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187-014
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. j ~ ~ - ~ 1~ Well History File Identifier Organization (done) ~TWD-Sided III IIIIIIIIIII IIIII ~ FZescan Needed III IIIIIIIIII 111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) ^ Color items: ^ Diskettes, No. ^ Maps: ^ Other, No/Type ^ Other items scannable by ^ Grayscale items: large scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds ^ Other TOTAL PAGES: ~ ~ NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Project Proofing III IIIIIIIIIII II III III IIIIIIIIII III III ~ .Staff Proof By; Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Scanned (done) IIIIIIIIIIIIIIIIIII PAGES: ~Y ~ (at the time of scanning) SCANNED BY. BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: "'f ~ ~~ . ® L /S/ ~~' fff o Rescanned tdone, IIIIIIIIIIIIIIIIIII RESCANNED BY. BEVERLY BREN VINC ~.O,WEl.t~LL .* ., ~;DAT~; ~ - . J/ ~ a ~,:- lSl General Notes or Comments about this file: .add--rte ~ ~ .Quality Checked laonel IIIIIIIIIIIIIIII~I PAGES: Rev1NOTScanned.wpd • STATE OF ALASKA ~~~~~~® ALASKA OIL AND GAS CONSERVATION COM~~SI~N3 ~QQ$ WELL COMPLETION OR RECOMPLETION REPOR AN OG 1a. Well Status: Oil ~ Gas Plugged / Abandoned ^/ Suspended ^ A aS a 1 20AAC 25.105 20AAC 25.110 Anchor GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: ass: lopment Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: November 20, 2008 12. Permit to Drill Number: 187-014 / 308-394 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: March 1, 1987 ~ 13. API Number: 50-029-21696-00 4a. Location of Well (Governmental Section): Surface: 1250' FNL, 1722' FEL, Sec. 25, T13N, .R8E, UM 7. Date TD Reached: March 7, 1987 14. Well Name and Number: 3M-03 " Top of Productive Horizon: 912' FSL, 1408' FWL, Sec. 25, T13N, R8E, UM 8. KB (ft above MSL): 64' RKB Ground (ft MSL): 15. Field/Pool(s): Kuparuk River Field Total Depth: 691' FSL, 1267' FWL, Sec. 25, T13N, R8E, UM 9. Plug Back Depth (MD + TVD): 7320' MD / 5949' TVD Kuparuk Oil Pool ` 4b. Location of Well (State Base Plane Coordinates): NAD 27 Surface: x- 506146 y- 6016248 Zone- 4 10. Total Depth (MD + TVD): - 8065' MD / 6474' TVD " 16. Property Designation: ADL 25523 TPI: x- 503999.7 y- 6013129 Zone- 4 Total Depth: x- 503859 - 6012908 Zone- 4 11. SSSV Depth (MD + TVD): nipple @ 504' MD / 504' TVD 17. Land Use Permit: ADL 2559 1 S. Directional Survey: Yes ^ No ^/ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1650' approx. 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surf. 115' Surf. 115' 24" 198 sx CS II 9-5/8" 36# J-55 Surf. 3608' Surf. 3306' 12.25" 900 sx AS III, 300 sx Class G 7" 26# J-55 Surf. 8041' Surf. 6457' 8.5" 30o sx Class G, 175 sx AS I 23. Open to production or injection? Yes No / If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 7634' 7607 plugged and ab ~r~~~tte~d ` ~ [j `; ~, ~.~ ~~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ m f j ~I DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7320'-7550' cement P&A - 28 bbls Class G, 5 bbls left in sump with 20 bbls pushed behind pipe, 3 bbls cement on top of plug 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged and abandoned Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No ^/ ~ Sidewall Cores Acquired? Yes No Q If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 2 071. ~~Q-~4-~.YnFrt,~ k DATA ....,. NONE -~ Form 10-407 Revised 2/2007 ~~ ~ /~ ~ ~p-J~I~E!/EVl~3Sry51DE /~ /2 ~ Z.~• ~~~ ~ 28. GEOLOGIC MARKERS (List all formations and ma encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes ~ No If yes, list intervals and formations tested, Permafrost -Top not applicable not applicable briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom needed, and submit detailed test information per 20 AAC 25.071. N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS Summary of Daily Operations 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz Printed Name Gu Schwa Title: Wells Enoineer Signature Phone ?~ S--_ (oct S'O Date ~ 2 '" az `d8 INSTRUCTIONS Sharon Aflsup-Drake 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a welt producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, December 24, 2008 11:21 AM To: Allsup-Drake, Sharon K Subject: RE: 3M-03 (187-014) _ Has there been any rig work accomplished on 3M-03 so far? If so, it is appropriate to send in the operations summary up to just past milling out of the casing. if not, once that work is accomplished then you can send in the operations summary. Tom From: Allsup-Drake, Sharon K [mailto:Sharon.K.Allsup-Drake@conocophillips.com] Sent: Wednesday, December 24, 2008 11:04 AM To: Maunder, Thomas E (DOA) Subject: RE: 3M-03 (187-014) and 2N-305 So, should I send in more detail about 3M-03? Thank you, Sharon 263-4612 -t,,~ ,~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, December 24, 2008 11:02 AM To: Allsup-Drake, Sharon K Subject: RE: 3M-03 (187-014) and 2N-305 Thanks Sharon. That is correct to send with 3M-03A, however there is some amount of the work that the rig will accomplish that we consider to occur within 3M-03. You are correct, I am suppased to be on vacatian, but the flight on Monday got cancelled. Next try out is Friday morning. Best wishes far the holidays. Tom From: Allsup-Drake, Sharon K [mailto:Sharon.K.Allsup-Drake@conocophillips.com] Sent: Wednesday, December 24, 2008 9:22 AM To: Maunder, Thomas E (DOA) Subject: RE: 3M-03 (187-014) and 2N-305 We will send pre and post rig work with the 407 for 3M-03A. P.S. Aren't you supposed to be on vacation? Thank yau; Shoron 263-4612 2/11/2009 Page 2 of 2 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, December 23, 2008 1:51 PM To: Schwartz, Guy L Cc: Allsup-Drake, Sharon K; Greener, Mike R. Subject: RE: 3M-03 (187-014) : ' " Guy, Sharron and Mike, We have received the 407 for 3M-03, thanks. One thing to remember with P&As for redrill is that by our convention, the permit to drill is not effective until the actual drilling of new hole occurs (of the TIN immediately prior). On 3M-03, there is still rig work to be done that precedes the actual drilling of new hole. I suggest you al! coordinate on how best to work the operations and paperwork. Thanks in advance, Tom Maunder, PE AOGCC From: hwartz, Guy L [mailto:Guy.L.Schwartz@conocophillips.com] Sent: Mo ay, December 22, 2008 8:49 AM To: Maunder, Thomas E (DOA) Subject: RE: 3 -03 (187-014) I checked with Sharrc~.. she wili send a 407 instead. Our mistake. Nave a great Noliday.... Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.I.schwartz@conocophillips.com From: Maunder, Thomas E (DOA) [mailto:tom.m der@alas Sent: Friday, December 19, 2008 12:18 PM To: Schwartz, Guy L Cc: Allsup-Drake, Sharon K Subject: 3M-03 (187-014) Guy, I am reviewing the 404 you submi d for the recent plugging work on this well. Th noted on the sundry. Would yo lease prepare and submit a 407 with a "after plugs When is 3M-03A to spud? Si a the actual work approved by the sundry goes up to Sharon be the one to file th 407? Call or message with any uestions? Tom Maunder, PE AOGCC rrect form is a 407 as drawing of the wellbore. ~g the window, would 2/11/2009 Maunder, Thomas E {DOA) From: Schwartz, Guy L [Guy.L.Schwartz@conocophillips.com] Sent: Monday, December 22, 2008 8:49 AM To: Maunder, Thomas E (DOA) Subject: RE: 3M-03 (187-014) 1 checked with Sharron... she will send a 407 instead. Our mistake. Have a great Holiday.... Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.I.schwartz(a~conocophillips.com Page 1 of 1 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov~ Sent: Friday, December 19, 2008 12:18 PM To: ~hwariz, Guy L Cc: Allsup-Drake, Sharon K Subject: 3M-03 (187-014) Guy, I am reviewing the 404 you submitted for the recent plugging work on this well. The correct form is a 407 as noted on the sundry. Would you please prepare and submit a 407 with a "after plugging" drawing of the welfbore. When is 3M-03A to spud? Since the actual work approved by the sundry goes up to milting the window, would Sharon be the one to file the 407? Call or message with any questions? Tom Maunder, PE AOGCC 12!22/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Pertormed: A ndOn Q Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Alter ing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Progra ^ Operat. Shutdown^ Perforate ^ Re-enter Su pended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ ~ Exploratory ^ 187-014 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alask 9510 50-029-21696-00 7. KB Elevation (ft): 9. Well Na and Number: RKB 64' 3M-03 ' 8. Property Designation: 10. Fiel ool(s): ADL 25523 Kup k River Field / Kuparuk Oil Pool . 11. Present Well Condition Summary: Total Depth measured 8065' feet true vertical 6474' feet Plugs (measured) 7320', 7550' Effective Depth measured 795 feet Junk (measured) true vertical 6393' feet Casing Length Size TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SURFACE 3544' 9-5/8" 3608' 3306' PRODUCTION 7977 7" 8041' 6457 ~ ~ ~~~,~b ,, -- ~ ~~~ ~ . ~ ~~ . Perforation depth: Measured depth: 7704'-7726',7740'-7752', 7 0'-7780', 7794'-78 ', 7828'-7832' true vertical depth: 6221'-6237', 6246'-625 6261'-6275', 6285'-6305 , 309'-6312' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7634' D. Packers & SSSV (type & measured depth) Baker'SAB-3' pe anent pkr ~ 7so7' Camco'DS' nip @ 504' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7320' 7550' ceme &A, 3 bbls cement on top of plug Treatment descriptions including volumes used nd final pressure: 13. Representative Daily Average Production or Injection Da Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation Subsequent to operation P&A -- 14. Attachments 15. Well Class after work: lugged and Abandoned ~ • Copies of Logs and Surveys run Exploratory ^ Development ^ Service Daily Report of Well Operatio X 16. Well Status after work: Plu d and Abandoned ~ ' Oil^ Gas ^ WAG ^ GINJ ^ W ^ WDSPL ^ 17. I hereby certify that the for oing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-394 Contact Guy hwartz @ 265-6958 Printed Name Gu ch Title Wells Engineer c~/ Signature r''~ Phone: 265-6958 Date ~~~ (7-Oa P ared b Sharon Allsu -Drake 263-4612 i2.ig.c8 Form 10-404 Re ised 04/2006 Submit Ori final Only /~~/~~ r CanacoPhillips Time Log & Summary WefNfew Web Reporting Report Well Name: 3M-03 Rig Name: DOYON 141 Job Type: DRILLING SIDETRACK Rig Accept: 11/26/2008 2:00:00 PM Rig Release: 12!24/2008 4:00:00 PM Tune. Lo s e From To Dur S. D th E. D th Ph e Code ubc T m nt 11/26/2008 ~hrsummarv Move camp from 3C and Rig from 1J 14:00 17:00 3.00 0 0 MIRU MOVE MOB P Move boiler, motor, pumps and pit complexes from 1J pad to 31 pad and sta a there 17:00 18:30 1.50 0 0 MIRU MOVE MOB P Shuttle trucks back to 1J pad, IoadWTS on sow, get trucks under pipe sheds, hitch up and jack sub and read for road. 18:30 20:30 2.00 0 0 MIRU MOVE MOB P Wait on Peak Blade mechanical roblems blockin road 20:30 00:00 3.50 0 0 MIRU MOVE MOB P Continue move to 3M-03A 11 /27/2008 Rig up with 1 1/2 crews. 00:00 00:00 24.00 0 0 MIRU MOVE RURD P Continue rig in for acceptance. 11 /28/2008 Two full crews by noon. Rig up. Pull BPV. 50 psi on tubing. Bleed off into bleed tank. Work on 3" demco on um .Build berms for Ti er tank. 00:00 12:00 12.00 0 0 MIRU MOVE RURD P Ready rig for acceptance. 12:00 14:00 2.00 0 0 MIRU MOVE RURD P Ri acce ted 12:00 alerted Bob Noble, AOGC, 24 hour notice for pressure test. Will update tomorrw AM as he is required to observe 5000psi pressute test after warmstack period. Load test jts. Get BOP's ready, nipple up brake adapter flange on stack, function test rams, annular. Load pipe shed w/jars, whipstock, DC's, HWDP, get 4" tools, and safe valves on floor. 14:00 16:00 2.00 0 0 MIRU MOVE RURD P PJSM, flange up lines to circ. the well. 16:00 17:00 1.00 0 0 MIRU MOVE RURD P PJSM, Install 5" x 2 7/8" VBR's in BOP. Lower set. 17:00 20:00 3.00 0 0 MIRU MOVE RURD P Load pipe shed w/ 4" DP, and strap. 186 'ts. RU SWACO centrifu e. 20:00 21:00 1.00 0 0 MIRU MOVE RURD P PJSM, RU lubricator, pull BPV. (60 Ibs inside tubing pressure.) bleed off into 300 al tank. LD lubricator. 21:00 00:00 3.00 0 0 MIRU MOVE RURD P Bring on 500 BBIs of freash water, bring on 525 BBLs of 8.4 ppg seawater. Prime pumps, Pressure test um s, RU ti er tank berm. 11 /29/2008 Displaced well down tubing to seawater to tiger tank. Re-run BPV, remove tree, install and pressure test BOP's. Page 1 of 24 ~~ Time to s Date From To Dur S. th E. th Ph e Code Subcode T amment 00:00 01:00 1.00 0 0 MIRU RPCOM RURD P Bleed off 50# tubing pressure into 300 al tank. Ri u ti er tank. 01:00 03:00 2.00 0 0 MIRU RPCOM RURD P Hammer up hard lines from tree annulus to choke house, and tiger tank.Place spill containment under each connection. 03:00 03:30 0.50 0 0 MIRU RPCOM SFTY P Hold prejob for displacement. 03:30 03:45 0.25 0 0 MIRU RPCOM CIRC P Test hardlines with air, followed by fresh water, hold 500 si, ood test. 03:45 06:00 2.25 0 0 MIRU RPCOM CIRC P Dis lace well with seawater taking all returns outside into tiger tank, 100 feet from wellhead. Start displacement @ 4 BPM / 300 psi. After 50 BBLs away, pressure dropped to 140 psi, @ 88 .BBLs away 180 psi, brought rate to 5 BPM, 300 psi, displaced 300 BBLs, 50 BBLs over, last ressure 600 si. 06:00 07:00 1.00 0 0 MIRU RPCOM RURD P Blow down hardlines. Monitor well, 50 psi built back up on annulus, from the initial zero. 07:00 08:30 1.50 0 0 MIRU RPCOM CIRC P Rig up back to hardline in cellar, dis lace 100 BBLs to ti er tank. 08:30 12:00 3.50 0 0 MIRU RPCOM SIPB P Well shut in, monitor well. blow down lines. Wait on FMC hand. Well is dead. 12:00 13:00 1.00 0 0 MIRU WELCTL NUND P Set BPV Prep to nipple down. 13:00 14:00 1.00 0 0 MIRU WELCTL SFTY P Hold prespud meeting in camp. Sweeny wrench safety video with crew. 39 attendees. 14:00 15:30 1.50 0 0 MIRU WELCTL NUND P Nipple down Xmass tree, install blankin lu . 15:30 19:00 3.50 0 0 MIRU WELCTL NUND P Nipple up flange adapter and 5k 13 5/8" H dril BOP stack. 19:00 21:00 2.00 0 0 MIRU WELCTL NUND P Rig up to test BOP, fill stack and choke with water. 21:00 00:00 3.00 0 0 MIRU WELCTL BOPE P Attem t to test BOP. w/ 4" test joint, tube/packing for leaks in choke valves, #2,5,9,12,13,14-Hammer up Ram doors on blinds, & 13 5/8" flan e. crew chan e. 11 /30/2008 Finish BOP test. Prepare to pull tubing, circulate one bottoms up. Pull cut tubing. Set test plug, test bottom VPR to 250 psi low, 5,000 high. chart, pull test plug, attempt to set wear ring, egged, (Did not run), pick up Mill/casin scra er assembl ,sin le in the wellbore. Page 2 of 24 f me Lo s Date Fr m To Dur S. De Th E. De th Pha Cade Subcode T Comment 00:00 07:30 7.50 0 0 MIRU WELCTL BOPE P PJSM, continue to test BOP. C/O valve #14 cap and stem, cont. test - 2501ow, 5000 high (Test #1 -Top VPR, valves, 1,12,13,14.) (Test#2- Upper IBOP, choke valves 9,11), C/O stem and valve on #14 again. (Test #3 - Lower IBOP, HCR kill, choke valves 5,8,10.) (Test #4, dart valve, choke valves 4,6,7.) {Test #5 floor valve, choke valve 2.) (Test #6 HCR choke.) (Test#7, manual choke.) (Test #8 Annular w/ 4" DP.) lay down 4" test joint P/U 3.5" test joint. (Test #9 Top VPR's w/ 3.5" DP) (Test #10 Annular w/ 3.5" DP.) (Test #11 blinds choke valves, 3,14.) (accumulator test initial system pressure 2850 psi. after all rams closed 1900 psi. 200 psi build up attained in 42 secs. Full pressure attained in 3 min 8 sec. All tests witnessed by AOGC rep. Bob Noble. 07:30 08:00 0.50 0 0 MIRU RPCOM RURD P Rig down test equipment, blow down choke and kill lines. 08:00 08:30 0.50 0 0 MIRU RPCOM RURD P Pull FMC blanking plug out. 08:30 11:00 2.50 0 0 MIRU RPCOM RURD P Pick up casing equipment to rig floor. Rig all equipment up. Back out LDS, reconfigure floor safety valve from 4" HT 39 to 3.5" 8R EUE. Pull strip /tubin han er to ri floor. P/U wei ht 87,000 lbs. UD han er. .11:00 12:00 1.00 0 0 MIRU RPCOM CIRC P Screw into 3.5" tubing. Break circulation. Circulate @ 2.5 BPM. 50 si. 12:00 13:30 1.50 0 0 MIRU RPCOM CIRC P Continue to circulate @ 4.5 BPM, 250 psi. Stop circ. Monitor well 30 mins. Static. Blow down top drive, calibrate block hei ht. 13:30 20:30 7.00 0 0 MIRU RPCOM TRIP P POOH w/ TBG. Pull 15 jts. Monitor well 15 mins. Dead. Cont. to trip out. lay down 221 joints, one cutjoint, 4 GLM's, one X nipple. Monitor well static. Hole dis lacement ood. 20:30 21:30 1.00 0 0 MIRU RPCOM RURD P Rig down all casing running tools. 21:30 22:30 1.00 0 0 MIRU WELCTL BOPE P PJSM. R/U and test lower variable ipe rams as was a reed u on w/ AOGC. VPR's 5" x 2 7/8", test w/ 4" test joint. 250 psi low, 5,000 psi hi h. Good. 22:30 23:00 0.50 0 0 MIRU WELCTL BOPE P R/D test equipment. Attempt to install wear bushing on running tool. E ed out, unable to use. 23:00 00:00 1.00 0 0 MIRU RPCOM PULD P P/U one 3.5" HWDP, and bring mills, casin sera er to ri floor. 12/01 /2008 Make amill/scraper run to 6973' MD. Set CIBP @ 5524' MD. Test CSG/CIBP to 2500 psi. 15 mins. Nipple down BOP, TBG head. 7" CSG rew 5.25" Papa 3 of 24 Time Lo s Date From To Dur S. De E. De th Phase ode Subcode T Comment 00:00 01:30 1.50 0 0 MIRU RPCOM PULD P Pick u BHA#1. Bak r mi-U a 'n scra er run. Make u BHA #1. 01:30 08:15 6.75 0 6,732 MIRU RPCOM TRIP P Trip in the hole. P/U 3 stands collars, 6 stands HWDP. 186 jts. 4" DP. to 6732' M D 08:15 09:00 0.75 6,732 6,732 MIRU RPCOM CIRC P Calibrate MWD & Totco depth indicators/wheels. 09:00 09:45 0.75 6,732 6,973 MIRU RPCOM TRIP P Trip in to tag top of cut tubing. 13 feet higher than recorded coil tubing cut death.(6973 versus 6986') Up Wt=147k, Dn Wt=105k. LD one 'oint. 09:45 10:45 1.00 6,973 6,973 MIRU RPCOM CIRC P Break circulation. Pump 25 BBL high vis sweep surface to surface. No solids coming over shakers. Pump 380 GPM, 2000 si. 10:45 12:00 1.25 6,973 5,789 MIRU RPCOM TRIP P POOH. Crew change. 12:00 14:00 2.00 5,789 100 MIRU RPCOM TRIP P POOH. Worked the scraper from 5601 to 5506' MD. Monitor welt @ HWDP static. Displacement 1 BBL Ion . to BHA 14:00 15:00 1.00 100 0 MIRU RPCOM PULD P Lay down mills/bumper sub/scraper. Clear and clean ri floor. 15:00 18:30 3.50 0 0 MIRU RPCOM WOEQ T Waiting on computer board from Deadhorse fro SLB WL unit. Crashed mother board. 18:30 19:00 0.50 0 0 MIRU EVALWE SFTY P Safety meeting with SLB crew. Settin a cast iron bride lu . 19:00 21:30 2.50 0 5,524 MIRU EVALWE FLOG P Pick u a CIBP, run in the hole correlate. Set CIBP @ 5524' MD. 8 feet above nearset collar. 35 feet below collar. POOH w/ WL. Rig down SLS unit. 21:30 22:00 0.50 5,524 5,524 MIRU WELCTL OTHR P Test casing /CIBP to 2500 psi for 15 low down kill line. 22:00 00:00 2.00 5,524 5,524 MIRU WELCTL NUND P PJSM. Nipple down BOP. and tubing head. 7" 26# casin rew 5.25". 12/02/2008 Nipple down BOP and tubing spool. Spear 7" casing and pull up 40k over. Check casing slips and reset. Released spear. Set packoff in tubing spoof and cut off 9" section of 7" casing. Installed tubing spool and tested void to 1500 psi for 10 minutes-OK. Nipple up BOP and retest breaks. Set wear bushing. Make up whipstock and mill assembly. Run in the hole to 5470' and cut and slipped drilling line. Displaced well with 9.8 ppg LSND mud. Orient whipstock 68 deg. left of high side and set anchor. Sheared off whipstock and milled windown from 5507' to 5520'. Drilled new hole from 5520' to 5541'. Pumped sweep and reamed throu h window. 00:00 00:30 0.50 0 0 MIRU WELCTL NUND P Nipple down and remove tubing spol and 7" ackoff 00:30 02:00 1.50 0 0 MIRU WELCTL OTHR P Make up 7" spear assembly and stab into casing. Pull 40 k over. Remove and inspect casing slips. Slps alright. Re-set slips and releases ear. La downs ear. 02:00 03:00 1.00 0 0 MIRU WELCTL OTHR P Change out secondary packoff in tubing spool and rig up cutter. cutoff 9" len th of casin and set rima ackoff Page 4 of 24 s Time Lo s Dat From To Dur S. De th E. th Ph se Cod Subcade T Cammenf 03:00 04:00 1.00 0 0 MIRU WELCTL NUND P Install tubing spool and test void between packoffs to 1500 psi for 10 minutes-OK. 04:00 05:30 1.50 0 0 MIRU WELCTI NUND P Nipple up BOPE and install secondary working valve on upper annulus. 05:30 06:30 1.00 0 0 MIRU WELCTI BOPE P Rio up and test adapter flange on BOPE to 250 psi Low and 5000 psi Hi h. Ri down test a ui ment 06:30 07:00 0.50 0 0 MIRU WELCTL OTHR P Set wear bushing 07:00 09:30 2.50 0 0 INTRM1 STK PULD P Make up mile and whipstock assembl 09:30 10:30 1.00 0 500 INTRM1 STK WPST P Run in hole to 500' and shallow test MWD at 267 gpm, 63 spm, 600 psi. Blow down to drive 10:30 14:30 4.00 500 5,470 INTRM1 STK WPST P Run in hole with whipstock assembly to 5470' 14:30 15:30 1.00 5,470 5,470 INTRM1 RIGMNT SVRG P Cut and slip 63' of drilling line. Inspect and adjust brakes. Displace well to 9.8 mud. 15:30 16:30 1.00 5,470 5,507 INTRM1 STK WPST P Orient whipstock 68 deg left of high side. P/U 115k, S/O 90k. Tag CIBP ~, ~ at 5525'. Set 20K on CIBP and `~ _ ~ ` shear anchor. Shear off whipstockw/ k. 16:30 22:15 5.75 5,507 5,520 INTRM1 STK WPST P Mill window from 5507' to 5520'. Pump 10 bbl high vis sweep at 5514' and 20 bbl hi h vis swee at 5520' 22:15 23:30 1.25 5,520 5,541 INTRM1 DRILL DDRL P Drill new formation from 5520' to 5541' 23:30 00:00 0.50 5,541 5,541 INTRM1 DRILL CIRC P Circulate and ream through window. 12/03/2008 Polish window. Pull out of the hole and lay down extra collars and HWDP. Laydown mills. Make up directional BHA and run in the hole. Slide bit and motor through window. Slide drill to get upper stabilizer throu h window. Slide and rotate from 5541' to 5572'. 00:00 01:00 1.00 5,541 5,541 INTRMI DRILL CIRC P Polish window. Ream through window 3 times with rotation and pumps on. Circulate hig vis sweep out of the hole. Slide through window with pump on and no rotation, slide through window with no pumps and no rotation with no roblems 01:00 01:30 0.50 5,541 5,541 INTRM1 DRILL FIT P Ri u and erform FIT to 14.55 EMW. Ri down test a ui ment 01:30 03:30 2.00 5,541 989 INTRM1 DRILL TRIP P Monitor well, pump slug and POOH to 989' MD 03:30 06:30 3.00 989 0 INTRM1 DRILL PULD P Laydown 6 jts HWDP. Rack back 4 stands HWDP, 9 spiral dc's and rack back flex collars. UD mill assembly. Clear floor 06:30 08:00 1.50 0 0 INTRM1 DRILL OTHR P Pull wear bushing and flush stack. Set wear bushin . 08:00 09:30 1.50 0 0 INTRM1 DRILL PULD P Make up directional BHA #3. 09:30 10:15 0.75 0 0 INTRM1 DRILL OTHR P Load MWD Page 5 of 24 3M-03 Plugged and Abandoned Summary DATE SUMMARY 7/21/08 PULLED 2.75 CA-2 PLUG @ 4' RKB. TAGGED @ 7747' RKB, EST. 85~ FILL. MEASURED BHP @ 7744' RKB: 4756 PSI. SET 2.75" CA-2 PLUG @ 7624' RKB; CONFIRMED SET WITH DRAW DOWN TEST. COMPLETE. 11/5/08 PULLED 2.75" CA-2 PLUG @ 7624'. MEASURED BHP @ 7743' RKB: 4294 PSI. SET CA-2 PLUG (a 7624' RKB. DRAW DOWN TEST CONFIRMED SET. COMPLETE. 11/14/08 CMIT T X IA -PASSED, FUNCTION TESTED T & IC LDS (PRE- SIDETRACK) 11/18/08 PERFORMED 30 MIN CMIT.PASSED.PULLED 2.75" CA-2 PLUG FROM 7624' RKB.ESTABLISH INJ RATE 1 BPM @ T/1=2450/2475/620 11/19/08 SET HES 3.5" EZSV PLUG AT 7550' MD. Pressure tested plug to 2500 psi and draw down both passed TD NOT TAGGED. ` 11/20/08 PERFORMED CEMENT P&A THRU HALLIBURTON EZSV RETAINER PUMPED TOTAL OF 28 BBLS CLASS G, 5 BBLS LEFT IN SUMP WITH 20 BBLS PUSHED BEHIND PIPE BEFORE ACHIEVING SQUEEZE PRESSURE OF 950 PSIG, LAYED IN 3 BBLS OF CEMENT ON TOP OF PLUG, WASHED DOWN TO 7320' CTMD USING 30 BBLS BIOZAN AND SEAWATER, WELL LEFT SHUT IN AND FREEZE PROTECTED WITH DIESEL TO 7000' CTMD, TURN OVER TO DSO, 24 HR. WAIT TIME BEFORE DRIFT/TAG AND PRESSURE TEST. 11/22/08 DRIFT TBG W/ 2.770" GAUGE S/D @ 7128' SLM WORKED TO 7132' SLM, RUN SAMPLE BAILER TO 7132' SLM, OBTAINED SAMPLE, PULL DGLV FROM STA # 4 @ 6540' SLM-6555' RKB, PERFORM COMBO MITIA TO 1500 PSI, MITIA PASSED._*""JOB COMPLETE**" Note: State rep witness of MIT/Tag waived by Chuck Scheve) 11/24/08 JET CUT 3.5" TUBING WITH 2.5" POWERCUTTER AT 6986'. T/IA UNCHANGED AT 500/100 BEFORE AND AFTER FIRING. • 3M-03A SIDETRACK - P&A FINAL - 9-5/8" x 7" annulus arctic packed March 1987 w/ 29 bbls cmt & 60 bbls Arctic Pack. 0 - 1,850'. 9-5/8" 36# J-55 BTC casing Set @ 3,608' MD / 3,305' TVD Baker "K-1" CIBP below set point for whipstock~@ +/- 5,520' MD CBT run 4/30/8 Estimate TOC 6.( 3-'/z' tbg cut and pul from 6,986' MD Retainer set at 7,5E ~MD. Top of cmt P8 plug @ 7,320' MD PKR' 7,607 M Original Wellbore 7.0" 26.0# J-55 @ 8,041' MD / 6,457' TVD Conoco hillips Perfs: 7,704' - 7,726' 7,740' - 7,752' 7,760' - 7,822' 7,828' - 7,832' M. A. Winfree 12/22/2008 Rev 1 ~ ~ ~ Conot©~hiliips ~ Al~isk~,.lnc CONDUCTOR, Its NIPPl E. 504- -- GAS LIFT. 2,758 SURFACE, 3.608 GAS LIFT, 4,388 GAS LIFT. 5.740 GAS LIFT. 6.555 GAS LIFT. 7.'28 GAS LIFT, 7.519 CEMENT PLUG, 7.320 PLUG. 7.550 - NIPPLE, 7,Sfi4 PACKER, 7.607 -- - NIPPLE. 1.624 - - SOS. 7,fi33 ~ TR, 7.634 - - IPERF. • 7,704-7,726 IPERF, • 7.740-7752 IPERF. • 7.760-7,]71 IPERF. • 7,171-7,772 IPERF, _ _. • 7,772-7.774 IPERF. 7.774- IPERF. 7.774-7.780 • IPERF. 7,794-7,822 _ IPERF, _ 7.828-7,832 • PRODUCTION, 8.041 TD (3M-03). 8.065 KUP • 3M-03 Well Attribut Wellbore APl/U WI es _ _-._ _-__-__. Field Name _ ______--. Well Status Protl/Inj Type i Max An le $ MD Inc! (°) MD (fiKB) ' TD_ _ I Act Bim (ftKBI 5002921696W KUPARUK RIVER UNIT (PROD 5.7(1000 47.03 ~ ~ 8,0650 Comment MIS (ppm) (Date IAnnotation ;End Date KB-Grd (it) Rig Release Dati SSSV: NIPPLE 0 7!112008 'Last WO: 6/25/1997 ~ 40.71 3/811987 Annotation Depth (ftKe) End Data I Annotation 'i,EndDate Last T ag: 7 747.0 7/21/2008 Rev Reason: P & A, AUU CEMENT PLUG 11/21!2008 Casing Strin gs __ _ String OD String ID _ _ _ Set Depth Sat Depth (FVD) String Wi String __ _ Casing Descripti on ~ (inl (inl ~ Top (ftK8) ~~ (HKB) (HKB) (Ibs/ft) Grade Siring Top Thrc CONDUCTOR j 16, 15.062; 0.0 115.01 115.0 6258H-40 SURFACE 95/81; 8.765'1 0.0 3608.01 3,305.8 36.00'. J-55 PRODUCTION 7 6.151 00' A041.0 6,457.21 26.OOIJ-55 ~,, Tubing Strin gs . _ String OD '~ String ID Sat Depth Set Depth (TVD) String WI Suing Tubing D ripti on (iN lint Top (ftK B) 'i (HKBI ; (HKB) (Ibs/ft) Grade SMng Top Thrr TUBING ' 3112 2.992',, 0.(1 7,634.0 6,171.3; 9.30''~ L130 EUE AB MOD Inch 1 1.86 Description Comment NIPPLE Camco'DS' Nipple !.57 GAS LIFT CAMCO/KBUG/1lDMY/BW/I Comment: STA 1 i.37 GAS LIFT CAMCO/KBUG/1lUMYlBW//Comment STA2 '.00 GAS LIFT ICAMCO/KBUG/1/DMY/BK/I/Comment: STA 3 1.62 GAS LIFT ~CAMCO/KBUG/1/DMY/BK///Comment: STA4 L48', GAS LIFT !ICAMCO/KBUG/i/DMY/BK/// Comment STA 5 {.92i GAS LIFT ICAMCO/MMM11.5/DMY/RK/// Comment STA 6 187 PLUG SET 35" EZSV PLUG {.85 NIPPLE Camco'W' Nipple NO GO Top (TVD) '~ Btm (TVD) Dens m (ftKB) (HKB) I (HKB) Zone Date (sh.,. Type Common[ 7 726.0 6,221.Oi 6,236.6 C-0, 3M-03 3/5/1991 6.0 IPERF 2 1!8' Dyna Stdp, 0 deg. ph 7,752 0 6,246.6 6,255.1 A-3, 3M-03 3/5!1991 6.0 IPERF 2 1/8" Dyna Strip, 0 tleg. ph 7,771.0 6,260-8 Q268.6 A-2, 3M-03 3/5/1991 6.0 IPERF 2 1/8" Dyna Strip, 0 deg- ph 7,772 0 6,268.6 6,269.3 A-2, 3M-03 3/5!1991 7 0 IPERF 4" Csg Gun, 120 deg ph 7,774 Oli 6,269.31 6,270.7 A-2, 3M-03 3/5/1991 1 6 O IPERF 4" Csg Gun, 120 deg ph 7,780.0 6,270.7 6,274.9 A-2, 3M-03 3/5/1991 6.0 IPERF 4' Csg Gun, 120 deg ph 7,774 0~ 6,270.71 6,270.7 A-2, 3M-03 3/5/1991 I 7.O IPERF 4" Csg Gun, 120 deg ph 7,822.0 6,284.A1 6,304.6 ', A-1, 3M-03 7/3/1987 1 0 IPERF 4" Csg Gun, 120 deg ph 7,832.0 6.308.A ri,311.6'',i A-1. 3M-03 7/3/1987 1.0 IPERF 4' Csg Gun, 120 deg ph queez es Top DePih'~.. Bim Depth ----~--- _ (TVD) (TVD) m (HKB( (HKBI (tiK6) D cription StaA Date Comment --- 7 550 0 5,949.1 6.112.0 CEMENT PLUG 1 1 /2 0120 08 CEMENT P & A, FINISHED BY LAYING 3 E ', CEMENT ON TOP OE PLUG :neral _$_Safety _ ---- -__ _ _ - _ - Annotation NOTE: GAUGED TBG w/2.80"drift to 7624 '; tagged rathole @ 7841' RKB NOTE: Lost 3 KOT Arm Springs: 3.5' Long x 625" Wide x .050" thick NOTE FOUND LEAK IN TBG W/PONYTAIL @ 7508' SLM Ataska, fnc. 11 009 fi:¢42~.PM.. _ Scdl~ea4lc.At>val _.. _ NIPPLE, 5 W GAS LIFT, z,7se SURFACE, 3.608 GAS LIFT, 4,386 GAS LIFT, 5.740 GAS LIFT, 6,555 GAS LIFT, ].128 CEMENT PLUG, 7,320 PLUG, 7,550- NIPPLE,7,566- PACKER, 7,fi07- NIPPLE, 7,624- 505, 7,633- TR, 7,634 - IPERF, _ 7,]04-7,726 IPERF, _ 7,]40-7,752 IPERF, 7,760-7,771 IPERF, 7,771-7,772 IPERF, _ 7,772-7,7]4 IPERF, ],7I4- IPERF, _ 7,]74-7,780 IPERF, _ 7,794-7,822 IPERF, 7,828-7,832 PROOUGTION, 8,041 ~',\ TD (3M-03), 8,065 KUP ~ 3M-03 Well_Attrtbutes Max A~g_8~ MD STD Wellbore APl/UWl Freitl Name waO Status Yrow h,,)~ypa I I() MD (ftKB) n Act Btm (kK6) 500292169600 I (UPARUK RIVER UNIT JPROD ~_ 4703 5,700.00 8,065.0 Commetd ~ H26 (ppm) Date nd Date Annotatio ~ KBGrd (fq Rig Release Oate SSSV: NIPPLE 0 7/1/2008 ~ Last WO: 6/25/1997 40.71 3!8/1987 A lotion De pth (kK6) End Dot A nnotate n End Date Last Tag: 7,747 0 7!21!2008 L __, Rev Reason P & A ADD CEMENT PLUG -,._ 11/21/2008 Casing Strings __ ___ __ _ __ String OD String ID Set Uepth Jet Ueptn (TVDJ J[nng Wt Jtrm g Casin Desai lion (In) ~ (in) To kK6 (kK6) (kK6) _ (Ibs/k) Grade Sting Top Thrd CONDUCTOR 16 15.062 0.0 115.0 115.0 62.58 H-40 SURFACE 9518 8.765 0.0 3,608.0 ~~ 3,305.8 36.00 J-55 PRODUCTION 7 6.151 0.0 8,041.0 6,4572 26.00 J-55 Tubtng Stnng s _ Tubin De i lion string oD (in) str ng ID (n) To ftKe set Depth set Delnn irvDl Jtring wt (kK6) (kK6) (IbsHt) ~ Jving Grade Strin To Thrd TUBING 31/2 2.992 0.0 7,634.0 6,171.3 9.30 L$0 EUE AB MOD _ - Other In Hole f . _ All Jewelry: Tubin _ - g Run g Retrievable; Flsh,_eta) - - - Top Depth (ND) Top Inc! To KB (kK6) (7 Description Comment _ Run Data ID in 504.0 504.0 0.86 NIPPLE Camco'DS' Nipple 6/25/1997 2.813 2,758.0 2,675.7 32.57 GAS LIFT CAMCO/KBUG/1/DMY/BK/!/Comment STA 1 6/18/2003 2.920 4,388.0 3,869.9 45.37 GAS LIFT CAMCO/KBUG/1/DMY/BKI//Comment STA 2 6/18/2003 2.920 5,740.0 4,815.2 47.00 GAS LIFT CAMCO/KBUG/1/DMY/8K/!/Comment STA 3 6/18/2003 2.920 6,555.0 5,402.2 43.62 GAS LIFT CAMCO/KBUGl1/DMYlBK//l Comment STA4 6118/2003 2.920 7,128.0 5,612.6 44.48 GAS LIFT CAMCOJKBUG/1/DMYlBKI//Comment STA5 1/21/2001 2.920 7,519.0 6,090.0 44.92 GAS LIFT CAMGO/MMM/1.5IDMY/RK!// Comment: STA 6 1/2112001 2.920 7,550.0 6,112.0 44.87 PLUG SET 3.5" EZSV PLUG ~~ 11/19Y2008 0.000 7,564.0 6,121.9 44.85 NIPPLE Camco'W Nipple NO GO ~~ 6/2511997 2.812 7.607.0 6,151.9 44.35 PACKER Baker'SAB-3'Pertnanent Packerw/K-22'Anchor Seal 6/25/1997 3.500 7,634.0 6,171.3 44.49 ~TTL TTL ELMD 7631' SW53~//198/ Perforations _ - _ sl„~ Top (ND) Btm (ND) Dens fo B Btm (ftKB (ftl(B) (NKB) Zone Date (sh.° Type Ibrzon oar ~ ~ omment 7,704.0 7,726.0 6,221.0 6,236.6 C-4, 3M-03 3/5/1991 6.0 IPERF 2 1/8" Dyna Strip, 0 deg. ph 7,740.0 7,752.0 6,246.6 6,255.1 A-3, 3M-03 3/5/1991 6.0 IPERF 2 1/8" Dyna Stdp, 0 deg. ph 7,760.0 7,777.0 6,260.8 6,268.6 A-2, 3M-03 3/5/1991 6.0 IPERF 2 1/8" Dyna Strip, 0 deg. ph 7,771.0 7,772 0 6,268.6 6,269.3 A-2, 3M-03 3/5/1991 7.0~ IPERF 4" Csg Gun, 120 deg ph 7,772.0 7,774.0 6,269.3 6,270.7 A-2, 3M-03 3/5/1991 6.0 IPERF 4" Csg Gun, 120 deg ph 7,774.0 7,780.0 6,270.7 6,274.9 A-2, 3M-03 3/5/1991 6.0 IPERF 4' Csg Gun, 120 deg ph 7,774.0 7,774.0 6,270.7 6,270.7 A-2, 3M-03 3/5/1991 7.0 IPERF 4" Csg Gun, 120 deg ph 7,794.0 7,822.0 6,284.8 6,304.6 A-1, 3M-03 7/3/1987 1.0 IPERF 4" Csg Gun, 120 deg ph 7,828.0 7,832.0 6,308.8 6,311.6 A-1, 3M-03 7!3/1987 1.:,,IPERF 4" Csg Gun, 120 deg ph .;ernent fo HKB Saueez Btm kK6 es _ _ ___; Top Depth Btm Depth (ND) (ND) (kK6) !kK6) Deswi ion Stag Date I _ _-: Comment - ENT P & A, FINISHED BY LAYING 3 BBLS 7,320.0 7,550.0 5,949.1 6,112.0 CEMENT PLUG 11/20/2008 CEM CEMENT ON TOP OF PLUG Votgs: General & Safe y ____ _ Entl Gabe ,watn ~~ U15/2001 NOTE: GAUGED TBG w/2.80" drift to 7624'; tagged rathoL - W 1' RKB !/13/2002 NOTE: Losi 3 KOT Arm Springs: 3.5' Long x .625" Wide x 050" thick r/15!2004 NOTE: FOUND LEAK IN TBG W/PONYTAIL @ 7508' SLM • • 3 ,~ "~ s ~ ~ (~ ~ ~ ^~ ~' °' ~ i ~ .r ~ ,~ ~~'' ~ ~ ~ ~. ~, ~ SARAH PALIN, GOVERNOR C ~T p. ALAS OIL AI~TD ~ ~ / 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA'1`IOI~T COl-~II~II5SIOI~T ;dr ANCHORAGE, ALASKA 99501-3539 % PHONE (907) 279-1433 1 FAX (907) 276-7542 Guy Schwartz Wells Engineer ConocoPhillips Alaska Inc. ~ b' PO Box 100360 1 Anchorage, AK 99510 1 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3M-03 Sundry Number: 308-394 Dear Mr. Schwartz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As pro~~ided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Corrunission grants for good cause sho~~n~, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day i ( t:he 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been regt: ~-: geed. Sincerely, Daniel T. Seamount, Jr. Chair DATI ~: ~ this S day of November, 2008 Encl . ~~ ~~~~~ ' . ~'. ~ A STATE OF ALASKA ~~~ r ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ( .,~ L.u2,~. \ APPLICATION FOR SUNDRY APPROVAL ~ .n . 20 AAC 25.280 1. Type of Request: Abandon ^/ Suspend ^ Operational Shutdown ^ Perforate ^ Wa(vbr ^-' Other ^ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 187-014 • 3. Address: Stratigraphic ^ Service ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-21696-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS ^ NO Q 3M-03 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25523 RKB 64' • Kuparuk River Field /Kuparuk Oil Pool ' 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (tt): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8065' 6474' ~ 7950' 6393' 7624' Casing Length Size MD TVD Burst Collapse CONDUCTOR 115' 16" 115' 115' SURFACE 3544' 9-5/8" 3608' 3306' PRODUCTION 7977' 7" 8041' 6457' Perforation Depth MD ( 77oa'-772s', Perforation Depth TVD (ft): 6221'-6237' Tubing Size: Tubing Grade: Tubing MD (ft): 7740'-7752', 7760'-7780', 7794'-7822', 7828'-7832' 6246'-6255', 6261'-6275', 6285'-6305', 6309'-6312' 3-1/2" L-80 7634' Packers and SSSV Type: Packers and SSSV MD (ft) Baker'SAB-3' permanent pkr @ 7607' Camco 'DS' nipple @ 504' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Plugged and Abandoned Q Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat November 7, 2008 Oil ^ Gas ^ Plugged ~ Abandoned 'Q 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Name GU SChW Title: Wells Engineer /~' Signature C.~ Phone 265-6958 Date V ~ ~ D Commission Use Onl Sundry Nu ber: Conditions of approval: Notify Commission so that a representative may witness (~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ 1 GS~ ~cO~vC~ ~ p other: 3 ~~ \ °i l VIZ t~ ~ Vv~`j P,~~O 1~ ~..~. S ~1' ~~ ~JS%' I Subsequent Form Required: ~.~ (~ ~ ' ~1 ~>. = _,~... ~ ~~ APPROVED BY ' Approved b ~ COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 ~ i _ ~ ; Y._ 3 Submit i Duplicat ~.' ~~~ ~ ~ ~ IVY ~ ~,.. :~: ~ ~_:~~~. ~ ~ zo~~ ~~ ,~~ ~.os ^., ~.,~- c %yi • • 3M-03 P & A Outline October 20, 2008 Summary: 3M-03 was originally drilled and completed in 1987 as an A and C sand single completion, gas lifted producer. In mid 2002 the well died and was found to have large rocks in the tubing. After remedial attempts to repair the problem failed the well was permanently shut-in. Due to the quantity and type of fill and the condition of the tubing (it is 3 1/2" J-55 that is severely corroded) it is impossible to repair the well using non-rig' intervention. The well status currently has fill at 7747' and which covers most of the open perforations. There is a tubing tail plug installed at 7624' to secure the well. The goal of this project is to sidetrack the original wellbore 3M-03 to a new bottom-hole location which will target the original well's remaining reserves as well as incremental reserves. The new bottom-hole location has been optimized from a geologic standpoint to place it in along the edge of the current fault block which will improve areal sweep efficiency and remove the well from the area of solids production. Initial oil rate from the new well should also be positively affected as the area should be currently un-swept by the waterflood and therefore have a lower water saturation and lower initial water cut. ~,v ~ c ~: ,;,~ ~~ ~~, After pre-rig P & A is completed Doyon 141 will then move in and pull the 3 %" tubing. E-line will seta 7" CIBP at approximately 5520' . A whipstock will be set on ~ ~ ~/~ ~~'~ top of CIBP to sidetrack the 7" casing at 5500' md. Pre-rig Wellwork: 1) Test wellhead packoffs/ cycle LDS's. 2) Use existing plug in tubing tail to perform CMIT. Pull Plug. Establish injection rate into perf zone. 3) Set 3 %2" cement retainer at 7550' md- rkb. (just above SAB-3 packer) 4) Pump cement into A and C sand zones via retainer. Pump cement until 1000 psi squeeze pressure is attained. S~S~ vo~v w~~ ~- (fl ,j~~5 ~7~-~ i~ ~ S) Pull out of retainer and lay in cement in tubing to depth of 7450' md. POOH w ~ CTU. 6) Wait 24 hours. RU SL and tag cement plug. Pressure test IA and tubing. 7) Pull GLM DV at 7128'. Cut tubing at 7400' md. (Powerjet cut with E-line) • 8) Set BPV, prep wellsite for rig. • Rig Work P & A component: 1. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. MI/RU Doyon 141. Test BOP's. 2. L/D the tubing hanger and pull 3-1/2" tubing. 3. PU mill, casing scraper, and 4" DP. RIH to top of tubing stub at 7400'md. POOH. 4. RU wireline set a CIBP inside the 7" casing at +/- 5520' and based on casing collar depth. ~~ S ~pP~~` 5. RIH with Whipstock and sidetrack well at approx. 5500' md. ConocoPhillips , ~ corvoucroR,__ ~ 115 NIPPLE, 504 - - - - GAS LIFT, 2,758 SURFACE, 3,608 ~-- TUBING. 0 GAS LIFT, 4.366.. GAS LIFT, 5,740 GAS LIFT. 6.555 GAS LIFT, ],128 GAS LIFT, ],519 NIPPLE, 7.568 PACKER, 7,607 NIPPLE. 7,624 ~ PLUG, ],624 SOS, 7,633 - TTL, ],634 - - -- IPERF, 7.704-7.726 7!E6 IPERF. ], ]a0-],]52 IPERF. - _~~ 7J60-0Pt ~ IPERF, 7,nf-].nz IPERF, T ]n2],n4 IPERF. ], Pa- - IPERF, _ 7, T/4-],]BO IPERF, _ - _ _~~jl 7,794-],822 R®7 IPERF, _ __ 7,828-7,832 - 10DUCTIgJ. e,o4f TD, 8.065 KUP ~ 3M-03 Well Attributes Nellbore APUUWI '.Field Name Tofal DepfN (ftKB) Well Staf us Maximum Inclination (°) 500292169600 ~ KUPARUK RIVER UNIT ( PROD 47.03 I 8,065.0 Oomment H2S (ppm) - D~ Annotation End Date KB-Grd (H) Rig Release Date NIPPLE I Las[ WO: 6/25/1997 40.71 3/8/1987 4nnotation Depth (ftKB) End Date Annotation End Date Last Tao: 7.747.0 7/21/2008 Rev Reason: TAG, C/O PLUG 8/1/2008 9 6,171 Comment: STATION #2 Comment: STATION a3 Comment: STATION q4 Comment: STATION 115 7,624.0 PLUG 2.75' CSA-2 PLUG set 6/29/200 7,633.0 SOS Baker 7,634.0 TTL TTL ELMD 7631' SWS 3/7/1987 7,704.0 1 7,726.0 6,221.0 6,236.6 IPtHF C-4, 3M-U3 ti.U 3/5/1991 ' 2 1]8- Uyna imp, u aeg. pn 7,740.Oi 7,752.0 6,246.6 6,255.1 IPERF A-3, 3M-03 6.0 3/5/1991 2 1/8' Dyna Strip, 0 deg. ph 7,760.0 1 7,771.0 6,260.8 6,268.6 IPERF A-2, 3M-03 6.0 3/5/1991 2 1/8' Dyna Strip, 0 deg. ph 7,771.O i 7,772.0 6,268.6 6,269.3 IPERF A-2, 3M-03 7.0 3/5/1991 4' Csg Gun, 120 deg ph 7,772.0 1 7,774.0 6,269.3 6,270.7 IPERF A-2, 3M-03 6.0 3/5/1991 I 4' Csg Gun, 120 deg ph 7,832.0 6.308.81 6, 311.6 ~IIPERF ~A-1,3M-03 ~ 1.07/3/1987 ~4'Csg Gun, 120 deg ph w/2.80' drift l0 7624'; lagged ra[hole r4 7841' HKB n Springs: 3.5' Long z .625' Wide x .050' thick IN TBG W/PONYTAIL ~ 7508' SLM . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MlT) The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road SuiteC Anchorage, AK 99518 Fax: (907) 245-8952 1) 2) 3) 4} 5) 6) 7) 1 Report / EDE 3M - 03 Caliper Report 11-May-07 SCANNEDMA'l ,2 92007 ¡ff?-OJL( d; 1~(t.(O RECEIVED Signed: ulA- MAY ,~7007 1'1 ,2 _ ¡ Print Name: ß1t d.~~ \A-P ~IA '^ (,c.oAA Da~('~l & ~ CoII$. camrøl$-~ioo Anchol'age PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATlONAL AIRPORT RD SUITE C, ANCHORAGE, AI< 99618 PHONE: (907)245-8961 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: 'J\I\I\/W.MEMORYLOG.COM D:\Master _Copy _00_ PDSANC-2OxxIZ_ WoIli\Distribution\TronsmittaC Sheets\Transmit _ Original,doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3M-03 Log Date: April 16 & 28 & May 11, 2007 Field: Kuparuk Log No. : 7154,8590 & 7160 State: Alaska Run No.: 1,2&3 API No.: 50-029-21696-00 Pipe1 Desc.: 3.5" 9.3 lb. L-80 EUE Top Log IntvI1.: Surface Pipe1 Use: Tubing Bot. Log Intvl1.: 7,607 Ft. (MD) Inspection Type : COMMENTS: Corrosive & Mechanical Damage Inspection This caliper data is tied into GLM 5 @ 7,128' (Drillers Depth). This log was run to assess the condition of the 3.5" tubing with respect to internal corrosive and mechanical damage. The recordings indicate the 3,5" tubing is in good to poor condition with respect to corrosive damage. A hole is recorded in joint 239 at 7,545'. The damage appears in the forms of lines of corrosion, isolated pitting, and general corrosion. As illustrated În the Body Corrosion Profile the deeper penetrations are recorded in the interval between GLM 4 (6,550') and 7,607'. A 15% cross-sectional wall loss is recorded in joint 239 at 7,545'. No significant ID restrictions are recorded. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. Three separate runs of this tubing were made. The first run was made in the top 7,242' of the tubing. (The caliper was lowered to a depth of 7,588' and programmed to start recording at 10:35:00. However, the wire- line operator started logging 7 minutes too early at 10:28:35, resulting in a loss of coverage for the bottom -346' of tha tubing (or 7 minutes of data). The second run was made in the interval between GLM 5 (7,128') and 7,590'. However, the caliper fingers closed/opened periodically below 7,392', resulting in a loss of coverage below 7,392'. The third run was made between 7,603' - 6,870'. This report represents a composite analysis of all runs (April 16 and 28, 2007 and May 11, 2007). MAXIMUM RECORDED WALL PENETRATIONS: Hole Line Corrosion Line Corrosion Line Corrosion Line Corrosion 239 @ 240 @ 229 @ 232 @ 235 @ 7,545 Ft. (MD) 7,592 Ft. (MD) 7,226 Ft. (MD) 7,306 Ft. (MD) 7,394 Ft. (MD) ( 100%) ( 78%) ( 72%) ( 71%) ( 71%) Jt. Jt. Jt. Jt. Jt. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Hole 239 @ 7,545 Ft. (MD) ( 15%) Jt. No other areas of significant cross-sectional wall loss (> 8%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. I Field Engineer: Wm. McCrossan & K. Miller Analyst M. Tahtouh Wtness: T. Senden, C. Fitzpatrick, C. Kennedy I ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 0ECEIVED Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memoryloA Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 MAY 22 Z007 ( ~~-Oíq '¢ (~tLID Alaska 011 & Gas Cons. Commission Anchorage I I I Well: Field: Company: Country: 3M-03 Kuparuk ConocoPhiliips Alaska, ¡ne. USA I Tubing: Weight 9.3 f Nom.OD 3.5 ins Grade & Thread L-80 WE I I Penetration ami Metal loss (% wall) metal loss body I I I o to 1% 10 to 20 tD 40 tD over 20% 40% 85% 85% 1 to 10% 1 o I I Damage Configuration ( body ) 40 I 30 20 I 10 I o isolated general line ring hole I poss pitting corrosion corrosion corrosJon ¡hie hole I I I PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No, of Fingers: Anal st: NomJD 2.992 ins May 11, 2007 MFC 24 No, 214320 1,69 24 M. T ahtouh Nom, Upset 35 ins Upper len. 6.0 ins lower len, 6.0 ins GlM 1 GlM 2 GlM3 GlM4 GlM 5 GLM6 Analysis Overview page 2 I I Damage Profile (% wall) _ penetration body o o metal lass body 50 100 Bottom of Survey = 240,1 I I Correlation Damage to Borehole Profile Pipe 1 3,5 in ·7602,1') Well: 3M-03 I Field: Kuparuk Company: ConocoPhillips Alaska, loc. Country: USA Survey Date: May 11, 2007 I I Approx. Tool Deviation Borehole Profile I 8 I 25 781 I 50 1572 I 75 2352 GLM 1 I 100 3125 (¡) -0 ".; E u.. I ;;:¡ 125 3923 .E z +' c: GLM 2 I 150 4703 I 175 5494 GLM 3 I 200 6262 GLM 4 I GLM 5 7066 GLM 6 240.1 7602 I 0 50 100 Profile wall) I Tool Deviation I Bottom of Survey = 240.1 I I ------------ I I I I I I I I I I I I I I I I I I I JOINT LATION SH Pipe: Body Wall: Upset Wall: Nomina! I.D.: 3.5 in 9.3 0.254 in 0.254 in 2.992 in L-80 WE Well: 3M-03 field: ConocoPhillíps Country: USA Survey Date: May 11, 2007 Inc. joint jt Depth Pen Pen. Pen ! ¡!Aetal Min. Damag e Profile No. Body !.D. Comments (% (If .) (Ins.) % (Ins.) 0 50 100 .1 3 !1tif 2.89 1 8 2.92 Shallow oittinll. ') 43 0:03 12 2.92 3 83 ft±]:03 11 2.93 4 121 ( 01 11 2.93 5 152 0.03 11 2.93 6 184 0.0') q 2.'13 7 216 0.03 ) 7.94 8 248 0=t;= j 2.93 9 281 0 2.93 10 312 o .04 7.93 Shallow nittinc. 11 341 0 I ~ 12 372 0 13 402 0 14 433 0 2.93 1'1 465 0 0.02 2.93 1" 1 4% (' 10.01 D,,' 2.81 DS NIPPLE 16 497 1 2.93 17 529 ) 2.Q2 18 <¡hO 1 2.93 19 590 O.O~I ) 1 2.93 :>0 618 o O.O':! i! 2.93 21 649 o.m i1 2.93 22 682 0.02 2.93 7~ 715 ft') 7,«:13 24 748 2.93 25 781 2.95 26 812 0.02 2.94 27 84':! 0.02 2.91 28 87'1 0 0.03 ;) 2.93 29 '1011 0 0.02 i 2512 30 941 0 0.03 ] ~ 31 973 I 0.02 32 1004 0.02 2.93 33 1034 0.02 7.92 34 1064 0.03 11 2.92 35 1095 0.02 2.92 36 1127 0.Q2 2.91 37 1159 °iliti 0 2.93 38 1191 O. Ö 2.92 39 1221 0 (ÚÜ 2.94 40 1252 0.02 ±H= 41 1 '>81 0.02 J 42 1312 0.03 1 2.93 4'{ 13M ~ 2.92 44 1377 1 2.92 Lt. Deoosits. 45 1409 0.02 2.93 46 1441 0.02 ~ 47 1474 n.03 13 Shallow corr""¡tWI. 48 1506 0.03 10 ? 2.91 Body Metal loss Body I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT Wall: Upset Wall: Nominal I.D.: 3.5 in 93 ppf 1.-80 EUE 0.254 in 0.254 in 2.992 in USA May ", 2007 Well: field: 3M-03 Kuparuk Alaska, Ine. Joint Jt Depth PerL Pen. Pen. Metal Min. Damag e Profile No. I(:::~(;t 1.0. Comments (°/0 (Ins.) (Ins.) 0 50 100 49 1539 () 2.92 Shallow Dittiml. 50 1572 () ISh.,IoWoith. 51 1606 () 52 1640 () 53 1674 0 Shallow nitlin<1'. III 54 1707 () 0.04 15 2.8 Shallow njltiml. 55 17'H3 () O.lH hH 2.93 Sh;¡lIow nitl:inll. 56 1772 0 0.03 2.91 57 1806 () 0.01 1 2.111 58 1839 0.03 =lli 59 1870 0.03 60 1901 0.02 I 2.93 61 ~ 0.03 ì 2. 2.92 Shallow Dittim:. 62 0.03 t 2.93 I 63 1993 0.04 6 ì 2.93 . . 64 2024 () 0.04 4 ì 2.92 Shallow nitl:inQ. I 65 2054 ) ~ I 2.93 66 2085 ) 2. 2.91 67 2115 ) 2.91 Shallow nittinll. 68 2145 ) 0.03 2.93 69 2175 0.03 2.91 70 2205 () 0.0'1 3 2.92 Shallow nittirlll. 71 2215 () 0.02 2.91 72 2265 () 0.04 I 2. 2.92 Shallow corrosion. 7.3 2291) :> 2.92 Shallow corrosion. 74 2324 0.04 2. 2.93 Shallow Dittim:. 75 2352 ~ 2.92 76 2381 () 2.93 II 77 2412 0.02 :¡ 2.93 . 78 2442 0.02 2.93 79 7471 J It 2.93 80 2503 () 0 [) 2.93 81 2533 ( 0 2.92 82 2562 ( O. 1 2.92 83 2592 ( 0.03 2.94 84 2621 ( 0.02 2.94 85 2652 0 0.02 7.93 86 2683 0 0.02 2. }2 87 2714 0 0.02 2., 17 87.1 2744 ( 0.0; I NA GlM 1 (latch @ 3:001 88 2751 ( 2. 1 89 2781 ( 2.91 Shallow cOffQsiOI1. 90 2810 0.03 2.94 91 2840 0 0.04 2.90 Shallow nittil1ll. 92 2872 0.02 2.95 93 2903 !t 2.91 Shallow corrosion. 94 2933 2.94 95 2962 ( 2.91 96 2993 ( 0..03 ! 2.92 97 3024 ( 0.04 ! l 1 2.89 Shallow niWng. Body Metal loss Body 2 I I I I I I I I I I I I I I I I I I I Pipe: Body Wali: Upset Wall: Nomina! 1.0.: 3.5 in 9.3 ppf l-80 WE 0.254 in 0.254 in 2.992 in Well: Field: 3M-03 USA May 11, 2007 Alaska, Inc. Joint Jt. Depth Pen. Pen. Melal Min. -" Profile No. LD. Comments wail) (Ins) (Ins.) '% (Ins.) 0 50 100 98 3051'1 n 0.03 n :¡ /.89 ShaiJow ruttinq ~ :i 7.90 2.95 3157 n W ~- 2.g1 Shallow corrosion. 31 90 n i---' :ftf: Shallow nittiru;¡. 103 '{:?1 0 104 ,,!:'''6 2.93 Shallow oiltio!:l. 105 3 91 ~ 2.94 106 3376 '-- 2.94 2.91 108 3387 0.02 m tOg "1417 003 i 110 3448 0.01 11 111 34.RO 2.91 Shallow nittím:!. 112 3'>11 I 113 '1543 ~ Shallow corrosion. till: -:¡<;¡ 0.02 q 1 5 3611 116 363 [) ~ 3666 2.94 118 3698 i 19 ±±2.89 Shallow corrosion. 1 3732 1 2.91 1 376'1 2.93 121 I 3797 2.93 Shallow corrosion. 122 82<1 0.03 288 123 i 0.03 I 2.91 124 3892 0 0.02 11 2.95 125 3923 0.02 q 2.94 126 3954 $ ¡{ 2.93! corrosion. 127 3984 gm 128 4014 129 4043 no 4073 0 131 4103 2.92 132 4136 10 2.'n 133 4169 2.92 1'14 i 420Q .2 2.90 j!III 135 4231 2.89 Shallow oHlin ;!. j!III 136 426"1 2.9? 137 4295 0 2.91 138 4328 (1 tµ 2.9"l 139 4357 2.87 139.1 4391 Q NIA G! M 2 {latch @ 4:0m 140 439B =¡ 11 2.92 141 4430 ¡ 2.90 142 4463 2.95 143 4492 tti 2.97 Sh"lIow oitijnq. 144 4521 I 2.91 Shallow corrosion. ill 14'5 4552 ¡ VIS 146 4584 I 2.88 3 I I I I I I I I I I I I I I I I I I I Wall: Upset Wall: Nominal 1.0.: TABULATION 3.5 in 9.3 0.254 in 0.254 in 2.992 in 1.-00 WE Well: Field: Joint Jt. Depth Pen. Pen. Pen, Metal Min. No. LD. (Insì (Ins.) (Ins.) 147 148 149 467 150 4703 151 4734 152 4761 153 4792 154 4822 ~ 4853 1 4884 i57 491 i fi58 4IJ44 1 9 4<175 5006 61 5038 162 5069 163 164 5136 165 5168 166 5201 167 5233 168 5266 169 5298 170 5330 171 5360 172 5392 173 5476 174 5461 175 5494 176 5525 177~ 178~ 179 5620 180 5652 181 5684 182 5717 182.1 5749 183 5755 184 5787 185 5816 186 5845 187 5876 188 5907 189 5939 190 5969 191 5999 192 6028 193 6056 194 6085 195 6n5 .L 2 2.93 Shallow Dittil12. S 2.'10 ) 7.92 ') Shallow pitt¡n~. 0.03 it. Deoosits, 0.02 2 0.00 2 0.04 14 2 2.92 . 00 . .k.2:l .2.2L Shallow corrosion. í 0.02 1.1 2.95 { (:> ·~tHt ( 2 ( B 2 Sh allow corrosion. Lt Denosits. 002 I 0.04 ¡ 2 Shallow Ditting. 0.02 ¡ 8 2.90 I ShaUow corrQsion. U· ) Shallow pittirw;. o . N/A GlM 3 II ""." @ 2·00> · J L 2.91 Snal!owpittios{. 2 2.94 2.95 o 2 2.92 :> ¡J 2.93 2.Q1 2.95 2.Q2 2.92 J 2.94 ') J- 2.94 2= 2.93 " 2.92 a 1 lIow oittioo n n Shallow oittin2. ?91 Shallow pittim!. Shallow corrosion. 0.02 n o o o J J J J 0.02 0.02 0.02 0.02 4 3M.{)3 USA May 11, 2007 Comments Alaska, ¡nc. Profile 1",1 .11I \ 10 """'I o 50 100 I I I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: Nomina! I.D.: 3.5 in 9.3 ppf L-80 EUE 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-03 Kuparuk ConocoPhìllips AlasKa, Ine. USA May 11, 2007 I joint jt. Depth 1\'1 Pen. Perr Melal Min. Damage P rofile No. (Ft) Body LD. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 196 6143 ;100 I 2.93 f!II 197 6172 I /.88 f!II 198 6202 I 0.03 4 2.93 Shallow pittím~. 199 6232 0.03 :' 2.94 200 6262 =$I I 3 293 Shallow oitting. 201 6294 I:J ) 2.93 202 6325 1 O.O~ IB 6 2.90 ShaJlow oittin\2. 203 6353 1 3 2.94 204 6385 n 0.Q2 2.93 205 6414 0.04 16 2.91 Shallow pittim;¡;. 206 6445 0.02 7 2.93 207 6477 0.02 ~ 208 6509 0.04 5 Shallow oittim!. 208.1 6539 0 I GLM 4 (Latch @ 1 :00) 209 6546 0 0.08 2.92 isolated oittim!. 210 6578 0.04 0.10 2.93 Isolated oittim!. Lt. Denosits. 211 6610 0 0.14 2.92 line corrosion 212 6641 I 0.07 2.91 line corrosion. 213 6673 ( 0.18 I 2.91 line corrosion. Lt. Denosits. 214 6705 ( 0.10 £10 6 2.90 line corrosion. Lt. Deoosits. 215 6735 0.15 r)8 r¡ 2.90 Line corrosion 216 6767 0 0.09 36 r¡ 2.84 Line corrosion. Lt. Denosits. 217 6799 0 0.10 38 2.87 Line corrosion. Lt Deoosits. 218 6830 0.06 0.10 ti 2.94 line corrosion. 219 686? 009 0.13 2.91 line corrosion. 220 6909 007 0.12 2.93 line corrosion. 221 6940 n 0.15 ( I 2.93 line corrosion 222 6972 007 0.15 r 4 2.90 line corrosion. 223 7004 cwn 0.16 f I 2.93 Line corrosion. 224 7036 0.1 0.12 2.94 line corrosion. 225 7066 0.15 ( I 2.91 line corrosion. It. Denosits. 226 7098 0.17 f 2.95 Une corrosion. 226.1 7129 0 0 N/A GLM 5 (Latch @ 7:00\ 227 7137 0.16 f f, 2.77 Corrosion. Lt. Deoosits. 228 7168 O.lS 6 2.93 line corrosion. 229 7199 ( 0.14 6 2.92 Line corrosion. Lt. Deoosits. 230 7230 0.16 2.93 line mrrosíon. 231 7262 O. 17 0.18 ( 2.95 line corrosion. 232 7294 O. )6 0.18 2.92 Line corrosion. 233 7327 0 0.17 2.95 line corrosion. 234 73.5R .10 0.17 2.94 Line corrosion. 235 7390 '2 0.18 2.93 line corrosion. 236 7421 ¡(¡ 0.16 I 2.95 line corrosion. 237 7452 :0 0.17 I ) 2.92 line corrQsion. 238 7483 2 0.17 6 2.95 line corrosion. 238.1 7515 0.D2 2.97 PUP 238.2 7520 0 0 ¡ N/A GLM 6 (Latch @ 8:30\ 238.3 7531 0 o~ 4 2.85 PUP Shallow pitting, Lt. Deoo5Íts. 239 7535 ()IN O. DO 1 S 2.95 HOLE! 239.1 7567 0 o 0 ( 2.81 W NIPPLE I I I I I I I I I I I I I I Body Metal Loss Body Page 5 I I I I I I I Wall: Upset Wal!: Nomina! 1.0.: Joint Jt. No. 240 240.1 I I I I I I I I I I I I PDS NT TABULATION SH 3.5 in 9.3 ppf L-80 WE 0.254 in 0.254 in 2.992 in Well: Field: Dare: 6 3M-03 ConocoPhillips USA May 11, 2007 Comments loe. Profile wall) o 50 100 Body Metal loss Body .. .. .. .. .. Well: Fieid: Company: Country: Tubin : 3 M.{) 3 Kuparuk .. .. USA 3.5 ins 9.3 f L-80 WE Alaska, Inc. .. .. Too! '" 43 Nominal 10 '" 2.992 Nomina! 00 = 3.500 wall area'" 85 % Tool deviation = 45 0 .. .. .. .. .. .. .. s Penetration = 0.556 ins HOLE 0.56 Ins = 100% Wall Penetration 15% Cross-Sectional Wall Loss HIGH SIDE'" UP S Report Cross Survey Date: Too! Type: Tool Size: No, of Fingers: Anal st: 11,2007 MFC UW 24 No. 214320 1.69 24 M. Tahtouh 14 ft Cross Sections page 1 .. .. .. .. .. .. - .. We!!: Field: Company: Country: Tubin : .. .. .. 3M-03 Kuparuk ConocoPhmips Alaska, Inc. USA 3.5 ins 9.3 f l-80 WE Section for Tool " 43 Nominal to" 2,992 Nominal 00" 3.500 wall area" 93 "/" Tool deviation" 440 .. 7592 .. .. .. .. .. .. S Repo Cross ons Survey Date: Tool Type: Tool Size: No, of Anal st: May 11, 2007 MFC UW 24 No. 214320 1.69 24 M. Tahtouh it Finger 24 Penetration" 0.197 ins Une Corrosion 0.20 ins" 78% wall Penetration HIGH SIDE" UP Cross Sections page 2 .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. s Wen: 3 M"() 3 Field: Kuparuk AlasKa, inc. USA Tubin : 3.5 ins 9.3 f l-80 WE Date: Tool Type: Tool Size: No. of Anal st: Aprìl16 & 28,2007 MFC 24 No. 214320-211 90 1,69 24 M. Tahtouh ft Tool '" 50 Nominal 10"" 2.992 Nominal 00 '" 3.500 wal! area'" 94 % Tool deviation'" 42 0 10 Penetration'" 0.182 ins line Corrosion 0.18 Ins'" 72% Wall Penetration HIGH SIDE = UP Cross Sections page 3 .. s .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. s Well: 3M.{)] Field: Alaska, Inc. USA Tubin: 3.5 ins 9.3 f IA30 WE 16 & 28,2007 MfC 24 No. 214320-21190 1.69 24 M. Tahtouh ft Too! "" 49 Nomina! 10"" 2.992 Nominal 00 "" 3.500 wall area'" 94 % Tool deviation"" 45 " Finger 7 Penetration'" 0.18 ins line Corrosion 0.18 ins 71 % Wall Penetration HIGH SIDE = UP Cross Sections page 4 .. s .. .. .. I I I NIP (504-505, 00:3,500) I G~sUft , n<:IIellDummy Valve 1 (2758-2759. OD:5,390) I GasUft , n<:IIeIIDummy Valve 2 (4388-4389, 00:5,390) I I GasUft , ndrellDummy Valve 3 (5740.5741. 00:5,390) I Gas Lift , ndrnIlDummy Valve 4 (6555-6556, OD:5,390) I Gas Lift , ndrnIlDummy Valve 5 (7128-7129, 00:5.390) I Gas Lift , ndrnIlDummy Valveô (7519-7520, 00:6.018) I NIP (7564-7565, 00:3,500) I I PKR (7607-7ô08. 00:ô.151) I PLUG (71)24-7625. 00:2.750) I TUBING (0.7634. 00:3,500. 102992) 80s (7633-7634. OD:3500) Pert (7704-7726) I I Pert (7740-7752) Pert (7760.7780) Pert (7794-7822) I Pert (7828-7832) I 1aJ ;c - 1-- - - = =t '- -, -- - -- - ~7 Comoletion: lastW/O: 6125/1997 Ref loa Date: TD: 8065 ftKB ~700 Siz~ 16.000 0 115 9.625 0 3608 7.000 0 8041 API 0292 SSSV Type: Nìpple Annular Fluid: Reference loa: ~ ~2004 DescriDtioo CONDUCTOR Interval 7704· 7726 7740·7752 7760 - 7771 7771 - 7772 7772 - 7774 7774 - 7774 7774· 7780 7794 - 7822 T T 3 4 S- a - 6237 C-4 - 6255 A-3 6261·6269 A-2 6269 - 6269 A-2 6269 - 6271 A-2 6271 - 6271 A-2 6271 ·6275 A-2 6285 - 6304 A-1 6309.631~ Man~ Mfr 2676 Cameo KBUG 3870 Cameo KBUG Cameo KBUG Cameo KBUG Cameo KBUG MMM 2 4 5740 Status KRU 3M..03 TVD Tv_ 504 NiP Cameo 'OS' 6122 NiP Cameo 'W' Nioole NO GO 7607 6152 PKR Baker'SAB-3' Perm. 7624 6164 NIP Cameo '0' Nioole NO GO 7624 6164 PLUG 12.75" CSA·2 PLUG set 81612004 ;¡¡~~~¡ 6171 ~~E 1 Baker BG wl2.S0· drift to 7a24"~' @7841'RKB T Arm Sorinos: 3.5" lono x 050" thick 7/15 ND LEAK IN TBG WIPONVTAll 7508' SlM f...- ~ Angie @ 065 Rev Reason: Set PLUG last Uodate: 81812004 NO 115 3306 6457 Wt Grade 62.58 H-40 36.00 J·55 26.00 J.55 Ft 22 6 dea.pJ¡ 12 a 3/5/1 dea. pJ¡ 11 6 3/5/1991 Strip, Om 1 7 3/5/1991 IPERF 2 1/8" Dvna Strip, 0 2 _3/5/1991 21/S" DvnaStrio, 0 ° 7 3/5/1991 trio. 0 dea. oJ¡ 6 6 315/199 trio. ° dee. oJ¡ 28 1 713/198 20 dea oJ¡ 4 1 V Type V latch Port VMfr DMY DMY DMY DMY DMY DMY 1.0 1.0 1.0 1.0 1.0 1.5 Descrintioo w/ 'K-22' Anchor Sea! BK BK BK BK BK RK Run 0,000 0 6/18/2003 ~O'OOO 0 6/1812003 o 6/18/2003 6/1812003 2.813 2.812 ~ Cmnt I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. April 16, 2007 7154 1 3.5" 9.3 lb. L-80 EUE Tubing Well: Field: State: API No.: Top Log Intvl1.: Bot. Log Intvl1.: 3M-03 Kuparuk Alaska 50-029-21696-00 Surface 7,242 Ft. (MD) Inspection Type: COMMENTS: Co"osive & Mechanical Damage Inspection This caliper data is tied into GLM 5 @ 7,128' (Drillers Depth). This log was run to assess the condition of the 3.5" tubing with respect to internal corrosive and mechanical damage. The recordings indicate the 3.5" tubing is in good to poor condition with respect to corrosive damage, with a recorded maximum wall penetration of 69% in joint 213 at 6,677'. Penetrations ranging 20% to 69% are recorded in 22 of the 213 joints logged. The damage appears in the forms of lines of corrosion, isolated pitting, and general corrosion. As illustrated in the Body Corrosion Profile the deeper penetrations are recorded in the interval between GLM 4 (6,550') and 7,242'. No significant areas of cross-sectional wall loss or 10 restrictions are recorded. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Line Corrosion Line Corrosion Line Corrosion Line Corrosion Line Corrosion ( 69%) ( 64%) ( 63%) ( 63%) ( 61%) Jt. Jt. Jt. Jt. Jt. 213 @ 226 @ 227 @ 230 @ 223 @ MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (>9%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded. I Field Engineer: Wm. McCrossan Analyst: M. Tahtouh 6,677 Ft. (MD) 7,121 Ft. (MD) 7,151 Ft. (MD) 7,238 Ft. (MD) 7,168 Ft. (MD) RECEIVED APR 1 9 Z007 Alaska Oil & Gas Cons. eommlssion AndlOrage Witness: T. Senden I Pro,A,ctive Diagnostic Services. Enc P.O. Box 1369, Stafford, TX 7ì497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax; (907) 659-2314 1~1- - O(L..{ ¥ 16Ó<./L ( I I I Well: Field: Company: Country: 3M-03 Kuparuk ConocoPhiflips Alaska, Ine. USA I Tubing: NomDD 3.5 ins Weight 9.3 f Crade & Thread L-80 WE I Penetration and Metal loss (% wall) I metal loss body o o I I I 20 to 40 to over 40% 85% 85% pene. loss I I Damage Configuration ( body ) 40 I 30 20 I 10 o I isolated generd! !ine ring hole / pass pitting corrosion corrosion corrosion ¡ble ho!e I o I I PDS Report Overview Body Region Analysis penetration body o o Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Nom.ID 2.992 ins CLM 1 CLM2 GLM 3 CLM4 April 16, 2007 MFC UW 24 No. 214320 1.69 24 M. Tahtouh Nom. Upset 3.5 ins Upper len. 6.0 ins Lower len. 6.0 ins Damage Profile (% wall) metal loss body 50 100 CLM 5 Bottom of Survey = 230 Analysis Overview page 2 I I I I Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (3.4' - 7232.0') Well: Field: Company: Country: Survey Date: 3M-03 Kuparuk ConocoPhillips Alaska, Ine. USA April 16, 2007 I I I Approx. Tool Deviation Approx. Borehole Profile I 2352 CLM 1 0 3125 ~ ~ (j) .,.; ...0 E LL ::;¡ .S: Z ..!:: E 3923 ã. 'õ (j) 0 CLM 2 4703 8 I I 781 I 1572 I I I I CLM 3 5494 I 6262 CLM 4 I CLM 5 I 50 7059 7232 100 Damage Profile (% wall) I Tool Deviation (degrees) I Bottom of Survey = 230 I I I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: NomínaII.D.: 3.5 in 9.3 ppf L-80 WE 0.254 in 0.254 in 2.992 in Well: field: Company: Country: Survey Date: 3M-03 Kuparuk ConocoPhillips Alaska, Ine. USA April 16, 2007 Joint Jt. Depth PCI) Pen. F'el) !vleta! Min. Damag e Profile No. (Ft.) Body LD. Comments (% wall) (Ins) (Ins.) (Ins.) 0 50 100 .1 3 0 0.01 S 0 2.89 PUP 1 8 () 0.04 I ) 2.92 Shallow nilling. 2 43 0 0.03 1 3 2.92 3 83 0 0.03 11 2.93 4 121 0 0.03 II I 2.93 5 152 0 0.03 1 ) 2.93 6 184 () .0.02 U) 2.93 7 216 I 0.03 ) > 2.94 8 248 I 0.03 1 ) 2.93 9 281 I 0.03 1 2.93 10 312 ! 0.04 15 2.93 Shallow nittino. 11 343 I 0.03 11 2.92 12 372 () 0.02 9 2.94 13 402 0 0.03 I 2.93 14 433 () 0.02 ) 2.93 15 465 () 0.02 ) 2.93 15.1 496 () 0 () 2.81 DS NIPPLE 16 497 () 0.03 I 2.93 17 529 () 0.02 ) 2.92 18 560 () 0.03 11 ¡ 2.93 19 590 () 0.03 12 I 2.93 20 618 () 0.03 1 I 2.93 21 649 () 0.03 ;; 2.93 IiI 22 682 () 0.02 ) 2.93 IiI 23 715 I 0.03 ) ) 2.93 24 748 ( 0.02 1 ) 2.93 I'll 25 781 ( 0.02 ) 2.95 II 26 812 ( 0.02 7 1 2.94 27 843 I 0.02 7 I 2.91 28 875 0 0.03 12 ) 2.93 29 908 () 0.02 9 ) 2.92 30 941 0 0.03 I J 2.92 31 973 () 0.02 n I 2.92 32 1004 0.02 9 ) 2.93 III 33 1034 0.02 9 2 2.92 34 1064 0.03 II I 2.92 11II 35 1095 0.02 f! ) 2.92 II 36 1127 () 0.02 7 ;- 2.91 II 37 1159 II 0.03 10 ;; 2.93 III 38 1191 0 0.03 10 ) 2.92 II 39 1221 I 0.02 ) 2.94 III 40 1252 I 0.02 I 2.93 41 1281 ( 0.02 I 2.93 I!tII 42 1312 I 0.03 1 I 2.93 43 1344 I 0.02 9 2 2.92 , 44 1377 ( 0.03 1 3 2.92 Lt. Deoosits. 45 1409 0 0.02 II ) 2.93 46 1441 () 0.02 7 ) 2.92 47 1474 () 0.03 n 4 2.92 Shallow corrosion. 48 1506 0 0.03 10 2 2.91 Body Metal Loss Body Page 1 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf 1.-80 WE 0.254 in 0.254 in 2.992 in Well: Field: Company: Coun try: Survey Date: 3M·03 Kuparuk ConocoPhíllips Alaska, Ine. USA April 16, 2007 Joint Jt. Depth ¡>en Pen. ¡>en. I~ Min. Damag e Profile No. (Ft.) Body I.D. Comments (% wall) ( (Ins.) (Ins.) 0 50 100 49 1539 ( 0.03 13 2.92 Shallow nitting. 50 1572 ( 0.04 Ii) 2.91 Shallow oittinll. 51 1606 { 0.02 9 2.92 52 1640 n 0.02 9 2.91 53 1674 n 0.03 13 4 2.91 Shallow nittin". 54 1707 n 0.04 Ii ¡ 2.89 Shallow nittin<>. 55 1738 n 0.03 1 ;{ 2.93 Shallow nittinll. 56 1772 n 0.03 J 2.91 57 1806 n 0.03 L 2.91 58 1839 0 0.03 2.91 59 1870 ( 0.03 12 2.93 60 1901 n 0.02 7 2.93 61 1932 I) 0.03 12 ) 2.92 Shallow nittirJ<i7. 62 1963 n 0.03 II I 2.93 63 1993 n 0.04 Ii) > 2.93 Shallow nitting. 64 2024 I) 0.04 1 > 2.92 Shallow nitting. 65 2054 n 0.02 9 2.93 66 I 2085 I) 0.ü3 1) ) 2.91 67 . 2115 0 0.03 13 I 2.91 Shallow nittinll. 11II 68 2145 n 0.ü3 1) ) 2.93 69 2175 n 0.ü3 11 I 2.91 70 2205 I) 0.03 3 l 2.92 Shallow nittin"'. 71 2235 0 0.02 j 2.92 72 2265 0 0.04 ) 2.92 Shallow corrosion. 73 2295 ¡ 0.04 ) 2.92 Shallow corrosion. I 74 2324 ( 0.04 I 2 2.93 Shallow oittinll. 75 2352 ( 0.02 7 I 2.92 76 2381 ( 0.03 10 2 2.93 77 2412 ¡ 0.02 9 ¡ 2.93 78 2442 0 0.02 B ) 2.93 79 2473 0 0.03 ! 1 2.93 80 2503 0 0.03 0 ) 2.93 IfII 81 2533 () 0.02 ) 2.92 pi 82 2562 () 0.03 0 :2 2.92 83 2592 ¡ 0.ü3 2 2 2.94 ~ 84 2621 ¡ 0.02 9 I 2.94 ~ 85 2652 0.02 1 2.93 11II 86 2683 ¡ 0.02 2.92 11II 87 2714 ¡ 0.D2 ) 2.87 pi 87.1 2744 () 0 n N/A GLM 1 (Latch @ 3:00\ 88 2751 0 0.03 ¡ 1 2.91 -w.1 89 2781 0 0.05 18 2.91 Shallow corrosion. 90 2810 0 0.03 10 2.94 91 2840 0 0.04 15 2.90 Shallow oittim¡:. 92 2872 0 0.02 2.95 93 2903 0 0.04 b 1 2.91 Shallow corrosion. 94 2933 0 0.02 ) 2.94 95 2962 () 0.03 :2 2.91 96 2993 0 0.03 2.92 97 3024 0 0.04 1 i 2.89 Shallow oittinll. Body Metal Loss Body Page 2 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NorninaII.D.: 3.5 in 9.3 ppf L-80 EUE 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-03 Kuparuk ConocoPhillips Alaska, Ine. USA April 16, 2007 Joint Jt. Depth pp Pen. Per \/lp \;1 1 Min. Damage Profile No. (Ft.) 'I Body I.D. Comments (%wa II) (Ins.) (Ins.) (Ins.) 0 50 100 98 3058 0 0.03 n ) 2.89 Shallow nittin2. 99 3092 1 0.02 9 I 2.90 100 3125 1 0.02 .2 2.95 !III 101 3157 ( 0.04 1B .2 2.91 Shallow corrosion. 102 3190 ( 0.02 8 I 2.94 !III 103 3221 0.03 13 2 2.91 Shallow nittinQ. 104 3256 0.03 13 3 2.93 Shallow oittimz. 105 3291 0 0.02 I 2.94 106 3326 0 0.02 2 2.94 107 3358 0 0.Q2 2.92 108 3387 0 0.02 2.92 109 3417 0.03 1 2.93 110 3448 0.03 II 2.94 111 3480 ( 0.03 13 2.91 Shallow nittim!. 112 3511 0.02 ß 2 2.94 113 3543 0.04 6 I 2.88 Shallow corrosion. 114 3573 0.02 9 3 2.90 115 3603 0.03 .2 2.92 116 3635 0 0.02 B 2.93 117 3666 0 0.02 7 2.94 II 118 3698 0 0.05 19 2.89 Shallow corrosion. 119 3732 0 0.03 12 I 2.91 120 3765 (I 0.02 9 2 2.93 121 3797 (I 0.03 13 2 2.93 Shallow corrosion. (!II 122 3829 0 0.03 1 2.88 ~ 123 3860 0 0.03 I I 2.91 !III 124 3892 0 0.02 2.95 !I' 125 3923 (I 0.02 2.94 126 3954 0.03 1 2.93 Shallow corrosion. 127 3984 0.03 10 2.92 128 4014 0.02 2.93 129 4043 0.02 2 2.91 130 4073 ( 0.02 2 2.93 131 4103 0 0.02 2 2.92 132 4136 0 0.03 () .2 2.93 133 4169 0 0.02 ¡ 2.92 134 4200 0 0.03 () .2 2.90 (!II 135 4231 (I 0.03 1\ 1 2.89 Shallow nittin2. IIIí 136 4263 0 0.02 B .2 2.92 1(1I 137 4295 (I 0.02 9 I 2.91 (!II 138 4328 (I 0.02 q 2 2.93 1(1I 139 4357 0 0.Q2 (1 I 2.87 '" 139.1 4391 (I 0 I (I N/A GLM 2 (Latch @ 4:00) 140 4398 0 0.03 11 1 2.92 141 4430 () 0.03 11 I 2.90 (!II 142 4463 (I 0.02 ß 1 2.95 !III 143 4492 (I 0.04 14 2.92 Shallow oittimL (!II 144 4521 0 0.04 IS 2.91 Shallow corrosion. 1(1I 145 4552 (I 0.03 ¡¡ 2.85 (!II 146 4584 0 0.03 11 2.88 Body Metal Loss Body Page 3 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION S EET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 EUE 0.254 in 0.254 in 2.992 in Well: Fíeld: Company: Country: Survey Date: 3M-03 Kuparuk ConocoPhillíps Alaska, Ine. USA April 16, 2007 Joint Jt. Depth Pen Pen. Pen lvleta! Min. Damag e Profile No. (Ft.) Body I.D. Comments (% wall) (Ins (Ins.) (Ins.) 0 50 100 147 4615 0 0.02 8 1 2.93 148 4645 0 0.04 IS 4 2.94 Shallow....íttin"'. 149 4674 í) 0.02 Ii I 2.91 150 4703 0 0.04 .:1 2.90 Shallow níttinQ. 151 4734 0 0.02 q 2.92 152 4761 0.03 1 2.91 Shallow nittinll. 153 4792 I 0.03 I 2.92 154 4822 I 0.03 I 11 2.91 Shallow corrosion. 155 4853 0.03 11 2.93 156 4884 0.04 14 2~ Shallow....ittífw. 157 4913 0 0.03 1 S 2. Shallow ....íttin". 158 4944 0 0.02 q ;; 2.92 ~ 159 4975 0 0.04 4 ) 2.93 Shallow ....ittínQ. 160 5006 0 if 02 2.90 161 5038 0 03 D 2.89 Lt. De....osits. 162 5069 0 0.02 2.92 163 5102 0 0.00 2.96 164 5136 0 0.04 4 2.92 Shallow corrosion. 165 5168 0 0.04 4 2.88 Shallow nittínQ. 166 5201 0 0.02 ) 2.94 167 5233 0 0.04 7 2 2.92 Shallow corrosion. 168 5266 0.02 ¡ 2.95 169 5298 0.03 I 1 2.92 170 5330 0.02 q ) 2.94 171 5360 I 0.03 I) d 2.92 172 5392 ) 0.ü3 13 ;; 2.93 Shallow....ittínQ. 173 5426 0 0.02 a 1 2.92 174 5461 0 0.05 113 t 2.87 Shallow corrosion. Lt. Deposits. !IlIA 175 5494 0 0.02 7 2.91 176 5525 0 0.04 14 2.92 Shallow oíUim!. 177 5557 0 0.02 Ii 2.92 178 5588 0 0.04 17 2.90 Shallow corrosion. 179 5620 0 0.03 12 2.90 180 5652 0 0.02 ) 2.95 181 5684 !) 0.02 ) 2.93 182 5717 0 0.03 1 I 2.92 Shallow ....ittínQ. 182.1 5749 0 0 D 0 N/A GLM 3 (Latch @ 2:00\ 183 5755 0 0.03 3 2 2.91 Shallow oittinll. II 184 5787 0 0.02 2 2.94 II 185 5816 0 0.02 8 1 2.95 II 186 5845 0 0.03 10 ) 2.92 II 187 5876 0 0.03 12 ) 2.93 188 5907 0 0.02 1 2.91 ill 189 5939 0 0.02 1 2.95 II 190 5969 0 0.02 ) 2.92 !II 191 5999 (J 0.02 I 2.92 192 6028 0 0.02 2 2.94 193 6056 C 0.02 a I 2.94 . 194 6085 0 0.02 7 ) 2.93 ill 195 6115 0 0.02 11 '1 2.92 I Body Metal Loss Body Page 4 I I PDS REPORT JOINT TABULATION SH I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 WE 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-03 Kuparuk ConocoPhillips Alaska, Inc. USA April 16, 2007 I Joint ]t. Depth Pen. Pen. Pen.. !·iÌelal Min. Damage Prof ile No. (Ft.) Body 1.0. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 196 6143 0.02 9 I 2.93 ... 197 6172 0.03 1 I 2.88 198 6202 0.03 !. 4 2.93 Shallow oittim¡:. 199 6232 0.03 2.94 200 6262 0 0.03 2.93 Shallow oiuim¡:. 201 6294 0 0.02 2.93 ¡ 202 6325 0 0.05 I ß 2.90 Shallow pitting. 203 6353 0 0.03 I 2.94 204 6385 0 0.02 ¡ 2.93 ~414 0 0.04 b ) 2.91 Shallow piUim:¡. 206 6445 0 0.02 3 2.93 207 6477 0 0.02 2.92 208 6509 I) 0.04 5 2 2.90 Shallow oittiml. 208.1 6539 0 0 N/A GLM 4 (Latch @ 1 :00\ 209 6546 0 0.08 2.92 Isolated piUiml.. 210 6578 o 1M 0.10 0 2.93 Isolated pitting. Lt Denosils. 211 6610 0 0.14 57 2.92 Line corrosion. 212 6641 0 0.07 27 2.91 Line corrosion. 213 6673 0 0.18 69 B 2.91 Line corrosion. Lt. Denosi ts. 214 6705 0 0.10 ¿ 6 2.90 Line corrosion. Lt. Denosits. 215 6735 0 0.15 5 2.90 Line corrosion. 216 6767 0 0.09 5 2.84 Line corrosion. L t. Deoosi Is. 217 6799 0 0.10 01 2.87 Line corrosion. Lt Denosils. 218 6830 O. )6 0.10 41 4 2.94 I ine corrosion. 219 6862 0 )q 0.13 50 7 2.91 Line corrosion. 220 6894 0 )6 0.12 47 6 2.91 Line corrosion. 221 6925 0.15 )7 7 2.89 Line corrosion. 222 6956 0.15 )ß 6 2.88 Corrosion. 223 6989 ¡ 0.16 ( 2.89 Line corrosion. Lt. Deoosils. 224 7025 012 0.12 2.90 Line corrosion. 225 7059 011 0.14 I 2.92 Line corrosion. 226 7094 0 0.16 ( 2.91 Line corrosion. 226.1 7128 0 0 I ~ GLM 5 (Latch @ 7:00\ 227 7135 ().IO 0.16 6 / Line corrosion. Lt. Denosils. 228 7167 007 0.15 5' 6 2.91 Line corrosion. 229 7201 II 0.14 5 6 2.88 Line corrosion. 230 7232 II.IIß 0.16 6. 6 2.90 Line corrosion. I I I I I I I I I I Body Metal Loss Body I I I Page 5 I I ------ - - -- - -..- - .. .. PDS Report Cross Sections Well: Field: Company: Country: Tubin : 3M-03 Kuparuk ConocoPhillips Alaska, Ine. USA 3.5 ins 9.3 f L·80 EUE Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: April 16,2007 MFC UW 24 ¡\lo. 214320 1.69 24 M. Tahtouh Cross Section for Joint 213 at depth 6676.53 ft Tool speed = 43 Nominal 10 = 2.992 Nominal OD = 3.500 Remaining wall area = 92 % Tool deviation = 44 0 Finger 13 Penetration = 0.175 ins Une Corrosion 0.18 ins = 69% Wall Penetration HIGH SIDE = UP Cross Sections page 1 .. - ----- .. ...... .. .. -.. .. .. - .. .. - PDS Repo Cross Sections Well: Field: Company: Country: Tubin : 3M-03 Kuparuk ConocoPhillips Alaska, Ine. USA 3.5 ins 9.3 f L·BO EUE Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: April 16, 2007 MFC UW 24 ¡'lo. 214320 1.69 14 M. Tahtouh Cross Section for Joint 226 at depth 7121.33 ft Tool speed = 43 Nominal 10 = 2.992 Nominal 00 3.500 Remaining wall area 94 % Tool deviation 450 Finger 4 Penetration = 0.162 ins Line Corrosion 0.16 ins 64% Wall Penetration HIGH SIDE UP Cross Sections page 2 I I I I I I I I I I I I I I I I I I I . . ,~ ( TUBING 3112" SINGLE COMPLETION PRODUCER KRU 3M..o3 DATE: 6/25/97 1 OF 1 PAGES ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS ' COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH . . TOPS ORIGINAL RKB TO TUBING HANGER LDS (Dovon 9) 33.00 FMC Gen IV, 3-1/2" Tubing Hanger,3-1/2" EUEland thd .50 33.00 PUP ioint (double pin) 3.5", 9.3-#, L-80, EUE, 8rd mod'tubina 2.68 33.50 226-240 . 3.5", 9.3#, L-80, EUE, 8rd mod tubing 468.02 36.18 . . Camco OS nipple wi 2.813 NO-GO profile, 00 4.54 .96 504.20 154-225 3.5",9.3#, L-80, EUE, 8rd mod tubina 2252.38 505.16 GLM #6 Cameo 3.5" xl", KBUG, w/DV, BK-Slateh. 5.39 00,2.9210 6.64 2757.54 102-153 3.5", 9.3#, L-80, EUE, 8rd mod tubina 1624.13 2764.18 GLM #5 Cameo 3.5" x 1 ", KBUG, w/OV, BK-5 latch. 5.39 00, 2.9210 6.59 4388.31 59-101 3.5", 9.3#, L-80, EUE, 8rd mod tubina 1345.37 4394.90 GLM #4 Cameo 3.5" xi". KBUG, w/DV, BK-5 latch. 5.39 00, 2.921D ··6.65 5740.27 33-58 3.5", 9,3#, L-BO, EUE, 8rd mod tubing 807..94 5746.92 GLM #3 Cameo 3.5" x 1 It, KBUG, w/DV, BK-5 latch. 5.39 00, 2.9210 6.63 6554.86 15-32 3.5", 9.3#, L-80, EUE, 8rd mod tubina 566.69 6561.49 GLM #2 CamcoS.5" x 1", KBUG, w/DV, BK-5 latch. 5.39 00, 2.921D 6.64 7128.18 3-14 .. 3.5", 9,3#, L-80, EUE, Brd mod tubina 377.78 7134.82 PUP ioint 3.5", 9.3#, L-80, EUE 8rd mod 6.21 7512.60 GLM#1 Cameo 3.5 x 1.5, MMM, wi DCR-1 dump, RKP2 latch. aD 6.02,ID 2.92 8.48 7518.81 Pup joint 3.5", 9.3#, L-80, EUE Brd mod 5.70 7527.29 2 3;5", 9.3#,L-80, EUE, 8rd mod tubina 31.45 7532.99 W' Nipple 3.5" Cameo W nippl~ wi 2.812 selective profile, OD 4.54, 1.95 7564.44 1 3.5", 9.3#, L-80, EUE, 8rd mod tubina 31.55 7566.39 Pup joint 3.5", 9.3#, L-80, EUE 8rd mod 9.19 7597.94 PKR Baker 3.5" x 7" SA B-3, perm. pkr., w/K22 Anchor seal assembly 6.78 7607.13 Pup ioint 3.5", 9.3#, L·80, EUE 8rd mod 10.17 7613.91 Dr NIPPLE Cameo 3.5" D nipple wi 2.75" NO-GO profile. aD 4.500" 1.01 7624.08 Pup joint 3.5", 9.3#,' L-80, EUE 8rd mod 8.18 7625.09 Baker 3.5" 80S pinned for 3500 psi. 00 4.556", ID 2.937" .90 7633.27 . i TUBING TAIL @ 7634.17 . I I ¡ ! ! ¡ Ij I ! I 1___ I I t--... ¡ I I . ¡ ¡ Remarks: String Weights with Blocks: 70K# Up, 50K# Dn, 8K# Blocks. . Ran 240 joints of tubing. Drifted tubing, GLMs, & hanger with 2.867" plastic rabbit. Used Arctic Grade APLModified No Lead thread compound on all connections. Tubing is non-coated. NordicRig #2 . Drilling Supervisor: R. L. Morrison I ! ' 1 ~ I I I I I I I I I I I I I I I I I I I . . ARCO ALASKA INC 0 TUBING TALLY WELL NUMBER: 3M-03 TUBING DESCRiPTION: DATE: 6/25/97 PAGE: 1 of 2 Kup"aruk River Unit 'RIG: Nordic Rig #2 3~1/2··,9.3#, l-BO, ABM,.EUE, f'lon-Coated -. ,Range 2 - Class A , Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7' Column 8 No Feet No Feet No. Feet No Feet No Feet No Feet No Feet No Feet 1 31.55 26 31.72 51 ' 31.63 76 31.33,. 101 3L61 126 31.39 .151 31.42 176 30.80 2 31 .45 27 31.5~ 52 31.51 71 ' 31.32 102 '31.37 127 31.40 152 29.34 171 31.50 3 31.47 28 31.47' 53 31.38 78 · 31.52 103 27.83 128 .31.39 153. 31,21 178 30.35 4 . 31.48 29 31.38 54 31 ,.5 2 79 31.49 104 31.50 129 30.38 154 31.52 179 30.42 5 31.53 30 31.55 55 31.39 . 80 30.75 105 31.49 130 31.56" 155 31.43 ' 180 31.39 6 31.38 31 31.51 56 31.51 81 29.44 106 31.32 131 31.51 156 31.78 181 30.47 7 31.49 32 31 .42 57 31.50 82 32.26 107 30.48 132 31048 157 31.67 182 31;52 8 31.55 33 29.48 58 31.54 83 31 .42 108 31 .42 133 ' 31.47 158 30.38 183 30.76 9 31.53 34 31.38 59 31.62 84 31.35 109 31.51 134 30.50 159 31.50 184 31.44 10 31.55 35 31.39 60 31.50 85 ' 31.32 110 31.55 135 31.55 160 30.38 185 31.37 11 31.52 36 29.82 61 31.52 86" 30.32 111 31.42 136 31.50 161 31.49 186 31.53 12 31.29 37 28.38 62 30.20 87 30:16 112 31.42 137 31.46 162 31.79 187 29.33 13 31.48 38 31 .48 63 31.31 ,88 31.51 113 31.55 138 31.53 163 31.77 188 31.45 14 31.51 39 28.20 64 31.44 89 31.43 114 31.54 139 30.36 164 31.82 189 31.25 15 31.73 40 31.35 65 31.34 90 31.53 115 31.57 140 31.57 165 31.77 190 31 .45 16 31.32 41 31.53 66 31.38 91 31.31 116 30.88 141 31.40 166 ,31.79 191 31.38 17 31.47 42 31.62 67 31.61 92 31 .44 117 31.47 142 31.60 167 29.20 192 31.40 18 31 .48 43 31.54 68 31.41 93 31.37 118 31.45 143 31.48 168 31.35 193 31.44 19 31.68 44 31.55 69 31.79 94 31.38' 119 31 :33 144 31.51 169 ' 31.51 194 31.40 20 31.48 45 31.51 70 31.46 .95 ,30.30 120 ' '31.67 145 31.48 170 30.48 195 31.56 21 31.05 46U 30.46' 71 31.52 96 .31.54 121 31.41 146' 31.47 '171 31.45 196 31.47 22 31.39 47 31.53 72 31.54: 97 31-.48 122 31.52 147 3Ö.08 112 30.53 197 31.49 23 31.46 48 31.58 73. 31:SÓ " 98 31.28 123 31.33 148 31.41 173 31.51 198 31.46 24 31.50 49 31.62 . 74 ,3.1.42 99 ·31.29 124 31.48 ' 149 31.49~ 174 30.76 199 31.34 25 31.52 50, " 31.54 75 3L31 , 100 31.35· 125 31.42 '150 31.26 17~ 30.48 200 31.53 Tot 786.86 Tot 776.57, Tot 785.85 To't 779.89 Tot 781.54 Tot 782.23 Tot ,778.33, Tot 779.50 TOTAL LENGTH THIS PAGE ,;. 6250.77 DIRECTIONS: TOTAL JOINTS THIS PAGE '" 200' , , , I I I I I I I I I I I I I I I I I I I . , ¡ ¡ . ARCO ALASKA INC 0 TUBING TALLY WELL NUMBER: 3M-03 TUBING DESCRIPTION: DATE: 6/25/97 PAGE: 2 of 2 Kuparuk River· Unit RIG: Nordic Rig #2 3-1/2", 9.3#, L-80, AB"'EUE. Non-Coated - Range 2 - Class A . Column 9 Column 1 0 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet . 201 30.43 226 30.91 251 276 301 326 351 376 202 31.~1 227 30.59 252 277 302 327 352 377 203 31.53 228 31.66 253 278 303 328 353 378 204 31.63 229 31.58 254 279 304 329 354 . 379 205 31.82 230 30.32· 255 280 305 330 355 380 206 31.39 231 31.59 256 281 306 331 356 381 207 31.64 232 30.78 257 282 307 332 357 . 382 208 31.78 233 31.40 258 283 308 333 358 383 209 31.80 '234 31.54 259 284 309 334 359 384 . 210 31.79 235 31.44 260 285 310 335 360 385 211 31.52 236 31.46 261 286 311 336 . 361 386 212 31.42 237 31.40 262 287 312 337 362 387 213 31.25 238 30.48 263 288 313 338 363 388 214 31.39 239 31.43 264 289 314 339 364 389 215 31.49 240 31 .44 265 290 315 340 365 390 216 31.49 241 31.47 266 291 316 341 366 391 217 31,66 242 31 .48 267 292 317 342 367 392 218 31.49 243 31.56 268 293 318 343 . 368 393 219 31.42 244 31.57 269 294 319 344 369 394 220 31.51 245 31~50 270 295 . 320 345 370 395 221 31.41 246 271 296 321 346 371 396 222 30.35 247 272 297 . 322 347 372 397 223 31.39 248 273 298 323 348 373 398 . . 224 31.52 249 274 299 324 349 374 399 225 31.59 250 275 300 .. 325 350 375 400 Tot 786.52 Tot 625.60 Tot Tot 'rot Tot Tot Tot , ¡ L ! ! r- I i . ¡ ¡ ¡ ¡ ¡ TOTAL LENGTH THIS PAGE = 1412.12 TOTAL LENGTH = 7662.89 DIRECTIONS: TOTAL JOINTS THIS PAGE = 45 . TOTAL JOINTS = 245 , .. Average Jt = 31.28 . I ¡ I ¡ ¡ ¡ 1 ¡ ! ' i ¡ ~ Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2926 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 07/31/03 Field: Kuparuk Well Job # Log Description Date BL Color CD 16-10 ' - iR) I~, DSBHP 07121/03 1C-27 ) ~-C~'~ TEMP/PRESS SURVEY 07/22103 1D-140 ~-- ~"~ (.~ SBHP 07/22/03 1J-10 ,,~_~., ~, -~7'~ ( SBHP 07/21103 26-01 ~<~ ~1'-~-\'~ PRODUCTION PROFILE 07/19/03 26-02 /~'~' I'~ PRODUCTION PROFILE 07/20/03 26-14 1~' ~1 \ PRODUCTION PROFILE 07/23/03 2E-11 ~ ~.~-i_'~:'-~. ~ PRODUCTION PROFILE 07/18/03 3K-08 \'~~ '~_~'~.~. LDL 07~25~03 3M-03 _[~'-~'~ I~ LDL 07124/03 36-'19 ~,J..f'?"~-~,,~'. ~? PERF/JEWELRY/& INITIAL SBHPS 07/11/03 DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1250' FNL, 1722' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 912' FSL, 1408' FWL, Sec. 25, T13N, R8E, UM At effective depth 761' FSL, 1311' FWL, Sec. 25, T13N, R8E, UM At total depth 691' FSL, 1267' FWL, Sec. 25, T13N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 8065 6473 feet feet 6. Datum elevation (DF or KB) RKB 64. 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-03 9. Permit number/approval number 87-14 10. APl number 50-029-21696-00 11. Field/Pool feet Plugs (measured) KuparUk River Field/Oil Pool None Effective depth: measured 7 9 5 0 true vertical 6 3 9 3 feet feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 3570' 9'-5/8" Intermediate Production 8006' 7" Liner Perforation depth: measured Cemented Measured depth True vertical depth 198 Sx CS II 1 1 5' 900 Sx AS III & 3608' 300 Sx Class G & 75 Sx Class G top job 300 Sx Class G & 8041' 175 Sx AS I 7704'-7726',7740'-7752',7760'-7780',7794'-7822',7828'-7832' true vertical 6221'-6236',6246'-6254',6260'-6274',6284'-6303',6308'-6310' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 7634' Packers and SSSV (type and measured depth) 115' 3305' 6456' Packer: Baker SAB-3 @ 7608'; SSSV: None, nipple @ 504' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sand on 7/3/97. Intervals treated:, (measured) 7740'-7752',7760'-7780',7794'-7822',7828'-7832' Treatment description including volumes used and final pressure Pumped 112 Mlbs of 20/40 and 12/18 ceramic proppant into~Jrlff~lld~aJ~ ~'g"~;~:)0 psi. 14. Representative Daily Average Production, or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 296 161 653 1325 200 Subsequent to operation 465 334 950 1329 211 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations .Z. 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. '4Form-10-~,04 I~ev 06J ,f ~,~,~' Title Wells Superintendent ,igned .//Af~~ SUBMIT IN DUPLICATE ARCO Alaska, Inc. X:UPARUK RIVER UNIT '~' WELL SERVICE REPORT ~ K1 (3M-03(W4-6)) WELL JOB SCOPE JOB NUMBER 3M-03 FRAC, FRAC SUPPORT 0513971508.1 DATE DAILY WORK UNIT NUMBER 07/03/97; "A" SAND REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 16 (~) Yes~ O NoI ® Yes O No DS-YOAKUM CHANEY FIELD AFC_,g CCr# DALLY COST ACCUM COST Signed ..'~./ ESTIMATE KD1851 23ODS36ML $105,833 $186,963 )/(-'/ / .'~.---~--"-~ ~'- Initial Tbq Press Final Tb.Q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann'~ I Final Outer Ann 1 900 PSI 1000 PSI 2000 PSI 500 PSII 0 PSII / 0 PSI DAILY SUMMARY "A" SAND REFRAC COMPLETED. SCREENED OUT BACK TO SURFACE. INJECTED 112000 LBS OF PROP IN THE FORMATION W/ 9.4# OF #12/18 @ THE PERF'S. MAXIMUM PRESSURE WAS 8000 PSI & F.G. @ (.79) TIME 06:30 08:00 08:15 09:25 10:40 LOG ENTRY MIRU DOWELL FRAC EQUIP, APC VAC TRK, AND APC PUMP TRK. HELD SAFETY MEETING (14 ON LOCATION). PT'D BACKSIDE LINES TO 4000 PSI AND RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9800 PSI. PUMP BREAKDOWN W/50# DELAYED XL. GW @ 30 TO 15 BPM. VOLUME PUMPED 450 BBLS. USED 5939 I.C,~ OF ~Y20/40 PROP. MAXIMUM PRESSURE 7500 PSi AND 'ENDING PRESSURE 3500 PSI. S/D AND OBTAINED ISi~ ,,....~I.~ 2160 PSI W/F.G. @ (.79). STOOD-BY AND PULSED TO DETERMINE CLOSURE. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 181 BBLS. MAXIMUM AND ENDING PRESSURE 3500 PSI. S/D AND OBTAINED ISIP OF 2350 PSI W/F.G. @ (.85). STOOD-BY AND MONITORED WHTP FOR CLOSURE. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SCREENED OUT BACK TO SURFACE. MAXIMUM PRESSURE WAS 8000 PSI. VOLUME PUMPED 1105 BBLS. PUMPED 133629 LBS OF PROP (21000 LBS OF #20/40 AND 112629 LBS OF #12/18). INJECTED 112000 LBS OF PROP IN THE FORMATION W/9.44f OF #12/18 @ THE PERF'S. LEFT 21629 LBS OF PROP IN THE WELLBORE. 12:00 STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D APC PUMP TRK. 13:00 14:00 REMOVED TREESAVER (ALL CUPS RETURNED) CONTINUED R/D. R/D COMPLETE AND DOWELL LEAVING LOCATION. SERVICE COMPANY- SERVICE DAILY COST ACCUM TOTAL $0.00 $5,258.00 APC $7,600.00 $13,550.00 DIES EL $250.00 $250.00 DOWELL $97,984.00 $104,003.00 HALLI BURTON $0.00 $40,953.00 LI'I-I'LE RED $0.00 $19,950.00 PETREDAT $0.00 $3,000.00 TOTAL FIELD ESTIMATE $105,834.00 $186,964.00 ARCO Alaska, Inc. Post Office Box 10036;~ Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 17, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3M-03 (Permit No. 87-14) Well Completion Report ORI INAt. Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent workover operations on KRU 3M-03. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad .... STATE OF ALASKA .... ALASAA OIL AND GAS CONSERVATION U,JMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG il. Status Of Well ........ Classificati°n of serVice Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 87-14 3. Address 8. APl Number P. O. Box 100360, Anchorage, Alaska 99510 50-029-21696 '-~-.-- Location of Well at surface ........... ~' _~ .... ;-"9: unit- o-r-Lea-s-e 1250, FNL, 1722' FEL, Sec. 25, T13N, R8E, UM ~,t,O¢,,A'i'I~I~I~ Kuparuk River Unit At top of productive interval ~"~~'l~e-"~' .................................. 912' FSL, 1408' FWL, Sec. 25, T13N, R8E, UM 3M-03 At total depth 'i i i'"Fie'l'd a-~d Pbol 691' FSL, 1267' FWL, Sec. 25, T13N, R8E, UM Kuparuk River 5~--EleVafi-0n i-~ fe~-t (ir~dicate K'B, DF, etc.)' -16~ Lease D'~signation ~'~d-Seriai RKB 64' ! ADL 25523, ALK 2559 12. Date Spudded 113. Date T.D. Reached i 14. Date Comp., Sus'p., o~ Aband.115. Water 3~!/87 i 3/7/87 ! 6/25/97 ! N/A MSq Two i7. Total DePth (MD+TVD)-! i8. plug BaCk Depth (MD+TVD)J19. DireCtional SurveY}20~ DePth where SSSV Set~l. ThiCknesS of Permafrosl ............. 8_0__6_5 .......... __647__3 ~ ........ 79_50 .... 6393 _.FT~ _DYes . ~_N0_ 1 ........ N/A__MDI .... _1_65__°_'!_A__P_P__!0___X:!_ ........ 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD CASING I ............ SE-I-rING ~EP'~H I HOLE ....... S~E --'- VVT: PER FT' ' GRADE ..... __TOP .... BO_.Tr. OM_, SIZE_ CEMENTING RECORD _ . _ AMOUNT__P__ULLED 16" 62.5# H-40 Surf. 115' 24" 198 sx OS II 9-5/8" 36.0# J-55 Surf. 3608' 12.25" 900 sx AS III & 300 sx Class G ............................................................. T0-p-j(::JiE--p~-i;f(::) r-~-e 8--W/7~--~,-~--Ci~-S-E~ .......................................................... 7" 26.0# J-55 Surf. 8041' 8.5" 300 sx class G &-i75 SX AS I 24. Perforations open tO Productic~n (MD+TVD of TOp and Bottom 25. TUBING RECORD and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 3.5" 7634' 7607' MD TVD MD TVD ........................... 7704'-7726' 6620'-6236' ~-- ................................................ 7740'-7752' 6246'-6254' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7760'-7780' 6260'-6274' i ~ 6spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7771 '-7772' 6268-6268' - .................................................................................... 7772'-7773' 6268'-6269' . 7774'-7775' 6270'-6270' 7794'-7822' 6284'-6303 .................................................................................................... 7828'-7832' 6308'-6310' 1 spf ~'f. ' .......... PRoDU'C:rioN'.TEST ..................... E)at~ Fir§t ProduCtion iMe(l~0d of Operation (flEWinIg; g'as lift; etc;) i Date of Test iHours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE i GAS-OIL RATIO i TEST PERIOD ' i !' I .................................... _ Fib-~-T-~JEingic-a. sir~-g---P-~'-~-S-~-~'CAL~bUL~'i:ED --~ -'Oi~:-~[ ............. ~,~-:i~1~: ......... i W,~:ri:R--BB~.- ........ (CORR) Press. I 24-HOUR RATE i . .. 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Sub~mitc~,o~r~ ~i~s~i'~.",~,'~'.~ Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Ma~' ; 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. Annulus left open - freeze protected with diesel. 3'1~ List of Attachm'~nts ........................................ Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 1....~ ~' ~. ~,,.,. ,..,.._.___ Title I'~/. ~.1.~..~, I,. [ ~ [,¢-..~ IH~ Date ~'~ · Prepared By Name/Number: 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 Date: 7/9/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3M-03 RIG:NORDIC WELL ID: 999063 TYPE: AFC:--999063 AFC EST/UL:$ 365M/ 456M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: START C0MP:06/20/97 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21696-00 06/20/97 (C1) TD: 7779' PB: 7950' SUPV:DLW DAILY:$ CIRCULATE MW: 0.0 BRINE Turn key well to well rig move from 3M-13 to 3M-03. Accept rig @ 1630 hrs. 6/20/97. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 06/21/97 (C2) TD: 7779' PB: 7950' SUPV: DLW DAILY: $ 06/22/97 (C3) TD: 7779' PB: 7950' SUPV:DLW DAILY:$ PULL 2-7/8" TUBING MW:13.0 LSND Displace well weith seawater and mud to kill well. Pump cement. Cement to surface. Monitor well, dead. N/U BOPE. Test BOPE 250/3500 psi. 0 CUM:$ 0 ETD:$ 0 EFC:$ POOH W/7" X 2-7/8" PROD. MW:13.3 LSND Pull 2-7/8" tubing, SSSV, 10 GLM's and Camco 'OEJ' . RIH w/fishing BHA %1. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 06/23/97 (C4) TD: 8065' PB: 7950' SUPV: DLW DAILY:$ CHANGE OUT TUBING SPOOL & MW:13.3 LSND P/U kelly and work over top of slick-stick @ 7591' Unset 7" x 2-7/8" Camco packer. POOH slowly swabbing. L/~ packer and tail pipe w/wireline tools stuck in tail pipe. Circulate out gas cut mud from 3255' Clean out from 7757' to 7944' Circulate hole clean. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 06/24/97 (C5) TD: 8065' PB: 7950' SUPV:RLM DAILY:$ RUNNING 3.5" COMPLETION MW:13.3 LSND Pull and lay down storm packer. Pre job safety meeting. Load 3.5" tubing into pipe shed. 0 CUM:$ 0 ETD:$ 0 EFC'$ 0 06/25/97 (C6) TD: 8065' PB: 7950' S UP V: RLM DAILY: $ RIG RELEASED/MOVING RIG T MW' 8.4 SW Run 3.5" completion. Set packer and test tubing for 30 min, good test. N/D BOPE. N/U tree test packoff to 250/5000. Test tree to 250/5000 psi. Freeze protect well. 0 CUM:$ 0 ETD:$ 0 EFC'$ 0 06/26/97 (C7) TD: 8065' PB: 7950' SUPV: RLM DAILY: $ RIG RELEASED MW: 8.4 SW Pull rig off well. Clean up around cellar and rig. Rig released at 0200 hrs. 6/26/97. 0 CUM:$ 0 ETD:$ End of WellSummary for We11:999063 ........ ]997 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 23, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Report of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. WELL ACTION 3 M- 0 3 Perforate 3 M - 0 8 Perforate 3M-08 Stimulate 3 M - 0 9 Perforate 3M-1 9 Perforate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer CC: M. E. Eck ATe 1176 S. M. Renke ATe 1126 KeEl .4-9 w/o attachments RECEIVED J U L ~' Alaska OJJ & Gas Coils. Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company AR3B-6003-C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown__ Pull tubing Alter casing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Location of well at surface 1250' FNL, 1722' FEL, Sec. 25, T13N At top of productive interval 912' FSL, 1408' FWL, Sec. 25, T13N, At effective depth 761' FSL, 1311' FWL, Sec. 25, T13N, At total depth 691' FSL, 1267' FWL, Sec. 25, T13N, 12. Present well condition summary Total Depth: measured 8 true vertical 6 Stimulate __ Plugging Repair well Perforate X Other 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ , R8E, UM R8E, UM R8E, UM R8E, UM 6. Datum elevation (DF or KB) 64' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-03 9. Permit number/approval number 87-14 10. APl number 50-029-21696 11. Field/Pool Kuparuk RiverField / Kuparuk River Oil Pool 065' feet Plugs (measured) None 473' feet Effective depth: measured 7950' feet Junk (measured) None true vertical 6393' feet Casing Length Size Cemented Measured depth True vertical depth Structural 8 0' I 6" 198 SX CS II I 1 5' I 1 5' Conductor 3571' 9 5/8" 900 sx AS III & 3608' 3305' Surface 300 SX Class G Intermediate Top job w/75 sx Class G Production 7329' 7" 300 sx Class G & 8041' 6456' Liner 175 SX AS I Perforation depth: measured 7704'-7726', 7740'-7752', 7760'-7752', 7760'-7780', 7828'-7832' true vertical 6221'-6237', 6247'-6255', 6261'-6275', 6285'-6304', 6309'-6311' RECEIVED Tubing (size, grade, and measured depth) 2-7/8", J-55 tbg w tail @ 7645' Packers and SSSV (type and measured depth) HRP-1-SP pkr @ 7616' & TRDP-1A-SSA SSSV @ 1795' 13. Stimulation or cement squeeze summary See attached well report 14. d U L t 5 1,99t. Alaska 0il & Gas r3ons. CommissiOn. Intervals treated (measured) See attached well report Anchorage Treatment description including volumes used and final pressure See attached well report Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 6 2 5 304 -0- 1280 155 Subsequent to operation 6 5 4 ~'~' 281 -0- 15. Attachments ~16. Status of well classification as: Copies of Logs and Surveys run -- I Water Injector Daily Report of Well Operations X Oil X Gas Suspended 17. I here_by certify that the foregoing is true and correct to the best of my knOwledge. SiCned '~~'~°~ Title Senior Operations Engineer Form 10-404 Rev 09/12/90 1260 155 Service Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL R=~ARKS o ~ '~ /~Z~ -IOPERATION AT REP_,.QRT TIME I I DAYS~ IDATE - ~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W#ther 1 ?imP' I Chill Factor VitibiliIyIWind Vel'~ 'F 'F mil# knots t Signed ARCO Alaska ..... Post Office ~ox Anchorage, AJask~, 9~5 Te:ephone 907 27G 1215 April 3, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. WELL ACTION 3 M - 03 Perforate 3 M - 0 8 Perforate 3 M - 2 2 Perforate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer CC: J. R. Brandstetter ATe 1120 L. L. Perini ATe 1130 S. M. Renke ATe 1126 KeEl .4-9 w/o attachments STATE OF ALASKA ALAbK~ OIL AND GAS CONSERVATION COMMI~:xSION REPORT OF SUNDRY WELL OPERATIONS 1. Operation performed: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Repair well 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1250' FNL, 1722' FEL, SEC. 25, T13N, R8E, UM At top of productive interval 912' FSL, 1408' FWL, SEC. 25, T13N, R8E, UM At effective depth 761' FSL, 1311' FWL,SEC. 25, T13N, R8E, UM At total depth 691' FSL, 1267' FWL~ SEC. 25~ T13N~ R8E, UM 12. Present well condition summary Total Depth: measured 8 0 6 5' feet true vertical 6473' feet Plugs (measured) Effective depth: measured 7 9 5 0 feet true vertical 6393' feet Junk (measured) Casing Length Size Structural Conductor 8 0' 1 6" Surface 3571' 9 5/8" Intermediate Production 8 0 0 6' 7" Liner Perforation depth: measured 7704'-7726', true vertical 6158'-6174', Cemented 198 SX CS II 900 sx AS III & 300 sx Class G 300 sx Class G & 175 sx AS I 774O'-7752', 6183'-6192', 776O'-778O', 6198'-6212', Tubing (size, grade, and measured depth) 2 7/8" J-55 Tubing w/tail @ 7645' Packers and SSSV (type and measured depth) HRP-1-SP PKR @ 7616; TRDP-1A-SSA SSSV @ 1795' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attached Well Report Treatment description including volumes used and final pressure 14. Perforate X . Other Prior to well operation Subsequent to operation 6. Datum elevation (DF or KB) 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X RKB 64' 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-03 9. Pe~ n_u?~.~r/approval 10. APl number 50-029-21696 11. Field/Pool Kuparuk River Oil Pool number Measured depth True vertical depth 115' 115' 3608' 3305' TopJob ~75sxClass G 8041' 6456' 7794'-7822', 6284'-6303', feet 7828'-7832' 6308'-6310' ' ECEIVED ......... '" .... 0ohs. Anchorage Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 594 275 -0- 1280 693 290 -0- 1250 Status of well classification as: Water Injector__ Oil X. Gas Suspended 16. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,Si,ned Form 10-404 Rev 09/12/90 Tubing Pressure 130 130 Date SUBMIT IN DUPLICATE ARCO Alaska, Ir Su[)sidiary of Atlantic Richfield Company WELL CONTRACTOR R,-MARKS WELL SERVICE REPORT /OPERATION AT REPORT TIME | Anchorag~ [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK J Sign~. _ knot. , ~. "'~,~ c~5' ,. STATE OF ALASKA ~ , ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,,, 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ..~.~ 2. Name of Operator 7. Permit Number ~I ARCO Alaska, Inc. 87-14 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21696 4. Location of well at surface 9. Unit or Lease Name 1250' FNL, 1722' FEL, Sec.25, T13N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 912' FSL, 1408' FWL, Sec.25, T13N, R8E, UM 3M-3 At Total Depth 11. Field and Pool 691' FSL, 1267' FWL, Sec.25, T13N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 64' ADL 25523 ALK 2559 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if offshore 116. No. of Completions 03/01/87 03/07/87 08/31/87'J N/A feet MSLI 1 17. Total Depth (MD+TVD) 18, Plug Back Depth (MD+ l-VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8065'MD, 6473'TVD 7950'MD, 6393'TVD YES ~] NO [] 1795' feet MDI 1600' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CBT, GCT .... ~3. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE' WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# U-40 Surf 115' 24" 198 sx CS ! I ,-, 9-5/8" 36.0# J-55 Surf 3608' 12-1/4" 900 sx AS III & 300 sx Class G Top ,~ob performed w/75 sx Class G 7" 26.0# J-55 Surf 8041' 8-1/2" 300 sx Class G & 175 st AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7771 ' MD 6268 ' TVD 2-7/8" 7645 ' 7616 ' 7772 'MD 6268 'TVD 7774 'MD 6270 'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7794'-7822'MD 6284'-6303'TVD DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED 7828 ' -7832 'MD 6308 ' -6310 'TVD See attached Addendum, dated 9/7/87 Perforated w/1 spf, 120° phasing for fracture data. ,, 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ I. "Flow Tubing :Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL el L GRAVITY-APl (corr) Press. 24-HOUR RATE I1~ 28. CORE DATA b r' ~' r [%1 r' ~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.~, ~ ~, r ! V [~ None SEP 2 a 19~7 Alaska 0il & Gas Cons. C0mmissi0n Anchorage *Note: Drilled ER 3/8/87. Perforated well & ran tubing 7/4/87. Fractured well 8/31/87, Form 10-407 WC:~/72 :DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. [' ' "-~' ,,. 30. ' GEOLOGIC MARKERS 'I~i3RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR,and time of each phase. Top Kuparuk C 7698' 6216' N/A Base Kuparuk C 7729' 6238' Top Kuparuk A 7729' 6238' Base Kuparuk A 7876' 6341' 31. LIST OF ATTACHMENTS Addendum (dated 9/7/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~//~/)/~,/~( / ~~,~ .~ Title Associ ate Engineer Date ~ ~ ~ ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 3/26/87 4/30/87 8/31/87 3M-3 Arctic Pak w/175 sx AS I & 60 bbls Arctic Pak. RU Schl, rn GR/JB to 7939'. Rn CBT f/7933'-5800'. Rn GCT gyro f/7901' - surf. Frac Kuparuk "A" sand perfs 7771', 7772', 7774', 7794'-7822' & 7828'-7832' as follows per procedure dated 8/21/87. Stage 1: 100 bbls gel diesel @ 5 - 20 BPM, 3200 - 4310 psi Stage 2: 470 bbls gel diesel @ 20 BPM, 4380 - 5000 psi Stage 3: 18 bbls gel diesel 2 ppg 20/40 sand @ 21BPM, 5000 - 4530 psi Stage 4: 34 bbls gel diesel 4 ppg 20/40 sand @ 20.5 BPM, 4530 - 4300 psi Stage 5: 32 bbls gel diesel 6 ppg 20/40 sand @ 20.5 BPM, 4300 - 4330 psi Stage 6: 30 bbls gel diesel 7 ppg 20/40 sand @ 20.5 BPM, 4330 - 4510 psi Stage 7: 14 bbls gel diesel 8 ppg 20/40 sand @ 20.5 BPM, 4510 - 4540 psi Stage 8: 5 bbls gel diesel 9 ppg 20/40 sand @ 20 BPM, 4540 - 4680 psi Stage 9: 11 bbls gel diesel 7.5 20/40 sand @ 19 BPM, 4680 - 4900 psi Stage 10:49 bbls gel diesel flush @ 19.5 BPM, 4900 - 4430 psi (NOTE: At end of stage 8, had trouble w/sand dump. Pmp'd 7 bbls of 9# slurry & appear to be out of sand. Sand broke lose & cont'd pmp'g @ 7.5#/gal, then flushed. Held flush short in att to ensure highest possible concentration @ perfs.) Fluid to Recover: Sand in Zone: Sand in Csg: Ave Pressure: 765 bbls 35,5001! 20/40 500# 20/40 4500 psi Job complete 8/31/87. Turn well over to Production. Dr~g Super~ RECEIVED Aiaska Oil & Gas Cons. 6ommissior, Anchora(Je ~UB.$URFACE DIRECTIONAL ~URVEY [~]UIDANCE r~ONTINUOUS r=flooL Company Well Name Field/Location ARCO ALASKAz INC. 3M-3(1250' FNL~ 1722' KUPARUK, NORTH sIrOP~, FEL~SEC ALASKA RECEIVED JuL 2 8 198/ ~aska 0il & Gas Cons. Commissiol Anr,.h~rage 25~T13N~R8E,UM) Jol3 Reference No. 72302 SARBER Date 28-APR-87 Computed By; KRUWELL GCT DZRECTZONA~ 6URV£¥ FOR ARCO ALASKA, INC. KUPARUK NORTH 8~OPE,AbA$KA SURVEY DATE; 28-APR-8? ENG~NEERI G, SARBER METHC~$ OF COMPUTATION TOOL bOCATIDNI TANGENTIAL- Averaged deviation and azlmut~ INTgRPOLATIONI LIN£AR VERTICAL SECTIONI HORIZ, DIST, PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 34 DEG 24 MIN WEST ARCO AbASKAt INC. 3N-3 KUPARUK NORTH SbOPEtAI, ASKA CDNPUTATZON DATEI 17-HA¥-87 PAG~ ~ATE O~ SURV~¥I 28~A~R~87 K~¥ BUSHING E~EVATION~ 64e00 ~T ENGINEERI G, SARBER INTERPObATED VAbUE~ FOR EVEN 100 FgET OF MEASURED D~PTH TRUE SUB-SEA COURSE HgASURED VERTICAL VERTICAb DEVIATION AZIPUTH DEPTH DEPTH DEPTH DEG NZN D£G MIN VERTICAb DOGbEG RECTANGUbAR COORDINATE& HORIZ, DEPARTURE SECT[ON SEVERXT¥ NORTH/SOUTH £AST/NEST DI$~e AZ~NUTH Fl:ET D£G/IO0 FEET FEET FEE~ DEG 0 O0 lO0 O0 2OO O0 3OO O0 4OO O0 5OO O0 600 O0 7O0 O0 8O0 O0 900 O0 0,00 99,90 199,90 99,89 ~99,88 499 86 599.85 b99.84 799,82 899.80 4 5,86 ~9 '6,92 5 5,85 0 5 N . 6 5,84 N .~2 22 E '8.58 0 7]5,82 I 9 N 8 24 E '~0,50 0 835.80 I ? N 24 32 E -12,51 0 1000 O0 O0 1099 600 1900 O0 1199 O0 1299 O0 1399 O0 1499 O0 1599 O0 1699 O0 1799 O0 1898 999 78 935,78 1~5,76 I° III ! 1435071 635,69 39 1735,39 28 1834,28 I 2 N 29 31: I 0 N 37 21 E I 0 N 44 52 E 0 54 N 58 28 0 51 N 69 32 E 0 44 N 73 28 £ 0 33 S 247£ 147 8 29 6 32 8 34 3O w 10 32 2000,00 1995.82 193[,82 14 50 oo 2300 O0 2277.95 2213,95 26 6 2400 O0 2365.85 2301,85 29 37 2500 O0 2452.79 2388,79 29 43 2600 O0 2539.28 2475.28 29 59 2700 O0 262b.1~ 2562.18 30 6 2800 O0 2710,89 2646,89 34 20 2900 O0 2790.92 2726,92 39 12 S 43 25 ~ $ 42 48 w $ 38 54 w S 35 11W S 35 38 w S 33 52 w S 3b 16 w $ 37 47 w 3000 O0 2867 26 2RO3,2b 40 29 O0 2942 20 2878,20 42 18 3 3600 3700 3800 3900 O0 3015 92 2951,92 43 15 O0 3086 98 3022098 46 7 O0 3156 04 3092,04 45 27 O0 3227 61 ~163,61 44 7 O0 3299 04 3235,04 43 48 O0 3371 56 3307.56 43 38 O0 3443,84 33 79,84 43 41 O0 3516,15 3452015 43 37 S 37 11 $344 .5 35 33 836 S 36 58 S 38 16 $ 39 31 w S 39 $384! S 38 N 5,55 E 10,51 N 31 50 g 22 I 73 N 6,47 E 12,53 N 31 4 E 3.22 · 22 220.13 270.32 ,88 432.68 497.17 563.34 630,9! 773, 843 19 9 52 3O ~9{ !~ 94 14,90, ~ 23 32 41 39 7u 2 81 $ 55 W 83 85 $ 41 29 W $ 19 123 6? 8 29 "?"' '?'". 507,9~ 374,91 N 63 36 25 S 416,72 ,63 36 ?, 785,38 590,29 ~982,47' ~39,13 633,70 05 1 ARCO AbASKA, THC. 3M-3 KUPARUK NORTH SLOPE,ALASKA COHPUTATION DATEI 17'HA¥-87 DATE OF SURVEY: 28"'APR"'8? KgLL.¥ BUSHING ~bEVATION; 64.00 ENGXNEERI G., SARBER VALUES FO~ EVSN 100 FEET OF HEASURED DEPTH TRU£ SUB-SEA COURS£ MEASUR£D VERTICAL V£R~ICAb DEVIATIDN AZI~UTH DEPTH DEPTH DEPTH DEG HIN DEG M~N VERT)CAb DOGbEG RECTANGUbAR COORDINATE& HORIZ. DEPARTURE SECTION $£VER~T¥ NORTH/SOUTH EAST/W£$~ D~$T, AZIHUTH FEET DEG/IO0 FEET FEET FEET DEG #XN 4000 O0 3588 57 3524 57 43 26 37 30 1188.15 66 947.73 718.92 1189 55 3~ 10 ' 34 3813 34 ~ ~ $ 1464.65 1258 25 1256,77 1002,46 4100O0 366 oo ii: ,,o.,,: 10 367010 S 6 1325,20 0 2 1057.42 132673 1607.31 0 48 1284,37 969,18 1609 01 10~0.47 1640 16 t6~8,47 0 40 4700 O0 4087 b6 4023 66 45 4800 O0 4158 23 4094 23 44 S w ! 1050,~9 1750 96 1090.56 ~ 182! )5 ~ 36 46 4900 O0 4229 19 4165 19 44 33 52 1890,08 0.92 15!?.07 1129,85 1891 57 36 40 5300 O0 4512 17 4448.17 45 5400 O0 4581 58 4517,58 46 $ 36 w 2174.38 1.03 1754,87 I~5,?? 2175 49 1 54 2246.90 u,4S 1817,03 1323,~3 ~2247 e4 5500 O0 4650 32 4586.32 46 5600 O0 4718 73 4654.73 46 35 47 2319.69 ~:I~ 1879.66 1360,72 2320 49 54 5800 O0 4855 15 4791.15 46 $ 30 21 ~ 2465.61 0.64 2005.58 1435~09 2466 14 35 35 5900 O0 4924.71 4860.71 44 S 31 21W 2537.28 2,89 2067841 6000 O0 499b.58 49~2,58 43 ~ 32 10 ~ 2606.74 ~844 212&,47 1508,~4 2607.10 35 20 6~00 00 5069.43 5005,43 42 o 34 50 2675,22 0,93 2183,48 1546.30 ~2675.66 6200 O0 5142'~0 5078.80 42 $ 34 46 W 2743.17 0,$1 2239,24 1585,12 w 2743,5~ 25w 2811.44 0,55 2295,44i 1623.88 b281J.77 6300 O0 5215 87 5151.87 43 $ 34 6500,00 5361 30 5297.30 43 29 i 33 2948,73 0,37 ~409,03 1701,00 2949,04 6700.00 5505 ~] 5441.8~ 44 3~ 3086.96 0,47 2524,05 1777.68 ~ 3087.21 6800,00 5577 54 5513.54 44 20 33 3156.65 0,34 2582,39 3156~89 6900,00 5648 99 b5~4.99 44 32 i 32 37 ~ 3226.59 0,47 2641,16 tlt~:~ ~3226.60 7100.00 579! 68 5727.68 44 2~ ~ 3~ ~ 50 3366.61 0.31 2759.84 1928.32 ~3366.77 7200.00 5862 91 5798.91 44 44 ~ 24 3436.71 0.21 2419.68 1~648~9 75OO O0 6011,67 3647,98 3647,94 0 9 3000,06 6075 67 44 3!~ 40 - 40 7600 O0 6146 50 6082.50 44 23 3718,46 0 ~B 3059.96 3718.48 7900 oo 635s 26 6291:t6 45 49 i 32 30, 39~o.85 4 ~0 3238.,8 2227.41- 393o.e6 ARCO AbASKAw INC, KUPARUK NORTH SbOP£,AbASKA COMPUTATZON DATEI 17-MA¥-87 PAGE 3 DAT£ OF SURVEY I 28,,,APR,,8'7 K£bl~¥ BUSHZNG EI, EVATZONI 64.00 FT ENGZNE~RI G. 6ARBER ZNTERPObATED VAlUeS FOR EVEN 100 FEET O~ #EASURgD DEPTH TRUE #EASHRED VERTICA~ CDUR6E VERTZCAb DOGbEG, RECTANGUbAR DZNATE$ HORZZ.' DEPARTURE DE~TH DEPTH DEP DEG NZN DEG M~N FEET DEG/~O0 FEE~ FEET FEET DEG NZN 8000.00 6427.~ 6363:~½ 45 51 ~ 32 31W 4002.57 0.00 I~.39 ~ ~t65.98 . 4002.~8 ~ t~ 28 ~ 8065.00 6473, 6409 45 5 $ 32 31W 4049,20 0.00 .72 91.06 N 4049. 0 27 ~ ARCO AbASKA, INC, KUPARUK NORTH 3LOPE,AbASKA COMPUTATZON DATEI DATE OF SURVE¥I KELLY BUSHZNG ELEVAT[ONI ENGZNEER! PAGE 4 26"APR'B7 64.00 FT INTERPObATzD VAbUE3 FOR EVEN tO00 FEET OF MEASURED DEPTH TRUE: SUB-SEA _ COUR$_1: ASURED VICHT;[C'AL VICRTICA~ DEVIATXDN AZI.UTH #EDEPTH DEPTH DEPTH DEG NIN DEG ~IN VERTICAb DOGbEG RECTANGUbAR COORDINATE& HORIZ.. SECTIOa SEVERITY NORTH/SOUTH E~$T/N£&T DXSTo, FEET DEG/IO0 FEET FEET FEET DEPARTURE AZIMUTH DE:G 0 1000 2000 3000 4000 5O00 6000 ?000 8000 8065 OD o.oo .~,.oo ~o,==~,, ~ ~i.oo .oo ,o.oo ?.4, E ~:oo oo ~.8~ x~.o2 ~4 ~ ~ 4~ ~ .~ . ~4.~o 2~.~2 718.92 t189.55 .00 3588,57 3524057 43 6 30 X188,15 44 52 1890'0U .92 t5i70 1129085 !891,57 ,00 4300.30 4236.30 2 ~ : ' : ~ 40 '°° '~"""'~"~ !ioo ~?.~, ~,~,.,, ,, ~i'~, '" 3296.66 ,42 .37 1891,35 - 3296, 3 31 4002,57 ,00 3299 39 ~65,98 4002e 28 5t $ 32 31W .20 .00 3338 72 4o4~ '. ~2~x.o. O0 6473,17 5409,17 45 ARCO AbASKAp INC. KUPARUK NORTH ~LOPEAAbASKA CONPU?ATION DA?El 17-MA¥-87 PAGE 5 DATE Or SURVE;¥1.- 28-A_PR-87 KE:~,b¥ BU~HZNG EbEVATZO#t 64,00 rT ENG/NEERI G, SARBER ZNTERPO~AT£D VALUES FOR EVEN lO0 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTJCAL DOGLEG R~CTANGU~AR COORDINAT£S HORZ~,. ~PARTURE #EASURED VERTZCAb VERTICAb DEVZATZON AZZHUTH SECTION $EVERIT¥ NOR?H/SOUTH EAST/NEST DIST.r .~ZHUTH DEPTH DEPTH DEPTH DEG HXN DEG NXN FEET DEG/IO0 FEET FEET FEET D~G HXN oo .oo oo .oo o o.oo ,o~i:gg .~.oo g',~ o~ I o.'°° ~ .03 '00 ' ' ~I [ 0.0~ '1 ~,45 51 45 ~oo.oo ' ' I:~ [ 64 '2 364,~ 300.00 §5!50 ~29 29 43 ~ '4'31~.79 ~.18.0837 .,745099 ~ 2. 4,79 3,28 464 t3 464. 400.00 0 08 29 3, 6,34 , , *7,94 . 6o18 E 11,82 ~64, ,00 24 52 29 '13,76 ~o~,.~ ~o~,.oo ~ooo.oo I ~ ~~ ~ [ -~.~, . , oo.oo o.,o ,.,o '~8,96 0,59 tt~:~ ~2~,.oo ~oo.oo g ~6~o ~o [ 1664.30 1664.00 1600.00 ~! ~ is °22.26 13,84 21.30 33 1764,43 1764.00 1700.00 33 1967,18 ~964,00 !900.00 1322 4335 15.30 4,67 12,.12 9,38 2176,~$ 2164.002'00,0020~19 ~ 402~ ~ 74.72 4,65 S6,23 [ 50,12 ~ 2~84.52 2264.00 2200.00 25 35 2397.87 2364.00 2~00.00 29 35 ~ 169.69 0.50 13~.1~ 105.92 170.1) 30 226,97 45 22 226.58 , 35 !! 342.57 203,95 2744.03 2664.00 2600 O0 3~ 34 42 - 5,2 2865,61 2764,00 2700 O0 37 37 40 411,33 5, ~ 24~,94 2099,72 2864.00 2800 O0 40 29 a , 494.40 1.39 396.62 295.84 . ~? 15 494.80 677.61 1 ii' 545.63~! 402 52 618,03 . 36 . 3967.06 3064 O0 3000 O0 45 36 48 3412.34 3164 O0 3100 O0 45 7 36 ~" 78t 51 628.78 464 98 782.03 ~689.96 3364 O0 3300 oO 43 { 39 974 33 0.48 ??9.77 . 3827.89 3464 O0 3400 O0 4~ ~ 104 69 1166.24 3966,13 3564 O0 3500 O0 43 37 43 2164 s7 O.aO ~ 1004.55 762 O! 4103.81 3664 O0 3600 O0 43 o 30 53 - ~259 ~e 4240,98 3764 O0 3700 O0 43.2! COMPUTATION DATEI 17-MAY-87 ARCeO ALASKA~ INC. NORTH SLOPE,ALASKA ...oo r, . ENGX#EERI Go: SARBER XNTERPOLATED VALU£5 FOR EVEN 100 FEET OF SUB-SEA DEPTH DEVXATCOURXON E VERTICAL DOGLEG: RECTANGULAR CO08DINATE$ HORIZo~ DEPARTURE MEASURED VERTICAL VERTICAL AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/MEST OlaTo~ AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG Mia FEET DEG/tO0 FEET FEET FEET D~G MIN 4808 16 4164 O0 4100 O0 S 34 27 1755 09 5.8 185420 1487030 S 09082 b ,.: 6 · 0 4 195365 24 1569,68 1653028 52J1 54 4464 O0 4400 O0 45 5314 56 4564 450o O0 46 b 2156 O! $519 9 4664 4600 O0 46 $ 0 1829,53 $ w 6 , $ 5666 4764 4700 oo 46 30 41 2367 87 0 53 5812 4864 O0 4800,00 46 $ 3022 w 247506 099 2013,75 S 1439,87 w 2475,57 $ )5 $3 w: 2179 33 S 1543041 W 2670050 S 35 t8 2670 6092 5064 O0 5000 O0 1 01 40 2762 91 0 39 2255 46 S 1596,36 W 2763,24 S 35 17 6366 ~t~ 5264 oo 5200 00 43 6503 5364 oo 5300 oo 4~ s )~ 57 2951 29 o 38 2411 15 s 1702.43 i~i!'8086627 546400556456645764000000 550056005400ii5700 4444444~ Sss333332~:3,3~ww 324~31433046674138 046004 $ )t w ~33955 040 27367~ $ 1914,08 w 33~9,7t S 34 Sm 7201 54 5864 O0 5800 O0 44 S w 343779 023 282061S 1965,55 w 3437,91 S 3452 64,00 6100,00 44 43 S 32 W 3735,79 64.00 ~00.00 45 1~ S 3~ 37 W ~35.25 3 6364,00 00,00 45 5 S 3 31 W 36,75 ~ ~6,.oo b,oo.oo ~ ~I s ~ ~ w ,o~.?~ OD 6~;~.~ ~,o~.t; ,~ ~ s ) sx ~ ,o~,.;o 7624 7765 7908 8051 8065 ARCO AL, ASKA, INC. NORTH SLOPE:~,A[,ASKA COHPUTAT~ON ~ATEI I?-MA¥-87 ~ARK£R TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BAS£ KUPARUK A PBTD INT£RPO~ATED VALUES FOR CHOSEN HORZZON$ MEASURED DEPTH BEbOW KB SURFACE L, OCATIO# ORIGINa: 1.250 FNL,; 1722. FEb. SEC~"~$. TI3N Rag TVD RECTANGUL, AR COORDINATES FROK Ki::) SUB-SEA NORI'H/$OUTH 7698.00 ??~ 0 78?6.00 79 o: o 8065 0 62 1'1 6 6238.10 6174 b34~,48 6 6473.17 6409 I? 0 ARCO AbASKA~ INC. KUPARUK NORTH SLOPE,ALASKA COHPUTATION DATEI 17-NAY-87 DATE OF SURVEY.I KEL,[,'/ BUSHXNG EL, EVAT{[O#. 64,.00 IrT gNG]:NEER 1 G.,,~ SARBER HARKER TOP KUPARUK C BA~E KUPARUK C TOP KUPARUK A BASE KUPARUK A TO NEA6URED D£PTH BELON KB 7698.00 7?29.00 ?729.00 7876,00 7950,00 8065.00 SURFACE ~OCA't'ION 1250 FNb, 1'/22 6238.t0. 61 . 0 6 ,09 632 .09 b473~t7 6409.17 FINAL ~ELL LOCATION TRUE SUB SEA NEASUEED VERTICAL V£R~]CAb DEPTH DEPTH DEPTH HORIZONTAL D~:ARTURE DI$'Z'ANCE T~MUZ'H FEET DEG IqlN 8065.00 6473.27 6409,17 4049.20 S 34 27 W SCHLUMBERGER 0 ]; RECT ~ ONAL SURVEY COMPANY ARCO ALASKA INC. WELL 3M-3 F I ELD KUPARUK COUNTRY USA RUN 1 DATE LOOOED 28 - APR - 87 REFERENCE ?2302 - RECEIVED JUL 2 8 1987 ~aska Oil & Gas Cons. Commisslo~ Anchorage WELl:-' 3M-3 (1250' FNL, 1722' FEL, SEC 25, T13N, R8E, UM) HORIZONTAL PROJECTION NORTH 3000 ~000 1000 - 1000 -2000 -9000 -4000 SOUTH -~000 -SO00 WEST REF 72302 f!ii ii! !ii-~--;.-.i...;..-! ....... ii:";'-:!~i Iii !!ii;'--:--';'4--:"-;"-;-'¢"!!ii ii ii ~i ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::: t · , ..... '.ZZ]Z]:Zi]]iZ!LtL']ZZ ...?.+.++.~..+.+..~-. ~...~ ....... ~, ................. i...~...~ ..... ~ ....... : .................. -;..¢ ...... ~...? ....... ~ ~ ~ · ~ ? ........... ~-"';'-"-~"-, ....... ~ ...... r"? ........ !' ............ ?'-'~ ..,....:.: ........... l ....... ~..:...~ ........... I .................... ~ .............. :::;~ ~ '. i ~ ! ................. ~ .................. I .................................. :':'.:..k.:'.: ~; ::i ....... t ....... :. :!:!.~..::.. :::::::::::::::::::::::::::::::::::::::: ......... :...~..f..:...;....:... t ................ ~ ........ ~ .... j ......... ~ ........ ~"':'"~ ............. I : ....... ! ................ ! , I , I , , , / , ; .... I ........... ,...t .......... ! ...... ? ............... t ............... i ........... : ......... ::i:::i":::::!':'?'i:::i:::::'"~'T':'":'":":::~' :.. :":"':'"I'"':'"':"':'":" ::' ::: :'": : i ............ ~ ............ [ ...................... ;":"'~'. ........ : ..... j" ':';' 2.1 .............. ~ ..................., ............... ~ .................. ~'":'"~":'! :~~£..:_i ....... :" ,' :'":":-" T'?'-''- , - ~ ...... ~ t !' -4000 -BO00 -2000 - I00O o 1000 - 2000 ~000 WELL' 3M-3 (1250' FNL, 1722' FEL, SEC 25, T13N, R8E, UM) VERTICAL PROJECTION -2000 - ] 000 0 0 ! 000 2000 ~1000 4000 ~000 --,'t ...... ? ....... , ....... -:...? .................. '~ .................... 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' ' ; ........ ~. ...... .~ ..... .;..,.;....; .' . - .~ ~....4....~ ...... ~-..b...~...,; ...... ¢............~.-...~........~...~...~.;...~.......4 ...... · ....... .~ ....... . ........... 4 .......... ;...~...~ ....... ~.; ..... .................. + ............ ., ...... .._,_.,__,.. ........... .,_? ..... ,_., ...... . ~ ........ ., ..... .?~ ~ ........... .._. .... .;._~...~....i..., ....... ~_..;...; ....... ~....~,...;....,...H,...;....;....~ ...... .;_..; ....... ,;...+ ....... .L..;....: .............. .;._~. ....... : ............... ~....~..4..4....;...i...~ ....... .?..~ ..... t...~-.-.;.-.,.---~ ............... ~ ...... ~.---; .......... ~...: ........... -: ........... -: ........... ; ........... .. :/ZIIIIJ. :. ! : !- !l!i:[i;;i, i ; i i i; ~ ' { F t ; ' i ! ! : - , ! ;;ii:.. : , , I ...... I ' = .... I ' 2 ' ! ' ' : : ~ . ....... = ....................... ~...,.....; .-i--?.-:...i.--?-?f .............. ?'"t ....... ~'":"-: ...... :'"'~ ....... ~""r'"*:~---:-":'-"?"r".7?"? ...... ?':'"'T'?*"*?~ ....... ?'"***'r'"r'":'".*..'"~-~'"?"*'r""'~'":'"~'-~'-r ~ ? ?' ? .... i ' ~ ~" .... H...i..: .......1 ':', '''''~. , .... :' ,i~, ....... : ' :qnon .... ~:-i, ....'i'!i.~ ,~,:, .-: ....... , ~-!---~- .t'"~'"'~'"~'.,, i-j....i--..~, : . ?--'-~.. ..... ,~'"~". -:-', i-, -t--! ~,,: , .... :-. ':", ,~" ,~"t. .... .:'"~'"'?~,, --"i-"-,'-'*,,, i, i"~:. ,~-,:-'~. .... ';..'+'.'? ....... ~ .......... ;'": ................... + ............ i ..... : ........I~i ii~!I: ............ :'-':"i"r"~: ...... : ..... ~'"i .........i '~*'":'": ..... !'"'!'"':" !''i''?''':'''f'': ........ ~' '! i'-'*r'~'"f'"~'"'r'i---~--i-"f ....... ? ....... ':-;-: .4...L:-Li.-i..-~...:...Li...LL.LL.bLL~ .................... L.Li...:...;.... ~~H..L..L~...i...?-~...,...-i...~...~...i...~...;..-i...~...~ ...... bb;...L+...i...':---L~ :::::::::::::::::::::::::::::::::::: ..... ......... .................... , ....... , ........ : ................... ,..: ........ : ....... ; ................... ...HH~..~-.H~ ............... ~ ........... ~ ....... i'"~ ............ r ' ~ .......................................... T ............. ;'":" ~ ....... ~ ........ :"T'"~"'~'": ....... : ....... :"~'"~"T''?'''~''': ....... : ....... T"T'~r"~'"~ ...... ~'-?-T-T-T-T-*'TV-z-T-'~ ::::::::::::::::::::::::::::::::::::::: :::::::::::': :::I::::":7~ :::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: · "H'"H"'t": .................... ~ .............. ~'":"':'"'~ .................... t ............ ~ ............................. ~ ........... ~'"~']I3'"7':'":"'~ ........... ?": ....... :"-:"-i ....... ~'-':'"i'--?+T'~-":'"~"-7'?"~'-'t'"i'T't'"t'"?'t'": ....... :'"; '":'":"'~'"?"k'~' i'"?'H' ":'7 .......... .'' :~"':'"';'":':...::'"L ..... i'~ .... ~.:L..~ ~.. 2~nng ...... ~.~: :ZZ2 } 2..LZ..Z2.;LLLL.~...Z.L:Z:L:I22Z2Z~ ::]ZZZ~2Z2Z~~ ~ Z2ZZ[ZZZZ~~,~ :~ ZZZZZLL2L ~,: / '''.' ' ' ~ '' ~. '~ ''',~ ~'~ ~ {'~' ~. : ::~ · ";'"~*-'~'"~"4'"; .......... ~ ..................... * ...... ~ ................ ~ ....... ?'"? ...................... t .................. . ........ y-' ~-'-~'--~---~ ............ ? .......... ??"T' ~ ........ ? ........ ; .......... ? ........... + ........ 7'"r-?-'~ ........... t ....... ~ · -~--;...;...;.4...~.-~.-.; ........... ~...~ ........... ; ....... ;--.~ ................. :..+.'?.~ ....... ~.-.~ ....... ~ ........... ~ ........... ?-H.-~-.+..~--+-+.+.+.+.+.~.-+---~..-+-~.4.--f---f~--+.-~ ....... f"~'"~"'+"+'+"i-?~-'~-+-5?-: ....... :%? 6000 214. II PROJECTION ON VERTICAL PLANE 214, - 34. SCALEO IN VERTICAL DEPTHS HORIZ scqI_F_ = ]/1000 IN/FT ARCO Alaska, In¢ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: August 11, 1987 Transmittal # 6020 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2Z-4 Dual-Zone PBU ~A'~Sand 7-14-87 2Z-4 Dual-Zone PBU 'C' Sand 7-14-87 2Z-12 Dual-Zone PBU 'C' Sand 7-2-87 2Z-12 Dual-Zone PBU 'A' Sand 7-2-87 2U-15 Pressure Buildup 5-28-87 2W-6 Dual-Zone PBU 'C' Sand 7-15-87 2W-6 Dual-Zone PBU 'A' Sand 7-15-87 3M-9 Static Well Pressure Report 7-26-87 3M-3 Static Well Pressure Report 7-17-87 3M-8 Static Well Pressure Report 7-28-87 2Z-6 Static Well Pressure Report 7-21-87 2Z-8 Static Well Pressure Report 7-25-87 2U-6 Static Well Pressure Report 7-19-87 3I-9 BHP Report 7-16-87 2W-7 Static Well Pressure Report 7-21-87 2X-lO Static Well Pressure Report 7-17-87 2X-14 Static Well Pressure Report 7-17-87 2X-12 Static Well Pressure Report 7-17-87 2W-3 Pressure Buildup Test 7-4-87 2Z-2 Static Well Pressure Report 7-17-87 2Z-6 Static Well Pressure Report 7-13-87 2Z-2 Static Well Pressure Report 7-9-87 2Z-8 Static Well Pressure Report 7-13-87 3M-1 Static Well Pressure Report 7-13-87 3M-2 Static Well Pressure Report 7-13-87 1Y-lO Static Well Pressure Report 4-23-87 1Y-4 Static Well Pressure Report 4-21-87 1Y-4 Static Well Pressure Report 3-3-87 Receipt Acknowledged; AUG1 1987 Alaska Oil & 6as Cons. 6ommission Anchorage Date: DISTRIBUTION: BP Chevron Mobil SAPC Unocal State of Alaska D&M ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany .... '~ STATE OF ALASKA AL , , OIL AND GAS CONSERVATION CO ..... 5SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~X Pull tubing [] Alter Casing [] Other ~ COMPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 64' 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1250' FNL, 1722' FEL, 5ec.25, T13N, R8E, UM At top of productive interval 912' FSL, 1408' FWL, 5ec.25, T13N, R8E, UM At effective depth 761' FSL, 1311' FWL, Sec.25, T13N, R8E, UM At total depth 691' FSL~ 1267' FWL~ 5ec.25~ T13N~ R8E~ UM 11. Present well condition summary Total depth: measured 8065'MD true vertical 6473 'TVD Effective depth: measured 7950 'MD true vertical 6393 'TVD 6. Unit or Property name Kuparuk River Unit 7. Well number 3M-3 8. Approval number 7-203 9. APl number 50-- 029-21696 10. Pool Kuparuk River Oil Pool feet Plugs (measured) None feet feet Junk (measured) None feet Fee Casing Conductor Surface Production Length Size Cemented Measured depth 80' 16" 198 sx CS II 115'MD 3571' 9-5/8" '900 sx AS III & 3608 'MD 300 sx Class G Top job w/75 sx Class G 8006' 7" 300 sx Class G & 8041 'MD 175 sx AS I Rue Vertical depth 115'TVD 3305'TVD 6456'TVD Perforation depth: measured 7771'MD, 7772'MD, 7774'MD, 7794'-7822'MD, 7828'-7832'MD true vertical 6268'TVD, 6268'TVD, 6270'TVD, 6284'-6303'TVD, 6308 ' -6310 'TVD Tubing (size, grade and measured depth) 2-7/8", J-55 tubing w/tail @ 7645' Packers and SSSV (type and measured depth) HRP-1-SP pkr @ 7616" & TRDP-1A-SSA SSSV @ 1795' RECEIVED JUL 2 8 ]987 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure ~las]m 0ti & Gas Cons. Commission Anchorage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Complete We11 Hi story w/Addendum, dated 5/15/87) Daily Report of Well Operations EX , Copies of Logs and Surveys Run [~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 (Dani) SW02/50 Date Submit in Duplicate ARCO Oil and Gas ComPany Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District I County or Parish State Alaska I North Slope Borough Alaska Field ILease or Unit IWoll no. Kuparuk River ADL 25523 3M-3 Auth. or W,O. no, ~Title AFE AK2033 I Completion Nordic 1 Operator I ARCO Alaska, Inc. Spudded or W.O. begun Date Complete 7/03/87 thru 7/04/87 Date and depth as of 8:00 a.m. A.R.Co. W.I. Complete record for each day reported API 50-029-21696 ITotal number of wells (active or inactive) on this Icost center prior to plugging and 56.24% labandonment of this well IHour IPrlor status if a W.O. 7/3/87 ! 1000 hrs. 7"'@ 8041' 7950' PBTD, RI{ 6.9 ppg Diesel Accept .rig @ 1000 hfs, 7/3/87. ND tree, NU & tst BOPE. RU Gearhart, perf 7771', 7772', 7774', 7794'-7822', 7828'-7832' @ 1SPF 120' phasing. Make JB/GR rns, RU & rn 231 its, 2-7/8", 6.5#, J-55 EUE 8RD AB Mod tbg w/SSSV @ 1795', HRP-1-SP Pkr @ 7616', TT @ 7645'. Set pkr, tst tbg to 1000 psi. Tst csg to 2500 psi - ok. Tst SSSV; OK. ND BOPE, NU & tst tree. Displ well w/diesel. RR @ 0600 hfs, 7/04/87. RECEIVED JuL 2 8 1,987 ~laska 0il & Gas Cons. C0mmlssi0n Anchorage Old TD New TD Released rig Date 0600 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data PB Depth i~ nd of rg 7/04/87 I Type completion (single, dual, etc.) Single I Official reservoir name(s) { Kuparuk Sands 7950' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date {Title Drilling Supervisor ADDENDUM WELL: 3/26/87 4/30/87 3M-3 Arctic Pak w/175 sx AS I & 60 bbls Arctic Pak. RU Schl, rn GR/JB to 7939'. Rn CBT f/7933'-5800'. Rn GCT gyro f/7901' - surf. RECEIVED JUL 2 8 1,987 Oil & Gas Cons. Commission Anchorage ~//%-- ~ate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1987 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3M Pad (Wells 1-22) Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. If Sincerely, Gruber Associate Engineer JG/pk GRU1/31 Enclosure Oil & Gas Cons. Anchor~9~ ARCO Alaska, Inc. is a Subsidiary of Atl,,~nticRichfir~ldCompanY I. ALL :OORDINA1 ES 2.ALL DISTANCES SHOWN ARE TP,UE. VICINITY MAP~ S~,ALE I"" 2MILES NOTES: I. ALL COORDINATES ARE A.$.P., ZONE 4. ALL WELLS LOCATED IN SEC. 25, TISN, R8E, UMIAT MERIDIAN. 5.ELEVATIONS ARE B.P.M.$.L. 4.REF. FIELD BOOK LI7-5, Pg~. 7-1~ bi7-1, P.T; L87-5,PSI- 55; 5.0.G.ELEVATIONS FROM F.R. BELL & ASSOCIATES. 6.mRIZONTAL POSITS)NS eaSED MONUMENTS PER LHD & ASSOCIATES. ~., 1~'7 ASPs 'X' LATITUDE LONGITUDE Dist. F..N.L. DisI. F.E.L. ,l~O~'.l 7 506,t~ 6.'~! :?'! 14905 1291' 1741' 25.1' 26.6' 6,225.i0 506,156.45 .7' i6' 59.7 1275' 1752 6,246.21 506,145.96 7'20.2 t6159.459 12 50', 1722 25. S', 26.9, :6~271.24 506,155.57 ,7'20.4 ~6.59.15T 1227' 1713 6,~94.~8 506,165.01 ~T'~O.E ~6~.~77 1~04', ITO~ E,31?.4Z 5~,174.6~ _~7'20'9 ~6 58~9E I1~1 1694 26.6 6,016,~40.48 5~,164.1~ ~°27'21'1 ~6'58.~16 1158~ 1~84 2~.Z~ ' ' 6,016,563.49 5~,193.52 lo27'~1.3 ~'~.~( 11~5 1675 ~. I ~6.6' 6,016,366.92 506,203.14 )o27;21.e s6;IT. TS6 II IZ' 1665 ES.O', 6,016,456.13 506 ~2~2.0~ ~27,22.2 56, 56.9~ 1~2', 16~6 6,016,479.~2 506,~41.5a ~27 ~a.l ~6 ~.62~ 1019 16~6 016~525.51 506,Z60.~ 7~27 22.~ )°5656D61 973 1607 ~l.t ~6.3 ,548.6Z 5~,270.50 70°27',25'1~ ~°56'55'776 950', 1598' El I' ~6.4~ 1.43 5~,2*79.77 70°27-25-410 t°56'55'~1 927, 1586'_ ~9~ ~6.4, 4.73 5~,2e9.40 7~7'2~.639 P56'55.21~ 904, 1576', ~0~9', 7~9 506,t99.05 70°27'2~-868 )°56'54'953 681 1569 ~0.9 6,016~1.02 5~08.76 7~z7'24.094 4~56'54.647 858' 1559' ~0.8' E6.6' ~,17~.~ ~,/17.~ 7~'z7'/~.55~ /~f'57'~.~/' /~' /7~/' z~.~' ARCO Alaska Inc. I HERF-BY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MAD[ BY ~ OR UNDER MY SUPERVISION, AND 'THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF ~5/8/67 --" D.S. SM WELL CONDUCTOR AS-BUILT DWN BY: GLL CHK BY: AdR ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: May 12, 1987 Transmittal # 5976 RETURN TO: ARCO Alaska, Inc.' Attn: Kuparuk Records Clerk ATO-1119~ P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted her&with are the following items. Please acknowledge receipt and return one signed copy of this transmittal; 2Z-7 3K-9A 3K-8 3K-17 iA-10 3Q-16 lA-2 3Q-15 3M-6 3M-2 3M-5 3M-7 3M-4 3M-3 3M-1 2Z-5 2Z-5 CET Log 4-20-87 8275-8597 CBL 11-14-86 5408-7460 CET 11-15-86 7148-8376 CET 11-15-86 7940-9400 CET' 11-21-86 8650-8936 CBL 12-20-86 5349-7173 CET 12-21-86 7095-7781 CBL 12-20-86 5453-7360 CBL 4-30-87 5300-7312 CBL 4-28-87 6500-8295 CBL 4-28-87 6200-8795 CBL 4-30-87 6300-8359 CBL 4-28-87 7950-9845 CBL 4-28-87 5800-7933 CBL 4-28-87 4900-7187 Squeeze & Plug/Retainer Record 4-30-87 8090-8144 CET 4-30-87 7000-8324 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC / .~~:0t! & G~ C0~. Commission ~~s~ ~,(+SeP ia }~?~'~'~ BPAE Chevron Union Vault ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany STATE OF ALASKA ALAS,... Oil AND GAS CONSERVATION COMi,. .,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon D Suspend [] Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~J Time extension [] Change approved program ~ Plugging .rq, Stimulate [] Pull tubing [] Amend order ~ Perforate ~ Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P. 0. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 1250' FNL, 1722' FEL, Sec.25, T13N, R8E, UM At top of productive interval 913' FSL, 1424' FWL, Sec.25, T13N, R8E, UM At effective depth 774' FSL, 1263' At total depth 704' FSL, 1219' 11. Present well condition summary Total depth: measured true vertical (approx) FWL, Sec.25, T13N, R8E, UM (approx) FWL, 5ec.25~ T13N~ R8E~ UM (approx) 8065'MD feet Plugs(measured) 6466'TVD feet 5. Datum elevation (DF or KB) RKB 63 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3M-3 8. Permit number 87-14 9. APl number 50_029-21 696 10. Pool Kuparuk River Oil Pool None Effective depth: measured 7950 'MD feet true vertical feet .6386 ' TVD Casing Length Size Junk (measured) None Cemented Measured depth True Vertical depth Conductor 80 ' I 6" Surface 3571 ' 9-5/8" Product i on 8006 ' 7" 198 sx CS II 900 sx AS II I & 300 sx Class G Top job w/75 sx Class G 300 sx Class G 115'MD 3608'MD 8041'MD 115'TVD 3309'TVD 6450'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth)None 12.Attachments WELL HISTORY Description summary of proposal [] Detailed operations program ~ BOP sketch [] 13. Estimated date for commencing operation August, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed L~f~(,,~/~/~: ¢~.~ Title Associate Engineer ~ Commission Use Only (Dani) SA2/28 Conditions of approval Approved by ;~-:~' :..., . Form 10-403 Rev 12-i:-85 Notify commission so representative may witness [] Plug integrity I Approval No. [] BOP Test [] Location clearance "~* ~ ~-/-~X * by order of .... .......................... · .... --*~mmissioner the commission Date Submit in triplicate ARCO Oil and Gas Company Well History - Initial Report- Daily ~ Instructione: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty, parish or borough State I Alaska North Slope Borough I Alaska Field Lease or Unit Well no. Kuparuk River ADL 25523 3M-3 Auth. or W.O. no. ~Title AFE AK2033 I Drill Doyon 9 API 50-029-21696 I ARCO W.I. Operator ARCO Alaska, Inc. Spudded or W.O, begUnspudded IDate 3/1/87 IH°ur 0400 hrs. IPri°r status if a W'O' Date and depth as of 8:00 a.m. 3/01/87 thru 3/02/87 3/03/87 3/04/87 3/05/87 3/06/87 !Complete record for each day reported 16" @ 115' 2645', (2530'), Drlg Wt. 9.2, PV 14, YP 14, PH 9.5, WL 13.2, Sol 6 Accept rig @ 0200 hrs, 3/1/87. NU diverter sys. Spud well @ 0400 hrs, 3/1/87. Drl & surv 12¼" hole to 2645'. 523, .8°, N19.8E, 522.98 TVD, - 3.53 VS, N 3.44, El.21 1414', .7°, N84E, 1413.89 TVD, - 15.53 VS, N13.11, E8.34 1854', 8.3°, S40.9W, 1853.08 TVD, 1.60 VS, S .56, W2.02 9-5/8" @ 3608' 3627', (982'), Prep to pmp top job Wt. 9.2, PV 22, YP 25, PH 9.0, WL 11.2, Sol 6 Drl & surv 12¼" hole to 3627', short trip, C&C, POOH. RU & rn 90 jts, 9-5/8", J-55, 36#, BTC csg w/FC @ 3525', FS @ 3608'. Cmt w/900 sx AS III & 300 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. ND diverter. Prep to pmp top job. 2759', 32.1°, S36.8W, 2676.15 TVD, 359.34 VS, 285.15, 219.58 3203', 42.9°, S36.6W, 3017.84 TVD, 641.24 VS, 508.04, 393.04 3551', 45.1°, S39.7W, 3268.15 TVD, 882.42 VS, 698.11, 542.34 9-5/8" @ 3608' 4953', (1326'), Chg out turbine Wt. 9.0, PV 5, YP 2, PH 9.0, WL 8.8, Sol 5 Pmp 75 sx Class G top job. NU & tst BOPE. RIH, tst csg to 2000 psi. DO cmt & flt equip + 10' new formation. Conduct formation tst to 12.5 ppg EMW. Drl & surv to 4953', POH, LD turbine. 3742', 43.8°, S39.1W, 3404.50 TVD, 1015.66 VS, 801.46S, 627.24W 4407', 45.7°, S37.4W, 3880.11TVD, 1479.60 VS, 1169.27S, 911.23W 4716', 45.3°, S36.0W, 4096.69 TVD, 1699.81VS, 1345.98S, 1042.94W 9-5/8" @ 3608' 6206', (1253'), POH to repair rotary table Wt. 9.1, PV 7, YP 4, PH 9.5, WL 8.2, Sol 6 Drl & surv to 6206', POH f/rig repair. 5000', 44.8°, S34.7W, 4297.34 TVD, 1900.77 VS, 1509.91, 1159.23 5630', 47.0°, S30.6W, 4736.90 TVD, 2351.84 VS, 1888.29, 1405.03 9-5/8" @ 3608' 6640', (434'), Drlg Wt. 9.2, PV 8, YP 5, PH 9.0, WL 9.2, Sol 7 Repair rotary table. Drl to 6640'. 6194', 43°, S36°W, 5135.71TVD, 2750.58 VS, 2221.62S, 1623.98W 56.24% The above is correct Signaturetare~~~ j~ ~ For form preparation a~-d '~T~ibution, -- / see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date Title Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District Alaska Field Kuparuk River Auth. or W,O. no. AFE AK1631 County or Parish Lease or Unit Title North Slope Borough ADL 25523 Completion Nordic #1 API 50-029-21696 State Alaska Well no. 3M-3 Operator ARCO Alaska, Inc. A.R.Co. W.I. 56.24% Spudded or W.O. begun Date Spudded 3 / 1/87 Date and depth Complete record for each day reported as of 8:00 a.m. 3/07/87 thru 3/09/87 I otal number of wells (active or inactive) on this DSt center prior to plugging and I bandonment of this well I our I Prior status if a W,O, I 0400 hrs. 7" @ 8041' 8065' TD, 7950' PBTD, (1425'), RR 10.0 ppg NaC1/NaBr Drl & surv 8½" hole to 8053', 25 std short trip, C&C, POH. RU Schl, rn OHL, RD Schl RIH, make wiper trip, drl 15' to 8065' · , CBU, POH, LD DP. RU & rn 184 its, 7", 26#, J-55 BTC csg. Cmt w/lO0 sx 50/50 Pozz w/4% D-20, .2% D-46 & .5% D-65 & 200 sx Cl "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ w/lO.0 ppg brine, bump plug. Tst csg to 3500 psi. ND BOPE, NU & tst tree to 3000 psi. RR @ 1930 hrs, 3/8/87. 6794', 44.3°, S32.9W, 5569.85 TVD, 3164.73 VS, 2563.14S, 1858.25W 7295', 44.8°, S31.9W, 5926.88 TVD, 3515.96 VS, 2860.22S, 2046.07W 7953', 46.2°, S32.6W, 6388.08 TVD, 3984.92 VS, 3257.57S, 2295.81W Old TD New TD Released rig Date 1930 hrs. Classifications (oil, gas, etc.) Oil Flowin~ Producing method 8065' TD IPB Depth I Kind of rig 3/8/87 Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 7950' PBTD Rotary Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SP.M X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drillin~ Supervisor ARCO Alaska, Inc. !',o~t Office Box 100360 A~mhora_qe, Alaska 99510~0360 Telephone 907 276 1215 March 27, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3M Pad (Wells 1-18) Dear Mr. Chatterton' Enclosed is an as-built location'plat for the subject wells. you have any questions, pleaSe call me at 263-4944. Sincerely, Gruber Associate Engineer JG/db GRU1/31 Enclosure RECEIVED ¢'vlA I, 1987 Oil & GaS [;Ol~S, Commission /~,llCO Al,~st',~, Inc, is a Subsidiary of AllanlicRichfiehlComp,-my ............. ' ' ' ' ' ! __ OLIKTOK PT. 24 19 __.: /~ SIMPSON __ ~____1~_ I ..~.x, ''~ LAGOON' '~" 25 ~3 ~ I ·~ , - VICINITY MAP ~CALE I"= ~MILE5 NOTES: I.iLLC~RDIN~TE5 ~RE i.5.P., ZONE 4. ~.~ DISTANt5 ~ AR~ TRUe. ALL WELLS LOCATED IN SEC. 25, 3.ELEVATIONS ARE B.RM.S.L. 4.REF. FIELD BOOK L87-:5, PCS. 7-1~ LBT-I, R 7; L87-$,P51 - 5:5; 5.0.G. ELEVATIONS FROM F.R. BELL & ASSOCIATES. 6.HORIZONTAL POSITIONS BA~ED ON 3M CONTROL MONUMENTS PER LHO & ASSOCIATES. : A._SP~ '~: LATI TUD________~__E LONGI_____.~TUD.__~E ~ 5,202.17 506,126.~9 70°27'19.?l~3"149°57'00'000'! 6,016,225.10 506,156.45 70027'20.005'' 149o56'59720" 1273 I ' II I 6pl6,248.21 506,145.98 70027'?.0.?.$2, 149o56,59.439, 1250, 6~016,271.24 506,155.57 70027'20.459. 149o56 59.157 1227 6,016,294.28 506,165.07 70°27'20.685:'149056'58'877"~ 1204', 6,016,:517.42 506,174.6:5 70o27'20.91:5 149056'58.596" 1181 Il Ii 58: 6,016,:540.48 506,184.1:5 70°27'21'140 149°56',58':516' 6,016,:565.49 506,19:5.52 70°27'21-:566 149°56.58'040 6,016,586.92 506,20:5.14 ?no27'21 596 149°56'5TM II 12' '"' , ' o ' 042', 6,016,456.13 506,252.02 70027,22.277 149_56,56.906 I 6,016,479.22 506,241.52 70°27 22.504, 149°56,56-627 t019 ?oo27'22 7:50 149056.56.:545, 6,016,502.26 506,251.07 -- -7'22'959 149°56~56-061 6,016,525.51 506,260.73 7002 - 6,016,548.62 506,270.30 70°27',23.186: 149°56;55'779 ?n°27 2:5 410 149056.55.501 6,016,571.4:5 506,279.77 --o 7'23'~39' 149056:55217 6,016,594.7:5 506,289.40 70 2 . . - . 6,016,61 7.99 506,299.05 70°~7'23.868,.149°56,54'9:53,, 6 ,016 ~ 641.02 506~:508.76 70°27'24-094 114905654.647 Dis t.F.E.L.O.G.Elev. 1741' 17:52' 17 22 1715 1703', 1694 1684 1675 1665' 16:56 1626 25. I' 23.2' 23.$', 25.4 23.4', 23.3 2:5.2' 23.1' [3.0', 21.5 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME: OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF ;5/8/87 996', 9?3 950', 927, 904 881' 858' 16171 1607 1598' 1586' 1578' 1569' 1559' 21.4' 21.2' 21.1 20.9 20.9 20.9 20.8' Pad Elev. 26.6' 26. , 26.6 26.8', 26.7 26.6' 26.6' 26.4' 5' 26.5, 26. 26.4: 26.3 26.4 26.4 26.5 26.5 26.6 ARCO Alaska Inc. D.S. 3M ELL CONDUCTOR AS-BUILT DATE: :5/8/87 NSK 6.31:5-d2 ARCO Alaska, Inc. Post Office ,.,~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 18. 1987 Transmittal #: 5940 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. · 3M-3 OH LIS Tape + Listing 3-7-87 f/72223 'Receipt Acknowledged: DISTRIBUTION: D. Wetherell ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, h' Posl Office =ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 18, 1987 Transmittal #: 5942 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Finals 3M-2 3M-3 Cyberlook 2-27-87 7800-8400 2" DIL 2'27-87 3938-8478 5" FDC Porosity 2-27-87 5984-8452 ,2" FDC Porosity 2-27-87 5984-8452 2'"-FDC Raw 2-27-87 5984-8452 5" FDC Raw 2-27-87 5984-8452 i5" DIL 2-27-87 3938-8478 Cyberlo°k 3-7-87 7450-7950 5" FDC Raw 3-7-87 7450-8021 2" FDC Raw 3-7-87 7450-8021 5" FDC Porosity 3-7-87 7450-8021 2" FDC Porosity 3-7-87 7450-8021 5". DIL 3-7-87 1000-8047 2" DIL 3-7-87 1000-8047 'Receipt Acknowledged: DISTRIBUTION: NSK Drilling L. Johnston (vendor pkg) Date: ~ Rathmell ~~~ Vaul Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany February 10, 1987 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Kuparuk River Unit 3M-3 ARCO Alaska, Inc. Permit No. 87-14 Sur. Loc. 1250'FN~L, 1722'FEL, Sec. 25, T13N, R8E, UM. Btmhole Loc. 691'FSL, 1272'FWL, Sec. 25, T13N, RSE, UM. Dear Mr. KeWin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify.you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior 'to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ver~v-. tru~ly v~urs, ' © Chairman o f Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery .... STATE OF ALASKA ALASKA L _ AND GAS CONSERVATION CO,,,,vlISSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork Drill~ Redrill ~1 lb. Type of welI. Exploratory [] StratigraphicTest []Single Development Oil ~Multiple Re-Entry Deepen Service [] Developement Gas [] Zone/~ Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 63', PAD 26' feet Kuparuk River Field 3. Address 6. Prop, arty Desionation Kuparuk River Oi 1 Pool P.O. Box 100360 Anchorage, AK 99510-03~60 ADL 25523 /~LK 2559 .,, 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 1250'FNL, 1722'FEL, Sec.25, T13N, R8E, UM Kuparuk River Unit Statewide _A.t top. of productive interval 8. Well number Number 913'FSL- 1424'FWL, Sec.25, T13N, R8E, UM 3M-3 ' #8088-26-27 At total depth 9. Approximate spud date Amount 691'FSL, 1272'FWL, Sec.25, T13N, R8E, UM 02/27/87 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3M- ~_ r~ 8065 ' MD 1250'~ Surface feet 25' @ '.,,,'~,/~-/,Fl~(~ 2560 (6464'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff deptt~650' feet Maximum hole angle 45 0 Maximum surface 1985 psig At total depth O'VD) 3130 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 cf 12-1/4' 9-5/8" 36.0# J-55 BTC 3615' 35' 35' 3650' 3353' 900 sx AS III & HF-EFW 300 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC 8031' 34' 34' 8065' 6464' 200 sx Class G(minimum HF-EFW TOC 5,)0' above top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface ; ,, Intermediate Production Perforation depth: measured true vertical ' '~ 20. Attachments Filing fee/~ Property plat [] BOP Sketch ~_ Diverter Sketch/~ Drilling program~ Drilling fluid program~ Time vs depth plot [] Refraction analysis [] Seabed repoFt [] 20 AAC 25.050 requirements 21. I hereby certi/f¥~hat the foregoi~,.q, is true and correct to the best of my knowledge Signed ~.~~~,/'~~~ CommissionTitle Regionaluse Only Dril '~[~ En'i~'~8~ Date'/~/~/~// ' ? ?-i h~~ 50-- o ,~-~ '- ~ I' O,q 4~ 0 2 / Z 0 / 8 7 for other requirements ,,. Conditions of approval Samples requir.ed [] Yes ~ No Mud Icg required L~ Yes ~,~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~Yes [] No~ Requiredwork~sure f~~~2M~ J~SM; F1 5M; [] 10M; [] 15M by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 cate -"-'~", ~ ....... ~ .... ., .,-,-, , -, . ,. ,., ? -- - __2 ......... 7: ........ ~PAF'~;;~XELD, 'NORTH' SLO~ ALASKA" ....... ~ ' ' _~_- ; - ~:~:" ~ ' " ~ ..... ~ ...... ~i~nei~'~ ..... ~ ..... ~ ' ' ..... . ,~ ..... ~ , ~ ~ _ ~ ,, ~-- ~ ......... .... ~ ' t ~ .... ~ ' ~ ' ....... ! ~ -' ' ; ~ ~ : , , ~ 'j' ......................................... ~ ................ .. ~ .... ~ ........ ,_ . ~.-~ ..... r ............. ~+ ~ ~ ~ ....... ~ ............................ ' :: ..... :.~_.;;~-;;;..~:.-~.;;;'.~.;.. ~ "."-. '.~ ::.. _.. ;. . ; ; ;~ .. - ;'~ ........... : ..... : /; .' :'~' ':" {.~; .... ........... ~_~ .... ~. ................... ¥_.~ ......................... ~ ..... ,. -::-:::':: ::'.~:;-:'-~'a~nn:'-: ::-;':':' ::::::::::::::::::::::::::::::: :-':"AVER ::.:-L-.-~--;,~ ~:::.- :;.: :::' ::::~%'.. _ .. ~5 DE~. .......................................... ~ ..... _..: _ ~nnn ...... ~ , ,.,,., ~ ,, ~ ~ ......................... { ..................... ~ ..... : ' : .~_ . ~nn~_ ._. ~ .... ~. . . .~ ......... ;.;;. ~ KUP SND~ TVD 632~' T~,.Z865 ~P ' '"I ....~ ...... -': :: :-.i ....... ...... - - ~ .... I ...... ; ....... f , . . ....... , .......... } ..., .... ~ .... ~. . A~ ,~, I ,ROPO~ED .:' ~ ,~~.-~I:L NO, , I ~. AL,',SKA ~. / J[ ~.. ; ~~-FIt~LD, NORTH SLOP __ nan * ~ .~ ....... [ ........ : ........... :.. :~, ~.,,.~..m ': ...... J ' t .... L ' [ ' ~ ' ' ' : .... :'~:~ ................................ 1 ~ ............. - t ' ' .................. .... ' ~ ~- ~4 ~2~ Iq-t-N-W . ,.. ~ j ~ ........... ....... KUPARUK RIVER UNIT 20' DIVERTER SCHEMATIC · I I DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10" OUTLETS S. 10" HCR BALL VALVES W/lO" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION . . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY, CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMS.,TANCE$ JG 11-3-86 7 6 DIAGRAM #l 13-5/8" 5000 PSI RSRRA BOP STACK I. 16" - 2000 PSI TAN<CO STARTING HEAD 2. Ii' - 3000 PSI CASING HEAD 3. II" - 3000 PSI X 13'-5/8" - 5000 PSI SPACER SPOOL 4. 13-'5/8' - 5000 PSI PIPE PJM~ 5. 1~"5/8' - 5000 PSI DRILLING SPOOL W/CHOKE /V43 KILL L II'~:.S 6. 13-'5/8" - 5000 PSI DO, JBI, E RAM W/PIPE ~ ON TOP° ?. 1~'-5/8' - 5000 PSI ~ ACQ,MJLATOR CAPACITY TEST I. cl-~cl( AI~ FILL ACO.IvLLATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ~ THAT A(X]J4J. ATDR PRESSiJRE IS 50(X) PSI WITH 3. OBSERVE TIldE, THEN CLOSE ~ UNITS SI~JLTA~OIJS..Y ALL UNITS ARE CLOSED WITH CHARGING PU~P CI=F. 4. RECORD ON NADC REP(]iq', THE ACCEPTABLE LOAER LIMIT IS 45 SEC~N~ CLOSING TIldE AN~ 1200 PSI REI~INING PRESSJRE. 5 4 13-5/8" BOP STACK TEST I. FILL BOP STACK AN) CHCI(E MANIFClD WITH ARCTIC 2. CHECK THAT ALL LOQ( ~ ~ IN V~_U-EN) ARE FULLY RETRACTED. SEAT TEST PLUG IN V~ELU-EAD WITH ~ING JT AhD RUN IN L~ SDRE]NS. LIhE VALVES ADJACENT TO BOP STACK. ALL OTHER VALVES AN3 CHCKES SHOULD BE OPEN. 4. PRES.gJRE UP TO 250 PSI AhD HOLD FOR I0 MIN. IN- CREASE PRESSIJRE TO Z~X]O PSI AhD HOLD FOR I0 MIN. BLEED PRESSJRE TO 0 PSI. LIhE VALVES. CLOSE TOP PIPE RAMS AI~ HCR VALVES ON K~ILL AhD Q-EI<E LIra, S. 6.TEST TO 250 PSI A~ 5000 PSI AS IN STEP 4. 7. CGNTI~ TESTING ALL VALVES, LI~.S, N~D O-EKES WITH A 250 PSI LOW AI~ 5000 PSI HIGH. TEST AS IN STEP 4. DO J~'[ p~.e~l.J~ TE.~T ANY CHOKE THAT NOT A FlJLL CLOSING POSITIVE SEAL CH(~. ONLY FUNCTIC~ TEST O-[~ES THAT DO NOT FULLY CLOSE. 8. OPEN TOP PIPE RAMS AI~ CLOSE BOTTCM PIPE RAMS. TEST BOTTCM PIPE ~ TQ 250 PSI AI~ 5000 PSI. 9.OPEN BOTT(~ PIPE RAMS, BACK OUT RIJI~ING JT A~D I0. CLOSE BLIhD RAMS AhD TEST TO 250 PSI AhD 5000 PSI. il. OPEN BLIhD RAMS ~ RETRIEVE TEST PLUG. MAKE SURE MANIFOLD ~ LI~ES ARE FlJLL CF NON-FREEZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAI~PIPE VALVES, KELLY, KELLY COQ<S, DRILL PIPE SAFETY VALVE, AhD INSIDE BOP TO 250 PSI AhD 13. RECORD TEST I~FC~ATION ON BLO~IJT PREVENTER TEST FO~I, SIGN, AhD ~ TO DRILLING SUPERVISDR. 14. PERF(~ COV~ETE BOPE TEST AFTER NIPPLING UP WEEKLY T~EREAFTER FUNCTIONALLY CI:~mRATE BOPE DAILY. 510084001 REV. 2 MAY 15,1985 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations, The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LWK5 / ih GENERAL DRILLING PROCEDURE KUPARUK RIVER FIgLD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. I0. Run and cement 7" casing. Pressure test to 3500 psig. Il, Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run caged hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standin~ tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE _ SHAKER,5 HUD CLEANER STIR ~ STIR __ STIR TYPICAL HUD SYSTEH SCHEHATIC L~4/ih IT~ APPROVE DATE ~ YES NO (1) Fee ~/~ ~ ~ ;~ 1 Is the permit fee attached~ ~ ~ e~ · e e e e e e e · e · · · · · · · · · · · e e · · e e e · · · · · · · · · · · · · · e , ,, (2 thru 8) (3) Admin (9 fhru 13) 10. (10 and 13) 12. 13. (4) Casg /~.~f ;.- ~o ~? (14 thru 22) (5) BOPE ~.f~.~( ~-,y- ~? (23 t!'u--'u 28) 2. Is well to be located in a defined pool ............................. 3.~ Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................. 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ...... 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator Have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval-needed i e e e e e e e e e e e · e e · · e e ® · · · · · · · · · · e · · · · Is the lease n~mber appropriate .......................... ~ Does the well have a unique na2~ ~'n~nber .... [ ~. ~.. [i.. ~.. ~. ~ Is conductor string prOVided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~ ~ psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) C~ /~,~, (29 thru 31) For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented (6) Add: 32. Additional requirements ............................................. Geol9~/y: WWB wv~ Engineering: rev: 01/28/87 ,6.011 INITIAL GEO. UNIT DN/OFF roo cuss mros NO. Additional Remarks: $Jd-3 ~v ~ u;;~;,v ~'~ ZM-~- Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. HIf. RO ILM[I} .VO OlO.HO2 VS~IFiC~TIJ~ CiS7iNG ~AGE I SERVICE NA~E :~OiT DATE :87/03/12 ORIGIN : REEL NAME CONTINUATION ~ :01 PREVIOUS REEL : COMMENTS :LIBRARY TAPE -~- TAP: HEADER ;):~ SERVICE NAME :EDIT DATE :87/03/12 ORIGIN :FSiA TAPE NAME : CONTINUATION ~ :01 PREVIOUS T~PE : COMMENTS :LIBRARY TAPE ~ FiLE HEADER FILE NAME :EDII .001 SERVICE NAME VERSION f : DATE : MAXIMUM LENGTH : 1024 ~ILE TYPE PREVIOUS FiLE : .-.,. INFORMATION R~COR, GS ;I~'".,. MNEM CONTENTS UNIT TYPE CATE SiZE CODE CN : ARCO A'LASKA~ zN~. 000 000 018 065 WN : 3M-3 000 000 00~ 065. FN : KUPARUK 000 000 008 06'5 RANG: BE 000 000 002 065 TOWN: 13N 000 000 004 065 SECT: 25 000 000 002 065 COUN: NORTH SLOPE 000 000 012 065 STAT: ~LASKA 000 000 006 065 MNEM CONTENTS UNiT TYPE CATE SIZE COOE PRES: E 000 000 001 0.55 ~.'~ COMMENTS _VP OlO.H02 VERIFiCaTION LISTING [ PAGE 2 ~ S CHLUM$E RGER ~',-' ~LASKA COMPUTING CENTER ;,: 20MPANY = ARCQ ALASKA INC N~LL = 3M-3 FIEL~~ = KUPaRUK COUNTY = NORTH SL~P~ 5~ROUGH STATE = ALASKA JOB NUMSER AT ACC: 72223 RUN ~'ONE, DATE LOGGED: 7 MAR 87 LDP: T HALSTE'~D CASING = 9.625" @ 3608' - BIT SiZ: = 8.5" TC B055' TYPE FLUID = LSND FOLYMF. R DENSITY = 10.0 LB/G RM = 4.590 ~ 75 DF VISCOSITY : 43.0 S RMF = 3.5Z0 ~' 64 OF PH = 8.5 RF~C = 3.910 ~ 69 OF FLUID LOSS = ~.6 C3 R~ AT BHT = Z.476 ~ 145 DF MATRIX SANDSTONE -,--,--,- THIS D,&TA HAS NOT B:EN D~PTH SHifTeD OVERLAYS FIELD PRINTS -,--..,. ...... VERiFICATiON LISTIN6 PAGE ' 3 SCHLU~,iBERGER LCGS iNCLUDED ~,ilT~ TP.,,iS M~GNETIC "'-,- DUAL INDUCTION ..qPMERZCfiLLY FOCUSEO L~G (~. L) , "' D~T~ ~VAiL~BLE: 6047' TO 3808' , COMeENSATED NEUTRON LOG (FDN) "' D~T~ gVIILAgL6: 8021' TC 7450' "' '" AY IN CASING (GR.CNL) -,-"~"" GAMMAD~TA AVAZL~aLE: 360'8' Tu'~ 1000' ** DATA FORMAT R~CGRg ** ENTRY BLOCKS TYPE SiZE REPR CODE ENTRY Z 1 66 0 4 1 66 1 ~ 4 73 60 9 4 65 .lin 16 I 66 0 1 66 0 DATUM SPECIFICATION 6LOCKS MNEM SERVICE SERVICE UNiT API APi AP! AP1 PiLE SiZE SPL REPR ID 8ROER ~ LOG TYPE CLASS MUD NO. DEPT FT O0 000 OO 0 0 4 SFLU CIL ~HMM O0 220 Ol 0 0 4 ILO OIL OHMM O0 120 46 0 0 4 ILM OiL OHMM O0 1lO 4~ 0 0 4 SP OIL MV O0 010 Ol 0 0 4 GR DIL GAP! O0 310 O! 0 0 4 GR ~N GAPI O0 310 O1 0 0 4 CALl PON IN O0 280 Oi 0 0 4 PROCESS CODE (OCTAL) 1 68 00000000000000 1 68 00000000000000 1 58 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 58 00000000000000 I 68 00000000000000 _VP OlO.H02 VERIFICATION LISIiNG PAGE 4 RHO6 FDN G/C3 O0 350 02 3RHO FON G/C3 O0 355 NRAT FDN O0 420 01 RNRA FDN O0 000 O0 NPHI FDN PU O0 890 O0 DPHI FDN FU O0 890 O0 NCNL PON CPS O0 330 31 FCNL FDN CPS O0 330 30 GR CNL G~I O0 310 Ol DEPT 8074.5000 SFLU SP -48.7500 GR RHO5 :2.3926 DRMO NP~I 33.4961 DPHi GR -999.2500 OEPT 8000.0000 SFLU SP -30'7656 GR RHOE 2.2129 ORHO NPH! 32.8613 DPHI GR -999,2300 DEPT 7900.0000 SFLU SP -11.5000 GR RHOB 2.~160 ~RHG NPHI 41.3574 CPHI GR -999.2500 DEPT 7800.0000 SfiLU SP -51.0000 GR RHDB 2.2637 ~RHO NPHI 31.2500 DPHi GR -999.2500 DEPT 7700.0000 SFLU SP -~0.2813 GR RHOB 2.5645 DRHO NPHi 29.1016 DPHI GR -999.2500 OEPT 7600.0000 SFLU · SP -38.7500 GR RHOB 2.316~ DRHO NPHi 48.0~69 OPHi GR -999.2500 DEPT 7500.0000 SFLU SP -43.0000 GR RHG5 2.4688 DRHO NPHI 45.1660 DPHi GR -999.2500 3.0459 101.9375 0.0293 15.6096 3.2~89 87.0000 0.0928 26.4988 3.9980 ~9.5000 0.1777 14.1594 29.5160 59.5625 0.0283 23.~215 3.6856 91.8125 -0.0298 5.1941 1.78'79 108.0625 -0.0024 20.2258 £.5308 103.7500 0.0303 10.9937 ILD GR NR AT NCNL ILB GR NRAT NC NL iLD GR NRAT NCNL ILD GR NRAT NCNL ILO GR NRAT NCNL ILO GR NRAT NCNL 'ILD GR NRAT NCNL 3.0439 101.9375 3.1035 187~.0000 3.1962 87.0000 2.9609 2090.0000 3.4452 89.5000 3..4199 1823.0000 16.0141 59.5625 2.$125 2144.0000 5.1353 91.8i25 2.7559 2724.0000 1.7790 108.0625 :3.8223 1615.0000 2.3~.34 103.7500 ..7441 1703.0000 1 6~ O000000CO00000 i 68 00000000000000 1 68 00000000000000 i 58 00000000000000 1 6~ 00000000000000 1 68 00000000000000 1 ~8 00000000000000 I 68 00000000000000 t 68 O0000000OO0000 iLM 3.3141 CA:LI 8.8594 RNRA 3.2656 FCNL 640.0000 ILM 3.5402 CALI 8.7422 RNRA 3.4102 FCNL 534.5000 iLM 17.5869 CALl 8.3906 RNRA 2.8574 FCNL 750.0000 ILM 4.5590 CALI 9.4297 RNRA 2.8242 FCNL 964.5000 iLM 1.8195 CALI 9.1953 RNRA 4.0000 FCNL 403.7500 ILM 2.3715 CALI 10.1'797 RNRA 4.0195 FCNL 423.5000 iLM 3.2274 CALl 10.1172 RNRA 3.1699 FCNL 592.5000 ¥~ OlO.m02 VfRiFICATION CiSTiNS ~aS~ 5 DFPT SP '4PHI DEPT SP RHOB NPHi GR DEPT SP RHOB NPHi GR DEPT SP RHOB NPHi GR DEPT SP RHD5 NPHI GR DEPT SP NPHi GR DEPT SP RHOB NPHI GR DEPT SP RHO5 NPMI GR DEPT SP RHOB NPM I GR 7~00,0000 SFLU -38,2500 G~ -999,2500 DR~O -'999. 2500 ¢~PHi -999.2500 7300.0000 SFLU -37.5000 GR -999.2500 DRH3 -999.2500 CPhl -999.2500 7200.0000 SFLU -54.0000 GR -999.2500 DRHO -999.2500 DPHZ -999,2500 7100,0000 SFLU -62,5000 GR -999,2500 DRHO -999,2500 DPHi -999,2500 7000.0000 SFLU -63.0625 GR -999.2500 DRHO -999.2500 DPHi -999.2500 6900.0000 SFLU -65.2500 GR -999,2500 DRHO -999.2500 DPHi -999.2500 6800.0000 SFLU -59,0000 GR -999,2500 ORHO -999.2500 DPHi -999,2500 6700,0000 SFLU -71,2500 GR -999,2500 DRH3 -999,2500 DPWi -999.2500 6600.0000 SFLU -34.2500 GR -999.2500 DRHO -999.2500 DPWi -999.2500 2.3170 iLD !1'3.~375 GA -999.2500 NR&T -999.2300 NCNL 3.7729 iLD 205.1250 G~ -999.2500 NRAT -999.2500 NCNL 4.3873 iLD 230.3750 GR -999.2500 NRgT -999.2500 NCNL 4,2640 ILO 121.0625 GR -999.2500 NRAT -999,2500 NCNL 4.2733 ILD 111.7300 GR -999.2500 NRAT -999.2500 NCNL ~.1412 ILO 99.2500 GR -999.2500 NRAT -999.2500 NCNL 3.6267 ILO 99.2500 GR -999.2500 NRAT -'999.2500 NCNL 4.0474 iLO 138.6250 GR -999.2500 NRAT -999.2500 NCN.L ~.01'7i IL'D 114.1250 GR -999.2500 NRAT -999.2500 NCNL 2.2589 -999.2500 -999.2500 -999,2500 3.1614 -999.2500 -999.2500 -999.2300 3,7130 -999,2500 -999,2500 -999.2500 4.3153 -999.2500 -999.2500 -999.2500 4.5763 -999.2500 -999.2300 -999.2500 4.3669 -999.2500 -999.2500 -999.2500 3.4159 -999.2500 -999.2500 -999.2300 4.3 ,'~:, 72. -999,2500 -999. Z 500 -999,230'0. 4.5556 -999.2500 '-999.2500 -999.2300 iLM CALl RNRA FCNL ILM CALl RNRA FCNL ILM CALl RNRA FCNL ILM CALl RNRA FCNL iLM CALI RNRA FCNL ILM CALl RNRA F CNL !LM CAL! RNRA FCNL ILM CALl RNRA F CNL ILM C~LI RNRA FCNL 2.3025 -999.2500 -999.2500 -999.2500 3.2642 -999.2500 -999.2500 -999.2500 3.7373 -999.2500 -999.2500 -999.2500 4.3030 -999,2500 -999.2500 -999,2500 4.4661 -999.Z500 -999.2500 -999.2500 4.2569 -999.2500 -999.2500 -999.2300 3.4396 -999.2500 -999.2500 -999.2500 4,3467 -999.2500 -999,2500 -999,2500 4.3274 -999.2500 -999.2500 -999.2500 .VP OlO.H02 VERiFiCATiON LISTING PAGE 6500.0000 SFLU -39.0625 -999.2500 -999.2500 -'999.2500 6400.0000 SFLU -36.7813 GR -999.2500 ORH~ -999.2500 OP~l -999.2500 6300.0000 SFLU -38.9687 GR -999.2500 OReO -999.2500 OP~I -999.2500 6200.0000 SPLO -37.6250 GR -999.2500 -999.2500 DPHI -999.2500 6100.0000 SFLU -28.2813 GR -999.2500 DRHO -99'9.2500 OPHi -999.2500 6000.0000 SFLU -43.3125 GR -999.2500 DRH.~ -999.2500 -999.2500 5900.0000 SFLU -26.7158 '-999.2500 DRHO -999.2500 DPHi -999.2500 5800.0000 SFLU -30.812:5 GR -999,2500 -999.2500 -999.2500 570'0.0.000 SFLU -39.8125 GR -999.2500 -999.2500 OPHI -999.2500 4.2092 ILD 35.1875 GR -9'~9.2500 NRAT -999.2500 NCNL 3.491~ iLD :~6.1875 GR -~'~9.2500 NRAT -999.2500 NCNL 3.6719 iLD 103.7500 GR -999.2500 NR4T -'999.2500 NCNL 3.4485 ILD 95.2500 GR -999,2500 NRAT -999.2500 NCNL 2,1341 iLO 105.9375 GR -999.2500 NRAT -999.2500 NCNL 3.4086 iLD 95.6250 GR -999.2500 NRAT -999.2500 NCNk 2.2185 iLD iZ3.4375 GR -999,2500 NRAT -999,2500 NCNL 1.7675 ILD 105.7500 GR -999.2500 NRAT -999.2500 NCNL 2.9361 ILD 118.0000 GR -99~.2500 NRAT -999.2500 NCNL 3.5364 -'999.2500 -999.2500 -999.2500 3.3294 -999.25~0 -9'99.2500 -999.2500 3.8519 -999.2500 -9~9.2500 -999.2500 3.6215 -999.2500 -999.2500 -999,2500 2.6642 -999.2500 -999.2500 -999.2500 3.6704 -999.2500 -999.2500 -999.2500 2.3605 -999.2:500 -999.2500 -999.2500 1.9113 -9~9.2500 -999.2500 -999.2500 3.4000 -999.2500 -~99.2500 -999.2500 !LN CALl RNRA FCNL ILM CALl RNRA FCNL ILM CALl RNRA FCNL ILM CALl RNRA FCNL !LM CALl RNRA FCNL ILM CALl RNRA FCNL ILM CALI RNRA ~CNL iLM CALl RNRA FCNL ILM CALl RNRA RCNL 3.7800 -999.2500 -999.2500 -999.2500 3.4938 -999.2500 -999.2500 -999.2500 3.8165 -999.2500 -999.2500 -999.2500 3.5964 -999.2500 -999.2500 -999.2500 2.6415 -999.2500 -999.2500 -999.2500 ~.6444 -999.2500 -999.2500 -999.2500 2.2924 -999.2500 -999.2500 -999.2500 1.9067 -999,2500 -999.2500 -999.2500 3.3507 -999.2500 -999.2500 -999.2500 .V? OlO.M02 VEriFiCaTION LiSTiNG PaGE 7 ]EPT 3600,0000 SFLO ~P -34,7813 GR ~< rig ~ -999,2500 DRHC qPHI -999,2500 DPHi ;R -999,2500 3EPT 5500,0000 SFLU SP -36,0625 GR EH08 -999,2500 DRHO ~P~I -999,2500 DPM! 3R -999,2500 ]EPT 5400.0000 SFLU SP -39.0313 GR RHOS -999.2500 DRHO NPHi -999.2500 DPHi GR -999,2500 DEPT 5300.0000 $~LU SP -57.3313 GR RHOB -999.2300 DRH~ NPHI -999.2500 DPHI GR -999,2500 DEPT 5200.0000 SFLU SP -36.8750 GR RHOB -999.2500 DRNG NPHI -999.2500 DPNi GR -999:.2500 DEPT 5100,0000 SFLU SP -36,0313 GR RH08 -999,2500 DR~D NPHI' -999,2500 DPHi GR -999.2500 DEPT 5000.0000 S~LO SP -41,5938 GR RHDB -999,2500 DRr~O NPHi -999,2500 DPHI GR -999.2500 OEPT 4900.0000 SFLU SP -4~.7813 GR RHO8 -99'9.2500 DRHD NPHi -999.2500 OPHi GR -999.2500 DEPT 4800.0000 SFLU SP -43.0313 GR RHOB -999,2500 DRHO NPHi -999,2500 DPHI GR -999.2500 2,$611 iLD 124,3125 -999,2500 NR~T -999,2500 NCNL 1.8038 iLO 132.8730 GA -9~9.2500 NRAT -999.2500 NCNL 3,9578 iLO 142,2500 GR -999,2500 NRAT -999,2300 NCNL 3.4976 ILO 123.0625 GR -999.2500 NRAT -999.2500 NCNL 2,4818 ILD 152,6250 GR -9'99,2500 NRAT -999.2500 NCNL 2,8563 iLD 67,6875 GR -9'99,2500 NRAT -999.2500 NCNL 2,1427 ILO 104,8'750 GR -999.2500 NRAT -999,2500 NCNL 0.9854 ILO 95.8750 GR -99'9.2500 NRAT -9~9.2500 NCNL 3.3715 ILD 100.4375 GR -999.2500 NRAT ,-999.2500 NCNL 2.6935 -999.2500 -999.2500 -999.2500 2.4010 -9~9.2500 -99~,2300 -999.2500 4.1393 -999.2500 -999.2500 -999.2500 4,1821 -999,2500 -999,2500 -999,2500 2.8558 -999.2500 -999-2500 -999.2500 2,7464 -999,2500 -999,2500 -9'99,2500 2.3959 -999.2500 -999.2500 -999.2500 1,0054 -999,2500 -999,2500 -999,2.500 3,4911 -999,2500 -999,2500 -999,2500 iLM CALl RNRA FCNL =LM CALl RNRA FCNL ILM CALl RNRA FCNL ILM CALl RNRA FCNL ILM CALl RNR. 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