The URL can be used to link to this page

Home My WebLink About204-172VTL 4/10/20 DSR-4/9/2020 THE STATE ALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E -114L1 Permit to Drill Number: 204-172 Sundry Number: 319-527 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, \6gA— Q- Jeremy�M. Price Chair DATED this +day of November, 2019. 113pMS ��NOV 2 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.28n NOV 15 2019 A®GCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate [7] - Other Stimulate❑ Pull Tubing E] Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE TRTMfl 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service Q • 204-172 ' 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23223-60-00 ' 7. If perforating: B. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 1,1 KRU 1 E-1141_1 " 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25651 Kuparuk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 11,841' 3,611' 11841 3611 1500psi NONE 8261 Casing Length Size MD ND Burst Collapse Conductor 77' 20" 108' 108' Surface 4,168' 103/4 4,198' 2,296' Production 7,839' 7518 1 7,866' 3,725' Liner 3,287' - 41/2 11,808' 3,609' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7802-11243, 11522.11767 3562-3592, 3594-3607 4.500" L-80 7,446' Packers and SSSV Type: ackers and SSSV MD (ft) and ND (ft): ZXP LINER TOP PACKER T7414 MD and 3478 ND ZXP LINER TOP PACKER 732 MD and 3548 ND HRD ZXP LINER TOP PACKER 70 MD and 3697 ND 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for 12/1/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG O ' GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce John Peirce Contact Name: Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com r� / i Authorized Signature: Ij,/ - " 2 i .t 4/y� Contact Phone: (907) 265-6471 � xr Date: l - COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: p trft�+ {,f'�/,/, fr Post Initial Injection MIT Req'd? Yes ❑ No ❑ ��DMS �- NOV 2 1 2019 ��/ Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 '— 'l l APPROVED BY Approved by: � � � COMMISSIONER THE COMMISSION Date: ` t m Y= #r( iv (' PPiO PPI IS.L7�'d df 'thN adi f yv1`/ rnn.nd ..,/// ' N! menta in Form and For 90 evised 4/ 0 ] A Vada IICah00 is I f T f th a Of epprOval. attachments in Duplicate I'Tubing Head nasv.+t X4AIT' Shoe, .Ma a MD, 2293WD I iu uM�m iwm / N IoM Wine ¢Y MD. ball A)a-911se a 0 osi.3A7,alx'i -- a.agSmlWmMec.leape am -ID I-� Tuan9ew1w114-1Y �— oRnnmg prime •ohmage Allgnnwnt or LEM PofXNeltlmmgeollel Mmoebs Como I.owde, sal goo.1 We. e\ I..W -Led'm Jade'. inraow \W.1-anvopwu W \ obst-1 ng Dlvene. Seal Bine For use. Interim - ME' to \ Landon SUI Memory 11" Sed De Sedam Tubing. Special Drat 522' MD. 521' TVD• 10.8 it.. -DB Nlppla, 3.315" profile 4477' MD. 2593'WD, 193 aeg -GLM. Cameo 1"KBa-2 TWO' MD, 0589' TVD, T1.9 deg - GLM, Cenwo 1" KBG4 A70'MD-Se 89'ND, 75Adeg- CMDS11ding Sleeve,a1S.91 T` Mlp,w Lw -w Enay Md.k ddQ Orim=M Flex' D.and window a11a95' MD ConoCOrlIII ps "Kno. West Sak 7-5/8" Injector BA -ORT -1, 1E-114 FINAL - AS COMPLETED Tri -Lateral Completion CONFIDENTIAL 4-1a" Casing Shoe, 12.6#, LA0 DWC Satellites' MC,M,10'TVD tan'. E—hoo IHLEM ofles" pooh ose o`/�w1.a..1�� a-to^ca.mg 9nce.taex,LAe Dwc Sen a 11808' MD, Sall' WD late )IB'MO.00-a-n Line egy s« -dud iom .ay oe- Sed M 3WE to 'Ae Sand nd ala Ina Lateral 7408" casing Shoe Set ate BMG' MD, 9725' We Fauioment Swelficatlons 41/T' X 7-518" HOOK Hanger Ma beh,. t aA:^ MemMn one with alwna I�Ixa Dna, as thunder or LEM: Su' We.Y D., M about, ao LEM: SAP ' nalerMadnbon MvndvoO: baa' 4172" Lateral EMry Module Memeele D d, Less- D.. IIPD.. wl h.aatm.M.w: Eger Latera Dap .fall dMrtre aeP Do of..He, and .— ysP Dustier and Mews Lges:.1. nA' 4th" Casing Ends, 12.09. Lao DWC Sat Q 11856' Mo, Was' TVD ad so, swased need Onvoin a— ose o`/�w1.a..1�� a-to^ca.mg 9nce.taex,LAe Dwc Sen a 11808' MD, Sall' WD late )IB'MO.00-a-n Line egy s« -dud iom .ay oe- Sed M 3WE to 'Ae Sand nd ala Ina Lateral 7408" casing Shoe Set ate BMG' MD, 9725' We Fauioment Swelficatlons 41/T' X 7-518" HOOK Hanger Ma beh,. t aA:^ MemMn one with alwna I�Ixa Dna, as thunder or LEM: Su' We.Y D., M about, ao LEM: SAP ' nalerMadnbon MvndvoO: baa' 4172" Lateral EMry Module Memeele D d, Less- D.. IIPD.. wl h.aatm.M.w: Eger Latera Dap .fall dMrtre aeP Do of..He, and .— ysP Dustier and Mews Lges:.1. nA' 4th" Casing Ends, 12.09. Lao DWC Sat Q 11856' Mo, Was' TVD t; KUP INJ WELLNAME 1E-114 WELLBORE 1E-114 Conocort n� tII11pS Well Attributes Max Angle & MD TD FName I WeIIMre SINus dl^I MOIXKeI /+ct 9hn lXKB1 Kaska, lInc.. re.,Welltnre APYOW Rnroma9npnn c n c •n n 1E-114,11/IA49181221p9PM Last Tag .. cm nenic (aced, Annobtion Cep1M1 (qKB) End Data Weldho,e feel Mord BY ................................................................ HANGER; v.z Last Tag: 1E-114 ImoffiOr corvouciov; 31 URGED NIPPLE; EB.3 6UR.E ZERA19]]- GP61JR:4.4]BB Gqs OFT: ].0asm SLEEM C T,sadC LOCATOp;],at90 SOCA66r,],419.]. Iso�5leEve, 7,457.1 wwoow a 7.05 7417/.0 LINER tY ],4a,?1 Te W.9 D LINER LEM: ],414.1-],7631 WbOOW IVERTE0.7.]80 LII; 7TTR 7kgP sto7s; 7,Iman.z4s.o- LINER u; 7 nEER I.me.4 (PERF. s.1EB.DE,161.0- B LINER LEM', 7,]324$81]8 PpOoucrlorv: 36.8d,]36.0� sto7s', 67n.0e,em0- smr6; e,o27.09,a38.o smrs; e,lm.o9.4w.o� sLois: 5.5]6.0.9,6L0�1 smTs; esoealo,lm.0- SLOT$1atB10.10.956.0� SLOTS, 10,4Cs 105EMD SLOTS: stars; mBnalo,em.o_ SLOTS, 1a7C30.10,7420_ sm7S; 10,e0s.0-11ensa SLOTS: 1t3z1.01f.as4.o� SLmptlp6ot1,7w.o-- LINER: EMETS-11,651�� Last Rev Reason Annotation End Data wenEore Wt Moe ey LU REV REASON; PULL EVD-TRIEVE PG 41142016 tE-114 GT4 Casing Strings edema Deecnpnon DO (In, ID(in)77-PT.lcB) sN Depb lrLKa) 6a10ePt INp1... wtlLan p_ Grade Top Thread CONDUCTOR 20 1912..TOLD 1080 9400 K55 WELDED Casing Description OD (Int ID I(a) 'PINKBI SN CeptM1 (IIKBI GN Depth (I W11Lan 9... Gfeda Top TM1read SURFACE 10314 10.05 29.9 41973 2,296.4 40.50 LA0 BTC Corning DeamllNbn OD (m) II Top MUST Set Depth Man) sat Down IMO)...NryLen p... Grede Top Them WINDOWLI 7.65 6.63 3,]]8.0 7,19,.0 3,559.4 29]0 L-80 BTC -M CIES, Description 00(TO ID gn) Top 111KB) SN Cep111111KB1 BH Depth ITV01... WLLen 6... Grade Top TM1reed WINDOW L2 )518 6.63 3,485.0 ],47'O 3,4923 CUInq Dnxrlptbn OD gni ID (in) Top IflKB) Se[pepN(Us) Set DepthIND)... WOLen p...GMe Top TM1r¢etl PRODUCTION ]5M 6.87 26.9 8,]36.0 3,]25.2 29.]0 L-80 BTCM Casing RLEI non OD lin) IDIin) To (MB) set Depth MKB) Set Depth(TVDd. WIILen(I DLINER LEM 4112 3.96 ],414.1 ],]632 3,5540 12.60 Grade Top TM1rcad L-80 IBT Liner Details -'- - xominal m Top(nn0) Top "Or Top mel 7) Irem Des Core (in) 3,414.1 3,478.5 77,13 PACKER Z P LINER TOP PACKER -4.960 7,433.1 3,482.] 7).29 SBE 10947 SEAL BORE RECEPTICLE 4.]50 7,451.9 3,486.8 77.45 XO BUSHING CROSSOVER BUSHING 3.930 7,457,1 3,4880 77.50 HANGER LEM ABOV HOOK HANGER 3.930 ],463.2 3,488.3 A.50 HANGER LSol ". HOOK HANGER 3.688 ],]600 3,5533 7804 SEAL ASBV BAKER SEAL ASSEMBLY 3.890 Casing Deacnpnom 00 In) ID (in) Top MKS) Set DeptM1 RKB) Set Depb(TV[S. WNzn S-6rade B LINER LEM 412 3.9fi ],]324 8,61].9 3,705.1 12.60 Top Tnnead L$0 IBT Liner Details xom ml ID Top MOST Top(LoTd MN.) Top mal•1 tem Des Core (in) ],]32.4 3,5475 7).66 PACKER ZXP LINER TOP PACKER 4.960 ],]51.4 3,551.5 1/SO SHE 10947 SEAL BORE RECEPTICLE 4250 ],7]0.3 3,555.5VXO BUSHING CROSSOVER BUSHING 3930 ),AU 3,5558 SWIVEL BAKER CASING SWIVEL 3.920 7,]]8.0 3,557.0 HANGERI LEM ABOVE HOOK HANGER 3.930 7,784.1 3,558.3 HANGER2 LEM INSIDE HOOK HANGER 3.688 7,849.7 3,570.6 NIPPLE CAMCO DBS NIPPLE 3.562 8,614.6 3,)04.5 SEAL ASSY BAKER SEALABSEMBLV 3.890 Casing Description ODgn)Top lflKBl Set pepb lflKB) SN Oepb IN01_. W11Len IL.. Grace iop TM1teetl LINER 41/28,569.5 11,856.2 3,7882 12.60 L-80 DWC Liner Details .., ,. . Top IflKB) Top ITV01 (flKBI Tap lnd l•) Ifem OeaCom Nominal lD (in)8,5695 3,696.6 79.89 PACKER HRD ZXP LINER TOP PACKER 5.500 8,588.6 3,6999 79.90 NIPPLE IRS PACKOFF SEAL NIPPLE 3.958 8,591.4 3,7004 7989 IHANGER IFLEXLOCK LINER HANGER 5.500 8,601.2 3,]02.1 ]9.87 SHE 19047 CASING SEAL3OR -EXTENSION 4]50 11,822.9 3)848 I 8426 1 BUSHING BAKER DRILLABLE PACKOFF BUSHING 3.958 Tubing Strings Tome oaami tion ET!,, Me... ID p 1 Pt IND) I... wt P (int Top l%KB) Se[Deb n..Set DeM1 (NM Grade Top Connecfion TUBING 412 396 22.2 7,44fi.3 3,485.6 12.60 L-80 IBTM Completion Details ToPIND) Topmnt Ixommal Top(nnel MKIN r) I nem Dee Co. wgn) 22.2 222 0.00 MANGER VETCO GRAY TUBING HANGER 3958 522.3 520.9 10]8 NIPPLE GAMCO DB -6 NIPPLE wMO GO PROFILE 3.875 7,370.0 3,468.6 7675 SLEEVE -C BAKER CMU SLIDING SLEEVE- CLOSED 111112004 3.810 ],4180 3,479.4 77.16 LOCATOR BAKER LOCATOR 3875 ],419] 3,479.8 77.18 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.675 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc) iap INNS Top(ND) rCp lnnl 1 (qHB) (°) pas Com pun Data 10 gn) ],45].1 3468.0 77.50 ISPSLEEVE TYPE -II ISOLATION SLEEVE ACROSS DSAND LEM 4I15I2016 2.]50 ],7]8.0 3,55>.0 )8.31 DIVERTER TYPE -I DIVERTER SET IN B -SAND LEM 4/14/2018 3.000 Perforations & Slots Sot Dene TOP (eKBI Btm RICO ToIXI(IND) Bmf BDI LInkM Zone p IaM1OWX ) Com 8,1880 893.0 3,630.4 3,631.3 WS A4, E- 72312012 PERFedre ,1Pe abatis loinjectCrysta 114L1 Seal R 8 LINER FAILEDI 8,781.0 89030 3,731.4 3,743.8 WS A2, 1E-114 10162004 400 SLOTS ANemating solidlepare pipe -0.125'k S"@4 Circumferential adjacent rows, 3- centers staggered 18 deg, 3' non-slwted ends 9,027.0 9,089.0 3,753.0 3,756.2 AS A2, 1E-114 10/812000 40.0 SLOTS 9,120.0 9,450.0 3,]5].0 3,751.1 WS A2, 1E-114 10182000 40.0 SLOTS 11 9,5)6.0 9,6fi00 3,]41.3 3)342 WB A$1E-114 1016121,4 40.0 SLOTS 9,809.0 10,160.0 3,]35.8 3,7520 WS A31E-114 1W82604 400 SLOTS 14191.0 10,358.0 3,754.0 3762.8 WS A2, 1E-114 101&2004 4010 SLOTS 10,482.0 10,5240 3,]68.3 3)69.3 WS A2, 1E-114 10I8I2004 40.0 SL TS 14555.0 10,59].0 37696 3,)69.3 WS A2, 1E-114 1101.2004 40.0 SLOTS Proposed 1E-1141-1 to 1E-1681-1 RPPG B MBE Treatment 1 E-1 14L Tri-Lat injector has 4.5" L-80 tubing & slotted liners set in West Sak D, B, and A sands. An at43c occurred 3/20/06 in 1E-1141-1 to producer 1E-1681-1. A 4/12/06 IPROF in 1E-1141-1 found B MBE at 8690' RKB where all PWI exited the liner. An IBP intended for set in A Lat in preparation for a B MBE treatment inadvertently entered & set in B Lat (without B Diverter), then became a fish —400' above B MBE that we could not pull. Attempts were made to seal the open B MBE by trying to pump treatments around the IBP fish. Molten wax was pumped down CT 10/10/10 from above IBP fish, then CT pumped Crystal Seal treatment on 7/27/12 from B Lat window because CT could not pass through B Diverter. Both of these MBE treatment attempts failed most likely due to poor access to pump to the MBE and due to the relatively small treatment volumes that were pumped. The IBP fish was eventually POOH on 7/10/17 using CT hydroshock tool to free it, then a Plug was set in the main -bore between B & D Lats to put 1E-1141-2 D Lat on PWI until the Plug was pulled 4/18/18 to reconfigure 1 E-114 to current configuration with a B Diverter set, and a D Iso-SIv set. Due to inability to successfully drift a Plug by the B Lat window, the A Lat has been left open. Efforts to set Plugs in the A Lat continue to result in apparent entry into the B Lat without a B Diverter set. It is now proposed that a fullbore RPPG treatment be pumped to seal the B MBE at 8690' RKB. Procedure: Coil Tubing 1) RIH with Perf Gun & shoot a 5' CAL of perforations in 1 E-1141-1 B Lat slotted liner at 8690 - 8695' RKB, at 6 spf, 60 deg ph, to enable RPPG slurry to enter B MBE. POOH w/gun. Verify ASF. RD CT. Pumping 2) At —12 hours before RPPG B MBE treatment, place 1E-1141-1 on PWI at 1000 BWPD to displace gas head and Diesel FP from tubing to open B MBE at 8690' RKB, and to lower WHP on tubing. MIRU mixing van and pumping equipment on 1 E-114. When ready to pump RPPG job, SI 1 E-1141-1 and verify that 1 E-168 offset producer to open B MBE is also SI, then begin fullbore RPPG treatment: a) 133 bbls of Lead ultraclean 2% KCL Brine at 1 to 4 bpm (depending on bpm needed to let the pump keep up with the apparent Vac rate), to displace remaining gas & Diesel from wellbore to open MBE and to flush all PWI (with any residual hydrocarbons) away, followed by b) RPPG slurry mixed in ultraclean 2% KCL Brine at a steady rate within the range of 1.5 - 3.0 bpm. Slurry will be mixed into Brine to keep —0.75 lbs/gal concentration while making slurry 'on -the -fly'. c) Continue pumping steady rate & slurry concentration until WHIP reaches 500 psi, then determine when to call Flush based on monitoring rate of increasing WHP as RPPG seals MBE, then d) Call Flush and swap to 82 bbls of 2% KCL Brine displacement pumped down tubing at the same established constant rate (to continue monitoring WHP build at constant rate), followed by e) 51 bbls Diesel FP / displacement at the established constant rate, followed by Shutdown Wait 48 hours for swollen RPPG particles to fully crosslink in B MBE to form a continuous stout amalgamated non -flowing gel plug in the B MBE, before returning 1 E-114 and 1 E-168 to service. 20 41 7 WELL LOG TRANSMITTAL#904786454 29295 To: Alaska Oil and Gas Conservation Comm. June 4, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 0 8 2818 RE: Injection Profile : 1E-114 Ll AOGCC Run Date: 4/16/2018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: FannySari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 g� $ FRS_ANC@halliburton.com 1E-114 L1 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23223-00 Injection Profile Log 1 Color Log 50-029-23223-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 SCANNED -.JUN 1 8 2.0r6 Office: 907-275-2605 FRS_ANC@halliburton.com lDate: OLP/I�/ Signed: IRO . Image Project Well History File Cover Page . XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 ~- j 7 d.. Well History File Identifier Organizing (done) t!fwo-sided 1111111111111111111 o Rescan Needed 111111111111111111I RE~AN ~olor Items: o Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: D Other:: BY: ~ Date: uf 30 þh Isl mF Project Proofing 11111111111I1111111 BY: ~ Datellj<--;¡ö I 0 ~ d- x 30 =100 151 ~ Scanning Preparation BY: Date: + Já = TOTAL PAGES bd- (Count does not include cover sheet) 151 Production Scanning Stage 1 Page Count from Scanned File: ¥- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES BY: (;Mari0 Date: ( t /30 lob Stage 1 If NO in stage 1, page(s) discrepancies were found: YES II 1/1111111I1111111 NO 151 (V\ f NO BY: Maria Date: 151 1IIII1I111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • STATE OF ALASKA AIWA OIL AND GAS CONSERVATION COMMSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon fl Repair w ell r Rug Ftrrforations r Perforate r Other Crystal Seal P Tubing Treatment Alter Casing r g � Stimulate - Frac r Waiv r Time Extensio j-° Change Approved Program r Operat. Shutdow n r Stimulate - Other r' Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204 -172 3. Address: 6. API Number: — P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50 029 - 23223 - 60 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25651 1E " 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11841 feet Plugs (measured) None true vertical 3611 feet Junk (measured) 8261 Effective Depth measured 11823 feet Packer (measured) none true vertical 3609 feet (true vertucal) none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108 108 SURFACE 4197 10.75 4198 2295 PRODUCTION 8736 7.625 8736 3725 LINER L1 4032 4.5 11808 3609 RECEIVED i Perforation depth: Measured depth: slotted liner 7802' 11522' - 11767 True Vertical Depth: 3561' 3591', 3594' - 3607' AUG 2 2 2012 Tubing (size, grade, MD, and TVD) 4.5, L - 80, 7446 MD, 3486 TVD Packers & SSSV (type, MD, and TVD) no packers NIPPLE - CAMCO DB -6 NIPPLE @ 522 MD and 521 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 7779' Treatment descriptions including volumes used and final pressure: 1320# of 4MM crystal seal 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 1693 Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service pi Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR `" WINJ r WAG ' GINJ SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -336 Contact John Peirce ( 265 -6471 Printed Name John Peirce Title Wells Engineer Signature � Phone: 265 -6471 Date g l Zl /1 a t..4.... G ''sue DMS AUG 2 3 2012 (. Z3. IL ' Form 10 -404 Revised 11/2011 fi ,fl l /601j Submit Original Only 1E-114 and 1E-114L1 C rystal Seal Treat t DATE SUMMARY 6/3/12 PERFORMED FLUFF AND SOF TO 11,855' CTMD. HIT HARD TAG. WASHED ACROSS "LEMS" AND "GLMS" AT 30 FEET PER MINUTE. FREEZE PROTECTED TO 2500' TVD. JOB COMPLETE. BLOW DOWN POP OFF AND SECURE WELL. JOB IN PROGRESS. 6/4/12 SET 2.13" OD IBP AT 8500' IN THE A- LATERAL. RUNNING TOOL SHEARED AT 2850 PSI. TAGGED IBP AT 8500.7' CTMD. SET DOWN 2000 POUNDS CONFIRMED PLUG SET. POOH JOB IN PROGRESS. 6/6/12 RIH TO PULL ISO SLEEVE AT 7780' CTMD, 15 JARLICKS AND IT CAME FREE, RIH TO PULL IBP IN "B" LATERAL, UNABLE TO ENTER THE "B" LATERAL WITHOUT A DIVERTER AFTER MULTIPLE ATTEMPTS, POOH, F/P CT AND TUBING, JOB IN PROGRESS 6/7/12 RIH AND SET B LATERAL DIVERTER AT 7798' CTMD, RIH AND SET TYPE 2 ISOLATION SLEEVE FOR THE D LATERAL AT 7479' CTMD, RIH LATCHED INTO IBP AT 8262' CTMD, PULLED IBP 3' UPHOLE, UNABLE TO GET DOWN MOVEMENT, F/P CT AND TUBING WHILE POOH, JOB IN PROGRESS 6/8/12 PERFORMED BOP TEST, RIH WITH FISHING BHA #1, UNABLE TO MAKE IT THROUGH THE B LEM DIVERTER, POOH AND DROP WT BARS AND INTINSIFIER, RIH AND LATCHED INTO THE IBP AT 8248' CTMD, 28 JARLICKS UP /10 JARLICKS DOWN WITH NO INDICATION OF MOVEMENT FROM THE IBP, PUMP OFF, F/P CT AND TUBING WHILE POOH, JOB IN PROGRESS 7/23/12 PERFORATED LINER FROM 8188' TO 8193' CTMD. UNABLE TO SHIFT OPEN CIRC SUB. PULLED OUT OF HOLE TO SURFACE. RECOVERED BALL IN REEL SWIVEL ON SURFACE. WELL FREEZE PROTECTED. JOB IN PROGRESS. 7/24/12 ATTEMPTED TO PUMP CRYSTAL SEAL. UNABLE TO PENETRATE THROUGH DIVERTER 7778' . DECIDED TO RESET MECHANICAL ZONAL MODIFICATIONS. PERFORMED BOPE TEST WHILE WAITING ON BOT. PULLED ISOLATION SLEEVE. WELL LEFT FREEZE PROTECTED. JOB IN PROGRESS. 7/25/12 RESET DIVERTER IN B -LEM AT 7797.5' CTMD. ATTEMPTED TO DRIFT WITH WAX NOZZLE BHA. MADE SEVERAL ATTEMPTS TO PASS THROUGH DIVERTER WITHOUT SUCCESS. CHANGED OUT BHA AND ATTEMPTED TO PASS THROUGH DIVERTER MULTIPLE TIMES WITHOUT SUCCESS. WELL FREEZE PROTECTED. JOB IN PROGRESS. 7/26/12 PULLED DIVERTER FROM B -LEM AT 7778'. ATTEMTPED TO ENTER ORIENTER WITH 1.5 DEGREE BENT SUB INTO B -LEM WITHOUT SUCCESS. RAN NEW TYPE 1 DIVERTER (2.75" ID) AND SET IN B -LEM AT 7796' CTMD. WELL FREEZE PROTECTED. JOB IN PROGRESS. 7/27/12 SET DIVERTER AT 7779' CTMD. MADE SEVERAL ATTEMPTS TO ENTER LEM WITHOUT SUCCESS. PUMPED 1320 POUNDS OF 4 MM MESH CRYSTAL SEAL. PUH TO SAFETY AT 4200' AND SQUEEZED 8 BBLS INTO MBE. WELL FREEZE PROTECTED, KUP 10 1E-114L1 ConocoPhillips g Well Attributes Max Angle & MD TD AldSka 1410 Wel!bore API /UWI Field Name Well Status Ind (°) MD (ftKB) Act Btm (ftKB) p,,,,L.,ti taps 500292322360 WESTSAK INJ 91,42 8,145.73 12,455.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date SSSV: NIPPLE Last WO: 31.52 10/26/2004 Well Coned: - 1E- 11411, 8/18/201211'14:03 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date - -- Last Tag: Rev Reason: ADD DIVERTER ninam 8/18/2012 HANGER, 22 i ° � Ataill r Casinz Strin•s I ' Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER L1 4 1/2 3.958 7,776.9 11,808.4 3,609.2 12.60 L-80 DWC CONDUCTOR. Liner Details 31 -108 Top Depth NIPPLE, 522 (TVD) Top Ind Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 7,776.9 3,556.8 78.28 HANGER B-SAND BAKER MODEL B1 FLANGED HOOK HANGER 4.500 SURFACE, J L 11,770.1 3,607.0 86.76 BUSHING B-SAND DRILLABLE PACK -OFF BUSHING 3.958 30 - 4,198 11,786.7 3,607.9 86.76 XO Reducing CROSSOVER 4.5 x 3.5 3.500 GAS LIFT, 4477 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT, _ Top Depth 7,070 (TVD) Top Inc! SLEEVE -C, Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 7.370 - 8,261 3,570.1 89.05 FISH 3" BAKER IBP @ 8261' CTMD IN B LATERAL 10/1/2010 0.000 LOCATOR. 7418 . Perforations & Slots SEAL ASSY 7,420 , Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (RKB) Zone Date (sh Type Comment 7,802 11,243 3,561.3 3,590.6 WS B, 1E -114L1 10/15/2004 40.0 SLOTS Alternating solid/slotted pipe - WINDOW L2, 0.125 "02.5" @ 4 circumferential 7,465 - 7,477 1 1 adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends r 11,522 11,767 3,593.9 3,606.8 WS B, 1E -114L1 10/15/2004 40.0 SLOTS D LINER LEM, 7414 -7,7x3 . � Notes: General & Safety End Date Annotation DIVERTER, 10/26/2004 NOTE: TRI LATERAL WELL 1E - 114 (A - SAND) 1E - 114L1 (B - SAND) 1E - 114L2 (D 7,779 W l il INDOW 11, 2/16/2011 NOTE: View Schematic w/ Alaska Schematic9.0REV 7,778 -7,790 SLEEVE, 7,784 °' 11 FISH, LEM, E61 B LINER • 7,732-8,618 18 PRODUCTION. D2CTIN, 27A.736 SLOTS, 7,802- 11,243 Mandrel Details Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run Ste Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type On) (p61) Run Date Corn... 1 4,476.9 2,398.3 70.08 CAMCO KBG-2 1 GAS LIFT DMY BK -5 0.000 0.0 4/3/2005 2 7,069.9 3,389.5 71.87 CAMCO KBG-2 1 GAS LIFT DMY BK -5 0.000 0.0 4/3/2005 SLOTS, 11,522- 11,767 LINER 11. 7,777. 11,608 TD (10- 114L1). 12,455 • • SMITE AILASEn EL SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John Peirce Wells Engineer 4 Al ConocoPhillips Alaska, Inc. w / P.O. Box 100360 I 172 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1E-114L1 Sundry Number: 311 -336 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 2 day of November, 2011. Encl. Ak TATE OF ALASKA PI\Veti • RECEIVED ALASKA OIL AN�AS CONSERVATION COMMISSION �� 2011 . APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 �� fl�l � � � 1. Type of Request: Abandon f Plug for Redrill r Perforate New Pool r Repair w ell r an ge O1r f 'ifllli Sion Suspend f Plug Perforations j"` Perforate f Pull Tubing r A PriitnEfetfision r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: Crystal Seal Treament F 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204 - 172 3. Address: Stratigraphic r Service p' 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 23223 - 60 ' 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 Required? Yes r No gr. 1E -114L1 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25651 • Kuparuk River Field / West Sak Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11841 . 3611 ^ 11823' 3609' 8261' Casing Length Size MD TVD Burst Collapse CONDUCTOR 108 20 108' 108' SURFACE 4197 10.75 4198' 2295' INTERMEDIATE 8736 7.65 8736' 3725' LINER L1 4032 4.5 11808' 3609' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner 7802 - 11767 3561 - 3607 4.5 L - 7446 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) no packer NIPPLE - CAMCO DB -6 NIPPLE MD =522 TVD= 521 12. Attachments: Description Summary of Proposal ' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory E Development r Service • 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/11/2011 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG 1✓ " Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Printed Name John Peirce Title: Wells Engineer Signature % it7.7 . Phone: 265 -6471 Date 1 O(31I� i 4 .----....„ ‘ Commission Use Only r�� Sundry Number:31- 3�j 1 , Conditions of approval: Notify Commission so that a representative may witness v i`� Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: /6 `1 l APPROVED BY ) I Approved by: I / COMMISSIONER THE COMMISSION Date: l ( 12- Form 10 -403 I 0 ev 03 ( Submit in Duplicate ,1t ' a �, *UP 01 E-11 4L1 C��Camim 1 ' Well Attributes Max Angle & MD _TD Ala T6 ,: Wellbore APUUWI F m eld Nae Well Status Ind () MD (ftKB) Act Btm (ftKB) c ar+oc�Mha6u'o 500292322360 j WEST SAK __ INJ __ 91A2 J 8,145.73 12 455 0 ' Comment H25 (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date SSSV 31.52 10/26/2004 wen Gonvg 1€ t 1411, 5136/281 t 1 1.38.03 AM NIPPLE Last WO: 31 Schemazc Aqubl .. A notatron Depth (ftKB) (End n Dale (Anotation Last Mod ...End Date Last Tag: 1 1 Rev Reason _ Pull Type II Iso, Set Type I Iso mnam 5/21/2011 — HANGEP.22— --+! "`i1 -- - - - — Casing Strings ""r 1 1 , . . . . Casing Description String 0... String ID ... Top (kKB) Set Depth (f... Set Depth (TVD) ... S Wt.. String ... 'String Top Thrd v LINER L1 'String I 3958 � 7,776.9 I 118084 3,6092__ 1260 L80 DWC Liner Details CONDUCTOR, _ 31 -108 " 1 Top Depth NIPPLE, 522— 1. (ND) Top Intl Nomi... ; Top (MB) (kKB) e) Item Daeription Comment ID (in) 7,776.9 3,556.8 78.28 HANGER B -SAND BAKER MODEL B1 FLANGED HOOK HANGER 4.500 SURFACE,_ "G ` 11,770.1 3,607.0 86.76 BUSHING 8 -SAND ORILLABE PACK -OFF BUSHING 3.958 30 1,196 11,786 7 3,607.9 86.76 XO Reducing CROSSOVER 45 8 35 3.500 GAS LIFT._ ......___ , x•477 allE Other In Hole jWireline retrievable lu s, valves, fish,etc- P 9 pumps, 1 GAS LIFT, 91118111182 Top Depth 7,070 .MO: (TVD) Top Incl SLEEVE-C,_ ____ T .. NUM) 0 Desc p tion Comment Run Date ID (in) 7,370 al�ern. 8,261 3,570.1 89.05 FISH 3" BAKER IBP @ 8261' CTMD IN B- LATERAL 10/1/2010 0.000 LOCATOR. 7,-716,_ .— Alt Perforations SEAL ASSV __ f' Shot Top (5190) Btm (TVD) Dens Top (ft613) Rim (fiK8j (kKB) (8I (B) Zone Date 4 h... Type _ Comment 7,802 11,243 3,561.3 3,590.6 WS B, 1E -114L1 10/15/2004 40.0 SLOTS Altemating solid /slotted pipe - WINDOW L2. 0.125 "x2.5" @ 4 circumferential 7,465 1 1 adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends - =- 11,522 11,767 3,593.9 3,606.8 WS B, 1E -114L1 10/15/2004 40.0 SLOTS D LINER LEM, - - - Y Tax 7,414 -7,763 Notes: s: General & Safety m a #U �� ; End Date Annotation 10/26/2004 NOTE: TRI- LATERAL WELL 1E-114 (A -SAND) 1 E -114L1 (B-SAND) 1E -114L2 (D -SAND) WINDOW LI, 2/16/2011 NOTE: View Schematic w/ Alaska Schematic90 7,778 -7,790 It _ t FISH, 8,261 - 8 LINER LEM, 77 7,732 -8,618 PRODUCTION, 27 -6,736 7,802- 11263 +J Mr .,,,,, Mandrel Details Top Depth Top - -_ —� Port (TVD) Inc! OD valve Latch SW TRO Run Stn Top (HIKBI (kKB) (1 Make Model (!n) Son TyPe Type (!n) (psq Run DM. Com..- -""""" 1 4,476.9 2,358.3 70.08 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 4/3/2005 2 7,069.9 3,389.5 71.87 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 4/3/2005 SLOTS. 11,522 - 11,767 LINER L1, 7,777 - '1,808 TD (1E-114L1), 5 L55 • 1E-114L1 to 1E-168L1 MBE Treatment A matrix bypass event (MBE) occurred 3/20/06 in 1 E -114L1 with breakthrough to 1 E -168L1 producer. A 4/12/06 IPROF in 1E-114L1 found a 'heel' MBE at 8690' RKB behind 4.5" liner. Most PWI appears to exiting the slotted liner at this MBE. We plan to seal the MBE with Crystal Seal. CrystalSeal is a Halliburton product intended for treating injector wells to restore water flood sweep efficiency by remediating direct communication paths through formation to offset producers. CrystalSeal is water swellable dehydrated crosslinked synthetic polymer gel available in various granular mesh sizes. CrystalSeal can swell to 400 times original size by absorbing water. Due to the swellability of CrystalSeal, it is used to fill highly conductive large voids or channels (MBE's) that dominate taking injection. Procedure: Coil Tubing 1) Pull Isolation Sleeve from the B LEM at 7784' MD. 2) Set a Diverter in the B LEM at 7784' MD to enable access to 1 E -114L1 lateral. 3) Set a 2.75" min ID Isolation Sleeve in the D LEM at 7465' MD to isolate the 1 E -114L2 lateral. 4) RIH with BHA on 2 "coil tubing consisting from bottom to top of 5' OAL x 2" OD TCP Perf Gun, a 2 -1/8" OD closed Circ -Sub, and hydraulic disconnect. Park perf gun to fire 6 spf large hole charges at 8188 - 8193' RKB in a 4.5" slotted liner above a stuck IBP located at 8261' MD. Drop ball to fire gun, hen RIH 5' with coil to spot the Circ -Sub over the perf interval. Drop ball #2 to shift Circ -Sub open, then proceed to pump Crystal Seal treatment through Circ -Sub and perfs to seal the MBE. Pump: a) Seawater Pad down coil. Maintain 2.0 bpm rate during treatment through Flush (step g) to monitor treating pressures at constant rate. Swap from Seawater to 2% KCI and pump, b) 2% KCI Water with 0.05 ppg CrystalSeal (4 mm mesh, all stages) down coil. Each stage volume is TBD during pumping based on treating pressures during the stage. c) 2% KCI Water w /0.10 ppg CrystalSeal down CT, or Flush (step g) should we see screen out. d) 2% KCI Water w /0.15 ppg CrystalSeal down CT, or Flush should we see screen out. e) 2% KCI Water w /0.20 ppg CrystalSeal down CT, or Flush should we see screen out. f) 2% KCI Water w/0.25 ppg CrystalSeal down CT, or Flush should we see screen out. g) If screenout occurs, open CT x Tbg annulus to return tank, and pump 1 CT volume of Seawater Flush to displace Crystal Seal Slurry from coil to well while POOH. If screenout indication has not been seen prior to Flush, leave CT x Tbg annulus shut -in and pump 1 full CT volume of Seawater Flush to displace Crystal Seal Slurry from coil to MBE while POOH with CT to D LEM, then swap to 73 bbls of Diesel FP down coil, followed by 1 CT volume ( -40 bbls) of Diesel to displace Diesel FP to tubing and FP CT, followed by SD. RD CTU. Wait 6 hrs before returning 1J-136 to PWI for post- treatment injectivity evaluation. STATE OF ALASKA ALAS41L AND GAS CONSERVATION COMMIS•N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Repair well �, Plug Perforations Stimulate Other � Matrix Bypass After Casing ull Tubing Event A g g � Perforate New Pool � Waiver r Time Extension Change Approved Program Operat. Shutdown Pearf orate Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r— Exploratory 204 -172 3. Address: 6. API Number: Stratigraphic ""` Service �` P. O. Box 100360, Anchorage, Alaska 99510 3 50- 029 - 23223 -60 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25651 1 1 E -1141_1 9. Field /Pool(s): Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 11841 feet Plugs (measured) None true vertical 3611 feet Junk (measured) 8261 Effective Depth measured 11823 feet Packer (measured) 7414, 7732 true vertical 3609 feet (true vertucal) 3479, 3547' Casing Length Size MD TVD Burst Collapse CONDUCTOR 108 20 108 108 SURFACE 4197 10.75 4197 2295 INTERMEDIATE 8736 7.625 8736 3725 LINER L1 4032 4.5 11808 3609 Perforation depth: Measured depth: 7802'- 11243', 11522'- 11767' True Vertical Depth: 3561'- 3591', 3594' -3607' $kANW NOV raS COOS. CM- Alzua Oil Aneh * Tubing (size, grade, MD, and TVD) 4.5, L -80, 7446 MD, 3486 TVD Packers & SSSV (type, MD, and TVD) NIPPLE - CAMCO D13-6 NIPPLE @ 522 MD and 521 TVD PACKER L2 - D -SAND ZXP LINER TOP PACKER @ 7414 MD and 3479 TVD PACKER - B -SAND ZXP LINER TOP PACKER @ 7732 MD and 3547 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 435 Subsequent to operation 564 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory I Development Service Stratigraphic rGSTOR r — Well Status after work: Oil Gas WDSPL Daily Report of Well Operations XXX III WINJ j✓' WAG GINJ "` SUSP �'° SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -110 Contact John W. Peirce (ED 265 -6471 Printed Name John W. Peirce Title Wells Engineer Signature Phone: 265 -6471 Date Z D 1 7 f o Form 10-404 Revised 10/2010 . C MS OCT 2' 9 °4 � lo-tt /� Submit Original Only 1 E -1141-1 Well Work Summary DATE SUMMARY 9/25/10 SET CATCHER ASSY @ 7370' 0 (TOP @ 7351' SLM). PULL DMY VLV @ 0' RKB. IN PROGRESS. 9/26/10 PULLED DMY VLV @ 4477' RKB. SET 1" HES -SPG's @ 4477'& 7070' RKB's. PULL CATCHER ASSY @ 7351' SLM. JOB COMPLETE. 9/30/10 PULL TYPE 1 ISO SLEEVE FROM B LEM @ 7784 RKB,SET IBP @ 7905 CTMD, POH, FP WELL,OOH HYD DISCONNECT PARTED OUT,BALL NOT SEATED ON DISCO, BACK TOMORROW,PLUG NOT SET, 10/1/10 PUSH 2" PIG THRU COIL INSEARCH OF 1/2" BALL, FAILED TO FIND BALL,1 1/2" PIECE OF CMT RECOVERED, PERFORM FSHNG RUN FOR IBP @ 7905 CTMD, UNABLE TO ENGAGE FISH @ 7905, PUSHED FISH TO 8261 TO LATCH, 7 UP JAR LICS & SEVERAL 37K OVER PULLS, FAILED TO FREE IBP, PUMPED OFF, LEFT FISH IN HOLE @ 8261 CTMD, FP WELL, BACK TOMORROW TO RUN DIVERTER & ISO 10/2/10 SET A TYPE 1 DIVERTER IN THE B LEM @ 7784 RKB, SET A TYPE 2 ISO SLEEVE IN THE D LEM @ 7465 RKB, FP, WELL SHUT IN. 10/6/10 PUMP 180 DEG SEAWATER DOWN TBG @ 1 BPM TO PRE -WARM WELL FOR MBE WAX JOB PREP. WSR COVERS 10/6/10 THROUGH 10/9/10. ** *LOOK IN ATTACHMENTS FOR PUMP REPORT * * ** 10/10/10 ATTEMPT TO PLACE NOZZLE AT KNOWN MBE IN B -LAT @ 8690' RKB BUT TAGGED UP @ 8240' CTMD. PUMP 9 BBLS OF 105 DEG MELT POINT WAX W/ 5% VYBAR 260 HARDNER. WELL TO STAY SHUT IN, WELL F/P W/ DIESEL. JOB COMPLETE. / JA 1�.9ft ,_ KUP 1E -114L �y� - - - Ct'�noc(3ilflp s We�A nbutes -- _ — - - a; ongle8 MD _ TD utSk� {F1C W Iibore APUUWI Field Name W II St t- 1 M 1 (o) D (ftK6) Act Btrn (ftK8) 50029232 WESTSAK _ �INJ _ 91.42 _ 8,145.73 124550 Comment H2S(ppm) IDto (Annotation -End Dale KB- Grd(It) Rig Rel se Date SSSV NIPPLE =1 Last WO 31.52 10/26/2004 Well COnhg 1,- 1- �41621013!24707;89A6 PM -- _ _ SchWaoq A41-AL __ Annotation Depth (MB) End Dat Annotat Last Mod BY End Date Last Taq: Rev Reason Divelter B LEM, ISO Siv D LEM _ Imostwr 10/32010 f Casin Strings String OD String ID Set Depth Set Depth (TVD) String � Str J Casing Description Top (NKB) {ftK6) (ftK8) (,,, - To p Thrd CONDUCTOR, - " � LINER 1-7 4 Y2 3.958 7776.0 11,808.0 3,609.1 1 Other In Hole (AII Jewel_ry_ubIF) Run & Retrievable, Ftsh, etc.)_ Top Depth NIPPLE, 522 (TVDI Top Ino1 T Run Date ID in 7,784.0 3,558.2 78.68 SLEEVE B - SAND ISOLATION SLEEVE SET ACROSS "B" LEM 4/1312006 2.580 SURFACE, 4,197 7,784.0 3,558.2 78.68 DIVERTER TYPE I DIVERTER SET IN B -LEM @ 7784' 102/2010 8,261.0 3,570.1 89.05 FISH 3" BAKER IBP @ 8261' CTMD IN B- LATERAL 1011/2010 0.000 8,614.0 3,5725 90A6 SEAL F - NO BAKER SEAL ASSEMBLY 10/17/2004 GAS LIFT. 3.875 - _ _... — _._... _ .... _ -..... _..... 4,4n GAUGE, 4,477 Perforations 8. Slots Shin Top (TVD) Btm (TVD) Dens To jtlK6) 13" (ftK6 (ftKB) _ (ftK6) no _ Date (sh.. Type Comment GAS LIFT, L 7,802.0 11,243.0 3,561.3 3,590.6 WS B, 1E -11411 10115/2004 40.0 IPERF Slotted liner w /2.5"x.125 "slots every 7,070 other joint GAUGE, 7,070 11,522.0 11,767.0 3,593.9 3,6061 WS B, 1E -1141-7 10/15/2004 40.0 IPERF Slotted liner w2.5"x.125 "slots every otherjoint SLEEVE-C, 7 7,370 End Date - Annotation 1026/2004 NOTE: TRI- LATERAL WELL 1 E -114 (A -SAND) 1 E -1 14L7 (B -SAND) 1E -11412 (DSAND) PMXar 1-2, _- 7,414 SEAL, 7,418 SBR L2, 7,433 SHOE, 7,446 — Hanger L2, 7,463 WINDOW 1-2,_ 7,477 PACKER, 7,732 SBR Lt, 7,751 SBR, 7,751 -- Hanger l-1, 7,777 Hanger Ll, 7,784 SLEEVE, 7,784 DIVERTER, _ 7,784 WINDOW Lt, 7,790 FISH, 8, 261 SEAL, 8,614 TERMEDIATE, 8,736 I PERF, — 7,802- 11,243 IPERF, ..,.: 11522-11,767 LINER L1, 11,808 TD(1E- 114L1), 12,455 • • ~~Q~C~ 0~ Q~Q~~{Q /,...M~~.~o~~. John Peirce ~.y Wells Engineer .:~~,"~.. ~.~'~,~.: ,~ I.' ~ `~ 7 ~j ConocoPhillips Alaska, Inc. ~' L ~. ~` v~ P.O. Box 100360 ~, "E Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1E-114L1 Sundry Number: 310-110 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ~~ DATED this day of April, 2010. ' cerely, Daniel T. Seamount, Jr. Chair Encl. ~~~ STATE OF ALASKA ~~A~~ ~~ ALASKl,L AND GAS CONSERVATION COMMISSI APPLICATION FOR SUNDRY APPROVALS APR n ~ 201p 20 AAC 25.280 1. Type of Request: Abandon j"` Plug for Redrill ~°"', Perforate New Pool ~ Repair well~~~tivnr Suspend " Plug Perforations ~ Perforate ~"" Pull Tubing ~"" ime Extension ~"' B ~ Operational Shutdown "` Re-enter Susp. Well ~"" Stimulate Atter casin (~ 9 r Er4fMEit/~ ~A ~ Other: Matrix Bypass Event ~' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development "" Exploratory r 204-172 3. Address: Stratigraphic )~ Serve ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23223-60 ' 7. If perforating, Gosest approach in pools} opened by this operation to nearest property line 8. Well Name and Number. where ownership or landownership changes: Spacing Exception Required? Yes ~ No ~/ 1E-114L1 9. Property Designation: 10. Field/Pool(s): ADL 25651 Kuparuk River Field /West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ff): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11841 3611 11823' 3609' Casing Length Size MD ND Burst Collapse CONDUCTOR 108 20 108' 108' SURFACE 4197 10.75 4197' 2295' INTERMEDIATE 8736' 7.625 g 6' 3725' LINER L1 4032 4.5 11808' 3609' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7802'-11243', 11522'-11767' 3561'-3591', 3594'-3607' 4.5 L-80 7446 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) NIPPLE - CAMCO DB-6 NIPPLE MD= 522 ND= 521 PACKER L2 - D-SAND ZXP LINER TOP PACKER MD= 7414 ND= 3479 PACKER - B-SAND ZXP LINER TOP PACKER MD= 7732 ND= 3547 12. Attachments: Description Summary of Proposal ~` 13. Well Class after proposed work: Detailed Operations Program "' BOP Sketch ~ Exploratory ~'•` Development ~"'~' Service /' 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/10/2010 Oil (""' Gas ~ WDSPL ~ Suspended r 16. Verbal Approval: Date: , WINJ ]~' GINJ ~' WAG ~" Abandoned r Commission Representative: GSTOR SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name John Peirce Title: Wells Engineer Signature ~ .~ Phone: 265-6471 Date ~`I7/~ o '---1 Commis io U nl Sundry Number:~~ O ^,~ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ~ BOP Test "" Mechanical Integrity Test ~°` Location Cl earance ~'' Other: Subsequent Form Required: ~ Q , Y ~ APPROVED BY ~~ ~ ~/ !\ Approved by: COMMISSIONER THE COMMISSION Date: V Form 10-403 Revised 1/2010 (~ ~ 6 ° ~' 10 Submlt in Duplicate • • 1 E-114L1 Proposal to Wax Fill the B Sand MBE Proposal & Objective: 1 E-114L1 is a B sand lateral with 4.5" slotted liner. A matrix bypass event (MBE) occurred in 114L1 on 3/20/06 to 1 E-168L1 producer. A 3/23/06 (PROF in 114 shows 100% PWI entering the B sand. A 4/12/06 IPROF in 114L1 saw a robust MBE at 8690' MD at the heel of 114L1. On 6/30/06 an Iso-sleeve was set in the B LEM, and 1 E-114 has since been on D & A only PWI. The Iso-Slv will be pulled from the 114 B LEM and a Plug will be set to isolate the A lateral. Next, a diverter will be set in the B LEM, and an Iso-Slv will be set in the D LEM to halt cross flow. In 1 E-168, the B lso-Slv will be pulled to allow inflow from the MBE, and an Iso-Slv will be set in the D LEM to halt cross flow. To reduce plant upset potential, pumping a 1 E-114L1 Step Rate Injection Test (BRIT) will be contingent upon the quality of 1 E-105L1 BRIT data. We would prefer to use 1 E-105 BRIT analog data (1 E-105 will be our first ever wax job) to determine fluid temperature pumped through an Active-Coil (I-Coil) nozzle at MBE depth vs. various pump rates to determine the pump rates needed for placing liquid wax into the MBE. An Active-Coil job will be performed to seal the 114L1 MBE using 125 F melting point wax . heated to 180°F at surface. The hot wax will be pumped down coil to the MBE at 8690' MD as liquid and- will be displaced by 130 - 160 F diesel to the MBE, followed by shutdown to let the wax solidify in the MBE to West Sak reservoir temperature of ~72 F. Work Sequence: 1 E-114 Infector Work 1 E-168 Producer Work CT Pulf 'B' Iso-Sleeve CT Set `A' Lateral Plu halt otential crossflow CT Set'B' Diverter CT Set'D' Iso-Sleeve halt otential crossflow Pull 'B' Iso-Sleeve o en access to MBE Set'D' Iso-Sleeve halt otential crossflow Contingent SR/T: Use Active-Coil with Distributed Temperature Survey (DTS), with 180°F Seawater pumped in 1 coil volume stages at various rates ranging. from 1.5 bpm to 0.5 bpm. Verify an open MBE with DTS across trunk of MBE, and by WHIP vs. In' Rate indicators. Pump Wax Job: Use Active-Coil with Distributed Temperature Survey (DTS). Pump 100 bbls 180°F Seawater at 1.5 bpm to ensure open & preheated MBE, followed by 10 bbls 180°F Wax at 1.5 bpm, f followed by 1 Coil volume of warm Diesel displacement at 1.5 bpm gradually slowed- to decreasing rates to put the tail of the wax slug into the MBE just a few degrees above cloud point, followed by shutdown to let wax solidify in MBE. Wait on Wax 4 da s to `cure'. Return to `B' sand onl PWI Flow as `B' sand onl ;evaluate Wax 'ob _ Pull,'D' Iso-Sleeve Pull `B' Diverter Pull `A' Plu Pull `D' Iso-Sleeve Restore PWI to A, B, and D laterals Restore roduction from A, B, and D laterals ~. ___, `•\1 ~C>I`1t3~C3~'11~~1~35 ~ A ;; ,.. ~ ,. it KUP ~ T 1 E-114L1 Well Attribu W III ie APIIU WI tes Field Name Max Well Stalus In.:l i', Angle 8r MD MD (k KB) TD Act Btm (fiKB) X00292322360 ~ W ES f SAK ~ INJ 91 A2 ~ 8,145 73 12455.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date SSSV~ NIPPLE ( iLast WOE 31.52 10/26/2004 Annotation Depth (HKB) End Date Annotation Last Mod By End Dafe Last Tag Rev Reason: FORMAT UPUA I E ~ Imosbor 8/1X2009 ~Casin Strin gs . _-.- _ ~ Stnng OD ~. Strmg ID _ __ ~ Set Depth Set Depth (TVD) String Wt Btring ' Casing Descript ion (IN Top (fiKB) 8 (ftK6) (ftKB) (Ibs/ft) G ade Siring Top Thrd LINER L7 41/2 3.95 7,776.0 11,8080 3,609.1 12.60 L80 DWC 522 _ NIPPLE (TVDI Top Inel . T_op (ftK6) (ftK6) (°) Description Comment Run Date ID (Ini 7,784 3.558.2 78 68ISLEEVE B-SAND ISOLATION SLEEVE SET ACROSS "B" LEM 4/13/2006 2 880 ;~ i I (18.93') SURFACE, 4.157 "~ I 8,614 3.5/2S i ' 90.4fi'SEAL ', B-SAND BAKER SEAL ASSEMBLY 10/17/2004 3.875 Perforat ions & Slots snm I Top (TVD) Sim (TVD) Dens - Top (ftK6) ~ Btrn (ftK6) (ftK6) (ftK6) Zone Date (sh-~ Type Comment cas uFT. 4an 7,802 11,243 3,561.3 3,590.6 W S B, tE-114L7 10/15/2004 40.0 IPERF Slotted liner w/25"x.125"slots every otherjoinf 11,522 11,767 3,593.9 3,606.8 W S B, tE-114L1 10/15/2004 40.0 IPERF Slotted liner w/2.5"x.125"slots every otherjoint GAS LIFE, _ _ ],070 SLEEVE-C, _ 7.370 Packer L2. 7,414 SEAL, 7,418 - SBR L2. ],433 - SHOE, 7.446- -'- Hanger L2, _ ].463 WINDOW L2,_ 7,4]7 PACKER, ],732 - SBR. ],751 SBk Lt, ],]51 Hanger Lt, _ _ 7.777 Hanger Ll, 7.]84 SLEEVE. 7,786 IPERF, 7,802-11,243- IPERF, " 11,52211,767 I INER L1, 11.808 TD (1 E~114L1), 12.455 ConocoPhillips April 14, 2007 Robert Buchholz /Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 RECEIVED Tom Maunder, P.E. APR 1 S 20Q8 Senior Petroleum Engineer State ofth laska, Oil & Gas Conservation Commission ~ ~ ~~ ~, 33 W. 7 Ave. Ste. 100 9e Anchorage, AK 99501 a,o `f' - I ~~-- Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has set blanking sleeves in the Lateral Entry Modules (LEM) of two West Sak multilateral injection wells. Enclosed you will find 10-404 Reports of Sundry Well Operation for ConocoPhillips Alaska, Inc. for ' ~ '-~-~z-'~;-, 1 E-114, and 1 E_ 1_ 14L 1. These reports record the setting of an LEM isolation sleeve in the Ll lateral for each of these two water injection wells. If you have any questions regarding this matter, please contact myself or Robert Christensen at 659-7535. Sincerel y' ~~{~ APR 2 ~ 200 Robert W. Buchholz Attachments APR 1 6 2008 STATE OF ALASKA Alaska Oil & Gas Cons. Cammissian ALASKA OIL AND GAS CONSERVATION COMMISSION Anchoarage REPORT OF SUNDRY WELL OPERATIONS 1. operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q et 1- EM Isolation Sleeve Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 204-172 3. Address: Stratigraphic ^ Service^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23223-60 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 95' 1 E-114L1 8. Property Designation: 10. Field/Pool(s): ALK 25651; ADL 469 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11841' ' feet true vertical 3611' feet Plugs (measured) Effective Depth measured 11823' feet Junk (measured) true vertical 3610' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE (45.5 ~ 4102' 10-3/4" 4197' 2296' INTERMEDIATE 8644' 7-5/8" 8739' 3726' D-SAND WIND01 1' 7-5/8" 7466' 3490' B-SAND WINDOI 1' 7-5/8" 7779' 3557' LINER B-SAND 4032' 4-1/2" 11808' 3609' Perforation depth: Measured depth: 7802'-11243', 11522'-11767' true vertical depth: 3561'-3591', 3594'-3607' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7446' MD. Packers &SSSV (type & measured depth) PKR= ZXP Liner Top Packer PKR= 7732' SSSV= NIPPLE SSSV= 522' 12. Stimulation or cement squeeze summary: Intervals treated (measured) _, ~ ~~. aP~ ;~ 2D08 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 2452 1039 60 Subsequent to operation 1511 519 14. Attachments 15. Well Class after proposed work: °~ Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz Title Production Engineering Technician Signature ~~~~ Phone 659-7535 pL i Date ~C /~ Form 10-404 Revised 04/2004 41GINAL ~ ~/.4 , o$ ~ ~a~ Sub i Ori i O I ~~ ~~~~ 1 E-114L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/30/06 04/13/06 Pushed B" lateral ISO sleeve an additional 2' into profile with Baker Hipp tripper to 7784' RKB, ran PDS temp & spinner with well on injection @ 2000 BPD. Verified that ISO sleeve is finally set with no injection going to "B" lateral." •~- PULL DIVERTER FROM B" LEM AND SET ISOLATION SLEEVE ACROSS "B" LEM AT 7784' RKB." H, (777 O[ (7802 ;11522 ConocoPhillips Alaska, Inc. KRU 1 E-114L1 1 E-114L1 API: 500292322360 Well T e: INJ An le TS: de UBING ~-7aas, ra.soo SSSV Type: NIPPLE Orig Com letion: 10/26/2004 Angle @ TD: 87 deg @ 11841 , ~:3.s6a> Annular Fluid: Last W/O: Rev Reason: FORMAT UPDATE Reference Lo 28' RKB Ref Lo Date: Last U ate: 12/27/2007 Last Ta TD: 12455 ftK6 Last Ta Date: Max Hole An le: 91 de 8146 Casin Strin -COMMON STRINGS Descrl lion Size To Bottom ND Wt Grade Thread CONDUCTOR 20.000 0 108 108 94.00 K-55 _ WELDED SURFACE 45.5 & 40.5 10.750 0 4197 2296 45.50 L-80 BTC INTERMEDIATE 7.650 0 8739 3573 29.70 L-80 BTC-M D-SAND WINDOW 7.650 7465 7466 3490 0.00 B-SAND WINDOW 7.650 7778 7779 3557 0.00 Casin Strin - B-SAND LINER Description Size To Bottom TVD WT Grade Thread LINER B-SAND 4.500 7776 11808 3609 12.60 L-80 DWC Tubin Strin -TUBING Size ~ To 4.500 0 Bottom TVD Wt 7446 i 3485 12.60 Grade Th_read__ L-80 IBT Perforations Summa -- Interval TVD _- Zone Status Ft SPF - - Date -- Type Comment 7802 - 11243 3561 - 3591 __ WS B 3441 40 10/15/2004 IPERF Slotted liner w/2.5"x.125"slots every other~oint 11522 - 11767 3594 - 3607 WS B 245 40 10/15/2004 IPERF Slotted liner w/2.5"x.125"slots every other~oint Gas Lift Mandrels/Valve s St MD TVD _ Man Mfr _ Man Type V Mfr V Type V OD Latch Port TRO _ Date Run Vlv Cmnt 1 4477'. 2399 __ CAMCO _ _ KBG-2 DMY 1.0 BK-5 0.000 0 4/3/2005 ~ ' _ 2 7070 3389 CAMCO _ KBG-2 DMY 1.0 BK-5 0.000 0 4/3/2005 :. Other lugs, equip., etc . -COMMON JEWELRY Depth_ f _ TVD Type Descri lion ID ' 522 I 521 _' _NIPPLE CAMCO DB-6 NIPPLE 3.875 7370 3469 SLEEVE-C BAKER SLIDING CMU SLEEVE -CLOSED 11/1/2004 ; 3.810 7414 3478 Packer L2 . ' D-SAND ZXP LINER TOP PACKER 5.500 7418 3479 SEAL BAKER LOCATOR/SEAL ASSEMBLY 3.875 7433 3483 SBR L2 D-SAND 190-47 CASING SEAL BORE RECEPTACLE 4.750 7446__ 3485 SHOE BAKER M_ ULE SHOE 3.875 7463 3489 Han er L2 D-SAND LEM INSIDE HOOK HANGER 5.500 Other lugs, a ui ., etc . - B-SAND LEM ASSEMBLY Depth TVD ~ Type Descri~on ID _ 7732 3547 PACKER B-SAND ZXP LINER TOP PACKER 5.500 7751 3551 SBR B-SAND 190-47 CASING SEAL BORE RECEPTACLE 4.750 7777 3557 HANGER B-SAND BAKER MODEL B1 FLANGED HOOK HANGER 4.500 7784 3558 HANGER B-SAND LEM INSIDE HOOK HANGER 4.750 7784 3558 SLEEVE B-SAND ISOLATION SLEEVE SET ACROSS "B" LEM 18.93' 2.580 8614 3572 SEAL B-SAND BAKER SEAL ASSEMBLY 3.875 General Notes Date Note 0/26/200 NOTE: TRI-LATERAL WELL 1E-114 A-SAND 1E-114L1 B-SAND 1E-114L2 D-SAND ANGER 7-7778, c7.625) I 1 I I I Pert 11243) I I 1 Part 11767) I • • e~ ~' ~- ~~. ;:. .,~ ~; MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc ;t '6 Ntt/ "- Q \ Jd DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2041720 Well Name/No. KUPARUK RIV U WSAK 1E-114L1 Operator CONOCOPHILLlPS ALASKA INC A!eo~029~~3~~O~ i MD 11841 .,-/ TVD 3611 / Completion Date 1 0/26/2004 ~ Completion Status 1-01L Current Status 1WINJ REQUIRED INFORMATION Mud Log No Samples No Directional Su DATA INFORMATION Types Electric or Other Logs Run: GRlRes (data taken from Logs Portion of Master Well Data Maint Well Log Information: . Log/ Electr Data Digital Dataset Log Log Run Interval OH/ ~ Med/Frmt Number Name Scale Media No Start Stop CH Received Comments p Directional Survey 7778 11841 Open 11/15/2004 13122 Induction/Resistivity 25 Blu 108 11841 Open 5/18/2005 MULTIPLE PROPAGATION RESISTIVITY-GR-RWD 13122 Induction/Resistivity 25 Blu 108 11841 Open 5/18/2005 MUL TJPLE PROPAGATION RESISTIVITY -GR-RWD 13122 LIS Verification 25 108 11841 Open 5/18/2005 MULTIPLE PROPAGATION RESISTIVITY-GR-RWD C 'IT /..,\ S 13122 Induction/Resistivity 108 11841 Open 5/18/2005 MULTIPLE PROPAGATION RESISTIVITY-GR-RWD- GRAPHIC IMAGES Injection Profile 5 Blu 7896 11718 Case 4/25/2006 Memory Injection Profile . GRlCCUPRESITEMP/SPI N 12-APR-2006 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? ~ Chips Received? ~ Daily History Received? ð/N ~/N Formation Tops Analysis Y..JJ:V Received? Permit to Drill 2041720 MD 11841 TVD 3611 UIC Y Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Well Name/No. KUPARUK RIV U WSAK 1E-114L1 Operator CONOCOPHILLlPS ALASKA INC Completion Date 10/26/2004 Completion Status 1-01L Current Status 1WINJ -~J:Þ Date: API No. 50-029-23223-60-00 ~ ~~tp . . ~ " . . JUN 0'7 2005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS l~ 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 95' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 5. Permit to Drill Number: 204-172 6. API Number: 50-029-23223-60 9. Well Name and Number: 1 E-114L 1 10. Field/Pool(s): Kuparuk River Field I West Sak Oil Pool Total Depth measured 11841 ' feet true vertical 3611' feet Effective Depth measured 11823 feet true vertical 6276' feet Casing Length Size MD Structural CONDUCTOR 108' 20" 108' SURFACE (45.5 C 4102' 10-3/4" 4197' INTERMEDIATE 8644' 7-5/8" 8739' WINDOW 12' 7-5/8" 7790' LINER B-SAND 4032' 4-1/2" 11808' Perforation depth: Measured depth: 7802-11767 true vertical depth: 3561-3607 Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2295' 3725' 3559' 3609' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7446' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIPPLE SSSV= 522' Form 10-404 Revised 04/2004 Submit Original Only . 1E-114L1 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 4/20/200sICommenced Water Injection . . f= ',....'!.':~..~9 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 95' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 5. Permit to Drill Number: 204-172 6. API Number: 50-029-23223-60 9. Well Name and Number: 1 E-114L1 10. FieldlPool(s): Kuparuk River Field / West Sak Oil Pool Total Depth measured 11841' feet true vertical 3611' feet Effective Depth measured feet true vertical 6276' feet Casing Length Size MD Structural CONDUCTOR 108' 20" 108' SURFACE (45.5 ~ 4102' 10-3/4" 4197' INTERMEDIATE 8644' 7-5/8" 8739' WINDOW 12' 7-5/8" 7790' LINER B-SAND 4032' 4-1/2" 11808' Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2295' 3725' 3559' Perforation depth: Measured depth: 7802-11767 true vertical depth: 3561-3607 RBDMS SF, L ,!UN 0 6 2005 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7446' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIPPLE SSSV= 522' Form 10-404 Revised 04/2004 n ......,é Submit Original Only . . 1E-114L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 4/20/200sICommenced Water Injection ~. ~...~.~,. . ~.~.~~ .~. .. ~~. ~~" ULJ~~."~U L~ L L~ \' ,'-'... . Subject: UPDATE: LPP Variance for West Sak injection welllE-114 (PTD 2041710) From: NSK Problem Well Supv <n1617@conocophillips.com> '----t ~L.l-\"'"'- J-. Date: Mon, 27 Jun 2005 06:46:56 -0800 .;lú '-\. - \ ~ ""::,. To: Thomas Maunder <tom_maunder@admin.state.ak.us>, James Regg <jimJegg@admin.state.ak.us> CC: AOGCC North Slope Office <aogccyrudhoe_bay@admin.state.ak.us> Tom & Jim, 1E-114 West Sak injector has built sufficient wellhead pressure to set a LPP. The LPP was place back in service last week. Please let me know if you have any questions. Marie McConnell ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: NSK Problem Well Supv Sent: Wednesday, May 18, 2005 5:30 AM To: 'Thomas Maunder'; Dethlefs, Jerry C; 'James Regg' Cc: AOGCC North Slope Office; NSK Problem Well Supv Subject: RE: FW: LPP Variance for West Sak injection well 1E-114 (PTD 2041710) Tom, 1E-114 (PTD 2041710) was brought on line May 7th and passed the initial MITIA yesterday, witnessed by State Inspector, Jeff Jones. The well is still in the process of "fillup" and tubing continues to operate on a vacuum. The variance to gag the LPP expires on 5-20-05. Conocophillips requests approval to extend the gagged pilot approval for an additional 30 days to expire on 6/20/05 or when the surface pressure increase to a level that a LPP can be put in service. Please let us know if this is acceptable. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom matlllder@admin.state.ak.us] Sent: Wednesday I Apri 1 m"2-Õ~--20'Õ-51õ"~-43"-'AM ..-...-....-...---..--...-----.-..-...~ To: Dethlefs, Jerry C Cc: AOGCC North Slope Office Subject: Re: FW: LPP Variance for West Sak injection well 1E-114 (PTD 2041710) Jerry, Given the low surface injection pressure, it is acceptable to "gag" the LPP on 1E-114. Please make sure your operators have a copy of this message. Tom Maunder, PE AOGCC Dethlefs, Jerry C wrote: Tom: West Sak injector 1E-114 will be ready for injection later today--can I assume you approve the variance for having the LPP gagged for up to 30 days? The other issues we discussed can wait, but the 10f5 6/27/20058:37 AM ~. ~. ..~. ~.. . ~U~.__ >v. "V~' ~~, 'UJVVe HVU >,-,-...,. \' 'ÅJ ... . well is almost ready to put on line. Thanks! Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 -----Original Message----- *From:* Thomas Maunder [mailto:tom maunder@admin.state.ak.us] *Sent:* Wednesday, April 20, 2005 7:27 AM *To:* Dethlefs, Jerry C *Cc: * i im r<:.9~§.ª~,.:hE!,,:,,_[3_t:..9:.!:~~_: us; NSK Problem Well Supv *Subject:* Re: FW: LPP Variance for West Sak injection well lE-114 (PTD 2041710) Good reasoning as to needing something "on paper". Lets talk later today. Tom Dethlefs, Jerry C wrote: Tom: Yes, the subject wells at West Sak are all water injectors--and you are right, we do not perform a State SVS test on these wells. However, we have found it prudent to strive to meet all the regulatory requirements that apply to our areas of operations, especially these days when we are under sufficient scrutiny that we could be found doing something wrong somewhere at anyone particular point in time. The issue here is that the pool rules (Conservation Order #406B, Rule 6, section b) state we either need dual check valves or a single check and fail safe SSV. We do not have dual checks, but do have a single check and fail safe ssv. If the LPP is gagged we have defeated the SSV and so will be out of compliance. We are not going to risk an NOV for lack of approval to gag the LPP. The requests we have been making are for an exemption from the Pool Rules I mentioned above. This is why I suggested we could specify some conditions for a mutually agreeable plan so we can just manage these situations as they come up rather than having to bother you each time on a well by well basis. We need to have something documented in our hand that shows we can deviate (with approval) from the Pool Rules should certain conditions exist (like insufficient wellhead pressure). Let me know your thoughts on this. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 -----Original Message----- *From:* Thomas Maunder [mailto:tom maunder@admin.state.ak.us] *Sent: * Tuesday, April 19-:-2-00Š--·f~õá--PM-----------------·_·_------- *To:* NSK Problem Well Supv *Subject:* Re: LPP Variance for West Sak injection well lE-114 (PTD 2041710) Jerry, I thought I sent a response back regarding the settings at Alpine. These WS wells are water injectors aren't they?? I am not sure how all of this works, but to my memory we don't test SSVs on water injectors do we?? MI for sure, but not water and in WS there are only a few wells approved for MI and they are on lC and ID. Let me know your thoughts on this and I will talk to Jim as well, but this may be something we don't need to be looking at. Just my thought for now, subject to change after discussion. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: 20f5 6/27/20058:37 AM service. 30f5 . --,_.__ __. .. ___ __n 'UJ-. .._u .~ " . \' .~ ... . Tom: The following is a request from Operations to operate West Sak injection well lE-114 with a gagged low pressure pilot. The request is for a period not to exceed 30 days. This is similar to the previous approvals we have requested for the startup of West Sak injectors recently. The Production Engineers believe the reservoir will charge up over time and that these wells will eventually behave with sufficiently high tubing pressure to return to normal LPP protected service. Please let me know if you concur with our plan. Secondly, the previous email is from a discussion we started last week. Rather than ask for approval for these various situations each time they occur, is it feasible to agree on a set of rules so that the concerns of your agency and our company are met without approval on a well by well basis? CPAI could submit a written document with a proposal on how to manage these issues, and if the AOGCC concurs we could be in business. Let me know your thoughts on this approach as well. Thanks! Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 We are requesting a temporary variance for 1E-114 (PTD 2041710) from Conservation Order #406B, Rule 6, section b which requires a SSVs for water injection well to operate. A temporary variance to operate lE-114 water injection wells with a defeated SSV pilot and without a 24 hr man watch for a maximum of 30 days is requested. Based on previously pre-produced West Sak injectors, this well will be injecting on a vacuum and the SSV low pressure pilot will not be placed in service at this time. This will be the initial injection for 1E-114 and once an established tubing pressure of 300 psi has been reached the SSV pilot will be placed back in working Thanks, *Peter Nezaticky* / Marie McConnell ConocoPhillips Alaska Inc. West Sak Production Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 -----Original Message----- *From:* NSK Problem Well Supv *Sent:* Wednesday, April 13, 2005 4:32 PM *To:* 'Thomas Maunder' *Cc:* NSK Problem Well Supv; jim regg@admin.state.ak.us *Subject:* RE: LPP Settings for Alpine and West Sak Tom: It would be nice to have a "general rule" or exemption that would apply to all of Alpine when we have this problem. For that matter, it would be nice for West Sak too, for these new injectors with low reservoir pressure. The problem is that not long ago we received approval from your agency to establish 1800 psi as the benchmark LPP setting for gas injectors at Alpine. This has worked out OK until the situation with CD1-06 and 14 (see injection pressure below). These wells are expected to eventually pressure up until they are similar to the others on the pad, however they are not high enough now to use 1800 psi or they will shut-in. Rather than risk another NOV for gagging the LPP we have instead asked for approval to set lower than the 1800 psi guideline. We could make it easier on us both if we agreed on a process to adjust these as needed until they have reached full injection pressure. I don't have a good feeling how 6/27/20058:37 AM _.u_____ --- __ ___ ---~-J-. ___u _~ --. \_.~... . long that may be--it could be weeks or months. These pilots are easy to change and set since it is largely a software issue, so they can be changed up as needed. If you are willing, I could propose that we just manage this internally until a well reaches it's maximum pressure at which time the standard 1800 psi would apply. For instance, we could say that the LPP must not be set lower than 200 psi below the average daily injection pressure until the injection pressure has reached the mature state. Of course we could document each well that has this problem so that the records could be provided to the Inspector when needed. That would allow us to keep these wells in service without nuisance trips and still provide protection in the case of a release. Should you agree to this type of approval we can formalize it in a letter to your agency. I mentioned earlier the problem with West Sak injectors--our new wells have very low injection pressure and cannot operate with our standard LPP in place of about 700 psi. The injection pressure can be as low as 100 psi on injection and will be vacuum if shut-in. That is the reason for the couple requests recently for a variance to run gagged. We have another (lE-114) that will be on soon that is expected to be near vacuum. I remember years ago when I was at Prudhoe EOA that the water injectors would go on vacuum when shut-in so they were always operated with the LPP gagged. How is that handled with your agency? Is it possible we can do what I proposed above for these cases too? The expectation is with time the injection pressure will increase and a LPP can be used, but initially it is not possible. I am very interested on your opinion on this and if my proposal is something you will consider. As long as we have an agreement in place on how to handle these situations, we can manage it without asking for your approval on a well by well basis. Drop me a line when you have time to review this. I go out tomorrow and MJ will be here, but she can carryon with the issue. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message----- *From:* Thomas Maunder [mailto:tom maunder@admin.state.ak.us] ----···------*sëiït~-*-wedÏie-šday;--AprTI 13, 2005 3: 4 0 PM *To:* NSK Problem Well Supv *Cc:* jim reaQ@admin.state.ak.us *Subject:* R~7 LPP Setting for Alpine CDI-06 Jerry, Jim and I have discussed this matter. Does it make more sense have you all request a low pressure trip pressure for each pad rather than addressing it on a well by well basis? We are in agreement to have a setting to avoid the nuisance trips. Is this only something encountered when a pattern has low pressure?? Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom: Alpine Operations has asked me to seek approval to temporarily reduce the LPP set point from 1800 psi to 1600 psi on MI injection well CD1-06. The injection pressure has been averaging just barely over 1800 psi, so any bobbles may shut-in the well. The following note is from the Alpine Lead Operator with more explanation: Now that we have put all the gas down CD1-06 instead of splitting it with CDl-14, the tubing pressure of 40f5 6/27/2005 8:37 AM '"-'.A .LJ',l.Jo.....I...J..L...I...... .,.......1.1..1.............. ....v. 50f5 .. ~.,. uu>~ u>J~. "~H U.J-> >""T \L > LI ... . CD1-06 is coming back up slowly. We would like to lower this trip point to 1600 # until we get some room. Do you think we can do this and then we can raise it in 6 months if the formation pressures back up. This well is also our black start Fuel Gas supply well. If we need to operate off this well for very long we would have the Low pressure trip by-passed with a setting of 1800 # that it has now. At 1600 # setting the by-pass would not be used. Rick Alexander 4220 With your approval we will reduce the LPP set point until such time that the tubing pressure increases to a point it can be reset at 1800 psi without nuisance trips. Thanks for your attention on this. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 6/27/20058:37 AM . ~ . . RECEIVE 2005 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS APR 1 3 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Convert to I~ector Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 A\as~ Qi\ & Gas ons Time Extens· Anchorag Change Approved Program 0 Opera!. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 204-172/305-012 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 50-029-23223-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 28',88' AMSL 1 E-114L1 8. Property Designation: 10. Field/Pool(s): ALK 25651, ADL 469 Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11841' feet true vertical 3611' feet Plugs (measured) Effective Depth measured 11823' feet Junk (measured) true vertical 3609' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 4169' 1 0-3/4" 4198' 2295' INTERMEDIATE 8708' 7-5/8" 8736' 3725' LINER - A SAND 4008' 4-1/2" 11808' 3609' Perforation depth: Measured depth: slotted liner true vertical depth: Tubing (size, grade, and measured depth) 4-112" , L-80, 7446' MD. Packers & SSSV (type & measured depth) pkr @ 8570' SSSV= Landing Nipple 522' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casino Pressure Tubino Pressure Prior to well operation Pre-produced Subsequent to operation SI 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oilD GasD WAG 0 GINJD WINJ0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Gary Targac @ 265-6586 Printed Name Randy Thomas Title Kuparuk Drilling Team Leader Signature \ <'~'l~ Phone Phone: 265-6830 Date '? /1 ~ /'0:5 Prenared bv ·">haron AlIs"n-Dr~k" 263-4612 \ µßø s . . . COI Form 10-404 Revised 04/2004 4r», AL Submit Original Only ) r . 1 E-114 Well Events Summary . Date Summary 04/01/05 GAUGED TBG TO 2087' SLM WITH 3.8" GAUGE RING. ENCOUNTERED HYDRATES. IN PROGRESS. [Hydrates-Ice] 04/02/05 CLEAR HYDRATES WITH METHANOL, BRUSH, & G/R. GAUGED TBG TO 3.83" TO 7370' RKB. SET 3.812" DB PLUG (NO PACKING) @ 7370' RKB. PULLED DV @ 7070' RKB. IN PROGRESS. [GLV] 04/03/05 SET DV @ 4477' RKB. LOADED IA WITH INHIBITED SW & DSL CAP. SET DV @ 7070' RKB. MITIA 3000 PSI, PASSED. PULLED PLUG. [MIT] 04/05/05 MEASURED BHP @ 7843' MD: 1098 PSI. [Pressure Data] RECEIVED APR 2 1 2005 Alaska Oil & Gas Cons. Commission Anchorage ~ ru'~i¡ ~" ~ H II IJ 'ñ)-- r! ¡¡In, I I, Ü!Ju ((ù ,S ,\'\ ïJU' ¡ '...;;..J . / I FRANK H. MURKOWSKI, GOVERNOR I I ¡ J/ j ~/'-17~ A. ..,ASIiA. OIL AlQ) GAS CONSERVATION COMMISSION I .' 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska Re: Kuparuk lE-1l4Ll Sundry Number: 305-012 Dear Mr. Thomas: 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. Please provide at least twenty-four (24) hours 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 provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior 0 unless rehearing has been requested. DATED thiS~ay of February, 2005 Encl. STATE OF ALASKA aKA OIL AND GAS CONSERVATION COMrve:>N APP~ATION FOR SUNDRY APPftOVAL 20 AAC 25.280 ~-J ~ ð-oS;- ~ '1 Perforation Depth MD (ft): slotted liner Packers and SSSV Type: pkr @ 8570' SSSV= Landing Nipple 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operat 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foreQoing is true and correct to the best of mv knowledQe. Printed Name Randv Thomas \ ~~ -vL,~ I 1. Type of Request: Abandon 0 o o Suspend 0 Repair well 0 Pull Tubing 0 Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 28',88' AMSL 8. PropertY Designation: ALK 25651, ADL 469 11. Total depth MD (ft): 11841' Casing Total Depth TVD (ft): Effective Depth MD (ft): 3611' 11823' Length Size CONDUCTOR 108' 20" SURFACE 4169' 10-3/4" INTERMEDIATE 8708' 7-518" LINER - A SAND 4008' 4-1/2" Perforation Depth TVD (ft): January 21, 2005 Date: Signature Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development _ 0 Stratigraphic 0 Perforate 0 Waiver 0 Annular Disp. 0 Stimulate 0 Time Extension 0 Other 0 Re-enter Suspended Well 0 Pre-produce Exploratory 0 Service 0 5. Permit to Drill Number: 204-172 6. API Number: 50-029-23223-60 9. Well Name and Number: 1E-114L1 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 3609' MD TVD Burst 108' 108' Collapse 4198' 8736' 11808' 2295' 3725' 3609' Tubing Size: 4-1/2" Tubing Grade: L-80 Tubing MD (ft): 7446' Packers and SSSV MD (ft) 522' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Contact· Title: r.Rry T¡:¡rgac @ 265-6586 Kuparuk Drilling Team Leader Date II (( (OS- '- Phone: 265-6830 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 305""- ,,~ Location Clearance 0 Other: s.~ ~S-()U-\ ~\ \ £ - \ \ \-\ ~- \ ì \) .(o~..),~~~),\_\-~ R E C; ~ ~\!~ 0 ¡AN l 200) BY ORDER OF 41,,,, Oi; & A,,,.,,~,::;O'i~'" Approv by ~ .--' COMMISSIONER THE COMMISSION Date: 1;'llfI tJS \ /L( / - 1 , Form ~03 R~d 12/2003 Submit in Duplicate Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 INSTRUCTðNRl G\~,j A L . ø ::?UD DA::::: : OFER & FIELD è704- \~ \ .. t..... ) .- t 13 (ÿ> Þr 1: \]\..J~~\ Sc. ~ \ e - \ \ L..\-Lt.,- L 'à . \ . \ HECHANI CAL INTEGRITY REPORT . ........ :.IG REL'::;..S~: WELL NtlliBER Cas ing: '15/<6 .:..::":ïe~ : f\) ~ \ ~~4( :~bi::g: W. l:J Packer ~I")OMD TVD j See at: \ ~ ::ole Size S'l/V;. anå ¡Perfs ~ 0\+1:0 \o..4\4\.·~ "o~ pa.c..\a\Ì""':> ð~Q ~~- \k Y\. +0b '\{'..~ ðuG. \c ,\ Lc. \-\'l (¿:<::v~ 1~~~V"\.. ~ :-SC?..ÞlnCl-~ INTEGRITY - PART 11 TD : . MD.. TVD¡ :? B TD : HD TVD Shoe: ~~D~ MD ~')dÇTVD i DV: \J~ MD ·TVl:> Shoe: MD TVD¡ :CP: HD :VD ~~LL DATA ¡IS min ; 30 min Annulus Press Test: IP COu:ï:ments: ,..- :-Œ CH/Ün CÞ..L INTEGRITY - PART ¡ 2 Cement: Volumes :'. ...A..mt. Liner~; CsgifO~ bb\> j DV \.:J ~ Cüjl: 701 to cover perf s <is?> b.~ \ ~ 0 ~ c...~Me-1A. \ .\ã<:..(")()(è" .\Ð ~ o&-\t.JS \) ,,\~\ ~s;ro( Q\\{)~\N ~O?a 'f..S ~ j Theoret:ical TOC û\'¥J~"h',c.~Ùlo 'ý..~ ~~\TV\c:.a·\ \0<:::' "Ç., \...~~O\ :) ¡WI'¡ -0 Y 'V Cement Bond Log (Yes or No) "-IV::" 5> ; In AOGCC File . \(~ _ . ·+"tOûS~. 'S.CCc t~-\ \. . I. .~¡ . CEL ~V'aluat~on, zone a~~~~~\- t-1O.~ ~ \jút\,(¡}~\f (~t'\~'\ç,' 'Ð'~~\L,-oo..N"'~\"jS.\f' \o..~~¡ ~c.c.t £\C(".J.,,~v~"'ro-.)' ,.\.-ò-C:-~"'ð". 0 t\ -, ~'.;>.'.' . .. D'. '. ''':>~ Proåuction Log: Type ¡ Evaluation tu (\~\.\-~ \' . -4~~ cr\ìJ~\.-\'1. CONCLUSIONS: ? ar I: f 1 : ? ar:: : Z : t--\'¡:-Ì'>, \\~ \'-1 ~1?Jz.- ~' . -0 S- .. I . vr I \Lie . . ß Tom, Here is the well orientation plot for the 1320 requested on lE-l14~ Also, included are the cementing reports for each one of these wells. Six wells Wére seen to intersect the 1320 plot: 1E-168 v ~)ö'-\-:}O() l\ 1E-123'/ :]Õ~_·O'ì. ~ "~~o\Q::~\~J ~5/~·-o~ 1 D-116 .../ \ ~ (6- \ ''\.,) 1D-113 -/. I~<;';;- \''\ <6' 1D-112 j. \~ \ç- \<6~ ~ c. 1 D-l 03 ';>0 ð - Oq (,.;; - <è ~\ ;,J <:':\$c.) 1/, s -0 ~ All the wells had good cementing operations with the exception of ID-I03. This was the well drilled two years ago and failed to get returns to surface. The bond log was suspect and we went ahead and perfonned a squeeze. The squeeze only took 9 bbls with fairly high squeeze pressures which told me that the cement was there but I think we may have run the bond log way to soon after the cementing operation (+/-48 hours, SLB recommends 72 hours). If you have any questions give me a call. Steve 263-4620 'T,^-"-\5 ~()<:'0~C"\- ~Û(-;~ ~'5\-'\ û\ -\ ~ þ3-t..\4£\ o.~-~S'<.~~c¿~· -Çð\ t-\:X-\ TI: '~\' \t::'-\'~ t-l~~,~'- Ldœ \ht \"0'\~\~~~ \ ~(\\... ~cty\~ ~ '-> $Qk~' ? \O-cx2\', "'- \~ ~S.F.\-tv:, ,ç::,\~. ~ ~,t·\ \J~\t\\> \J'-Jt.~<!(dQ ~~\-¡¡v(\~J .~ Ð \~ L CJ-CQ;.p\'cdÞ \C< \ \"-.:.\e:~I:''¿~ ' ~9-~~ , ~ ¿;"1 "C~O ..::> · / / / / / / / / / / / / / ""'. ../ I Kuparuk lD Pad, lD-I03, lD-I03 VI I I Kul Kuparuk lE Pad, lE-123, lE-123 V2 I 700 ANTI-COLLISION SETIINGS Conocó'Phillips 3538 3598 Interpolation Melhod:TVD Interval: 1.000 Depth Range From: 3478.000 To: 3788.250 Ma:dmum Range: 1376.200 Reference: Oefmitive Survey '2 ~ 0 0 0 ~ 3000 +' ~ 0 ~ i3 ;::I 0 VJ 2000 3718 600 5000 4000 1000 Circles of 1320' Radius 3000 4000 5000 W est( - )Æast( +) [1000ftlin] 6000 7000 8000 ~~.:'X:~~ ~ .1\....... ·>I,u" ".~...,""" . STATE OF ALASKA . ALA~ OIL AND GAS CONSERVATION COMrmlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG· 1a. Well Status: Oil 0 Gas U Plugged LJ Abandoned U Suspended U WAG 0 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WDSPl 0 No. of Completions _ Other _X Pre-Produced Injector Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. . 204-172 or Aband.: October 26, 2004 . 3. Address: 6. Date Spudded: bcic~ /DI UiG'¡ 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 .$QptGfl'tbeT"'25, 2004 .~ 50-029-23223-60 4a. location of Well (Govemmental Section): 7. Date TD Reached: ,/. Þf.t.1f 14. Well Name and Number: Surface: 91' FSL, 227' FEL, Sec. 16, T11N, R1OE, UM October 13, 2004 ' 1E-114L1 At Top Productive 8. KB Elevation (It): 15. Field/Pool(s): Horizon: 905'FSL, 191'FEL, Sec. 15, T11N, R10E, UM 28' RKB 188' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): West Sak Oil Pool 318' FNL, 66' FEL, Sec. 15, T11 N, R10E, UM 11823' MD / 3609' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 550301 y- 5959681 Zone-4 .. 11841' MD /3611' TVD . ALK 25651 TPI: x- 555609 y- 5960532 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 555698 , y- 5964589 / Zone-4 Landing Nipple @ 522' ADL 469 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 5765' MD 21. Logs Run: -rjW~ 7,77 ~ / m.t:> .Ál> GR/Res .3~? ".,-vL> 'l.~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20" 62.58# H-40 28' 108' 28' 108' 42" 335 sx AS I 10.75" 45.5# L-80 28' 4198' 28' 2295' 13.5" 730 sx AS Lite, 207 sx DeepCrete 7.625" 29.7# L-80 28' 8736' 28' 3725' 9.875" 515 sx DeepCrete 4.5" 12.6# L-80 7800' 11808' 3609' 6.75" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 7446' 8570' slots in liner from 7802'-11243', 11522'-11767' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 128 joints total wi a slot every other joint nla 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lilt, etc.) November 13, 2004 Pre-produced injector - production shared with 1 E-114 and 1 E·114L2 Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-Oil RATIO 11/17/2004 7 hours Test Period --> 368 166 5 45 Bean 517 Flow Tubing Casing Pressure Calculated Oll-BBL GAS-MCF WATER-BBl OIL GRAVITY - API (corr) press. 398 psi 1366 24-Hour Rate -> 1222 611 18 n/a 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none'. RBDMS 8FL NOV 2 6 2004 P~Õ0;[D:¡mil NONE ',c"" ¥ k~v;·¥·;·ö,.~ t -" ¡-·C· t ('!t\(^' .~)2:~.-f G (:: (1 n \ "'~""~i..~"""¡""'_~_'-' ,"''''J¡¡,.:~''''''_''¡¡''''''''>_~ :\ I.- Form 10407 Revised 12/2003 CONTINUED ON REVERSE 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1E-114L1 West Sak B West Sak B 7779' 11522' 3557' 3594' N/A ., 1 V 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Shultz @ 263-4620 KUDaruk DrillinQ Team Leader -z..6'56-ß 3<::> Date \(/(~ 10'1' Prepared by Sharon Allsup-Drake 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 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 well 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 elevation in feet abour mean low low water. 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: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 . . Legal Well Name: 1E-114 Common Well Name: 1 E-114 Event Name: ROT - DRILLING Contractor Name: n 1334@ppco.com Rig Name: Doyon 141 Hours 9/25/2004 00:00 - 02:00 2.00 MOVE RURD MOVE 02:00 - 08:00 6.00 MOVE MOVE MOVE 08:00 - 13:00 5.00 WELCTL NUND RIGUP 13:00 - 16:00 3.00 DRILL RIRD SURFAC 16:00 - 20:00 4.00 DRILL PULD SURFAC 20:00 - 20:30 0.50 WELCTL BOPE SURFAC 20:30 - 21 :30 1.00 DRILL PULD SURFAC 21 :30 - 22:00 0.50 DRILL CIRC SURFAC 22:00 - 00:00 2.00 DRILL DRLG SURFAC 9/26/2004 00:00 - 00:45 0.75 DRILL DRLG SURFAC 00:45 - 03:30 2.75 DRILL TRIP SURFAC 03:30 - 17:30 14.00 DRILL DRLG SURFAC 17:30 - 20:00 2.50 DRILL TRIP SURFAC 20:00 - 22:00 2.00 DRILL TRIP SURFAC 22:00 - 00:00 2.00 DRILL DRLG SURFAC Start: Rig Release: Rig Number: 9/25/2004 1 0/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: Tear out & rig down for rig move. Move rig from 1 E-166 to 1 E-114, Rig up & Connect all Air. Mud, Steam, Water & Pump lines. Accept rig @ 08:00 hrs 9/25/04, Nipple up Diverter system, Mix Spud mud, Load pipe shed w/ 5" drill pipe & HWDP. Change out all surface equip., Iron Roughneck & Top drive saver sub from 4" to 5". Pick up 34 stands 5" drill pipe, 29 jts 5" HWDP & Jars and stand back in derrick. Function test Diverter system- OK, Test waived by AOGCC Jeff Jones. Make up BHA #1, Pick up 3 NMDC's, RIH & tag btm of conductor @ 108'. Fill conductor & check for leaks- OK. Note; Rig back on High line power at 21 :30 hrs 9/25/04. Spud well @ 22:00 hrs 9/25/04, Drill 13-1/2" hole f/1 08' to 220', ART= 1.6 hrs, 5/15K WOB, 60 RPM, 550 gpm @ 500 psi, UP 50K, ON 50K, ROT 50K, Torque on btm 2000 fUlb, Off btm 1000 tUlb. Drill 13-1/2" hole f/220' to 279' (59'), ART= 0.6 hrs, 5/20K WOB, 60/65 RPM, 550 gpm @ 600 psi, UP 50K, ON 50K, ROT 50K, Torque on btm 2000 tUlb, Off btm 1000 tUlb. POOH, Pick up Motor w/1.8 AKO & MWD for BHA #2, Orient same, RIH to 279'. Directional Drill 13-112" hole f/279' to 1,848' (1,569'), Ran 3 Gyro Surveys, ART= 0.5 hrs, AST= 8.9 hrs, WOB 10/20, RPM 70, 550 gpm @ 1900 psi, UP 92K, ON 76K, ROT None. PUMP out of hole to HWDP, POOH (No tight spots - Hole in good shape), Lay down Motor & clean rig floor. Pick up Motor w/1.3 AKO, Make up BHA #3, Orient same & RIH to 1,848', No problems going in hole. Directional Drill 13-1/2" hole f/1 ,848' to 2,040' MD /1 ,588' TVD (192'), ART= 0.8 hrs, AST= 0.6 hrs, WOB 10/20, RPM 80,590 gpm @ 2100 psi, UP 90K, ON 77K, ROT None, Torque 4/5000 fUlb on btm, 5000 tUlb off btm. Note; Camp off High line power from 09:30 hrs to 14:00 hrs due to CPF 1 Frame 6 maintainance. 16.50 DRILL DRLG SURFAC Drill 13-1/2" hole f/2,040' to 4,205' MD /2,298' TVD (2,165') (10-3/4" casing point), ART= 7.7 hrs, AST= 3.7 hrs, WOB 10/20, RPM 100, 700 gpm @ 2500 psi, UP 135K, ON 60K, ROT 88K, Torque 12K tUlb on btm, 12K fUlb off btm, Max gas 841 units. 1.50 DRILL CIRC SURFAC Pump Hi-vis weighted sweep & circ hole clean. 5.50 DRILL TRIP SURFAC Observe well, Backream out of hole 4,205' to 960' at drilling rate of 590 gpm @ 2300 to 1700 psi, RPM 100, Pulling pipe at rate of 40/45 tUmin., Had to slow down from 3,560' to 3530' & 3,360' to 3,330' due to torque and mild packing off, worked thru spots and cleaned up same, Lay down Ghost reamer. POOH on elevators & stand back HWDP. LD BHA #3, LD 3- 6 3/4" Flex DC's, MWD and Motor RU Doyons 103/4" csg equipment with Franks fill up tool Held PJSM with rig crew and tong operator on running casing MU 10 3/4" float shoe, 2 jts 103/4" 45.5# L-80, BTC csg, fit collar, thread locked conn below FC and circ thru shoe track, RIH with 103/4" csg to 2,072' (52 Jts) Circ btms up at 2,072', staged pump rate up to 6 bpm at 325 psi, st wt 9/27/2004 00:00 - 16:30 16:30 - 18:00 18:00 - 23:30 23:30 - 00:00 0.50 DRILL TRIP SURFAC 9/28/2004 00:00 - 02:00 2.00 DRILL PULD SURFAC 02:00 - 03:15 1.25 CASE RURD SURFAC 03:15 - 03:30 0.25 CASE SFTY SURFAC 03:30 - 07:00 3.50 CASE RUNC SURFAC 07:00 - 08:30 1.50 CASE CIRC SURFAC Printed: 1111212004 11:23:10AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 1 0/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: Hours Sub Code Code Phase 9/28/2004 07:00 - 08:30 1.50 CASE CIRC SURFAC up 96K, dn wt 65K 08:30 - 09:15 0.75 CASE OTHR SURFAC Changed out rubber elements on Franks fill up tool 09:15 -13:00 3.75 CASE RUNC SURFAC Cont RIH with 103/4" csg, MU hanger and landed csg with float shoe at 4,198' MD/2,295' TVD, float collar at 4,112', no problems RIH, Ran a total of 79 jts (3,130') of 40.5# L-80, BTC csg above shoe track and a total 25 jts (1,032') of 45.5#, L-80, BTC csg including shoe track, total float equip, csg and hanger, 4,168', ran 15 bow spring centralizers and 1 stop ring per well plan 13:00 - 14:00 1.00 CEMEN SURFAC Circ btms up thru Franks fill up tool, staged pump rate up to 7 bpm at 600 psi, st wt up 190K, dn wt 65K 14:00 - 14:30 0.50 CEMEN SURFAC RD Franks fill up tool and MU Dowell's cement head 14:30 - 16:00 1.50 CEMEN SURFAC Fin circ and conditioning mud for cementing, final MW in & out, 9.3 ppg, 39 vis, 13 PV and 11 YP, circ at 7 bpm at 400 psi, st wt up 190K dn wt 70K, held PJSM with Dowell, APC vac truck drivers and rig crew on cementing operations while circ. 16:00 -18:15 2.25 CEMEN PUMP SURFAC Cemented 103/4" csg, Dowell pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 40 bbls of CW 100 (50 bbls total), then pumped 42 bbls of 10.5 ppg mudpush, began mixing and pumping Arcticset lead slurry, pumped 591 bbls (730 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 7 bpm at 180 psi, followed with 92 bbls (207 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.46 yield with add., ave 7 bpm at 300 psi, reciprocated csg till 17:45 hrs with 129 bbls lead cement out of shoe and had full returns, shut down and dropped top plug 18:15 - 19:15 1.00 CEMEN DISP SURFAC Dowell pumped 20 bbls fresh water then turned over to rig and rig displaced cement with 381 bbls of 9.3 ppg mud, displaced cmt at 7 bpm, initial circ pressure 550 psi, max pressure 725 psi, slowed rate to 3.5 bpm and bumped plug on calc displacement, pressured up to 1,300 psi, checked floats and held, CIP @ 19:15 hrs, had full returns during job and had 180 bbls of 10.7 ppg cmt back to surface 19:15 - 20:00 0.75 CASE DEQT SURFAC Tested 103/4" csg to 3,000 psi for 30 min, good test 20:00 - 21 :30 1.50 CEMEN RURD SURFAC RD Dowell cement head and LD landing jt 21 :30 - 00:00 2.50 WELCTL NUND SURFAC NO 16" diverter line and began NO 21 1/4" diverter and spool 9/29/2004 00:00 - 01 :15 1.25 WELCTL NUND SURFAC Fin NO diverter and starting head, used crane to set out diverter and set in wellhead equipment 01 :15 - 03:00 1.75 WELCTL NUND SURFAC NU Vetco Gray 13 3/8" 5M MB 222 wellhead, tested seals to 5,000 psi for 15 min, installed test plug 03:00 - 05:00 2.00 WELCTL NUND SURFAC NU BOP stack 05:00 - 10:30 5.50 WELCTL BOPE SURFAC RU and tested BOPE, choke manifold, 4" and 5" floor valves, rams including 7 5/8" csg rams to 250 psi low and 3,500 psi high, annular to 250 psi low and 2,800 psi high, Jeff Jones with AOGCC waived witnessing of test 10:30 -11 :00 0.50 DRILL OTHR SURFAC Installed wear bushing 11 :00 - 13:00 2.00 DRILL RIRD SURFAC Changed over top drive to 4" XT-39 DP, changed out saver sub, grabbers and pipe guide 13:00 - 18:30 5.50 DRILL PULD SURFAC PU and stood back 159 jts (53 stds) of 4" XT-39 DP 18:30 - 20:30 2.00 DRILL PULD SURFAC MU 9 7/8" BHA #4 with AutoTrak tool, initialized Autotrak and RIH to 1,077' with BHA #4, HWDP, jars and MU ghost reamer 20:30 - 23:15 2.75 DRILL TRIP SURFAC RIH from 1,077' to 4,048' with BHA #4 on 5" DP 23:15 - 23:30 0.25 DRILL SFTY SURFAC Discussed stripping drill procedure with crew on rig floor 23:30 - 00:00 0.50 RIGMNT RSRV SURFAC Began to slip and cut 100' of drlg line 9/30/2004 00:00 - 01 :00 1.00 RIGMNT RSRV SURFAC Fin slip and cut 100' of drlg line, serviced top drive and blocks 01 :00 - 06:45 5.75 CEMEN DSHO SURFAC RIH from 4,048', tagged plugs above float collar at 4,111', drilled out Printed: 11/12/2004 11 :23:10 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-114 1 E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 1 0/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: plugs, float collar at 4,112', shoe track, float shoe at 4,198' and cleaned out to btm at 4,205', drilled 20' of new formation to 4,225' MD/ 2,307' TVD, 5-30K wob, 60-120 rpms, 500-600 gpm, 1,300 psi to 2,100 psi, rot wt 85K, up wt 140K, dn wt 55K Displaced out spud mud with clean 9.0 ppg LSND mud, evening MW in and out at 9.0 ppg, circ at 510 gpm, 1,700 psi and 30 rpm's RU and performed LOT to 12.8 ppg EMW, 450 psi, 2,295' TVD with 9.0 ppg MW Drilled 9 7/8" hole with AutoTrak tool per directional plan from 4,225' to 6,250' MD/3,049' TVD (2,025'), ADT 10.0 hrs, 3-15K wob. 130 rpm's, 600 gpm, off btm pressure 2,700 psi, on btm 2,800 psi, off btm torque 9K ft-Ibs, on btm 9K ft-Ibs with 2% lubricants, rot wt 93K, up wt 120K, dn wt 73K, clean hole ECD with 9.0 ppg MW at 500 gpm was 9.7 ppg, raised MW from 9.0 to 9.3 ppg at 6,000' per well plan, ECD with 9.0 ppg mud ave 10.1 ppg, ECD with 9.3 ppg MWave 10.6 ppg, BGG with 9.0 ppg mud ave 175 units, max gas/conn gas ave 1,100 units, BGG with 9.3 ppg mud aye 100 units, max gas/conn gas ave 350 units 12.00 DRILL DRLG INTRM1 Drilled 9 7/8" Hole with AutoTrak tool per directional plan from 6,250' to 7,692' MD/ 3,539' TVD, (1,442') ADT 6.7 hrs, 5-15K wob, 130 rpm's, 600 gpm, off btm pressure 3,450 psi, on btm 3,500 psi, off btm torque 15K ft-Ibs, on btm 13K, rot wt 99K, up wt 165K, dn wt 65K, 9.3 ppg MW, aye ECD 10.8 ppg. Top of Ugnu "C" at 5,760' MD/2,847' TVD, Top of West Sak "0" at 7,457' MDI 3,488' TVD, aye BGG 100 units, max gas 1,200 units 9.00 DRILL DRLG INTRM1 Drilled 9 7/8" Hole from 7,692' to 8,741' MD/3,727' TVD, (1,049') (75/8" Csg pt) ADT 5.2 hrs, 5-15K wob, 130 rpm's, 600 gpm, off btm pressure 3,600 psi, on btm 3,675 psi, off btm torque 17K ft-Ibs, on btm 13K, rot wt 97K, up wt 176K, dn wt 62K, 9.3 ppg MW, aye ECD 11.0 ppg, pumped weighted hi vis sweep with no increase in cuttings back Top of West Sak "B" at 7,777' MD/3,577' TVD, aye BGG 350 units, max gas 1,270 units Circ to clear BHA and downlink AutoTrak to ribs off Backream out of hole from 8,741' to 6,947', backreaming out at 130 rpm's, 600 gpm, 3,500 psi with no problems Backreamed out from 6,974' to 5,265' at 130 rpm's, 600 gpm at 2,400 psi, pumped out of hole from 5,256' to 10 3/4" csg shoe at 4,198' Pumped weighted hi vis sweep and circ hole clean, circ at 600 gpm, 2,350 psi, had 10% increase in cuttings back from sweep, circ add. btms up and clean at shakers, rot wt 89K, up wt 145K, dn wt 58K Monitored well at shoe-static POOH from 4,198' to 4,048', hole taking proper fill, pumped dry job POOH LD 5" DP from 4,048' to 1,077' to BHA, LD 96 jts of 5" DP Monitored well at BHA-static Serviced top drive and blocks Repaired pipe skate POOH LD 29 jts 5" HWDP and jars, cont to LD BHA #4, downloaded Autotrak tool and LD same, cleared rig floor and pulled wear bushing RU Doyon's 7 5/8" csg equipment with Franks fill up tool Held PJSM with rig crew and tong operator on running of 7 5/8" csg RIH with 75/8",29.7#, L-80, BTC-M csg to 2,098', MU 7 5/8" Float shoe, 3 jts csg and float collar, thread locked btm 4 conn's and circ thru float equip and ck ok, RIH with 46 add. jts along with pup jts for spacing out to 2,098' 06:45 - 07:30 0.75 DRILL CIRC SURFAC 07:30 - 08:15 0.75 DRILL LOT SURFAC 08:15 - 00:00 15.75 DRILL DRLG INTRM1 10/1/2004 00:00 - 12:00 12:00 - 21 :00 21:00 -21:15 0.25 DRILL CIRC INTRM1 21:15-00:00 2.75 DRILL REAM INTRM1 10/2/2004 00:00 - 03:15 3.25 DRILL REAM INTRM1 03:15-04:15 1.00 DRILL CIRC INTRM1 04:15 - 04:30 0.25 DRILL OBSV INTRM1 04:30 - 05:00 0.50 DRILL TRIP INTRM1 05:00 - 07:45 2.75 DRILL PULD INTRM1 07:45 - 08:00 0.25 DRILL OBSV INTRM1 08:00 - 08:30 0.50 RIGMNT RSRV INTRM1 08:30 - 09:00 0.50 RIGMNT RGRP INTRM1 09:00 - 11 :30 2.50 DRILL PULD INTRM1 11 :30 - 13:30 2.00 CASE RURD INTRM1 13:30 - 14:00 0.50 CASE SFTY INTRM1 14:00 - 17:30 3.50 CASE RUNC INTRM1 Printed: 11/12/2004 11 :23:10 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n 1334@ppco.com Doyon 141 start: Rig Release: Rig Number: 9/25/2004 1 0/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: 10/2/2004 17:30 - 18:30 1.00 CASE CIRC INTRM1 18:30 - 20:30 2.00 CASE RUNC INTRM1 20:30 - 21 :30 1.00 CASE CIRC INTRM1 21 :30 - 00:00 2.50 CASE RUNC INTRM1 10/3/2004 1.25 CASE RUNC INTRM1 0.75 CASE CIRC INTRM1 00:00 - 01 :15 01 :15 - 02:00 02:00 - 08:45 6.75 CASE RUNC INTRM1 08:45 -10:15 1.50 CEMEN INTRM1 10:15 -10:30 10:30-11:15 0.25 CEMEN INTRM1 0.75 CEMEN INTRM1 11:15-12:45 1.50 CEMEN PUMP INTRM1 12:45 -14:15 1.50 CEMEN DISP INTRM1 14:15 - 15:00 0.75 CASE DEQT INTRM1 15:00 - 16:30 1.50 CASE RURD INTRM1 16:30 - 18:00 1.50 WELCTL EQRP INTRM1 18:00 - 19:00 1.00 DRILL PULD INTRM1 19:00 - 20:30 1.50 DRILL PULD INTRM1 20:30 - 23:00 2.50 DRILL PULD INTRM1 23:00 - 23:15 0.25 DRILL DEQT INTRM1 23:15 - 00:00 0.75 DRILL PULD INTRM1 10/4/2004 00:00 - 04:45 4.75 DRILL PULD INTRM1 04:45 - 05:45 1.00 DRILL TRIP INTRM1 05:45 - 07:30 1.75 RIGMNT RSRV INTRM1 07:30 - 08:45 1.25 CEMEN DSHO INTRM1 Description of Circ a csg cap at 2,098', staged pump rate up to 4 bpm at 350 psi, st wt up 103K, dn wt 48K RIH with 7 5/8" csg from 2,098' to 4,126' Circ a csg capacity at 103/4" shoe, staged pump rate up to 4 bpm at 350 psi, st wt up 142K, dn wt 50K RIH with 75/8" csg from 4,126' to 5,072', RIH to 4,710', pumped down from 4,710' to 4,770', had to push csg down from 4,770' to 5,072', pushed 2 jts and would pump 3rd one down, st wt up 170K, dn 35K, (block wt 35K) Total of 119 of 204 jts in hole RIH slow with 7 5/8" csg from 5,072' to 5,295' Circ btms up at 5,295', staged pump rate up to 5.5 bpm, 400 psi, st wt up 180K, dn wt 45K Fin RIH with 75/8" csg, RIH to btm slow due to excessive drag, MU hanger and landed 7 5/8" csg at 8,736' MD/3,725' TVD with float collar at 8,607', ran a total of 204 jts 7 5/8", 29.7#, L-80 BTC-M csg with 4-pup jts and hanger (Total 8,709'), ran 20 tandem rise cent, 40 bow spring and 24 straight blade centralizers per well plan, 1 every 30' Circ btms up thru Franks fill up tool conditioning mud for cementing, staged pump rate up to 6 bpm at 675 psi LD Franks fill up tool and MU Dowell cement head Cont to circ and cond mud for cementing, circ at 6 bpm at 700 psi, st wt up 275K, dn 50K, initial MW out, 9.8 ppg, 156 vis, PV 31, YP 29, conditioned mud to final MW out of 9.3 ppg, 43 vis, 17 YP and 18 PV, Held PJSM with Dowell, APC vac truck drivers and rig crew on cementing csg while circ Dowell pumped 10 bbls CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped 40 add. bbls of CW 100, pumped 50 bbls of MudPush at 10.5 ppg, dropped btm plug then pumped 210 bbls, (515 sxs) of DeepCrete cmt at 12.5 ppg, 2.24 yield with additives, ave 6 bpm at 250 psi, reciprocated pipe with full returns, shut down, washed up and dropped btm plug Rig displaced cement with 9.3 ppg OBM, bumped plug on calc displacement after pumping 395 bbls OBM (95% pump eff.) ave 6 bpm while displacing cmt, max pressure 990 psi, slowed pump rate to 3 bpm with 30 bbls left to pump and bumped plug to 1,500 psi, ck floats and held CIP at 14:00 hrs, reciprocated pipe until CW 100 was out of shoe when hole began getting tight and stopped reciprocating, Calc TOC @ 5,500' Tested 7 518" csg to 3,000 psi for 30 min LD landing jt and RD csg equipment Installed 75/8" pack-off and tested seals to 5,000 psi for 15 min, installed wear bushing Changed out elevator bales and PU 6 3/4" BHA to rig floor PU and stood back in derrick 9 stds of 4" Hybrid push pipe MU 6 3/4" BHA #5, 4 3/4" mud motor with 1.2 deg bend, MWD, LWD and PWD, oriented and uploaded MWD, RIH with BHA #5 to 283' Shallow tested MWD at 283', circ at 178 gpm at 550 psi, tool ck ok RIH with BHA #5 PU 4" XT-39 DP singles from pipe shed, RIH to 1032' Cont RIH with 6 3/4" BHA #5 PU 4" XT 39 DP from Pipe shed to 6,235', PU a total of 195 jts of 4" XT 39 DP RIH from 6,235' to 8,567' with 4" DP from derrick Slip and cut 65' of drlg line, serviced top drive and blocks RIH from 8,567' and tagged plugs above float collar at 8,606', drilled out Printed: 11/12/2004 11:23:10AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 1 0/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: 10/4/2004 07:30 - 08:45 1.25 CEMEN DSHO INTRM1 float collar at 8,607', shoe trak and float collar at 8,736', drilled 20' of new formation from 8,741' to 8,761' MD/3,729' TVD, drilled with 0-15K wob, 50 rpm's, 236 gpm at 1,900 psi, rot wt 85K, up wt 140K, dn wt 55K 08:45 - 10:00 1.25 DRILL CIRC INTRM1 Girc hole clean for LOT, 9.35 ppg MW in and out, circ at 296 gpm, 2,600 psi and 50 rpm's 10:00 - 10:45 0.75 DRILL LOT INTRM1 RU and performed LOT to 14.7 ppg EMW, 1,030 psi, 3.729' TVD with 9.35 ppg MW 10:45 - 11 :45 1.00 DRILL OTHR INTRM1 RU on 75/8" x 10 3/4" annulus with rig pump, pressured up to 3,500 psi and attempted to break down annulus with no success, Note: on 10/3/04 had pumped 6 bbls down annulus 7 hrs after GIP, At 16:00 hrs RU little Red and attempted to pump down annulus, after 2 hrs was able to pump 1 bbl into annulus, after next 2 1/2 hrs was only able to pump 0.8 bbl, shut down Little Red at 20:30 hrs 11:45 -18:15 6.50 DRILL DRLG PROD Directionally drilled 63/4" hole from 8,761' to 9.321' MD/3,755' (560') ART 2.6 hrs, AST 1.2 hrs, 2-5K wob, 80-120 rpm's, 75 spm, 318 gpm, off btm pressure 2,900 psi, on btm 3,000 psi, off btm torque 6K, on btm 5.5K ft-Ibs, rot wt 85K, up wt 136K, dn wt 63K, clean hole EGO with 9.35 ppg OBM was 11.4 ppg, EGO while drlg with 9.35 OBM ave 11.5 ppg, ave BGG 250 units, max gas 517 units, Est top of West Sak A2 sand 8,769' MD/3,730' TVD 18:15-20:00 1.75 DRILL DEQT PROD Trouble shoot MWD due to poor decoding, adjusted flow rates and surged pipe and after surging pipe several times, tool began to pulse, no sweeps had been pumped when problem occured, earlier had bad decoding but was able to drill ahead 20:00 - 00:00 4.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole from 9,321' to 9,605' MD/3,738' (284') ART 1 hr, AST 1.1 hrs, 2-5K wOb, 100-120 rpm's, 75 spm, 318 gpm, off btm pressure 2,900 psi, on btm 3,000 psi, off btm torque 6K, on btm 5.5K ft-Ibs, rot wt 84K, up wt 142K, dn wt 57K, 9.3 ppg OBM, ave ECD 11.4 ppg, ave BGG 250 units 10/5/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" "A" sand lateral from 9,605' to 10,475' MD/ 3,769' TVD (870'), ART 4.3 hrs, AST 2.6 hrs, 2-1 OK wob, 120 rpm's, 75 spm, 318 gpm's, off btm pressure 2,900 psi, on btm 3,100 psi, off btm torque 6K ft-Ibs, on btm 5.5K ft-Ibs, rot wt 85K, up wt 150K, dn wt 50K, 9.3 ppg OBM, aye ECD 11.45 ppg, ave BGG, 275-300 units 12:00 - 00:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" "A" sand lateral from 1 0,475' to 11,323' MD/ 3,748' TVD (848'), ART 3.3 hrs, AST 3.4 hrs, 2-15K wob, 120 rpm's, 75 spm, 318 gpm's, off btm pressure 3,150 psi, on btm 3,300 psi, off btm torque 7K ft-Ibs, on btm 7K ft-Ibs, rot wt 84K, up wt 170K, dn wt 48K, 9.3 ppg OBM, ave ECD 11.8 ppg, ave BGG, 275-300 units, max gas 425, began running push pipe at 11,274' 10/6/2004 00:00 - 07:00 7.00 DRILL DRLG PROD Directionally drilled 6 3/4" "A" sand lateral from 11,323' to 11,857' MD/ 3,788' TVD (534'), ART 3.8 hrs, AST .6 hrs, 2-15K wob, 120 rpm's, 75 spm, 318 gpm's, off btm pressure 3,500 psi, on btm 3.600 psi, off btm torque 7K ft-Ibs, on btm 6.5K ft-Ibs, rot wt 98K, up wt 182K, dn wt 58K, 9.3 ppg OBM, ave ECD 11.9 ppg, aye BGG, 275 units, began running push pipe at 11,274' 07:00 - 08:45 1.75 DRILL CIRG PROD Pumped weighted hi vis sweep and circ hole clean, circ at 318 gpm, 3,600 psi and 120 rpm's, had no increase in cuttings from sweep 08:45 - 09:00 0.25 DRILL OBSV PROD Monitored well-static 09:00 - 13:30 4.50 DRILL REAM PROD Backreamed out of hole at drlg rate from 11,857' to 8,730' to 7 5/8" csg shoe with no problems, 120 rpm's, 320 gpm, 2,900 psi 13:30 - 15:00 1.50 DRILL GIRC PROD Pumped weighted hi vis sweep and circ hole clean, circ at 320 gpm, 2,800 psi and 80 rpm's, had no increase in cuttings from sweep, circ 3X Printed: 11/12/2004 11 :23:10 AM . . Legal Well Name: 1E-114 Common Well Name: 1E-114 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Oöde SUP Code 10/6/2004 13:30 - 15:00 1.50 DRILL CIRC PROD 15:00 - 15:15 0.25 DRILL OBSV PROD 15:15 - 20:00 4.75 DRILL TRIP PROD 20:00 - 22:00 2.00 DRILL PULD PROD 22:00 - 23:15 1.25 RIGMNT RSRV CMPL TN 23:15 - 00:00 0.75 WAlTON EQIP CMPL TN 10/7/2004 00:00 - 02:30 2.50 LOG RURD CMPL TN 02:30 - 07:00 4.50 LOG ELOG CMPL TN 07:00 - 09:00 2.00 LOG RURD CMPL TN 09:00 - 09:30 0.50 DRILL PULD CMPL TN 09:30 - 13:00 3.50 DRILL TRIP CMPLTN 13:00 - 15:00 2.00 DRILL TRIP CMPL TN 15:00 - 16:00 1.00 DRILL CIRC CMPL TN 16:00 - 17:45 1.75 DRILL CIRC CMPL TN 17:45 - 20:15 2.50 DRILL TRIP CMPL TN 20:15 - 20:30 0.25 DRILL OBSV CMPL TN 20:30 - 23:30 3.00 DRILL TRIP CMPL TN 23:30 - 00:00 0.50 DRILL PULD CMPL TN 10/8/2004 00:00 - 01 :15 1.25 DRILL PULD CMPL TN 01 :15 - 02:00 0.75 CASE RURD CMPL TN 02:00 - 05:00 3.00 CASE PULR CMPL TN Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: Description of btms up and clean at shakers, st up wt 140K, dn wt 65K Monitored well-static POOH from 8,730' to BHA #5 at 252', SLM no corr Stood back std of HWDP, jars and Flex DC's, download MWD and LD MWD/LWD and motor, cleared rig floor Serviced top drive and drawworks while waiting on Schlumberger wireline, wire line unit was stuck behind rig move at KUP river bridge Waited on Schlumberger wireline unit. rig crew changed out air boot on riser, wireline unit arrived location at 00:00 hrs RU Schlumberger Wireline, MU US IT logging tool with Welltec's tractor tool, Held PJSM with SWS and rig crew RIH with US IT bond log, RIH to 8,630' without having to turn tractor tool on, logged up to 3,000' and POOH, had exceptable bond, est TOC @ 3,250' LD logging tools and RD Schlumberger, cleared rig floor MU BHA #6,6118" hole opener and RIH to 141' RIH from 141' to 8,730' to csg shoe, est circ to fill pipe, 300 gpm, 2,000 psi, rot wt 84K, up wt 128K, dn wt 60K, 80 rpm's with 6.5K ft-Ibs torque NOTE: Rig and Camp off highline from 09:45 to 11 :30 hrs TIH from 8,730' to 11,857', no problems RIH to btm Circ hole clean with 9.3 ppg OBM, circ at 300 gpm, 3,000 psi, 120 rpm's, 6K ft-Ibs torque, rot wt 99K, up wt 160K, dn wt 60K Changed hole over from 9.3 ppg OBM to 9.3 ppg solids free OBM, circ at 318 gpm, 2,850 psi, monitored well-static POOH from 11,857' to 8,668', no problems or swabbing Monitored well at shoe-static, dropped 1 3/4" rabbit on a wire POOH from 8,668' to BHA #6 to 141' POOH, LD 2 jts of HT-38 HWDP and jars, LD 61/8" hole opener, calc fill on trip out 75 bbls, actual fill 86 bbls PU and stood back 9 jts of 4" XT-39 HWDP and cleared rig floor RU to run 41/2" liner and held PJSM with rig crew PU and ran 4 1/2" liner per well program, ran 41/2" ROT silver bullet guide shoe with no float, 92 jts w/1-pup jt, (3,225') of 41/2" 12.6#, L-80, DWC liner, placed blank liners across shale sections per geology, ran 51 jts (1,591 ') of blank liner and 41 jts (1,634') of slotted liner, ran 1- 4 1/2" x 6 1/4" spiralglide centralizer 1/jt to csg shoe (86 total) ran 9 restrictor packers with 18 spacer rings placed on blank liner to isolate shale sections per geology. 1.00 CASE PULR CMPL TN MU Baker 190-47 csg seal bore ext, 5 1/2" x 7 5/8" Flexlock liner hanger, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 3,298' 6.00 CASE RUNL CMPL TN RIH with liner assembly to 8,719', (csg shoe) est circ at 4 bpm, 550 psi, then rotated liner at 10 rpm's with 5.5K ft-Ibs torque, rot wt 80K, up wt 115K, dn wt 62K, having to screw into each std to keep mud from running over 3.00 CASE RUNL CMPL TN Cont to run 4 1/2" liner in open hole, RIH from 8,719' and tagged btm at 11,857' with no problems, PU to 11,856', st wt up 163K, dn wt 70K 1.00 CASE OTHR CMPL TN Dropped 1 7/16" ball and pumped down to seat, pump at 4 bpm at 975 psi, with ball on seat pressured up to 2,000 psi to set Flexlock hanger, bled off the pressure, cont to set packer, pressured up to 4,200 psi and set ZXP packer, no problems setting hanger/packer, set "A" sand liner with TOL @ 8,569' MD/3,696' TVD and shoe at 11,856', st wt up after setting liner 145K, lost 18K wt 05:00 - 06:00 06:00 - 12:00 12:00 - 15:00 15:00 - 16:00 Printed: 11/12/2004 11:23:10AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-114 1 E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 1 0/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: RU & tested 7 5/8" csg and ZXP packer to 1,000 psi for 5 min, good test PU out of SBE 33' and circ btms up, circ at 7.5 bpm at 2,500 psi Monitored well-static POOH wet and LD Baker setting tool, SLM out, no corr, calc fill on trip out 59 bbls, actual fill 67 bbls, cleared rig floor Began MU whipstock assembly, PU whipstock and broke out btm trip anchor and LD whipstock, MU milling assembly and LD same, PU seal assembly, locator sub, 3 1/2" DP pup jt, unloader sub, then PU 10 jts 3 1/2" DP RIH to 327' with seal assembly 2.50 WINDO PULD CMPL TN Fin MU whipstock BHA #7, RIH from 327', PU a total of 24 jts of 3 1/2" DP for space out, 7 5/8" btm trip whipstock, milling assembly with MWD, oriented MWD and RIH with 3 stds 4" HWDP and 9 stds of 4" push pipe to 1,158' CMPL TN Shallow tested MWD and tool ck ok CMPL TN RIH with whipstock from 1,158' to 7,820' CMPL TN Made MADD pass from 6,970' to 7,000' (sensor depth) and correlated MWD to K-13 sand CMPL TN RIH with whipstock from 7,850' to 8,520' CMPL TN Oriented whipstock to 13 deg left of high side, RIH, tagged TOL at 8,569', set whipstock and sheared off from same, st wt up 137K dn wt 64K CMPL TN Displaced out 9.3 ppg solids free OBM with used 9.3 ppg OBM CMPL TN Milled window in 75/8" csg, top of window at 7,778', btm of window at 7,790', drilled 6 3/4" hole to 7,809' MD (31'), 2-6K wOb, 80-120 rpm's, 270-310 gpm. 2,800 psi, rot wt 85K, up wt 137K, dn wt 65K, 6-8K ft-Ibs torque Circ hi vis sweep and circ hole clean, circ at 310 gpm at 2,800 psi, worked mills thru window with no problem Monitored well-static, pumped dry job POOH from 7,809' to BHA #7 at 1,189', monitored well-static LD 3 jts of 4" HWDP, stood back 2 stds HWDP and 9 stds push pipe, LD MWD and milling assembly, upper mill was in gauge, cleared rig floor Pulled wear bushing and flushed out stack RU and began testing BOPE, testing valves, manifold and rams to 250 psi low and 3,500 psi high, tested annular to 250 psi low and 2,800 psi high. NOTE: John Crisp with AOGCC waived witnessing of test Fin. testing BOPE, valves, manifold and rams to 250 psi low and 3,500 psi high, Note John Crisp W/AOGCC waived witnessing of test Installed wear bushing Changed out 4" Xt-39 saver sub on top drive MU 6 3/4" BHA #8 with Autotrak tool and uploaded, PU std of flex DC's and MU std of XT 39 HWDP with jars RIH to 240' RIH with BHA #8 from 240' to 7,714', shalllow tested MWD at 2,295' and ck ok Slip and cut 75' of drlg line, serviced top drive and drawworks RIH from 7,714', washed down from top of window at 7,778' to btm at 7,809', no problems going thru window Drilled 6 3/4" hole with AutoTrak tool in "B" Sand lateral from 7,809' to 9,000' MOl 3,581' TVD, (1,191'), ADT 8.4 Hrs, 5-15K wob, 120-150 rpm's, 75 spm, 318 gpm, off btm pressure 3,250 psi, on btm 3,325, off btm torque, 7.5K ft-Ibs, on btm 6.5K ft-Ibs, rot wt 83K , up wt 137K , dn wt 59K, 9.3 ppg OBM in hole, (clean hole ECD =11.4 ppg) ave ECD 11.7 ppg, ave BGG 260 units, max gas 482 units 10/8/2004 16:00 -16:15 0.25 CASE DEQT CMPLTN 16:15 -17:15 1.00 DRILL CIRC CMPL TN 17:15 -17:30 0.25 DRILL OBSV CMPL TN 17:30-22:15 4.75 DRILL TRIP CMPL TN 22: 15 - 00:00 CMPL TN 10/9/2004 00:00 - 02:30 02:30 - 03:00 03:00 - 07:30 07:30 - 08:15 08:15 - 09:00 09:00 - 10:00 10:00 -10:30 10:30 -15:15 15:15 -16:00 CMPL TN 16:00 -16:15 CMPL TN 16:15 -18:30 CMPL TN 18:30 - 20:30 CMPL TN 20:30 - 21 :30 1.00 WELCTL OTHR CMPL TN 21 :30 - 00:00 2.50 WELCTL BOPE CMPL TN 10/10/2004 00:00 - 01 :30 1.50 WELCTL BOPE CMPL TN 01 :30 - 02:00 0.50 DRILL OTHR CMPL TN 02:00 - 03:00 1.00 RIGMNT RSRV CMPL TN 03:00 - 06:00 3.00 DRILL PULD PROD2 06:00 - 09:15 3.25 DRILL TRIP PROD2 09:15 - 10:15 1.00 RIGMNT RSRV PROD2 10:15 -11 :00 0.75 DRILL REAM PROD2 11 :00 - 00:00 13.00 DRILL DRLG PROD2 Printed: 11/12/2004 11:23:10AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n 1334@ppco.com Doyon 141 Sub Code Phase 10/11/2004 00:00-01:15 1.25 DRILL DRLG PROD2 01 :15 - 02:15 1.00 DRILL DEQT PROD2 02:15-03:15 1.00 DRILL DRLG PROD2 03:15 - 03:45 0.50 DRILL CIRC PROD2 03:45 - 06:00 2.25 DRILL REAM PROD2 06:00 - 07:00 1.00 DRILL CIRC PROD2 07:00 - 07:15 0.25 DRILL OBSV PROD2 07:15 -10:15 3.00 DRILL TRIP PROD2 10: 15 - 11: 15 1.00 DRILL PULD PROD2 11 : 15 - 13:00 1.75 DRILL PULD PROD2 13:00 - 18:00 5.00 DRILL TRIP PROD2 18:00 - 21 :15 3.25 DRILL DRLG PROD2 21 :15 - 22:30 1.25 DRILL DEQT PROD2 22:30 - 00:00 1.50 DRILL DRLG PROD2 10/12/2004 00:00 - 00:30 0.50 DRILL DEQT PROD2 00:30 - 01 :30 1.00 DRILL REAM PROD2 01 :30 - 03:00 1.50 DRILL TRIP PROD2 03:00 - 04:00 1.00 DRILL CIRC PROD2 04:00 - 07:30 3.50 DRILL TRIP PROD2 07:30 - 08:15 0.75 DRILL PULD PROD2 08:15 - 09:15 1.00 DRILL PULD PROD2 09:15 -10:15 1.00 DRILL PULD PROD2 10:15 -12:00 1.75 DRILL TRIP PROD2 12:00 - 13:45 1.75 DRILL TRIP PROD2 13:45 - 14:30 0.75 DRILL REAM PROD2 14:30 - 16:30 2.00 DRILL REAM PROD2 Start: Rig Release: Rig Number: 9/25/2004 1 0/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: Drilled 6 3/4" hole with AutoTrak tool from 9,000' to 9,113' MD/3.582' lVD, ADT .5 hrs Trouble shoot AutoTrak tool, unable to get pressure to ribs, to attempt to drill ahead in hold mode Drill from 9,113' to 9,206' MD/3,583'lVD (931 ADT 1 hr, 5-15K wOb, 150 rpm's, 318 gpm, on btm pressure 3,300 psi, off btm 3,300 psi, off btg torque 8K ft-Ibs, on btm 8K, rot wt 82K, up wt 136K, dn wt 63K, determined hydraulic seal on ribs of AutoTrak tool failed Downliked autoTrak to ribs off, got SPR's, monitored well-static Backreamed out from 9,206' to 7,714', backreamed out to above window at 7,778' at 120 rpm's, 318 gpm at 3,000 psi Circ hole clean at 318 gpm at 2,800 psi, 90 rpm's Monitored well-static POOH from 7,714' to 48' to AutoTrak tool, stood back HWDP, jars and flex Dc's, Downloaded AutoTrak tool and LD same MU BHA #9 with new AutoTrak tool, uploaded tool and RIH to 240' with flex dc's, jars and HWDP RIH from 240' to 9,116', washed 90' to btm at 9,206' with no problems RIH or going thru window Drilled from 9,206' to 9,580' MD/3,589'lVD (374') ADT 1.7 hrs Trouble shoot the ontrak survey package of AutoTrak tool, found the X-axis of the MAG package was bad, decided to drill ahead and survey eliminating X-axis Drilled from 9,580' to 9,673' MOl 3,590' lVD, (93') ADT 1.1 hrs, 5-15K wob, 150 rpm's, 318 gpm, off btm pressure 3,300 psi, on btm 3,300 psi, off btm torque 6.5K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 82K, up wt 135K, dn wt 56K, 9.3 ppg OBM, ave ECD 12.1 ppg, ave BGG 275 units, max gas 459 units. Note: Decision was made after taking survey that too much time would be required to get good survey, preparing to POOH and PU mud motor to drill lateral Trouble shoot the Ontrak survey package of the AutoTrak tool. Down link, ribs off. Take Slow pump rates, monitor well. Back ream out from 9,673' - 9,206' at 120 RPM and 315 GPM. POOH on elevators from 9,206' to 7,714' (pass thru window wlo problems). Circulate btms up at 75 SPM, 2,800 psi. Monitor well, pump dry job. POOH on elevators to 56', lay down stabilizer and float sub. Download MWD data, break bit, make service breaks, lay down AutoTrak and MWD. PU and MU Motor assembly, set AKO at 1.2 deg. Check connection torque on MWD/LWD and motor. Plug in and upload MWD. RIH to 2,584', shallow test MWD at 75 stks 1,759 psi, continue RIH to 3,892'. RIH to 7,723', orient toolface and pass thru window wlo problems. RIH to 8,564'. Wash and Ream from 8,564' - 8,844' at 60 SPM, 2000 psi, 40 rpm, 6,000 ft-Ib. Wash and Ream from 8,844' - 9,673' at 80 SPM, 2150 psi, 80 rpm, 7,000 ft-Ib. Took survey check shots at 9,218'. 9,311', 9,405', 9,498', 9,592'. Printed: 11/12/2004 11 :23:10 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: 10/12/2004 16:30 - 00:00 7.50 DRILL DRLH PROD2 Drill horizontal B-Lateral section f/9,673' to 10,420' MD - 3,597' TVD ADT - 3.8 hrs. = ART - 3.2 hrs. AST - 0.6 hrs. WOB 2-8 RPM 120 GPM 318 w175 spm @ 3,125 psi String wt. PU 137 SO 56 Rot 82 Torque onloff btm - 8,000 I 7,500 ft-Ib 10/13/2004 00:00 - 12:00 12.00 DRILL DRLH PROD2 Drill horizontal B-Lateral section f/1 0,420' to 11,460' MD - 3,592' TVD ADT - 6.2 hrs. = ART - 4.3 hrs. AST - 1.9 hrs. WOB 2-7 RPM 120 GPM 315 wI 75 spm @ 3,350 psi String wt. PU 165 SO 35 Rot 83 Torque on/off btm - 8,000 18,000 ft-Ib 12:00 - 14:15 2.25 DRILL DRLH PROD2 Drill horizontal B-Lateral section f/11 ,460' to 11,570' MD WOB 2-9 RPM 110-120 GPM 315 wI 75 spm @ 3,425 psi String wt. PU 166 SO 57 Rot 86 Torque on/off btm - 8,000 18,500 ft-Ib 14:15 - 15:15 1.00 DRILL DEOT PROD2 Downlink MWD/LWD. Decoding problem. Bump up mud pump dampner pressure to 1,000 psi. 15:15 -16:15 1.00 DRILL DRLH PROD2 Drill ahead 11,570' - 11,630'. 16:15 - 17:30 1.25 DRILL DEOT PROD2 MWD was not decoding properly. Reduced dampner pressure to 750 psi and had no success. Reduced dampner pressure to 450 psi and down linked MWD. 17:30 - 20:00 2.50 DRILL DRLH PROD2 Drill horizontal B-Lateral section f/11 ,460' to 11,841' MD - 3,611' TVD ADT - 2.9 hrs. = ART - 2.0 hrs. AST - 0.9 hrs (for tower). WOB 2-9 RPM 120 GPM 315 wI 75 spm @ 3,425 psi String wt. PU 158 SO 60 Rot 92 Torque on/off btm - 9,000 19,000 ft-Ib 20:00 - 21 :45 1.75 DRILL CIRC PROD2 Pump weighted HI-VIS sweep and circ out at 74 spm and 3,700 psi, 10 rpm. Monitor well - static. 21 :45 - 00:00 2.25 DRILL REAM PROD2 BROOH from 11,841' to 10,340' at drilling rate wlo probs. 10/14/2004 00:00 - 03:45 3.75 DRILL REAM PROD2 BROOH from 10,340' - 8,003', at drilling rate, wlo probs. 03:45 - 04:15 0.50 DRILL TRIP PROD2 Pull 25K over at the hard spot 41' outside of the window. Oriented to 13L of high side and pulled 10-15K over thru hard spot. Worked up and down from 7,831 '_7,816' wlo pumps and pulled into the 7-5/8" csg. 04:15 - 05:30 1.25 DRILL CIRC PROD2 Pump 30 bbl weighted Hi-Vis sweep and circ clean at 75 spm and 2,300 psi. 05:30 - 05:45 0.25 DRILL OBSV PROD2 Orient to high side and monitor well. 05:45 - 08:30 2.75 DRILL TRIP PROD2 Trip in hole to 9,200' wlo problems. Wash and ream thru tight spots, and work thru 3 additional times. Cont. RIH to 11,841' TO wlo probs. 08:30 - 09:30 1.00 DRILL CIRC PROD2 CBU at 11,841' at 70 spm and 3,450 psi. 09:30 - 11 :00 1.50 DRILL CIRC PROD2 Swap over to solids free OBM at 70 spm and 3,350 psi. 11 :00 - 12:00 1.00 DRILL OBSV PROD2 Take slow pump rates, monitor well, POOH on elevators to 11,180'. 12:00 - 14:15 2.25 DRILL TRIP PROD2 POOH from 11,180' - 7,680' wlo probs. Monitor well above window - static. 14:15-17:00 2.75 DRILL TRIP PROD2 POOH on elevators from 7,680'-248'. Monitor well - static, 17:00 - 18:30 1.50 DRILL OTHR PROD2 Rack back HWDP, Jars, and NMCSDP. Download MWD. Break bit, LD Motor/MWD. 18:30 - 20:30 2.00 CMPL TN PULD CMPL T2 PU whipstock retrieving tools, 1 jt 3-1/2" HWDP, F/S, Bumper sub and Oil Jars + 11 DCs. 20:30 - 23:00 2.50 CMPL TN TRIP CMPL T2 RIH to 7,790'. 23:00 - 00:00 1.00 CMPL TN OTHR CMPL T2 Wash whipstk slot and attempt to hook, turn 90 deg and wash, make several attempts. 10/15/2004 00:00 - 00:30 0.50 CMPL TN OTHR CMPL T2 Hook whipstock, shear trip anchor, pull 80K over. 00:30 - 02:00 1.50 CMPL TN CIRC CMPL T2 Circulate btms up 1.5x at 50 spm and 1,200 psi. 02:00 - 07:00 5.00 CMPL TN TRIP CMPL T2 Monitor well, blow down Top Drive and POOH to 430'. Monitor well. Printed: 11/12/2004 11:23:10AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 1 0/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: 10/15/2004 07:00 - 08:30 1.50 CMPL TN PULD CMPLT2 08:30 - 09:45 1.25 CASE PULR CMPLT2 09:45 - 10:00 0.25 CASE SFTY CMPL T2 10:00 - 12:00 2.00 CASE RUNL CMPL T2 12:00 -13:15 1.25 CASE RUNL CMPL T2 13:15 -13:45 0.50 CASE RUNL CMPL T2 13:45 - 16:30 2.75 CASE RUNL CMPL T2 16:30 - 21 :30 5.00 CASE RUNL CMPL T2 21 :30 - 00:00 2.50 CASE RUNL CMPL T2 10/16/2004 00:00 - 00:30 0.50 CASE RUNL CMPLT2 00:30 - 02:00 1.50 CASE RUNL CMPLT2 02:00 - 06:00 4.00 DRILL TRIP CMPL T2 06:00 - 10:00 4.00 RIGMNT RGRP CMPLT2 10:00 - 10:45 0.75 CASE PUTB CMPL T2 10:45 - 11 :00 0.25 CASE SFTY CMPLT2 11 :00 - 12:00 1.00 CMPL TN PULD CMPL T2 12:00 - 13:00 1.00 CASE PULR CMPL T2 13:00 - 17:30 4.50 CASE RUNL CMPL T2 17:30 - 20:00 2.50 CASE RUNL CMPL T2 20:00 - 00:00 4.00 CASE OTHR CMPL T2 10/17/2004 00:00 - 02:45 2.75 CASE OTHR CMPLT2 02:45 - 04:30 1.75 CASE RURD CMPL T2 04:30 - 05:00 0.50 CASE RURD CMPL T2 05:00 - 06:00 1.00 CASE RURD CMPL T2 06:00 - 08:00 2.00 RIGMNT RSRV CMPL T2 08:00 - 12:00 4.00 WELCTL BOPE CMPL T2 12:00 - 12:30 12:30 - 14:30 0.50 WELCTL BOPE CMPL T2 2.00 CASE RURD CMPL T2 cription of Operations LD Jars, Bumper sub, Retrieving tool, whipstock, 9x 3-1/2" DP, Trip anchor, 13 x 3-1/2" space out DP, seal assembly. Clean rig floor, LD Baker tools, PU casing tools and RU to run liner. PJSM wI Company Rep, rig crew, csg hand for running 4-1/2" liner. PUlMU bent 3-1/2" bent joint with Baker guide shoe, packoff bushing. RIH wI 2,522' of 4-1/2", 12.6Ib/ft, L-80, DWC blank I slotted liner with 32x 2.5" x 0.125 slots/ft with 4 circumfrential adjacent rows, staggered 18 degrees. Restrictor packers at 11,516' and 11,255', with blank liner joints between. Spiraglider centralizers (4-112" x 6-1/4"), free floating - 1 per joint, on joints #3 - #126. Average MU torque for liner was 6,300 ft-Ib. Run a total of 128 liner joints, MU Baker 7-518" x 4-1/2", Model B1 Flanged Hook Hanger, with hanger running tool. RD casing equipment. MU liner hanger and RD casing equipment RIH on DP to top of window at 7,778'. Orient and make 5 attempts to get bent joint through the window. PU and rotate on each pass. RIH to 11,771' and prep to hook the hook hanger. UP=155K, DWN=75K. RIH to 11,803', pass thru window and RIH an additional 10'. PU and hook hanger. Unhook and rehook to verify. Drop ball and pump down at 4 BPM and 1,000 psi. Seat ball and pressure up to 3,000 psi to release. PU to verify, was not released. Re-hook hanger and pressure up to 4,000 psi. PU to verify, not released. Re-hook hanger. RU test pump, and pressure up to 4,600 psi - released from hanger. Note: pinned for 2,500 psi. Blow down TD, POOH, make service breaks, LD liner running tool. Change out upper IBOP valve on Top Drive, test to 3,500 psi. RU casing equipment, clear rig floor. PJSM for running 4-112" liner. PU Baker seal assembly. RIH with 10 jts 4-1/2:, 12.6 Iblft, L-80 tbg. Continue to MU LEM assembly. RIH with LEM assembly on DP to 8,602' Attempt to stab into seal bore receptacle without success. Work pipe setting down 25K, and PU without any drag. POOH with LEM assembly. Continue POOH with LEM assembly. LD LEM, rack back 7 stds of 4-1/2" tbg in the derrick. RD casing equipment, clean rig floor. PU Baker Fishing tools, double stacked tubing tongs. MU Baker reverse circulating basket with 3-3/4" shoe. Cease RU fishing assembly after receiving confirmation of tool 10 restriction in the profile of the ZXP packer. Make service breaks, RD Baker fishing tools and power tongs. PJSM, Slip and Cut 97' of drill line. Service Top Drive and drawwork brakes. Pull Wear Bushing. RU and tested BOPE, choke manifold, 4" and 5" floor valves, rams excluding btm 7-5/8" csg rams to 250 psi low and 3,500 psi high, annular to 250 psi low and 3,500 psi high. Tested rig alarm system. Jeff Jones with AOGCC waived witnessing of test Install WB. PJSM and MU LEM assembly. Printed: 11/12/2004 11:23:10AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: Description of Operations 10/17/2004 14:30 - 19:00 4.50 CASE RURD CMPL T2 RIH with new space out joint and seal assembly +LEM I ZXP pkr assembly, on DP to 8,610'. UWT= 145K, DWT=85K. 19:00 - 19:30 0.50 CMPL TN PCKR CMPL T2 Drop 1-3/4" ball, and pump down at 4 BPM. Set 40K Ib down and pressure up to 3,500 psi and pressure bled back to +1- 2,000 psi, bumped pressure back up to 3,500 psi setting down 40K. The drill string moved down +1- 3'. Set packer. 19:30 - 20:00 0.50 CMPL TN DEQT CMPL T2 Close Annular preventor, test and chart liner top pkr to 1,000 psi for 5 min. - okay. Bleed off. 20:00 - 21 :00 1.00 CMPL TN CIRC CMPL T2 Circ btms up at 7,625' and monitor well. 21 :00 - 00:00 3.00 CMPL TN TRIP CMPL T2 POOH to 310'. 10/18/2004 00:00 - 01 :00 1.00 CMPL TN PULD CMPL T2 Finish POOH, LD LEM running tools (no damage seen). Clean rig floor. PU Baker milling assembly. 01 :00 - 02:30 1.50 WINDO CMPL T2 MU mill assembly, whipstock, seal assembly, 3 joints 3-1/2" HWDP, trip anchor, MWD, Bumper Sub, Oil Jar. 02:30 - 03:00 0.50 WINDO CMPL T2 Orient whipstock to MWD. 03:00 - 04:15 1.25 WINDO CMPL T2 RIH, PU 3 joints of 4" HWDP, to 1,824'. Shallow test MWD. 04:15 - 08:30 4.25 WINDO CMPL T2 Cont. RIH to 7,289', Log K-13 sands 7,289' - 7,309'. 08:30 - 09:30 1.00 WINDO CMPLT2 RIH to 7,709', orient whipstock 1 OL deg of high side. UWT=135K, DWT= 63K 09:30 - 09:45 0.25 WINDO CMPL T2 Set whipstock, shear off. 09:45 - 10:30 0.75 WINDO CMPL T2 Displace solids free OBM to treated 9.3 ppg drilling OBM fluid. 10:30 - 12:00 1.50 WINDO CMPL T2 Mill window from 7,465' ROT=80K, Torque on = 5-8,000 ft-Ib. 12:00 -15:00 3.00 WINDO CMPL T2 Continue milling window to 7,489' Note: TOW=7,465', BOW=7,479'. 15:00 - 16:00 1.00 WINDO CMPL T2 Pump Hi-Vis sweep, circ hole clean, monitor well. 16:00 - 20:00 4.00 WINDO CMPL T2 POOH. 20:00 - 20:30 0.50 WINDO CMPL T2 Wash out stack and clean rig floor. 20:30 - 21 :00 0.50 DRILL PROD3 PU/MU bit, 1.2 deg motor and MWD. 21 :00 - 22:00 1.00 DRILL PROD3 Upload MWD and orient. 22:00 - 00:00 2.00 DRILL PROD3 RIH with 6-3/4" motor + MWD drilling assembly to 3,708'. 10/19/2004 00:00 - 01 :30 1.50 DRILL PROD3 Continue RIH f/3,708' to 7,445': 01 :30 - 02:15 0.75 DRILL PROD3 Orient thru window @ 7,465' to 7,477', Wash & Ream down to 7,489' 02:15 -12:00 9.75 DRILL PROD3 Drill 6-3/4" Lateral 'D' Section fl 7,489' to 8,230' MD 3,513' TVD (741 '), ART 3.8 hrs, AST 1.8 hrs, UP 120K, ON 60K, Rot 80K, 315 gpm @ 2450 psi, 2/15K WOB, 120 RPM, Arrived clean hole ECD's from PWD 11.3 ppg, Ave ECD's 11.4 ppg, Max gas 234 units. 12:00 - 00:00 12.00 DRILL DRLH PROD3 Drill 6-3/4" Lateral '0' Section f/8,230' to 9,357' MD 3,538' TVD (1,127'), ART 6.7 hrs, AST 1.4 hrs, UP 135K, ON 55K, Rot 80K, 315 gpm @ 2550 psi, 5/15K WOB, 90/120 RPM, Ave ECD's 11.5 ppg, Max gas 285 units. 10/20/2004 00:00 - 12:00 12.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral '0' Section f/9,357' to 10,432' MD, 3536' TVD (1075'), ART 5.4 hrs, AST 2.1 hrs, UP 140K, DN 49K, Rot 80K, 315 gpm @ 2800 psi, 5/15K WOB, 120 RPM, Torq on bttm 8 k I off 8.5 k ,Arrived clean hole ECD's from PWD 11.3 ppg, Ave ECD's 11.5 ppg, Max gas 306 units. 12:00 - 00:00 12.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral '0' Section f/10,432' to 11619' MD, 3550' TVD (1187'), ART 6.9 hrs, AST 1.3 hrs, UP 157K, ON 53K, Rot 90K, 315 gpm @ 2950 psi, 2/10K WOB, 120 RPM, Torq on bttm 10 k 1 off bttm 10 k ,Arrived clean hole ECD's from PWD 11.3 ppg, Ave ECD's 11.6 ppg, Max gas 286 units. 10/21/2004 00:00 - 03:00 3.00 DRILL DRLH PROD3 Drill 6-3/4" Lateral '0' Section f/11 ,619' to 11,833' MD, 3539' TVD (214'), ART 1.5 hrs, AST 0.4 hrs, UP 170K, ON 50K, Rot 95K, 315 gpm @ 3500 psi, 2/14K WOB, 120 RPM, Torq on bttm 10K I off bttm 10K, Ave ECD's 12.0 ppg, Max gas 393 units, Pump weighted Hi-vis sweep Printed: 11/12/2004 11 :23:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-114 1 E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 1 0/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: Description of Operatìons 10/21/2004 00:00 - 03:00 3.00 DRILL DRLH PROD3 on last connection. 03:00 - 04:15 1.25 DRILL CIRC PROD3 Finish pumping out Hi-vis sweep (Increase in cuttings 20%). 04:15 - 04:30 0.25 DRILL OBSV PROD3 Survey, Record slow pump rates, Monitor well. 04:30 - 10:30 6.00 DRILL TRIP PROD3 Back Ream out of hole at drilling rate to 7,725', Pulling speed 45 to 55 ftImin., Pull thru window with no problems. 10:30 - 12:00 1.50 DRILL CIRC PROD3 Pump weighted Hi-vis sweep, Circ hole clean at 315 gpm @ 2350 psi. 12:00 - 15:00 3.00 DRILL TRIP PROD3 RIH f/7,725' to 11,800', Wash f/11 ,800' to 11,833'. 15:00 - 17:00 2.00 DRILL CIRC PROD3 Circ at rate of 315 gpm @ 3400 psi, Change over to Solids free MOBM. 17:00 - 20:30 3.50 DRILL TRIP PROD3 Monitor well, POOH on elevators to 7,725', No problems 20:30 - 20:45 0.25 DRILL OBSV PROD3 Monitor well- OK. 20:45 - 00:00 3.25 DRILL TRIP PROD3 POOH to BHA @ 251 '. 10/22/2004 00:00 - 02:00 2.00 DRILL PULD PROD3 Lay down 2 jts. HWDP & Jars, 1 stand NMDC's., Down load MWD tools, Lay down MWD tools, Motor & Bit. 02:00 - 03:00 PULD CMPL T3 Make up Baker whipstock retrieving tools, RIH wI 4-3/4" DC's. 03:00 - 06:00 TRIP CMPL T3 RIH to 7,403', Record UP 137K, ON 80K, Break circ. 06:00 - 06:30 OTHR CMPL 13 Hook whipstock on 2nd attempt on depth @ 7,471', Pull 60K over and unseat trip anchor, Pull up to 7,403'. 06:30 - 07:30 1.00 WINDO CIRC CMPL T3 Circ btm's up at rate of 8 bpm @ 2750 psi. 07:30 - 13:00 5.50 WINDO TRIP CMPL T3 POOH to BHA. 13:00 - 15:00 2.00 WINDO PULD CMPL T3 Lay down whipstock retrieving tools, whipstock and space out pipe. 15:00 - 16:00 1.00 CASE RURD CMPL T3 Clean rig floor, Rig to run 4-1/2" Slotted liner. 16:00 -19:30 3.50 CASE PULR CMPL T3 Run 3-1/2" Shoe & Bent joint, XlO's, Total of 61 joints Blank (1,891.52') and every other joint Slotted with total of 59 joints (2,387.58'), Last 2 joints Blank, Ran total of 120 joints, Ran total of 118 6-1/2" x 4-1/2" Spiralgliders 1 per joint for 118 joints. 19:30 - 21 :30 2.00 CASE RUNL CMPL T3 Make up Baker Model B1 Flanged Hook Hanger, RIH w. liner to top of window @ 7,465'. 21 :30 - 21 :45 0.25 CASE RUNL CMPL 13 Break eire, Record UP wt of 97K, ON 60K, Torque at 10 RPM 3500 fUlb, Attempt to rotate at 10 RPM while lowering down past window, RIH & tag down on lower liner at 7,764' (On depth), Pick back up to 10' above window, Rotate 4 rounds and release torque, RIH and enter window on 2nd try. 21 :45 - 00:00 2.25 CASE RUNL CMPL T3 Continue RIH wI liner to 11,160' with no problems. 10/23/2004 00:00 - 00:30 0.50 CASE RUNL CMPL T3 Continue RIH with 4-1/2" liner to 11,808'. 00:30 - 01 :00 0.50 CASE RUNL CMPL T3 Ran past bottom of window @ 7,477' to 7,487'- 6 times turning Hook 3/4 turn each time until Hooked wI 35K (Found bottom of window 2.26' low), Top of liner @ 7,462.43', Shoe @ 11,808.89', Rehook wI 35K, Unhook - turn 1/2 turn and run past window 10', Turn 3/4 turn 2 more times and rehook wI 35K to confirm at same depth. 01 :00 - 01 :30 0.50 CASE CIRC CMPL T3 Drop ball, Pump down at 3 bpm @ 600 psi, Pressure up to 3200 psi & Release from hanger. 01:30-02:15 0.75 CASE CIRC CMPL T3 Circ btm's up at 8 bpm @ 2700 psi. 02:15 - 06:30 4.25 CASE OTHR CMPLT3 POOH, Lay down liner running tool. 06:30 - 08:15 1.75 CMPLTN RUNT CMPL T3 PJSM, Rig & Ran LEM assembly as per detail. 08:15 -13:00 4.75 CMPLTN RUNT CMPL 13 RIH wI LEM on drill pipe to 7,477' (Unable to work past 7,477'). 13:00 - 14:30 1.50 CMPL TN RUNT CMPL 13 Attempt to work thru hook hanger @ 7,477' - Tried all combinations of orientaions and slow rotation. Mule shoe would not penitrate hook hanger port to main well bore. 14:30 - 18:30 4.00 CMPL TN PULL CMPL 13 POOH to LEM Assembly. 18:30 - 20:30 2.00 CMPL TN PULL CMPL T3 Rig, POOH & Lay down LEM assembly, Lay down swivel,Stand back tubing in derrick, Lay down Seal Aseembly. 20:30 - 22:00 1.50 CMPL TN RUNT CMPL 13 Make up new Seal Assembly on bent joint, Run tubing from derrick, Make up LEM Assembly. Printed: 11/12/2004 11:23:10AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-114 1 E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: 10/23/2004 22:00 - 00:00 2.00 CMPL TN RUNT CMPL T3 RIH wI LEM Assembly on drill pipe to 4,750'. 10/24/2004 00:00 - 01 :30 1.50 CMPL TN TRIP CMPL 13 Cont TIH to 7468' 01 :30 - 06:00 4.50 CMPL TN TRIP CMPL T3 Work Tight spot @ 7468' - Up wt 135k, On wt 85k - Worked past to 7513' stopped - Unable to work past 7513' - Tried several orientation multiple times wI up to 30k dn wt max. No results. After a conference with the town engineers workes several orientataions and set 50 k down wt on string. NO results. Could not get past 7513' 06:00 - 09:15 3.25 CMPL TN TRIP CMPL T3 TOH 09:15 -11:30 2.25 CMPL TN PULD CMPL T3 R/U & UD LEM assy - Clean rig floor of tools - Confer with engineers in town. Decision was made to attempt to run the LEM only to see if it would clear and Latch in. 11 :30 - 12:00 0.50 CMPL TN PULD CMPL T3 P/U bent jt wI seal assy on bttm and LEM only - XO to DP 12:00 - 15:30 3.50 CMPL TN TRIP CMPL T3 TlH to 7733' -( Top of "B" lat. ZXP @ 7732' ) Did not see ANY obstructions of any kind) It appears the Liner and Hook hanger are out the window - Up wt 138k, On wt 85k 15:30 -16:00 0.50 CMPL TN TRIP CMPL T3 TOH to 7410' to be above window. 16:00 - 16:45 0.75 CMPLTN CIRC CMPL T3 CBU - Monitor well - Static- MOBM 9.3 ppg, Vis 86 out & in, PP 1200, PR 60 spm, 255 gpm - Small show of oil on BU - Gas<50 units. 16:45 - 20:00 3.25 CMPL TN TRIP CMPL T3 TOH 20:00 - 21:00 1.00 CMPL TN PULD CMPL T3 UD LEM and clear & clean rig floor - Discuss options with town - The decision was made to attempt to fish the Hook Hanger& liner and attempt to re-hook hanger. 21 :00 - 23:30 2.50 CMPL TN PULD CMPL 13 MU Baker liner running tool wI bent jt of 2 718" under tool with circu sub and bull nose. TIH to 7450' 23:30 - 00:00 0.50 FISH FISH CMPL T3 MU top drive and attempt to orient out window. 10/25/2004 00:00 - 01 :00 1.00 FISH FISH CMPL T3 Orient bent joint thru window- Work torque in 1/2 turn per attempt - Total of 9 attempts and ran retreiving tool out window. Latched up running tool @ 7503' (Top of hook would be @ 7488'). PU Hook and Liner and work back thru window - No over pull, Liner free. Up wt 156K, On wt 65k. Orient and set hook hanger wI 30k dn, repeat release and hook 3 times to assure proper hook. Final hook all at same depth mark on DP w/35k dn wI.. Top of liner 7463.17' 01 :00 - 02:30 1.50 FISH FISH CMPL 13 Drop 29/32" ball and pump down - Last 5 bbls slow to PR 1.5 BPM, PP 300- Ball on seat - Pressure up to 3400 psi to release tool.- PU - tool free 02:30 - 06:15 3.75 FISH FISH CMPL T3 Monitor well - Static - TOH 06: 15 - 06:45 0.50 FISH PULD CMPL 13 Make all service breaks and UD Baker running tool. 06:45 - 12:00 5.25 FISH TRIP CMPL T3 Clear all tools from rig floor - RlU & P/U LEM assy per well plan. Seals will be run on bent jt. 10" bent, 14' up from seals.- TIH 12:00 - 13:00 1.00 FISH TRIP CMPL T3 Con't TIH to 7460' 13:00 - 13:30 0.50 FISH TRIP CMPL T3 Orient bent jt thru Hook Hanger @ 7472' into main well bore. 13:30 - 14:00 0.50 FISH TRIP CMPL T3 Con't TIH to TOP of ZXP - @ 7758' seals became tight wI 25k dn wt - Work seals down to 7763' and latch LEM at proper depth. Pull test LEM to 10k "OK" 14:00 - 14:30 0.50 CMPL TN PCKR CMPL 13 Drop 29/32" ball and pump down - PR 3 BPM, PP 675. Slow to 1.5 bpm last 5 bbls - Ball on seat - Pressure up to 2900 psi to set packer, wait 5 min - Con't to pressure up to 3500 psi to neutralize tool. When tool neutralize it showed release.-P/U 2' free. Close annular and test packer to 1000 psi f/1 0 min "OK" TOH - UD HWDP & DCs - UD Hybred SWDCs 14:30 - 15:00 15:00 - 19:30 0.50 CMPL TN DEQT CMPL T3 4.50 CMPL TN PULD CMPL 13 Printed: 11/12/2004 11 :23:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-114 1 E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: 4.50 CMPL TN PULD CMPL T3 '"Note''' MUD DOG not cleaning MOBM out of inside of DP. We will stand back DP in derrick and let it drain. ( Will have 111 stds 4" DP in derrick - All else has been laid down. All HWDP, Hybred stands and DCs) TOH standing back 4" DP in derrick Make service breaks and UD running tool. 10/25/2004 15:00 - 19:30 19:30-21:30 2.00 CMPL TN TRIP CMPL T3 21 :30 - 22:30 1.00 CMPL TN PULD CMPL T3 22:30 - 23:00 0.50 CMPL TN RURD CMPL 13 23:00 - 00:00 1.00 CMPL TN PULD CMPL 13 10/26/2004 00:00 - 00:15 0.25 CMPL TN SFTY CMPL T3 00:15 - 07:00 6.75 CMPL TN RUNT CMPL 13 07:00 - 09:45 2.75 CMPL TN RUNT CMPL T3 09:45 - 10:15 0.50 WELCTL OTHR CMPL T3 10:15 -13:00 2.75 WELCTL NUND CMPL T3 13:00 - 15:00 2.00 WELCTL NUND CMPL13 15:00 - 16:00 1.00 CMPL TN RURD CMPLT3 16:00 - 18:00 2.00 CMPL TN PULD CMPL 13 18:00 - 19:00 1.00 WELCTL EQRP CMPL 13 19:00 - 23:30 4.50 CMPL TN PULD CMPL13 23:30 - 00:00 0.50 CMPL TN OTHR CMPLT3 RIU and pull wear bushing Remove all un-needed tools, subs, ecL from rig floor - Clean working area of MOBM - RIU 4 1/2" tbg running tools and power tongs. Held PJSM on running 41/2" completion Ran 4 1/2" 12.6#, L-80 IBTM tbg with completion assembly to 7,400', ran a total of 235 jts 4 1/2" tbg Spaced out completion string, MU tbg hanger and landed tbg at 7,446' RILDS, landed tbg with open CMU sliding sleeve at 7,370' and DB-6 nipple at 522', st wt up 90K, down wt 57K, block wt 34K , tested hanger seals to 5,000 psi for 10 min, installed TWC Flushed out BOP stack NO BOP stack and set off NU Vetco Gray adapter spool and tree, tested void and tree to 5,000 psi for 10 min, pulled TWC RU to freeze protect well, clear cellar area and RU scaffolding Began LD 4" DP from derrick, freeze protected well while LD DP, displaced out 9.3 ppg OBM with diesel thru open CMU sliding sleeve at 7,370', displaced hole with 300 bbls of diesel at 6 bpm at 900 psi Installed BPY using lubricator Fin LD 4" Dp from derrick, LD a total of 112 stds Cleared rig floor and secured well RELEASED RIG @ 24:00 hrs 10/26/04, rig to move to 1E-168 Printed: 11/12/2004 11:23:10AM ~ , c:onocd'Nmps ConocoPhimps A,aSk!C..Slot #11. Pad 1 E, Kuparuk River Unit, North Slope, Alaska wellbor.4 L1 Well path: MWD wI Sag - IIFR<7866- 11841'> Date Printed: 8-Nov-2004 '&ií. BAKER HUGHES INTEQ 1~lIbore 114 L 1 I Created 11-0ct-2004 I Last Revised 8-Nov-2004 IWell ~ I~~~~~~~~oo I ~~:_~~:d Slot Name I East Pad 1 E 550528.194 True Installation I =~k ~,~ U,;t IEaSti~ 87754 6208 I Northi ~g48985 8206 I~~~ IN"IIb/Yonmant I .. R ERICAN DATIJM 1927 ',,"m: Tru, All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 95.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7295.56 Feet on azimuth 48.10 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated J.O'Í-/7~ ,. Conoc~illips ConocoPhillips Alaslnc.,Slot #114 Pad 1 E, Kuparuk River Unit, North Slope, Alaska wellbo.14 L1 Wellpath: MWD wI Sag - IIFR<7866 - 11841'> Date Printed: 8-Nov-2004 ,&¡. BAKER HUGHES INTEQ Wellpath (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severit) Vertical Easting Northing Positionly) PositionlX) Sectionrftl 7778.00 78.34 0.01 3557.03 815.14N 0.00 1026.81 ~~~AIUI ~II ~GAn~"I1 Ai 7Rnn 44 83.32 0.15 3571.13 902.42N 5.64 11140<1 ~~~Anll 1 'J 7958.97 89.85 0.92 3576.64 994.74N 5314.67E 7.11 1206.30 555608.36 5960711.19 8053.76 91.39 4.62 3575.61 1no" '>".., 4.23 1301.06 ~~~A1 'J <11 R14'i 7'i C}14? 1 R1 3573.35 1181.20N "''''.... Am'" <l0'i 1<1C}<l00 "'''''''''1'' 0'" 8239.78 90.99 359.65 3571.38 1275.19N 5325.60E 2.34 1486.97 555617.42 5960991.69 8333.85 89.05 1.18 3571.34 2.63 1'iRO C}R 'i'i'in1747 M?7 nO RC} O'i 358.75 3572.90 1462.98N 5326.23E ? 'ic} 1n74.f\4 'i55f11 fI.7Ç 8521.89 90.50 359.68 3573.27 1557.26N 5324.94E 1.83 1768.79 555614.86 5961273.71 8622.36 90.46 3.23 3572.43 3.53 1RnC} ?<I 4 5Çfl137414 R707?4 RÇ R'i ??Ç <I'i7? .20 174?.4nN 'i<l<l1 'i7F 1 <I? 1Ç54.10 555620.2f1 8801.29 87.12 2.05 3574.68 1836.40N 5335.13E 2.91 2048.11 555623.19 5961552.89 RRÇ'i 'i 1 RR.'iÇ <I.ço <I'i7R ?1 2.'i1 ?14? ?5 555f12745 5Ç61646.93 8Ç88 08 8875 4.7Ç <l580'::\fI ?O?? 70N 5::\47.0<lF 0Ç8 22::\4 74 ~~~""I"I 0" 59617<1c} ?4 9082.68 89.14 3.70 3582.10 2117.02N 5354.03E 1.22 2329.26 555640.21 5961833.60 Ç17R OÇ RÇ R'i 4 nO <I'iR? Ç4 ??1? 1RN 1 ?O ?4?4 n? ~~~~,~ An '!of Ç2f124f1 8Ç 1Ç ?81 <151'1<1 fl5 'J'JGA "IAII.I ??fI 2508Ç5 'i'i'in'i1 <In 9356.49 89.19 3.58 3584.98 2390.24N 5371.63E 0.82 2602.96 555655.98 5962106.90 Ç44A <lÇ RÇ 1Ç <l0'i <l5Rn ?R ?4R1 Ç7N O'iR ?nÇ4 M ~~~AnO All Ç54228 AÇ1Ç 37f1 35A7f\0 07f1 2788.70 ~~~AA~ n? .n 9630.30 89.16 3.70 3588.87 2663.51N 5388.24E 0.08 2876.68 555670.76 5962380.25 Ç7?? R<I RÇ ?'i ? Ç7 <l5Ç0 1 n .....,"'''' 00'" o 7Ç ?ÇflÇ 1Ç ~~~n7'i ~'J Ç81f1.71 AÇ37 1Ç? <l5Ç1 ?Ç 113 3063 06 'i'i'in7R ao 9909.34 89.10 1.69 3592.52 2942.24N 5400.55E 0.38 3155.68 555681.20 5962659.03 1nnn"l SILl RR 7Ç 1.7R <I'iÇ4.?n nnn. 540<l41F o .::\4 <I?501f1 ~~~~nn ,,'> 10097.51 89.03 1.01 35ÇfI.05 3130.30N 08f1 3::\43.80 555685.08 in 10191.81 90.02 359.87 3596.83 3224.59N 5406.41 E 1.60 3438.04 555685.17 5962941.39 1028425 8Ç.Ç5 <l5R ?Ç <I'iÇn R5 <I<I17.0?N "'An. n,>c 171 3530 ::\4 555683.07 79 10376.49 90.87 358.98 359619 ':I4na 'J"IN =()L :1t-: 1.25 3622.38 ~~~Alln 'J~ 10470.56 90.35 358.70 3595.19 3503.27N 5400.83E 0.63 3716.28 555677.72 5963220.00 1n~n"l ~n 8Ç Ç? <151'151 <l5Ç4 Ç7 <l5Çn 1RN 051 380çm 'i'i'in74 SILl 10n'i70'i 90.90 0.14 35Ç430 "InllG 7'JN "'nn"7 A ~r 2.03 3902.44 'i'i'in7<111 An 10749.80 90.81 359.75 3592.92 3782.46N 5397.37E 0.43 3995.11 555672.40 5963499.13 1 0Ril.4 Rn Ç{) Ç 1 10Ç 35Ç14Ç 3A7751N 141 4090.10 'i'i'in7? 4n 17 1nG"I1I A~ 90.78 2.01 3590.11 3971.25N 0.99 41R<I R7 ~~~A7 A "17 11031.23 89.59 2.81 3589.81 4063.75N 5404.50E 1.55 4276.45 555677.64 5963780.43 11124.13 89.19 2.00 3590.80 41565f1N "'Ann Anr 0.97 4369.34 ~~~Alln G'J 11?174'i C}O ?C} <I 'ic} <I'ic}1 ?? A')AG 7A'" ? 07 44n? n'i ~~~nSlLl SILl An ::>41 L!of::>t-: 11310.11 89.55 3.63 3591.35 4342.24N 5418.78E 0.80 4555.29 555690.06 5964058.98 11397.19 89.74 3.07 3591.89 4429.17N 0.68 4f\4? <I'i ~~~nQ;l ~n 5Çf\4145 Ç3 Rçm <I'iÇ 41 <I'iÇ? .RR 4'i?1 <I?N 404 47::\4.5? ~~'ina'i Q;I 11590.47 86.24 0.75 3597.05 4622.30N 5426.01 E 3.06 4835.42 555695.41 5964339.06 11nnÇ 7<1 RnR5 047 <ln01 R<I 4701.42N OR5 4Ç14.'i0 'i55f1Ç5 7? 5Ç64418.17 1175Ç.77 A71f1 1 ?O <lflOn'i<l 47Ç1.<I?N 54?R 1 nF 01'11'1 5004.3Ç 555696.43 7 11788.88 86.76 1.32 3608.07 4820.38N 5428.80E 1.43 5033.45 555696.87 5964537.14 11M1.00 Rn.7n 1 <I? <ln11.02 4872.41 N 000 'iOR'i.4R 555f1Ç7.7? 1n All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 95.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7295.56 Feet on azimuth 48.10 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated .. . ~Iips ConocoPhmOps Alas!.c.,s,ot #114 Pad 1 E, Kuparuk River Unit,North Slope, Alaska wellbo.14 L1 Wellpath: MWD wI Sag - IIFR<7866 - 11841'> Date Printed: 8-Nov-2004 r&l. BAKER HUGHES INTEQ 4872.41 N Hole Sections Diameter Start Start Start Start End End End Start Wellbore 3557.03 5429.99E Casin s Name Top Top Top Top Shoe Shoe Shoe Shoe Wellbore All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7295.56 Feet on azimuth 48.10 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . If/6ÿ jp: r6~ /~ /35- I Cj5- ;<0 if - . 11/19/04 Scblumbel'gel' NO. 3267 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL Color CD _ - ','; 1A-01 10922488 LEAK DETECTION LOG 11/08/04 1 :J- 21( 3F-09 10922490 PRODUCTION PROFILE 11/10/04 1 ~~7fo 3N-07 10922491 PRODUCTION PROFILE 11//11/04 1 1 G-13 10922487 LEAK DETECTION LOG 11/07/04 1 S - 2~~ 3F-06 10922489 PRODUCTION PROFILE 11/09/04 1 OIl. 2W-03 10942791 LEAK DETECTION LOG 10/30/04 1 22(¡;- 3F-02 10942790 PROD PROFILE/DEFT 10/29/04 1 1_ 1-/ 1E-114L1 10687709 USIT 10/07/04 1 hl ~ / Î / sç;~;aJ ~~~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. DATE: //ÞIoc¡ , / . . ~ æ; ~,? ¡nuIIL. llL) u FRANK H. MURKOWSKI, GOVERNOR A ItASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk lE-114Ll ConocoPhillips Alaska, Inc. Permit No: 204-172 Surface Location: 5188' FNL, 226' FEL, SEC. 16, TIIN, RI0E, UM Bottomhole Location: 319' FNL, 29' FEL, SEC. 15, TIIN, RI0E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new well bore segment of existing well KRU lE-114, Permit No. 204-171, API 50-029-23223-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907 659-3 (pager). Si BY ORDER 2f1 THE COMMISSION DATED thisL...{ day of September, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConoccJt,illipS Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com September 8,2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Injector, 1E-114 L1 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for an onshore production well bore, the upper lateral wellbore of a multilateral horizontal well, in the West Sak "B" sand. The main bore of this well will be designated 1E-112 and has been permitted under a separate application, submitted on September 8,2004. This application is for the upper lateral of that well, to be designated 1E-114L1. The expected date that operations will begin on 1E-114L1 is October 15, 2004. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of this well bore. Under separate cover, ConocoPhillips is applying for a spacing exception for this well bore, under the terms of 20 MC 25.055 Please contact Steve Shultz at 263-4620 if more information is needed to issue a Permt to Drill for 1E- 114L1. Sincerely, ~~ Randy Thomas GKA Drilling Team Leader OR' G1 f\1 ,A L / STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Randy Thomas -== ,~ , Commission Use Only Permit to Drill . r / API Number: Permit Approval See cover letter Number: ;2D '-t' ~ /7"2- 50- ð z.. C¡.- 2 3 L;¿ 3 -- t;;;, 0 Date: for other requirements Conditions of approval: Samples required DYes WNo Mud log required DYes r!i:YdrOgen sulfide measures D Yes ~ No Directional survey required ß:yes Other: .~s; ~ "'-\\M,-..)ij~eo\'-\ö\, ~\)y~\,,-~~\ '= \k\ ~'L<>' , ~(;1'A.ol.,\->~~O"'" <--\L\i"'IZ,^,1..CV\jQ'\~l ,o~ c::.", \r\.'s.y\~~,'oC;.\té" r_ / ;r/tJ/ Q BY ORDER OF tJ?/. III, Approved ~ COMMISSIONER THE COMMISSION Date: II V I Form 1~1 R~d 3/2003 0 R 16fNÄ[ / SUb~t in d~Plicate . 1a. Type of Work: Drill ~ Redrill U Re-entry D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1 b. Current Well Class: Stratigraphic Test D P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 5188' FNL, 226' FEL, Sec. 16, T11N, R10E, UM ,/ Top of Productive Horizon: 4384' FNL, 218' FEL, Sec. 15, T11 N, R10E, UM ./ Total Depth: 319' FNL, 29' FEL, Sec. 15, T11 N, R10E, UM .I 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550301'/ Y- 5959681 ./ Zone- 16. Deviated wells: Kickoff depth: 7820 18. Casing Program Size .I ft. Maximum Hole Angle: 91.6° Specifications Grade Coupling K-55 Welded L-80 BTC L-80 BTCM L-80 DWC Length 80' 4154' 8752' 4070' Hole Driven 13.5" 9-7/8" 6.75" Casing 20" Weight 94# 45.5# 29.7# 12.6# 10.75" 7-5/8" 4.5" 19 Total Depth MD (It): PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Length Size 20. Attachments: Filing Fee [2] Property Plat D BOP Sketch 0 Diverter Sketch D Drilling Program[2] Seabed Report D 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge, Printed Name Signature '\ . k Cl,~ 20 MC 25.005 ExploratoryU Development Oil U Multiple Zone D Service [2] Development Gas D Single Zone [2] 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1E-114L1 6. Proposed Depth: 12. Field/Pool(s): MD: 11854''¡ TVD: 3633' / Kuparuk River Field 7. Property Designation: ALK 25651 West Sak Pool 13. Approximate Spud Date: 10/15/2004 / 8. Land Use Permit: ADL 469 9. Acres in Property: 2560 / 14. Distance to Nearest Property: 5062' 10. KB Elevation 15. Distance to Nearest 4 Well within Pool: 1E-123 @ 1020'. I (Height above GL): 28 feet 17. Anticipated Pressure (see 20 AAC 25.035) / Max. Downhole Pressure: 1642 psig I Max. Surface Pressure: 1246 psig Setting Depth Quantity of Cement Bottom c. f. or sacks TVD (including stage data) 108' 260 cf ArcticCrete 2295' 718 sx AS Lite, 189 sx DeepCrete 3733' 508 sx DeepCrete 3633' slotted liner Top MD 28' 28' 28' 7784' TVD 28' MD 108' 4182' 8780' 11854' 28' 28' 3560' (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD TVD Perforation Depth TVD (ft): Time v. Depth Plot D Drilling Fluid Program [2] Date: Shallow Hazard Analysis D 20 AAC 25,050 requirements [2] Contact Steve Shultz @ 263-4620 Title Kuparuk Drilling Team Leader Phone ¿bÇ"- ~8 Ju Date 4("(0 '(' Pr<>nRrp.d hv .c::hRron All _no g No [J No · APPen for Permit to Drill, Well 1 E-114 L 1 Revision No.O September 2, 2004 Permit It - West Sak Well #1 E-114 L 1 ("B" Sand) Application for Permit to Drill Document MQxir'l'1izE Well Vglu~ Table of Contents 1. Well Name..................................................................................................................... 2 Requirements of 20 AAC 25.005 (f) . ..... ....... ....... ........ ..... ........ ............. ........... ...... ...... ...... ......... ........ 2 2. Location Sum mary....................................................................................................... 2 Requirements of 20 AAC 25.005(e)(2) ................ .... ........ ....... ...... ..... ......... ........... ........ ..... ....... .......... 2 Requirements of 20 AAC 25.050(b) ..... ............... ........... ......... ........... ............ ....... ....... ..... ......... ......... 3 3. Blowout Prevention Equipment Information ............................................................3 Requirements of 20 AAC 25.005(e)(3) ...... ..... ............... ........ ..... ..... ......... ............ ................. ........... ... 3 4. Dri II i ng Hazards Information ...................................................................................... 3 Requirements of 20 AAC 25.005 (e)(4) ............................................................................................... 3 5. Procedure for Conducting Formation Integrity Tests.............................................3 Requirements of 20 AAC 25.005 (e)(5) ...............................................................................................3 6. Casing and Cementing Program................................................................................4 Requirements of 20 AAC 25.005(e)(6) ....... ............. ... ..... ............. ......... .... ...... ..... ....... .............. .......... 4 7. Diverter System Information ......................................................................................4 Requirements of 20 AAC 25.005(e)(7) ..... ........ ...... ..................... ....... ...... ...... ...... ....... .............. .......... 4 8. Dri II i ng Flu id Prog ram................................................................................................. 5 Requirements of 20 AAC 25.005(e)(8) .... ....... ........... ......... ............. ......... ..... ..... ... ............. ................. 5 Lateral Mud Program (MI FloPro NT) . ............ ...... ..... ......... ............ ....... ............. ....... ....... .... ......... ...... 5 9. Abnormally Pressured Formation Information ........................................................5 Requirements of 20 AAC 25.005 (e)(9) ...............................................................................................5 1 O. Seism ic Analysis.......................................................................................................... 5 Requirements of 20 AAC 25.005 (e)(10) .... ....... ..... ......... ........ ............. ...... ...... ...... ....... ..... ......... ........ 5 11. Seabed Condition Analysis ............................ ............................................................ 5 Requirements of 20 AAC 25.005 (e)(11) ... ...... ........ ............... ..... ...... ........ ........................ ........ ...... .... 5 12. Evidence of Bonding ........ ............... ............................................................... ............. 6 Requirements of 20 AAC 25.005 (e)(12) ........ ............ ... .................... ...... ............. ..... ....... ...... .... ......... 6 ORiGiNAL L1 PERMIT IT RevO.doc Page 10f6 Printed: September 2, 2004 · APP. for Permit to Drill, Well 1 E-114 L 1 Revision No.O September 2, 2004 13. Proposed Dri lIing Program ..... ...... ............... ............................................................... 6 Requirements of 20 AAC 25.005 (c)(13) .............................................................................................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal........................6 Requirements of 20 AAC 25.005 (c)(14) ............................................................................................. 6 15. Attach ments..............................................................................................................~... 6 Attachment 1 Directional Plan (8 pages) ............................................................................................. 6 Attachment 2 Drilling Hazards Summary (1 page)...............................................................................6 Attachment 3 Well Schematic (1 pages).............. .......... ........ ..... ..... .............. ............ ..... ....... ... .......... 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each we/I must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission The well for which this Application is submitted will be designated as 1E-114 Ll. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface I ASP Zone 4 NAD 27 Coordinates Northings: 5,959,681 Eastings: 550,301 FNL:5188', FEL:226', See 16, T11N/R10E, UM I RKB Elevation I 94.5' AMSL I Pad Elevation I 66.5' AMSL / Location at Top of Productive Interval West Sak "8ft Sand ASP Zone 4 NAD 27 Coordinates Northings;S,960,523 Eastings: 555,582 FNL:4384', FEL:218', See 15, T11N/R10E, UM ./ Measured De th RKB: Total Vertical De th, RKB: Total Vertical De th, 55: 7784' 3560' 3465.0' Location at Total Depth I FNL:319', FEL:29', See 15, T11N/RlOE, UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 11854' Northings: 5,964,589 Eastings: 555,735 Total Vertical Depth, RKB: 3633' Total Vertical Depth, 55: 3538.0' ./ ./ v and (D) other information required by 20 MC 25. 050(b); ORIGINAL L 1 PERMIT IT RevO.doc Page 2 of 6 Printed: September 2, 2004 · APPen for Permit to Drill, Well 1 E-114 L 1 Revision No.O September 8, 2004 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviate~ the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable sca/~ showing the path of the proposed wellbor~ including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail,' or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25.035, 20 AAC 25.036, or 20 MC 25.037 as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete welllE-1l4 Ll. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following Item~ except for an item already on file with the commission and identified in the application: (4) information on dolling hazard~ including (A) the maximum downhole pressure that may be encountere~ criteria used to determine it, and maximum potential surface ú pressure based on a methane gradient; i't> 'I ,t<l,t; T The expected reservoir pressures in the West Sak sands in the 1E-114L1 area vary from'\'o.44' toj,0.47 ./ psi/ft, or 8.6 to 9.0 ppg EMW (equivalent mud weight)."' These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak D sand formation is 1245.66 psi, calculated thusly: MPSP =(3494 ft)(0.47 - 0.11 psi/ft) =1245.66 psi v (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zone~ and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following Item~ except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity test~ as required under 20 MC 25. 030(f); The parent wellbore/1E-1l4, will be completed with 75/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance ORIGINAL L 1 PERMIT IT RevO,doc Page 3 of 6 Printed: September 8, 2004 · APp.n for Permit to Drill, Well 1 E-114 L 1 Revision No.O September 2, 2004 with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c){6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.034 and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3, APD for 1E-114: Cement Summa!) Hole Top Btm CsglTbg Size Weight Length MOITVO MOITVO 00 (in) (in) (Iblft) Grade Connection (ft) (ft) (ft) Cement Proqram 20 X 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE 10 3/4 13 1/2 45.5 L-80 BTC 4154 28 / 28 4182 /2295 Cemented to Surface with 718 sx ASLite Lead, 189 sx DeepCRETE Tail 7 5/8 97/8 29.7 L-80 BTCM 8752 28 / 28 8780 / 3733 Cement Top planned @ 5500' MD / 2750'TVD. Cemented w/ 508 sx DeepCRETE 41/2 63/4" "A" 12.6 L-80 DWC 3090 8780/3733 11870/3808 Slotted- no slotted Lateral (lE- cement k7 11 A' -- D ( 41/2 63/4" 12.6 L-80 DWC 4070 7784/3560 11854/3633 Slotted- no slotted "B" Lateral cement -- ~. ~~4 Ll) - f..-"! 41/2 6 3/4 12.6 L-80 DWC 4357 7492/3494 118'49/3574 Slotted-no slotted "D" Lateral cement (lE-114 L2) 7. Diverter System Information Requirements of 20 AAC 25. 005(c) (7) An application for a Permit to Drill must be accompanied by each of the followmg items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 M C 25. 035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); No diverter system will be utilized during operations on 1E-114 Ll ORIGINAL L 1 PERMIT IT RevO.doc Page 4 0(6 Printed: September 2, 2004 · APPen for Permit to Drill, Well 1 E-114 L 1 Revision No.O September 2, 2004 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (8) a drilling fiuid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (VersaPro, Oil Base Mud) Properties ,,-.. Value '\ Density (ppg) / 9.3 J Funnel ~ Viscosity (seconds) Yield Point 18-28 (cP) Electric Stability 650-900 Chlorides (mg/I) 40000 pH NjA API filtrate <4 rcc / 30 min) **HTHP filtrate <10 (cc / 30 min) MBT (Ib / gal) ~. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon 141 Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a}; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and Identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. ORIGINAL L 1 PERMIT IT RevO.doc Page 5 of 6 Printed: September 2, 2004 · AP.n for Permit to Drill, Well 1 E-114 L 1 Revision No.O September 2, 2004 11. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 (Bonding}have been me~' Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: The proposed drilling program for 1E-114 L1 is listed below. ~ ~!\S Note: Previous operations are covered under the 1E-1l4 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 7784' MD / 3560' TVD, the top of the B sand. 2. Mill 6 3/4" window. POOH. " 3. Pick up 63/4" drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of "B" sand lateral at 11854' MD /3633' TVD, as per directional plan. J-5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4 1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. Displace liner annulus and liner to 9.3 ppg weighted brine. ¡ 10. POOH and PU lateral entry module 11. RIH with module and latch into the "B" sand hook hanger 12. POOH and prepare to drill the "D" sand lateral1E-114 L. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25. 080 for an annular disposal operation in the wel/./ Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1E Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1E Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 14. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic ORIGINAL L 1 PERMIT IT RevO.doc Page 6 of 6 Printed: September 2, 2004 . ~lUips ConocoPhillips Alaska, Inc.,Slot #114 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . PROPOSAL LISTING Page 1 Wellbore: 114L 1 Wellpath: 114L1 Verso #2 Date Printed: 9-Aug-2004 ..: INTEQ _~__.~_~~__,~ '·_~_~_____·~'________M_~·_.m____"·__,,_·_,__,___________~_.. .__,~___~_.__.~_~________~_____ .. -... -,,--->.'_.' --- "----,,. _.'.--, ...-.._--,,-.-.--.-~-.--- ---'--'~~'------~'-"--"'~'.'--~-~-- _.,,~.,----~----- Well bore Name j14L 1_.~_...M_..~~__.~__ --~--,._-------_._---- Created .______~..___ ~º=Aug_2004__.~_.. ._._~_~ _ __~_ ~__~ Last Revised __~.~. _9.:,A.J!Q-2QQL_~ -~._-"~~~~ ._----------~-----_._------------~------- W.êU Name 114 Slot· Name Slot #114 Installation Name Pad 1 E N orthi no 5959591.1090 Coord Svstem Name AK-4 on NORTH AMERICAN DATUM 1927 datu v Field N.amé Ku aruk River Unit All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7323.08 Feet on azimuth 48.30 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . ~illips ConocoPhillips Alaska, Inc.,Slot #114 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 2 Wellbore: 114L 1 Wellpath: 114L 1 Verso #2 Date Printed: 9-Aug-2004 .J£: INTEQ WeUpath Report MD[ft] Inc[deg] Azi[ deg] TVD[ft] Vertical North[ft] East{ft] Station Station Dogleg Vertical Station Comment Depth SS Position(Grid Position(Grid [deg/10 Section[f -~ North)~_ East) Oftl __ L~ 7783.60 80.00 _. ----.b~__ 3560.00 _~6r;¡~ _ª1L6.60N_ ~lE _ 5960522~8J1_ __5.55582.43__ ~º-Q -1QJV3 Top WhipstoclŒ~JJtln_______ 7795.60 81.91 2.29 3561.89 3466.89 818.44N 5287.94E 5960534.74 555582.82 15.90 1029.08 End of Build ~QO --ªl~ _ 2.29 3562.51 3467.51 822.79N 5288.12E 5960539.09 ~~5829'L -Q..Q!L J033M ¡..----~-----~-------- 7800.10 81.91 2.29 3562.52 3467.52 822.89N 5288.12E 5960539.19 555582.97 0.00 1033.53 Base Whiostock Face 7813.60 81.91 2.29 3564.42 3469.42 836.25N 5288.65E 5960552.55 555583.41 0.00 1046.90 End of Hold 7820.10 82.23 2.29 3565.32 3470.32 842.68N 5288.91E 5960558.98.. 555583.63 5.00 _ ~4 End Milled Qoenhole KOP 7913.60 86.91 - 2.29 3574.16 3479.16 935.66N 5292.62E 5960651.97._ 555586.71 5.00 1146.3~ 1----- -- 7956.66 89.06 2.29 3575.68 3480.68 978.66N 5294.34E 5960694.98 555588.14 5.00 1189.42 End of Build -- 8039,98 91.56 2.29 3575.22 3480.22 1061.90N 5297.66E 5960778.23 555590.91 3.00 1272.74 End of Build 8100.00 91.56 2.29 3573.59 3478.59 1121.85N 5300.05E 5960838.19 555592.90 0.00 1332.73 8145.05 91.56 ?29 3572.36 3477.36 1166.85N 5301.85E 5960883.20 555594.39 0.00 1377.77 l'End of Hold -- 8228.37 89.06 2.29 3571.91 3476.91 1250.10N 5305.17E 5960966.46 555597.15 3.00 1461.08 SIC Kick off Point 8300.00 89.06 2.28 3573.08 3478.08 1321.66N 5308.02E 5961038.03 555599.53 0.00 1532.70 8400.00 89.06 2.28 3574.72 3479.72 1421.57N 5312.01E 5961137.95 555602.85 0.00 1632.69 8500.00 89.06 2.28 3576.36 3481.36 1521.47N 5315.99E 5961237.87 555606.16 0.00 1732.67 8600.00 89.06 2.28 3578.00 3483.00 1621.38N 5319.98E 5961337.79 555609.48 0.00 1832.66 8700.00 89.06 2.28 3579.64 3484.64 1721.29N 5323.97E 5961437.72 555612.80 0.00 1932.65 8800.00 89.06 2.28 3581.28 3486.28 1821.20N 5327.95E 5961537.64 555616.12 0.00 2032.63 8900.00 89.06 2.28 3582.92 3487.92 1921.10N 5331.94E 5961637.56 555619.43 0.00 2132.62 9000.00 89.06 2.28 3584.55 3489.56 2021.01 N 5335.93E 5961737.48 555622.75 0.00 2232.61 9100.00 89.06 2.28 3586.19 3491.19 ?120.92N 5339.91E 5961837.40 555626.07 0.00 233?59 9200.00 89.06 2.28 3587.83 3492.83 2220.82N 5343.90E 5961937.32 555629.38 0.00 2432.58 9300.00 89.06 2.28 3589.47 3494.47 n20.73N 5347.88E 5962037.25 555632.70 0.00 2532.57 9400.00 89.06 2.28 3591.11 3496.11 2420.64N 5351.87E 5962137.17 555636.02 0.00 2632.55 9500.00 89.06 2.28 3592.75 3497.75 2520.55N 5355.85E 5962237.09 555639.33 0.00 2732.54 9600.00 89.06 2.28 3594.39 3499.39 2620.45N 5359.84E 5962337.01 555642.65 0.00 2832.52 9700.00 89.06 2.28 3596.03 3501.03 2720.36N 5363.83E 5962436.93 55564597 0.00 2932.51 9800.00 89.06 2.28 3597.67 3502.67 2820.27N 5367.81E 5962536.85 555649.28 0.00 3032.50 9900.00 89.06 2.28 3599.31 3504.31 2920.17N 5371.80E 5962636.78 555652.60 0.00 3132.48 9942.26 89.06 2.28 3600.00 3505.00 2962.39N 5373.48E 5962679.00 555654.00 0.00 3174.74 WS 1 E C6 B-MDPT#1 RVSD080304, End of Hold 9959.99 89.01 2.81 3600.30 3505.30 2980.10N 5374.27E 5962696.71 555654.67 3.00 3192.47 SIC Kick off Point 10000.00 89.01 2.81 3600.99 3505.99 3020.06N 5376.23E 5962736.68 555656.37 0.00 3232.47 10100.00 89.01 2.81 3602.72 3507. 72 3119.92N 5381.14E 5962836.56 555660.61 0.00 3332.45 10200.00 89.01 2.81 3604.44 3509.44 3219.79N 5386.05E 5962936.45 555664.85 0.00 3432.43 10300.00 89.01 2.81 3606.17 3511.17 3319.65N 5390.96E 5963036.33 555669.09 0.00 3532.41 10400.00 89.01 2.81 3607.89 3512.89 3419.52N 5395.87E 5963136.22 555673.33 0.00 3632.39 10500.00 89.01 2.81 3609.62 3514.62 3519.38N 5400.78E 5963236.11 555677.57 0.00 3732.37 10600.00 89.01 2.81 3611.35 3516.35 3619.25N 5405.69E 5963335.99 555681.81 0.00 3832.35 10700.00 89.01 2.81 3613.07 3518.07 3719.11N 5410.60E 5963435.88 555686.05 0.00 3932.33 10800.00 89.01 2.81 3614.80 3519.80 3818.98N 5415.51E 5963535.76 555690.29 0.00 4032.32 10900.00 89.01 2.81 3616.52 3521.52 3918.84N 5420.42E 5963635.65 555694.53 0.00 4132.30 11000.00 89.01 2.81 3618.25 3523.25 4018.70N 5425.32E 5963735.53 555698.77 0.00 4232.28 11100.00 89.01 2.81 3619.98 3524.98 4118.57N 5430.23E 5963835.42 555703.01 0.00 4332.26 11200.00 89.01 2.81 3621 70 3526.70 4218.43N 5435.14E 5963935.30 555707.25 0.00 4432.24 11300.00 89.01 2.81 3623.43 3528.43 4318.30N 5440.05E 5964035.19 555711.49 0.00 4532.22 11400.00 89.01 2.81 3625.16 3530.15 4418.16N 5444.96E 5964135.07 555715.73 0.00 4632.20 11500.00 89.01 2.81 3626.88 3531.88 4518.03N 5449.87E 5964234.96 555719.97 0.00 4732.18 11600.00 89.01 2.81 3628.61 3533.61 4617.89N 5454.78E 5964334.84 555724.21 0.00 4832.16 11700.00 89.01 2.81 3630.33 3535.33 4717.76N 5459.69E 5964434.73 555728.45 0.00 4932.14 ./ All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7323.08 Feet on azimuth 48.30 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . c:onocriPhillips ConocoPhillips Alaska, Inc.,Slot #114 Pad 1 E, Kuparuk River Unit,North Slope, Alaska -'-"~'._--~._.~--.-._.-._--_..~...,.."-_. - ---'-.-'~-' ..__._-----.~_.~_... Well MD[ft] ~- -----.- TVD[ft] Vertical North[ft] East[ft] Station Depth SS Position(Grid ____ ____ Nortt!L~_ 3632.06 __~5~7~OO_ _'H!17.QZJ-J _~4§Ac60E~964R34~6J 3633.00 3538.00 4872.00N 5467.27E 5964589.00 __lWQJ1QO _ 89~Q1_ ._2.~.__ 11854.45 89.01 2.81 . PROPOSAL LISTING Page 3 Wellbore: 114L 1 Wellpath: 114L 1 Verso #2 Date Printed: 9-Aug-2004 .J£: INTEQ Station Dogleg Vertical Station Comment Position(Grid [deg/10 Section[f EastL.._____ DftL~_ lJ_______ __ RQQTª-2.J?] __ Q,º-<L __ 503212 _____~________ 55573500 0.00 5086.56 TO,4 1/2in Uner, WS 1E C6 B TOE RVSD021804, 4 1/2in Casing, End of Tum All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7323.08 Feet on azimuth 48.30 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORtGINAL ~rtI:1fftL______ omment________________________.________ __________~_.___.______________ _ __ªº-º.-º-QN__IQQWI)lQ§t9gbce ..____ _ _____ _ _ __J~22_~-"L_ BasJ1 WhipsJQçkf_~ÇI;L_._______ ____ 842.68N__ Ençf_MiI!S!.<L<Æm1hQle..JSQP_ ____ ______ 4872.00N TO 4 112in Liner . . ..... ConocoPhillips ConocoPhillips Alaska, Inc.,Slot #114 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 4 Well bore: 114L 1 Wellpath: 114L 1 Verso #2 Date Printed: 9-Aug-2004 ··_~~~~·_,_·_~__~_·_~__~c"_~~~____,___ Comments MOfftl TV~_ as fiJ_____ _ __1783. 6Q____3560J2Q.u _. ..._~8lÆZE._ __-Zf!OOJ-º_____.]-ºº2.!?2.__ 528!L12E_ _~820.10 ___~65.~2._ __~ªª.91E___ 11854.45 3633.00 5467.27E - ..,.__._____._____'n...._"___ --'~ --~.~--,_.,----_..~--_._-_._~----_.,---_.------------~-- - - ------' ._--_.__._-_.._------_.~"_._- --~---~_._~----_._-----~---~~- End\nEast[ft] Well bore 5467.27E Cas in Name Tar ets Na e North ft WS 1E C6 B TOE 4872.00N RVS00218 4 WS 1 E C6 2962.39N B-MOPT#1 RVSD080304 Latitude N70 18 50.1112 W149 32 56.6563 555654.00 5373.48E 3600.00 N70 18 31.3311 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Datum #1 95.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7323.08 Feet on azimuth 48.30 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL øtI: INTEQ 114L 1 Wellbore 114L 1 Northin 5964589.00 5962679.00 ConocoPhillips Alaska, Inc. I I Location: North Slope, Alaska SICÚQt#ß/Pt #114 Field: Kuparuk River Unit Well: 114 Installation: Pad 1E Wellbore: 114 ~ ConocoPhillips Created by: Planner Date plotted: 3-Sep-2004 Plot reference is 114. Ref weilpath is 114 Verso 1f2. Coordinates are in feet reference Siot #114. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 95.00 ft. I Plot North is aligned to TRUE North. ¢:: ~ 0 -800 0 C\ II E 0 -400 -i Q) J ¡ ëü I 0 (/) -0 j RKB Elevation: 95' 0 KOP ::t) 400 t 6.00 - BldfTrn 4/100 GB 800 I ~ ~ 18.00 ... 1 J Bld/Trn 6/100 ;2š 1200 32.00 J 44.00 DLS: 6.00 deg/100ft ::ti EOC ~ 1600 j ns ~ Top T-3 CJ 1:: ~ 2000 Top K-15 G) 10 3/4" Casing PI. ~ 2400 ; '- I- 69.80 I start 200' Pump Tangent V 2800 BldfTrn 5/100 65.40 Top U9nu C -I 64.31 DLS: 5.00 deg/100ft ~ TO~ U9nu B 3200 67.66 op Ugnu A ~ 70.24 K-13EOC 73.39 3600 'i)~'o 'i>\sa.\\,\QQc ---4 ~o\' \fIIe'òu\\Ó $:~~ 'ò p..-Þ. p..-?> ~ 4000 ~o\' \file 1 6\'0' cs~' l sa.v..¡:.:2-· \fIIe'i>\ 4400 ~o\' I I . . 114L2 -1200 -800 -400 0 Scale 1 cm = 200 ft 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 Vertical Section (feet) .> Azimuth 2.29 with reference 0.00 N, 0.00 E from Slot#114 (STRONG!) ~ w ~ (j) _ 3200 - Q) .æ - 3360 .t:. - Q, Q) C 3520 (ij (.) O~ ;o~ -.= G1v - Z )::>oe r- ~ E u ~ w m Jj 3200 - - Q) 3360 Q) ~ .c - 3520 Q, Q) C (ij 3680 (.) t Q) > 3840 Q) ::s '- .... 4000 I V ~\7>':,.r7>~o\e,'f...O? \!'In\?~ . ",'IP O\,e~ O? '\o~7>",e ~~~\eÓ ~r_~~Eh~o\e''f...I ~~ \!'In~~'(\~ ",\0"''; \,e~ S\ Sø.¥-. ~\\()() C ~ ~o\' ,-!,!e <pU\\Ó ~~ø.¥-. <p ,.teS\ ~O\' 'I' oe o '" " 5 Bií. BAKER HUGHES -----..-------..-- INTEQ 3680 3840 4000 ConocoPhillips Alaska, Inc. Conoc6Phillips Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #114 Well: 114 Wellbore: 114 Created by: Planner Date plotted: 3-Sep-2004 at re erence is 14. Refwellpath is 114 Verso #2. Coordinates are in feet reference Slot #114 . True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 95.00 ft. Plot North is aligned to TRUE North. 114L2 114L 1 89.07 89.01 . CurveE?615'° ~ ?\. 1\ ()() ~OC 1 51~' 0"'%\Ó A 57>y..P'2-' ..te&\ ,\O? 'I' 320 480 640 Scale 1 cm = 80 ft 800 2880 3040 3200 Top West Sak A2, 7 5/8" Csg. PI. ~r::fj 4160 960 1120 1280 1440 1600 1760 1920 2080 2240 2400 2560 2720 Vertical Section (feet) -> Azimuth 2.29 with reference 0.00 N, 0.00 E from Slot #114 3680 3840 3360 3520 89.07 89.01 . Curve 3/100 EOC 89.07 89.01 TO, 5 1/2in Liner TO 4 1/2in Liner 89.07 1760 1920 2080 2240 2400 2560 Scale 1 cm = 80 ft 2720 2880 3040 3200 3360 3520 3680 3840 4000 4160 4320 4480 4640 4800 Vertical Section (feet) -> Azimuth 2.29 with reference 0.00 N, 0.00 E from Slot #114 4960 5120 5280 5440 · . lE-114Ll Drilling Hazards Summarï 63/4" ODen Hole I 4 1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Risk Level Low ./ Miti ation Strate Stripping drills, Shut-in drills, Increased mud wei ht. Good hole cleaning, PWD Tools, Hole o ener Decreased mud wei ht Reduced urn rates Mud rheolo LCM Trip speeds, Proper hole filling (use of trip sheets ,Pum in out Low Lost Circulation Hole Swabbing on Trips Moderate Low ORIGINAL 1 E-114 Drilling Hazards Summary prepared by Steve Shultz 9/1/2004 4:24 PM Tubing String 4-1/2" 12.6#, L-80, 18TM 3.968" ID, 3.833" Drift KOP: 300', build at 3-6 deg/100' Top of Cement: 6,500' MD Top of Ugnu: +/- 5,925' MD 13-1/2" Hole, 10-3/4" Casing, 4,182' MD, 2,296' TVD ¡lIips West Sak 7..5/8n Injector 1E..114 Tri..Lateral Completion 'D' Sand lateral D-sand Casing Exit 7,492' MD Intermediate and all laterals are to be drilled with Rotary Steerable. 6-3/4" Hole, 4-1/2" Liner Set @ 11,849' MD, 3,574' TVD 8-sand Casing Exit at 7,784' MD Tangent Angle: 70 deg 'B' Sand lateral 6-3/4" Hole, 4-1/2" Liner Set @ 11,864' MD, 3,633 TVD 9-7/8" Hole, 7-5/8" Casing Set @ 8,780' MD, 3,733' TVD 6-3/4" Hole, 4-1/2" Liner Set @ 11,870' MD, 3,808' TVD Eiaker Hugh1}$: 2Q03, This dopumentm<iY not be repnrouçedordì;!õ~rjbuted, in. Whole orin part, In ~nyJorm. Orb}' any means ~leGtrPIl¡PQr rnechardca!, Including ph?tocopying, r¡;çorQin,9, or by .any Date: R.evisionNo· KRU 1E-11 2041720 . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERfP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /<,J?I{ /E-/lt(L ( zocf -' i7Z-- PTD# Development /" Service Exploration Stratigraphic CHECK WßA T ADD-ONS ~'CLUEn APPLIES (OPTIONS) M1JLTI Tbe permit is for a new w~oresegment of LATERAL existing weD ~ I £r /1 _, Permit No,2Pc.¡- l7(API No.5cðZ9'·'2-?.-;!-?-3. ð.... ",' (If API number Production sbould continue to be reported as .... v last two (2) digits a function 'of tbe original API number, stated are between 60-69) above. PILOT HOLE In accordance witb 20 AAC 25.005(f), a1l (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) and API number (SO - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject -to fuD EXCEPTION compliance witb 20 AAC 2S.0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spa cing e:JCeption. (CompanY Name) assumes tbe liability of any prot est to tbe spacing .exception tbat may occur. DRY DITCH AU dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater -tban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and ] 0' sample inter:vals tbrough target zones. Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1E-114L 1 Program SER PTD#: 2041720 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType SER I PEND GeoArea 890 Unit 11160 On/Off Shore On 1 P~rmitfee Qttach~ . . . . . . . . . . . . . . . .NA. .. .... Multilateral weUsegment; fee.wajved per .20 MC 25.005(e) . . . . . . . . . . . . . 2 .LeQs~numberap:!ropriate . . . . . . . . . . . .. ...... y~s . WelJ bore se~m~otJocated jn.AQL.025651, . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 .U.nique welln.am~.and oumb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . 4 WeIlJocat~dinad.efine.dpool. .............. Y~s. . KßUWestSaJeOjIPool.goveroed.by.QonseNationQrder.No,4Q6A........... ...... 5 WelUocated proper .distance from driJling unitb.ound.al)'. . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . . . . 6 Well .located pr.operdistance. from otlJer welJs. . . . . . . . . . . . . . . . . y~s . . 7 .S.ufficient acreQge.avQilable ¡ndJilJiog unjt _ . . . . . . . . . . . . . . . .Yes. . . f\,omioé!1 spaci.ng within the poolis.10 .acres.. 8 Jf.d~viated. js. weJlbore platJncJuded . . . . . . . . . . . . . . . . y~s . . . . . . . . 9 Operator onl}' é!ffeçted Pé!rty. ............ . . . . . . . . . . . . . . . .. .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 .Operator bé!s.appropriate.bond i.nJorce . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . y~s . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 P~rmit c.ao Þe issued wjtbout conserva.tioo order. . . . . . . . . . . . . . . y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Appr Date 12 P~rmit. c.an Þe i.ssued wjtlJout administratilleapproval . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . SFD 9/15/2004 13 Can permit be approved before 15-day wait Yes 14 WelUocated wi.thin QreQ and.strata .authorized by.lojectioo Ord~r # (putlO# incQmm.eots) (For. Y~s. . Area Injection.Order No. 2B. . . . . . . . . . . . . . . 15 .AJlwelJs.wit!1tn1l4.mile.area.ofreyiewjd~otified(Forservjc~welJonl}')..... _......... .Y~s...... .KßU::10-.112.KRU.1P:113..KRU.tQ-116;KßU11;-:lZ3..KRU.tE.-t23I,.t 16 PJe-produ.ced injector; .duration of pn9-productioo less. thQn.:3 montlJs (For.servi.ce well onJy) . . Y~s. . . . WelJ will Þe pre-pro.duc;ed from2to 6 m.ooths.. . 17 ACMPFjodingofCon.si.stenc;yh.as Þeenissued.fortbis pr.oieçt . . . . . . . . . . . . .NA . . . Multilateralwell.bore, . . . . . . . . . . . . . Administration Engineering Appr Date TEM 9/28/2004 ~ Geology Appr SFD Date 9/14/2004 Geologic Commissioner: bTS Well bore seg Annular Disposal ~ - - - - - - - - - - - -- - - - - - - ~ - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 .Condu.ctor st(ingpJovided . . . . . . . . Y~s . . . Conduc:;torseUo motherÞore. !e-.114. . . . . . . . . 19SuúQœ.casingprotectsé!lIknown.USDWs................ .NA.. .. .Allé!quifersexempted.AOCFR147.::1Q21b)(3)............... 20CMTv.olé!dequ.ateto circulate.oncooductor.& su.rf.c¡;g . . . . . . . . . . . . . . . . . Y~s. . . . Surface ca.stng to.b.eœmented tosurfa.ce inmo.theJbore. . . 21 .CMT. vol adequateto tie-i.nJong .string tOSJJrf csg. No . . .,A.I[ hydroCé!rbonzooes.pJanoedlo be covered in.motherbore. . 22CMT. will c:;over.aJl koownpro.ductiye bori¡t;ons. . . . . . . . . . . . . . . . . . . . . . . . . . No. . Slotte.d JioerCOl11plet[on plaoned. . . . . . . . . . . . . 23 .C.asiog designs adeQuate for C,T. B.&. permé!fr.ost. . . . . . . . . . . . .. ..... .Y~s . . . . . .. ...... ........................... 24A.dequate.té!nkage.one.selYe pit . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. y~s . . . . . . . Rig jse.quipped.witb .st~elpjts. . No rese.rve.pjtplanoed, All waste toapprO'le.da[1ouJu.s.or dispo.sal.w.elJs~ . . . 25 Jf.a.re-drill. bé!sa tOAO;3 for abé!ndonment be~o approved.. ...... ....... NA. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 .A.dequate.wellboreseparatjo.n.proposed............ _ . . . . _ . . . . _ . . . . . . . . . . Y~s. . _ . . . . Pro~imi.t}'é!naIY$is pertorme.d, Nearestw~IJb.ore.is mot!1erþore,.,,: t30·t'ld.de~per.. . . . . . . . _ . . . . . . . . . . . 27 Jf.djverterreq.uiJed,doesjtme~treguJatioos. ..................... NA. .. . 60PstackwilJalready.b.eJnplaœ. ....................... ........ 28 .DrilJiog flujdprog.ré!m sc.hematic& eQ.uipJist.adequat~. . . . . . . . . . . . . . . . Y~s . . . . Maximum BHP 8..6- g..O.E.MW. Plaoned mud weigbts 9.3'ppg.. . . . . . . 29 .BOPEs..do.they meetreguJation . . . . . . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . 30 BOPE.Pfessra.tiog approprié!te;.testto(put psig i.n.comments). . . . . . . . . . . . . . . . . . . . .Y~s . . Cé!Ic:;uJa.tedMASP.t246 psi.. 3500 psUest press.ure.appropriate, CPAI.mé!ytesHo.5.00Q psj. . . . . . . 31Chokemé!njfold compJies w/API ßfJ-5:3 (May 84). . . . . . . . . . . . . . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32 Work will oc:;c.ur without.operationsbutdown. . . . . . . . . . . . . . . .Yes.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33 .Is :!resence. of H2S gQs. probaþle . . . . . . . . . . . . . . . . . . . .No . . . WSJs. no!known.to c:;ontainH2S. Rig. is equipped withs~osors and alarmsJ . . . . . . . 34 Mecha.nicalcpodit[onofwells withio AOß verified (for service welJ onJy). . . . . . . . . . y~s . . . Cementiog report.s .0fAQß wells.eXé!mioed, Some operati.oosnot o:!timal. ÞutisolatiOI1 is likely, . . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 35 .P~rmit c.ao Þe issu.ed wlo hydrogen. sulfide meé!SJJre:>. . 36 .D.atapJeseoted on pote.ntial ove.rpres.sure ..zooe.s. . . . . . . 37 .S~ism¡c.a.n..lysjs of :>ballow gé!s.zooes . . . . . . . . .. ............. 38S~abedcondjtioo survey .(if off-shore) . . . . . . . . . 39 . Conta.ct namelphoneJor.weekly progres;sre:!orts [exploratol)' .only] . . . . . . . . . . . . - - - - - - .Y~s. .. . . .. ........ Y~s . . . . . . . Expected r~servojr pre.sSUJe i.s .8,6. -9,0.ppg EMW; wjl.b~dril!eçl wjtb 9.3 ppg mud. . . . . . . . . NA. NA.. NA - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - ~ - - - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: Date Date ì 130 )1-- ~ D . e e e Well Histol)' 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. **** REEL HEADER **** LDWG 05/05/16 AWS 01 **** TAPE HEADER **** LDWG 05/05/16 01 *** LIS COMMENT RECORD . *** . C:<df -17~ fF 1)1;0-- LDWG File Version 1.000 Extract File: LISTAPE.HED !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 3 C. WONG D. GLADDEN MWD RUN 7 7 C. WONG M. THORNTON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # OPEN HOLE BIT SIZE (IN) 42.000 13.500 9.875 6.750 lE-114L1 500292322360 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 16-May-05 MWD RUN 4 4 F. WENDLER P. WILSON MWD RUN 6 6 H. PO M. THORNTON MWD RUN 8 8 G. SUTING D. LOWE MWD RUN 16 11N 10E 98.40 70.40 CASING SIZE (IN) 20.000 10.750 7.625 DRILLERS DEPTH (FT) 148.0 4198.0 7790.0 11841. 0 REMARKS: Tape Subfile: 1 . . PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 18' 2.2151" LONG: W149 DEG 35' 33.3755" LOG MEASURED FROM D. F. AT 98.4 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: 1) Baker Hughes INTEQ runs 1 & 2 utilized an 8" directional only tool to drill from 148 to 4205 feet MD (148 to 2299 feet TVD). 2) Baker Hughes INTEQ run 3 utilized a 6.75" ATK 2.5 with Reservoir Navigation Resistivity (RNT), Gamma Ray, along with Annular Pressure to drill from 4205 to 8741 feet MD (2299 to 3726 feet TVD) . 3) Baker Hughes INTEQ run 5 utilized a 4.75" directional tool with Gamma Ray to set a whipsttock and mill a window in the 7 5/8" casing. 4) Baker Hughes INTEQ runs 6 & 7 utilized a 4.75" Autotrak Generation 3.0 rotary steerable tool to drill from 7809 to 9673 feet MD (3563 to 3589 feet TVD). 5) Baker Hughes INTEQ run 8 utilized a 4.75" directional tool with a Multiple Propagation Resistivity (MPR), Gamma Ray, along with Annular Pressure to drill from 9673 to 11841 feet MD (3589 to 3611 feet TVD) . REMARKS : 1) Depth of 10 3/4" Casing Shoe - Driller: 4198 feet MD (2296 feet TVD). Depth of 10 3/4" casing Shoe - Logger: 4198 feet MD (2296 feet TVD) . 2) Depth of 7 5/8" Casing Window: Top of window: 7778 feet MD (3557 feet TVD) . Bottom of window: 7790 feet MD (3559 feet TVD). 3) Due to the change in resistivity tool type (from RNT in the 9.875" borehole to MPR in the 6.75" borehole) the resistivity presentation goes from 2 curves (RNT: RPD & RPS) to 4 curves (MPR: RPD, RPM, RPS, RPX) at 7790 feet MD (3559 feet TVD). 4) The interval from 11811 to 11841 feet (3609 to 3611 feet TVD) was not logged due to sensor offsets at TD. $ 91 records... Minimum record length: Maximum record length: 8 bytes 132 bytes LDWG .001 **** FILE HEADER **** 1024 *** LIS COMMENT RECORD !!!!!!!!!!!!!!!!!! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: *** LDWG File Version 1.000 Extract File: FILE001.HED 1 and clipped curves; all bit runs merged. .5000 . . # FILE SUMMARY PBU TOOL CODE MWD $ START DEPTH 4198.0 STOP DEPTH 11841. 0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO 3 6 7 8 MERGE TOP 4198.0 7790.0 9193.0 9659.0 MERGE BASE 7790.0 9193.0 9659.0 11841. 0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. Note: Due to the change in resistivity tool type (from RNT in the 9.875" borehole to MPR in the 6.75" borehole) the resistivity curves RPM & RPX are null in the 9.875" hole section above 7790' (MWD Run 3). $ # *** INFORMATION TABLE: CONS MNEM VALU --------------------------------~--- WDFN LCC CN WN FN COUN STAT le-114Ll 5.xtf 150 ConocoPhillips Alaska, Inc. lE-114Ll Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 ROP ROP ROPA 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME . Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 ------- 28 Total Data Records: 494 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 4198.000000 11841.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 542 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!! !!!!!!!!! LDWG File Version 1.000 ! !!!!!!!! !!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 . log header data for each bit run in separate files. 2 .2500 START DEPTH 4150.0 STOP DEPTH 7790.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: 01-0CT-04 MSB 18704 6.75 ATK MEMORY 8741. 0 4150.0 7790.0 o 66.5 . MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PRES DIR RNT GRAM $ BOTTOM) TOOL TYPE PRESSURE DIRECTIONAL RES. NAVIG. GAMMA RAY RES. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (ORMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 80.2 TOOL NUMBER 100009727 10035313 1127 1127 9.625 4198.0 F.W. Spud 9.15 .0 .0 200 .0 .000 .000 .000 .000 108.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWD Run 3). RNT/GR. The bottom of the 7 5/8" casing window was at 7790 feet MD on this MWD run. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-114L1.xtf 150 ConocoPhillips Alaska, I lE-1l4Ll Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPCH ROPA RPTH GRAM RPCL RPCH ROPA RPTH GRAM RPD RPS ROPA RPTHM 0.0 0.0 0.0 0.0 0.0 . . * FORMAT RECORD (TXPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 ROPA MWD 68 1 FPHR 4 4 5 RPTH MWD 68 1 MINS 4 4 ------- 20 Total Data Records: 347 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 4150.000000 7790.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 430 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD 3 log header data for each bit run in separate files. 6 .2500 START DEPTH 7790.0 STOP DEPTH 9193.0 . $ # LOG HBADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR PRES GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. PRESSURE GAMMA RAY RES. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 11-0CT-04 MSB 18704 4.75 ATK MEMORY 9207.0 7790.0 9193.0 o 89.1 89.9 TOOL NUMBER 10119900 10119900 10119900 10119900 6.750 7790.0 OBM 9.30 .0 .0 62000 .0 .000 .000 .000 .000 109.0 .0 .0 .0 .00 .000 .0 o BIT RUN 6 (MWD Run 6). MPR/GR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN 1e-1l4L1.xtf 150 ConocoPhillips Alaska, I 1E-1l4L1 . . FN COUN STAT Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP -~-------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 182 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7790.000000 9193.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 267 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 . 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!! !!!!!!!! !!!!! Extract File: FILE013.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 4 . log header data for each bit run in separate files. 7 .2500 START DEPTH 9193.0 STOP DEPTH 9659.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR PRES GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RES. PRESSURE GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: BIT RUN 6R (MWD Run 7). MPR/GR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) 11-0CT-04 MSB 18704 4 . 75 ATK MEMORY 9673.0 9193.0 9659.0 o 89.1 89.9 TOOL NUMBER 10118252 10118252 10118252 10118252 6.750 7790.0 OBM 9.30 .0 .0 55000 .0 .000 .000 .000 .000 105.0 .0 .0 .0 .00 .000 .0 o . . ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-I14Ll.xtf 150 conocoPhillips Alaska, I lE-114Ll Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 61 Tape File Start Depth 9193.000000 . . . Tape File End Depth Tape File Level Spacing Tape File Depth Units 9659.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 146 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .005 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!! !!!!!!! LDWG File Version 1.000 !!!!!!!!!!! !!!! !!!! Extract File: FILE014.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 5 log header data for each bit run in separate files. 4R .2500 START DEPTH 9659.0 STOP DEPTH 11841. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 13-0CT-04 MSB 18704 4.75 MPR MEMORY 11841. 0 9673.0 11841.0 o 86.8 89.1 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM PRES $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RES. GAMMA RAY PRESSURE TOOL NUMBER 10104208 6032 5058 10064654 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.750 7790.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): OBM 9.30 .0 .0 58000 .0 .. . . RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .000 .000 105.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 4R (MWÐ Run 8). MPR/GR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWÐ-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1e-114Ll. xtf 150 ConocoPhillips Alaska, I 1E-114L1 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F . . . 7 Curves: Name Tool Code samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 282 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 9659.000000 11841. 000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 6 367 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 05/05/16 01 **** REEL TRAILER **** LDWG 05/05/16 AWS 01 Tape Subfile: 7 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes