3Na,0~0~ 9~t S~-O/~-~ "'u~d'o ~)~' ~ 0~ '" z~ ~'L 0~'~ ~9~U'N~'"9~'~S 000~ ~-V~-~ snleis puq Pels azaa~-I eZaaJ:l sp!nl-I sp!nl~ qSeM s§lo ~ lelOl reno osao le§a'l snlnuuv ~pad lesods!o leU!:l reno m~elUl reno m~o-I "'no IdmOO reno §!~ reno pn~ ~no g L uo~ NqdO g6//-JcJ /-6//./9 Og L LG' L l[ AON O]NN¥3 ~ eS~d 9 LZ' t 9S9'~ E;t~6'cJ ~i8 L I:i'N8 LL'~gO~IS'-I~,~0Gt/'ISN, L 1.8~ , [ 8 LC 8~-S qB ~ sJoqet uedo Z.6/t2~ 96/L2/'& 0St 90['8 cj8~"8 L99'I~ 'NL LL '~8 'O=IS "lam ,z90t "ISN ,cj96Z Z88~ CC-O 6 UOXO( uedo /.6/0i/t~ 96/0Z/t~ 0gt 0~t qE:LH 'NL ~1 '9~ 'O~IS 9LZC LE:'O 6 uo~o( uedo . cj6/Lg/'&L G6/LE:/Z LgL LSI~'ZL 89g'ZL :10Lbl 'NgL£'9 oes '1:1M,809~ "ISN,6Z6 L 8Z99 cJl~-:ldlAl =1/.8 sJoqeF uedo g6/LS/~L ~;6/9/~ L cj/. Z~L'6 ~E~'6 =IOLH 'NSL.I.'9 oes "I~,LSZ~ "ISN,t~66 L L9Gg gS--IdlN ::IZ~ sJoq~p uedo ~;6/L8/~ 96/~81Z cJz OZ. /_88'9 ~E:0'Z q0Lt:J 'NE;LJ.'9 oeS '-I:I~,~Pg~ "ISN,L~6 L L~99 ZS--IdlN =IZ~ sJoqel~ uedo 96/~L/~L S6/~L/~ L OZ. 99~'9 9~cj'9 INIq :10 Lbl 'N~;L/'90 oeS L1~88 ~-_-Icl~ ~Z.~ sJoqsl~ lJodeEI eA!lelntuno g66 L Jeqtueoeo I!lUn S66 L 'gZ ~lnr setunloA uoqoelul Jelnuuv §u!IIUC] ,~o!~s P;~eqs Shared Se'i~vice D~:illing AnnlJii~'r injection Volumes July 25, 1995~ until December 1998 Cumulative Report Sudace Casing Rig Inj Well Depth Nabors 28E B-33 3504' Nabors 28E E-34 3664 Nabors 28E E-36 3648 Nabors 28E E-37 3810 Cum Mud Legal Desc Cum Total & Ctgs 969'SNL 1898'EWL, Sec 31, T11N, R14E 3,974 2,842 168'SNL 500'WEL, Sec 6, T11N, R14E 9,656 7,228 1706'SNL 822'WEL, Sec 6,T11 N, R 14E 9,271 4,417 3391'NSL 881'WEL, Sec 6,T11N, R14E 4,695 4,241 Cum Rig CumCompl Cum Form Cum Interm Cum Final Disposal Period Annulus Wash Fluids Fluids Freeze Freeze Start End Status 857 195 80 5/1/96 12/31/96 Broached · . 1.420 858 40 110 8/23/95 12/31/95 Open 1,293 3,096 365 100 7/25/95 12/31/95 Open 374 80 9/16/95 1 2/31/95 Open Nabors 28E E-39 3638 3358'NSL 501'WEL, Sec 6,T11N, R14E 2,250 928 220 1,022 80 8/28/95 12/31/95 Open Nabors 28E G-04A 3509 2917'NSL 1974'WEL, Sec 12,T11N, R13E 5,937 1,798 1.824 2,315 10/20/95 12/31/95 Open Nabors 28E G-21 3509 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 Nabors 28E S-24 2750 1633'SNL ~ 4228'WEL, Sec 35,T12N, R12E 20,261 11,773 2,177 5.751 275 285 12/9/95 12/9/96 Open Nabors 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 Nabors 28E S-42 3077 Sec 35, T12N, R12E 168 100 68 3/13/96 3/13/97 Open Nabors 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 Nabors 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 CANNED NOV 1 3. 2002 Page 3 PERMIT 95-206 95-206 95-206 95-206 95-206 AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS 7069 BHP DIFL/GR ~/SEPIA FMT / GR ~L~/SEP IA GR/CCL QI.C¢'~ ~\'-<' i~,'[) ~ISEPiA 95-206 SSVD 95-206 ZDL/CN/GR 95-206 GR/CCL/SET 95-206 GR/CCL-PERF 95-206 GR/CCL 95-206 CDR- TVD 95-206 CDR-MD 95-206 7449 J~100-6730 ~'/100-6840 ~DR 66-6896 Page: 1 Date: 06/09/98 RUN RECVD 1 01/26/96 1 01/26/96 1 01/26/96 i 01/26/96 1 01/26/96 1 01/26/96 1 01/26/96 1 05/10/96 1 06/21/96 1 06/21/96 FINAL 09/05/96 FINAL 09/05/96 1,2 09/05/96 T 10-407 ~OMPLETION DATE ~//3~/ 'f~/ DAILY WELL OPS R /~2~/g37 TO ~/2Y~7~ / Are dry ditch samples required? /yes ~And received? Was the well cored? yes ~3knalysis & description received? Are well tests required? , yes ~.Received? Well is in compliance /IJ~.} In~tial COMMENTS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown []Stimulate [] Plugging [] Perforate [~ PulI Tubing [~AIterCasing [~ Repair Well [~Other ESPExchange 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1086' NSL, 2419' WEL, Sec. 10, T13N, R10E, UM At top of productive interval 2066' NSL, 2847' WEL, Sec. 10, T13N, R10E, UM At effective depth 2133' NSL, 2855' WEL, Sec. 10, T13N, R10E, UM At total depth 2139' NSL, 2855' WEL, Sec. 10, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE = 48' 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-26 9. Permit Number / Approval No. 95-206 10. APl Number 50-029-22634 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 7444' feet true vertical 7294' feet Effective depth: measured 7400' feet true vertical 7251' feet Casing Length Structural Conductor Surface Intermediate Production Liner Size 80' 20" 4673' 9 5/8" 6854' 7" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (approx) 924 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 170 sx Class 'G' Perforation depth: measured true vertical 6966'-6976',7032'-7052',7106'-7160' 6867'-6877',6933'-6953',7006'-7059' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 6626' Packers and SSV (type and measured depth) None MD TVD 112' 112' 7404' 7591' 6882' ORIGINAL 6738' RECEIVED Alaska 0il & Gas Cons. Comt~is.~' Anchorage 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 Oil-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 ~[l~($~ Prepared By Name/Number: Mary Youngers 564-5242 Form 10-404 Rev. 06/15/88 Submit In Duplic~ Facility M Pt C Pad Progress Report Well MPC-26 Page 1 Rig Nabors 5S Date 17 February 98 Date/Time 21 Dec 97 22 Dec 97 23 Dec 97 24 Dec 97 25 Dec 97 26 Dec 97 27 Dec 97 28 Dec 97 29 Dec 97 18:00 18:30 03:45 04:15 00:00 17:00 20:00 21:00 22:30 23:30 00:00 19:00 19:30 23:30 03:00 06:00 09:00 10:30 12:30 14:00 18:00 18:30 02:00 05:00 13:00 19:30 03:30 06:00 10:00 14:00 18:00 18:30 23:30 03:30 06:00 13:00 16:00 23:30 02:30 06:00 Duration Activity Stopped: To hold safety meeting Completed operations Began precautionary measures Completed operations At well location ~ Cellar Resumed operations Equipment work completed Equipment work completed Pressure test completed successfully - 3500.000 psi Equipment work completed Completed operations Stopped: To hold safety meeting Completed operations Hole displaced with Brine - 100.00 % displaced Equipment work completed Function test completed satisfactorily Function test completed satisfactorily Began precautionary measures Equipment work completed Equipment work completed Stopped: To hold safety meeting Completed operations Stopped: To pick up/lay out tubulars Completed operations Completed run with Cleaning / Investigation tools from 7050.0 ft to 13 At Top of fill: 6728.0 ft Hole displaced with Brine - 100.00 % displaced Stopped: To hold safety meeting Hole displaced with Brine - 100.00 % displaced Began precautionary measures Began precautionary measures Completed operations Completion string handling equipment failed - Change operation Equipment work completed Stopped: To hold safety meeting Equipment work completed Equipment work completed Completed operations Equipment work completed Stopped: To hold safety meeting Oft STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION CL,,vlMISSION WELL COMPLETION OR RECOMPLETION 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. 95-206 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22634 ~. ~:~.,.~::_~L .......... 9. Unit or Lease Name 4. Location of well at surface .~ ':,~,:~;-~ ;-. ~-;~-~.~¢, ~ ~:~;-~'~: '7??:. ~~~-' ~ . !~.?:?,-: ::.'~?~"~":!. Milne Point Unit 1086' NSL, 2419' WEL, SEC. 10, T13N, R10E j ,-.'_'~T~: At total depth .. 11. Field and Pool · . . 2143' NSL, 2847' WEL, SEC. 10, T13N, R10E .................. ~ ........... ~,~--~- Milne Point Unit/Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 48'I ADL 047434 2. Date Spudded12/2 /9S 0 /0e/ eoe/~ 5/96 N/A MSL One 17. Total Depth (MD+'I-VD) 18. F'lug Back Depth (MD+'I-VD)19. Directional Survey 20. Depth where SSSV set,.1. Thickness of Permafrosi 7445 7342 FT 7400 7297 FT []Yes [] No N/A MD! 1800' (Approx.) 22. Type Electric or Other Logs Run RFT, GR/CDL/CNL/MLL/DLL 23. CASING, LINER AND CEMENTING RECORD CASING SETI'ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 sx Arctic Set I (Approx.) 9-5/8" 40# L-80 31' 4704' 12-1/4" 924 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 7" 26# L-80 28' 6882' 8-1/2" i170 sx Class 'G' 5" 14.9# NT13CRS0 6727' 7444' 8-1/2" !115 sx Class 'G' .... 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 2-7/8", L-80 6669' N/A M D TVD M D TVD 6966'-6976' 6867'-6877' 7032'-7052' 6933'-6953' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7106'-7160' 7006'-7059' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect w/60 bbl diesel i27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) June 25, 1996 I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL :GAS-MCF WATER-BBL CHOKE SIZE 1 GAS-OIL RATIO TEST PERIOD · I Flow Tubing Casing PressureCALCULATED . OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 128. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SubmiLc~r9 RECE/VIJ NOV 2 ~ 199~ Ata~ka 0tl & Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate Geologic Marku.o 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. (Subsea) Top Kuparuk 'B' 6925' 6781' Top Kuparuk 'A' 7095' 6949' Top Kuparuk A3 7108' 6962' Top Kuparuk A2 7126' 6979' Top Kuparuk A1 7172' 7025' 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I hereby certify that the foregoing is true and cerl'ect to the best of my knowledge 'nm Scho, ie,d /~,~-~ ~ ¢_~'1'~"'~?"~,~.' Title Senior Drilling Engineer Date i~(/-/,C ~ Prepared By Name/Number: Kathy Campoamo~ 564-5122 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO WelIName: MPC-26 RigName: N-22E/Polar AFE: 337003 Rig #1 Accept Date: 1 2/28/95 Spud Date: 1 2/28/95 Release Date: 05/1 0/96 Dec 26 1995 (1) Rig waited:Equipment. Dec 27 1995 (2) Rig waited: Equipment. Rig moved 50 %. Dec 28 1995 (3) Rig moved 60%. Rig moved 65%. Rig moved 75%. RU divertor. RU surface lines. Rig moved 100%. Nabors rig #22E accepted @ 0200 hrs, 12/28/95. RU service lines. Dec 29 1995 (4) RU divertor. Racked back drillpipe. Tested divertor. Racked back drillpipe. MU BHA #1. Drilled-to 145 ft. MU BHA#1. Drilled to 707 ft. Dec 30 1995 (5) Drilled to 2594 ft. Circulated at 2594 ft. POOH to 253 ft. Serviced cranes. RIH to 2594 ft. Drilled to .2785 ft. Circulated at 2785 ft. Drilled to 2976 ft. Dec 31 1995 (6) Drilled to 4408 ft. Circulated at 4408 ft. POOH to 3850 ft. Singled in drillpipe to 4315 ft. Drilled to 4734 ft. Circulated at 4734 ft. POOH to 1071 ft. RIH to 4734 ft. ~- Circulated at 4734 ft. POOH to 253 ft. Pulled BHA. Jan I 1996 (7) Pulled BHA. RD drillstring handling equipment. RU casing handling equipment. Held safety meeting. Ran casing to 2675 ft (9.625 in OD). Serviced casing handling equipment. Ran casing to 4673 ft (9.62 in OD). Ran casing on landing string to 4704.42 ft. Circulated at 4704 ft. Mixed and pumped slurry - 408.3 bbl. Mixed and pumped slurry- 58 bbl. RD divertor. Installed wellhead housing. RU BOP stack. Page ! Jan 2 1996 (8) RU BOP stack. Tested BOP stack. RD BOP stack. Installed bore protector. MU BHA #2. Serviced top drive. MU BHA#2. Drilled cement to 4625 ft. Tested additional services. Drilled installed equipment- Float collar. Drilled to 4744 ft. Performed formation integrity test, 12.5 ppg EMW. Drilled to 5373 ft. Jan 3 1996 (9) Drilled to 6875 ft. Circulated at 6875 ft. Held safety meeting. Drilled to 6896 ft. Circulated at 6896 ft. Circulated at 6860 ft. POOH to 4704 ft. Serviced top drive. RIH to 6896 ft. Circulated at 6896 ft. Monitor well pressures. Jan 4 1996 (10) Monitor well pressures. Circulated closed in well at 6890 ft. Flow check. POOH to 4704 ft. RIH to 6896 ft. Circulated at 6896 ft. Flow check. Circulated at 6890 ft. Took EMS survey at 6890 ft. POOH to 231 ft. Pulled BHA. RD BOP stack. RD casing handling equipment. Ran casing to 6881.73 ft (7 in OD). RU casing handling equipment. Circulated at 6882 ft. Mixed and pumped slurry - 34.8 bbl. Displaced slurry- 260 bbl. Jan 5 1996 (11) Tested casing. RD casing handling equipment. Installed wellhead integral components. RU drillstring handling equipment. Tested BOP stack. RD well control. MU BHA #3. RIH to 6732 ft. Washed to 6799 ft. Circulated at 6799 ft. Tested casing. Drilled cement to 6896 ft. Drilled to 6907 ft. Circulated at 6907 ft. Performed formation integrity test, 15.3 ppg EMW. Jan 6 1996 (12) Performed formation integrity test. Circulated at 6907 ft. to 7024 ft. Jan 7 1996 (13) Held safety meeting. Drilled Drilled to 7306 ft. Jan 8 1996 (14) Drilled to 7380 ft. Circulated at 7380 ft. POOH to 7380 ft. Repaired drillstring handling equipment. RIH to7380 ft. Circulated at 7380 ft. POOH to 183 ft. Pulled BHA. Ran electric logs. Page 2 Jan 9 1996 (15) Conduct braided cable operations - 7/32 size cable. Tested BOP stack. RIH to 7387 ft. Drilled to 7445 ft. Circulated at 7445 ft. POOH to 183 ft. Pulled BHA. Conduct braided cable operations - 7/32 size cable. Jan 10 1996 (16) Conduct braided cable operations - 7/32 size cable. MU BHA # 4. RIH to 7445 ft. Circulated at 7445 ft. Flow check. POOH to 192 ft. Pulled BHA. RU casing handling equipment. Held safety meeting. Ran casing to 717 ft (5 in OD). RU drillstring handling equipment. Ran casing on landing string to 817 ft. RD casing handling equipment. Ran casing on landing string to 1692 ft. Repaired surface lines. Ran casing on landing string to 6300 ft. Jan 11 1996 (17) Ran casing on landing string to 7444 ft. Circulated at 7444 ft. Mixed and pumped slurry- 24 bbl. Reverse circulated at 6727 ft. Pulled casing in stands to 0 ft. Ran drillpipe to 2000 ft (2.875 in OD). Serviced block line. Ran drillpipe to 6700 ft (2.875 in OD). Tested casing. Ran drillpipe to 7356 ft (2.875 in OD). Held safety meeting. Circulated at 7356 ft. Jan 12 1996 (18) Circulated at 7356 ft. Circulated at 7356 ft. LD drillpipe of 0 ft. Held safety meeting. Retrieved bore protector. RU tubing handling equipment. Ran tubing to 7164 ft (2.875 in OD). Held safety meeting. PU guns. Run Atlas wireline-correlate to open hole logs. Perfed Kuparuk A Sand, 7106'-7160' MD. Space out tubulars. Jan 13 1996 (19) Space out tubulars. RD tubing handling equipment. Held safety meeting. RD well control. RU surface test tree. Freeze protect well - 80 bbl of Diesel. Conducted slickline operations on slickline equipment - setting run. Set retrievable packer at 6655 ft with 1500 psi. Conducted slickline operations on slickline equipment - retrival run. Tested hydraulic packer. Freeze protect well - 60 bbl of Diesel. Nabors rig #22E released @ 0400 hrs, 01/13/96. RD rig services. May 4 1996 Finish MIRU Polar rig #1. Wait on wireline to finish work on locating tubing leak. Wireline finished work on MPC-26. Tubing pressure test conclusion is the packer is leaking. Start removing snow and wellhead barrier. Crew removing scaffording and leveling location. Spot rig and RU. Page 3 May 5 1996 Raise derrick and RU pulling unit. RU HB & R to the tubing. Pressure test all of the surface equipment. Open well WHP. Flowing through the white gas buster (all gas). Started fluid packing with HB & R. Holding 2300 to 2500 psi on the annulus to circulate 10.9 ppg into the wellbore. Shut down HB & R and WHP dropped to 0 psi. RU and pumped 20 bbl of 10.9 ppg down the IA passed the leaking packer. Shut down and monitored the well. In 10 minutes the WHP=IA pressure=0 psi. Monitored the well. SWl and RD HB & R. RU to install TWC. RD tree and install BOP's. May 6 1996 RU BOP's. Having trouble RU the HCR to the choke hose. Locating parts to RU choke line and BOP's. Located all parts and start to fabricate the lines. Installed · choke line. RU HB & R and pressure test. Conduct BOP test. Fix leaks on lines. Pressure test the blinds. The donut on the bottom of the test joint is to thick to allow the pipe rams to close. The ESP plugs are sticking to high to allow the donut to get below the rams. Interchange the blinds and rams block. May 7 1996 Changing out rams and blinds. Working to get hydraulic lines routed. The hydraulic lines are to short from the accumulator. Fluid pack BOP's and lines. Pressure test blinds. OK. Pressure test pipe rams, door leak. Changed out BOP door 0-ring. Finish pressure test BOP system. All test indicated that the 21 way check is leaking and this was confirmed with a pressure test of the upstream side of the HCR. Pressure test kill line. RU wireline to pull TWO and 'X' plug. Pulled 2-way check. RU wireline to pull 'X' plug at 6689' WLMD. Open TIW valve and WHP. TIH with prong and tagged at 6635' WLMD. POOH with equalizing prong. PU prong and GS fishing tool and TIH to pull plug. Tagged plug and POOH. Tight several times coming out of the hole. POOH and recovered 'X' plug. RD Camco WL and RU to unset packer. Started circulating will down the tubing and up the IA. Circulated 260 bbl of fluid around at 1000 psi and 4 bpm. Shut down pump, well dead. Check flow, well dead. Open hydril, pressure under hydril, hanger leaked. Un-landed tubing. Packer wasn't set. String weight up is 60000#. Circulate 1-1/2 volume. Hole staying full with brine. Shut down and monitor the well. POOH with completion string. POOH at 5200'. May 8 1996 POOH with tubing. POOH and LD perf guns with AWL. Recovered all production tools. RD pipe shed and RU wireline to conduct drift run. Wait on Camco for drift run. TIH with 4" junk basket and tagged PBTD. Wait on wireline to set WLSBP. RU AWL and pressure test lubricator. TIH and set WLSBP at 6650'. POOH and RD AWS. Tested plug. OK. RU to TIH to LD tubing. TIH to LD tubing, open ended with tubing collar. Stopped at 6170' and RU to LD tubing. POOH LD tubing. Page 4 May 9 1996 POOH LD tubing. LD 216 jts and tubing and RU to cimulate diesel to FP. Pumped 7 bbls of diesel down tubing and FP the top 93'. POOH and LD 90 of tubing. Pressure test casing, OK. ND BOP's. The two barriers are 10.9 ppg brine and WLSRBP set at 6650'. Install 7/16", 5000 psi tree with false bowl. RU HB & R to pressure test casing and tree. Pressure test tree and WLSRBP to 4000 psi, OK. RD HB & R. Polar rig #1 released at 0200 hrs, 05/10/96. Page BP EXPLORATION (ALASKA) INC. Mine Point Unit TO: S. Rossberg FROM: J. Fox DATE: 05/22/96 RE: MP C-26 Data Frac ! Frac SERVICE CO'S.: Dowell, Peak JOB SUMUARY II INJECTIVITY TEST Design Rate, Bbls Max Rate, Final STP, ISIP, NWB Treat grad, BPM Pumped bpm psi PSI friction, psi psi/ft max. (40) data frac 4 0 data frac n/a n/a n/a DATA FRAC Bbls Bbls XL Time XL gel Final STP, ISlP, psi NWB Treat grad, Pumped gel to on perfs psi friction, psi/ft Perfs psi 260 250 8.33 min 3031 2587 444 0.8 FRA C Sand Lead prop Tail prop Design total Tresaver pumped, behind behind behind Liner rubber left Job was M# pipe, M# pipe, M# pipe, M# Sand, M# in hole? /size /size Flush 99.5 M # 95.4 M # n/a 92 M # 4100 # no 16 / 20 Ft of Estimated Final ISIP, psi ISIP Incr Actual TSO, TSO, sand in sand top STP, over sand:pad design, Nolte P i pe psi datafrac ratio m in Plot 400' 7000' 3672 3260 690 0.145 8.17 if broken (???) Operational problems The post frac pressure falloff survey indicates the outer annulus pressure increasing rapidly (over two minutes) from zero to approx, the same as the casing pressure. It was not noticed until several hours after rig down at which time the OAP was down to (a believable) 250 psig. The frac crew did not see indication of excessive pressures when the pressure transducer was removed. It is suspected that all of the annulus pressures were erroneous. BPM IPS~G IPS~GI BBL BBL Comments The well treated fairly well, although there was no surface indication of a tip screen out. Late in the flush (last 29 bbl.) an attempt was made to force a screen out by dropping the rate to as Iow as 5 bpm w/no noticeable effect. The rate would have been dropped earlier but it was desired to get the "Prophet" additive (that was in the final 15% of the slurry/placed into the fracture. This was the first utilization of the proppant foss control additive 'Prop net', It was placed in the final 70 bbl. of 10 ppg slurry. It was mixed in at a concentration of 0.15 % by weight of proppant. DATE/TIME OPERATIONS SUMMARY 05/21/96 MIRU majority of frac equipment. Install tree saver. Check seawater. 05/22/96 RU remainder of frac equipment. 0705 Pressure test surface lines to 7500 psig. Set trip outs at 6100 psig. Hold safety meeting Data Frac 0755 Start data fmc. Ramping up to max. rate (40 bpm). 0802 Pad 100 bbl. away from perfs - reduce rate to 30 bpm. 0805 Go to flush w/seawater 081 3 S/D pumps. SI well and monitor pressure falloff. 0914 End pressure falloff survey. Assemble data and send into Anchorage for analysis. Frac 1200 Receive confirmation to utilize original TSO design. Prepare to pump frac. 1228 Start pumping 119 bbl. XL 40 ppt gel pad. 1232 Start pumping 1 ppg slurry. 1238 Pad on perfs 1241 Start final slurry stage - 10 ppg. 1 ppg on the perfs. 1249 Go to flush. Pumping 100 bbl. XL gel. stage. 1252 Switch to seawater w/diesel cut in to finish up displacement 1256 With 30 bbl. of remaining flush vol. there is no indication of imminent screenout. Start reducing rate to induce screen out - no response. Reduce down to min. pump rate of 5 bpm. 1259: S/D pumps. Monitor pressure falloff. 1314 End pressure falloff survey. Secure well. Start RDMO. PUMPING SUMMARY TIME RATE ANNP WHP STAGE CUM COMMENTS BPM PSlG PSlG BBL BBL 05/22/96 DATA FRAC 0755 8 0 1543 I 1 Start pumping 50 bbl. seawater spacer 0758 40 0 3200 40 Max. rate established. 0802 40/30 0 3232 205 Pad 100 bbl. away from perfs - reduce rate to 30 bpm 0803 30 0 3035 227 30 bpm rate established 0805 30 0 3283 321 Go to seawater flush. PUMPING SUMMARY TIME RATE ANNP WHP STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL 0813 30/0 0 3031 563 S/D pumps - monitor pressure falloff. I$1P =2587 psig o818 0 2449 o819 0 2431 0820 o 2408 0821 0 2381 0823 o 2340 0828 0 2248 0833 o 2157 0838 0 2042 o848 0 1786 0858 0 1598 0908 o 1447 0914 0 1383 End pressure falloff survey. Flhtc 1228 0 0 861 565 Prepare to start pumping frac design. 1230 30 0 2742 605 Rate established. 1232 30 0 2706 678 Start pumping first slurry stage. 1238 29.8 0 2816 830 pad on perfs 11241 30.3 0 2651 930 Start pumping final (10 ppg) slurry stage. :1249 30 0 2189 1162 Go to flush 1252 29.8 0 2605 1262 Switch to seawater / diesel 1256 30 0 3507 1371 Start to slow rate to induce screen out 1257 1 9 0 3461 1384 Slowing rate down. 1257 1 5 0 3484 1391 1257 1 0 0 3457 1393 1257: 5 0 3511 1396 1258.5 5 0 3672 1400 S/D pumps. Monitor pressure for pressure falloff 1300 0 0 3127 Falloff pressure 1301 0 0 3063 1302 0 0 2990 1303 0 0 2926 1305 0 0 2797 1310 0 2595* 2500 1315 0 2421' 2367 Discontinue pressure falloff survey. RDMO * indicates suspected erroneous data Page 4 FLUIDS PUMPED DOWNHOLE DATA FRAC: 565 Bbls FRAC: 835 Bbls 1400 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME 8 0 Diesel to IA, tubing, or GC 0__ Diesel Recovered (not downhole) 8 0 Total Diesel NONE P ETREDAT WINDOW GEL QUALITY CONTROL CHECK SEA H20 SEA H20 40# GEL 40# GEL PIPE XL XL pH TEMP pH VISCOSITY TIME TIME pH DF/FRAC 7.6 100 7.6 37 8.3 4.3 8.9 FLUID ADDITIVES Gelling agent: J-877 - 9.3 gpt Biocide: M-275 - 6 lbs. /450 bbl. tank Surfactant: F-75 - 2 gpt FLA: J-478 (Adomite Regain) - 40 ppt pH control: Y-6 (boric acid) - 2 ppt Proppant control additive: J-105 (Prop Net) - 0.15% by wt. of proppant over the final 15% of proppant Activator: J-465 - 36 ppt Breaker: J-218 - 1/2 gpt - data frac, 2 gpt - frac, 4 gpt -frac displacement Milne Point Unit, Alaska TO: Steve Rossberg FROM: J. Fox Well Name: MP C-26 Main Category: Initial Perf Sub Category: B and C Sands Operation Date: 05~25~96 Date: [ 05/25/96 Objective: Following the post frac cleanout and in preparation for the flowback the "B" and "C" Sands need to be perforated. In addition, a GR log from PBTD to surface is required to depth shift the open hole MWD log. Sequence of Events: 0330 - Move E-Line unit from F-10i gyro job to C-26 and RU. Rehead to small line for pressure control. MU a standard 3 5/8" OD GR/CCL toolstring, Initial Pwh = 650 psi. Pressure test lubricator- OK. 0430 - Start to RIH - surface software locking up intermittantly. Tag fill. Log up. Pulling weight at 7100' (inside 5" liner - 4.4" ID). Drop back down. Depth correct 10'. Fill tagged at 7228' wlm. Log up - software locked up again. Abort - POOH. Call out a 1 11/16" GR/CCL tool ( that takes a different software package) from Deadhorse and prepare to run first perf. gun. 0830 - RIH w/20' x 3 3/8" hollow carrier gun / PFC (GR)/CCL assembly. Correlate depth to open hole log and depth correct. Log into shooting depth (CCL at 7030') and detonate gun perforating the liner from 7032' - 7052'. Log off and POOH. Pwh remains at 650 psig. All shots fired. 1000 - RIH w/10' x 3 3/8" hollow carrier gun / PFC (GR)/CCL assembly. Correlate depth to open hole log and depth correct. Log into shooting depth (CCL at 6964') and detonate gun perforating the liner from 6966' - 6976'. Log off and POOH. Pwh remains at 650 psig. All shots fired. 1230 - MU 1 11/16" GR/CCL logging assembly and RIH. Correlate and depth correct to open hole DIL / GR log of 01/08/96. Log entire interval from PBTD to surface. 1530 - RDMO Atlas E-Line unit - prepare to start flowback operation. Results: The 'B' and 'C' Sands were perforated as per procedure. See listing below for depths and details. Depths were tied into the openhole DIL / GR log that was previously (01/08/96) run on marked line. ~ E (~ E IV E~ ~ ~4.0v 2 ,s ~996 Alaska 0il & Bas Cons, C0mmissi01~ Anchorage A GR/CCL log was run from surface to TD. For pressure control reasons the smaller unmarked wireline was used. Depths were tied into the openhole log which was previously run on marked line. The well is ready for the flowback operation. Tie in log/date_01/08/96 Atlas DIL/ SFL / GR__ .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Shot Density Orientation Phasing 6966' 16976' JSPF Irandom / 45 3/8" JSPF / 45 Irandom 21 gm. Alpha Jet charges (EHD = 0.47", TTP = 22.8") RECEIVED NOV 2 6 ]996 .Alask~ Oil & 6as Cons. 6o.mmissieD A:lchora~e ANNULAR INJECTION DATA ENTRY SCREEN Asset .Mille ........................................ Legal Desc .1.QA6..~SL,..2.4.19..~/E.I_,..Se.c...1.0,~'.lA~..EL1.0.E ...................... Rig Name .bla. b. Qr.S.2.~E. .......................... · ...................................................................................................................... Inj Well Name .MB.C,.-2.6 .................................. Permit Start .... 1.2~..1.9.J..9.5... Permit End .... 1.2Z.l.9Z.9.~... Sur Csg Dep ..4.Z0.A .............. · ............................................................. Cumulative Data Rig Completion Formation Intermittant Final Well Total Mud/Ct~l Wash Fluids Fluids Freeze Freeze Daily Data :sdurce WaSh : Well : Fluids :i ;Flu:ids proteCt;ion ;:: Rate ! PreSsurel ;Comments;COmplications ,, MPC-26 01/04/96 180 180 MPC-26 01/05/96 120 120 MPC-26 01/06/96 125 125 MPC-26 01/07/96 230 230 MPC-26 01/08/96 105 105 MPC-26 01/09/96 133 133 MPC-26 01/10/96 600 600 MPC-26 01/11/96 530 530 MPC-26 01/12/96 635 100 60 795 , , MPC-26 01/19/96 680 60 740 ..,.M...P.,.C...:.,2...3. ................. 0...2.../...~....6.../...9....6. ................. K~.O...O. .......................... !....o.....o.. ................................................................................................................................................................ VU C~MPA~f¥ BP WELL N~E ~PC-~6 bSCA?!ON ! M~ P? ~CA~tC~.i ~ ALaSkA MAGN~!C DECLiNAT!O~ 2~i6 Cf~t~ C~¥ERGENCE A~iGLE 0~00 WELL NUMBER 0 WELL ' ~ ^~ .......... fi- nn AZV~H~u FROM ROVAR¥ TABLE ~0 ~,~.r.~ 337003 MEgBURED DERTH 112~00 ~:UE gERT ~EF?H 11~00 INCLINATION 0~00 ~IN~JTH 0,00 LATtTL~E(N/-S) 0,00 DEPARTURE(E/-W> 0~ RECEIVED NOV 2 ~ 1996 0il & t3as Cons. Oo.mmm$ion Ano.,.'lorege MEASLG+D r ..... ~^' ~NzEnwL V~:TICAL D~'TH DEPTH ft ft ft ii2,00 0,0 1i2+00 i71~37 59,4 i71,37 ~o,,~ 90,! 439+55 o~s~IUN !NCLN, W-S ft deb d.eg ft O+(K, 0,00 0,00 0,00 0+12 0,54 276+26 0,03 0,52 n.M w~.M 0,i4 1+1! i,!3 273+94 0+26 2,08 2,0? 27i,46 0+37 DEF'AR~JRE DISPLACEMENT .:at AZIMUTH E/-W 0+00 0,00 0,00 -1,i5 1 ~' o'7~ ~o -5,05 ~,06 274,16 DLS dec/ !OOft 0,00 0,91 0,08 0,57 1,07 53!+38 91,8 531,93 6i9,79 86,4 6!?+46 7t3+94 94+i =~ ~ 804+40 90,5 803,37 · ---, 3+53 ~ ~o ~4 .... o+~, 269,_. 0,37. . -9,~/ ?,~ ~ ~7Z,2~, 5,24 3,96 267,!6 0,!8 -i4,78 i4+79 270,7i 17 5,02 o~ ~S ~-~q -22,ti '~'>,i! '-'=' ~ i2+6i 6,0i 285,36 2,46 -30,58 30,68 274+60 !8,62 6,24 2~&,71 5,29 -39+78 40,i3 277,57 0,47 i077 +3~ I268+96 i36,4+94 ,= . i074+I1 ~, / ~ ~.. ~o,.r 1169+Z¥ 94,9 1262~6i %,0 1357,05 %.A= ~ co 292,83 9,i2 35,40 9,69 297+47 !4,99 ' 48,3i i0~83 299,39 23,20 61,93 .. -~- 7A+/U IA,q~ -49+M 5E~,A4 ~on ~ 1,36 -62,13 63,?2 283,56 2,62 -77,2.7 80,68 286,71 i,23 -91,96 o? ~ ...... = ' Z~Y,o/ i~Ig -i0~.o'7 i!3,'~ ~'"~ ~'" . .~ i%0+91 !555+84 i650+82 1745,97 !84!,76 96+0 1451+37 94,9 !544,54 95+0 1637,83 ~+~ t73i+37 '~5~ !825+50 ~!i. ,~° 1i+04 339,79 73,46 129 ~ 1n ~c. 342,18 off.q2 164+5A [n,66 342,94 ~ .~ -11a,09 129,42 i96,23 -124+09 i44,20 3(KJ,62 2,4? -i29,% 158,23 304 ..... ! v,,54 -!35+44 172,52 308+28 0,2'? i937,56 2033+52 2i26,25 2224+09 2319,94 ~ .... !919+5~ 72+0 96+0 20i3+78 94,7 2!06+76 '~5,8 2200,84 ?5,8 .... 20x),90 10,98 ~.~+7.'~ ''~ 158,5i ~4~ ~ '~ -' 237,00 [0 ~" ~!~iA ~'~q ~ 255+~A !i,0i 2~q =', 2i0,73 2508 2604+87 27'96,3? 94,2 2480+47 95,? 2574,57 96,3 2669+19 55,2 276~,77 ~"' ~ i oa "~ i2 245,70 309,89 i!,i2 345+28 263+64 327+98 i0,55 341,2! 281,00 -171,':'~' ':285,63 .......... ~, u , _iv,' zo 3f12,A2 324,26 ...' ,., +,.~%, . . .... ~,._. -i8t,42 320,03 325,47 -~ 8A./-~ 337,33 ~: 41 0,?7 ..... -!92,29 354,21 .~, OQOO O~ 2986,67 ~ 74 3i78,05 3273,15 "',0 2857,~s 94,3 Z949+85 9A,i 3044+28 "'~+o ~ 3137,~ lv,., ~$, ,ii314,00. 380,10 I0+60 341+45 333,32 3'97,80 10,64 34i,68 '347,i2 ,i~,~J 10+61 ._,. ..... 432,96 i0,78 ~44,,~°' oo 380,83 -197,98 371,20 327,77 0,05 -203,51 387,98 328,36 0,!4 -209,!1 405,24 328~94 0,06 -9i0 9;~ ~,', ' ~,,,~v 40,,% 330,06, 0,42 3464,63 3559+6E 0635, q7~O Aq 95,9 34!9,52 95~0 351~,85 95,7 2t¢~A ~ ?5+3 3700,53 450 +,¢ 10,77 345,06 ~oo,J6 ,7i 486,16 !0,73 345+32 432+48 503 z~,J~ 10.75 344,42 -223+92 456,74 330,64 -228,49 474,07 33i+19 -232,57 491 ,';q 331,69 RECEI'VED 0 0,03 0,20 0,07 NOV ?, 6 1996 AIrmko Oi} & (i~ Cong. [;ommiss;on PAGE t.~]. ~ MPC-26 **~********** NJADRILL SURVEY CALCULATIONS ************* CIRCUD~R ARC METHOD******** ~EASUR£D INTERVAL VERTICAL DEPTH 3845,13 94.5 3793.36 3941.53 96,4 3888,06 4037.25 95,7 3982.07 41o~.5~ 96.3 4076,72 4228,54 95,0 4170,13 TA~ET STA?iON AZIMUTH LATITUDE SECTION INCLN, ~V-S it ~eg ~eg ft 5~?.14 10.76 344.3? 483.70 557,14 10,84 345,21 501.13 575,02 10,82 346,73 518,58 592,70 10,46 345~36 57~,83 609,~ 10,46 346,93 552.56 DEF'ARlq]RB DISPLACEMENT at it ft -247,15 543,18 -251.88 560,87 -256,24 578.43 -260.53 595.61 -264.66 AZIMUTH deq 332,94 333.70 334,07 3~4.4i DLS deg/ 10Oft 0.03 0.3,3 0,45 0.30 4321,60 93,3 4261,66 4419,47 97,7 4357,94 4515,25 95,6 4452,19 4610,33 95,1 4545,80 4649.61 3?,5 4584,69 616,63 ~0,35 342,39 644,14 10.33 342.96 5~5,56 661.14 10.14 342.66 601.82 677,77 10.04 343,23 617,74 6~4,62 9,~ 341.21 624,26 -~.¥ 11 A29,26 334,66 -274,33 646,~ 334.90 -279,36 663,49 335.10 -284,24 6~0,00 335,29 -286,33 ~ ,r 0.39 0.!0 0 0.15 0 4756,20 i06.4 4~9.44 4608,61 52,6 4741,26 4904,59 95.6 4535,64 5(~)0.64 96,0 4930,31 5092,89 92,3 5021,29 703,14 10,16 344,53 641,99 712.25 9.62 338.27 650.64 72~.56 9,~1 341,23 665.95 744,77 9,62 343.60 661.40 760,00 9,42 342,72 696,00 -291,79 705,19 335,56 -294.69 714,26 335.63 -300,34 7~,55 ~'~ ~o ~J.l~ -305,24 746.64 335,~7 -30?,66 761,76 336,02 0,59 2.16 O,-q.'q 0,46 0,?.' 5187.49 94.6 5114.64 5284.73 97.2 5210.44 5340.14 95.4 53-~4.2S 5475,85 95,7 5398,53 5569.86 94,0 5491.16 /z~,~ 9,i9' 341,55 710,56 791,96 10,57 340,12 726,31 g09.1^_ . 10.21 ~,.~ ~ 742,41 825,&5 9.89 339.59 758.02 841.69 9,51 339.12 772,83 -314,35 776,99 336,[4 0,32 -319,84 7'~.61 ~^~..~ ~? 1.44 -325,86 810,78 336,30 0,46 -331,82 827,46 336,36 0,37 -337.40 843,27 336.41 0.41 5665.09' 95.3 5585.19 ~g J.gO,lY ../..1.44 96,4 =A' '- Q L 5~5 .... 8B 95.4 5774.17 5952.53 95.6 5668,45 6047,10 .94,6 5'3'61,77 856.96 6.95 337,09 787,01 873,01 10.25 338,41 801,88 889,67 9,86 338,56 817.39 905,72 9,47 337,19 832,27 921,07 9,25 336,40 846,40 -343,09 556,54 336,45 0,6~ -349,16 874,60 336.47 1,3.7 -~__,~/ ~?1.26 336.51 0.40 -361,31 907,31. 336.53 0.48 -~.7.37 922,69 336,54 0,27 6143~21 96,1 6¢~6,68 6~ ~ 95,2 6150,77 .&334,17 ?5,7 6245,31 64~,35 96,2 6340.11 6523,23 92,9 6431,60 936,21 8,91 335.95 860,28 950,74 8,68 337,01 873,63 965,83 9,49 326,26 687,50 982,11 10,02 335,3! 902,54 998,08 9,79 341,86 917,55 -373,50 937,86 336,53 0,36 ~3.5,53 0.30 -379,31 952,42 ~ -385,31 ?67,53 ..~.,53 0,~6 -391,59 988,~3 336,54 0,$6 -397,04 9?9,76 336.60 0,70 6713.64 94,8 ' 661¥,4~ 6791,94 78,3 6696,~3 6926,59 134,6 6829,99 7019.29 92,7 6921,65 1013,97 9,39 345,35 932,62 1029,08 9.05 365,20 947,54 1041,02 6,58 344,38 959.15 1060,92 8.46 343,86 978.34 i074,67 8.69 346,80 991,70 -401.54 1015,58 35%.71 0,73 -405,2fi 1030.58 336,84 0,38 -408,32 1042,44 336,94 0,70 -413,77 1062,~4 '~q~,07.,~,O.LO.. -417.2^ 1075.91 237.1~ (.Jo. 7112,17 93,9 7014,42 72¢~5,75 93,6 7106.96 7300,25 ~,5 7199,52 ,~5v.~5 50,0 7249,09 ~ LAST SU~VE~ IS PROJECTED 7445.¢~ 94.8 7343,02 i088,90 6,96 350,60 1005,82 1102,7i 8,44 354,55 1019,85 1114,98 7,55 3.37 1032,81 1121,¢~ 7,52 3,33 1039,36 1132,38 7.52 ~,3~ 1051,74 · -420,0~ 1090,02 337,33 -421,92 1103,68 337.52 -421,83 1121,70 337,9i -421,11 1132,91 S38.1~ 0,66 0,65 L,62 0,06 0,03 S~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPC-26 500292263400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 2/96 DATE OF SURVEY: 123195 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-50130 KELLY BUSHING ELEV. = 46.30 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS DIRECTION DEGREES DG/10 TOTAL RECTANGULAR COORDINATES VERT. 0 NORTH/SOUTH EAST/WEST SECT. .00 .00 -46.30 148.86 148.86 102.56 237.98 237.97 191.67 328.40 328.38 282.08 419.75 419.70 373.40 0 0 0 34 0 39 1 3 1 41 N .00 E S 85.21 W N 87.30 W S 88.60 W N 89.15 W .00 .00N .00E .00 .39 .06S .74W .20 .14 .08S 1.71W .52 .45 .07S 3.07W .99 .69 .07S 5.27W 1.74 510.88 510.76 464.46 602.27 602.01 555.71 693.37 692.88 646.58 784.00 783.14 736.84 874.88 873.53 827.23 2 43 3 35 4 27 5 59 5 55 S 88.97 W S 87.54 W N 86.13 W N 63.23 W N 71.15 W . 14 .09S 8.78W 2.93 94 .25S 13.80W 4.50 07 .14S 20.18W 6.80 83 2.23N 27.91W 11.68 91 5.89N 36.59W 18.09 965.78 963.89 917.59 1061.48 1058.71 1012.41 1157.20 1153.01 1106.71 1251.56 1245.71 1199.41 1347.09 1339.67 1293.37 6 37 8 43 10 56 10 36 10 10 N 69.07 W N 63.75 W N 61.13 W N 59.11 W N 51.69 W 80 9.28N 45.93W 24.48 32 14.46N 57.59W 33.35 36 22.06N 72.06W 45.45 54 30.84N 87.35W 58.94 47 40.58N 101.52W 72.96 1442.91 1433.88 1387.58 1538.16 1527.38 1481.08 1633.62 1621.10 1574.80 1729.13 1714.95 1668.65 1824.69 1808.81 1762.51 10 49 11 17 10 35 10 50 10 49 N 39.95 W N 26.46 W N 17.99 W N 18.18 W N 17.65 W 2.33 2.75 1.83 .25 .11 52.73N 113.94W 88.63 67.93N 123.84W 106.30 84.64N 130.71W 124.36 101.52N 136.22W 142.10 118.61N 141.75W 160.05 1919.21 1901.60 1855.30 2014.56 1995.16 1948.86 2110.13 2088.92 2042.62 2205.82 2182.84 2136.54 2301.68 2276.93 2230.63 11 4 11 12 11 6 10 57 11 6 N 17.06 W N 16.43 W N 16.17 W N 15.73 W N 15.83 W .30 .18 .12 .18 .16 135.75N 147.10W 177.98 153.39N 152.41W 196.38 171.13N 157.60W 214.82 188.73N 162.63W 233.08 206.38N 167.62W 251.37 2397.33 2370.78 2324.48 2489.36 2461.04 2414.74 2584.86 2554.68 2508.38 2680.46 2648.45 2602.15 2776.04 2742.32 2696.02 11 11 N 15.15 W 11 17 N 14.76 W 11 19 N 14.11 W 11 8 N 15.31 W 10 32 N 19.23 W .17 .13 .14 .31 1.00 224.21N 172.56W 269.82 241.55N 177.19W 287.69 259.69N 181.86W 306.33 277.71N 186.59W 324.88 294.88N 191.91W 342.83 2871.44 2836.10 2789.80 2966.04 2929.07 2882.77 3061.60 3022.98 2976.68 3157.35 3117.05 3070.75 3252.48 3210.51 3164.21 10 37 10 39 10 42 10 43 10 46 N 18.15 W N 17.84 W N 17.36 W N 16.91 W N 16.41 W .23 .07 .11 .09 .11 311.47N 197.52W 360.34 328.09N 202.92W 377.80 344.99N 208.28W 395.51 362.00N 213.52W 413.30 379.01N 218.61W 431.01 RECEIVED NOV g 1996 =RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPC-26 500292263400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 2/96 DATE OF SURVEY: 123195 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-50130 KELLY BUSHING ELEV. = 46.30 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3348.16 3304.48 3258.18 10 57 N 15.52 W .26 396.36N 223.57W 3443.99 3398.58 3352.28 10 50 N 15.32 W .13 413.84N 228.39W 3539.23 3492.13 3445.83 10 44 N 16.01 W .18 431.01N 233.21W 3634.57 3585.78 3539.48 10 53 N 15.64 W .19 448.22N 238.09W 3730.27 3679.77 3633.47 10 46 N 15.53 W .13 465.55N 242.92W 449.01 467.08 484.86 502.71 520.64 3826.23 3774.03 3727.73 10 50 N 14.86 W .15 482.92N 247.64W 3919.74 3865.85 3819.55 10 55 N 14.59 W .11 500.00N 252.13W 3941.00 3886.73 3840.43 10 58 N 13.92 W .62 503.92N 253.12W 4015.25 3959.63 3913.33 10 54 N 13.93 W .10 517.60N 256.51W 4110.91 4053.60 4007.30 10 38 N 13.52 W .29 534.96N 260.76W 538.58 556.16 560.18 574.19 591.96 4206.71 4147.77 4101.47 10 31 N 13.39 W .13 552.06N 264.85W 4302.40 4241.87 4195.57 10 26 N 14.55 W .24 568.95N 269.05W 4398.04 4335.93 4289.63 10 24 N 18.81 W .81 585.50N 274.01W 4419.04 4356.59 4310.29 10 24 N 18.78 W .09 589.09N 275.23W 4493.57 4429.92 4383.62 10 9 N 17.20 W .50 601.75N 279.34W 609.43 626.73 643.98 647.77 661.07 4589.00 4523.86 4477.56 10 6 N 17.57 W .09 617.78N 284.36W 4629.00 4563.25 4516.95 9 56 N 17.33 W .43 624.43N 286.45W 4744.00 4676.52 4630.22 9 56 N 17.33 W .02 643.39N 292.37W 677.85 684.81 704.65 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 706.70 FEET AT NORTH 24 DEG. 26 MIN. WEST AT MD = 4744 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 339.93 DEG. "ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING MILNE PT/MPC-26 500292263400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 2/96 DATE OF SURVEY: 123195 JOB NUMBER: AK-EI-50130 KELLY BUSHING ELEV. = 46.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -46.30 1000.00 997.88 951.58 2000.00 1980.87 1934.57 3000.00 2962.45 2916.15 4000.00 3944.65 3898.35 .00 N .00 E .00 10.69 N 49.61 W 2.12 2.12 150.68 N 151.61 W 19.13 17.00 334.07 N 204.84 W 37.55 18.43 514.80 N 255.82 W 55.35 17.79 4744.00 4676.52 4630.22 643.39 N 292.37 W 67.48 12.13 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ~ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPC-26 500292263400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 2/96 DATE OF SURVEY: 123195 JOB NUMBER: AK-EI-50130 KELLY BUSHING ELEV. = 46.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -46.30 46.30 46.30 .00 146.30 146.30 100.00 246.31 246.30 200.00 346.32 346.30 300.00 .00 N .00 E .00 N .00 E .06 S .72 W .07 S 1.80 W .08 S 3.41 W .0O .00 .00 .00 .00 .01 .01 .02 .01 446.36 446.30 400.00 546.46 546.30 500.00 646.65 646.30 600.00 746.98 746.30 700.00 847.50 846.30 800.00 .06 S 6.05 W .12 S 10.48 W .34 S 16.63 W .83 N 24.59 W .98 N 33.92 W .06 .04 .16 .10 .35 .19 .68 .33 1.20 .52 948.08 946.30 900.00 1048.92 1046.30 1000.00 1150.37 1146.30 1100.00 1252.16 1246.30 1200.00 1353.83 1346.30 1300.00 8.55 N 44.02 W 13.62 N 55.89 W 21.43 N 70.93 W 30.89 N 87.45 W 41.32 N 102.45 W 1.78 .57 2.62 .85 4.07 1.45 5.86 1.80 7.53 1.66 1455.55 1446.30 1400.00 1557.45 1546.30 1500.00 1659.25 1646.30 1600.00 1761.05 1746.30 1700.00 1862.86 1846.30 1800.00 54.59 N 115.43 W 71.31 N 125.52 W 89.12 N 132.17 W 107.22 N 138.10 W 125.44 N 143.92 W 9.25 1.73 11.15 1.90 12.95 1.80 14.75 1.80 16.56 1.81 1964.76 1946.30 1900.00 2066.69 2046.30 2000.00 2168.60 2146.30 2100.00 2270.46 2246.30 2200.00 2372.38 2346.30 2300.00 144.12 N 149.66 W 163.10 N 155.27 W 181.92 N 160.71 W 200.59 N 165.98 W 219.54 N 171.29 W 18.46 1.89 20.39 1.94 22.30 1.90 24.16 1.86 26.08 1.92 2474.33 2446.30 2400.00 2576.31 2546.30 2500.00 2678.27 2646.30 2600.00 2780.08 2746.30 2700.00 2881.82 2846.30 2800.00 238.71 N 176.44 W 258.06 N 181.45 W 277.31 N 186.48 W 295.57 N 192.15 W 313.29 N 198.11 W 28.03 1.95 30.01 1.98 31.97 1.96 33.78 1.82 35.52 1.73 2983.57 2946.30 2900.00 3085.34 3046.30 3000.00 3187.12 3146.30 3100.00 3288.91 3246.30 3200.00 3390.76 3346.30 3300.00 331.18 N 203.91 W 349.20 N 209.59 W 367.30 N 215.13 W 385.54 N 220.54 W 404.16 N 225.74 W 37.27 1.75 39.04 1.77 40.82 1.78 42.61 1.79 44.46 1.85 "-~ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPC-26 500292263400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 2/96 DATE OF SURVEY: 123195 JOB NUMBER: AK-EI-50130 KELLY BUSHING ELEV. = 46.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3492.58 3446.30 3400.00 422.64 N 230.82 W 46.28 1.82 3594.37 3546.30 3500.00 440.91 N 236.03 W 48.07 1.79 3696.20 3646.30 3600.00 459.41 N 241.21 W 49.90 1.83 3798.00 3746.30 3700.00 477.79 N 246.28 W 51.70 1.80 3899.82 3846.30 3800.00 496.35 N 251.18 W 53.52 1.83 4001.68 3946.30 3900.00 515.10 N 255.90 W 55.38 1.85 4103.48 4046.30 4000.00 533.63 N 260.44 W 57.18 1.80 4205.21 4146.30 4100.00 551.80 N 264.78 W 58.91 1.73 4306.91 4246.30 4200.00 569.74 N 269.25 W 60.61 1.69 4408.58 4346.30 4300.00 587.31 N 274.62 W 62.28 1.68 4510.21 4446.30 4400.00 604.56 N 280.21 W 63.91 1.63 4611.79 4546.30 4500.00 621.58 N 285.56 W 65.49 1.58 4713.32 4646.30 4600.00 638.33 N 290.79 W 67.02 1.53 4740.00 4672.58 4626.28 642.73 N 292.16 W 67.42 .40 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS RECEIVED SH3LRED SERVICES DRILLING MILNE PT/MPC-26 500292263400 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 2/96 DATE OF SURVEY: 010996 MWD SURVEY JOB NUMBER: AK-EI-60004 KELLY BUSHING ELEV. = 46.30 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 .00 -46.30 148.86 148.86 102.56 237.98 237.97 191.67 328.40 328.38 282.08 419.75 419.70 373.40 COURS INCLN DG MN 0 0 0 34 0 39 1 3 1 41 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST N .00 E .00 .00N .00E S 85.21 W .39 .06S .74W N 87.30 W .14 .08S 1.71W S 88.60 W .45 .07S 3.07W N 89.15 W .69 .07S 5.27W VERT. SECT. .00 .20 .52 .99 1.74 510.88 510.76 464.46 602.27 602.01 555.71 693.37 692.88 646.58 .784.00 783.14 736.84 874.88 873.53 827.23 43 35 27 59 55 S 88.97 W 1.14 .09S 8.78W S 87.54 W .94 .25S 13.80W N 86.13 W 1.07 .14S 20.18W N 63.23 W 2.83 2.23N 27.91W N 71.15 W .91 5.89N 36.59W 2.93 4.50 6.80 11.68 18.09 965.78 963.89 917.59 1061.48 1058.71 1012.41 1157.20 1153.01 1106.71 1251.56 1245.71 1199.41 1347.09 1339.67 1293.37 6 37 8 43 10 56 10 36 10 10 N 69.07 W .80 9.28N 45.93W N 63.75 W 2.32 14.46N 57.59W N 61.13 W 2.36 22.06N 72.06W N 59.11 W .54 30.84N 87.35W N 51.69 W 1.47 40.58N 101.52W 24.48 33.35 45.45 58.94 72.96 1442.91 143'3.88 1387.58 1538.16 1527.38 1481.08 1633.62 1621.10 1574.80 1729.13 1714.95 1668.65 1824.69 1808.81 1762.51 10 49 11 17 10 35 10 50 10 49 N 39.95 W 2.33 52.73N 113.94W N 26.46 W 2.75 67.93N 123.84W N 17.99 W 1.83 84.64N 130.71W N 18.18 W .25 101.52N 136.22W N 17.65 W .11 118.61N 141.75W 88.63 106.30 124.36 142.10 160.05 1919.21 1901.60 1855.30 2014.56 1995.16 1948.86 2110.13 2088.92 2042.62 2205.82 2182.84 2136.54 2301.68 2276.93 2230.63 11 4 11 12 11 6 10 57 11 6 N 17.06 W .30 135.75N 147.10W N 16.43 W .18 153.39N 152.41W N 16.17 W .12 171.13N 157.60W N 15.73 W .18 188.73N 162.63W N 15.83 W .16 206.38N 167.62W 177.98 196.38 214.82 233.08 251.37 2397.33 2370.78 2324.48 2489.36 2461.04 2414.74 2584.86 2554.68 2508.38 2680.46 2648.45 2602.15 2776.04 2742.32 2696.02 11 11 11 17 11 19 11 8 10 32 N 15.15 W .17 224.21N 172.56W N 14.76 W .13 241.55N 177.19W N 14.11 W .14 259.69N 181.86W N 15.31 W .31 277.71N 186.59W N 19.23 W 1.00 294.88N 191.91W 269.82 287.69 306.33 324.88 342.83 2871.44 2836.10 2789.80 2966.04 2929.07 2882.77 3061.60 3022.98 2976.68 3157.35 3117.05 3070.75 3252.48 3210.51 3164.21 10 37 10 39 10 42 10 43 10 46 N 18.15 W .23 311.47N 197.52W N 17.84 W .07 328.09N 202.92W N 17.36 W .11 344.99N 208.28W N 16.91 W .09 362.00N 213.52W N 16.41 W .11 379.01N 218.61W 360.34 377.80 395.51 413.30 431.01 Alaska 0il & 8~s Cons. Commission Anchorage ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPC-26 500292263400 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 2/96 DATE OF SURVEY: 010996 MWD SURVEY JOB NUMBER: AK-EI-60004 KELLY BUSHING ELEV. = 46.30 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3348.16 3304.48 3258.18 3443.99 3398.58 3352.28 3539.23 3492.13 3445.83 3634.57 3585.78 3539.48 3730.27 3679.77 3633.47 10 57 N 15.52 W .26 396.36N 223.57W 10 50 N 15.32 W .13 413.84N 228.39W 10 44 N 16.01 W .18 431.01N 233.21W 10 53 N 15.64 W .19 448.22N 238.09W 10 46 N 15.53 W .13 465.55N 242.92W 449.01 467.08 484.86 502.71 520.64 3826.23 3774.03 3727.73 3919.74 3865.85 3819.55 3941.00 3886.73 3840.43 4015.25 3959.63 3913.33 4110.91 4053.60 4007.30 10 50 N 14.86 W .15 482.92N 247.64W 10 55 N 14.59 W .11 500.00N 252.13W 10 58 N 13.92 W .62 503.92N 253.12W 10 54 N 13.93 W .10 517.60N 256.51W 10 38 N 13.52 W .29 534.96N 260.76W 538.58 556.16 560.18 574.19 591.96 4206.71 4147.77 4101.47 4302.40 4241.87 4195.57 4398.04 4335.93 4289.63 4419.04 4356.59 4310.29 4493.57 4429.92 4383.62 10 31 N 13.39 W .13 552.06N 264.85W 10 26 N 14.55 W .24 568.95N 269.05W 10 24 N 18.81 W .81 585.50N 274.01W 10 24 N 18.78 W .09 589.09N 275.23W 10 9 N 17.20 W .50 601.75N 279.34W 609.43 626.73 643.98 647.77 661.07 4589.00 4523.86 4477.56 4629.00 4563.25 4516.95 4774.35 4706.38 4660.08 4870.13 4800.70 4754.40 4965.86 4895.03 4848.73 10 6 N 17.57 W .09 617.78N 284.36W 9 56 N 17.33 W .43 624.43N 286.45W 10 6 N 18.40 W .17 648.50N 294.21W 9 54 N 18.86 W .22 664.27N 299.53W 9 41 N 19.30 W .23 679.68N 304.85W 677.85 684.81 710.09 726.72 743.02 5057.89 4985.77 4939.47 5153.49 5080.09 5033.79 5249.09 5174.26 5127.96 5344.67 5268.24 5221.94 5440.07 5362.11 5315.81 9 30 N 19.80 W .23 694.14N 309.99W 9 16 N 20.24 W .25 708.79N 315.33W 10 33 N 20.65 W 1.34 724.21N 321.08W 10 25 N 20.41 W .14 740.50N 327.19W 10 7 N 20.43 W .32 756.45N 333.12W 758.37 773.96 790.41 807.82 824.83 5534.66 5455.29 5408.99 5630.21 5549.52 5503.22 5725.99 5643.92 5597.62 5821.17 5737.62 5691.32 5916.86 5831.89 5785.59 9 44 N 21.45 W .45 771.69N 338.95W 9 17 N 22.27 W .49 786.35N 344.83W 10 8 N 21.85 W .90 801.33N 350.90W · 10 5 N 22.18 W .09 816.83N 357.17W 9 40 N 22.57 W .43 832.01N 363.41W 841.14 856.93 873.09 889.80 906.20 6012.71 5926.41 5880.11 6107.91 6020.37 5974.07 6203.23 6114.51 6068.21 6238.28 6149.15 6102.85 6298.93 6209.10 6162.80 9 25 N 23.47 W .30 846.66N 369.63W 9 8 N 23.84 W .31 860.73N 375.80W 8 50 N 24.34 W .33 874.34N 381.88W 8 47 N 24.38 W .15 879.23N 384.10W 8 39 N 24.60 W .23 887.60N 387.91W 922.09 937.43 952.29 957.65 966.82 ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPC-26 500292263400 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 2/96 DATE OF SURVEY: 010996 MWD SURVEY JOB NUMBER: AK-EI-60004 KELLY BUSHING ELEV. = 46.30 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DGMN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6336.24 6245.94 6199.64 9 26 N 24.80 W 2.12 892.94N 390.36W 6394.84 6303.69 6257.39 10 3 N 24.11 W 1.06 901.98N 394.47W 6488.29 6395.73 6349.43 9 52 N 21.15 W .58 916.89N 400.69W 6583.65 6489.72 6443.42 9 34 N 17.10 W .78 932.10N 405.98W 6679.25 6584.05 6537.75 9 7 N 15.37 W .56 947.02N 410.33W 972.67 982.57 998.72 1014.82 1030.32 6775.00 6678.64 6632.34 8 45 N 15.54 W .38 961.37N 414.29W 6926.59 6828.52 6782.22 8 27 N 16.12 W .21 983.20N 420.48W 7019.29 6920.18 6873.88 8 41 N 13.20 W .53 996.58N 423.97W 7113.17 7012.95 6966.65 8 57 N 9.40 W .68 1010.70N 426.79W 7206.78 7105.48 7059.18 8 26 N 5.45 W .85 1024.73N 428.63W 1045.16 1067.79 1081.55 1095.78 1109.60 7300.25 7198.04 7151.74 7 33 N 3.37 E 1.62 1037.69N 428.92W 7350.25 7247.61 7201.31 7 31 N 3.33 E .06 1044.24N 428.54W 7380.00 7277.10 7230.80 7 31 N 3.33 E .00 1048.12N 428.31W 1121.87 1127.88 1131.46 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1132.26 FEET AT NORTH 22 DEG. 13 MIN. WEST AT MD = 7380 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 339.93 DEG. ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPC-26 500292263400 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 2/96 DATE OF SURVEY: 010996 JOB NUMBER: AK-EI-60004 KELLY BUSHING ELEV. = 46.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -46.30 .00 N .00 E 1000.00 997.88 951.58 10.69 N 49.61 W 2000.00 1980.87 1934.57 150.68 N 151.61 W 3000.00 2962.45 2916.15 334.07 N 204.84 W 4000.00 3944.65 3898.35 514.80 N 255.82 W .0O 2.12 2.12 19.13 17.00 37.55 18.43 55.35 17.79 5000.00 4928.69 4882.39 685.10 N 306.76 W 6000.00 5913.88 5867.58 844.75 N 368.80 W 7000.00 6901.11 6854.81 993.74 N 423.31 W 7380.00 7277.10 7230.80 1048.12 N 428.31 W 71.31 15.97 86.12 14.81 98.89 12.76 102.90 4.01 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPC-26 500292263400 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 2/96 DATE OF SURVEY: 010996 JOB NUMBER: AK-EI-60004 KELLY BUSHING ELEV. = 46.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -46.30 46.30 46.30 .00 146.30 146.30 100.00 246.31 246.30 200.00 346.32 346.30 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .06 S .72 W .00 .00 .07 S 1.80 W .01 .01 .08 S 3.41 W .02 .01 446.36 446.30 400.00 -546.46 546.30 500.00 646.65 646.30 600.00 746.98 746.30 700.00 847.50 846.30 800.00 .06 S 6.05 W .06 .04 .12 S 10.48 W .16 .10 .34 S 16.63 W .35 .19 .83 N 24.59 W .68 .33 4.98 N 33.92 W 1.20 .52 948.08 946.30 900.00 1048.92 1046.30 1000.00 1150.37 1146.30 1100.00 1252.16 1246.30 1200.00 1353.83 1346.30 1300.00 8.55 N 44.02 W 13.62 N 55.89 W 21.43 N 70.93 W 30.89 N 87.45 W 41.32 N 102.45 W 1.78 .57 2.62 .85 4.07 1.45 5.86 1.80 7.53 1.66 1455.55 1446.30 1400.00 1557.45 1546.30 1500.00 1659.25 1646.30 1600.00 1761.05 1746.30 1700.00 1862.86 1846.30 1800.00 54.59 N 115.43 W 71.31 N 125.52 W 89.12 N 132.17 W 107.22 N 138.10 W 125.44 N 143.92 W 9.25 1.73 11.15 1.90 12.95 1.80 14.75 1.80 16.56 1.81 1964.76 1946.30 1900.00 2066.69 2046.30 2000.00 2168.60 2146.30 2100.00 2270.46 2246.30 2200.00 2372.38 2346.30 2300.00 2474.33 2446.30 2400.00 2576.31 2546.30 2500.00 2678.27 2646.30 2600.00 2780.08 2746.30 2700.00 2881.82 2846.30 2800.00 144.12 N 149.66 W 163.10 N 155.27 W 181.92 N 160.71 W 200.59 N 165.98 W 219.54 N 171.29 W 238.71 N 176.44 W 258.06 N 181.45 W 277.31 N 186.48 W 295.57 N 192.15 W 313.29 N 198.11 W 18.46 1.89 20.39 1.94 22.30 1.90 24.16 1.86 26.08 1.92 28.03 1.95 30.01 1.98 31.97 1.96 33.78 1.82 35.52 1.73 2983.57 2946.30 2900.00 3085.34 3046.30 3000.00 3187.12 3146.30 3100.00 3288.91 3246.30 3200.00 3390.76 3346.30 3300.00 331.18 N 203.91 W 349.20 N 209.59 W 367.30 N 215.13 W 385.54 N 220.54 W 404.16 N 225.74 W 37.27 1.75 39.04 1.77 40.82 1.78 42.61 1.79 44.46 1.85 ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPC-26 500292263400 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 2/96 DATE OF SURVEY: 010996 JOB NUMBER: AK-EI-60004 KELLY BUSHING ELEV. = 46.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 3492.58 3446.30 3400.00 3594.37 3546.30 3500.00 3696.20 3646.30 3600.00 3798.00 3746.30 3700.00 3899.82 3846.30 3800.00 4001.68 3946.30 3900.00 4103.48 4046.30 4000.00 4205.21 4146.30 4100.00 4306.91 4246.30 4200.00 4408.58 4346.30 4300.00 4510.21 4446.30 4400.00 4611.79 4546.30 4500.00 4713.33 4646.30 4600.00 4814.90 4746.30 4700.00 4916.42 4846.30 4800.00 5017.87 4946.30 4900.00 5119.25 5046.30 5000.00 5220.65 5146.30 5100.00 5322.36 5246.30 5200.00 5424.01 5346.30 5300.00 5525.54 5446.30 5400.00 5626.95 5546.30 5500.00 5728.40 5646.30 5600.00 5829.98 5746.30 5700.00 5931.47 5846.30 5800.00 6032.87 5946.30 5900.00 6134.18 6046.30 6000.00 6235.40 6146.30 6100.00 6336.60 6246.30 6200.00 6438.11 6346.30 6300.00 6539.61 6446.30 6400.00 6641.02 6546.30 6500.00 6742.28 6646.30 6600.00 6843.46 6746.30 6700.00 6944.57 6846.30 6800.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 422.64 N 230.82 W 440.91 N 236.03 W 459.41 N 241.21 W 477.79 N 246.28 W 496.35 N 251.18 W 515.10 N 255.90 W 533.63 N 260.44 W 551.80 N 264.78 W 569.74 N 269.25 W 587.31 N 274.62 W 604.56 N 280.21 W 621.58 N 285.56 W 638.35 N 290.83 W 655.25 N 296.46 W 671.80 N 302.10 W 687.92 N 307.75 W 703.61 N 313.42 W 719.33 N 319.24 W 736.72 N 325.78 W 753.81 N 332.14 W 770.25 N 338.38 W 785.86 N 344.63 W 801.73 N 351.06 W 818.26 N 357.75 W 834.28 N 364.36 W 849.69 N 370.95 W 864.55 N 377.49 W 878.83 N 383.91 W 892.99 N 390.39 W 908.87 N 397.56 W 925.10 N 403.82 W 941.17 N 408.72 W 956.56 N 412.96 W 971.40 N 417.08 W 985.75 N 421.21 W MD-TVD VERTICAL DIFFERENCE CORRECTION 46.28 1.82 48.07 1.79 49.90 1.83 51.70 1.80 53.52 1.83 55.38 1.85 57.18 1.80 58.91 1.73 60.61 1.69 62.28 1.68 63.91 1.63 65.49 1.58 67.03 1.53 68.60 1.57 70.12 1.52 71.57 1.45 72.95 1.38 74.35 1.40 76.06 1.71 77.71 1.65 79.24 1.54 80.65 1.40 82.10 1.46 83.68 1.58 85.17 1.49 86.57 1.40 87.88 1.31 89.10 1.22 90.30 1.21 91.81 1.51 93.31 1.50 94.72 1.40 95.98 1.27 97.16 1.18 98.27 1.11 ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SH3LRED SERVICES DRILLING MILNE PT/MPC-26 500292263400 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 2/96 DATE OF SURVEY: 010996 JOB NUMBER: AK-EI-60004 KELLY BUSHING ELEV. = 46.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANG~ COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7045.71 6946.30 6900.00 1000.47 N 424.89 W 99.42 1.15 7146.94 7046.30 7000.00 1015.89 N 427.65 W 100.64 1.22 7248.04 7146.30 7100.00 1030.72 N 429.15 W 101.74 1.11 7348.93 7246.30 7200.00 1044.06 N 428.55 W 102.63 .89 7380.00 7277.10 7230.80 1048.12 N 428.31 W 102.90 .27 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS RECEIVED NOV ~ 6 1996 Alaska Oil & Gas Cons. Commissior, Anchorage TO: 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) August 29, 1996 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the Depth Shifted CDR, CDR TVD for well MPC-26 Job # 96055 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape 3 Bluelines each 1 Film each 1 Depth shift display State of Alaska Alaska Oil & Gas Conservation Comm. Attn' Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 .. ! OH LIS Tape ,, .... -___. 1 Blueline each ---.... 1 RF Sepia each \ OXY USA, Inc Attn: Darlene Faidy P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail Z 777 937 464 .NOTE: NO DEPTH SHIFT PER MATT LINDER PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA) INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 Schlumberger Courier: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 RECEIVED Date Delivered:SEP 05 '~,,PO Received By: .~. ¢~~/ Alaska 0il & G~ Cons. Commission, Anchorage HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 7 June 1996 Transmittal of Data ECC #: 6559.04 Sent by: HAND CARRY Data: GR/CCL Dear Sir/Madam, Reference: MPC-26 MILNE POINT / KUPARUK NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PFC/PERF FINAL BL+RF Run # 1 1 GR/CCL FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by: Date: AlAska Oil & Gas Cons. Commission A~chorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP MPC-26 MILNE POINT / KUPARUK NORTH SLOPE, AK Enclosed, please find the data as described below: Date: RE: Prints/Films: 1 GR/CCL FINAL BL+RF Run # 1 13 May 1996 Transmittal of Data ECC #: 6559.03 Sent by: HAND CARRY Data: GR/CCL Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 (907) 563-7803 Received by: . Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 18 January 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ~~0~ MPC-26 ~0~ 1 LDWG TAPE+LIS ECC No. Run ~ 1 6559.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, ~ 99518 ~~ Or F~ to (907) 563-7803 Received by: ~ Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 16 January 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: 1 GR/CCL FINAL BL+RF ECC No. Run # 1 6559.01 Run # 1 6559.02 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 AX to (907) 563-7803 Received by: Date: - \ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP MPC-26 MILNE POINT / KUPARUK NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Date: RE: 1 ZDL/CN FINAL BL+RF Run # 1 1 DIFL FINAL BL+RF Run # 1 1 BH PRO FINAL BL+RF Run # 1 1 SSVD FINAL BL+RF Run # 1 16 January 1996 Transmittal of Data ECC #: 6559.00 Sent by: HAND CARRY Data: OH-LDWG Received by:. Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 to (907) 563-7803 Date: JA~ 2 6 A. la.-:ka Ofi ~ ~3as 0o~.$. Commiss.br~, A,qcho~age MEMORANDUM TO: THRU: DaVid Chairmah State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 9, 1996 Blair Wondzell, P. I. Supervisor /- FROM' Lou Grimaidi, :....,.~ SUBJECT: Petroleum Inspector FiLE NO: AWOJAHDD.doc BOPE Test, Nabors 22E BPX, Milne Point Unit Well MPU MPC-26 PTD #95-206 Friday, January 8', 1996: I traveled to BPX's Milne Point Unit to witness a BOPE test on Nabors 22E drilling well #MPU C-26 i arrived at 0600 AM and the test got underway at 0730 and ended approximately 1030 in the morning. There were 2 valves on the choke manifold that failed to hold their pressure test. one had a body leak at the grease fitting and the other although holding a high pressure test failed its Iow pressure test. The grease fitting was changed out and the other valve was cycled and both retested "OK". The Methane and H2S detectors were tested and worked fine. The rig was cold on the rig floor but Laverne Linder (Nabors Toolpusher) explained to me that they had just finished E-Line logging and had had the rig floor doors open most of the previous night. I toured the rig and found the rest of the rig to be warm even though the outside temperature was -40 F. The area surrounding the rig was orderly and well kept. Summary: I witnessed a BOPE test on Nabors 4ES drilling well #MPU C-26. The test lasted 3 hours and there were 2 failures. Attachment: AWOJAHDD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: Nabors Rig No. 22E PTD # 95-206 BPX Rep.: MPC-26 Rig Rep.: Set @ Location: Sec. Weekly X Other DATE: Rig Ph.# Dave Mountjoy 1/8/96 659-4454 Laveme Linder 10 T. 13N R. IOE Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves 1 HCR Valves 2 Kill Line Valves Check Valve Well Sign P Drl. Rig P Hazard Sec. P Test Press. P/F 250/3,000 P 25O/5,000 P 250/5,000 P 250/5,00O P P 250/5,000 250/5,000 1 250/5,000 P N/A 250/5, 000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan Pressure P/F 1 250/5, 000 P 250/5,000 P 250/5, 000 P 250/5, O0O P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 18 250/5,000 F 42 250/5,000 P 2 P Functioned Func~oned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn, Btl's: Eight BoNes 3,100 1,500 minutes 33 sec. minutes 20 sec. P Remote: P 2000 avemge Psig. TEST RESULTS Number of Failures: '/ ,Test Time: 3.0 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within N/A 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 REMARKS: Grease fitting on choke manifold leaked. #16 valve leaked on Iow pressure test, cycled and retsted "OK" ~'' Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R. Grirnaldi FI-021L (Rev. 12/94) AWOJAH DD.XLS MEMORANDUM State of Alaska TO: Alaska Oil and Gas Conservation Commission DATE: December 28,1995 THRU: Blair Wondzell, :.;E.~,. FILE NO: P. I. Supervisor FROM: John Spauid ing,..v;', SUBJECT: Petroleum Insp. ewoll2cd.doc Diverter Function Test Nabors 22E BPX MPU well MPC-2'~ ~ Kuparuk River Field PRD 95-206 Thursday December 28, 1995: ! traveled this date to BPX's Milne Point Unit to witness thi9 Diverter Function Test on Nabors rig 22E. The test report is attached for reference. All portions of the diverter system was found to be in compliance with AOGCC regulations. The air supply line for the accumulator had an abundant supply of water which affected the operation of the accumulator air pump. The air line is used to blow down the boilers prior to moving the rig, and apparently water entered the line. This problem is being addressed with the addition of a manual valve near the blow down line. Summary' i witnessed the successful Diverter Function Test on Nabors 22E, no failures. Attachments: ewoll2cd.xls Drlg Contractor: Operator: Well Name: Location: Sec. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Nabors BPX MPC-26 10 T. 13N R. Operation: Rig No. Oper. Rep.: Rig Rep.: 10E Development 22E PTD # X Exploratory: 95-206 Rig Ph. # Dave Mountjoy Leonard Schiller Merdian Umiat 659-4454 TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok Reserve Pit: na (Gen.) DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Turns Targeted / Long Radius: Well Sign: Drlg. Rig: Flare Pit: 2O yes yes 10 75~' yes yes yes yes ok ok na in. in. ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 8 @ 2100 average 3OOO 1900 32 min. 26 MUD SYSTEM INSPECTION: Light Alarm Trip Tank: ok ok Mud Pits: ok ok Flow Monitor: ok ok GAS DETECTORS: Light Alarm Methane ok ok Hydrogen Sulfide: ok ok psig psig sec, sec, psig DIVERTER SCHEMATIC Production Facilities ~gcamp South sub-base ~ Mud pits i~ipe shed motors · North Wind direction Existing wells and towlines /' 10" vent line bifurcated and valved at bifurcation Entrance to pad area Distribution orig. - Well File c - Oper/Rep c- Database C - Trip Rpt File c - Inspector AOGCC REP.: OPERATOR REP.' FI-022 EWOLL2CD.XLS TONY KNOWLE$, GOVERNOR ALASI OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 19, 1995 Tim Schofield, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Milne Point Unit MPC-26 BP Exploration (Alaska), Inc. ' 95-206 1085'NSL, 2419'WEL, Sec 10, T13N, R10E, UM 2180'NSL, 2900'WEL, Sec 10, T13N, R10E, UM Dear Mr. Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to ddil does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test.performed before ddlling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Chairman BY ORDER OF THE COMMISSION dlf/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill I-Illb. Type of well. Exploratoryl-I 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. KBE = 42 feet Milne Point / Kuparuk River 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047434 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1085' NSL, 2419' WEL, SEC. 10, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 2112'NSL, 2876' WEL, SEC. 10, T13N, RIOE MPC-26 2S100302630-277 At total depth 9. Approximate spud date Amount 2180' NSL, 2900' WEL, SEC. 10, T13N, RIOE 12/20/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 025516 2180 feet No Close Approach feet 2560 7542' MD / 7430' 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 ~o.6 o Maximum sudace 3301 psig At total depth (TVD) 7000'/3998 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' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# -' L-80 Btrc 4671' 31' 31' 4 702' 4639' 918 sx PF 'E', 250 sx 'G; 150 sx PF 'E' 8-1/2" 7" 26# L-80 Btrc 7512' 30' 30' 7542' 7430' 240 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 ~EC ] 3 1~' Production Liner ~aska Oi~ & G,~s Cons. -"':". Perforation depth: measured ,~ch. or~g~ true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify thatLhe f~regoingl i~ true and correct to the best of my knowledge Signed '~-~.-fr)~ ~-~--'~'CJ~' "" Title Senior Drillin~ En~Tineer Date Commission Use Only !Permit Number ~PI number IApproval date See cover letter 15o- ? -- %~,~).~ for other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required []Ybs ~ No Hydrogen sulfide measures [] Yes ];~ No Directional survey required ~] Yes [] No Required working pressure foro~l~} ~j~ ~[~3M; ~SM; []1OM; ID15M; Other: by order of /,;~/~/ Approved by David W. Johnston Commissioner me commission Date, Form 10-401 Rev. 12-1-85 Submit in I Well Name: IMP C-26 Well Plan Summary IType of Well (producer or injector)' IKuparuk Producer Surface Location: 1085 NSL 2419 WEL Sec 10 T13N R10E UM., AK Target Location: 2112 NSL 2876 WEL Sec 10 T13N R10E UM., AK Bottom Hole 2180NSL2900WELSec 10T13N R10E UM.,AK Location: IAFE Number: 1337003 I IEstimated Start 120DEC95 IDate: I Rig: I Nabors 22-E- I Operating days to I10 complete' IWell Design (conventional, slimhole, etc.): Milne Point Ultra Slimhole:9-5/8" SURFACE CASING X 7" LONGSTRING Formation Markers: Formation Tops MD TVD (bkb) .,base permafrost 1,856 1,842 NA 4,278 4,222 · Top of Schrader Bluff Sands (8.3 ppg) Seabee Shale 4,552 4,492 Base of Schrader Bluff Sands (8.3 ppg) HRZ 6,559 6,465 High Resistivity Zone Top Kuparuk 6,8 6 4 6,7 6 5 Kuparuk Cap Rock Target Sand -Target 7,1 4 4 7,0 4 0 Target Sand (9.6 ppg) Total Depth 7,5 4 2 7,4 3 0 Casing/Tubing Pro~ ram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 1 12/1 12 12 1/4" 9-5/8" 40# L-80 btrc 4,671 31/31 4,702/4,639 8 1/2" 7" 26# L-80 btrc 7,512 30/30 7,542/7,430 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 3998 psi is 3301 psi, well below the internal yield pressure rating of the 7" casing. Logging Program- Open Hole Logs: Surface MWD Directional and LWD GR/RES Intermediate N/A Final Cased Hole Logs: MWD Directional and LWD (GR/CDR/CDN). Mudloggers are NOT required for this well. None-SPUD MUD Mud Program: ISpecial design considerations Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 100 15 8 10 9 8 to to to to to to to 9.0 50 35 1 5 30 1 0 1 5 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 1 0 3 7 8.5 6 - 8 to to to to to to to 10.4 50 1 5 1 0 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 KOP: I 00' Maximum Hole Angle: Close Approach Well: I0'6° (No Shut Ins) Disposal: Cuttings 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. Request to AOGCC for Annular Pumping Approval for MP C-26: 1. Approval is requested for Annular Pumping into the MP C-26, 9-5/8" x 7" casing annulus and any well on the pad/drillsite previously permitted for disposal activities by AOGCC. 2. The base of the Permafrost for all wells located in the Milne Point Unit is ___1,850' TVD. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by 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 4,702' md (4,639 tvd) which is a minimum of 500' tvd below the Permafrost and into the Seabee/Colville formation which has an established history of annular pumping at Milne Point. 4. There are _+21 wells on Milne Pt. 'C' Pad. There may be additional unidentified wells within one quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. The wastes to be disposed of during drilling operations can be defined as "DRILLING WASTES". The burst rating (80%) for the 9-5/8" 40# LB0 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Prince Creek formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping regardless of fluid density is 2000 psi as per Shared Services Drilling "Recommended Cuttings Injection Procedure". A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7/24/95 which demonstrates the confining layers, porosity, and permeability of the injection zone. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. . . , ANNULAR INJECTION: THE FOLLOWING MILNE PT. 'C' PAD WELLS HAVE BEEN PERMITTED FOR ANNULAR INJECTION FOR 1995 AREA WELL PREV VOL PERMITTED PERMITTED I NJ ECTED VOL DATES (BBLS) (BBLS) Milne Point 1JAN95-31DEC95 Milne Point 1JAN95-31 DEC95 Milne Point 1JAN95-31 DEC95 Milne Point 1JAN95-31 DEC95 Milne Point 1JAN95-31 DEC95 Milne Point 1JAN95-31 DEC95 Milne Point 1JAN95-31 DEC95 Milne Point 1JAN95-31 DEC95 DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. MAXIMUM EXPECTED FLUID DENSITY IS 17.0 PPG BURTST PRESSURE 9-5/8" 40# L-80 CASING: 5750 PSI COLLAPSE 7", 26#, L-80 CASING: 5410 PSI 9-5/8" SURFACE CASING SHOE DEPTH: 4,702' MD/4,639' TVD HYDROSTATIC PRESSURE @ 4,639 TVD WITH VARIOUS DENSITY FLUIDS: (0.052) X (4639) X (FLUID DENSITY) = HYDROSTATIC PRESSURE 80% OF 7' COLLAPSE PRESSURE = (5410 PSI) X (0.8) = 4328 PSI MAXIMUM ALLOWABLE INJECTION PRESSURE 2000 PSI AT ANY PPG SURFACE CASING SHOE DEPTH (-I-VD): 4,6 3 9 HYDROSTATIC MAXIMUM ALLOWABLE PRESSURE AT SURFACE 7" COLLAPSE ANNULAR INJECTION FLUID DENSITY CASING SHOE DEPTH PRESSURE (80%) SURFACE PRESSURE (PPG) (PSI) (PSI) (PSI) 8 1929.82 4328 2000 9 2171.05 4328 2000 1 0 2412.28 4328 1 916 1 1 2653.51 4328 1 674 1 2 2894.74 4328 1433 1 3 31 35.96 4328 1 1 92 1 4 3377.19 4328 951 1 5 3618.42 4328 71 0 1 6 3859.65 4328 468 1 7 41 00.88 4328 227 MAX ALLOWABLE INJECTION PRESSURE = 4328 PSI - HYDROSTATIC PRESSURE or 2000 psi (whichever is less). , . . . . . . . . 10. 11. 12. 13. 14. MP C-26 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Run Directional/Gamma Ray/Resistivity MWD/LWD across Schrader Bluff sands. Run and cement 9-5/8" casing. ND 20" Diverter, NU and Test 13-5/8" BOPE. MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 10' of new formation. Perform FIT to 12.5 ppg. Drill 8.5" hole to TD as per directional plan. Run and Cement 7" Casing. Displace cement with seawater and enough diesel to cover from the base of permafrost to surface. Test casing to 3500 psig. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. Perforate and Stimulate in absence of rig. Displace well with 10.2 ppg brine and set a wireline retrievable bridge plug. MIRU Nabors 4ES or Polar 1 Rig. NU & Test BOPE to 5000 psig. Complete well with 3-1/2" tubing and packer hookup. Install Surface Lines and Wellhouse and put the well on production. Drillin~l Hazards and Risks: 1. The Kuparuk reservoir sands are expected to be a maximum of 3500 psig or 9.6 ppg. The closest injection well is Milne Pt. Well# C-lOi. Although the bottom hole locations will be more than 2000' apart; as a precaution surface casing will be deep set and cover the Shcrader Bluff Sands. 2. See the Milne Point C-Pad Data Sheet prepared by Pete Van Dusen for a general recap of wells drilled by Conoco on C-Pad plus wells recently drilled by BPX. 3. There will be no close approach wells associated with the drilling of Milne Pt. Well# C-26. 4. No GYRO or IN-HOLE REFERENCE GYRO will be required to be run in this wellbore. LOST ClRCULATION: There were no reports of lost circulation while DRILLINGin the production intervals. However, Milne Pt. "C' Pad was developed in the early to mid 1980's with virgin reservoir pressures. Several wells at Milne Pt. 'C' Pad have experienced partial to full lost returns while running, circulating and cementing 7" casing. Have the LCM materials outlined in the Drilling Fluid Program on location and recommended pills ready to address the Lost Circulation Problem when drilling into the Kuparuk Sand. Stuck Pipe Potential: Stuck pipe has occurred on 2 wells on this pad in the Schrader Bluff Sands. These wells and the corresponding depths at which they were stuck were: C- 09 @ 4,427' ss with a mudweight of 9.4 ppg. Milne Pt. 3,911' ss with 9.2 ppg mudweight. ~.~"~~-¥ ~.~ ~chorage Gas hydrates: Although hydrates were encountered on E, H, and Pads, no hydrates are expected on Milne Pt. 'C' pad. No hydrates were encountered during the recent drilling of MP C-21 and MP C-22. 4. No other drilling hazzards or risks have been identified for this well. CASING SIZE: 9-5/8" MP C-26 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CIRC. TEMP 50 deg F at 2500' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE' ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 918 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: 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 WEIGHT: 12.0 ppg APPROX NO SACKS: 150 YIELD:2.17 ft3/sx 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 (15 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 618' 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. 3. 80'md 9-5/8", 40# capacity for float joints. 4. Top Job Cement Volume is 150 sacks. MP C-26 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140° F BHST 170° 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.Sppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 240 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: , , 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 22 joints of 7" casing. This will cover 300' above the KUPARUK C1 Sand (44 total). Run two 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9- 5/8" casing shoe. 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 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: . Stage 1 cement volume is calculated to cover 1000' md above the Kuparuk Target Sand with 30% excess. Dec-ll-gB 10:19 Anadrill DPC t . 907 344 2160 P.04 SHARED- ERVICES DRILLING · i i i III I Il [ Il [ Il I .. MPC-26 (P4) VERTICAL SECTION VIEW · __ Section at; 339.95 ~ TVD Scale.' ~ ~nch = ~000 feel <KB> o-- A Dep Scale.' ~2/~0/95J inch : JO00 feet I ~ DPawn · , 500- - B .............. " ......... ' ~nadrj ]] Sch]umberg~r : m I i i i I _ ~000-- : .... Marker Identification MD BK8 SECTN INCLN C ' - A) KB 0 0 0 0.00 O ' B) KOP/BUILD ~.5/]00 500 500 0 0.00 i C) BUILD 2.5/~00 1100 ~OgB 30 9.00 ]500 ........ E, ' ..... D) CURVE 2.5/~00 1200 ]196 42 li.50 , E) END 2,5/100 CURVE 1572 1562 lO0 20.57 .... . . %~.~m~r.~.~i F) 9-5/B CASING POINT 4702 4639 674 ~0.57 2000--' ! Gl TARGET 7144 7040 1122 ~0.57 i HI 7" CASING PDINT 7542 7430 1J95 ]0.57 I) TO 7542 7430 1195 ~0.57 · K NA RI! ' Al<A-DPC 8 3ooo I' , ~r r ~v · Bu i ' FOR PERMi~-TIN~ 3500 ............................. F'i K I ! .V ~.~i ~l L. I ............ I" ,ooo- ; i PLAN ¢¢ 7''~'~,.' :: ,,oo "~' -':' =::i ='-'-'--'-i ............... I ....... j " 5000 . , i ' ' 6000- ~=~......_ ,..,].=~ ~=._.: ~ ~, ~ · :li¢:t~t -{-_- -- _--_--:=_-- :,.,.,_; _--::==.. = .:;:====-= = ---. 7500 ............... I .4- .. " -iooo -500" 0 .500 looo ~500 ~000 2500 3000 3500 4000 4500 5000 5500 6000 --. ..... " S~.ct ion Departure Dec-11-95 10:19 Anadrill DPC '907 344 2160 ~P.05 !' SHARED' -SERVICES DRILLING i ii ii Marker Identification MO' N/S ~, ~ o o o MPC-26 (P4) ~o~/~u~ ,.~/,oo soo o o ~I BUILD 2.5/100' "00 '6 ~4 PLAN VIEW CUnVE 2.5/~00 t200 22 6~ -- ~I END 2.5/~00 CURVE ~572 67 i08 CLOSURE ..... : 1~97 feet at Azimuth 336 F) 9-5/8' CASING POINT · 4702 606 304 · G) TARGET 7~44 : $027 458 DECLINATION.' +0.000 (E) ~ TO7" CASING POINT 75427542 ~0~6~°~ 483483 SCALE · ~ inch: 200 feet DRAWN ' 12/10/95 m Xnadri ] ] ~ch]umberger . " , / ~2oo ............................. 1~00 I ~00 FI Tt~RGET RACmlUS I , ' .~ .... t0o0 ~ ~~ ................. ~o0 , ~ 800 . .......... ~ -- ; ....~., i " .................. 700 I ANA DRILL A~ [,)PC I , ~,PPRI)VEE -~ '~" FORPER}AITilNGi' ~~oo ·q00 I ' ~ ................. 300 , ' ' ~E 100 ~-0 .. 1300 1~00 1100 1000 ~00 800 700 800 fi00 400 300 · '- WEST ' EAST -> (~ad~lll [C]~ C~6P4 2.5~.03 4:43 ~ P) WELL PERMIT CHECKLIST WELL NAME GEOL AREA PROGRAM: exp [] // dev~ redrll [] serv [] ADMINISTRATION ENGINEERING 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............ 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. 10. Operator has appropriate bond in force ........ 11. 12. 13. . ~Y N f N f N £ N Permit can be issued without conservation order .... ~ N Permit can be issued without administrative approval. ~ N Can permit be approved before 15-day wait ....... DATE 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... ~ N 23. If diverter required, is it adequate .......... N 24. Drilling fluid program schematic & equip list adequate N 25. BOPEs adequate .................... -~Y~ N 26. BOPE press rating adequate; test to ~-~ psig'~ N 27. Choke manifold complies w/API RP-53 (M~y 84) ...... ~-Y----'-N-~/~ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N REMARKS GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 32. Seismic analysis of shallow gas zones .......... Y/ N 33. Seabed condition survey (if off-shore) ........ / N 34. Contact name/phone for weekly progress reports .... /. Y N [exploratory only] ENGINEERING: JDH ~ COMMISSION: DWJ ~ Comments / Instructions: HOW/ljb - A:%FORMS%cheklist rev 11/95 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. MPC - 26 MILNE POINT // / ----_ ~ 6480 7376 Tape Subfile 2 is type: L~S TAPE HEADER MILNE POINT UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: MPC - 26 500292263400 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 17-JAN-96 RUN 1 6559.00 J. DAHL D. MOUNTJOY RUN 2 RUN 3 10 13N 10E 1085 2419 45.40 45.40 16.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 6882.0 6.000 7380.0 DIFL/ZDL/CN/GR. CIRCULATION STOPPED @ 2030, 07-JAN-96. BARITE PRESENT IN MUD SYSTEM (17.6%) CAN EFFECT PE RESPONSE. AFTER LOG GR VERIFICATION NOT DONE DUE TO TOOL QUITTING WHILE COMING OUT OF THE HOLE. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CALIPER CORRECTED. THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR DIL SDN 2438 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 6884.0 7320.0 6884.0 7376.0 6884.0 7343.0 6884.0 7325.0 BASELINE DEPTH LL8 6886.0 6893.5 6899.0 6927.0 6927.5 6927.5 all EQUIVALENT UNSHIFTED DEPTH ILD RHOB NPHI 6885.5 6893.0 6898.0 6927.0 6927.5 6928.0 6940.0 6954.0 6953.5 6953.5 6965.5 6972.0 6972.5 6972.0 6971.5 6976.5 6976.0 6982.5 6983.0 6982.5 6982.5 6988.5 6990.5 6992.5 6991.5 6991.5 6994.5 6996.5 6996.0 6996.0 7009.0 7021.0 7030 . 0 7030 . 0 7030 . 0 7038.5 7039 . 0 7039 . 0 7039 . 0 7049.0 7049.5 7049.5 7054.0 7053.5 7053.5 7058.5 7058.5 7058.5 7068.0 7073.5 7073.5 7073.5 7075.5 7076.5 7076.0 7076.0 7079.5 7079.5 7079.5 7088.5 7088.0 7088.0 7093.0 7092.5 7092.5 7098.5 7104.5 7104.0 7104.0 7107.0 7111.0 7126.5 7140.0 7139.5 7139.5 6928.5 6940.5 6954.0 6972.0 6939.5 6965.0 6972.5 6976.5 6982.5 6997.0 7039.5 7049.5 7054.0 6988.5 6990.0 6992.0 6994.5 6996.5 7009.5 7020.5 7030.0 7038.5 7049.5 7054.0 7073.5 7068.0 7073.5 7075.0 7080.0 7079.0 7093.0 7093.0 7098.5 7098.5 7104.5 7106.5 7111.0 7127.0 7140.5 runs merged; no case 7145 7146 7154 7155 7170 7187 7199 7199 7208 7208 7209 7212 7223 7246 7268 7272 7298 7301 7306 7320 .5 .0 .5 .0 .0 .5 .0 .5 .0 .5 .0 .0 .0 .5 .0 .5 .0 .0 .5 .0 MERGED DATA SOURCE PBU TOOL CODE GR DIL SDN 2438 $ REMARKS: 71eJ. 5 7145.5 7146.0 7155.0 7155.0 7155.5 7170.5 7199.0 7199.0 7208.5 7200.0 7208.5 7223.5 7319.5 7301.0 7145.5 7155.0 7187.5 7199.0 7208.0 7212.5 7246.5 7268.0 7273.0 7298.0 7306.5 RUN NO. PASS NO. MERGE TOP 1 3 6884.0 1 3 6884.0 1 3 6884.0 1 3 6884.0 OPEN HOLE portion of MAIN PASS. MTEM, SP, TEND, & TENS WERE SHIFTED WITH ILM, RT, & DI WERE SHIFTED WITH ILD. DRHO, PEF, & CALl WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. LL8 . MERGE BASE 7320.0 7376.0 7343.0 7325.0 CN WN FN COUN STAT / ? ?MATCH1. OUT / ? ?MATCH2. OUT /? ?MATCH3. OUT / ? ?MATCH4. OUT : BP EXPLORATION (ALASKA) : MPC - 26 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 GR DIL 68 1 GAPI 4 2 LL8 DIL 68 1 OHMM 4 3 ILM DIL 68 1 OHMM 4 4 ILD DIL 68 1 OHMM 4 5 RT DIL 68 1 OHMM 4 6 DI DIL 68 1 IN 4 7 MTEM DIL 68 1 DEGF 4 8 SP DIL 68 1 MV 4 9 TEND DIL 68 1 LB 4 10 TENS DIL 68 1 LB 4 11 RHOB SDN 68 1 G/C3 4 12 DRHO SDN 68 1 G/C3 4 13 PEF SDN 68 1 BN/E 4 14 CALl SDN 68 1 IN 4 15 NPHI 2438 68 1 PU-S 4 16 FUCT 2438 68 1 CPS 4 17 NUCT 2438 68 1 CPS 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 73 4 08 310 01 4 08 995 99 4 08 995 99 4 08 995 99 4 08 995 99 4 08 995 99 4 08 995 99 4 08 995 99 4 08 995 99 4 08 995 99 4 49 995 99 4 49 995 99 4 49 995 99 4 49 995 99 4 36 995 99 4 36 995 99 4 36 995 99 68 Tape File Start Depth = 7392.000000 Tape File End Depth = 6884.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 18307 datums Tape Subfile: 2 238 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH $ BASELINE CURVE FOR SHIFTS: START DEPTH 6480.0 STOP DEPTH 6884.0 CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIPTED DEPTH BASELINE DEPTH $ REMARKS: CASED HOLE portion of MAIN PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPC - 26 : 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 GRCH GR 68 1 GAPI 4 2 TEND GR 68 1 LB 4 3 TENS GR 68 1 LB 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 18 4 30 310 01 1 4 30 635 99 1 4 30 635 99 1 12 Tape File Start Depth = 6884.000000 Tape File End Depth = 6318.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4533 datums Tape Subfile: 3 45 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 presented first (primary depth control string used for depth shifting) followed by files for other main pass tool strings per run. other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 3 .2500 VENDOR TOOL CODE START DEPTH GR 6480.0 DIFL 6850.0 ZDL 2438 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 6850.0 6850.0 STOP DEPTH 7334.0 7389.0 7363.0 7344.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT COMR GR CN ZDL SLAD DIFL $ CABLEHEAD TENSION COMMON REMOTE GAMMA RAY COMPENSATED NEUTRON Z- DENS I LOG/CALI PER SLAM ADAPTER DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : 08-JAN-96 ECLIPS 2.1 2030 07-JAN-96 0615 08-JAN-96 7380.0 7378.0 6480.0 7376.0 1500.0 TOOL NUMBER 3981XA 3510XA 1329XA 2438XA 2228XA 3516XA 1503XA 6.000 6882.0 6884.0 LSND 13.60 47.0 9.0 4.4 152.0 1.760 .760 66.0 152.0 MUD FILTRATE AT MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPC - 26 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA .}10 .000 3.310 .000 THERMAL SANDSTONE 2.65 .000 1.0 77.0 .0 76.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 27 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 Name Tool Code Samples Units GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM RT DIFL 68 1 OHMM DI DIFL 68 1 IN CFOC DIFL 68 1 MMHO CILM DIFL 68 1 MMHO CILD DIFL 68 1 MMHO SP DIFL 68 1 MV WTBH DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN HRD1 ZDL 68 1 CPS HRD2 ZDL 68 1 CPS SFT2 ZDL 68 1 CPS SOFT ZDL 68 1 CNC 2438 68 1 PU-S CNCF 2438 68 1 PU-S CN 2438 68 1 PU-L LSN 2438 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 07 310 01 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 120 46 1 4 07 120 44 1 4 07 210 06 1 4 07 110 44 1 4 07 110 46 1 4 07 010 01 1 4 07 995 99 1 4 07 635 99 1 4 07 635 99 1 4 07 636 99 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 280 99 1 4 46 354 02 1 4 46 354 01 1 4 46 354 99 1 4 46 354 99 1 4 36 995 99 1 4 36 995 99 1 4 36 890 01 1 4 36 334 31 1 27 SSN 2438 68 1 CPS 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 478 4 36 334 30 108 Tape File Start Depth = 7392.000000 Tape File End Depth = 6318.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 138624 datums Tape Subfile: 4 556 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6850.0 DIFL 6850.0 ZDL 6850.0 2438 6850.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 7334.0 7389.0 7363.0 7344.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT COMR GR CN ZDL SLAD DIFL $ CABLEHEAD TENSION COMMON REMOTE GAMMA RAY COMPENSATED NEUTRON Z - DENS I LOG/CAL I PER SLAM ADAPTER DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT MT: MUD FILTRATE AT BHT: 08-JAN-96 ECLIPS 2.1 2030 0045 7380.0 7378.0 6480.0 7376.0 1500.0 07-JAN-96 08-JAN-96 TOOL NUMBER 3981XA 3510XA 1329XA 2438XA 2228XA 3516XA 1503XA 6.000 6882.0 6884.0 LSND 13.60 47.0 9.0 4.4 152.0 1.760 .760 .910 .000 66.0 152.0 77.0 .0 MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPC - 26 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA 3 .~±0 .000 THERMAL SANDSTONE 2.65 .000 1.0 76.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 27 Curves: Name Tool Code Samples Units AP1 API AP1 API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM RT DIFL 68 1 OHMM DI DIFL 68 1 IN CFOC DIFL 68 1 MMHO CILM DIFL 68 1 MMHO CILD DIFL 68 1 MMHO SP DIFL 68 1 MV WTBH DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN HRD1 ZDL 68 1 CPS HRD2 ZDL 68 1 CPS SFT2 ZDL 68 1 CPS SOFT ZDL 68 1 CNC 2438 68 1 PU-S CNCF 2438 68 1 PU-S CN 2438 68 1 PU-L LSN 2438 68 1 CPS SSN 2438 68 1 CPS 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 07 310 01 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 120 46 1 4 07 120 44 1 4 07 210 06 1 4 07 110 44 1 4 07 110 46 1 4 07 010 01 1 4 07 995 99 1 4 07 635 99 1 4 07 635 99 1 4 07 636 99 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 280 99 1 4 46 354 02 1 4 46 354 01 1 4 46 354 99 1 4 46 354 99 1 4 36 995 99 1 4 36 995 99 1 4 36 890 01 1 4 36 334 31 1 4 36 334 30 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 277 108 Tape File Start Depth = 7392.000000 Tape File End Depth = 6771.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 74114 datums Tape Subfile: 5 353 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS 96/ ~/~7 01 **** REEL TRAILER **** 96/ ~/~8 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 18 JAN 96 ll:07a Elapsed execution time = 3.84 seconds. SYSTEM RETURN CODE = 0 * ALASKA COMPUTING CENTER * * ............................ . * ....... SCHLUMBERGER ....... * . ............................ * COMPANY NAME : B.P. EXPLORATION WELL NAME : MPC- 26 FIELD NAME : MILNE POINT BOROUGH · NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22634-00 REFERENCE NO : 9605 $ Date. ............................... Date.~=~~ -'--- RECEIVED SEP 05 1996 NaltlaOIl&Gas Cals. ~ * ALASK~ COMPUTING CENTER * ....... SCHLUMBERGER COMPANY NAME : B.P. EXPLORATION WELL NAME : MPC-26 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22634-00 REFERENCE NO : 96055 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1996 16:27 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE ' 96/08/12 ORIGIN · FLIC REEL NAME : 96055 CONTINUATION # : PREVIOUS REEL : COMMENT . B.P. EXPLORATION, MILNE POINT MPC-26, API #50-029-22634-00 **** TAPE HEAi~ER **** SERVICE NAIVE : EDIT DATE · 96/08/12 ORIGIN : FLIC TAPE NAME : 96055 CONTINUATION # : 1 PREVIOUS TAPE : CO~IENT : B.P. EXPLORATION, MILNE POINT MPC-26, API #50-029-22634-00 TAPE HEADER MILNE POINT ~¢D LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA BIT RUN 1 JOB NUMBER: 96055 LOGGING ENGINEER: DENNETT OPERATOR WITNESS: MOUNTJOY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL : FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MPC-26 500292263400 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES 12-AUG-96 BIT RUN2 ........ 96055 RUMINER MOUNTJOY BIT RUN 3 10 13N iOE 1085 2419 46.20 46.20 28.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 112.0 8.500 9.625 4704.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1996 16:27 3RD STRING PRODUCTION STRING REMARKS: Well drilled 28-DEC-95 through 4-APR-96 with CDR only. All data ~zas collected in two bit runs. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 96/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGEDPlWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH ..................... 66.5 6896.0 BASELINE DEPTH 88888.0 6816.5 6813 0 6804 5 6781 0 6755 0 6743 5 6727 0 6679 0 6651.5 6646.0 6637.0 6624.5 6598.0 6569.5 6535.0 6517.5 6498.0 6471.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... ....... 88888.0 6816.5 6813.5 6802.5 6781.5 6755.5 6743.0 6727.0 6680.5 6651.0 6646.0 6636.5 6624.5 6597.0 6569.0 6534.5 6516.5 6497.0 6470.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1996 16:27 PAGE: 6455.5 6440.0 112.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: 6455.0 6439.5 112.0 BIT RUN NO. ~IERGE TOP MERGE BASE 1 66.5 4734.0 2 4734.0 6896.0 The depth adjustments shown above reflect the MWD GR to the CH GR logged by Atlas. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOC TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630210 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0H~4~630210 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1996 16:27 PAGE: 4 NASfE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RP MWD 0P2~4 630210 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OH~M 630210 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~R4 630210 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OPk4M 630210 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 630210 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 630210 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630210 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TIE GAPI 630210 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 6896.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 189.603 FET.~D -999.250 GR.MWD -999.250 GRCH. TIE 75.535 DEPT. VRP.MWD GR.MWD 6000.000 RA.MWD 2.417 RP.MWD 2.243 V~.MWD 2.407 2.258 DER.MWD 2.302 ROP.MWD 299.961 FET.MWD 0.407 94.756 GRCH. TIE -999.250 DEPT. VRP.MWD GR~MWD 4000.000 RA.MWD 1.739 RP.MWD 1.672 VRA.MWD 1.786 1.673 DER.MWD 1.697 ROP.MWD 343.768 FET.MWD 0.442 57.352 GRCH. TIE -999.250 DEPT. 2000.000 RA.MWD 12.311 RP.MWD 11.235 VRA.~D 13.737 VRP.MWD 11.574 DER.MWD 11.477 ROP.MWD 379.333 FET.~FD 0.410 GR.MWD 54.940 GRCH. TIE -999.250 DEPT. 68.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD -999.250 FET.MWD -999.250 GR.RFWD 11.572 GRCH. TIE -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1996 16:27 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE N-UMBER 2 RAW ~D Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUlVk4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 66.5 4734.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWArHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): 04 -JAN-96 FAST 2.5 4.0 MEMORY 6896.0 66.5 6896.0 60 0 9.9 TOOL NTJMBER RGS904 12. 250 112.0 LSND 10. O0 45.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1996 16:27 PAGE: FLUID LOSS (C3): RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TE~IPER~TURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 2.270 2.030 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: ******* RUN1 - CDR ONLY ************* DRILLED INTERVAL 125' - 4734' RES TO BIT: 50.85'; GR TO BIT: 61.27' Rm=2.27@66 DEG, Rmf=2.09@64 DEG ******* RUN2 - CDR ONLY ************* RES TO BIT: 54.35'; GR TO BIT: 64.77' DRILLED INTERVAL 4735' - 6896' TD REACHED 17:56 02-JAN-96 $ LIS FORMAT DATA 66.0 66.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 0 66 0 66 0 73 28 66 1 66 73 65 68 0.5 65 FT 66 36 68 66 0 65 FT 66 68 66 1 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1996 16:27 PAGE: ** 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 630210 ATR LW1 OH~M 630210 PSR LW1 Otff~4630210 DER LW1 OH~4 630210 ROPE LW1 F/HR 630210 TAB LW1 HR 630210 GR LW1 GAPI 630210 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 4734. 000 ATR.LW1 -999.250 PSR.LW1 -999.250 ROPE. LW1 146.102 TAB. LW1 -999. 250 GR. LW1 -999.250 DEPT. 4000. 000 ATR.LW1 1. 676 PSR. LW1 1. 558 ROPE. LW1 320. 020 TAB. LW1 O, 433 GR. LW1 50. 121 DEPT. 2000.000 ATR.LWl 12.311 PSR.LW1 11.235 ROPE. LW1 379. 333 TAB. LWl 0,410 GR. LW1 54. 940 DEPT. 66. 500 ATR. LW1 -999. 250 PSR. LW1 -999. 250 ROPE. LW1 - 999.250 TAB. LW1 - 999.250 GR. LW1 11 . 038 DER. LW1 DER. LW1 DER. LW1 DER. LW1 -999.250 1. 601 11.477 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE · 96/08/12 MA~REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1996 16:27 PAGE: FILE HEADER FILENUMBER 3 RAW.CD Curves and log header data for each bit run in separate files. BIT RUN NUM~ER: 2 DEPTH INCREMENT: 0.5000 FILE SOW2ViARY VENDOR TOOL CODE START DEPTH STOP DEPTH 4668.0 6896.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (Otflvk4) 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): 04 -JAN-96 FAST 2.5 4.0 MEMORY 6896.0 66.5 6896.0 65 8.6 9.9 TOOL NUMBER RGS055 12.250 112.0 LSND 10. O0 45.0 2.270 66.0 2. 030 66.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1996 16:27 PAGE: TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: ******* RUN1 - CDR ONLY ************* DRILLED INTERVAL 125' - 4734' RES TO BIT: 50.85'; GR TO BIT: 61.27' Rm=2.27@66 DEG, Rmf=2.09@64 DEG ******* RUN2 - CDR ONLY ************* RES TO BIT: 54.35'; GR TO BIT: 64.77' DRILLED INTERVAL 4735' - 6896' TD REACHED 17:56 02-JAN-96 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630210 O0 000 O0 0 3 1 1 4 68 0000000000 ATR LW2 OH~k4630210 O0 000 O0 0 3 1 1 4 68 0000000000 PSR LW2 OP24M630210 O0 000 O0 0 3 1 1 4 68 0000000000 DER LW2 OP24M 630210 O0 000 O0 0 3 1 1 4 68 0000000000 ROPE LW2 F/HR 630210 O0 000 O0 0 3 1 1 4 68 0000000000 TAB LW2 HR 630210 O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI 630210 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-AUG-1996 16:27 PAGE: 10 ** DATA ** DEPT. 6896.000 ATR.LW2 -999.250 PSR.LW2 -999.250 ROPE. LW2 189. 603 TAB. LW2 -999. 250 GR. LW2 -999. 250 DEPT. 6000. 000 ATR. LW2 2.417 PSR. LW2 2. 250 ROPE. LW2 299. 961 TAB. LW2 O. 406 GR. LW2 92 . 095 DEPT. 4668. 000 ATR. LW2 -999. 250 PSR. LW2 ~ 999. 250 ROPE. LW2 - 999.250 TAB. LW2 - 999.250 GR. LW2 44 . 072 DER. LW2 DER. LW2 DER. LW2 -999.250 2.307 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER . **** SERVICE NAME : EDIT DATE : 96/08/12 ORIGIN : FLIC TAPE NAME ' 96055 CONTINUATION # : 1 PREVIOUS TAPE : CONk4ENT : B.P. EXPLORATION, MILNE POINT MPC-26, API #50-029-22634-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/08/12 ORIGIN : FLIC REEL NAME · 96055 CONTINUATION # : PREVIOUS REEL CON2~ENT : B.P. EXPLORATION, MILNE POINT MPC-26, API #50-029-22634-00